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Home My WebLink About200-192David Douglas Hilcorp Alaska, LLC 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 or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 10 50133204820000 200192 2/25/2021 PERF GAMMA RAY/GPT Yellowjacket BCU 10 50133204820000 200192 3/2/2021 SET PLUG/GPT Yellowjacket BCU 10 50133204820000 200192 3/9/2021 PERF Yellowjacket BCU 01B 50133200060100 214001 4/2/2021 PERF GAMMA RAY Yellowjacket Please include current contact information if different from above. PTD: 2001920 E-Set: 35171 06/01/2021 David Douglas Hilcorp Alaska, LLC 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 or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 10 50133204820000 200192 2/25/2021 PERF GAMMA RAY/GPT Yellowjacket BCU 10 50133204820000 200192 3/2/2021 SET PLUG/GPT Yellowjacket BCU 10 50133204820000 200192 3/9/2021 PERF Yellowjacket BCU 01B 50133200060100 214001 4/2/2021 PERF GAMMA RAY Yellowjacket Please include current contact information if different from above. PTD: 2001920 E-Set: 35170 06/01/2021 David Douglas Hilcorp Alaska, LLC 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 or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 10 50133204820000 200192 2/25/2021 PERF GAMMA RAY/GPT Yellowjacket BCU 10 50133204820000 200192 3/2/2021 SET PLUG/GPT Yellowjacket BCU 10 50133204820000 200192 3/9/2021 PERF Yellowjacket BCU 01B 50133200060100 214001 4/2/2021 PERF GAMMA RAY Yellowjacket Please include current contact information if different from above. PTD: 2001920 E-Set: 35169 06/01/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,854 feet 5448, 5515, 6838 feet true vertical 8,560 feet N/A feet Effective Depth measured 5,413 feet N/A feet true vertical 5,121 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)N/A; N/A N/A; N/A N/A; N/A N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 3,450psi 10,160psi 113' 2,329'6,430psi Collapse 1,950psi 3,830psi 10,540psi Casing Structural 13-3/8" 7" Length 113' 2,374' 8,817' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 890 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-080 108 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 910 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-192 50-133-20482-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 400 Beaver Creek Unit (BCU) 10 N/A FEDA028083 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek Unit / Sterling GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 3-1/2"8,817'8,523' WINJ WAG 0 Water-Bbl MD 113' 2,374' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:56 pm, May 19, 2021 gg Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.19 15:15:42 -08'00' Taylor Wellman (2143) DSR-5/19/21 RBDMS HEW 5/20/2021 SFD 5/21/2021BJM 9/27/21 Rig Start Date End Date 2/25/21 5/10/21 Travel to location. Contact DSO, Fill out PTW, PJSM,. Make up 5' 2-3/8" HSC, 5 spf, 60° phase, 11gram gun, Stab on well, Open well, WHP 1,675 PSI. RIH. Tag at 5,481', log up to 5,050', send log to town for correlation. Got approal to shoot 5,467'-5,472' ( Ben Siks), RIH tag 5,481', log up getting on CCL depth 5,457.5', CCL t/top shot 9.5', CCL t/bottom shot 14.5', wHP 1,640psi, IA 950, No change in WHP. Did not get any indication gun fired. POOH to inspect tools. Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Bleed N2 off to tank. Started to get LEL's, Shut in flow to tank. Make up Gun #2, 2-3/8", 5', 5 spf, 60* phase 11 gram gun. Make up Gun #2, 2-3/8", 5', 5 spf, 60* phase 11 gram HSC gun. Stab on well, Open up, RIH. Tag at 5,448', log up to 5,050', send log to town for correlation. While waiting for tie in we lost 8 more feet of hole. Standing by to find out what zone we're gonna shoot next. RIH, tag again, tagged at 5,436'. Decision made to pooh and rig down. POOH, Tagged up, swab shut, bleed down, Pop off well. RDMO Yellow Jacket Eline. 02/25/2021 - Thursday Travel to location. Check in, Fill out PTW, PJSM, inspect location. Spot equipmet. MIRU Yellow Jacket Eline. Make up GR/CCL, test wire, good test. Make up 7' wt bar, GPT, Setting tool and 3.5" CIBP. CCL T/Mid Element 16.5', Stab on well, PT low/high 250/3,500. Good test. Open well, Swab 23 turns, T/I/O= 1,100/920/na. RIH. Fluid level at 3,700', come online with N2 at 1,000 scfm. WHP 1,250 @ 1,000 scfm. Pump for 30 min, shut down. Offline with N2, RIH to find fluid top. Fluid level is 5,560'. Pull log up to 5,050'. Send log to town for correlation. Make +5' correction. Thumbs up to set plug ( Jeff Nelson). RIH to 5,520', PU getting on CCL depth @ 5,498.5'. CCL to Mid element 16.5'. Set plug at 5,515'. POOH, tagged up, swab shut, bleed down, pop off well, Setting tool look's good. Rig down setting tool.Make up 35', 2" bailer. MIx up 6.5 gal of 16ppg class G cement. Stab on well, Open up, RIH. Lightly tag plug at 5,515', pu get wt back. Park and dump 6.5 gal on plug. Wait 10-15min, POOH. Make up 35', 2" bailer. MIx up 6.5 gal of 16ppg class G cement. Stab on well, Open up, RIH. Lightly tag plug at 5,515', pu get wt back. Park and dump 6.5 gal on plug. Wait 10-15min, POOH. Tagged up, swab shut, bleed down, pop off well. Wires hanging out end of bailer. Check for fire, good test. Mix up another 6.5 gallons 16 ppg cement. load 35', 2" Bailer. Stab on well, Open well. RIH to 5,480' Fire cap off, let cement fall out for 15 min. POOH. Cement Top is +/-5,480. Let cement cure over night. Job in progress. 02/26/2021- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-10 50-133-20482-00-00 200-192 Park and dump 6.5 gal on plug. Mix up another 6.5 gallons 16 ppg cement. dump 6.5 gal on plug. Set plug at 5,515' RIH. Tag at 5,481', Cement Top is +/-5,480. o shoot 5,467'-5,472' ( Rig Start Date End Date 2/25/21 5/10/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-10 50-133-20482-00-00 200-192 03/02/2021 - Tuesday Travel to location. Arrive on locaiton, Contact DSO, PTW, PJSM. Spot equipment, MIRU Yellow Jacket Eline, Make up GR/CCL, test wire. Good test. Make up 3.5" CIBP, Stab on well, Wait on Fox energy to rig up and cool down N2, PT WLV/LUB low/high 250/3,500. Open well, swab 23, WHP 100, RIH, Found fluid at 775'. Come online with N2 at 1,000 scfm, WHP worked its way up to 3,500 psi. Could not inject into formation. POOH with Eline. Tagged up, swab shut, bleed down, pop off well. Cap the riser with night cap. Got okay to try and inject at into formation at 4,000psi. No luck. Bleed down WHP to 1,500. Shut well in, Make up bullnose on bottom of wt bar. Stab back on well with Eline. Open up, RIH. Tag at 5,445' ELM. About 35' of fill over perfs. POOH. Tagged up, swab shut, bleed down, pop off well. Stack back Eline, Standby for Slickline crew to arrive. Slickline on location, PTW, PJSM, MIRU Pollard Slickline unit. Make up lubricator, stab wire, Make up 6' 2.25" pump down bailer. Stab on well, pt low/high 250/1,500. Open well, RIH. Tag at 5,445' Bail for 15 min, POOH, OOH with empty bailer, Looks like Hydrates in and on the bailer. Make up 2.80" gauge ring. Stab on well, open up, RIh. Tag at 775', 810', 834', possibly ice starting to build up here. Worked through these spots clean. CTRIH, Tag at 5,445'. Work gauge ring, POOH. Tagged up, swab shut, bleed down, pop off well. Gauge ring was clean. Make up 4' X 2.5" DD bailer. RIH with DD bailer, Tag at 5,445' work Bailer for 20 min, POOH, OOH swab shut, bleed down, pop off well. Bailer had about 1/2 cup formation sand and mud. Stab back on well with 2.5" DD bailer. Open well, RIH. WHP 1,200 psi, Tag at 5,445', Work DD bailer down to 5,447', POOH, Bailer about half full formation sand and mud. Stab back on with 4' X 2.25" DD bailer. Open well. RIH, Tag at 5,447', Work 2.5" DD bailer. Made 1' on SL counter. POOH, OOH, Swab shut, bleed down, pop off well. Bailer full with mud and fine formation sand. Take off DD bailer, Make up 6' X 2.25" Pump Bailer. Stab on well. Open well, RIH. Tag at 5,447', work wire for 20 min, POOH, OOH tagged up, swab shut, bleed down, pop off well. Bailer empty. Stack down for the night. Job in progress. 03/03/2021 - Wednesday Travel to location. Arrive on location, get PTW, PJSM with crew. Fire up equipment, Let it warm up, Make up 2.25" X 6' Pump bailer. Stab on well, Open up, RIH, Tag at 5,440', Bail for 20 min, POOH, OOH tagged up, swab shut, bleed down, pop off well. Bailer empty. Make up 2.25" x 6' DD bailer, Stab on well, Open well, RIH, Bleed whp down another 200 psi, Bail for 30 min, POOH, OOH, swab shut, bleed down, pop off well, Bailer empty. Swap out Bailer with 1.75" X 4' DD bailer, Stab on well. Open well, RIH.Tag at 5,440'. Drive down 4', POOH, OOH, swab shut, bleed down, pop off well. bailer was packed off at the bottom. Break off 1.75" bailer, Make up 2" X 4' DD bailer. Stab on well, Open well, RIH, Tag at 5,448', Bail down to 5,452', POOH, OOH swab shut, bleed down, pop off well. Bailer half full silt and mud. Stab back on, RIH with same. Tag at 5,452' Bail for 20 min, POOH, OOH tagged up swab shut, bleed down, pop off well, 3/4 full bailer. formation sand. Stab back on, RIH with same. Tag at same, bail for 30 min, POOH, OOH, swab shut, bleed down, pop off well. Bailer packed with formation sand and fluid, Stab back on well, RIH with same. OOH 3/4 bailer full, RIH with same, Bail for 30 min, POOH, OOH bailer 1/4 full, Stab back on well, RIH w/same. Bail for 20 min, POOH, OOH 3/4 bailer full, Lay down and cut wire. RDMO Slickline. Job in progress. Rig Start Date End Date 2/25/21 5/10/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-10 50-133-20482-00-00 200-192 05/10/2021 - Monday HES e-line arrives at office and obtains permit to work. Rig up and begin mixing cement. Load dump bailer in lubricator and PT to 250 psi low / 3,500 psi high. Good test. RIH with CH/WB/CCL/ 40' of 2.5" dump bailer. Sit down on existing cement top @ 5,430.5'. Pull up 20 and dump cement. POOH inspect bailer, good dump. New TOC is 5,413'. RDMO HES e- line. 03/09/2021 - Tuesday Yellow Jacket E-line hold JSA and approve PTW. MIRU. MU GR/CCL and 2-3/8" x 4' long perf gun. PT lubricator to 250/3,500 psi. RIH. Log up for correlation pass and have a large gamma ray spike ~ 5,350'. Make several other passes and gamma ray spike repeats. POOH and change out GR/CCL. RIH with GPT and find GR spikes again ~ 5,350', which is also fluid depth. Appears GR spike due to fluid level. Send correlation data to Geo, confirm on depth with 2-3/8" x 4' gun, razor charges, 60 deg phasing, 5 spf. Perforate 5,408 - 5,412'. Initial pressure = 1,050 psi, 5 min press = 1,050 psi, 10 min press = 1,050 psi, 15 min press = 1,050 psi. Confirm shots fired, small amount of fluid in perf gun bull plug. Hand well over to operations. RDMO. 04/04/2021 - Sunday OE had discussion with RE and Geologist about feasibility of evacuating water from well and perforating an additional 2' of the B3B sand. Economics did not pass the test so this Sundry will be closed. 03/04/2021 - Thursday Travel to location. Arrive on location, Contact DSO, PTW, PJSM. Fire up equipment, Make up GR/CCL with bullnose for drift/tag run. Stab on well, Open well, RIH. Tag at 5,448.5', pull log up to 5,150'. Send log to town for correlation. On depth per Ben Siks. POOH, OOH break off drift bha, Make up 3.5" CIBP (2.75" X .5'), Stab on well, Open well, WHP 100, IA 900,. RIH, Tag @ 5,448', pu getting on ccl depth 5,431.5', CCL t/Mid element 16.5'. Set plug at 5,448'. POOH, OOH, swab shut, bleed down, pop off well. Make up 30' X 2" bailer. Mix up 6.5gal 16ppg class G cement. Load bailer, stab on well, Open well. RIH, Lightly tag plug at 5,448', PU, stop when we got wt back. Dump 6.5gal (17.5') 16ppg cement on plug. CMT top 5,430.5' +/-. POOH, OOH bailer empty. RDMO Yellow Jacket Eline. Well ready to be swabbed. Perforate 5,408 - 5,412' New TOC is 5,413'. Dump 6.5gal (17.5') 16ppg cement on plug. CMT top 5,430.5' Set plug at 5,448' Lease: State/Prov:Alaska Country:USA Angle/Perfs:0ºĺ2º 158' 21' 2/3/2015 5/12/2021 RKB (above GL):04/13/01 Schematic Revision Date: Kenai Peninsula Borough 3.0º / 100 ft @ 1,250'Maximum Deviation:28º @ 3,708' A - 028083 Revised By:Donna Ambruz Downhole Revision Date: Well Name & Number: County or Parish: Beaver Creek Unit #10 Date Completed:Ground Level (above MSL): Angle @KOP and Depth: TD MD: 8,854' TVD: 8,560' Conductor 13-3/8" K-55 68 ppf Top Bottom MD 0' 113' TVD 0' 113' Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' 8-1/2" hole cmt w/ 350 sks plus 156 sks top-job Permit #:200-192 API #:50-133-20482-00 Property Des:A - 028083 KB Elevation:179' (21' AGL) Spud Date:3/26/2001 TD Reached:4/08/2001 Lat:60°39' 31.42" N Long:151°1' 5.15" W BC-10 Pad 3 943' FNL, 2,958' FWL, Sec. 34, T7N, R10W, S.M. PBTD MD: 5,431' TVD: 5,139' Perforations: Sterling B-3B 5,408'- 5,412' (3/9/21) Open B-4 5,467'-5,472' (2/26/21) Isolated B-4 5,535'-5,550' (7/06/14) Isolated Lower Beluga 2-1/2" HSD 6spf, 60 deg, 10.7 gm PJ2506 MD LB-16 7,400’-7,413’ (10/2/01) Isolated LB-17 7,507’-7,527’ (10/2/01) Isolated LB-18L 7,595'-7,602' (5/22/02) Isolated LB-19 7,650'-7,658' (5/22/02) Isolated LB-19L 7,683'-7,692' (5/22/02) Isolated LB-20 7,717’-7,737’ (10/2/01) Isolated LB-20L 7,758’-7,778’ (10/2/01) Isolated LB-21 7,828’-7,848’ (10/2/01) Isolated LB-21 7,833'-7,853' (5/22/02) Isolated LB-22 7,927’-7,966’ (10/2/01) Isolated LB-22L 7,996'-8,001' (5/22/02) Isolated LB-24 8,085’-8,100’ (10/2/01) Isolated LB-28 8,257'-8,277' (12/3/01) Isolated LB-28L 8,334'-8,354' (12/3/01) Isolated LB-30 8,530'-8,545' (11/30/01) Isolated LB-31 8,634'-8,654' (11/29/01) Isolated 2.813" Otis X Nipple @ 7,182' Sidepocket Chemical Injection Mandrel 2.992" ID @ 1,209' 1/4" OD, 0.049" wall SS control line loaded w/ 1" double-check injection TOC 3-1/2" Csg 4,142' (CBL 4/28/14) SCHEMATIC Production Casing 3-1/2" L-80 9.3 ppf EUE-Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' 6-1/8" hole cmt w/ 125 sks (47 bbl) of 12.5 ppg Lead Cement and 500 sks (105 bbl) of 15.7 ppg Tail Cement Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD Damaged Pipe @ 7,820' (Cannot pass 2.40" Swedge) Tree cxn: 6-1/2" Otis LB-16 LB-17 LB-18L LB-20 LB-20L LB-21 LB-24 LB-28 LB-28L LB-30 LB-31 Capillary Tubing 3/8" 2205 Stainless Steel Top Bottom MD 0' 0' TVD 0' 0' (***Pulled 02/14/2013***) Tag @ 8,700' CTM (9/02/13) 1.75" Coil Tubing Jet Nozzle Magna Range Plug @ 8,207' MD Capped w/ 8' of cement LB-22 LB-22L LB-19 LB-19L Cement Plug Top @ 6,838' SLM Tag @ 6,362' SLM (02/03/15) 2.75" Gauge Ring CIBP @ 5,515' w/ 35' cement -TOC @ 5,480' 2/25/21 CIBP @ 5,448' w/ 35' cement -TOC @ 5,413' 5/10/21 B-4 B-4 B-3B gSterling (3/9/21) Open 5,408'- 5,412'B-3B Sterling ()p 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: N2 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): 8,854'N/A Casing Collapse Structural Conductor 1,950psi Surface 3,830psi Intermediate Production 10,540psi 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 Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 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 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. Authorized Signature: February 20, 2021 N/A 8,817' Perforation Depth MD (ft): See Attached Schematic 8,817' 8,523'3-1/2" 13-3/8" 7" 113' 2,374' 3,450psi 6,430psi 113' 2,329' 113' 2,374' N/A TVD Burst N/A 10,160psi MDLength Size CO 237A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 200-192 50-133-20482-00-00 Beaver Creek Unit (BCU) 10 Beaver Creek Unit / Sterling Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 8,560'6,838'6,545'1,683 6,838' N/A N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:50 am, Feb 12, 2021 321-080 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.02.11 23:03:58 -09'00' Taylor Wellman (2143) GLS 2/15/21 SFD 2/16/2021 GAS r: N2 10-404 Plug Perforations SFD 2/16/2021 Perforate 237B DSR-2/16/21Comm. 2/16/21 dts 2/16/2021 JLC 2/16/2021 RBDMS HEW 2/17/2021 Well Prognosis Well: BCU-10 Date: 2/3/2021 Well Name: BCU-10 API Number: 50-133-20482-00-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: 2/10/2021 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-192 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max Expected BHP: ~2200 psi @ 5174’ TVD Based on actual reservoir conditions Max Expected WHP: ~1683 psi Based on expected BHP minus 0.1 psi/ft gas gradient Brief Well Summary BCU-10 drilled and completed in 2001 targeting the lower Beluga formations. This well was completed as a 3- 1/2” monobore to surface. 16 Lower Beluga sands were perforated within the first 6 months of production with peak rates hovering around 11-12 MMCFD. A few coil tbg cleanouts over the course of the next 12 years helped sustain the decline – until the well finally succumbed to water and solids in 2013. The lower 4 sands were isolated in September of 2013. The well would not come back around. Suspected casing damage was thought to be the culprit. In July 2014, all of the lower beluga sands were isolated and the Sterling B4 was added and came online making 2.5 MMCFD and soon water broke through. Eventually, it loaded up and died in 2015. The objective of this work is to plug back the existing Sterling B4 perforations and add more uphole Sterling pay. Notes Regarding Wellbore Condition x Minimum ID is 3.5” casing: 2.992” x Last tag fill 2/3/15 @ 6363’ RKB w/ 2.75” gauge ring x Fluid level last recorded at 1700’ Slickline Procedure 1. Drift to PBTD with BHA including 2.80” gauge ring and sample bailer. 2. Record fluid level. If unable to determine with drift run make a blind box run. E-line Procedure: 1. MIRU E-line and pressure control equipment, PT lubricator to 250 psi low & 3500 psi high. 2. MIRU Nitrogen unit. a. Ensure that standard nitrogen SOP is reviewed during PJSM. 3. RIH with toolstring including GPT, setting tool and 3.5” CIBP. 4. Depress fluid level with nitrogen into the open perfs from 5535’-5550’. 5. Set CIBP at 5515’. 6. RIH with cement dump bailer and dump 35’ (13 gallons) of cement. 7. Bleed WHP down to 1500 psi. 8. Perforate the following intervals with 2-3/8” HSC guns loaded at 5 SPF: (isolate B4 sands) (B4 perfs) Well Prognosis Well: BCU-10 Date: 2/3/2021 Sterling Sand Top MD Bottom MD Total Top TVD Bottom TVD B1X ±5183’ ±5215’ 32’ ±4893’ ±4925’ B1 ±5239’ ±5271’ 32’ ±4948’ ±4980’ B3B ±5408’ ±5417’ 9’ ±5116’ ±5125’ B3B ±5427’ ±5446’ 19’ ±5135’ ±5154’ B4 ±5467’ ±5487’ 20’ ±5174’ ±5194’ a. Final perforation intervals will be provided prior to loading guns for exact depths. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. 9. RD E-line. 10. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Standard Nitrogen Procedure Sterling Perfs Lease: State/Prov:Alaska Country:USA Angle/Perfs:0ºĺ2º 158' 21' 2/3/2015 2/4/2015 RKB (above GL):04/13/01 Schematic Revision Date: Kenai Peninsula Borough 3.0º / 100 ft @ 1,250'Maximum Deviation:28º @ 3,708' A - 028083 Revised By:Stan Porhola Downhole Revision Date: Well Name & Number: County or Parish: Beaver Creek Unit #10 Date Completed:Ground Level (above MSL): Angle @KOP and Depth: TD MD: 8,854' TVD: 8,560' Conductor 13-3/8" K-55 68 ppf Top Bottom MD 0' 113' TVD 0' 113' Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' 8-1/2" hole cmt w/ 350 sks plus 156 sks top-job Permit #: 200-192 API #: 50-133-20482-00 Property Des: A - 028083 KB Elevation: 179' (21' AGL) Spud Date: 3/26/2001 TD Reached: 4/08/2001 Lat: 60° 39' 31.42" N Long: 151° 1' 5.15" W BC-10 Pad 3 943' FNL, 2,958' FWL, Sec. 34, T7N, R10W, S.M. PBTD MD: 8,754' TVD: 8,460' Perforations: Sterling B-4 5,535'-5,550' (7/06/14) 12 spf 2-1/2" HSD 6spf, 60 deg, 10.7 gm PJ2506 MD LB-16 7,400’- 7,413’ (10/2/01) LB-17 7,507’- 7,527’ (10/2/01) LB-18L 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19L 7,683'- 7,692' (5/22/02) LB-20 7,717’- 7,737’ (10/2/01) LB-20L 7,758’- 7,778’ (10/2/01) LB-21 7,828’- 7,848’ (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-22 7,927’- 7,966’ (10/2/01) LB-22L 7,996'- 8,001' (5/22/02) LB-24 8,085’- 8,100’ (10/2/01) LB-28 8,257'- 8,277' (12/3/01) LB-28L 8,334'- 8,354' (12/3/01) LB-30 8,530'- 8,545' (11/30/01) LB-31 8,634'- 8,654' (11/29/01) 2.813" Otis X Nipple @ 7,182' Sidepocket Chemical Injection Mandrel 2.992" ID @ 1,209' 1/4" OD, 0.049" wall SS control line loaded w/ 1" double-check injection TOC 3-1/2" Csg 4,142' (CBL 4/28/14) ACTUAL SCHEMATIC Production Casing 3-1/2" L-80 9.3 ppf EUE-Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' 6-1/8" hole cmt w/ 125 sks (47 bbl) of 12.5 ppg Lead Cement and 500 sks (105 bbl) of 15.7 ppg Tail Cement Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD Damaged Pipe @ 7,820' (Cannot pass 2.40" Swedge) Tree cxn: 6-1/2" Otis LB-16 LB-17 LB-18L LB-20 LB-20L LB-21 LB-24 LB-28 LB-28L LB-30 LB-31 Capillary Tubing 3/8" 2205 Stainless Steel Top Bottom MD 0' 0' TVD 0' 0' (***Pulled 02/14/2013***) Tag @ 8,700' CTM (9/02/13) 1.75" Coil Tubing Jet Nozzle Magna Range Plug @ 8,207' MD Capped w/ 8' of cement LB-22 LB-22L LB-19 LB-19L Cement Plug Top @ 6,838' SLM B-4 Tag @ 6,362' SLM (02/03/15) 2.75" Gauge Ring Fluid Level 1,700' Lease: State/Prov:Alaska Country:USA Angle/Perfs:0ºĺ2º 158' 21' 2/3/2015 1/28/2021Revised By:T. Hallett Downhole Revision Date: Well Name & Number: County or Parish: Beaver Creek Unit #10 Date Completed: Ground Level (above MSL): Angle @KOP and Depth: Kenai Peninsula Borough 3.0º / 100 ft @ 1,250'Maximum Deviation:28º @ 3,708' A - 028083 RKB (above GL):04/13/01 Schematic Revision Date: TD MD: 8,854' TVD: 8,560' Conductor 13-3/8" K-55 68 ppf Top Bottom MD 0' 113' TVD 0' 113' Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' 8-1/2" hole cmt w/ 350 sks plus 156 sks top-job Permit #:200-192 API #:50-133-20482-00 Property Des:A - 028083 KB Elevation:179' (21' AGL) Spud Date:3/26/2001 TD Reached:4/08/2001 Lat:60° 39' 31.42" N Long:151° 1' 5.15" W BC-10 Pad 3 943' FNL, 2,958' FWL, Sec. 34, T7N, R10W, S.M. PBTD MD: 8,754' TVD: 8,460' Perforations: Sterling B1X ±5,183' - ±5,215' (32') TBD Proposed Sterling B1 ±5,239' - ±5,271' (32') TBD Proposed Sterling B3B ±5,408' - ±5,417' (9') TBD Proposed Sterling B3B ±5,427' - ±5,446' (19') TBD Proposed Sterling B4 ±5,467' - ±5,487' (20') TBD Proposed Sterling B-4 5,535'-5,550' (7/06/14) 12 spf 2-1/2" HSD 6spf, 60 deg, 10.7 gm PJ2506 MD LB-16 7,400’- 7,413’ (10/2/01) LB-17 7,507’- 7,527’ (10/2/01) LB-18L 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19L 7,683'- 7,692' (5/22/02) LB-20 7,717’- 7,737’ (10/2/01) LB-20L 7,758’- 7,778’ (10/2/01) LB-21 7,828’- 7,848’ (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-22 7,927’- 7,966’ (10/2/01) LB-22L 7,996'- 8,001' (5/22/02) LB-24 8,085’- 8,100’ (10/2/01) LB-28 8,257'- 8,277' (12/3/01) LB-28L 8,334'- 8,354' (12/3/01) LB-30 8,530'- 8,545' (11/30/01) 2.813" Otis X Nipple @ 7,182' Sidepocket Chemical Injection Mandrel 2.992" ID @ 1,209' 1/4" OD, 0.049" wall SS control line loaded w/ 1" double-check injection TOC 3-1/2" Csg 4,142' (CBL 4/28/14) PROPOSED Production Casing 3-1/2" L-80 9.3 ppf EUE-Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' 6-1/8" hole cmt w/ 125 sks (47 bbl) of 12.5 ppg Lead Cement and 500 sks (105 bbl) of 15.7 ppg Tail Cement Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD Damaged Pipe @ 7,820' (Cannot pass 2.40" Swedge) Tree cxn: 6-1/2" Otis LB-16 LB-17 LB-18L LB-20 LB-20L LB-21 LB-24 LB-28 LB-28L LB-30 LB-31 Capillary Tubing 3/8" 2205 Stainless Steel Top Bottom MD 0' 0' TVD 0' 0' (***Pulled 02/14/2013***) Tag @ 8,700' CTM (9/02/13) 1.75" Coil Tubing Jet Nozzle Magna Range Plug @ 8,207' MD Capped w/ 8' of cement LB-22 LB-22L LB-19 LB-19L Cement Plug Top @ 6,838' SLM B-4 Tag @ 6,362' SLM (02/03/15) 2.75" Gauge Ring Sterling B sands CIBP @ ±5,515' w/ 35' cement Sterlingg B sands X ±5,183' - ±5,215' (32') TBD Proposedg,,()g 8 (Sterling B1X ±5,183' - ±5,215' (32') TBD Progo8(g,,()gggg g B1Sterlingg () p,(,(,,() (32') TBD Proposed9' - ±5,271'±5,23 o9(() p,g,gg ( (9') TBD Proposed8' - ±5,417'g B3B ±5,40Sterlingg r0() p,g,gg g B3B ±5,427' - ±5,446' (19') TBD Proposed7' - ±5,446' (SterlingSt li B3B 5 427' 5 446' (19') TBD Pgr2(St li B3B ±5 427' ±5 446' (19') TBD Pggg g B4SterlinggSterling B4gSterling B4 () p,(,( (20') TBD Proposed7 - ±5,487±5,46±5 467' ±5 487' (20') TBD Pro7(±5 467 ±5 487 (20) TBD Pro STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard 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 Transport. 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 Nitrogen vendor 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 Transport. Imasa Project Well History File Cove, Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- 0 O' I ~ & Well History File Identifier Organizing Ido,,',;I [] RESCAN Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL ~)NINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL ~~JVINDY Scanning Preparation L~ x 30 = BY: BEVERLY ROBIN VINCENT SNERYL~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: _) ~/j PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ,' ~"' "'~'"' DATE' '' Stace 2 IF No IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY:, BEVERLY~INOEN, SHERYL MARIA WINDY DATE~/-/~.A¢ 'S~~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDI~DUAL PAgE DUE TO QUALITY, G~YSCALE OR COLOR I~AGE8 ) NO ' NO RESCANNEDB?: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd E� � I/7%oma YiA �� /, 7 A (7` 7,7- ,T\ ilift: L� F 3 j3 West Sevent,- Avenue ' GOV'LR OR SEAN PARNL LL Anchorage A'cska 295C-3572 Vr Mc 9O/.2i 9 14 3 A LA.e. _;h. Iii/.2%6./J4! Stan Porhola SCANNED JUL 16 2014 Operations Engineer q D 0 - l9 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 10 Sundry Number: 314-338 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /a)i,G51 I w Cathy P. oerster Chair DATED this 2 day of June, 2014. Encl. . . RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 9 2014 APPLICATION FOR SUNDRY APPROVALS 4'TS(Gfit/14. 20 MC 25.280 AOGCC 1 CC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations El • Perforate❑., . Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Atter Casing❑ Other. Coiled Tubing Plugback 0• 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development Q• 200-192 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20482-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237 Beaver Creek Unit(BCU)10. Will planned perforations require a spacing exception? Yes ❑ No 0❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 Beaver Creek Unit/Beluga Gas 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): 8,854 ` 8,560 • 8,754 8,460 N/A N/A Casing Length Size MD TW Burst Collapse Structural Conductor 113' 13-3/8" 113' 113' 3,450 psi 1,950 psi Surface 2,374' 7" 2,374' 2,329 6,430 psi 3,830 psi Intermediate Production 8,817' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program [—I BOP Sketch n Exploratory IT Stratigraphic❑ Development[r] Service 11 14.Estimated Date for 15.Well Status after prorosed work: 06/04/14 Commencing Operations: Oil ❑ Gas 2 ' WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email sDorholaehilcorD.com Printed Name Stan Porhola Title Operations Engineer 5/"1/64 Signature !° Phone 907-777-8412 Date J 2 1/64 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. c-1___ 3�`�333 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required: / Ls -y c `/ 7 APPROVED BY Approved by: e...1,47 COMMISSIONER THE COMMISSION Date: G -2 -/ �'�� ,� ! Submit Form and Form 10-403(Revised 10i2012 Approve a ©©ti ,(r v li Qr nths from the date of approval. ! Attachments in ou licate JUN -216- RBEMS014Y\ laR v `� pp b s-,3U / Well Prognosis . . Well: BCU-10 Hilcorp Alaska,Lb Date:5/28/2014 Well Name: BCU-10 API Number: 50-133-20482-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: June 4th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 200-192 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,075 psi @ 8,106' ND (Flowing survey Sept 2010 mid pert 8,400' MD) Maximum Expected BHP: —2,075 psi @ 8,106' ND (Flowing survey Sept 2010 mid perf 8,400' MD) Max.Allowable Surface Pressure: — 1,265 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#10 was drilled as a Grass roots gas well with a 3-1/2" monobore design in 2001.The well was completed in the Lower Beluga intervals in 2001.Additional perforations were added in the Lower Beluga in 2002.A capillary string was installed in 2009 and pulled in 2010.A coil tubing cleanout was performed in Aug 2013 but the well did not produce.The bottom of the Lower Beluga was isolated in Sept 2013.The well has been shut-in since February 2013. The purpose of this work/sundry is to squeeze off the Lower Beluga and recomplete the Sterling in the 3-1/2" casing. Notes Regarding Wellbore Condition • Last tag at 5,347'SLM on 5/03/14 w/a 2.50" Drive Down Bailer. Coiled Tubing Procedure: > v�-;j 7„ipe ' 1. MIRU Coiled Tubing, PT BOPE to�,060"psi Hi 250 Low. 2. RU 1.75" coil cleanout BHA. 3. RIH and cleanout fill from 5,347'to top of cement at 8,199' MD using 8.5 ppg lease water. 4. Mix and pump 10 bbl of 15.8 ppg cement from 8,199' MD. "//ov l "s-4- 3 S"-t4j 5. POOH with 1.75"coiled tubing to above top of proposed top of cement at 7,200' MD. 6. Reverse circulate well clean with 8.5 ppg lease water. 7. POOH to surface. ND Injector. 8. Wait on cement min 12 hours. 9. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. 10. RU 2.70"gauge ring, RIH and tag top of cement at+/-7,200'. 11. RD Slickline. L_ PT, 4 1 50D e S'- 12. NU Injector. .— P r. `(S1:1 13. RIH w/coil to 6,500' MD. 14. Displace well fluids with Nitrogen. a. Estimated volume of displaced lease water is 56.5 bbl. b. Measure starting and ending fluid volumes of flowback tank. Well Prognosis Well: BCU-10 Hilcorp Alaska,LI) Date:5/28/2014 15. Pump additional Nitrogen to leaver 2,000 psi Nitrogen pressure on the tubing. 16. POOH w/coil. 17. RD Coiled Tubing. 18. Turn well over to production. E-line Procedure: 19. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 6.5"OTIS. 20. RU 2.50" 6 spf HC wireline guns(will use 2 each 15'guns for 12 spf shot density). 21. Bleed tubing pressure down to below 2,000 psi, as directed by Reservoir Engineer. 22. RIH and perforate the Sterling B-4 from 5,535'-5,550' (2 runs,total of 12 spf). b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB PNL log dated 4/25/14. (Tie-in log depth is 5,535'-5,550'). e. Record tubing pressures before and after each perforating run. f. Distance to nearest well open in same sands=2,520'to BCU-09. g. Spacing allowance is based on CO 237,no closer than 1,320'in the Sterling Pool. 23. RD E-line. 24. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic - -nBC-10 ACTUAL Pad3 Mamma Alaska,lit 943' FNL, 2,958' FWL, SCHEMATIC Sec. 34, T7N, R1OW, S.M. API#: 50-133-20482-00 Conductor Property Des: A-028083 13-3/8" K-55 68 ppf KB Elevation: 179' (21'AGL) -ipg Bottom Spud Date: 3/26/2001 MD o' 113' TD Reached: 4/08/2001 ND 0' 113' Lat: 60°39'31.42"N on!: '151°_1.'5,15"W .�..,v...�,.,,_„ > il. Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom Tree cxn:6-1/2"Otis MD 0' 2,374' TVD 0' 2,329' Sidepocket Chemical ; I •: BC-10 PROPOSED , Pad 3 HileorpAlaska,IAA: 943' FNL, 2,958' FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. API#: 50-133-20482-00 conductor Property Des: A-028083 13-318" K-55 68 ppf KB Elevation: 179' (21'AGL) '', Tom Bottom Spud Date: 3/26/2001 1 MD 0' 113' TD Reached: 4/08/2001 • TVD 0' 113' Lat: 60°39'31.42"N Long: 151° 1'5.15"WJo Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom Tree cxn:6-1/2"Otis MD 0' 2,374' TVD 0' 2,329' Sidepocket Chemical 8-1/2"hole cmt WI 350 sks plus 156 sks top-job Injection Mandrel 2.992"ID @ 1,209' 1/4"OD,0.049"wall SS control line Production Casing loaded w/1"double-check injection ti,( �. 3 112 To L-80 Bottm 9.3osue-Mod et. , � B-4 = / MD 0' 8,817' TVD 0' 8,523' TOC 3-1/2"Csg • a 1 re- 4,142' .i 4,142'(CBL 4/28/14) - I, 6-1/8"hole cmt w/125 sks(47 bbl)of 12.5 ppg O- Lead Cement and 500 sks(105 bbl)of 15.7 ppg Tail Cement • 2.813"Otis X Nipple _ @ 7,182' _ ' Directional Data: t= LB-16 KOP-1,250'at 3 deg/100'build Cement Plug Top IC EOB-2,326',27.5 deg hole angle @ 7,200'MD c LB-17 Drop-4,000'@ 1.5 deg/100' C LB-18L Hold-5,719', 1.2 deg hole angle to TD C - c LB-19 a= LB-19L 7CPerforations: i-maged Pipe @ 7,820' C LB-20 Sterling B-4 5,535'-5,550'(Proposed) (Cannot pass 2.40"Swedge) ► LB-20L 2-1/2" HSD 6spf,60 deg, 10,7 gm PJ2506 1. r LB-21 MD c LB-22 LB-16 7,400'-7,413' (10/2/01) ' ' c LB-22L LB-17 7,507'-7,527' (10/2/01) C LB-18L 7,595'-7,602' (5/22/02) Magna Range Plug @ 8,207'MD itLB 24 LB-19 7,650'-7,658' (5/22/02) Capped w/8'of cement T _ e LB-19L 7,683'-7,692' (5/22/02) LB-20 7,717'-7,737' (10/2/01) Capillary Tubing , LB-20L 7,758'-7,778' (10/2/01) 3/8" 2205 Stainless Steel _ 2LB-21 7,828'-7,848' (10/2/01) Top Bottom c LB-28L LB-28 8 LB-21 7,833'-7,853' (5/22/02)reperf MD 0' 0' TVD 0' 0' C LB-22 7,927'-7,966' (10/2/01) LB-22L 7,996'-8,001' (5/22/02) (***Pulled 02/14/2013***) LB-30 LB-24 8,085'-8,100' (10/2/01) C LB-31 LB-28 8,257'-8,277' (12/3/01) rf r r LB-28L 8,334'-8,354' (12/3/01) Tag @ 8,700'CTM(9/02/13) .. • .'.' LB-30 8,530'-8,545' (11/30/01) 1.75"Coil Tubing Jet Nozzle TD PBTD LB-31 8,634'-8,654' (11/29/01) MD:8,854' MD:8,754' TVD:8,560' TVD:8,460' Well Name&Number: Beaver Creek Unit#10 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 3.0°/100 ft @ 1,250' Angle/Perfs: 0°-+2° Maximum Deviation: 28°@ 3,708' Date Completed: 04/13/01 _ Ground Level(above MSL): 158' RKB(above GL): 21' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 5/28/2014 Beaver Creek BC # 10 Proposed Coil BOPE 5/28/2014 Hikarp Alaska.1.1.1. Lubricator to injection head f ` l I \y r� aJQte�/s�o I emd/Sht-:.E P irA/Sheat l L1 !�-I'll &7nd/Sheae {f_ 51 nl hr.. j-1 p•I MI •I.I pIpM51� rioe;S''� 0,41111111 InVe Emir Mud Cross 4 1/16 10M x 2 1/16 5M 11 � 1 ® I_��. Outlet 4 ea 15M • O 1 x 1 ,, full opening plug valves Crossover spool 4 1/16 10M x 3 1/8 5M 44' ti9.4V 1\�Q ago Valve,Swab,Gray �°e"G^b '� ° � 54 tc Model C,3 1/8 5M FE ` �� Ja��Q* MIME Valve,Upper Master, Gray Model C,3 1/8 •';.• 5M FE Valve,Lower Master, T Gray Model C,3 1/8 5M FE ,I,-:t' • WM ..__ • Completion spool, •.•— --•-- Vetco, u. �1 a NI 115MX75M Grade Level RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR Q 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well L] Plug Perforations U Perforate Li Other L Cap String Removal Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ •" 200 -192 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 d 50- 133 - 20482 -00 7. Property Designation (Lease Number): 8. Well Name and Number: r FEDA028083 4 Beaver Creek Unit (BCU) 10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , N/A Beaver Creek / Beluga Gas 11. Present Well Condition Summary: Total Depth measured 8,854 feet Plugs measured N/A feet true vertical 8,560 feet Junk measured N/A feet Effective Depth measured 8,754 feet Packer measured N/A feet true vertical 8,460 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13 -3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353" 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production 8,796' 3 -1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED APR 0 4 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) N /A; N/A N /A; N/A N /A; N/A N /A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 300 Subsequent to operation: 0 0 0 0 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development E V Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ .. Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Email chelgesonAhilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature .d Phone 907 - 777 -8405 Date 3A, RSDMS MAR 0 6 2013 1(0 r- / 3 Form 10 -404 Revised 10/2012 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU -10 50- 133 - 20482 -00 200 -192 2/4/13 2/4/13 Daily Operations: 02/04/2013 - Monday MIRU BJDC crane and deck equipment. Turn off chemical pump and disconnect the cap string from the chemical feed and cap both lines. POOH at 500 feet, 20 feet per minute per 100 feet left in -hole. Tag FCV at surface. Close swab valve fully. Bleed off WH pressure. Lift injector off of well 1 -2 feet. Unthread WPA. Lift injector up and away from WH, lower injector and remove FCV and WPA. Cap tubing. Remove tubing from chains. Secure tubing tail. Remove tubing spool from unit. Rig -down v` unit. Secure area. Pump methanol and pressure test string to 4K. Drop spool at edge of pad. WPA, manifold in CICM. Permit #: 200 -192 BC-1 0 API #: 50- 133 - 20482 -00 -00 Pad - 3 Prop. Des: A - 028083 KB elevation: 179' (21' AGL) 1,069' FNL, 1,54T FWL, Hilcorp Alaska, la.c Latitude: 60° 39' 30.77° N Sec. 34, T7N, R10W, S.M. Longitude: 151° 1' 5.56" W Conductor S ud. 3/15/2001 _ � � 13 3 /8" K -55 68ppf TD: i Top Bottom Rig Released: 4/17/2001 MD 0' 113' PA #: TVD 0' 113' 5 i i i Surface Casing 4 i 7" L -80 23 ppf BTC -Mod i Top Bottom i MD 0' 2,374' Tree cxn: 6 -1/2" Otis TVD 0' 2,329' 1 Cmt w/ 350 sks plus 156 sks top -job Sidepocket chemical injection mandrel @ 1,209' Production Tubing w/ 1/4" OD, 0.049" wall SS control line 3 -1/2" L -80 9.2ppf EUE Mod ID= 2.992" Loaded w/ 1" double -check injection valve Top Bottom 8rd MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Top of Cement 1 (design) @ -- 4,500' MD Otis "X" Nipple @ 7182' -II■ . II ID= 2.813" f Directional Data: ` KOP - 1,250' at 3 deg /100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg /100' . Hold - 5,719', 1.2 deg hole angle to TD Perforating Record: All perfs: c 2 -1/2" HSD 6spf, 60 deg, 10.7qm PJ2506 LB -16 7,400'- 7,413' (10/2/01) • II LB -17 7,507' - 7,527' (10/2/01) LB -19 7,595'- 7,602' (5/22/02) LB -19 7,650'- 7,658' (5/22/02) Damaged Pipe ai= LB -19 7,683'- 7,692' (5/22/02) Stuck 2 -1/2" GR @ 7820' 'c LB -20a 7,717'- 7,737' (10/2/01) L LB -20b 7,758'- 7,778' (10/2/01) LB-21 7,828'- 7,848' (10/2/01) ' i= LB -21 7,833'- 7,853' (5/22/02) reperf 2.23" GR Tag 8,639' and -slm_ LB -23a 7,927'- 7,966' (10/2/01) (9/15/2010) C LB -23b 7,996'- 8,001' (5/22/02) L LB -24 8,085'- 8,100' (10/2/01) LB -26 8,257'- 8,277' (12/3/01) lc LB -27 8,334'- 8,354' (12/3/01) _ LB -29 8,530'- 8,545' (11/30/01) rra -- LB -30 8,634'- 8,654' (11/29/01) Xedusir TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska I Country: I USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' I Ground Level: I 158' Revised by: Chad Helgeson Date: February 25, 2013 • Marathon JNARATHON Alaska Production LLC August 25, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek Unit #10 Dear Mr. Aubert: Mahon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~.,~ *~ ~~ ~.ij(~ `~ 201Q A1~~k~ ~' ~~ ~ ~~~ J~~inssian ~,s5lbi~C~~B ~~a- Attached for your records is the10-404 Report of Sundry Well Operations for BC-10 well. This report covers the work performed to remove the capillary string from the BC-10 well. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, A~ .~? ~-7/~ Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS I~C,~!- d $ ~; t `toto 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Removed Capillary Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ tubing Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development ~ Exploratory^ ~ 200-192 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. Property Designation (Lease Number): ~ 8. Well Name and Number: ~ FEDA - 028083 Beaver Creek Unit #10 9. Field/Pool(s): Beaver Creek Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 8,$54' feet Plugs (measured) NA feet true vertical 8,560' feet Junk (measured) NA feet Effective Depth measured $,754' feet Packer (measured) Nq feet true vertical 8,460' feet (true vertical) Nq feet Casing Length Size MD ~ TVD Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production g,7g6' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner / ~ ~~® Perforation depth: Measured depth: 7,400' - 8,654' a~ ~ I ~'~ ~ ~ ~ ~ True Vertical depth: 7,107' - 8,360' ~(~ak8 a"~t ~8~ ~~, ~~1iSS101~ Tubing (size, grade, MD &TVD): NA r ~ TVD ~.a= 39 . SSSV: NA NA MD NA TVD Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Removed 3l8" capillary tubing. 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 2,200 50 0 323 Subsequent to operation: 0 0 0 0 312 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ ~, Daily Report of Well Operations X 15. Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature - , Phone (907) 283-1371 Date August 25, 2010 ttBp~IS AUG 2 7 ZO'~ ~-~~~1'~ Form 10-404 Revised 7/2009 Submit Original Only • Prop. Des: FEDA - 028083 KB elevation: 179' (21' AGL) Latitude: 60° 39' 30.77" N Longitude: 151° 1' 5.56" W Spud: 3/15/2001 TD: Rig Released: 4/17/2001 PA #: Tree cxn: 6-112" Otis Sidepocket chernical injection mandrel @ 1,209' w/ 1/4" OD, 0.04.9" wall SS control line ID = 2.992" Loaded w/ 1"double-check injection valve Top of Cement (design) @ - 4,500' MD ~C-10 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R10W, S.M. Otis "X"Nipple @ 718: ID=2.813" Directional Data: KOP - 1,250' at 3 deg!100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD *Slickline tag at 7,683' (8/14/2010) *Dynacoil tagged fill at 8,230' (1/27/2010) *Slickline tag at 8,661' (2/21 /2003) *E-line tagged fill at 8,677' (11/28/2001) TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD Perforating Record: All perfs: 2-1/2" HSD 6spf, 60 deg, 10.7gm PJ2506 LB-16 7,400'-7,413' (10/2/01) LB-17 7,507'-7,527' (1012/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'- 7,737' (10/2/01) LB-20b 7,758'-7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'-7,853' (5/22/02) reperf LB-23a 7,927'-7,966' (10/2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'- 8,100' (10/2/01) LB-26 8,257'- 8,277' (12/3/01) LB-27 8,334'-8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' Perf (TVD): 7,107 - 8,360' Angle @ KOP & Depth: 1.1° / 100 ft @ 1,200' MD Angle @ Perfs: _ 1° Date Completed: 10/2/2001 Ground Level: 158' (AMSL) RKB: 21' (AGL) Revised by: Kevin Skiba Revision Date: 8/24/2010 M MARAT110M Conductor 13-3/8" K-55 68ppf Tom Bottom MD 0' 113' TVD 0' 113' Surface Casing 7" L-80 23 ppf BTC-Mod T_p Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks plus 156 sks top-job Production Tubing 3-1/2" L-80 9.2ppf EUE 8rd Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks ~ r~ ~ C _=`` Marathon operations Summary Report by Job w„~ J ~j~ ~ Well Name: BEAVER CREEK 7 0 OtrlOtr. Block. Sec. Town, Range Field Name License No. StatelProvince Country BEAVER CREEK ALASKA USA Dailv Operations Re ort Date: 7(292010 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU Dyna Coil to pull cap string for inspection. Displace cap string wl MEOH. PT cap string to 5K psi. Test good. Only noticed only one abraided area about 700' from the end of the tubing. Marked it and left this area visable on the spool. Ops Trouble Start Time End Time Dur hrs O s Code Aetivi Code Status Code Comment 07:30 08:30 1.00 SAFETY MTG Hold PJSM. Discuss emergency response, alarms-red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specifcjoh hazards. Obtain SW Permit. 