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207-088
Seth Nolan Hilcorp AIasLC 2 0 0 e 8 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 2 9 1 6 1 Tele: 907 777-8308 Hilenrp:'1/41:.4.01..1.u. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 04/02/18 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 • �i3D' Anchorage, AK 99501 'APR el 2018 DATA TRANSMITTAL AOGCC SU 41-15RD Prints Radial Cement Bond Log CD : PLUG 12/18/2017 3:26 PM File folder RADIAL BOND LOG 12/18/2017 3:26 PM File folder Please include current contact information if different from above. Please acknowledge receipt by si•i' g and returning one copy of this transmittal or FAX to 907 777.8337 Received ; : Date: Li 12:31 I e 0 4110 • STATE OF ALASKA MAR 1 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION ��;;�� WELL COMPLETION OR RECOMPLETION REPORT AN��EI'C 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ - Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or Zlisitt 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 2/,12018 t.` • 207-088/317-537 ✓ 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Anchorage,AK 99503 7/7/2007 50-133-20484-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2327'FSL,iFEL,Sec 9,T5N, R10W,SM,AK• 7/20/2007 Sterling Unit 41-15RD • Top of Productive Interval: ',I 37 I � lei 9. Ref Elevations:tions:: KB: :245' • 17. Field/Pool(s): � N/A ' • GLS.21'ZZ'1 BF:4j y0/ Lower Beluga&Upper Tyonek Gas • Total Depth: 10. Plug Back Depth'/MD/TVD: 18. Property Designation:rt"/j q 7,z.StS 474'FNL, 1080'FEL,Sec 15,T5N, R1 OW,SM,AK 0'MD/TVD • ' ADL002497/FEDA 028063 I S 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD:Wd 19. DNR Approval Number: 4-,/rs•/6 Surface: x- 314748.9602 • y- 2390036.9200 • Zone- 4 • 11,655'MD/11-689`TVD/ N/A TPI: x- N/A y- N/A Zone- 12.SSSV Depth MDTIVD:`j,`a1`'*10.Thickness of Permafrost MD/TVD: Total Depth: x- 319345.6101 y- 2387165.0900 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U (attached) No Q 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDFIVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCNED 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 133 K-55 0 79' 0 79' Driven 13-3/8" 61 K-55 0 2,271' 0 2,270' 17-1/2" 1,185 sks of Class G 9-5/8" 40 L-80 0 6,281' 0 5,615' 12-1/2" 2,284 sks of Class G 3-1/2" 9.3 L-80 6,275' 11,632' 0 9,499' 8-1/2" 2,001 sks of Class G 24.Open to production or injection? Yes ❑ No Q • 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): 3-1/2" 5,675' N/A Ar(54y3O o)-A1O 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 1K No ❑ 1-itteitt Per 20 AAC 25.283(i)(2)attach electronic and printed information t,� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate . 6.- Form 10-407 Revised 5/2017 d s/lie CONTINUED ON PAGE 2 RE 13 MS U,' mu a 2013 Submit ORIGINIAL on CI i • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q • Permafrost-Top If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. tea N/A N/A w• Formation at total depth: 31. List of Attachments: Operations Summary,Schematic, MIT-IA, Photo document casing cut-off/cement top/welded plate. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Ted Kramer,Operations Engineer Authorized Title: Operations Manager Contact Email: tkramertC7!hllcorp.com Authorized err Contact Phone: 907-777-8420 Signature: �`% Date: 5/(Z,I$ INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 11/28/17 2/15/18 DailY Operations: 11/28/2017-Tuesday Pollard arrive on location. PTW, safety meeting. Review job procedure with crew. RU PESI. Make up 2.25" dump bailer. 31'from bailer to ccl. Stab on well. PT stack 250/2,000 psi. Open master and swab 23.5 turns. RIH. Initial WHP 50 psi. Previous slick line fluid level was seen at 780'. E-line fluid level 620' (5.3 bbl void).Set down at 6575'. Dump 6 gallons of cement from 6530'. POOH to surface. Re-load bailer. RIH. Park at 6530'. Dump cement.Total cement dumped on top of previous CIBP/cement was 34'. Sent 24 hr P&A test witness notification to state 11/28/17 @ 14:28 am.Tagged up at surface. Close master and swab 23.5 turns. Rig back. Location secure. Estimated TOC 6,541'. 11/29/2017 Wednesday Crews arrive on location. Hold safety meeting, discuss and review job procedure, sign permit to work. Fire equipment. Rig up Pollard E-line. 3.5" CIBP setting tool has not been rebuild. Pollard supervisor depart for shop. Make up 3.5" CIBP. Stab on well. PT stack 250/2,000 psi. Open swab. RIH. Initial WHP 50 psi. Fluid level 600'. CCL to element of plug 12.5'. Log strip and send to town. Shifted current log up 2' as per town. Parked at 6,462.5' with CCL puts CIBP element at 6,475'. Set CIBP. Saw good inication of setting tool shear on voltage meter in E-line unit. Picked up and RIH to set down on CIBP. RIH past set depth . Not able to set down at 6,485' where CIBP should be. POOH.At surface. Setting tool sheared. CIBP left in hole but didn't appear to set. PESI crew rebuilding setting tool. Make up new 3.5" CIBP. RIH. Log strip. Confirm still on depth with previous correlation pass. Picked up one tool joint to attempt 2nd set of 3.5" CIBP. Parked with CIBP at 6,455'. Set CIBP, picked up and confirmed tag at depth. Looks like 2nd CIBP set and in place. POOH to surface. Start rigging up field triplex to fill tubing void. 600'fluid level gives us a 5.2 bbl void. At surface, close swab. Pop off. 24 hr P&A test witness notification sent 11/28/17 @ 14:28 hrs. nt•' (? State Representative Matt Herrera on location to witness PT of CIBP. 15:10 start recording pressure of 1,800 psi. 30 (1 I minute test . Test finished at 15:40 hrs end pressure 1,733 psi. State Rep likes test results. Bleed down PT. Move triplex test line and crystal gauge line to IA, (3-1/2" x 9-5/8"). Start filling IA. Make up 30' x 2.5" dump bailer. Mix cement. RIH with 30' of 2.5" bailer. Dump bailer at 6,450'. POOH to surface. Close swab. Pop off well. Mix up 2nd batch of cement. 16:40 hrs pressure up IA to 1,788 psi. RIH with 2nd cement dump bailer run. Parked at 6,445' dump 2nd cement bailer. POOH to surface. 17:10 hrs 30 minutes PT on IA at 1,756 psi. Good test. Continue monitoring IA pressure. At surface. Break down dumb bailer. Make up 2.5"jet cutter. Finish making up Jet cutter. Stab on well. RIH. Log and confirm on depth. Park at 3,000' CCL depth puts cut at 3,010'. BLeed down IA from 1,720 to 200 psi. P Fired cutter and saw pressure drop on IA. Good indication of cut. POOH to surface. OOH. Break down spent cutter. -p Make up 2.5"jet cutter. 2nd cutter run, stab on well. RIH. Make it past previous cut and stopped at 3,025'. Log a')1 OOH. Good signature noticed at cut. Stopped short at 3,000.7'to attempt to cut control lines, fired 2nd tubing cut. POOH to surface. Tagged up. At surface, shut in well. Master and swab secure. Rig down PESI. Location secure. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 11/28/17 2/15/18 rt Daily Operations: e" � e,. _ .; -14"; �� .,: _` 11/30/2017 Thursday Day shift arrive on location. Hold safety meeting. 24 hr BOPE test witness notification sent to state on 11-30-17 @ 11:24 am. Email sent to BLM for BOPE test notification. Unload Weaver Bros floats. RU light plants. Lay pit liner. Spot in Carrier, accumi unit, generator, fuel tank, pits, pump house, choke house, dragon heater. Berm up equipment in pit liner. Crew change and Co Rep change out. Hold safety meeting with night crews. Winterize rig equipment with Visqueen, enclose carrier, pits, pump, choke house. Moncla test pump fluid tank 3/4 full of ice. Crews rigging up heater trunks to thaw tank for BOPE test. Weaver truck on location with Weatherford BOPE equipment. (2130 hrs). Perform inventory of said equipment. Only one HCR loaded out vs the requested 2. Pull BOPE hoses, fluid pump hoses. Lay grating through main traffic areas in containment. Northern Oil Solutions wellhead hand on location. Set BPV, wellhead hand functioned each hanger lock down/shoulder bolts. RU to perform void test on hanger. Low void test 500 psi for 5 minutes. High void test 3,500 psi for 15 minutes. Test is good. Make up 13-5/8" 10M to 5M DSA to flow cross. Install DSA and 2x gate valves on kill side. Remove wellhead tree and Vetco tubing head. Trim control lines. Cycle hager bolts again. Install 10M to 5M DSA and flow cross. Install BOPE rams. 12/01/2017- Friday Crew change. Safety meeting w/ Moncla crew and work permit to work. Continue N/U, mud, cross double gates, BOP and kill line, choke line valves, set annular tight up all bolts on stack and flanges. Continue R/U, set stairs to rig floor, rig up floor and hook up all Koomey hoses to stack. Crew/Co man change out. Hold safety meeting. Discuss plan forward. Continue rigging up hoses to pits. Peak vac truck on location with 100 bbls of water @ 125*F. 150 bbls total fluid on location. Call out NOS wellhead tech. Remove back pressure valve. Make up test joint,TIWV, IBOP. Remove back pressure valve, install 2-way check. State Rep Matt Herrera on location. Fluid pack stack. Attempt shell test. Tighten flanges. Matt Herrera perform rig inspection. Start testing gas alarms. 24 hr BOPE test witness notification sent to the State 11-29-17 @ 21:54. Contacted by Matt Herrera to come witness test. BLM, BOPE test notification sent 11-30-17 @ 1103 am. Amanda Eagle and Quinn Sawyer, BLM on location for test witness. Informed from BLM only needed 5 minute test vs previous 10 minute test requirement. 2nd manual choke valve failed. Moncla called for replacement choke. Accumulator draw down test complete. BOPE test completed. Failed manual choke valve. Rebuild manual choke valve. Re-test and chart all good. Clean screens on accumulator unit. Dial back regulator to drop system pressure. Recommendation from state rep. Continue t/rig down all test equipment. • • Hilcorp Alaska, LLC /` Well Operations Summary iv^° t Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 11/28/17 2/15/18 Daily Operations: 12/02/2017-Saturday PJSM and continue RU power tongs, slips elev, P/U Weatherford spear and MU. RIH, latch up, BOLDS w/ NOS, hand pull hanger free PU wt 21k/ LD hanger, spear and recover manual slips 1/hanger. Continue POOH and standing back 3- 1/2" tubing in derrick removing all centralizers and ss bands, wire rope 3/8"cable and control lines. 13 stand removed from well. 819' of 3.5'tubing average removed from well. Crew/Co man change out. Hold safety meeting with night crew. Remove Foster tongs and install McCoy tongs. Start pulling stands. Trip OOH. Remove ss clamps, wire rope, and control lines. Pulled 35 stands for a total of 48 stands. Averaging 15 minutes per stand. NOTE: sent email to BLM and Amanda Eagle for 9-5/8" CIBP setting. Email sent 12/2/17 @ 11:57 PM. Clean up location. Stage control line on herculite pit liner on edge of pad. Halliburton E-line on location. Spot in equipment. Rig up HES to run CBL. Fill tubing from pipe displacement. 10.5 bbl volume. Make up rope socket for pressure control gear. Rig up to well. RIH with lubricator past annular bag. Close bag on lubricator. Chain down E-line lubricator. Pressure test to 1,500 psi. Bleed down to 1,000. RIH with CBL. Log from 3,000' to surface. 051 12/03/2017-Sunday Continue RIH with CBL. Log from 3,010' to surface and send logs in for evaluation. P/U 9-5/8" CIBP- HES. RIH t/ 2,380' WLM, set plug @ 2,380' w/ BLM present. POOH. R/D HES E-line. R/U test equipment, test 9-5/8" CIBP t/ 2,000 psi, chart 30 mins, witness w/ BLM. All good, bleed down to 0. R/D test euip. R/U Pollard E-line unit. RIH tubing punch t/2,255'-2,259' RKB. Total 4' holes w/9 holes. POOH t/surf. R/U t/attempt to circulate down the C`' ,+ 13-3/8" X 9-5/8" casing, pres up on 13-3/8" 1,200 psi, lost 100 psi in 5 mins w/ no returns, bleed down t/0, line up on is 9-5/8 " casing, pumping down 9-5/8" @ 1-1/2 bbl min with 650 psi injection rate @ 1 1/2 bbl min. Shut down pumping. Injected a total of 6 bbls. Crew and Co man change out, hold safety meeting. Discuss tripping pipe IH. Rig down Pollard E-line. Tighten bands on pipe tongs.Trip pipe in hole. Remove remaining centralizers. RIH with 37.5 stands in hole or 75 joints of pipe or 2,362' tagged top of CIBP. NOTE: Halliburton cement crews arrive 0400 start rigging up. 410 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 11/28/17 2/15/18 Daily Operations: ', x- lotto 12/04/2017- Monday PJSM w/crew change, continue R/U Hilb, cement hard lines to rig floor. Continue t/mix and batch up cement 15.3 lb 33 bbls and pump 5 bbls water, head test lines t/3,000 psi, all good.Start pumping Class G cement @ 3 bbls min w/ 150 psi and pump total 33 bbls G cement, spot balance plug, shut down I/D head pin. POOH, slow TI 1,950' TOC. Continue POOH t/ 1,450'. R/U cement head,fill hole w/calculating displacement w/ 1 bbl loss. Attempt to squeeze @ 1/2 bbl in pres up to 500 psi cont pumping t/ 1,000 psi, pump total 4 .5 bbls t/ 1,000 psi, hold f/30 mins, lost 25 psi. All good, bleed pres off t/0. R/ D cement crew. R/U t/l/d 3-1/2" tubing, continue I/d 3-1/2" tbg 47 jts. RIH w/ 21 stands out of derrick. Crew change/Co man change. Hold safety meeting. Discuss plan forward. Lay down 42 joints of pipe. Install thread protectors. All joints laid down. Pollard E line on location. Halliburton completion hand on location with CIBP. Rig up PESI. BLM representatives on location. RIH wtih CCL and 7' weight bar for a cement tag. Tag 1,934' correlated. PU and re tag for BLM. Print log and attach in well folder. POOH. At surface. Fill well. PT 9- 5/8" casing with CIBP and cement plug at 1,934'. RKB. 1,700 psi for 30 minutes. Good test. BLM satisfied with results. RU 9-5/8" CIBP. RIH. Log strip. ON'-146' depth. CIBP set at 160'. POOH to surface. RIH with tubing punch. Log and get on depth. Parked with CCL at 146'. 4'from CCL to top shot. Tubing punch from 150'-154'. 9-1/2" holes. POOH to surface. Rigged up to pump down 9-5/8" casing taking returns up the 13-3/8". Online pumping 2.5 bbls/min. Good returns to surface. Pump 35 bbls. Rig down Pollard E-line services. Halliburton cement crews on location. Cruz vac truck pull 55 bbls from water well. Steam on wheels heating up to 70°F. RU HES cement pumps, measure from top of OA valve (13-3/8")to top of annular bag. 15.4' RIH with 3.5" tubing joint 15.4' close VBR rams and annular bag. Hold pre-cement job safety meeting. Mix up chemicals. Pump 5 bbls spacer ahead to fluid pack pump lines. Close TIW. Pressure test 250/3,500 psi online with cement at 2 bbls/min, pump 23 bbls of cement. Cement returns to surface. Shut down clear lines. Clean up cement truck. 02/13/2018-Tuesday AOGCC and BLM given 48 hr witness. Witness waived by both agencies. Rig up excavator to wellhead. Cut wellhead. 5.5' below natural ground level. Document with pictures. Cement to surface in annulus. 6' void in casing. Will perform top cement job in the am. 02/14/2018 Wednesday Arrive on location. Meet with electrician. Remove power cable running from junction box into well cellar. Cruz vac truck on location. Rig up 1" PVC stinger pipe. Pull vac and remove fluid from 7" casing to a depth of 6' and tag TOC. Best transit on location. Rig cement truck and chutes over top of well. Fill 6' void with cement slury. Move cement truck to SU 23-15. Cement put in place at 11:20 am. Cement setup time is 3 hrs as per Best Transit mix. 7 sack cement. 111 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 11/28/17 2/15/18 Dal Y OpCrations at ,�` "f(- 02/15/2018 02/15/2018-Thursday Arrive on location with Udelhoven welder. Have safety meeting. Confirm cement is at surface and setup. Prepare well stub. Grind casing and bevel for marker plate. 20" marker plate seal welded on 20" conductor pipe. Markings as follows: Hilcorp Alaska PTD: 207-088,Well name SU 41-15RD,API #50-133-20484-01. Pack up welding truck and move to SU 23-15. Northstar on location to run excavator. Fill out PTW and hold safety meeting. Remove cellar and place cellar parts in dumpster. Dispatch Alaska waste to remove dumpster. Northstar delivered two loads of gravel. Fill hole. Load excavator on low boy and move to SU 23-15 pad. • i SU 41 -15RD SCHEMATIC Cement: 23.2 Pad 43-9 bbls15.8# Tubing Punch Class G 150'-154' 2327' FSL,437' FEL J1214/17 Hilcorp Alaska,LLC 12/4/17 Sec. 9, T5N, R10W, S.M. 3.5"CIBP 160'w/cement to surface 12/4/17 Permit#: 207-088 API#: 50-133-20484-01-00 Conductor Surface Casing '�ti 1 1 1.1 + r r r r•r•r r•r•.- 20" K-55 133ppf PE Property Des: r• •r, ti �•�•�•.* 13-3/8" K-55 61 ppf BTC AOGCC= ADL-2497 ri'.r r� Tog Bottom Top Bottom *� r r.v BLM = A-028063 P TMVD 0' 79' MD 0' 2,271' KB: 21'AGL (245'KB Elevation) O''' ND o' 2,270' X= 314,742.19 riCmt w/1,186 sks of Class G Intermediate Casing Y= 2,390,034.43 9-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N r rLflrtiflftiftiftitiT� Bottom a{L•'••ti•ti•ti•ti:91 ti Production Tubing Lon 151° 01' 51.643" W r�5�-.-L�•r•r•r•r•r•r•r•r •r 1 Long: •.'L•1•L•ti•ti•ti•ti 1.1:-.7.... MD 0' 6,281' 3-1/2" L-80 9.3 ppf EUE r•r r•r.r•r•r•r•r•r Spud: 09.00 hrs 7/07/2007 ND 0' 5,615' T� Bottom Tubing Punch Cmt original well w/2,284 sks of TD Reached: 7/20/2007 2,255-2,259' MD o' 11,632' Rig Released: 6:00 hrs 7/27/07 class G. TVD 0' 9,499' Cement: 35.5 bbls 8rd with 6.25"OD control line IN 15.8#Class Gprotectors. 8-1/2"hole,Cmt w/ 3.5"CIBP 2,380'w/446'cement '1 (1,934')TOC 12/4/17 545 sks(176 bbls)13.5 ppg G cmt Tree cxn =4-1/2"Otis 4 i lead and 1,456 sks(300 bbls),15.8 t, ppg Class G cmt tail. r Top of Cement 600'MD above 9-5/8"window @ 5,675'MD .. 3.5"CIBP 6,475'wl 35'cement J... (6,440')TOC 11/29/17 9-5/8"Casing Window °- 'F: milled from _F ~ 6,275'to 6,294'(MD) 3.5"CIBP(-6,650')w/25'cement 5,611'to 5,624'(TVD) �� (-6,625')TOC 1. ~1,5c Excape System Details ;d+ .r- Fish:20'pert gun with hydrostatic bailer on top.-6800' - 6 Excape module system , + -Red control line for top 4 modules I �_ Wr 4 Green control line for bottom 2 modules = 3.5"CIBP w/10cement -9,0 -9,090'TOC -Ceramic flapper valves below each module L except for modules 1 &2. - Perfs MD(RKB)(Beluga/Tyonek): LB-6,497'-6,514' (Lower Beluga)10/20/16 - 4:. , . i _ } LB-7,255'-7,275' (Lower Beluga)10/6/16 -- 0 s Tagged sand @ 9,334' LB-7,957'-7,973' (Lower Beluga)10/6/15 -__-_- .:ti (4/23/15) LB-9,161'-9,181' (Lower Beluga)4/01/15 " °ti w/2.75"Blind Box LB-9,231'-9,251' (Lower Beluga)4/01/15 - - t 0.{ Carbolite Sand on LB-9,433'-9,444' (Lower Beluga)3/31/15 .=* ? - 1!E} r= packoff plug @ 9,365' LB-9,452'-9,459' (Lower Beluga)3/31/15 I- JI - %. 7.- Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 - -aExcape System Details: Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 ', Wag°� = I I = -4 Conventional flappers Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 - -Mod 1 &2=no flappers Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 -Ceramic flapper valves below Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 - i each module as follows: 17' - 11,467'-11,480' (Tyonek) 9/22/07 = (2-1/8",6spf,60°phasing) = 1c frs iii Flappers MD(RKB) ND Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 = a= =xc I = Module 6 - 9,951' 7,984' 13' - 11,489'-11,506' (Tyonek) 9/22/07 a Module 5 - 10,052' 8,074' (2-1/8",6spf,60°phasing) _ -/ Module 4 - 10,178' 8,181' ssh [ ] Module 3 - 10,222' 8,228' ' TD PBTD Weatherford Float Collar 11,655'MD 0'MD 3/8" Capillary String (pulled on 7/9/10) 9,517'ND 0'ND BHA fish at 10,176'MD 11,584'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe -12"long 11,621'MD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(ND): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: Chad Helgeson Downhole Revison Date: 4/27/2015 Schematic Revison Date: 02/23/18 • STERLING UNIT 41-15RD - CEMENT TO SURFACE �R awe• r" r An 9+ de • ir }« _R • STERLING UNIT 41-15RD - CUT OFF WELLHEAD , . *k' 1 ,;" x}. 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(1)` .CFP. .30. .0 51,t'. .C.,93. �3,. �c3. Off. orli Ot'`. 0\. 00 <1 N5`. '\C0. '\C3. Cl>. Elapsed Time hh:mm:ss PSI G • S V\ Consulting Inc McLNE Well S.U. 41-15 Plug & Abandon Memo Via email Date: 6 February 2018 To: Hilcorp Alaska LLC. Attn: Cole Bartlewski From: Stan A. McLane, PE, PLS Project: Sterling Unit 41-15RD Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Sterling Unit 41-15RD well located on the "Sterling Pad" in section 9 T5N R1OW S.M. Alaska. The survey was performed on February 5, 2018. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was measured by comparing (3) check shots of corners of existing concrete pads to relevant data from a 2007 asbuilt survey. Horizontal accuracy checked within 0.25'. Vertical accuracy checked +0.59', likely due to frost heaving. A top of pad elevation was recorded adjacent to the well casing then (2) reference grade stakes were set with measurements to the proposed cutoff elevation. Original ground elevations were utilized from a design survey of the pad area by McLane in 1998. Enclosed is Exhibit A which includes pad asbuilt data from 2007 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. Basis of coordinates was established during pad expansion construction in 1998 and confirmed during a pad asbuilt update in 2007 for Marathon Oil. Results of the survey are as follows: • Mean pad surface grade in vicinity of well casing: 224.0' ± (2018) • Original ground elevation in vicinity of well casing: 222.5' ± (1998) • Cutoff depth requirement: 3.0' below original ground elevation • Survey control elevation adjustment: +0.6' • Minimum casing cutoff elevation: 218.9' • Casing cutoff elevation as staked in field: 218.5' The cutoff mark elevation of 218.5', as referenced in the field, exceeds the required minimum cutoff elevation of 218.9'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email samclane@mclaneg.com • • ie., Consulting Inc Page 2 of 2 IMcLAN Please feel free to contact me if you have any questions or comments. Sincerely, Stan A. McLane, PE, PLS �Abe OF A4 'III Principal P. %� 5�,, McLane Consulting, Inc. TH* 49 TE *e� STAN A. UcLANE / 's 4631—S X111'1\\\SN.% .. 2/8/2018 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email samclane@mclaneg.com • • IIII R STERLING PAD ASBUILT \ LAST SURVEY UPDATE: MARCH 2007 11 /:,C------'-6-a>-2,4-..._'•..e:_';_7__:t---E---------- r2NCE_ 0 iv— eo 1 WATER �E-7577,AO �e e 1 WELL /•'/� ///,, S.U..22 ON CONCRETE PAD 228 10'O WELL HOUSE CHAINGIZ 1� colv GRID N:2389891.71 GATE GRID E:1454877.04 ELEV.223.]0' CELLAR S.U.AR ' O GRID N:2389888.03 / if Z�\ GRID E:1454772.45 '� ' ' STERLING PAD ELEV.223.50' e SECTION 9 " ' T5N R10W S.M. AK 220 I I S.U.41-15RD ' 18'G WELL HOUSE / / 0 GRID E:14549]82.48 I S.U.3US9 ELEV.223.70' 18WELL HOUSE ® . '6/4‘k/ GRID N:238918151 GRID E:1454752.09 / m ELEV.223.70' 11.5'035.1' / INJECTION BUILDING /ON CONCRETE PAD H 6.8'X25.0' �, / METALBLDG. TANKS ON PIPE a 229 ON CONC.PAD CONC.PAD `MA.I ' I 8.2'%25.ON COMETAL NC.PAD 9.4'X25.T \� , •; �,> '``! OF AL1',,, METAL LDG. PIPE , ..... `` •••4Y 9.4'X28.1' ONCONC.PAD A `\\ tP '/L- BUILDING CONC.PAD MA PIPE . riI�W 4 ` —CI' ••• (�••.'737 ', o 6.0 OV ^ iit POWER RHEAD .. 1. ``\\. /*:44.7 \ '. 12.0'%42.2' ELEV.224.31' ED GU I H CP 12•RBR .� •�.RETE `�(/�/�//�/{���(J��//�� 40 N 2389630.890 I , ' '' SUPPOR 3"IPE �••••�••-••�/��'•'••••f�^��^� / E 14545RBR GEO _ ii . , PIPE ARD I • ry I/ ••.STAN 3 -S .. ff l�_ ___ •1 - PIPES - e _ •• � 1.(14:4:. 4637-5 4.5.0 f� ryb t/ • ! ••00 _ _. � PIPE 1 •0 PI' � 'o ho- 2,> NORTH I FEET 1I0 _____.4 WELL CASING CUT-OFF DETAIL: 4II II�III hl a VIII III"'" SCALE:1"=5' SCALE NOTES i WELL CASINGTO I BE REMOVED EDD 1.BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS I I PAD ELEV=224'± AN OPUS SOLUTION FROM NGS COORDINATES STATIONS"KEN1 CORS I I ARP","TLKA TALKEETNA CORS ARP",AND"POT3 POTATO POINT 3 ARP" I I O.G.ELEV=222.5'± TO ESTABLISH THE POSITION OF NGS BENCHMARK V80 PID TT0508.THE — ' _I_ —t— — — GEODETIC POSITION OF V80 WAS DETERMINED TO HAVE A LATITUDE I OF 60°31'54.63013"N AND A LONGITUDE OF 151°04'53.81758"W.THE ( I ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE 4.1'* I REFERENCED WELL N:2387882.684 I 1 E: 1445616.925 I CASINGELEV2185'CUTOFF AT = ELEV:158.63' 2.BASIS OF VERTICAL CONTROL IS NGS BM V80 PID TT0508 LOCATED WITHIN THE KENAI SPUR HIGHWAY RIGHT OF WAY AT MILE POST 3.75 *INCLUDES SURVEY HAVING AN ELEVATION OF 158.63 FEET NGVD29 ACCORDING TO NGS CONTROL CORRECTION FACTOR OF+0.6' PUBLISHED DATA. 3.ALL DISTANCES LISTED IN FEET. PROJECT HILCORP ALASKA, LLC REVISION: - /vb.CansuLting Inc S.U. 41-15 R D DATE: 2/7/2016 STERLING ALASKA DRAWN BV: CRM PLUG AND ABANDON EXHIBIT-A SCALE: 1'=100' PROJECT NO. 187007 ENGINEERING/MAPPING/SURVEYING/TESTING NAD 83, ASP ZONE 4 BOOK NO. 17-08 P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283-4218 FAX:(907)283-3265 SECTION 9 TO5N R10W SHEET EMAIL:SAMCLANE@MCLANECG.COM I tilcm]) Alaska, t I.Ir..1/' I/� OF 1 SEWARD MERIDIAN, ALASKA Stericukt 4 _l web 7Ceee Regg, James B (DOA) From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Sent: Monday, February 19, 2018 8:53 AM 1<e- ..(1 e To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); 'BLM_AK_AKSO_EnergySection_Notifications@blm.gov'; 'Eagle, Amanda'; Brooks, Phoebe L(DOA) Cc: Ted Kramer Subject: RE: Hilcorp SU 41-15RD Attachments: IMG_3426.JPG; IMG_3408.JPG Two more photos showing the cellar and back fill. From: Cole Bartlewski - (C) Sent: Monday, February 19, 2018 8:52 AM To: 'AOGCC.Inspectors@alaska.gov'; 'Regg, James B (DOA)'; BLM_AK_AKSO_EnergySection_Notifications@blm.gov; 'Eagle, Amanda'; 'Brooks, Phoebe L(DOA)' Cc: Ted Kramer Subject: Hilcorp SU 41-15RD Good morning. As per requested. I have attached documentation from McLane Consulting showing pad level vs natural ground level and wellhead cut off reference. I have also attached pictures of our Pad levet mark, and picture of our cut reference mark on wellhead. Su 41-14RD pad elevation is 224' . Original ground level is 222.5'. WE cut the wellhead at 218.25' which ✓ puts the top of SU 41-15rd wellhead 4.25' below natural ground level. This email would not allow me to attach anymore photos I will send an additional email with remaining photos. COLE BARTLEWSKI WELLS CONSULTANT CELL: 907-690-2854 5(41406 1 • c , i 4(McLANC.- P7b 70t5t0 Well S.U. 41-15 Plug & Abandon Memo Via email Date: 6 February 2018 To: Hilcorp Alaska LLC. Attn: Cole Bartlewski From: Stan A. McLane, PE, PLS Project: Sterling Unit 41-15RD Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Sterling Unit 41-15RD well located on the "Sterling Pad" in section 9 T5N R10W S.M. Alaska. The survey was performed on February 5, 2018. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was measured by comparing (3) check shots of corners of existing concrete pads to relevant data from a 2007 asbuilt survey. Horizontal accuracy checked within 0.25'. Vertical accuracy checked +0.59', likely due to frost heaving. A top of pad elevation was recorded adjacent to the well casing then (2) reference grade stakes were set with measurements to the proposed cutoff elevation. Original ground elevations were utilized from a design survey of the pad area by McLane in 1998. Enclosed is Exhibit A which includes pad asbuilt data from 2007 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. Basis of coordinates was established during pad expansion construction in 1998 and confirmed during a pad asbuilt update in 2007 for Marathon Oil. Results of the survey are as follows: • Mean pad surface grade in vicinity of well casing: 224.0' ± (2018) v- • • Original ground elevation in vicinity of well casing: 222.5' ± (1998) • Cutoff depth requirement: 3.0' below original ground elevation • Survey control elevation adjustment: +0.6' „- • Minimum casing cutoff elevation: 218.9' -- • • Casing cutoff elevation as staked in field: 218.5' The cutoff mark elevation of 218.5', as referenced in the field, exceeds the required minimum cutoff elevation of 218.9'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email samclane@mclaneg.com • Pae2of2 C, �t�Esirsa Inc g cL.AN . ,. Please feel free to contact me if you have any questions or comments. Sincerely, � v1 l l Stan A. McLane, PE, PLS �E C% A4,,7 I Principal ..L`P ` to McLane Consulting, Inc. :* : 49TH % i,, c`r �, S AN A. '\4c! AN f 4 6.5/—S P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email samclane@mclaneg.com . • ,ice° STERLING PAD ASBUILT \€-.4''''7." --•-\_•‘415,60,6, LAST SURVEY UPDATE: MARCH 2007 FENCE 4......... \o °1 I \ NI T�Of M --•----_____:.. o I 41k. `,i "7-7.-e..-DGE SF Pq WATER C."'_ � _.., o WELL � I1.5'X 35.1' TRAILER ITI: \ CONTROL ROOM LCOMM.TOWER ""'�~ \\ ON CONCRETE PAD _,it'd"/ 10 GRI W:2 8 HOUSE '� CHAIN LI GRID N:2389B91.71 G GRID E.1454677.04 7].O4 .. J j' ELEV.223.70 \. ...• _1 ..;' TO CO _ ER NN O CELLAR AD ' GRID N2789888.07 GRID E.1454)72.45 , ' , ^.- ' STERLING PAD ELEV.223.50' ,'. I i I', T5N REOWDS.M. AK . 8 rl/: __ S.U.41-15RD / / 18'O WELL HOUSE I 0 GRID E:145476248 S.U.32-09ELEV.223.70' 18'0 WELL HOUSE O GRID N:2389781.51 • I GRID E:1454752.09 ).B'%20.0' ELEV.223.70 ENSTAR BUILDING1 II f 11.5'X35.1' ON CONCRETE PAD INJECTION BUILDING /I I' j ON CONCRETE PAD t PIPE I • 8.8'%250' 4'0 \ TANKS PON AD 10/ L O,yi° METAL BLDG. CONK.PAD PIPE `,`���� 1 1 I ti 8.2'%25A'METALBLDG. ONCONC.PAD '0 e PI ��c OF A�q 11, ON CONC.PAD 9.4 X 25.7' x' METAL BLDG. A S 9.4'X28.1' ON CONC.PAD \�� ,P�PE[12'O ANTENNA POLE _ �[.•''' ••.�It BUILON CONC.PAD L .' PIPE j _ ' �; T� 91 120'%d2.Y 6'D CV RHEAD CONTROL .. 49 T ]4,/ BUILDING BUILDINGg• - ` / /ii:1111:74:;-RpERETECP 12'RBR I /lir • VH / ' / //;389630.8903 IPEi �-�,4545fifi.979 I ouna0 Ii ' ON. TANA. McLANEr .�ELEV.224.34' �0'^`��1DGEEOFPAD , / ""/ 46/37-5 • °__fi_ ' PIPE I�4'O PIP \ / ••••w1/2•4!..•••... _` TOP OF BERM 1V�'y 6.]L20.2 - / Ep _�� COLLECTION TANK 1� I ,1 II�• `� .o _�_ ON CONCRETE PAD \\ I/ �//24 \," 1 1\`..`` elliLrin min 0 100 /DHE NORTH II FEET I WELL CASING CUT-OFF DETAIL: "Iiil/I lllllllII SCALE: 1"=5' ( IiIII SCALE II WELL CASING TO NOTES I I / BE REMOVED 1.BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 2003)IS I I PAD ELEV=224't AN OPUS SOLUTION FROM NGS COORDINATES STATIONS"KEN1 CORS I I ARP","TLKA TALKEETNA CORS ARP",AND"POT3 POTATO POINT 3 ARP" I I O.G.ELEV=222.5'± TO ESTABLISH THE POSITION OF NGS BENCHMARK V80 PID TT0508.THE — — -- -i- -I-- — — — — — — GEODETIC POSITION OF V80 WAS DETERMINED TO HAVE A LATITUDE I I OF 60°31'54.63013"N AND A LONGITUDE OF 151°04'53.81758"W.THE I I ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE 4.1" I I REFERENCED WELL N:2387882.684I CASING CUTOFF AT E: 1445616.925 `Iln I^I'/ ELEV=218.5' ELEV: 158.63' 2.BASIS OF VERTICAL CONTROL IS NGS BM V80 PID TT0508 LOCATED WITHIN THE KENAI SPUR HIGHWAY RIGHT OF WAY AT MILE POST 3.75 *INCLUDES SURVEY HAVING AN ELEVATION OF 158.63 FEET NGVD29 ACCORDING TO NGS CONTROL CORRECTION FACTOR OF+0.6' PUBLISHED DATA. 3.ALL DISTANCES LISTED IN FEET. PROJECT HILCORP ALASKA, LLC REVISION: - IIConsulting Inc S.U. 41-15RD ;~47;'T -Ze 7 c(212k) N DATE: 2/7/2018 =hil STERLING ALASKA DRAWN BY: CRM ItilfPLUG AND ABANDON EXHIBIT-A SCALE: 1'=100' PROJECT NO. 187007 NAD 83, ASP ZONE 4 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. 17-08 P.O.BOX 488 SOLDOTNA,AK.99669 LOCATION VOICE:(907)283-4218 FAX:(907)283-32657 LLC/'� SECTION 9 TO5N R 10 W SHEET EMAIL:SAMCLANE©MCLANECG.COM Hilc-orp Alaska,L1 01 1 SEWARD MERIDIAN, ALASKA I , . . 0 • -3k-A t itk. rt P zi"ccek° ---------_______hi , IIMmt I 41111! I' • il, thik i -,1- *- •)-.:-. _ 7`‘' ... ....,.._-- • . , ••••_....„., i . .. ...4 ' - . ii N... ' LA, :•- • 4.-' .0. ' ••• ••••••.,., " . .; 'V '"••,74 1-VA' , ', ' • _ti ''' - ' .r:ifi---: ',. - '1:.'' i';-- ..-f,:-. . , , ,';' • ,-- „,........ ....,___..,!: „ IC ' _ -- ore.-•.' . .. -._ . ' • . ,. --, .- . . -.. - • t."t. - .. • . ....,, '''. .7).-, • ..... ., . •f..., . .....i‘tr ... . ..--'-• -•- .', ' • ' .. . . , •-..'-_...,••• '•..”- ' ,. 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'1 �.� . ar. itr' F. #,,, f F f L12 - ,, 1 ,'i, -:: : .. a C " ,, '`. , . �--- i ; f ' 1, Nor_ T h ". •..�: k4 ( , s 1 $ t m._ j i I tw - , , 'iff'7.'l''X:4' .i R 4ii(00/410.. . p -r9a � �`s .. .f ' ( ski _ �` l % � �A� .,% 7e � k I \ --f �• Ies ' �- ,. te . rr ,_+ t`r/ ti t•`.. t� ► r 0 � Z705e':t) • 0 • 40 fri • k"J yytGx 2 M I . \ . 2\kgile Siy Ayt J i, t-+ 4(-i s ° .e OF PJ 2070550 • • k _'' '#' a , 2 � 6S 66 61 . . � . . , 65 + 67 ,''''''' ,A111.11.4r —11" 4 ` ,0* *:fir w 'M, :i 1r , ,-,.4• ..., ' ...;47t , , , . 2 t lcl l i e) Pais '7 or U . - 4 i - 1 P'Tf, Zoe o 3 o • . .4:4 -4, ,4 , . . . .. , ,,, -T- J. : - - / , ....„. ..,.....,,.. , ,, 1... . . . ,' ,++ � h - - ';. � a,✓�, E.31 ;'+r , a4 4, , IV ,:„..`;-°,--".4%1,...:1'''Se`-, � e� �#�^ `s.`j p�,,,t" '�" 4 " t t' ..ry ' { µ r, • Fav`4) rs7r r AI ;` a. r ' I . Qk . ; s l III 1, ii lk sr \ k $ ,,,,v..,‘- :*i ,77,k,i,,:iski,,,•1 . ir °1 a � � �; ,.. �• ,,.,,c .., , h.. . 4'-4-....' . w r 4 ..y a, � Mme. a uYL^' p ` f S 2ltQfi , 1, k 41—i cie36 Pa le„ 3 OJ ziD7c 0 • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Sunday, December 03, 2017 6:06 PM To: Schwartz, Guy L(DOA) Cc: Donna Ambruz Subject: RE: SU 41-15RD P&A- Plan Forward PTD-207-088, Sundry#317-537 Guy, As we discussed on the phone after the pressure testing, here is our plan forward for plug#2: 1.) PU RIH W/3-1/2"Tubing String and lightly tag CIBP @ 2,380'. 2.) PU 5'and pimp a balanced plug of cement from 2,375' up to 1,950' (32 bbls). 3.) PU above TOC and clean up our pipe. 4.) Perform braden head squeeze pushing cement into tubing punch holes from 2,255 to 2,559'. Calculate volume pumped for squeeze performing hesitations if necessary. WOC. 5.) Perform pressure test to 1,500 psi on chart for 30 min. 6.) POOH with tubing. 7.) RU Slickline. RIH and tag cement to insure TOC is 100 ft above surface casing shoe. 8.) Move forward to plug#3. Sincerely, Ted Kramer SCANS l ' Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420(Office) 985-867-0665 (cell) From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Sunday, December 03, 2017 12:18 PM To:Ted Kramer Cc: Donna Ambruz Subject: Re: SU 41-15RD P&A- Plan Forward PTD - 207-088, Sundry# 317-537 Ted, You have approval to proceed with your proposed steps below. I'll catch up with you Monday morning . Regards , Guy Schwartz AOGCC Sent from my iPhone On Dec 3,2017, at 11:49 AM, Ted Kramer<tkramer@hilcorp.com>wrote: 1 • • Guy, I have attached the approved sundry for your reference. The CBL called TOC at 2,265' which is 6 feet above the top of the Surface casing shoe. After looking at the log, Hilcorp feels that further testing is needed to insure that the Surface casing shoe is cemented. Hilcorp proposes the following as a plan forward for AODCC's approval: Starting at Step# 15: 15.) PU RIH W/CIBP to 2,380' and set same. POOH W/E-line. 16.) From Surface, close blinds and pressure up on CIBP to 1,500 psi and pressure test on chart for 30 min. 17.) RU E-line, PU RIH W/tubing punches setting the top hole at 2,255'. Punch holes in the 9-5/8"casing string. POOH W/e-line. 18.) Line up pump truck to pump through the 13-3/8"casing valve down and attempt to circulate well down the 9-5/8"X 13-3/8"annulus through the punches and up the 9-5/8" casing. Try to achieve between 1 —2 bpm. 19.) Bleed off all pressure, PU and RIH W 3-1/2"tubing to 2,240' (+/-). Open 13-3/8" casing valve and attempt to circulate down the tubing, out the punches,and up the 9-5/8"X 13- 3/8"annulus to surface. Try to achieve between 1-2 BPM rate. 20.) Close 13-3/8"casing valve,pressure up on tubing to 1,400 psi to try to pump water through the punches down past the Surface casing shoe. Do not exceed 1,400 psi. Note: Original FIT was conducted to 13.8 PPG EMW. 21.) Consult with Operations Engineer with testing results for plan forward. Once we have these results we can devise the plan forward for plugging the well. Just to let you know what Hilcorp is thinking ,there are three possible scenarios: 1.) if we can circulate to surface and fluid is not going south past the shoe,we will start pumping cement and circulate it filling all annuli and cementing the 3-1/2"tubing in the well to surface. 2.) If we cannot circulate to surface and the surface casing shoe will hold pressure, We will set our cement plug from the CIBP @ 2,380' up to 2,150' (+/-). POOH with tubing, set a CIBP @ 160',punch holes in the 9-5/8"cement and circulate cement from 160' to surface. 3.) If the Surface casing shoe is not holding,then we will POOH, PU cement retainer and RIH to 2,240' and set same. Pumping through the retainer displace the equivalent amount of cement from 100' below the Surface casing shoe up to the retainer. We will then un-sting from the retainer and place 100' of cement on top of the retainer. Then pull up hole and set our CIBP at 160' and punch holes and circulate the surface plug. 2 • Hilcorp is asking for approval to conduct steps 15 through 21 above. We will discuss the results at that point with AOGCC and arrive at the best plan to Plug the well. Sincerely, Ted Kramer Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420 (Office) 985-867-0665 (cell) <SU 41-15RD AOGCC 10-403 Approved 2017-11-28.pdf5 3 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ! �j t2161 tT DATE: November 29, 2017 P.I. Supervisor SUBJECT: Well Bore Plug &Abandonment Sterling Unit 41-15RD - FROM: Matt Herrera Hilcorp Alaska LLC Petroleum Inspector Sterling Unit - PTD 2070880 - Sundry 317-537 Section: 9 Township: 5N - Range: 10W Meridian: Seward Drilling Rig: Moncla 401 Rig Elevation: 21 ft - Total Depth: 11634 ft MD - Lease No.: ADL 0002497 - Operator Rep: Bartlewski/Dalton Casing/Tubing Data: Casing Removal: Conductor: 20" - O.D. Shoe@ 79 - Feet(MD) Casing Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2271 - Feet(MD) Casing Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 6281 - Feet(MD) Casing Cut@ Feet Production: 3 1/2" O.D. Shoe@ 11632 . Feet(MD) Casing Cut@ Feet Liner: O.D. Shoe@ Feet Casing Cut@ Feet Tubing: 3 1/2" - O.D. Tail@ 11632 - Feet(MD) Casing Cut@ 3010 _. Feet Plugging Data: Type Plug Founded on Bottom of T.O.C. Depth T.O.C. Mud Weight Pressure (bottom up) Cement Verified? above plug Test Casing - CIBP - 6475 ft MD 6445 ft MD - W/L Tag ! 8.34 ppg - 1800 - Annulus - ! 1750 REMARKS: 3 1/2"CIBP set at 6445 ft. Pressure test CIBP for 30 minutes(1510- 1540 hrs): Initial pressure 1800 psi; Final pressure 1733 psi; 67 psi loss; Pass. Pressure test 3 1/2"x 9 5/8"annulus for 30 minutes(1710-1740 hrs): Initial pressure 1756 psi; Final pressure 1714 psi;42 psi loss; Pass. Dump bail 35 ft of cement on top of CIBP. cc: DNR/DOG Attachments: none rev.4-20-16 2017-1129_Pl ug_Verification_Sterling_41-15R D_mh ti OF 7•4 • • yw\��\I 77;sv THE STATE Alaska Oil and Gas FSM ofLA sKA. Conservation Commission 333 West Seventh Avenue w,hGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T` 0.0;ALAgY'� Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC sagoteJAN U 8 '11)16 3800 Centerpoint Drive, Suite 1400 - Anchorage, AK 99503 Re: Sterling Field, Lower Beluga and Upper Tyonek Gas Pool, SU 41-15RD Permit to Drill Number: 207-088 Sundry Number: 317-537 Dear Mr. Helgeson: 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, Hollis S. French Chair DATED this Zee day of November, 2017. REDcJ S t - i 2017 • • • • RECEIVED STATE OF ALASKA NOV 1 4 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION ATS q (et((1 APPLICATION FOR SUNDRY APPROVALS AOGCC / 20 AAC 25.280 1.Type of Request: Abandon EP Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 - 207-088 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-133-20484-01 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Sterling Unit(SU)41-15RD • Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL002497 ' Sterling Field/Lower Beluga and Upper Tyonek P 1) 11// .0 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,655' ' 9,517 • 6,640' 7,843' —2.544 6,550' —6,800 Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' Surface 2,271' 13-3/8" 2,271' 2,270' 3,090 psi 1,540 psi Intermediate 6,281' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,632' 3-1/2" 11,632' 9,499' 10,160 psi 10,530 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" L-80 11,632' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: December 1,2017 OIL ❑ WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 • 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerahilcorp.com Contact Phone: 777-8420 Authorized Signature: `/ �y Date: i V/`''/(7O COMM ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: „/7 7 Plug Integrity E7 BOP Test NJ Mechanical Integrity Test 0 Location Clearance 0 `/,( 'J/� Other: .,/ 25 66 pSZ, 6j') s 1,- € ,1t. 249 /' (4--&. Post Initial Injection MIT Req'd? Yes 0 No i GSpacing Exception Required? Yes ❑ NoSubsequent Form Required: / 0 •-y 0 rr � 27,3 t lj '2017 APPROVED BY Approved by: glacC J I COMMISSIONER THE COMMISSION Date: t t 12.'6 It-4 R I Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 1 mon s 0 om t ate of approval. ttt chments in Duplicate fr(//, ( ,4 /4./C, r-7 • ti • • Well Prognosis Well: SU 41-15RD He1ioi" 1°'"1"' Date: 11/27/2017 Well Name: SU 41-15RD API Number: 50-133-20484-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: November 29th, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 207-088 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: 1754113 Current Bottom Hole Pressure: —2,450 psi @ 10,157' TVD (Based on shut-in survey 7/8/2013) Maximum Expected BHP: —3,299 psi @ 7,553' TVD (Based on normal grad of btm interval) Max. Potential Surface Pressure: —2,544 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary This well was drilled and completed as a dual gas well in the Beluga and Tyonek in 1998/1999 as SU 41-15. A workover in 2003 pulled the dual completion and ran a single completion in the Beluga.The well was abandoned and sidetracked in July 2007 and drilled as SU 41-15RD.The SU 41-15RD was fracture stimulated using the EXXCAPE completion system in Sept 2007. Additional perfs were added in the Tyonek in Sept 2007. A capstring was installed in Nov 2008 to help with fluid unloading but was pulled in July 2010.The bottom part of the capstring was lost in the well and could not be fished out. The well was perforated in the Lower Beluga and has not produced since April 2015. The purpose of this work/sundry is to P&A the Well. As part of this work, Hilcorp requests a variance from 20 AAC 25.112(b) (1) (A)from setting plugs below and above the perforated intervals. Y p� �;�,� ` Cr 2Z?_ / 7 The top perforated interval is already contained by cement below the interval. Hilcorp proposes setting a CIBP in the tubing,above the top perforation and placing 35'of cement above the CIBP (Note—Escape completion, b' 3-1/2"tubing is cemented in place). Hilcorp will then cut the 3-1/2"tubing above the top of cement(reported to be 5,675' MD)and place a CIBP and 100'of cement on the CIBP. P&A steps to continue from there as described below. Notes Regarding Well: • Fluid level is at 1,390'. Fill was tagged at 9,232'on 8/27/16. Pre Rig E-line Procedure: 1. Provide 24hr notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112.(h). 2. MIRU E-line, PT Lubricator to 2,000 psi Hi 250 Low. a. Tree connection is 6.5" Otis. 2. PU RIH with 2.80"Gauge Ring(GR)to TOC @ 6,640'. 3. PU dump bailer. RIH and dump bail 15'of cement on top of CIBP. (TOC new=6,625'). 06 4. PU RIH with 3-1/2"CIBP to 6,485'. Set Same. 5. Dump Bail 35'of cement on top of CIBP. (TOC=6,450'.) Rev 1 changes made by Chad Helgeson "Dr At. W ell+e-$41 � �, '.��5 Pw Well: SUgnosis 41-15RD Hilearp Alaska,Lr. 4�' Date: 11/27/2017 6. PU jet cutter and RIH and cut tubing at approximately±3,000',cut in the middle of a joint. 7. RIH and attempt to make a 2"cut at the same depth to cut any cable or capillary strings that may be behind the tubing. (Assuming tubing was in tension when cemented in place and may have a gap in the pipe. Escape completions were run with rigid centralizers,so don't expect pipe to shift too much.) 8. RD E-line. Rig Procedure OlkAA5P 14, ) G i S 9. MIRU Moncla 401. 10. Ensure no pressure is on the well,fill well and circulate with 8.4 ppg water or produced water. 11. Set back pressure valve. ND wellhead, NU BOP and test 250 low 2,500 psi high, (hold each ram/valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. (Note: Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness). a. Perform Test. b. Test VBR rams on 3-1/3"test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 12. Ensure well is full of 8.4 ppg water or produced water. 