08:30 09:30 1.00 PREP LOC Spot UOSS crane and remove well house. Reconnect 3"flow lines to sand separator. 09:30 11:00 1.50 RURD COIL Spot DynaCoil unit. Lay liners and drip pans. RU DynaCoil Unit. PU spool on unit. Diconnect foamer line. Thread coil thru the side of the injector assembly. Wind tag end of cap string onto spool. Carry injector to WH while "walking" injector down string. Release Ratigun. Release mechanical slips. Reduce packoff pressure. 11:00 14:30 3.50 RUNPUL COIL Cap string set @ 8090'. Pick up to 3200#, string pulls up to 8058' and stops. Work tubing up and hack down many times. Does not come free. Pull steady load and notice 600# loss. Continue working tubing and applying steady pull increasing to d000#. Continue gaining footage. Pump several gallons of foamer out end of cap string. Prepare to flow well to test tank. As tubing pressure drops from 900 psi to 400 psi. capstring come free at 7860'. POOH. 14:30 15:00 0.50 RURD COIL OOH.GIose swab and upper master valves. Remove packoff from WH. Carry injector back to unit. Install 6" OTIS tree cap plug. PT to well pressure. Test good. Bleed off pressure from cap string. Only notice one abraded area about 700' from the end of the tube. Marked this area and spooled the rest tubing so that it stayed visable. 15:00 16:45 1.7~ PUMP TRET Displace cap string w138 gallons MEOH. PT cap string to 5K. Test good. Set spool down on the ground. 16:45 17:45 1.00 RURD COIL RD DynaCoil unit. 17:45 18:00 0.25 SECURE WELL Sercure well. Turn in permit. Sign out and leave loc. Re ort Date: 7;30;2010 Job Cate o R&M MAINTENANCE 24 Hr Sumrriarv MIRU Expro to run tag and PT Survey. RIH w12.5" OD GR. Fluid level @ 4632' wtm. Tag fill @ 7366' wlm. Ops Trouble Start Time End Time Dur'h rl 0 s Code Activi Cade Status Cade Comment 08:00 08:45 0.75 SAFETY MTG Hold PJSM. Discuss emergency response, alarms-red flashing strobe for fire alarm, blue flashing strobe for gas alarm, muster area, wind direction, and specific job hazards. Obtain SW Permit. 08:45 09:51 1.10 RURD ELEC Spot crane and loggint unit. Lay liners and drip pans. RU Exprol Unit. MU lubricator. MU tool string- GammalCCl, sponges, 2.5" OD gauge ring. PU lubricator and carry it to WH. 09:51 10:06 0.25 TEST EQIP PT lubricator to 1500 psi. Test good. 10:06 11:30 1.40 RUNPUL ELEC RIH w12.5" OD GR. Tag up at 7366' wlm. Spud several times and can not make hole. POOH. 11:30 13:00 1.50 RUNPUL ELEC PU 1.75" OD Drive Down Bailer. RIH. Set down @ 7366' wlm. Work tools to obtain sample. POOH. 13:00 15:30 2.50 RUNPUL ELEC PU PT Logging tools. RIH to 21' for 5 minute bench - l57 psia and 51 degree F. RIH @ 120 fpm to 7350' wlm. Fluid level @ 4632' wlm. 5 minute bench @ 7350'- 2034 psia and 119 degrees F. POOH. 15:30 16:30 1.00 RURD ELEC OOH. RD Eline unit. Install 6" Otis tree cap. PT with well pressure. Test good. 16:30 16:45 0.25 SECURE WELL Secure well. Turn in permit and sign out. www.peloton.com Report Printed: 8232010 ~ Marathon operations Summary Report by Job ,,,`~,~, • ~~i ~ Well Name: BEAVER CREEK 1 D Casing Flange Elevation (ft) Ground Elevation (ft) KB•Casing Flange Distance (ft) KB•Ground Distance (tt) Spud Date Rig Release Date Daily Operations Re ort Date: 8!10!2010 Joh Cate o R&M MAINTENANCE 24 Hr Summary MIRU Pollartl VVireline to dump bail fll in well. Well bridged off with Beluga fnes up to 7281' Md. Dump bail down to 7701' MD. Rig down. Start Time End Time Dur hrs O s Code Activi Code Ops Status Trouble Code Comment OS:OD 08:30 0.50 SAFETY MTG AF Arrive at Beaver Creek office, sign in, receive work permit, hold PJSM -topics discussed -reviewed JSA, assigned jobs, slips, trips, falls, hand placement, emergency vehicles, emergency numbers, muster area, smoking area changed to NE corner of pad away from all equipment, red lights for fire, blue lights for gas emissions, sirens for audible, Stop the Job, Three Second Rule, Buddy System and keeping the focus on the job at hand. 08:30 10:30 2.00 RURD SLIK AF transport equipment to PAD 3, rig up crane truck, slickline unit and lubricator. Wellhead pressure is 700# with well shut in. Pressure test lubricator and wireline BOP to 2000#-test good. 10:30 11:30 1.00 RUNPUL SLIK AF Run 2.5 inch dump bailers. Hit bridge at 7281' MD.. Spudded on bridge with dump bailer twice. Tool blown uphole. POOH. Tool stringdragging. Lost tool string at 5110' MD indicated by lost weight on tension device. Continue pulling out of hole. Re-head, install tool string jars and LIB. Pressure test to 2000# good. 11:30 12:30 1.00 RUNPUL SLIK AF Run in hole with LIB to determine if wire or fishing neck looking up. Fluid level at 3413' MD. Previous fluid level tag was at 4600 feet. Fluid level moved up 1200 feet. Set down with LIB at 7667' MD. POOH At surface -fishing neck with wire stub bent over 12:30 13:30 1.00 RUNPUL SLIK AF Run in hole with overshot. Set down on top of fish at 7667' MD. Latch on fsh. Verify weight. POOH. At surface, recovered tools but no wire. Prepare to go into hole after wire. 13:30 14:30 1.00 RUNPUL SLIK AF Run into hole with wiregrab spear. Set down at 7667' MD. POOH. At surface, no wire. 14:30 15:30 1.OD RUNPUL SLIK AF Run into hole with 2.5" dumpbailer. Hit bridge at 7698'MD. Bail down to 1701' MD. POOH At surface, contents of dump bailer -beluga fines. 15:30 16:00 0.50 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. Re-install nitecap,secure wellhead Re ort Date: 8,`11,'2010 Job Cate o R&M MAINTENANCE 24 Hr Summary Rig Pollard VVireline back up to well Ops Trouble Start Time End Time Dur hrs 0 s Code Activi Code Status Code Comment 08:00 08:30 0.50 SAFETY MTG AF Arrive at Beaver Creek office, sign in, receive work permit, hold PJSM -topics discussed -reviewed JSA, assigned jobs, slips, trips, falls, hand placement, emergency vehicles, emergency numbers, muster area, smoking area changed to NE corner of pad away from all equipment, red lights for fire, blue lights for gas emissions, sirens for audible, Stop the Job, Three Second Rule, Buddy System and keeping the focus on the job at hand. 08:3D D9:30 1.00 RURD SLIK AF Rig up slickline unit, crane truck and lubricator, pressure test lubricator to 2000E#-test good. 09:30 11:00 1.50 RUNPUL SLIK AF Run in hole with dump bailer loaded with soap sticks and foamer to 7700' MD. Fluid level at 2982' MD. Pressure on wellhead 850#. Dump 1.5 gallon foamer and six soap sticks, swab well on way out of well. 11:00 12:00 1.00 RUNPUL SLIK AF Run in well again with 1.5 gallons foamer and 3 soap sticks. Fluid level at 1430 and coming up. Dump foamer and soap sticks then swab well on way out of hole. 12:00 13:30 1.50 BLOWDN CSG AF Well flowing approx. 3 BPM water and gas at 200 PSI on wellhead. Continue monitoring well. After 1.5 hour, well is dying off. Drop 3 soapsticks to help it come back. Prepare to gD into hole again with foamer in bailer. 13:3D 14:30 1.00 RUNPUL SLIK AF Run into well with 3 soapsticks and 1.5 gallons foamer. Set down at 7689' MD. Dump soap and foamer across perforations. Swab well on way out Df hole. No rfesponse from well. 14:30 15:15 0.75 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. Secure wellhead, leave location, sign out and turn in work permit. www.peloton.com Report Printed: 8f23l2010 ,~ Marathon '~eratians Summary Report by Jab N~ W~jj~ Welt Name: BEAVER CREEK 10 Daily Operations Re ort Date: 8/1d12010 Job Cate o R&M MAINTENANCE 24 Hr Summary Rig up Pollard'JVireline to dump bail fill. Ops Trouble Start Time End Time Dur hrs D s Cade Activi Code Status Code Comment 07:30 08:00 0.50 SAFETY MTG AF Arrive at Beaver Creek office, sign in, receive work permit, hold PJSM -topics discussed -reviewed JSA, assigned jobs, slips, trips, falls, hand placement, emergency vehicles, emergency numbers, muster area, smoking area changed to NE corner of pad away from all equipment, red lights for fire, blue lights for gas emissions, sirens for audible, Stop the Job, Three Second Rule, Buddy System and keeping the focus on the job at hand. Challenged the crews to go one step further in environmental integrity by putting their duck ponds under their equipment when they stop to sign in and hold their PJSM at the main office which takes approx. 30 minutes. This could prevent a spill. 08:00 08:45 D 75 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. 08:45 09:30 0.75 WAITON EQIP CS Wait on manlift being transferred form Kenai Gas Field to this well 09:30 10:00 0.50 RURD SLIK AF Finish rigging up lubricator, tool string and pressure test lubricator to 2000#- good. 1D:00 10:30 D 5i7 RUNPUL SLIK AF Run in hole with 2.5" dump bailer. Fluid level is at 2398' MD. Set down at 7689' MD. Work dump bailer. POOH Note: original depth reached on slickline odometer was 8051' MD. However, operator said when we got back to surface, the depths were off. The set down depth is copied 1 corrected from the second run in the hole. 10:30 11:30 1.D0 RUNPUL SLIK AF 2nd trip into hole with 2.5" dump bailer. Set down at 7689' MD. Work bailer. Not making any hole. 11:30 12:15 D.75 RUNPUL SLIK AF 3rd trip into hole. Switch to smaller OD bailer. OD is 2 inch. Work bailer, get down to 7001 and then begin to lose hole. Something alongside bailer. Pickup as shallow as 6983' MD. POOH At surface, nothing in bailer. Prepare to go in hole with wire grab spear to check on wire debris from fishing job on 8-10-10 12:15 13:00 D 75 RUNPUL SLIK AF 4th trip into hole with wire grab spear. Did not appear to pick up anything. POOH. On surface -tip broken off spear, spear bent and mashed. Possible - casing damage. Prepare to run LIB 13:00 14:00 1.00 RUNPUL SLIK AF 5th trip into hole with LIB. Maximum depth reached - 7682' MD. POOH I ding on what appears to be low side of hole. No damage to face of LIB. Confusion block 14:00 15:00 1.00 RUNPUL SLIK AF 6th trip into hole with 2 inch bailer with mule shoe end on bailer. Set down at 7685' MD. Last pickup at 7683' MD. For the day, deepest depth reached 77D1' and final pickup was 7683' MD. Net loss was 18 feet for the day. At surface - 3 foot section of 2 inch dump bailer full of Beluga fines. Pressure from below may be pushing bridge uphole. www.peloton.com Report Printed: 8CL3C1010 lUlarathon MQRATNON Alaska Production LLC February 9, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations r~ ~~ Marathon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~E~CEIVED ~~e 1 a za,a Alaska 0~ & bas Cons. Cornrr~ssion An~haraga ao~= Field: Beaver Creek Field ~{q~1 y^ - ~~~R ~s.~U W V~3p~ k ~ ~ 'L 3 V Well: Beaver Creek Unit #10 Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for BC-10 well. This report covers the work performed to lower the capillary string down-hole 402'. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~~'~ ~~ ~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS ALASKA AND GASTCONSERVAT ON COMMISSI~ ~~~tG~ V G~ REPORT OF SUNDRY WELL OPERATIONS FEB ~ ~ 2010 Q~~~ nl~ ~ Gae rrw. f-~~_ 1. Operations Abandon Repair Well Plug Perforations Stimulate her Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension n~hOfng depth Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-e ter Suspended Well ^ 2.Operator 4. Well Class Before Work: .Permit to Drill Number: Name: Marathon Alaska Production LLC Development ~ Exploratory^ 200-192 3. Address: PO Box 1949 Stratigraphic ^ Service ^ .API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. Property Designation (Lea~Number): 8. Well Name and Number: A - 028083 ~ Beaver Creek Unit #10 9. Field/Pool(s): Beaver Creek Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured $,$54' feet Plugs (measured) NA feet true vertical 8,560' feet Junk (measured) NA feet Effective Depth measured $,754' feet Packer (measured) NA feet true vertical 8,460' feet (true vertical) NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production 8,796' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,400 - 8,654' True Vertical depth: 7,107' - 8,360' Tubing (size, grade, MD &TVD): Capillary String 3/8" 2205 Stainless Steel 8,090' MD 7,796' TVD SSSV: NA NA MD NA TVD Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Adjusted 3/8' capillary string setting down-hole 402' and landed at 8,090' MD. 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: 0 970 8 - 341 Subsequent to operation: 0 1,430 - - 327 13. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ ~ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician ` Signature ~ ~ Phone (907) 283-1371 Date February 9, 2010 F~DMS F~ ~ l Y0~ Form 10-404 Revised 7/2009 Submit Original Only ;;== Marathon rations Summary Report by Jab N~~ ;QilCompany Well Name: BEAVER CREEK 10 QtrlQtr, Block, Sec, Town, Range Field Namz License No. StatzlProvince Country BEAVER CREEK ALASKA USA Casing Flange Elevation (tt) Greund Elevation (tt) KB•Casinp Flange Distanoe (iC) i®-Ground Distance (ft) Spud Date Rig Release Date Daily Operations Re ort Date: 1/2802010 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU BJ Dynacoil. PU on 3P8" capillary string (set @ 7,688 MD RKB) and pulled free wJ 700# overpull. RIH w/ capstring and tag fill @ 8,230'. Discuss set point wl offce and set capstring @ 8,D90' (LB-24 perfs). RD BJ Dynacoil. Foamer rate remains set at 2.5 gallday. Ops Tr ouble Start Time End Time Dur hrs O s Code Aotivi Code Status C ode Comment 07:3D 09:00 1.50 SAFETY MTG AF Held PJSM w/ BJ Dynacoil, Pollard, ASRC, and operator. Discussed crane operations, manlift operations, and emergency procedures. Obtained safe work permit. 09:00 10:00 1.00 RURD EQIP AF RD flowback equipment and remove wellhouse. 10:00 11:15 1.25 RURD COIL AF Spot equipment and RU. 11:15 13:30 2.25 RURD COIL AF Load spool on truck. When landing injector on wellhead, tubing buckled and came aut of tubing guides. Inserted tubing back in guides. 13:30 14:45 1.25 RUNPUL COIL AF PU on 3P8" capillary string (set @ 7,688 MD RKB) and pulled free w! 700# overpull- string weight POOH= 2100#. RIH wl capstring and tag fll @ 8,230'. Discuss set point wl offce and set capstring @ 8,090' (LB-24 perfs). 14:45 16:45 2.00 RURD COIL AF RD injector head, hook chemical feed to capstring, and set rate @ 2.5 gallday. RD Dynacoil equipment, install wellhouse, and hook up flowback equipment. Sign out, turn in safe work permit, and leave location. www.peloton.com Page 1f1 Report Printed: 215f2010 C~ 50-133-20482-00-00 A - 028083 n: 179' (21' AGL) 60° 39' 30.77" N 151° 1' 5.56" W 3/15/2001 4/17/2001 BC-10 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R10W, S.M. I M ~-n~oM Conductor 13-318" K-55 68ppf Top Bottom MD 0' 113' TVD 0' 113' Tree cxn: 6-112" Otis Sidepocket chemical injection mandrel /~ . @ 1,209' w/ 114" OD, 0.049" wall SS control line ID = 2.992" Loaded w/ 1"double-check injection valve Top of Cement (design) @ - 4,500' MD Otis "X" Nipple @ 7182' ~~ ID=2.813" Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD ~ Dynacoil tagged fill at 8,230' (1 /27/2010) E-line tagged fill at 8,677' (11 /28/2001) Slickline tag at 8,661' (2/21/2003) TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD Surface Casing 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks plus 156 sks top-job Production Tubing 3-1/2" L-80 9.2ppf EUE 8rd Mod Tom Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Capillary String 3/8" 2205 Stainless Steal T~ Bottom MD 0' 8,090' TVD 0' 7,796' (Reset 06/05/2009 & 1/27/2010) ,II perfs: 2-1/2" HSD 6spf, 60 deg, 10.7gm PJ2506 LB-16 7,400'- 7,413' (10/2/01) LB-17 7,507'-7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'-7,737' (10/2/01) LB-20b 7,758'- 7,778' (10/2/01) LB-21 7,828'- 7,848' (10!2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-23a 7,927'- 7,966' (10/2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'-8,100' (10/2/01) LB-26 8,257'- 8,277' (12/3/01) LB-27 8,334'- 8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Revised by: Kevin Skiba Date: February 9, 2010 Marathon h50.RATHON Alaska Production LLC January 14, 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404, Report of Sundry Well Operations n LJ Marathon Alaska Production LLC Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 t5L ~~~?,~ ~ g ~~~~ lask~ ail Cart Cis. Corrrm~si ,~ , Field: Beaver Creek Field Well: Beaver Creek Unit #10 ~~ JA~~ ~ ~ ~01~ Dear Mr. Aubert: Attached for your records is the10-404 Report of Sundry Well Operations for BC-10 well. This report covers the work performed to raise the capillary string up-hole 847'. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISSI~ ~~~~~~~~ REPORT OF SUNDRY WELL OPERATIONS `~~}'~ia ~ `~ ~"~'~ I~~k~ ail ~ ~~s Gc~t~s. Commissiti 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ ,.,, - ,Adjust Capillary Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension String Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-e ter Suspended Well ^ 2. Operator 4. Well Class Before Work: .Permit to Drill Number: Name: Marathon Alaska Production LLC Development ^~ Exploratory 200-192 3. Address: PO BoX 1949 Stratigraphic ^ Service ^ API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. Property Designatign (Lease Number): .Well Name and Number: ~ A - 028083 Beaver Creek Unit #10 9. Field/Pool(s): Beaver Creek Field /Belu a Pool g 11. Present Well Condition Summary: Total Depth measured g,g54' feet Plugs (measured) NA feet true verticat~„ 8,560' feet Junk (measured) NA feet Effective Depth measured 8,754' feet Packer (measured) NA feet true vertical 8,460' feet (true vertical) NA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production 8,7g6' 3-1 /2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,400 - 8,654' True Vertical depth: 7,107' - 8,360' Tubing (size, grade, MD &TVD): Capillary String 3/8" 2205 Stainless Steel 7,688' 7,395' SSSV: NA NA MD NA T\/D Packers and SSSV (type, MD &TVD): Packers: NA NA MD NA TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): The 3/8' capillary string was moved up-hole 847' and landed at 7,688' M D. 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 1,573 40 - 320 Subsequent to operation: 0 2,085 8 - 352 13. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X 15. Well Status after work: Oil Gas ~ WDSPL GSTOR ^ WAG ^ GINJ^ WINJ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician Signature ~ Phone (907) 283-1371 Date January 14, 2010 ~ RBDI1~ J ~ 4 2010 ~h Form 10-404 Revised 7/2009 Submit Original Only r~ M Marathon N;1QaTMO~ .Oil Company G eratians Summary Report by Job Well Name: BEAVER CREEK 10 QtdQtr, Block, Sec, Town, Range Field Name BEAVER CREEK Lice ripe No. StatelProvince Country ALASKA USA Casing Flange Elevation (ft) Ground Elevation (ft) KB•Casing Flange Distance( ft) KB-Ground Distance (ft) Spud Date Rig Release Date Daily Operations Re ort Date: fif5/2D09 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU BJ Coiltech. Pull up capstring to 7688'. RDMO BJ Coiltech. Start Timz Er~d Timz Dur hrs 0 s Code Acti vi Code Ops status Tro C uble ode Comment 07:30 08:30 1.D0 SAFETY MTG AF Held PJSM with operator, BJ Coiltech, crane operator 08:30 10:00 1.50 RURD OTHR AF MIRU and spot equipment crane, coil unit. 10:00 11:30 1.50 WORK COIL AF Thread tubing into injector, counter, and spool. Spool tbg tail. Land injector on tree. 11:30 13:30 2.00 SERVIC EQIP CS Stop job, hydrolic leak on BJDC unit, few drips into duck pond. Contacted operator, contacted HES at Marathon. Call out mechanic. Mechanica arrive on location, tighten nut fitting, no leaks. 13:30 1d:30 1.00 RUNPUL COIL AF Pull up hole 3113" capstring, landed at 7688'. 14:30 16:30 2.00 RURD OTHR AF RD coil unit. Hookup foamer skid and begin pumping at 4gpd. Sign out, leave location www.peloton.com Page 1;'1 Report Printed: 1/132010 50-133-20482-00-00 A - 028083 n: 179' (21' AGL) 60° 39' 30.77" N 151 ° 1' 5.56" W 3/15/2001 BC-10 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R1OW, S.M. M MARATMOM 4/17/2001 Tree cxn: 6-1/2" Otis Sidepocket chemical injection mandrel @ 1,209' w/ 1/4" OD, 0.049" wall SS control line I D = 2.992" Loaded w/ 1"double-check injection valve Top of Cement (design) @ - 4,500' MD Otis "X" Nipple @ 7182' ~~ ID=2.813" Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD E-line tagged fill at 8,677' (11 /28/2001) Slickline tag at 8,661' RKB (2/21 /2003) TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD Conductor 13-3/8" K-55 68ppf Tom Bottom MD 0' 113' TVD 0' 113' Surface Casino 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks plus 156 sks top-job Production Tubing 3-1/2" L-80 9.2ppf EUE 8rd Mod TOP Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Capillary String 3/8" 2205 Stainless Steal Top Bottom MD 0' 7,688' TVD 0' 7,395' (Reset on 06/05/2009) II perfs: 2-1/2" HSD 6sof. 60 deg. 10.7am PJ2506 LB-16 7,400'- 7,413' (10/2/01) LB-17 7,507'-7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'- 7,737' (10/2/01) LB-20b 7,758'- 7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-23a 7,927'-7,966' (10/2101) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'-8,100' (10/2/01) LB-26 8,257'- 8,277' (12/3/01) LB-27 8,334'- 8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Revised by: Kyle Miranda Date: January 5, 2010 M Marathon MARATHON Oil Company .Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 9071283-1371 Fax 907/283-1350 June 11, 2009 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek Unit #10 Dear Mr. Aubert: ~~~~~ JUN 1 2 Lu: Alaska Oil & Gas ~c~r.~. ~.=i13'"zti¢;:.<3~; Anct~~r~~;: odl~~~ a, Attached for your records is the10-404 Report of Sundry Well Operations for BC-10 well. Marathon received permission to install a 30' casing patch to isolate a~~e~aring zone under Sundry # 308-461. This sundry is being closed out as a on-work activity. ~... ~'. After running a production survey, it was determined that a substantial amount of gas was also being generated from the targeted water producing zone. It was determined that it would be more prudent to deal with the infiltrating fluids rather than shut off a ~. source of significant gas production. Marathon has since installed a capillary string for the utilization of foamer as a means to remPve the wellbore fluids. Permission for this work was granted under Sundry #308-440 and was closed out on June 1, 2009. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, .~ ~~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS Ktctev~a~~ 6 is oy' JUCV 1 2 2009 GJ~~4- u ji5 j2r.~t? Alaska Oii & Gas Cons. Commission Anrhnr~nn 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Non- ork - Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: p ^ Develo ment ~ p ry^ Ex lorato 200-192 - 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 179' (21' AGL) Beaver Creek Unit #10 - 8. Property Designation: 10. Field/Pool(s): A - 028083 - Beaver Creek Field /Beluga Pool 11. Present Well Condition Summary: Total Depth measured 8,854' _ feet Plugs (measured) NA true vertical 8,560' - feet Junk (measured) NA Effective Depth measured 8,754' ~ feet true vertical 8,460' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 13-3/8" 113' 113' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production 8,796' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,400 - 8,654' gross True Vertical depth: 7,107' - 8,360' gross Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 8,535' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): This sundry is being closed out as a non-work activity. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ^ Development 0- Service ^ Daily Report of Well Operations NA 16. Well Status after work: Oil ^ Gas ^~ ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-461 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician Signature r ~ Phone (907) 283-1371 Date June 11, 2009 V per`` Form 10-404 Revised 04/2006 b~ ~u~ ~ ~ 2~~~ Submit Original Only BC-10 50-133-20482-00-00 A - 028083 n: 179' (21' AGL) 60° 39' 30.77" N 151 ° 1' 5.56" W 3/15/2001 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R1OW, S.M. 4/17/2001 Sidepocket chemical injection mandrel @ 1,209' w/ 1/4" OD, 0.049" wall SS control line ID = 2.992" Loaded w/ 1" double-check injection valve Top of Cement (design) 4,500' Otis "X" Nipple @ 7182' ID=2.813" r Directional Data: KOP - 1,250' at 3 deg/100' build ~ ~ EOB - 2,326', 27.5 deg hole angle ~ t~ Drop - 4,000' @ 1.5 deg/100' ;~ Hold - 5,719', 1.2 deg hole angle to TD ~j ~[ t ~ ~ s~ i ~i ~t .+ E-line tagged fill at 8,677 (11!28/2001) + Slickline tag at 8661' RKB (2/21/2003) ~~„ y~ TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD MARATHON Conductor 13-3/8" K-55 68ppf Top Bottom MD 0' 113' ND 0' 113' 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks pl us 156 sks top-job 3-1/2" L-80 9.2ppf EUE 8rd Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Caoillarv Tubing 3/8" 2205 Stainless Steal Top Bottom MD 0' 8,535' TVD 0' 8,240' ,II perfs: 2-1/2" HSD 6sof. 60 deo. 10.7gm PJ2506 LB-16 7,400'- 7,413' (10/2/01) LB-17 7,507'- 7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'- 7,737' (10/2/01) LB-20b 7,758'-7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-23a 7,927'- 7,966' (10!2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'- 8,100' (10/2!01) LB-26 8,257'-8,277' (12/3/01) LB-27 8,334'-8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Revised by: Kevin Skiba Date: May 26, 2009 • M Marathon MARATHON Oil Company June 1, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek Unit #10 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 / ~~ ~l~sk~ o, tfUN 0 2 ZrI09 / & Gas ~~ ns. Cvmmissia~~ Anchorage ~~p-Ida" Attached for your records is the10-404 Report of Sundry Well Operations for BC-10 well. This report covers the work performed to complete the capillary string installation that was approved under Sundry #308-440. The string was installed on 5/14/2009 and set at a depth of 8,535' MD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~i~,~..~. Sk~- ~~ Kevin J. Skiba Regulatory Compliance Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Operations Summary KJS STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 6 ~' ~~- ~~,jN ~ 2 ~c~o~ `~ 31~~'f ~m,,..~..~ ~,,, r 1. Operations Abandon Repair Well Plug Perforations Stimulate t Of1bsE'~~I~DiSSIO~s Performed: Alter Casing ^ Pull Tubin~ Perforate New Pool ^ Waiver^ Time Extension [~t10~~ary String' Change Approved Program ^ Operat. Shutdowr^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development Q Exploratory^ 200-192 - 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. KB Elevation (ft): 9. Well Name and Number: 179' 21' AGL Beaver Creek Unit #10 • 8. Property Designation: 10. Field/Pool(s): A - 028083 Beaver Creek Field / Belu a Pool 11. Present Well Condition Summary: Total Depth measured 8,854' - feet Plugs (measured) NA true vertical 8,560'- feet Junk (measured) NA Effective Depth measured $,754'- feet true vertical 8,460' - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production g,7g6' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 7,400 - 8,654' gross True Vertical depth: 7,107' - 8,360' gross Tubing: (size, grade, and MD) Capillary String 3/8" 2205 Stainless Steel 8,535' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): A 3/8' capillary string was installed to create a path for foamed insertion to aid in wellbore fluid removal. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,719 48 339 NA Subsequent to operation: 0 2,216 - 367 NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~' Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas 0' WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-440 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Technician Signature ~ ~ Phone (907) 283-1371 Date June 1, 2009 °-s Form 10-404 Revised 04/2006 - ~~ ~~~ ~~ ~ Q Submit Original Only -- Marathon ,,,M ~;, GOmpany Operations Summary Report Well Name: BEAVER CREEK 14 Daily Operations Re ort Date: 5/15/2009 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU BJ Coiltech. Run 3/8" capillary string from BC 13 and set @ 8,535'. RDMO BJ Coiltech. Start Time End Time Dur Aa 0 s Code Activi Code Ops Status Trouble Code Comment 01:30 08:00 0.50 SAFETY MTG AF Held PJSM w/ operator, BJ Dynacoil, and ASRC. Discussed Simops, cranelmanlift ops, emergency procedures, and smokinglmuster area. Obtained safe work permit. 08:00 08:45 0.75 RURD COIL AF Drive to location and spot Dynacoil equipment. 08:45 10:00 1.25 RURD OTHR AF Change out tree cap adapter to hold packoff assembly. 10:00 10:30 0.50 RURD COIL TA MSOT Packoff leaking, change out inserts and gaskets in packoff. 10:30 11:00 0.50 RURD COIL AF PU injector head and land on wellhead. 11:00 11:30 0.50 TEST EQIP AF PT packoff assembly and wellhead adapter to 1500 psi. Good test. 11:30 13:30 2.00 RUNPUL COIL AF RIH w13~8" capillary string ,sinker bar wl centralizers, wobble, and fluid control valve to 8,535' RKB. 13:30 16:00 2.50 RURD COIL AF RD injector head and Dynacoil unit. Secure well (place signs and LO valves), turn in safe work permit and well ops transfer form, sign out, and leave location. www.peloton.com Report Printed: 5/20/2009 ` .. • • BC-10 50-133-20482-00-0 A - 028083 ~: 179' (21' AGL) 60° 39' 30.77" N 151 ° 1' 5.56" W 3/15/2001 4/17/2001 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R1OW, S.M. J ~1 II I L Sidepocket chemical injection mandrel @ 1,209' / w/ 1/4" OD, 0.049" wall SS control line ID = 2.992" Loaded w/ 1" double-check injection valve Top of Cement (design) 4,500' Otis "X" Nipple @ 7182' I D=2.813" M~w-nioN Conductor 13-3/8" K-55 68ppf Top Bottom MD 0' 113' TVD 0' 113' 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks pl us 156 sks top-job Production Tubing 3-1/2" L-80 9.2ppf EUE 8rd Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Capillary Tubing 3/8" 2205 Stainless Steal Top Bottom MD 0' 8,535' TVD 0' 8,240' Directional Data: L~ KOP - 1,250' at 3 deg/100' build ~ € C EOB - 2,326', 27.5 deg hole angle ~ ~ ~ Drop - 4,000' @ 1.5 degl100' Hold - 5,719', 1.2 deg hole angle to TD ~ c ~ ~ ~ I I _ ~ E-line tagged fill at 8,677' - (11 /28/2001) Slickline tag at 8661' RKB (2/21 /2003) TD PBTD 8,854' MD 8,754' MD 8,560' TVD 8,460' TVD ,II perfs: 2-112" HSD 6saf, 60 deo, 10.7gm PJ2506 LB-16 7,400'-7,413' (10/2/01) LB-17 7,507'-7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'- 7,737' (10/2/01) LB-20b 7,758'-7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-23a 7,927'-7,966' (10/2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'-8,100' (10/2/01) LB-26 8,257'-8,277' (12/3/01) LB-27 8,334'-8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Revised by: Kevin Skiba Date. May 26, 2009 ' • • ~.) r F'" z„ 3 ~ ~.~ t._ ~ / SARAH PALIN, GOVERNOR ~~ OIL t~isil ~A~7 333 W. 7th AVENUE, SUITE 100 C01~5ERQATIOI~T COl-II~IISSIO1gT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kyle Miranda PE Marathon Oil Company #~a~..'~'~~~~,~~ ~~~ `~ ~ ~~ PO Box 1949 Kenai AK 99611-1949 Re: Beaver Creek Field, Beluga Oil Pool, BCU # 1 U ~, Sundry Number: 308-461 ~ ~.~ Dear Mr. Miranda: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr, / Chair DATED this ~ d/a-y~'of December, 2008 Encl. • M Marathon MARATHON Oil Company December 18, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Beaver Creek Field Well: Beaver Creek #10 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Submitted for your approval is the Application for Sundry Approvals, 10-403, for BC-10 well. Marathon proposes to seta 30' casing patch to isolate a water bearing zone. 7,825' 7,855' 30' Please contact me at (907) 283-1371 if you have any questions or need additional information Sincerely, ~ ~.~.~, s Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application for Sundry Approvals Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS JKM ' I~~ .tip STATE OF ALASKA \~~?- ~ ~~~~ \~ ALA OIL AND GAS CONSERVATION COM ON ~~~ ~~ ~ ~`' APPLICATION FOR SUNDRY APPROVALS l'_ ~n aar. ~s ~Rn 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^, Waiver ^ Other^ Alter casing Q ~ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Casing Patch 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ ~ Exploratory ^ 200-192 3. Address: PO BOX 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Beaver Creek Unit #10 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A - 028083 ~ 179' (21' AGL) Beaver Creek Field /Beluga Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft}: Effective Depth MD (ft}: Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,854' ~ 8,560' . 8,754' - 8,460' - NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 13-3/8" 113' 113' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production g,796~ 3-1 /2" 8,817 8,523' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,400 - 8,654' gross 7,107' - 8,360' gross NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 10, 2008 Oil ^ Gas ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kyle Miranda Title Production Engineer Signature ~ ~ _ Phone Date ~ ~ ~ (907) 283-1371 ~~ r December 18, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ ~~ / ~G~S~ '~7C~OU:~L~~ dh Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location C le arance ^ ~~ T ~ ~ ~ ~~~ ~ ~(~ 1 ~ ^ ~ Other: ~1~~~ CSJl~~V`O~ t2f~ Vet p t"\~~~ V t~ GC~~t~ ~ ~ ~ ~Q~~~~ .iJ~'S 1 < `,~~ Subsequent Form Required: y~` " t /J APPROVED BY ~ ~ Approved by: "/ COMMISSIONER THE COMMISSION ~ Date: Form 10-403 Revised 06/2006 Submit in Duplicate ~~ • ARARATHON Marathon Oil Corporation Field: Beaver Creek WBS: Requested BC 10 December 10, 2008 Well Status: 3350 MCFPD @ 390 psi (12/11/2008 SCADA) and 40 bwpd. History: Well has consistently returned high water rates but remains above unload rate. On 11/29/08 a PLT was run and it was determined that 100% of the water and only 5% of the gas is coming from the LB-21 zone at 7828' - 7853' MD. Well Configuration: The wellbore is constructed with 3 %2", 9.2 ppf tubing with 7" casing running from surface to 2374' MD. - Otis X Nipple at 7182' MD with ID = 2.813" -Tagged fill at 8647' MD on 11/29/08 during PLT Objective: Patch LB-21 interval from 7828' - 7853' MD. r'' etch _ ; Length 30' Casing O.D. 3.500 Casing I.D. 2.992 Patch Max running O.D. 2.715 Patch I.D. after setting 2.259 Patch Burst & Collapse 3500 psi Minimum restriction 2.813 @ 7182' Patch Procedure: 1. MIRU Pollard Slickline equipment with full lubricator, GR, brush, and dummy patch tools. 2. Hold PJSM. Pressure test lubricator with 50/50 methanol water to 1000 psi. 3. RIH with 2.75" Gauge Ring to a minimum depth of 8000' MD. POOH. 4. PU a minimum of 20' dummy patch and RIH to 8000'. POOH. 5. PU brush tools, RIH and brush tubing from 7200' to 8000'. POOH. 6. MIRU Expro E-Line equipment with full lubricator and patch. Hold PJSM, pressure test lubricator with 50/50 methanol water to 1000 psi. 7. PU casing patch (2.715" running O.D. and 2.259" final minimum I.D.), setting tool and pull into lubricator. RIH and correlate depth with CBL and OH logs, set patch as follows: 7825' ~ 7855' 30' ~ 8. POOH, RDMO Expro, Pollard. CONTACTS Ken Walsh: 907-283-1311 (w) 907-394-3060 (c) Kyle Miranda: 907-283-1370 (w) 907-394-8271 (c) Lyndon Ibele: 907-565-3042 (w) Clyde Scott: 713-296-2336 (w) 907-748-2819 (c) KGF Operators: 907-283-1305 Permit #: API #: 200-192 50-133-20482-00-0 Proa. Des: A - 028083 KB elevation: 179' (21' AGL) Latitude: 60° 39' 30.77" N Longitude: 151° 1' 5.56" W Spud: 3/15/2001 TD: Rig Released: 4/17/2001 Tree cxn: 6-1/2" Otis BC-10 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R10W, S.M. M~l~AT1!Q!M Conductor 13-3/8" K-55 68ppf Top Bottom MD 0' 113' TVD 0' 113' Sidepocket chemical injection mandrel @ 1,209' w/ 1/4" OD, 0.049" wall SS control line ID = 2.992" Loaded w/ 1"double-check injection valve Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/100' Hold - 5,719', 1.2 deg hole angle to TD E-line tagged fill at 8,677' (11 /28/2001) Slickline tag at 8661' RKB (2/21 /2003) ~~ ;-a TD 8,854' MD 8,560' TVD TOC - 4,500' (design) ~~ 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks pl us 156 sks top-job 3-1/2" L-80 9.2ppf EUE 8rd Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks Otis "X" Nipple @ 7182' I D=2.813" c i e a x PBTD 8,754' MD 8,460' TVD II perfs: 2-1/2" HSD 6sof, 60 deg, 10.7gm PJ2506 LB-16 7,400'-7,413' (10/2/01) LB-17 7,507'-7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'- 7,737' (10/2/01) LB-20b 7,758'- 7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf ' LB-23a 7,927'- 7,966' (10/2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'-8,100' (10/2/01) LB-26 8,257'-8,277' (12/3/01) LB-27 8,334'-8,354' (12/3/01) LB-29 8,530'- 8,545' (11/30/01) LB-30 8,634'-8,654' (11129/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Revised by Kevin Skiba Date. December 4, 2008 • • ~~ d a ~ ~~ 0 a SARAN rALIN, GOVERNOR ~+ ~SRA OTE ~`L+~+~ 333 W 7th AVENUE, SUITE 100 CO1~T5ER~ATIOI~T COl-il~iIS~IOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kevin Skiba Engineering Technician Marathon Oil Company PO Box 1949 '~~~ IBC; °k. ~~0~ ©D ~ r G~ ~-- Kenai AK 99611-1949 ~ ` 1 ,~ Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek.: Unit # 10 Sundry Number: 308-440 Dear Mr. Skiba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission. decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ! day of December, 2008 Encl. • M Marathon MARATHON Oil Company December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Beaver Creek Field Well: Beaver Creek #10 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Submitted for your approval is the Application for Sundry Approvals, 10-403, for BC-10 well. Marathon proposes to install a 3/8" capillary string to facilitate foamer injection. A tentative date of December 18th has been selected for the installation. This date is dependant on the availability of securing a qualified BJ service representative to oversee the installation. Please contact me at (907) 283-1371 if you have any questions or need additional information Sincerely, .~~U7~ Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File KJS P(~ ~ STATE OF ALASKA ~~//11 ~~~^,~ ALA OIL AND GAS CONSERVATION COM ION 1ti APPLICATION FOR SUNDRY APPROVALS ~~-~ ~n nn~ ~s pan +.f /a8op ~~yrt? ~~`~~~ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^ Waiver^ Other^~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Install Capillary Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ String 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 200-192 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20482-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^~ Beaver Creek Unit #10 Spacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~S A- 028083 179' (21' AGL) Beaver Creek Field /Beluga Pool' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,854' ~ 8,560' 8,754' - 8,460' ~ NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3,450 psi 1,950 psi Surface 2,353' 7" 2,374' 2,329' 6,430 psi 3,830 psi Intermediate Production 8,796' 3-1/2" 8,817' 8,523' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,400 - 8,654' gross 7,107' - 8,360' gross NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 18, 2008 Oil ^ Gas Q ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature ~ one (907) 283-1371 Date December 4, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ V Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~®~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~, I .- Form 10-403 Revised 06/2006 OR'CINAL ~~`; ~ l)~ + .~ €~ X000 Submit in Duplicate • 2008 Capillary String Installation BC 10 Pad 3 Capillary String Install WBS: Requested Objective • Install capillary string (3/8" 2205 0.049" WT) into well for delivering foamer to alleviate liquid loading. Procedure Capstring Set Depth: 8530' (Note: this depth may change due to new PLT data) TVD at Set Depth: 8236' Tag: 8647 ELM Installation Procedure: Disconnect power to wellhouse (call electrician) MI crane, manlift. Remove wellhouse. On site: Spool, Well Head Adapter (WHA), Sundry, Work Permit, Well Control Standards Sheet. Install Capillary Strin JSA): 1. MIRU BJ Dyna-Coil unit. Place liner around wellhead and truck. 2. Shut swab valve, pull tree-cap flange, remove OTIS blanking plug. 3. Replace plug with WHA (note o-ring). MU flange. Pressure test 1.Sx SITP. 4. P/U Dyna-Coil injector with crane, run 3/8" string through injector. 5. Set Fluid Control Valve pressure = (Setting TVD 8236')(0.433 psi/ft H20)(1.036 foamer SG) = 3694 + 306 psi = 4000 psi 6. MU BHA; run the 3/8" string through pack-off; attach BHA. 7. Perform "pull test" on BHA. 8. Thread pack-off assembly into 2-7/8" female connection (a wrench or chain tongs may be needed to hold the adapter from turning). Wrap wellhead with absorbents to catch drips. 9. Configure tubing to pump foamer downhole while running in, or cap tubing end. 10. Set Rattiguns to running tightness, and pump up pressure on pack-off. 11. Open swab valve. 12. Adjust Rattiguns and pressure on pack-off as needed to minimize leaks. 13. RIH to setting depth of 8530'. 14. Set slips. Set Rattiguns; leave 1.5 times SITP on hydraulic pack-off. 15. Pull tubing excess through injector. 16. Cap tubing with a Swagelok cap and valve, pressure gauge, and filter. 17. Lockout Swab, Upper Master, and Lower Master as per Capstring Lockout Procedure. 