13. POOH with tubing standing back, lay down capillary lines,clamps and centralizers. 3"D ' 14. RU Eline and pressure test lubricator to 2,000 psi. 15. PU RIH W/CBL to verify there is no cement across the 9-5/8" by 13-3/8" shoe at 2,270'. Pressure up 1,000 psi on 9-5/8" casing and log well under pressure. o,ra; If the CBL in Step#15 shows that the cement behind 9-5/8" casing is above the 13-3/8" {3P shoe, PU 9-5/8"CIBP and RIH on 3-1/2"tubing to 2,380'. Set CIBP. Shear off and pick up 2'. Pressure test CIBP to 1,500 psi. Place 200'of cement from 2,380' up to 2,180'across the 13- 5/8"casing shoe. Go to step 23. ( r4 .,r ('u s S 16. If there is no cement across the shoe(assumed) PU 9-5/8"CIBP on eline and RIH and set at 2,380'. 17. PU perforating guns and shoot holes in 9-5/8" casing and establish circulation out of surface casing, attempt to get 2 bpm without exceeding 1,000 psi on 9-5/8" casing. a. If circulation is not achieved to be able to circulate cement up entire outer annulus (13-3/8 x 9-5/8"), prepare for suicide squeeze across Surface shoe and email procedure to AOGCC ' prior to execution. , fit. k. ,Wft ,. 18. RIH with 3-1/2"tubing to top of CIBP 19. RU cementers and place 100ft of cement(7.5 bbls)on top of CIBP PU 100ft above perforations. 20. Pump cement with Bclse od on 3-1 "t /2ubing to circulate cement up surface casing, monitoring returns in annulus onceOP cement is seen at surface stop pumping cement and pull up laying 200ft of cement over perfs. 21. Circulate cement out of tubing. 22. POOH with 3-1/2"tubing and LD 3-1/2", racking back 4 stands of tubing. 23. PU CIBP and RIH and set at 160'. If cement to surface behind 9-5/8" casing. Place Cement from 160'to surface. Note: If suicide squeeze is needed across the Surface shoe, RIH with perf guns, perforate 9- 5/8"casing and establish circulation with back side. RU cementers,circulate cement down the annulus and back to surface inside 9-5/8"casing. WOC. 24. Clean and Clear Rig Floor. Flush all surfaces and lines and clean pits. 25. ND BOPE, NU Dry hole tree. 26. RDMO Rig 401. Rev 1 changes made by Chad Helgeson • • •• Well Prognosis Well: SU 41-15RD HiIcorp Alaska,LL Date: 11/27/2017 Post Rig Abandonment Procedures: 27. Excavate cellar, cut off casing 3' below natural GL. 28. Notify AOGCC 48hrs in advance. 1. N`' 29. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10.The following must be bead-welded directly to the marker plate: AOC16- a. Hilcorp Alaska, b. PTD: 207-088 c. Well Name:SU 41-15RD d. API:50-133:. 30. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 31. Photo document casing cut-off, Welded Plate install, and indication of original ground level. 32. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic Current Wellhead Diagram Rig Workover Change Form Rev 1 changes made by Chad Helgeson • • HILCORP ALASKA 13-5/8" 5M BOPE 13-5/8"5M HYDRIL GK ANNULAR 54-1/8"TALL, FLANGE TO FLANGE f � J fret tm10 13-5/8" 5M CAMERON TYPE U 1.45"W 431/ ( 1 DOUBLE GATE BOP 01 DRESSED 2-3/8" -3-1/2" RAMS IN TOP DRESSED BLIND RAMS IN BOTTOM )73/ 55-7/8"TALL, FLANGE TO FLANGE 13-5/8" 5M DRILLING SPOOL -te® ® W/2 EA. 3-1/8" 5M OUTLETS e"�"th"` 24"TALL, FLANGE TO FLANGE 134"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 14.16 gallon open chamber volume - 17.98 gallon close chamber volume GATE STYLE BOP SPECS: -5.5 gallons to open per gate -5.8 gallons to close per gate -7.0:1 closing ratio -2.3:1 opening ratio . H • • Well Prognosis Well: SU 41-15RD Hilcorp Alaska,LL Date: 11/14/2017 Well Name: SU 41-15RD API Number: 50-133-20484-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: Decemer 1, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 207-088 First Call Engineer: Ted Kramer (907) 777-8420(0) (985)867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: —2,450 psi @ 10,157' TVD (Based on shut-in survey 7/8/2013) Maximum Expected BHP: — 3,299 psi @ 7,553' TVD (Based on normal grad of btm interval) Max. Potential Surface Pressure: —2,544 psi (Based on actual re--rvoir conditions and gas gradient . surface (0.10psi/ft) Brief Well Summary This well was drilled and completed as a dual gas well in the Beluga and Tyon- in 1998/1999 as SU 41-15. A workover in 2003 pulled the dual completion and ran a single completion in th: :eluga.The well was abandoned and sidetracked in July 2007 and drilled as SU 41-15RD.The SU 41-15RD was .cture stimulated using the EXCAPE ' completion system in Sept 2007. Additional perfs were added in the onek in Sept 2007. A capstring was installed in Nov 2008 to help with fluid unloading but was pulled in Jul 2010. The bottom part of the capstring was lost in the well and could not be fished out. The well was pe orated in the Lower Beluga and has not produced since April 2015. The purpose of this work/sundry is to P&A the Well. As part of this work, Hilcorp requests a variance from 20 , •C 25.112 (b) (1) (A)from setting plugs below and 4.--;-------- above the perforated intervals. The top perforated interval is already contained by •ment below the interval. Hilcorp proposes setting a CIBP in the tubing, above the top perforation and piaci : 35'of cement above the CIBP (Note—Escape completion, 3-1/2" tubing is cemented in place) . Hilcorp w. thenut the 3-1/2"tubing above the top of cement (reported to be 5,675' MD) and place a CIBP a . 100's t on the CIBP. P&A steps to continue from there as described below. ' Notes Regarding Well: '%E_, 0). • Fluid level is at 1,390'. Fill was .gged at 9,232' on 8/2'7jJ . 4.44. Pre Rig E-line Procedure: '.,. 1ti 1. Provide 24hr notic- o AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 A 112.(h). 2. MIRU E-line, PT ubricator to 2,000 psi Hi 250 Low. a. Tree nnection is 6.5" Otis. 2. PU RIH with .80" Gauge Ring (GR)to TOC @ 6,640'. 3. PU dump ailer. RIH and dump bail 15' of cement on top of CIBP. (TOC new= 6,625'). 4. PU RIH th 3-1/2" CIBP to 6,485'. Set Same. 5. Dump Bail 35' of cement on top of CIBP. (TOC=6,450'.) 6. RD E-line. . • • Well Prognosis Well: SU 41-15RD Hilcorp Alaska,LL Date: 11/14/2017 Rig Procedure 7. MIRU Moncla 401 set . 8. Insure no pressure is on the well. 9. Set Back pressure valve. ND wellhead, NU BOP and test 250 low 3,000 psi high, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. (Note: Notify AOGCC 24 hours in advance of test to extend the opportunity to witness). a. Perform Test. b. Test VBR rams on 3-1/3""test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE t-: . 10. RU E-line . RIH with Free point tool to determine where tubing is free rote: Excape Well,tubing cemented in place). 11. PU Jet cutter. RIH On E-line to 10' above free point and cut tubi.:. ( Note:TOC reported to be at 5,675'. ) 12. PU on tubing to determine if Capillary lines are cut and fre-. 13. If not free, pick up on tubing 2 ft. and RIH with second J- cutter to just below the tubing and fire to sever capillary lines. 14. Ensure well is full of 8.4 ppg brine. 15. POOH with tubing standing back, lay down Capil :ry lines and clamps. 16. PU RIH W/CBL to determine top of cement b- ind 9-5/8". Pressure up 1,000 psi on 9-5/8" casing and log well under pressure. Determine too of cement behind the 9-5/8" casing. 17. PU RIH with 9-5/8" CIBP on 3-1/2"tubing o 5,670' (+/-). 18. Set CIBP, shear off and pick up 2f +,�,,P��re• ure test CIBP to 1,500 psi. 19. RU Cementers. Place 100' of cemer4 ,. op of CIBP. PU and clean up tubing. POOH. If the CBL in Step# 16 shows that t • certFe ,behind 9-5/8" casing is above the 13-3/8" shoe, PU 9- 5/8" CIBP and RIH on 3-1/2"tubin; to 2,380')Sel CIBP. Shear off and pick up 2'. Pressure test CIBP to 1,500 psi. Place 200'of t-merit from 2 *'`gip to 2,180' across the 13-5/8" casing shoe. Note: If CBL shows that there ' not cement to surfabghind the 9-5/8"casing,then step# 19 will change to shooting hole• in the 9-5/8"casing,establish circulation to surface,then set a cement retainer and sque- ing/circulating cement to surface. 20. RU E-line. Set CIBP at 16'x'. U Tubing to 160'. If cement to surface behind 9-5/8" casing, PU tubing and RIH to 160" . d tag top of CIBP. Place Cement from 160'to surface. If no cement behind 9-5/8" casing, ' H with perf guns, perforate 9-5/8" casing and establish circulation with back side. RU cemen ers, circulate cement down the annulus and back to surface inside 9-5/8" casing. WOC. 21. Clean and Clear Rig Floor. Flush all surfaces and lines and clean pits. 22. ND BOPE, NU D hole tree. 23. RDMO Rig 401. Post Rig Abandonment Pr. edures: 24. Excavate cellar, cut off casing 3' below natural GL. 25. Notify AOGCC 48hrs in advance. 26. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10.The following must be bead-welded directly to the marker plate: 27. Hilcorp Alaska, LLC 28. PTD: 207-088 i • Well Prognosis Well: SU 41-15RD Hilcarp Alaska,LI) Date: 11/14/2017 29. Well Name: SU 41-15RD 30. API: 50-133-20484-01 31. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 32. Photo document casing cut-off and Welded Plate install. 33. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic Current Wellhead Diagram Rig Workover Change Form • . 11 • • SU 41 -15RD SCHEMATIC Pad 43-9 nih•or xlaeha t.t.c 2327' FSL, 437' FEL Sec. 9, T5N, RIOW, S.M. Permit#: 207-088 API#: 50-133-20484-01-001 ,. Surface Casing Property Des: i14 20" K-55 133 ppf PE 13-3/8" K-55 61 ppf BTC AOGCC= ADL-2497 4y; Top Bottom Top Bottom BLM = A-028063 i'.4 MD 0' 79' MD 0' 2,271' KB: 21'AGL (245'KB Elevation) t� 3t it TVD 0' 79' TVD 0' 2,270' X= 314,742.19 Cmt w/1,186 sks of Class G Y= 2,390,034.43 Intermediate Casing 4 9-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N , w "L Top Bottom Production Tubing Long: 151° 01' 51.643" W 14* 11LMD 0' 6,281' 3-1/2" L-80 9.3 ppf EUE Spud: 09:00 hrs 7/07/2007 1 TVD 0' 5,615' Top Bottom TD Reached: 7/20/2007 a i Cmt original well w/2,284 sks of MD 0' 11,632' Rig Released: 6:00 hrs 7/27/07 + class G. TVD 0' 9,499' 1•+ - 8rd with 6.25"OD control line , ` protectors. 8-1/2"hole,Cmtw/ i,;. y, 545 sks(176 bbls)13.5 ppg G cmt Tree cxn =4-1/2"Otis -,4' lead and 1,456 sks(300 bbls),15.8 appg Class G cmt tail. Top of Cement \ 600'MD above 9-5/8"window @ 5,675'MD .. '.', NN 4 IV(' (' 9-5/8"Casing Window / milled from 6,275'to 6,294'(MD) 3.5"CIBP 1-6,650')w/10'cement 5,611'to 5,624'(TVD) *r 1-6,640')TOC A Excape System Details - Fish:20'pert gun with hydrostatic bailer on top.-6800' 6 Excape module system II r -0' _ -Red control line for top 4 modules I° _x 3.5"CIBP w/10'cement -Green control line for bottom 2 modules a -Ceramic flapper valves below each module .., 9,090'TOC_ except for modules 1 &2. ,3 Perfs MD(RKB)(Beluga/Tyonek): '° `" ,, ae ' LB-6,497'-6,514' (Lower Beluga)10/20/16• _ I ' LB-7,255'-7,275' (Lower Beluga)10/6/16 Tagged sand @9,334' a s (4/23/15) LB-7,957'-7,973' (Lower Beluga)10/6/15 . .,LB-9,161'-9,181' (Lower Beluga)4/01/15 • r. w/2.75"Blind Box LB-9,231'-9,251' (Lower Beluga)4/01/15• " �- l me = Carbolite Sand on LB-9,433'-9,444' (Lower Beluga)3/31/15 • - '' ; - um: = packoff plug @ 9,365' LB-9,452'-9,459' (Lower Beluga)3/31/15 . J� - •),"- Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 • - �= = Excape System Details: Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 • me :- = r s 4 Conventional flappers Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 - M +: `4 -Mod 1 &2=no flappers Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 • t -Ceramic flapper valves below Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 ' , each module as follows: 17' - 11,467'-11,480' (Tyonek) 9/22/07• a (2-1/8",6spf,60°phasing) = = Flappers MD(RKB) WD Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 - =1 = ii ` r� Module 6 - 9,951' 7,984' 13' - 11,489'-11,506' (Tyonek) 9/22/07 - L Module 5 - 10,052' 8,074' (2-1/8",6spf,60°phasing) a 31= 1 [' Module 4 - 10,178' 8,181' CI Module 3 - 10,222' 8,228' -- 11111111111111111111111111111 ] TD PBTD 11,655'MD 11,585'MD 3/8" Capillary String (pulled on 7/9/10) Weatherford Float Collar 9,517'TVD 9,460'TVD BHA fish at 10,176'MD 11,584'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe * -12"long 11,621'MD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: J.Kaiser Downhole Revison Date: 4/27/2015 Schematic Revison Date: 11/16/2016 II II SU 41 -15RD PROPOSED /- Pad 43-9 SCHEMATIC Ilileorp Alaska,LLC 2327' FSL, 43T FEL Sec. 9, T5N, R10W, S.M. r P 1160'wl cement surface Permit#: 207-088 API#: 50-133-20484-01-00 Conductor ti+1• Y1.1H•1.1•YY 1•Y'.• Surface Casing r.r r:r•r•r•r.r•r•r•r.r r.r•r) PropertyDes: ti••• ;.;: •1•ti•ti•iii.pi :: ti•ti•'.• 20" K-55 133 ppf PE r r •1,11.1 r r r_�_r r r ,111.1 13-318" K-55 61 ppf BTC AOGCC= ADL-2497 ;Si; ;;{f;{ 7gp Bottom Top Bottom rr r•r•r MD 0' 79' BLM = A-028063 ir4r ''r:f:fMD 0' 2,271' ti+y. 1.PP. TVD 0' 7s' TVD 0' 2,270' KB: 21'AGL (245'KB Elevation) ti% 11::41, X= 314,742.19 •{f{': {rti;tir Cmt W/1,186 sks of Class G r•r .....r-r Intermediate Casing Y= 2,390,034.43 4�r 414141 .,,:q. ;•,,ti 9-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N •,,. -�L L YYY��L ti ti� ti ti{ To Bottom r r,.-.r•r•r r r r•r•r r.'-ie.1' --p Production Tubing •LL L•LL15,•1•U11• r rsr.r•r r r r•r•r r•r".r.r. 3-1/2" L-80 9.3 ppf EUE Long: 151° 01' 51.643" W •ti r4r4r'r::::::PV,,. "`='`• TVD 0' 5,281 Spud: 09:00 hrs 7/07/2007 22-/iTop Bottom TD Reached: 7/20/2007 Cmt original well w/2,284 sks of MD 0' 11,632' Rig Released: 6:00 hrs 7/27/07 class G. TVD 0' 9,499' 8rd with 6.25"OD control line 3.5"CIBP z2,380'w/200'.cement x�" protectors. 8-1/2"hole,Cmt w/ . (:2,180')TOC .!' 545 sks(176 bbls)13.5 ppg G cmt Tree cxn=4-1/2"Otis lead and 1,456 sks(300 bbls),15.8 ppg Class G cmt tail. Top of Cement ` 600'MD above 9-5/8"window . ,� @ 5,675'MD '^'/1�'"- t-6 P /// 3.5"CIBP 16,485'w/35'cemr.,- (16,430')IOC 9-5/8"Casing Window 0.-• A milled from 4ti,. 6,275'to 6,294'(MD) .•ti:. 3.5"CIBP(-6,650')wl 'cement 5,611'to 5,624'(TVD) ` ' (-6,6 )roc 4 i' • Excape System Details -. Fish:20'pert gun with hydrostatic - bailer on top.-6800' - 6 Excape module system �_ " -^;ti_ r _ r •Red control line for top 4 modules t 3.5'CIBP wno cement -(' control line for bottom 2 modules E -9,090'TOC -Ceramic flapper valves below each module - I except for modules 1 &2. = DI Ports MD(RKB)(Beluga/Tyonek): ti LB-6,497'-6,514' (Lower Beluga)10/20/16 +A LB-7,255'-7,275' (Lower Beluga)10/6/16 - TIO = Tagged sand @ 9,334' LB-7,957'-7,973' (Lower Beluga)10/6/15 +.a'' i."= - .• --- (4/23/15) LB-9,161'-9,181' (Lower Beluga)4/01/15 ‘ "' rrflit w!2.75"Blind Box LB 9,231'-9,251' (Lower Beluga)4/01/15 -_ x1 Carbolite Sand on LB-9,433' 9,444' (Lower Beluga)3/31/15 ,° �` - DV: A packoff plug @ 9,365' LB-9,452'-9,459' (Lower Beluga)3/31/15 "?meow,: J -- ." Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 - - Excape System Details: Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 ' ,'; - M Llg�i = -4 Conventional flappers Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 ,-� - ) - -Mod 1 &2=no flappers Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 J -Ceramic flapper valves below Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 r� each module as follows: 17' - 11,467'-11,480' (Tyonek) 9/22/07 (2-1/8",6spf,60°phasing) __ __ �t Flappers MD(RKB) TVD Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 .il■ - Module 6 - 9,951' 7,984' 13' - 11,489'-11,506' (Tyonek) 9/22/07 C _= Module 5 - 10,052' 8,074' (2-1/8",6spf,60°phasing) __ Module 4 - 10,178' 8,181' Module 3 - 10,222' 8,228' TD PBTD 11,655'MD 11,585'MD 3/8" Capillary String (pulled on 7/9/10) Weatherford Float Collar 9,517'TVD 9,460'TVD BHA fish at 10,176'MD 11,584'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe * -12"long 11,621'MD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska I Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle©KOP and Depth: 2.17°!100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58' @ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: Chad Helgeson Downhole Revison Date: 4/27/2015 Schematic Revison Date: 11/27/2017 • ll • • SU 41 -15RD PROPOSED Pad 43-9 SCHEMATIC llilcorp Alaska,LLC 232T FSL, 437' FEL Sec. 9, T5N, R10W, S.M. 3.5"CIBP±160'w/cement to surface Permit#: 207-088 API#: 50-133-20484-01-00 Conductor Surface Casing Property Des: M ,," ;t 20" K-55 133 ppf PE 13-3/8" K-55 61 •..f BTC AOGCC= ADL-2497 t t. Mp Toon Bottom Top Bottom BLM = A-028063 MD 0' 2,271' KB: 21'AGL (245' KB Elevation) ',„ i ; TVD 0� 7s' TVD s 2,270' , Cmt w/ ,186 sks of Class G X= 314,742.19 * a Intermediate Casing Y= 2,390,034.43 9-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N '...-'9' 545 i5M54 ;" Top Bottom •++ rti•ti ;;,�tir%.9." r P •dUCtlOn Tubing r• •r-r• •rwr•r,r•:- MD 0' 6,281' Long: 151° 01' 51.643" W � "� ,p '41?# �� 3-1/2" L-80 9.3 ppf EUE Spud: 09:00 hrs 7/07/2007 $t;`"•• " } "- TVD 0' 5,615' Top Bottom TD Reached: 7/20/2007 ".,•o Cmt original well w/2,284 sks MD 0' 11,632' Riq Released: 6:00 hrs 7/27/074 of class G. TVD 0' 9,499' 8rd with 6.25"OD control line :,.-4-kJ,:r...r w; 3.5"CIBP±2,380'w/200'ceme, ° protectors. 8-1/2"hole,Cmt w/ (±2,180')TOC 545 sks(176 bbls)13.5 ppg G cmt Tree cxn =4-1/2"Otis lead and 1,456 sks(300 bbls),15.8 et ppg Class G cmt tail. a , .. 4 Top of Cement "Yr °, I + 600'MD above 9-5/8"window '. 3.5"CIBP±S,. 0'w/100'cement 's (± 70')TOC @5,675'MD ..t }P * \ 3.5"CIBP±6,485'w135'cement (±6,450')TOC 9-5/8"Casing Window d �/ milled from . I' 6,275'to 6,294'(MD) . � 3.5"CIBP(-6,650')w125'cement 5,611'to 5,624'(TVD) . /r (-6,625')TOC Excape System Details , 5.`'+a '` Fish:20'pert gun with hydrostatic bailer on top.-6800' 6 Excape module system r �� -Red control line for top 4 modJLExcape s I, ��� 1 P€ . -Green control line for bottom odules " • � _ 3s"CIBP w/1o'cement -Ceramic flapper valves belowh module i s,o90 TOC except for modules 1 &2. .�Perfs MD(RKB)(Beluga/Tvon : t*r '' ,"'� ti , °"LB-6,497'-6,514' (Lower Belu10/20/16 �•.`�LB-7,255'-7,275' (Lower Belu10/6/16 '-` ,, s E`yTagged sand @ 9,334' LB-7,957'-7,973' (Lower Belu10/6/15 is• ' - (4/23/15) LB-9,161'-9,181' (Lower Belu4/01/15 ' x ' w/2.75"Blind Box LB-9,231'-9,251' (Lower Bel )4/01/15 / , .. `- Carbolite Sand on LB-9,433'-9,444' (Lower Bel )3/31/15 / .`rt;s?" �°• ) y packoff plug @ 9,365' LB-9,452'-9,459' (Lower Bel )3/31/15 k• "" 77 ,g ;!Mod 6 - 9,930' - 9,940' (Be ) 9/11/07 - ;: .3° -y- Excape System Details: Mod 5 - 10,031'-10,041' (Bel ) 9/11/07 = •- ( 4 Conventional flappers Mod 4 - 10,157-10,167 (Bel ) 9/11/07 y; -r -Mod 1 &2=no flappers Mod 3 - 10,201'-10,211' (Bel ) 9/11/07 -Ceramic flapper valves below Mod 2 - 10,571'-10,581' (Bel ) 9/10/07 ) each module as follows: 17' - 11,467'-11,480' (Tyok) 9/22/07(2-1/8",6spf,60° sing) >c _ , . Flappers MD(RKB) TVD Mod 1 - 11,479'-11,527' (Tyk) 9/12/07 >c �' cModule 6 9,951' 7,984' 13' - 11,489'-11,506' (Tyok) 9/22/07 -I E Module 5 - 10,052' 8,074' (2-1/8",6spf,60° sing) �t Module 4 - 10,178' 8,181' ig - !) Module 3 - 10,222' 8,228' TD PBTD Weatherford Float Collar 11,655'MD 11,585'MD 3/8" Capillary String (pulled on 7/9/10) 9,51T TVD 9,460'TVD BHA fish at 10,176'MD 11,584'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe -12"long 11,621'MD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: Donna Ambruz Downhole Revison Date: 4/27/2015 Schematic Revison Date: 11/8/2017 • • HILCORP ALASKA 11" 5M BOPE 11" M HYDRILGK ANNULAR 47-7/ TALL, FLANGE TO FLANGE Grfn On 11" 5M CAMERON TYPE U 4144,14tp 144,, DOUBLE GATE BOP o d' M1 DRESSED W/VARIABLE RAMS IN TOP ® F DRESSED W/BLIND RAMS IN BOTTOM } / 54-1/2"TALL, FLANGE TO FLANGE 11" 5M DRILLING SPOOL ® W/2-1/16" &4-1/16" 5M OUTLETS R"ft"ft' 24"TALL, FLANGE TO FLANGE —127"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: -8.08 gallon open chamber volume -9.81 p Hon close chamber volume GAT STYLE BOP SPECS: -3 gallons to open per gate - .5 gallons to close per gate - .3:1 closing ratio 2.5:1 opening ratio • • Sterling Unit SU 41-15RD Current mewl,A .,IAA: 11/09/2017 Sterling Pad False hanger neck,Vetco SU 41-15RD Gray,11"10M x 3"CIW 20X133/8X95/8X3Y: Type H BPV profile, No Lift Threads Tree cap,Otis,3 1/16 10M FE X 6 Y.Otis Quick Union Co Valve,Swab,VG-300, y�p4 Se 4+ '4 oQ 3 1/16 10M FE,HWO, dill III Jam,1(0100 610 ��o1ya�� DD trim �.. ',, OSP�,y\1 -.11'Page �tl i"itiew ' O •Sr R Valve,Upper Master, 1a,� VG 300,3 1/16 10M FE, ��c,ir. HWO,DD trim O \�l Valve,Master,VG-300, 0)`', 3 1/16 1GM FE,HWO, ., .lif DD trim O 1 Adapter,Vetco,11"10M Escape lines x 2 ,111, stdd X 3 1/16 1OM stdd top, ---- prepped f/6 W'extended neck \ (— Tubing head,Vetco-CWC-T, t1 11"5M stdd bottom X -■�tt:1 1 ! 'I�mIGi J•= 11"10M FE top,w/ 2-4 1/16 10M SSO r F 7.11I Ally \ Isolation sleeve _ -• i 1 , off•= 95/8x31/2 annulus J Casing spool,Vetco-CWC-F, ` 13 5/8 5M bottom X 11 SM _ 40•411' 1" ,y) top,2-2 1/16 SM SSO •wit , t Casing head,Vetco-CWC-F, I �..�µ 11 13 3 8 x 9 5 8 annulus 13 5/8 head, /8"sow,w/ / / 2-2 1/16 5M SSO �� 1.1161 D @ X75' ,r J 8 r_.. Na� J 13 3/8" 9.625" it_ 1I 3.5" . • . CD k � co 0 / � � 2 7 a Q e c 2 171 E 002 U2 �ell. a) « E ® 03 2 / § 10. co ff « = 0 Ch / _a � �� fE> = � c\ (. a_ 0- _ CU el � ■ ■ I& $ � 2 aCO CO Ct CI G CISC t �Z • CO Ce 0CD � L. � / OS 0 > CI 2 8 O Ce k c 0k - C � � Co = 00 g % / ■ f0 CD C J § < _ CD E E t(r) / 0 2 § / � � /a \ / a) g a) _ o ) cut)s k -0 = 2 cm > \ 0 _ @ o § � g 0 c. oG « \ o 0 o. .x x 0 a) 2 CC: Q ■ R * R m / x c ° 0 = x 2 / § 2 O) 0 / > « iZ - C ' \ U k : U ng Q ■ > t3 U C 2 f 0 Ca C. / 2 2 CO Q I U) 2_0-1-Q15'6 ti el Nolan Hilcorp Alaska, LLC j—1 ? 1 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hile+irp:thaka,1.l.i: ' i‘ 4, i Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED ', ;J \\ t /20oG .moi M K BENbE DATE 11/18/16 AC0-0 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AKi �I' ' ,1,r 99501 DATA TRANSMITTAL NOV 22 2013 A A SU 41-15RD Prints Prints: .NNED r Wa P,,, Plug Setting Record 5" ��� ` Perforation Record 5" Plug Setting Record 5" Perforation Record 5" CD PERF_050CT16 11/18/2016 2:21 PM Fie folder .44 PLUG_030CT16 11/18/2016 2:21 PM Fie folder 11,PLIG_PERF_190Cr16 11/18/2()16 2:21 PM Fie folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received8 : // 6,4rtgeetDate: ullK2A2.42 )V STATE OF ALASKA ALARA OIL AND GAS CONSERVATION COMItION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations IJ Fracture Stimulate LI Pull Tubing LJ Operations shutdown LI Performed: Suspend ❑ Perforate 111 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 207-088 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-13-20484-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL002497 Sterling Unit(SU)41-15RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Sterling Field/Lower Beluga and Upper Tyonek Undefined Gas 11.Present Well Condition Summary: j Total Depth measured 11,655 feet Plugs measured 9,365 „ f� L 0 V true vertical 9,517 feet Junk measured 10,174 feet NOV 1 '? 2616 Effective Depth measured 9,365 feet Packer measured N/A feet true vertical 7,483 feet true vertical N/A fe Cid„ Casing Length Size MD ND Burst Collapse Structural Conductor 79' 20" 79' 79' Surface 2,271' 13-3/8" 2,271' 2,270' 3,090 psi 1,540 psi Intermediate 6,281' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,632' 3-1/2" 11,632' 9,499' 10,160 psi 10,530 psi Liner Perforation depth Measured depth See Attached Schematic t> ttis R .w JLTJG True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" L-80 11,632'MD 9,503'ND Packers and SSSV(type,measured and true vertical depth) 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 20 50 Subsequent to operation: 0 0 0 15 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas E WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 316-479 Contact Joe Kaiser-777-8393 Email jkaiserehilcorp.com Printed Name Chad Helgeson� Title Operations Manager Signature / /��% �7�! Phone 907-777-8405 Date VI(ffi 4, f 16 /0/' // Form 10-404 Revised 5/2015 jr� c z-RBDMS L NOV�2 8 2016 Submit Original Only • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD E-Line 50-133-20484-01 207-088 10/3/16 10/21/16 Daily Operations: 10/03/2016- Monday PTW and JSA.Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. TP- 50 psi. RIH w/2.28" OD magna range plug and tie into perf log sent from town. Ran correlation log. Spot and set plug at 9,100'. Lost 100 lbs line wt when plug set. Pick up 30' and go back down and tag plug. POOH. Plug set with 50 psi on tubing. Setting tool looked good. MU 2" x 40' positive displacement bailer and fill with water and 3.7 gals of cement. RIH and dump 10' of cement on top of plug at 9,100'. Lost 50 lbs of wt when bailer dumped. POOH. Cement in place at 1440 hrs. Good dump. Rig down e-line for standby, secure well and wait on cement. 10/04/2016-Tuesday PTW and JSA. Spot equipment and rig up lubricator. Depth counter electric cable got caught in drum chain and pulled apart. Repair cable (30 min). PT to 250 psi low and 3,000 psi high.TP-0 psi. RIH with sample bailer and tag TOC at 9,080' KB WLM. POOH. RIH with 3-1/2" swab cups and swabbed well from surface to 6,036' KB WLM.After last swab waited 20 min and went back down and tagged fluid level at 6,036' KB WLM. POOH. Strapped tank and showed approx. 57 barrels but there is sand in tank and couldn't get accurate strap. Rig down lubricator and secure well. Will perforate tomorrow morning. 10/05/2016-Wednesday PTW and JSA. Pressure test to 250 psi low and 3,000 psi high. RIH with 2-1/2" x 16' HC, 6 spf, 60 degree phase and tie into partial log sent from town. Found fluid level at 6,028'. Run correlation log and send to town. Get ok to perf from 7,957' to 7,973'. Spotted gun and fired with 54 psi on Scada (with Scada at 52 psi well has 0 psi on it). Pressure went to 55 psi and after 5 min it was 56 psi. POOH.TP-59 psi. Ran in hole with GPT tool and found fluid level at 6,008'. Log showed water came up hole 20".TP read 54 psi. Log showed warming at perfs. Waiting on guns. RIH with 2-1/2" x 20' HC, 6 spf, 60 degree phase and tie into partial log sent from town. Found fluid level at 6,000'. Run correlation log and send to town. Get ok to perf from 7,255' to 7,275'. Spotted gun and fired with 53 psi on Scada (with Scada at 52 psi well has 0 psi on it). Pressure did not increase. Pulled up hole with eratic line wts and line stopped at 6,810' top and 6,838' bottom of tool. Called town and discussed. Worked tools up and down adding 50 lb increments to wt from 1,800 lbs to 2,700 lbs and pulled out of rope socket at 2,700 lbs.TP-53 psi. Rig down lubricator and secure well. 10/07/2016- Friday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high.TP-75 psi. RIH w/2"JDC to 6,667' KB. Work tools but could not latch. POOH.JDC not sheared. RIH w/2.25" LIB to 6,667' KB. Hit down on obstruction and POOH. No impression on LIB. Made 3 runs with 2.25" x 8' pump bailer from 6,667' to 6,678' KB. Got 1 cups of clay and soupy liquid mud. Made 3 runs with 2" x 5' DD bailer from 6,678'to 6,686' KB. Got out 1 cup clay, trace of flecks of coal and thick mud like fluid. Made 2 runs with 2.5" x 5' DD bailer from 6,684' to 6,690' KB. Got out full bailers of liquid. Made 1 run with 1.75" x 6' DD bailer from 6,690' to 6,693' KB. Got out liquid. Made 1 run with 2.5" x 8' pump bailer from 6,693' to 6,694'. Got out soupy liquid. Rig down lubricator and secure well. ® • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SU 41-15RD E-Line 50-133-20484-01 207-088 10/3/16 10/21/16 Daily Operations: 10/19/2016-Wednesday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high.TP-0 psi. RIH with 2.3" OD magna range plug and tie into perf log. Run correlation log and send to town. Get ok to set plug at 6,650'. Spot plug and set plug. Lost 100 lbs line wt when set. Picked up 30' and went back and tagged plug. POOH. Everything looks like good set. RIH w/2" x 30' positive displacement dump bailer with 3.6 gals of cement (10')and tie into plug log. Tag plug at 6,650'. Pick up and dumped 10' of cement on top of plug. Est TOC is 6,640' and cement in place at 1330 hrs. POOH. Good dump. Rig down lubricator and secure well. WOC. Plan is to start swabbing in the morning at 0700 hrs. 10/20/2016-Thursday PTW and JSA. Rig up lubricator, PT to 250 psi low and 3,000 psi high. RIH w/2.70' cent and sample catcher and tag TOC at 6,639'. Tagged hard. POOH RIH w/swab cups and swab fluid from 200' down to 4,000'. POOH and wait 15 min. Run back in hole and tag fluid at 4,020'. POOH. Rig down slickline. Rig up Halliburton E-line. PT 250 psi low and 3,000 psi high. RIH with 2-1/2" x 17' HC, 6 spf, 60 degree phase and tie into partial log sent from town and tagged at 6,639'. Found fluid level at 4,006'. Run correlation log and send to town. Get ok to perf from 6,497' to 6,514'. Spotted gun and fired with 0 psi on tubing. Saw no pressure increase after shot.TP was 2.3 psi after 20 min. POOH. All shots fired. Rig down lubricator and turn well over to field. 10/21/2016- Friday Arrive @ Sterling Pad. PJSM and review JSA. TR- Inspect location and spot equipment. Rig up .160" slickline. Pressure test lubricator 250 psi to 3,000psi. 30 psi on well. RIH W/2.75" blind box.Tag @ 6,589' KB. Fluid @ 2,004' KB. POOH. OOH w/tools. RIH w/tandem 3-1/2" swab cups. See job log on tab below. Decision made to end job. Approximately 44.5 bbls in flowback tank swabbed from well. Swabbed to 6,411' KB. No gas returns. Past 6,000' the well went on a vacuum after swabbing. Rig down slickline and turn well over to field. HLB perf tools left in well on 10-6-16: 1-7/16" cable head,Titan contact sub, 1-11/16" HLB GR/CCL tool, Geodynamics wireline top sub, Geodynamics bull plug. 11 SU 41 -15RD SCHEMATIC ink Pad • , 437 �t , ,,l,t,k,t-t.l.t. 232T FSL437' FEL Sec. 9, T5N, R10W, S.M. MEr#: 207-088 API#: 50-133-20484-01-00 j i I Conductor Surface Casing Property Des: i 20" K-55 133 ppf PE 13-3/8" K-55 61 ppf BTC AOGCC= ADL-2497 Bottom Top Bottom BLM = A-028063 MD o' 79' MD 0' 2,271' ND 0' 79' TVD 0' 2,270' KB: 21'AGL (245'KB Elevation) X= 314,742.19 ,, Intermediate Casing Cmt w/1,186 sks of Class G Y= 2,390,034.439-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N Tom Bottom Production Tubing Long: 151° 01' 51.643" W • MD 0' 6,281' 3-1/2" L-80 9.3ppf EUE Spud: 09:00 hrs 7/07/2007 TVD 0' 5,615' Top, Bottom TD Reached: 7/20/2007 :1 Cmt original well w/2,284 sks of MD 0' 11,632' Rig Released: 6:00 hrs 7/27/07 y class G. TVD 0' 9,499' 8rd with 6.25"OD control line es. 8-1/2"hole,Cmtw/ 545protsksctor(176 bbls)13.5 ppg G Tree cxn=4-1/2"Otis lead and 1,456 sks(300 bbls),15.8cmt ppg Class G cmt tail. Top of Cement 600'MD above 9-5/8"window @ 5,675'MD 9-5/8"Casing Window milled from 6,275'to 6,294'(MD) y 3.5"CIBP(-6,650')w110'cement 5,611'to 5,624'(TVD) '?./ (-6640')roc N. Excape System Details T ..4: Fish:20'perf gun with hydrostatic bailer on top.-6800' - 6 Excape module system t 1r 11 �ti - -Red control line for top 4 modules S , , -Green control line for bottom 2 modules . - _ 3.5"clap who'cement -Ceramic flapper valves below each module T - -9,090'TOC except for modules 1 &2. = h! s Perfs MD(RKB)(Beluga/Tyonek): LB-6,497'-6,514' (Lower Beluga)10/20/16 5 •.- _ _ - LB-7,255'-7,275' (Lower Beluga)10/6/16 i� = LB-7,957'-7,973' (Lower Beluga)10/6/15 , t' _ _ 1..• Tagged sand @ 9,334' • - (4/23/15) LB-9,161'-9,181' (Lower Beluga)4/01/15 ` LB-9,231'-9,251' (Lower Beluga)4/01/15 __ g;.47- _ Cwrboli BlindSBox ` , '1%4 �' -: rip. Carbolite Sand on LB-9,433'-9,444' (Lower Beluga)3/31/15 .y-'+ -'" = A0 LB-9,452'-9,459' (Lower Beluga)3/31/15 - h• packoff plug @ 9,365' Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 - - Excape System Details: Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 mu = ht 4 Conventional flappers Mod 4 - 10,157'-10,167' (Beluga) 9/11/07I - ) - -Mod 1 &2=no flappers Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 .1 -Ceramic flapper valves below T� each module as follows: 17' - 11,467'-11,480' (Tyonek) 9/22/07 - its (2-1/8",6spf,60°phasing) _ _ _ j Flappers MD(RKB) TVD Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 _ -------- Ill = Module 6 - 9,951' 7,984' 13' - 11,489'-11,506' (Tyonek) 9/22/07 - Module 5 - 10,052' 8,074' (2-1/8",6spf,60°phasing) = Module 4 - 10,178' 8,181' IffiI Module 3 - 10,222' 8,228' TD PBTD 11 Weatherford Float Collar 11,655'MD 11,585'MD 3/8" Capillary String (pulled on 7/9/10) 9,517'TVD 9,460'TVD BHA fish at 10,176'MD 11,584'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe -12"long 11,621'MD Well Name&Number Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: J.Kaiser Downhole Revison Date: 4/27/2015 Schematic Revison Date: 11/16/2016 • yOF Ty • • I THE STATE Alaska Oil and Gas of ACKA Conservation Commission x=:_ = `; 333 West Seventh Avenue s GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p �Q, Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager FEB! 1 On' (! ' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Sterling Field, Lower Beluga and Upper Tyonek Undefined Gas Pool, SU 41-15RD Permit to Drill Number: 207-088 Sundry Number: 316-479 Dear Mr. Helgeson: 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, CY-4 / 14- -t-i5/-7 Cathy y. Foerster Chair DATED this zipday of September, 2016. RBDMS \ i SEP 2 6 2016 • • RECEIVED • STATE OF ALASKA SEPP ?�� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑., • Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑✓ • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Dell Number: Exploratory 0 Development ❑✓ • 207-088 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20484-01 . 7.If perforating: 8.Wel Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 583 Sterling Unit(SU)41-15RD Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): uyk(e_A",z '44 ADL002497 • Sterling Field/Lower Beluga and Upper Tyonek.Pr9.{Federel) 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,655' • 9,517' • 9,365' 7,483' 2,544 psi 9,365' 10,174' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' Surface 2,271' 13-3/8" 2,271' 2,270' 3,090 psi 1,540 psi Intermediate 6,281' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,632' 3-1/2" 11,632' 9,499' 10,160 psi 10,530 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 1-80 11,632' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A NIA,WA;WA,NIA 12.Attachments: Proposal Summary Q Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: September 30,2016 OIL ❑ WINJ ❑ WDSP1 ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser(dzhilcorD.com Printed Name ,,, Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date 'I/(p/t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: br' • q la LI I ic, Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No U Subsequent Form Required: /0— '/a 't/ RBDMS L' SEP 2 6 2016 a/67 /4.e_ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: q_ 2,3--/� �'`i'Z4'1t:),ER j � A Submit Form Form 10-403 Revis 11/2015 O li r/j"$, lid for 12 months from the date of approval. Attachments it Duplicate • S Well Prognosis Well: SU 41-15RD • epi`°'°Alaska, tI ,ka' "i.c Date:9/16/2016 Well Name: SU 41-15RD API Number: 50-133-20484-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: September 30th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 207-088 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,450 psi @ 10,157' TVD (Based on shut-in survey 7/8/2013) Maximum Expected BHP: — 3,299 psi @ 7,553' TVD (Based on normal grad of btm interval) Max. Allowable Surface Pressure: —2,544 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary This well was drilled and completed as a dual gas well in the Beluga and Tyonek in 1998/1999 as SU 41-15. A workover in 2003 pulled the dual completion and ran a single completion in the Beluga. The well was abandoned and sidetracked in July 2007 and drilled as SU 41-15RD. The SU 41-15RD was fracture stimulated ✓ using thy,EXCAPE completion system in Sept 2007. Additional perfs were added in the Tyonek in Sept 2007. A capstring was installed in Nov 2008 to help with fluid unloading but was pulled in July 2010.The bottom part of the capstring was lost in the well and could not be fished out.The well was perforated in the Lower Beluga and has not produced since April 2015. The purpose of this work/sundry is to add perforations to the Lower Beluga interval. Notes Regarding Well: • Fluid level is at 1,390'. Fill was tagged at 9,232' on 8/27/16. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 6.5" Otis. 2. MU 3-1/2" CIBP. RIH and set CIBP at^'9,100. POOH. RD E-line. 3. RU Slickline. Swab fluid down to—6,000'. Confirm depth with Engineer prior to concluding swabbing operations. 4. MU Bailer. RIH and dump bail 35'of cement on CIBP.TOC^'9,065'. POOH. 5. RU 2-1/2" 6 spf HC(will make 4 separate runs, each interval only 6 spf shot density). 6. RIH and perforate the Lower Beluga in the following intervals: Zone Top (MD) - Btm (MD) Top (TVD)- Btm (ND) FT SPF Lower Beluga 6,497' -6,514' 5,762'—5,773' 17' 6 Lower Beluga 7,210' -7,218' 6,167'—6,172' 8' 6 Lower Beluga 7,255'-7,275' 6,192'—6,203' 20' 6 Lower Beluga 7,957'-7,973' 6,575'—6,583' 16' 6 a. Bleed tubing pressure as require by Engineer. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL log dated 9/6/07. (Tie-in log depth match above depths). s i Well Prognosis Well: SU 41-15RD Hili ui i ii: Date:9/16/2016 d. Record tubing pressures before and after each perforating run. e. Proposed interval is in the Lower Beluga/Tyonek PA. Perfs are located in ADL-002497. f. Distance to nearest well open in same sands= None. g. Distance to nearest well =4,664'to SU 32-09 (PTD 198-042) in the Upper Beluga. h. Spacing allowance is based on CO 583.Allows well within 1,500'of section line. 7. RD E-line. 8. Turn well over to production. E-line Procedure (Contingency):If any zone produces sand and/or water. 9. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 10. RIH and set 3-1/2" CIBP at depth ^'10' above zone. 11. RU Slickline. Swab fluid down to depth approved by Engineer. 12. RIH with bailer assembly. Dump bail cement. POOH. Wait 24hrs for cement to cure. a. If spacing between Top of CIBP and 5'below bottom of proposed perf interval allows, 35'of cement must utilized to meet BLM requirements. Otherwise, dump bail sufficient cement from Top of CIBP and within 5'of proposed perf interval. 13. Continue with Step 5 above. Attachments: 1. Actual Schematic 2. Proposed Schematic • Ili • SU 41 -15RD ACTUAL Pad 43-9 SCHEMATIC llilcorp Alaska,LLA: 2327' FSL, 437' FEL Sec. 9, T5N, R1 OW, S.M. Permit#: 207-088 Conductor 20" K-55 133 ppf PE API#: 50-133-20484-01-00 Top Bottom Property Des: MD 0' 79' AOGCC= ADL-2497 TVD o' 79' BLM = A-028063 KB: 21'AGL (245'KB Elevation) X= 314,742.19 11 Surface Casing 13-3/8" K-55 61 ppf BTC Y= 2,390,034.43 Top Bottom Lat: 60° 32' 14.914" N MD 0' 2,271' Long: 151° 01' 51.643" W TVD 0' 2,270' Spud: 09:00 hrs 7/07/2007 Cmt w/1,186 sks of Class G TD Reached: 7/20/2007 Tagged fill @ 9,232'KB(8/27/16) Rip Released: 6:00 hrs 7/27/07 wi 2.61"LIB Intermediate Casing Tagged sand @ 9,334' 9-5/8" L-80 40 ppf BTC (4/23/15) Top Bottom Tree cxn 4-1/2"Otis - w/2.75"Blind Box MD 0' 6,281' Carbolite Sand on TVD 0' 5,615' packoff plug @ 9,365' Cmt original well w/2,284 sks of class G. Top of Cement ' 600'MD above 9-5/8"window , @ 5,675'MD Production Tubing 3-1/2" L-80 9.3 ppf EUE Top Bottom 9-5/8"Casing Window MD 0' 11,632' milled from _ TVD 0' 9,499' 6,275'to 6,294'(MD) / 8rd with 6.25"OD control line protectors. 5,611'to 5,624'(TVD) . i� f• / 8-1/2"hole,Cmt w/545 sks(176 bbls)13.5 ppg 'fr ; // Class G cmt lead and 1,456 sks(300 bbls) _ ,� {" 15.8 ppg Class G cmt tail. Excape System Details - 6 Excape module system i �; -Red control line for top 4 modules .' - I ilk I_ Excapeon System Details: -Green control line for bottom 2 modules f R, ::- 4 Conventional flappers -Ceramic flapper valves below each module = -Mode1 &2=no flappers except for modules 1 &2. x 111 I each Ceramic module flapper volves below each as follows: Perfs MD(RKB)(Beluga/Tyonek): t .. • Flappers MD(RKB) TVD •I - Module 6 - 9,951' 7,984' LB-9,161'-9,181' (Lower Beluga)4/01/15 t 1t• Module 5 - 10,052' 8,074' LB-9,231'-9,251' (Lower Beluga)4/01/15 - Module 4 - 10,178' 8,181' LB-9,433'-9,444' (Lower Beluga)3/31/15 '-- , - Module 3 - 10,222' 8,228' LB-9,452'-9,459' (Lower Beluga)3/31/15 '- ' _ Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 `Et1 Module 2 - NA Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 I iI. --1 IJ , 1e --7-.. od 4 - 10,157'-10,167' (Beluga) 9/11/07 Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 -' m I __ Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 t--- -.i T 7 17' - 11,467'-11,480' (Tyonek) 9/22/071 (2-1/8",6spf,60°phasing) Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 = L, 13' - 11,489'-11,506' (Tyonek) 9/22/07 = -' (2-1/8",6spf,60°phasing) = T ' J L = 1 3/8" Capillary String (pulled on 7/9/10) c BHA fish at 10,176'MD Weatherford Float Collar In * FCV&2.25"centralizer&Spear left in well 11,584'MDJ____1 * -12"long Weatherford Float Shoe 11,621'MD TD PBTD 11,655'MD 11,585'MD 9,517'TVD 9,460'TVD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD). 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58'@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: J.Kaiser Downhole Revison Date. 4/27/2015 Schematic Revison Date: 9/9/2016 SU 41 -15RD PROPOSED Pad 43-9 SCHEMATIC Hilcorp Alaska,LLC 2327' FSL, 43T FEL Sec. 9,T5N, R1 OW, S.M. :ems 1--1`:. API#: 50-133-20484-01-00 Conductor Surface Casing Property Des: 20" K-55 133 ppf 13-3/8" K-55 61 ppf BTC AOGCC= ADL-2497 k, S' MD Top Bottom Top Bottom BLM = A-028063 TVD o' 7s' MD 0' 2,271' KB: 21'AGL (245'KB Elevation) C TVD 0' 2,270' X= 314,742.19 r4 I Intermediate Casing Cmt w/1,186 sks of Class G Y= 2,390,034.43 9-5/8" L-80 40 ppf BTC Lat: 60° 32' 14.914" N Top Bottom Production Tubing Long: 151° 01' 51.643" W MD 0' 6,281' 3-1/2" L-80 9.3 ppf EUE Spud: 09:00 hrs 7/07/2007 5t' TVD 0' 5,615' Top Bottom TD Reached: 7/20/2007 "'s 1 Cmt original well w/2,284 sks of MD 0' 11,632' Rig Released: 6:00 hrs 7/27/07 A class G. TVD 0' 9,499' 8rd with 6.25"OD control line protectors. 8-1/2"hole,Cmtw/ ,,;1, 545 sks(176 bbls)13.5 ppg G cmt Tree cxn=4-1/2"Otis •4 lead and 1,456 sks(300 ..I bbls),15.8 ppg Class G cmt tail. ) . Top of Cement 600'MD above 9-5/8"window @ 5,675'MD 9-5/8"Casing Window milled from 4----_ Proposed Perforations 6,275'to 6,294'(MD) , 5,611'to 5,624'(TVD) �,- N Excape System Details T ' ' - 6 Excape module system -Red control line for top 4 modules .1 tr ,» 1., , -Green control line for bottom 2 modules I _ -- ' Proposed Ceramic flapper valves below each module �, 3.5"CIBP(-9,100')w/35' except for modules 1 &2. I cement(--9,065')TOC Perfs MD(RKB)(Beluga/Tyonek): LB-6,497'-6,514' (Lower Beluga)Proposed _ >� { LB-7,210'-7,218' (Lower Beluga)Proposed = Tagged sand @ 9,334' LB-7,255'-7,275' (Lower Beluga)Proposed °° (4/23/15) LB-7,957'-7,973' (Lower Beluga)Proposed ' ' Alli r, 1 r 1 w/2.75"Blind Box LB-9,161'-9,181' (Lower Beluga)4/01/15IF .1 T� Carbolite Sand on LB-9,231'-9,251' (Lower Beluga)4/01/15 _----- Lg° packoff plug @ 9,365' LB-9,433'-9,444' (Lower Beluga)3/31/15 r Jl LB-9,452'-9,459' (Lower Beluga)3/31/15 g-. = --- Excape System Details: Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07Imoa Di =lc -4 Conventional flappers Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 1- 1 - -Mod 1 &2=no flappers Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 , -Ceramic flapper valves below Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 - each module as follows: Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 - a 17' - 11,467'-11,480' (Tyonek) 9/22/07 = = J Flappers MD(RKB) TVD (2-1/8",6spf,60°phasing) Module 6 - 9,951' 7,984' Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 - ++3 - Module 5 - 10,052' 8,074' 13' - 11,489'-11,506' (Tyonek) 9/22/07 = _ C.A - Module4 - 10,178' 8,181' (2-1/8",6spf,60°phasing) Module 3 - 10,222' 8,228' TD PBTD li, Float Collar 11,655'MD 11,585'MD 3/8" Capillary String (pulled on 7/9/10) Weatherford 1 ,54'MD 9,517'TVD 9,460'TVD BHA fish at 10,176'MD * FCV&2.25"centralizer&Spear left in well Weatherford Float Shoe -12"long 11,621'MD Well Name&Number Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish:_ Kenai Peninsula Borough State/Prov. Alaska Country: USA Perforations(MD)-. 