18. Hookup injection line to CICM. NOTE: Start foamer at 1 gpd. 19. RDMO. Cleanup site. Sign-out. 20. Replace well house NOTE: When replacing well house, be careful of the tubing "bend" as it goes back inside if it extends through the roof. M • 50-133-20482-00-0 A - 028083 n: 179' (21' AGL) 60° 39' 30.77" N 151 ° 1' 5.56" W 3/15/2001 4/17/2001 Tree cxn: 6-1/2" Otis BC-10 Pad - 3 1,069' FNL, 1,542' FWL, Sec. 34, T7N, R10W, S.M. Sidepocket chemical injection mandrel @ 1,209' wl 1/4" OD, 0.049" wall SS control line ID = 2.992" Loaded w/ 1" double-check injection valve Directional Data: KOP - 1,250' at 3 deg/100' build EOB - 2,326', 27.5 deg hole angle Drop - 4,000' @ 1.5 deg/10D' Hold - 5,719', 1.2 deg hole angle to TD E-line tagged fill at 8,677' (11 /28/2001) Slickline tag at 8661' RKB (2/21 /2003) ~s -a .. 9. i TD 8,854' MD 8,560' TVD c c TOC - 4,500' (design) Production Tubin g 3-1/2" L-80 9.2ppf EUE 8rd Mod Top Bottom MD 0' 8,817' TVD 0' 8,523' Cmt in place w/ 625 sks MARATH01~ Conductor 13-3/8" K-55 68ppf Top Bottom MD 0' 113' ND 0' 113' 7" L-80 23 ppf BTC-Mod Top Bottom MD 0' 2,374' TVD 0' 2,329' Cmt w/ 350 sks plus 156 sks top-job Otis "X" Nipple @ 7182' I D=2.813" PBTD 8,754' MD 8,460' TVD 2-1/2" HSD 6spf, 60 deg, 10.7gm PJ2506 LB-16 7,400'-7,413' (10/2/01) LB-17 7,507'-7,527' (10/2/01) LB-19 7,595'- 7,602' (5/22/02) LB-19 7,650'- 7,658' (5/22/02) LB-19 7,683'- 7,692' (5/22/02) LB-20a 7,717'-7,737' (10/2/01) LB-20b 7,758'-7,778' (10/2/01) LB-21 7,828'-7,848' (10/2/01) LB-21 7,833'- 7,853' (5/22/02) reperf LB-23a 7,927'-7,966' (10/2/01) LB-23b 7,996'- 8,001' (5/22/02) LB-24 8,085'-8,100' (10/2/01) LB-26 8,257'-8,277' (12/3/01) LB-27 8,334'-8,354' (12/3/01) LB-29 8,530'-8,545' (11/30/01) LB-30 8,634'-8,654' (11/29/01) Well Name & Number: Beaver Creek Unit #10 Lease: Beaver Creek Field (Pad 3) Municipality: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): 7,400' - 8,654' (TVD): 7,107' - 8,360' Dated Completed: 10/2/2001 KB: 21' Ground Level: 158' Rey.-!sec ,~ Kevin SK:ba Date: December 4, 2008 BC-13 & BC-lOCap-String R~rting Requirements ~ Page 1 of 1 Maunder, Thomas E tDOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 03, 2008 10:28 AM To: 'Skiba, Kevin J.' Subject: RE: BC-13 & BC-10 Cap-String Reporting Requirements Kevin, ~ ~ ~' ~ ~~~ You have captured our discussion. Call or message with any further questions. I will put a copy of this message in the files. Thanks for the compliment. Tom Maunder, PE AOGCC From: Skiba, Kevin .l. [mailto:kskiba@marathonoil.com] Sent: Wednesday, December 03, 2008 9:19 AM To: Maunder, Thomas E (DOA) Subject: BC-13 & BC-10 Cap-String Reporting Requirements Tom, As per our telephone conversation, no 10-403 sundry is required to pull the capillary string out of BC-13 well for use in BC-10 well. Documentation of the BC-13 work will be reported on the follow-up 10-404 Report of Sundry Well Operations. A 10-403 Application for Sundry Approvals will be submitted for the installation of the BC-10 capillary string. No 10-403 approval will be required for reinstalling a replacement capillary string back into BC- 13, when one becomes available. As with removing the BC-13 string, documentation of this reinstallation work will be provided on a follow-up 10-404 Report of Sundry Weil Operations. I realize that you are a busy person. 1 appreciate your willingness to take the time to work through and clarify issues, as they come up. Yaur helpful approach is a refreshing aspect in dealing with the many hurdles, which need to be overcome, of bringing gas/oil to market. Thanks again for all your help, Kevin Skiba Engineering Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ~~~.`~ ~ ~i~~ ~~ E~ 1E~t 12/3/2008 5~ Marathon MARATHON OII COIY~pC~I1y Y May 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Submittal List 6`r`~ '"`\','` ~~ ~~-~ ~'' ~ ~,~ ~° ~,, a .--~ ~~,~~~ "~~ ~ `~ ~~~ ~ ~ 200$ c~~ ~~~Scc~~ ~.~~~~~ S~v ~ , ~ ~= °'~-c ~, ~; ~.LIA~ ~ ~ _ S ~ /~ ~ _~~s~ ~.~~ ,~pa~s~h~F . r • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Ca~S ~`.~i15. `~Oi'~~~s~6~~~ ~ ~,laska Otl ~ ~chora9~ O ' ~ I ~o ~~ ~~5~~~ e~.cc.c~~~+•.~~~ Dear Mr. Maunder: c~,~~-~c~ ~ ~ca ~--~ ~- ~.~~ ~~ Marathon and the AOGCC have had discussions on the follow-u re ortin needed to ~J' ~- / p P g close out 10-403 Sundry approved well work activities. Work has been ongoing to `~'.~~~1 identify the suspect well activities and complete the appropriate reporting. Submitted for your records is a list of the completed reports along with the indicated 10-404 Sundries. I am continuing to work on the remaining sundry reports and plan to submit them upon their completion. Please contact me at (907) 283-1371 if you have any questions or need additiona! information. ~ ..'~,ag~~~,i ~ i `;~; ~,~ '? 44, - i . . ~na~~k~ Sincerely, '~~ ~e~iMi Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Submittal List cc: Houston Well File Accompanying 10-404 Sundries Kenai Well File KJS • M Marathon ,~~~~~~ MARATHON Oil Company ~ MAY ~ ~ "~t~~» Alaska ~il ~` Anc~ ~~~~~~~~~ May 7, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Beaver Creek Unit Well: Beaver Creek Unit #10 Dear Mr. Maunder: • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 ti?iSSI01'~x 9071283-1350 Attached for your records is the Report of Sundry Well Operations, 10-404, for the perforations added to BCU-10 wellbore. This work was performed under Sundry #302-139. The five perforation intervals, added to the wellbore, are listed below: 7,595'-7,602' 7,650'-7,658' 7,683'-7,692' 7,833'-7,853' 7,996'-8,001' Also attached for your records is a copy of the operations summary. Please contact me at (907) 281-1371 if you have any questions or need additional information. Sincerely, , , ~~ .,~i~l'~, Kevin J. Ski a Engineering Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Operational Summary Kenai Well File KJS - S~~ STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM ON R~~~ ~~~ ~ Mi~Y ~ ~ zUL~ REPORT OF SUNDRY WELL OPERATIO~~ ~i~ & Gas Gons. Com~ission A ....L... 1. Operations Abandon Repair Well Plug Perforations Stimulate Oth PerFormed: Alter Casing ^ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ^ Perforate ~^ ~ Re-enter Suspended Weil ~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: rvame: Marathon Oil Company Development ^~ , Exploratory^ 200-192 - 3. Address Stratigraphic ^ Service~ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20482 UO-00 7. KB Elevation (ft): 9. Well Name and Number: 185' Beaver Creek Unit #10~ 8. Property Designation: 10. Field/Pool(s): A- 028083 Beaver Creek Field / Beluga Pool 11. Present Well Condition Summary: Total Depth measured g,$54'_ feet Plugs (measured) NA true vertical 8,560'~ feet Junk (measured) NA Effective Depth measured $,754' ~ feet true vertical 8,460' ~ feet Casing Length Size MD ND Burst Collapse Structural Conductor 112' 13-3/8" 133' 133' 3450 1950 Surtace 2,353' 7" 2,374' 2,329' 6430 3830 Intermediate Production 8,796' 3-1/2" 8,817' 8,523' 10160 10540 Liner Perforation depth: Measured depth: 7,400'-8,654' True Vertical depth: 7,107'-8,360' Tubing: (size, grade, and measured depth) NA NA NA Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 Subsequent to operation: 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ~^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 302-139 i/ Contact Kevin Skiba (907) 283-1377 Printed Name Michael A. Mullin Title Senior Production Engineer ~~ Signature Phone (907) 283-1337 Date May 7, 2008 Submit Original Only Form 10-404 Revised 04/2006 ` ~ ~~ ~"~~ u~~~ ~~' 2009 . ~ ~ MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DA7E: 5/22/2002 FIELD: Kenai Gas Field , WELL #: BC 10 FILL DEPTH/DATE: 8677', 11/28/01 TUBING: 3-1/2", 9.3ppf CASING: cemented 3-1/2" tubin DATE LAST WORK: 11/29/2001 TREE CAP: 6-1/2" OTIS WORK DONE: Perforate BENCHES OPEN: Beluga SUMMARY OF OPERATIONS RU SLB E-Line Safe and rocedure meetin PU 5' 2-1/2' HSD un loaded with 60de , 10.7 m PJ2506 char es. Set well to flow at -2.5MM Q1500 si P-test lubtricator w/ WHP to 1500 si, Test ood RIH w/ Gun #1 Corretate on de th, Shoot 7996'-8001'. POOH At surtace, PU Gun #2 20' , have o rator rease swab valve. RIH Correlate on de th, Shoot 7833'-7853'. POOH. Pwh-1650 si PU Gun #3 9' . RIH Correlate on de th, Shoot 7683'-7692'. POOH. Pwh=1650 si PU Gun #4 8' . RIH Correlate on de th, Shoot 7650'-7658'. POOH. Pwt~1850 si PU Gun #5 7' . RIH Correlate on de th, Shoot 7595'-7602'. POOH At surface, all shots fired. Be in RD SLB leave location Vendor Equipment Daily Cost Cumulative Cost Schlumber er E-line Misc DAILY COST: CUM: REPORTED BY: Titus F:\LaserFiche\CvrPgs _ (nserts\M icrofilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~" '11.''''; '~'In"",.'~ ") ) Permitto Drill 2001920 MD 8854 -'"' TVD DATA SUBMITTAL COMPLIANCE REPORT 10~22~2003 Well Name/No. BEAVER CK UNIT 10 Operator MARATHON OIL CO 8560 J Completion Date 10/1/2001f Completion Status 1-GAS Current Status APl No. 50-133-20482-00-00 1-GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ ~J~/'~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED T 10040 i'] ::]~i.]..'~. ]']']'Z.]:] i'] ]';:. :.;?:i ':] ]:~: ':~.']::'; ]...] ;": :;': ]:]'.'] :'.:;' ::;': ~':'.'.' '.'.'.':':'i:;'i :'.'"..':'i:]':': (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH I Scale Media No Start Stop CH Received Comments 2301 8874 Case 5/9/2001 2301-8874 ED T 10039 ~?!::i..:~:::~!~:..:~;i.~:?~:.i!i~..~i.~i.:~:.~..~?i.!.i.!.~i~.ii:;~i;~:;:::i?i:::i~?i:i.?.i::::;::.;.:~:~:.!?:~;~.:~::i?~!;:;i~ 2201 8874 Case 5/9/2001 Rpt ~,,' ?-~-~::::?:~?~--~-:-;:---i;-~--::--~-::~;?~--;-~:;!~-:-:~]i~i-~:i:;:-~!;!i:i-~-~:i~;~--i:-i-~---~;-:-;~--:-i Final Well Report FINAL Case 5/10/2001 ~ ? '.'.....'.:.........'.! :. :, .: ..Z '.:. :..]:'::.. '.].!.]:.,..]: :..':. ].]:.~:] :],'.'; :.]:]~] :2.:] ... ED C 10039 :. ..................... . ................ ~:~:~:~:~:~¥~:~ FINAL 2201 8874 Case 5/10/2001 ~:;.;[.~[.::.:~:~::~:: ::: :..: :.:.[ .:::.:..:: .:...:. :. :.;..: :..: .:.::.:....: .:. :...-: ED C 10040 ~ .......................... FINAL 2201 8874 Case 5/10/2001 .............................. ............................. ED C 10041 --'~ ..... .. FINAL 2201 8874 Case 5/10/2001 2401-8874 2201-8874 Final Well Report 2201-8874 Digital Data 2201-8874 Digital Data 2201-8874 Digital Data Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 5000 8854 1052 ~ Cuttings ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Daily History Received? Y / N Formation Tops ~/N Comments: Compliance Reviewed By: Date: Surface pressures from BC 10 Subject: Surface pressures from BC 10 '~ ,~(~)(~ ,._ ~, %('.,1~"~" Date: Thu, 13 Feb 2003 09:31:21 -0900 From: "Tank, W J (Will)" <WJTank@MarathonOil.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Berga, P K (Pete)" <PKBerga@MarathonOil.com>, "Affinito, Ralph J." <RJAffinito@MarathonOil.com>, "Lanz, R C (Bob)" <RCLanz@MarathonOil.com>, "Eller, John G." <JGEIler@MarathonOil.com>, "Eynon, D E (Don)" <DEEynon@MarathonOil.com> Tom, Here are the measured surface pressures seen at the BC 10 well. As seen from the data, no pressures are at or above 3,000 psi. If you need any further information, please let me know. Thanks, Will Tank BC 10 Surface Pressures Date Shut-in Pressure 10/01 2,485 psi 05/02 2,060 psi Current Flowing Pressure 1,000 psi 1 of 1 2/13/2003 3:47 PM Surface pressures from BC 10 Subject: Surfaco pressures from Be 10 Date: Thu, '13 Feb 2003 09:31:21 -0900 From: "Tank, W J (Will)" <WJYank@MarathonOil.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CO: "Berga, P K (Pete)" <PKBerga@MarathonOil.com>, "Affinito, Ralph J." <RJAffinito@MarathonOil.com>, "Lanz, R C (Bob)" <RCLanz@MarathonOil.com>, "Eller, John G." <JGEller@MarathonOil.com>, "Eynon, D E (Don)" <DEEynon@MarathonOil.com> Tom, Here are the measured surface pressures seen at the BC 10 well. As seen from the data, no pressures are at or above 3,000 psi. If you need any further information, please let me know. Thanks, Will Tank BC 10 Surface Pressures Date Shut-in Pressure 10/01 2,485 psi 05/02 2,060 psi Current Flowing Pressure 1,000 psi 1 of 1 2/13/2003 4:09 PM Alaska F~ ess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 20, 2002 Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 VIA COURIER RE: Marathon Beaver Creek #10- CONFIDENTIAL Accompanying this letter are four (4) boxes of CONFIDENTIAL well samples for the above referenced well, as described below Box # Depth To Depth 1 5000 - 5800 2 58OO - 644O 3 6440 - 7060 4 7060 - 7390 Please review the enclosed data, sign and return one copy of this transmittal. Thank you, Kaynell Zeman ' '" Technical Assistant Attached (4 boxes) Received by: Date: ~x~ Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request. Abandon __ Suspend _ Alter casing _ C~enge approved program .... = 2. Name of Operato~' Repair well_ Plugging _ Pull tubing _ i x. my~'~ of We,'; ' MARATHt3N OIL COMPANY Development Exploratory Ei-~,ddress .......... StraUgmphlc __ PO Box 196168 Anchorage, AK gg519-6168 Service 4. Loce. tlon of well at surface t096' FNL, 1542' FWL, $e0. 34, TTN. R10W, S,M, At top of productive interval At total depth g43' FNL, 2955' FWL, Sec. 34, 'r7N, R10W, $.M. 12, Present well co'~'ditlon sun'maW .~' Total Depth: measured drilling 8854 ./feet (6pprox) true vertical 8560" feet Effective deptli~; measured 8754. feet (~tpprox) true vel'tlc=el 8460 feet' Casing Length Slze StructuraJ Conductor 113' 13-3/8" Su~f~ce 2374' 7" Intermediate P reduction 8817' ~l- 1/2" Lirl.er Perforation depth: Operation Shutdown __ Re-enter Suspended well _ 'l'ime extension, Stimulate_ Variance ~ Perforate X Other 6, Da~um'eievatlon"(OF or 7. Unit or Property name Beaver Creek Unit "' 8. Well nu'~ber .J~C-10. 9. Permit num~i~ 2.00_-192. 10. APl number S0; 133-204,8~ ...... Tubing (size. grade, end meaeumd depth} N/A 11, Field/Pool Beaver Creek Field/Beluga Pool/ Plugs (measured) N/A Junk (measured) N/A measured Beiug~ Sands: 7400.413, 7507-527, 7717-737; 7758.??~,' 7828.8,{8, '7927-966, 8085-100, 8267-277, 8334-35~, 8530-54~o 8634-684 true vedic~l Belug~ Sands: 7107-120, 7214-284, 7424-444, 7465-485, 7535-555, 7634-673, ?791-806, 7963-983. 8040-060, 8236-251, 8340-360 Cemented Measured depth True vertical depth Driven t33' 133' 350ex + 156 Sx top job 2374' 2142' 6~Ssx 8S17' 85t t' ,, P~okerS and SSSV (type and measured depth) N/A Attachments Description summary of proposal_ Estimated date for commencing operation If p]:~P0sal w~"verb~ll)~' approved ..... Name o! approver Da, re approved Detailed operation program ~ BOP sketch lS, Status of well classification as; Oil. . Gas _~..X Suspended .__ 17, I hereb~ certify that tha.f.oregolng Is true end correct to the best of my knowledge, ~ignecl [\/I..~,I~\ -- ~ Title Production Engineer Denise M. Titus.. FOR coMMis$[0N USE ONLY D=te 4/22/02 Condition, s of approval: NotifY Commission so representative may witness Plug integrity -- BOP Test _ Lo=etlon clearan0e_ Meohanical Integrity Test_ Subsequent form require 10-~~ , Ong!nal S~9n~ Cammy Oechsli Tay~{ ~ppmved by. the order of the Comml~ion Commisslo~er 110 MARATHON OIL COMPANY ALASKA REGION Beaver Creek BC 10 Perforate WBS # TA.O2.06766. EXP Perforate AdditiOnal Lower Beluga sands LB-19 7595'-7602' 7' LB-t9 7650'-7658' 8' LB-19 7683'-7692' 9' LB- 7833'-7853' 20' LB-23b 7996'-8001' 5' Total 49' 'NOTE: The SBHP of the BC Lower Beluga is approximately 2319 psla. 1. Shut-in well atthe wing valve. RU Schlumberger WL service w/pressure control equipment. Hydro-test lubricator to 260/3500 psig. 2. C~all operators. Hold Pre.job safety meeting. Guns will be SAFE actuated (radio silence .ct necessary). 3. MU 2 Ya" HSD gun loaded with 6 Spf, 60° phase, 10.7 gm PowerJet PJ2505 charges. RIH and correlate with CCL to tie-in Icg of 11/28/01. Perforate from deepest to shallowest interval as shown above, noting any .changes in surface pressure. Longest gun section will be 20'. 4. RDMO Schlumberger. BC 10 Additional Pedoretions ~O/l~O'd ZO$-.L 4/~312002 3:37 PM KB-GL: 21,$' :APl: b0-133.20452-00 t059' i-:NL, 154Z' FWL Sec. ~.~4, TTN, F{IOW, $.M. Tree c~n; 6-1J2" Otis Ii 'PoCket cl~e~nical injectic;~ ~'~jtel ~ 1309' w/1/4' OD, 2,992'. tied w/1 double,,che~k injection NIpple ~ 7182' ID=2.813" KoP - t2S0' at ~' deg/100' build EOI~ - 2a26', 27.5 deg hole angle Drop - 4000' @ 1.~ deg/to0' old - 571!a', 1.2 deg hole artgle to TD .-- 'q,O.u'nty ar p,~rla~: , P~rforatio~a (M D) I ~ Laalr Revised: Beaver Creek #10 ] L i ' PBTD := TD = BO t0' Kenal I Q, Eller I Date Revised: 13 3/8'. 61~ppl. K-55 Dfiveplpe @ 1t3' 7~, 28 ppf, L-8O, B'i'C-Mod Casing ~ ' Cml wi 350 sx crnt plus ~ 55 sk top-Job TO(;: - 4S00' (design) LB-17 LB-20b LB-2'I LB-23e LB-~4 Lb-26 L.B-27 LB.2~ LB-30 7~07'-7527' 7717'-7737' ?788'-7778' 7828'-7848' 7927'-7966' 808 $'-81 B257'-a27'7' 8s3o'.SB4~' (11/30/01, 6 epf, 60 dag) asa4'-86.5..4..'..{'l t/29/01, 8 spf, 60 deg) 8 1/2", 9,P_ppf, L-80, EUE 8rd Mod tublng @ 8817' cemented in place wJ 62S sks iLoase; .... 'I ' Beav'e;'Creok Reid IPe'd $) .... I , (TVD) ,J '' , .... ',,, ' I 4-Dee-01 , 'l oan..~ Cd/Cll'A 7NR-I 6a~9vgGGI8+ qlO NOHZV~¥~-mo]J mdJS:;O M. arathon O,I Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99919-6166 Telephone 9071561.5311 Fax 9071564-6489 April 23, 2002 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: BC 10 / Dear.Mr, Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form for additional perforations to Marathon well BC 10 in the Beaver Creek Fieid. If you need any additional information, i can be reached at 907-564-6317 or bye-mail at dmtitus@marathonoil.com, Sincerely, DeniSe M. Titus Production Engineer ,, Alaska Region Domestic Production _M. arathon Oil Company P-O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LEI-rER DATE: PLEASE DELIVER THE FOLLOWING TO: ............ ~-~,","~ ........... ~-'~'~'~:~ ' ~". -' · .,~ _ - , , , t'!! ,,I ~,,"'~' ;' ,,,' ,,, ;' - ,, ' , ~ ...... : ,,.~£-'_--' ,.,, ~-' -~ , ,~~o~. . . ..... ........... ~ .................... ~:. .............................. Number of Pag~ (,~1~i~ ~ m~): ~ ~L-~.~-~,~-:~ '--'T,.-,-~;,.~ ,~"; ...... , ,, ' , ,,' '~ . ' .... ~- f ,,~ ' ," - ~_ ' '- ~ ...... ;';', ' FROM: .,, Loc;att~n/.~ens!orc. .... &~'( ,,'7 , Fax No.; 907/564-6489 If transmission is not complete, please call 907/561.5311. 880-~ ~O/lO'd ~06-1 Environmentally aware forthe long run, llO ~OHIV~V~-mo~ mdgs:~O Alask~ gion Domestic Production Marathon Oil Company May 9, 2001 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Lisa Weepie Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 LETTER OF TRANSMITTAL Via Hand Delivery Enclosed are the following well samples for the Marathon BC 10 well. Box ] From ] To 1 7390' 7800' 2 7800' 8150' 3 8150' 8480' 4 8480' 8854' Please sign and return confirming you have received this data. Thank you, MARATHON OIL COMPANY Exploration Aide Enclosures Delivery Receipt No. 24932 Received Date: /.(' A subsidiary of USX Corporation Environmentally aware for the long run. BI,ti t STATE OF ALASKA ,' Ad'~' (A OIL AND GAS CONSERVATION CON' .SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well o..FI ^sEE] s v,cd-1 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 200-192 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50-133-20482 Classification of Service Well 4. Location of Well at Surface 1096' FNL, 1542' FWL, Sec. 34, T7N, R10W, S.M. - At top of Producing Interval At Total Depth ,~~ 943' F~ FVVL, Sec. 34, T7N, R1 OW, S.M. .....% ................ 'C:Z ..... 5. Elevation in feet (indicate KB, DF, etc.) 16. I 21.5' DF-GL 12. Date3/~/200~S~ludde.~ ~ 113. Date4/8/2001T.D. Reached 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 8854' MD, 8560' TVD 8754' MD, 8460' TVD 22. Type Electric or Other Logs Run AIT-CNT-LDL-GR Lease Designation and Serial No. A-028083 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC-10 11. Field and Pool Beluga Pool Beaver Creek Field 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost Yes[~No r'"-II N/A feet MD '1 N/A 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 K-55 0 113 N/A Driven N/A 7" 23 L-80 0 2374 8-1/2" 350 sk + 156 sk top-job N/A 3-1/2" 9.3 L-80 0 8817 6-1/8" 625 sks N/A 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Beluga Sand:7400-413,7507-527,7717-737,7758-778,7828-848, 7927-966,8085-100,8257-277,8334-354,8530-545,8634-654 MD Beluga Sand:7107-120,7214-234,7424-444,7465-485,7535-555, 7634.673,7791-806,7963-983,8040-060,8236-251,8340-360 TVD 6 spf, 2-1/2" Hollow Carriers, 60-degree phased SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production 3-0 ct-O 1 Date of Test 12/4/2001 Flow Tubing Pres. 1400 PRODUCTION TEST I Method of Operation (Flowing, gas lift, etc.) flowing Hours Tested I PRODUCTION FOR 24 ITEST PERIOD Casing Pressure I CALCULATED 0 124-HOUR RATE OIL-BBL 0 OIL-BBL 0 GAS-MCF 4O4O GAS-MCF 4040 WATER-EEL 0 WATER-BBL 0 CHOKE SIZE IGAS-OIL 11/64" I N/A OIL G RAVITY-API (corr) N/A RATIO 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal E E E D 2001 A,nch0rag~ Form 10-407 Rev. 7-1-80 N:\drlg\kgf\welIs\KBU33-6~AOGCOMPL xls CONTINUED ON REVERSE SID~ B D M S B F L BEC t8 2001 Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Sterling 5407' 5115' Beluga 6134 5841' 31. LIST OF ATTACHMENTS Daily operations summary, wel~bore schematic, directional survey 32. I hereby cer~t the foregoingc~is ~i~ and correct to the best of my knowledge Signed ~,~- ~~ (~ GaryEIler Title Production Engineer Date 12/6/2001 '"'"'J X. 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 only 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 N:\drlg~sterling~su32~9~AOG COMP L.xls ITB-G L: 21.5' PI: 50-I 33-20482-00 1069' FNL, 1542' FWL Sec. 34, TTN, R10W, S.M. tee cxn: 6-1/2" Otis Beaver Creek #10 Sidepocket chemical injection mandrel @ 1209' w/1/4" OD, wall SS control line ID = 2.992" Loaded w/1" double-check injection va ve Otis "X" Nipple @ 7182' ID=2.813" I L Directional Data: K~-"1250' at 3 dog/100' build EOB - 2326', 27.5 deg hole angle Drop - 4000' @ 1.5 dog/100' tHold - 5719', 1 2 deg ho e ang e o TD E-line tagged fill at 8677' 11/28/01) PBTD = 8754' TD = 8854' Ii el! Name & Number: I BC 10 unty or Parish: Kenai rforations (MD) ated Completed: sr Revised: G. Eliot 13 3/8", 68ppf, K-55 Drivepipe ~ 113' 7", 23 ppf, L-80, BTC-Mod Casing @ 2374' Cmt w/350 sx cmt plus 156 sk top-job TOC - 4500' (design) Perforating Record: LB-16 7400'-7413' (10/2/01,6 spf, 60 deg) LB-17 7507'-7527' (10/2/01,6 spf, 60 dog) LB-20a 7717'-7737' (10/2/01,6 spf, 60 dog) LB-20b 7758'-7778' (10/2/01,6 spf, 60 deg) LB-21 7828'-7848' (10/2/01,6 spf, 60 deg) LB-23a 7927'-79661 (10/2/01,6 spf, 60 deg) LB-248085'-8100' (10/2/01,6 spf, 60 deg) LB-268257-8277' (12/3/01,6 spf, 60 deg) LB-278334'-8354' (t2/3/01,6 spf, 60 deg) LB-298530'-8545' (11/30/01,6 spf, 60 deg) LB-308634'~8654' (11/29/01,6 spf, 60 deg) 3 1/2", 9.2ppf, L-80, EUE 8rd Mod tubing ~ 8817' Cemented in place w/625 sks Lease: Beaver Creek Field (Pad 3) I State/P .... Alaska Ic°ur~try: I (TVD) J Date Revised: J 4~Dec-01 J Survey Report Company: Marathon Oil Company Field: Beaver Creek Site: Pad 3 Well: BC #10 Wellpath: OH Original hole Date: 12/6/2001 Time: 09:55:25 Page: 1 Co-ordinate(NE) Reference: Well: BC #10, True North Vertical (TVD) Reference: New KB 179.0 Section (VS) Reference: Well (0.00N,0.00E,84.89Azi) Survey Calculation Method: Minimum Curvature Dh: Sybase Field: Beaver Creek Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: Wmm_95 Site: Pad 3 Site Position: Northing: 2434023.25 ft From: Map Easting: 317305.34 ft Position Uncertainty: 0.0 ft Ground Level: 0.0 ft Latitude: 60 39 30.525 N Longitude: 151 1 6.022 W North Reference: True Grid Convergence: -0.89 deg Well: BO #10 Well Position: +N/-S 90.7 ft Northing: 2434113.25 ft +E/-W 43.6 ft Easting: 317350.34 ft Position Uncertainty: 0.0 ft Slot Name: Latitude: 60 39 31.418 N Longitude: 151 1 5.147 W Wellpath: OH Original hole Current Datum: Magnetic Data: Field Strength: Vertical Section: Drilled From: Surface Tie-on Depth: 0.0 ft New KB Height 179.0 ft Above System Datmn: Mean Sea Level 0/0/2000 Declination: 21.56 deg 0 nT Mag Dip Angle: 0.00 deg Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.0 0.0 0.0 84.89 Survey: Survey #1 Start Date: 3/27/2001 Company: Marathon Oil Company Engineer: Craig Young Tool: MWD/GYRO, Tied-to: From Surface Survey: Survey #1 · .... . :......... . . . MD . ":' Incl. .'.. AZim. TVD ..' +N/:S ' : i+E{~w :Vs . DLS . :Build :" .Turn: .T0ol/Comment .'. :~'i:.'ff' '~ :':':' dog::.": :'deg .: ::::ff :":...":ff": .'ff' "' ff..'" deg/100ffdeg/1.0~ff:=.dbg/i00ff · "· ' ' :' 0.0 0.00 0.00 0.0 0.0 0.0 0.0 0.00 0.00 0.00 MWD/GYRO 195.0 1.02 134.30 195.0 -1.2 1.2 1.1 0.52 0.52 0.00 MWD/GYRO 315.0 1.21 138.60 315.0 -2.9 2.8 2.6 0.17 0.16 3.58 MWD/GYRO 434.0 1.06 141.00 433.9 -4.7 4.4 3.9 0.13 -0.13 2.02 MWD/GYRO 555.0 0.80 97.70 554.9 -5.7 5.9 5.4 0.60 -0.21 -35.79 MWD/GYRO 676.0 0.60 123.40 675.9 -6.2 7.3 6.7 0.30 -0.17 21.24 MWD/GYRO 797.0 0.37 100.60 796.9 -6.6 8.2 7.6 0.24 -0.19 -18.84 MWD/GYRO 920.0 0.52 137.40 919.9 -7.1 9.0 8.3 0.26 0.12 29.92 MWD/GYRO 1044.0 0.96 173.70 1043.9 -8.5 9.5 8.7 0.50 0.35 29.27 MWD/GYRO 1137.0 0.20 212.92 1136.9 -9.4 9.4 8.6 0.88 -0.82 42.17 MWD/GYRO 1293.0 3.29 92.30 1292.8 -9.8 13.8 12.8 2.18 1.98 -77.32 MWD/GYRO 1356.0 3.49 96.30 1355.7 -10.1 17.5 16.5 0.49 0.32 6.35 MWD/GYRO 1449.0 5.66 92.40 1448.4 -10.6 24.9 23.8 2.36 2.33 -4.19 MWD/GY RO 1554.0 8.31 87.20 1552.6 -10.5 37.6 36.6 2.59 2.52 -4.95 MWD/GYRO 1639.0 10.07 83.60 1636.5 -9.3 51.2 50.1 2.18 2.07 -4.24 MWD/GYRO 1733.0 12.19 82.40 1728.7 -7.1 69.2 68.3 2.27 2.26 -1.28 MWD/GYRO 1830.0 13.67 78.90 1823.3 -3.5 90.6 89.9 1.73 1.53 -3.61 MWD/GYRO 1941.0 17.11 81.90 1930.3 1.3 119.6 119.3 3.18 3.10 2.70 MWD/GYRO 2044.0 20.18 81.40 2027.9 6.1 152.2 152.1 2.98 2.98 -0.49 MWD/GYRO 2158.0 22.45 80.90 2134.1 12.5 193.1 193.5 2.00 1.99 -0.44 MWD/GYRO 2232.0 24.76 80.60 2201.9 17.2 222.4 223.0 3.13 3.12 -0.41 MWD/GYRO 2326.0 27.47 81.70 2286.3 23.6 263.3 264.3 2.93 2.88 1.17 MWD/GYRO 2448.0 27,23 79.50 2394.6 32.7 318,5 320.2 0.85 -0.20 -1.80 MWD/GYRO 2573.0 26.75 79.20 2506,0 43.2 374.3 376.7 0.40 -0.38 -0.24 MWD/GYRO Survey Report 2891.0 27.75 78.30 2788.3 71.6 517.9 522.2 0.20 0.06 -0.40 MWD/GYRO 3078.0 27.14 79.80 2954.3 88.0 602.5 607.9 0.49 -0.33 0.80 MWD/GYRO 3176.0 27.55 79.40 3041.3 96.1 646.8 652.8 0.46 0.42 -0.41 MWD/GYRO 3332.0 26.91 82.50 3180.0 107.3 717.2 723.9 1.00 -0.41 1.99 MWD/GYRO 3518.0 26.72 82.50 3346.0 118.3 800.4 807.8 0.10 -0.10 0.00 MWD/GYRO 3708.0 28.05 83.10 3514.8 129.2 887.1 895.1 0.71 0.70 0.32 MWD/GYRO 3836.0 27.39 81.50 3628.1 137.2 946.1 954.6 0.78 -0.52 -1.25 MWD/GYRO 3898.0 27.27 81.30 3683.1 141.5 974.3 983.0 0.24 -0.19 -0.32 MWD/GYRO 3993.0 26.12 83.50 3768.0 147.1 1016.6 1025.6 1.60 -1.21 2.32 MWD/GYRO 4086.0 25.22 82.80 3851.8 151.9 1056.6 1065.9 1.02 -0.97 -0.75 MWD/GYRO 4181.0 24.05 84.30 3938.2 156.4 1095.9 1105.5 1.40 -1.23 1.58 MWD/GYRO 4272,0 22.61 83.50 4021.7 160.2 1131,7 1141.5 1.62 -1.58 -0.88 MWD/GYRO 4397.0 21.21 85.23 4137.7 164.8 1178.2 1188.1 1.23 -1.12 1.38 MWD/GYRO 4493.0 19.53 87.70 4227.7 166.9 1211.5 1221.5 1.97 -1.75 2.57 MWD/GYRO 4587.0 18.83 87.30 4316.5 168.2 1242.3 1252.4 0.76 -0.74 -0.43 MWD/GYRO 4684.0 17.67 84.60 4408.6 170.4 1272.6 1282,8 1.48 -1 '.20 -2.78 MWD/GYRO 4776.0 15.92 83.50 4496.7 173.1 1299.1 1309.3 1.93 -1.90 -1.20 MWD/GYRO 4871,0 14.71 86.90 4588.3 175.2 1324.1 1334.4 1.59 -1.27 3.58 MWD/GYRO 4965.0 13.06 84.90 4679.6 176,8 1346,6 1357.0 1.83 -1.76 -2.13 MWD/GY RO 5061.0 12.25 86.00 4773.2 178.5 1367.5 1378.0 0.88 -0.84 1.15 MWD/GYRO 5151.0 10.20 82.90 4861.5 180.2 1385.0 1395.5 2.37 -2.28 -3.44 MWD/GYRO 5245.0 8.87 83.70 4954.2 182.0 1400.4 1411.1 1.42 -1.41 0.85 MWD/GYRO 5339.0 8.06 86.30 5047.2 183.2 1414.2 1424.9 0,95 -0.86 2.77 MWD/GYRO 5466.0 5.63 81.70 5173.3 184.7 1429.3 1440.0 1.96 -1.91 -3.62 MWD/GYRO 5562.0 3.50 79.80 5269.0 185.9 1436.8 1447.6 2.22 -2.22 -1.98 MWD/GYRO 5626.0 2.80 92.40 5332,9 186.2 1440.3 1451.1 1.53 -1.09 19.69 MWD/GYRO 5719.0 0.64 131.10 5425.8 185.7 1443.0 1453.8 2.51 -2.32 41.61 MWD/GYRO 5846.0 0.43 171.60 5552.8 184.8 1443,6 1454.3 0.33 -0.17 31.89 MWD/GYRO 5970.0 0.56 192.30 5676.8 183.7 1443.5 1454.1 0.18 0.10 16.69 MWD/GYRO 6095.0 0.38 173.80 5801.8 182.7 1443.4 1453.9 0.19 -0.14 -14.80 MWD/GYRO 6222,0 0.63 178.70 5928.8 181,6 1443.5 1453.9 0.20 0.20 3,86 MWD/GYRO 6347.0 0.61 183.00 6053.8 180.2 1443.5 1453.8 0.04 -0.02 3.44 MWD/GYRO 6471.0 0.85 179.60 6177.8 178.7 1443.4 1453.6 0.20 0.19 -2.74 MWD/GYRO 6596.0 1,02 171.80 6302.8 176.6 1443.6 1453.6 0.17 0.14 -6.24 MWD/GYRO 6684.0 1.03 194.30 6390.7 175.1 1443.5 1453.4 0.45 0.01 25.57 MWD/GYRO 6852.0 0.74 291.50 6558,7 174,0 1442.1 1451.9 0.80 -0.17 57.86 MWD/GYRO 6977,0 1.05 266.70 6683.7 174.3 1440.2 1450.0 0.39 0.25 -19.84 MWD/GYRO 7104.0 1.36 259.50 6810.7 173.9 1437.6 1447.4 0.27 0.24 -5.67 MWD/GYRO 7177.0 1.78 254.30 6883.7 173.5 1435,6 1445.4 0.61 0.58 -7.12 MWD/GYRO 7359.0 1.21 233.30 7065.6 171.5 1431.4 1441.0 0.43 -0.31 -11.54 MWD/GYRO 7483.0 1.83 229.60 7189.6 169.5 1428,8 1438.2 0.51 0.50 -2.98 MWD/GYRO 7607.0 0.68 245.90 7313.5 167.9 1426.6 1435.9 0.96 -0.93 13.15 MWD/GYRO 7732.0 0.86 240.50 7438.5 167.1 1425.1 1434.4 0.16 0.14 -4.32 MWD/GYRO 7857.0 1.03 258.70 7563.5 166.4 1423.2 1432.4 0.27 0.14 14.56 MWD/GYRO 7983.0 1.23 256.70 7689.5 165.9 1420.8 1429.9 0.16 0.16 -1.59 MWD/GYRO 8013.0 1.06 266.20 7719.5 165.8 1420.2 1429.3 0.85 -0.57 31.67 MWD/GYRO 8172.0 0,62 167.60 7878.5 164.9 1418.9 1428.0 0.82 -0.28 -62.01 MWD/GYRO 8235.0 0.72 182.60 7941.5 164.2 1419.0 1428.0 0.32 0.16 23.81 MWD/GYRO 8360.0 0.84 195.30 8066.4 162.5 1418,7 1427.5 0.17 0.10 10.16 MWD/GYRO 8485.0 1.01 189.10 8191.4 160.5 1418.3 1426.9 0.16 0.14 -4.96 MWD/GYRO 8531.0 1.24 200.00 8237.4 159.6 1418,1 1426.6 0.68 0.50 23.70 MWD/GYRO 8609.0 1.26 190.00 8315.4 158.0 1417,6 1426.1 0.28 0.03 -12.82 MWD/GYRO Company: Marathon Oil Company Date: 12/6/2001 Time: 09:55:25 Page: 2 Yield: Beaver Creek Co-ordinate(NE) Reference: Well: BC #10, True North Site: Pad 3 Vertical (TVD) Reference: New KB 179.0 Well: BC #10 Section (VS) Reference: Well (0.00N,0.00E,84.89Azi) Wellpath: OH Original hole Survey Calculation Method: Minimum Curvature Db: Sybase Survey: Survey #1 MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 2766.0 27.67 78.80 2677.7 60.1 460.9 464.4 0.49 0.48 -0.21 MWD/GYRO Survey Report Company: Marathon Oil Company Date: 12/6/2001 Time: 09:55:25 Page: 3 Field: Beaver Creek Co-ordinate(NE) Reference: Well: BO #10, True North Site: Pad 3 Vertical (TYD) Reference: New KB 179.0 Well: BC #10 Section (VS) Reference: Well (0.00N,0.00E,84.89Azi) Wellpath: OH Original hole Survey Calculation Method: Minimum Curvature Db: Sybase Survey: Survey #1 MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn Tool/Comment ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft 8797.0 1.27 208.20 8503.4 154.1 1416.3 1424.4 0.21 0.01 9.68 MWD/GYRO 8854.0 1.28 208.20 8560.3 153.0 1415.7 1423.7 0.02 0.02 0.00 MWD/GYRO I P.Oi Mlrithon *"... re: ? DATE: O3tf~(01 LOCATIO .,rs: -4' 8PUD DAYS: 011 Gompiny AFE#: 8102B01 GL: , KB; , MOC WI: . ~90 81ZE: CSG MD: . ~8~ ~D: 8HOE T~ST; Mg 81 ,, 1. _ , , LINE~ IOP: · PRESENT OP:RAISE MA~T FOR MECHANICA~ BRA~ REP~ENT .... CO~NUE ~ ~VEL CAMP. RI~ UP S~ER LINES, ELECTRICAL CAB~, WATER ~NES . S~ MA~ SPOT' E~CUTNE ~ ~, MU~ BOAL AND CARRIER 8UM~ MW VI8 PV YP GELS ,WL, T 7.5 30 HT FC CEO 8AND 6LD, SENT 8ALT DRi~_ ~TE Ill'l f iL/,., l Sqt~z I,, [ ' PPB PPg PPg "' qOIL ~R pH, Pm PI MI eL CA LIME MUD LO8%~,[bblm} ~GD CONN TRIP mm .... dilly ~um [ BIT I 81lB ~PE OFF ~ HRB FWHR RPM WOE I 0 D L B O OT R CPF COMMENT8 ~('~}T ~ 8EmAL ~ PRESS. OPM .,. JET6 TFA ' ANNU~R VELOCI~., BIT HP BHA; ............... ,..,., ,. . . DRILL PIPE DESCRIPTION: M~ PULL: [ / [ i [ 1 1 BHA' Pu- Rot 8~ Eft [ M~. DEPTH ANGLE DIRECTION WD VERT. aEC. Nla ~ ao~ CEO ..... . i - CII I I II II _ ' ' III IIIIIIIIII STA~j "'E:ND HOU~ DESGRIPTiO~. 8:~ ,e:O0 10.00 GONnNUW TO ~a~C CaMP UNI~L LAY LINER ~R SEP~C S~M · SET LIFT STA~ON AND ~EPTIC TANK. NOOK UP SE~R LINES, WA[ER.L{~ AN0 E&EG~IGA~ - SPOT PAR~$ ~N ANO ME~HAM~'$ SHOP- ~E~ ~LDING SHOP. ~Y HERC~Ir~ AND MA~N~ BOARDS FOR SUB ~$E AND MUD ~OAT . ~r GAff~I~R ~N MuD BOAT. i I~_ I_ I REMO~ DRIP PAN~ FROM ~UB BA~E- UNLOAD RI~ EQUIPMEN~ ~ROM ~A~ ...,. . .., ,~_._ ~ . .... ,. ~ .... gailY: 0 G~M; 0 DAIhY; ~{,t59 GUM; 5f, 1~ NO ACCIDEN~ RE~RTED ~DAY _ ~ ... i . DR~LING'SUPERVIsOR:' DARRE~ ~KEEN i ,, Marathon ~"~T#: 1 DATE: 03/16/01 LOCATIOI~.,..'~YS: SPUD DAYS: Oil Company ~ "#: 8102801 GL: KB.~ . MDC Wh WELL: Beaver Creek-t0 RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 0 (TVD) 0 CSG SIZE: 13.385 CSG MD: 713. CSG TVD: 113~" ~HOE TES~":' MAX. SI 0 LINER TOP: PRESENT OP:RAISE MAST FOR MECHANICAL BRAKE REPLACEMENT CONTINUE TO LEVEL CAMP- RIG UP SEWER LINES, ELECTRICAL CABLE'S, WATER LINES- SET MATS SPOT EXECUTIVE SUB BASE, MUD BOAT, AND CARRIER SUMMARY "'~'"' ' '"' ............ :" ...... ":": '" '~"*"' "~'"" ..... i =:"'~ =~":"" *"' """~""~'"" '"'~' =:::' '"'":'"'"'~i~'i"~"i"i''''~ '~':'i''~ '" ........ "' ~='?;' '~ ¥ ...... ";'"' ' '~;""' ........ ":'"~'~'" ~'~' "'~"'-"'""~"' ~"" ';' '~:,::' ' "~'~ ..... ~'~'; "~i'~''~- '~¥'i' "~ *'?'~ '~' .... ,': ""~'~-:'~-i'" ~' '"" ""~':'~ ~MW VIS PV YP GELS WL T 7.$ 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE ~ 9.4 1471 101221 10 / 16r6.4111011 I I I 2 /32 5.0 I 6.3 I / 9.1 PPB. 60.9 PPB PPB (~OIL WTR pH Pm Pf M,f eL CA LIME MUD LOSSES (bbllftI BKGD CONN TRIP MAX ¢ 93 7,~[~ 90 101 01 191~ 28'000 1 daily cum ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ~ t~ BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ 5 !_X5916 2400 295 12 12 14 0.371 DP 331.0 DC 483.3 CRIT DC 384.7 93.0 BHA: 5 STC XRISTDGPS 6 I/8" Bit, 4 3/4" MOTOR .8AKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5, HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PiPE '~ESCRIPTION ': 4" IqPPF S-135 DP, MAX PULL: 303 ( JARS MWD MOTOR TORQUE WEIGHT (1~)00) · 98.0 I1 1 98.0 [644106 1 61.0~ ~ET14861 6,000 fi/lbs.[~BHA'. 20 Pu 120 Rot 105 So 90 Eft 15 ~ MEA. DEPTH ANGLE 'DIRECTION TVD VERT. SEC. NIS E/W DOG LEG ~ {~ OPERATIONS IN SEQUENCE ) START END HOURS DESCRIPTION , 6:00 6:30 0.50 CONT. RIH. 6:30 7:00 0.50 W/R F/6715' TO 6906: 7:00 23:30 16.50 DIR DRILL AND SURVEY F/6906' TO 7480'. ART 14.0HRS AST f. SHRS. 23:30 1:00 1.50 RIG POWER SHUT DOWN WHILE DRILLING. SET RIG TO MANUAL OPERATION. PICK UP AND RACK BACK 1 STAND CIRCULATE AND ROTATE WHILE TROUBLE SHOOT RIG POWER SYSTEM. HAD TO RESEAT GENIUS CARD IN THE DRILLERS CONSOLE. 1:00 6:00 5.00 DIR DRILL AND SURVEY F/7480' TO 7632: ART 3. SHRS AST.SHRS. AFL: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/05/01 ................................ ~'b COSTS ACTUAL WELL COSTS A~TuAL .......... LAST BOP TEST DATE: 03/08/01 DAIL~ ..... ~,~2 CUI~I: 56~4 ....... [~'~,'ll-~'i ..... ~-,6-46-"~UM: ...... '~ ' NO ACCIDENTS REPORTED TODAY DRILLING S'[JPERVISOR: DAi~RELL GREEN - - Marathon =~ r~,. T#: 2 DATE: 03/17/0'1 LOCATION .~'e, ys: SPUD DAYS: Oil Company {' .# 8'10280'1 GL: KB:(~ . MDC WI: WELL: Beaver Creek. lO RIG: Glacier Drilling Rig '1 'FTG: DEPTH: (MD) 0 (TVD) 0 CSG SIZE: '13.385 CSG MD~ 1'13. CSG TVD: '1'13.'- ~HOE TEST: MAX. SI 0 LINER TOP: PRESENT OP:CHANGE LINERS ON MUD PUMPS RAISE MAST ON CARRIER AND REMOVE BRAKES ON DRAW WORKS- WORK ON CAMP SET UP ORGANIZE EXECUTIVE RIG PARTS. WORK ON GAS DETECTORS - RAISE WALLS ON DOG HOUSE'S AND INSTALL LIGHTS- LOWER SUMMARY MAST ~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I I I II i I ,1 I /32 I I ,I. PPB PPB ~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES, ,(bbl/ft) BKGD CONN TRIP MAX I 1~ daily cum ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IO D LB G OT R CPF COMMENTS .~ BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP BHA: Length: DRILL PIPE DESCRIPTION': MAX PULL: .~ JARS MW~ MOTOR TORQUE WEIGHT (~00) '- "' J].. ,,,_,. I 1 I 1 ,~[ BHA'. Pu -Rot' -S° Eft- .~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. HIS E/W DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 8:00 '18:00 '10.00 RAISE SUB BASE AND PIN- PREPARE AND RAISE MAST ON CARRIER. REMOVE BRAKE BANDS ON DRAW WORKS TAKE BANDS TO TUBOSCOPE FOR INSPECTION - BUILD PARKfl AREA FOR VEHICLES. HOOK UP WATER TO CAMP- RAISE WINDWALLS ON DOG HOUSE'S AND INSTALL EXTERIOR LIGHTS - ORGANIZE PARTS HOUSE- INSTALL DERRICK HOUSE WORK ON CARRIER LANDINGS, WORK ON GAS DETECTION SYSTEM- LOWER MAST ,,_ AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/05/0'1 ~ ..... ~:' ,.;.,'.',...,"..'.., ,.?~;i~'" ,~ ~."::~.,.:ii WELL COSTS ACTUAL I ::..,'i?=i;i ~i: LAST BOP TEST DATE: 03/08/0'1 ~~~[-~UD COSTS ACTUAL~ ...... '" '""~*': ,... ,~ .., :.~...,.,- · DAILY: 0 CUM: 0 DAILY: 8,045 CUM: 59,200 NO ACCIDENTS REPORTED TODAY DRILLING S[IPERVISOR: DARRELL GREEN ,,, Marathon ~,~"T# · 3 DATE: 03/18/01 LOCATIO~.n~,YS: SPUD DAYS: Oil Company {, E# 8102801 GL: KB,~, . MOL Wh --WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 0 ,.(TVD) 0 CSG SIZE: 13.385 CSG MD~ 113. CSG TVD: 113~ SHOE TEST: MAX. SI 0 " L'INER TOP: PRESENT OP:WORK ON PIT AND PUMP ROOM COMPLEX GENERAL RIG MAINTENANCE- CHANGE PUMP LINERS TO 5" EXECUTIVE SUMMARY ;~W VIS PV YP' GELS WL T 7.5 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE ) I I I I / I I / I I ) I tPPB PPB PPB ~OIL ~R EH Pm Pf Mf CL CA LIME MUD LOSSES._ .(bbllff) BKGD CONN TRIP M~ ~ ~ ~ 1 J ~ I ~ ~dailY . cum ~ [ } ~ ~ BIT~ SIZE ~PE OFF FTG HRS FT/HR RPM WOB IOD LB G OT R CPF COMMENTS ~ ( BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULAR VELOCI~ BIT HP) BHA: Length: DRILL PIPE DESCRIPTION · M~ PULL · ( JARS MWO MOTOR TORQUE WEIGHT (1000) - ' ~ ~ J [ ~ [BHA: pU R~t- -So' Eft " ~M~A. DEPTH , ANGLE DIRECTION ~D VERT. SEC. NIS E~ DOG LEG .... ( OPE~TIONS iN SEQUENCE ~ START END HOURS DESCRIPTION 8:00 ~8:00 10.00 RAISE MAST AND CLEAN INSIDE DRAWORKS. REPAIR OIL LEAK ON DENISON PUMP. MODIFY CARRIER LANDING PAD EYES ON DRILLERS SIDE- CHANGE LINERS IN MUD PUMJ TO 5" - BEGIN FABRACTING PILL PIT SUCTION LINE TO MIX PUMPS. CHANGE POSITION OF LEVEL SWITCH PROBES IN BOILER RETURN TANK- CHANGE ALTERNATOR ON 966D LOADER, RAISE POOR BOY GAS BUSTER AND HOOK UP LINES - CHECK NITROGEN PRESSURE ON KOOMEY BOTTLES AND GET RIGGED UP TO CHANGE OUT BLADDER ON N BO~LE- INSTALL ~HAUST ON GENERATOR AND PUMP ROOM- RAISE AND PIN BOILER ,, STACK - CLEAN AND INSPECT BRAKE LINAGE - RIG UP BAG pHONE ANTENNA - INCREA~ NITROGEN PRESSURE ON NO.? PUMP DAMPNER - FUEL CAMP GENERATOR - INSTALL ~TERIOR"LIGHTS~ ON PIT AND PUMP COMPLY. ,,, ,, . ~FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/05/0~ ~.; , ..-..;... ,.~ .' .~.::.:'.~;~,,,~;:~,~,.'~ .:~ ...... WELL COSTS'ACTUAL ~.;~,.: :~'.~ LAST BOP TEST DATE: 03/08/01 · ,;':~:~;~'~;~.~;;¥';.~..~:~ MUD COSTS" ACTUAL.~'~':', .~ = · ....~ :'*~ .... .:~*.~; ............ .'..:..... = "'= '* ~' DAILY: 0 CUM: , 0 DALLY: 9,270 CUM: 68,470 NO ACCIDENTS REPORTED TODAY ., ~ DRiLuN~ SUPERViSOr: ~A~ELL GREEN Marathon /~#: 4 DATE: 03/?9/0? LOCATION ?~YS: SPUD DAYS: Oil Company ~. '# 810280? GL: KB:{, MDC Wh WELL: Beaver Creek-?O RIG: Glacier Drilling Rig ? FTG: 0 DEPTH: (MD) 0 (TVD) 0 CSG sIZE: 13.385 CSG M~i 713. CSG TVD: ??3'. SHOE TEST~ - MAX. SI 0 LINER TOP: PRESENT OP:WORK IN PIT AND PUMP COMPLEX GENERAL RIG MAINTENANCE EXECUTIVE SUMMARY GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE · I I I I I II I I I 132 I 1 PPB PPB PPa (~OIL WTR p, Pm Pf Mf CL CA LIME MUD LOSSES (bbllft) BKGD CONN TRIP MAX ~ ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ~ ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION: M~ PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1~00) [ 1 ~ ~ I ~ [BHA:- Pu- Rot So -Eft .~ MEA. DEPTH ANGLE DIRECTION ~D VERT. SEC. NIS E~ DOG LEG i i , i( OPE~TIONS IN SEQUENCE ; START END HOURS DESCRIPTION 8:00 ?8:00 ~0.00 LAY OUT AND FAB 6" LINE FOR NO. 2 MIX PUMP TO PILL PIT AND BUILD SUMP FOR SAME FINISH CHANGING BLADDER IN NO. 3 KOOMEY BOTTLE AND REINSTALL ON MANIFOLD FINISH CHANGING LINERS IN NO. 2 MUD PUMP- REPAIR TIMING CHAIN COVER ON CARRIER 3406 ENGINE- REPAIR BROKEN LIGHT FIGURE TO BE INSTALLED ABOVE BOP DOORS TO SUB BASE UNDER DOG HOUSE - PREP FOR DESILTER INSTALLATION RELOCATE GAS ALARM LIGHTS AND SIREN, FAB OUTLET TO BE INSTALLED IN WALL OF MUD TANK PLUMB WATER LINE FOR SHAKERS AND STUB OUT 6X6 TUBE TO SUPPLY .. MI sOLIDS VAN. ,,, .... AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/05/01 ~,'~:~:~;'~,~*.~'~=:'~.~:.~ MUD COSTS ACTUAL = '''~''~ ~' '"~= © '~':'' ~'~"~: ,'?' WELL COSTS ACTUAL i'.~:'.,,..:'"~ LAST BOP TEST DATE: 03/08/0~ ~'; :...'..'. ~..~...' :'., '~: ~, '..",.' ~:'*=~;t, ,,,;. ' :~L~..~:..~;~.' ~., "='*1 .,.~ .*. ......... ,~., .,.~,, ......... I .... ",' DAILY:. 0 CUM: 0 DAILY: 6,615 CUM: 75,085 NO ACCIDENTS REPORTED TODAY DRILLIN® S~PERVISOR: DARRELL GREEN .... Marathon ,. =PT#: 5 DATE: 03/20/01 LOCATIO/~, qAYS: SPUD DAYS: Oil Company i "E#- 8102801 GL: K,', MOCWI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 0 (TVD) 0 CSG S~'ZE: 13.385 CSG MD: 113. CSG TVD: 113. *SHOE TES;F:' MAX. SI 0 LINER TOP: PRESENT OP:RIG MAINTENANCE , GENERAL RIG MAINTENANCE , EXECUTIVE SUMMARY (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I I I I I i I I 132 I I ,I. ..PPB_ PPB PPB i(OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllftl BKGD CONN TRIP MAX I [ ] Idaily -cum '"~ /'; '"" '¢ i;i '"',';','; ,~,~'" ~'"~'~ '""i~~:''':~''~'::''''': ";' 'I;',"'~'~' ""'"":'"':==""'",""'~;,","~'iii:i"' '=~: ........ ' ~' ,,~.,.,=¢:.,..,i~ ~::,?~!. ,. :,f ~".~ ,,..':' .,;!:.~'. ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IO D LB G OT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ I BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1"~)00) - :,.," '~ ,,.k, ,.,' ,,; ~ ~' , '~,,, ~ : '..~.h<......~,., """'." ' ';'=;',i~,, ~, ,~ ........ ' ,;~",'i"~'~ ~";' '''''' i ' '~,' ~','"~ ,, , '' ' :~ ":':"'~'~ ';'"""~:"':'""~'""' ~"~'~;=~;'"'": !' :" ~'4: :":"~?"~"~": ':':"'" :~' =:":~"~i~;~'"':'~:'""~ ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 8:00 18:00 I0.00 REMOVE PINS AND HYDRAULIC JACKING CYLINDERS FROM PUMP COMPLEX TRAILOR HONE AND TAP CYLINDER FOR GREASE ZERTS - TURN DOWN PINS - CLEAN CEMENT OUT OF FLOW LINE- WELD RELEASE SPRING MOUNTS ON MECHANICAL BRAKE BANDS SEND IN FOR INSPECTION *NOTE THAT BANDS WERE REJECTED AND ARE DRESSED WITH ASBESTOES BLOCKS*- CONTINUE WITH 6" LINE TO PILL TANK- FAB SUMP AND CANNON HOLE FOR DESlLTER- CLEAN SUB BASE RASING SLIDES AND PIN POCKETS FINISH CLEANING DRAWORKS - DRESs CARRIER PINS- RAISE DERRICK- CLEAN AND INSPECT DISC BRAKE- CHANGE SHAKER SCREENS TO ~50 MESH - REPIN MUD PUMP POP OFFrS TO 3000 PSI. - DIG OUT LOWER SECTION OF TORQUE TUBE AND PREP FOR MODIFICATION- THAw OUT CAMP WATER LINE- REPLACE PIN ON DRILL PIPE SPINNER- REPLACE LEAKING FUEL LINE ON NO. I CARRIER ENGINE- CONTINUE TO ORGANIZE PARTS - INVENTORY SHAKER SCREENS .. &FE: DH TSTICSG coMP TOTLAST PIT DRILL DATE: 03/05/01 ,, :-- ..~ .,.,,.... .... · i :',,";.,.:;' ::":':'::,::?.,':,:?' :i M U D COSTS ACTUAL'"":!,'?,! ;,:?::..i'~,"?,';~,.i' '~ !'~!.;' ".-:,:'; i WELL COSTS ACTUAL i'.:~i.i!i!i.~ LAST BOP TEST DATE: 03/08/01 ... .... . .,: .:.. ,;..~:.....,:, :.:,. ,. . DAILY: 0 CUM: 0 DAILY: 11,540 CUM: 86,625 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: DARRELL GREEN Marathon ,,p.oT#: 6 DATE: 03/2,/0, LOCATION~p,YS:___ SPUDDAYS: .._ OilCompany [ .# 8,02801 GL: KB,,~{ . MOCWh WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 0 ('I'VD) 0 CSG SIZE: '13.385 CSG MD: 113. CSG TVD: 113~ ~;HOE TES:r~ - MAX. SI 0 " LINER TOP: PRESENT OP:GENERAL RiG MAINTENANCE GENERAL RIG MAINTENANCE EXECUTIVE SUMMARY ';~' :T: ''~'' '~''"''~''~'' := '~'~'~'~'"i":"~'"~"~:'"""~; ""'i""'"":'"' ::~' ":"' "' 'i:'~ '' ~ ""' ~'~" ....... '= ~'~':"~" ~ ~ ':' '~" "'~"~" '"~'7" =": ~"'i'~"' ""="~"~"~' :~'~ ........ '~"~"' :'" "'~" {MW VIS PV YP GELS WL T 7.5 30 "T FC CDC SAND SLD BENT SALT DRILLED BARITE I I I I / I I[ t / I I 132 I I / PPB PPB PPB {OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllft) BKGD CONN TRIP MAX L 1 daily cum ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOD LB O OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: { JARS iWD MOTOR TORQUE WEIGHT (1~)00) '" BHA' pU Rot So Eft ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. ElS E/W DOG LEG ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 8:00 '18:00 10.00 'STRAIGHTEN DERRICK CLIMBER - GREASED ALL SHEAVES AND INSPECTED ALL LINES :IN DERRICK- CLEANED AND TIGHTENED ALL DERRICK LIGHTS - TIGHTEN CASING STABBING BOARD BOLTS AND CHECK ALL HYDRAULIC CONNECTIONS- WELD OUT BRAKE BANDS AND SEND FOR INSPECTION, CHECKED OUT GOOD - REPACK 3" CHICKSANS IN MUD PIT SYSTEM- RUN WATER LINE TO CAMP- CONTINUE TO WELD OUT 6" LINE IN PILL PIT ~ UNLOAD WELL HEAD EQUIPMENT- INSTALL JACKING RAMS ON PUMP TRAILOR- DRESS 4" RAMS FOR DOUBLE GATE AND CONFIRM THAT 4" RAMS ARE IN SINGLE GA TE - CHANGED OUT BATTERIES AND REMOVED TIRE CHAINS FROM 966D FORK LIFT - FINISHED HOOKING UP POOR BOY DEGASSER - INSTALLED HANDRAILS ON WATER TANK- sTART INSTALLING LIGHT UNDER DOG HOUSE- CONTINUE TO ORGANIZE PARTS - WORK ON KOOMEY BLADDERS - UNLOAD CASING CENTRILIZERS FOR 7" SURFACE PIPE- CLEANING UP PAD 41-7. UNLOAD '13 5/8" 5K SLIP LOCK WELLHEAD AND DSA TO 2~ '1/4" 2K DIVERTER SPOOL AND 1'1" 5K TO '13 5/8" 5K ADAPTER AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/05/01 ,.~',.!~ i::.':.~,' ~?.i:~.i:!...:.' .! MUD COSTS ACTUAL i 'i:'::;';:.i, :~; i~'..'!;';!!' ii~':i:ii'~;~.!.'i'.::'i?~i:~l WELL COSTS ACTUAL ;.i {,~ ";;i:! LAST BOP TEST DATE: 03/08/01 DAILY: 0 CUM: 0 DAILY: 9,298 CUM: 95,923 NO ACCIDENTS REPORTED TODAY ... :DRILLING SUPERVISOR: DAI~RELL GREEN ,. Marathon ?'~T#: 7 DATE: 03/22/01 LOCATION~..~,YS: SPUD DAYS: Oil Company ( .:# 8102801 GL: KB.( . MOC Wh [_WELL: Beaver Creek-t0 _RIG:_Glacier Drilling Rig I FTG: DEPTH: (MD) 0 (TVD) 0 - CSG SIZE: 13.385 CSG MD: 113. CSG TVD: 113. SHOE TEST: MAX. SI 0 ILINER TOP: PRESENT OP:SET SUB BASE ON BC-IO ............ & ......... RIG UP RIG MAINTENANCE- LAY MATTING BOARDS EXECUTIVE SUMMARY '" ' "'";:" ...... ' ....... ' .... ':" · ""°='~"~ ' ~ "'~" "' ..... "~' = "*'i "i =~ i" ~"~ ~=:~ ....... ~, ~"'"t'~ ' '" '~"~:*~':':" ~:'* ='"~' ' "' "~'~"= '"'~:~'~'~ '~ :'~"~i~~''~*~['~'' ~' ....... "~:'~=~ ""¥"='" ~i~'' ~ ........ ........ "~=' ........ '~" ii' ~'"'~'~=~'~'' ~ ~'=~? 'i~' ~:l'~'~'~? ~ ~MW ViS PV YI~ GELS WL T 7.5 30 HT 'F~. CEC SAND SLD BENT SALT DRILLED BARITE I I I I I I Il [ / I I /32 I I i PPB PPB .(OIL WTR pR Pm Pf Mf CE CA LIME MUD LOSSES lbbllft! BKGD CONE TRIP MAX ],,[ 1 daily cum _~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IO D L B G OT R CPF COMMENTS ~ BIT# SERIAL# PRESS. GPM , JETS TFA ANNULAR VELOCITY BIT HP~ I BHA: Length: DRILL PII~E DESCRIPTION: MAX PULL: (~ JARS MWD MOTOR TORQUE WEIGHT (1-000) I 1 [ } i / IBHA:' Pa Rot- So Eft ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. ElS E/W DOG LEG .... ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 18:00 12.00 RAISE DERRICK AND INSTALL MECHANICAL BRAKE BANDS - LOWER MAST AND DRIVE CARRIER OFF MUD BOAT- LOWER SUB BASE AND INSTALL LIGHT UNDER DOG HOUSE SLEEVE 6" TUBE FOR WA TLR LINE TO CUTTINGS BOX- CUT PAD LINER BACK PULL BACK AND FILL WITH GRAVEL, LEVEL AND RESEAM LINER - LAY RIG MATS FOR SUB BASE, CARRIER, PUMP ROOM, AND PITS - START INSTALLING DERRICK MUD CLEANER - MOVE PVT IN PIT NO. 3 - FIX ANTIFREEZE LEAK ON 966D LOADER - WORK ON COMPENSATORS FOR MUD PUMPS . CHANGE OUT BLADDER ON KOOMEY BOTTLE MOVE MUD BOAT WITH LOADER AND PIN GOOSENECK ON SUB BASE - WELD ANGLED FOOT ON TESCO TORQUE TUBE AFL: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/05/01 , .'~.:::.~i:'.i;,!i:!::i?:~i,~'~!:?,;.i.i MUD COSTS ACTUAL !.=.; ,:i;i.~:.;::i;:'?,,:..i.~ii?~. , ..::;~'~i:' ':~,:!.: "~:",..,.,:~,..~... WELL COSTS ACTUAL ?i'..~i:'.:i':!i,ii,.i;I LAST BOP TEST DATE: 03/08/01 DAILY: 0 CUM: 0 DAILY: 11,021 CUM: 106,944 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOr': DARRELL GREEN - " Marathon ~PT#: 8 DATE: 03/23/01 LOCATION ~AYS: I SPUD DAYS: 8102801 GL: . MOC Oil Company WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 0 (TVD) 0 .. . CSG SIZE: 13.385 CSG MD: 113. CSG TVD: 113. SHOE TEST: MAX. SI 0 _ LINER TOP: _ PRESENT OP:HOOK UP EQUIPMENT - PREPARE TO SCOPE OUT MAST A T DA YLIGHT RIG UP ON BC-10 EXECUTIVE SUMMARY ~..... --.- ~O~L ~R pH Pm Pf Mf CL CA LIME MUD LOSSES ~bbllff~ BKGD CONN TRIP M~ 1 daily- cum ~ BIT~ SIZE ~PE OFF FTG HRS FWHR RPM WOB IOD LB G OT R CPF COMMENTS I I I I I I I I ( BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULARVELOCI~ BIT HP BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: .... ~ JARS MWD MOTOR TORQUE WEIGHT (1000) [ ] I ,,~I ~ I ' BHA' Pu -Rot' SO 'Eft ~ MEA. DEPTH ANGLE DIRECTION ~D VERT. SEC. NIS E~ DOG LEG ( OPE~TIONS IN SEQUENCE START END HOURS DESCRIPTION 8:00 6:00 22.00 SET IN RIG COMPONETS - SPOT GENERA TOR, BOILER HOUSE, SET PUMP AND PIT COMPL~ ON MATTING BOARDS - PUT SUB BASE OVER THE HOLE - SPOT MUD BOAT AND BACK IN CARRIER- MOVE PUMP ROOM AND PIT UNITS INTO POSITION CONTINUE TO WORK ON MUD CLEANER INSTALLATION- SET CU~INGS TANK SET (2) BJ CEMENT SILO'S - SET FUEL TANK ON BOILER HOUSE- LEVEL AND RAISE MAST- SET (2) DOG HOUSE'S - INSTALL LANDING ON BACK OF RIG FLOOR BEHIND DERRICK - INSTALL STAIRS TO PITS AND (2) SETS TO CARRIER - INSTALL FLOWDNE- HOOK UP UTILITIES AND ELECTRICAL CABLES - SCOPE UP SUB BASE AND INSTALL OUT RIGGERS - PLACE TESCO TOP DRIVE ON RIG FLOOR - SPOT DIVERTER STACK BY SUB BASE - SET MUFFLERS ON CARRIER MOTORS - STAND UP "V" DOOR WIND WALLS - SET TRIP TANK IN SUB BASE- FRAME IN CELLER WITH 3Xf2'S - INSTALL TURNBUCKLES ON CARRIER - HOOK UP BRAKE LINAGE TO RIG FLOOR - HOOK UP DRILLERS PLC CONTROL CONSOLE - INSTALL WIND WALLS BEHIND DERRICK AFL: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/05/01 ......... ~ ~ ..~...,..[~...., ,..~ ....~ .~.=,. ,~..... MUD COSTS ACTUAL ~.~;~;:..~..~;?..;:~:...:.~..:~.~:::;?:..~:~:~:;.;;:~..~ WELL COSTS ACTUAL;... ~'..=;.~ LAST BOP TEST DATE: 03/08/01 DAILY: .0 CUM: 0 DAILY: 21,~02 CUM: 128,~6 NO ACCIDENTS REPORTED TODAY ....... DRILLING S~PERVlSO~: DARRELL GREEN ., Marathon .'~OT#: 9 DATE: 03/24/0'1 LOCATION DAYS: 2 SPUD DAYS: Oil Company ~, .#: 8'102801 GL: KB ~[ . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig '1 FTG: DEPTH: (MD) 0 (TVD) 0 CSG S~'ZE: 13.385 CSG MD~ '113. CSG TVD: 113. ~HOE TEST: MAX. SI 0 .... LINER TOP: _ PRESENT OP:FOLD UP WIND WALLS ON DERRICK BOARD GENERAL RIG UP EXECUTIVE SUMMARY (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLO BENT SALT DRILLED BARITE ~ I I I I i I II I I I I 132 I I I PPB PPB PPB ~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft) BKGD . CONE TRIP I~AX ·[~ 1 daily cum ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D LB O OT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP'~ , BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: .. ~ JARS MWD MOTOR TORQUE WEIGHT (1000) 1 BHA' Pu Rot- -So Eft ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG ( OPERATIONS,IN SEQUENCE START END HOURS DESCRIPTION 6:00 '12:00 6.00 CONTINUE TO RIG UP ON BEAVER CREEK 10- CHANGE OUT BRASS IN DRILLING LINE DEAD MAN CLAMP - HOLD PRE JOB SAFETY MEETING AND SCOPE OUT MAST. ' SET EPOCH UNIT AND BAKER INTEQ MWD UNIT- LAY HERCULITE AND SPLICE FOR ,,. MI SOLIDS VAN AND HANSON STORAGE TANK - INSTALL 6X6 BERM AROUND RIG HOOK UP HYDRAULIC'S TO RIG FLOOR - OFF LOAD TRAILORS - INSTALL HYDRAULIC ROTARY DRIVE MOTOR - HOOK UP CENT. DISCHARGE AND SUCTION LINES - HOOK UP POP OFF LINES - WORK ON DESlLTER INSTALLATION - RESKIN BLUE CAMP UNIT ,AND REPAIR MIsc. ITEMS INSIDE BOTH CAMP UNITS '12:00 0:00 12.00 SPOT CAT WALK AND PICK UP BEAVER sLIDE- HANG TESCO TOP DRIVE TORQUE TUBE - RIG UP COMMUNICATIONS FROM RIG TO CAMP UNITS - INSTALL TARP ON CARRIER- CIRCULATE STEAM AND WATER AROUND RIG- PICK UP TESCO TOP DRIVE 0:00 6:00 6.00 INSTALL TURNBUCKLES ON TORQUE TUBE- FILL WATER TANKS - FIX OIL LEAK ,, ON ROTARY MOTOR - INSTALL 4 1/2 IF SAVER SUB ON TOP DRIVE- EXTEND ,,, LANDING TO DERRICK BOARD - INSTALL CHOKE LINE - CHANGE GAUGE AND FITTING ON TOP DRIVE COUNTER BALANCE SYSTEM . INSTALL BALES - ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/05/01 · ~' ~'~." ~'"1~??:~,,,::..~.,;~ ............ :.,.~;.~,;. ~'..~,~i,~"~ .~i" ,. ..... WELL COSTS ACTUAL '^ST aOP TEST DATE: ~'~' '~:?i!'";i~=.=i~i;'~ i MUD COSTS ACTUAL =. '"'.'.".' '~:~'':;',' '".? .i,, .~;..~. DAILY: 0 CUM: 0 DAILY: 23,455 CUM: '151,90'1 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR-: DARRELL GREEN Well: Beaver C reek-10 'i"' (" Date: 24-Mar-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 1/2 HOUR MINIMUM START END HOURS DESCRIPTION HOOK UP VIB. HOSE BETWEEN PUMP ROOM AND CARRIER- SET PIPE RACKS AND LOAD 4" DRILL PIPE AND 5" HWDP- UNLOAD WEAVER BROTHERS TRAILORS BUILD DOCK FOR MISC. EQUIPMENT Marathon ~,r~T#: 10 DATE: 03/25/01 LOCATION P~YS: 3 SPUD DAYS: Oil Company q,. # 8102801 GL: KB ( . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 70 DEPTH: (MD) 105 (TVD) 105 __ _ CSG SIZE: 13.385 CSG MD: 113. CSG TVD: 113. SHOE TEST: MAX. SI 0 LINER TOP: PRESENT OP:NIPPLE UP D!VERTER SYSTEM GENERAL RIG UP - MAKE UP BHA NO. 1 AND CLEAN OUT TO 105'- POH - PICK UP HAMMER AND DRIVE PIPE EXECUTIVE TO 113' RKB - LA Y DOWN HAMMER AND MAKE ROUGH CUT ON 13 3/8" DRIVE PIPE- LA Y DOWN SUMMARY 13 3/8" AND MAKE FINAL CUT- INSTALL SLIP LOCK WELL HEAD AND TEST ...................................................... VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT 8.3 1341 I I I I II I I I I 132 I I i PPB PPB FPS (:OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllff) BKGD CONN TRIP, MAX .'.....',.:.'.. '..,.;.r.:.~"~.',.:?:,~,::...'.."~.~.~ ,,.....,,,~,~.,.,.~.~,=.i..~<;....,;~.~.,....~.~?.,,,, ,, :. ~.....,.....~ :... ~..~,..,.:~.,.,..::..:....,c: .,~. ,....,. ,.,,:..,..:.., , .~ .~: ~ .! .?.,:....,,,..~. ~. ;.,,: ~.: .,.~ (~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IO D LB GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP-~ 1RR MG4610 105 465 12 18 18 20 0.914 BHA: J 12 1/4" BIT, BIT SUB, X/O SUB, 4-5" HWDP, Length: 125.02 DRILL PIPE DESCRIPTION: MAX PULL: (~ JARS MWD MOTOR TORQUE WEIGHT (1~)00) - ·,:,~LBHA' Pu Rot So Eft I I . (MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG :(: OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 14:00 8.00 CHANGE OIL IN SWIVEL - WELD DERRICK BOARD FINGER- RIG UP CHOKE AND KILL LINE - RIG UP DB RIG TONGS AND PIPE SPINNER. RIG UP MUD MANIFOLD - INSTALL CELLER SCAFFOLDING - ADD WA TLR TO PILL PIT AND REPAIR LEAKS - CLEAN METAL OUT OF PITS - LOAD PIPE RACKS WITH 4" DRILL PIPE AND 5" HWDP INSTALL COVERS ON DERRICK CYLINDERs- FILL PITS WITH WATER 14:00 15:00 1.00 MAKE UP 12 1/4" BHA TO CLEAN OUT 13 3/8" CONDUCTOR 15:00 16:30 1.50 'DRILL FROM 35' TO 105' AND POH WITH 2 STANDS OF HWDP BREAK BIT AND CROSS OVERS 16:30 21:00 4.50 PICK UP HAMMER- MOVE TESCO TOP DRIVE TORQUE TUBE- WELD OUT 13 3/8" CONDUCTOR PIPE 21:00 22:00 1.00 DRIVE PIPE FROM 78' RKB TO 96' 22:00 2:00 4.00 BEVEL AND WELD 22' SECTION OF 13 3/8" CONDUCTOR 2:00 3:30 1.50 DRIVE PIPE FROM 96' RKB TO 113' RKB - AT 161 TO 207 BPF FOR FINAL 2 FEET LA Y DOWN HAMMER · 3:30 5:00 1.50 MAKE ROUGH CUT AND LA Y DOWN 13 3/8" CONDUCTOR PIPE- MAKE FINAL CUT AND GRIND BEVEL ON SHOULDER ~.FE: DH TST/CSG COMP. TOT LAST PIT DRILL DATE: 03/05/01 '?,~'~ii:'ii:.':~i'i' .'i MUD COSTS ACTUAL ri..: ..... :': · .,..' !':~'i'? '?. ,: ~'...":'~.,,~;~ .",:,, IwELL COSTS ACTUAL i'.:.'i.:,:~?':': LAST BOP TEST DATE: 03/08/01 DAILY: 0 CUM: 0 DAILY: 25,391 CUM: 177,292 NO ACCIDENTS REPORTED TODAY DRILLING sUpERVISOR: DARRELL GREEN Well: Beaver Creek-lO i'i' t' Date: 25-Mar-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: '112 HOUR MINIMUM START END HOURS DESCRIPTION 5:00 6:00 '1.00 INSTALL VETCO GRAY SLIP LOCK SOW Marathon RPT#: 11 DATE: 03/26/01 LOCATIOn!. DAYS: 4 SPUD DAYS: Oil Company E#: 8102801 GL: K . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 797 DEPTH: (MD) 902 (TVD) 902 cs~ S~E: 13.385 cs~ M~-.: ~13. CS~ TVD: 1137- ~HOE TES~i MAX. S~ 0 LINER TOP: PRESENT OP:DRILL AHEAD TO 902' CHANGE SAVER SUB TO HT-38 NIPPLE UP 21 1/4" 2K DIVERTER SYSTEM - FUNCTION TEST WITH AOGCC REPRESENTIVE - PICK UP 4" DRILL EXECUTIVE PIPE AND 5" HWDP AND STAND BACK IN MAST- PICK UP BHA AND SPUD BC-?O @ 2300 HRS. DRILL AHEAD SUMMARY TO 902' (~MW ViS PV YP GELS WL 'T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE · 8.6 1681~2137124 / 33120.0tl62[ / I I 2 /32 0.0 I 2.4 I / 0.4 PPB 3~.9 PPB PPB OIL WTR p, Pm Pf Mf CL CA LIME MUD LOSSES lbbllft) BKGD CON" TRIP MAX~ 0.0 197.6I 9.5 }0.2 0.1 1 0.4 I 2,100 I } [daily 0.11 cum 0.11I [ 1 ( BIT~ SERIAL~ PRESS. GPM JETS TFA ANNULARVELOCI~ BIT HP) 2 MGS020 ~300 457 14 16 ~4 0.497 178.3 BHA: 2 8 1/2" BIT, MACH lX MOTOR w~ 1.2 AKO, 8 3/8" STRING STAB, MWD, PULSER SUB, ~0 SUB, 4-5" HWDP, 6 1/4" Length: HYDRAULIC JARS, 23-5" HWDP, ~0 SUB, 905.92 DRILL PIPE DESCRIPTION: 4" 14 PPF S-135 DP, M~ PULL: ~ JARS MWD MOTOR TORQUE WEIGHT (1000} 7.0 lDAILYf5111 7.0 [804064 [ 7.0 {M2-058 ~ 900~lbs ~BHA: PU 45 Rot 45-So 45 Eft { MEA. DEPTH ANGLE DIRECTION ~D VERT. SEC. NIS E~ DOG LEG 555.00 0.800 97. 70 554.93 5.31 -5. 69 5.91 0.60 676.00 0.600 ~ 23.40 675.92 6.62 -6.15 7.28 0.30 797.00 0.370 ~00.60 796.92 7.49 -6.57 8.19 0.24 ( OPE~TIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 15:00 9.00 NIPPLE UP 21 ~/4" DIVERTER SYSTEM - INSTALL 21 ~/4 2K TO ~3 5/8 5K DSA - SET IN DIVERTER SPOOL AND INSTALL 16" HYDRAULIC KNIFE VALVE- INSTALL 3 SECTIONS OF ~6" DIVERTER PIPE- SET IN BELL NIPPLE- HOOK UP FLOW LINE AND CHECK FLOW LINE SENSOR - HOOK UP KOOMEY LINES AND FUNCTION TEST (CALL STATE MAN) TEST GAS ALARMS - HOOK UP TRIP TANK FLOW LINE - RIG UP GERONIMO LINE , INSTALL MOUSE HOLE AND SEAL AROUND SAME - BRING SAFETY VAL YES TO RIG FLOOR - DRESS OUT DESILTER WITH CONES - PICK UP TOOLS AND TRASH AROUND RIG HOLD PRE JOB SAFE~ AND SPUD MEETING 15:00 ~6:00 1.00 PREFORM DIVERTER TEST WITH AOGCC REPRESENITIVE "LOU GRIMAULDI" ~6:00 ~7:00 1.00 PICK UP 4" DRILL PIPE 17:00 17:30 0.50 REP~CE ELECTRIC SWITCH ON TOP DRIVE CONSOLE 17:30 21:30 4.00 CONTINUE TO PICK UP 4" DRILL PIPE AND 5" HWDP 2~:30 23:00 1.50 MAKE UP BHA AND ORIENT 23:00 6:00 7.00 DRILL AHEAD FROM ~05' TO 902'- ACTUAL SLIDE TIME AT .25 HOURS. ACTUAL ROTA TING TIME A T 3.25 HOURS AFE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/25/01 DAILY: 2,258 CUM: 2,258 DAILY: 39,252 CUM: 216,544 NO ACCIDENTS REPORTED TODAY DRILLING S'~PERVISOR: DARRELL GREEN "' Marathon D°T#: 12 DATE: 03/27/01 LOCATIO~.nAYS: 5 SPUD DAYS: 2 Oil Company { .-'# 8102801 GL: EL( . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 1,483 DEPTH: (MD)... 2,385 (TVD) 2,338 CSG SIZE: 7.000 CSG MD~ 2,374. CSG TVD: 2,32~;'. ~HOE TEST: 16.40 MAX. SI 920 LINER TOP: PRESENT OP:CHANGE BALES AND RIG UP TO RUN SURFACE CASING DRILL AHEAD FROM 902' TO 2,385'. CIRCULATE HOLE CLEAN . BACK REAM OUT OF THE HOLE TO 905' EXECUTIVE POH TO SHOE WITH 5" HWDP - SERVICE TOP DRIVE AND REPAIR LEAK ON MUD LINE- CIRCULATE HI. VIS SUMMARY SWEEP . LEVEL DERRICK AND CROWN FOR CASING RUN - POH - LA Y DOWN HWDP - LA Y DOWN BHA AND CLEAR RIG FLOOR (.MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 8.8 }631 161161 9 / 12110.01661 / J I2 132 0.1 14.0I ,I. 0.1 PPB 47.7 PPB PPB ~OIL W'rR pH Pm Pf Mf CL CA LIME MUD LOSSES tbbl/ft! BKGD CONN TRIP MAX ~ O0 960I 89 01 01 04~ 400 I 1 idaily cum 004 ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ 2 MGS020 1800 457 14 16 14 0.497 I 182.5 I BHA: 2 8 1/2" BIT, MACH 1X MOTOR w/1.2 AKO, 8 3/8" STRING STAB, MWD, PULSER SUB, X/O SUB, 4-5" HWDP, 6 1/4" Length: HYDRAULIC JARS, 23-5" HWDP, X/O SUB, 905.92 DRILL PIPE DESCRIPTION: 4" 14 PPF S-135 DP, MAX PULL: ~ JARS MWD MOTOR TORQUE WEIGHT (1'000) - ~ , 17.0 DAILY151,1 17.0 1804064 117'° IM2'°58 1 IBHA: pU 75 Rot 70 SO 67 Ef- ~.MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. ElS E/W DOG LEG ~ 2,158.00 22.450 80.90 2,134.07 193.40 12.47 193.13 2.00 2,232.00 24.760 80.60 2,201.87 222.98 17.24 222.37 3.13 2,326.00 27.470 81.70 2,286.27 264.29 23.58 263.25 2.93 ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:30 0.50 CONTINUE TO DRILL AHEAD FROM 902'- ClRCULATE AND STAND BACK 1 STAND - CHANGE SAVER SUB TO HT-38 AND CHANGE ELEVATOR INSERTS FOR 4" PIPE 6:30 16:30 10.00 DRILL AHEAD FROM 902' TO 2,385'- ACTUAL ROTATING TIME AT 4.75 HOURS - ACTUAL SLIDE TIME AT 2.5 HOURS 16:30 17:00 0.50 CIRCULATE HOLE CLEAN 17:00 19:30 2.50 BACK REAM OUT OF THE HOLE TO 5" HWDP- CHANGE ELEVATOR INSERTS FOR 5" TUBE 19:30 20:30 1.00 CONTINUE TO POH TO SHOE 20:30 23:00 2.50 SERVICE TESCO TOP DRIVE - CHANGE GRABBER DIES - FIX LEAK' ON TOP DRIVE MUD LIN REPLACE BOLT ON TOP DRIVE LINK TILT 23:00 0:30 1.50 RIH TO BOTTOM - NO PROBLEMS OR FILL 0:30 2:30 2.00 CIRCULATE HI-VIS SWEEP AROUND - LEVEL DERRICK MOVE CROWN OVER HOLE- ADJU5 TOP DRIVE TORQUE TUBE AND OUT RIGGER GUY LINES - PUMP DRY JOB AND BLOW DO1 ,,. CIRCULATING LINES 2:30 3:30 1.00 POH WITH 4" DRILL PIPE 3:30 5:00 1.50 POH LAYING DOWN 5" HWDP .... 5:00 6:00 1.00 LA Y DOWN BOTTOM HOLE ASSEMBLY- CLEAR RIG FLOOR ~.FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/25/0~ ~::i :~;.~ ::%'i:.;'.~. :i! M U D COSTS ACTUAL i. ~.'~':.i~;:,i: ".: :~ '~'?.: "'. ~i ."~i .~ ;'-'" ~1 WE EL COSTS ACTUAL~'. ":'; ...... , ? ........... .. = i~'. ~.:.,'~:=~.,:,.: LAST BOP TEST DATE: 03/25/0t DALLY: 4,094 CUM: 6,352 DALLY: 47,658 CUM: 264,202 NO ACCIDENTS REPORTED TODAY ..... DRILLING S~PERVISOR: DARRELL GREEN Marathon ~PT#: 13 DATE: 03/28/01 LOCATIO!~! r}AYS: 6 SPUD DAYS: 3 Oil Company f~' ,=E#: 8102801 GL: K~"~ = MOCWI: WELL: Beaver Creek-lO RIG:..Glacier Drilling Rig I FTG: DEPTH: (MD) 2,385 (TVD) 2,338 SI~E: M~): CSG 7.000 CSG 2,374. CSG TVD: 2,327-- SHOE TEST: 16.40 MAX. SI 908 LINER TOP: PRESENT OP:PREPARE TO N/D DIVERTER. FINISH ED 8.5" BHA. RUN 7" CSG AND CEMENT. PERFORM TOP JOB F/165' TO SURFACE. EXECUTIVE SUMMARY 'i¢~w' v~s'~; ~;. °'t'~s "Wi'"'* "~i~ .... ~0 .~ ~c C~c S~,~ s['~, "a~'., s^[~ ~,~t~'e~ ' '~^,~i~"'~) 8.9 1641 161131 6 I 9 110.61681 / I I2 /32 ]4.°1 ~0''PPBi.m39'~PPaa. 2.0 PPB= (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllft} BKGD CONN TRIP MAX 96 0 8 8 1 0 1 0 4..~. ~I.. 400 II~daily Cum 0 04 ( BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IO D L B G OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP 2 MG8020 1800 457 14 16 14 0.497 182.5 BHA: 2 8 1/2" BIT, MACH 1X MOTOR wi 1.2 AKO, 8 3/8" STRING STAB, MWD, PULSER SUB, X/O SUB, 4-5" HWDP, 6 I/4" Length: HYDRAULIC JARS, 23-5" HWDP, X/O SUB, 905.92 DRILL PIPE DESCRIPTION: 4" 14 PPF S-135 DP, MAX PULL: ~' JARS MWI~ MOTOR TORQUE WEIGHT (1000) - 17.0 DAILYI51~l~ 17.0~..~i!804064 1 17.0I~M2-058 ~~BHA'. Pu 75~ Rot 70 So 67 Eft ~, MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG 2,158.00 22.450 80.90 2,134.07 193.40 12.47 193.13 2.00 2,232.00 24.760 80.60 2,201.87 222.98 17.24 222.37 3.13 2,326.00 27.470 81.70 2,286.27 264.29 23.58 263.25 2.93 ( OPEP~T~O,S ~, SEQUENCE START END HOURS DESCRIPTION 6:00 6:30 0.50 CONTINUE TO LAY DOWN BHA AND CLEAR RIG FLOOR. 6:30 9:30 3.00 HOLD PRE-JOB sAFETy MEETING - CHANGE BALES TO LONG SET - RIG UP WEA THERFORD CSG RUNNING TOOLS. 9:30 14:00 4.50 RUN 57 JOINTS 7" 26PPF L-80 MODIFIED BUTTRESS CASING. 14:00 14:30 0.50 CIRC. 7" CSG @ 2374'. 14:30 17:00 2.50 PUMP 5BBLS WATER AHEAD. TEST CEMENT LINES TO 2500P$1. PUMP 40 BBLS MUD CLEAN II. DROP BOTTOM PLUG. MIX AND PUMP 350SXS TYPE"I" CEMENT W/1.5% CACL2, 20% LW-6, .3% CD-32, 1GPS FP-6L, 1% SODIUM METASILICATE, 20% MPA-l, AND 96.2% FRESH WATER TO YIELD 156BBLS 12PPG SLURRY. DROP TOP PLUG AND CHASE W/SBBLS FRESH WATER FROM BJ. SWITCH OVER TO RIG PUMPS AND DISPLACE 7" CSG W/86BBLS 8.SPPG MUD. BUMP PLUG W/5OOPSI OVER DISPLACEMENT PRESSURE. Clp~ 14:30. FULL RETURNS WITH NO CEMENT TO SURFACE. BLEED BACK PRESSURE AND FLOATS HELD OK. 17:00 1:00 8.00 WHILE WOC. CHANGE OUT TO SHORT BAILS. P/U 4" DP AND RACK BACK IN DERRICK. CLEAN MUD PITS. 1:00 3:00 ZOO . OFF LOAD AND .STRAP 1 1/4" TUBING. FABRICATE AND R/U FALSE ROTARY TO RUN 1 1/4" ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/25/01 ':' i':;'...'".i:i.': .'~ i MUD COSTS ACTUAL i. ~' ''~ '~; '" ''=: ~ ~' ......... " ..... = ..:?.':. ::~.' ..? .::.~!,:.....' i:; .'.'=. ~ WELL COSTS ACTUAL ?'....':',i~' LAST BOP TEST DATE: 03/25/01 DALLY: 1,654 CUM: 8,006 DALLY: 93,622 CUM: 357,824 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. ~"'AWSON / DARRELL GREEN '" Well: Beaver Creek-10 ~,,, Date: 28-Mar-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION TUBING. 3:00 4:00 1.00 P/U AND RUN 1 1/4" TUBING IN THE 7" ANNULUS. TAG CEMENT @ 165: R/U CIRCULATING LINE AND ATTEMPT TO WASH PAST CEMENT @ 165'WITH NO SUCCESS. HOLD SAFETY __ MEETING PRIOR TO CEMENT JOB. 4:00 5:00 1.00 PERFORM TOP JOB W/156SX TYPE "1" CEMENT W/1.5% CACL2 TO YIELD 32BBLS 15.8PPG SLURRY(CIRCULATED CEMENT TO SURFACE). 5:00 6:00 1.00 FLUSH CEMENT LINES. FLUSH AND DRAIN STACK. JET FLOW LINE. PULL OUT W~ 1 1/4" TUBING. ,, Marathon RPT#: 14 DATE: 03/29/01 LOCATION .nAYS: 7 SPUD DAYS: 4 Oil Company (' .#: 8102801 GL: KB.~' . MDC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 2,385 (TVD) 2,338 CSG SIZE: 7.000 CSG Mi~: 2,374. CSG TVD: 2,327. SHOE TES'~: 16.40 ' MAX. SI 908 .... LINER TOP: PRESENT DP: PREPARE TO TEST BOPE. ED 1 9/4" TUBING USED FOR TOP JOB. N/D DIVERTER. N/D DSA. REMOVE 13 5/8" 5M SLIP LOCK EXECUTIVE WELLHEAD. INSTALL 7" SOW X 11" 5M WELLHEAD. N/U BOP. M/U TEST STRING AND PLUG. RIH AND SUMMARY SEAT TEST PLUG. 8.9 1621161'151 8 / 11111.0166t / I 12/32 I 5'°1 ./. 0.1 PPB 61.0 PPB PPB ~O~L WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft) BKGD CONN TRIP MAX TM · · ] ] [95 0 1 8 8 0 1 0 3 400 daily cum 0 04 ~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOE I O D L B G OT R CPF COMMENTS · ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION :, MAX PULL: (~ JARS MWD MOTOR TORQUE WEIGHT (1'~)00) '" ~ ~ I / I 1 [ 1 IBHA:- 'PU Rot So Eft ~ MEA. DEPTH ANGLE_ DIRECTION TVD VERT. SEC. ElS E/W DOG LEG ~ 2,158.00 22.450 80.90 2,134.07 193.40 12.47 193.13 ZOO 2,232.00 24.760 80.60 2,201.87 222.98 17.24 222.37 3.13 2,326.00 27.470 81.70 2,286.27 264.29 23.58 263.25 2.93 ( OPERATIONS IN SEQUENCE ) START END HOURS DESCRIPTION 6:00 7:30 1.50 CONT. ED 1 1/4" TUBING. BLOW DOWN LINES. 7:30 12:00 4.50 N/D DIVERTER LINE AND DIVERTER' LINE VALVE. ROUGH CUT 7" CSG. ED CUT JOINT. N/D BELL NIPPLE. INSTALL PROTECTOR PLUG INTO DIVERTER AND ENERGIZE. N/D DIVERTER. N/D 13 3/8"5M X 21 1/4"2M DSA. 12:00 15:00 3.00 CONT. N/D DSA. ATTEMPT TO PULL 13 5/8" 5M SLIP LOCK HEAD FROM 13 3/8" CSG WITH OUT SUCCESS. CUT 13 3/8" CSG AND ED 13 5/8" SLIP LOCK HEAD. 15:00 20:30 5.50 FABRICATE 13 3/8" SPACER. PREHEAT 7" CSG AND WELD ON 13 3/8" SPACER AND 7" SOW X 11" 5M WELLHEAD· ALLOW WELLHEAD TO COOL. TEST VOID ON WELLHEAD TO 2400PSl/15MIN. 20:30 2:00 5.50 N/U 11" 5M X 13 5/8" 5M SPOOL. N/U 13 5/8" BOP. N/U BELL NIPPLE. 2:00 5:30 3.50 N/U KILL AND CHOKE LINES. HOOK UP KOOMEY LINES. ED P/U SLINGS. INSTALL BOP TURNBUCKES AND CABLES. P/U TEST STRING AND TEST PLUG RIH AND SEAT. FILL STACK. 5:30 6:00 0.50 CHECK VALVE ON KILL LINE LEAKING. REPAIR CHECK VALVE. ON GOING WORK FOR LAST 24 HRS: CHANGE LINERS TO 4 1/2" ON MUD PUMPS. I_/0 DP AFL: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/25/01 " ..... .MUD'COSTS ACTUAL ........... WELL COS'I:S ACTUAi'- . LAST BOP TEST DATE: 03/25/01 .......... 'D~i'L:9: 1,o86 ..... RUM: 9,093 DAILY: 41,13~' CUM: ' 398,960 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISORi R. LAWSON ...... Well: Beaver Creek-10 ~, Date: 29-Mar-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION AND BHA ON RACK. CLEAN PITS AND BEGIN TO BUILD NEW MUD SYSTEM. NOTE: CHANGED OUT DOUBLE GATE RAMS ON BOP. NEW RAMS ARE AUTO LOCK RAMS ,,, ,,, .... ..... .... Marathon ,,, r~pT#: 15 DATE: 03/30/01 LOCATION DAYS: 8 SPUD DAYS: 5 Oil Company '{. :E#: 8102801 GL: K,(~'' . MOC WI: WELL: Beaver Creek-lO ...RIG'._Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD)_ 2,385 . (TVD) 2,338 CSG SIZE: 7.000 CSG MD: 2,374. CSG TVD: 2,327. ~HOE TEST~ 16.40 MAX. SI 932 LINER TOP: __ PRESENT OP:RIH. TEST BOPE. P/U 6 1/8" BIT AND BHA. P/U 162 JOINTS DP AND RACK BACK. CUT AND SLIP DRILL LINE. RIH. EXECUTIVE SUMMARY (~w ............... , ............. ViS PV YP GELS WL T 7.5 30 HT FC CRC SAND SLD BENT SALT DRILLED BARITE 8.7 13513110iS1 7110.6[1581 i I 1°t32 11.2[ I 9.8 PPB 16.4 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft) BKGD CONN TRIP" M/~X 9~ ~ ~ 1 o o o o o ~k..~'~°° 1 ,~i,~ cu~ o 04~ ( BIT# SIZE TYPE OFF FTG HRS FI/HR RPM WOB IO D LB G OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: 3 STC 6 1/8" MGR52PX PDC Bit, 4 3/4" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4.3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S.135 DP, MAX PULL: ( JARS MW~ MOTOR TORQUE WEIGHT (1000) - 2.5Ill1 2.5I6,644106 1 2.5I339911 IBHA:' 20 Pu Rot So Eft- 15 ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 2,158.00 22.450 80.90 2,134.07 193.40 1Z 47 193.13 2.00 2,232.00 24.760 80.60 2,201.87 222.98 17.24 222.37 3.13 2,326.00 27.470 8'~. 70 2,286.27 264.29 23.58 263.25 2.93 ( OPERATIONS IN SEQUENCE , START END HOURS DESCRIPTION 6:00 15:30 9.50 TEST ANNULAR 250PSI/lOMIN 3000PSI/IOMIN. TEST UPPER AND LOWER TDS SAFETY VALVES, TIW, AND IBOP VALVES TO 250PSI/lOMIN 5000PSI/IOMIN. TEST UPPER AND LOWER PIPE RAMS, BLIND RAM, CHOKE AND KILL LINE VALVES, AND ALL CHOKE MANIFOLD VALVES TO 250PSl/IOMIN 5000PSI/IOMIN. PERFORM ACCUMULATOR TEST. R/U PANIC LINE. 15:30 16:00 0.50 R/D TEST STRING AND TEST PLUG. RUN WEAR BUSHING. 16:00 16:30 0.50 TEST CSG TO 1500PSI/3OMIN AGAINST BLIND RAMS. 16:30 1~:00 2.50 P/U 6 1/8" BIT AND BHA. TEST MOTOR AND IVIWD. 19:00 21:30 2.50 POOH AND CHANGE RESTRICTER AND PULSER. RIH W/BHA. TEST MOTOR AND MWD. 21:30 4:00 6.50 P/U 162 JOINTS DP AND RACK BACK. 4:00 5:30 1.50 SLIP AND CUT 156' DRILL LINE. 5:30 6:00 0.50 RIH P/U DRILL PIPE. ONGOING WORK DURING LAST 24HRS: COMPLETED MIXING NEW MUD FOR 6 1/8" SECTION. ~,FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 03/25/01 i~.:'..~'.;~.':~:~'i i::.[,~.~:..'..-:,.?....'~"!:1 WELL COSTS ACTUAL i!i ] !~.:i~i~i~:: LAST BOP TEST DATE: 03/25/01 ~=:!]~..i i:':'.:':i:.:',.ii'i~i?~,~:. MUD COSTS ACTUAL ~.:.~...,..~:..~::,?.~.,~,.,,:,,~.,. ..... ...:~..~.~.;:~::,::,~ · ..;', ':. .,:' ':,,i.""~ DAILY: 10,998 CUM: 20,091 DAILY: 38,337 CUM: 437,297 NO ACCIDENTS REPORTED TODAY DRILLING s'UPERVISO~: R. LAWSON ..... Marathon RPT#: 16 DATE: 03/31/01 LOCATION DAYS: 9 SPUD DAYS: 6 Oil Company -'Il" .:E#: 8102801 GL: K~~ MDC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 1,066 DEPTH: (MD) 3,451 (TVD) 3,342 CSG S~'ZE: 7.000 CSG MD: 2,374. CSG TVD: 2,327-'. ~HOE TEST~. 16.40 -' MAX. SI 914 LINER TOP: PRESENT OP:DRILLING AHEAD @ 3451: · .,,~..,,~ ~.,., ~,,~..,-,~,~, ,,..:~.,,.,.~..~ ~.~,,,,:,, ~.. .... =~.,~,. ,.,..::,:,~ :.~,,.,~,,. ....... ;,.,.,,, ,.-,....;;,,~;,;,,,;,....,....,,., ,.;'~'. ~.~ .,,.,,,' .~,.,'..: ~ .~".~'.~ ..... ~,~ ;.,~- ~'*.= ,,,.' =~ ~, -~=.' ,,~,~, ~,:'~,.~,',.~. ~ '. ,~ ~7,,~' RIH. DRILL SHOE TRACT. DRILL F/2385' TO 2405: PERFORM LOT. DIR DRILL AND SURVEY F/2405' TO 2980: EXECUTIVE POOH TO THE CSG SHOE. REPAIR PIPE GRIPPER ON TDS. RIH. DIR DRILL AND SURVEY F/2980° TO 3451: SUMMARY i~'*~ ~:~ '~'~ ~'., ~:~ v~-~'~,~?.,*. ~ ~,~ .=~%. ~,~ ~,, ~-~.~.,~ ~,?,~,~,, ? ~/;*,,'~? ~*. ,.1',~., · ':, ,~:?~%~ ~-~,i=,' ~..~, ~=~' ..*~. '~ '~ ~'~,' ..'.~'~;: ,~'~ *'~i.~'.'- ~.,','.~ '.,';' ~ ;**"~. - ~',,'° ~ '~" "~il '~ ~":";~'"'~ ~r'''~ =""~ "' '~** "' ~' "*' ~' ""~' ~:~' ~'' ~ '~ ~'~=~? ~'~"~'~ "*' ' ~'~ =' ~'~ (MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE 8.9 1401511911011217.211681 I I 11132 13.71 i 10.3 PPB 57.0 PPB (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbl/ft) BKGD CONN TRIP MAX 4 2 30,500 1 Idaily cum 0 03 ,,;'.,.. "'*.."~:.~'~ ~ :~ ':~:" :"~,~1' ';;~'~ ~' "' '"~'~;~': ~:',r :' 2 i "~'"";,'" ;';'""'~:;,~'~:~ .... ""'" ....... '"""~ .... ",,;"i'''''*'' ,','h"i',',,'~'; ....... ' ......... i' ' 't ' i' ° "'i'" ..... t'~";; ~'" ~'"~="': ..... "'"= '"":~ :':':' ~ :~ ~:~ ~'? :~ ~='~ ~:' E BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IO D LB G OT R CPF COMMENTS 3 I 6.125 IMGR52PX 13,451 1,066 15.75 67.7 40 I 3 18,2, CT, N,X,O, WT, DTF 29 I ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ 3 JS4579 1300 295 10 10 10 10 10 10 0.460 DP 331.0 DC 483.3 CRITDC 316.8 57.6 BHA: 3 STC 6 1/8" MGR52PX PDC Bit, 4 3/4" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869,70 DRILL PIPE DESCRIPTION: 4" 14PPP S-135 DP, MAX PULL: 303 -- (~ JARS MWD MOTOR TORQUE WEIGHT (1000) 19.0 I1 ~ 19.0 644'106 19.0 I3991 1,500f t/lbs [BHA: 20-Pu 65 Rot 65 So 65 Eft 15 (~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 3,078.00 27.140 79.80 2,954.28 608.28 87.98 602.50 0.49 3,176.00 27.550 79.40 3,041.33 653.15 96.10 646.77 0.46 3,332.00 26.910 82.50 3,180.05 724.38 107.35 717.24 1.00 ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 8:00 2.00 CONT. RIH P/U DP. 8:00 9:00 1.00 TAG UP ~ 2289'. DRILL FLOAT COLLAR @ 2290'. DRILL CEMENT IN SHOE TRACT AND SHOE @ 2374'. CLEAN OLD HOLE TO 2385'. 9:00 9:30 0.50 DRILL 6 1/8" HOLE F/2385' TO 2405'. ART .25HR, AST OHR. 9:30 10:00 0.50 CBU ~ 2405: 10:00 10:30 0.50 PERFORM LOT. 16.4PPG EMW(8. gPPG MW AND 910PSI). 10:30 11:00 0.50 DISPLACE WELL TO 8. TPPG FLO-PRO MUD SYSTEM. 11:00 11:30 0.50 REPAIR PIPE GRIPPER ON TDS. 11:30 19:30 8.00 DIR DRILL AND SURVEY F/2405' TO 2980'. ART 4.75HRS, AST .SHRS. 19:30 20:00 0.50 CBU @ 2980'. 20:00 20:30 0.50 POOH TO CSG SHOE. 20:30 23:30 3.00 REPAIR PIPE GRIPPER ON TDS. 23:30 0:00 0.50 RIH WASH DOWN LAST 50'. 0:00 6:00 6.00 DIR DRILL AND SURVEY F/2980' TO 3451'. ART 3.0HRS, AST 1.25 HRS. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 03/25/01 ;.;i~!:.:.i';~.i!';.~:i::'?.::.i MUD COSTS ACTUAL i~;~':::~.?i';.;;?~i:.;;i::='?.:i;!ii:!?;~i'~;i;'~'ii.i~;'i WELL COSTS ACTUAL;.!= :,,;...:..?~;;:.~:" ' :=":'" LAST BOP TEST DATE: 03/29/01 DAILY: 7,751 CUM: 27,842 DAILY: 64,816 CUM: 502,113 NO ACCIDENTS REPORTED TODAY DRILLING S[~PERVISOR: R. ~AWSON .... Marathon ~. RPT#: 17 DATE: 04/01/01 LOCATIO~ DAYS: 10 SPUD DAYS: 7 Oil Company ( "E#: 8102801 GL: K[ . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 1,256 DEPTH: (MD) 4,707 (TVD) 4,430 .... CSG SIZE: 7.000 CSG MD: 2,374. CSG TVD: 2,327. SHOE TEST: 16.40 MAX. SI 895 LINER TOP: PRESENT OP:DRILLING AHEAD ~ 4707: DRILL F/3451' TO 4516'. CIRC. AND WIPER TRIP TO THE SHOE. RIH AND DRILL F/4516' TO 4707'. EXECUTIVE SUMMARY [MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.0 1391 6 121111 / 13 t 7.61 76I / t t I /32 5.0 t 3.7 I 1.4 / 10.3 PPB 38.4 PPB PPB i(~OIL VVTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllff) BKGD CON', 3:RIP MAX 1:963 9.2 10;9 0.5 } 3.6 130'500I 1 [daily cum 0.02 1 I 1 [ '="- '. .......... ,,'~'..~ .i*~. .', =~ *~ '. '. i:*,, ..... ' ~'.'.; 'r '; ........... i'":',*, i ,' ~i,*'~''*' ' '* ~ ..... :~ :i:i'~=*ii~"t'~i:; ' i ............. *~ 'i~'c~* ''~ ~'"'~' ''~ *' ~' i~''~" i~*'~ ~ '~'~'~ ~''': ::~ ........ "':'~ ~"*"'~'~ ':'~' *:~'~::~ "; "''~ ' ""'"~ ~' ~";=""',~:~" ~'~ ' '*,; :':'='; ..... ~"~ ;~'~'' ~ ...... ,~ '~'*' '~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS ,( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) 3 JS4579 1600 295 101010101010 I 0.460 I DP331.0DC483.3 CRITDC334.3 58.6 I I BHA: 3 STC 6 I/8" MGR52PX PDC Bit, 4 3/4" MOTOR .SAKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4.3.5" HWDP, 4 3/4" DAILE¥ HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S.135 DP, MAX PULL: 303 ~ JARS MWD MOTOR TORQUE WEIGHT (1'000) " 37.01 37.0 [644106 ]37.0 13991 t 1,50Oft~lbs fBHA: 20 PU 80 Rot-75 So 70 Eft 15 ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. HIS E/W DOG LEG 4,493.00 19.530 87.70 4,227.71 1,222.12 166;90 1,211.49 1.97 4,587.00 18.830 87.30 4,316.49 1,252.95 168.24 1,242.35 0.76 4,684.00 17.670 84.60 4,408.61 1,283.31 170.37 1,272.64 1.48 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 21:00 15.00 DIR DRILL AND SURVEY F/3451' TO 4516' ART 7.SHRS AST 5HRS. 21:00 21:30 0.50 CBU @ 4516: 21:30 23:30 ZOO POOH TO THE CSG SHOE. 23:30 0:00 0.50 SERVICE RIG. 0:00 2:00 2.00 RIH. 2:00 3:00 1.00 MOVE CLOCK 1 HR FORWARD FOR TIME CHANGE. 3:00 3:30 0.50 CONT. RIH. WASH DOWN LAST 50'(8' PILL). 3:30 6:00 2.50 DIR DRILL AND SURVEY F/4516' TO 4707'ART IHRS AST.SHRS. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 04/01/01 .'i;:i!ili:.ili,!....,~.; ii:~. ,~:i MUD COSTS ACTUAL ~ '~,...~...:_,~.~ .... :., .~:,. ,.~"~, :.,,""~'. .... .,.~... :~,~,~..:~ .~*~' :.~ '~ .IWELL COSTS ACTUAL i"::.'~:'~"!'?i:~ LAST BOP TEST DATE: 03/29/01 DAILY: 5,298 CUM: 33,140 DAILY: 3~,911 CUM: 541,024 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. ~-AWSON " Marathon RPT#: 18 DATE: 04/02/01 LOCATIO~ DAYS: 11 SPUD DAYS: 8 Oil Company { -'E#: 8102801 GL: . K . MDC WI: WELL:_Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 878 DEPTH: (MD). 5,585 (TVD) 5,292 CSG SIZE: 7.000 CSG MD: 2,374. CSG 'FVD: 2,32~ 'SHOE TEST: 16.40 MAX. SI 895 LINER TOP: PRESENT OP:DRILLING AHEAD @ 5585'. EXECUTIVE DRILL AND SURVEY F/4707' TO 5215: CIRC. SHAKERS CLEAN. POOH AND CHANGE BIT AND MOTOR. RIH. SUMMARY DRILL AND SURVEY F/5215' TO 5585: · (:MW VIS PV YP GELS WL T 7.6 30 HT FC CEC, SAND SLD BENT SALT DRILLED BARITE · 9.0 1461 7 I 241 10 I 14 I 7'51 70] / I [ I 132 4.0 J 3.7 I / 9.7 PPB 40.4 PPB PPB oCoC WTR pH CL CA UME MUdEOSSES BKGD CONN TR P- MAX i 963 95 03 03 26 29,000 1 daily cum 002 · I{ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I O D LB GOT R CPF COMMENTS 3 6.125 IMGR52PX IS,215 2,830 29.75 95.1 40 3 18,2, CT, N,X,O, WT, DTF ~ BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP.~ 14 LY7012 2000 295 12 12 14 0.371 DP 331.0 DC 483.3 CRIT DC 360.7 I 90.0 3 JS4579 ~ f800' 295 10 10 10 10 10 10 0.460 DP 331.0 DC 483.3 BHA: 4 STC XRf5TDGPS 6 118" Bit, 4 314" MOTOR .8AKO WI6" UBHS, 6" STRING STAB, 4 314" COLLAR MWD, 4 314" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 ~ JARS MWD MOTOR TORQUE WEIGHT (1~)00) -' 44.5 I1 1 44.5 I644106 1 7.5 lET14861 1 2,00Oft/lbs IBHA:' 20 Pa 110-Rot 85 So 75 -Eft' 15 (: MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. HIS E/W , DOG LEG · 5,339.00 8.060 86.03 5,047.18 1,425.45 182.95 1,414.24 0.94 5,466.00 5.630 81.70 5,173.27 f,440.58 184.46 1,429.29 1.95 5,562.00 3.500 79.80 5,268.96 1,448.20 185.66 1,436.83 2.22 ~ OPERATIONS IN SEQUENCE .. START END HOURS DESCRIPTION 6:00 13:30 7.50 DIR DRILL AND SURVEY F/4707' TO 5215'. ART 3.2HRS AST 2.SHRs. 13:30 14:30 1.00 CIRC. SHAKERS CLEAN AND SLUG PIPE. .... 14:30 18:30 4.00 POOH. 18:30 19:30 1.00 BIO BIT#3. ED MUD MOTOR(STABILIZERS FROM MWD HAD WASHED INTO MOTOR. FOUND STABILIZER PARTS AND MUD MOTOR RUBBER IN BIT NOZZLES).. PULL MWD PROBE AND REPLACE STABILIZERS. P/U NEw MUD MOTOR AND M/U BIT #4. ADJUST AKO AND SCRIBE MOTOR AND MWD. TEST MWD AND MOTOR. 19:30 21:00 1.50 RIH TO CSG SHOE. 21:00 21:30 0.50 SERVICE RIG. 2~:30 22:30 1.00 RIH TO 5f47'. 22:30 23:00 0.50 WASH AND REAM F/5147' TO 5215'(10' FILL). 23:00 6:00 7.00 DIR DRILL AND SURVEY F/5215' TO 5585. ART 3.SHRS AST 1."5HRS. ,, ~FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 04/01/01 ..¥:...~-w ...... · ...... ., ...... WELL COSTS ACTUAL =: :'::.=' :"?' LAST BOP TEST DATE: 03/29/01 .!,~:~¥;~.~i~.,.=.,'..~= ?"?d MUD COSTS ACTUAL ?::i'.:!i.,'::' ::'*!,'.~:': :~¥"i".~i~' ~..::. ,,:. ,~:. DALLY: 5,123 CUM: 38,263 DAILY: 55,890 CUM: 596,914 NO ACCIDENTS REPORTED TODAY DRILLING sUPERVISOR: R. LAWSON .... Marathon ~_~PT#: 19 DATE: 04/03/01 LOCATION I'~AYS: 12 SPUD DAYS: 9 Oil Company ( E#: 8102801 GL: KE(~'" . MOC Wh WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 1,066 DEPTH: (MD) 6,651 (TVD) 6,357 ~:SG SIZE: 7.000 CSG M~i 2,374. CSG TVD: 2,32~' '~HOE TEST-:' 16.40 - MAX. SI 859 LINER TOP: PRESENT OP:DRILENG AHEAD @ 6651: DRILL F/5585' TO 6215: CBU. WIPER TRIP F/6215' TO 4950'. RIH. DRILL F/6215' TO 6651'. EXECUTIVE SUMMARY {O;L ~R pH Pm Pf Mf CL CA LIME MUD LOSSES ~bbllff} BKGD CONN TRIP M~ 93.2[ 10.010.6 0.6 1 3'0 ~ 29'000 I 1 daily cum 0.011 21 { 1 22 I 206 , ~,~ , , .. .... ,,.~,, ,... , . ., . ..... , ............. ,.. ., .......,2 '(- ~;. s~z~ ~.~ o~ ~m .~s ~;~,~ ..= wos ~o ~"~ ~ ~ o; . c.~ co==;.;s 4 6.125 IXR~ST~GPSI 6,651 1,436 22.50 63.8 40 10 la, a,B~A,F, 4, SD, HR 17 ~ BIT ~ SERIAL ~ PRESS. GPM JETS TFA ANNULAR VELOCI~ BIT HP~ 5 ~5916 ~ f2 ~2 14 0.37~ 4 C~012~ 2100 295 12 12 14 0.37~ DP 33~.0 DC 483.3 CRITDC 391.~ 93.0 BHA: 4 STC XRISTDGPS 6 1/8" Bit, 4 3/4" MOTOR .SAKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLOR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, ~0 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S-f35 DP, M~ PULL: 303 ~ :~.s ~w~ ~o~o. ~o.~u~ w~,~.~o0o~ ~o~.~ 1~o~o~ ~o I~~~ ~.ooo~,~~.~. =o .u .= .or-~oo so ~o ~, ~= .... ~ *~.:, ......... ~ ..... =.~,~.,. , .~ ~., ~.,. . ~,, ~.~..~.~.,,r,.,.,.~.... ~.~.,.~ .~ ~,.: ~.,.. ~.,~,~ ...... ~ ~.~.~,~ , . ., ~ .,,.~,...:~. 7~'. ~.';~ ....... ,.~,;..~ ,..,~ ...... , ..,.,~.;.=;=.~..;.,.;=~,:,;~.;,;.t*.~.;;,T.~=... ~....,.,,~.,'~,~.?,~:=,=~5.~.;;~=~.~.~,..:.:::..~,~ ~ MEA. DEPTH ANGLE DIRECTION ~D VERT. SEC. NIS E~ DOG LEG 6,347.00 0.610 183.00 6,053. 79 ~ ,454.25 ~ 80.04 f ,~3.48 0.04 6,471.00 0.850 179.60 6,177. 78 1,454.07 178.46 I,~3.45 0.20 6,595.00 f.020 171.80 6,30f. 76 1,454.03 176.45 1,~3. 61 0. ~ 7 ( OPE~TIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 ~6:30 ~0.50 DIR DRILL AND SURVEY F/5585' TO 62~5'. ART 8HRS AST .SHRS. ~6:30 ~7:00 0.50 CBU ~ 6215' AND SLUG PIPE. ~7:00 ~9:00 ZOO POOH F/62~5' TO 6087'. WASH AND REAM TIGHT SPOTS F/6087' TO 5907~ POOH F/5907' TO 4950'. RIH(NO FILL). ~9:00 6:00 11.00 DIR DRILL AND SURVEY F/6215' T0 6651'. ART ~HRS AST OHRS. AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/0~/01 · MUD COSTS ACTUAL [[.[:~ ::.::~.:~.~.:~;=.~=~.':h:.;.~.:?%:.=~..:~. WELL COSTS ACTUAL ~;..~= :;=~;:..~.~ LAST BOP TEST DATE: 03/29/01 -- ~: ~.o~ CUM: ~6.~0~ e~v: ~.~oo CUM: 6~.~ NO ~CC~E. rS ;;PO;rE~ ~0~ Marathon RPT#: 20 DATE: 04/04/01 LOCATION pAYS: 13 SPUD DAYS: 10 Oil Company . 8102801 GL: KB: MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 255 DEPTH: (MD) 6,906 (TVD) 6,613 CSG SIZE: 7.000 CSG MD: ~374. CSG TVD: 2,32~[' SHOE TES:I:i 16.40 - MAX. SI 859 LINER TOP: PRESENT OP:RIH @ 6400'. DRILL AND SURVY F/6651' TO 6906: POOH. TEST BOPE. RIH TO CSG SHOE. SLIP AND CUT DRILL LINE. EXECUTIVE CONT. RIH. SUMMARY ~'~ ........ ~'"'"' ....... '~'~;' ~'~ "'"'~<"~"T=vl~ ......... ~'*~ '~a ";~1~' '~'~ ~ ............ "'~;'"="~ ..................... iv ...... "'i' ' .......... ;'"' *~ '~*= '~' ........ i ................ ~=""'"~'"' ii ............ '~' ~';' ':~ ~' ? "~ ............. ~i'~ '~=' ~ '~ '*: ~" ....... "~ "* <~; ............. ............ *' ~" *' "=;' "~"=i*'*' '" (~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE · 9.a 1451 9 127110 1 1517.01821 I I I I I32 5.0 I 5.8 I I 9.1 PPB 58.2 PPB PP- (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllftI BKGD CONN TRIP MAX 194.2 9.5 10.3 o.a 1 2.7 t28,000I 1 ~ Ida"y cum 0.01 I .~, t l ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB GOT R CPF COMMENTS ~· 5 6.125 IXR15TDGPSI 7,632 726 19.50 37.2 350 14 6,6, WT',A,E, 2, LT, HR 33 (~ BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCiTY BIT HP~ 4 LY7012 2300 295 12 12 14 0.371 DP 331.0 DC 483.3 CRIT DC 384.7 93.0 5 I_X5916 2400 295 12 12 14 0.371 DP 331.0 DC 483.3 CRIT DC 384. 7 93.0 BHA: 5 STC XR15TDGPS 6 9/8" Bit, 4 3/4" MOTOR .8AKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIP-~ ~ESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 ........ I~ JARS MWD MOTOR TORQUE WEIGHT (1000) 76.0 I1 1 76.o 1644106 1 39.o IEr148~1 1 6,000~Ib, fB.A:' 20 Pa 1~5-Rot 100 So 75 E, 15 ,~ ~ :. ( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 6,595.00 1.020 171.80 6,301.76 1,454.03 176.45 1,443.61 O. 17 6, 684.00 1.030 194.30 6,390. 75 1,453. 79 174.89 1,443.53 0.45 6,852.00 0.740 291.50 6,558.73 1,452.31 173.82 1,442.15 0.80 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 13:00 7.00 DIR DRILL AND SURVEY F/6651' TO 6906'. ART 5. SHRS AST .SHRS. 13:00 14:00 1.00 CIRC. SHAKERS CLEAN @ 6906'. 14:00 16:00 ZOO B/R 6906' TO 6844: POOH F/6844' TO 6720: B/R F/6720' TO 6038'(TIGHT SPOTS). 16:00 20:00 4.00 SLUG PIPE AND POOH. BIO BIT. 20:00 20:30 0.50 PULL WEAR BUSHING. 20:30 0:00 3.50 TEST UPPER PIPE RAMS, LOWER PIPE RAMS, BLIND RAMS, ALL CHOKE MANIFOLD VALVES, UPPER AND LOWER TOP DRIVE VALVES, TIW AND IBOP VALVES, CHOKE AND KILL LINE VALVES TO 250PSl/SMIN 5000PSl/SMIN. TEST ANNULAR TO 250PSl/SMIN 3000PSl/SMIN. 0:00 0:30 0.50 RID TEST PLUG. 0:30 ~:30 1.00 IVl/U BIT#5. TEST MUD MOTOR AND MWD. 1:30 2:30 1.00 RIH TO 2370'. 