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: J.Kaiser Downhole Revison Date: 4/27/2015 Schematic Revison Date: 9/9/2016 STATE OF ALASKA AL ..,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate El Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool El Repair Well LI Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 207-088 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-13-20484-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL002497 Sterling Unit(SU)41-15RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Sterling Field/Lower Beluga ,-ryonttG U+1/414ntcl Cz?S 11.Present Well Condition Summary: Total Depth measured 11,655 feet Plugs measured N/A fedt u E V E D true vertical 9,517 feet Junk measured 10,174 feet MAY 2 0 2015 Effective Depth measured 11,585 feet Packer measured N/A feet true vertical 9,460 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate Production Liner SCAINtle _,i Ji ` 7 J1�> Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" L-80 11,632'MD 9,503'ND Packers and SSSV(type,measured and true vertical depth) 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 0 165 Subsequent to operation: 0 0 0 0 1003 14.Attachments: 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❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 315-114 Contact Stan Porhola Email sporholac hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date 2,0 7P-/./5- RBDMS 3 MAY 2 9 2015 Form 10 404 Revised 5/2015 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SU 41-15RD 50-133-20484-01 207-088 3/31/15 4/20/15 Daily Operations: 03/31/2015 -Tuesday PTW and JSA. Mobe and spot equipment. Rig up and arm gun. PT lubricator to 250 psi low and 3,000 psi high.TP- 1,425 psi. RIH with 2-1/2" x 11' with 2-1/2" x 8' blank x 2-1/2" x 7' Connex HC, 4 spf, 60 deg phase perf gun and tie into Expro CBL log dated 09/05/07. Run correlation log and send to town. Get ok to perf from 9,433' to 9,444' and 9,452' to 9,459'. Spotted shot and attempted to fire guns. Did not fire,TP- 1,425 psi. POOH. Found suspect detonator. RIH with 2-1/2" x 11' with 2-1/2" x 8' blank x 2-1/2" x 7' Connex HC, 4 spf, 60 deg phase perf gun and tie into Pollard correlation log run#1. Run correlation log #2 and send to town. Get ok to perf from 9,433' to 9,444' and 9,452' to 9,459'. Spotted shot and attempted to fire guns. Did not fire,TP- 1,400 psi. POOH. Found intermittent open in the pin end of the firing head. Made guns 6 spf. RIH with 2-1/2" x 11' with 2-1/2" x 8' blank x 2-1/2" x 7' Connex HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log run #1. Run correlation log#3 and send to town. Get ok to perf from 9,433' to 9,444' and 9,452' to 9,459'. Spotted shot and fired guns. TP - 1,400 psi.TP went to 1,410 psi. POOH. RIH with 2-1/2" x 20' Connex HC, 6 spf, 60 deg phase perf gun and line stranded at 4,139' (2130 hrs). Closed rams, bled off lubricator, tightened pack-off and have grease on. Pollard will leave a man on location. They will gather up tools and what they need to get tools out of hole and be back at first light. Will also bring another wireline unit.TP-1,410 psi. 04/01/2015-Wednesday PTW and JSA. TP - 1,410 psi. Cut and strip stranded line out of grease tubes. Run good line back thru grease tubes and clamp wireline together and pull tools from well. Full recovery. Spot wireline truck. Rig up lubricator and grease head. Pressure test lubricator to 250 psi low and 3,000 psi high. Arm gun. RIH w/2-1/2" x 20' Connex HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log#1 gun run. Run correlation log and send to town. Get ok to perf. Spot shot from 9,231' to 9,251'. TP- 1,410 psi. Fired gun and saw no pressure change. POOH. All shots fired. Got out of hole and TP was 1,500 psi. RIH w/2- 1/2" x 20' Connex HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log#1 gun run. Run correlation log and send to town. Get ok to perf. Spot shot from 9,161'to 9,181'.TP- 1,600 psi. Fired gun and TP increased to 1,625 psi in 5 min. POOH. RIH with GPT tool, tie into Pollard correlation log#1 gun run and stop at 10,000'. Wait 5 min and pull up to 9,900' and wait 5 min. Pull to 9,400' and wait 5 min. Pull to 9,200' and wait 5 min. RIH back to 10,000' repeat pass. POOH. Fluid Level at 5,040'.TP - 1,750 psi. Rig down lubricator and turn well back to field. 04/20/2015 - Monday Arrive on location. Hold JSA and issue safe work permit. RU lubricator and PT to 1,500 psi. RIH with 3.5" AD-2 stop. Set down at 9,150'. Would not fall. POOH. Pin sheared. RIH with 2.80 GR to 9,513'. Tagged fill. RIH with 3.5" AD-2 stop with 2 shear pins to 9,365'. Sheared pins, POOH. RIH with Weatherford packoff. Set packoff and sheared off. POOH. RIH with 3.5" A stop to 9,366'. Sheared pin. POOH. RIH with 2.5" x 6' dump bailer full of carbolite. Dumped at 9,365'. POOH. RIH with same dump bailer full of carbolite. Dumped full load of carbolite. POOH. RD lubricator and secure well. II SU 41 -15RD ACTUAL Pad 43-9 SCHEMATIC Hilcorp Alaska,1.1.l 2327' FSL,437 FEL Sec. 9, T5N, R10W, S.M. Permit#: 3M18 !' Conductor 20" K-55 133 ppf PE API#: 50-133-20484-01-00 Top Bottom Property Des: s MD 0' 79' AOGCC= ADL-2497 TVD o' 7s' BLM = A-028063Ji : KB: 21'AGL (245'KB Elevation) X= 314,742.19 ( I `' Surface Casing Y= 2,390,034.43 - ' 13-3/8" K-55 61 ppf BTC Lat: 60° 32' 14.914" N Top Bottom Long: 151° 01' 51.643" W MD 0' 2,271' TVD 0' 2,270' Spud: 09:00 hrs 7/07/2007 Cmt w/1,186 sks of Class G TD Reached: 7/20/2007 Tagged fill @ 9,202'(4/27/15) Rig Released: 6:00 hrs 7/27/07 w/2.50"DD Bailer Intermediate Casing Tagged sand @ 9,334' 9-5/8" L-80 40 ppf BTC (4/23/15) Top Bottom Tree cxn=4-1/2"Otis wl 2.75"Blind Box MD 0' 6,281' Carbolite Sand on TVD 0' 5,615' \\ 1 packoff plug @ 9,365' Cmt original well w/2,284 sks of class G. Top of Cement 600'MD above 9-5/8"window @ 5,675'MD Production Tubing \ 3-1/2" L-80 9.3 ppf EUE Dm Bottom 9-5/8"Casing Window . MD 0' 11,632' milled fromTVD 0' 9,499' 6,275'to 6,294'(MD) • ' 8rd with 6.25"OD control line protectors. _ 5,611'to 5,624'(TVD) }: 8-1/2"hole,Cmt w/545 sks(176 bbls)13.5 ppg • •f• Class G cmt lead and 1,456 sks(300 bbls) i {, N 15.8 ppg Class G cmt tail. Excape System Details _ - 6 Excape module system i' t! r �I�. � Excape System Details; control line for top 4 modules .::= -4 Conventional flappers GIcell control line for bottom 2 modules Mod 1 &2=no flappers Ceramic flapper valves below each module t = i I -Ceramic flapper valves below except for modules 1 &2. - - each module as follows: , Perfs MD(RKB)(Beluga/Tyonek): =a :i Flappers MD(RKB) TVD -j.,. •, = Module 6 - 9,951' 7,984' LB-9,161'-9,181' (Lower Beluga)4/01/15 ' `� - I _ Module 5 - 10,052' 8,074' LB-9,231'-9,251' (Lower Beluga)4/01/15 + - Module 4 - 10,178' 8,181' LB-9,433'-9,444' (Lower Beluga)3/31/15 :------All i !- LB-9,452'-9,459' (Lower Beluga)3/31/15 ' = Module 3 - 10,222' 8,228' Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 •- ( Module 2 - NA Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 I I. ' ! I Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 �a = Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 i _f ' _ Hi _ Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 I T 17' - 11,467'-11,480' (Tyonek) 9/22/07 Tagged fill @ 9,976'(4/15/15) (2-1/8",6spf,60°phasing) - I t = w/2.25"Gauge Ring Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 13' - 11,489'-11,506' (Tyonek) 9/22/07 =II c - )t _ (2-1/8",6spf,60°phasing) �� _ / A L 3 8" Capillary String (pulled on 7/9/10) 3 =. / MC 1 • BHA fish at 10,176'MD Weatherford Float Collarlj l • FCV&2.25"centralizer&Spear left in well 11,584'MD -- -12"long Weatherford Float Shoe 11,621'MD TD PBTD 11,655'MD 11,585'MD 9,517'TVD 9,460'TVD Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063 I ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(TVD): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL):_ 21' Revised by: Stan Porhola Downhole Revison Date: 4/27/2015 Schematic Revison Date: 5/20/2015 1. �FTH . 4,ii I//7,;4\ THE STATE Alaska Oil and Gas � � o fALASIc;A Conservation Commission __ -_ }#=_- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF a *a Main: 907.279 1433 ALA5I" Fax 907.276 7542 www.aogcc.alaska.gov Sattille Stan Porhola 3.6Operations Engineer O (._D Hilcorp Alaska, LLC a 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Sterling Field, Lower Beluga and Upper Tyonek PA (SU 41-15RD) Sundry Number: 315-114 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, Cathy P. F erster Chair, Commissioner DATED this day of March, 2015 Encl. RECEIVED STATE OF ALASKA FEB 2 7 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Weill] Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate Q - Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 2. 207-088 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20484-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 583 Sterling Unit(SU)41-15RD • Will planned perforations require a spacing exception? Yes ❑ No iil 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL002497 • Sterling Field/Lower Beluga and Upper Tyonek PA(Federal) 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,655' • 9,517'- 11,585' 9,460' N/A 10,174' Casing Length Size MD TVD Burst Collapse Structural - Conductor 79' 20" 79' 79 Surface 2,271' 13-3/8" 2,271' 2,270' 3,090 psi 1,540 psi Intermediate 6,281' 9-5/8" 6,281' 5,615 5,750 psi 3,090 psi Production 11,632' 3-1/2" 11,632' 9,499 10,160 psi 10,530 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic See attached schematic 3-1/2" L-80 11,632' Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A WA,N/A;N/A,N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphitn Development n Service n 14.Estimated Date for 15.Well Status after prop sed work: Commencing Operations: 03/13/15 Oil ❑ Gas 2 • WDSPL ❑ Suspended ❑ 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 Sten Porhda Email sDorhola( ihilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature �.•G � Phone 907-777-8412 Date 2--(2-.)7/S— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6-`/OV APPROVED BY _ Approved by:(2V (4_,.....__11COMMISSIONER THE COMMISSION Date: 3-Z— Ls-- 3-245 S 3-2-/s //I1 ,.7-,7 -1,s Ok R.,,I,Gnikpi,AvE Submn Forth ane Forth 10.403(Revised 1 012) for 12 months fr the date of approval. �+ttachments in Duplicate RBDMS- MAR - 5 1015 ••' 1417f5 - C.11) .3 -z-/3 Well Prognosis Well: SU 41-15RD llilrorp Alaska,LL' Date:2/26/2015 Well Name: SU 41-15RD API Number: 50-133-20484-01 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: March 13th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 207-088 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: —2,450 psi @ 10,157' TVD (Based on shut-in survey 7/8/2013) Maximum Expected BHP: — 3,299 psi @ 7,553' TVD (Based on normal grad of btm interval) Max. Allowable Surface Pressure: —2,544 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary This well was drilled and completed as a dual gas well in the Beluga and Tyonek in 1998/1999 as SU 41-15. A workover in 2003 pulled the dual completion and ran a single completion in the Beluga. The well was abandoned and sidetracked in July 2007 and drilled as SU 41-15RD. The SU 41-15RD was fracture stimulated using the EXCAPE completion system in Sept 2007. Additional perfs were added in the Tyonek in Sept 2007. A capstring was installed in Nov 2008 to help with fluid unloading but was pulled in July 2010. The bottom part of the capstring was lost in the well and could not be fished out.The well has not produced since July 2014. The purpose of this work/sundry is to add perforations to the Lower Beluga interval. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 6.5" Otis. 2. RU 2-1/2" 6 spf HC (will make 4 separate runs, each interval only 6 spf shot density). 3. RIH and perforate the Lower Beluga in the following intervals: a. Lower Beluga 9,451'-9,458' (7') (1 run, total of 6 spf). b. Lower Beluga 9,432'-9,443' (11') (1 run, total of 6 spf). c. Lower Beluga 9,230'-9,250' (20') (1 run, total of 6 spf). d. Lower Beluga 9,171'-9,191' (20') (1 run, total of 6 spf). ) b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using CBL log dated 9-06-07. (Tie-in log depth match above depths). d. Record tubing pressures before and after each perforating run. e. Proposed interval is in the Lower Beluga/Tyonek PA. Perfs are located in ADL-002497. - f. Distance to nearest well open in same sands= None. g. Distance to nearest well =4,664'to SU 32-09 (PTD 198-042) in the Upper Beluga. h. Spacing allowance is based on CO 583. Allows well within 1,500'of section line. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic r. II SU 41 -15RD ACTUAL • Pad 43-9 SCHEMATIC Hamra Alaska,LLC 2327' FSL,43T FEL Sec. 9, T5N, R10W, S.M. rmlf Conductor 20" K-55 133 ppf PE ar PI#: 50-133-20484-01-00 Top Bottom roperty Des: MD 0' 79' AOGCC= ADL-2497 ,t; TVD 0' 79' BLM = A-028063 p�1 KB: 21'AGL (245'KB Elevation) I 4L X= 314,742.19 I i Surface Casinq Y= 2,390,034.43 13-3/8" K-55 61 ppf BTC Lat: 60° 32' 14.914" N Top Bottom Long: 151° 01' 51.643" W MD 0' 2,271' ND 0' 2,270' Spud: 09:00 hrs 7/07/2007 ''3 Cmt w/1,186 sks of Class G TD Reached: 7/20/2007 Rig Released: 6:00 hrs 7/27/07 Intermediate Casinq 4 9-5/8" L-80 40 ppf BTC Top Bottom Tree cxn=4-1/2"Otis MD 0' 6,281' ND 0' 5,615' \ Cmt original well w/2,284 sks of class G. Top of Cement 600'MD above 9-5/8"window @ 5,675'MD Production Tubing 3-1/2" L-80 9.3 ppf EUE Top Bottom 9-5/8"Casinq Window ,, _ MD 0' 11,632' milled from ..,. TVD 0' 9,499' 6,275'to 6,294'(MD) 8rd with 6.25"OD control line protectors. 5,611'to 5,624'(TVD) . ' 1 8-1/2"hole,Cmt w/545 sks(176 bbls)13.5 ppg Class G cmt lead and 1,456 sks(300 bbls) t 1 15.8 ppg Class G cmt tail. )I Excape System Details: Excape System Details � t31 .tl 4 Conventional flappers I _ y -Mod 1 &2=no flappers - 6 Excape module system = Dl _ -Ceramic flapper valves below -Red control line for top 4 modules -- - each module as follows: -Green control line for bottom 2 modules -Ceramic flapper valves below each module _ Flappers MD(RKB) ND except for modules 1 &2. �.• ., - , - li Module 6 - 9,951' 7,984' 4 si= _ DModule 5 - 10,052' 8,074' Perfs MD(RKB)(Beluga/Tyonek): - .= - j - Module 4 - 10,178' 8,181' Module 3 - 10222' 8,228' Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 - - ._- , Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 D! Module 2 - NA Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 G .� : s Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 t - - Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 `i- _I = ID _ ( At';if,:i t,t` r(1,1 M 17' - 11,467'-11,480' (Tyonek) 9/22/07 I- H ? (2-1/8",6spf,60°phasing) . _ I = Tagged fish @ 10,174'(12/02/10) Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 = 10w/1.50"Bailer 13' - 11,489'-11,506' (Tyonek) 9/22/07 (2-1/8",6spf,60°phasing) _ D 1E I = 3/8" Capillary String (pulled on 7/9/10) BHA fish at 10,176'MD Weatherford Float Collar . FCV&2.25"centralizer&Spear left in well 11,584'MD * -12"long Weatherford Float Shoe 11,621'MD TD PBTD 11,655'MD 11,585'MD 9,517'ND 9,460'ND Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(ND): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: I 58° at7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: Stan Porhola Downhole Revison Date: 12/2/2010 Schematic Revison Date: 8/7/2013 H 0 SU 41 -15RD PROPOSED Pad 43-9 SCHEMATIC liilcory Alaska,LLC 2327' FSL,437' FEL Sec. 9,T5N, R1 OW, S.M. NNW 207a8 Conductor 20" K-55 133 ppf PE API#: 50-133-20484-01-00 Top Bottom Property Des: MD 0' 79' AOGCC= ADL-2497 TVD 0' 79'i i BLM = A-028063 KB: 21'AGL (245'KB Elevation) X= 314,742.19 I I ', Surface Casing Y= 2,390,034.43 13-3/8" K-55 61 ppf BTC Lat: 60° 32' 14.914" N Top Bottom Long: 151° 01' 51.643" W MD 0' 2,271' TVD 0' 2,270' Spud: 09:00 hrs 7/07/2007 `1 Cmt w/1,186 sks of Class G TD Reached: 7/20/2007 Rig Released: 6:00 hrs 7/27/07 Intermediate Casing 9-5/8" L-80 40 ppf BTC Tree cxn=4-1/2"Otis Tom Bottom MD 0' 6,281' • TVD 0' 5,615' Cmt original well w/2,284 sks of class G. Top of Cement \ 600'MD above 9-5/8"window @ 5,675'MD Production Tubing i, 3-1/2" L-80 9.3 ppf EUE T� Bottom 9-5/8"Casing Window MD 0' 11,632' milled fromTVD 0' 9,499' 6,275'to 6,294'(MD) 8rd with 6.25"OD control line protectors. 5,611'to 5,624'(TVD) 8-1/2"hole,Cmt w/545 sks(176 bbls)13.5 ppg Class G cmt lead and 1,456 sks(300 bbls) r_ r 15.8 ppg Class G cmt tail. Excape System Details - 6 Excape module system t i)- Il i L h Excape System Details: -Red control line for top 4 modules . -i 1 F - ' • - -4 Conventional flappers -Green control line for bottom 2 modules ( y -Mod 1 &2=no flappers -Ceramic flapper valves below each module = Tt = -Ceramic flapper valves below except for modules 1 &2. = L) - each module as follows: Perfs MD(RKB)(Beluga/Tyonek): Flappers MD(RKB) TVD -�.- - _LI - Module 6 - 9,951' 7,984' LB-9,171'-9,191' (Lower Beluga)Proposed? . _ `c Di _ Module 5 - 10,052' 8,074' LB-9,230'-9,250' (Lower Beluga)Proposed rr . _ tt Module 4 - 10,178' 8,181' LB-9,432'-9,443' (Lower Beluga)Proposed J LB-9,451'-9,458' (Lower Beluga)Proposed -' _--:,, I. _ - Module 3 - 10,222' 8,228' +- � T1� = Module 2 - NA Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 �•../1•.,t' „ = DI Mod 5 - 10,031'-10,041' (Beluga) 9/11/07 I " i - 7 '- Mod 4 - 10,157'-10,167' (Beluga) 9/11/07 �.. - Mod 3 - 10,201'-10,211' (Beluga) 9/11/07 Mod 2 - 10,571'-10,581' (Beluga) 9/10/07 1- -t 17' - 11,467'-11,480' (Tyonek) 9/22/07 1 (2-1/8",6spf,60°phasing) j Tagged fish @ 10,174'(12/02/10) � T w/1.50"Bailer Mod 1 - 11,479'-11,527' (Tyonek) 9/12/07 J = D) 13' - 11,489'-11,506' (Tyonek) 9/22/07 a= A - (2-1/8",6spf,60°phasing) = T L i jai 3/8" Capillary String (pulled on 7/9/10) BHA fish at 10,176'MD Weatherford Float Collar * FCV&2.25"centralizer&Spear left in well 11,584'MD - -12"long Weatherford Float Shoe 11,621'MD TD PBTD 11,655'MD 11,585'MD 9,517'ND 9,460'ND Well Name&Number: Sterling Unit SU 41-15RD Lease: A-028063/ADL-002497 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations(MD): 9,930'-11,527' Perf(ND): 7,965'-9,408' Angle @ KOP and Depth: 2.17°/100ft @ 2,785' Angle/Perfs: 25° Maximum Deviation: 58°@ 7,883' Date Completed: 9/10/2007 Ground Level: 224' RKB(above GL): 21' Revised by: Stan Porhola Downhole Revison Date: Proposed Schematic Revison Date: 2/26/2015 # • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~- ~~~ Well History File Identifier Or anizing {done) ^ Two-sided III II~IIIIIIII IIIII ^ Rescan Needed III II'l1l~Ill II~III 9 RE AN olor Items: Greyscale Items: ^ Poor Quality Originals: DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Pro "ect Proofin ! g II I II II II I I III I I III BY: Maria Date: l ~ /s/ Scanning Preparation ~ x 30 =~~6 + J~ = TOTAL PAGES 1~/ (Count does not include cover sheet) ~/~ /~-~ BY: Maria Date: t~/ ;~,..I~ /s/ y~~ II Production Scanning """"""" "" Stage 1 Page Count from Scanned File: ~~~(count does inciude cover sneet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: I ~~~ ~ ~S~ ~~ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ (IIIIII Scannin is complete at this point unless rescanning is required. II I II ~I II I 9 ReScanned (I I II II II I I III I( III BY: Maria Date: ~S~ Quality Checked III II'll) III II~IIII Comments about this file: 10/6l2005 Well History File Cover Page.doc w 4 • • Marathon Alaska Production LLC c, k Marathon Alaska Asset Team P.O. Box 1949 MARATHON ) Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 June 14, 2011 Mr. Winton Aubert 0 Ogg Alaska Oil & Gas Conservation Commission 333 W 7 Ave Anchorage, Alaska 99501 �� � E Reference: 10 -404 Report of Sundry Well Operations Oil cons. Niamission iigo Field: Sterling Uni Well: Sterling Unit 41 -15RD 2.011 Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for SU 41 -15RD well. This report covers the work performed to remove /recover the capillary string from SU 41 -15RD. The cap- string broke during the pulling operation requiring considerable fishing activity. All of the remaining 3/8" tubing was recovered leaving only the bottom hole assembly down -hole. It was determined to close out the work completed to date while developing a plan to clean out the remainder of this wellbore. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, t Si- • �J 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 • RECEIVEb 11.12,00 t STATE OF ALASKA ALASKA "AND GAS CONSERVATION COMMISSIO _RI„INI : b :),iii REPORT OF SUNDRY WELL OPERATIONS a1 nka & nA Cm* Ctrtisillsska 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Othe Removed Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver El Time Extension ❑ ° ' /1d "b -4 J Ury String 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 0 Exploratory — 207 -088 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 ` 50- 133 - 20484 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 0002497 - Sterling Unit 41 -15RD 9. Field /Pool(s): Sterling Field / Beluga & Upper Tyonek Pools 10. Present Well Condition Summary: Total Depth measured 11,655' feet Plugs measured NA feet true vertical 9,517' feet Junk measured 10,176' feet Effective Depth measured 11,585' feet Packer measured NA feet true vertical 9,460' feet true vertical NA feet 1 Casing Length Size MD TVD Burst Collapse / Structural Conductor 58' 20" 79' 79' 3,060 psi 1,500 psi Surface 2,250' 13 -3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,260' 9 -5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,611' 3 -1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner / Perforation depth: Measured depth: 9,930' - 11,527' feet True Vertical depth: 7,969' - 9,403' feet Excape 3 - 1/2" L - 80 11,585' 9,460' Tubing (size, grade, MD & TVD): Capillary String 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): The cap- string parted during removal. The remainder of the cap - string was fished out during the next two months leaving only the 1' BHA Treatment descriptions including volumes used and final pressure: down -hole. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1.6 0 2,395 Subsequent to operation: 0 0 - 0 1,007 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development MI Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil U ,Gas U WDSPL ❑ GSTOR❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 16. 1 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 6-4, Title Regulatory Compliance Representative Signature ��11 .� `� 4 -6 Phone (907) 283 -1371 Date June 14, 2011 r /� vv/ RBDMS JUN 16 2011 CA Form 10 -404 Revised 10/2010 Submit Original Only e • Permit #: 207 -088 SU 41 -15 R D API #: 50- 133 - 20484 -01 -00 Property Des: Pad 43 -9 AOGCC = ADL - 2497 2327' FSL, 437' FEL MARATNON BLM = A - 028063 KB: 21' AGL (245' KB Elevation) Sec. 9, T5N, R1 OW, S.M. Conductor X= 314,742.19 20" K -55 133 ppf PE Y= 2,390,034.43 Top Bottom MD 0' 79' Lat: 60° 32' 14.914 °' N TVD 0' 79' Long: 151° 01' 51.643" W / L Spud: 09:00 hrs 7/07/2007 , : '' . , TD Reached: 7/20/2007 Surface Casing Rig Released: 6:00 hrs 7/27/07 1 I 13 -3/8" K -55 61 ppf BTC Top Bottom J M 0' 2,271' TVD 0' 2,270' ' Cmt w/ 1,186 sks of Class G Tree cxn = 4 - 3/4" Otis Intermediate Casing - 9 -5/8" L -80 40 ppf BTC Top of Cement Top Bottom 600' MD above 9 -5/8" window MD 0' 6,281' TVD 0' 5,615' a Cmt original well w/ 2,284 sks of class G. 1' 9 -5/8" Casing Window milled from �c Production Tubing 6,275' to 6,294' (MD) 3 -1/2" L -80 9.3 ppf EUE 5,611' to 5,624' (TVD) ' , Top Bottom MD 0' 11,632' TVD 0' 9,499' + 8rd with 6.25" OD control line protectors. 8 -1/2" hole, Cmt w/ 545 sks (176 bbls) 13.5 ppg I Class G cmt lead and 1,456 sks (300 bbls) Excape System Details ' , s - r 15.8 ppg Class G cmt tail. - 6 Excape module system _ _ - Red control line for top 4 modules - Green control line for bottom 2 modules T / i ; - Ceramic flapper valves below each module Excape System Details: except for modules 1 & 2. 1 NV � 4 Conventional flappers i - Mod 1 & 2 = no flappers Perfs MD (RKB) (Beluga/Tyonek): - Ceramic flapper valves below each module as follows: ii Mod 6 - 9,930' - 9,940' (Beluga) 9/11/07 11 }t: 7 ✓ an= Mod 5 - 10,031 - 10,041' (Beluga) 9/11/07 ',. . " s1*" !� ( Flappers MD (RKB) TVD I Mod 4 - 10,157' - 10,167' (Beluga) 9/11/07 7 :,: j - Module 6 - 9,951' 7,984' Mod 3 - 10,201' - 10,211' (Beluga) 9/11/07 ° , Y ; s m � 1 _ Module 5 - 10,052' 8,074' y Mod 2 10,571' 10,581' (Beluga) 9/10/07 t . Module 4 10 178' 8 181' 17' - 11,467' - 11,480' (Tyonek) 9/22/07 _ f = Module 3 - 10,222' 8,228' (2 -1/8 ", 6spf, 60° phasing) Module 2 - NA Mod 1 - 11,479' - 11,527' (Tyonek) 9/12/07 ? 13' - 11,489' - 11,506' (Tyonek) 9/22/07 I I ` DI (2 -1/8 ", 6spf, 60° phasing) = - 7 r 1 = i ,1 li t 3/8 Capillary String (pulled on 7/9/10) s c BHA fish at 10,176' MD 1 Al C } T * FCV & 2.25" centralizer left in well C * - 12" long Weatherford Collar IL1 �1 1 11,,5584' ' MD MD Weatherford Float Shoe 11,621' MD TD PBTD 11,655' MD 11,585' MD 9,517' TVD 9,460' TVD Well Name & Number: SU 41 -15RD I Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State /Prov: Alaska I Country:I USA Perforations (MD): 9,930' - 11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° / 100ft @ 2,785' Completion Fluid: 6% KCL I Angle /Perfs:I 25° Dated Completed: 9/10/2007 Ground Level (MSL): 224' Revised by: Kevin Skiba Last Revison Date:_ 6/13/2011 6 , M Marathon Cations Summary Report by Job M ARATHON ® Oil Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 ' ST E RLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Daily Operations Report Date: 7/8/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU DynaCoil to pull cap string. Were unable to pull the cap string free. Left cap string in the well. Reconnectedd foamer and MEOH. Reconnected 3" flow lines to sand separator and gas buster. Well ready to flow. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:15 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. 08:15 10:27 2.20 RURD COIL Spot equipment. Lay liner down. RU Dynacoil unit. PU spool. Stab coil thru side of injector. Carry injector to WH while "walking" injector down coil. Set injector on WH. Install hydraulic line on packoff. Check pressure. Set pressure to 3000 psi. Back off Ratigun. Release mechanical slips. 10:27 10:57 0.50 RUNPUL COIL PU on cap string. String won't pull free. Decrease pack off pressure to minimun and repeated pulls from 3200 -3500 lbs won't move it. String is only moving an inch or two at the packoff. Definitely not enough movement to be tubing strech. 10:57 11:27 0.50 RUNPUL COIL After consulting w/ office, it was determined to apply tension and hang it back off prepare well to flow. Reapply foamer and MEOH and get the well read to flow to production. 11:27 13:27 2.00 RURD COIL Hang off cap string. Set Mechanical slips and Ratigun. Pull string out thru the side of the injector. Reconnect foamer and MEOH. Reconnect 3" chicksan to sand separator and gas buster. Well is ready to flow. 13:27 14:27 1.00 RURD CSG RD DynaCoil unit. 14:27 14:57 0.50 SECURE WELL Secure well. Sign off permit. Sign out and leave loc. Lock gates on the way out. Report Date: 7/9/2010 Job Category: R&M MAINTENANCE - 24HrSummary MIRU BJ DynaCoil to pull inactive 3/8" capillary string. Worked string from +4000# to -500# with little to no movement. Attempted to lubricate packoff elements, bleed packoff to zero, and loosen packoff all while working string with no progress. Attempted to blow down well to relieve pressure on packoff and tree was freezing off. Began pumping methanol into wellhead and noticed small string movement. Pumped a total of 55 gals methanol into wellhead and string pulled free. POOH to surface and find parted capstring. —634' of 3/8" tubing, FCV, and centralizer left in hole. RD BJ Dynacoil. ,, , Ops ° , =" ; , Trouble .: _ . Start Time End Time, Dur (hr) OPS Code - ActMty Code Status_! Code .. G9r» - , ' 09:00 09:30 0.50 SAFETY MTG AF Held PJSM w/ BJ Dynacoil and operator. Discussed pinch points, job procedures, and manlift ops. Obtained safe work permit. 09:30 11:00 1.50 RURD COIL AF MIRU BJ Dynacoil equipment. PU empty spool, run tubing through injector, and load excess tubing. Walk injector and land on wellhead. Install packoff and release slips. 11:00 18:00 7.00 RUNPUL COIL AF Attempted to pull 3/8" capstring and was stuck. Worked string from +4000# to -500# with little to no movement. Attempted to lubricate packoff elements, bleed packoff to zero, and loosen packoff all while working string with no progress. Attempted to blow down well to relieve pressure on packoff and tree was freezing off. Began pumping methanol and noticed small string movement. Pumped a total of 55 gals methanol and string pulled free. P001110 surface and find parted capstring. —634' of 3/8" tubing, FCV, and centralizer left in hole. 18:00 19:30 1.50 RURD COIL AF Lift injector off wellhead and set on Dynacoil truck. Cut tubing and put on spool. RD Dynacoil truck and equipment. Sign out, turn in work permit, and leave location. Report Date: 7/27/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" unit) to fish —600' of 3/8" capillary string. RIH w/ 2.70" LIB and tag © 6682' MD RKB, POOH- small marks on side. RIH w/ same and tag © 6700', WT- solid, POOH- no marks. RIH w/2.75" GR and tag © 6704' and WT to 6713', POOH- metal marks on GR. RIH w/ 2.65" GR and roller bogies, tag @ 6711' and WT to 6713', POOH. RIH w/ 2.50" DD bailer and tag @ 6713' and WT to 6719', POOH- bailer full of wet fine sand. RIH w/ same and tag @ 6723' and WT to 6730', POOH- bailer full of same. RIH w/ same bailer (2.70" bottom) and tag © 6730' and WT to 6751', POOH- bailer full of same. RD Pollard for night. Fluid level — 6000'. . : QPS Trouble, rc Start Time:„ End Time Dur.(br) -- , - Mtivity Status,.; r Code: Go114. . - -- 07:30 08:30 1.00 SAFETY MTG AF Held PJSM w/ Pollard and operator. Discussed emergency operations, working with trapped pressure, and wet conditions. Obtained safe work permit. 08:30 09:45 1.25 RURD SLIK AF RU 0.160" slickline unit and equipment. MU 1.75" RS, KJ, 2.30" x 5' stem, 2" x 10' stem, 1.75" KJ, OJ, and LSSJ into lubricator and stab on well. 09:45 10:00 0.25 TEST BOPE AF PT lubricator to 3000 psi. Good test. www.peloton.com Page 1/12 Report Printed: 6/13/2011 i t M Marathon Orations Summary Report by Job ID (MARAnioN Oil Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.921 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 10:00 10:45 0.75 RUNPUL SLIK AF RIH w/ tool string and 2.70" LIB and tag @ 6682' MD RKB, POOH- small marks on side. 10:45 11:30 0.75 RUNPUL SLIK AF RIH w/ same and tag @ 6700', WT- solid, POOH- no marks. 11:30 12:15 0.75 RUNPUL SLIK AF RIH w/ same BHA and 2.75" GR and tag @ 6704' and WT to 6713', POOH - metal marks on GR. 12:15 14:00 1.75 RUNPUL SLIK AF Add roller bogies to BHA and RIH w/ 2.65" GR, tag @ 6711' and WT to 6713', POOH. 14:00 14:45 0.75 RUNPUL SLIK AF RIH w/ same BHA and 2.50" DD bailer and tag @ 6713' and WT to 6719', POOH- bailer full of wet fine sand. 14:45 15:30 0.75 RUNPUL SLIK AF RIH w/ same and tag @ 6723' and WT to 6730', POOH- bailer full of same. 15:30 16:30 1.00 RUNPUL SLIK AF RIH w/ same bailer (2.70" bottom) and tag @ 6730' and WT to 6751', POOH - bailer full of same. Fluid level - 6000'. 16:30 17:00 0.50 RURD SLIK AF LD lubricator and secure well for night. RD Pollard for night. Sign out, turn in work permit, and leave location. Report Date: 7/28/2010 Job Category: R &M MAINTENANCE '24 Hr Summary RU Pollard wireline (0.160" unit) to fish -600' of 3/8" capillary string. Continued bailing on fill or possible bridge from 6750' to 7076' MD RKB. Made 6 runs with 2.50" x 6' bailer & 2.70" bottom w/ approx 5 gals of sand to surface. Still no sight of bottom of bridge, but making good hole with each run. We had to shut down early to repair brakes on slickline unit. RD Pollard for night. - Start Time . . End Time Dur (hr) Ops Code ` - Abtivdy Code, Status , Code Com 07:30 08:30 1.00 SAFETY MTG AF Held PJSM w/ Pollard and operator. Discussed emergency operations, working with trapped pressure, and trip hazards. Obtained safe work permit. 08:30 09:45 1.25 RURD SLIK AF RU 0.160" slickline unit and equipment. PU 1.75" RS, KJ, RB, 2.00" x 15' stem, RB, 1.75" KJ, RB, OJ, LSSJ, RB, and 2.00" x 3' stem into lubricator and stab on well. 09:45 10:00 0.25 TEST BOPE AF PT lubricator to 3000 psi. Good test. 10:00 11:00 1.00 BAIL FILL AF RIH w/ tool string and 2.50" x 6' bailer & 2.70" bottom to 6750' MD RKB and WT to 6772', POOH- bailer full of fine wet sand. 11:00 12:00 1.00 BAIL FILL AF RIH w/ same to 6774' MD RKB and WT to 6826', POOH- bailer full of fine wet sand. 12:00 13:00 1.00 BAIL FILL AF RIH w/ same to 6835' MD RKB and WT to 6898', POOH- bailer full of fine wet sand. 13:00 14:00 1.00 BAIL FILL AF RIH w/ same to 6905' MD RKB and WT to 6965', POOH- bailer full of fine wet sand. 14:00 15:00 1.00 BAIL FILL AF RIH w/ same to 6964' MD RKB and WT to 7071', POOH- bailer full of fine wet sand. 15:00 16:00 1.00 BAIL FILL AF ' RIH w/ same to 7071' MD RKB and WT to 7076', POOH- bailer full of fine wet sand. 16:00 18:00 2.00 REPAIR EQIP TA ' MSOT Repair brakes on slickline unit and rebuild rope socket. 18:00 18:30 0.50 RURD SLIK AF LD lubricator and RD slickline equipment for night. Secure well, sign out, tum in work permit, and leave location. Report Date: 7/29/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish --600' of 3/8" capillary string. Ops' Trouble • ,, Start Time End Time ' , Qur,{hr) '. Ops Code , AptMtyCode .. Statue ' ..- Code ,: :.. •,Coal , 07 :30 08 :00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - items discussed slips, trips, falls, review JSA's, assign jobs, three second rule, sop the job authority, emergency vehicles, emergency numbers, muster area, possible bee problem, allergies 08:00 08:30 0.50 RURD SLIK AF rig up crane, lubricator, slickline unit. Pressure test lubricator to 3000# - test successful, bleed down lubricator to 2500# to equalize with wellbore pressure. 08:30 10:00 1.50 RUNPUL SLIK AF Run 2.5 inch dump bailer. Hit bridge at 7115' MD. Clean out to 7175' MD. POOH with bailer. Bailer filled with blue / gray Beluga mud. Tool coated with same 10:00 11:00 1.00 RUNPUL SLIK AF Run #2 - Pressure test to 3000 #, bleed lubricator to 2500 #, equalize presssure to Wellhead pressure. RIH with 2.5" dump bailer. Set down at 7175' MD. Clean out to 7180' md. POOH www.peloton.com Page 2/12 Report Printed: 6/13/2011 i ` M Marathon Orations Summary Report by Job ei MARA THON e OiilCompany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 11:00 12:00 1.00 RUNPUL SLIK AF Run #3 - Pressure test to 3000 #, bleed lubricator to 2500 #, equalize presssure to Wellhead pressure. RIH with 2.5" dump bailer. Set down at 7188' MD. Cleaned out to 7210' MD. POOH 12:00 13:00 1.00 RUNPUL SLIK AF Run #4 - Pressure test to 3000 #, bleed lubricator to 2500 #, equalize presssure to Wellhead pressure. RIH with 2.5" dump bailer. Set down at 7201' MD. Cleaned out to 7271' MD. 13:00 14:00 1.00 RUNPUL SLIK AF Run #5 - Pressure test to 3000 #, bleed lubricator to 2500 #, equalize presssure to Wellhead pressure. RIH with 2.5" dump bailer. Set down at 7270 MD. Cleaned out to 7314' MD. POOH 14:00 15:30 1.50 RUNPUL SLIK AF Run #6 - Pressure test to 3000 #, bleed lubricator to 2500#, equalize presssure to Wellhead pressure. RIH with 2.5" dump bailer. Set down at 7317' MD. Cleaned out to 7372 ' MD. 15:30 16:00 0.50 RURD SLIK AF Rig back crane truck, lubricator and wireline unit. 16:00 16:15 0.25 SECURE WELL AF Secure well for evening Report Date: 7/30/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish -600' of 3/8" capillary string. Start Time . End Tirne Our (hr} s Ops Code Activity Code s Status Code , . - Crum , - . 08:00 09:00 1.00 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. 09:00 09:30 0.50 RURD SLIK AF Rig up crane, lubricator and wireline unit. Rebuild rope socket. 09:30 10:30 1.00 RUNPUL SLIK ' AF Run 2.5" dump bailer. Tool set down at 7317' MD and cleaned out hole to 7383' MD. POOH 10:30 11:30 1.00 RUNPUL SLIK AF Run 2. Ran 2.5" dump bailer. Tool set down at 7388' MD. Cleaned out to 7450' MD. POOH 11:30 12:30 1.00 RUNPUL SLIK ' AF Run 3. Ran 2.5" dump bailer. Tool set down at . 12:30 14:00 1.50 RUNPUL SLIK AF Run 4. Ran 2.5" dump bailer. Tool set down at 7610' MD. Cleaned out to 7812' MD. 14:00 15:30 1.50 RUNPUL SLIK AF Run 5. Ran 2.5" dump bailer. Tool set down at 7835' MD. Cleaned out to 8002' MD. POOH 15:30 16:00 0.50 SECURE WELL AF Rig down and set back lubricator, crane truck and wireline unit. Secure wellhead, turn in work permit, sign out and leave location Report Date: 7/31/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish -600' of 3/8" capillary string. ► ops . ° Trouble Start Time End Time Dur (ht) s;l - ,' Ops Code: ,. Activit l Outs-, .- £ Status , Code, _ : , Com ,, , , :, z - : .. 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. 08:00 08:30 0.50 RURD SLIK AF Rig up wireline unit, crane and lubricator. Pressure test lubricator and wireline BOP's to 3000# - test successful 08:30 10:00 1.50 RUNPUL SLIK AF Run 1- Run 2.5" dump bailer with 2.7' OD gauge ring. Set down at 7961' MD. Clean out to 8051' MD 10:00 11:00 1.00 RUNPUL SLIK AF Run 2- Run 2.5" dump bailer with 2.7' OD gauge ring. Set down at 8057' MD. Clean out to 8151' MD 11:00 12:30 1.50 RUNPUL SLIK AF Run 3- Run 2.5" dump bailer with 2.7' OD gauge ring. Set down at 8144' MD. Clean out to 8180' MD 12:30 13:30 1.00 RUNPUL SLIK AF Run 4- Run 2.5" dump bailer with 2.7' OD gauge ring. Set down at 8181 MD. Clean out to 8280' MD 13:30 14:30 1.00 RUNPUL SLIK AF Run 5- Run 2.5" dump bailer with 2.7' OD gauge ring. Set down at 8315' MD. Fell free after working to 8500'MD. POOH to run LIB 14:30 ' 15:30 1.00 RUNPUL SLIK AF Run Lead Impression Block (LIB) to find top of fish. Tagged bridge at 9888' MD. Probably the top of Module #6. Picked up and set LIB down one more time then POOH to inspect LIB. 15:30 16:00 0.50 RURD SLIK AF Set back lubricator, lay down mast and rig down slickline truck 16:00 16:15 0.25 SECURE WELL AF Secure wellhead, turn in work permit, sign out and leave location. www.peloton.com Page 3/12 Report Printed: 6/13/2011 M Marathon Olations Summary Report by Job • mammon OiICOmpany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Daily Operations Report Date: 8/3/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —600' of 3/8" capillary string. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:30 09:00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 09:00 10:00 1.00 RURD SLIK AF rig up slickline unit, crane truck and lubricator. Rebuild rope socket and intall fishing tool to bottom of tool string. 10:00 11:00 1.00 RUNPUL SLIK AF Run fishing tool into hole. Top of fish at 9888' MD. Attempted to engage fish - unsuccessful. POOH to try different fishing tool. 11:00 12:00 1.00 RUNPUL SLIK AF Engage top of fish at 9888'MD after three attempts with second fishing tool. Pulled up to 2600# before slacking off on weight. Appeared to shear release pin. POOH. On surface, fishng tool slipped off fish and shear pin only partially sheared. Run back into hole with first tool. 12:00 13:30 1.50' RUNPUL SLIK AF Re -run first fishing tool with overshot. Engaged tool several times but tool slipped out of teeth. POOH. Circumferential grooves in the OD of the fishing tool suggests we are battling a flapper valve at the fish top. Teeth show wear in the lowest set but unable to pound the fish into the upper set of teeth. 13:30 14:30 1.00 RUNPUL SLIK AF Re -run the second fishing tool. Unable to latch onto capillary string. 14:30 15:30 1.00 RUNPUL SLIK AF Run BJ overshot and grappel tool. Fish still at same depth but tool will not engage. Multiple attempts unsuccessful. POOH 15:30 16:00 0.50 RURD SLIK AF Rig back lubricator, crane truck and slickline unit, secure wellhead for evening, sign out and turn in work permit Report Date: 8/4/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —600' of 3/8" capillary string. Ops Trouble • Start Time End Time Dur (hr) Ops Code Activity Code Status Code - Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 08:00 08:30 0.50 RURD SLIK AF Rig up wireline truck, crane truck and lubricator. Prepare to run LIB. Pressure test lubricator and wellhead with water and methanol mixture to 3000 #, equalize pressure to downhole pressure - 2500#, dump methanol to clean out hydrates. 08:30 09:30 1.00 RUNPUL SLIK AF Run Lead Impression Block - LIB with decentralizer to determine obstruction and orientation. Results of LIB - on a clock scale with 6 o'clock being the low side of the hole, we have the cap string bent over towards the 12 o'clock position making a full 360 arc with the open end slightly off center and half the radius of the hole towards the 9 o'clock position. 09:30 11:30 2.00 RUNPUL SLIK AF Run spear into hole in attempt to get alongside fish. Spear got alongside fish but not deep enough to engage hook. Multiple attempts. POOH. Spear came out of hole bent from spudding on fish. 11:30 13:00 1.50 RUNPUL SLIK AF Run into hole with alligator jows while straightening original spear shaft. Did not engage fish. POOH 13:00 14:30 1.50 RUNPUL SLIK AF Run original spear (straightened) that almost engaged fish on first fishing run attempt. Tool made multiple engagements with fish. Held tension and let oil jars go off. Impact caused spear to slide off fish every time.POOH 14:30 16:00 1.50 RURD SLIK AF Rig down lubricator, crane truck and wireline unit. Rebuild packoff and wireline ropesocket. Secure wellhead, sign out and tum in work permit Report Date: 8/5/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —600' of 3/8" capillary string. www.peloton.com Page 4/12 Report Printed: 6/13/2011 Ar il Marathon •rations Summary Report by Job • m* ® Oil Cornpany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name I License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 08:00 08:30 0.50 RURD SLIK AF Rig up wireline unit, crane and lubricator. Rig up tool string consisting of decentralizer, orienting tool, bait sub and fishing tool. 08:30 10:00 1.50 RUNPUL SLIK AF Run first fishing tool. Spear engaged fish but did not get deep enough to get caught onto barb. POOH Point bent inward after sliding down past top of fish and casing wall. Indicates sprial cap string tubing against casing wall below top of fish. 10:00 11:30 1.50 RUNPUL SLIK AF Run spiral cork screw sucker rod shaft with barbs fishing tool. No orientation, knuckle joint for rotation and centralized. Minimal engagement with fish. POOH 11:30 13:00 1.50 RUNPUL SLIK AF Run modified spear run on first attempt. Distance to first barb shortened. Engaged fish and pulled up to 2600 #, released oil jars and remained engaged to fish. Reset jars and hammered one more time. Spear released from fish. POOH to inspect spear. On inspection, shortened up barb to run again. 13:00 14:30 1.50 RUNPUL SLIK AF Re -run remodified spear. Engaged fish, attempted to seat spear deeper, pulled up. Appears to be good solid engagement. Continued to pull on fish until fish released. POOH. Lost line weight coming out of hole at 6300 feet MD. Will run back into hole and attempt to re- engage fish. 14:30 15:30 1.00 RUNPUL SLIK AF Re -run to 6300' MD to re- engage fish if possible. Engaged fish at 6283. POOH At surface retrieved approx. 1 foot of 3/8" stainless capillary string balled up into a mess approx the size of a tennis ball. 15:30 16:30 1.00 RUNPUL SLIK AF Run LIB to determine what top of fish looks like. Tagged fish at 7333' MD. POOH Edge of cap string up against casing wall. 16:30 17:00 0.50 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. Secure wellhead, sign out and leave location Report Date: 8/6/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.16(Y" unit) to fish —599' of 3/8" capillary string. - ' OpS Trouble . Startt Time End Time Our (hr) - • Ops'Code i Activity Code - Status Code _ , -Com .. - , 07:00 08:30 1.50 SAFETY MTG AF Attend monthly safety meeting at Beaver Creek. 08:30 09:00 0.50 SAFETY MTG AF Arrive location, sign in, hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 09:00 10:00 1.00 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Pressure test lubricator to 3000# - test good 10:00 11:00 1.00 RUNPUL SLIK AF Run centralized spear designed to engage cap string tubing sprialed around inside of casing. Multiple marginal engagements. POOH At surface, spear had been released. Prepare to go into hole and engage fishing neck. 11:00 12:00 1.00 RUNPUL SLIK AF Run into hole to fish spear. Engage fishing spear. POOH 12:00 14:00 2.00 RUNPUL SLIK AF Run spear from day before that was successful twice. Engaged fish at 8030' POOH with section of capstring. Hung up at 2000' but did manage to bring two small section of capstring out of hole. Each section approx. 