2:30 4:00 1.50 SLIP AND CUT DRILL LINE. 4:00 4:30 0.50 SERVICE RIG. 4:30 6:00 1.50 CONT. RIH. AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/0~/01 MUD COSTS ACTUAL WELL COSTS ACTUAL LAST BOP TEST DATE: 04/03/01 · . . D~AILY: 5,253 CUM: 51,562 DAILY: 42,031 CUM: 693,346 NO ACCIDENTS REPORTED TODAY DRILLING S'I~PERVISOR: R. L"AWSON ..... Marathon :.,RPT#: 2t DATE: 04/05/01 LOCATION..DAYS: 14 SPUD DAYS: Oil Company ~ "#: 8102801 GL: Kl (~ . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 726 DEPTH: (MD)_ 7,632 (TVD) 7,339 ~:SG SIZE: 7.000 CSG M~)'~ 2,374. CSG TVD: 2,32~. ~HOE TEST: 16.40 MAX. SI 847 LINER TOP: PRESENT OP:DRILLING AHEAD @ 7632'. CONT. RIH. W/R 6715' TO 6906'. DRILL F/6906' TO 7480; TROUBLE SHOOT RIG POWER FAILURE. DRILL EXECUTIVE F/7480' TO 7632: SUMMARY .... · , ',, ,, ,' 4' ' .... ~" ......... '~ "'" ' "' .... ''1' ' ~ ' ' .... ' ""' ' '1' ' ' .......... ' ' " CMW ws PV YP GELS WL T 7.S 30 HT rC CEC SAND S,b BE.T SALT DRILLED'" BARITE 9.4 1471 101251 10l 16i6.41101l / I I 2 I32 5.0 I 6.3 I I 9.1 PPB 60.9 PPB PPB OIL WTR pH 'Pm Pf Mf CL CA LIME MUD LOSSES (bbllft [~,~]193 7 9.0 1 0.1 0.1 1 1.9 28,000I! I'daily cum 0.01 I (~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB IO D LB G OT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) 5 I. X5916 2400 295 12 12 14 0.371 DP 331.0 DC 483.3 CRIT DC 384.7 93.0 BHA: 5 STC XR15TDGPS 6 1/8" Bit, 4 3/4" MOTOR .SAKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, '869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 ;(~ JARS MWD MOTOR TORQUE WEIGHT (1-000) - 98.0 I1 98.0 644106 61.0 ET14861 6,000f t/lbs BHA: 20 PU 120 Rot 105 So- 90 Eft ~5 I( MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 7,359.00 1.210 233.30 7,065.60 1,441.37 171.33 1,431.40 0.43 7,483.00 1.830 229. 60 7,189.56 1,438.62 7,607.00 O. 680 245.90 7,3 ~ 3.53 1,436.29 167.68 1,426.67 0.96 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:30 0.50 CONT. RIH. 6:30 7:00 0.50 W/R F/6715' TO 6906'. 7:00 23:30 16.50 DIR DRILL AND SURVEY F/6906' TO 7480'. ART 14.0HRS AST 1.SHRS. 23:30 1:00 1.50 RIG POWER SHUT DOWN WHILE DRILLING. SET RIG TO MANUAL OPERA TION. PICK UP !AND RACK BACK 1 STAND CIRCULATE AND ROTATE WHILE TROUBLE SHOOT RIG POWER SYSTEM. HAD TO RESEAT GENIUS CARD IN THE DRILLERS CONSOLE. 1:00 6:00 5.00 DIR DRILL AND SURVEY F/7480' TO 7632'. ART 3. SHRS AST.SHRS. / ~,FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/0~/01 ~" ' t" ...... D =;' ~:?,~,.:~ "..'~.~¥~..~:: :: MU COSTS ACTUAL [?:~. =~, ,::"~;i'~'~ ::' ";~ .,-~ ,...:: .. ,: '.~!:~'¥~!~:~'~?~:';~;~.%~ :~ ~*' ..:'1 WELL COSTS ACTUAL i~,,=::.~::..~ '." .' ~:,' '~. ~.~.~.~-.~;- I ..... . . DAILY: 5,202 CUM: 56,764 DAILY: 44,646 CUM: 727,992 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR': R. LAWSON - Marathon ~RPT#: 22 DATE: 04/06/01 LOCATION .nAYS: 15 SPUD DAYS: 12 Oil Company ( #: 8102801 GL: KB.(' :. MDC WI: WELL: Beaver Creek-lO .... RIG:_Glacier Drilling Rig I FTG: 318 DEPTH: (MD) 7,950 (TVD) 7,632 CSG SIZE: 7.000 CSG.MD: 2,374. CSG TVD: 2,32~i' ~HOE TES~' 16.40 "MAX. SI 835 LINER TOP: PRESENT OP:DRILLING AHEAD ~ 7950: DRILL F/7632' TO 7788[ CIRC. FOR BIT TRIP. POOH. CHANGE OUT BITS. RIH. DRILL F/7788' TO 7950: EXECUTIVE SUMMARY (,MW VIS "V Ye GELS WL T 7.5 30 .T FC CEC SAND SLD BENT SALT DRILLED BARITE (~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES..(bbllft) BKGD CONN TRIP MAX 92.71 8.7 }0.1 0.1 1 1.8 128,000I 1 daily cum 0.01 33 I ] 33 I 186 ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS 5 6.1 5 IXRISTDGPSI 7,788 882 24.5O 36. O 14 16,6, arr, a,E, 2,Lr, HR 3O ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) 6 LY0226 2350 295 12 14 14 0.411 DP 331.0 DC 483.3 5 LX5916 2500 295 12 12 14 0.37~ DP 331.0 DC 483.3 CRIT DC 373.3 95.0 BHA: 6 STC XR2OHTDGPS 6 I/8" Bit, 4 3/4" MOTOR .SAKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIP-E bESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 ( JARS MWD MOTOR TORQUE WEIGHT (1-000) '" 112 0I1 1 112 0 16441061 75 0 IET14861i 7,500 fi/lbs[BHA' Pu 130 So 100 ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. HIS E/W DOG LEG 7,607.00 0.680 245.90 7,313.53 1,436.29 167. 68 1,426. 67 0.96 7, 732.00 0.860 240.50 7,438.51 1,434. 73 166.92 1,425.17 O. 16 7, 857. O0 1.030 258. 70 7, 563. 50 1,432. 75 166. 23 1,423. 25 0. 27 ( OPERATIONS I, SEQUENCE START END HOURS DESCRIPTION 6:00 12:30 6.50 DIR DRILL AND SURVEY F/7632' TO 7788'. ART 5.5HRS AST OHRS. 12:30 13:30 1.00 CIRC. SHAKERS CLEAN. 13:30 15:30 2.00 POOH F/7788' TO 7354'. B/R F/7354' TO 7324'(TIGHT HOLE). POOH F/7324' TO 7161. B/R F/7161' TO 69f3'(TIGHT HOLE). PUMP OUT F/6913' TO 6785'(TIGHT HOLE). POOH F/6765' TO 6412'. 15:30 19:00 3.50 SLUG PIPE AND POOH(HOLE TOOK 11 BBLS MUD OVER DISPLACEMENT). 19:00 19:30 0.50 BIO BIT~ AND M/U BIT#6(OBSERVED FLUID LEVEL TO BE STATIC WHILE CHANGING BITS) 19:30 21:00 1.50 TEST MWD AND MOTOR. RIH TO 2370'. 21:00 21:30 0.50 SERVICE RIG. 21:30 0:30 3.00 CONT. RIH TO 7788(TAGGED FILL @ 7782' W/R TO 7788'). 0:30 6:00 5.50 DIR DRILL AND SURVEY F/7788' TO 7950'. ART 5.0 HRS AST OHRS. AFL: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/01/01 .. MUD COSTS ACTUAL .. WELL C(~'~;i'~"A~T~I.[.-L- ....... LAST BOP TEST DATE: 04/03/01 ...... I~AIL~'i ' ~,~'43 ..... -~'bM: ~,8o~ DAILY:"-,~;[,~ ...... '~'U-~-i' ~'~,"~'~ ' NO ACCIDENTS REPORTED TODAY DRILLING sUpERVISOR: R. LAWSON "' Marathon , .r~pT#: 23 DATE: 04/07/01 LOCATION ..r~AYS: 16 SPUD DAYS: 13 Oil Company ( 8102801 GL: KE ~ MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 550 DEPTH: (MD) 8,500 (TVD) 8,162 CSG SIZE: 7.000 CSG MD'~ 2,374. CSG TVD: 2,327. ~;HOE TEST: 16.40 MAX. SI 853 LINER TOP: PRESENT OP:DRILLING AHEAD @ 8500'. DRILL F/7950' TO 8069: CHENGE SWAB ON MUD PUMP. DRILL F/8069' TO 8418: CIRC. WHILE CHANGE EXECUTIVE HYDRAULIC PUMP ON MUD PUMP #2 MOTOR. DRILL F/8418' TO 8500. SUMMARY ~MW VIS PV YP GELS WL T 7.6 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.4 1431 9 1211 12 / 1715.811041 / I I I /32 5.0 I 6.4 I t 8.7 PPB 65.3 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft} BKGD CONN TRIP MAX ,~l~ !J~,~93 6 95 01 01 1 13 27,000 Idaily cum 001 ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT 6 LY0226 2400 295 12 14 14 0.411 DP 331.0 DC 483.3 CRIT DC 344.3 76.2 BHA: 6 STC XR2OHTDGPS 6 1/8" Bit, 4 3/4" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869. 70 DRILL PIPE DESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 ~ JARS MWD MOTOR TORQUE WEIGHT (1'000) - 129.5 111 129.5I6~644106 1 92.5],ET14861! 7,00Oft~lbs~BHA:' 20 Pu 160-Rot 130 So- 100 Eft 15 ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. ElS E/W DOG LEG 8,235.00 0.720 182.60 7,941.45 1,428.30 163.94 1,419.01 0.32 8,360.00 0.840 195.30 8,066.44 1,427.85 162.27 1,418.73 0.17 8,485.00 1.010 189.10 8,191.42 1,427.24 160.30 1,418.32 O. 16 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 10:00 4.00 DIR DRILL AND SURVEY F/7950' TO 8069'. ART 4.0HRS AST OHRS. 10:00 10:30 0.50 CHANGE SWAB ON #2 MUD PUMP. 10:30 0:00 13.50 DIR DRII. L AND SURVEY F/8069' T0 8418'. ART gHRS AST IHRS. 0:00 4:00 4.00 CIRC. WHILE CHANGE OUT HYDRAULIC PUMP ON #2 MUD PUMP MOTOR(RUPTURED SEAL IN HYDRAULIC PUMP). 4:00 6:00 2.00 DIR DRILL AND SURVEY F/8418" TO 8500'. ART 2HRS AST OHRS. · AFL: DH TST/CSG · COMP TOT LAST PIT DRILL DATE: 04/01/01 ~. %~ ~ ~ ~ ,:::~ .~[. ;. ~. ::. :,~:.~":~:~":=~: ~:~,'~i'~1 MUD COSTS ACTUAL~:~.:. :~.:.~ ~: ~"~'~". ;,...~..:i.~,:i.:~i!.:..'~· ...... ~![~::~';.".~ :i;~.iI .... WELL COSTS ACTUAL !?.ii[,.i! i.i:.i~ LAST BOP TEST DATE: 04/03/01 DAILY: 6,198 CUM: 64,005 DAILY: 43,914 CUM: 816,143 NO ACCIDENTS REPORTED TODAY . DRILLING S'I~PERVISOR: R. LAWSON '" Marathon -.RPT#: 24 DATE: 04/08/01 LOCATION.DAYS: 17 SPUD DAYS: 14 Oil Company ( E#: 8102801 GL: Kt /. MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 122 DEPTH: (MD) 8,622 (TVD) 8,328 CSG SIZE: 7.000 CSG MD: 2,374. CSG TVD: 2,32~" ~HOE TEST~ 16.40 MAX. SI 811 LINER TOP: PRESENT OP:DRILLING AHEAD ~ 8622'. DRILL F/8500' TO 8587'. CBU AND POOH. CHANGE BIT. RIH. DRILL F/8587' TO 8622'. EXECUTIVE SUMMARY (~MW VIS PV YP GELS WL 'T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.7[461,i21114~2115.71901 / I 12132 6.3 ]8.9I I 8.1 PPB 89.4 PPB PPB (OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllft ..... .... o,, ...... cum oo, { BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB G OT R CPF COMMENTS 6 6.125 IXR2OHTDGFI 8,587 799 24.50 32.6 40 15 4,4, WT, A,E, I, SD, HR ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP 7 LY0220 2450 295 12 14 14 0.41 6 LY0226 2450 295 12 14 14 0.411 DP 331.0 DC 483.3 CRITDC 348.5 79.1 BHA: 7 STC XR2OHTDGPS 6 1/8" Bit, 4 314" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 869.70 DRILL PIPE DESCRIPTION: 4" 14PPF S.135 DP, MAX PULL · 303 ..... (~ JARS MWD MOTOR TORQUE WEIGHT (1000) 140.0 I1 1 140.0 I644106 103 0 ET14861 1 9,000 ~/Ibs fBHA'- 20 Pu 160 { MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 8,485.00 1.010 189.10 8,191.42 1,427.24 160.30 1,418.32 O. 16 8,531.00 1.240 200.00 8,237.41 1,426.92 159.44 1,418.08 0.68 8,609.00 1.260 190.00 8,315.40 1,426.32 157.80 1,417.65 0.28 { OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 6:30 0.50 CIRC W/PUMP~1 WHILE CHANGE SWAB#2 IN MUD PUMP~2. 6:30 10:00 3.50 DIR DRILL AND SURVEY F/8500' TO 8587'. ART 3.75HRS. 10:00 10:30 0.50 CIRC. WITH PUMP#2 WHILE CHANGE SWABft3 IN MUD PUMP#1. 10:30 11:30 1.00 CIRC. SHAKERS CLEAN. 11:30 14:30 3.00 B/R F/8587' TO 8541'. PULL F/8541' TO 8357'. B/R F/8357' TO 7728'(TIGHT HOLE). PUMP OUT F/7728' TO 7541'. 14:30 15:00 0.50 CBU ~ 7728'. 15:00 20:30 5.50 SLUG PIPE AND POOH(SLM)(TOOK 11BBLS OVER DISPLACEMENT). 20:30 21:30 1.00 L/D MWD PROBE AND CHANGE BATTERY. B/O BIT#6 AND M/U BIT#7. P/U MWD. 21:30 22:00 0.50 RIH TO 2370; 22:00 0:00 2.00 SERVICE RIG. ADJUST BRAKE BANDS. PUMP UP PRESSURE SENSOR FOR MUD PUMP. 0:00 1:30 1.50 SLIP AND CUT DRILL LINE. ,,, 1:30 4:00 2.50 RIH AND TAG FILL ~ 8577'(10' FILL). WASH TO 8587; 4:00 6:00 2.00 DIR DRILL AND SURVEY F/8587' TO 8622'. ART I.SHRS. ~,FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 .~:?.~,,!~',:, ¥,.~:.,:: i,.~'.,,. ,,;~.: ,.. :~.*.,: ~.~ :~ ~, ..- ...... i., .~..~. :~.,+,'?::~'~:~.:~.[::*,~:":.d MUD COSTS ACTUAL :'~.~:'::.: :*~;~: ,:~.' ~:.~='.~,:,:~:;..~:..':~*;'*~..'..I WELL COSTS ACTUAL .~?:ii!?*:':~; ' LAST BOP TEST DATE: 04/03/01 DAILY: 2,558 CUM: 66,563 DAILY: 30,281 CUM: 846,424 NO ACCIDENTS REPORTED TODAY .............. DRILLING S'~PERVISOR: R. LAWSON ...... Marathon ?~T#: 25 DATE: 04/09/01 LOCATION.nAYS: 18 SPUD DAYS: 15 Oil Company { ;# 8102801 GL: KB,{ MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 232 DEPTH: (MD) 8,854 (TVD) 8,560 CSG SIZE: 7.000 CSG MD~. 2,374. CSG TVD: 2,327. SHOE TEST: 16.40 MAX. SI 823 LINER TOP: PRESENT OP:R/U SCHLUMBERGER. DRILL F/8622' TO 8854: CIRC. SHAKERS CLEAN. SHORT TRIP TO 6984: RIH. CIRC. COND MUD. POOH. R/U EXECUTIVE SCHLUMBERGER FOR OH LOGGING. SUMMARY (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.6 1411 9 1201' / ==l~.olr==t / J 1 2/32 7.5 ] 6.7 1 2.7 i 9.8 PPS 51.5 PPB 11.2 PPB i~OIL VVTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft! BKGD CON, TRIP ' MAX 93 3 8 7~L~,O 1 0 1 1 1 1 30,000 I Idaily cum 0 01j, 120 120 ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB O OT R CPF COMMENTS 6 6.125 I×R2OHTDGFI 8,587 799 24.50 32.6 40 15 4,4, WT, A,E, 1, SD, HR 32 (~ BIT # SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP 7 LY0220 2450 295 12 14 14 0.411 DP 331.0 DC 483.3 CRIT DC 332.2 78.3 6 LY0226 2450 295 12 14 14 0.411 DP 331.0 DC 483.3 CRIT DC 348.5 79.1 BHA: 7 STC XR2OHTDGPS 6 I/8" Bit, 4 3/4" MOTOR .8AKO WI6" UBHS, 6" STRING STAB, 4 3/4" COLLAR MWD, 4 3/4" Length: PULSER SUB, 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21-3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38.B, !869.70 DRILL PIPE DESCRIPTION: 4" 14PPF S-135 DP, MAX PULL: 303 lC JARS MwD MOTOR TORQUE WEIGHT (1'~)00) .... 1585]11! 1585!644106 1 1215I~ET14861[ 9,000 fi~lbsIIBHA' 20 Pu 160 Rot 130 So 100 Eft 15 (~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 8,609.00 1.260 190.00 8,315.40 1,426.32 157.80 1,417. 65 0.28 8,797.00 1.270 208.20 8,503.35 1,424.60 153.93 1,416.30 0.21 8,854.00 1.280 208.20 8,560.34 1,423.89 152.81 1,415.70 0.02 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 15:00 9.00 DIR DRILL AND SURVEY F/8622' TO 8854'. ART 8.25HRS. 15:00 16:00 1.00 CIRC. AND CONDITION MUD FOR SHORT TRIP. 16:00 18:30 2.50 POOH TO 6984: 18:30 19:30 1.00 RIH TO 8854'. 19:30 21:30 ZOO CIRC. AND CONDITION MUD. PUMP HI-VIS SWEEP AND CIRC. OUT. 21:30 22:00 0.50 POOH TO 8481: 22:00 4:30 6.50 PUMP SLUG. POOH(TOOK 16BBLS OVER DISPLACEMENT). 4:30 5:00 0.50 ED MWD PROBE AND PULSER SUB. BIO BIT. 5:00 6:00 1.00 R/U SCHLUMBERGER. SAFETY MEETING PRIOR TO RUNNING OH LOGS. ~,FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 DAILY: 5,276 CUM: 71,839 DAILY: 50,595 CUM: 897,019 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. LAWSON Marathon RPT#: 26 DATE: 04/10/01 LOCATION I)AYS: 19 SPUD DAYS: 16 Oil Company { #: 8102801 GL: KB . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: DEPTH: (MD) 8,854 (TVD) 8,560 CSG SIZE: 7.000 CSG MD-~ --2,374. CSG TVD: 2,327'-' '~HOE TEST': 16.40 MAX. SI 805 LINER TOP: PRESENT OP:RUNNING CMR LOG. RUN SCHLUMBERGER AIT/HGND/HRMS LOG. WIPER TRIP. RUN DSl LOG. EXECUTIVE SUMMARY ~ ~'"'~'¥'"~' '~'~'~"~"~'~"~"~'~ ~'~"~°~ '"~" ~¢ '~'""'~'*~"¢~'¢ *'~"~'~ ~ *~'~'~:~:~' ~' "'~"':'~:":~"~'~'~'~ '~ ~ ~ "'~"~"~'~"~':~'*~*" "~'~:~'~':~:~ ....... ~? ~' "':"~'"~? ~'~'"*~'~ F '=~ '"'T ........ i' ..... I¥ ~'°~ '~'' ~' ~i~*'*~' (MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.8 1491 11 J 211 20 / 3015.4118°1 I I I 2 /32 9.0 t 7.7 I 3.6 / 9.7 PPB_ 58.9 PPB 12.8 PPB (OIL WTR pH Pm. Pf Mf CL CA LIME MUD LOSSES lbbllftt BKGD CONN TRIP MAX 92.3I 8.5 1 '.~01 0.1 1 1'0 30,000 1 ldaily cum 0.01 I 1 140 I 140 .,~ ~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB lCD L B G CT R CPF COMMENTS ( BIT# SERIAL# PRESS· GPM JETS TFA ANNULAR VELOCITY BIT HP~ 7 LY0220 2450 295 12 14 ~4 0·411 DP 331.0 DC 483.3 CRIT DC 332.2 78.3 BHA: 8 STC XR2OHTDGPS 6 1/8" Bit, 4 3/4" MOTOR .aAKO W/6" UBHS, 6" STRING STAB, 4 3/4" MONEL COLLAR, Length: 4-3·5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 21.3.5" HWDP, X/O 3 1/2" IF-P X 4" HT38-B, 867.11 DRILL PIPE DESCRIPTION: 4" 14PPF S.135 DP, MAX PULL: 303 ~ JARS MWD MOTOR TORQUE WEIGHT (1-000) - 160.5 I1 1 160.5 1644108 1 123.5 IET14861 1 IAEA:- 20 -Pa- 160 -Rot 130 So- 100 Eft- 15 ( MEA. DEPTH A~I~LE DIRE'CTiON TVD VERT. SEC. NIS I~/W DOG L~=G 8,854.00 1.280 208.20 8,560.34 ~ ,423.89 152.81 1,415. 70 0.02 !( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 10:30 4.50 RIH W/AIT/HGNS/HRMS TO 8854'(LOGGERS TD 8855'). HAD SEVERAL TIGHT PULLS WHILE LOGGING OUT AND LOST 1-5.5" OD RUBBER STANDOFF IN HOLE(HOLE TAKING ·SBBUHR-1BBUHR). 10:30 13:00 2.50 CALIPER SCHLUMBERGER CMR TOOL AND FIND THAT OVERBODY DECENTRALIZER MAKES TOOL TOO LARGE TO RUN IN A 6 1/8" BOREHOLE. WAIT ON SCHLUMBERGER DSl TOOL AND INLINE SLIMHOLE DECENTRALIZER. '13:00 17:00 4·00 RIH W~ 6 t/8" BIT TO 7" CSG SHOE AND BREAK CIRCULATION. CONT. RIH TO 8854'. '17:00 19:00 2.00 CIRC. AND CONDITION MUD. SLUG PIPE· ~9:00 0:30 5.50 POOH. WORK TIGHT SPOTS @ 8~25' AND 7395'(TOOK 13 BBLS OVER DISPLACEMENT).. 0:30 1:00 0.50 R/U SCHLUMBERGER. 1:00 5:30 4.50 RUN DSI LOG. ED DSI LOG(LOSSES TO HOLE MINIMAL). 5:30 6:00 0.50 RUN CMR LOG. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 04/07/01 MUD COSTS ACTUAL :, ~ ;-~;,.I,, .~ :~ ,:-.,,; · ~.: ..~ ,~ :: ;";.,:'~ :: i: :::i ;.. ! ...:..... :..;,~ :;.;!: ,.;~,:,:~;..N.:;.,:~:.~ ,1 WELL COSTS ACTUAL i LAST BOP TEST DATE: 04/03/01 .... ,, .~.: ~ :,,, .~,¢. .. ~,{..;;::~..'. ~' ,. DAILY: 3,279 CUM: 75,118 DAILY: 23,199 CUM: 920,218 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. LAWSON Marathon RPT#: 27 DATE: 04/11/01 LOCATION DAYS: 20 SPUD DAYS: Company ~ ~,' /t: 8102801GL: KB MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 8,854 (TVD) 8,560 CSG SIZE: 7.000 CSG M~: 2,374. CSG TVD: 2,327. ~HOE TEST: 16.40 MAX. SI 835 LINER TOP: PRESENT OP:POOH ED DP. RUN CMR LOG. R/D LOGGERS. TEST BOPE. M/U BIT AND RIH. CIRC. COND MUD. POOH ED DP. EXECUTIVE SUMMARY ws .v ~ ~93 21 85 ~ 0 ~ O ~ 1 0~99 ~ ~,29,400 daily cum 001 ~ BITg SIZE ~PE OFF FTG HRS FT/HR RPM WOB I O D LB G OT R CPF COMMENTS ( BIT~ SERIAL~ PRESS. GPM JETS TFA ANNU~RVELOCI~ BIT HP) BHA: 9 STC XR2OHTDGPS 6 ~/8" Bit, 4 3/4" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 4 3/4" MONEL COLLAR, Length: 4-3.5" HWDP, 4 3/4" DAILEY HYD/MECH JARS, 2~-3.5" HWDP, ~0 3 1/2" IF-P X 4" HT38-B, 867.11 .. DRILL PIPE DESCRIPTION: 4" f4PPF S.~35 DP, M~ PULL: -- ~ JARS MWD MOTOR TORQUE WEIGHT (~ 000) 165.5 ~ 165.5 644~06 ~ ~28.5 ET~486~ BHA: 20 -Pu Rot So -Eft ( MEA. DEPTH ANGLE DIRECTION ~D VERT. SEC. N/S E~ DOG LEG 8,609.00 ~.260 ~ 90.00 8,3 ~ 5.40 1,426.32 157.80 1,4 ~ 7. 65 0.28 8,797.00 1.270 208.20 8,503.35 1,424.60 ~53.93 1,4~6.30 0.2f 8,854.00 1.280 208.20 8,560.34 1,423.89 152.8 ~ 1,415.70 0.02 ( O.E iO.S SE UE.CE STA~ EN~ HOUES DESCRIPTION 6:00 12:00 6.00 CONT. RUN CMR LOG. f2:00 12:30 0.50 ~D SCHLUMBERGER. f2:30 18:30 6.00 TEST UPPER PIPE RAMS, LOWER PIPE RAMS, BLIND RAMS, ALL CHOKE MANIFOLD VALVES, UPPER AND LOWER TOP DRIVE VALVES, TIW AND IBOP VALVES, CHOKE AND KILL LINE VALVES TO 250PSI/SMIN 5000PSl/SMIN. TEST ANNULAR TO 250PSI/SMIN 2500PSl/SMIN. f8:30 22:30 4.00 M/U BIT AND RIH. 22:30 3:30 5.00 CIRC. AND COND MUD. 3:30 4:00 0.50 SPOT 3BBLS f6.0PPG PILL ON BOSOM. 4:00 4:30 0.50 RACK BACK 3 STANDS TO 8668~ 4:30 6:00 f.50 SLUG PIPE AND POOH(RACK BACK FIRST 30 STANDS AND THEN BEGIN TO POOH UD DP). ..... AFE: DH TSTICSG CO~P TOT LAST PIT D~ILL DATE: 04/07/01 f~.?~?.::~E...:.. ...... ::',:.. ..... :::, MUD- COSTS ACTUAL_ ._ ~=,.~'~E.::=?;~'E?~?=....=?::'~':.'='::.~':='i~: :.~...~.~:=::~.~., ...~'~:...~ WELL COSTS ACTUAL'"'~.:.:.' .:.::~. LAST BOP TEST DATE: 04~fO/Of DAILY: 713 CUM: 75,831 DAILY: 15~,778 ~U~: f, 07~,9~ NO ACCIDENTS REPORTED TODAY ~ILLING sUpEEVlSOE: ~. LAWSON Marathon ,-. r~PT#: 28 DATE: 04/'/2/01 LOCATIO~ r~AYS: 2'/ SPUD DAYS: 18 Oil Company i E#: 8'/02801 GL: K[~ MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig '/ FTG: 0 DEPTH: (MD) 8,854 (TVD) 8,560 CSG sIZE: 3.500 CSG MD: 8,818. CSG TVD: 8,524. '~;HOE TES~: - MAX. SI 0 LINER TOP: PRESENT OP:RUNNING 3 '//2" PRODUCTION CSG. POOH ED DP AND BHA. CHANGE TOP PIPE RAMS TO 3 1/2". RUN 3 1/2" PRODUCTION CSG. EXECUTIVE SUMMARY {~MW VIS PV YP GELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE 9.6 1471 1012°1 16 / 2515.8. ! 661 ,/, I I 2 /32 7.5 I 6.7 I 2.2 / 9.6 PPB 55.7 PPB 5.6 PPB o~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES (bbllft! BKGD CONN TRIP MAX u 93 3 8 3 0 0 0 0..[~ 0 9,.~29,500 1 daily -cum 0 01 BIT"# { SIZE TYPE OFF FTG HRS FT/HR RPM WOB IOO LB GOT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: 9 STC XR2OHTDGPS 61/8" Bit, 43/4" MOTOR .SAKO W/6" UBHS, 6" STRING STAB, 43/4" MONEL COLLAR, Length: 4-3.5" HWDP, 43/4" DAILEY HYD/MECH JARS, 2'/-3.5" HWDP, X/O 31/2" IF-P X 4" HT38-B, 867.11 DRILL PIPE DESCRIPTION: 4" '/4PPF S-135 DP, MAX PULL: { JARS MWI~ MOTOR TORQUE WEIGHT (1000) " '/76.0Iff 1 '/76.0I~644'/06~ '/39.01. O IJET1486'/! IEBHA: 20 Pu Rot 'So Eft { MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. N/S E/W DOG LEG 8,609.00 1.260 '/90.00 8~315.40 '/,426.32 '/57.80 '/ ,417.65 0.28 8,797.00 '/.270 208.20 8,503.35 '/,424.60 '/53.93 1,416.30 0.21 8,854.00 1.280 208.20 8,560.34 '/,423.89 152.8'/ 1,415. 70 0.02 (~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION ...... 6:00 '/6:30 10.50 POOH L/D DP. RIH W/ 33STANDS DP THAT WAS RACK BACK IN DERRICK. POOH L/D DP, BHA, AND BIT. 16:30 19:00 2.50 PULL WEAR BUSHING. RUN TEST PLUG ASSY. CHANGE OUT TOP PIPE RAMS TO 3 '//2% PERFORM BODY TEST TO 250PSl/SMIN 3000PSI/5MIN AGAINST ANNULAR. R/D TEST PLUG ASSY. 19:00 20:00 1.00 CHANGE TO LONG BAILS AND 3 1/2" CSG ELEVATORS(HOLE TAKING 1BBUHR LOSSES). 20:00 21:30 1.50 R/U WEATHERFORD CSG RUNNING TOOLS. M/U CSG HANGR ASSY TO LANDING JOINT AND ED. M/U 3 '//2" 8RD X 4" HT-38 X/O TO TIW VALVE. FUNCTION VALVE AND LEAVE IN OPEN POSITION ON RIG FLOOR. 2'/:30 22:00 0.50 P/U 3 1/2" CSG JOINT#1 AND BAKERLOK FLOAT SHOE. TEST FLOAT. P/U JOINT#2 AND BAKERLOK. P/U FLOAT COLLAR AND BAKERLOK. P/U JOINT#3 AND BAKERLOK. TEST FLOATS. , 22:00 22:30 0.50 SAFETY MEETING PRIOR TO RUNNING CASING. 22:30 3:00 4.50 RIH W/'/5 JOINTS 3 '//2" 9.3PPF L-80 CSG TO THE CSG SHOE. 3:00 4:30 1.50 WHILE ClRCULATE A T SHOE R/U SHEAVE FOR RUNNING THE INJECTION CONTROL LINE. M/U 3 1/2" BUTT X 3 '//2" IF Y,/O TO PLUG DROPPING ASSY AND ED. AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 ....~,...: ...... . .... WELL COSTS ACTUAL :...i~!.:'~.'i LAST BOP TEST DATE: 04/10/01 DAILY: 2,6'/'/ CUM: 78,442 DAILY: 25,140 CUM: '/,'/05,136 NO ACCIDENTS REPORTED TODAY DRILLINGSUPERVISOR: R. LAWSON Well: Beaver Creek-10 Date: 12-Apr-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 1/2 HOUR MINIMUM START END HOURS DESCRIPTION 4:30 6:00 1.50 CONT. RIH W/ 3 1/2" 9.3PPF L-80 PRODUCTION CASING. 105 OF 281 JOINTS RUN. Marathon ~T#: 29 DATE: 04/13/01 LOCATION,~ ~YS: 22 SPUD DAYS: 19 Oil Company ( .# 8102801 GL: KB'.( . MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 8,854 (1'VD) 8,560 CSG SIZE: 3.500 CSG MD: 8,818. CSG TVD: 8,524. ~HOE TEST~ MAX. SI 0 LINER TOP: PRESENT OP:PREPARE TO N/D BOP. · ~ · ~,~ ..... ~=. .;' ~', . .~'. ~ .... .'.. ' * '. · ,;;-,' ; '" ~ ..... ;",~',"'" ' *' ," ..... ," ' ' '" ~ ',' '" * · ' , ~ ',' *'" , ..... '" "' , , '~'=' "~ ', '" '",, ' ': '"' ~; ," '~' ,'* ' 2'. RUN 3 1/2" PRODUCTION CSG. CIRC. AND CONDITION MUD FOR CEMENTING. CEMENT 3 1/2" PRODUTION EXECUTIVE CSG. WOC WHILE BEGIN TO R/D. SUMMARY ?'"~=i~ '~'~" "~'~'""' '~ 'T "'~"::?"~*~", ................... '~' '~ ....... ~"~'?'~'=' f .............. ~' F'~'''' ~'~ ........ :~' *'"'""~ ~"" ~"'"~ ........... ~' ...... ~ ....... ' "' ............ "'"~'"T" *' ................... '" '~ '~ ...... ~ ........ P" .......... ' ....... i;~'' ~""~' ~i ..... , .... '~" = '" '~'= "*'" ..... (~MW VIS PV YP GELS WL T 7.5 30 "T FC CEC SAND SLD BENT SALT DRILLED BARITE 9.6 13919191 7 / 1316.01681 I I [ 2 /32 I 6'81 / 9.4 PPB.. 65.8 PPB 5.7 PPB (o~g WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllft} BKGD CONN TRIP MAX 193.21 ~.2 1 1 129'°°°I I Idaily cum 0.01 1 [ 1 ii ' i1'/-- ' ' (~ BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB lOB LB G OT R CPF COMMENTS !( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP~ BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ~ JARS MWI~ MOTOR TORQUE WEIGHT (1000) I 1 I 1 I 1 BHA: PU ~ot -So 'Eft · { MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 8,609.00 1.260 190.00 8,3 ~ 5.40 1,426.32 157.80 1,417.65 0.28 8,797.00 1.270 208.20 8,503.35 1,424.60 153.93 1,416.30 0.2~ 8,854.00 1.280 208.20 8,560.34 1,423.89 152.81 1,415. 70 0.02 ~ OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 8:30 2.50 CONT. RIH W/3 I/2" PRODUCTION CSG. 8:30 9:00 0.50 BREAK CIRC. @ 5000: . 9:00 11:30 2.50 CONT. RIH W/3 1/2" PRODUCTION'CSG. 11:30 12:00 0.50 BREAK CIRCULATION @ 7000'. 12:00 13:30 1.50 M/U INJECTION MANDREL AND INJECTION LINE. ~3:30 16:00 2.50 CONT. RIH. M/U HANGER ASSY AND LAND CSG HANGER(TOTAL 281JNTS 3 1/2" 9.3PPF L-80 CSG). DRAIN STACK AND VERIFY HANGER HAS LANDED. 16:00 21:00 5.00 M/U TIW PLUG DROPPING ASSY. CIRCULATE AND CONDITION MUD. MIX IOOBBLS 3% KCI. FOR DISPLACEMENT FLUID. 2~:00 22:30 1.50 PUMP 4BBLS KCL WATER AHEAD. TEST CEMENT LINES TO 3500PSI. MIX AND PUMP 40BBLS IO.5PPG SPACER. MIX AND PUMP 125SXS "G" CEMENT W/.3%BWOC CACL2, .4%BWOC CD-32, 2%BWOC SODIUM METASlLICATE, 1GPS FP-6L, .25%BWOC CELO FLAKE 5%BWOC KOL SEAL, 95.2% FRESHWATER TO YIELD 47BBLS f2. SLEAD SLURRY. TAIL IN WITH 500SX "G" CEMENT W/.9%BWOC BA-IO, . 15%BWOC, R-3, 2%BWOW KCL, .2%BWOW FL-63, .6%BWOW CD.32, 1GAI_/IOOSX FP.6L, . 15% BWOC SODIUM METASILICA TE, 44.7% , FRESH WATER TO YIELD 105BBLS 15.7PPG SLURRY. DROP PLUG AND DISPLACE WITH AFE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 , ;~ ~:: ::~:,~..::...,~ ;.. :,~ ;' ~:~. [!?:.;?i, li!!ii~:;~ii??i MUD COSTS ACTUAL :~;, '. ~:~':,"~':~,=.:,:'~k~,~ ':.=..~ .~' WELL COSTS ACTUAL i:::.:."' 'i; ..~ LAST BOP TEST DATE: 04/10/01 ~_.. ~.~_;__.; : , ~. ,......, .; .., ., .~ ~..~ ! ,'.'.:', .: ~;~. DAILY: 500 CUM: 78,942 DAILY: 142,088 CUM: 1,247,224 NO ACC/DENTS REPORTED TODAY DRILLING sUpERVISOR: R. LAWSON Well: Beaver Creek-10 f"' t' Date: 13-Apr-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION 76BBLS 3%KCL WATER. BUMP PLUG W/2600PS1500PSI OVER DISPLACEMENT =RESSURE. PRESSURE BLED TO BACK TO 1870PSl IN 30 SECONDS. PUMP UP TO 2150PSI. PRESSURE BLED BACK TO 1860PSI IN 1 MIN. RELEASE PRESSURE. FLOATS HELD OK. 22:30 6:00 7.50 WHILE WOC R/D CEMENT LINES, BLOW DOWN LINES, ED WEATHERFORD CSG RUNNING TOOLS. DRAIN AND RINSE BOP STACK~ N/D FLOW LINE. CLEAN MUD PITS. CLEAN TRIP TANK. NOTE: CREDIT OF $24,045 TO DAILY COST DUE TO OVERCHARGE ON COST FOR 04/12/01. ....... , --,. .. ..... Marathon ~,T#: 30 DATE: 04/14/01 LOCATION r~YS. 23 SPUD DAYS: 20 Oil Company ( ;: 8102801 GL: KB. ~ MOC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 8,854 (TVD) 8,560 CSG SIZE: 3.500 CSG M~-: 8,818. CSG TVD: 8,524. ~HOE TEST: MAX. SI 0 LINER TOP: PRESENT OP:N/U X-MAS TREE. WHILE WOC CLEAN AND ORGANIZE RIG AND LOCATION. N/D BOP. ATTEMPT TO SET CSG HANGER PACK EXECUTIVE OFF. N/U BOP. MODIFY CSG HANGER PACK OFF. N/D BOP. SET CSG HANGER PACK OFF. N/U X-MAS SUMMARY TREE. NO TEST ON CSG HANGER PACK OFF. TEST TREE TO 5000PSI/IOMIN. N/D X-MAS TREE AND CHANGE COMPRESSION FITTING ON INJECTION MANDREL CONTROL LINE. N/U X-MAS TREE. ;=,~,'-'~r'."'~,-.~.~'.,.".'~'".'~,,',~',~"','~.~'~''. ........... ~.'~.;~", ..... ~ .............. ~ ........ ~,~".'~ ......... 'r .......... ;,~"'~*',' ~'r"'~'"*'r'r"*'"i ........... · .................. 'r'~,',~' ............. , ................ ,~ ..... '~'~"'"'"~"~*i, ................... ~'~,"i~°**~,,= (:MW VISPVYPGELS WL T 7.5 30 HT FC CEC SAND SLD BENT SALT DRILLED BARITE I I I I / I I I / I I /32 I I / PPB PPB PPB ~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES <bbl/ftI BKGD CONN TRIP MAX 1 [ 1 1 I I I [daily 'cum 0.01I [ ] ~ I~IT~" SIZE TYPE OFF FTG HRS FTIHR RPM WOB IOD LB GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS , MWI~ MOTOR TORQUE WEIGHT (1-000) - BHA: PU Rot -so Eft ( MEA. DEPTH ANGLE DIRECTION 'FVD VERT. SEC. N/S E/W DOG LEG 8,609.00 1.260 190.00 8,315.40 1,426.32 157.80 1,417. 65 0.28 8,797.00 1.270 208.20 8,503.35 1,424.60 153.93 1,416.30 0.21 8,854.00 1.280 208.20 8,560.34 1,423.89 152.81 1,415. 70 0.02 ( OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 11:00 5.00 WHILE CONT. WOC CLEAN LOCATION. LOAD EQUIPMENT ON TRAILERS. CLEAN AND ORGANIZE RIG. 11:00 12:00 1.00 N/D BOP. 12:00 13:00 1.00 N/D ADAPTOR SPOOL. 13:00 16:00 3.00 ATTEMPT TO INSTALL VETCO CSG HANGER PACK OFF. PACK-OFF WOULD NOT FIT IN WELLHEAD(WRONG MODEL WELLHEAD INSTALLED ON WELL. BOWL TOO SHALLOW TO A CCOMMODA TE PA CKOFF). 16:00 0:00 8.00 N/U BOP. WHILE WAIT ON PACKOFF TO BE MODIFIED AT MACHINE SHOP CONT. TO CLEAN AND ORGANIZE RIG AND LOCATION. PERFORM MAINTENANCE ON RIG EQUIPMENT. PUMP WATER OFF OF LOCATION. REPAIR ACCUMULATOR ACTUATER ON KOOMEY UNIT FOR ANNULAR. 0:00 1:00 1.00 N/D BOP. N/D ADAPTOR SPOOL. 1:00 3:30 2.50 INSTALL MODIFIED CSG HANGER PACKOFF. N/U X-MAS TREE. ATTEMPT TO TEST X-MAS TREE VOID, NO TEST. TEST TREE TO 5000PSI/IOMIN. 3:30 4:30 1.00 N/D X-MAS TREE. 4:30 5:00 0.50 CHANGE COMPRESSION FITTING ON INJECTION MANDREL CONTROL LINE. ~,FE: DH TST/CSG COMP TOT LAST PIT DRILL DATE: 04/07/01 ~i~?i?.':i:..:;:.'.:i,.'ii MU~ COSTS ACTUAL i'?i~,..:i:.i!';!i:',~..?~i.:~':i?,;~.~!:,~!:~.!..,i? :"::i WELL COSTS ACTUAL J.!;i.'.__*' "iii LAST BOP TEST DATE: 04/T0/01 DALLY: 0 CUM: 78,942 DALLY: 18,395 CUM: 1;265,619 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. LAWSON Well: Beaver Creek-lO i" ~ Date: 14-Apr-01 Operations Cont (d) SEQUENTIAL OPERATIONS (REPORT TIGHT SPOTS, LOC. TORQUING UP PROBLEMS, ETC.: 112 HOUR MINIMUM START END HOURS DESCRIPTION 5:00 6:00 '1.00 N/U X-MAS TREE. Marathon .?#: 31 DATE: 04/15/01 LOCATION nA~YS: 24 SPUD DAYS: 21 Oil Company 8102801 GL: KB'. MDC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD). 8,854 (TVD) 8,560 CSG SIZE: 3.500 CSG MD~' 8,818. CSG 'I'VD: 8,52~-. ~HOE TEST: MAX. SI 0 LINER TOP: PRESENT OP:CLEAN, ORGANIZE AND SERVICE RIG. TEST CSG HANGER PACKOFF TO 5000PSI/IOMIN. TEST X-MAS TREE TO 5000PSl/IOMIN. TEST 3 1/2" EXECUTIVE PRODUCTION CSG TO 3200PSl/30MIN. CLEAN, ORGANIZE AND SERVICE RIG EQUIPMENT AND LOCATION. SUMMARY I I I I i I I I i I I I32 f I i PPB PPB PPa i(~OIL VVTR pH Pm Pf Mf CL CA LIME MUD LOSSES {bbllff} aKGD CONN TRIP MAX 1 daily cum 0 01 C BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B GOT R CPF COMMENTS ( BIT# SERIAL# PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: JARS MWD MOTOR TORQUE WEIGHT (j'000)- I ]~,I.. 1 I[,~, ,~,I,~ ~ BHA'. Pu Rot So Eft ~ MEA. DEPTH ANGLE DIRECTION TVD VERT. SEC. NIS E/W DOG LEG 8,609.00 1.260 190.00 8,315.40 1,426.32 157.80 ~,4~7.65 0.28 8,797.00 1.270 208.20 8,503.35 1,424.60 153.93 1,416.30 0.21 8,854.00 1.280 208.20 8,560.34 1,423.'89 152.81 1,415. 70 0.02 { OPERATIONS IN SEQUENCE START END HOURS DESCRIPTION 6:00 7:30 1.50 TEST CSG HANGER PACKOFF TO 5000PSI/IOMIN. PULL B-P VALVE AND SET 2-WA Y CHECK. TEST TREE TO 5000PSI/IOMIN. PULL 2-WAY CHECK. , 7:30 8:30 1.00 TEST 3 1/2" PRODUCTION CSG TO 3200PSl/30MIN. ~ 8:30 9:00 0.50 SET BPV. INSTALL TREE CAP. 9:00 12:00 3.00 LOAD OUT EXCESS DRLG TOOLS AND MATERIALS. CLEAN AND ORGANIZE SUB BASE AREA. FINISH CLEANING PITS. 12:00 0:00 12.00 RID PANIC LINE. CLEAN MATTING BOARDS. DRAIN AND CLEAN OUT KOOMEY TANK. STEAM CLEAN DERRICK. REPLACE ESD'S ON MUD PUMP MOTORS. 0:00 6:00 6.00 FINISH CLEAN KOOMEY TANK AND STRAINERS. FILL TANK WITH NEW OIL. MOUNT ESD'S FOR MUD PUMP ENGINES OUTSIDE OF PUMP ROOM. RID SLOP TANK. CONT. TO CLEAN RIG. REWRAP SPIRAL CONTROL LINE PROTECTORS OVER TOP DRIVE CONTROL LINES. GRATE AND BACK DRAG LOCATION. SERVICE CARRIER TRANSMISSION. ~.FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 .... I~D'~)"~0STS 'A'~':i;UAL ................... WELL COSTS ACTUAL LAST BOP TEST DATE: 04/10/01 ...... I~iL'~'.'- ........ 0 .... C~'l~l-:' 7'~;~2 ' 'DAILY:--' '~-4~'0-~ .... c-~'~i' '-~'~"66~ NO ACCIDENTS REPORTED TODAY DRILLING S~IPERVISOR: R. I'~WSON ......... Marathon R~pT#: 32 DATE: 04/16/01 LOCATION ~YS: 25 SPUD DAYS: 22 Oil Company ( : 8102801 GL: KB.tf . MDC WI: WELL: Beaver Creek-lO RIG: Glacier Drilling Rig I FTG: 0 DEPTH: (MD) 8,854 (TVD) 8,560 CSG S~'ZE: 3.500 CSG MD: ~818. CSG TVD: 8,524. ~HOE TEST~' MAX. SI 0 LINER TOP: PRESENT DP: CLEAN, ORGANIZE AND SERVICE RIG. EXECUTIVE SUMMARY ........ , ............................................................, W VIS PV YP GELS WL T 7.5 30 HT FC CEC SANu SLD BENT SALT DRILLED BARI-I-E' ~.,-, i~OIL WTR pH Pm Pf Mf CL CA LIME MUD LOSSES lbbllft} BKGD CONN TRIP MAX I 1 1 I [ ldailY cum 0.0'/1 [ ] ~ ;~.. ~.# ;J:,~,:~,,,~:~,' ~,~',~.;~'; ,:., ~>. ~ .. ,..,~ ;,~,~ ~,,~ .~a~' ~-, '... ,.~,*^.,,.~.~.=w,~,,,~ ~,., ;,.~, .,,~.~.~,, ,,~=~y~,~, ,,.,.= ,....,,~.:.~ ~,~: :, ,,.,..., :~'~;"~'~i "Tii' ~;: ~'~ ~';~::~: ~ ~ ~'~ ';"' '~;'~':" ' "'" "" % "'""~;":"'~, '"" ';i,~'~'",' ', · '~' "' ~ ' ' "~°'.~'.~';:;: '~';:;';:'.. ",?';:~" ~"; 'r;';:. ;.;.~; ~;, i~ BIT# SIZE TYPE OFF FTG HRS FT/HR RPM WOB I O D L B G OT R CPF COMMENTS =( BIT# SERIAL # PRESS. OPM JETS TFA ANNULAR VELOCITY BIT BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ~ JARS MW~ MOTOR TORQUE WEIGHT (1'~)00) - I / ! I ~ IBHA:- PU -Rot' -So- Eft- (~ MEA. DEPTH ANGLE DIRECTION TVD VERT, SEC, HIS E/W DOG LEG 8,609.00 1,260 190,00 8,315,40 1,426.32 157.80 1,417.65 0.28 8,797,00 1.270 208,20 8,503.35 1,424.60 153.93 1,416.30 0.21 8,854.00 ~,280 208.20 8,560,34 1,423.89 152.81 1,415,70 0.02 ( OPERATIONS IN SEQUENCE START END 'HOURS DESCRIPTION 6:00 12:00 6.00 STEAM CLEAN ROOF ON MUD PIT AND PUMP ROOM MODULES. REMOVE BAILS FROM TOP DRIVE UNIT AND SLIDE UP SAVER SUB CLAMP. CLEAN PUMP ROOM. STEAM CLEAN TOP DRIVE AND DERRICK. REMOVE CUTTINGS 'TANK AND LOAD OUT CEMENT SILOS. ~2:00 0:00 12.00 CONT. STEAM CLEAN DERRICK AND PITS. 0:00 6:00 6.00 REWIRE PERGE ALARM ON TOP DRIVE. FIX LEAK ON DRAIN LINE IN CHANGE HOUSE. AFL: DH ' TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 MUD COSTS ACTUAL ...... .. ' ........ i-"'",-W-E'LL C~3-S'¥§'A'~TUAL ......... LAST BOP TEST DATE: 04/10/01 .......... bali's': "' 0 CUM: 78,942 DAILY: .... ~4~,~3 CUM:' "~'3~114 NO ACCIDENTS REPORTED TODAY DRILLING SUPERVISOR: R. LAWSON '" Marathon . RPT#: 33 DATE: 04/17/01 LOCATION .r)&YS: 26 SPUD DAYS: 23 Company "(" .: 8102801 GL: KE ( MOC WI: Oil WELL: Beaver Creek-lO RIG: Glacier Drilling Rig 1 FTG: 0 DEPTH: (MD) 8,854 (TVD) 8,560 ~:SG SIZE: 3.500 CSG MD: 8,818. CSG TVD: 8,524. ~HOE TES~i' - MAX. SI 0 LINER TOP: PRESENT OP:RELEASE RIG FROM WELL BC-IO @ 17:00HRS 04/16/01 PERFORM RIG MAINTENANCE. EXECUTIVE SUMMARY ,,~=~ ,;,,~.,. ;,::::.~,;;~::.-.~. ~,,~,. ~-~,,~,,,,~,i~.. ~:,~, ,is~ ..-=~,,u,.'. ,,'i?...,.'~; ', ;'= '"i' ~':;"~"~ ''" '~""~"'";ii''''=' '"='" ' "'" ' *':'"' '=" "' '*' ':e ""~' ';'~i ' '~ '":'~"i '"j:~' 'j':vii"'~';' ~ "~"~' '~'~"'"'"'"~ '~:~' ' ~"'~:*'~i''';''~;;' ................ ~"~"~' *' ~ ~'j:* ~'~"":'~';~ ....... ~'~'~ ........ (MW,VIS PV YP GELS WL t 7.5 30 HT FC CPC SAND SLD BENT SALT DRILLED BARITE I I I I I I I I I I 132 I I .l, PPB PPB PPB ~ ~ WTR pH Pm Pf Mf CL CA LIME MUD LOSSES Ibbllft} BKGD CONN TRIP MAX t 1 I ( BIT# SIZE TYPE OFF FTG HRS FTIHR RPM WOB I O D L B G OT R CPF COMMENTS ( BIT# SERIAL # PRESS. GPM JETS TFA ANNULAR VELOCITY BIT HP) I BHA: Length: DRILL PIPE DESCRIPTION: MAX PULL: ( JARS MWD MOTOR TORQUE WEIGHT (1000) BHA' Pu -Rot So Eft ( MPA. DEPTH ANGLE DIRECTION 'FVD VERT. SEC. N/S E/W DOG LEG 8,609.00 1.260 190.00 8,315.40 1,426.32 157.80 1,417.65 0.28 8, 797.00 1.270 208.20 8,503.35 1,424.60 153.93 1,416.30 0.21 8,854.00 1.280 208.20 8,560.34 1,423.89 152.8 ~ 1,415. 70 0.02 ~ OPERATIONS IN SEQUENCE START END ~ HOURS DESCRIPTION 7:00 17:00 10.00 HANG FLOWLINE EXTENSION. HANG BEAM CLAMPS IN CELLAR FOR CRANE AIR HOIST. PREP BOP FOR PAINTING. STEAM CLEAN DERRICK AND PITS. REMOVE DRAWWORKS CHAIN GUARD AND INSPECT CHAIN, REFAB COVER. CLEANOUT AND . SMASH EXTRA OIL DRUMS. RUN NEW ELECTRIC WIRE TO TOP DRIVE ALARM SYSTEM. WELD SLEEVE FROM WA TER LINE THROUGH 6X6 FOR WA TER TO MI CENTERFUGE UNIT. REBUILD BROKEN PARTS ON DRAWWORKS DRUM CLUTCH. REPLACE DRAWWORKS CHAIN. ORGANIZE AND LOAD ON TRAILERS EXTRA MUD PRODUCTS NOT NEEDED FOR UPCOMING WELL PROGRAM. WASH OUTSIDE DOGHOUSE WIND WALLS. FAB SKID FOR MILLER WELDER. INSTALL SLEA VE IN MUD PIT TUBE FOR WA TERLINE TO MI CENTERFUGE UNIT. RELEASE RIG FROM WELL BC. IO @ 17:00HRS 04/16/01 a. FE: DH TSTICSG COMP TOT LAST PIT DRILL DATE: 04/07/01 MUD COSTS ACTUAL' WELL COSTS ACTUAL i:.:'.. .... :. , = i~..:.i~.v.::= LAST BOP TEST DATE: 04/10/01 DAIL~': 0 CUM: 78,942 -- DAILY: 1-6-,359 CUM: 1,349,773 NO ACCIDENTS REPORTED TODAY DRILLING SOPERVISO~I-.' R. LAWSON MARATHON OiL COMPAN~!'i' DALLY WELL OPERATIONS PAGE 1 OF 1 DATE: 12/3/2001 FI ELD: FILL DEPTH/DATE: 8677', 11/28/01 TUBING: DATE LAST WL WORK: 11/30/2001 WORK DONE: perforate PRESENT OPERATION: perforate OTHER: BCF WELL #: 3 1/2" CASING: TREE CONDITION: BENCHES OPEN: BC-10 9 5/8" Good SUMMARY OF OPERATIONS MIRU Schlumberger after making repairs to logging truck. Held safety and operations meeting. Will now perforate under flowing conditions due to demand for gas, but applying methanol and heat at critical locations. Well making 4 MMCFD with 1400 psi FTP on an 11/64" choke. PU 20' of 2.5" hollow carriers (same guns as used on 11/29/01). Pressure test lubricator to 3000 psi using methanol. RIH with guns. Tie-in CCL with correlation log of 11/28/01. Had about 2 hours downtime unable to get current developed to fire guns. Fixed oroblem, perforated the LB-26 sand 8257' - 8257' with roughly 700 psi underbalance. POOH. _D old guns; all shots fired. PU another 20' gun section and RIH with well flowing. Perforated the LB-27 sand 8334' - 8354' with roughly 700 psi underbalance. POOH. OOH. Having to release Schlumberger to catch a rig job even though we're not done oerforating. RDMO Schlumberger. Produce well to sales. So far apear to be getting neglible increase in production from the addition of these perfs. Vendor Equipment Daily Cost Cumulative Cost DALLY COST: CUM: REPORTED BY: Gary Eller MARATHON OIL COMPANY(" DALLY WELL OPERATIONS RE{ ~' PAGE 1 OF 1 DATE: 11/30/2001 FIELD: FILL DEPTH/DATE: 8677', 11/28/01 TUBING: DATE LAST WL WORK: 11/29/2001 WORK DONE: perforate PRESENT OPERATION: perforate OTHER: BCF WELL #: 3 1/2" CASING: TREE CONDITION: BENCHES OPEN: BC-10 9 5/8" Good SUMMARY OF OPERATIONS RU repaired Schlumberger wireline valve and pressure test to 3000 psi using methanol. Held safety and operations meeting. Decided to perforate with the well shut-in after yesterday's problem with ice forming in the tree. SITP = 2100 psi. PU 15' section of 2.5" hollow carrier guns (same guns as used on 11/29/01) and RIH. Tie in with CCL to correlation log of 11/28/01. Perforate the LB-29 sand 8530' - 8545' MD. POOH. Logging truck is having difficulty POOH due to electrical problems from the alternator. Eventually able to pull all the way OOH. Unable to fix in the field, so decide to halt perforating operations until logging truck is repaired. Secure well, SDFN. Vendor Equipment ' DailyCost ' cumulative cost DALLY COST: CUM: REPORTED BY: Gary Eller MARATHON OIL COMPANYi' ~ DALLY WELL OPERATIONS RE~ ,' PAGE 1 OF 1 DATE: 11/29/2001 FIELD: FILL DEPTH/DATE: 8657' WLM TUBING: DATE LAST WL WORK: 11/12/2001 WORK DONE: tagged fill ran GR PRESENT OPERATION: perforate OTH ER: Beaver Creek WELL #: BC-10 3 1/2" CASING: 9 5/8" TREE CONDITION: Good BENCHES OPEN: LB 16, 17, 20a, 20b, 21, LB 23a, 24 SUMMARY OF OPERATIONS PU 20' of 2.5" hollow carrier guns (6 spf, 60-degree phase loaded with 10.7 gm PJ-2506 charges with a 0.32" entrance hole) and RIH with well flowing. Pumping methanol in at downhole injection point. Tie in with CCL, and perforate the LB-30 Sand 8634' - 8654'. POOH. When guns were pulled up across the tree, they got stuck due to ice. Unable to close the master valves or swab valve because the tool string is in the way. Shut-in well at wing valve. Attempt to close wireline valve and bleed off lubricator, but wireline valve not holding pressure. RU external heat source and pump-in methanol at the lubricator. After several hours were able to free tool string and RD. All shots fired. SDFN. Vendor Equipment Daily Cost Cumulative Cost Schlumberger pert unit Toloff DAILY COST: CUM: REPORTED BY: Wayne Cissell MARATHON OIL COMPAN~ DAILY WELL OPERATIONS RI~" PAGE 1 OF I DATE: 11/28/2001 FIELD: FILL DEPTH/DATE: 8657' WLM TUBING: DATE LAST WL WORK: 11/12/2001 WORK DONE: tagged fill ran GR PRESENT OPERATION: perforate OTHER: BCF WELL #: BC-10 3 1/2" CASING: 9 5/8" TREE CONDITION: Good BENCHES OPEN: LB 16, 17, 20a, 20b, 21, LB 23a, 24 SUMMARY OF OPERATIONS Schlumberger arrive on location start RU on well. Held environmental, safety meeting and discussed procedure. Problem with electronics reading through the stem. Picked up Lubricator, start PT lubricator. Pack off would not seal off for a period of time. PT Lubricator to 3000 psig. took awhile to get 5" lubricator pressure tested.., no leaks open well up WHP= 1500 psig,Well flowing at 3000 MCF rate at surface. RIH with 2.125" tool string with PBMS tool Made tie in log correlated back to measured depth array induction log dated April 9, 2001. Tagged fill at 8677' KB. POOH making log pass from 8677' up through 6000' finish POOH OOH with tool string. Put night cap on well secure for night. SCH leave lease. Note; during logging pass noted the LB 24 perforations (8085 - 8100') had a 25 deg F. shift in temperature on the temperature tool that SCH had on the tool string & down hole pressure was recorded at 1800 psig. Vendor Equipment Daily Cost Cumulative Cost Schlumberger perf unit $4,200.00 Toloff $800.00 DAILY COST: $5,000.00 CUM: $5,000.00 REPORTED BY: Wayne Cissell MARATHON OIL COMPANY i" ' DALLY WELL OPERATIONS PAGE 1 OF 1 ~-"" DATE: 10/18/2001 FILL DEPTH/DATE8682' KB, 10-18-01 TUBING: DATE LAST WL WORK: Unknown WORK DONE: Gauge Tubin~l - Pressure Survey PRESENT OPERATION: Complete OTHER: Wire twist test - 23 turns FIELD: Kenai Gas Field WELL #: BC-10 3 1/2" CASING: 7" TREE CONDITION: New BENCHES OPEN: WIRELINE CREW: WhitakedDoherty Hrs. 12 SUMMARY OF OPERATIONS Depart Pollard Shop Arrive @ Beaver Creek Facility, meet w/Foreman, discuss job Hold safety meeting, check equipment Spot equipment Pre-Wireline well Parameters as follows Gas Rate 4 MMCFD Water Rate 5 BBLS per day Surface Flowing Pressure 1495 # PSI R/U, pressure test Lub & WL ValVe, test - good iRIH w/2.75" GR to 8659' WL, tagged fill, POOH, make up Tandem Gauge arrangement Top #2108 Bottom #2168 Batteries on 11:21 Swab Open @ 11:36 RIH w/Tandem Gauges on 3 1/2" X-line R/T to 7182' KB, set Bombs in X-nipple (2.81"), POOH RIH w/3 1/2" Check set (2.81"), check set, POOH, sheared RID Meet w/Foreman to compare Data Tools: 2.75" GR $50.00 3 1/2" X-line R/T $200.00 3 1/2" Check set $75.00 Tandem Gauges $800.00 Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Tools $1,125.00 $1,125.00 Pollard Wireline Inc. Unit & crew $1,830.00 $2,955.00 DAILY COST: ~ CUM: $2,955.00 REPORTED BY: Brian Millyard MARATHON OIL COMPANY DALLY WELL OPERATIONS REP PAGE 1 OF I DATE: 10/11/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: 8682' CTM FIELD: TUBING: N/A Flow Test Complete Beaver Creek Field WELL #: 3-1/2", 9.3#, L-80 CASING: TREE CONDITION: BENCHES OPEN: WIRELINE CREW: BC-10 N/A Good B- 16-24 10/9/01 '10110/01 Well producing 4.1 MMCFGPD / 3 BWPD at 1460 psig and 48 degrees F. This corresponds to a 40% Drawdown based upon a 3000 psig SBHP (estimated). Note that the maximum drawdown on the well to date was a 50% drawdown at 3.7 MMCFGPD / 3 'BWPD at 1260 psig FTP. No problems were encountered. Orifice plate was pulled and some sand was observed. Well producing 4.15 M MCFGPD / 3 BWPD at 1500 psig and 48 degrees F. This corresponds to a 38% Drawdown based upon a 3000 psig SBHP (estimated). Note that the daily rate and pressure continue to increase as the well cleans up. See attached charts in the file. Perf Summary: LB-16 7400'-7413' 13' LB-17 7507'-7527' 20' LB-20a 7717'-7737' 20' LB-20b 7758'-7778' '20' LB-21 7828'-7848' 20' LB-23a 7927'-7966' 39' LB-24 8085'-8100' 15' Total147' *All guns HSD-WL-DP 2.5", 2506 P J, HMX 6 spf, 60deg phase, (10.5 gram chgs) 0.32" entrance hole, 25.2" pene. Vend~)r E~luipment Daily Cost Cumulative Cost " ,, , , ,. DALLY COST: CUM: REPORTED BY: Affinito MARATHON OIL COMPANY DAILYWELL OPERATIONS REPO . PAGE 1 OF I DATE: 10/2/2001 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: 8682' CTM FIELD: TUBING: N/A Flow Test Complete Beaver Creek Field WELL #: 3-1/2", 9.3#, L-80 CASING: TREE CONDITION: BENCHES OPEN: WlRELINE CREW: BC-10 N/A Good B- 16-24 0~2~01 2300 hrs 10/310:1 0200 hrs 10/06101 10108/01 SITP 2300 psig. Open well to tank for 3 hours. Well unloaded no fluid and produced dry free gas at 1350 psig FTP. Turn well to sales at 0200 hrs. Well produced at 2.7 MMCFGPD / 0 BWPD rate at 1500 psig FTP and 41 degrees F. Open well further to reach the unloading rate to 3.2 MMCFGPD / 3 BWPD rate at 1400 psig FTP and 42 degrees. Continue to produce well which slugged some liquid at times. Rate varied from 2.7 MMCFGPD TO 3.8 MMCFGPD at 1280 psig to 1550 psig. Hydrate problems are severe. Injecting methanol at 30 gal/day rate and well continues to hydrate off in the choke (with pre-heat). SITP after a 4 hour SI was 2484 psia (from SPIDR). Well was SI to combat a hydrate plug. Well producing 4.0 MMCFGPD / 3 BWPD at 1460 psig and 43 degrees F. Perf Summary: LB-16 7400'-7413' 13' LB-17 7507'-7527' 20' LB-20a 7717'-7737' 20' LB-20b 7758'-7778' 20' LB-21 7828'-7848' 20' LB-23a 7927'-7966' 39' LB-24 8085'-8100' 15' Total147' *All guns HSD-WL-DP 2.5", 2506 P J, HMX 6 spf, 60deg phase, (10.5 gram chgs) 0.32" entrance hole, 25.2" pene. Vendor Equipment Daily Cost Cumulative Cost Schlumberger Ron's Veco DALLY COST: CUM: REPORTED BY: Affinito MARATHON OIL COMPA,,, DALLY WELL OPERATIONS PAGE I OF I DATE: 10/1/2001 FIELD: Beaver Creek Field WELL #: BC-10 FILL DEPTH/DATE: 8682' CTM TUBING: 3-1/2", 9.3#, L-80 CASING: N/A DATE LAST WL WORK: N/A TREE CONDITION: Good WORK DONE: Perforate Beluga Intervals BENCHES OPEN: See below PRESENT OPERATION: Complete WIRELINE CREW: Dalebout, +2 MIRU Schlumberger wireline unit w/0.23" wire. Work on new facilities installation RIH, correlate depth of first zone to Schlumberger AIL (4/9/01) Apply 900psi pressure from BC9 (to limit perf draw down to 50%) Fire13' gun #1 8085'-8100' (string lost 100#). Pwh=900psi At surface: Pwh=1200 psi. MU Gun #2 RIH w/19' Gun #2 Correlate and fire gun 7947'-7966' (string lost 200#) Pwh=1400psi. POOH At surface: Pwh--1900psi. MU Gun #3. RtH Correlate and fire gun 7927'-7947'. No result. Fire gun again (string lost 150#). POOH At surface: Pwh=2100 psi MU Gun #4. RIH Correlate and fire gun 7828'-7848' (string lost 70#). POOH At surface: Pwh=2150psi, Re-string gun head MU Gun #5. RIH Correlate and fire gun 7758'-7778' (lost 130#). POOH At surface: Pwh=2150psi. MU Gun #6. RIH Correlate and fire gun 7717'-7737'. (lost 80#). POOH At surface: Pwh=2150psi. MU Gun #7. RIH Correlate and fire gun 7507'-7527'. No change in weight detected. Electrical equipment indicates gun did fire. Activate again to be certain. POOH. At surface. All shots fired. Pwh=2150psi. MU Gun #8. RIH !Correlate. Pefs zone from run #7 is a little sticky. PU above restricted hole. Correlate and shoot. 7400'-7413'. 'No change in weight. Re-fire. POOH All shots f red iBegin RD Schlumberger Peff Summary: LB-16 7400'-7413' 13' LB-17 7507'-7527' 20' LB-20a 7717'-7737' 20' LB-20b 7758'-7778' 20' LB-21 7828'-7848' 20' LB-23a 7927'-7966' 39' LB-24 8085'-8100' 15' Total 147' *All guns HSD-WL-DP 2.5", 2506 P J, HMX 6 spf, 60deg phase, (10.5 gram chgs) 0.32" entrance hole, 25.2" pene. Vendor Equipment Daily Cost Cumulative Cost Schlumberger Wireline unit, guns $65,000.00 Ron's Light Plant Veco Scaffolding ., DALLY COST: CUM: $70,000 REPORTED BY: Titus DALLY WELL OPERATIONS R~ .... PAGE 1 OF 1 DATE: 7/26/2001 FIELD: FILL DEPTH/DATE: 8682' CTM TUBING: DATE LAST WL WORK: N/A WORK DONE: PRESENT OPERATION: Unload completion fluid OTHER: AFE 8102801 Beaver Creek Field WELL #: 3-1/2", 9.3#, L-80 CASING: N/A TREE CONDITION: Good BENCHES OPEN: none WIRELINE CREW: TIME: BC-10 SUMMARY OF OPERATIONS MIRU 1-3/4" CT unit. Held safety and environmental meeting. Discussed procedure with crew. PT BOP to 250/3000 psig with fresh water. No problems RIH with 1.75" Coil. Tagged up in the tree. Made calls, determined back-pressure valve had never been pulled. Stand back injector head, pull BPV with dry rod. RU coil tubing again. RIH jetting with nitrogen. No problem getting past mandrel at 1209'. Jet down to 8682'. Set down, unable to make any extra hole. Jet well dry with nitrogen. Recovered 73 bbl of fluid. POOH, RDMO coil tubing. Vendor Equipment Daily Cost Cumulative Cost BJ services coil, nitrogen Toloff crane Vetco pull BPV DALLY COST: CUM: REPORTED BY: Larry Keen MA RA THON OIL COMPA NY BEAVER CREEK #~0 BEAVER CREEK FIELD Section 34-TTN. RfOW, SM Kenai Peninsula, Alaska April 8, 2001 Ralph Winkelman- Sr. Logging Geologist Jerry Stafford- Logging Geologist Kurt Leonard- Logging Geologist EPOCH ~-~Marathon Oil Company - Beaver Creek #10 TABLE OF CONTENTS MARATHON Marathon Oil Company Beaver Creek #fO Beaver Creek Field Kenai Borough, Alaska TABLE OF CONTENTS ........................................................................................................ 2 WELL RESUME .................................................................................................................... 3 LITHOLOGY SUMMARY ...................................................................................................... 4 DALLY CHRONOLOGY ...................................................................................................... 14 RIG ACTIVITY SUMMARY ................................................................................................. 17 MUD RECORD ...................................... ............................................................................. 18 SURVEY RECORD ............................................................................................................. 19 BIT RECORD ...................................................................................................................... 21 DALLY REPORTS ............................................................................................................... 22 FINAL LOGS ..................................................................................................... APPENDIX 1 EPOCH 2 (~Marathon Oil Company - Beaver Creek #10 WELL RESUME WELL NAME: BC-10 FIELD: BEAVER CREEK FIELD REGION: KENAI PENINSULA, ALASKA LOCATION: 1074' FNL,1532' FWL BOROUGH: SEC34-T7N-R10W SM KENAI BOROUGH STATE: ALASKA ELEVATION: RKB: 179.0' AMSL GL: 158.0' AMSL APl NUMBER: #50-133-20482-00 OPERATOR: Operator Representatives: Company Geologist: CONTRACTOR: MARATHON OIL COMPANY ROWLAND LAWSON, DARRELL GREEN BOB LANZ INLET DRILLING DRILLING RIG: Toolpusher: MUDLOGGING COMPANY: Logging Geologists: MUD COMPANY: Mud Engineers: MWD COMPANY: MWD Engineer: DIRECTIONAL COMPANY: Directional Driller: GLACIER DRILLING #1 GEORGE BREWSTER, MIKE LESLIE EPOCH WELL SERVICES, INC. RALPH WINKELMAN, JERRY STAFFORD MI ROD MABEUS,BOB WILLIAMS BAKER HUGHES INTEQ STEVE STURGEON BAKER HUGHES INTEQ TOMM DUNN CEMENT COMPANY: BJ SERVICES WIRELINE COMPANY: SCHLUMBERGER EPOCH 3 (~Marathon Oil Company - Beaver Creek #10 LITHOLOGY SUMMARY TUFFACEOUS CLAYSTONE (5000 - 5050) = LIGHT GRAY TO LIGHT BROWNISH GRAY WITH LIGHT BROWN SECONDARY HUES; FIRM; SUBBLOCKY TO IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY TO OCCASIONALY WAXY LUSTRE; NON CALC. SAND/SANDSTONE (5045 - 5110) = MEDIUM TO DARK GRAY OVERALL APPEARANCE, "DIRTY" VARICOLORED; INDIVIDUAL GRAINS ARE LIGHT TO DARK GRAY, BLACK, GREENISH GRAY, WHITE TRANSLUCENT, DUSKY RED; VERY FINE UPPER TO VERY COARSE UPPER, OCCASIOANAL LARGE BROKEN FRAGMENTS, DOMINANTLY MEDIUM UPPER TO COARSE LOWER; ANGULAR; POORLY SORTED; DISAGGREGATED, OCCASIONALY CONSOLIDATED; MODERATELY HARD, FRIABLE; NON CALCAREOUS. CARBONACEOUS SHALE/COAL (5130- 5200) = DARK DUSKY BROWN TO BLACK; FIRM TO OCC ASIONALY HARD; SLIGHTLY BRITTLE; PLATY GROUND UP CUTTINGS FROM PDC BIT ACTION; FIBROUS TO DENSE MATTE TEXTURE; EARTHY TO SLIGHTLY RESINOUS LUSTRE; PRESENT AS VERY THIN BEDS AND MICROTHIN LAMINATIONS IN DOMINANTLY TUFFACEOUS CLAYSTONE/SILT STONE FORMATION. TUFFACEOUS CLAYSTONE (5200 - 5230) = LIGHT GRAY TO BROWNISH GRAY; SOFT TO OCC FIRM; SILTY TO VERY SLI SANDY; SUBBLOCKY TO IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO SLI EARTHY LUSTER; NON-CALC. SAND/SANDSTONE (5230 - 5260) = LIGHT GRAY TO CLEAR; VERY FINE TO LOWER MED GRAINED; TRACE UPPER MED; SUB ANG TO OCC SUB ROUNDED; TRACE ANGULAR; OCC TRACE FROSTED GRAINS; NO VIS MATRIX; UNCONS; 80% QTZ, 20% LITHIC FRAGMENTS; NO VIS SHOWS. SAND/SANDSTONE (5275 - 5340) = LIGHT GRAY TO CLEAR TO WHITE; VERY FINE TO LOWER MEDIUM; OCC UPPER MEDIUM GRN; ANGULAR TO SUB ANGULAR; TRACE FROSTED GRAINS; TRACE TO MOD AMOUNTS RED TO GREEN CHERT; NO VIS MATRIX; UNCONS; 70% QTZ, 20% CHERT, 10% LITHIC FRAGS; NO VIS SHOWS. SAND (5340 - 5350) = LIGHT GRAY TO CLEAR TO OCC WHT; VERY FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUB ROUNDED; OCC FROSTED GRAINS; UNCONS; NO VIS SHOWS. COAL (5360 - 5385) = BLACK TO DARK BRN FIRM TO HARD; VIT LUSTER; BLOCK; SMOOTH TEX; GRADING INTO CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (5385 - 5410) = LT GRAY TO GRY BRN; VERY SOFT TO OCC FIRM; BLOCKY TO IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; NON-CALC. EPOCH ~Marathon Oil Company - Beaver Creek #10 COAL/CARBONACEOUS SHALE (5410 - 5440) = BLACK TO DARK BROWN; FIRM TO HARD; SMOOTH TEXTURE; MATTE TO SHINY LUSTER; SPLNTRY CUTTINGS; GRADING TO DRK BRN CARBONACEOUS SHALE. COAL/CARBONACEOUS SHALE (5440 - 5460) = BLACK TO DARK BROWN; FIRM TO VERY HARD; WAXY LUSTER; SMOOTH TO ROUGH TEXTURE; PLATY TO SPLNTRY CUTTINGS. SAND/SANDSTONE (5460 - 5500) = LIGHT GRAY TO CLEAR; VERY FINE TO MEDIUM GRAINED; FROSTED IP; ANGULAR TO TRACE SUBROUNDED; UNCONS; NO VIS MATRIX; SLI TO NON CALC; RED TO GREEN CHERT; 70% QTZ, 20% CHERT, 10% LITHIC FRAGS; NO VIS SHOWS. TUFFACEOUS CLAYSTONE (5500 - 5530) = LT GRY TO GRY BRN; SOFT TO FIRM; SILTY TO OCC SLI SDY; EARTHY LUSTER; ABUNDT CARBONACEOUS MATERIAL IN CLAYSTONE. SAND/SANDSTONE (5530-5520) = LIGHT GRAY TO WHITE TO CLEAR; VERY FINE TO LOWER MEDIUM; TRACE SOME LOWER COARSE; SUB ANGULAR TO SUB ROUNDED; UNCONS; POOR SORTING; MOD SPHER; OCC CLAY MATRIX; DECREASE IN CHERT; INCREASE IN LITHIC FRAGMENTS; 80% QTZ, 20% LITHIC FRAGMENTS; NO VIS SHOWS. SAND/SANDSTONE (5520-5580) = VERY LIGHT GRAY TO DARK GRAY; VERY FINE GRAINED TO LOWER MEDIUM GRAINED; MODERATE SPHERICITY; MODERATE TO POOR SORTING; OCC VIS CLAY MATRIX; COMPOSED OF 70% QTZ, 10% CHERT, 20% LITHIC FRAGMENTS; NO VIS SHOW. SAND/SANDSTONE (5580-5650) = LIGHT GRY TO DRK GRAY TO CLEAR; VERY FINE TO LOWER MED GRAINED; SUBANGULAR TO SUBROUNDED; UNCONSOLIDATED; POOR SORTING; MOD SPHERICITY; OCC TRACE CLAY MATRIX; COMPOSED OF 70% QTZ, 10% CHERT, 20% LITHIC FRAGMENTS; NO VIS SHOWS. SAND/SANDSTONE (5650 - 5680) = LIGHT GRAY TO DARK GRAY; VERY FINE TO LOWER MEDIUM GRN; OCC LOWER COARSE; SUBANGULAR TO SUBROUNDED; POOR SORTING; MODERATE SPHERICITY; OCC TRACE CLAY MATRIX; COMPOSED OF 70% QTZ, 10% CHERT, 20% LITHIC FRAGMENTS; NO VIS SHOWS. SAND (5680-5715) = LIGHT GRAY TO DRK GRAY; VERY FINE TO LOWER MED GRN; POOR SORTING; MOD SPHERICITY; TRACE CLAY MATRIX; SUBANGULAR TO SUBRDD; COMPOSED OF 80% QTZ, 20% LITHIC FRAG; NO VIS SHOWS. COAL (5730-5755) = BLACK TO DRK BRN; FIRM TO HARD; BLOCKY TO SPLNTRY; WAXY LUSTER; GRADING INTO A DRK BRN CARBONACEOUS SHALE. SAND (5760-5840) = MEDIUM GRAY WITH STRONG "SALT AND PEPPER" OVERALL APPEAR ANCE; INDIVIDUAL GRAINS ARE LIGHT TO MED DARK GRAY TO GREENISH GRAY, BLACK, WHITE TRANSLUCENT, WITH COMMON PINK TO DARK GRAY TO EPOCH 5 ~)Marathon Oil Company - Beaver Creek #10 GREENISH GRAY, BLACK, WHITE ASIONAL COARSE BROKEN FRAGMENTS, DOMINANTLY MEDIUM LOWER; ANGULAR WITH LARGER LITHS BEING SUBROUNDED AT TIMES; POOR TO MODERATE SORTING; DOMINANTLY DISAGGREGATED, OCCASIONAL CONSOLIDATED PIECES WITH DULL WHITE SUPPORTING MATRIX, NON TO SLIGHTLY CALCAREOUS; COMMON ASHY TUFF WHITE; SOFT TO SLIGHTLY FIRM. TUFFACEOUS CLAYSTONE (5800-5900) = LIGHT TO MEDIUM GRAY WITH LIGHT TO MEDIUM BROWN TO BROWNISH GRAY SECONDARY HUES; SOFT TO SLIGHTLY FIRM; AMORPHOUS TO IRREGULAR CUTTINGS; VERY SOLUBLE; HYDROPHILIC; CLAYEY TO ASHY TEXTURE; DULL EARTHY TO SLIGHTLY MICROSPARKLY LUSTRE; POOR TO FAIR COHESIVENESS AND ADHESIVENESS; NON CALCAREOUS; PRESENT AS SUPPORTING MATRIX FOR SAND/SANDSTONE FORMATION; TRACE WHITE TO LIGHT GRAY ASHY TUFF SAND (5875-5960) = LIGHT TO MEDIUM GRAY OVERALL WITH INDIVIDUAL GRAINS LIGHT TO DARK GRAY, TRANSLUCENT, BLACK, WHITE, LIGHT GREENISH GRAY AND DUSKY RED LITHS; ANGULAR TO SUBANGULAR; FINE LOWER TO 34 MM FRAGMENTS AND LITHS, DOMINANT MEDIUM LOWER; MODERATELY WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH LIGHT GRAY ASHY/ CLAYEY SUPPORTING MATRIX; SCATTERED WHITE ASHY TUFFS. SAND (5955-6040) = LIGHT TO MEDIUM GRAY OVERALL WITH INDIVIDUAL GRAINS LIGHT TO DARK GRAY, TRANSLUCENT, BLACK, WHITE, LIGHT GREENISH GRAY AND DUSKY RED LITHS; ANGULAR TO SUBANGULAR; FINE LOWER TO 34 MM FRAGMENTS AND LITHS, DOMINANT MEDIUM LOWER; MODERATELY WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH LIGHT GRAY ASHY/ CLAYEY SUPPORTING MATRIX; SCATTERED WHITE ASHY TUFFS. TUFFACEOUS CLAYSTONE/TUFFACEOUS SILTSTONE (5995-6080) = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN AND LIGHT GRAYISH BROWN SECONDARY HUES; SOFT TO MODERATELY FIRM; SUBBLOCKY TO IRREGULAR CUTTINGS; STICKY AND CLUMPY; EXPANSIVE WHEN HYDRATED; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY LUSTRE; FAIR TO GOOD ADHESIVENESS FAIR COHESIVENESS; NON CALCAREOUS; TRACE LIGHT GRAY TO GRAYISH WHITE TUFFS; TRACE CALCITE PIECES. TUFFACEOUS CLAYSTONE (6080-6140) = SAME GENERAL CHARACTERISTICS AS DESCRIBE ABOVE WITH A MAJOR INCREASE IN OVERALL SAMPLE PERCENTAGE AT 6100; CLAYSTONE BECOMING MORE CLUMPY AND VERY STICKY; TR BLACK CARBONACEOUS MATERIAL PRESENT. TUFFACEOUS CLAYSTONE (6120-6195) = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN TO LIGHT BROWNISH GRAY SECONDARY HUES; VERY SOFT; VERY STICKY; CLUMPY; EXPANSIVE WHEN HYDRATED; AMORPHOUS, IRREGULAR CUTTINGS; CLAYEY TEXTURE; DULL EARTHY LUSTRE; FAIR TO GOOD COHESIVENESS; GOOD ADHESIVENESS; NON CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL PRESENT. EPOCH 6 ~Marathon Oil Company - Beaver Creek #10 SAND (6175-6215) = LIGHT GRAY OVER ALL APPEARANCE; INDIVIDUAL GRAINS LIGHT TO MEDIUM GRAY, LIGHT GREENISH GRAY; BLACK, WHITE, TRANSLUCENT, SCATTERED DUSKY RED LITHS; FINE LOWER TO VERY COARSE UPPER, DOMINANTLY MEDIUM UPPER TO LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED TO VERY LOOSELY CONSOLIDATED WITH LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY/CLAYEY SUPPORTING MTX. SAND/SANDSTONE (6225-6285) = LIGHT GRAY TO MEDIUM GRAY; OCC LIGHT GREEN GRAY; VERY FINE TO LOWER MED GRAINED; SUBANGULAR TO OCC SUBRDD; UNCONSOLIDATED; FAIR SORTING; OCC TR CLAY MATRIX; COMPOSED OF 70% QTZ, 20% LITHIC FRAGMENTS, 10% CHERT; NO VIS SHOWS. COAL/CARBONACEOUS SHALE (6285-6300) = BLACK TO DARK BROWN; FIRM TO HARD; BRITTLE; EARTHY TO WAXY LUSTER; GRADING TO DARK BRN CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE/TUFFACEOUS-SlLTSTONE (6300-6375) = LIGHT TO MED GRAY; TR LIGHT GRY BRN; SOFT TO MOD FIRM; SUBBLOCKY TO IRREGULAR CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY LUSTER; SILTY TO VERY SLI SDY; FAIR TO GOOD ADHESIVENESS; NON CALC; TRACE LIGHT GRAY TO GRAYISH WHITE TUFFS. COAL/CARBONACEOUS SHALE (6375-6400) = DARK BROWN TO BLACK; MOD FIRM TO VERY HARD; WAXY LUSTER; SMOOTH TO EARTHY TEXTURE; BRITTLE TO SLI PLATY; GRADING TO DARK BROWN CARBONACEOUS SHALE. SAND/SANDSTONE (6400-6420) = LIGHT GRAY TO MED GRAY; VERY FINE TO LOWER MEDIUM GRAINED; SUBANGULAR TO SUBRDD; MODERATELY WELL SORTED; UNCONS; TRACE CLAY MATRIX; CARBONACEOUS IP; NO VIS SHOWS. TUFFACEOUS CLAYSTONE (6420-6445) = LIGHT TO MED GRAY; SOFT TO MOD FIRM; IRREG TO SUBBLOCKY CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY LUSTER; TRACE COAL PRESENT. TUFFACEOUS CLAYSTONE (6445-6500) = LIGHT TO BROWNISH GRAY; SOFT TO OCC FIRM; BLOCKY TO IRREGULAR SHAPED CUTTINGS; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY LUSTER; TRACE COAL PRESENT. TUFFACEOUS CLAYSTONE (6500-6560) = LIGHT TO MED GRAY; VERY SOFT, VERY CLUMPY; CLAYEY TO ASHY TEXTURE; DULL TO EARTHY LUSTER; TRACE FRAGMENTS OF COAL. TUFFACEOUS CLAYSTONE/TUFFACEOUS SlLTSTONE (6500-6560) = LIGHT GRAY TO GRAY BROWN TO DARK BROWN; SOFT TO MOD FIRM; BLOCKY TO SUB BLOCKY; SILTY TO VERY SLI SANDY; CLAYEY TO ASHY TEXTURE; CARBONACEOUS IN PART; EARTHY LUSTER. EPOCH 7 ~-~Marathon Oil Company - Beaver Creek #10 SAND/CONGLOMERATE (6570-6620) = LT GRAY TO DARK GRAY TO BLACK; VERY FINE TO UPPER MEDIUM GRAINED; TRACE TO FAIR AMOUNTS OF LOWER COARSE GRAINED; SUBANGULAR TO ROUNDED; CLEAR TO OCC FROSTED GRAINS; UNCONSOLIDATED; NO VIS MATRIX; POOR SORTING; POOR TO OCC FAIR SPHERICITY; NO VIS SHOWS. TUFFACEOUS CLAYSTONE (6620-6680) = LIGHT TO MEDIUM GRAY; SOFT TO SLI FIRM; CLUMPY; AMORPHOUS; IRREGULAR CUTTINGS; DULL EARTHY LUSTER; INTERBEDED WITH TRACE CARBONACEOUS MATERIAL; WITH LIGHT GRAY TO GRAY WHITE ASH TUFF; NON CALC; SILTY TO VERY SLI SANDY. COAL (6680-6685) = DARK BROWN TO BLACK; FIRM TO VERY HARD; SMOOTH TO TRACE ROUGH TEXTURE; WAXY TO VITREOUS LUSTER; BLOCKY; WITH GAS BUBBLES COMING FROM COAL CUTTINGS. CONGLOMERATE (6695-6715) = LIGHT GRY TO DRK GRY TO CLEAR; FINE TO VERY COARSE GRAINED; SUBANGULAR TO RDD; ABUNDANT LITHIC/META FRAGMENTS; SLI TO VERY CALC; POSS GAS SHOW. CONGLOMERATE/SAND/SANDSTONE (6730-6820) = VARICOLORED APPEARANCE, DOMINANTLY DARK GRAY OVERALL; INDIVIDUAL GRAINS ARE LIGHT TO DARK GRAY, BLACK, GREENISH GRAY, WHITE, TRANSLUCENT, SCATTERED DARK DUSKY RED LITHS; FINE LOWER TO BROKEN PEBBLES TO 7 MM; ANGULAR TO SUBROUNDED LITHS, DOMINANTLY ANGULAR TO SUBANGULAR; UNSORTED; DISAGGREGATED TO WELL CONSOLIDATED SANDSTONE; NON TO SLIGHTLY CALCAREOUS; OCCASIONAL LOOSELY CONSOLIDATED SANDSTONE WITH LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY/CLAYEY SUPPORTING MATRIX; TRACE LIGHT GRAYISH WHITE WAXY TUFF. TUFFACEOUS CLAYSTONE (6800-6860) = LIGHT TO MEDIUM GRAY; VERY SOFT; VERY STICKY; CLUMPY; AMORPHOUS, IRREGULAR CUT TINGS; CLAYEY/ASHY TEXTURE; DULL EARTHY LUSTRE; EXPANSIVE WHEN HYDRATED; FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; NON CALCAREOUS; PRESENT AS SUPPORTING MATRIX FOR LOOSELY CONSOLIDATED SANDSTONE; TRACE BLACK CARBONACEOUS MATERIAL. COAL (6870-6905) = BLACK WITH DARK BROWN SECONDARY HUES; FIRM TO HARD; BRITTLE; PLATY; PLANAR FRACTURE; SCATTERED BIRDEYE FRACTURE; SMOOTH TEXTURE; RESINOUS TO VITREOUS LUSTRE; TRACE VISIBLE OUTGASSING BUBBLES PRESENT IN LARGER PIECES; TRACE AMBER BEDDED ON COAL. CONGLOMERATE/SAND (6905-6960) = VARICOLORED, DOM DRK GRAY; FINE TO UPPER COARSE GRN; SUBANGULAR TO RDD; UNCONSOLIDATED; SLI TO MOD CALCAREOUS; TRACE CARBONACEOUS MATERIAL. EPOCH 8 ~Marathon Oil Company - Beaver Creek #10 TUFFACEOUS CLAYSTONE (6950-7020) = LIGHT GRAY TO LIGHT GRAYISH BROWN WITH LIGHT GREENISH GRAY SECONDARY HUES; SOFT STICKY; CLUMPY; AMORPHOUS, IRREGULAR CUT TINGS; EXPANSIVE WHEN HYDRATED; ASHY/ CLAYEY TEXTURE; DULL EARTHY TO SLIGHTLY MICROSPARKLY LUSTRE; FAIR ADHESIVENESS AND COHESIVENESS; NON TO SLIGHTLY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL. CONGLOMERATE/SAND (7000-7080) = SAME GENERAL CHARACTERISTICS AS DESCRIBE ABOVE WITH INCREASE IN LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF AT 7050; MEDIUM TO DARK GRAY OVERALL; VERY FINE 7 MM BROKEN FRAGMENTS, DOMINANTLY VERY COARSE; ANGULAR; POORLY SORTED; MODERATE WELL CONSOLIDATED; VERY CALCAREOUS. TUFFACEOUS CLAYSTONE (7060-7120) = LIGHT GRAY TO LIGHT GRAYISH BROWN WITH LIGHT GREENISH GRAY SECONDARY HUES; SOFT STICKY; CLUMPY; AMORPHOUS, IRREGULAR CUT TINGS; EXPANSIVE WHEN HYDRATED; ASHY/ CLAYEY TEXTURE; DULL EARTHY TO SLIGHTLY MICROSPARKLY LUSTRE; FAIR ADHESIVENESS AND COHESIVENESS; NON TO SLIGHTLY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL TRACE LIGHT GRAY TO LIGHT GRAYISH WHITE ASHY TUFF; TRACE VISIBLE SHARDS. SAND/SANDSTONE (7110-7200) = MEDIUM GRAY TO GREENISH GRAY OVERALL APPEARANCE SLIGHT GREENISH "SALT AND PEPPER" APPEAR ANCE; INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAY, MEDIUM GREENISH GRAY, TRANSLUCENT, BLACK, WHITE, DULL BLUISH GREEN; FINE LOWER TO COARSE UPPER WITH COMMON LARGE BROKEN LITHS; ANGULAR; MOD ERATELY SORTED; WELL CONSOLIDATED; HARD TO FRIABLE; VERY CALCAREOUS; COMMON LIGHT GRAYISH WHITE ASHY TUFF. TUFF (7200-7240) =MODERATE INCREASE IN OVERALL AMOUNT AT 7215; LIGHT GRAY TO LIGHT GRAYISH WHITE, OCCASIONALY MOTTLED BROWNISH GRAY; VERY SOFT; ASHY TEXT GLASSY TO DULL LUSTRE; SCATTERED VISIBLE SHARDS; MODERATELY TO STRONG CALCAREOUS. CONGLOMERATE/SAND/SANDSTONE (7230-7300) = MEDIUM TO DARK GRAY TO DARK GREENISH GRAY OVEARALL WITH VARICOLORED LITHS THROUGHOUT; VERY FINE LOWER TO 10 MM BROKEN FRAGMENTS; ANGULAR TO SUBANGULAR; POORLY SORTED; WELL CONSOLIDATED; MODERATE TO VERY CALCAREOUS FOR SOME FRAGMENTS; TRACE TUFFS; TRACE BLACK CARBONACEOUS MATERIAL. CONGLOMERATE/SAND/SANDSTONE (7280-7340) = MEDIUM TO DARK GRAY TO DARK GREENISH GRAY OVEARALL WITH VARICOLORED LITHS THROUGHOUT; VERY FINE LOWER TO 10 MM BROKEN FRAGMENTS; ANGULAR TO SUBANGULAR; POORLY SORTED; WELL CONSOLIDATED; MODERATE TO VERY CALCAREOUS FOR SOME FRAGMENTS; TRACE TUFFS; TRACE BLACK CARBONACEOUS MATERIAL. CONGLOMERATE/SAND (7355-7365) = MED GRY TO DARK GRAY; FINE TO LOWER MED GRAINED; SOME UPPER MED TO LOWER COARSE; SUBANGULAR TO EPOCH 9 ~-~Marathon Oil Company - Beaver Creek #10 SUBROUNDED; FRIABLE IP; OCC CONSOLIDATED TO UNCONSOLIDATED; MODERATE TO VERY CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (7365-7400) = LT GRY TO MED GRY; SOFT TO SLI FIRM; AMORPHOUS; DULL EARTHY LUSTER; TR CARB MATERIAL. SAND/SANDSTONE (7400-7430) = MED GRY TO DRK GRY; FINE TO LOWER MEDIUM; OCC UPPER MEDIUM GRAINED; SUBANGULAR TO SUBROUNDED; POOR SPHERICITY; FAIR SORTING; UNCONSOLIDATED TO OCC TRACE CONSOLIDATED; CALC MATRIX GRADING TO CLAY MATRIX; TR TUFFS; NO CUT OR FLUOR. TUFFACEOUS CLAYSTONE/TUFFACEOUS SlLTSTONE (7430-7480) = MED TO DRK GRY TO DRK BRN; CLAYSTONE IS SOFT TO MUSHY; SILTSTONE IS FIRM TO SLI HARD; SILTY TO SLI SDY; EARTHY LUSTER AND TEXTURE; TR CARBONACEOUS MATERIAL. TUFFACEOUS SlLTSTONE (7480-7495) = DRK BRN; VERY FIRM; GRITTY TEXTURE; EARTHY LUSTER; VERY SILTY TO SLI SDY; OCC CARBONACEOUS MATERIAL; SLI TO MOD CALC. SAND/SANDSTONE (7495-7525) = DRK GRY TO GRY BRN TO DRK BRN; FINE TO LOWER MED GRN; SUBANG TO SURDD; UNCONSOLIDATED POORLY SORTED; TR CALC MATRIX GRADING TO CLAY MATRIX; NO CUT OR FLUOR. COAL/CARBONACEOUS SHALE (7545-7570) = DARK BROWN TO BLACK; SOFT TO VERY HARD; BRITTLE; CONCHOIDAL FRACTURE; VITREOUS TO RESINOUS LUSTER; TRACE VISIBLE GAS BUBBLES. COAL/CARBONACEOUS SHALE (7590-7605) = DARK BROWN TO BLACK; FIRM TO VERY HARD; BRITTLE; CONCHOIDAL FRACTURE; VITREOUS TO RESINOUS LUSTER; SMOOTH TO EARTH TEXTURE; TR VIS GAS BUBBLES. TUFFACEOUS CLAYSTONE/TUFFACEOUS SILTSTONE (7605-7650) = MED GRY TO DRK GRY TO DRK BRN; SOFT TO VERY FIRM; SMOOTH TO EARTHY TEXTURE; SILTY TO SANDY; DULL TO WAXY LUSTER; NON-TO SLI CALC. SAND/SANDSTONE (7650-7690) = DARK GRAY TO DRK BRN; FINE TO LOWER MED GRAINED; SUBANGULAR TO SUBROUNDED; POOR SORTING; POOR SPHERICITY; MOD TO VERY CALCAREOUS; UNCONSOLIDATED; NO VIS SHOWS; WITH TRACE CARBONACEOUS MATERIAL PRESENT. TUFFACEOUS CLAYSTONE (7690-7770) = LIGHT TO MEDIUM GRAY WITH LIGHT BROWN SECONDARY HUES; VERY SOFT; VERY STICKY; CLUMPY; AMORPHOUS, IRREGULAR CUTTINGS; EXPANSIVE WHEN HYDRATED; CLAYEY TEXTURE; DULL TO EARTHY LUSTRE; FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; NON CALCAREOUS; PRESENT AS SUPPORTING MATRIX FOR SAND; TRACE BLACK CARBONACEOUS MATERIAL. [:::1 EPOCH lO ~Marathon Oil Company - Beaver Creek #10 COAL (7735-7770) = BLACK WITH DARK DUSKY BROWN SECONDARY HUES; VERY FIRM TO HARD; BRITTLE; PLATY TO BLOCKY; DOMINANT PLANAR FRACTURE; OCCASIONAL BIRDEYE FRACTURE; DENSE, SMOOTH TEXTURE; GLASSY TO RESINOUS LUSTRE; COMMON VISIBLE OUTGASSlNG BUBBLES PRESENT. TUFFACEOUS CLAYSTONE (7790-7820) = LIGHT TO MEDIUM GRAY; VERY SOFT TO SOFT; CLUMPY; SMOOTH TO CLAYEY TEXTURE; TRACE AMOUNTS OF CARBONACEOUS SHALE AND COAL. COAL (7820-7830) = DARK BROWN TO BLACK; FIRM TO MOD HARD; CONCHOIDAL FRACTURE; VITREOUS TO RESINOUS LUSTER; SMOOTH TO EARTHY TEXTURE. SAND/SANDSTONE (7840-7860) = COLOR VARIES FROM MILKY TO DK GRAY; VERY FINE TO MEDIUM; SUBANGULAR TO SUBROUNDED; POOR TO FAIR SORTING; LOW TO MODERATE SPHERICITY; SLIGHTLY CALCAREOUS; CALCAREOUS TO CLAYEY MATRIX. 7900 SAND/SANDSTONE (7880-7910) = MEDIUM GRAY TO DARK GRAY; VERY FINE TO MEDIUM; SUBANGULAR TO SUBROUNDED; LOW TO MODERATE SPHERICITY; POOR TO FAIR SORTING; PREDOMINANTLY UNCONSOLIDATED; CLAYEY MATRIX. SAND/SANDSTONE (7930-7956) = LIGHT TO DRK GRY TO BLACK; VERY FINE TO UPPER MED GRAINED; SUBANGULAR TO SUBRDD; OCC ROUNDED; PREDOMINANTLY UNCONS; FAIR SPHERICITY; POOR TO OCC FAIR SORT; NON-TO MOD CALC; CALC MATRIX GRADING TO CLAYEY MATRIX. TUFFACEOUS SlLTSTONE (7965-7985) = DRK GRAY TO DRK BROWN; FIRM TO SLI HARD; CHUNKY; SLI TO VERY CALC; SILTY TO VERY SANDY; DULL EARTHY LUSTER; ROUGH TEXTURE. SAND (7995-8005) = DARK GRAY TO GRY BLK; V FINE TO LOWER MED; TR LOWER COARSE; SUBANG TO SUBRDD; POOR SORT; POOR SPHERICITY; VERY CALC; CALC TO SLI CLAY MATRIX; VERY DIRTY. COAL (8030-8075) = BLACK WITH DARK BROWN SECONDARY HUES; MODERATELY HARD; BRITTLE; SPLINTERY; PLATY TO BLOCKY CUT TINGS; VERY STRONG PLANAR FRACTURE; SMOOTH, GLASSY TO PITHY, FIBROUS TEXTURE; EARTHy TO RESINOUS LUSTRE; COMMON VISIBLE OUTGASSING BUBBLES PRESENT; OCCASIONALY GRADING TO CARBONACEOUS SHALE. SAND (8075-8110) = MEDIUM TO DARK GRAY TO DARK GREENISH GRAY OVERALL; INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAY TO BLACK, LIGHT GRAY TO TRANSLUCENT WHITE; FINE LOWER TO COARSE UPPER, DOMINANTLY MEDIUM UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH LIGHT GRAY TO LIGHT BLUISH GRAY CLAY SUPPORT MATRIX; NON CALCAREOUS; TRACE BLACK CARBONACEOUS MATERIAL. EPOCH 11 ~Marathon Oil Company - Beaver Creek #10 TUFFACEOUS SlLTSTONE (8130-8190) = GRAYISH BROWN; FIRM TO FRAGILE; PLATY TO SUBBLOCKY; CLAYEY TO SLIGHTLY GRITTY TEXTURE; DULL TO SLIGHTLY WAXY LUSTRE; SCATTERED BLACK, MICROTHIN CARBONACEOUS LAMINATIONS AND PIECES; NON CALCAREOUS; TRACE GRAY TO GRAYISH WHITE ASHY TUFF, MODERATELY TO VERY CALCAREOUS. SAND/SANDSTONE (8180-8250) = MEDIUM GRAY TO DARK GREENISH GRAY OVERALL; INDIVIDUAL GRAINS DOMINANTLY MEDIUM TO DARK GRAY TO BLACK, LIGHT GRAY TO TRANSLUCENT WHITE; FINE LOWER TO COARSE UPPER, DOMINANTLY MEDIUM UPPER; ANGULAR TO SUBANGULAR; MODERATELY WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH LIGHT GRAY TO LIGHT BLUISH GRAY CLAY SUPPORT MATRIX; NON CALCAREOUS; COMMON BLACK TO DARK DUSKY BROWN CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (8230-8310) = LIGHT GRAY WITH LIGHT BROWNISH GRAY SECONDARY HUES; VERY SOFT; VERY STICKY; AMORPHOUS, GLOBULAR CUTTINGS; EXPANSIVE WHEN HYDRATED; CLAYEY TEXTURE; DULL TO EARTHY LUSTRE; GOOD ADHESIVENESS; FAIR TO GOOD COHESIVENESS; MODERATE TO STRONGLY CALCAREOUS; COMMON BLACK CARBONACEOUS MATERIAL PRESENT; TRACE GRAYISH WHITE TO GRAYISH BROWN, ASHY TUFFS. SAND (8290-8350) = LIGHT TO MEDIUM GRAY, MEDIUM GREENISH GRAY, TRANSLUCENT, WHITE, BLACK; VERY FINE LOWER TO COARSE LOWER, DOMINANTLY MEDIUM LOWER; ANGULAR TO SUBROUNDED, DOMINANTLY SUBANGULAR; MODERATELY WELL SORTED; DOMINANTLY DISAGGREGATED WITH OCCASIONAL PIECES CEMENTED SANDSTONE; HARD; NON CALCAREOUS CEMENT; COMMON BLACK CARBONACEOUS MATERIAL. TUFFACEOUS CLAYSTONE (8345-8385) = LIGHT GRAY TO DARK GRAY; VERY SOFT; DULL TO EARTHY LUSTER; AMORPHOUS; GLOBULAR CUTTINGS; CLAYEY TEXTURE; SLI TO MOD CALCAREOUS; COMMON BLACK TO DARK BRN CARBONACEOUS MATERIAL PRESENT; TRACE GRAYISH WHITE TO GRAYISH BROWN ASH. SAND/SANDSTONE (8385-8420) = MD GRY TO DRK GRY TO BLACK; FINE TO UPPER MED GRAINED; SUBANGULAR TO SUBROUNDED; MODERATELY WELL SORTED; FAIR SPHER; UNCONSOLIDATED; OCC TRACE CLAYEY TO SLI CALC MATRIX; COMMON DRK BRN TO BLACK CARBONACEOUS MATERIAL PRESENT. COAL (8455-8470) = DARK BROWN TO BLACK; SOFT TO MODERATELY FIRM; BLOCKY; SMOOTH TO EARTHY TEXTURE; DULL LUSTER; GRADING TO A DARK BROWN CARBONACEOUS SHALE; TRACE AMOUNTS OF LIGHT BROWN TUFFACEOUS ASH. SAND/SANDSTONE (8475-8500) = COLOR VARIES FROM TRANSLUCENT TO DARK GRAY; VERY FINE TO FINE GRAINED; SUBANGULAR TO SUBROUNDED; POOR TO EPOCH 12 ~Marathon Oil Company - Beaver Creek #10 FAIR SORTING; LOW TO MODERATE SPHERICITY; PREDOMINANTLY UNCONSOLIDATED; SLIGHTLY CALCAREOUS TO CLAYEY MATRIX. TUFFACEOUS CLAYSTONEI TUFFACEOUS SILT STONE (8500-8585) = CLAYSTONE CONTINUES TO SHOW SAME CHARACTERISTICS ASDESCRIBED ABOVE; SILTSTONE IS DOMINANTLY MEDIUM TO DARK BROWN WITH GRAY SECONDARY HUES; FIRM TO VERY FIRM; IRREGULAR SHAPE CUTTINGS; SILTY TO CLAYEY TEXTURE; GREASY TO SLIGHTLY WAXY LUSTRE; COMMON VERY DARK BROWN TO BLACK MICROTHIN CARBONACEOUS LAMINATIONS AND PIECES THROUGHOUT; NON CALCAREOUS; TRACE GRAY TUFF. SAND/SANDSTONE (8600-8630) = LT TO DARK GRAY; VERY FINE TO FINE GRAINED; SUBANGULAR TO SUBROUNDED; POOR SORTING; LOW TO MODERATE SPHERICITY; UNCONSOL; TRACE AMOUNTS OF GREEN QUARTZITE PRESENT; CALCAREOUS MATRIX. SAND/SANDSTONE (8630-8670) = TRANSLUCENT TO MEDIUM GRAY; VERY FINE TO FINE GRAINED WITH OCC LOWER TO UPPER COARSE GRAINS PRESENT; POOR TO FAIR SORTING; LOW TO MODERATE SPHERICITY; UNCONSOLIDATED; COAL IS BLACK; FIRM TO HARD; CONCHOIDAL FRACTURE. TUFFACEOUS CLAYSTONE (8670-8740) = LIGHT TO MEDIUM GRAY WITH FAINT LIGHT BROWN SECONDARY HUES; VERY SOFT TO SLIGHT FIRM; AMORPHOUS TO BLOCKY CUTTINGS WITH FIRMER PIECES; OCCASIONALY VERY STICKY AND CLUMPY; EXPANSIVE WHEN HYDRATED; CLAYEY TEXTURE; DULL LUSTRE; FAIR TO GOOD ADHESIVENESS AND COHESIVENESS; MODERATE TO STRONGLY CALCAREOUS; COMMON TO ABUNDANT BLACK CARBONACEOUS MATERIAL/ COAL, PRESENT AS THIN LAMINATIONS AND MINOR 2 TO 3 BEDS. COAL (8670-8800) = BLACK WITH VERY DARK BROWN SECONDARY HUES; VERY FIRM TO HARD; BRITTLE; PLATY TO BLOCKY CUTTINGS; DOMINANT PLANAR FRACTURE, RARE BIRDEYE AND CONCHOIDAL FRACTURE; SMOOTH TO MATTE TEXTURE; VITREOUS TO EARTHY LUSTRE; SCATTERED VISIBLE OUTGASSING BUBBLES FROM LARGER FRAGMENTS; PRESENT AS THIN BEDS IN DOMINANTLY TUFFACEOUS CLAYSTONE/SILT STONE AND SAND FORMATION. SAND (8800-8854) = VERY LIGHT GRAY TO TRANSLUCENT TO CLEAR QUARTZ; VERY FINE UPPER TO MEDIUM LOWER; ANGULAR TO SUBANGULAR; WELL SORTED; DISAGGREGATED TO LOOSELY CONSOLIDATED WITH VERY CALCAREOUS CLAYEY SUPPORTING MATRIX. EPOCH 13 ~JMarathon Oil Company - Beaver Creek #10 DAILY CHRONOLOGY 313012001: Pick up 162 joints 4" drill pipe and rack back. Slip and cut 156' drill line. RIH, pick up drill pipe. Complete mixing new mud for 6.125" hole section. Tag up @ 2289'. Drill float collar @ 2290'. Drill cement in shoe tract and shoe @ 2374'. Clean old hole to 2385'. Drill 6.125" hole f/2385' to 2405'. CBU @ 2405'. Perform LOT. 16.4 EMW (8.9 ppg MW and 910 psi). Displace well to 8.7 ppg FLO-PRO mud system. Repair pipe gripper on TDS. Directional drill and survey f/2405' to 2980'. CBU @ 2980'. POOH to CSG shoe. Repair pipe gripper on TDS. RIH, wash down last 50'. 313112001: Directional drill and survey f/2980' to 4516'. CBU @ 4516'. POOH to CSG shoe. Service rig. 4101/2001: RIH. Move clock ahead 1 hour for day light savings time. Continue RIH. Wash down last 50' (8' fill). Directional drill and survey f/4516' to 5215'. Circulate shakers clean and slug pipe. POOH. B/O bit #3/LID mud motor ( stabilizers from MWD had washed into motor. Found stabilizer parts and mud motor rubber in bit nozzles). Pull MWD probe and replace stabilizers. P/U new mud motor and M/U bit #4. Adjust AKO ans scribe motor and MWD. Test MWD and motor. RIH to CSG shoe. Service rig. RIH to 5147'. Wash and ream f/5147' to 5215' (10' fill). Directional drill and survey f/5215' to 5302'. 4102/2001: Continue to directional drill f/5302' to 6215'. CBU @ 6215' and slug pipe. POOH f/6215' to 6087'. Wash and ream tight spots f/6087' to 5907'. POOH f/5907' to 4950'. RIH. (No fill). Directional drill and survey f/6215' to 6400'. 410312001: Continue to directional drill and survey f/6400' to 6906'. Circulate shakers clean @ 6906'. B/R 6906' to 6844'. POOH f/6844' to 6720'. B/R f/6720' to 6038' (Tight spots). Slug pipe and POOH. B/O bit. Pull wear bushing. Test upper pipe rams, lower pipe rams, blind rams, all choke manifold valves, upper and lower top drive valves, TIW and IBOP valves, choke and kill line valves to 250 psi/5 min, 5000 psi / 5 min. Test annular to 250 psi / 5 rain, 3000 psi/5 min. 410412001: RID test plug. M/U bit #5. Test mud motor and MWD. RIH to 2370'. Slip and cut drill line. Service rig. Continue RIH. Wash and ream f/6715' to 6906'. Directional drill and survey f/6906' to 7480'. Rig power shut down while drilling. 4105/2001: Set rig to manual operation. Pick up and rack back 1 stand. Circulate and rotate while trouble shoot rig power system. Had to reseat Genus card in drillers console. Directional drill and survey f/7480' to 7788'. Circulate shakers clean. POOH f/8877' to 7354'. Back ream f/7354' to 7324'(tight hole). POOH f/7324' to 7161'. Back ream f/7161' to 6913'. Pump out f/6913' to 6785'. POOH f/6785' to 6412' Slug pipe and POOH (Hole took 11 bbls mud over displacement). Break off bit #5 and make up bit #6 (Observed fluid level to be static while changing bits). Test MWD and motor. RIH to 2370'. Service rig. Continue to RIH to 7788' (Tagged fill @ 7782', wash and ream to 7788'). 4/0612001: Finish RIH. Directional drill and survey f/7788' to 8069'. Change swab on #2 mud pump. Directional drill and survey f/8069' to 8418'. EPOCH 14 ~Marathon Oil Company - Beaver Creek #10 410712001: Circulate while change out hydraulic pump on #2 mud pump motor (Ruptured seal in hydraulic pump). Directional drill and survey f/8418' to 8500'. Circulate with pump #1 while change swan #2 in mud pump #2. Directional drill and survey f/8500' to 8587' Circulate with pump #2 while change swab #3 in mud pump #1. Circulate shakers clean. Back ream f/8587' to 8541'. Pul f/8541' to 8357'. Back ream f/8357' to 7728' (tight hole). Pump out f/7728' to 7541'. Circulate bottoms up @ 7541'. Slug pipe and POOH (SLM)(Took 11 bbls over displacement). Lay down MWD probe and change battery> Break off bit #6 and Make up bit #7. Pick up MWD. RIH to 2370'. Service rig. Adjust brake bands. Pump up pressure sensor for mud pump. 4/0812001: Slip and cut drill line. RIH and tag fill @ 8577'(10' fill). Wash to 8587'. Directional drill and survey f/8587' to 8854'. Circulate and condition mud for short trip. POOH to 6984'. RIH to 8854'. Circulate and condition mud. Pump hi-vis sweep and circulate out. POOH to 8481'. Pump slug. POOH. 4109/2001: Continue to POOH.(Took 16 bbls over displacement). Laydown MWD probe and pulser sub. Break off bit. Rig up Schlumberger. Safety meeting prior to running open hole logs. RIH with AIT/HGNS/HRMS to 8854'(loggers td 8855'). Had several tight pulls while logging out and lost 1 - 5.5" rubber standoff in hole( Hole taking .5 bbl/hr- 1 bb./hr). Caliper Schlumberger CMR tool and find that overbody decetralizer makes tool too large to run in a 6 1/8" borehole. Wait on Schlumberger DSI tool and inline slimhole decentralizer. RIH with 6 1/8" bit to 7" casing shoe and break circulation. Continue to RIH to 8854' Circulate and condition mud. Slug pipe. POOH. Work tight spots @ 8125' and 7395'.( Took 13 bbls over displacement). 4/1012001: Rig up Schlumberger. Run DSI log. Lay down DSI log( Losses to hole minimal). Run CMR log. Rig down Schlumberger. Test upper pipe rams, lower pipe rams, blind rams, all choke manifold valves, upper and lower top drive valves, TIW and IBOP valves, choke and kill line valves to 250 psi/5 min, 5000 psi/5 min. Test annular to 250 psi/ 5 min, 2500 psi/5 min. Make up bit and RIH. Circulate and condition mud. 411112001: Continue to circulate and condition mud. Spot 3 bbls, 16.0 ppg pill on bottom. Rack back 3 stands to 8668'. Slug pipe and POOH( Rack back first 30 stands and then begin to POOH laying down drill pipe.) RIH with 33 stands that was racked back in derrick. POOH, lay down drill pipe, HWDP, BHA and bit. Pull wear bushing. Run test plug assembly. Change out pipe rams to 3 %". Perform body test to 250 psi/5 min, 3000 psi/5 min against annular. Rig down test plug assembly. Change to long bails and 3 %" casing elevators (Hole taking I bbl/hr losses.) Rig up Weatherford casing running tools. Make up hanger assembly to landing joint and lay down. Make up 3 %" 8RD x 4" HT-38 cross over to TIW valve. Function valve and leave in open position on rig floor. Pick up 3 %" casing joint #1 and Bakerlok. pick up joint #3 and Bakerlok. Test floats. Safety meeting prior to running casing. RIH with 3 %", 9.3 ppf L-80 casing. 411212001: Continue to RIH with 3 %' casing to shoe. While circulate at shoe, rig up sheave for running the injection control line. Make up 3 %" butt x 3 %" IF cross over to plug dropping assembly and lay down. Continue to RIH with 3 1/2/" casing. EPOCH 15 (~Marathon Oil Company - Beaver Creek #10 4/1312001' Epoch Unit #6 released. EPOCH 16 RIG ACTIVITY RIG ACTIVITY SUMMARY Marathon Oil Company Beaver Creek BEAVER Creek Fileld Section 34-77N-RIOW SM WlRE~~Ous SLIP D R I L$-~t¥~Y RIG REPAIRS CIRCULATING DRILL REAM TRIP [] DRILL [] TRIP [] REAM [] CIRCULATING El SHORT TRIP [] RIG SERVICE []RIG REPAIRS []SLIP DRILL LINE []SURVEY []WIRELINE LOG []TOP DRIVE ~ RUN CASING []CMTING ACTIVITY []DRILL CEMENT []RIG UP/DWN EQUIP. []B H A •TEST LINES/BOPE []NIPPLE UP/DOWN •TEST CASING EILEAK OFF TEST •FISHING •DIP WORK []CLEAN PITS []MISCELLANEOUS (/~Marathon Oil Company - Beaver Creek #10 MUD RECORD MUD REPORT RECORD M I MARATHON~ ~ BC-10 BEAVER CREEK OIL COMPANY KENAI PENNINSULA, AK GLACIER DRILLING RIG #1 MARCH 3t, 2001 TO APRIL 11, 2001 APl Number: 50-'133-20482-00 Depths: 2385' TO 8854' DATE DEPTH MW VIS PV YP GELS FL FC SOL OIL SD MBT pH AIk Cl- Ca+ MD / TVD 3/29/0i' i 2385'/2355' ~ 8.70 i 35 i 3 ! 10 i 5/7/8 10.6 0 i 2.5 i0/97.5i0.00! 0.0 i 7.5 i0.00 28500i 80 3/30/01 i 319873065' i 8.85 i 40 i 5 i~ 19 i10/12/16! 7.2 i 1 i 5.0 i 0/95 i TR i 2.5 i 8.5 i TR !30500i 80 i 9.00 ~ ~ I i i 30500 i 100 3/31/0i 4516'/4241' : , 39 ~ 6 i 21 111/13/141 7.6 i I ! 5.0 i 0/95 i TR i 5.0 I 9.2 0.90~ 4/1/01 / 5260'/4969' !i 9.00 ' 4121-01_ - i 6440'/6147' i 9.25 ! 45 i 8 ! 29 !11/14/15i 7.1 i 2 i 8.0 1 0/92, i TR i 5.5 !10.0!0.60!29000.1140 4/3/01 ', 6906'/6614' ~ i 9.30 i 45 i 9 i 27 110/15/18! 7.0i 1 i 7.0 : 0/93 i TR ! 5.0 i 9.5 i0.30128000i 60 -' i - ~ ~ i i TR i 5.0 I 9.0 i0.10i 4/4/01 .... i_ 7480'/7186' 9.40 i 47 i 10 ~ 25 ~ 10/16/16 ~ 6.4 i 2 i 7.5 i0/92.5~ i ~28000i 80 4/5/01 i 7788'/7494' ! 9.50 i 47 ~ 10 ~, 25 i11/18/20i 6.3 i 2 i 8.5 !0/91.5! TR i 5.0 i 8.7 i0.101280001 60 4/6/01 - i ~ i 8418'/8125' ! 9.35 i 43 ; 9 i 21 i12/17/18! 5.8 ! 1 i7.5 i0/92.51 TR i 5.0' 9.5!0.10 i27oooi 4o 4/7/Ol ', 8587'/8294' ! 9.40 i 43 ! 9 i 19 !11/16/18i 6.1 i 1 i 8.o i o/92 i TR i 5.0 i 9.0 i0.10i26000i 40 4/8/01 ,. 8854'/8560' ~ 9.55 ! 47 i 9 i 20 !18/25/271 6.o i 2 i 8.0 ! 0/92 i TR' 7.5!8.7!0.10 i30000i 80 ' 4/9/0'~ ' i 8854'/8560' i 9.75 ! 49 i 11 i 21 120/30/331 5.4i 2 i 9.0 ! 0/91 i TRI 9.0 i 8.5 i0.05 !3ooooi lOO ....... :- 4/10/01 I 8854'/8560/ i 9.50 ! 48 10 ~ 19 i16/24/27i 5.8i 2 ~ 8.0 i 0/92 i TR i 8.0 ! 8.5 i0.05i30000i100 4/11/01 ' 8854'/8560' ~ 9.55 i 47 i 10 i 20 116/25/271 5.8 i 2 ! 8.0 ! 