1 foot log and spiraled around inside the casing. www.peloton.com Page 5/12 Report Printed: 6/13/2011 Marathon Otions Summary Report by Job • Ci mon s OiI Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 14:00 18:30 4.50 RUNPUL SLIK AF Re -run spear. Engage top of fish at 8463' MD. Dis- engage when jars released. Re- engage fish. Work fish to try and pull free. Lost fish and re- engage several times. Re- engage and pull up to release jars. Unable to release jars. Unable to go up or down. Work line. Send for cutter bar while continuing to work line. Close wireline BOP, bleed pressure off lubricator, break lubricator, attach cutter bar, reset lubricator, equalize pressure, open wireline BOP, drop cutter bar at 5 pm. At 5:15 bar appeared to reach bottom. Pulled tension on wireline and wireline was still not free. Increased tension and whole tool string came loose. POOH. At surface at 6:30 pm. Closed master valves, bled off pressure, closed wireline BOP, broke lubricator, capped bottom of BOP and layed entire tool string inside lubricator down. When pulled tool string out of lubricator, approx. 4 inch piece of 3/8" cap string was caught in lowermost roller bogey. Most likely cause was piece on previous fishing run when 2 pieces were retrieved, caught in tree and then fell down on top of tool. The cutter bar dislodged the piece and was slowed enough to not cut wire. As we brought string to surface, the piece lodged in the lowermost roller bogey. 18:30 19:00 0.50 SECURE WELL AF Secure well for evening, sign out, tum in work permit, leave location. Report Date: 8/7/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —596' of 3/8" capillary string. Ops Trouble' . • . Start Time End Time . - Our (hr) Ops Code Activity Code Status Code , - . . Com 07:30 08:00 0.50 SAFETY MTG AF PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 08:00 09:00 1.00 RURD SLIK AF Rig up slickline unit, crane truck, lubricator, pressure test lubricator, brush tree, pick up fishing spear, pressure test lubricator 09:00 11:00 2.00 RUNPUL SLIK AF Run spear to engage fish. Engage fish at 9893' MD. Work fish, jars, flow well to tank - pull up to 4000 #. Either came loose or broke piece off but came loose. POOH No fish to surface 11:00 12:30 1.50 RUNPUL SLIK AF Re -run spear. Tag fish at 9893'MD Work fish, lose fish, re- engage fish, work fish. Piece appears to have broken off fish. Drag out of hole. At surface, approx. 1 foot 3/8" capstring that is spiraled inside casing. 12:30 13:30 1.00 RUNPUL SLIK AF Run new spear while repairing original spear. New spear has two arms to go alongside spiraled capstring. Engage fish at 9893' MD. Work fish. Piece broke off. POOH At surface, 1 foot spiraled piece of capstring 13:30 15:00 1.50 RUNPUL SLIK AF Re -run new spear. Engage fish at 9893' MD. Work fish, lose fish and re- engage fish several times. POOH. At surface, fish was a triangle of capstring approx. 8 -9 inches long total. 15:00 15:30 0.50 RURD SLIK AF Rig down slick line unit, crane truck and lubricator for weekend, secure wellhead, sign out and leave location Report Date: 8/24/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —595' of 3/8" capillary string. Ops Trouble Start Time Es d Time Dig Or) Ops Code .Activity Code • Statue :Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule Last year 40% of all incidents were hand injuries. Stressed hand placement safety. 08:00 10:00 2.00 RURD SLIK AF Rig up crane truck, wireline unit and lubricator. Pressure test lubricator to 200 # - 0 ring failed. Replace, Retest to 3000# - test good. 10:00 11:30 1.50 RUNPUL SLIK AF Run into hole with fishing spear. Engage fish at 9907' MD. Pull and release fish several times, Re- engage, pull several times. POOH At surface: spear bent towards center of casing. Replace with slimmer version to try and get outside of fish. 11:30 13:00 1.50 RUNPUL SLIK AF Run into hole with slim version of fishing spear. Set down at 9923' MD. Engage fish multiple times, pull, release and re- engage. POOH. At surface, no pieces of fish. Realign barb and run back into hole. www.peloton.com Page 6/12 Report Printed: 6/13/2011 ti ( M Marathon Crations Summary Report by Job MARATHON e 0i1 Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 13:00 14:30 1.50 RUNPUL SLIK AF Run into hole with modified spear. Set down at 9923' MD. Engage fish, pull, lose and re- engage fish.Pulled on fish and something came loose. POOH to check spear. On surface, tip of spear folded over into a "J" pattern. No fish parts. Modify original spear. 14:30 16:00 1.50 RUNPUL SLIK AF Run original spear modified back into hole. Engaged fish at 9923'MD. Multiple engagements, pull, dislodged. Final engagement, pulled 4000 #, something pulled loosed, may be pulling small piece out of hole. POOH. At surface, rolled edge on tip of barb on spear. Fish not completely over barb. No fish. Will modify spear with longer shaft between tip and no go. Also barb's closer to tip and slimmer to go alongside fish. 16:00 16:45 0.75 RUNPUL SLIK AF Run Lead Impression Block. Set down at 9923'MD. At surface, balled up cap string along low side of hole and spiraled also. 16:45 17:00 0.25 RURD SLIK AF Rig down slickline unit, crane truck and lay down lubricator. Secure wellhead, sign out , tum in work permit and leave location. Report Date: 8/25/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish -595' of 3/8" capillary string. r Ops Trouble Start Time End Time Dur (hr,) Ops Code Activity Code' Status Code Com, 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in ,hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 08:00 09:00 1.00 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Rig up fishing string oriented to spear ball of cap string as per orientation on LIB.. Pressure test lubricator to 3000# - test good. 09:00 10:30 1.50 RUNPUL SLIK AF Run #1 - slim spear single arm to go alongside fish. Spear oriented for the two (2) O'clock position to get alongside the fish. Set down on fish at 9927'MD. Engaged fish immediately, pulled up to 3000# tension and started moving fish uphole. Set back down and then pulled up to tension two more time when shear pin released (good). Good solid bite on fish. Coming out of hole, going back into hole with oil jars so we can get serious with fish. 10:30 15:00 4.50 RUNPUL SLIK AF Solidly onto fish at 9927' MD. Jarring fish and moved it approx. 34 feet. Continue jarring and attempting to pull fish free. May have to shear from fish and bring in heavier line and jars. Continue jarring, fish moving. Continue jarring to 8600 and fish moving freely uphole. Come out of hole at approx. 100 FPM. At surface -no fish, spear is missing 3 of 4 barbs made from Grade 8 bolts. Get backup spear ready to go into hole and pickup fish. Lost most of weight at 8600 feet. Will start looking there. 15:00 15:45 0.75 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. Rebuild rope socket and packoff to prepare for the fishing operation tomorrow. Build wireline valve with shear rams to cut capillary string in preparation for removing from wellbore through lubricator. 15:45 16:00 0.25 SECURE WELL AF Secure wellhead, sign out, turn in work permit and leave location Report Date: 8/26/2010 Job Category: R&M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish -595' of 3/8" capillary string. Ops Trouble stilt End Our (tr) ,Ops Code . Activity Code Status ;y. 'Code ` - Gom 07:30 08 :00 0.50 SAFETY MTG AF Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Special emphasis on school started yesterday. School busses will be running, students running across roads for busses and young drivers talking on cell phones. www.peloton.com Page 7/12 Report Printed: 6/13/2011 M Marathon O11 Illations Summary Report by Job • MARATHON ® Oil Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country ry 6009005N010W01 I STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Corn 08:00 10:00 2.00 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Added a cap string valve into the lubricator string at the bottom below wireline valve to cut the cap string and then move up into the lubricator, close valves below bottom of fish and then bleed off pressure to remove that section of the fish if we get anything of any length. Pressure test lubricator and wireline / capstring valves - Cutter valve failed low pressure test. Replace "O" ring - failed low pressure test. Rebuild stem on cutter valve. Retest to 3000# - test good. 10:00 11:30 1.50 RUNPUL SLIK AF Run into hole with fishing spear. Tag fish at 8754'MD. Engage fish and work fish. Shear off with up shear tool. POOH to install down shear tool and jars. 11:30 15:30 4.00 RUNPUL SLIK AF Run shear down tool and jars to engage fishing neck. Engage fish and bring to surface. Reduced drag as we get closer to surface due to wear on surfaces. On surface, approx. 5 -6 feet of 3/8" capillary string balled into a one foot mess and an unknown length of cap string hanging below lubricator. Pulled an additional length of cap string out before shutting down for the evening. 15:30 16:00 0.50 SECURE WELL AF Secure wellhead, lay down lubricator, sign out, turn in work permit, leave location. Report Date: 8/27/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish —595' of 3/8" capillary string. Ops Trouble - Start Time . End Time Our (hr) Opt Code Activity Code Status code , • Com 08:30 09:00 0.50 SAFETY MTG AF Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Special emphasis on hand safety, stop the job authority and communications since this was such an unusual job 09:00 09:30 0.50 RURD SLIK AF Rig up slickline unit, crane truck and lubricator to fish cap string 09:30 11:30 2.00 RUNPUL SLIK AF Pull 35 foot section from well. Operator did not leave enough distance from stopping point to bump up point to close wireline BOP's. Forced to cut cap string with Swab Valve and then attempt to go back in and latch onto top of fish below swab valve. Could not latch onto top of fish, fish slipped out of upper Master Valve. Will have to rig up tool string to go into hole and find top of fish. 11:30 16:30 5.00 RUNPUL SLIK AF ' Run into hole with cap string grab tool. Set down at 9909' MD. Engage fish, pick up additional 30# of weight. POOH At surface - pulled fish into lubricator, cut approx. 35 feet, shut in below cut, bleed off pressure, break lubricator, remove that portion of fish, reset lubtricator,equalize, engage fish, pull up into lubricator, cut fish, repeat 20 times. Estimated length fished at 350 feet. Roughly 250 feet remaining. 16:30 16:45 0.25 RURD SLIK AF Break lubricator at top of BOP's, lay back lubricator,rig down wireline truck and crane 16:45 17:00 0.25 SECURE WELL AF Secure wellhead for evening, turn in work permit, sign out and leave location. Report Date: 8/28/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline (0.160" unit) to fish -245' of 3/8" capillary string i Ops -' ' . Trouble StartTime End Time Dur (hr) Ops Code . ' Activity Code Status' ..Code - Com .. 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Empasized the need to focus on the job. We have been on this location all week, it is getting old, we want to have the weekend off, but we need to keep the focus on the job. 08:00 08:30 0.50 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Pressure test lubricator to 3000# - test good. www.peloton.com Page 8/12 Report Printed: 6/13/2011 " M Marathon O0ations Summary Report by Job (MARATI101\1) mpany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB -Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:30 10:00 1.50 RUNPUL SLIK AF Run into hole with LIB, excentralizer to determine shape of fish on bottom. OD of LIB is 2.75 ". Tool set down at 10,051' MD. Module #5 flapper is located at 10,052 MD. POOH At surface, LIB has no marks on face. Appears to have flapper ring impression around circumference of face of LIB. 10:00 11:30 1.50 RUNPUL SLIK AF Run into hole with 2.62" OD LIB. Excentralizer is 2.72' OD. Set down at 10,051. POOH No marks on face of LIB. Some small marks on circumference. 11:30 13:00 1.50 RUNPUL SLIK AF Run into hole with 2.55" LIB and roller bogey's that are 2.63 "OD. Set down at 10,143'MD (top of Module 4). Had to pull 3000# to pull off bottom. POOH. Decentralizer will not fit through restriction at 10,051 (Module 1 flapper). At surface - Twisted cap string at side of the hole. 13:00 15:30 2.50 RUNPUL SLIK AF Have machine shop turn down no go to 2.63" OD. Run into hole with spear, no go, roller bogeys and shear up jars. Tag fish at 10,143 and chase it down to 10,250' MD. Engage fish, pull tight - 3000 #, shear off and POOH. 15:30 17:00 1.50 RUNPUL SLIK AF Run into hole with down shear jars and latch onto fishing neck. Work fish and pull out of hole. 17:00 17:15 0.25 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. 17:15 17:30 0.25 SECURE WELL AF Secure wellhead for evening, tum in work permit, sign out and leave location. Pressure on wellhead 1100 #. Report Date: 9/14/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish —300' of 3/8" capstring. RIH w/ baited 2.50" LIB on 2.63" OD decentralizer and sat down @ 9937' MD RKB. WT and won't pass, POOH (no marks on LIB). RIH w/ 2.50" DD bailer and passed through tight spot and sat down © 10,132'. WT and sticky, POOH- nothing in bailer. RIH w/ RB baited wire grab and 2.64" no -go, tag fish @ 10,132'. WT and engage fish, pull up to 3200# and sheared pin, POOH. RIH w/ 2.50" JDC and engage fish, WT and pull up to 3000# and lost fish. WT w/ no luck, POOH. RIH w/ RB baited wire grab and 2.64" no-go, tag fish © 10,126'. WT and engage fish, pulling up to 3800# before shearing pin. POOH. RD Pollard for night. . Ops Trouble • , , Start Time End Time Dur (hr) Ops Code- Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Held PJSM w/ Pollard and operator. Discussed job procedures, incident reporting, and manlift operations. Obtained safe work permit. 08:00 10:00 2.00 RURD SLIK AF RU 0.160" slickline unit and equipment. MU lubricator and tool string (1.75" RS, KJ, RB, 15' x 2" stem, RB, KJ, RB, OJ, LSSJ, RB, KJ) and stab on well. 10:00 10:15 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 10:15 11:15 1.00 RUNPUL SLIK AF RIH w/ tool string and 2.50" LIB on a 2.63" decentralizer, baited on a 2.50" RB to 9937' MD RKB and sat down. WT and wouldn't pass. POOH- no marks on LIB. 11:15 11:30 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 11:30 12:15 0.75 RUNPUL SLIK AF RIH w/ same tool string and 2.50" DD bailer. Passed tight spot no problem, sat down © 10,132' and WT. No progress, but sticky- POOH. Nothing in bailer. 12:15 12:30 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 12:30 13:30 1.00 RUNPUL SLIK AF RIH w/ same tool string and 2.50" RB baited 2.64" no go sub, and wire grab. Tag fish © 10,132', WT and engage fish. Pull up to 3200# to confirm and sheared pin. POOH. 13:30 13:45 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 13:45 14:45 1.00 RUNPUL SLIK AF RIH w/ same tool string and 2.50" JDC, latch fish at 10,121' and pull up to 3000# before slipping off. Attempt engaging fish several times with no luck, POOH. 14:45 15:00 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 15:00 16:15 1.25 RUNPUL SLIK AF ' RIH w/ same tool string and 2.50" RB baited 2.64" no go sub, and wire grab. Tag fish © 10,126', WT and engage fish. Pull up to 3800# to confirm and sheared pin. POOH. 16:15 16:45 0.50 RURD SLIK AF RD slickline truck and equipment for night. Secure well, sign out, and leave location. www.peloton.com Page 9/12 Report Printed: 6/13/2011 ' O0ations Summary Report by Job ,r uamw_ »J Marathon � Qi1COmpeny Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB -Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Daily Operations Report Date: 9/15/2010 Job Category: R &M MAINTENANCE 24 Hr Summary RU Pollard wireline. RIH w/ 2.50" JDC and latch bait sub @ 10,129' MD RKB. One hit on oil jars @ 2300# and lost fish. WT and attempt to engage fish, no luck - POOH. RIH w/ 2.62" LIB and 2.65" no -go sub. Sat down hard @ 10,129', POOH- LIB shows one rolled edge, capstring appears to be curled around ID of tubing. RIH w/ 2.50" RB baited '/2" rod center spear and no -go sub to 10,134' and engage fish. Confirm set several times by pulling 4000 #, sheared off. RIH w/ 2.50" JDC and latched bait sub © 10,129'. One hit on oil jars @ 2300# and lost fish. WT and attempt to engage fish, no luck- POOH. RIH w/ 2.50" RB baited '/2' rod center spear and no -go sub to 10,132' and engage fish. Getting good bites and holding 4000 #, one jar lick @ 2000# and appeared to shear tool, POOH. Tool did not shear, bait sub still present- spear heavily scratched up from capstring fish. RIH w/ 2.50" RB baited pigtail spear and no -go sub to 10,131' and engage fish. Confirmed latch by pulling 4000# several times, attempt to shear off w/ 3 jar licks @ 3000# and came free. Bait sub to surface with no fish. RD Pollard. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Held PJSM w/ Pollard and operator. Discussed weapons policy, job operations, and muster areas. Obtained safe work permit. 08:00 08:15 0.25 RURD SLIK AF RU 0.160" slickline unit and equipment. PU lubricator and tool string (1.75" RS, KJ, RB, 15' x 2" stem, RB, KJ, RB, OJ, LSSJ, RB, KJ) and stab on well. 08:15 08:30 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 08:30 09:45 1.25 RUNPUL SLIK AF RIH w/ tool string and 2.50" JDC, latch bait sub @ 10,129' MD RKB. One hit on oil jars @ 2300# and lost fish. WT and attempt to engage fish, no luck - POOH. 09:45 10:00 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 10:00 10:45 0.75 RUNPUL SLIK AF RIH w/ tool string and 2.62" LIB and 2.65" no -go sub. Sat down hard @ 10,129', POOH- LIB shows one rolled edge, capstring appears to be curled around ID of tubing. 10:45 11:00 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 11:00 12:00 1.00 RUNPUL SLIK AF RIH w/ tool string and 2.50" RB baited '''A" rod center spear and no -go sub to 10,134' and engage fish. Confirm set several times by pulling 4000 #, sheared off. POOH. 12:00 12:15 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 12:15 13:30 1.25 RUNPUL SLIK AF RIH w/ tool string and 2.50" JDC and latched bait sub @ 10,129'. One hit on oil jars CO 2300# and lost fish. WT and attempt to engage fish, no luck - POOH. 13:30 13:45 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 13:45 15:00 1.25 RUNPUL ' SLIK AF RIH w/ tool string and 2.50" RB baited 'A" rod center spear and no -go sub to 10,132' and engage fish. Getting good bites and holding 4000 #, one jar lick @ 2000# and appeared to shear tool, POOH. Tool did not shear, bait sub still present- spear heavily scratched up from capstring fish. 15:00 15:15 0.25 TEST BOPE AF PT lubricator to 2500psi w/ methanol. Good test. Dump to well. 15:15 16:30 1.25 RUNPUL SLIK AF RIH w/ tool string and 2.50" RB baited pigtail spear and no -go sub to 10,131' and engage fish. Confirmed latch by pulling 4000# several times, attempt to shear off w/ 3 jar licks @ 3000# and came free. Bait sub to surface with no fish. 16:30 18:00 1.50 RURD SLIK AF RD slickline truck and equipment for night. Secure well, sign out, and leave location. Report Date: 10/14/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish -300' of 3/8" capstring. RIH w/ baited 2.50" LIB on 2.63" OD decentralizer Start Time End Time Dur (hr) Ops Code , Activity Code " , Status.' - Code ' • . Com 07:30 08:00 0.50 SAFETY MTG AF J Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Empasized the need to focus on the job. We have been on this location all week, it is getting old, we want to have the weekend off, but we need to keep the focus on the job. 08:00 10:00 2.00 RURD SLIK AF Rig up crane truck, wireline valves, wireline truck and tool string 10:00 10:30 0.50 TEST BOPE AF Pressure on wellhead is 1900 #. PT wireline valves and lubricator with methanol to 3100# - test good. www.peloton.com Page 10/12 Report Printed: 6/13/2011 M Marathon O ations Summary Report by Job • M ARATHO N ® Oil Cotmpany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 10:30 12:00 1.50 RUNPUL SLIK AF MIRU Pollard wireline (0.160" wire) to fish —300' of 3/8" capstring. RIH w/ baited 2.50" LIB on 2.63" OD decentralizer. Hit bridge at 9950' MD. Appears to be flapper ring of Module 6. Multiple attempts to get through. POOH to check LIB. At surface, no marks on LIB face. 12:00 13:00 1.00 RUNPUL SLIK AF RIH with 2.70 swedge and 2.73 centralizer. No problems getting past sticky module at 9950. Problems appears to be a length issue. Decentralizer will not work in long string, possibly if knuckle joints above and below decentralizer. Go down past 10,000 feet. POOH. Prepare to run into hole with single spang spear and no go 13:00 14:30 1.50 RUNPUL SLIK AF RIH with single shaft spear made from spang jar and 2.65 NO GO. No issues going thru 9950 module flapper. Engage fish at 10,151. Pull up to 3250# tension several times, fish pulled loose each time. Continue working tool. POOH to check spear. 14:30 15:30 1.00 RUNPUL SLIK AF RIH with double shaft spear and barbs perpendicular to shafts. Slight bobble on tension weight at 9951 feet MD flapper. Engage fish again at 10146 -151 feet. Pull tension up to 4000 # but fish appears to be sliding off barbs. POOH At surface, marks on barbs and shaft where engaged fish. Capillary string may be fairly straight and not sprialed inside casing 15:30 16:15 0.75 RURD SLIK AF Rig down and lay back lubricator, crane truck and wireline unit for evening 16:15 16:30 0.25 SECURE WELL AF Secure well for evening, turn in work permit, sign out and leave location. Report Date: 10/15/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish —300' of 3/8" capstring. RIH w/ baited dual shaft spear and 2.65" NO GO. Multiple fishing attempts. Got onto fish but it released from spear multiple times. We did get one 3 foot section out of the well in late afternoon and did move the fish uphole some distance before losing it. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in , hold PJSM - topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Empasized the need to focus on the job. Vetco gray is on location greasing wellhead valves, so we will let them maintain our tree first, then continue with our job. 08:00 09:00 1.00 RURD SLIK AF Rig up slickline truck, crane and lubricator. Make up tool string and pressure test lubricator to 3000# - good test 09:00 10:30 1.50 RUNPUL SLIK AF Run in hole with dual shaft spear, shear up tool and 2.65 NO GO. Engage fish at 10,145' MD. Pull up to 4000 #, tool sheared. POOH. At surface - confirmed shear. 10:30 12:00 1.50 RUNPUL SLIK AF Run in hole with shear down tool and jars to pull up fish. Engaged fish at 10,142. Pulled up 2500# and spear pulled loose. Tried to re- engage fish unsuccessfully. POOH 12:00 13:00 1.00 RUNPUL SLIK AF RIH with 2.70 LIB and 2.73 centralizer. Set down at 10,145' MD. POOH At surface - multiple balled up pieces around circumference against pipe wall. No marks in center 13:00 14:00 1.00 RUNPUL SLIK AF RIH with single shaft center spear, up shear tool and 2.65 NO GO. Engage fish at 10,145 feet MD. Pull up 4000# and up shear appeared to shear. Tried to set down two more time but no apparent engagement. POOH At surface - spear barbs had not gotten under cap string ball. Marks on paint showed we needed one more inch to get under cap string. Added weight to tool string. Prepare to RIH 14:00 15:00 1.00 RUNPUL SLIK AF RIH with same tool string but additional high dense weight. Engage fish at 10,145 feet MD, pull up to3000# and pull fish up to 10,134' MD. At that depth, stuck in hole, either pull free from spear or sheared up -shear tool. POOH At surface - 2 1/2 feet of cap string in spear. Short upside down J at top and straight 2 foot section crimped at bottom that probably goes into another ball 15:00 16:00 1.00 RUNPUL SLIK AF RIH with center shot spear with 45 degree phasing of barbs around shaft. Engaged fish 100 feet higher than where we thought the lower section broke off. Engaged at 10,032 feet MD, pulled up and started dragging it out of the hole. POOH At surface - fish disengaged on way out of hole. 16:00 17:00 1.00 RUNPUL SLIK AF RIH with same spear and BHA.. Engage fish at 10,151'- seemed to be pushing downhole. Multiple engagements and pull free events. Finally engaged fish, pulled 4000# and sheared up shear tool. POOH www.peloton.com Page 11/12 Report Printed: 6/13/2011 0) Marath on Oiations Summary Report by Job • Companr Well Name: STERLING UNIT 41 -15 Qtr/Qtr, Block, Sec, Town, Range Field Name License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 17:00 18:00 1.00 RUNPUL SLIK AF RIH with downshear tool BHA to jar on fish. Engage fish at 10,151 feet MD, pull up 2500 #, jar fish, lost fish. POOH 18:00 18:30 0.50 RURD SLIK AF Rig down slickline unit, crane truck and lubricator 18:30 18:45 0.25 SECURE WELL AF Secure well for evening, sign out, turn in work permit and leave location Report Date: 10/19/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish —300' of 3/8" capstring. Attempt to engage fish, truck malfunction, damage crane, major incident. Remove truck and crane for repairs Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:30 09:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips,,trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule. Empasized the need to focus on the job. Also, assigned a Stop the Job assignment drill to SASS. 09:00 10:30 1.50 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Pressure test wellhead equipment to 3000# - test good 10:30 11:30 1.00 RUNPUL SLIK AF RIH with center shaft spear, 2.65 No Go centralizer and up shear tool. Engage fish at 10,050 and chase downhole to 10,141. Multiple pulls and releases, Pull up to 3000 #, slack off, Pull up to 3000# and Truck brakes released, truck was pulled into crane truck. Major incident. - NEAR MISS - w High POTENTIAL 11:30 13:30 2.00 SAFETY SD TA ESSI Truck brakes released, rolled over chocks, cable tension pulled the slickline truck into the crane truck with damage to the crane truck. Crane truck needs to be recertified, slickline truck needs to have brakes worked on and wheel chocks need to be improved 13:30 14:30 1.00 RUNPUL SLIK AF Release spear from fish. Attempted to shear off from fish but fish slipped off when jars hit. POOH. Spear has some damaged barbs 14:30 15:00 0.50 RURD SLIK AF Rig down crane truck, lubricator and slickline truck. 15:00 15:15 0.25 SECURE WELL AF Secure well for evening, turn in work permit, sign out and leave location Report Date: 12/9/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Expro Wireline to run camera or Gamma Ray / CCL OpsCode' Activity Code. Status Code Troubl Start Time End Time Our (hr) y Corn 08:00 08:45 0.75 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM Topics discussed slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. Shared near miss that happened the previous day while driving. Emphasized need to focus on current job. 08:45 11:00 2.25 RURD ELEC AF Rig up wireline truck, crane truck and lubricator. Pressure test wellhead to 2000# - test successful. 11:00 14:30 3.50 RUNPUL ELEC AF RIH with camera. Fluid level at 1158' MD. Log no good after entering fluid column due to opaque fluid. POOH 14:30 17:00 2.50 RUNPUL ELEC AF RIH with CCL / weight bars. Set down at 10,140' MD correlated to Expro CBL dated 9 -05 -2007. This is the collar for the 8 foot lifting pup at the top of Module 4. Spud an additional 5 -7 times with no changes. Log up to 9700' MD. POOH 17:00 17:30 0.50 RURD ELEC AF Rig down wireline unit, crane truck and lubricator. 17:30 18:00 0.50 SECURE WELL AF Secure wellhead, sign out, turn in safe work permit, leave location www.peloton.com Page 12/12 Report Printed: 6/13/2011 A • Marathon O1ations Summary Report by Job (NAlf,A11711o) a OilCompany Well Name: STERLING UNIT 41-15 QtrlQtr, Block, Sec, Town, Range Field Name I- icense # State /Province Country 6009005N010W01 STERLING HELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB Casing Flange Distance (m) KB Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Daily Operations Report Date: 11 /9/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish — 300' of 3/8" capstring Ops Trouble Start Tune End Time Dur (hr) Ops Code Activity Code Status Code Com 1000 10:30 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, hold Empasized the need to focus on the job as this is ow first snowfall of the season. The plows have made-the pad very slick. Eight bags of sand in back of my truck. Used two to sand around location before sanding truck gets here, Also, assigned a Stop the Job assignment drill to Mike. 10:30 13:30 3.00 RURD SLIK AF Rig up crane, lubricator and wireline truck. Pressure test wellhead to 3000# - test successful, Sand around wellhead, shovel snow. 13:30 15:00 1 50 RUNPUL SLIK AF Run in hole with spear. Engage fish at 10,141, pull 1000# fish released. Multiple attempts to engage fish, no further engagements. POOH to check marks on spear. On surface, shear up tool has come apart. The housing above the spring has unscrewed itself (threads backed off) and the set screw was not set into the groove. 15:00 16:30 1.50 RUNPUL SLIK TS MDLG Run in hole with LIB to determine position of spring and shroud while waiting for magnet and overshot tool. At surface, appears to be cap string fish looking up. Spear and shear tool below top of fish. Bottom of spear is on 18 inches below 2.65 " OD no go. NO Go is below top of cap string? 16:30 16:45 0.25 RURD SLIK TS MDOT Rig down slick line unit, crane truck and lubricator 16:45 17:00 0.25 SECURE WELL TS MDOT Secure wellhead for evening , turn in work permit, sign out and leave location Report Date: 11/10/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) to fish — 300' of 3/8" capstring Ops Trouble Start Time End Time Our thr) Ops Code Activity Code Status Code Com 08:30 09:00 0.50 SAFETY MTG TS MDOT Arrive location, sign in, receive work permit, hold PJSM - Topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 09:00 10:00 1.00 RURD SLIK TS MDOT Rig up crane truck, lubricator and slickline unit. Pressure test lubricator to 2500# - test successful. RIH 10:00 11:00 1.00 RUNPUL SLIK 'TS MDOT Run magnet into hole to try and retrieve spring and shroud cover over spring from backed off shear up tool. Engage top of fish at 10,046 POOH. At surface, magnet was covered with metal shavings. 11:00 12:30 1.50 RUNPUL SLIK TS MDOT Run in hole with sucker rod spear and 2.65" OD centralizer no go. Engage fish with spear at 10,137' MD. Pull 1000# and lose weight, Try to re- engage fish, chase fish down to 10,141' MD. Multiple engagements, pulls but loss of weight above 1000# tension. POOH. At surface, marks on tip of spear, no engagement of barbs. 12:30 13:30 1.00 RUNPUL SLIK TS MDOT RIH with LIB. Set down at 10,143' MD. POOH. At surface, cap string and top of fishing tool appear to be alongside each other. Pollard wants to go into hole with alligator grab 13:30 15:00 1.50 RUNPUL SLIK TS MDOT RIH with alligator jaw grab. Set down at 10,143' MD. Pull 1500 #, work tool, pull 1500 #, lost weight, come out of hole. At surface, grab brought out shroud and spring. We can now go in with overshot to grab body of shear up tool that came apart. 15:00 16:00 1.00 RUNPUL SLIK TS MDOT RIH with overshot to fish "Shear Up" tool body attached to spear. Tried to engage top of fish at 10,149'MD but could not get over top of fish body. Ring below spring may be in way along side Shear UP body. POOH At surface - marks on lips of overshot makes it appear that "Shear Up" body is cocked over to side of hole (Not Centered). 16:00 17:00 1.00 RUNPUL SLIK TS MDOT RIH with LIB to look at top of fish. Tag top of fish at 10,149' MD. POOH. At surface - top of fish nearly centered in casing, pin looking up. Will try smaller OD overshot on next trip tomorrow. '17:00 17:15 0.25 RURD SLIK TS MDOT Rig down slickline, lay back lubricator and crane. cap wireline BOP's 17:15 17:30 - 0.25 SECURE WELL TS MDOT Secure wellhead, sign out, turn in work permit, leave location Report Date: 11/11/2010 Job Category: R &M MAINTENANCE ]24 Hr Summary MIRU Pollard Wireline (0.160 "wire) www.petoton.com Page 1/7 Report Printed: 6/9/2011 A ig Marathon Oillations Summary Report by Job • ® OiVCompany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name 1 e ense # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start tune End Time Dur (tir) Ops Code Activity Code Status Code Corn 0830 09:00 0 50 SAFETY MTG TS MDOT PJSM - Topics discussed - reviewed JSA's, assigned jobs, overhead loads, pinch points, slips, trips, falls, egress, muster area, emergency numbers, emergency vehicles, hand injuries, PPE requirements. Emphasized unusual job, stop points to evaluate steps moving forward, stop the job authority and three second rule 09:00 10:00 1 00 RURD SLIK TS MDOT Rig up slickline unit, crane truck and lubricator Pressure test lubricator to 3000# - test successful 10:00 11:00 1 00 RUNPUL SL IK TS MDOT Run into hole with centralized slimhole magnet to try and pick up ring that may be alongside Shear Up housing. Set down on fish at 10,149' MD. Set down / pick up 10 times POOH. At surface, magnet covered with shavings. 11:00 1200 1.00 RUNPUL SLIK TS MDOT Run into hole with slimhole overshot. Tagged top of fish at 10,149' MD Pulled approx. 1500# and lost weight. Set down and picked up with no weight increase POOH At surface, grapple had engaged fish but released. 12:00 13:30 1.50 RUNPUL SLIK TS MDOT RIH(3) with same slim hole overshot - changed out grapple to .75 " ID. Work tools. Engage fish @ 10151' wlm. Pull up to 2400 lbs. Jar up a couple times. Pull fish up hole and work to 9828'. Fish begins coming up hole w/ 50Ibs over pull. POOH. Recover RB and ring, baited spear w/ approx 1' of 3/8" cap string ball. 13:30 15:00 1.50 RUNPUL SLIK AF RIH(4) w/ wire grab to engage cap string. Tag fish @ 10157' wlm. Work tools Hit jars. Pulls free. Hangs up in perfs of modules 5 & 6. POOH. OOH. Recover 1' ring of 3/8" tube. Fish looks like it broke off straight. 15:00 16:00 1.00 RUNPUL SLIK AF RIH(5) w/ 2.61" LIB "baited ". Set down. LIB hangs up. Must have gone beside fish. Work tools. One jar lick and jars free. POOH. OOH. Left LIB down hole. 16:00 17:00 1.00 RUNPUL SLIK AF RIH (6) w/ JDC.Engaged LIB fish, jarred free and POOH. 17:00 18:00 1.00 RUNPUL SLIK AF RIH with spear and Shear Up tool. Engage cap string fish at 10,159' MD. Pull up 1500 #, lose, re- engage multiple times..Final time engaged, pulled fish up 2 feet and then pull tight, jar, reset jar, jar. Final pull was 3100 #, jar and shear off fish. POOH 18:00 18:15 0.25 RURD SLIK AF Rig down slickline unit, crane truck and lay back lubricator. 18:15 18:30 0.25 SECURE WELL AF Secure well for evening, sign out , turn in work permit and leave location Report Date: 11/12/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard Wireline (0.160" wire) ; Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, hold PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:30 1.50 RURD SLIK AF Rig up crane truck, slickline truck, lubricator, rebuild packoff. Pressure test lubricator to 3000# - test successful 09:30 13:00 3.50 RUNPUL SLIK AF RIH with Shear Up tool to latch onto fishing spear. Engage fishing neck at 10,153. Pull up and jar, repeat. Fish appeared to move uphole 2 feet. Continue pull up, jar, reset, pull up, jar multiple times. Fish appears to be very solid. May need to get bigger wire onto location in order to get fish free. Will jar until 11:30 am and then release from fish. Gained about 5 feet total in 13/4 hours of jarring on fish. Release from fish by spudding down, shear pin and POOH 1 13:00 14:30 1.50 RUNPUL SLIK AF RIH (2) w/ same. Engage fish @ 10153' wlm. PUH to 3300 lbs. and pull free. OOH. Recover 6" circular piece of 3/8" cap string bent back on itself. 14:30 15:30 1.00 RUNPUL SLIK AF RIH (3) w/ 2 -1/2" RB to 10160' wlm. Work tools. Spear released or Shear Up released. POOH At surface - clean spear, no pieces. 15:30 16:30 1.00 RUNPUL SLIK ' AF RIH with same spear. Engage fish at 10,140', push down to 10,160'. Pull fish up to 10,130' before fish is stuck in casing. Pull, jar multiple times. Shear off of fish. POOH. At surface, Shear Up tool has separated as designed. Fishing neck is looking up for next week. 16:30 16:45 0.25 RURD SLIK AF Rig down wireline unit, crane truck and lubricator. www.peloton.com Page 2/7 Report Printed: 6/9/2011 63 Marathon O aborts Summary Report by Job • ____ Oil WeII Name: STERLING UNIT 41 -15 g Qtr /Qtr, Block, Sec, Town, Range Field Name - License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) 'Ka-Ground Distance (m) Spud Date Rio Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Mart Time End Time Dur (hr) Ops Cade Activity Code Status Code Corn 1645 17 0.25 SECURE WEl I. AF Secure wellhead, pressure test night cap, Sian out, turn in work permit and leave location. Report Date: 11/16/2010 Job Category: R&M MAINTENANCE - 24 Hr Summary MIRU Pollard Wireline (0.160 "wire) Ops Trouble , Start Time End Time Dur (hr) 1 Ops Code Activity Code Status Code Com 07:30 08 0.50 SAFETY MTG AF PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:30 1.50 RURD SLIK AF Rig up lubricator, crane and slickline unit. Pressure test lubricator to 3000# - test successful '09:30 11:00 1.50 RUNPUL SLIK AF Run shear down tool to engage fish and spear on bottom. Engage fish at 10,153' MD. Multiple pull, jar, reset, pull, jar events. It appears to have pulled fish uphole 4 feet by jarring. Continue working fish. Pull 4000 #, three inch section of fish came free or broke off. POOH At the surface, the three section of cap string was wrapped around shaft and one barb. 11:00 12:00 1.00 RUNPUL SLIK AF (2)RIH with LIB. Tagged top of cap string at 10,159' MD. Cap string appears to be vertical 12:00 13:00 1.00 RUNPUL SLIK AF (3)Run in hole with roller dog grab with 2.5" funnel donut in front of grabs. Tag fish at 10,159' MD. Tension 50# over pickup weight. Set down multiple times. No changes. POOH At surface - no fish 13 :00 14:00 1.00 RUNPUL SLIK AF (4) RIH with spear. Engage fish at 10,161' MD. Multiple pulls up to 2000 #, slack off tension. Released from fish (Shear Up) POOH 14:00 15:30 1.50 RUNPUL SLIK AF (5) RIH with Shear Down tool. Engage fish at 10,156' MD. Multiple sequences of pull, jar, reset jars. It appears that we made 2 feet. Need to cut wire so that we do not fatigue wire across sheaves. Down Shear from fish and POOH. 15:30 17:00 1.50 SERVIC EQIP AF Cut 0.160" wireline so that it does not fatigue where it had been going over sheaves under high tension during fishing and jarring operations. Cut 150 feet of wire. Rebuild packoff 17:00 17:15 0.25 RURD SLIK AF rig down methanol pump truck 17:15 17:30 0.25 SECURE WELL AF Secure wellhead for evening. Pressure on wellhead 1350 #. Sign out, turn in work permit, leave location Report Date: 11/17/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard Wireline (0.160' wire) Ops Trouble Start Time End Time Dur (Er) Ops Code Activity Code Status Code ' Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in,receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed • JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:00 1.00 RURD SLIK AF rig up crane truck, lubricator and wireline truck. Pressure test lubricator to 3000# - test successful. 09:00 10:00 1.00 RUNPUL SLIK AF (1) Run in hole with Shear Down tool to engage fishing neck. Engage fish at 10,155' MD. Pull 3400 # tension, jar and fish released. POOH. At surface, four inch circular piece of capillary string wrapped around shaft and across one barb. 10:00 11:00 1.00 RUNPUL SLIK AF (2) RIH with Shear Up tool and spear. Engage fish at 10,157' MD. Pull, relax tension multiple times. Pull up to 2400 #, shear off tool. POOH 11:00 12:00 1.00 RUNPUL SLIK AF (3) RIH with Shear Down tool. Engage fishing neck at 10,151' MD. Pull up tension, jar, reset, pull up tension to 3800# and something came loose when jars went off. Line weight approx. 50 # over hanging weight. POOH. At surface no fish 12:00 13:00 1.00 RUNPUL SLIK AF (4) RIH with Shear Up tool and spear. Engage fish at 10,160' MD. Multiple pulls, relax, pulls. Shear off of fish and POOH www.peloton.com Page 3/7 Report Printed: 6/9/2011 e Marathon O IosSumrnaryReport by Job MA N ) OilCompany Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name _ license # State /Province Country __` 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start lame End Time Dur {hr) Ops Code Actnaty Code Status Cone _ Com 1300 15:00 2.00 RUNPUL SL IK AF (5) RIH with Shear Down tool. Engage fish at 10,156' MD. Multiple pulls, jar, reset jars, pulls Put tension varied from 3400 4000 #. Tool appeared to pull free or cap string broke again POOH. At surface, spear pulled free, no fish 15:00 16:00 1.00 RUNPUL SLIK AF (6) RIH with 1/2 spang jar spear to verify that perforations are not hanging up fishing tool Engage fish at 10,160. Pull tension but spear releases multiple times. POOH to change track to original spear 1600 17:00 1.00' RUNPUL SLIK AF (7) RIH with original spear to engage fish. Spear set down at 10,147' MD which is 13 feet above last run in hole. Pulled up 1500# tension and tool pulled free. Last tool came out of the hole and possibly had some mud on it Wellhead pressure is down to 1300 # and fluid level is approx. 2200 feet. 17:00 17:45 0.75 RURD SLIK AF Rig down slickline unit, crane truck and lubricator 17:45 18:00 0.25 SECURE WELL AF secure well for evening, sign out, turn in work permit, leave location Report Date: 11/23/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:30 1.50 RURD SLIK AF Rig up conventional slickline unit, crane truck and lubricator. Offload big crane, braided line unit . Prepare to go into hole to hook onto fish. Pressure test lubricator to 2500# - test successful 09:30 11:00 1.50 RUNPUL SLIK AF 1) Run in hole with LIB - 2.70" ID. Engage fish at 10,161' MD. Set down, appeared to go alongside fish, pulled tension to 2500 #, jars went off and released from engagement. POOH. At surface, no marks on LIB 11:00 12:00 1.00 RUNPUL SLIK AF 2) RIH with spear to engage fish. Engage fish at 10,167' MD. Multiple pulls, re- engagements. Shear off using Shear Up tool. POOH 12:00 14:00 2.00 RUNPUL SLIK AF 3) RIH with Shear Down tool and jars. Engage fish at 10,165' MD. Multiple tension pulls, jar, re -set jars, pulls. Broke 4 inch piece off on final pull. POOH i. 14:00 15:00 1.00 RUNPUL SLIK AF 4) RIH with redressed,spear, 2.64" No Go and Shear Up tool. Engage tool at 10,167' MD. Multiple pull and release sequences. Re- engage fish and pull. Something pulled loose. Attempt to drop back down to fish but something dragging. POOH At surface, another short 4 inch section of control line. 15:00 16:30 1.50 RUNPUL SLIK AF 5) RIH with spear and Shear UP tool. Engage fish at 10,170' MD. Pull fish up to 10,167' MD then pulls tight. Pull up to 2500# tension twice then shear off. POOH At surface, spear pulled free. 16:30 17:00 0.50 RURD SLIK AF Rig down slickline unit, crane truck and lubricator 17:00 17:15 0.25 SECURE WELL AF secure well for evening, sign out, turn in work permit and leave location Report Date: 11/24/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 08:30 0.50 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Pressure test lubricator to 3000# - test successful 08:30 10:00 1.50 RUNPUL. SLIK AF 1) Run into hole with spear (sucker rod shaft with barbs rotated 360 degree around shaft ), Shear Up tool and 2.64" OD No Go. Engage fish at 10,167' MD. Multiple engagements, pull tension, slip off and re- engage. Final time, pull up to 4000 #, slack off, pull up to 2500 #, Shear off and POOH www.peloton.com Page 4/7 Report Printed: 6/9/2011 I ! Marathon O ations Summary Report by Job 6 OilCo►npany Well Name: STERLING UNIT 41 - 15 Qtr/Qtr Block, Sec, Town, Range Field Name _`— License # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB- Ground Distance (m) Spud Date _ Rig Release Date 0.00 71.77 80.92 9.15 911/1998 9/9/2003 Ops Trouble Start lirne End time Dur (hr) Ops Gone Activity Ccde Status Code Cum 10'00 11:30 1 50 RURD SLIK AF Rig down slickline unit, lubricator and crane truck Start rig up braided line unit, larger crane and lubricator with grease injection flow tubes Change of plans Re -rig up conventional slickline unit. Tensil strength of capillary string is only 5500# new. Pressure test lubricator to 3000# - test successful 11:30 13:00 1 50 RUNPUL SLIK . AF 2) Run in hole with Shear Down tool Engage fishing neck at 10,163' MD Pull tension up to 4000# -jars hit and section broke loose. POOH At surface one of the heavy duty barbs broken off. No cap string 13:00 14:00 1 00 RUNPUL SLIK Al 3) Run in hole with original spear, 2.64 "OD No Go and Shear Up tool. Engage fish at 10,169' MD. Multiple pulls and releases Final pull up to 3800# and something came loose. Something appears to be dragging on tension device. POOH At surface, no pieces of fish. 14:00 15:30 1.50 RUNPUL SLIK AF 4) Change out spear, go to double spang jar shafts with barbs. RIH and engage fish at 10,169' MD. Multiple pulls and releases. Once latched onto fish, pulls up to 4000 #. Start jarring at 2500# up to 3000# before Up Shear released. POOH. 15:30 16:30 1.00 RURD SLIK AF Rig down slickline unit, crane truck and lubricator. Spot braided line unit and prepare to go into hole in the AM 16:30 16:45 0.25 SECURE WELL AF Secure wellhead for evening, sign out, turn in work permit, leave location Report Date: 11/25/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (Braided wire). Fished 50 feet 9 inches of capillary string fish. Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code . Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 10:00 2.00 RURD SLIK AF Rig up braided line unit, big crane and lubricator with grease injection. Pressure test lubricator to 2500# - test successful 10:00 15:30 5.50 RUNPUL SLIK AF RIH with braided line unit. Tag fishing spear top at 10,098' MD. (New logging unit, new cable, different measuring device). Pick up weight is 2100 #. Picked up and pulled tension, slacked off and repeated. Started at 3000# tension and worked up to 8100# tension (6000# tension on fish). Reset jars, jarred at 6500# tension. Checked pickup depth at 10,091' MD. Fish appeared to move uphole 7 feet. Pulled up to 7000# gross tension, jars hit and fish or part of it came loose. Pulled up and tension approx. 300 # over pickup weight. Tried to set down and fish would not slide back down hole. POOH At surface we had capillary string fish. We started cutting and pulling fish into lubricator, bleeding off pressure, remove fish, re- install lubricator, equalize pressure, repeat. Pulled approx. 44 feet of cap string from well. Attempted third pull and grapple did not engage cap string. When upper master released cap string it fell back into well. Due to holiday and time, proceeded to rig down for the weekend. Measured length of fish pulled from well was 50 feet 9 inches. 15:30 16:30 1.00 RURD SLIK AF Rig down braided line unit, lubricator with flow tubes and heavy duty crane. 16:30 17:00 0.50 SECURE WELL AF Secure well for weekend, sign out, turn in work permit and leave location Report Date: 11/30/2010 Job Category: R&M MAINTENANCE 24 Hr Summary MIRU Pollard wireline (0.160" wire) Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 08:30 09:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 09:00 10:30 1.50 RURD SLIK AF Start equipment, prepare rigup. Wind speed indicator, anemometer, has wind speed above 25 MPH with gusts to 34 MPH Wait 30 minutes, recheck. Wind speed building Shut down job for day. Maximum windspeed for manlifts is 25 MPH. www.peloton.com Page 5/7 Report Printed: 6/9/2011 S t Marathon Oat Jo ions Summary Report by b •awrtxor e Oil Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Name License # State /Province Country —`- 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB- Casing Flange Distance (m) KB-Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Ops Trouble Start Time End Time Dur iht) Ops Code Activity Code Status Code Com 10:30 11:00 0.50 SECURE WELL AF Secure wet for day, sign out, turn in work permit and leave location. Report Date: 12/1/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard Wireline (0.160" wire). Pulled 359 feet of 3/8" capillary string from wet. Centralizer and Fluid Control Valve are still on bottom. Ops Trouble Start Time End Time Du! thr) Ops Code Activity Code Status Code Com 0730 08.00 0 50 SAFETY MTG . AF Arrive- location, sign in, receive safe work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 10:00 2 00 RURD SLIK AF Rig up slickline truck, crane truck and lubricator. Pressure test to 3000# - test successful Joystick on manlift frozen, use Frost Fighter heater to thaw out joystick. 10:00 15:30 5.50 RUNPUL SLIK AF Run into hole with overshot to pick up fish dropped last week. Engage fish at 9832. Pulled 1500# and fish came free. Perforations in Module 6 are 9930 -40'. Good possibility of 100 feet of fish below our pickup point of 9832'. POOH At surface, pulled and cut 359' of 3/8" capillary string. Bottom of string shows where compression fitting had been installed but pulled off. Centralizer and Fluid Control Valve remain in hole. 15:30 16:30 1.00 RUNPUL SLIK AF RIH with LIB to determine bottom of hole and if possible top of fish. Set down at 10,168' MD. POOH At surface, one small ding on circumference, none on face of LIB 16:30 17:00 0.50 RURD SLIK AF rig down slickline unit, crane truck and lay down lubricator. Install nite cap and plug all bleed valves. 17:00 17:15 0.25 SECURE WELL AF Secure well for evening, sign out, turn in work permit and leave location Report Date: 12/2/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard Wireline (0.160" slickline) Ops Trouble Start Time End Time Dur (hr) Ops Code Activity Code Status Code Com 07:30 08:00 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed I JSA's, assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment - fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:30 1.50 RURD SLIK AF Rig up slickline unit, crane truck and lubricator. Work slowed down by sub zero temperatures. Work 1/2 hour then mandatory warm up period for 1/4 hour. Pressure test lubricator to 3000# - test successful 09:30 11:00 1.50 RUNPUL SLIK AF 1) Run 2.5" OD magnet and 2.62" OD No Go. Set down at 10,166' MD. POOH At surface, filings on magnet, some marks on circumference. 11:00 12:00 1.00 RUNPUL SLIK AF 2) RIH with 2.70" max OD swedge. Set down at 10,168' MD. Sticky, and whatever stopped tool appears to be moving uphole approx. 2 feet whenever we pull up on tool string. POOH 12:00 13:00 1.00 RUNPUL SLIK AF 3) RIH with spear grab made from spang jars. Engage fish at 10,166' MD. Pull up to 3400# twice, set jars, Shear Up released tool string. POOH 13:00 14:00 1.00 RUNPUL SLIK AF 4) RIH with Shear Down tool and jars. Engage fish at 10,166' MD. Try to engage fishing neck, push tool down to 10,171'MD. Could not engage fishing neck, POOH 14:00 15:00 1.00 RUNPUL ' SLIK AF 5) RIH with smaller OD Shear Down tool. Attempt to engage fishing neck. Multiple attempts. Appears to be stopping in perforations and pulling across perforations. POOH. At surface, no fish. 15:00 16:00 1.00 RUNPUL SLIK AF 6) RIH with same Shear Down Tool with knuckle joint just above tool. Set down at 10,167' MD. Unable to engage fish. POOH At surface, marks on high density weights approx. 2.5 feet above end of tool is possible wear on metal indicating dogleg. 16:00 17:00 1 00 RUNPUL SLIK ' AF 7) RIH with LIB and 5 foot high density weight below previous tool string. Try to verify dogleg. Set down at 10,169' several times. POOH 17:00 17:30 0.50 RURD SLIK AF Rig down slickline unit, crane truck and lay down lubricator 17:30 17:45 0.25 SECURE WELL AF secure well for evening, sign out, turn in work permit, leave location www.peloton.com Page 6/7 Report Printed: 6/9/2011 Marathon ions Summary Report by Job (uARAMOM il Company Well Name: STERLING UNIT 41 -15 Qtr /Qtr, Block, Sec, Town, Range Field Nome I icense # State /Province Country 6009005N010W01 STERLING FIELD ALASKA USA Casing Flange Elevation (m) Ground Elevation (m) KB Casing Flange Distance (m) IKB Ground Distance (m) Spud Date Rig Release Date 0.00 71.77 80.92 9.15 9/1/1998 9/9/2003 Daily Operations Report Date: 12/3/2010 Job Category: R &M MAINTENANCE 24 Hr Summary MIRU Pollard Wireline (0 160" wireline) Ops Trouble Start Time End Time Dur Mr) Ops Code Activity Code Status Code Com 07:30 0800 0.50 SAFETY MTG AF Arrive location, sign in, receive work permit, PJSM - Topics discussed - slips, trips, falls, pinch points, overhead loads, working in cold weather, reviewed JSA's; assigned jobs, active gas production pad, red lights for fire, blue lights for gas emission, sirens for audible, muster area, emergency numbers, emergency vehicles, emergency equipment fire ext., eye wash stations, buddy rule, three second rule. 08:00 09:00 1.00 RURD SL IK AF Rig up slickline unit, crane truck, lubricator and work string. Workstring is 1.5" max OD. Longest section is spang jars extended at 7 feet, each section has knuckle joints above and below Bottom of tool string is 1.5" LIB 09:00 10:30 1.50 RUNPUL SLIK AF * 1.) RIH with LIB on 1.5" tool string. Set down at 10,169' MD. Slight pull. POOH At surface, 2 marks on circumference. Appears to be casing collapse just below perforations in module4 10:30 11:30 1.00 RUNPUL SLIK AF 2.) RIH with 1.6" swedge. Set down at 10,169', unable to make any depth and actually losing depth on set down. POOH to check for marks on swedge. At surface, marks above max. diameter of swedge. Metal appears to be sand blasted. One small mark below max OD on swedge from setting down on something 11:30 13:30 2.00 RUNPUL SLIK AF • 3.) RIH with bailer to try and get sample. Set down at 10,174' MD. Spud and make it down to •10,176' MD. Spot tool across 10,170' for 5 minutes to check for crossflow. POOH At surface, nothing in bailer. Possible bright spots on metal in several spots across bailer. 13:30 14:30 1.00 RURD SLIK AF Rig down wireline unit, crane truck and lubricator. Release crew. 14:30 15:00 0.50 SECURE WELL AF Secure well, sign out, turn in work permit, leave location. www.peloton.com Page 7/7 Report Printed: 6/9/2011 • ~,:- ~, r " ~ `" ~, . ~~` ~": ;~~; . ~,~ ~" <A.~,. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:ltemp\Temporary Internet Files\OLK9\Microfilm_Marker.doc I~ o ~" DATA SUBMITTAL COMPLIANCE REPORT 7/20I2009 Permit to Drill 2070880 Weil Name/No. STERLING UNIT 41-15RD Operator MARATHON OIL CO MD 11655 ND 9517 Completion Date 9/12/2007 Completion Status 1-GAS Current Status 1-GAS API No. 50-133-20484-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATpN Types Electric or Other Logs Run: Quad Combo, Gamma Ray, CCL, CBL, PT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / T e Med/Frmt Number Name ~ca~e men~a No Start stop cri rzecervea commenrs ED C 15337 Report: Final Well R Open 8/23/2007 Final Well Report w/Mudiog PDF graphics, Daily Drilling Reports and LAS files. Wireline files in I LAS format. Nell CoreslSamples Information: Name ADDITIONAL II~FORM~TIO,N Well Cored? Y1~,~ Chips Received? Y~ Analysis KL~~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? "'~ N Formation Tops ~~ N Comments: ~ ~ Compliance Reviewed Bv• Date: ~ ~ ~Q,i~ ~ ~ M Marathon MARATHON Oil Company November 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Sterling Unit, Pad 43-9 Well: Sterling Unit 41-15RD (PTDY20~-98~ ~Q-1-o ~~ Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Attached for your records is the Report of Sundry Well Operations, 10-404, for SU 41- 15RD well. This report covers the work performed to run a 3/8" capillary string to mitigate water loading. The capillary string was installed on 11-03-08 and set at a depth of 10,400'. All work was completed under Sundry #308-334. SU 41-15RD is presently flowing at 1,555 mcf at 945 psi. Please call me at (907) 283-1371 if you have any questions or need additional information. Sincerely, , ~ ' ~ ~~ Kevin J. Ski a Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Current Well Schematic KJS ~ STATE OF ALASKA ~ - /~~ ALA~OIL AND GAS CONSERVATION COMMI~s10N REPORT OF SUNDRY WELL OPERATION~` ~~" 1. Operations Abandon Repair Well Plug Perforations Stimu #e Other ~ Install Capillary Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ String . 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: Development ^~ _ Exploratory^ 207-0880 ' 3. Address: p0 Box 1949 Stratigraphic ^ Service^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20484-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 245' (21'AGL) ' SU 41-15RD ' 8. Property Designation: 10. Field/Pool(s): ADL-2497 ~ Sterling Field / Beluga 8~ Upper Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 11,655'MD - feet Plugs (measured) NA true vertical 9,517' ND - feet Junk (measured) NA Effective Depth measured 11,585' ' feet true vertical 9,460' - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79" 20" 58' 58' 3,060 psi 1,500 psi Surface 2,292' 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,606' 3/-1/2" 71,632' 9,499' 70,160 psi 10,540 psi Liner Perforation depth: Measured depth: 9,930' - 11,527' (Gross) True Vertical depth: 7,969' - 9,403' (Gross) Capillary String 3/8" 2205 Stainless Steel 10,400' Tubing: (size, grade, & MD) Production String 3-1/2" L-80 11,585' Packers and SSSV (type and measured depth) NA NA 12. Siimulation or cement squeeze summary: Intervals treated (measured): Installed 3l8" Capillary String to a setting depth of 10,400' MD. Treatment descriptions including volumes used and final pressure: 73. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 945 2.7 0 2,055 Subsequent to operation: 0 1,555 1.5 0 945 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ - Service ^ Daily Report of Well Operations 16, Well Status after work: Oil^ Gas Q~ 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: 308-334 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician , Signature ~ Phone (907) 283-1377 Date November 12, 2008 Form 10-404 Revised 04/2006 _ , ,`; Submit Original Only ~~ • M Marathon Dperations Summaty Report ,,~,T„o„ ~~~ ~~~~ Well Name: STERLING UNIT 41-15 Report Date: 77C112008 Job Category: R&M MAINTENANCE 2lnrS~mmary MIRU BJ Dyna coil, run capillary string. S~rtTlne E~tlTtne D~r O CoOe F~cW Cotle oa ~i TroWkCOOe Canme~t 06:00 07:00 1.00 SAFETY MTG AF Held PJSM, discussed todays operaions, Safety hazardous around the weh head, cold work haxardous, overhead hazardous, working with main basket and others. Obtained work ermit. OT:00 08:00 1.00 RURD COIL AF Spot equipmerit, removed well house. Mu air conditioned und. Problem with swab vatve leaking to access tree cap. Called out Vetco to grease tree. 08:00 10:00 2.00 RURD COIL AF BJ Dyna coil services rigging up the 318" SS tubing to the injector. 10:00 11:00 1.00 RURD COIL AF PU injector with boom truck, connect the Chemical 8HA to end of the cap string under the injector. Chemical mandrel set to open at 4000 psig. Vetco could not qet the swab to hold. Shut weN in to access the tree connection. 11:00 13:00 2.00 RURD COIL TS MSCT MU the tree connection. Go to wetl w~h injector. Found the 31'8" dyna coil courrter is mounted to clase to the spool. Only option is to lay down the i'ector and have welder modif . 13:00 15:00 2.00 RURD COIL TS MSCT Lay down injector, secured well. Open well back up to production. 15:00 16:00 1.00 RURD COIL TS SCT Dyna Coil Crew removed the courrter arm to take to fab shop and fix. leaned up around well head. Released crew for day. Daily Operations Report Date: 77l3/2008 Job Category: R&M MAIHTENAHCE 2l M r S~mmary IRU BJ Dyna cal, run cap~lary string. StirtTlne E~OTInt Du 0 Cotle J~c1U C ~ ~~ Tro~Dk C e~t 08:00 09:00 1.00 SAFETY MTG AF Held PJSM, discussed todays operaions, Safety hazardous around the well eed, cold work hazardous, overhead hazardous, working wdh main asket and others. Obtained work rmit. 09:00 10:00 1.00 D OIL AF U injedor, new courder arm installed. BJ worked ai tFxottle cable for 1 our. PU injecta. Shut in swab valve to hook up tree connedion to cross ~er to pack off . Swab ~elve held. 10:00 11:00 1.00 RLN3D OIL AF the tree connedion. Go to weM +~h iryector, MIU pack off to tree. PT ree connection to 3500 psig. Good test. Open well. RIFI wdh 318" cap string wdh BHA chemical mandrel set a~t 4000 psig. 11:00 13:00 2.00 RK O~ AF ordinue down hole when tubing art 3400 psig, problem with the injector ocking, during reel stoppage because of brake issues on spool. Packoff or hain causing packoff hyd fluid to drip down beyond liner. kyedor rocks rd when injedor stops. NNNJ straps from bottom sides of the injector and strapped off to ground equipment to stab~ize the irye~tor. Still having roblems with the brake drum on trailer. 13:00 15:00 2.00 RK COIL AF ork capillary string down to 7151' KBD. Carwiot move the capillary sting up or down. Revi~w options decide to secured packoff on 3I8" cap string. Remove side of the injector and puMed the tubing out and layed the tubinq rcel on the trailer on the round. 15:00 16:00 1.00 RURD COIL TS MSCT Cleaned up equipmer~t around treiler unit. Secured misc to trailer and putled he truck and trailer off to side oi location. Drive the ather larger truck unR and spot up around tree. PU the reel and Iocate on back of truck. Decided o shut down operation for evening. Secured area around well head. BJ yne Coil left lease. www.peloton.com Report Prirrted: 77M712008 ~ IlAarathon ,~~ ; ~il Comp~nY Operations Summary Report Well Name: STERLING UNIT 41-15 7151', cor~tinue RIH wl load coil w/ 07:30 08:15 0.75 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discussed operatians, Safety hazards around the well head, cold work hazards overhead hazards workin wdh man-lift. Obtained work ermd. 08:15 09:15 1.00 RURD COIL AF Start equipmer~t. Split injector on Canadian unit. Install Dyna-Coil in injector. PU injector and "walk it down" the coil. 09:15 10:15 1.00 RURD COIL AF Carry injector to well head. Reconnect hydraulic pack-off. Release Ratagon. 2-3/8" cal and BHA hanging aLD 7151'. PU cal tubing 200' and make sure it is hanging free. 10:15 11:00 0.75 RK COIL AF RIH w/ 2-3f8" coil and BHA to 10,400'. 11:00 11:30 0.50 RK COIL AF Land coil ~10,400'. Install mechanical sl~s to land coil. Set hydraulic pack-off ~ 3000 psi. and set Rattigon. Reel off additional 100' of coil and cut. 11:30 11:48 0.30 RURD COIL ,~F RD Dyna-Coil unit off WH. PU coil for NS-1 and NS-3. 11:48 12:30 0.70 INSTAL SEQP AF Set well house over well head. Secure well head. Reconnect MEOH and ~errt Nnes. Electrician restores power to WH. 12:30 15:00 2.50 PUMP TRET AF RU pump on coil unit to fill Dyna-Coil w! foamer. 15:00 15:34 0.50 SECURE Ll AF Triplex foamer pump nat working properly. Switch to foamer skid to finish. RD and secure well. Turn in ermit and si out. Leave loc. www.peloton.com Report Prirrted: 71M1r2008 ~ 2~~-~8~ ` 50-133-20484-01-00 ~ AOGCC = ADL - 2497 BLM = A - 028063 _ 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N g 151 ° 01' 51.643" W ~d: 09:00 hrs 7/07/2007 Reached: 7/20/2007 a Released: 6:00 hrs 7/27/07 Tree cxn = 43/4" Otis Top of Cement 600' MD above 9-5/8" window 9-5/8" Casinq Window milled from 6,275' to 6,294' (MD) 5,611' to 5,624' (TVD) SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, T5N, R10W, S.M. Excaae Svstem Details - 6 Excape module system - fted control line for top 4 modules - Green control line for bottom 2 modules - Ceramic flapper valves below each module except for modules 1& 2. Perfs MD (RKB) (BeluaalTvonekl: Mod 6- 9,930' - 9,940' (Beluga) 9/11/07 Mod 5- 10,031' - 10,041' (Beluga) 9/11/07 Mod 4- 10,157' - 10,167' (Beluga) 9/11/07 Mod 3- 10,201' - 10,211' (Beluga) 9/11/07 Mod 2- 10,571' - 10,581' (Beluga) 9/10/07 17' - 11,467' - 11,480' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) Mod 1- 11,479' - 11,527' (Tyonek) 9/12/07 13' - 11,489' - 11,506' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) 318" 2205 Stainless Steel Top Bottom MD 0' 10,400' ND 0' 8,389' • Conductor 20" K•55 133 ppf PE ' '~ To~ Bottom ~ ~( MD 0' S8' ND 0' S8' '' Surface Casina 13-3/8" K-55 61 ppf BTC T9,Q Bottom MD 0' 2,271' ND 0' 2,270' Cmt wl 1186 sks of Class G, `.~ • y.~. _: .--L ~ ~. : J w~' ,~• - ~` ~~ ~ ~ • r,. : '•_ _ t ~ ~. -- ~ f~ _ ~ °' ~- =i ~; . ~,~ - .. =! ~ s I . _ a ,_ ~ ~ ~ f' ~ 3 -- ~ ~ ~~"... ~i = G ~; ~ ~ Intermediate Casinn 9-5/8" L-60 40 ppf BTC ~p Bottom MD 0' 6,281' TVD 0' 5,615' Cmt original well wl 2284 sks of class G. Production Tubina 3-112" L-80 9.3 ppf EUE To~ Bottom MO 0' 11,632' ND 0' 9,499' 8rd with 6.25" OD eontrolline protectors. 8-112" hoie, Cmt w/ 545 sks (176 bbis) 13.5 ppg Class G cmt lead and 1456 sks (300 bbls) 15.8 ppg Class G Excaoe Svstem Details - Ceramic flapper valves below each module as follows: Flaooers MD (RK6) TVD Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA J = ~~ ' „s Weatherford Float Collar j ~ s ~ 11,584' MD ' _ ~ Weatherford Float Shoe ;: ~ 11,621' MD ;~~ TD - 11,655' (MD) / 9,517 (ND) PBTD - 11,585' (MD) / 9,460 (ND) Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' -11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° I 100ft @ 2,785' Completion Fluid: 6°/a KCL An le/Perfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Revised by: Mike Sulley Last Revison Date: 11/6/2008 ~ ~~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~..e ~ ~ ~ ~-~ ~ ""t'~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~.. ~I.ASS~ ~II, ~D G~S COI~TSERQATIOI~T COMMIS5IOI~T Micha.el Darruneyer Production EngXneer Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 ~ SARAH PAL/N, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Sterling Gas ~eld, 'I~onek Undefined Gas Pool, SU 41-15RD Sundry Number: 308-334 Dear Mr. Damineyer: 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 shoum, 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 unl~ss rehearing has been requested. Sincerely, ~ Daniel T. Seamount, Jr. Chair DATED this ?`sday of September, 2008 Encl. ~o'~ - p~$ ~ ~ M Marathon MARATHON Oil Company September 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Sterling Unit, Pad 43-9 Well: Sterling Unit 41-15RD (PTD 2 0) Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~ ~~ ~~~ ~ _,~. ~~~ ~ ~ r~IC~~ ~Ila~-~~ Ai1 ~i ~a~ ~r~ns ~ .,.;,~~~< ;~:;; ~11~~~trr~~ ~p~`1-~ ~~ Marathon proposes to run a 3/8" capillary string in SU 41-15RD to mitigate water loading. Setting depth of the capillary string should be roughly 10,400' MD. Please find attached a 10-403, current wellbore diagram, and detailed operations program. If you have any questions or need further information please call me at (907) 283-1371. Sincerely, `..~~ C (~ Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice Current Well Schematic Detailed Operations Program cc: AOGCC Houston Well File Kenai Well File KJS MDD "°~~~ ~,/ . ~ ' ~ ~ STATE OF ALASKA 9~~ ~~~ ~ ~ ~~a ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~g~sk~ ~ii ~~~~ ~O~S, APPLICATION FOR SUNDRY APPROVALS~ ~~~~~' 2o aac 2s.2so (~~ A~hor_~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^~ Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ^ ~nstall 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 ~ 207-0880 ~ 3. Address: p0 BoX 1949 Stratigraphic ~ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20484-U1-00 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: ^ ~ SU 41-15RD ~ Spacing Exception Required? Yes No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~ -~A---0.28963- ~o[~pD~1•J~~ 245' (21'AGL)~ Sterling Field / Beluga & Upper Tyonek Pools 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,655'MD ~ 9,517' ND . 11,585' ~ 9,460'~ NA NA Casing Length Size MD ND Burst Collapse Structural Conductor 79" 20" 58' S8' 3,060 psi 1,500 psi Surface 2,292' 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,606' 3/-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,930' - 11,527' (Gross) 7,969' - 9,403' (Gross) 3-1/2" L-80 11,585' 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 ~ BOP Sketch ~ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: September 30, 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 Michael D. Dammeyer Title Production Engineer Signature ~ Phone Date (907) 283-1333 September 15, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30~ ~3 3 Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~` ~ ~' ~~~, ~~p ~~ 1~~~ APPROVED BY / Approved by: ~~ 2S ~ COMMISSIONER THE COMMISSION Date: ~ _ ~ Form 10-403 Revised 06/2006 y~;, g~, ,,,, J ~ ~'< " r~_, Submit in Duplicate ~ 2008 Capillary String Installation Page 1 ~ 2008 Capillary String Installation Program #2 KGF, SU, NGF KBU 24-7X - Requested KBU 14-6Y - Requested KBU 31-7RD - Requested SU 41-15RD - Requested FC 3 - Requested NS 3 - Requested NS 1 - Requested Obiective 1) Install six new CICM's (injection skids) with 545 gallon totes of foamer at wellheads. 2) Install capillary strings (3/8" 2205 0.049" WT) into seven wells for delivering foamer to alleviate liquid loading. Procedure Companies involved: BJDC, BJCS, UOSS, Big G Setting Setting String Estimated Depth Depth Spool Setting Fluid Maximum Tag Above Under PT Max Order Well Len th De th Level PerF De th De th Fill yyater Well Notes ID ran 1 KBU 247X 9000' 7965' 7850' 8141' 8165' 300' 115' Exca e 1.75 2 KBU 146Y 8000' 7050' 7000' 7138' 7132' 82 50' Exca e 1.69 3 KBU 31-7RD 8000' 7220' 7120' 7534' 7392' 172 100' 1.75 4 SU 47-15RD 12000' 10400' 10300' 11506' 11498' 98 100' Exca e 1.75 5 FC 3 10000' 2720' 2615' Gas from SS 7770' N~A 105' Lon strin 6 NS 3 11000' 9785' 9550' 10862' 10970' 1185' 235' 4-1/2" 2 7 NS 1 9000' 8733' None 8956' 10220' 1487 0 4-1/2" 2 Installation Procedure: 1) BJCS and ASRC: (PJSM & JSA~ a) Place 6 new CICM skids at listed wells (BJCS, Steve Bolton, 252-9864) - deliver with truck (Oilfield Hotshot Service, Billy Hill, 398-4827) - unload CICM from truck with loader (ASRC Hardline Group, Tony, 294-0548) - unbolt and remove CICM roof with loader and place 545 gal foamer tote with loader - replace CICM roof with boom truck (UOSS, Tom David) and bolt roof b) Install CICM internals (BJCS, Steve Bolton, 252-9864). 2) COGZ work order (contact Senette's ~ro_u~ a) Electrical hookup of CICM. b) Tubing hookup of CICM. ' ~ ~' 2008 Capillary String Installation Page 2 3) UOSS - pull well house 4) BJDC, UOSS (PJSM and JSA~: 1. Have on site: proper spool, Wayne's Well Head Adapter (long/short both), Sundry. Well Control Standards Sheet. Z. MIlZU BJ Dyna-Coil unit. 3. Shut swab valve, pull tree-cap flange, remove snap ring and OTIS blanking plug. Replace plug with WWHA (note o-ring). MU flange. 4. P/U Dyna-Coil injector with UOSS crane, install BJDC packoff assembly into 2-7/8" female connection. NOTE: a wrench or tongs may be needed to hold the adapter 5. Set Fluid Control Valve release (set based upon TVD, but OVER) 6. MU BHA with centralizers and secure to 3/8" string. 7. SHVT IN WELL AT WING VALVE to prevent BHA from traveling into flow-tee and down flowline. NOTE: Operator or Company Supervisor may bring well back on after string is below flow-tee 8. RIH to setting depth. 9. Set Rattiguns. Leave 1.5 times SITP (or greater per BJDC) on hydraulic pack off. 10. OPEN WELL TO PRODUCTION 11. Leave remaining spool of tubing outside of well in plastic tote for soap injection skid hookup. 12. Cap the tubing with a Swagelok cap, Swagelok valve, and pressure gauge and HP filter. 13. Lockout Swab, Upper Master and Lower Master as per Capstring Lockout Procedure. 14. Hookup injection line to CICM. NOTE: Start foamer at 1/2 gpd, slowly raising the level to planned rate as the week progresses. CHECK FOR FOAM RETURNS. 15. RDMO. Cleanup site. Sign-out. NOTE: When replacing well house, be careful of the tubing "bend" if it extends through the roof 5) UOSS - replace well house ~ , t~: 50-133-20484-01-00 >ertv Des: A - 028063 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N ~ 151° 01' S1.643" W d: 09:00 hrs 7/07/2007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Toa of Cement 600' MD above 9-5/8" window 9-5/8" Casinq Window milled from 6,275' to 6,294' (MD) 5,611' to 5,624' (TVD) SU 41-15RD Pad 43-9 2,327' FSL, 437' FEL Sec. 9, TSN, R10W, S.M. - 6 Excape module system - Red control line for top 4 modules -.% ~-- control iine for bottom 2 modules - Ceramic flapper valves below each module except fo~ modules 1& 2. Perfs MD (RK61 Beluaa/Tvonek): Mod 6- 9,930' - 9,940' (Beluga) 9/11/07 Mod 5- 10,031' - 10,041' (Beluga) 9/11/07 Mod 4 - 10,157' -10,167' (Beluga) 9/11/07 Mod 3- 10,201' - 10,211' (Beluga) 9/11/07 Mod 2- 10,571' - 10,581' (Beluga) 9/10/07 17' - 11,467'-11,480' (Tyonek) 9/22/07 (2-1J8", 6spf, 60° phasing) Mod 1- 11,479' - 11,527' (Tyonek) 9l12/07 13' - 11,489'-11,506' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) Weatherford Float Collar 11,584' MD Weatherford Float Shoe 11,621' MD Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' -11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° / 100ft @ 2,785' Completion Fluid: 6% KCL Angle/Perfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Prepared By: Kevin Skiba Last Revison Date: 7/31/2008 ~a~-n~oN Conductor 20" K-55 133 ppf PE T~ Bottom MD 0' S8' ND 0' S8' Surface Casina 133/8" K-55 61 ppf BTC Top Bottom MD 0' 2,27'I' ND 0' 2,270' Cmt wl 11 S6 sks of Class G, Intermediate Casina 9-5/8" L-80 40 ppf BTC To~ Bottom MD 0' 6,281' ND 0' 5,615' Cmt original well wl 2284 sks of class G. Production Tubinq 3-'ll2" L-80 9.3 ppf EUE To~ Bottom MD 0' 11,632' ND 0' 9,499' 8rd with 6.25" OD control line protectors. 8-1/2" hole, Cmt wl 545 sks (176 bbls) 13.5 ppg Class G cmt lead and 1456 sks (300 bbls) 15.8 ppg Class G cmt tail. Excaae Svstem Details - Ceramic flapper valves below each module as follows: Flappers MD (RKB) TVD Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA • M Marathon MARATHON Oil Company September 15, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 ~ Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~~' ~~.~~ ~EP ~ ~ ~t~C~ Reference: 10-404 Report of Sundry Well Operations ! ~~ ~~~ ~a°~; °~` ~ °- AI~s7~~~ ~?~ .. ~ t -,y,~;~,,r.,~ ~:~ Field: Sterling Unit ~~~'~ `'` `°~"` Well: Sterling Unit 41-15RD Dear Mr. Maunder: Marathon has elected to close out Sundry # 309-277 as a non-work sundry. The intended purpose of this sundry was to create a foamer injection path for SU 41-15RD by perforating one of its Excape system module tanks. BJ Dynacoil has made a crew available, for capillary string deployment, later this month on the Kenai Peninsula. The installation of a capillary string presents us with a more attractive foamer injection route option than the existing Excape system control line option approved under the current sundry. Along with closing out Sundry # 309-277, Marathon intends to submit a new Application for Sundry Approvals covering the capillary string installation request for SU 41-15RD. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ ` ~~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Sundry Report cc: Houston Well File Kenai Well File KJS ~ ~~ ~ ~ ~ _~~~ ~ STATE OF ALASI~ ~ ~p~lJ~ ALAS~OIL AND GAS CONSERVATIOI~ ~M, ~~I F REPORT OF SUNDRY WELL O~~~RA~ONS ~E .~ , . ;~~;~~;~~;~~ ' ,~ 'a.' i 1. Operations Abandon Repair Well Plug Perfor i ris ti ul~.tg , Other ~ Non-Work of ~ / Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ^ ~W iver Time Extension ~ ExCape Tank Change Approved Program ~ Operat. Shutdown ~ Perforate ^ Re-enter Suspended Well ~ perforation 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permitto Drill Number: ame: Development ^~ Exploratory^ 207-0880 ~ 3. Address: p0 BoX 1949 Stratigraphic ~ Service^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20484-01-00 7. KB Elevation (ft): 9. Well Name and Number: 245' (21'AGL) SU 41-15RD ~ 8. Property Designation: 10. Field/Pool(s): -"~4~ADLG?~oo~+fL9,,? Sterling Field / Beluga & UpperTyonek Pools 11. Present Well Condition Summary: Total Depth measured 11,655'MD ' feet Plugs (measured) NA true vertical 9,517' TVD ~ feet Junk (measured) NA Effective Depth measured 11,585' ~ feet true vertical 9,460' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 7g" 20" 58' 58' 3,060 psi 1,500 psi SurFace 2,292' 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,606' 3/-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 9,930' - 11,527' (Gross) True Vertical depth: 7,969' - 9,403' (Gross) Tubing: (size, grade, and measured depth) 3-1/2" L-80 11,585' Packers and SSSV (type and measured depth) NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): The Excape tank perforating work was canceled. 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 Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations 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: 308-277 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba ` Title Engineering Technician Signature ~ Phone (907) 283-1371 Date September 15, 2008 Form 10-404 Revised 04/200 ~ ~ ~ ~ ~ !~;' - ~ ~~- ~FP ~ ;. ~~~8 Submit Original Only ~~~ io~AL ~~~ ~ ~~ ~ ~. ~:' ~~ ~ ~ 4 ,~ 4 ' ~ t ~ ,~.._~ ~,. ~ ~..~ ~ ~ 9 M ~ ~ ; ~ -- ~ ~_;_ ,r k ~~~~ `'~ ~~ a ~~ ~ ~~~ ~ k ~ ~ `yy'„'~!' A.ek' ~. ~ p i„„~ tm.~ ~ `1 ~ ~.~ 4S f~'.',`.`~~ ,1 l, , . e ~ S. ,a . `~, ~~+ ~ ~ t ~ L_~ t. ~".3 L~ ~.~ l 11l l.J 1~..~ ~~~5 ALASH'i.~ OIL 1f1~TD G~S CON5ERQ'ATIOrIT CO1rII-IISSIOl~ Kevin Skiba Engineering Technician Marathon Oil Company PO Box 1949 Kenai AK 99611-1949 L J SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Sterling Field, Lwr. Beluga 'I~onek Undefined Gas Pool, SU 41-15RD Sundry Number: 308-277 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 provicling notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90'7) 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 ne~ 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, ~~'~'d~ / ~L DATED this ~? day of August, 2008 Daniel T. Searnount, Jr. Chair Encl. ~0~--fd~ ~ M Marathon MARATHON Oil Company July 31, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Sterling Field Well: Sterling Unit 41-15RD Dear Mr. Maunder: ~ Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~j ~~~~~ s } .'.'' ~, ~~ ..,, ~,a~ !'. .. _~ f ~ _~. ;1 ia ~J' b Rl~.~h=~~~~~ ~ ~.' ._ ~ _ .~~~-~~~~ ~ .,.. . >. ._ Fluids are currently infiltrating the wellbore of SU 41-15RD causing a decrease in gas production. Marathon requests permission to add perForations to SU 41-15RD well in an attempt to puncture the Excape tank above module #2. This will create a path to feed foamer into the wellbore to facilitate fluid removal. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, . ~ ~ ..L'•!J~ ' ~ Kevin J. Skiba Engineering Technician Enclosures: 10-403 Sundry Notice cc: AOGCC Work Scope Procedure Houston Well File Current Well Schematic Kenai Well File KJS DMD U " ~,o~ ~~~~~~~..%~~ ~ ~ ~~~ STATE OF ALASKA 4, ~ ~~~ ALAS~ OIL AND GAS CONSERVATION COMM SION ~' `=, ' fi~;~_ ~ p~ APPLICATION FOR SUNDRY APPROVA~~S ~ 20 AAC 25.280 ps 7S~ c~ ~I~ +~ t:::. ,~~~:, .~~.Rt?~} ~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ ~ W~N~r~ ;y~ Other ^ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ~ Pul~ Tubing ~ PerForate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: Marathon Oil Company 4. Current Wel! Class: 5. Permit to Drill Number: " Deveiopment ~; Exploratory ~ 207-0880 3. Address: p0 BOx 1949 Stratigraphic ~ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20484-01-00~ 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 ~ SU 41-15RD - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): A- 028063 A,dGOoOo? ~ 245' (21'AGL) Sterling Field I Beluga 8~ Upper Tyonek Pools 12• PRESENT WELL CONDITION SUMMARY Totai Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,655'MD ~ 9,517' ND i 11,585' - 9,460'~ NA NA Casing Length Size MD ND Burst Collapse Structural Conductor 79" 20" 58' 58' 3,060 psi 1,500 psi Surface y,2g2~ 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,606' 3/-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,930' -11,527' (Gross) 7,969' - 9,403' (Gross) 3-1/2" L-80 11,585' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: August 15, 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 , e e ~w ~ Date (907) 283-1371 July 31, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ., a Plug Integrity ~ BOP Test ^ Mechanicai Integrity Test ^ Location Clearance ^ Other: Subsequent Form Re uired: ~~y ~ /~ ` ~ APPROVED BY ~~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ v~ ~ ~~ ~~(~v ~ L ~~ _: ~ QF~ pUG 4 71008 Submit in Du ~icate Form 10-403 Revised 06/200 p' ~ • / ` MARATHON July 24, 2008 Marathon Oil Corporation Alaska Region SU 41-15rd WBS# Draft only Objective: Perforate the "Tank" in Excape Module #2 @ 10,568'-10,570' with 2' of 2" HSD guns loaded 6 SPF 60 degree-phased with RTG-2125-302LS charges and PX-1 firing head. Current status: Well is flowing-1.605 mmcf/d @ 837 psi FTP and producing 3-5 BWPD. Procedure: 1. MI diesel fueled man-lift and remove well house. MIRU Expro wire line service with full lubricator, pump-in sub, flow tubes, and pressure control equipment on 4- 3/4" Otis Tree cap. Hold PJSM. P Test lubricator to 3000 psi. RIH with 2.8" GR to 10,600' . 2. Pressure green Excape control line to 10,000 with Expro Excape pump unit. 3. Run correlation log thru Excape modules 1, 2, & 3. 4. RIH w/ 4' of 2" HSD guns loaded 6 SPF 60 degree-phased with RTG-2125-302LS charges. Index the top 2' of guns 30 degrees out of phase from the lower 2' of guns. Correlate Expro CBL/GR/CCL log depth to open hole logs. Pull up into position and shoot the upper 2' guns 10,568-10,570'(CH). If no pressure is lost from green control line, Pull up into position with the second 2' gun and shoot the same zone again. POOH. 5. RD Expro. 5. MIRU temporary foamer skid and begin injecting foamer down the green control line at rate specified by Mr. Clyde Willis at BJ Chemical Services. SU 41-15rd Add perfs ~ -CONTACTS Ken Walsh: Lyndon Ibele: 907-283-1311 (w) 907-394-3060 (c) 907-565-3042 (w) 907-748-2819 (c) Scott Szalkowski Clyde Scott: u 713-296-3390 (w) 713- 301-9834 (c) 713-296-2336 (w) Ninilchik Operators: 907-260-7660 or 907-567-3248 (Susan Dionne Pad) KGF Operators: 907-2831305 SU 41-15rd Add perfs , . ~ • ~: 50-133-20484-01-00 iertv Des: A - 028063 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N ~ 151 ° 01' 51.643" W i: 09:00 hrs 7/07I2007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Too of Cement 600' MD above 9-5/8" window 9-5/8" Casinq Window milled from 6,275' to 6,294' (MD) 5,611' to 5,624' (TVD) SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, T5N, R10W, S.M. - 6 Excape module system - Red control line for top 4 modules - Green control line for bottom 2 modules - Ceramic flapper valves below each module except for modules 1& 2. I Perfs MD IRKB) IBeluaa/Tvonekl: Mod 6- 9,930' - 9,940' (Beluga) 9/11/07 Mod 5 - 10,031' -10,041' (Beluga) 9/11/07 Mod 4- 10,157' - 10,167' (Beluga) 9/11/07 Mod 3- 10,201' - 10,211' (Beluga) 9/11/07 Mod 2- 10,571' - 10,581' (Beluga) 9/10/07 17' - 11,467'-11,480' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) Mod 1- 11,479' - 11,527' (Tyonek) 9/12/07 13' - 11,489' - 11,506' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) Weatherford Float Collar 11,584' MD Weatherford Float Shoe 11,621' MD Well Name 8 Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' -11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° / 100ft @ 2,785' Completion Fluid: 6% KCL Angle/Perfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Prepared By: Kevin Skiba Last Revison Date: 7/3112008 MARATNOM Conductor 20" K-55 133 ppf PE T~ Bottom MD 0' 58' ND 0' 58' SurFace Casina 133I8" K-55 61 ppf BTC To~ Bottom MD 0' 2,271' ND 0' 2,270' Cmt w/ 1186 sks of Class G, Intermediate Casins~ 9-518" L-80 40 ppf BTC To~ Bottom MD 0' 6,281' TVD 0' S,615' Cmt original well wl 2284 sks of class G. Production Tubinn 3-112" L-80 9.3 ppf EUE To~ Bottom MD 0' 11,632' ND 0' 9,499' 8rd with 6.25" OD control line protectors. 8-1/2" hole, Cmt wl 545 sks (176 bbls) 13.5 ppg Class G cmt lead and 1456 sks (300 bbls) 15.8 ppg Class G cmt tail. Excaoe Svstem Details - Ceramic flapper valves below each module as follows: Fla~oers MD 1RK61 ND Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA . ~ ~ ~. . nit #: 207-080 ~: 50-133-20484-01-00 iertv Des: A - 028063 21' AGL (245' KB Elevation) 314, 742.19 2,390,034.43 60° 32' 14.914" N ~ 151 ° 01' S1.643" W d: 09:00 hrs 7/07/2007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Too of Cement 600' MD above 9-5/8" window :~:9-5/8" Casing Window milled from 6,275' to 6,294' (MD) `"~~ 5,611' to 5,624' (TVD) Excaoe Svstem Details - 6 Excape modules placed - Red conWl line for top 4 modules - Green control line for bottom 2 module - Ceramic Napper valves bebw each module except for modules 1 8 2. Perfs MD (RKB11BeluaalTvonekl: Module 6- 9,930' - 9,940' (Beluga) 9111/07 Module 5- 10,031' - 10,041' (Beluga) 9/11107 Module 4- 10,157' - 10,167' (Beluga) 9/11107 Module 3- 70,20'I' - 10,211' (Beluga) 9/11l07 Module 2- 10,571' - 10,581' (Beluga) 9110I07 17' - 11,467'-11,480' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) PROPOSED - 10,568' - 10,570' ( Beluga)(2 1/8" 6spf, 60° phasing) Modulel - 11,479'-11,527' (Tyonek) 9112/07 13' - 11,489' - 11,506' (Tyonek) 9/22/07 (2-1/8", 6spf, 60° phasing) Tagged fill @10,136' KB (1/8/08) Excaae Svstem Detai ls - Ceramic flapper valves below each module as follows: Flaopers MD (RKB) ND Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA Weatherford Float Collar 11,584' MD Weatherford Float Shoe 11,621' MD Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' - 11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° I 100ft @ 2,785' Completion Fluid: 6% KCL Angle/Perfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Revised By: Mike Sulley Last Revison Date: 7/24/2008 Conductor 20" K-55 133 ppf PE To~ Bottom MD 0' S8' TVD 0' S8' Surface Casina 133/8" K-55 61 ppf BTC T~ Bottom MD 0' 2,271' TVD 0' 2,270' Cmt w11186 sks of Class G, Intertnediate Casinsa 9-518" L$0 40 ppf BTC ~p B om MD 0' 6,281' TVD 0' 5,615' Cmt original well wl 2284 sks of class G. 3-1@" L-80 9.3 ppf EUE Tgp B om MD 0' 11,632' TVD 0' 9,499' wfth 6.25" OD control line protectors. 8-1/2" a, Cmt wl 545 sks (176 bbls) 13.5 ppg Class G lead and 1456 sks (300 bbls)15.8 ppg Class G *~u ~ ~ ~ '~ • • Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 . Kenai, AK 99611 MARATHON O~I Company Telephone 907/283-1371 Fax 907/283-1350 ~ ~ ~ ~_ ~ : ~ ~~~~~~" ~....w~t,., July 31, 2008 ~!~!~ Q ~ 20~~ Mr. Tom Maunder Alaska Oil & Gas Conservation Commission ~~ `~ - - ~ ~ ~ ~~=~ ~ ~5`:.. . w. ~.~~ . . ;~~:;. 333 W 7th Ave . .;. Anchorage, Alaska 99501 c~ ~ D~~ Reference; 10-404 Report of Sundry Well Operations d~~~ Field: Sterling Field Well: Sterling Unit 41-15RD Dear Mr. Maunder: The AOGCC approved Marathon's requested to install a velocity string in SU 41-15RD on April 4, 2008 under Sundry #308-083. Evaluation of our current capillary string program indicates that SU 41-15RD has the potential to unload fluids more effectively utilizing foam injection. Based on this information, Marathon has decided not to install the velocity string at this. A new Application for Sundry Approvals 10-403 will be submitted covering our present work intentions. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ..~~~y~ ~ ~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Kenai Well File KJS .r~' Gy>'- ~ STATE OF ALASKA ~ Og ALA~ OIL AND GAS CONSERVATtON COM~ION REPORT OF SUNDRY WELL OPERATIONS p ;. ~n ~ ;~ ~~~ ~~~ ~~~ ~'~ #~; `.~ l~ ~ C~.'L~ i' ~` ~1I~a~~'~;I ~ ~'~;~ ~~":,. ~~ '3''~~~3~~ 1. Operations Abandon Repair Well Plug PerForations Stimulate Other ~, f~g~p,~rk of ~ Pertormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time E~ension ^ VeloCity String Change Approved Program ~ Operat. Shutdown ^ Perforate [] Re-enter Suspended Well ~ Installation 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Dritl Number: ame: Development Q Exploratory~ 207-0880' 3. Address: PO Box 1949 Stratigraphic ^ Service ~ 6. API Number: Kenai Alaska, 99611-1949 '~ 50-133-20484-01-00~ 7. KB Elevation (ft): 9. Well Name and Number: ~ 245' 21'AGL - ~~ SU 41-15RD ~ 8. Property Designation: '., `,:, ~ ' 1Y~Field/Pool(s): • A- 028063 ~... ~~~P ~ ~ Sterling Field / Beluga 8~ Upper Tyonek Pools 11. Present Well Condition Summary: ~F~ ~` 1`" ~~ l Total Depth measured 11,655'MD~ feet Plugs (measured) NA true vertical 9,517' ND ~ feet Junk (measured) NA Effective Depth measured 11,585' - feet true vertical 9,460'- feet Casing Length Size MD TVD Burst Collapse Structural Conductor ~g" 20" 58' 58' 3,060 psi 1,500 psi Surface 2,292' 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' S,750 psi 3,090 psi Production 17,606' 3/-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation depth: Measured depth: 9,930' - 11,527' (GrOSS) - True Vertical depth: 7,969' - 9,403' (Gross) Tubing: (size, grade, and measured depth) 3-1/2" L-80 11,585' 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: NA • Subsequent to operation: NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ~ Development Q Service ^ Daily Report of Well Operations 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: 308-083 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba ~ Title Engineering Technician ~ Signature ,~ Phone (907) 283-1371 Date July 31, 2008 ~ Form 10-404 Revised 04/2006 ~ ~ 1~~i T` ~''~~~~~~ Submit Original Only ~ i F~,.