0/92 i TR i 7.5 i 8.3 !0.00i29500i100 DI EPO"'H 8 (~Marathon Oil Company - Beaver Creek #10 SURVEY RECORD SURVEY RECORD MARATHON OIL COMPANY BC-10 (fi) I (deg) I (deg) I (ft) 195.00 1.02 134.30 195.00 315.00 1.21 138.60 120.00 434.00 1.06 141.00 119.00 555.00 0.80 97.70 121 676.00 0.60 123.40 121.00 797.00 0.37 100.60 121.00 920.00 0.52 137.40 123,00 1044.00 0.96 173.70 124.00 1137.00 0.20 212,92 93.00 1293.00 3.29 92.30 156.00 1356.00 3.49 96.30 63.00 1449.00 5.66 92.40 93.00 1554,00 8.31 87.20 105,00 1639.00 10.07 83.60 85.00 1733.00 12.19 82.40 94.00 1830.00 13.67 78.90 97.00 1941.00 17.11 81.90 111,00 2044.00 20.18 81.40 103.00 2158,00 22.45 80.90 114.00 2232.00 24.76 80.60 74.00 2326.00 27.47 81.70 94.00 2448.00 27.23 79.50 122.00 2573.00 26.75 79.20 125.00 2766,00 27.67 78.80 193,00 2891,00 27.75 78,30 125.00 3078.00 27.14 79.80 187.00 3176.00 27.55 79.40 98.00 3332.00 26.91 82.50 156.00 3518.00 26.72 82.50 186.00 3708.00 28.05 83.10 190.00 3836.00 27.39 81.50 128.00 3898.00 27.27 81.30 62.00 3993.00 26.12 83.50 95,00 4086.00 25.22 82.80 93.00 4181.00 24.05 84,30 95.00 4272.00 22.61 83.50 91,00 4397.00 21.21 85.23 125.00 4493.00 19.53 87.70 96.00 4587.00 18.83 87.30 94.00 4684.00 17.67 84.60 97.00 4776.00 15.92 83.50 92.00 4871,00 14,71 86.90 95.00 4965.00 13.06 84.90 94.00 5061.00 12.25 86.00 96.00 5151.00 10.20 83.90 90.00 5245.00 8.87 83.70 94.00 5339.00 8,06 86.30 94.00 5466.00 5.63 81.70 127.00 5562,00 3.50 79.80 96,00 5626.00 2.80 92.40 64.00 5719.00 0.64 131,10 93.00 5846.00 0.43 171.60 127.00 5970.00 0.56 192.30 124.00 6095.00 0,38 173.80 125.00 6222.00 0.63 178.70 127.00 6347.00 0.61 183.00 125.00 6471.00 0.85 179.60 124.00 6595.00 1.02 171.80 124.00 6684.00 1.03 194.30 89.00 6852.00 0.74 291.50 168.00 6977.00 1.05 266.70 125.00 7104.00 1.36 259.50 127.00 7177.00 1.78 254.30 73.00 7359.00 1,21 233.30 182,00 7483.00 1.83 229.60 124. O0 7607.00 0.68 245.90 124.00 7732.00 0.86 240.50 125.00 7857.00 1.03 258.70 125.00 7983.00 1,23 256.70 126.00 depth I section (ft) (ft) 194.99 1.11 314.97 2.54 433.95 3.87 554.94 5.30 675.93 6.61 796.93 7.48 919.93 8.40 1 043.92 8.75 1136.91 8.65 1292.83 12.91 1355,72 16.58 1448.42 23.89 1552.63 36.60 1636.54 50.16 1728.77 68.30 1823.31 89.95 1930.32 119.33 2027.90 152.23 2134,10 193.60 2201.90 223.18 2286.30 264.49 2394.66 320.42 2506.05 374.94 2677.69 464.81 2788.35 522.65 2954.31 608.48 3041.36 653.35 3180.08 724.59 3346.08 808.46 3514.78 895.83 3628.09 955.32 3683.17 983.76 3768.04 1026.41 3851.86 1066.68 3938.21 1106.28 4021.77 1142.31 4137.74 1188.95 4227.74 1222.33 4316.52 1253.17 4408.64 1283.52 4496.71 1310.10 4588.34 1335.17 4679.59 1357.72 4773.26 1378.75 4861.53 1396.26 4954.23 1411.83 5047.21 1425.66 5173.29 1440.78 5268,98 1448.41 5332.89 1451.90 5425.84 1454.51 5552.83 1455.02 5676.83 1454.85 5801.83 1454.66 5928.82 1454.61 6053.81 1454.46 6177.80 1454.27 6301,78 1454.23 6390.77 1453.99 6558.76 1452.51 6683.75 1450.65 6810.72 1447.99 6883.69 1446.01 7065.63 1441.58 7189.59 1438.83 7313,56 1436.50 7438.55 1434.94 7563.53 1432.97 7689.51 1430.50 EPOCH BEAVER CREEK FIELD I +N/S- +E/W- (deg/ Rate (ft) (ft) ioof) (+) (-) -1.21 1.24 0.52 0.52 -2.91 2.84 0.17 0.16 -4.71 4.36 0.13 -0.13 -5.69 5.90 0.60 -0.21 -6.15 7.27 0.30 -0.17 -6.57 8.18 0.24 -0.19 -6.57 9.12 0.12 0.12 -6.20 9.61 0.50 0.35 -9.11 9.61 0.88 -0.82 -9.52 13.94 2.18 1.98 -9.80 17.65 0.49 0.32 -10.30 25.05 2.36 2.33 -10.15 37.80 2.59 2.52 -9.02 51.32 2.18 2.07 -6.79 69.33 2.27 2.26 -3,23 90.73 1.73 1.53 1.60 119.78 3.18 3.10 6.39 152.35 2.98 2.98 12.78 193.30 2,00 1.99 17.54 222.54 3.13 3.12 23.89 263.42 2.93 2,88 33.04 318.71 0.85 -0.20 43.52 374.46 0,40 -0.38 60.36 461.09 0.49 0.48 71,90 518.06 0.20 0.06 88.28 602.67 0.49 -0.33 96.41 646.95 0.46 0.42 107.65 717.42 1.00 -0,41 118,60 800.61 0,10 -0,10 129.54 887.31 0.71 0.70 137,51 946.31 0.78 .0.52 141.77 974.46 0.24 -0.19 147.43 1016.75 1.60 -1.21 152.23 1056.75 1.02 .0.97 156.69 1096.09 1.40 -1.23 160.51 1131.93 1.62 -1,58 165.11 1178.34 1.23 -1.12 167.20 1211.68 1.97 ~1.75 168.55 1242.53 0.76 -0.74 170.67 1272.82 1.48 -1.20 173,41 1299.26 1.93 -1.90 175.54 1324,25 1.59 -1.27 177.13 1346.75 1.83 -1.76 178.80 1367.71 0.88 -0.84 180.32 1.85.16 2.32 -2.28 182.00 1400.64 1.42 -1.41 183.22 1414,42 0,95 -0.86 184.69 1429.47 1.96 -t.91 185.89 1437.02 2.22 -2.22 186.17 1440, 50 1.53 -1.09 185.74 1443.16 2,51 -2.32 184,80 1443.77 0.33 -0.17 183,75 1443.70 0,18 0.10 182.74 1443.62 0.19 -0.14 181.62 1443.68 0.20 0.20 180.27 1443,66 0.04 -0.02 178.69 1443.63 0.20 0.19 176.68 1443.79 O. 17 0.14 175.12 1443.71 0.45 0.O1 174.05 1442.33 0.80 -0.17 174.28 1440.44 0.39 0.25 173.94 1437.80 0.27 0.24 173,45 1435.86 0.61 0.58 171.57 1431.60 0.43 -0.31 169.50 1429.04 0,51 0,50 167.92 1426.86 O. 96 -0.93 167.16 1425.37 0.16 0.14 166.48 1423.45 0.27 O. 14 165.95 1421.02 0.16 0.16 19 (~ Marathon Oil 70 8013.00 1.06 266.20 30.00 71 8172.00 0.62 167.60 159.00 72 8235.00 0.72 182.60 63.00 73 8360.00 0.84 195.30 125.00 74 8485. O0 1.01 189.10 125, O0 75 8531.00 1.24 200.00 46.00 76 8609.00 1.26 190.00 78.00 77 8797.00 1.27 208.20 188.00 78 8854.00 1.28 208.20 57.00 Company - Beaver Creek #10 7719.50 1429,90 165.86 1420.43 0.85 -0.57 7878.49 1428.53 164.92 1419.15 0,82 -0.28 7941.49 1428.51 164.19 1419.21 0.32 O. 16 8066.48 1428.08 162.52 1418.93 0.17 0,10 8191.46 1427.46 160.55 1418.51 0.16 0,14 8237.45 1427.14 159.68 1418.28 0.68 O. 50 8315.43 1426.54 158.04 1417.84 0.28 0.03 8503.39 1424.81 154.17 1416.49 0,21 0.01 8560.37 1424.11 153.05 1415.90 0.02 0.02 EPOCH 20 (~Marathon Oil Company - Beaver Creek #10 BIT RECORD BIT REPORT RECORD MARATHON OIL COMPANY BC-10 BEAVER CREEK FIELD GLACIER KENAI PENNINSULA, AK DRILLING RIG #1 VlARCH 31 2001 TO APRIL 8, 2001 APl Number · 50-133-20482-00 FROM 2385' TO , 8854' SER NO. JETS DEPTH DEPTH ROP RPM PP GRADE BIT SIZE i TYPE 1 2 8.5 STC FGSS+2 3 6.125 STC MGR32XP 4 6.125 STC XR15TDGPS 5 6.125 iSTC XR15TDGPS 6 6.125 STC XR20HTDGP _ - 7 ' 6.125 i STC XR20HTDGP 8 ; MG8020 JS4579 LY7012 LX5916 LY0226 14,16,14 6X 10'S 12,12,14 12,12,14 12,14,14 105' 2385 5215 69O6 7788 OUT 2385' 5215 69O6 7788 8587 FTG , 2280' 2830' 1691 882 796 i WOB HRS i I-O-D-L-B-G- Avg }Hi-Lo-Avg Hi-Lo-Avg Hi-Lo-Avg OT - R 10.75 29.75 28.50 24.50 212.1 95.1 59.3 36.0 32.6 24.4O 15 15 10 14 45.0 i 1800-1300 40.0 1800-1300-1600 40-35 35.0 40.0 i2300-2000-2100 2,2,WT,A,E,0,NO,TD 8,2,CT,N,X,0,WT, DT F 8,8,BT,A,F,4,SD,HR 2650-2300-2500 i 6,6,WT,A,E,2,LT, HR 2750-2300-2450 LY0220 12,14,14 8587 8854 267 9.75 27.4 15 35.0 ~ 2450 i 2,2,WT,A,E,0, NO,TD EPOCH ~Marathon Oil Company - Beaver Creek #10 DAILY REPORTS EPOCH Daily Report Page 1 of 1 BC-10 REPORT FOR COMPANY MAN DATE Mar 30, 2001 TIME 19:24:03 CASING INFORMATION 7" to 2374' DEPTH SURVEY DATA BIT INFORMATION NO. SIZE TYPE S/N JETS DAILY WELLSITE REPORT DEPTH 2980 YESTERDAY 2385 24 Hour Footage 595 INCLINATION INTERVAL IN OUT FOOTAGE DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW FC MWD SUMMARY INTERVAL TO TOOLS HIGH LOW 496.7 @ 2825 11.0 79 @ 2825 1 4 @ 2406 0 @ 0 @ 2980 0 @ 1796 @ 2771 838 DEPTH: VIS PV SOL SD EPOCH PRESENT OPERATION= DRILLING GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 4 @ 2403 0 @ 2391 0.1 CUTTING GAS 0 @ 2980 0 @ 2980 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 915 @ 2403 -1 @ 2954 15.0 ETHANE(C-2) 0 @ 2980 .4 @ 2400 -1.0 PROPANE(C-3) 0 @ 2980 -4 @ 2400 -1.0 BUTANE(C-4) 0 @ 2980 -8 @ 2400 -2.0 PENTANE(C-5) 0 @ 2980 -8 @ 2400 -2.0 HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY DALLY ACTIVITY SUMMARY DRILL TO 2980', REPAIR TOP DRIVE, RESUME DRILL AZIMUTH HOURS VERTICAL DEPTH CONDITION REASON T/B/C PULLED AVERAGE CURRENTAVG 2688 138.5 141.8 fi/hr 2693 59.6 11.9 amps 2386 3.0 3.0 Klbs 2980 0,0 0 RPM 2410 1270.8 1375 psi YP FL Gels CL- OIL MBL pH Ca+ CCI TRIP GAS= N/A WIPER GAS= N/A SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= N/A CURRENT N/A CURRENT BACKGROUND/AVG <lu GAS DESCRIPTION Epoch Personel On Board= Daily Cost 1,575.00 Report by: KURT LEONARD 0 file:/A\DML2000\WELL ~20REPORTS\Marathon\BC 10\20010330.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROVVLAND LAWSON DATE Mar 31, 2001 TIME 20:56:12 CASING INFORMATION 13.375" @113' 7" @ 2376' DEPTH SURVEY DATA 4086 DAILY WELLSITE REPORT DEPTH 4516 YESTERDAY 2980 24 Hour Footage 1536 INCLINATION AZIMUTH 25.22 82.80 EPOCH PRESENT OPERATION= WIPER TRIP VERTICAL DEPTH 3851.86 BIT INFORMATION NO. SIZE TYPE SIN 6.13" PDC DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 8.7 VIS 39 FC 1 SOL 4 MWD SUMMARY INTERVAL TO TOOLS INTERVAL JETS IN OUT 6xl 0 FOOTAGE HOURS HIGH LOW AVERAGE 403.9 @ 2995 2.7 @ 4168 134.1 160 @ 3866 1 @ 4369 84.0 13 @ 4383 0 @ 4132 3.5 0 @ 4516 0 @ 4516 0.0 1820 @ 4069 825 @ 3013 1512.5 DEPTH: PV 5 YP 14 FL 8.8 Gels SD TR OIL 0 MBL 0 pH GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 26 @ 3130 0 @ 4477 4.1 CUTTING GAS 0 @ 4516 0 @ 4516 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 6964 @ 3175 -1 @ 4403 960.9 ETHANE(C-2) 0 @ 4516 -1 @ 4403 -0.1 PROPANE(C-3) 0 @ 4516 -1 @ 4403 -0.1 BUTANE(C-4) 0 @ 4516 -2 @ 4403 -0.2 PENTANE(C-5) 0 @ 4516 -2 @ 4403 -0.2 HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS LITHOLOGY PRESENT LITHOLOGY DALLY AcTIvITY SUMMARY DRILLED TO 4516, WIPER TRIP TO CASING SEAT. WILL BEGIN LOGGING @ 5000' CONDITION REASON T/B/C PULLED CURRENT AVG 86.6 fi/hr 136.4 amps 3.8 Klbs 0 RPM 1671 psi 9/11/12 CL- 28000 8.2 Ca+ 180 CCI TRIP GAS= N/A WIPER GAS= N/A SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= N/A CURRENT 0 CURRENT BACKGROUND/AVG N/A GAS DESCRIPTION Epoch Personel On Board= 4 Daily Cost 1,575.00 Report by: JERRY STAFFORD 0 file:/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010331.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 01, 2001 TIME 23:15:00 CASING INFORMATION 13.375" @113' 7" DEPTH S U RVEY DATA 5151 DAILY WELLSITE REPORT DEPTH 5215 YESTERDAY 4516 24 Hour Footage 699 INCLINATION 10.2 AZIMUTH 83.9 £:1 EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 4861.53 BIT INFORMATION NO. SIZE TYPE 3 6.125 PDC 4 6.125 STC-XR 15TDG PS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE INTERVAL S/N JETS IN OUT 5215 LY7012 2x12.14 5215 HIGH LOW 340.5 @ 5056 9.3 @ 940 @ 4868 -1784 @ 21 @ 5129 0 @ 40 @ 5215 40 2067 @ 5139 1345 @ DRILLING MUD REPORT MW 9.0 VIS FC 1/ SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C-5) HYDROCARBON SHOWS INTERVAL PV SD DEPTH: 4516 6 YP 21 FL TR OIL 0 MBL 24 0 HIGH 5246 @ 47 @ o @ o @ o @ LOW AVERAGE 5154 0 @ 4932 3.7 5215 0 @ 5215 0.0 CHROMATOGRAPHY(ppm) 5154 50 @ 4557 772.3 4543 1 @ 4874 4.9 5215 0 @ 5215 0.0 5215 0 @ 5215 0.0 5215 0 @ 5215 0.0 None LITHOLOGY/REMARKS FOOTAGE 2824.7 5O23 5112 5064 5215 4517 HOURS 29 AVERAGE 123.4 -387.9 3.7 40 1779.1 LITHOLOGY SAND/TUFFACIOUS CLAYSTONE PRESENT LITHOLOGY SAME DAILY ACTIVITY SUMMARY 4516 CBU. PUMP PILL, SHORT TRIP TO SHOE. SERVICE RIG AND TOP DRIVE. CONDITION REASON T/B/C PULLED CURRENT AVG 23.0 ft/hr 2.4 amps 8.9 Klbs 40 RPM 1841 psi 7.6 Gels 11/13/14 CL- 30500 0 pH 9.2 Ca+ 100 GAS CCI TRIP GAS= 16u WIPER GAS= 0 SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= NIA CURRENT 4u CURRENT BACKGROUND/AVG 4u DESCRIPTION Epoch Personel On Board= 4 Daily Cost 1,575.00 Report by: JERRY STAFFORD 0 file :/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010401 .htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 02, 2001 TIME 23:20:27 DAILY WELLSITE REPORT DEPTH 6400 YESTERDAY 5215 24 Hour Footage 1185 CASING INFORMATION 13.375"@113' TVD 7"@2376' MD DEPTH SURVEY DATA 5970 INCLINATION 0.56 AZIMUTH 192.3 BIT INFORMATION NO. SIZE TYPE 4 6.125" STC-XR15TDGPS DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.0 VIS 46 FC 1INA SOL 5 MVVD SUMMARY INTERVAL TO TOOLS PV SD GAS SUMMARY(units) HIGH DITCH GAS 206 CUTTING GAS 0 METHANE(C-I) 62534 ETHANE(C-2) 62 PROPANE(C-3) 54 BUTANE(C-4) 74 PENTANE(C-5) 45 HYDROCARBON SHOWS INTERVAL INTERVAL S/N JETS IN OUT LY7012 2x12.14 5215 HIGH LOW 332.2 @ 5729 6.9 358 @ 6270 0 @ 25 @ 5312 0 40 @ 6400 40 2413 @ 6395 1665 DEPTH: 5260'/4969' 7 YP 24 FL TR OIL 0 MBL LOW AVERAGE 6291 0 @ 6384 17,3 6400 0 @ 6400 0.0 CHROMATOGRAPHY(ppm) 5437 73 @ 6369 4157.6 5457 1 @ 6308 2.2 6395 1 @ 6277 0.7 6395 1 @ 6305 1.0 6299 1 @ 6338 0.5 NONE LITHOLOGY/REMARKS LITHOLOGY SAND, TUFFACEOUS CLAYSTON'E, COAL PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE AT SAMPLE DEPTH 6400' DALLY ACTIVITY SUMMARY 6215 WIPER TRIP, DRILL AHEAD FOOTAGE EPOCH PRESENT OPERATION= DRILLING VERTICAL DEPTH 5676.83 CONDITION REASON HOURS T/B/C PULLED AVERAGE CURRENT AVG 5411 93.4 64.5 fi/hr 5636 178.7 193.5 amps 5791 9.6 16.0 Klbs 6400 40 40 RPM 5618 2099.2 2368 psi 7.5 Gels 0 pH 10/14/16 CL- 29000 9.5 Ca+ 160 CCI TRIP GAS= 0 WIPER GAS= 22u SURVEY= N/A CONNECTION GAS HIGH= N/A AVG= N/A CURRENT 21u CURRENT BACKGROUND/AVG 21u GAS DESCRIPTION Epoch Personel On BOard= 4 Daily Cost $2,225.00 Report by: JERRY STAFFORD 0 file:/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010402.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY DALLY WELLSITE REPORT BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 03, 2001 DEPTH 6906 TIME 23:00:00 YESTERDAY 6464 24 Hour Footage 442 CASING INFORMATION 13.375"@113' (113' TVD) 7"@2376' (2329 TVD) DEPTH INCLINATION SURVEY DATA 6852.00' 0.74 BIT INFORMATION NO. SIZE TYPE S/N JETS 4 6.125" STC-XR15TDGPS LY7012 2x12.14 45 PV 8 SD HIGH 41 @ o @ DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.25 VIS FC 2/NA SOL MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS INTERVAL IN' 5215 HIGH LOW 122.6 @ 6585 11.1 @ 340 @ 6606 2 @ 28 @ 6746 3 @ 40 @ 6906 40 2574 @ 6856 2031 @ DEPTH: 6440 8 YP 29 FL TR OIL 0 MBL LOW AVERAGE 6708 1 @ 6743 7.3 6906 0 @ 6906 0.0 CHROMATOGRAPHY(ppm) 6743 1648.3 6721 0.6 6697 0.3 6597 2.3 6597 2.6 i 6708 290 6505 1 6701 3 6487 1 6576 1 NONE METHANE(C-I) 9484 ETHAN E(C-2) 15 PROPANE(C-3) 29 BUTANE(C-4) 57 PENTANE(C-5) 68 HYDROCARBON SHOWS INTERVAL LITHOLOGY CONGLOMERATE PRESENT LITHOLOGY CONGLOMERATE LITHOLOGY/REMARKS EPOCH DALLY ACTIVITY SUMMARY TRIP OUT OF HOLE, TEST BOPS, TRIP IN HOLE PRESENT OPERATION= BOP TESTING/TRIP IN HOLE AZIMUTH VERTICAL DEPTH 291.50 6558.76' OUT FOOTAGE HOURS 6906 1689.5' 28.6 AVERAGE 6588 46.5 6746 231.0 6741 10.6 6906 40 6716 2359.7 CONDITION REASON T/B/C PULLED CURRENT AVG 24.1 ft/h r 327.7 amps 12.3 Klbs 40 RPM 2422 psi 7.1 Gels 11/14/15 CL- 29000 0 pH 5.5 Ca+ 140 CCI TRIP GAS- NA WIPER GAS= NA SURVEY= NA CONNECTION GAS HIGH= NA AVG= NA CURRENT NA CURRENT BACKGROUND/AVG NA GAS DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD file:/A\DML2000\WELL%20REPORTS\Marathon\B C 10\20010403.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 04, 2001 TIME 23:24:15 DAILY WELLSITE REPORT DEPTH 7450 YESTERDAY 6906 24 Hour Footage 544 CASING INFORMATION 13.375"@113' (113' TVD) 7"@2376' (2329 TVD) DEPTH INCLINATION SURVEY DATA 6852.00' 0.74 EPOCH PRESENT OPERATION= DRILLING AZIMUTH VERTICAL DEPTH 291.50 6558.76' BIT INFORMATION NO. SIZE 5 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.3 FC 1/NA TYPE S/N JETS STC-XR15TDGPS LX5916 2x12.14 ViS 45 PV SOL 7 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU']q'ING GAS METHANE(C-I) ETHANE(C-2) PROPANE(C-3) BUTANE(C-4) PENTANE(C~5) HYDROCARBON SHOWS INTERVAL 7400-7430 HIGH 202 @ o @ 53530 @ 28 @ 24 @ o @ 17 @ SHOW FROM 7400' - 7430' INTERVAL CONDITION REASON IN OUT FOOTAGE HOURS T/B/C PULLED 6906 HIGH LOW AVERAGE CURRENT AVG 278.0 @ 7355 9.8 @ 6976 48.0 53.3 fi/hr 386 @ 7353 1 @ 7253 245.3 334.3 amps 31 @ 7254 2 @ 7236 13.9 13.8 Klbs 40 @ 7450 40 @ 7450 40 40 RPM 2773 @ 7375 2270 @ 6908 2578.3 2584 psi DEPTH: 6906 MD 9 YP 27 FL 7.0 Gels 10/15/18 CL- 28000 TR OIL 0 MBL 0 pH 9.5 Ca+ 60 CCI 0 LITHOLOGY PRESENT LITHOLOGY SAME LOW AVERAGE 7409 I @ 7022 12.9 TRIP GAS= 37u 7450 0 @ 7450 0.0 WIPER GAS= NA CHROMATOGRAPHY(ppm) SURVEY= NA 7409 247 @ 7022 2617.6 CONNECTION GAS HIGH= 0 7409 1 @ 7401 0.9 AVG= NA 7409 I @ 7448 0.8 CURRENT 15u 7450 0 @ 7450 0.0 CURRENT BACKGROUND/AVG 15u 6910 5 @ 6919 0.2 LITHOLOGY/REMARKS GAS DESCRIPTION SAND 203u SAND; MED TO DK GRAY; FINE TO MED GRAINED; SUBANGULAR TO SUBROUNDED; MAX UNCONSOLIDATED; CALCITE MATRIX GRADING TO CLAY MATRIX; POOR SORTING; NO CUT; NO FLUOR. SAND AND TUFFACEOUS CLAYS DALLY ACTIVITY SUMMARY DRILLING AHEAD Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD o file :/A\DML2000\WELL ~20REPORTS\Marathon\BC 10\20010404.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-IO REPORT FOR ROWLAND LAWSON DATE Apr 05, 2001 TIME 11:37:42 CASING INFORMATION 13.375" @ 113' 7" @ 2376' DEPTH SURVEY DATA 7732' DAILY WELLSITE REPORT DEPTH 7788 YESTERDAY 7450 24 Hour Footage 338 INCLINATION 0.86 BIT INFORMATION NO. SIZE 5 6.125" 6 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.4 VIS FC 2INA SOL MWD SUMMARY INTERVAL TO TOOLS TYPE SIN STC-XR15TDGPS LX5916 STC-XR20TDGPS LY0226 47 PV 7.5 SD GAS SUMMARY(units) HIGH DITCH GAS 186 CUTi'ING GAS 0 METHANE(C-I) 34820 ETHANE(C-2) 29 PROPANE(C-3) 27 BUTANE(C-4) 0 PENTANE(C-5) 0 .YDROCARBO. S.OWS INTERVAL INTERVAL JETS IN OUT FOOTAGE 2x12.14 6906 7788 880 2x14x14 7788 HIGH LOW 241.8 @ 7586 2.0 @ 7766 426 @ 7646 0 @ 7575 30 @ 7588 3 @ 7539 40 @ 7788 40 @ 7788 2780 @ 7512 2230 @ 7573 'DEPTH: 7480' 10 YP 25 FL TR OIL 0 MBL 0 LOW AVERAGE 7597 1 @ 7484 33.0 7788 0 @ 7788 0.0 CHROMATOGRAPHY(ppm) 7597 313 @ 7484 6748.0 7582 1 @ 7739 3.8 7649 1 @ 7645 1.6 7788 0 @ 7788 0.0 7788 0 @ 7788 0.0 NONE LITHOLOGY/REMARKS LITHOLOGY SAND AND TUFFACEOUS CLAYSTONES AND SILTSTONES PRESENT LITHOLOGY SAME DAILY ACTIVITM SUMMARY TRIP OUT FOR NEW BIT. TRIP IN HOLE EPOCH PRESENT OPERATION= TRIP IN HOLE AZIMUTH 240.5 HOURS 24.3 VERTICAL DEPTH 7438.55' CONDITION REASON T/B/C PULLED 6-6-WT-A-E-Z-LT-HR AVERAGE CURRENT AVG 45.8 22.1 fi/hr 260.3 291.4 amps 13.7 12.1 Klbs 40 40 RPM 2628.7 2641 psi Gels 10/16/16 CL- 28000 pH 9 Ca+ 80 i CCI 0 TRIP GAS= NA WIPER GAS= NA SURVEY= NA CONNECTION GAS HIGH= NA AVG= NA CURRENT TRIP IN CURRENT BACKGROUND/AVG NA GAS DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD 0 file:/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010405.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 06, 2001 TIME 23:31:11 CASING INFORMATION SURVEY DATA DALLY WELLSITE REPORT [-1 EPOCH DEPTH 8400 YESTERDAY 7789 24 Hour Footage 611 DEPTH 8172' INCLINATION 0.62 PRESENT OPERATION= DRILLING AHEAD AZIMUTH VERTICAL DEPTH 167.60 7878.49' BIT INFORMATION NO. SIZE 6 6.125" TYPE STC-XR20TDGPS S/N LY0226 INTERVAL JETS IN OUT 2x14x14 7788 FOOTAGE CONDITION REASON HOURS T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE ,, DRILLING MUD REPORT MW 9.5 VIS FC 2/NA SOL MVVD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CUTTING GAS 47 8.5 PV SD 238.4 359 34 40 2791 HIGH LOW @ 8056 7.1 @ 7969 @ 8364 I @ 8074 @ 8079 4 @ 7851 @ 8400 40 @ 8400 @ 7852 1435 @ 8381 DEPTH; 7788' 10 YP 25 FL 6.3 TR OIL 0 MBL 0 HIGH 540 @ o @ LOW AVERAGE 8149 4 @ 7808 51.5 8400 0 @ 8400 0.0 CHROMATOGRAPHY(ppm) METHANE(C-I) 152850 @ 7900 528 @ 7913 ETHANE(C-2) 87 @ 7900 1 @ 8349 PROPANE(C-3) 44 @ 8148 1 @ 8393 BUTANE(C-4) 0 @ 8400 0 @ 8400 PENTANE(C-5) 0 @ 8400 0 @ 8400 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY SAND AND TUFFACEOUS CLAYSTONES PRESENT LITHOLOGY SAME DAILY ACTIVITY SUMMARY DRILLING LITHOLOGY/REMARKS 11120.7 5.3 2.2 0.0 0.0 AVERAGE CURRENT AVG 44.5 25.9 ft/hr 285.3 330.6 amps 13.7 14.8 Klbs 4O 4O RPM 2588.0 2281 psi ~ ,, Gels 11/18/20 CL- 28000 pH 8.7 Ca+ 60 GAS CCI 0 TRIP GAS= NA WIPER GAS= NA SURVEY= NA CONNECTION GAS HIGH= NA AVG= NA CURRENT 96u CURRENT BACKGROUND/AVG 96u DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD file :/A\D ML2000\ WELL %20REPO RTS\Marathon\B C 10\20010406.btm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY BC-10 REPORT FOR ROWLAND LAWSON DATE Apr 07, 2001 TIME 23:30:00 DAILY WELLSITE REPORT DEPTH 8587 YESTERDAY 8442 24 Hour Footage 145 CASING INFORMATION 13.375"@113' (113' TVD) 7"@2379' (2329' TVD) DEPTH INCLINATION SURVEY DATA 8360.00 0.84 TYPE S/N JETS STC-XR20TDGPS LY0226 2x14x14 STC-XR20HTDGPS LY0220 12x14x14 HIGH 129.5 @ 8528 39O @ 85O5 18 @ 8444 40 @ 8587 2822 @ 8475 DEPTH: 8418 9 YP TR OIL HIGH 589 o @ INTERVAL IN OUT 7788' 8587' 8587' LOW 11.4 @ 269 @ 13 @ 40 @ 2607 @ EPOCH PRESENT OPERATION= TRIPPING IN HOLE BIT INFORMATION NO. SIZE 6 6.125" 7 6.125" DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.35 FC 1 i MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) DITCH GAS CU'I-I'ING GAS VIS 43 PV SOL 7.5 SD AZIMUTH VERTICAL DEPTH 195.30 8066.48 FOOTAGE HOURS 796.5 24.4 CONDITION REASON T/B/C PULLED AVERAGE CURRENT AVG 8446 37.9 21.2 ft/hr 8479 325.2 323.5 amps 8544 15.4 15.1 Klbs 8587 40 40 RPM 8480 2772.7 2751 psi 21 FL 5.8 Gels 0 MBL 0 pH i i i LOW 8462 8 @ 8445 8587 0 @ 8587 CHROMATOGRAPHY(ppi) METHANE(C-I) 123440 @ 84621677 @ 8445 ETHANE(C-2) 86 @ 84621 @ 8586 PROP^NE(C-a) 54 @ 8462i @ 8563 BUTANE(C-4) 0 @ 85870 @ 8587 PENTANE(C-5) 0 @ 85870 @ 8587 "YD"OC~R~O'',, ,-, ~, ,,SHOWS ' NONE ' ' ~NTERV^L UTHO'~OGY'REMARKS 12/17/18 CL- 27000 9.5 Ca+ 40 ii AVERAGE 65.7 0.0 CCI 13281.6 7.4 3.5 0.0 0.0 i i [ i LITHOLOGY SAND AND TUFFACEOUS CLAYSTONE/SILTSTONE PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE AND SILTSTONE DAILY ACTIVITY SUMMARY DRILL TO 8587.9'; TRIP OUT OF HOLE; TRIP IN HOLE. TRIP GAS= NA WIPER GAS= NA SURVEY= NA CONNECTION GAS HIGH= 50U AVG= NA CURRENT NA CURRENT BACKGROUND/AVG NA GAS DESCRIPTION i , Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD 0 file:/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010407.htm 4/26/01 Daily Report Page 1 of 1 MARATHON OIL COMPANY DAILY WELLSITE REPORT BC-10 REPORT FOR ROWLAND LAWSON DATE 04/08/01 , DEPTH 8854 TIME 23:50:00 YESTERDAY 8442 24 Hour Footage 412 CASING INFORMATION 13 3/8" @113' 7"@ 2374' 3 1/2" @ TD DEPTH SURVEY DATA NA BIT INFORMATION NO. SIZE TYPE S/N 7 6.125" STC-XR20HTDG PS LY0220 EPOCH PRESENT OPERATION= WELL AT TD; TRIP OUT FOR E-LOGS INCLINATION NA AZIMUTH VERTICAL DEPTH NA NA INTERVAL JETS IN OUT 12x14x14 8587 8854 FOOTAGE HOURS 267 9.7 CONDITION REASON T/B/C PULLED DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE , DRILLING MUD REPORT MW 9.4 VIS FC 1 SOL HIGH NOT DRILLING LOW DEPTH: 8587 43 PV 9 YP 19 FL 6.1 Gels 8 SD TR OIL 0 MBL 0 pH MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH AVERAGE DITCH GAS 0 @ 2350 0 @ 2350 -1.$ CUTTING GAS 0 @ 2350 0 @ 2350 -1.$ CHROMATOGRAPHY(ppi) METHANE(C-I) 0 @ 2350 0 @ 2350 -1.$ ETHANE(C-2) 0 @ 2350 0 @ 2350 -1.$ PROPANE(C-3) 0 @ 2350 0 @ 2350 -1.$ BUTANE(C-4) 0 @ 2350 0 @ 2350 -1.$ PENTANE(C-5) 0 @ 2350 0 @ 2350 -1.$ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS LITHOLOGY TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY TOFFACEOUS CLAYSTONE LOW DALLY ACTIVITY SUMMARY WELL WENT TO TD; WIPER TRIP; TRIP OUT OF HOLE FOR E-LOGS AVERAGE CURRENTAVG 11/16/18 9.0 GAS CL- 26000 Ca+ 40 ft/hr amps Klbs RPM psi CCI TRIP GAS= 250u WIPER GAS= 120u SURVEY= NA CONNECTION GAS HIGH= O AVG= NA CURRENT Ou CURRENT BACKGROUND/AVG NA DESCRIPTION Epoch Personel On Board= 4 Daily Cost $2225.00 Report by: JERRY STAFFORD o file:/A\DML2000\WELL ¼20REPORTS\Marathon\BC 10\20010409.htm 4/26/01 ALASKA OIL AND GAS CONSERVA~I~I ON COHYlISSION Peter Berga, Drilling Superintendent Marathon Oil Company P. O. Box 196168 Anchorage, AK 99519-6168 / t /i TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Beaver Creek Unit BC-10 Marathon Oil Company Permit No: 200-192 Sur. Loc. 1074'FNL, 1532'FWL, Sec. 34, T07N, R10W, SM Btmhole Loc. 914'FNL, 2987' FWL, Sec. 34, T07N, R10W, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all .other required permitting determinations are made. Since your calculated Maximum Anticipated Surface Pressure (MASP) is in excess of 3000 psi, the BOP stack employed must include 3 rams and an annular unless an application for exception is requested and approved. , The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the diverter function test and BOPE test(s) must be given so that a representative of the Commission may witness the .test(s) if desired. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~Daniel T. Seramount, Jr. Commissioner , BY ORDER OF THE COMMISSION DATED this 7-~ ~ ~ day of February, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o encl. STATE O F ALAS KA ,' g:\cmn\drlg~sterling~su44~10'¢,OGCC~PTD~s ALi" (A OIL AND GAS CONSERVATION CO~ ,ISSION ' PERMIT TO DRILL - 1~'~ 210 AAC 25.OO5 'la. Type of Work Drillr~'1 Re-DrillO lb. Type of well. ExploratoryO Stratigraphic TestE] Development OilE] Re-EntryD DeepenD serviceFI Development Gasr~1 Single Zoner~1 Multiple ZoneO 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY 179' KB feet Beaver Creek/Beluga 3. Address 6. Property Designation P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.o25) 1074'FNL, 1532'FWL, Sec. 34, T7N, R10W, S.M. Beaver Creek Unit Blanket Surety At top of Productive Interval 8. Well Number Number 914'FNL, 2987'FWL, Sec. 34, T7N, R10W, S.M. DC-10 5194234 At Total Depth 9. Approximate Spud Date Amount 914'FNL, 2987'FWL, Sec. 34, TTN, R10W, S.M. 2/01/01 $200,000 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD andTVD) :Property Line(unit boundary) 4700 feet 2000 feet 2560 8806' MD/8500' TVD feet !16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25,085 (e) (2)) Kickoff Depth 1250 feet Maximum Hole Angle 28.4 o Maximum Surface 3088 psig at Total Depth (TVD) 8500' 118. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage d,ata) Driven 13 3/8" 68 K-55 PE +/- 100' 0' 0' 100' 100' 8-1/2" 7" 23 L-80 BTC 2385' O' 0' 2385' 2339' 250 sx , 6 1/8" 3 1/2" 9.3 L-80 BTC 8806' 0' 0' 8806' 8500' 950 sx PC:FiVFi,-,] / NOV ?. t~ ?{)Or} The BO-10 well will be directionally drilled to an estimated total depth of 8806' MD, 8500' TVD from the existing Beaver 'Creek Unit pad 3.The production interval will be cased with 3 1/2" casing cemented in place and run to surface. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Pad drawing, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing FeelS] Property PlatF~] BOP Sketch[~ Diverter SketchF~1 Drilling Program[~] Drilling Fluid Pro§raml~ T,me vs Depth PlotD Refraction Analy$,sD Seabed Report['-'] 20 AAC 25.050 RequbementsD 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Phone: 907-564-6319 Date 11/15/2000 Commission Use Only Permit Number IAPI Number IApproval Date ISee Cover Letter .~_.~..~... /,,¢~..I 50--/'~ ~"'~::)//('~2.."'(~)I d:2~ "" ~ ~ "- (..~// IF°r °ther Requirements Conditions of Approval Samples Required r"-lYes r~No Mud Log Required DYes [~lNo Hydrogen Sulfide Measures F1Yes F~'lNo Directional Survey Required r~Yes r--INo Required Working Pressure for DOPE [~2M ['"~3M Other: Commissioner the Commission Date &/, . Approved by D T~ylor' ~-' ._. Form 10-401 Rev. 12-1-85 Submit in Triplicate BC-10 (Proposed PTD 200-192) -Reply Subject: BC-10 (Proposed PTD 200-192) -Reply Date: Mon, 29 Jan 2001 16:55:56 -0600 From: "Craig E Young" <ceyoung@marathonoil.com> To: tom_maunder@admin.state.ak.us Tom, There is an error in the program. We will test the stack to 250/5000 psi. The stack will be the one indicated on the drilling program. It should be returned to service by the time this well is drilled. The top of cement will be at 4600' M D, over 500' above the top of hydrocarbons. If you need any additional information, please let me know. In addition, Marathon will be requesting a waiver to allow us to use the 16" diverter. I will request this after some additional reasearch is complete. Craig >>> Tom Maunder <torn_maunder~,admin. state, ak. us> 01/27/01 10:56am >>> Craig, Just a few questions with regard to BC-10. I see this well is a slim design. Same questions on the stack arrangement. Since you estimate a MASP greater than 3000 psi, your BOP test pressure needs to be greater than 3000 psi. I would propose 3500 psi. Will you be attempting to reciprocate either casing string?? The planned cement top for the 3-1/2" job is 2000' which puts it above the 7" shoe. Is that planned?? Thanks again. Tom 1 of 1 2/23/01 12:01 PM DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: BC-10 FIELD: Beaver Creek Unit PAD: BC 3 AFE No.: 8102801 SLOT: NA TYPE: Development. REVISION NO.: 0 DATE: 11/13/00 SURFACE LOCATION: TARGETS:' Beluga 1074' FNL, 1532' FWL, Sec. 34, T7N, R10W, S.M. 914' FNL, 2987' FWL, Sec. 34, T7N, R10W, S.M. BOTTOMHOLE LOCATION: 914' FNL, 2987' FWL, Sec. 34, T7N, R10W, S.M. KB ELEVATION: 179 ft. mean S.L. (est.) GL ELEVATION: 158 ft. mean S.L. I. IMPORTANT GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 5220 4916 Beluga 6301 5995 I1. ESTIMATED FORMATION TOPS AND CONTENT: POTENTIAL FORMATION DEPTH(M~ ~ DEPTH(TVD) CONTENT Sterling B-0 5220 ~ ~J~ 4916 gas/water Sterling B-2 5312 , 5008 gas/water Sterling B-4 5601 5295 gas/water Beluga B-15 7321 7015 gas/water Beluga B-16 7356 7050 gas/water Beluga B-18 7598 7292 gas/water Beluga B-20 7779 7473 gas/water Beluga B-21 7824 7518 gas/water Beluga B-23 7937 7631 gas/water Beluga B-24 8109 7803 gas/water Beluga B-26 8287 7981 gas/water Beluga B-28 8436 8130 gas/water Beluga B-30 8568 8262 gas/water TD 8806 ~'/'DO__..."T~j 8500 page 1 n :drlg\bc\wells\BC 10prog.xls III. WELL CONTROL EQUIPMENT DIVERTER SYSTEMS The diverter system will consist of a 20 3/4" X 3000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line valve will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top, a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets, and a 13-5/8" x 5000 psi single gate ram type preventer with pipe rams. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system, Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING HEAD: 13 3/8" SO x 13 5/8" 5M with 13 5/8" x 21 1/4" 2M DSA. CASING HEAD: .~3--518" 5M x 7" SOW CASING HEAD: None TUBING HEAD: 7" 5M x I'3-g/~" 5M". RECEIVED Alaska Oil & Gas Cons. Commission Anchorage CHRISTMAS TREE: 4 1/16" - 5000 psi christmas tree including two master valves, one flow tee, one wing valve and one swab valve. page 2 n:drlg\bc\wells\BCl0prog.xls IV. CASING PROGRAM: CASING DESCRIPTION SET SET HOLE TYPE SIZE WT. GRADE THREAD FROM TO SIZE (md/tvd) (md/tvd) CON DUCTOR: 13 3/8" 68 ppf K-55 PE Surf +/-100 Driven SURFACE: 7" 23 ppf L-80 BTC Surf 2385'/2339' 8 1/2" PRODUCTION: 3 1/2" 9.3 ppf L-80 BTC Mod Surf 8806'/8500' 6 1/8" CASING DESIGN SIZE SETTING FRAC GRD FORM PRSS DESIGN FACTORS WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP TENS COLL BURST 7" 23 ppf L-80 2339' 12.5 1034 826 11.49 2.67 4.74 3 1/2" 9.3 ppf L-80 8500' 16.0 4048 3098 3.10 4.05 1.93 All tubulars are new. page 3 n:drlg\bc\wells\BC10prog.xls V. CEMENTING PROGRAM SURFACE: 7" 2385'md/2339' tvd LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: SURFACE WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): % in open hole. ESTIMATED VOLUME: sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: SURFACE ft. WEIGHT: 12 ppg. YIELD: 2.38 cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): 75 % in open hole. ESTIMATED VOLUME: 250 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED ! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joint. Check float. Fill pipe until cimulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U cementing head. Test lines. 6. Circulate until no gain in circulating efficiency is made. 7. Pump spacer as follows: To be designed. 8. Drop top bottom plug. 9. Mix and pump lead slurry. 10. Mix and pump tail slurry. 11. Drop top plug and displace cement. 12. Check floats. 13. WOC. 14. N/D diverter. Weld on tubing head and N/U blowout preventers. 15. Test BOPE. Run wear bushing. RECEIVED NOV ~, 0 ?f~8~ Alaska 0il & Gas Cons. Commission Ar~"horage page 4 n:drlg\bc\wells\BClOprog.xls V. CEMENTING PROGRAM (continued) Intermediate None LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: ft. WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): % over caliper log. ESTIMATED VOLUME: 0 sks. TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: ft. WEIGHT: ppg. YIELD: cu. ft./sk WATER REQ.: gal/sk PUMPING TIME: hrs:min EXCESS (%): % over caliper log. ESTIMATED VOLUME sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1.Remove thread protectors and visually inspect connections. 2.Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3.M/U float collar. (Baker-lok all connections to top of float collar) 4.Fill pipe until circulating. 5.Run remaining casing. M/U cementing head and test all lines. 6.Circulate and reciprocate until no gains in circulating efficiency is made. 7.Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed. 9. Drop bottom plug. 10. Mix and pump tail slurry. Drop top plug., 11. Displace cement with water or brine. 12. Bump plug w/500 psi over final circulating pressure. Check floats. 13. WOC 14. P/U BOP stack. Set slips. N/U casing spool and test. N/U BOP stack. 15. Test BOPE. RECEIVED NOV AJaska Oil & Gas Cons. Commission Anchorage page 5 n:drlg\bc\wells\BC10prog.xls V. CEMENTING PROGRAM (continued) PRODUCTION 3 1/2" @ 8806'md/8500' tvd LEAD SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME: 12.8 ppg. 2.08 cu. ft./sk gal/sk hrs:min 50 %(use 25% over caliper log.) TAIL SLURRY: Class "G" + required additives. TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 53O0 ft. 15.8 ppg. 1.15 cu. ft./sk gal/sk hrs:min 50 %(use 25% over caliper log,) 630 sks. RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe and 2 shoe joints. Check float. Fill pipe until circulating. 3. M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating. 5. Run remaining casing and centralizers. M/U cementing head and test all lines. 6. Circulate until no gains in circulating efficiency is made. 7. Drop bottom plug and begin pumping spacer. 8. Pump spacer as follows: To be designed 9. Mix and pump tail slurry. Drop top plug. 10. Displace cement. 11. Bump plug with 500 psi. over displacement pressure Check floats. 12. WOC. page 6 n:drlg\bc\wells\BC10prog.xls VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO TVD ppg sec/qt LOSS TYPE 0' 2339' 8.6-9.0 80-250 15-30 Freshwater gel 2339' 8500' 9.0-10 50-70 <5 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two flowline cleaners and the MI centrifuge van. Included will be equipment to dewater the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM CONDUCTOR: No logging is planned for this interval. SURFACE: No logging is planned for this interval. PRODUCTION: To be determined COMPLETION: Gammaray/CCL. MUD LOGGING The well will be gas logged to 5175'md/4872'tvd and mud logged from there to TD at 8800' md. CORING PROGRAM No coring planned. TESTING PROGRAM No open hole tests are planned for this well. page 7 n:drlg\bc\wells\BClOprog.xls VIII. OTHER INFORMATION DESC DIRECTIONAL PLAN MD TVD NORTH INCL AZIM COORD EAST COORD VERT SECTION RKB 0 0 0 0 0 0 0 KICKOFF HOLD build 1250 1250 0.0 84.9 0 @ 2.5deg/100ft 2385 2339 28.4 84.9 24 0 0 274 275 DROP 3915 3685 28.4 84.9 89 998 1002 END of DROP 5806 5500 0.0 84.9 130 1455 1461 Total Depth 8806 8500 0.0 84.9 13O 1455 1461 POTENTIAL INTERFERENCE: WELL BC-3 DISTANCE (ft.) 72 DEPTH (MD) 1425 page 8 n:drlg\bc\wells\BC10prog.xls IX. DRILLING PROGRAM CONDUCTOR: Drive 13 3/8" conductor to +-100 ft. RKB. Install starting head on drive pipe. Move in and rig up rotary drilling rig. Nipple up 20" diverter, 16" diverter valve, and 16" diverter line. Function test diverter and diverter valve. SURFACE: Drill a 8 1/2" hole to 2385' md/2339' tvd per the directional plan. Run and cement 7" casing. WOC. Cutoff 7" and 13 3/8". Weld on 13 3/8" SOW by 13 5/8" 5M wellhead and test. N/U 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250/~si. Set Wear bushing. Test surface casing to 1500 psi. INTERMEDIATE PRODUCTION' Drill flOat equipment and 20' of new formation w/6 1/8" bit. CBU. Test shoe to leak off. Estimated EMW 12.5 ppg. Drill a 6 1/8" directional hole from 2385'md/2339' tvd to 9806' md/8500' tvd' per the directional program. Log. Make wiper trip. Pull wear bushing. Run and cement 3 1/2" casing. Test casing to 3000 psi. COMPLETION: Complete well as per comletion program. page 9 n:drlg\bc\wells\BClOprog.xls X. POTENTIAL HAZARDS Well BC-10 To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller) is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/-4916'tvd/5220'md to total depth of the well. These sands should be normally pressured and no lost circulation or differential sticking hazards are anticipated. Minor well interference hazards exists from surface to 1500' md from well BC-3. page 10 n:drlg\bc\wells\BC10prog.xls Xl. NOTES MASP CALCULATIONS: Surface casing: 7" MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = (12.5 ppg + 1.0 ppg) x .052 x 2339' - (.115 x 2339') MASP = 1642 psi - 269 psi MASP = 1373 psi. Intermediate casing: None. MASP = Injection pressure at shoe + S.F. - Hydrostatic pressure of gas column. MASP = MASP = MASP = Production casing: 3 1/2". MASP = Formation pressure(producing zone) - Hydrostatic pressure of gas column. MASP = 9.4 ppg x .052 x 8262' - (.115 x 8262') MASP = 4038 psi - 950 psi MASP = 3088 psi. Cementing The 7" casing must be cemented to surface. Contact AOGCC in advance to see if they want to witness the cement job. BOP/Diverter Tests. Contact AOGCC a minimum of 24 hrs prior to tests to see if they wish to witness. Tubulars All tubulars are new. page 11 n:drlg\bc\wells\BCl Oprog.xls Marathon Oil Well BC-IO BOP Stack IFIow Nipple 13 5/8" 5M Annular Preventer I FIow Line 13 5/8" 5M Double Ram Preventer I Pipe Ram I IBlindRamI 3 1/8" 5M Manually I Operated Valves ~, ~ I,, I 13 5/8" 5M Single Ram Preventer IPipe Ram I 3 1/8" 5M Hydraulically Operated Valve 13 1/8" 5M Manually '-~ IOperatedValve I l/I Marathon Oil Well BC-IO Choke Manifold Gas Buster JTo Blooey Line J tj JBleed off Line to J Shakers J2 9/16" 1 OM Swaco Hydraulically Operated J From BOP Stack J Choke t J3 1/8" 5M Manually Adjustable Ohoke Marathon Oil Well BC-IO Diverter 20 3/4" 3M Diverter Flow line IDiverter Spool 16" Automatic Hydraulic Valve 16" Diverter Line GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT fCreOted by Sutherland FOI': P. BergsI Dote plotted: 13-Nov-2000 I Plot Reference ia BC t110 Verakm MARATHON Oil Company Sfruofure: Pad ~3 Field : Beaver Creek Unit Well: BC-IO Location: Kenai Peninsula, Alaska I v 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 7OOO 7500 8OOO 8500 East (feet) -> 200 0 200 400 600 800 1000 I I I I I I I I I I I I I o.oo KOP 2.50 7.50 12.50 DLS: 2.50 dog per 100 fi: 17.50 22.50 27.50 28.37 End of Build 7 Cos[ng TANGENT ANGLE 28.37 DEG 28.57 27.09 24.09 21.09 18.09 15.09 12.09 Sterling B Coal 9.09 Sterling B1A Sterling B2 6.09 Sterling BSA 5.09 0.09 0.00 Beluga 82 Beluga B4 Beluga Top Conglomerate Beluga B15 Beluga Base Conglomerate Beluga B18 Beluga B20 Beluga B25 Beluga B24 Beluga B26 Beluga B28 Beluga B30 5 1/2 Casing J End of Hold DIS: 1.~0 d~ I~' 100 et Sterling BO Sterling B1B Sterling 83 . Sterling 84 Tgi 1 - BC ~10 - 13 Nov O0 End of Curve Beluga B16 Beluga B21 L T.D. i i i i i i ! i 0 500 1000 1500 Vertical Section (feet) -> 200 1400 I I I 84.89 1600 600 400 200 0 200 400 TRUE RECEIVED 84.89 Deg Azimuth 1461' Lo TargetN0V 2 o ?O~O ***Plane of Proposal*** A/asks Oil & Gas Cons. Commission Anchorage WELL PROFILE DATA ..... Pofnt ..... MD Inc Orr WE) North East V. Sect Oeg/l O0 Tie on 0,00 0,00 B4.89 0.00 0.00 0.00 0,00 0.00 KOP End of Build End of Hold Target Tgt t - BC #10 T.D. ac End of Hold 1250.00 0.00 84,89 1250.000.00 0.00 0.00 0,00 23B4..88 28.57 64-.892338.89 24..49 274.10 275.20 2.50 3914.70 28.57 84.89 3685.19 89.18 998.16 1002.14. 0.00 5805.83 O.O0 8~.89 5500.00 130.00 14~.00 1460,80 1.50 8808.~ 0.00 ~.89 8500.00 130.00 145~.00 14~0.80 0,00 Azimuth 84.89 wlth rsferenoe 0.00 N, O.O0 E fram slot #10 MARATHON Oil Company Pad #3 BC-IO slot #10 Beaver Creek Unit Kenai Peninsula, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : BC #10 Version#6 Our ref : prop4288 License : Date printed : 13-Nov-2000 Date created : 13-Nov-2000 Last revised : 13-Nov-2000 Field is centred on n60 38 50.050,w150 59 49.92 Structure is centred on n60 38 50.050,w150 59 49.92 Slot location is n60 39 31.418,w151 1 5.147 Slot Grid coordinates are N 2434113.250, E 317350.340 Slot local coordinates are 4201.40 N 3749.36 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North MARATHON Oil Company Pad #3, BC- 10 Beaver Creek Unit,Kenai Peninsul a, A1 aska Measured Inclin, Azimuth True Vert Depth Degrees Degrees Depth 0,00 0,00 84,89 0,00 500.00 0.00 84.89 500.00 1000,00 0.00 84,89 1000.00 1250,00 0,00 84.89 1250,00 1350,00 2,50 84,89 1349,97 1450,00 5,00 84,89 1449,75 1550,00 7,50 84,89 1549,14 1650,00 10,00 84,89 1647,97 1750.00 12.50 84.89 1746.04 1850,00 15,00 84,89 1843,17 1950,00 17,50 84,89 1939,17 2050.00 20,00 84,89 2033,85 2150,00 22,50 84,89 2127,05 2250,00 25,00 84,89 2218,57 2350,00 27,50 84,89 2308,25 2384,68 28,37 84189 2338,89 2500,00 28,37 84,89 2440,36 3000,00 28,37 84,89 2880,32 3500,00 28,37 84,89 3320,28 3914,70 28,37 84,89 3685,19 4000.00 27,09 84,89 3760,69 4100,00 25,59 84,89 3850,31 4200,00 24,09 84,89 3941,06 4300,00 22,59 84,89 4032,87 4400,00 21,09 84.89 4125,70 4500,00 19,59 84,89 4219,46 4600,00 18,09 84,89 4314,10 4700,00 16,59 84.89 4409,55 4800,00 15,09 84,89 4505,75 4900,00 13,59 84,89 4602,64 5000,00 12,09 84,89 4700,14 5100,00 10,59 84,89 4798,18 5174,96 9,46 84,89 4872,00 5200,00 9,09 84,89 4896,71 5219,53 8.79 84,89 4916,00 5294,30 7,67 84,89 4990,00 5300,00 7,59 84,89 4995,65 5349,75 6,84 84,89 5045,00 5400,00 6,09 84,89 5094,93 5413,14 5,89 84,89 5108,00 5466.38 5.09 84,89 5161,00 5500,00 4,59 84.89 5194,50 5539,61 3,99 84,89 5234.00 5600,00 3,09 84,89 5294,27 5600,73 3,08 84.89 5295,00 5700,00 1,59 84,89 5394,18 5800,00 0,09 84,89 5494,17 5805,83 0.00 84,89 5500,00 6000,00 0,00 84,89 5694,17 6300,83 0,00 84,89 5995,00 RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : BC #10 Version#6 Last revised : 13-Nov-2000 Dogleg Vert Deg/lOOft Sect 0,00 N 0.00 E 0.00 0,00 0,00 N 0,00 E 0,00 0,00 0,00 N 0,00 E 0,00 0,00 0,00 N 0,00 E 0,00 0,00 0,19 N 2,17 E 2.50 2.18 0,78 N 8,69 E 2,50 8,72 1,74 N 19,53 E 2,50 19,61 3.10 N 34.68 E 2.50 34.82 4,83 N 54,11E 2,50 54,33 6,95 N 77,78 E 2,50 78,09 9,44 N 105,65 E 2.50 106,07 12,30 N 137,67 E 2,50 138,21 15,53 N 173,76 E 2,50 174,46 19,11N 213,87 E 2,50 214,73 23.04 N 257.92 E 2,50 258,95 24,49 N 274,10 E 2,50 275,20 29,37 N 328,68 E 0,00 329,99 50,51N 565.29 E 0,00 567,55 71,65 N 801,91 E 0,00 805,10 89,18 N 998,16 E 0,00 1002,14 92.71 N 1037,69 E 1,50 1041,82 96,66 N 1081,88 E 1,50' 1086,19 100,40 N 1123,71E 1,50 1128,19 103,93 N 1163.17 E 1,50 1167,80 107,24 N 1200,22 E 1,50 1205,00 110,33 N. 1234,83 E 1,50 1239,75 113.20 N 1266,99 E 1.50 1272,04 115,85 N 1296,67 E 1,50 1301,84 118,28 N 1323,86 E 1,50 1329,13 120,49 N 1348,52 E 1,50 1353,89 122,46 N 1370,65 E 1,50 1376,11 124,21 N 1390,23 E 1,50 1395,77 125,37 N 1403,23 E 1,50 1408,82 Sterling B Coal 125,73 N 1407,25 E 1,50 1412,85 126,00 N 1410,27 E 1,50 1415,89 Sterling BO 126,96 N 1420,94 E 1,50 1426,60 Sterling BiA 127,02 N 1421,69 E 1,50 1427,35 127,58 N 1427,91E 1,50 1433,60 Sterling BiB 128,08 N 1433,55 E 1,50 1439,26 128,21N 1434,91E 1,50 1440,63 Sterling B2 128,66 N 1439,99 E 1,50 1445,72 Sterling B3 128,91N 1442,81E 1,50 1448,56 129,17 N 1445,76 E 1,50 1451,52 Sterling B3A 129,51 N 1449,48 E 1,50 1455,25 129,51N 1449,52 E 1.50 1455,29 Sterling B4 129,87 N 1453,54 E 1,50 1459,33 130,00 N 1455,00 E 1.50 1460,79 130,00 N 1455,00 E 1,50 1460,80 Tgt 1 - BC #10 - 13 Nov O0 130,00 N 1455,00 E 0,00 1460,80 130,00 N 1455,00 E 0,00 1460,80 Beluga B2 All data is in feet unless otherwise stated, Coordinates from slot #10 and TVD from Est, RKB (179,00 Ft above mean sea level), Bottom hole distance is 1460,80 on azimuth 84,89 degrees from wellhead, Total Dogleg for wellpath is 56,73 degrees, Vertical section is from wellhead on azimuth 84,89 degrees, Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3, BC- 10 Beaver Creek Unit,Kenai Peninsul a. A1 aska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : BC #10 VersionS6 Last revised : 13-Nov-2000 Dogleg Vert Deg/lOOft Sect 6408.83 0.00 84.89 6103.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B4 6500.00 0.00 84.89 6194.17 130.00 N 1455.00 E 0.00 1460.80 6608.83 0.00 84.89 6303.00 130.00 N 1455.0~ E 0.00 1460.80 Beluga Top Conglomerate 7000.00 0.00 84.89 6694.17 130.00 N 1455.00 E 0.00 1460.80 7315.83 0.00 84.89 7010.00 130.00 N 1455.00 E 0.00 1460.80 Beluga Base Conglomerate 7320.83 0.00 84.89 7015.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B15 7355.83 0.00 84.89 7050.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B16 7500.00 0.00 84.89 7194.17 130.00 N 1455.00 E 0.00 1460.80 7597.83 0.00 .84.89 7292.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B18 7778.83 0.00 84.89 7473.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B20 7823.83 0.00 84.89 7518.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B21 7936.83 0.00 84.89 7631.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B23 8000.00 0.00 84.89 7694.17 130.00 N 1455.00 E 0.00 1460.80 8108.83 0.00 84.89 7803.