~~I~~IV~~ ~l`~ ~ ~~ r ~ ~~ r'~~ "~g ~ ~°`~ ,`"~ ~ ~, ~. _.~ ~_~ ~ , .. ~ ~ f ~~ ~ ~~ ~~~ ~ ;~-- ~j~ ~}~~ ~~~ ~~ ~~g ~~_~s~'~ _` ~ ~ a ~ } ~ ~ ~ , i x. a,..~~~' ~,.~~ ~:.a ~.i ~ ~ : ~.~ ..~ ~_.~ l._~:~ ~~. l ~~~ ~_ ` '~.~1 ~.tr^~ AL.AS~A ~IL ~D G~-.S CO1~T5ERQATIOI~T COMbIISSIOI~T Michael Mullin Senior Production Engineer Marathon Oil Company PO Box 1949 Kenai, Alaska 99611-1949 ~~ I ~ SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Sterling Gas Field, Sterling Gas Pool, SU 41-15RD Sundry Number: 308-083 Dear Mr. Mullin: 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, conta.ct the Commission's petroleum field inspector at (90'~ 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 worlflng 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. Seamcunt, Jr. , t Chair --7 J 'i DATED this ! day of April, 2008 Encl. ~O'~- -a~ * ~ ~ ~ ~ ~ Marathon MARATHON Oil Company March 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Sterling Unit Well: Sterling Unit 41-15RD Dear Mr. Maunder: u Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~CEIVED M,AR ~, ~ ~00~ Ala~~ c~ii ~ Gas Corts. ~ctmmissi~an Arxtrorage We propose to run a 1.75" velocity string in SU 41-15RD to a setting depth of 11,450'. We anticipate increasing the well's production by improving ifs ability to unload water. Attached for your records are the 10-403 Sundry Notice, operational program, wellbore diagram, and proposed wellbore schematic. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, ~ -~%~~ Kevin J. Skiba Production Technician Enclosures: 10-403 Sundry Notice Operations Procedure Well Schematic Proposed Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS MAM ORIGINAL .~ STATE OF ALASKA ~ ~~~~I V ~~ ~ I~' ALA OIL AND GAS CONSERVATION COMM~I~ION ~Q~ ~~" R~82Q ,~ APPLICATION FOR SUNDRY APPROVALS M~ ~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ai er ~ r ~ Alter casing ~ Repair well ~ Plug Perforations ^ Stimulate ^ Time Ex e Install ' Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ Velocity String 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: ~ Development ~ Exploratory ~ 207-0880 3. Address: p0 Box 1949 Stratigraphic ~ Service ~ 6. API Number: Kenai Alaska, 99611-1949 50-133-20484-01-00 ' 7. If perforating, Gosest 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 ^ o ~^ SU 41-15RD . 9. Property Designation: 10. KB,Elevation (ft): 11. Field/Pool(s): , A- 028063 ADLoODo?~q 245' (21'AGL) Sterling Field / Beluga 8~ Upper Tyonek Pools 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,655'MD ' 9,517' TVD ~ 11,585' ~ 9,460' ` NA NA Casing Length Size MD ND Burst Collapse Structural Conductor 79" 20" 58' 58' 3,060 psi 1,500 psi Surface 2,292' 13-3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' 5,615' 5,750 psi 3,090 psi Production 11,606' 3/-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): . 9,930' - 11,527' (Gross) 7,969' - 9,403' (Gross) 3-1/2" L-80 11,585' Packers and SSSV Type: Packers and SSSV MD (ft): NA NA 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory [] Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 4, 2008 g p 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 Michael A. Mullin Title Senior Production Engineer Signature Ph e (907) 283-1337 Date March 17, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ " Q Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ~ Other: ~~~ ~~ ~ ~'_'~ ~~"~ ,~.~-~~ Subsequent Form Required: ~,.~o ~ ~ ~ 1G~~~: ~k~~ ~~ ~ ~~1~~ A roved b : APPROVED BY ~ l(~, COMMISSIONER THE COMMISSION Date ~ ~ ~ pp y : Form 10-403 Revised 06/2006 Submit in Duplicate ~ ~ MARATHON ~ 14 March 2008 Marathon Oil Company Alaska Region SU 41-15rd Sterling Unit V-string Program WBS# W0.08.17294.CAP.001 History: Due to liquid loading this well was not able to hold line pressure and continue to produce. While in production the water that was made to surface also brought in sand into the wellbore. The well must be controlled to around 1.8MM to prevent sand entry and does not stay unloaded at that rate. The installation of the v-string will increase the average rate from 1.2MM to 1.8MM. Objective: Run 1.75" CT Velocity String. Procedure: 1. Move and RU CTU ~--~ ~~v ~~~ ~T ~~ ~5~ p~r ~~S\•a ~. ~~~`~ ~t(.3 2. Test BOP. NOTE: Notify Jim Regg with AOGCC 24 hours prior to BOP Test! ! 3. Run 1.75" v-string to 11.450' RKB with well flowing. V-string will be composed of 2 pieces around 6000' attached by a external double connector. 4. Pressure up v-string and blow out double plug. 5. Open well through v-string and close backside. 6. Allow well to clean up flowing only v-string. 7. Lock out tubing wing valve and tree master valve and make clear to production that the well is not to be flowed up the tubing, only the v-string. 8. RD and release CT Contact: Mickey Mullin 398-9954 C~ • Ken Walsh 283-1311 ~ ~: 50-133-20484-01-00 ~ertv Des: A - 028063 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N ~ 151 ° 01' 51.643" W d: 09:00 hrs 7/07/2007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Top of Cement 600' MD above 9-5/8" window SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, TSN, R10W, S.M. ~, 9-5/8" Casinq Window milled from 6,275' to 6,294' (MD) 5,611' to 5,624' (TVD) - 6 Excape modules placed - Red conVol line for top 4 modules - Green control line for bottom 2 module - Ceramic flapper valves below each module except for modules 1 8 2. Perfs MD IRKB11Beluaa/Tvonekl: Module 6- 9,930' - 9,940' (Beluga) 9111I07 Module 5- 10,031' - 10,041' (Beluga) 9111/07 Module 4- 10,157' - 10,167' (Beluga) 9111/07 Module 3- 10,201' - 10,271' (Beluga) 9111/07 Module 2 - 10,571' -10,581' (Beluga) 9/10/07 17' - 11,467' - 11,480' (Tyonek) 9/22/07 (2-118", 6spf, 60° phasing) Mod~lel - 11,479'-11,527' (Tyonek) 9It2/07 13' - 11,489' - 11,506' (Tyonek) 9I22107 (2-1/8", 6spf, 60° phasi~g) Excaae Svstem Detaiis - Ceramic flapper valves below each module as follows: Flapaers MD (RKB) ND Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA Weatherford Float Collar 11,584' MD Weatherford Float Shoe 11,621' MD Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' - 11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° / 100ft @ 2,785' Completion Fluid: 6% KCL AnglelPerfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Prepared By: Kevin Skiba Last Revison Date: 11/29/2007 ~ Conductor 20" K-55 733 ppf PE 7~o Botlom MD 0' S8' TVD 0' 58' Surface Casina 13-3/8" K-55 67 ppf BTC Too Bottom MD 0' 2,271' ND 0' 2,270' Cmt wl 1186 sks of Class G, Intermediate Casina 9-5/8" L-80 40 ppf BTC T~ Bottom MD 0' 6,281' TVD 0' 5,615' Cmt original well wl 2284 sks of class G. Production Tubina 3-112" L-80 9.3 ppf EUE TOP Bottom MD 0' 11,632' TVD 0' 9,499' Brd with 6.25" OD control line protectors. 8-112" hole, Cmt wl 545 sks (176 bbis)13.5 ppg Class G cmt lead and 1456 sks (300 bbis) 15.8 ppg Class G cmt tail. • ~: 50-133-20484-01-00 iertv Des: A - 028063 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N ~ 151 ° 01' 51.643" W i: 09:00 hrs 7/0712007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Toa of Cement 600' MD above 9-5/8" window 9-5t8" Casinq Window milled from 6,275' to 6,294' (MD) 5,611' to 5,624' (TVD) Proposed SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, TSN, R10W, S.M. - 6 Excape modules placed - Red control line for top 4 modules - Green control line for bottom 2 module - Ceramic flapper valves below each module except for modules 1& 2. Perfs MD (RKBI IBeluqalfvonekl: Modu~e 6- 9,930' - 9,940' (Beluga) 9I11/07 Module 5- 10,031' - 10,041' (Beluga) 9111/07 Module 4- 10,157' - 10,167' (Beluga) 9I11107 Module 3 - 10,201' -10,211' (Beluga) 9111/07 Modute 2- 10,571' - 10,581' (Beluga) 9/10I07 17' - 11,467'-11,480' (Tyonek) 9/22I07 (2-1/8", 6spf, 60° phasing) Modulel~- 11,479'-11,527' (Tyonek) 9/12/07 13' - 11,489'-11,506' (Tyonek) 9f22/07 (2-1/8", 6spf, 60° phasing) Conductor 20" K-55 133 ppf PE To~ Bottom MD 0' S8' TVD 0' S8' Surface Casinq 13-3I8" K-55 61 ppf BTC T~ Bottom MD 0' 2,271' ND 0' 2,270' Intermediate Casinq 9-518" L-80 40 ppf BTC To~ Bottom MD 0' 6,281' rvo o• s,s~s~ Production Tubin~ 3-112" L-80 9.3 ppf EUE T~o Bottom MD 0' 11,632' TVD 0' 9,499' 8rd with 6.25" OD control line protectors. 8-112" hole, Cmt wl 545 sks (176 bbls) 13.5 ppg Class G cmt lead and 1456 sks (300 bbls) 15.8 ppg Class G cmt Wil. Velocity Stri~g 1.75"" QT-800 coiled tubing T~ Bottom MD 0' 11,450' (below mod t) Excaae Svstem Details - Ceramic flapper valves below each module as follows: Flaaaers MD (RKB) ND Module 6 - 9,941' 7,975' Module 5 - 10,042' 8,065' Module 4 - 10,167' 8,178' Module 3 - 10,211' 8,218' Module 2 - NA Module 1 - NA Weatherford Float Collar 11,584' MD Weatherford Float Shoe 11,621' MD Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' - 71,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: 2.17° / 100ft @ 2,785' Completion Fluid: 6°/a KCL Angle/Perfs: 25 deg Dated Completed: 9/10/2007 Ground Level (MSL): 224' Prepared By: Kevin Skiba Last Revison Date: 11/29/2007 ~ ~ • M Marathon MARATHON Oil Company March 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-421 Open Flow Potential Test Report Field: Sterling Field Well: Sterling Unit 41-15 ReDrill Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEIVED MAR 0 7 2008 qlaslca Oil 8~ Gas Cons. Commission Anchorage Enclosed is the 10-421 Open Flow Potential Test Report for SU 41-15RD well. This well was completed into the Beluga and Upper Tyonek formations. We can not vary SU 41- 15RD's rate or pressure since it is operating at line pressure. Therefore, the information provided in this report was obtained from a one point test. Please contact me at (907) 283-1371 if you have any questions or require additional information. Sincerely, ,,e,~-~,,~, • ~ Kevin J. Skiba Production Technician Enclosures: 10-421 Open Flow Report cc: Houston Well File Kenai Well File KJS -- STATE OF ALASKA ~~~ MAR 0 7 2008 ALA~ OIL AND GAS CONSERVATION COM~SIO ~ica Oil 8 Gas Cons, C+ammisslon GAS WELL OPEN FLOW POTENTIAL TEST REPO~horac~e 1a. Test: ~ Initial Annual Special 1b. Type Test: Stabilized Non Stabilized Multipoint ^ Constant Time ~ Isochronal ~ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Marathon Oil Company September 10, zoo~ Zo~-osa 3. Address: PO BoX 1949 6. Date TD Reached: 12. API Number: Kenai, Alaska 99611-1949 July20, 2007 50- 133-20484-01 4a. Location of Well (Govemmental Section): 7. KB Elevation (ft): 13. Well Name and Number: SurFace: 2,953' FNL, 4,843' FWL, Sec. 9, T5N, R10W, S.M. 245' above MSL Sterling Unit 41-15 ReDrill Top of Productive Horizon: 8. Plug Back Depth(MD+TVD): 14. Field/Pool(s): 715' FNL, 3,641' FWL, Sec. 15, T5N, R70W, S.M. 11,585' MD 9,460' ND Sterling Field / Total Depth: 9. Total Depth (MD + TVD): Beluga & Upper Tyonek Pools 474' FNL, 4,194' FWL, Sec.15, T5N, R10W, S.M. 11,655' MD 9,517' ND 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 314,749 Y- 2,390,123 Zone- 4 A- 028063 TPI: x- 318,600 Y- 2,387,552 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 319,160 Y- 2,387,126 Zone- 4 6 module Excape completion 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 3-1/2" 9.3 # 2.992" 11,632' 9,930' 11,506' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. NA - - - 20. Packer set at ft: 21. GOR cf/bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): NA - - 0.56 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): ^ Tubing ^~ Casing 153.3 F° 1348 psia @ Datum 9,460' TVDSS 14.73 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO2: % N2: % HZS: Prover: Meter Run: Taps: 9,930' MD 7,965' ND 0.56 0.215 0.171 0 Facility 26. FLOW DATA TUBING DATA CASING DATA No. Prover Choke Line X Orifice pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow Size (in.) Size (in.) Psig Hw F° psig F° psig F° Hr. ~• 3.826" X 1.00 1099 3.74 79 - - - - 4.00 2• X 3. X 4. X 5. X N Basic Coefficient 24 H h~ Pressure Flow Temp. Gravity Factor Super Comp. Rate of Flow o. ( - our) Pm Factor F g Factor Q u{cfd ~ Fb or Fp Ft Fpv 1. 91.80 17.189 1113.73 1.00 1.336 1.1433 1578 2. 3. 4. 5. Temperature for Separator for Flowing No. Pr T Tr z Gas Fiuid Gg G 1. 1.65 460 7.34 0.765 0.56 NA 2. 3• Critical Pressure 673.1 4. Critical Temperature 343.2 5. Form 10-421 Revised 1/2004 ~~~~ ~ N L~4`3~RSE SIDE ~~ Submit in Duplicate ~1 ~~j P~ 3315 Pc2 10987435 ~f P~ 25. I hereby certi Signed AOF (Mcfd) 1,726 Remarks: that the foregoing is true a correct to the best of my knowledge. y 4~ Title Production Technician n 0.750 Date 3/6/2008 No. Pt Pt~ Pc2-Pt~ PW Pv~ Pc2-Pu~ PS Ps2 Pf -Ps2 ~ • 1114 1240394.5 2. 3. 4. 5. DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= /1 Z dimensionless Ft Flowing temperature facto~, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (siope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma Citv, Oklahoma. Form 10-421 Revised 1/2004 Side 2 ,~ ~~~ `~I -- ~ ~ ~7 CoMPANY: Marathon Oil Company EXPRO ,- ' FIELD: Sterlin Unit 9 , SURFACE WELL TESTING REPORT f ~ : ~~~ '~~'~~1. ~EASE: Sport Lake ' :: ' . .. ...`. . .. ...... ~: PIthRGY7:{iX . : ~~ wE~~#: 41-15RD Support 43-9x co. ReP.: Mickey Mullins > A> 1T+~ > p .TF.iT _ .. ': <: F~1N~4R~S::: t) . :;.1~~k.1.#i~AIJ.~...1~€?I I~ES T~t3... >:::: 5 R: : ,::,;. ~+P~1E!~YT~?. .~~~R i NS : J[?tT.~? ................::......... Td7A .................... ~ G ......~~....:.:::;. » C5 .>:....:::;;:.::;:....T...T~1f«::UVl~T&Ti:::>:"i::::::.....:::>:. ; : ,:. :. ;.. . ...... ;:;<. >: ~lild(" ut!HT ~3-9x. ; Cfi#Q~~ BSUCI ;St"rR`TIC.. . C~1~F::: 'fE1U1P" CXRI~IC~ C,A~:G~FfAY t'.,~AS ~ki~ iG~S ~lljVli!l1: ;;1~1~1`:; G1'1~QI~Cf~~$ ' I#,Z<? f~7~ .CU~Ato1:: mla!' hr snp,: , . >: .... • s~G .:: e ~ iG ~ ~d€hs o) iG) ;: . :: ~nsHQ€7 ;: e :.. ~~s;; ~ s:atr~~._¢:: : .::.;:.;.: ..:.. ::; i?~scff4t :::: . . ::;. ms m wE4 b~~ : Open 41-15Rd to Inlet of Separator 12111/2007 6:15 3390 Trap Pressure in Separator, Lite 12111/2007 6:20 ; Burner 3390 I I ~ Liquid Rates from 43-9X 12111/2007 9:00 3390 Start Flowing 41-15RD, Sending Gas 12I1112007 10:15 to 43-9X, choke 4I64 3390 Flowing 41-15RD, Sending Gas to 43• 121111200710:30 9X 3190 42 4 1280 38 88 1.000 0.642 1458.14 20.25 38.40 0.40 Flowing 41-15RD, Sending Gas to 43• 12111I200711:00 9X 2950 42 4 1260 44 84 1.000 0.642 1565.61 52.87 1632.00 34.40 Flowing 41-15RD, Sending Gas to 43• 12/11/200711:30 9X 2850 42 4 1200 44 78 1.000 0.642 1537.62 84.90 907.68 53.31 Flowing 41-15RD, Sending Gas to 43~ 12/11/200712:00 9X 2750 44 4 1150 44 76 1.000 0.642 1504.86 116.25 907.68 72.22 Flowing 41-15RD, Sending Gas to 43• ' 12/11/2007 12:30 9X 2700 46 4 1110 44 77 1.000 0.642 1471.32 146.91 818.40 89.27 Continue flowing 41-15RD, Open ~ 12/11/2007 13:00 choke to 6/64 2650 46 6 1110 49 77 1.000 0.642 1552.71 179.25 782.88 105.58 ~ Continue flowing 41-15RD, Flowing I 12111/2007 13:30 gas to 43-9X 2800 48 6 1110 59 77 1.000 0,642 1703.90 214.75 903.36 124.40 Continue flowing 41-15RD, flowing 12/1112007 14:00 gas to 43-9X 2800 46 6 1110 60 77 1.000 0.642 1718.29 250.55 1211.04 149.63 Continue flowing 41-15RD, New gas 12/111200714:30 g~~ity 2800 47 6 1110 60 77 1.000 0.563 1789.91 287.84 650.40 163.18 Continue flowing 41-15RD, flowing 12/11/2007 15:00 gas to 43-9X 2800 47 6 1110 60 77 1.000 0.563 1789.91 325.13 896.16 181.85 Continue flowing 41-15RD, flowing 12/11/2007 15:30 gas to 43-9X 2800 48 6 1110 59 77 1.000 0.563 1774.92 362.11 1010.88 202.91 Continue flowing 41-15RD, flowing 12/11/2007 16:00 gas to 43-9X 2800 48 6 1100 59 77 1.000 0.563 1765.98 398.90 960.00 222.91 Continue flowing 41-15RD, flowing - 12111I2007 16:30 gas to 43-9X 2800 47 6 1100 59 77 1.000 0.563 1765.98 435.69 790.08 239.37 Continue flowing 41-15RD, flowing 12111/2007 17:00 gas to 43-9X 2790 48 6 1090 59 78 1.000 0.563 1754.40 472.24 960.00 259.37 Gontinue flowing 41-15RD, flowing 12I11I2007 17:30 gas to 43-9X 2790 48 6 1080 59 78 1.000 0.563 1745.42 508.60 1120.80 282.72 Continus flowing 41-15RD, flowing 12111/2007 18:00 gas to 43-9X, 2790 47 6 1080 59 76 1.000 0.563 1750.60 545.07 483.84 292.80 Estimated liquid rate due to vac 12111/2007 18:30 truck pulling load 2790 47 6 1080 57 76 1.000 0.563 1720.65 580.92 816.00 309.80 ~ ~ Page 1 coMPANY: Marathon Oil Company EXPRO , ~ ~~~ FIELD: Sterlin Unit 9 SURFACE WELL TESTING REPORT J ~ . : LEASE: Sport Lake ; . : ~` , .. ; ,~,~NTx~re ~~~~~ we~~#• 41-15RD Support 43-9x co. ReP.: Mickey Mullins ~3A~F-~T11UI~:< > ' R~1~AF2k~S;: ;:. <.~f~L1.:Eikfl~.GtO(yI~ IT1~7TsE5 ;;.>:;.>::>::::. 5~#'~F+AT[?RCO~ 1f,~IT1.DNS ; :.: TQT~ L..G~ >:' T4li'~41:.~VA'fEJa'::>.:::>: .; , ;;. ;. ; 1~1~(P : .. :.UtWM~t <..; ..::: ~3-~x' Hc?~~ sw 7~tT~c 1~~: .:.. .:T~~IP:.:: : a~i1~IG~:: :~a3~a~u< ;:.;.:..:.. ~AS~t~~ as Cunnn~. nE~. ~11.44~kp~: ::~v t~'~~: . c~h4Ni. ;.; xnidl ` hr mn < „ .. . > ; :; ~~~ ` de ~ ssG > : ~fiks lo > si >::; .i.asN~~a : de ~'rns; .: arr:~;ts ri?scf/d > ~~.: .. m %' "bwxd ..::;: >:: k~f~l~ <: choke to 8164, Estimated liquid rate, ~ 12/11/2007 19:00 vac truck puliing load 27g0 47 6 1080 56 76 1.000 0.563 1705.48 616.45 816.00 326.80 Continue flowing 41-15RD, flowing 12/11I2007 19:30 gas to 43-9X 2750 47 8 1080 57 76 1.000 0.563 1720.65 652.30 672.00 340.80 Continue flowing 41-15RD, flowing 12I1112007 20:00 gas to 43-9X 2740 47 8 1080 57 76 1.000 0.563 1720.65 688.14 846.24 358.43 Estimated liquid rate due t vac truck 12I11I2007 20:30 pulling load 2720 47 8 1080 56 76 1.000 0.563 1705.48 723.68 768.00 374.43 Continue flowing 41-15RD, flowing 12111/2007 21;00 gas to 43-9X 2700 46 8 1080 62 76 1.000 0.563 1794.59 761.06 823.68 391.59 choke to 6164, Estimated liquid rate 12111/2007 21:30 due to vac truck pulling load 2700 47 8 1080 62 76 1.000 0.563 1794.59 798.45 816.00 408.59 Continue flowing 41-15RD, flowing 12111/2007 22:00 gas to 43-9X 2690 48 6 1080 62 76 1.000 0.563 1794.59 835.84 816.00 425.59 Continue flowing 41-15RD, flowing 12/11/2007 22:30 gas to 43-9X 2670 48 6 1080 60 76 1.000 0.563 1765.39 872.62 806.88 442.40 Continue flowing 41-15RD, flowing 12/11/2007 23:00 gas to 43-9X 2660 48 6 1080 59 76 1.000 0.563 1750.60 909.09 768.00 458.40 Continue flowing 41-15RD, flowing 12111/2007 23:30 gas to 43-9X 2640 48 6 1080 59 76 1.000 0.563 1750.60 945.56 768.00 474.40 Continue flowing 41-15RD, flowing 12/12/2007 0:00 gas to 43-9X 2640 48 6 1080 59 76 1.000 0.563 1750.60 982.03 907.20 493.30 Continue flowing 41-15RD, flowing 12I1212007 0:30 gas to 43-9X 2640 48 6 1080 59 76 1.000 0.563 1750.60 1018.50 756.48 509.06 Continue flowing 41-15RD, flowing 12I12/2007 1:00 gas ta 43-9X 2630 48 6 1070 59 76 1.000 0.563 1741.55 1054.78 958.08 529.02 Continue flowing 41-15RD, flowing 12/1212007 1:30 gas to 43-9X 2620 48 6 1070 58 76 1.000 0.563 1726.71 1090.76 812.64 545.95 Continue flowing 41-15RD, flowing 12112/2007 2:00 gas to 43-9X 2620 48 6 1070 58 76 1.000 0.563 1726.71 1126.73 815.52 562.94 Continue flowing 41-15RD, flowing 12112I2007 2:30 gas to 43-9X 2620 48 6 1070 58 76 1.000 0.563 1726.71 1162.70 790.56 579.41 Continue flowing 41•15RD, flowing I ~ 12I1212007 3:00 gas to 43-9X 2600 48 6 1070 57 76 1.000 0.563 1711.75 1198.36 803.04 596.14 r Continue flowing 41-15RD, flowing ' 12112/2007 3:30 gas to 43-9X 2600 48 6 1070 57 76 1.000 0.563 1711.75 1234.02 903.36 614.96 ; Continue Fiowing, increased choke 1211212007 4:00 to 8/64 2600 48 6 1070 56 76 1.000 0.568 1691.46 1269.26 618.24 627.84 flowing 41-15RD, flowing gas to 43- 12112/2007 4:30 I 9X, choke to 7/64 2550 48 8 1080 64 76 1.000 0.568 1817.76 1307.13 1070.88 650.15 Continue flowing 41-15RD, flowing 12/12/2007 5:00 gas to 43-9X 2550 48 7 1080 59 76 1.OOp 0.568 1745.26 1343.49 555.84 661.73 ~ ~ Page 2 coivlPaNV: Marathon Oil Company EXPRO F- FIELD: Sterling Unit SURFACE WELL TESTING REPORT ~• ~~ ~~'3~'~?11 ~EASE: Sport Lake J .` '~~`FT7°" ~~~~~ _ wE~~#: 41-15RD Support 43-9x co. REP.: Mickey Mullins ~1A~~1'1M~ :::. .. f3~11~II~ft~fS::. ';i . . 44F~~L.:Ei~AL7 G~Nt7~ 133L1TsE5 > S~PAF~ITDR C0~ 1~3kT1~~1S >::::i; TQ3`,4 E::GAS ;: TQ3'A[. WATF.1~~:::. . '::::`:: ' ;' ; 1~1H~ . :VxrHT ~3~9x CM<#. 95U~f ::~TR71C :: : ....til~~.:; ,: .. C~11~P;; ?::a~i(~1~~2 ::G~A$~RT~sf ~RS Ra~~ ~+~ cµl~iivl: ixVT. CHl.a~tW~S k#~i~.E~l'~ ~UR~III~: I'iqdl .. ~1' ttttt : ;; :. ">: ;. .. ' .i;:;>;? siG ;.: ~e.. F s1G ;;:;. 6$~~s . ..,.to ..: si~ : : ingN~fl ;:.. '. de 1~~: `aRS'~1,4 ~ijscfld ms tT+.:>:: ~?W!Q :; 4b1S':: Continue flowing 41-15RD, flowing 12/12/2007 5:30 gas to 43-9X 2500 47 7 1070 58 76 1.000 0.568 1721.42 1379.36 790.56 678.20 Continue flowing 41-15RD, flowing 12/12/2007 6:00 gas to 43-9X 2500 46 7 1060 58 76 1.000 0.568 1712.41 1415.03 1185.60 702.90 Continue flowing 41-15RD, flowing 12/12/2007 6:30 gas to 43-9X 2500 46 7 1060 58 76 1.000 0.568 1712.41 1450.71 732.96 718.17 Continue flowing 41-15RD, flowing 12/12/2007 7:00 gas to 43-9X, Rock choke 2500 46 7 1060 58 76 1.000 0.568 1712.41 1486.38 903.84 737.00 Continue flowing 41-15RD, flowing 12/12/2007 7:30 gas to 43-9X 2500 46 7 1070 64 76 1.000 0.568 1808.33 1524.05 790.56 753.47 Continue flowing 41-15RD, flowing 12/12/2007 8:00 gas to 43-9X 2450 45 7 1080 64 76 1.000 0.568 1817.76 1561.92 790.08 769.93 Continue flowing 41-15RD, flowing 12/12/2007 8:30 gas to 43-9X 2400 46 7 1080 62 76 1.000 0.568 1789.11 1599.20 903.36 788.75 Estimated liquid rate due to vac ~ 12112/2007 9:00 truck pulling load 2400 46 7 1080 62 75 1.000 0.568 1791.81 1636.53 828.00 806.00 Estimated liquid rate due to vac 12112/2007 9:30 truck pulling load 2400 46 7 1080 62 76 1.000 0.568 1789.11 1673.80 840.48 823.51 Continue Flowing 41-15RD, flowing 12112/2007 10:00 gas to 43-9X 2400 46 7 1080 61 76 1.000 0.568 1774.62 1710.77 621.60 836.46 Continue Flowing 41-15RD, flowing 12112/2007 10:30 gas to 43-9X 2400 46 7 1080 60 76 1.000 0.568 1760.00 1747.44 903.36 855.28 Continue Flowing 41-15RD, flowing 12/12/2007 11:00 gas to 43-9X 2350 46 7 1080 60 76 1.000 0.568 1760.00 1784.11 732.96 870.55 Continue Flowing 41-15RD, flowing 12/12/2007 11:30 gas to 43-9X 2350 46 7 1080 60 76 1.000 0.568 1760.00 1820.77 790.56 887.02 Estimated liquid rate due to vac 12/12/2007 12:00 truck pulling load 2350 46 7 1070 60 76 1.000 0.568 1750.87 1857.25 808.80 903.87 Estimated liquid rate due to vac 12/1212007 12:30 truck pulling load 2350 46 7 1070 58 76 1.000 0.568 1721.42 1893.11 847.20 921.52 Continue flowing 41-15RD, flowing 12/12I2007 13:00 gas to 43-9X, Rock choke 2300 46 7 1070 56 76 1.000 0.568 1691.46 1928.35 860.64 939.45 Continue flowing 41-15RD, flowing 12I1212007 13:30 gas to 43-9X, 2300 46 7 1070 60 76 1.000 0.568 1750.87 1964.83 860.16 957.37 Continue flowing 41-15RD, flowing 12/12/2007 14:Q0 gas to 43-9X, 2300 46 7 1070 60 76 1.000 0.568 1750.87 2001.30 719.52 972.36 Continue flowing 41•15RD, flowing 12/12/2007 14:30 gas to 43-9X, 2250 46 7 1070 58 75 1.000 0.568 1724.00 2037.22 790.56 9$8.83 Continue flowing 41-15RD, gas to 43• 12/12/2007 15:00 9X, rocked choke 2250 46 7 1070 57 75 1.000 0.568 1709.07 2072.83 677,76 1002.95 Continue flowing 41-15RD, flowing 12/12/2007 15:30 gas to 43-9X, 2200 46 7 1070 64 75 1.000 0.568 1811.05 2110.56 902.88 1021.76 ~ CJ Page 3 cOMPANY: Marathon Oil Company EXPRO , FIe~D: Sterling Unit ' , , : SURFACE WELL TESTING REPORT k• '~ ~~~~ ~EQSE: Sport Lake . .:::. ,. `: '~'~FT''p~` ~~~~~ wE~~#: 41-15RD Support 43-9x co. REP.: Mickey Mullins ; I?AT~T11N~::: <F~1VI#~F'ti~$:> >:.~~1:F1~AL7GaNEx ITIUTsE5 ;: S~WAF±~AT~R~CYN RIT:IQN$ Tf37A I::G~rB...:<: '.:::>::::;1'S~TA[~::WAT~Ta' ; , 1MFi~ ~iMT ~a-~x cr1a~~ asvV srRra~ :: D1~F ' r~Nj~ . a~1~1c~ ~,a$ ~ffAV ~as w~'~~ ~~ ~ui~t~: :::~u`~: cti~«oi~IQ~s ::r~za ~1'~ cupr~~A,: mfU~ hr c~ii~ :: . > . .. ; . srG :. ; de F ; ~iG ~$fh:s . /o siG i: : i~sH~Q de '.. .. ... ~t1F~ ~t~1 ¢ rrmscfld ms tl?'::;.. tiwld ', '; bfils ::'. Estimated Iiquid rate due to vac 1211212007 16:00 truck pulling load 2200 46 7 1080 62 76 1.000 0.568 1789.11 2147.83 845.76 1039.38 Estimated liquid rate due to vac 12/12/2007 16:30 truck pulling load 2150 46 7 1080 60 76 1.000 0.568 1760.00 2184.50 808.80 1056.23 Continue flowing 41-15RD, flowing 12I1212007 17:00 gas to 43-9X, 2150 46 7 1080 60 76 1.000 0.568 1760.00 2221.16 752.16 1071.90 Continue flowing 41-15RD, flowing 12112/2007 17:30 gas to 43-9X, 2150 46 7 1070 60 76 1.000 0.568 1750.87 2257.64 754.56 1087.62 Continue flowing 41-15RD, flowing 12/12/2007 18:00 gas to 43-9X, 2130 46 7 1070 58 76 1.000 0.568 1721.42 2293.50 563.04 1099.35 Estimated liquid rate due to vac 12I12I2007 18:30 truck pulling load 2120 46 7 1060 57 75 1.000 0.568 1697.58 2328.87 600.96 1111.87 ~ncreased Choke to 8/64 12I121200719:00 2100 46 7 1060 57 75 1.000 0.568 1697.58 2364.23 984.00 1132.37 ' Increased Choke to 9/64 I12/12/200719:30 2100 46 8 1060 57 75 1.000 0.568 1697.58 2399.60 651.84 1145.95 ' Continue flowing 41-15RD, gas to 43• ~ 12/12/2007 20:00 9X, rocked choke 2100 46 9 1060 53 75 1.000 0.568 1636.89 2433.70 852.96 1163.72 ', Continue flowing 41-15RD, gas to 43• ' 12/12/2007 20:30 9X, rocked choke 2100 46 9 1060 57 75 1.000 0.568 1697.58 2469.07 718.56 1178.69 ', Continue flowing 41-15RD, gas to 43• 12/12/2007 21:00 9X 2100 46 9 1060 64 75 1.000 0.568 1798.87 2506.54 636.48 1191.95 Continue flowing 41-15RD, gas to 43• 12I12/2007 21:30 9X 1975 46 9 1060 60 75 1.000 0.568 1741.71 2542.83 713.76 1206.82 Continue flowing 41-15RD, gas to 43• 12I12I2007 22:00 9X 1950 46 9 1060 57 75 1.000 0.568 1697.58 2578.20 857.28 1224.68 Increased Choke to 11/64 1211212007 22:30 1900 46 9 1060 60 75 1.000 0.568 1741.71 2614.48 554.40 1236.23 Continue flowing 41-15RD, gas to 43• 12I1212007 23:00 9X 1940 46 11 1060 60 75 1.000 0.568 1741.71 2650.77 806.88 1253.04 Continue flowing 41-15RD, gas to 43• 12/12I2007 23:30 9X, rocked choke 1900 46 11 1060 58 75 1.000 0.568 1714.97 2686.50 553.92 1264.58 Continue flowing 41-15RD, gas to 43• 12/13/2007 0:00 9X 1850 46 11 1070 68 75 1.000 0.568 1866.83 2725.39 1186.08 1289.29 Decreased choke to 10/64 12/13/2007 0:30 1820 46 11 1080 65 75 1.000 0.568 1834.64 2763.61 655.68 1302.95 Continue flowing 41-15RD, gas to43- 12113120071:00 9X 1820 46 10 1070 58 75 1.000 0.568 1724.00 2799.53 737.28 1318.31 Continue flowing 41-15RD, gas to43- 12/13/20071:30 9X 1820 46 10 1060 58 75 1.000 0.568 1714.97 2835.26 691.68 1332.72 Continue flowing 41-15RD, gas to43- 12I13I2007 2:00 9X 1830 46 10 1060 58 75 1.000 0.568 1714.97 2870.98 554.88 1344.28 ~ ~ Page 4 comPaNV: Marathon Oil Company ~ EXPRO ~ ~~~ . FIELD: Sterling Unit SURFACE WELL TESTING REPORT ~• '; ;~~ ~~3~'~1'1 ~EASE: Sport Lake :..... .... ::: .: muteaxxost '~~~~~ we~~#: 41-15RD Support 43-9x co. REP.: Mickey Mullins ;:AA;~F~T1iUl~ f~11~IJ~Et1~S.> > `>:: ~~LL:EI~AIJ:~~?NI~I TI~fTi~s ; ;:: S:~PAf~TUR ~ONRITI~NS ; TQ'fA I:;G~ `:::: T~7'r4~ WiAT~R ; , ,: :: ' 1XVHP` ;: <11titH~` .43-9X . ;: CHf}kt 9SrlV , %.;.~^j'HcT4~"r . , . DIF~ : T~.,fVIP ;~RIFICF Cy'A$C(~AV Gi45 RATR+: .1'~~:C'i4lMIVI 1NT ,. C1"I~Q~YI~1~3 F~'~Q 1~~'~?. CR1MM:~ ;: ld:l hf mn : : ,, ;; ,; . . ~G . #~ F ,,: sR~a ;. B~tI~:S o :. s~G~ .: ~~sH~fl ~ . 3ns:: [r=1 t3 scfld ;: ms' ..,. : :... qa ::::; : ~W14~ d~s.': Continue flowing 41-15RD, gas to43- 12/13/2007 2:30 9X 1830 46 10 1060 58 75 1.000 0.568 1714.97 2906.71 508.80 1354.88. Continue flowing 41-15RD, gas to43- 1211312007 3:00 9x 1800 46 10 1060 64 75 1.000 0.568 1801.56 2944.24 518.40 1365.68 Continue flowing 41-15RD, gas to43- 12I13I2007 3:30 9X 1780 46 10 1060 61 75 1.000 0.568 1758.80 2980.89 778.08 1381.89 Continue flowing 41-15RD, gas to43- 12113I2007 4:00 9X 1750 46 10 1060 60 75 1.000 0.568 1741.71 3017.17 605.76 1394.51 Continue flowing 41-15RD, gas to43- 12I13I2007 4:30 9X 1730 46 10 1060 57 75 1.000 0.568 1700.11 3052.59 604.32 1407.14 Continue flowing 41-15RD, gas to43- 12/13/2007 5:00 9X 1750 46 10 1050 60 75 1.000 0.568 1735.10 3088.74 700.80 1421.70 Continue flowing 41-15RD, gas to43- 12/13/2007 5:30 9X 1740 46 10 1050 60 75 1.000 0.568 1735.10 3124.89 609.12 1434.39 Continue flowing 41-15RD, gas to43- 12/1312007 6:00 9X 1750 48 10 1050 58 75 1.000 0.568 1705.91 3160.43 1008.00 1455.39 Continue flowing 41-15RD, gas to43- 1211312007 6:30 9X 1725 47 10 1050 58 75 1.000 0.568 1705.91 3195.97 908.16 1474.31 Well Starting to produce sand and 12/13/2007 7;00 water, open choke to 13/64 1950 46 10 1000 28 76 1.000 0.568 1151.57 3219.96 731.04 1489.54 ~ Liquid rate estimated, open choke to ' 12/13/2007 7:30 16/64 1825 45 13 1020 42 76 1.000 0.568 1426.13 3249.67 605.76 1502.16 Continue dumping sand buster, 12/13/2007 8:00 Rocked Choke 1700 42 16 1030 32 76 1.000 0.568 1251.53 3275.74 504.00 1512.66 Continue dumping sand buster, 12/13/2007 8:30 Rocked Choke 1650 45 16 1040 52 77 1.000 0.568 1601.85 3309.11 907.20 1531.56 Dumped sand buster, Rocked 12/13/2007 9:00 Choke, estimated water rate 1600 45 16 1040 48 75 1.000 0.568 1543.53 3341.27 791.52 1548.05 Continued Flowing 41-15RD 12/13/2007 9:30 Dumped sand buster, 1550 45 16 1050 64 75 1.000 0.568 1792.04 3378.61 1163.04 1572.28 Gontinued Flowing 41-15RD 12/1312007 10:00 Dumped sand buster, 1550 45 16 1040 62 75 1.000 0.568 1754.40 3415.16 1310.88 1599.59 Estimated Fluid Rate, Dumped sand 12I13I200710:30 buster, 1550 44 16 1060 60 75 1.000 0.568 1744.31 3451.49 847.20 1617.24 Continue Flowing 41 •15RD, Dumped 12/13/2007 11:00 sand buster, 1400 46 16 1080 60 76 1.000 0.568 1760.00 3488.16 1109.76 1640.36 Flowing 41-15RD, Dumped sand 12I1312007 11:30 buster,Rocked choke 1350 45 16 1080 60 76 1.000 0.568 1760.00 3524.83 604.32 1652.95 Continue Fiowing 41-15RD, Open 12/13/2007 12:00 choke to 20/64 1300 44 16 1070 54 76 1.000 0.568 1660.96 3559.43 806.88 1669.76 Continue Flowing 41-15RD, 12/13/2007 12:30 Continue dumping sand buster 1300 45 20 1060 62 76 1.000 0.568 1770.52 3596.32 818.40 1686.81 ~ ~ Page 5 coMPaNr: Marathon Oil Company ....... EXPRO ~- ~ ~~~~ F~e~~: Sterlin Unit 5 SURFACE WELL TESTING REPORT ~•- ~ . % ~E,4se; Sport Lake :,... ..... .: ::. ~~~ ' °A"~`~~'O7 ~~ wE~~#: 41-15RD Support 43-9x Co. REP.: Mickey Mullins p;4~F..FTINFE:::: ;:i ; :E~1VIAf'~S:::.' ~1$EE~I.:FI~AL7 Gi~Na1 71~3TVS > .. >. SFF'AFi~1TOR..Ci~N Q#TIDf~3S ..: ; ; . : A TS~T <G S ;: L. P: . . ..:: T R <:`::::::::;::::: •: .:.. ;;::>:::>::. : ::TATA[:::WA..~ ....................... > , >. > ;:. ~ ; WH ,, r NYH . >.; . a- .. A...~~F.. c ' .1~~i~+ ~~IN ;: ' c~ I . wl .. ~ G.. ; > `:: . Al~~ T ~NlP' .. L1 1 C .... f~.F1.. ~.~. ~ '':~ ' <: .... A~...1?ikV . : ns ~tr~ Ca... .. . ... ~ e : .: ...1kS 111VItUf: :::~Y~':<:: G~i~.Q~E4~8 1~<?..f~l'~+> :>~~MVI~: 'tnid!` hr mn>: ;. scG . de ~ . sFG . 8$.~~5) . .Jo) : siG) . :: i~SH?{7 : <fe ~ps;' atr 1 Q mScffit : . : nls RIn :is: I?ti'fXS~ : 4blg . Continue Flowing 41-15RD, 12/13I2007 13:p0 Estimated Fluid rate 1300 44 20 1080 68 76 1.000 0.568 1873.75 3635.35 743.04 1702.29 Continue Flowing 41-15RD,close 12/13/2007 13:30 choke to 19/64 1300 44 20 1080 68 76 1.000 0.568 1873.75 3674.39 604.80 1714.89 Continue Flowing 41-15RD,dumping 12/13/2007 14:00 sand buster 1300 43 19 1080 62 75 1.000 0.568 1789.11 3711.66 554.88 1726.45 Continue Flowing 41-15RD,dumping 12/13/2007 14:30 sand buster 1300 43 19 1080 64 74 1.000 0.568 1823.26 3749.65 504.48 1736.96 Continue Flowing 41-15RD,dumping 12/13/2007 15:00 sand buster 1325 44 19 1080 68 75 1.000 0.568 1876.58 3788.74 806.88 1753.77 Continue Flowing 41-15RD,dumping 12/13/2007 15:30 sand buster 1325 44 19 1080 68 75 1.000 0.568 1876.58 3827.84 655.68 1767.43 Continue Flowing 41-15RD,dumping 12/13/2007 16:00 sand buster 1350 44 19 1080 68 75 1.000 0.568 1876.58 3866.93 705.60 1782.13 Continue Flowing 41-15RD,dumping 12/13/2007 16:30 sand buster 1350 44 19 1080 67 74 1.000 0.568 1865.54 3905.80 706.08 1796.84 Continue Flowing 41-15RD,dumping 12/13/2007 17:00 sand buster 1350 44 19 1080 69 75 1.000 0.568 1890.34 3945.18 688.80 1811.19 Continue Flowing 41-15RD,dumping 12/13/2007 17:30 sand buster 1350 43 19 1080 68 75 1.000 0.568 1876.58 3984.28 806.88 1828.00 Continue flowing 41-15RD,dumping 12/13/2007 18:00 sand buster 1350 43 19 1080 68 75 1.000 0.568 1876.58 4023.37 406.56 1836.47 Continue Flowing 41-15RD,dumping 12/13/2007 18:30 sand buster 1340 43 19 1080 65 75 1.000 0.568 1834.68 4061.60 615.84 1849.30 Continue Flowing 41-15RD,dumping 12/13/2007 19:00 sand buster 1340 43 19 1080 64 75 1.000 0.568 1820.50 4099.52 818.40 1866.35 Continue Flowing 41-15RD,dumping 12/13/2007 19:30 sand buster 1340 43 19 1070 65 75 1.000 0.568 1825.15 4137.55 396.48 1874.61 Continue Flowing 41-15RD,dumping 12/13/2007 20:00 sand buster 1330 43 19 1070 65 75 1.000 0.568 1825.15 4175.57 806.88 1891.42 Estimated Fluid Rate,Continue 12/13/2007 20:30 dumping sand buster 1320 43 19 1070 60 75 1.000 0.568 1753.50 4212.10 496.32 1901.76 Continue Flowing 41-15RD,dumping 12/13I2007 21:00 sand buster 1320 43 19 1070 63 75 1.000 0.568 1796.83 4249.54 779.04 1917.99 Continue Flowing 41-15RD,dumping 12/13/2007 21:30 sand buster 1320 43 19 1070 63 75 1.000 0.568 1796.83 4286.97 605.28 1930.60 Continue Flowing 41-15RD,dumping 12/13/2007 22:00 sand buster 1320 42 19 1070 64 75 1.000 0.568 1811.05 4324.70 806.88 1947.41 Continue Flowing 41-15RD,dumping 12/13/2007 22:30 sand buster 1320 42 19 1070 62 75 1.000 0.568 1782.50 4361.83 907,68 1966.32 Continue Flowing 41-15RD,dumping 12/13/2007 23:00 sand buster 1320 42 19 1070 60 75 1.000 0.56& 1753.50 4398.37 800.64 1983.00 i C ~ Page 6 connParvv: Marathon Oil Company EXPRO ,,- ~~ : FIELD: Sterling Unit SURFACE WELL TESTING REPORT ~~ ~ ~ •'~~ ~~/+~,~ 1 . . ~e.4sE: Sport Lake ' ~ ~ ~ y~~py y ~ y.~ ....:.... ..... .. .: ...:. ~:~ ~4'. -A6R&47:pH ~ ~k~i.~."~'.' 7 , . _ wE~~#: 41-15RD Support 43-9x co. ReP.: Mickey Mullins A ; 1 p..~~ na~ ;.. _ , . _ ; .. ;> ..:..........::.....: <:>;:.:.::::::E2~1111. . _ a€~s .... . ... . . ..... ,, . :.:.:.:.::... H A .: a~lal fr......... ~~~.~, ~ ~ : T~3T4I5. >::.::::::::>::::..:...:: A .7t~.:: : . R s~ r~ ....ca~ N .....:.::::::`;::::::. I 1 ~~ ~ s ...:; TQTA :l3. r. ~s::::::::>;: ; : ... ;;:;;;;; :<::>:<::< ; : ~~r~~.:w,~7~~ .::>::::::>;::>::;:: ; ;i~11HP 1lfifklT A3-~X CH' ~S.1N. ...STAT#i"v : DI~~ : ~'k"N!R' CXRIKI~~, 'G~A$s~EtA1f ,~"xaS.RAT~ i~l~i$'CLI-1~IIN. .~l'T::>: G~li~c'ak[Ci~S '#~(?:E~1'~ CfI~/IAA.. ttiid~' hr.~i(1 ;> > ;: SrG d4 F SiG &~ths . io .: si~i ::;>: : ~qs1i+C76 ; de ; ....,1Ff~,. a~r:1 4 ; 1nS4ffd ;: ms : ~ m;: bWtcl bI?I~ :: Continue Flowing 41-15RD,dumping 12/13/2007 23:30 sand buster 1320 42 19 1065 60 75 1.000 0.568 1748.91 4434.80 690.72 1997.39 Continue Flowing 41-15RD,dumping 12/14/2007 0:00 sand buster 1300 42 19 1070 62 75 1.000 0.568 1782.50 4471.94 554.88 2008.95 Continue Flowing 41-15RD,dumping 12114I2007 0:30 sand buster 1275 40 19 1070 61 73 1.000 0.568 1768.06 4508.77 756.48 2024.71 Continue Flowing 41-15RD,dumping 12I14I2007 1:00 sand buster 1285 40 19 1065 64 73 1.000 0.568 1811.77 4546.52 605.28 2037.32 Estimated Fluid Rate,Continue 12114/2007 1:30 dumping sand buster 1285 40 19 1065 62 73 1.000 0.568 1783.21 4583.67 873.60 2055.52 Continue Flowing 41-15RD,dumping 12114/2007 2;00 sa~d buster 1280 41 19 1065 62 73 1.000 0.568 1783.21 4620.82 655.68 2069.18 Continue Flowing 41-15RD,dumping 12/14/2007 2:30 sand buster 1280 41 19 1065 62 73 1.000 0.568 1783.21 4657.97 705.60 2083.88 Continue Flowing 41-15RD,dumping 12/14I2007 3:00 sand buster 1280 41 19 1065 62 73 1.000 0.568 1783.21 4695.12 750.24 2099.51 Continue Flowing 41-15RD,dumping 12I1412007 3:30 sand buster 1280 41 19 1060 60 73 1.000 0.568 1749.57 4731.57 691.68 2113.92 Continue Flowing 41-15RD,dumping 12/1412007 4:00 sand buster 1280 40 19 1060 64 73 1.000 0.568 1807.00 4769.21 806.88 2130.73 Continue Flowing 41-15RD,dumping 12114/2007 4:30 sand buster 1260 40 19 1050 59 74 1.000 0.568 1723.14 4805.11 655.20 2144.38 Continue Flowing 41-15RD,dumping 12114/2007 5:00 sand buster 1270 40 19 1060 62 74 1.000 0.568 1775.86 4842.11 806.88 2161.19 Estimated Fluid Rate,Continue 12/14/2007 5:30 dumping sand buster 1280 40 19 1060 61 74 1.000 0.568 1761.44 4878.81 719.52 2176.18 Continue Flowing 41-15RD,dumping 12/14/2007 6:00 sand buster 1280 40 19 1060 64 74 1.000 0.568 1807.27 4916.46 338.40 2183.23 Continue Flowing 41-15RD,dumping 12/14/2007 6:30 sand buster 1290 40 19 1060 61 74 1.000 0.568 1761.44 4953.15 1160.16 2207.40 I Continue Flowing 41-15RD,dumping I 12/14/~ Zpp7 7;pp sand buste~ 1290 I 39 19 1060 61 74 1.000 0.568 1761.44 4989.85 705.60 2222.10 ~ Continue Flowing 41-15RD,dumping 12(14/2007 7:30 sand buster 1290 39 19 1060 61 74 1.000 0.568 1761.44 5026.55 655.20 2235.75 Continue Flowing 41-15Rqdumping 12/14/2007 8:00 sand buster 1290 38 19 1060 61 74 1.000 0.568 1761.44 5063.24 712.32 2250.59 Continue Flowing 41-15RD,dumping 12114I2007 8:30 sand buster 1290 38 19 1060 60 74 1.000 0.568 1746.93 5099.64 700.32 2265.18 Continue Flowing 41-15RD,dumping 12114/2007 9:00 sand buster 1290 38 19 1060 60 74 1.000 0.568 1746.93 5136.03 805.92 2281.97 Continue Flowing 41-15RD,dumping 12/14/2007 9:30 sand buster 1280 37 19 1060 60 73 1.000 0.568 1749.57 5172.48 703.20 2296.62 i ~J Page 7 con~Parvv: Marathon Oil Company EXPRO "' , ~~ ~~M1 FIELD: Sterlin Unit J ;,_ ;, SURFACE WELL TESTING REPORT g ~ : ^ LEASE: Sport Lake - -ABRFTN611 ~~ ' . ~ .::..... ..•. . .:....:. ; ~~ , , wE~~#: 41-15RD Support 43-9x co. REP.: Mickey Mullins l?Pi~E)T111A~ ::; E~11~I+~E2~'~'S;; Il1f~k~.:H~Al3 ~`~3N[~1 7it]I4E5 > S~F~k~Tt?R CQp! 1Qk~lt'~[ti4fi ' fiQTA ;;(: ;:' E..... ~. ;:::::Q J4 <::... T T. ; . . : ft' ' ::;;::;;;;.` . G.. WAT.~ ....................... ., ; :.... , ....: .....:::: . ,...::::;.:. . ;,. ;;;;::;;;:.; . ..................: _ .......... :;:;>;::>; ..::: ... ; ~1M#~.::: ' . ,'~' ~~T:ii .:Ufi!k#.... ii:i23:3:..:«::; .......9X .. ;«::.:<.;::,:. GW . .. ..... .~SVal. . . ... STaT)~:::: .::. ..... C?I~F..:... ::; ; .:. T~MP... . :::.:~::::::. .. o:fJ I ~'. .. .....~4.F7.. E. . : . . . .:. u ..GA~.C~F?~ ... .. . . .. . G 5 ~ ...I~ ...RJ%.. ~. ....... . . . '.::' 11 Mk. G~ks. c ..1~.... . ;:; ..1~1't. _ H C...L4f~Mp~S : M#z4:'~1'~: :~~1RA1~;. ;. ;:.4Tt~dl~ ~ hr mn :: . ~ ~ ~ ~ ~~ ~ ~ ~~ ~ ~ : ... > s~G ~e . F s1.~~a. : : 86ths lo ~. .. i si~ :~'~ ~~ :iasH?{ll~ ;. ~ . ~d!9. .: ~ . '~g . . ai~.1.4 . riiscf/d :" s ' . .. . . . tii .''' rvf~:':: ' . . bbls ': Continue Flowing 41-15RD,dumping ~ 12/14/2007 10:00 sand buster 1270 37 19 1060 60 72 1.000 0.568 1752.23 5208.99 702.24 2311.25 Continue Flowing 41-15RD,dumping 12/14I2007 10:30 sand buster 1280 38 19 1060 61 74 1.000 0.568 1761.44 5245.68 602.40 2323.80 Continue Flowing 41-15RD,dumping 12114I2007 11:00 sand buster 1290 38 19 1060 61 75 1.000 0.568 1758.80 5282.32 665.28 2337.66 Continue Flowing 41-15RD,dumping 12/14/2007 11:3p sand buster 1270 38 19 1060 61 75 1.000 0.568 1758.80 5318.97 697.44 2352.19 Continue Flowing 41-15RD,dumping 12114/2007 12:00 sand buster 1275 38 19 1060 60 75 1.000 0.568 1744.31 5355.31 714.24 2367.07 Continue Flowing 41-15RD,dumpi~g 12/14/2007 12:30 sand buster I 1275 39 19 1060 60 75 1.000 0.568 1744.31 5391.65 675.84 2381.15 Estimated Fluid Rate,Continue 12/14I2007 13:00 dumping sand buster 1275 40 19 1060 63 75 1.000 0.568 1787.42 5428.88 695.52 2395.64 Continue Flowing 41-15RD,Continue 12/14/2007 13:30 dumping sand buster 1275 40 19 1060 61 75 1.000 monthly/wee 1758.80 5465.53 648.00 2409.14 Continue Flowing 41-15RD,Continue 12/14/2007 14:00 dumping sand buster 1270 40 19 1060 60 75 1.000 0.568 1744.31 5501.87 552.96 2420.66 Continue Flowing 41-15RD,Continue 12/1412007 14:30 dumping sand buster 1275 40 19 1060 60 75 1.000 0.568 1744.31 5538.21 708.96 2435.43 Continue Flowing 41-15RD,Continue 12l1412007 15:00 dumping sand buster 1275 40 19 1060 61 74 1.000 0.568 1761.44 5574.90 899.04 2454.16 Estimated Fluid Rate,Continue 12I1412007 15:30 dumping sand buster 1275 40 19 1060 60 74 1.000 0.568 1746.93 5611.30 720.48 2469.17 Estimated Fluid Rate,Continue 12114/2007 16:00 dumping sand buster 1275 40 19 1055 60 75 1.000 0.568 1739.71 5647.54 776.16 2485.34 Continue Fowing 41-15RD,Continue 12/14/2007 16:30 dumping sand buster 1275 40 19 1050 60 74 1.000 0.568 1737.69 5683.74 782.88 2501.65 Estimated Fluid Rate,Continue 12/14/2007 17:00 dumping sand buster 1275 40 19 1050 60 74 1.000 0.568 1737.69 5719.94 759.84 2517.48 Continue Fowing 41-15RD,Continue 12/14I2007 17:3~ dumping sand buster 1275 39 19 1050 61 74 1.000 0.568 1752.13 5756.45 705.60 2532.18 Continue Fowing 41-15RD,Continue 1211412007 18:00 dumping sand buster 1275 37 19 1050 57 74 1.000 0.568 1693.66 5791.73 252.96 2537.45 Continue Fowing 41-15RD,Continue 12/14/2007 18:30 dumping sand buster 1275 37 19 1050 59 74 1.000 0.568 1723.14 5827.63 655.20 2551.10 Continue Fowing 41-15RD,Continue 12/14/2007 19:00 dumping sand buster 1275 37 19 1050 58 74 1.000 0.568 1708.47 5863.22 717.12 2566.04 Estimated Fiuid Rate,Continue 12114/2007 19:30 dumping sand buster 1275 37 19 1050 58 74 1.000 0.568 1708.47 5898.82 519.36 2576.86 ', Continue Fowing 41-15RD,Continue 12/14/2007 20:00 dumping sand buster 1275 35 19 1050 58 72 1.000 0.568 1708.47 5934.41 762.72 2592.75 • ~ Page 8 coMPANY: Marathon Oil Company ;.... EXPRO , ~ ~~~ FIELD- Sterlin Unit 9 SURFACE WELL TESTING REPORT S• : LE.4sE: S ort Lake ; ; _.::... ....: ~ . .: ....:. ~~ t ~~'t p~~ . r~au~ti~;e:e ~ y we~~#• 41-15RD Support 43-9x co. Rev.: Mickey Mullins >. ~Jf1~~T1N[~ ;: ft~ll+li~Ftl~S:::: > 1~~.~'~i~AD.C~?Np lTic?~i5 ;: S~AE~,4T~R ~QN L?tTIDNS .. :. ... ::::::>'%> . TQTA ~::G~S':> T4~TA[,1RVAT&~'` ; " i~UF~P ,.: :.:.. :: 't'; V%~~... .;:.;: .. ;i' 3- X . ~..5 CHC#. . ~. ~'^11~/ i$ lk T'~1C::: FF :: Ol > 'C~h9P' OI 1 C€ F4Fl Cy tu.C` ;; A.. Et~V:. 5 ~ ~,~R...RP..~. [s 11AIN. ...~.GU.._... 1At :. .....'t... ~'' k ..i~l«cv..tp~.. ::~G.:l~1'~:: ..G~h/11~11:: ;.; mtd! hr:inn : : ..: ;. iG ~ '~ i~ ~ths ~ :> .si~a > ansH~{~ , ... de . ns:: , ,. airs~,4 iiscftd < »» rsis , :: ::: ::: >....m iwtd b1s.. Continue Fowing 41-15RD,Continue 12114/2007 20:30 dumping sand buster 1275 35 19 1050 57 72 1.000 0.568 1698.78 5969.80 706.08 2607.46 Estimated Fluid Rate,Continue 12114I2007 21:00 dumping sand buster 1275 37 19 1050 59 72 1.000 0.568 1728.34 6005.81 690.72 2621.85 Continue Fowing a1-15RD,Continue ~ 12/14/2007 21:30 dumping sand buster 1275 37 19 1049 58 71 1.000 0.568 1715.31 6041.54 454.08 2631.31 I Continue Fowing 41-15RD,Continue ' 12/14/2007 22:00 dumping sand buster 1275 37 19 1049 57 71 1.000 0.568 1700.45 6076.97 553.92 2642.85 Continue Fowing 41-15RD,Continue 12114/2007 22:30 dumping sand buster 1275 37 19 1049 57 72 1.000 0.568 1697.87 6112.34 706.56 2657.57 Estimated Fluid Rate,Continue 12I14I2007 23:00 dumping sand buster 1275 37 19 1049 57 72 1.000 0.568 1697.87 6147.71 606.24 2670.20 Estimated Fluid Rate,Continue I 12/14/2007 23:30 dumping sand buster 1275 35 19 1049 62 72 1.000 0.568 1770.83 6184.61 302.40 2676.50 Continue Fowing 41-15RD,Continue 12115/2007 0:00 dumping sand buster 1275 34 19 1050 57 77 1.000 0.568 1686.12 6219.73 605.28 2689.11 Continue Fowing 41-15RD,Continue 12115/2007 0:30 dumping sand buster 1275 34 19 1049 56 77 1.000 0.568 1670.36 6254.53 806.88 2705.92 Increased Choke to 22/64 12I15I20071:00 1275 33 19 1047 48 76 1.000 0.568 1544.73 6286.71 706.08 2720.63 Increased Choke to 32164 12/15120071:30 1200 30 22 1046 50 77 1.000 0.568 1575.77 6319.54 696.00 2735.13 Increased Choke to 64164 12/15/2p07 2:00 1160 25 32 1044 60 78 1.000 0.568 1721.90 6355.42 604.80 2747.73 Increased Choke full open 128 bean 12/15/2007 2:30 1140 22 64 1010 60 77 1.000 0.568 1514.11 6386.96 806.88 2764.54 Continue Fowing 41-15RD,dumping 12/15/2007 3:00 sand buster 1120 23 128 1046 65 77 1.000 0.568 1796.86 6424.39 806.88 2781.35 ASRC Pumping MEOH @ Well i 12/15/2007 3:30 Head,Reduced Choke to 64/64 1110 29 64 . 1100 80 78 1.000 0.568 2047.32 6467.05 663.84 2795.18 ~ Decreased Choke to 24/64 12/15/2007 4:00 1110 34 32 1080 65 79 1.000 0.568 1823.74 6505.04 705.60 2809.88 I Continue Fowing 41-15RD dumping ~ 12/15/2007 4:30 sand buster 1110 35 24 1060 66 79 1.000 0.568 1818.69 6542.93 555.36 2821.45 Continue Fowing 41-15RD dumping ~ 12/15/2007 5:00 sand buster 1110 35 24 1q50 62 79 1.000 0.568 1753.41 6579.46 655.20 2835.10 Decreased Choke to 22164 12/15I2007 5:30 1110 35 24 1050 63 79 1.000 0.568 1767.50 6616.28 622.56 2848.07 I Continue Flowing 41-15RD, Dumped ' 12/15/2007 6:00 sand buster, 1110 35 22 1050 62 79 1.000 0.568 1753.41 6652.81 1211.04 2873.30 ' Continue Flowing 41-15RD, Dumped 12/15/2007 6:30 sand buster, 1110 35 22 1050 62 79 1.000 0.568 1781.48 6689.93 806.88 2$90.11 ~ ~ Page 9 coMaanlr: Marathon Oil Company EXPRO ~ ' , FIELD: Sterling Unit , ., SURFACE WELL TESTING REPORT ~_ ~ ~~ ~~~ . ~easE: Sport Lake ;: . . '~ ' ~ ~ ~ ~ ` °A°"`'"' ~~` ~~~~ ~ ` wEL~#: 41-15RD Support 43-9x Co. REP.: Mickey Mu/lins ;~3A_~EtTI~::: ;: f~Nl#EtI~S:: ~t~~;l:~i~A17~~JN~1 3i~a~tS. ' ::: S~P~RAT~ftG:QN C~ITIDhIs : ;: . . T.4~TA r.:c3~s T4~T~C ~:WAT~t~ .... ... , » . :>. ;: < . ixlthll'. VVW7 ;. ~l3:~x CH4#k~ .~SU1I :STA~'tC': : D1F~': ..T~MP ~RIF1:C~ '~AS;~gAV ~RSR~kT~: :GI~s.~~lMM. ~l~': G~14Cii~1~-~. ;WZQ~T~ 'GUMI1~i mtdi' . hr m~ , ': :::. ; srG .: de ~ , . . sFG 6~tEIS Jo ~ ~i~i ; ;: insHYO d~e :; . 3ps:; ai~134 : .. riiS~f/d ; ri1~ Fn . . ;:: b+Nt~ `:;::;:; : . bb1$ .:::: Continue Flowing 41-15RD, Dumped 12115I2007 7:00 sand buster, 1110 36 22 1050 65 79 1.000 0.568 1795.36 6727.33 706.56 2904.83 Continue Flowing 41-15RD, Dumped 12I15I2007 7:30 sand buster, 1110 36 22 1060 66 79 1.000 0.568 1818.69 6765.22 554.40 2916.38 Continue Flowing 41-15RD, Dumped 12/15/2007 8:00 sand buster, 1110 36 22 1060 63 79 1.000 0.568 1776.85 6802.24 762.24 2932.26 Continue Flowing 41-15RD, Dumped 12/15/2p07 8:30 sand buster, 1110 36 22 1050 63 79 1.000 0.568 1767.50 6839.06 756.48 2948.02 Continue Flowing 41-15RD, Oumped 12/15/2007 9:00 sand buster, 1110 37 22 1050 64 79 1.000 0.568 1781.48 6876.17 548.64 2959.45 Continue Flowing 41-15RD, Dumped 12I15I2007 9:30 sand buster, 1110 38 22 /050 64 79 1.000 0.568 1781.48 6913.29 653.76 2973.07 Continue Flowing 41-15RD, Dumped 12/15/2007 10:00 sand buster, 1110 38 22 1050 63 79 1.000 0.568 1767,50 695Q.11 952.80 2992.92 Estimated Fluid Rate,Continue 12115I2007 10:30 dumping sand buster 1110 39 22 1050 62 79 1.000 0.568 1753.41 6986.64 718.08 3007.88 I Continue Flowing 41-15RD, Dumped ' 12/15/2007 11:00 sand buster, 1110 39 22 1050 62 80 1.000 0.568 1750.85 7023.12 806.88 3024.69 Continue Flowing 41-15RD, Dumped 12/15/2007 11:30 sand buster, 1115 40 22 1050 62 80 1.000 0.568 1750.85 7059.59 604.80 3037.29 Continue Flowing 41-15RD, Dumped 12/15/2007 12:00 sand buster, 1140 40 22 1045 64 80 1.000 0.568 1774.17 7096.56 603.36 3049,86 Continue Flowing 41-15RD, Dumped 12115/2007 12:30 sand buster, 1140 40 22 1045 62 80 1.000 0.568 1746.21 7132.93 702.24 3064.49 Continue Flowing 41-15RD, Start 43- ' 12/15/2007 13:00 9X WHP 1150 41 510 22 1045 63 80 1.000 0.568 1760.25 7169.61 903.36 3083.31 Continue Flowing 41-15RD, Dumped 12115/2007 13:30 sand buster, 1150 41 510 22 1045 63 80 1.000 0.568 1760.25 7206.28 514.56 3094.03 Continue Flowing 41-15RD, Dumped 12/15/2007 14:00 sand buster, 1150 41 510 22 1045 63 80 1.000 0.568 1760.25 7242.95 706.56 3108.75 Continue Flowing 41-15RD, Dumped 12/15/2007 14:30 sand buster, 1150 41 510 22 1045 64 81 1.000 0.568 1771.60 7279.86 755.52 3124.49 Continue Flowing 41-15RD, Dumped 12/15I2007 15:00 sand buster, 1150 41 510 22 1045 62 81 1.000 0.568 1743.68 7316.19 902.88 3143.30 Con6nue F{owing 41-15RD, Dumped 12/15/2007 15:30 sand buster, 1150 41 510 22 1045 62 80 1.000 0.568 1746.21 7352.56 501.60 3153.75 Continue Fiowing 41-15RD, Dumped 12l15I2007 16:00 sand buster, 1150 40 510 22 1045 62 80 1.000 0.568 1746.21 7388.94 559.20 3165.40 Continue Flowing 41-15R0, Dumped 12/15/2007 16:30 sand buster, 1150 40 510 22 1045 61 80 1.000 0.568 1732.06 7425.03 486.24 3175.53 Continue Flowing 41-15RD, Dumped 12/15/2007 17:00 sand buster, 1150 40 510 22 1045 63 80 1.000 0.568 1760.25 7461.70 676.80 3189.63 ~ ~ Page 10 CoMPANY: Marathon Oil Company EXPRO ~~ .- FIELD: Sterlin Unit 9 SURFACE WELL TESTING REPORT ~• ; ,: :.: ;: ;~~ ~'~t~1'# ~easE: Sport Lake ..... .. .. :. . RUn;o t ~`~'~f~~ : vaa r ~ wE~l#: 41-15RD Support 43-9x co. ReP.: Mickey Mullfns >k~A:TFlT11Ul~ s; E~11~1#~Et}fS;: > i: (lkF~l.Lfi~A3,7.G.Qf3~13`1~3isF5 ; $F.;}?AFtATt'?RCON4?I7IDIVS :::: . ::: ;< TQTAL;:GPuS T4~T~I..WAT'~+~ > s: UFiF : YfM7:. 3:~X Wc]. 51~. ; :~TATIC:::: , :... D1~F ::: f~1VlP ~RI~I.C~ ~A~;G~t~AV AS RAfi~: ; .G+~s.Gtl1~INI IIT.. HI:aF~I~i~S 4 -~'C~: ~UlY1Ph- mld~ br mn;: . ; : s~G ci~ F si~ ; ~4th~ /a ;.. $~~ : ;: ~~s--I~~? ~~ .: <~n~:; air=~ cs i;is~f~d ms m' ` ::.. bwtd ;; 'bbls ; Continue Flowing 41-15RD, Dumped 12~1512007 17:30 sand buster, 1150 40 510 22 1045 61 80 1.000 0.568 1732.06 7497.78 661.92 3203.42 Estimated Fluid Rate,Continue 12/15/2007 18:00 dumping sand buster 1150 40 510 22 1045 65 80 1.000 0.568 1787.99 7535.03 605.76 3216.04 Increased choke to 24/64 12/151200718:30 1150 40 510 22 1045 53 80 1.000 0.568 1614.41 7568.67 704.64 3230.72 Continue Fiowing 41 •15RD, Dumped 12/15/2007 19:00 sand buster, 1150 40 510 24 1030 62 80 1.000 0.568 1732.25 7604.76 539.52 3241.96 Continue Flowing 41 •15RD, Dumped 12/15I2007 19:30 sand buster, 1150 40 510 24 1035 60 80 1.000 0.568 1708.25 7640.35 612.96 3254.73 Continue Flowing 41 •15RD, Dumped 12/15/2007 20:00 sand buster, 1150 40 510 24 1035 62 80 1.000 0.568 1736.91 7676.53 710.88 3269.54 Estimated Fluid Rate,Continue 12/15/2007 20:30 dumping sand buster 1150 39 510 24 1035 61 80 1.000 0.568 1722.84 7712.42 595.20 3281.94 Estimated Fluid Rate,Continue 12/15/2007 21:00 dumping sand buster 1150 39 510 24 1040 61 80 1.000 0.568 1727.45 7748.41 663.36 3295.76 Continue Flowing 41-15RD, Dumped 12/15/2007 21;3~ sand buster, 1150 39 510 24 1035 59 78 1.000 0.568 1696.80 7783.76 665.28 3309.62 Continue Flowing 41-15RD, Dumped 12/15/2007 22:00 sand buster, 1150 39 510 24 1035 60 79 1,000 0.568 1711.13 7819.41 697.44 3324.15 Continue Flowing 41-15RD, Dumped , 12/15/2007 22:30 sand buster, 1150 39 510 24 1035 61 79 1.000 0.568 1722.84 7855.30 602.88 3336.71 Continue Flowing 41-15RD, Dumped 12/15/2007 23:00 sand buster, 1150 39 510 24 1035 62 79 1.000 0.568 1739.44 7891.54 618.24 3349.59 Estimated Fluid Rate,Continue 12/15/2007 23:30 dumping sand buster 1150 36 510 24 1035 60 79 1.000 0.568 1711.13 7927.19 660.48 3363.35 Continue Flowing 41-15RD, Dumped 12I16I2007 0:00 sand buster, 1150 37 510 24 1030 60 79 1.000 0.568 1706.53 7962.74 507.36 3373.92 Continue Flowing 41-15RD, Dumped 12/16/2007 0:30 sand buster, 1150 38 510 24 1030 60 79 1.000 0.568 1706.53 7998.30 977.28 3394.28 Continue Flowing 41-15RD, Dumped 12/1612007 1:00 sand buster, 1150 38 510 24 1030 60 79 1.000 0.568 1706.53 8033.85 443.52 3403.52 Continue Flowing 41-15RD, Dumped 12/16/2007 1:30 sand buster, 1150 38 500 24 1030 58 79 1.000 0.568 1677.83 8068,8U 564.00 3415.27 Increased choke to 26/64, Estimated I 12/16I2007 2:00 Fluid Rate 1150 38 490 24 1015 60 80 1.000 0.568 1690.26 8104.02 702.72 3429.91 ~ Continue Flowing 41-15RD, Dumped 12l1612007 2:30 sand buster, 1150 39 490 26 1025 60 80 1.000 0.568 1699.47 8139.42 568.32 3441.75 Continue Flowing 41-15RD, Dumped 12/16/2007 3:00 sand buster, 1150 39 500 26 1035 62 80 1.000 0.568 1736.91 8175.61 594.72 3454.14 Continue Flowing 41-15RD, Dumped 12116/2007 3:30 sand buster, 1150 39 500 26 1030 62 80 1.000 0.568 1732.25 8211.70 943.68 3473.80 ~ • Page 11 coMPqNV: Marathon Oil Company EXPRO ""' f ~~ ~~~'M1 F/ELD, Sterlin Unit _, : SURFACE WELL TESTING REPORT f ~ g ~ ` ~EASE: Sport Lake ~ •• ` n~'a~`uTh°" ~~'~f~i~~'~/ wEl.~#• 41-15RD Support 43-9x co. REP.: Mickey Mullins pAT~fl'1A11~ ;: ;:Ft~11~IfiF`~k£S : :::: `::.W~1.1~:F1~AI3:G~JNp ITI£}N5 ;;:. . :' . ; .5EPAF~iC'f1JR:GON 1?171L'?h1S ;:: .T.Cl~A L::G~S::.;:.... TUT~1l::;VICRT~~:: ; <>: t;: .. ;':: z `...... .. 1~U}'~F :': .Vx1l~{7 33-5D(: GI'~4kC. 9,SNf ::~TRTIC.: , ': D1~F .;: TEIII~A!; LIRIFICt~"., CyAS;Gf~AV ,~`aR$ R+bi~'I`E X'i~ Pr4N!llR. ;;1~1('f. Ck~(<41~kE'~~$ I~{2d:iXA4~'~': :..F''i+~~V11VJ.: ; ~n/dl hr rn~ : i: ,;:: sr~ i~e F sIG ;;: 64ths . /o ~iG ; ~-+gH~t) de ,' itls: a~!'?:1 4 tij9c#td . : ~ns . ;: tl3 ;:;?> ' .;:I?'kWt~ ..... .' 6bls ; Continue Flowing 41-15RD, Dumped 12/16/2007 4:00 sand buster, 1150 38 500 26 1030 63 78 1.000 0.568 1751.26 8248.18 621.12 3486.74 Estimated Fluid Rate,Continue 12116/2007 4:30 dumping sand buster 1150 38 500 26 1030 59 78 1.000 0.568 1694.71 8283.A9 734.40 3502.04 Continue Flowing 41-15RD, Dumped 12116I2007 5:00 sand buster, 1150 38 500 26 1020 55 80 1.000 0.568 1622.66 8317.29 355.68 3509.45 Continue Flowing 41-15RD, Dumped ~ 12/16I2007 5:30 sand buster, 1150 37 500 26 1035 60 80 1.000 0.568 1708.65 8352.89 731.52 3524.69 Continue Flowing 41-15RD, Dumped 12~16I2007 6:00 sand buster, 1155 39 500 26 1040 60 80 1.000 0.568 1713.22 8388.58 888.96 3543.21 Estimated Fluid Rate,Continue 12116/2007 6:30 dumping sand buster 1155 39 500 26 1040 6p 79 1.000 0.568 1715.72 8424.33 658.56 3556.93 Continue Flowing 41-15RD, Dumped 12/16/2007 7:00 sand buster, 1155 39 500 26 1040 58 79 1.000 0.568 1686.86 8459.47 659.52 3570.67 Continue Fiowing 41-15RD, Dumped 12/16/2007 7:30 sand buster, 1155 39 500 26 1040 60 79 1.000 0.568 1715.72 8495.21 732.48 3585.93 Continue Flowing 41-15RD, Dumped 12/16/2007 8:00 sand buster, 1155 39 500 26 1040 62 79 1.000 0.568 1744.10 8531.55 648.96 3599.45 Continue Flowing 41-15RD, Dumped 12/16/2007 8:30 sand buster, 1155 39 500 26 1040 57 79 1.000 0.568 1672.24 8566.39 555.84 3611.03 Estimated Fluid Rate,Continue 12/16I2007 9:00 dumping sand buster 1150 39 500 26 1040 60 79 1.000 0.568 1715.72 8602.13 645.60 3624.48 Continue Flowing 41-15RD, Dumped 12/16/2007 9:30 sand buster, 1150 39 500 26 1040 60 79 1.000 0.568 1715.72 8637.88 803.52 3641.22 Continue Flowing 41-15RD, Open 12/16I2007 10:00 Choke to 27164 1150 40 500 26 1040 59 79 1.000 0.568 1701.35 8673.32 641.76 3654.59 Continue Flowing 41-15RD, Dumped 12I16I2007 10:30 sand buster, 1150 40 500 27 1040 59 79 1.000 0.568 1701.35 8708.76 667.20 3668.49 Continue Flowing 41-15RD, Dumped 12/16/2007 11:00 sand buster, 1150 40 500 27 1040 60 79 1.000 0.568 1715.72 8744.51 600.96 3681.01 Continue Flowing 41-15RD, Dumped 12I1612007 11:30 sand buster, 1150 40 500 27 1040 59 80 1.000 0.568 1698.88 8779.90 617.76 3693.88 Estimated Fluid Rate,Continue 12/16/2007 12:00 dumping sand buster 1150 40 500 27 1040 60 80 1.000 0.568 1713.22 8815.59 624.96 3706.90 Continue Flowing 41-15RD, Dumped 12/16/2007 12:30 sand buster, 1150 40 500 27 1040 60 80 1.000 0.568 1713.22 8851.29 606.72 3719.54 Continue Flowing 41-15RD, Dumped 12/16/2007 13:00 sand buster, 1150 40 500 27 1040 60 80 1.000 0.568 1713.22 8886.98 589.44 3731.82 Continue Fiowing 41-15RD, Dumped 12/16/2007 13:30 sand buster, 1150 40 500 27 1040 60 80 1.000 0.568 1713.22 8922.67 568.80 3743.67 Continue Flowing 41-15RD, Dumped 12/16/2007 14:00 sand buster, 1150 40 500 27 1040 60 80 1.000 0.568 1713.22 8958.36 658.56 3757.39 • ~ Page 12 connPANV: Marathon Oil Company EXPRO , ~ ~~ . Fle~o: Sterling Unit SURFACE WELL TESTING REPORT ~• ~ . ;~ ~~~ ~e,4SE: Sport Lake ~ ~ , . :•... ...°. . . :.:: ..: PA1~RfiTFbk ~~~~ weu#: 41-15RD Support 43-9x co. aeP.: Mickey Mullins Df1T~f71~ ,; ` ;::`::::::;.;':'>F~1VIi4F'J~S:::':::;. , i ~~k~N~Ai) C~NI~I TIfi.11;E5; ; :::: ; S~PAFi:4TDR CONI[?J~IDNS .: . > <:`<T417A 1. GAS ;:: T457~[. WA'~1~ <;. . . :~l}!~P' . FiT , :....: . '.~,3.?9X 1^i4kfi~ ~SI~E" $TRTIC : ;>;:>i~` ~1+`~' ~".,IV~~ Ifi1FIC~ ~A$:GiffAY. ; ~"aRS REkTF+ k~''CLlMIVI. ~U~':'' '.~1+C1i fFE~`li ~ ~i f~l~k'~'~ i'+C~~~': d:' ,;: ;.ml. ~ hr ma .. ;:. . ;.;;:: <; ~G ,. s . ... e d.. .~' s .. ..r~ ~ t _4 Mt~ .. 10 .. s . i~ . i~sH . ......~s~ tf , . .~. .. . i s: ..... n... a rs:li .:. _.t.......v . '.. cf ., ... ~s.../d .. g.;. .'' ... m . ::?:; ;.;: :;: m :;; (isrvld bbls :. Estimated Fluid Rate,Continue 12/16/2007 14:30 dumping sand buster 1140 40 500 27 1040 59 80 1.000 0.568 1698.88 8993.76 600.00 3769.89 Continue Flowing 41-15RD, Open 12I1612007 15:00 Choke to 28/64 1125 40 500 27 1040 60 80 1.000 0.568 1713.22 9029.45 653.76 3783.51 Continue Flowing 41-15RD, Dumped ~ 12/16/2007 15:30 sand buster, 1125 40 500 28 1035 59 79 1.000 0.568 1696.80 9064.80 528.00 3794.51 Continue Flowing 41-15RD, Dumped 12/16/2007 16:00 sand buster, 1125 40 500 28 1035 59 79 1.000 0.568 1696.80 9100.15 727.20 3809.66 Continue Flowing 41-15RD, Open 12116/2007 16:30 Choke 30/64 1120 40 500 28 1035 59 79 1.000 0.568 1696.80 9135.50 547.20 3821.06 i Continue Flowing 41-15RD, Dumped 12/16/2007 17:00 sand buster, 1110 40 500 30 1035 59 79 1.000 0.568 1696.80 9170.85 561.12 3832.75 Continue Flowing 41-15RD, Dumped 12116/2007 17:30 sand buster, 1110 40 500 30 1035 60 79 1.000 0.56$ 1711.13 9206.50 733.92 3848.04 Estimated Fluid Rate,Continue 12/16/2007 18:00 dumping sand buster 1110 39 500 30 1030 60 78 1.000 0.568 1706.53 9242.05 605.76 3860.66 Increased choketo34/64 12/16/200718:30 1110 39 500 30 1030 58 75 1.000 0.568 1787.70 9279.29 688.32 3875.00 Continue Flowing 41-15RD, Dumped 12I16I2007 19:00 sand buster, 1110 39 500 34 1030 56 72 1.000 0.568 1665.76 9314.00 877.92 3893.29 Incresed choke to 38/64 12/16/200719:30 1110 40 500 38 1030 58 70 1.000 0.568 1700.39 9349.42 281.76 3899.16 Continue Flowing 41-15RD, Dumped 12/16/2007 20:00 sand buster, 1110 41 500 38 1030 55 69 1.000 0.568 1658.32 9383.97 677.76 3913.28 Incresed choke to 42/64 12/16/2007 20:30 111a 41 500 38 1030 57 66 1.000 0.568 1696.03 9419.30 677.28 3927.39 Estimated Fluid Rate, Incresed 12116I2007 21:00 choke to 44/64 1110 40 500 42 1030 60 73 1.000 0.568 1721.68 9455.17 655.20 3941.04 Estimated Fluid Rate, Incresed 12/16/2007 21:30 choke to 48/64 1100 40 500 44 1030 60 72 1.000 0.568 1724.27 9491.09 663.36 3954.86 Continue Flowing 41-15RD, Dumped 12116I2007 22:00 sand buster, 1100 40 500 48 1030 56 70 1.000 0.568 1670.80 9525.90 601.44 3967.39 Continue Flowing 41 •15RD, Dumped 12I16I2007 22:30 sand buster, 1090 38 500 48 1030 58 72 1.000 0.568 1695.26 9561.22 554.40 3978.94 Continue Flowing 41-15RD, Dumped 12/16/2007 23:00 sand buster, 1090 41 500 48 1030 60 69 1.000 0.568 1732.12 9597.31 68$.32 3993.28 Continue Flowing 41-15RD, Dumped 12J16I2007 23:30 sand buster, 1090 40 500 48 1030 59 69 1.000 0.568 1717.61 9633.09 614.40 4006.08 Estimated Fluid Rate,Continue 12/17l2007 0:00 dumping sand buster 1090 39 500 48 1030 55 63 1.000 0.568 1673.81 9667.96 629.76 4019.20 Estimated Fluid Rate, Choke Full 12/17/2007 0:30 Open 128 1090 39 500 48 1030 55 62 1.000 0.568 1676.45 9702.89 622.08 4032.16 i ~ Page 13 con~PaNY: Marathon Oil Company EXPRO , ` . FIELD: Sterling Unit SURFACE WELL TESTING REPORT f• ; ; ;~ ~~E~~M1. LEASE: Sport Lake . .. ; :.. ~.:.: .....: ~'~'t~4"i~i : ~a,~Fn;ou ~~/ WELL#; 41-15RD Support 43-9x CO. REP.; Mickey Mullins >:::<:>:;, . :::: : .ilNf ::::>;: ~3..TF,.1.......E ..... :::::> :::>::::>::::>:<:::»> »:: . >::«:::>::::>::::>::>::>:z:<:s>: .... ...................ft~1~il~fti~S....................... ::::>::»>::>::< ::. ...: :: ::::: .: . i: . N.> ............~f~~I.H~RI~.~~......f~1 : :1L3i~E ':>::>:::<:>:::>:: T......~~........... :<:::>::::>::»>::»::>::>::s::::: : .:..A '. TDR:C >:fi ......................"a.~P..E~A...........a.. l :: : . S ::::>::::>:::<i:»>::>::::>::>;: .t~tT(UEV......................... :::>::::>:::»> :Q:: : ......... T...TA :<r. : . ::>s::>::>::::: f~.c3PcS::::::::.. :'<:;::::>:>:>::>::>::>:::>;: . ..:: ; a> : . : . :;;;;;;»>:.;>;:.;;>;; ......:.:::::: :.::: T4?T~f.:aNAT&R::::. :::: :.:.:::::: . ., ..; . ;. ~~;:~;:.1'1.~;:~:~;:~~ _ vv P..... ~::~.:' ...:: ..~~kt . :::::..:3_..:.::: ..~...~x.. ::.;;~<'Q... c~i...~ .:. : ~~ asu~- ~z::$:.',:;~~~>:~;:2~: ... T,a'flc.. ~:~~~;:;.~;.;:~:~:.:::;;:;: . ~1~~.... ;:;::;.'.~':~;:~;:~':~:<; .T~M~ :;;«.>~~;~~;:~:;:::~r~:: o~RIFI~~ .:::p::;:;.>;:>:;::~;::~r::. ~A~~ffasr.: ::::.::~;:.:;;~o;:o:~:«~: .~~~ ~€~. ~;:~r~::;:<;::;~;~>::~;::>:: ~,~:Gtl~~n ::':;;:.;.;,~:: ~+l'~.;. .;,;.,~,::;.;::.;,::.;~o:~~ ~H~aREq~. ::::::;:~::.::>~.;;~:;,:;~. Hz4.:~~'~: ~.:::.;:::;.~::.;. ;:~~MI~::: ~ Rl/dl~'''.' ht:~1711 ~ ~i: ~:~..~;: ::~:: ~ : ...:.::.:, ~ ' , .. ~ ~s1G ~~ ~d@ F ,.. :.: . Sk.F'a:'~: ::. '84th~ n~ .. ~:;:;:'.:'IC`a insH~~~ de~'~~.~. ..:.. an~: ~::; . ai~1 4 ~ ... ii?~scftd ? '~ms ~ :.:~'~Rri~ 'i>: bwi~i ~~~~ . bbls : Continue Flowing 41-15RD, Dumped 12/17/2007 1:00 sand buster, 1090 39 500 128 1030 50 60 1.000 0.568 1603.48 9736.29 622.08 4045.12 Continue Flowing 41-15RD, Dumped 12/17I2007 1:30 sand buster, 1090 39 500 128 1030 52 60 1.000 0.568 1635.26 9770.36 554.40 4056.67 Continue Flowing 41 •15RD, Dumped 12/17/2007 2:00 sand buster, 1090 39 500 128 1030 55 62 1.000 0.568 1676.45 9805.29 704.16 4071.34 Continue Flowing 41-15RD, Dumped 12/17/2007 2:30 sand buster, 1090 39 500 128 1030 55 65 1.000 0.568 1668.58 9840.05 451.20 4080.74 Continue Flowing 41 •15RD, Dumped 12I17/2007 3:00 sand buster, 1090 40 500 12$ 1030 54 64 1.000 0.568 1655.91 9874.55 700.80 4095.34 i Continue Flowing 41-15RD, Dumped 12l17/2007 3:30 sand buster, 1090 I 40 500 128 1030 55 65 1.000 0.568 1668.58 9909.31 759.84 4111.17 Continue Flowing 41-15RD, Dumped 12/17/2007 4:00 sand buster, 1090 39 500 128 1030 58 65 1.000 0.568 1713.51 9945.01 486.24 4121.30 Estimated Fluid Rate,Continue 12/17/2007 4:30 dumping sand buster 1090 38 500 128 1030 55 64 1.000 0.568 1671.19 9979.82 663.36 4135.12 Continue Flowing 41-15RD, Dumped 12/17/2007 5:00 sand buster, 1090 38 500 128 1025 55 65 1.000 0.568 1664.00 10014.49 402.24 4143.50 Continue Fiowing 41-15RD, Dumped 12117I2007 5:30 sand buster, 1090 39 500 128 1025 57 66 1.000 0.568 1691.39 10049.73 651.36 4157.07 Continue Flowing 41-15RD, Dumped 12117/2007 6:00 sand buster, 1090 39 500 128 1025 55 66 1.000 0.568 1676.47 10084.65 753.12 4172.76 Continue Flowing 41-15RD, Dumped 12/17/2007 6:30 sand buster, 1090 39 500 128 1025 55 66 1.000 0.568 1676.47 10119.58 688.80 4187.11 Continue Flowing 41-15RD, Dumped 12/17I2007 7:00 sand buster, 1090 39 500 128 1025 54 66 1.000 0.568 1646.24 10153.88 458.88 4196.67 Continue Flowing 41-15RD, Dumped 12/1712007 7:30 sand buster, 1100 40 500 128 1025 55 66 1.000 0.568 1661.43 10188.49 596.64 4209.10 Continue Flowing 41-15RD, Dumped 12117/2007 8:00 sand buster, 1100 39 500 128 1025 55 66 1.000 0.568 1661.43 10223.10 726.72 4224.24 Continue Flowing 41-15RD, Dumped 12I17I2007 8:30 sand buster, 1100 39 500 128 1025 56 64 1.000 0.568 1681.69 10258.14 790.56 4240.71 Continue Fiowing 41-15RD, Dumped 12/1712007 9:00 sand buster, 1100 39 500 128 1025 56 64 1.000 0.568 1681.69 10293.17 507.84 4251.29 Continue Flowing 41-15RD, Dumped 12117/2007 9:30 sand buster, 1100 40 500 128 1025 57 65 1,000 0.568 1694.01 10328.47 564.96 4263.06 Continue Flowing 41-15RD, Dumped ~ 12I17I2007 10:00 sand buster, 1090 40 500 128 1025 58 65 1.000 0.568 1708.82 10364.07 563.52 4274.80 Continue Flowing 41-15RD, Dumped 12117/2007 10:30 sand buster, 1090 40 500 128 1025 57 65 1.000 0.568 1694.01 10399.36 734.88 4290.11 Continue Flowing 41-15RD, Dumped 12/17/2007 11:00 sand buster, 1090 40 500 128 1025 56 65 1.000 0.568 1679.07 10434.34 733.92 4305.40 • ~ Page 14 connaANY: Marathon Oil Company EXPRO ,, ~ ' . FIELD: Sterlin Unit ~, . , SURFACE WELL TESTING REPORT f ~ ' ~ ~~~~ .... LE.4sE: Sport Lake ::... ..... .; ...:.• ~: m~ti~;ou ~~~~~ wE~L#: 41-15RD Support 43-9x co. ReP.: Mickey Mullins #)A~~fTl1l~ :: F~~11~I1~Ftl!£S:: : ::. < 1~fF~lk1~AL7 Ga.NI~ tTl~31~#5 i ....... . :. S~PAF~~~1kR ~:.~R S1~1T{tl . TQT~1 :6 "` . f«. .. "::....:TL,~'fAf~>)11FAT~::::`:.`.'.::"::;. ,... ,... 3~U~~ H$fY#'f 43-9)C.. ~~<INfE 8511~F ;~T'Pc'~'f~"r:': . Dl~~ > >:'fk`:IV~P . 0!1+~~(~~G~ CyASGf(AS~ . ~".,~$ R~#T~ G~ C11MIVt 1~U'~`: CI~La~~,~`f~'.S I~Q:I~4`~'~. ("rU~~i: ; `Flldl~ ~ 17! ~~rrll] :: ;.: : .:. ~:. ;.; : . . iG . .:. d€ R ~ s-~~.~ B~MfIS o : s~~ "? : j~sH~#] , d~~ ~ ~::: . .~ rnS: ?:~: ~"air-1,~ i7sc#!d .': ::>: ii1S :>::... ~ ' ~ ~ .q3 . ::'' ~.` . ~'ASl'~.: .; , ~b~7~5 ~`. 12/17/2007 11:30 Co~tinue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 56 66 1.000 0.568 1676.47 10469.26 564.00 4317.15 12/1712007 12:00 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 54 66 1.000 0.568 1646.24 10503.56 621.12 4330.09 12/17/2007 12:30 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 55 66 1.000 0.568 1661.43 10538.17 734.40 4345.39 12/17I200713:00 Estimated Fluid Rate, Dumped sand buster, 1090 40 500 128 1025 56 66 1.000 0.568 1676.47 10573.10 638.40 4358.69 ~ 12J17I2007 13:30 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 52 65 1.000 0.568 1617.95 10606.81 846.72 4376.33 12/17/2007 14:00 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 56 65 1.000 0.568 1679.07 10641.79 791.04 4392.81 12I1712007 14:30 Continue Flowing 41-15RD, Dumped sand buster, 1090 41 500 128 1025 57 65 1.000 0.568 1694.01 10677.08 677.76 4406.93 12/17/2007 15:00 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 56 65 1.000 0.568 1679.07 10712.06 620.64 4419.86 12/17/2007 15:30 Continue Flowing 41-15RD, Dumped sand buster, 1090 40 500 128 1025 56 65 1.000 0.568 1679.07 10747.04 564.96 4431.63 ~ 12I17I2007 16:00 Continue Flowing 41-15RD, Dumped sand buster, 1U80 40 500 128 1025 55 65 1.000 0.568 1664.00 10781.71 620.64 4444.56 12/17/200716:30 Estimated Fluid Rate, Dumped sand buster, 1080 40 500 128 1025 54 64 1.000 0.568 1651.37 10816.11 601.92 4457.10 12/17I200717:00 Shut in 41-15RD, End of Test 1060 39 500 128 1020 55 64 1.000 0.568 1662.00 10850.74 564.48 4468.86 ~- ~ ~ Page 15 Report 41-15Rd Support 43-9~2-17-07.x1s ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, December 17, 2007 2:00 PM To: Maunder, Thomas E (DOA) Subject: FW: Report 41-15Rd Support 43-9X 12-17-07.x1s Attachments: Report 41-15Rd Support 43-9X 12-17-07.x1s ~ data ~~~ -~~~5 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Monday, December 17, 2007 1:39 PM To: Regg, James B (DOA) Subject: Report 41-15Rd Support 43-9X 12-17-07.x1s Jim, ~1~~-o~S Per your request this morning, I have attached the well test sheet for gas produced from SU 41-15rd to gas lift the long string side of the SU 43-9X to atmosphere. Also, I sent a separate emai to you today that clarifies what Marathon proposes to do concerning gas venting from this project. We plan to perform a four-hour test of the SU 43-9X short string through our production facilities to sales (no venting) while gas lifting the long string side to atmosphere (venting at about 1.7 MMscfd rate ) with motive gas from the SU 41-15rd well. At the conclusion of the four-hour test, Marathon will discontinue using the SU 41-15rd for lift gas which also means that we will discontinue venting gas from either well at this time. ~~ Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) «Report 41-15Rd Support 43-9X 12-17-07.x1s» ~ ~~ ~ `~' ~ ~;~~ 4/9/2009 ~ ~ ~`~ ~~~~ ~ ~~~ SU 43-9X: Post Meeting Plan~ard Plan Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, December 17, 2007 1:45 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA) Subject: FW: SU 43-9X: Post Meeting Plan Forward Plan Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 • Page 1 of 2 ~~~ -~~~~~ From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Monday, December 17, 2007 12:54 PM To: Ibele, Lyndon; Martens, Dave; Mulfin, Mickey; Paxton, Todd D.; )ohnson, Edward C.; Sweet, Welby C.; Yadav, Sharad Cc: Rang, Craig L.; Regg, James B(DOA); Cheek, Ben; Ophus, Tim Subject: SU 43-9X: Post Meeting Plan Forward Plan All, Thanks to all of you for your input regarding this project. The plan forward beginning around noon today, December 17, is as follows: 1. Open the Sterling Unit 43-9X short string (SS) side to flow to the production facilities at a fixed fluid unloading rate of 1.7 MMscfd for four hours. Record the SS gas and water rates during the flow test. Continue metering SU 41-15rd gas production through the sand buster and Expro Well Testers to lift the SU 43-9X LS side to atmosphere venting through the gas buster. Immediately upon the completion of the four-hour test of the SS, disconnect the SU 41-15rd from the SU 43-9x annulus and discontinue ventin aas. Release the Expro Well Testers. 2. If the SS is flowing dry gas at 1.7 MMscfd above 1090 psi FTP at the end of the four-hour flow test, then direct the SS flow to the annulus to lift water from the LS to the production facilities. If the SS begins to produce water after the four-hour test period and while being directed to the annulus, continue lifting LS if lift is sustainable. If LS lift cannot be sustained, shut in LS and produce SS to production facilities. 3. If the SS begins to produce water before the four-hour test period has past, then continue to flow the SS to the production facilities and shut in LS. Please contact me immediately if I have not captured the plan accurately. 4/9/2009 ~ • Page 1 of 1 Maunder, Thomas E (DOA) From: Ibele, Lyndon [Icibele@marathonoil.com] Sent: Monday, December 17, 2007 11:37 AM To: Maunder, Thomas E (DOA) Subject: Sundry status ~0~ - ~~g Tom-- FYI, just wanted to let you know that we have had an on-going, company-wide IT probiem that may affect our ability to file sundry notices timely for a few wells. The data-base system that is used to generate all of our downhole activity reports crashed on December 8th, and all the king's horses and all the king's men haven't been able to put Humpty-Dumpty back together yet and we have been given no timeline for completion. We know we are close to the 30 day deadlines for submitting Form 404 for recent work performed on Wells G03 and G05, and the 407 for G06. However, shouid the afore-mentioned database not be functionai in the next few days, we will be unable to retrieve operations summaries that are required with the sundries, and it is likely these sundry reports could be tardy. I will keep you posted if that looks likely to occur. RE Forms 10-421, there are several pending. However, we have not yet achieved stable production rates and have been unable to perform multi-point tests on Sterlin Unit wells 41-15rd and 43-9x. Those tests will be performed and submitted as soon as possible. For We Is NS-3 and GO-6, we have single-point tests only to report, because the wells are producing at maximum capacity but at very low rate. The only means to achieve multiple flow points would require that the wells be choked-back, but doing so would cause them to be produced below the unloading rate. This would not only be meaningless from a multi-point test perspective, but would also jeopardize killing the wells. We will submit a cover letter with this explanation when we submit the form 10-421 for these two wells. 4/9/2009 FW: Sterling Unit Field: Gas V~ng • Page 1 of 2 Maunder, Thomas E (DOA) _ _ _ __ . From: Walsh, Ken [kdwalsh@marathonoil.com] Sent: Tuesday, December 11, 2007 4:35 PM aO~ ~~~C To: Regg, James B (DOA) ~ Cc: Ibele, Lyndon; Mullin, Mickey; Skiba, Kevin J.; Maunder, Thomas E(DOA) Subject: FW: Sterling Unit Field: Gas Venting Jim, As a follow-up to our telephone conversation regarding this matter and at your request, Marathon will issue a 10-403 sundry tomorrow to the AOGCC that states that you provided verbal approval to continue venting gas per Marathon's request below. ~~e~2 Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) From: Walsh, Ken Sent: Tuesday, December 11, 2007 4:10 PM To: AOGCC (jim_regg@admin.state.ak.us) Cc: Ibele, Lyndon; Mullin, Mickey; Skiba, Kevin J.; Maunder, Thomas E(DOA) Subject: Sterling Unit Field: Gas Venting Jim, Mickey Mullin and I left messages on your office telephone this afternoon requesting a return call. The issue that we wished to discuss with you is how to handle additional gas venting while trying to kick off the reverse coning of gas down through the water leg to establish continuous flow from the longstring side of the Sterling Unit 43-9X wellbore. The situation is as follows: - The SU 43-9X (PTD #207-073) was permitted as a dual gravel pack gas well under Sundry Approval #307-220 to produce the Sterling B-4 Sand. The intent was to use an anticipated relatively water-free gas source from the short string side of this well to be the motive gas source to lift produced fluid up the long string side at a high enough rate to cone the gas cap gas down through the water leg and establish a reverse coning gas lift producer. Unfortunately due to the amount of fluid lost to the SS side during the workover, a water-free gas source was not available for the gas lift on the long string side. - It was decided to meter the gas production from the SU 41-15rd well (PTD #207-0880 ~__ through the Expro WeII Tester's equipment to use as the motive gas source to lift the long 4/9/2009 ~W: Sterling Unit Field: Gas ~ing ~ ~ Page 2 of 2 string. It was anticipated that production, both water and gas, would be routed through the production equipment without having to vent any of the gas. Unfortunately, the surface facilities were unable to handle the production slugs and was shut down immediately after discovering a high dew point at the sales point. - Marathon reconfigured the ffowback equipment downstream of the SU 43-9X LS to bring the well on to atmosphere for a short period to stabilize the well production and attempt to eliminate the fluid slugging. We have been flowing to atmosphere for about 6 hours as of 16:00 hrs on 12/11/2007. We anticipate that we will need to vent this gas overnight and perhaps for up to another 96 hours to establish unaided production from the long string. We are injecting about 1.6 MMscfd rate down the SU 43-9X annulus from the SU 41-15rd source well. - Marathon and Expro personnel are maintaining full record of the rates and volumes being transferred from one well to the other. Marathon will report this volume to the AOGCC on the Form 10-422. The expected total volume to be vented would be no more than 10.00 MMSCF over the venting period proposed. It is quite possible that this venting period and total volume could be much less if the total production stream can be successfully put through the production facility without jeopardizing the sales gas quality. Marathon plans to make every effort to try to take this production through the facility as soon as can be done safely and responsibly. Our question is does this situation require 10-403 approvai far the volumes and rates aforementioned? If so, can Marathon continue venting this gas as proposed above with your verbal approval and submit a 10-403 sundry tomorrow as follow up to the verbal? Marathon did not anticipate this situation and therefore did not request approval for venting the gas previously. ..~{~!2 Ken D. Watsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907-283-1311 (office) 907-394-3060 (cell) 4/9J2009 SU 41~15RD & SU 43-9x 10-4~dry Status ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, December 06, 2007 3:23 PM To: 'Skiba, Kevin J.' Cc: Ibele, Lyndon; Rang, Craig L.; Donovan Jr, Dennis M.; Walsh, Ken Subject: RE: SU 41-15RD (207-088) 8~ SU 43-9x (207-073) 10-421 Sundry Status Kevin, Thanks much for the update. I will place a copy of this message in the flles. Call or message with any questions. Please remember to include the PTD numbers in the message header. It helps with the filing. Tom Maunder, PE AOGCC From: Skiba, Kevin ). [mailto:kskiba@marathonoil.com] Sent: Thursday, December 06, 2007 3:13 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Rang, Craig L.; Donovan Jr, Dennis M.; Walsh, Ken Subject: SU 41-15RD & SU 43-9x 10-421 Sundry Status Tom, I wanted to update you on our progress status for the 10-421 Sundries for SU 41-15RD and SU 43o9x. A 4-point test was perFormed on SU 41-15RD well resulting in erroneous data. We will have to retest the well after we work through the issues that are preventing us from bringing it on production. We are still working to kick-0ff SU 43- 9x. A 4-point test will be performed once gas production stabilizes from this well. I will start working on the 10-421 Sundries, for both of these wells, once the proper data is available. Thanks, Kevin Sidba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 12/6/2007 ~ ~ Page 1 of 1 ~ Maunder, Thornas E (QOA) From: Skiba, Kevin J. [kskiba@MarathonOif.Comj Sent: Tuesday, October 16, 2007 1:53 PM To: Maunder, Thomas E (DOA) Gc: Icibete@MarathonOii. Com Subject: RE: SU 41-15RD (207-088) Attachments: SU 41-15RD Drilling ~perations Summary.pdf ( r ,~ \ _ _\ ~ `~"'R CJF`~~~~~~~~Et`C~:~`~c~h~ c~~~~cJ ~~ `'{,~~ Tom, ~ ~ ~~ c~,~ ~ /cr~ J ~'- ~ The 10-407 Sundry for abandoning the 5U 41-15 well bore has not been submitted yet. I will be working on getting it out to you soon. I have attached the drilling portion of the Operations Summary for SU 41-15 / SU 41-15RD well. There are a number of people involved with the distribution of drilling information. So please disregard this attachment if someone else has already forwarded this information to you. We are currently evaluating the process that we use to distribute drilling information. We are looking at ways that we can refine and improve this process to ensure that the appropriate information gets to the AOGCC. Thanks, Kevin Skiba Production Technician Marathon Qil Company Office (9U7) 283-1371 Cell (907) 394-1332 Fax (9Q7) 283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, October 12, 2007 10:07 AM To: Skiba, Kevin 3. Cc: Ibele, tyndon Subject: SU 41-15RD (207-088) Kevin, I am reviewing the 407 for this wetl. The operations summary does not haue any of the drilling details. Could you please send the reports, emait is fine. Afsa, do you know the status of tf~e 407 for abandoning SU 41-15? I do not find any entry in our log that we have received the report for the recent P&A work. Thanks in advance. Call or message with any questions. Tam Maunder, PE AOGCC 10/16/2047 ~ ~ ~arathon MARQTHON ~II COI~pa~~ October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-407 Completion Report Field: Sterling Unit Well: SU 41-15RD Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Enclosed is the 10-407 Sundry Completion Report for Sterling Unit well SU 41-15RD. ~ This well was side tracked in July 2007 and the perforation and fracturing work was concluded in late September 2007. Completion operations were conducted on the Tyonek and Beluga formations. Both formations were perForated and the Beluga was fracture stimulated. The well was producing 2.3MM at 710 psi flowing pressure. If you have any questions or require additional information, please call me at (907) 283- 1371. Sincerely, r ,`~ ~~~~~~~~' ~ ~ Kevin Skiba Production Technician Enclosures: 10-407 Completion Report cc: Houston Well File Welt Schematic Kenai Well File Operations Summary KJS Directional Survey CLR ~ ~ ~3 6r.+~Q ~ ~~~ ~ ,~ ~ STATE OF ALASKA i ~~ '; C~ii~? ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L~7~ ~' `~~" °"'~~' 1a. Weli Status: Oii~ GasQ Plugged ~ Abandoned ~ Suspended ~ 2onac2s.~os 2orac2a~io GINJ^ WINJ ~ WDSPL~ WAG ^ Other^ No. of Completions: ~ 1b. Well Class: Development Q- E~cpioratory^ Service ~ Stratigraphic Test ^ 2. Operator Name: Marathon Oil Company 5. Date mp., Susp., or Aband.: 9/ /2007 . 12. Permit to Drili Number: 207-0880 ' 3. Address: PO Box 1949 Kenai Alaska 99611-1949 6. Date Spud5led: ~~ ~ 7/7/2007 ~N 13. API Number: 50-133-20484-01-00 ~ 4a. Location of Well (Govemmental Section): Surface: 2,327' FSL, 437' FEL, Sec. 9, TSN, R10W, S.M. 7. Date TD Reached: 7/20/2007 14. Well Name and Number: SU 41-15RD - Top of Productive Horizon: 115' FNL, 3,641' FWL, Sea 15, T5N, R10W, S.M. 8. KB (ft above MSL): ~ 245' Ground (ft MSL): .- y24' 15. Field/Pool(s): Sterling Field - Total Depth: 474' FNL, 4,194' FWL, Sec. 15, T5N, R10W, S.M. 9. Plug Back Depth(MD+TVD): 14,585' MD 9,460' ND Beluga & Upper Tyonek Pools 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 314742.19 y- 2390034.43 Zone- 4 10. Total Depth (MD + TVD): 11,655 'MD 9,517' ND 16. Property Designation: A- 028063 ' TPI: x- 316993.39 y- 2388503.44 Zone- 4 Total De th: x- 319309.51 P y- 2387144.21 Zone- 4 11. SSSV Depth (MD + TVD): NA 17. Land Use Permit: ~ 18. Directional Survey: Yes ~ No (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: Nq (ft MSL) 20. Thickness of Permafrost (TVD): ! NA i 21. Logs Obtained (List all logs here and sul~mit electronic and printed information per 20 AAC 25.071): ~~a~~ ~~~MD~~/TYb, ~ ``~•s Quad Combo, Gamma Ray, CCL, CBL, PT ; 22. CASING, L WER AND CEMENTING RECORD ' CASING WT. PfR GRADE SETTING DEPTH MD SETTING DEPTH ND H E IZE AMOUNT FT TOP BOTTOM TOP BOTTOM OL S CEMENTING RECORD pULLED ~ 0 20" 133 K-55 0' S8' 0' 58' Driven ', 13-3/8" 61 K-55 0' 2,271' 0' 2,270' 17.5" 1,186 sacks I 9-5/8" 40 L-80 0' 6,281' 0' 5,615' 12.25" 2,284 sacks ~ 3-1/2" 9.3 L-80 0' ,,,f~32~ 0' 9,499' 8.5" 2,001 sacks o ~-~a ~ 23. Open to production or injection? Yes Q No ~ if Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) ' 6 Excaae Intervals ' ' 9,930 - 9,940 MD 7,965'-7,974' TVD (10') 10 031' 10 041' MD 5 8 ' T ' ' , - , ,065 8,0 6 - VD (10 ) 10 157'-10 167' MD 8 169'-8 178' TVD (10') 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' , , , , 10,201'- 10,211' MD 8,209'-8,218' TVD (10') DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ' 10,579'- 10,581' MD 8,542'-5,551' TVD (10') 9,930' - 9,940' 44,021# 20/40mesh White Ottawa Sand ' 11,479'-11,527' MD 9,364'-9,407' TVD (48') " 10,031' - 10,041' 23,969# 20/40mesh White Ottawa Sand ' 2-1/8 . 6saf. 60 des~ree ahase 11 467' 11 480' MD 9 353' 9 365' TVD 13' 10,157'-10,167' 31,902# 20/40mesh White Ottawa Sand , - , , - , ( ) 11 489'-11 506' MD 9 373'-9 388' TVD (17') 10,201'- 10,211' 11,076# 20/40mesh White Ottawa Sand , , , , 10,571'- 10,581' 19,054# 20/40mesh White Ottawa Sand 26. PRODUCTION TEST Date First Production: 9/23/2007 Method of Operation (Flowing, gas lift, etc.): Flowin Date of Test: 9123/2007 Hours Tested: 24 Product+on for Test Period Oil-Bbl: 0 Gas-MCF: 2,300 Water-Bbl: 93 Choke Size: 128 (64ths) Gas-Oil Ratio: i NA ~, Flow Tubing Press. 710 Casing Press: 0 Calculated 24-Hour Rate .••- Oil-Bbl: 0 Gas-MCF: 2,300 93 Oil Gravity - API (corr): 'I NA 27. CORE DATA Conventional Core(s) Acquired? Yes U No LJ Sidewall Cores Acquired? Yes U No U If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and Iaboratory analytical results per 20 AAC 25.Q71:;::i+.;:~ ~i,t:T'tU~ ~~S ~~~ OCT ~ 3 2D07 ~ ~~ ~ .. Y' . .. ~° ~~~ Form 10-407 Revised 2/20070 R I G I N A~NTINUED ON REVERSE ~ ~ ~ 28. GE~LOGIC MARKERS (List all formations and m encountered): 29. FORMATION TESTS ' NAME MD ND Weli tested? Yes ~ No if yes, list intervals and formations tested briefly , summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost - Top detailed test information per 20 AAC 25.071. Permafrost - Base Upper Beluga 6,300' 5,628' Middle Beluga 7,241' 6,184' Excape completion - there were no tests of individual formations. Lower Beluga 8,865' 7,117' Tyonek 11,060' 8,983' Formation at total depth: Tyonek 11,655' 9,524' 30. List of Attachments: Operations Summary, Well Bore Diagram, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kevin Skiba (907) 283-1371 Printed Name: Craig L. Rang Title: Senior Completions Engineer Signature: Phone: (907) 283-1372 Date: October 4, 2007 u , ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ftem 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~~ , ~, #~ M ~: 50-133-2048400-00 ~ertv Des: ADL 2497 21' AGL (245' KB Elevation) 314,742.19 2,390,034.43 60° 32' 14.914" N ~ 151° 01' S1.643" W d: 09:00 hrs 7/07/2007 teached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Top of Cement 600' MD above 9-5/8" window 9-5/8" Casinq Window milled from 6,275' to 6,294' (MD) SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, TSN, R10W, S.M. 3-1/2" L-80 To~ MD 0' ND 0' 9.3 ppf EUE Bottom 11,632' 9,499' rd with 6.25" OD control Iine protectors. 8-1/2" ole, Cmt w/ 545 sks (176 bbls) 13.5 ppg Class G mt lead and 1456 sks (300 bbls) 15.8 ppg Class G m} fail ~ • Ceramic flapper valves below each module as follows: Module 6 - 9,941' Module 5 - 10,042' Module 4 - 10,167' Module 3 - 10,211' Module 2 - NA Module 1 - NA ~laooers MD (RKBI: WeatherFord Float Collar 11,584' MD ; Weatherford Float Shoe ~ , "1 62~' I Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' - 11,527' Perf (TVD): 7,965' - 9,408' Angle @ KOP and Depth: Completion Fluid: 6% KCL Angle/Perfs: 25 deg Conductor 20" K-55 133 ppf PE To~ Bottom MD 0' S8' ND 0' S8' Surface Casina 13-3/8" K-55 61 ppf BTC To~ Bottom MD 0' 2,271' ND 0' 2,27D' Cmt w/ 1186 sks of Class G, 9-5/8" L-80 40 ppf BTC To~ Bottom MD 0' 6,281' ND 0' S,615' original well w/ 2284 sks of class G. Milled track window 6,281' - 6,293' MD ~ ~ ~ ~~ P ~ ~ a ~ ~~ ~~. ~ ~ ~, ~ ~ ; ~IVlarathari C)if C~impany ~ ~'a~~ ~ n~1ci °, €~pe~ra~tr~an~=Summ~ry R~pc~rt ;~"~ << ~ . ;~ ; . _ ~~~~~, ~z.~, ti~~ ~ ~ ~~ ~ ti~ L~g~l Weli ~fame: STERLIM G UNIT 41~1S _ ~camrrtc~n W ell Narne; STERLI NG UNIT 41-15 Spud Da#s: 9/111998 Event Nam e: RE-ENT R'Y Start: 6/2~12t~~7 End; ~ontr~ctc-r Name: GLA~fE R C7E21LL ING Rig Release: 9l9/~fJtl3 Grcaup;: F2~g lVarne: ~LA~IE R qRILL lfVG Rig Rlumber: 1 ~ ~~ . ~ C~~t~ ~ ~ Frcrm-=~T~ , H~uts; .~ode ;~ub ~orle ~; ~ Plta~e"; ~ ~,~ '~ : Descri ~a~ s~f O e~t~€~rts s;'~~ ~ _ , ~ ~.t ~. _:. ~. _: . - . , ~~. S/25l2t}D? t?9:00 - 10:34 1.5L1 MOB R(+~ MIRU Liner was cut tao short .Sp![ce and se.am v~retd , 'IU:30 - 21.3Q 19.00 M~JB R(G : MIRU Move sub and center on well, 5st C~'enerafar, bcaiier,M+ater tank . mud pump and pats. mave carri~r and set on mud baat. Levef cafier. 5et 5t~iiways R{U gits and Mud pumps;:R~ise tterriCk,Pull e{ectrica! uvires, ~'1:30 - 22:pU f1.54 SAFETY MTG_ MIRI! : Hoid safety mee#ing wifh erane operator: 22:~C1- 44:O1t 6;Ob MOB I~i~ MIRU {Crar~e warYc) set in fuei iank,Drill~rs side ~rey iran,Start gen. and set lights,Dog house,Chake house,Wlnduvalis tJ4:Ob - d6~00 2.4D RURb f21G MIRU Raiss mast,antl hook up guide lines ~126i2047 -06.00 - d6:Qfl 34.00 RURD RIG_ MIRU Spot B4P st~~k in gray iron.. Splice and wetd on tiner on cuttings tank and ~ 3 mud pump area. inspvct man riders 5etbeaver slide and stairway to conex se# euttings tank and # 3: mud pum~s. F~un c~ntrall lines antl rig service lanes Chang~ pu~np liners Yd 4" on mud pumps.tnspect bridge cxanes,hytl. hoisE.M~ve Rig up #3 pump,change to ' 4" liners.5pvt RA-( van,and cemsnt silo.Hang torque hrbe;: Rig up seruice Iocap.Saver sub from 4 1f2 IF ta 4" FiT-38 6/2?12t~47 ~6,OQ - d9:30 3.50 RURD_ RIG_ MIRU R/U elwke and kiif lines. Comp(ete R/U GD-~t 09;30 - 05:OD ' 19.5Q SERVIC RI~ WBPREP ' Insp~cE Drawv~orks h~ake system. Bulld volurrte fn pits rJaQ}Jr71S f~r»Q ~8F ~t°~o f~f`i1,,. Repi~ce pads on c~id brake b~Mds.and instalF,: ' Rig up SJ Cemenfers,tn~talf cellar grating ou~:[ last weli. ' M1l~te instalk 'f" H{? buli pfug in pressure, relie# valve on flov/ lin~ frorr~ 32-9 weli Val~e Sef at 22i~psi, Q5:q0 - 06:00 ' ` 1.46 7EST EQIP WBPREP ' Test surface lines,kill,choke,high prassure mud lirtes to; ' 3~OQ psi- 6i~812Di#7 0,6:QQ - Q8:3Q 2.5l7 TEST EQlP VitB}~REP ~ort. Test SurEace HP mud lines, Repair ieak`s Kill Line, #9 Mwd. _ , pump liner, Gray lock clacr3p an HP m~nfold,ri~ floc~r. Galibrata and _ T esi Gas Monifors. Q8:30 -1Q:4Q 1.50 MIX Ftd WBPREP ' Mix 8.6ppg KG~ brine. Inspect well an~t prepare frrrwell kil[. 1Q~0~ -11:30 't.50 CIE~C C~lp WVBPREP ' PJShtt. Glpen choke t~ 1f4, open a~d Girculate down 2.318" TBG ~ w1B.6PP9 KGL hrine ~in~tial G5G pressure 2~24~psi last G5G pressure ~ ' 22QOpsi, tc~ak 234Qpsi tti open BPV}. 19:34 - 12_30 ~ 1.00 INS~ CT WLHD WBPI2EP Shut-in vueii due to lealting wing Walus. ln5tall #hr~aded flang~ with ; needle v~llve{C~G pressure increased F/220flpsi tcs 2500psi}. 12:3~ -15;30 i 3.f70 C1RC GF~Q WBPREP ' f'JSM. Gc~ntirnrs fa circulate TRG and bleed down annulus. Ci~a. ~ ' pressure ~5psi anc! not increasing,(pumped 40Ubhls Annulus pressure ' hl~ci F11540psi to E~si). ~15:30 -16~C3lT ~ ~.5Q FLO~1V CHEK 1A!BPt2EP -Sh~Edovitn p~mp and ~bsenteTB~'a c~n vae~um. RID ki~i Itne. 1fi:Q0 -~~:~10 i 1.0~ M[X- RIL~ W,BPREP ' Mix mo~~ 8.6PF9 [iCl brine and 50bb1 LGM p[II w/2.5ppb Fla-di~; 6ppb i po~Y pack. 50ppb CaCa2 4(? and 50ppb CaGo31d; 17:4D -17:3(l ; t3.SD PULL E{~IP V1iBPREP P,15M and pull PBU,Rig up kilf liirs 17~~0 -15.OQ' ~ 1,50 MI9C PILL V1+BPREP Pump 5~ bbl. LCN{ pitl,Spat ori bottom, Lel set for 1!2 hr. 1,J:OQ - 22:00 ~ 3.00 ,_, GlRCT, GFLR WBPREP Pump 3 bpm. 1~QD0 stks..Shut down welk ,flowiflg thru:tubing. ' Rumq E.~M to &ufec~. ~ Pump aiiother5t7 bbls.well static on esg. and' htbing.