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B24 8286.83 0.00 84.89 7981.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B26 8435.83 0.00 84.89 8130.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B28 8500.00 0.00 84.89 8194.17 130.00 N 1455.00 E 0.00 1460.80 8567.83 0.00 84.89 8262.00 130.00 N 1455.00 E 0.00 1460.80 Beluga B30 8805.83 0.00 84.89 8500.00 130.00 N 1455.00 E 0.00 1460.80 All data is in feet unless otherwise stated. Coordinates from slot #10 and TVD from Est. RKB (179.00 Ft above mean sea level). Bottom hole distance is 1460.80 on azimuth 84.89 degrees from wellhead. Total Dogleg for wellpath is 56.73 degrees. Vertical section is from wellhead on azimuth 84.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company Pad #3, BC- 10 Beaver Creek Unit,Kenai Peninsul a, A1 aska PROPOSAL LISTING Page 3 Your ref : BC #10 Version~ Last revised : 13-Nov-2000 Comments i n wel 1 path MD TVD Rectangul ar Coords. Comment 5174.96 4872.00 125.37 N 1403.23 E Sterling B Coal 5219.53 5294.30 5349 75 5413 14 5466 38 5539 61 5600 73 5805 83 6300 83 6408 83 6608 83 7315 83 7320 83 7355 83 7597 83 7778 83 7823 83 7936 83 8108 83 8286 83 8435 83 8567 83 4916.00 126.00 N 1410.27 E Sterling BO 4990.00 126.96 N 1420.94 E Sterling BIA 5045.00 127.58 N 1427.91 E Sterling BIB 5108.00 128.21 N 1434.91 E Sterling B2 5161.00 128.66 N 1439.99 E Sterling B3 5234.00 129.17 N 1445.76 E Sterling B3A 5295.00 129.51 N 1449.52 E Sterling B4 5500.00 130.00 N 1455.00 E Tgt 1 - BC #10 - 13 Nov O0 5995.00 130.00 N 1455.00 E Beluga B2 6103.00 130.00 N 1455.00 E Beluga B4 6303.00 130.00 N 1455.00 E Beluga Top Conglomerate 7010.00 130.00 N 1455.00 E Beluga Base Conglomerate 7015.00 130.00 N 1455.00 E Beluga B15 7050.00 130.00 N 1455.00 E Beluga B16 7292.00 130.00 N 1455.00 E Beluga B18 7473.00 130.00 N 1455.00 E Beluga B20 7518.00 130.00 N 1455.00 E Beluga B21 7631.00 130.00 N 1455.00 E Beluga B23 7803.00 130.00 N 1455.00 E Beluga B24 7981.00 130.00 N 1455.00 E Beluga B26 8130.0Q 130.00 N 1455.00 E Beluga B28 8262.00 130.00 N 1455.00 E Beluga B30 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 8805.83 8500.00 130.00N 1455.00E 3 1/2" Casing 0.00 0.00 O.OON O.OOE 2427.99 2377.00 26.32N 294.60E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ....... : ........ : ................................... .... o.00, -,ov. 000 BCU 10 ESTIMATED TOPS AND PRESSURES* 11/9/00 TOP SSTVD TVD LOWEST HIGHEST PRESSURE LOWEST PRESSURE HIGHEST GRAD. PRESSURE GRAD. PRESSURE STERLING BCU 6 NEARBY COMPLETIONS BCU3 BCU9 BCUIA B COAL 4694 4872 BO 4738 4916 B1A 4812 4990 B1 B 4867 5045 B2 4830 5008 B3 4983 5161 B' ' 5056 5234 ~ 5117 5295 0.23 1152 0.23 1187 0.21 1099 0.41 2171 BELUGA A A A A A A A A A A C B2 5817 5995 0.44 2638 B4 5925 6103 0.44 2685 Top Conglomerate 6125 6303 Base Conglomerate 6832 7010 B15 6837 7015 0.42 2946 0.49 3437 B16 6872 7050 0.42 2961 0.49 3455 B18 7114 7292 0.42 3063 0.49 3573 B20 7295 7473 0.42 3139 0.49 3662 B21 7340 7518 0.42 3158 0.49 3684 B23 7453 7631 0.42 3205 0.49 3739 B24 7625 7803 0.42 3277 0.49 3823 B26 7803 7981 0.28 2235 0.49 3911 B2 7952 8130 0.28 2276 0.49 3984 B3~''' 8084 8262 0.42 3470 0.49 4048 Total Depth 8300 8478 C C c c c c c Beluga depletions possible in zones identified by "A" (abandoned) and "C" (active completion) in the nearby wells. Sterling depletions expected across the field. CONTROL Used B3A seismic structure (1998) & BCU 6 . Used B3A seismic structure (1998) & BCU 6 ii Used B23 sub-surface structure (1994) & BCU 6 i! ii . ii i! i! 2o, T7Nii10W BCU 8 26 BCU T6N-R~10W Structure Base Beluga C.I. 50' l°l MARATHON OIL COMPANY ALASKAN PRODUCTION REGION BEAVER CREEK KENAI, ALASKA BCU 10 Loca~on November 2000 o:/ffeehand/bcul01oc.fh7 l~iOV ? u Oil & GaS Cons Commission Anchorage Surface Use Plan for Beaver Creek #10 Surface location: Anticipated at 1074' FNL, 1532' FWL, Sec. 34, T7N, R10W, S.M. 1) Existing Roads Existing roads which will be used for access to Beaver Creek #10 are shown on the attached map. Kenai, Alaska is the nearest town to the site and is also shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access Beaver Creek #10. 3) Location of existing wells Well BC-10 will be drilled on pad BC 3. A pad drawing is enclosed that shows existing wells and the proposed location of BC-10. 4) Location of existing and/or proposed facilities The locations of existing production facilities are shown on the enclosed pad drawing. These facilities will be upgraded to handle the additional gas production. 5) Location of Water Supply A water supply well exists on the pad that Beaver Creek #10 will be drilled from. This is shown on the pad drawing. 6) Construction Materials No construction is planned on the pad. If the pad requires minor leveling, the sand and gravel will be obtained from the approved gravel pit in the SW/4, NE/4, Sec. 5 T6N, R10W, S.M. Other materials will be obtained from various vendors and suppliers in Alaska. 7) Methods of handling waste disposal; a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula BoroUgh Soldotna Landfill. c) Completion Fluids Clear fluids will be injected into approved disposal wells Beaver Creek # 2 (Alaska Oil and Gas Conservation Commission Disposal Injection Order No. 4) or hauled to Pad 34- 31 of the Kenai Gas field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad. S and R will collect and transport sanitary wastes to their ADEC approved disposal facility. 9) Plans for reclamation of the surface Beaver Creek #10 will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of Beaver Creek #10 and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Beaver Creek Unit is the U.S. Fish and Wildlife Service. The minerals are under the jurisdiction of the U.S. Bureau of Land Management. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6319 T_7N. T. 6N. T. 6N. T_5N~ 238OOOO FEET )C _ _ 19 _- . j 20_ ---! -' --'""-~:'~:' ...... i- ' / ~-------- ~ · ~-,k~'-r--~3-~- --'~., ·_ _ - ' -.~ / ~ -.- .--:" - - i .... - - '~3, ' :: - i ( ..-:? i5 '! i .... " /'-'< ' ' ?'_| - '.a -? -- -- i ,O ~ I. t I -,i ....... _ ¥.?' · <1~. _ ./ .: .....-- ........-.; j: · CJ o 9 33 _ :-.-. 60°3ff . 151007,30" 300 000 FEET 5' 78 ML Mapped, edited, and published by the Geological Survey Control by USCE 36 -: .o K~NA/ 13 ML Topography by photogrammetric methods from aerial photographs . t6~ .... -.~ taken 1950. Cuture revised in part from aerial photographs Ii 1 Field annotated 1980. Map not field checked Projection and lO00-meter grid ticks: Universal s- lO,O00-foot grid ticks based on Alaska coordinate system, zone 5. 1927 North American datum Gray land lines represent unsurveyed and unmarked locations um GRID lC RTH predetermined by the Bureau of Land Management DECLINATION A,~EN~ER OF' SHEET Folio S- 16, Seward Meridian Swamps, as portrayed, indicate only the wetter areas, usually of Iow relief, as interpreted from aerial photographs To place on the predicted North American Datum 1983 move the projection lines 67 metem north and 121 meters east There may be private inholdings within the boundaries of the National or State reservations shown on this map 5 Mink :25 _ R. I0 W. B--3) R. 9 W. 55' SCALE 1:63360 I 21- 0 1 2 3000 0 3000 6000 9000 12000 15000 ~ ~ ~--~ i i ' I I I I i i i i i i ii i i 1 .5 ' 0 1 2 3 4 29 CONTOUR INTERVAL 50 FEET DOTTED LINES REPRESENT 25-FOOT CONTOURS NATIONAL GEODETIC VERTICAL DATUM OF ]929 [.' 1800O FOR SALE BY U, S, GEOLOGICAL SURVEY FAIRBANKS, ALASKA 99701, DENVER, COLORADO 80225, OR RESTON, VIRGINIA 22092 A FOLDER DESCRIBING TOPOGRAPHIC' MAPS AND SYMBOLS IS AVAILABLE ON REQUEST 27. Forest L G :.: ,.. ROBINSON ~ · j - 4 MILES 21000 FEET I I KILOMETERS QUADRANGLE LOCATION , VICINITY MAP SEC 34 TTN R 10W SM Drillgite , I SCALE IN FEET ~' , '~ BCU lO // PAD 7 PURPOSE: DRILL & COMPLETE PLAN VIEW, PROPOSED LOCATION FOR'~ BCU 10 BC~ 10 ON: PAD 3 0 1000 2000 AT: BEAVER CREEK PRODUCTION ADJACENT PROPERTY ~ , i FACILITY OWNERS SCALE IN FEET . IN: PAD 3 KENAI PENINSULA , · KEN'Al NATIONAL WILDLIFE REFUGE MARATHON OI~:'COMPANY BOUROUGH. AK. ' P.O. BOX 190168 APPLICATION BY: ANCHORAGE. AK. 99519 MARATHON OIL COMPANY BCU NO.IO G 1~4 GLO/tILbl matummt fQund t~b mrvay. 0 Feund 5/8' rabar dth d. oap ). Faund aurvey matumen[ of record, · F.,datlng ~ ~ ~ 1) Jul baa~k~ are gdd unlam noted 2) Badm of Coorctm~ lB U~S,C..& g.S, i BEAVER. CREEK PAD AS-BUIL~ . BEAVER ~~ PAD 8 I,~.~ Alaska~' ion Domest,,,/roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 15, 2000 Mr. Robert Christianson Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: BC-10 Dear Mr. Christianson: Enclosed is the PERMIT TO DRILL application for Marathon Well BC-10 and a check for $100. This well was permitted in January of 1998 (Permiit # 98-26, APl #50-133-20482) but never drilled. Please advise if additional information is required. I will be on vacation until November 30, 2000, but Craig Young will be available on 564-6310 or ceyoung@marathonoil.com. Sincerely, Peter K. Berga Drilling Superintendent Enclosure RECEIVED NOV 2. u ?nfln Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. Alaska[ 'lion Dome~ .~roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 November 15, 2000 Ms. Riki Lebman Project Review Coordinator, Oil & Gas Projects Alaska Division of Governmental Coordination 411 W. 4th Avenue, Suite 2C Anchorage, AK 99501 Coastal Project Questionnaire and permit applications Marathon Beaver Creek Unit BC-10 natural gas development well Kenai National Wildlife Refuge, Alaska Dear Ms. Lebman: Attached is the final Coastal Project Questionnaire and relevant permits for drilling the Marathon Beaver Creek Unit BC-10 natural gas development well at Pad 3 within the Kenai National Wildlife Refuge, Alaska. Current plans are to commence this project in February 2001. I have included five copies of the permit package for you to distribute to the involved agencies that include the Alaska departments of Environmental Conservation, Fish and Game, and Natural Resources, the Kenai Peninsula Borough, and the U. S. Fish and Wildlife Service. If you have any questions or require additional information, I can be reached at 907-564-6372 or rjmenzie @marathonoil.com. Sincerely, Robert J. 1V~nzie, Jr. ~/ Advanced HES Professional File: 160.14 A subsidiary of USX Corporation Environmentally aware for the long run. Coastal Project Questionnaire and Certification Statement Please answer all questions. To avoid a delay in processing, please call the department if you answer "yes" to any of the questions related to that department. Maps and plan drawings must be included with your packet. An incomplete packet will be returned. · APPLICANT INFORMATION 1. Marathon Oil Company 2. Robert J. Menzie, Jr. Name of Applicant P.O. Box 196168 Agent (or responsible party if other than applicant) P.O. Box 196168 Address Address Anchorage Alaska 99519-6168 Anchorage Alaska 99519-6168 City/State Zip Code City/State State Zip Code Zip Code 907-561-5311 907-564-6372 Daytime Phone Daytime Phone 907 -564-6489 907 -564 -6489 Fax Number E-mail Address Fax Number rj menzie @ marathonoil, com E-mail Address · PROJECT INFORMATION Yes No 1. This activity is a: X new project [] modification or addition to an existing project If a modification, do you currently have any State, federal or local approvals related to this activity? ........................................................................................................................... [] [] Note: Approval means any form of authorization. If "yes," please list below: Approval Type Approval # Issuance Date Expiration Date 2. If a modification, has this project ever been reviewed by the State of Alaska under the ACMP? ........... [] [] Previous State I.D. Number: AK Previous Project Name: · PROJECT DESCRIPTION 1. Provide a brief description of your entire project and ALL associated facilities and land use conversions. Attach additional sheet(s) as needed. Marathon Oil Company is proposing to drill a directionally drilled natural gas development well, BC-10, at the surface location described as 1074 ft from the north line, 1532 ft from the west line of Sec. 32, T7N, R10W, Seward Meridian from existing gravel pad 3 in the Beaver Creek Field. The bottom hole location is 914 ft from the north line, 2987 ft from the west line of Sec. 34, T7N, R10W, Seward Meridian. Pad 3 is located approximately 12 miles northeast of Kenai, Alaska. This project consists of drilling, groundwater use, and temporary waste storage. In order to protect surrounding wetlands and avoid potential hydrocarbon impacts from the project, Marathon intends to take the following four precautions: 1) place a double liner beneath the drilling rig, diesel storage tank, and mud system; 2) use a double-walled diesel storage tank that has an annulus capable of Revised 1/99 Page 1 containing 110% of the volume of the inner tank; 3) place the diesel storage tank at least 100 feet away from wetlands; and 4) store adequate spill response equipment on site to handle accidental leaks or spills of oil, gas, or other toxic materials. The liner consists of a bottom layer of geotextile felt overlain by a 20-mil-thick polyethylene liner. The edges of the liner are bermed using timbers that result in a freeboard of six inches. The total capacity of the lined area under the rig, diesel tank, and mud system is greater than the equivalent volume of 110% of the volume of the diesel tank plus 12 inches of freeboard. Proposed starting date for project: February 1, 2001 Proposed ending date for project: December 31, 2001 2. Attach the following: · a detailed description of the project, all associated facilities, and land use conversions, etc. (Be specific, including access roads, caretaker facilities, waste disposal sites, etc.); · a project timeline for completion of all major activities in the proposal; · a site plan depicting property boundary with all proposed actions; ® other supporting documentation that would facilitate review of the project. Note: If the project is a modification, identify existing facilities as well as proposed changes on the site plan. · PROJECT LOCATION 1. Attach a copy of the topographical and vicinity map clearly indicating the location of the project. Please include a map title and scale. 2. The project is located in which region (see attached map): [] Northern X Southcentral [] Southeast [] within or associated with the Trans-Alaska Pipeline corridor 3. Location of project (Include the name of the nearest land feature or body of water.) 12 miles northeast of Kenai, Alaska Township: 7N Range: 10W Section: 34 Meridian: S Latitude/Longitude N 60o39' 31.418" W151° 1'5.147" USGS Quad Kenai C-3 , Is the project located in a coastal district? Yes X No [] If yes, identify: Zone 17 Kenai Peninsula Borough (Coastal districts are a municipality or borough, home rule or first class city, second class with planning, or coastal resource service area.) Note: A coastal district is a participant in the State's consistency review process. It is possible for the State review to be adjusted to accommodate a local permitting public hearing. Early interaction with the district is important; please contact the district representative listed on the attached contact list. 5. Identify the communities closest to your project location: Sterling, Alaska , The project is on: [] State land or water* X Federal land [] Private land [] Municipal land [] Mental Health Trust land *State land can be uplands, tidelands, or submerged lands to 3 miles offshore. See Question #1 in DNR section. Contact the applicable landowner(s) to obtain necessary authorizations. · DEPARTMENT OF ENVIRONMENTAL CONSERVATION (DEC) APPROVALS Yes 1. Will a discharge of wastewater from industrial or commercial operations occur? .................................. [] Will the discharge be connected to an already approved sewer system? ................................................. [] Will the project include a stormwater collection/discharge system? ....................................................... [] No X X X Revised 1/99 Page 2 2. Do you intend to construct, install, modify, or use any part of a wastewater (sewage Yes or greywater) disposal system? .................................................................................................................... [] a) If so, will the discharge be 500 gallons per day or greater? .............................................................. [] b) If constructing a domestic wastewater treatment or disposal system, will the system be located within fill material requiring a COE permit? ....................................................... [] If you answered yes to a) or b), answer the following: 1) What is the distance from the bottom of the system to the top of the subsurface water table? No 2) How far is any part of the wastewater disposal system from the nearest surface water? 3) Is the surrounding area inundated with water at any time of the year? ............................................. [] 4) How big is the fill area to be used for the absorption system? (Questions 1 & 2 will be used by DEC to determine whether separation distances are being met; Questions 3 & 4 relate to the required size of the fill if wetlands are involved.) , Do you expect to request a mixing zone for your proposed project? .................................................... [] (If your wastewater discharge will exceed Alaska water quality standards, you may apply for a mixing zone. If so, please contact DEC to discuss information required under 18 AAC 70.032.) , a) Will your project result in the construction, operation, or closure of a facility for the disposal of solid waste? .................................................................................................................. [] (Note: Solid waste means drilling wastes, household garbage, refuse, sludge, construction or demolition wastes, industrial solid waste, asbestos, and other discarded, abandoned, or unwanted solid or semi-solid material, whether or not subject to decomposition, originating from any source. Disposal means placement of solid waste on land.) b) Will your project result in the treatment of solid waste at the site? ................................................. [] (Examples of treatment methods include, but are not limited to: incineration, open burning, baling, and composting.) c) Will your project result in the storage or transfer of solid waste at the site? .................................... X d) Will the project result in the storage of more than 50 tons of materials for reuse, recycling, or resource recovery? ...................................................................................................................... [] e) Will any sewage solids or biosolids be disposed of or land-applied to the site? ............................. [] (Sewage solids include wastes that have been removed from a wastewater treatment plant system, such as a septic tank, lagoon dredge, or wastewater treatment sludge that contain no free liquids. Biosolids are the solid, semi-solid, or liquid residues produced during the treatment of domestic septage in a treatment works which are land applied for beneficial use.) 5. Will your project require the application of oil, pesticides, and/or any other broadcast chemicals? ............................................................................................................................................. [] o a) Will you have a facility with industrial processes that are designed to process no less thanfive tons per hour and needs air pollution controls to comply with State emission standards? ........................................................................................................................ [] b) Will you have stationary or transportable fuel burning equipment, including flares, with a total fuel consumption capacity no less than 50 million Btu/hour? ...................................... [] c) Will you have a facility with incinerators having a total charging capacity of no less than 1,000 pounds per hour? ........................................................................................................... [] d) Will you have a facility with equipment or processes that are subject to Federal New Source Performance Standards or National Emission Standards for hazardous air pollutants? ...... [] i) Will you propose exhaust stack injection? ............................................................................... [] e) Will you have a facility with the potential to emit no less than 100 tons per year of any regulated air contaminant? ............................................................................................................... X f) Will you have a facility with the potential to emit no less than 10 tons per year of any X X X [] X X X X X X X X Revised 1/99 Page 3 Yes hazardous air contaminant or 25 tons per year of all hazardous air contaminants? ................................. [] g) Will you construct or add stationary or transportable fuel burning equipment of no less than 10 million Btu/hour in the City of Unalaska or the City of St. Paul? ...................................... [] h) Will you construct or modify in the Port of Anchorage a volatile liquid storage tank with a volume no less than 9,000 barrels, or a volatile liquid loading rack with a design throughput no less than 15 million gallons? ................................................................................... [] Will you be requesting operational or physical limits designed to reduce emissions from an existing facility in an air quality nonattainment area to offset an emission increase from another new of modified facility? ................................................................................................... [] 7. Will you be developing, constructing, installing, or altering a public water system? .............................. [] , a) Will your project involve the operation of waterborne tank vessels or oil barges that carry crude or non-crude oil as bulk cargo, or the transfer of oil or other petroleum products to or from such a vessel or a pipeline system? ................................................. [] b) Will your project require or include onshore or offshore oil facilities with an effective aggregate storage capacity of greater than 5,000 barrels of crude oil or greater than 10,000 barrels of non-crude oil? ............................................................................. [] c) Will you be operating facilities on the land or water for the exploration or production of hydrocarbons? .............................................................................................................................. X If you answered "NO" to ALL questions in this section, continue to next section. If you answered "YES" to ANY of these questions, contact the DEC office nearest you for information and application forms. Please be advised that all new DEC permits and approvals require a 30-day public notice period. DEC Pesticide permits take effect no sooner than 40 days after the permit is issued. Based on your discussion with DEC, please complete the following: Types of project approvals or permits needed Date application submitted No X X X X X X X 9. Does your project qualify for a general permit for wastewater or solid waste? ....................................... [] Note: A general permit is an approval issued by DEC for certain types of routine activities. X If you answered "YES" to any questions in this section and are not applying for DEC permits, indicate reason: [] (DEC contac0 told me on that no DEC approvals are required on this project because X Other: (6e) Title V Operating Permit Application-Beaver Creek Field (dated October 7, 1997); (4c) only a solid waste plan is required for this proiect (i.e., no permit required). · DEPARTMENT OF FISH & GAME (DFG) APPROVALS 1. Will you be working in, removing water or material from, or placing anything in, a stream, river or lake? (This includes work or activities below the ordinary high water mark or on ice, in the active flood plain, on islands, Revised 1/99 Page 4 in or on the face of the banks, or, for streams entering or flowing through tidelands, above the level of mean lower low tide.) Note: If the proposed project is located within a special flood hazard area, a floodplain development permit may be required. Contact the affected city or borough planning department for additional information and a floodplain determination.) ................. [] Name of waterbody: 2. Will you do any of the following: ........................................................................................................... [] o Please indicate below: [] Build a dam, river training structure, other instream impoundment, or weir [] Use the water [] Pump water into or out of stream or lake (including dry channels) [] Divert or alter the natural stream channel [] Change the water flow or the stream channel [] Introduce silt, gravel, rock, petroleum products, debris, brash, trees, chemicals, or other organic/inorganic material, including waste of any type, into the water [] Alter, stabilize or restore the banks of a river, stream or lake (provide number of linear feet affected along the bank(s) [] Mine, dig in, or remove material, including woody debris, from the beds or banks of a waterbody [] Use explosives in or near a waterbody [] Build a bridge (including an ice bridge) [] Use the stream, lake or waterbody as a road (even when frozen), or cross the stream with tracked or wheeled vehicles, log- dragging or excavation equipment (backhoes, bulldozers, etc.) [] Install a culvert or other drainage structure [] Construct, place, excavate, dispose or remove any material below the ordinary high water of a waterbody [] Construct a storm water discharge or drain into the waterbody [] Place pilings or anchors [] Construct a dock [] Construct a utility line crossing [] Maintain or repair an existing structure [] Use an instream in-water structure not mentioned here Yes Is your project located in a designated State Game Refuge, Critical Habitat Area or State Game Sanctuary? ........................................................................................................................... [] 4. Does your project include the construction/operation of a salmon hatchery? ......................................... [] 5. Does your project affect, or is it related to, a previously permitted salmon hatchery? ............................ [] 6. Does your project include the construction of an aquatic farm? ............................................................. [] If you answered "No" to ALL questions in this section, continue to next section. If you answered "Yes" to ANY questions under 1-3, contact the Regional or Area DFG Habitat and Restoration Division Office for information and application forms. If you answered "Yes" to ANY questions under 4-6, contact the DFG Commercial Fisheries Division headquarters for information and application forms. Based on your discussion with DFG, please complete the following: Types of project approvals or permits needed No Title 16 Special Area Permit needed according to Mark Fink (11/15/00). Date application submitted NA X X No X X X X If you answered "YES" to any questions in this section and are not applying for DFG permits, indicate reason: [] (DFG contact) told me on that no DFG approvals are required on this project because Revised 1/99 Page 5 [] Other: · DEPARTMENT OF NATURAL RESOURCES (DNR) APPROVALS Yes Is the proposed project on State-owned land or water or will you need to cross State-owned land for access? ("Access" includes temporary access for construction purposes. Note: In addition to State-owned uplands, the State owns almost all land below the ordinary high water line of navigable streams, rivers and lakes, and below the mean high tide line seaward for three miles.) ......................................................................................................... [] a) Is this project for a commercial activity? ........................................................................................... X 2. Is the project on Alaska Mental Health Trust land (AMHT) or will you need to cross AMHT land? Note: Alaska Mental Health Trust land is not considered State land for the purpose of ACMP reviews .................................... [] o Do you plan to dredge or otherwise excavate/remove materials on State-owned land? .......................... [] Location of dredging site if different than the project site: Township __ Range __ Section __ Meridian USGS Quad Map . Do you plan to place fill or dredged material on State-owned land? ....................................................... [] Location of fill disposal site if other than the project site: Township__ Range_ Section__ Meridian USGS Quad Map Source is on: [] State Land [] Federal Land [] Private Land [] Municipal Land o Do you plan to use any of the following State-owned resources: ............................................................ [] [] Timber: Will you be harvesting timber? Amount: [] Materials such as rock, sand or gravel, peat, soil, overburden, etc.: ............................................... Which material? Amount: Location of source: [] Project site [] Other, describe: Township_ Range__ Section__ Meridian__ USGS Quad Map ° Are you planning to divert, impound, withdraw, or use any fresh water, except from an existing public water system or roof rain catchment system (regardless of land ownership)? ............................... X Amount (maximum daily, not average, in gallons per day): 42,000 Source: existing Pad 3 water well Intended Use: drilling mud maintenance If yes, will your project affect the availability of water to anyone holding water rights to that water? ... [] 7. Will you be building or altering a dam (regardless of land ownership)? ................................................. [] 8. Do you plan to drill a geothermal well (regardless of land ownership)? ................................................. [] 9. At any one site (regardless of land ownership), do you plan to do any of the following? ....................... [] [] Mine five or more acres over a year's time [] Mine 50,000 cubic yards or more of materials (rock, sand or gravel, soil, peat, overburden, etc.) over a year's time [] Have a cumulative unreclaimed mined area of five or more acres If yes to any of the above, contact DNR about a reclamation plan. If you plan to mine less than the acreage/amount stated above and have a cumulative unreclaimed mined area of less than five acres, do you intend to file a voluntary reclamation plan for approval? ..... [] No X [] X X X X X X X X Revised 1/99 Page 6 10. Will you be exploring for or extracting coal? .......................................................................................... [] Yes 11. a) Will you be exploring for or producing oil and gas? ......................................................................... X b) Will you be conducting surface use activities on an oil and gas lease or within an oil and gas unit? X 12. Will you be investigating, removing, or impacting historical or archaeological or paleontological resources (anything over 50 years old) on State-owned land? ................................................................. [] 13. Is the proposed project located within a known geophysical hazard area? .............................................. [] Note: 6 AAC 80.900(9) defines geophysical hazard areas as "those areas which present a threat to life or property from geophysical or geological hazards, including flooding, tsunami run-up, storm surge run-up, landslides, snowslides, faults, ice hazards, erosion, and littoral beach process." "known geophysical hazard area" means any area identified in a report or map published by a federal, state, or local agency, or by a geological or engineering consulting firm, or generally known by local knowledge, as having known or potential hazards from geologic, seismic, or hydrologic processes. 14. Is the proposed project located in a unit of the Alaska State Park System? ............................................ [] If you answered "No" to ALL questions in this section, continue to Federal Approvals section. If you answered "Yes" to ANY questions in this section, contact DNR for information. Based on your discussion with DNR, please complete the following: Types of project approvals or permits needed Temporary Water Use Permit renewal Date application submitted pending X No X X X If you answered "YES" to any questions in this section and are not applying for DNR permits, indicate reason: [] (DNR contact) told me on that no DNR approvals are required on this project because. [] Other: · FEDERAL APPROVALS U.S. Army Corps of Engineers (COE) 1. Will you be dredging or placing structures or fills in any of the following: Yes No tidal (ocean) waters? streams? lakes? wetlands*? ................................................................................... [] X If yes, have you applied for a COE permit? ...................................................................................... [] [] Date of submittal: (Note: Your application for this activity to the COE also serves as application for DEC Water Quality Certification.) *If you are not certain whether your proposed project is in a wetlands (wetlands include muskegs), contact the COE, Regulatory Branch at (907) 753-2720for a wetlands determination (outside the Anchorage area call toll free 1-800-478-2712). Bureau of Land Management (BLM) 2. Is the proposed project located on BLM land, or will you need to cross BLM land for access? .............. X If yes, have you applied for a BLM permit or approval? ................................................................... X Date of submittal: Permit to Drill BC-10, submitted 11/15/00 U.S. Coast Guard (USCG) 3. a) Will you be constructing a bridge or causeway over tidal (ocean) waters, or navigable rivers, streams or lakes? ............................................................................................................................... [] b) Does your project involve building an access to an island? .............................................................. [] Revised 1/99 Page 7 [] [] X X Yes c) Will you be siting, constructing, or operating a deepwater port? ...................................................... [] If yes, have you applied for a USCG permit? ............................................................................. [] Date of submittal: U.S. Environmental Protection Agency (EPA) 4. a) Will the proposed project have a discharge to any waters? .............................................................. [] b) Will you be disposing of sewage sludge (contact EPA at 206-553-1941)? ...................................... [] If you answered yes to a) or b), have you applied for an EPA National Pollution Discharge Elimination System (NPDES) permit? ....................................................................................... [] Date of submittal: (Note: For information regarding the need for an NPDES permit, contact EPA at (800) 424-4372.) c) Will construction of your project expose 5 or more acres of soil? (this applies to the total amount of land disturbed, even if disturbance is distributed over more than one season, and also applies to areas that are part of a larger common plan of development or sale.) .................................................................................................. [] d) Is your project an industrial facility which will have stormwater discharge which is directly related to manufacturing, processing, or raw materials storage areas at an industrial plant? ............ [] If you answered yes to c) or d), your project may require an NPDES Stormwater permit. Contact EPA at 206-553-8399. Federal Aviation Administration (FAA) 5. a) Is your project located within five miles of any public airport? ........................................................ [] b) Will you have a waste discharge that is likely to decay within 5,000 feet of any public airport? ..... [] If yes, please contact the Airports Division of the FAA at (907) 271-5444. Federal Energy Regulatory Commission (FERC) 6. a) Does the project include any of the following: ~ . 1) a non-federal hydroelectric project on any navigable body of water .......................................... [] 2) a location on federal land (including transmission lines) ........................................................... [] 3) utilization of surplus water from any federal government dam .................................................. [] b) Does the project include construction and operation, or abandonment of natural gas pipeline facilities under sections (b) and (c) of the Federal Power Act (FPA)? ............................................. [] c) Does the project include construction for physical interconnection of electric transmission facilities under section 202 (b) of the FPA? ..................................................................................... [] If you answered yes to any questions under number 6, have you applied for a permit from FERC? ....................................................................................................................................... [] Date of submittal: (Note: For information, contact FERC, Office of Hydropower Licensing (202) 219-2668; Office of Pipeline Regulation (202) 208-0700; Office of Electric Power Regulation (202) 208-1200.) U.S. Forest Service (USFS) 7. a) Does the proposed project involve construction on USFS land? ...................................................... [] b) Does the proposed project involve the crossing of USFS land with a water line? ............................ [] If the answer to either question is yes, have you applied for a USFS permit or approval? ......... [] Date of submittal: 8. Have you applied for any other federal permits or authorizations? ......................................................... [] AGBNCY APPROVAL TYPE DATE SUBMITTED No X X X X X X X X X X X X X X [] X Revised 1/99 Page 8 Please be advised that the CPQ identifies permits subject to a consistency review. You may need additional permits from other agencies or the affected city and/or borough government to proceed with your activity. Certification Statement The information contained herein is tree and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alaska Coastal Management Program. Signature of-App~t or Agent ~ ~/ - Date INote: Federal agencies conducting an activity that will affect the coastal zone are required to submit a federal consistency determination, per 15 CFR 930, Subpart C, rather than this certification statement. DGC has developed a guide to assist federal agencies with this requirement. Contact DGC to obtain a copy. This certification statement will not be complete until all required State and federal authorization requests have been submitted to the appropriate agencies. · To complete your packet, please attach your State permit applications and copies of your federal permit applications to this questionnaire. Revised 1/99 Page 9 Pay to the order of: AI'4CHOFLAGE AI.~\SKA ..... . · . , . , · . . .,. , . . · :,.... '... ; ',...". -,', , · . . AOGCC 3001 Porcupine ])rive ~chorage, AK 99501-3192 .......... ..... :':~:i~Ciiii!ii~!].:?%: ......... .i~?i~ :/;iii!i:i~iiii]];~':. ......... .'..~,'~::. :'?: . [ ....... M ATe iT %i"~ O"-6J f4~-I N ' WORDS WITH NUMBERS Pay: VOID AF'FEF1 180 DAYS · .THE AMOUNT tM NUMBERS MIJST'MA'rCH-.THE AMOUNT IN WORDS .... ..... · ... · - - . · ....- ...... ,.,,// ar o ,lC · y NATIONAL BANK OF ALASKA ANCHORAGE ALASKA By /'~~~_' _,?'/," ~~""'L . ,'00 ~, 5 ~, ?,' ~: i, P 5 i~O00 S ?,:0 ~-,'0 ?,q, S P, ,_ ,. ,. ~7[~t~I1~'[~{'1&1:t~ Marathon Oil Company ~[,~];t~,]:i11~[~3~I1,~/ - -- P.O. Box 196168 ' - ~ I ~ ~8o I/0o ~ 01517 ANCHO~GE, ALASKA 99519-6168 NON-REPORTING ' ' ~ ' ~: "' ~ ~1 ~~ l~[~Je][~[ll~l:la= '100% REPORTABLE OPERATOR -- INDICATE sERVICEs .... CITY OR TYPE OF NON-EMPLOYEE COMP. . . . PAYMENT , Pmz~s, AwARus, OR STATE -- -- ~Au,a~s Filing Fee for,.2ermi~ tO D,ri~! Be.lO ...... WELL PERMIT CHECKLIST COMPANY PROGRAM: exp dev ~ redrll serv wellbore seg ann. disposal para req FIELD & POOL ~--_.)~~~ INIT CLASS ~~,/ ,~'~~ ADMINISTRATION 1. APPR . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. 13. Permit fee attached ....................... Lease number appropriate.~. ~.~.~:. ? C .r'e-:-:-:-:-_-~..~.b':'. ~ /.~ ': 'ff.~/ Unique well name and number.-,~.'.~. .............. Well' located in a defined pool .................. Well located proper distance from drilling unit.boundary .... Well located proper distance from other wells.'?~. ....... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can. be issued without administrative approval ...... Can permit be approved before 15-day wait ........... GEOLAREA ~~ UNIT# ~5~ :Z_/ ~-- ON/OFF SHORE ENGINEERING 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... ~) N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ ..Y.. N 18. CMT will cover all known productive horizons .......... r~~ N 19. Casing designs adequate for C, T, B & permafrost ....... . N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... ......... -~¢)~~'P~,~/ TD~,~._._~ 26. BOPE press rating appropriate; test to ,..GC~¢,._~ psig. ,.,~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... '-~ , 32. Seismic analysis of shallow gas zones ............ ~. [~/'Y N II APPR DATE 33. Seabed condition survey (if off-shore) ......... ....¢~./.v'' ' Y N II ~'~ULAR DISPOSAL35. With proper cementing records, this plan ' (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE N ~ n N ENGINEERING: UIC/Annular TEM ~¢~Y-I ~/'~..~ COMMISSION: JMH Comments/Instructions: O z O c:\msoffice\wordian\d iana\checklist (rev. 11/01fl00)