~lo losses 22:00 - 22_3Q 0.5t} RUt~D R1G_ INBPREP P.tSM;Rig"up on esg. 9 518 X 7" annulus srtd bieed 925 psi daivn to 0 psi, 22:30 - 03:Q0 2.50 NUNLl TREE WSPFtEP PJSM;set PBV Nipple dcrwn Eree. Q1:QD - 06:Q0 5.00 NUND 6t7PE WBPEiEP Nipple up 19"-i t"'fQM X'}3 518"5M adaptor spooi . l~llll S,Rd,A 13 5/8" 5M B~P. 8/29/2407 06:aU - 12:40 6.Q0 NIiND BORE WBPREP Cont. taNfU. CIO tap rams ta 2 3/8" rams. Carrier btrit: broke while kightening on rams. Ctmt to N/U riser and WU dtip pan while r~pare 2 . .. . . ... ... . . . . . . . . .... ..... . .. . . . ..... . .. . . . . .. . .. .. ..... . . . Printetl: 10t~1612QU7 12:58:45 PM ~ ~ ~ ~_ ~ : , s M~t`~tMC7tl ':~i( ~C~tT1(a~rt~/ Page ~ of ~ 0 ' ~ ~ ~-~ ~ ~ ~ , ~ _ ~. ~ t~p~rat~c~ns ~ummary t~~~ar~ : . , L~al Well Name: STERLING t~NIT 41-15 _ Common W~II Name: ST~RLING UNI"f 41-1~ Spud Date: 9/1t1998': Ev~nt ~lame: RE-ENTaY ~tart: 6/24/20~7 End: ~or-tractor Nam~;: Gt~CIER ~R1LLlNG Rig Rel~ase: 91912tI03 l~roups Rig Name: GL~CfER C7RtLLING Rig hlumb~r: 1 Date ; From -:T~ Hour~ .Cot€e ~ub Ptiase Descript~on of Qperat~ans . C ade. 6l29/20C~7 ~6:00 - t2:OQ 6.QQ NUND BOPE VUBPREP 3J$" ram :carr~ers; ft/U mous~ hc~le, 12:Q0 - 43:00 i.~D NUNQ BQPE WBpREP PJSM. Instatl2 318" rams: 13:44 -'I4:40 1.OU h1U~id BOPE WBPREP PJSM;Tes# 2 3J8 8~`d. flc~orvalve and d~~t valv€~. 14.Dp -~5:00 1.Q0 NUND B()PE WBPREP PJSRrt;Pull BPV ,InstaU iwv way check. 15AD - iFi:31~ ' 7.5Q NUND B~P~ VItBPREP P~IU 2 3J8 Tesxjoint.attempt tes# looking #orleaks,; 16:30 - 17:30 9.OE1 NUNt~ Bi~P~ WB(~REP Open rams.e6eck and r~:instali,. 17:3t1- 't$:UU Q.Sd NUN[l BQP~ VttBPREP ' Attempt to screw track into' hanger ,O-rir~g puli~d uff,unahte tQ screw in. F2ig up tt~sh pump and purnp tluid`ou~ 4f BOP. 18:00 - 20:40 2,04 NU{*JD BOPE WBPREP :Atfempt fest,nu g4od;Fternoue kifl line and eripple eheck valve fo dr~in stack; Three more attempts fo test,fry tu observe teak: 20.DQ ~- 2~:30 1,5U NUND BOPE WBPREP Ciose doar~,cont, to te~t BOP.Red~~s 2 3/8 rams ~nrith new rubb~rs. .2'i_3f! - 22:DU U.50 NUNb B~PE W~~'REP tnsYaU 2 3/8 rams with new Yubber: :22:0~ - 02:t10 ' ~S.aQ NUND BOPE WBPREP BOP tesi»25Q psi }uw 2Qflf} psi high-l0 min. ea.,Test blind rams,~ 3f8 rams,Choke Nlartifaid :valves # 1,2,3,~}.5;6,7,8,3,1U.1 ~,'t2-lnside and outside kill line uatves,Check vatve,ti~i~: 2 i/& FIc~QT vatve,and dart valve,V~hres on Tnp Qrive P~rfomance test on koomey unit. 02:fiQ - UF:30 Q.Sa NtlJdd 6tlRE WBPREP Rig down BOP Test equip. `U2:~4 - 03:30 9.00 RURD,_ GSG_ CMRPUI Rig up fo putl 2 3!8 tubing 03:30 - Q4:3fl 1.04 F~lti~fPU TBG_ GMFPUL Pick-up landing joint and make up.Back t~ut:anchor screws. ro4:3Q - 05:04 Q.5Q RUNPU T8~^ GMPPUL Pull tobing hanger free and brin~ t~ rig flaor:Lay down hanger and cut.chem. injecticrn, Iine prep to pult aut Of hole. Cheek fiow.~iuid `m well static. 05,QfJ - 06:40 1.0~~ Ri1NRU TBG_ G#UlPPUL PC}OH l,ay dbwn 2 3/$ fubing(check for nortn;}. 6/3012U07 06:60 - 1~:04 ' 6.Op Pl1LD` 'fB~ CMPRUt Pt3C~H U13 2 3I8" TBCi~check for norrn). 12;Q0 - 17:3d 5.50 P(J~D TBG CNiPPUL PJ,~M witb craw caming on. FOCJti Lf~ 2 3f~" 7~G ft~itat 126~nts 4.7RPF l-80 8rd and 173jnt5 4.7pp# J-55 8rd, check for norm}. 1~:3t~ - 19:30 ' 2.00 FillRD, GSG_ GMPPUt RlD 2 318" handling tools.P.JSM; Pick-up Test-toots arrri ehange rams to ~ ~vari6ks~.. 19:3t~ - 21:00 1,~0 T~ST B~PE GMPRUL Test Warible rams,floar valve and IBOP.254 psi k~w , 20Q0 psi high,foe 1 a min. 21:ti0 - 21;30 0.50 RUIdPU VNBSH GMPPUL Rig down test equip,set wear bushing 29:30 - 22:30 1.00 RURD RfG~ GMP`PUC PJSM;Rig floor fo piek up 4" dritl pipe: 22:~0 - 06:00 7.50 PULD IIP_ GMPRUL PJ51W1; fVlake up 4" mule shoe and RtH picking up 4" drill p~pe and drifting. Mlonitor srvelf ,No Gains No (asses 7/1/2007 06:Od - 42:00 6,00 PUL~ pP GMPPUL Cant. P/U 4" HT-38 D1'while RIH wlmule shae: 1~:00 - 12:3Q U.50 PIJLD DP GMPPUL PJSM. Coni. to t'/U 4" DP. Tag fi11~ 97~5'. 12:30 - 15:04 2.5t7 WASN FItL CMPPUL Wash Fill F/9725' to 5825` Pumped 25~bi sweep and circ aut ~' 9825'". Observed sand on shakers: 15:40 -16:3p 1.5tt W}~N FtlL GMPPUL Cont. fv wash flll F/9825' to 9839' pump 5t3bbis.sweep @ 9838' and cire, out. Ubserv~d sand c~n sMake,rs.(PfU fo4~l of 3't3 ~nts 4" DP). ~ ~16:3f1- 1~:Qp 1.5Q P-~7R+tF~ : ~Iv17- GNIPPUL PJ~M_ RlU ce~nent line. Purnp 2h6}s ~resh ntater ~he~d. Test ~ine~ Ea 1500psi. Pump 9b61s fresh water ahead. Mix and pump 211sxs <Class"~" ce:ment,w/.7~4FL~3, .3°loCD-31, .~~lr~R-3, ,1°~aASA-3U~, and ~ gphs FP-6L to yield 43.4bbls 75.$ppg slurry: Followwith 2bb15 ftesh watsr. Disp#ace wt93bhls $.6Pp9 K~L brine(p3ug Ft9839' to 92fiQ'}. 18:A~ - 19:~0 1.Q4 TRIP DP Gt+hPPUL POOFi to 8800''. 19:00 ~ 20:Qd 1.04 PUMP CMT_ GMPPUL lrrstail wiper dart and pump bottoms up to clear piga; 2Q:0~ - 00:34 4.5t1 TRIP DP GMPPUL PJSM;!'E50ff anci lay down muleshoe; 00:3D - Q'i:09 0.5p SERVlC RIG CMPPUt 5erv. rig and top drive . . ... . . . . . ..... . . . . . . .. t~iAied.:. t QJ'f;B12407 1 Z•.S8:q5 A{N , ~ ~ ~ a( V~/eli I~ame: STERLING' UM1liT 41-1~ mm~n Well Name: STERLII~~ UIJIT 4'1-15 Spud" {~ate: JJ1C'i998 nt Name: RE-~I~TRY Start: 6f2412007 End: ~tractor Name: GLACI~R ~RILL[N~ Rig Release: 9C9/~DO~ Group: ~lame: GLAGIER Dl~ILL(~iG Rig Number: 1 7{9/2D07 p1:a0 = p2:3t7' 1.50 4iEPAIR RIG_ GMPRUL ',YVtsrtc an brawarlcs brakes. d~:3~ - a6:~7t? 3.5Q TRIP DP ~ CMPPUL. 'iNake up bif and bit sub RCH 7/212Q07 (?6:Q0 - U'T:O(~ 1.0~ 'fRiP DP GMPPUL 'Gont. to RlH w161l8" bit to 8820`. Q7.44 - OS:OQ 1.,00 WASFf FIIL GItAPPUL V~Xash P/8820' ft~ fop cif p1Ug a~ 9242'~~at daw~ 9flk vn ptug with putrip~ :on~; 08:~0 - 09:OQ i.p0 GIRC N[t3Q Citi}PPUL Circ. clean (e,~ 9200'(275GPM, 56Dpsi, observed some eantarnirtateci ~ ~~me~f i~ retums~ ~9:Qf? - 09:30, 0.50 TRlP C3P ~A9PPUL :FJSM. POOH to 9040'. (19:3d -~t0_b0 0.~~ TEST~ GSG CMRPUL ':Test CS~ tcs 1QOOpsi/3Dmin: 'IQ:t~Q- 14:UQ 4.0~ TRlP DP GiNFPUL ' to 14:Oq -14=30 0.5b GI~2C ~FLq GNIPPUL Circ. u~ 17d0'(~50GPM 1S6psi), 1d:3Q - 15:3Q 1.OQ SET€iEL PKR_ GMPRUL ,PfU and sek 7" RTTS ~ 2~'. Rele~se #r~am RTT~ arrd POCiN and L!D runnitrg #004. 'i5:30 - 16,00 Q.Sd TEST_ f'KR Civ1PPUL 'Test RTTS tcs iQOQpsi{15min 16:00 -16:30 O.~a RUNPU WBSH CMPPUI ''Fufl Wear Ring '1&:30 ~ 2{3:0{) 3,5Q ~+IUND BO~'~ GMPPUL PJSM;(Vippie dawn BOP.flow nipple;~h€~ke ~nd kili line,rBrnQVe B~P, and spacer spool, 2Q:OQ - 22:OQ 2.00 NUND 1NLND CMPPUL Rembv~ 1 t' SN1 X 91"10M Eubing fiead. 22;0~ - OQ:00 ~.Q~ NLtNtJ B{?PE CR?iPPUL Insfall dS;411"-5Ff X 13 5/8'!-5ff ~ 9'.5" long and spacea'spoot ~3 5l~-5K X 3fi^ 'iong. ~Q;04 - Q6:U0 6.00 NtJhiD BOFE GMPPUL PJSM;Idipple up BO(~ ,conne~t choke #ine,install chake`vaive,hoak up' 'kiA line. 7131200~ 06:04 - 0$:30' 2.50 NU(+tC3 BO#~E GTt9PPUL 'N/U B PE. 08:3Q - 0~:30 7.OQ TEST_ B(?PE CMPPUL 5he11 test against biind rams and RTTS 254J2fl~E)psi 1Umin. ~9:90 - 1Q:30 1.00 GI:EAt~!_ Ft1G_ CMPPUL ~ ean and cleae cellararea. 10:3Q -11:30' 1.OQ Pl1LD F!ICR_ ~MPPEIL sf~etrieve,arrd U~ 7" RTT'S. 11:3Q -'t2~(lb' 4.50 GIRC,_, IulUb CNIPPUL :Girc. BfU. PJSM with creiv caming an. 12:(~0 - 13:Op' 1.00 TRIP,,~ €?P,,,_ GMPRUI~ 'POOH w( 6't/8" bit:. 13:t10 - 14:0(~ 1AQ TEST~ BCSPE CMPPUt, C/O to 7" Ramsand C/U ta lpng ba~es. 94:U0 - 14:30 Q,50 TEST_ B(3PE GNIFPUL T~st 7" Rams 250{ 0 Opsi ~t6mi~. 14:30 -15:00 0_50 PERF_ Tt3C,_ G(uIPPUL `PJSM. WU ExRrQ E/[. 1b:04 - 1~3:Q0 ' 3.40 PERP TB~_ CRi7PPUl 'RIH w/ t 9h8" 76G puncher Purtch `hoi~s F1811a fo $712 4spf. HoJd 5p6psi while shaot puncher. Did not loose pressure. Pull gun up abnve perfs. A#temgt to cira w1750psi. Cou{d nczt circ. PQOH" wiTBG purscheC; 15:00 - 2t]:Dfl 2.40 PERF TBG_ CMPRUL :Rlhi with peri. gun to B4'tD' Misfire no perfs_POOH v¢itF~ gun. 20:00 - 2'1;30' 1.50 PERF TBG GMPPUL Ghangr~ ouY perf gun and RIN ta 8f310' Mis~re AUfJH wiin gun,; 2'I :3d - 22:U0 0.5t1 PERF_, TBG CMPPUL 'PJSM;Rig up top sheave cm hanging tin~; 22:00 - Qa:00 2.0€I PER~ 'fBG, GIUIPPUL Make up tubinq eutt~r for 7"- 2&# pipe RIH io 8d20' Pull string weighf to QO:OQ - 00:3Q ~ 0,54~ t~l1RG1_~ ELEC ~ GNfAPUL J PJSM; Rig dawn €xpro wireline OD:3D - OZ:f1U 1.5D CIRG_ CFLD GiVfPPUL PJSM;Girc_ out Packer fluic7 between 9 5/8 "and ~" 02:QD - 66:00 9.~C1 PULQ TBG_ CMPRUL PJSfN;Gheck for flow,Lay-down 7" haoger , Ff~QH Tay down 7"-26# Tubing. 96:00 - 94:fl0 S.QO PI~LD,_ TBG CIt11PPUL PQpH UD 7" TBG(flara was 8.58"check for norm}: 14:OQ - 14:3D d.50 RUR~. C5G GCi/tPpUL 'RtD W€aiherEarci TBG tc5ols. 14:30 -1a:3Q 1.D0 TEST_ GSG_ PLUGAB Test 9 518" CSG to 100~p~i/30min toak 36b1s ta `{04apsi). 9 5:30 -17:OQ 9.5(} TEST BOPE PLUGAB G(d top rams fa 2 7l8" X 51l2" varEable rams. Test to:2S0/2pU(lpsi 17:00 -1~:3Q p.50 RkJNPU WS~H PLUGAB tnstall wear bushin,g: 17:30 - 19.U0 1.54 RURL3 CS~ PLttGA6 G!O to short bates and DP elevatoc5. :99:00 - 21:~0 2.fiQ FUL[3 BNA~ PLUGAB PJSM;Piek up and make up BHA #or tiit ahd scraper run: Printed; tWi6/2W7 T?;58:4SPM ~ ~I Vtiell N~me; STERLIN~ Uf~!"~ 41-15 _ ~man Wetl Name: ~TERLtN~ UNtT 4~i-1~ n# lUame: RE~ENTRY tr~c#or Narn~: ~LAGIER ~RIl.L1NG: Name: GLACIER dRILL1NG° . P. _. i : ... .y,,~: .. . ..y a.o _. ~sr ^' Q~:~Q - 02:34 - 64:Q0 TRIP,~ ~P_ CtRG CfLQ TRiP_,_, DP 04:00 - 06;~0 os:aa - o~:~o 07:3(5 - U9:OU 09:00 - 03:~D 49:3t7 -12:Q0 12:00 - 15.~0 15: d0 - '16:3Q '16:3Q -19:3iT ~s:so - z1:aa 21:49 - 23:9Q 23:OD - OQ:3d Ofl:30 - 03.3Ci 03:30 - 04:30 Q4,30 - 05:Od 05;00 - 06:flQ Q6:00 - U8:Q4 f 2.Q0 PULd_ DF'_ 1.5Q PItL[3_ DP_, 'I.~O TRIP_,,., BHA_ 0,50 T~iIP_ BtfA: 2.5E~ Ti21P (]P 3.0(3 F~l1LD ^ Df' 1.5Q TR1P DP 3.OU P[JLD_ DP~ 1.5a TRIP_,,,' DP;^ 2.~10 PLlLD` DF''~. 1.5Q TfttP ~ DP_ 3.UU TRtP DF 1:db TF21P_ BHA_ 0.54 SER\f!C RIG: 1.00 CHAi~G EG21P 2AU TRlP BHA ~t8:00 - 12:06 4.~4 TR1P 12:00 -12:3Q 0.5iS SE7f 12:30 -16:30 4A~ TRIP 16:34 - r~:0t~ " 0.5Q T~~'1 :17.00 -19:00 ' 3.C~d NllNI 19:()0 - Ob:30 ' 5.5U NUI~I OQ:34 - 06:U0 ' S.50 iVllNl 7/7120Q7 46:U0 - 47:30 ' 1.5~ ,NUhJI 07:30 -12:00 ' 4.50 T~S"I '12:00 - 14~00 ' 2.00 TE"Sl 14:OQ - 95:30 ' 9.5~ SLPC 15:34 - 17;00 1.50 TE`Sl BH,0. PLt:1GA8 6EL PL.~t~ PLUGAB ElP PLUGAB' FLUG F?LIJGAB ) BC}P~ PLUG,4B 3 iFVLHD PLUGAR ) Bf1PE PLU~AB ) BOPE, F?LUGAB ~(JPE F?LUGAB BOPE !?LU~AB ~11T CkLIN PLU .f'.tiAB _ BQl~E PLUGAB 17.DD - 21:00' I 4.OQ I Pl1LD_ ~ B#iA_ Tt~IP_ I DP^ SETREL Pf4R- ~ Sputt C?~~:: 9~1I'1998 Starti: fi/2412007 End': f~ig F2~lease: 9/9I2003 Group; Rig Ni~mber: 1 h 4" driil pipe. ~i~ visc, suu~~P and ~irc. c[ear~;~ip Wt,-'~40K ~3n:1N#.=444~: Ch.eck fluw;P~OH frotn ~~120" #~ 5723`S#~nt! back in PJSM;P4QH lay doc~n 4" ti~itl pipe from ~7~3`. Cont. POOhi and lJd 4" DF(to#al 95~nts L~D}. P't7nH~~ r.a~lc I~ack BHA andi Ui~.8.5"~'it,8.~" miff and 9~l8".scr~p~~ PJSM. 1N/l14" mule shoe and RIH w/BHA. P.ISM. RlH w178 sttls 4" OP to 5648'. PJSRri. R11 65jf,s 5' 19.5# 5~13513P:. TOH a~d raek back ~a" QP (5LM) PU 64 jts 5" D€'. TdH and r~ck back 5" Df~ (~LM) PU remaining fi7 jts of 5" DP.(~tal of 196 jts 5") TOH and tack back 5° DP (5LM) RU #a handie 4". Tf3H w! 4" pP 5LM TQN w! iiWDF'; M. Change Saver Suti and gripper bfdcks':3o 5":. 9 518" Halliburton ~ZDR. M/U setting tool. RIH wE4" HWDP. LID 4 5~$" EZDR PIu9 ta 6289', 3N wlHalliburton setting toal and UD. t E~Dtt to 'l040psi/14rnin(taok 2bb{S to 1Q(30ps"r)', ~M: N/D BOPE. Eropfiy ansl clean mcrd pits. Changeouf wiring tess pn #2 c~rrier motor. Yetco `B' 11" 5M X 11" 'IOM section csg, spaol. instal! tesf sle~ue. t # but failetl tlue tir le~king O-~ng. R~:mt~ve ar~d repi~ce t1-ring. Test NU 11" 14M X 13 5f8"' 5 M 19" adap#orspoo[' iUN S,Rci,A 13 5f8" 5M BOPE. Sarr1e tirne mixing new Fiapro mud sys~em. Flnish NU BOPE. R/tJ koom~y lines. WU chain and tumbucktes': Test BQt?E 756/3500~rsi 10enin(wiYness waveti A(3~CG by Bob Nolanj: PJSM. R!U to tesf BOPE. Tes# 250/3500psi 1 Dmih. Test annutar, variabie rams, 4" darf. 4" TIW, uPP~r and lower top ~rive v~lves: lnsa~ie and outsitle kill line values, cheek uatue, maual chake IYne vatve,. N~R, man'rtold valves 2,5,6,7,8~9,14,11,12. PJSM. Test 80PE 25013"50ppsi 10min 8kind rams, Cf>i1V 3,4, 5" TIIN and IBOP. Test uariable rams, annuiar on 5" test joiat: P~[form kc~nmey test. Install wear ring. PJ~M. Slip and cu# 33' driliing line. Adjust drawworks braks. ~heck CQM. L~o~cF ~nc,.h~~o~~ va~~D ~ Rebuil~J ~Mt/#1 and re#est; Test ~aikecf. L.flu , ramafdi waved tes# or~ CMV#1(parts shqutd be in early n~~'•week). P!U 8.5" SNhipstoek and mill assy w/MWD. ~(H ttul Ff1lUL}P. Test MWD at 300gpm. Gnod'pu{se: TIH tp fi~69', GMeck v!its up=125k dwrt 1a7k. C7rient whipsfock taolface using' (t~tWQ to 318 dec~. RIH tag CIBP at 6299'. Set whipsf€rck ancfior paeker. 5hear off whipstock. Top of whipstock #ray at 6275'. ~Brass bolt set to shear at' 35k dwn wt. Work several tim€;s w! ~i0-5Qk. Fiqally had t+a put torque into drillsiring and cantinu~ working to shear 3he bolt uv( 5Qk dw~ wt:~ :Frinted: 10t16/20Q7 72;58:45.PM~". ~ Lega{ Wel! I~ame: STERLING UNIT 41-15 Common W~It Name: STERL}N~ l1NIT 41-15 Euenf I~4ame~ RE-ENTRY Confractor tVam~`. GLA,CIER ~RtLI~I~IG Rig Name~ GLA~IEFi I~RILLINCa ~ Spud 6ate: J1111998': ~tart: 6/24/2Oi?7 End: Rig Release: 9I9~2pD3' Group: Rig Number: 1 7Rl'20A7 42:bA - Cf6:ti~' 4.06 MILL~ _ iNNQ SIDEfi Star# milling wind4w fccarn 6275'. S~me kime sw~pping tc~ new'8:$ppg Flo-Pro' mud. GPN1= 3~6 PP= 9QD - 975psi RPM= 9b W(a~=1-5k Trq= 5-9k 7J8/2Q47 06:at~.- 08:4,5 2.~5. MILL WND1N SiDET Continue miiling 8.~" window F/628T to 6285':, 0$:45 - 09:00 0.25 GIR~ EFLD SIDEI' Pump 301~bt hi-vis sweep attd w€~rk milis. t39;OQ -'CU:30' 1.5~ T111LL_ WNDW SIDET Mili 8.5" window.F/~i2~5' fa 629~4' (goad c~ment"iri samptesj, Top af' Sv~` _~~ ' h, ~ '~ '10:39 - 13:0(l 2.50 DRtLL_ ROT SIQET wintiow= 6275' bat#am of vv+rzffow= b`~34' Driil open hcsle FF6~94"ta 631Q`. 13:0(1-14:3U 1.50 GiRC MUb SIDET Pump 306b1 tri-vis sw~ep ~xark mills thraugh windaw. Girc. ~fearr spofi 25hbis LCM pill wJ4flPP~ GAGU3, 14;30 -15:3fl 1.p0 TEST_ LQ"T_ SIDET Attemptta per~orm FIT Eo't&ppg EMW. Fd~natfon btak~ @'1550psi' (14.1ppg EMW w#8.8ppt~ rnud) and 61ed douuri !o ~ 15~psi in 12min. ~5:3Q-1`6:OD ': Q.5Q [3RI~l. . ROT SIQET dnll form on o~3~~'. 16:~0 -16:3(T 0.50 CiRC MUQ_ StDET Circ, clean ~ 8313'. Run miti through window with no pumps ar rota#ian (windaw is in gnrsd cAndi#ion}. 16:3fl -17:00 0.50 TEST Lf}T_ SlDET ~ PerF~srm L~T to 13.7PPG EMW (8.Sppg MW 145qpsij, Pressut-e bled 17:00 - 20:45 2i?:43 - F2:45' 22:95 -~3:~f 5 23;15 - 23:45; 23:d5 - 03:0(} 413:IIQ -(I~:3Q' 3.75 2.Q0 0.5a 0.5Q 3.~5 ~.5(7 TRIP_ PULp ~ERU(G P[1LD TR1P TEST - dP_ BHR_ RIG_ B}iA DP CSG_ StDET ~ 51~ET ~ SIQET S1DET SIDET 51DET Fiow eheck pump dry job and PflC)f-1 ta C~G's. LD 6 6-1t4" DG's. LD mi-Iing BF}A. Upper vrrat$rmeton;miH in gauge 8.5". Statting mfiiF normal wear, Clear cig floor; Rig seruiee, PU Havrco RTfS PJSM. Tffi Break circutatican at 6254' ihen set R?TS. Tsst casing but leaking trtf at 1420ps~: F1ns~at ~1~- and tesst ~t 6~50' with ~me rescilt~<_ Unseat pkr and circulat~ at 230 gpm 550psi whife working sfring' 3fl'. (may have soms rnetat shavings arou~d pk~ etement} Rese# R1TS presSure csg and hs~ltliriq at 204E?psi for 3d min. f~o- ~c-o . U5:3U - 08:04 Q.54 TRiP DP SIQET PJSfN. TQH w! RTTS. O~r:4~i - T 1:U0 5.(H} TR1P dP SII36T POOH L/D 9 5/8" RTTS. ~1:00 - 13:0~ 2.00 TRiP BHR Pt21DF~L ' M1U 8.5" Directional assy. Tsst MWt3: '13;OQ - 1~:3U: U.Sp Ti21P BHA PR1DRL Cont. RIH w/~t" HWQP'. 13:9Q- 16:3~ : 3.00 T~tIP ~~ PR1DRL f21H w/4" and 5" DP Fa ~22Q': 16;30 - 17:Od ' Q.Sfl SURV~ DIR ~ PRi DRL ~rienf toois above window, Slide dawn Narouh window to ~308'. Cire. dov,rn to>6313~. i7;Otl -'~`B.flT} 1.0~ C~I~,ILL~, ROT F~1~RL 'Dir drie and surv€~+ FI63'13"t€~ B~SS?a ~ART= Q~ A~T- ~1:~ 1~:(i~ - 40:00 8.Q0 [7i21LL E~QT - PRiQRL Directiat~aily dritl ahead it 6338' to 657T. 7rq =3-t3k up wE=12~k dwn ' wt= 115 rat yvt=lb5 wab= 5-15k ART= 1.2 ftST= 1'.9 Slawly inc flow raYe'f 360gpm to 41Qgpm as mud shea~s and sfiakers sereens ailow: 4Q:Q0 - 6fi:OD 6.d0 C}F~fLL FiOT PR1 DRL Llirectionatly drilt ff 6577' fo 6840`: ART= 1.6 AST= 2:1 OCx:00 -1'2;D~ ~i_00 DRfLL~, 'F20T_ PR'tDf2L Dir dnli and survey Ff6840' ta 7~99(ART-3.Otirs AST=:5hrs): 12:Q0 -15:OQ 3.0~ DRlLL_ ROT_ PR1RRL Dirdrill and survey F/7299 to 749(3`(RRT=1Ahrs AST=.5hrs}, 15,:04 - 16:p0 '1.00 GIRC {v1Ua PR1 DRL Circ. ciean (CSUX1 j. F{ov;~ cheek, 96:Od -19:45 3.75 7Rii'_ BP_ PRIDRL PO~H (wet) fight @ 7136, 7105, 7062, 7045; 7D~3, 70a9, ?006';. WfR 7041-6984. POOH tigMt@6954' , 6873' W/t~ 892U'-68~6' W!R POOFi tight @&832', 6824' W/R 6858' to 630U'. Pull `though wiadaw okay to 6209'. 19:45 - 20:30 q.75 SERUIC F~IG PR1dRL S~nrice ric~ ~nd topdYive. 20;30 - 21:30 1.Q4 TRIP WIPR PR1DRl. TlH ream tast stand to batt+~m. No fi#I. Pri~tfed: 7QIit'st2Up7 i2t5&:45 PM~: ~ ~ ; P 6of1~ Nlar~thr~n t~~l Cornpany age . ;., ~_ : , r , . ' C}p~ratic~ns. Sumr~~ . , Re +~~°t , ~ p , Legal VYeIt Narne; STE~UNG llNIT~41-']5 Gnmtrtan Well C~lame: STEf~LfNG UNIT 4~-~5 Spud [?at~~ 9f1i~ 3~8 E~rent Name: RE=ENTRY 5tart; 6i24i2007 End: ContractorName: GI~AGIER DRILl.I~lG Rig Release: 9l9/~~03: ~rc~up: Ri~ fVam~: GLACtER DRILLI:f~G Rig Number: 1 ' ~uti:: : Da~e ° From - To Hours Cari~; Pha~~. ` ' Dc~sc~'tpt~s~n;a# C3peratic~ns ' t' d . . : e ~ ~ :~.~.. , ~ ~ , .. ~,~ '~. .~~ ,. 7l1U12t}07' 21:36 - C}Q:00 2_50 flF21LL R~T_ RR1 DFi~ Directionally driil ahead ff"7490` to ?627` 412 gpm M 80Qpsi ofF bEm, 2-344psi MW. k~atatin~ 7Qrpm's 5-'I0k wc~b AR7= 1.4 ,ft57= .2 ' Qo:00 - 06:OQ': 6.QQ DF~ILL FtC3°C PR1DFtL Qirectionaliy driN f/ 7627' to 7980' .415 gpm 1.90Upsi off btm '1~3UQ psi MW Up wt 135k, dwn wt 1'44k Rv# 3rrt 125k Trq 46k @ 7arpm's SPft 60sprnl2~(Jpsi Swaco sWids v~n main#aining mud wt at 9.2ppg. ARfi= 3.1 AST= .9 711 ~l/2Q~7 06:00-- 12:f1d. fs.00 aRILL }~OT_ PR1 C#RL Dir drill and sunrey F1798~' to 83?6'(ART=3.~hrs AST=-3hrsj 12:Q0 -18:d0:' 6.40 ~RIi.L_ RQT~ , PR1 DRL ~ir drill and suevay F/8326:ta 8600` (kRT= ~:9hrs AST- 0.9hrsj. Control drIll w/2 pump~ wMile repai~ hydrautic leale on 'hydr~uiic pump lina pump#F{30mi~). Rep2ir and EE:st ~MU#'C.WOB=8-1514 7flRPM 18~TF while sliding_ P~mped hi-vis' sweep @ 858Q ~nd circ. caut whi[e tlrillins~ saw a sltght increase in c~ittings aCross shakers. 18:OQ - 00:34 6.~0 Dk21LL RQT_ PR'iDRL ~irecti~na~ly drilling #f 8606 to 8$95'. 415gpm 1750psi off tthn. 2-304psi on b#m. 70rpm trq= 6k wob= 8-15k ART= 3,~ AST- 9:7 :00:3Q - U'1:30 1.00 GIRC (VfUD PR1DRL C811 01:3~ -(T6:00 4.50 'f{21PT WIPR PFt1DRL 1Nipev trip. Fulled good f! 8815 io 8539'. Backreaming f~ 8539' to 7fi0D`: 412gpm 1754 psi 711 ~Cf2~97 05:OU -'42:34 6.50 TRIP_ WEPt~ PR1 QRL Conitrtue wiper trip and backreaming f17600'- 7fk15', Pulf ~ree ft 7045'- 69~0' Hofe appears ta tae sfuffing,very li#fle clays in cuttings. 12:30- 43:44 fl,50 SERUIC R1G_ PRIDRL Service r{g. Lube carrier,fop dri~~:,blocks and d~nnisoh drive lines: 't3:~0 -14:Ofl 7.00 TRIP_ WIPR ' PR1DRt Tih f- 6945'- 8753' wash f- $753' - 8815' No Fill ,i-fo[e slick: 14:04- 4~:00 10.U0 bRIC.~ FtE1T pR1DRL Qirectionally Drili f- 8815'_:908Q'. 415-430gpm 7Qrpm's wcab= 5-15k. ART= 4:8hrs AST= 2.3fi~rs Begin increasin~g Mud weight to 9.~pp9 ia S#abiize hole.l~s:r~ase lulie Eex ta 4% to aid in slidin~ Q0:00 - OB.00 6.00 [IFt1LL_ ftE}T_ PR1 DRL Directionally drFli ahead f! 9D8tf` Slaw to 415 gpm {mAtors runriing 2~75"`) 9750psi aff btm 2-30Dpsi MW waf~= 5-15k 7b rpms up wi=162k dwn vvt= "[251i roTwf='f41k f~q,6-8k TF= 180-200 while skidittg; rap +f 2(l'hr fairly gaad wt trahsf~r once started,: Ai~T= 3:Ohrs AST~ 1.3hrs: '~113l200T 06:Q0 -12:00' ~.QU CtR1LL E207_ PR1 ~FtL Continue directiorially drilling aheari'f/ 9251`- 93~0' 41~7-42bgptri 1854( 21'50psi . Up Wt. 17ttk Dn. ~1Vt. 133k R# lhlt. 14$k TQ 6-Sk 5-75wab. 70rpm Ast = 2:7 Arf= 1.5 Siidiny f4p 24 fph . Rt rop 45-50fpr 't2:00 - 16,30 4.5p DRILL ROT_ PM21 DRI. Rriectionally deii! anead 9380'- 9506' ~1ZQ-425gpm 19d012230psi. Up Wt. t72k Dn. Wt. 135k Rt.Wt 1~4k Tq CrBk '10-1~k wot~ 70rpm, Ast=1.7 Art= 1.2 Siiding rop 3Q-35fph R~ rop 55-65fpr Note: pump 3~bbt weigftted sweep at 9474` 16:30 -17:3Q 7.~0 CIRC 11t[UD_ j PR1 RRL Circufate weighted swsep at 9506'. ~44spm 426gpm ?150psi Candition: ( hale far w'rper trip. lncrease rot~ry to 12Qnpm. sweep retumed witt~ 3-4X i~crease in euttings. continiie to circ:and rotate. untill shak~rs cle~ned up;; 17:30 - 19:45 , 2.?5 TRIP tNf~R PR1t~RL Monitor'w~ll. POH ( wipsr trip~ F- 95fl6- $753`: First 3 stds pulled gt~ad, ~ Then progressivly wflrse with 30-5Dk averpulls. Backr~amed f! 9235' tc> 8815'. Pu(ted 1 more std ta 8753' v,iith 20-30k ouerpuiis. i 9:45 - 20:20 (1.5$ TRIP WIPf2 PR1 DRL ' RIH W/r fast std fo battom. No fiiL 20:2a - 22;00 1.57 DR1LL ROT PR1DRL Dfrectionally drili ahead f! 9506' fo $543' 3x116} 43Q gpm 203ppsi off .. .... . . . . . . . . . .. .. .. . . . .. .. . . . . . . ~ Printed: 1D116/2007 '~2:88:45 PM ~ .. ~ ~ ': Nlarathan ~tr# Go~inpany : ' Page 7 0~ ~Q ' C~perati,ons Summary Report L~al Wel! fVarne; ~TER~ING UhtIT ~1y15 Camm~n We14 ~larne: STER~I~iG l1NIT41-15 5pud D~te: 911/yJ98 Evenfi Narne: RE_ENTRY ~tart: 6J~4l2a07 ~n~l: Contractor Narne:; GLACIER: DRtLLtNG Rig F2elease: 9/91~f}03 Group: Rig Narrte; GLACfER DRILLING Rig Number: ~I ~~ ' Date ~ From ~:Tc~ Hours Gcfde ~~~e Pt~ase D~s~riptii~n of ~ ?pe~~a#~ons' ,. _.. ~ ~.~: ~ ; _ ,,.~ .w. ~ ~~~ ~ s~r _,~~ . 9. ~. ~.~ .~_< 7ft3I2t107 20:2tT- 22:U4 1.67 QRILL E20T_ P'R'IDRL botton 1-20dpsi M4V. Rat 7Drpm 'I(k'I~k wQb; `t~4P dre~pping t~fR significantly fram 5d'/hr ta ~q'ltir: 'ART= 1:6fir AST= Q 22:~0 - aD;3Q ' 2.50 FtEP~41Ft F~IG_ f'R'1 DRL Pinhcste teak an pump #2 disch~rge tin~. RU off bottorrr:circulate whi)e making ce~aairs. ~ctuai, stress crack on tee and cap weld, Cut and grout~d out..,good' metal suFrcaunding. crack.lNelded up. Allo~'fa:cocsl. 00.30 - D1.00 D,5(~ DE21LL~ R~T PR1 ~RL Ccaniinue drilling to 9551'. tJot seeirig any ~`eas4rt ftar siow ROP a#her :than a wom bit. BU sampl~s indicafe gaod sand tha# should dri11 +I- 8Q-1 bD/kr~, ART= U:2hrs AST= 0 01:Q0 - 41:10 ' fl.1T SA~EI``~ DRlL PR1~RL PJSM. Review tripping hazards and;possibte tigttf ho~e s'rtuations. 01:1E~ -06:bQ ' 4.83 7RIP_ C}P,_ RRIDRL 'TON. Pulled good3a 8756' ihen became tigF~i= Backreamed ta 850Q' fhen pufled normally into casing. h1o pr~biarrss through window. 7/94/200? 06:00 -09:3~7 ' 8.50 TRI;P_ d~P PRIDRL ;Gontinue TQH To BNf~. hla gain ioss carre~f hole fili: p9_30 -11:OQ ' 1.50 TRIP_ BHA_ PR1 Df2L ;PC?M stand back hwdp jars and mrsnel.dc. Lay dawn ,Siab, pany dc and mwd bre~k aut bit and tay down motor. °11:4~ -'t1~3(} ' 0.5t1 Ci.EAN_ RIG_ PRi DRL 'Clean clear rig floor 11:30 -'f5.45 4.25 TEST Bi~P~ PR1 DRL 'Heid PJSM testing kope- Pufl wear bushing, s~t test plug. Test BQPE ~ and a1t relatsd com oneots 25d/3~00 f-5min i'est gas alarms k.EUH2S antl P~ITsystem. P~rksrm accuEnulator drawdou~m t~st, Ail iterns pa~se€3. Witness+,rr~ved by Lou Grimaldi AOGCC.. Puil tsst ~Slug, sef weae bushing, lay down test jt: 15:45 -17:t5 'k,5p PII~.D_ ~HA ~R1DRL PJSM; M/U 8 if2"`directianat assy # 8, sc~ibe motarlmwd, RCH pulse test mwd 'f7:15 -~4~30 3.25 TRIP DP PR'tDRL TIH to 6222`. 20:30 - 2tY.45 q.25 SAFETY QRIL PR1DRL P.lSM /,ISA reuiew prncedures for siip & cut drig line. 20.45 - 22:00 1.25 GlJT~ 1NfRE PR1DRL Gut and slip drtg Iine, ~2:~0 - 22_3E} 0.5Q SER1tIG Rf~ PR1DRL .Service rig, topdriv~ and erirwn, 22:34 - OU:~O 1.5Q TFZIP DP PR'IDRL Continue T[H. No problems fhrc~ugh wlndotn+ at 6275 - 6~94'. 'TIH Co 6690': 00:00 - 01:1D 't.17 TRiP QP_ PRIEIRL 'Crew ch~ng$. PJS~vl: Continue TIH tio 9508: W/R last'std to bottom no 'fill:. 01~10 - Q6:OU 4.83 [TRILL Rt?T PRIDRL 'Directionapy drill ahead f/ 9551' A9D gpm 190Qpsi off btm w! 2-3QOpsi mohrrworlc. wQb= 5-8k rop= $Q-90'/hr white ro#a#ing ~t 70rpm's trq=8k on bfm 6k aff btm, Sliding rop 20-3Q`hr ',ART= '1:4 AST= 1,7 7J15l2Q07 d6_UO -12:t10 6.00 ~FiTI,L FtQT - PRIDRL 'Continue driliing ahead ff 9796' - 9883` ci~4ttgpm 175W20~Opsi w~b=5-10k 15-20fpr siiding.&5-125fph roEating. tlp Wt•=175k pn= Wt.135 Rt Wt. 155k. Tq 7-Sk: Art 1.3 Ast 9.7 92:Q0 -18:00 6.00 t)R1LL - Ft~i' - PR1~RL 'Drill ahead f/ 98~3' -1d'197 Ai2T= 3:8hrs AST= b.5hrs 18.00 - 20:'15 225 dRILL SL(0 PR7 DRL Cont(nue drilliny ~hsad fI 1 Q~97' to 14212' sEit1'sng only. lnereasit~gly di~eult tlue to wei~ht ttansfer. Try decreasin~: pump rafe tc~ 375g~m. :Daesn't hefp, artylouver rate and MWD pulses are too iroeak. Lutitex pil{s cieaHy workirtg, i2aise T°1o lubetex to 5°!o C~tal. RST= 0;7hes 2~:15 - a6:00 3.?5 DRtLL - Rt~T - Pti1 D~L Continue directidnally dri}k ahe~ad f/10212' to 1(i323' 410gpm 1924ps1 :7~ rpm"s. Stiding 70-20' every std 45R TF to stop ang, Up wt= 185k dwn wt= 14~k:rot wt= '162k Nq= &10k ART= 1;2hrs AST= 0.6hrs Qfl:00 - Q6:Q0 6.00 Df21LL RC7T_ PRIDRL Continue directional[y drifl ahead f1 1U323` to 1U543' sliding Rt~F' has ~~increas~~t to 25-3alhr mairatainfig 3fI-4~R TF~ 4~ot~ting"'.s(ou~eer ai '44-50rpm'S to help keep 26 dag inc: ...._. . .. . . . . ... .... . ... . .. . .. . ... P[inisd: 1~I16120~7 t2:58:A5PM :........ ~ ~ ;~ ;. , " ~ ! Mara~hOr~'Otl ~~mp~iiiy : Page ~ o# ta ~~~ ~ ~ ~ : ~ ~~ -~: ~ ~~~y } . ._ .` ,. : . n ~.,. ~pi~'i~~i~~~~ ~~~~~~p ~~~.,,~~ '. , .i .;' ~~, , ~: ; Legal Vltell t~ame: STE}~LING UNIT 41-15 Cammon We11 Name: STERLIN;~ UI~IT 41-15 Sprud t7ate: 9/1l1998 Event Name. RE-ENTR~`' Start: 61Z4/2007 End:' ~ontractc~r Name; GLACIER Cla1LLTl~~ Rig Release: 9!9/2003 Graup: F2ig t~lame': GLACt~R DFt1LL1N~ F~'r~ fJum{aer; 1 i ? ~~~~ ~~~~ . ~ 5ub ~ . :~ ~~ : ~ ~~~e": Fram .T~, Hiau~s ~ode Phase ' Qescr~p~tcin=vfQper~t~c~ns ;. Cade 711~l~Oi37 4p:0~-a6.0U ~.00 DRtLL_ F~OT R~21Dl2L Af2T~1;9hrs AaT=2.ihr~ --- 7/M~/21147 ~I6:Q~ -1~:Of1 7.D0 RRILL_ ~t~t)T_ PR1 DRL ~ Corrtinue ditectlonally driit af~~ad f/ ~Qs43'-9~~64' Slid'ing rop stowetl down i~fph. ra#at3ng r~rp 9Q~'f20fph, Up wt 1:5Qk fln.Wi.145k Rt Wf 167Jc T~2 7-8.5k, Ast 1.6 Ark ~.~ fulax gas 90u '~3:k10 -'~4;'E5 1.~5 GlRC MUC1_ PR1 DRI. Gircutate B!U conditian hole for wiper trip. Pump 1954Rsi 427gpm 33t~spm':. Hvy cuttings returfng ov~r shak8rs Gc~a[ santl and clay 14:15-- ~Q:04 ` 9_75 1`Ft1P_ WIPR PR1 DRL Monitor well POH ( wiper trip ) F-'l~765'. FirsE 7 stds akay. 5tarted ba~kreaming f/102$~' to 972tS'; #3 pump's starter faulty. Only 2 pUmps used at 280 gpm. Brought #3 badc on line around 976Q' didn't hetp with ba~kreamir~g onfy with hole cie~ning. Backre~mir~g a s}csw go with topdriv~ stailing feequenUy. Last stand has #aking 2 hrs. O~~t}(1- t~6.40 6A0 TRIP tiNfPR PR1 DRL Continue wiper trip. Whils backreaming a# 9743' pumped 35hbls low vis pifl fi~tlowed by 35, btsts 19.~ppg Very Ilttie additional ~.itttngs to ~urfa~e. Whlfe backreaming the anly cutting structure available:i~as been the 8 3/8" stabilizer. It's becaming apparent #hat has kast the ma~orit~r of its ' effec6veness. Talkei~ ~rtith towt~ ar-d have decidad fo ccjntinu~ ba~kreaming. Rresently at 97q3', 7ti7(2t)07 D6:00 - Of}:00 18.f7Q TRIP_ WfPR ~R1 DRL. Cnntinue backing:reaming'#197~3' tp 9624` Orisnted lowside sever,af ~~ times taday and afCempted(pult~ar u~hQle. H~ve anly puiisd 7Qt~ aver~ ~. S~Rft9 Ntt,. : llp wt 17~k Rof wt=150k Dwn wt= 135k Trq while-nok BR= Sk, BR- 18#~ @ 6tlrpm's QU:~a - 06:p0 f.00 T#~IP WIPR Pt~1 DRL Cantinue back reaming #i 9624' ta 9606' 35fSgprn 137Qpsi {no mato~vortc) 6[krptn. At 961(}' sf~awed to 1 pnmp and jarred 3 times onee at 2QOk twic~ at 2~t Ok. fVo e#€ect. i?rt~ps out #airly easy. Resumed back reaming. Up wt 170K Rot wE i50K Dwn wt= 1°3f1K 7/"i812Q07 fl6:4Q -18:t}4 ' ~2,00 'TRIP_ WIPR PRIDRL Continue back reaming f/ 96~6' to 9f'tS' Starfing fa show signs Af r~~ming fa5ter. Last stand has Naken 5hrs. NO Ffuid Ioss~. 18:OLt - 22:3o ' 4_5Q TRIP_ WIPR PR1 DRL GonBnue back reaming #l 9616' to 9t380' J~rring on occassion' 70k over s#ring wt: Doesn'krnove but bat~oms-up has increa~ed cuttings. At 94~~ slowty starting ta come ea5ier. Thereafter having to back re~m with pumps but onfy v minlstd 22:30 - 23:04 ' 0.5~ SERVIC 'RIG PRi dRL #1 carrier mcstor low on ccfotanf. Shutdown Fa add cxiolant: 23:b0 - 05:(}0 B.OQ TRIP_ 4VIPR PR'lQf~l, Cantinue TOH back rearnEng eaeh std in less':than 5 min. At 8A(td' pu!ling wo roatiqn ar pump~ but puiling 40-50k aver string wC. At 810E3' pul(i~g 20-3Qk auec At 3'8~~" pullinr~ 1~-20k~ver. Purop dry joF~. Pulling: n~irmell~. Came thraugh window goad rto overpulis wifh either sfabiiizer 4r bit, 05:(}tl - 06:4Q 1.f10 TFtIP_ DP PRIRRL TC7H 5wap uver ta 4" to~is;. eame aut on uneven I~reak. 5600' a3 ~T6€~4tir~ ~ 7/19/2QElZ 06:OQ - 09:30 3.60 TRIP DP F'R1 DRL Contii~ue TOH ft 56Q0` - To bha 09:3Q , h i:00 1.50 TRIP BHA PRIDRL i'fJH Stand back HWDP and }"ars. Lay dovm Monels - X-overs :,Mwd ,pony drilieotlar. Bfeak aut bit Lay down mator. MUVR koat had 12" long crack. on box .Bit was undercut on top 5118" bit was in gauge. Mt~tor dr~ined, No damage to motor, Feces on pony coilar gailed. 54me boxes are Undercui on HWDP. WiU reptace joirrYs. '11:00,- 92:30 ' 1.50 SERVIC RI~_ Pf21DRL Clean elear rig floor, Servi~e and it~ispect rig. Repiace savQr sub an tflp ~ ~ Printed:,lQf~961Z(J67 4~~58:45 PM ~~ ~ ~ _. ; ~ ' ~llarath~n C3~1 C~mpany `;= ~a~e 9 of.9c~ ' ~ ~ , ,. _:-. . ~ Qperatians ~urr~mary Repc-rt , , Legat Well Name: STERLI~JG Uhl1T 41-15 Cammon 1A/ell Name: STERLIhJG UNIT 41-15 Sp~ad Date: 9~1i1998' Event Name: RE-ENTf~Y" Statk° 8J24/2f#a7 End; Gontracfar Name; GLACIER DF~1LL(NG Rig Refease: 9!9/2t~d3 Group: Rig Name: GLACIER DRILL(~IG Rig ~tumber: 1 D~te 'Frorn =To. Hours Cr~de ~u~ t~l~ase ~escn{~t~on t~f ~peraaticrns Gflt~B E v ,~ ~, _ ~,<~ . 7/19l2Qtl7 11:fl0 -12:34 1.50 SERVIC FtlG PE21DRL drive 12:30 -17;84: 5.Q0 TRMP_, BHA PRtDRL P1U M!U BHA # 9 Cutt out Iaad HW.bP jainfs and replace with SMWC3P: RIH Layed daairn 5 bad jcaints~4 HWt~P :17:~0 - I8:04 0.5(i FLC~W GMEK PRiDt~L :Surface 7est MWD '18:40 - 23:Ufi ' 5AQ 7filP L7F'_ PR1UFtL PJSM;Run in H4fe with 4" and 5" dril] pipe #o z+J576' 23:00 --D~:Op ' 9.00 WAShf FiLL PR1DRL Fill p[pe: , wash and ream from 40576' ta 1(~~6~ 00:0.0 - 02:Ot7 2.QQ Gif2C_ MIUD_ PR1 DRL PJSM; Cire. botttc>t+ts up,Pump Hi Visc_ svaeep :Max. G~s bottoms up 2~1(1 units 02:00 - O~:t~b ' 4.00 L?Ril,fr ROT : RR1 DFtL PJSM;Direct. Drill' from 107~5' t4 '}0890`' Up Wt.=~00K Dn. VHt=140fC lRT. Wt.=1651Z. Lay dowei joint #159 wasfi aUt toal jcsint 7f20f2007 ~6:9(3 -12:QQ 6.OD 13RILL : SLID ~''fi1DRt :Drill ahead f-1t3$94'- 112C1Qt Up wt 21:Q Dn uvC 15d Rt w# 165Tq 8-9k . Max gas 90u Ma Gainf Lass, 418gpm ~700f235~psi 334spm. Ast= .6 Art-3.Shr 12:OQ - 13_30 1.Sp DRILL R4T PRIDRL Dril! ahead f- 992(70'-1i268' ~irt.=,5 ,Ast.=:4 13;3~ r'I;4:3~1 1.00 CIRC_ MU#~ PR1DRL Circutate BN far vyiper ~rip. Pump at 334spm 420gprrt:21~Qpsi. Ciec ~ ~untif shakees clea~ed up. '14:30 = 17:00 2.50 TR1P_ W1PR PR1DRL Mfonf€or wet! POH ( wiper trip ) f-1'1268'- 10~00' .~ame o~ter pulls 2Q-5Dk back ream 1'[€#25-'! 4fl4Q' pump at 10952' RIH tag ledge at 1 D990' work thrqugh 1N/C) pumping car rota~tng. Hole slick to 1~ 265° 17:~0 - 20:6~ 3.OQ DFtILL_ F2QT PRi DRL C}rill ~head f- 11268'-1?3~5` Up wt.=2154~ Dr~ 4vt.=154K Rot.uvL =173t4 Tc}~ 7-8K M.W.=3.~ Ast--O Att=1.5MWD Fuise quit warking, lasi survey at 1128d` 20:60 - 21:Q0 1.40 E~~PAIR f2IG_ PR1 DR~ 'PJSM;Repface bent linktilt hyd. rarns,Bent on Conne~4n and change. swab in #2 pump, Nate 5' siabbing guide was:;also bent. 21:DU - 23:30 2.b0 D~tCLL RQ"f_ PR1DRL 'brill ahead f-11395'=11520.'`U~ru~+t.=215K Dn. wt~=15Qk( tot. wt.=173K Tq. =7-8K Ast=4 l~rt.=1.6 Mud'wE.10.S 23:3~ - OO:QO 0.50 REAAIR RIG_ PR1QRL PJSM; ~hange swab in #2 pump. Girc. up 320 ur~efs gas.Wi#h 45 llnits . background gas.Wt. mud up to 11,1 Mud wF, OQ:UO-03:Q0 3.04 ClE2iLL ROT PFt1DRL driitaheadf-1152D'-1163~''Ast-UArt=2.9 03:00 ~ 05:00 ' 2.04 CIRC! MUD PF2IDRL Circ. bottoms up for sample. 05=t10 - 05:3D: 0.50 E?RILL RQT PF~1 DRL L7rill ahead f-11365'- 11655` Up wE.~Z5QK pn. uvt.-150tC Ftt,wt. 175K Tq.=B-9 bK Ast=U Ait-::5U [}5:30 - Ofi:00 0.54 GiRG~ MUC~ PR~DRL Cfrc. bc~ttoms up 7/2112007 06:fl4 - 07:7~ ' '1.25 CIRC_ N1UD_ PR1 ~RL Girc BN form samples to confrm TD, and prep far wiper Frip. Pump at; :335spm'<425gpm 21~Opsi 07:15 - 09:45' 2.50 TF2fP_ WIpR PR1DRL ' Monit4r weli, P~H ( wiper trip} F-11655- 11073' Woek #hrough various 6ght spats witi~ very li~tte back ream'sng or p~mping. Rih ta 1159tI" wasFi f-1 1 595-1 1 655' hole slick: 49:45 ~ 13:30' 2.75 Cft~G MUD_ PR1 ~RL Cire~atate sweep 425gpm 33~sEks 21'SOpsi at 11655' Hvy returR o# cottings av~r shakers aftet 6Qpnstks. sweep i~e3umed with 56°1a increase:in cuttings. Saw 440 units t~f gas at' 10,OQQ s{ks, At Bflt 32units o# gas. Continue Griculating untit shaker~ cleaned up at 28,450stks. Sweep reiumed es cacul~ted. 12:3b -18:00 ' S.54 7RIP ~P PR1 DRI. PJSM; Monifor well, POM f-11655' for 3ogging pragrarrt, pulf 5 stands, Ftow Ck;; pump dry job. Contiune PQFi f~i 12Q5' -98~1$' ~Nash and ream at 11254' 1Q7~6 to 4U159` Pull Free from 1t~^~25'-9818'. RiH f- 5818' -11 fi`~~ 18:Q0 - 30:6Q 2.00 CIRC MU[7 FRIDRL Cire. and canditian hole .spr~t cley gitard in open hole:PJSM;Monitor weil. Max Gas-75 un{ts 2Q:~0- 410:3t3 4.5b TRtP_ :DP_ PRIC~RL POUN for logs ,Hole sUck irt gaosi condition.llp wt.=215K an, wE.-955K ~ ~ Rot. wk.=97bK Tq.=7-~K S'LM dr[(1 p2pe_ Q0.3t? - 01:00 0,~0 CfRC_ MUD_ PR1DFtL ; ' Pum~ dry job. 1 .. .. . .. . , . .. . ..... .... :Printed: ~Oifi67F0A7 42;58:45PM ... .. ... . ~ ~ 6 ~ ,; ~ - Marat~on ~.7EC ~~_mpany ~~~ , , , page ~~a of;7~ ~'~~ Operatians Sumrr~ar~,R~p+~rfi L~gal Weil Narrte; STE~Ll~1G UNtT~1-15 Cornmon We11 Name: ~TERLiNG E1NIT 41~~5 Spud Date: ~f111998 Event Name: RE-ENTRY Start: 6fZ4f2f~7 End: ~ontractor Name;, GLACIER DRILLING Rig Release: ~/9/~OQ3 Group; Rig t~am~° GLACIER DRILLING Rig Nurriber:, "1 ~ ` L?ate , ;From =''Tg :Nours Code,. 5ub ~~de .P~-ase ~ ~ : ` DescnptTC~n of Qperations ': , ~_ a - - . _ . : ,~~..,.o.~_. ~ ~ ~~~.. 7/21120Q7 :fli:00 -'66:~0 5A4J TR1P_ QP_ PR1 DRL Conf: to puli caut of hole.Gl~ang~ elevator inserts #Q 4".dt~p rabbit dowra 4" dril! pipe POOH w14" re~over €abbii at drifiing jars: finish POQH with BNA. 7/221~i347 0~3:t1d - 06:45 U.?5 'fRIP BHA PRIDRL k.ay da~m Monels, MWD, pony, coti~ar ,stabiizer and mator. No#e;SLM no cofreCtion. Nti g2irt lo5s. Gorrect hale fil. U6:45 - Q7:15 0.5C1 CLEAN_ ~iG_ PR1 DRL C#ean clear rig flaor' 0~:15 - 07:~5 0,54 S~RVIC ~C2fP PR1 ~VL Service Rig .Camer,driY~ Eines, top driue bfocks crawn and swivel ~ D7:~5 - 10:30 2.75 LOG Oh1 FR1 EVL P,ISM PIU M!U sttuttte ~sy prift all taols to 2;254/2.0~"' 10:30 - 11:45 1.25 WAITtJN EQIP PR9EVL Found 2 crasks in w~atherFor~d float sub. Wait fiQr replacement sub. Tooif~ce: an sub harl d~mage also. Tod! was part of shuttie system providetl byweaUtetf~rd wire line seruice. 11:45 - 20:00 8,25 TR1P flP PR1 EVL Rih wittr Qraad camba logging taots on drillpipe shuttle; Ck pressures at 15Q; 255d".63~4A~38S5`.1fl4~7',R~~l i~s11,3£~` _ 2Q:OU - 22:OQ 2.4Q REAM_ C}1-1, PR1 EVL PJSM; Pr~cautionary Wash and ream to bo#tiam fl1138#' to 1'l635',Stand back stand numb~r 170 Up wt,=200K Dn. wt.=15QK Rt wf.=17E~lC Tq.=B-9K Max. Gas 57 units 22_00 - 40:UQ 2.OQ GTf2C MUD_ PF~1 EVL Circ. Go#toms up .Repair hyd, hase in service (oop while circ: OO:QO - 01:00 1.a4 REPAIR R(G_ PR1 EVL Fittish repair'tnc~ hyd. hose irr seru. loo#~. Q1:00-03:00 2,0~ LG1G O}i~ PRIEVL PJSM: Wifh W~atherFord e.st.cRrc. pressure.,Rrcjp depfpyment dart,Datt hit at calcufatetl volume and deployed #apl. i~riflpipe at 1153~' deployed Joggi~g tools a€ 9163f?' '03:Ot1- (76:0~ 3.00 lOG QH~ PR~EVL Pump dryjob and tog with,drilipipe shuttle {rom 1h63fl' to 9320' at 460Qhrs . . 'if23l20i~? D6:04 - 12:30 6.50 lt~G ` ~H PRi EUL Canfrnue Logging W! Quad combo An driApipe shutUe systetn. f ~$?Q-3Q00' 12;3D - 15:30 3.~D TRIP_ DP_ PR1 EVL POFf wittr shuttie as"sy. f 3000'. lay logging to41s and shuCtfe assy down. change to ca~plet~an phese at 1530hrs 7l2-2$2007 i i 1 _ Pnrried: 1D1t6/2b07 i2:58:45PM ~ ~ Legal Well Name: Common Well Name: ' Event Name: 'Contractor Name: ' Rig Name: STERLING UNIT 41-15 STERLING UNIT 41-15 ORIGINAL COMPLETION GLACIER DRILLING GLACIER DRILLING Spud Date: 9/1/1998 Start: 7/10/2007 End: Rig Release: 9/9/2003 Group: Rig Number: 1 7/23/2007 15:30 - 18:30 3.00 TRIP DP PR1CSG 18:30 - 19:00 0.50 SERVIC RIG PR1CSG 19:00 - 20:00 1.00 SERVIC RIG PR1CSG 20:00 - 23:00 3.00 TRIP DP PRICSG 23:00 - 00:00 1.00 WASH FILL PRICSG 00:00 - 01:30 1.50 CIRC MUD PR1CSG 01:30 - 02:00 0.50 CIRC MUD PRICSG 02:00 - 06:00 4.00 PULD DP PR1CSG 7/24/2007 06:00 - 0830 2.50 TRIP DP PRICSG 08:30 - 10:30 2.00 WAtTON ORDR PR9CSG 10:30 - 17:00 6.50 TRIP DP PR1CSG 17:00 - 18:00 1.00 RURD CSG PR1CSG 18:00 - 19:30 1.50 TEST CSG PR1CSG 19:30 - 22:00 2.50 RURD CSG PR1CSG 22:00 - 22:30 0.50 SAFETY MTG_ PR1CSG 22:30 - 06:00 7.50 RUN_ CSG_ PR1CSG 17/25/2007 I 06:00 - 23:30 23:30 - 01:00 01:00 - 04:30 17.50 ~ RUN_ ~ CSG_ ~ PR1 CSG 1.50 CIRC MUD PR1CSG 3.50 LOG OTHR PR1CSG 04:30 - 05:00 05:00 - 05:30 05:30 - 06:00 7/26/2007 06:00 - 09:00 09:00 - 10:30 10:30 - 17:00 17:00 - 01:00 0.50 TEST EQIP PR1CSG 0.50 PUMP CMT PR1CSG 0.50 REPAIR EQIP PR1CSG 3.00 PUMP CMT PR1CSG M/U clean out BHA Rih T/ 5648' PJSM; Slip drilling line PJSM:Service rig,Top drive,Carrier,Crown,Change out elevator inserts. PJSM;Run in hole f/5648'-11580' Precautionary Wash to bottom f/11580'-11655' Circ. bottoms up at 11655' .Max Gas=205 units. Check for flow and pump dry job. Note: spot conqor 303 in dry job. PJSM; Pull out of hole laying down drill pipe.F/11655' -7600' Up Wt.=215K Dn wt.=150K Rt Wt.=175K Flush drillpipe with H2o in mouse hole and inspect tool faces for damage. Continue POH laying down drillpipe F- 7600'- 5416' Wait on orders for completion. Rig crew working on service loop. monitor well no fluid loss Resume laying down drilipipe F- 5416'. Total of 375ts of drilipipe and 23 jts HWDP UD Note; found 5 damaged hwdp. R/D rig floor. Clear off Rig floor ,subs,pipe handling tools Pull wear bushing set test plug. Test 3 1/2 csg rams 250/3500psi 5 min PJSM;Lay down rig tongs,pipe spinners,change bails,and elevators. Rig up WeatherFord tools. Hang control line sheaves and spools. Pre job safety meeting with service hands and rig hands to run 3 1/2 csg.. Pick up shoe and float jt CK floats Run 3 1/2 9.3# L-80 eue Csg.With 6 Modules and 3 control lines and one sacrificiai line. to 1764' at 0600hrs Continue running 3 1/2-9.3# eue 8 rd. excape casing F-1764'-11621' (355 Jts.,14 pup Jts.) (6 Excape modules) Up Wt.=135K Dn wt.=74K Note shoe at 11621 Circ and spot Inhibitor in Annulus.Rig down Excape sheave. R/U Expro wire Line and run Excape Correlation W/ GR/CCL toola To set module depth Hold PJSM;R/U BJ 3 1/2 cement head and lines Pump 5bbls H2o, test lines to 4500. Attempt to pump 40bb1 spacer. shut down due to problem with BJ cement pump Repair BJ cement pump Continue Cement 3 1/2 Casing. Mix and pump 40bb1 MCS-4 11.5ppg spacer followed by 176bb1s 545sx 13.5ppg ciass G Lead cement with a yield of 1.816. Pump 300bb1s 1456sx 15.8ppg class G tail cement with a yield of 1.162. Shut down and pump 5bbl H2o wash out lines. Drop plug and dispiace casing with 101bbs KCL.to 2400psi/ bump pluq at 102bb1s. and 2900psi. Hold pressure for 5min, bleed off.,1bbl retumed Floats held. 100 % r~turns. Cement in place at 0900hrs. Note reciprocate pipe 1.50 RURD_ CMT PR1CSG R/D cement head and lines, clear rig floor. Begin cleaning pits. WOC 6.50 NUND BOPE PR1CSG PJSM; N/D flow & trip tank lines. remove drip pan & flow nipple. Begin nipple down bop stack. WOC. Clean pits. R/D BJ unit and move to staging area. Move cement bulk tanks. Load out MI van and haul to Mi yard. 8.00 CUT CSG_ PR1CSG P/U BOP stack pull control lines ,set slips. with 84k down wt. Make ruff cut on 3 1/2 casing. Set pack off,and test to 8400 psi for 10 min.Load out BOP and set in production tree.Test void in tree to 10,000 psi hold I 10 min.Rig up and test tree and flanged connections to 10000 psi and ( hold 10 min. all test passed. Printed: 10/4/2007 12:49:59 PM ~ ~. . ~ . i ! 7/26/2~07 01:00 - 06:00 5.00 RURD_ RIG_ RDMO Rig down GD-1 Prep derrick for scoping down.Prep sub base,lay down top drive,start working on torque tube.Rig down #3 Mud pump. 7/27/2007 06:00 - 06:00 24.00 RURD_ RIG_ RDMO Complete rig down of torque tube. R/D and move hanson tank, epoch and bhi units. R/D#3 mud pump and move out. R/D pits and pumps. Pull service lines. Remove hand rails from pits and pumps. UD beaver slide,remove catwalk. Scope down mast. PJSM;Crane operations,Remove back wind walis,and remove back landing,lay down mast,onto carrier.tie up all lines,remove monkey board,chain mast sectiomns together for the road.PJSM;Crane down dog house,choke house,stairs,gray iron,fuel tank,flow line.lsplit mud pits,remove carrier from mud boat,pull wires,lower hand rails on pits.Scope sub base down and release rig to GO-6 at 0600 hrs. 7-27-07 PriMed: 10/4/2007 12:49:59 PM • ! 11~arathori =0i1:C~m~a~y Pa~e ~ ofi s Opera#ions S~~mar~ Repor# Legal Well Name: STERLING UNIT 41-15 Common WeN Name: STERLING UNlT 41-15 Spud Date: 9/1/1998 Event Name: ORIGINAL COMPLETION Start: 7/15/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 9/9/2003 Group: Rig Name: GLACIER DRILLING Rig Number: 1 ~u~ ~ Date ~ror~ = To Hours Code Phase ~escr~ptiort of Operat~ons ~;~t~ie. 9/6/2007 08:00 - 09:00 1.00 SAFETY MTG PR1 EVL Arrive on loaction obtain work permit and sign in. Hold PJSM with JSA 09:00 - 09:30 0.50 RURD ELEC PR1 EVL MIRU E-line Unit, Crane 09:30 - 10:40 1.17 RUNPU ELEC PR1EVL PU CBL tool and open valve, RIH 10:40 - 10:45 0.08 RUNPU ELEC PR1EVL TD @ 11,540' KB. PUH run Repeat Pass 10:45 - 10:50 0.08 RUNPU ELEC PR1EVL End Repeat Pass, RIH 10:50 - 14:50 4.00 RUNPU ELEC PR1 EVL Start Main Pass @ TD 14:50 - 15:20 0.50 RUNPU ELEC PR1 EVL End Main Pass @ 4500' KB. POOH 15:20- 15:45 0.42 RURD ELEC PR1EVL OOH, RD 15:45 - 16:00 0.25 RURD ELEC PRIEVL Sign out and leave location 9/11/2007 08:00 - 08:30 0.50 SAFETY MTG CMPSTM Hold PJSM and obtain safe work permit 08:30 - 09:30 1.00 RURD STIM CMPSTM Rig up Expro Americas hydraulic lines to perf Module 2 on green line perf 10571 -10581 feet MD 09:30 - 10:00 0.50 TEST TBG CMPSTM Pressure test hydraulic lines 10:00 - 11:30 1.50 RURD STIM CMPSTM Rig up trash pump, pump rainwater to retention pond 11:30 - 12:30 1.00 PERF_ CSG_ CMPSTM PerForate module 2 on green line. Verify acoustically and by vibration on wellhead 12:30 - 13:00 0.50 PERF CSG_ CMPSTM Bleed off pressure on control line and close in for the duration of the day 9/12/2007 07:30 - 08:00 0.50 SAFETY MTG_ CMPSTM Hold PJSM with supervisors and distribute MOC job orientation hard hat sticker replacements 08:00 - 09:00 1.00 SAFETY MTG_ CMPSTM Hold PJSM with all crews. Discussed slip, trips, falls, high pressure frac operations, perForating operations and flowback operations. 09:00 - 09:30 0.50 RURD STIM CMPSTM Pressure test frac lines to 9500#. Maximum frac pressure 8500# 09:30 - 10:30 1.00 PUMP FRAC CMPSTM Open well. 0 psi. Begin frac operations with BJ Liphtninq 1800 frac fluid on Module #2 (perff 10,571-10572 MD). Broke down perfs. At 7634~ STP @ 12.4 BPM . Pumped 19,054 # 20/40 mesh white Ottawa sand, 241 barrels of fluid, 5496 # shut in pressure. Pumped 204 BBL 2# slurry #12 bpm, 227 BBL 4# slurry @ 12 bpm, 258 BBL 6# slurry @ 12 bpm and 305 BBL 8# slurry @ 12 bpm. Tubing volume 92 BBL. Flushed with 94 BBL frac fluid. 10:30 - 11:30 1.00 PUMP_ FRAC CMPSTM Perforated module 3- 10,201-10,211 feet MD. Open well. 5399 psi. Broke down perf.'s 6500 psi @ 15 bpm - 32 BBL Lightning 1800 frac ~ fluid. Pumped 44 BBL 2# slurry @15 bpm, 60 BBL 4# slurry @15 bpm, 76 BBL 6# slurry @ 15 bpm 97 BBL 8# slurry @ 15 bpm. Tubing volume 90 BBL - flushed with 90 BBL frac fluid. Pumped 143 BBL Lighting 1800 frac fluid and 11,076# 20/40 mesh white Ottawa sand. 11:30 - 12:00 0.50 PUMP_ FRAC CMPSTM Perforated module 4-10,157 - 10,167 feet MD. Open well. 4550 psi.~ Broke down perf's 6500 psi @ 15 bpm -27 BBL Lightning 1800 frac fluid. Pumped 14 BBL 2# slurry @ 15 bpm, pumped 19 BBL 4# slurry @ 15bpm, pumped 26 BBL 6# slurry @ 15 bpm, pumped 49 BBL 8# slurry @ 15 bpm, pumped 72 BBL 10# slurry @15 bpm and 90 BBL flush @15 bpm. Total 216 BBL Lightning 1800 frac fluid and 31,902 # white Ottawa frac sand. Average frac pressure 5200# 12:00 - 13:00 1.00 PUMP FRAC CMPSTM Perforate module 5-10,031-10,041 feet MD. Open well 4346 psi. Break down perf's 5574# @15 bpm- 19 BBL Lightning 1800 frac fluid. Pump 18 BBL -2# slurry@15bpm, pump 26 BBL - 4# slurry @ 15bpm, pump 38 BBL - 6# slurry @ 15 bpm, pump 72 BBL 8# slurry @ 15 bpm ~ and 89 BBL flush.. Total 268 BBL Lightning 1800 frac fluid and 23,969 #t 20/40 mesh white Ottawa sand. Average trac pressure 5000# 13:00 - 13:30 0.50 PUMP_ FRAC CMPSTM Perforate module 6- 9930-9940 feet MD. Open well - 5000 psi. Break down perfs' S186# with 20 B L Lightning 1800 frac fluid @ 15 bpm. Pump 20 BBL 2# slurry @15bpm, pump 29 BBL 4# slurry @15 bpm, I pump 46 BBL 6# slurry @15 bpm, pump 66 BBL 8# slurry @ 15 bpm, Printed: 10/4/2007 12:5024 PM . ~ 9/12/2007 I 13:00 - 13:30 I 0.501 PUMP I FRAC I CMPSTM 13:30 - 14:00 0.50 SAFETY MTG CMPSTM 14:00 - 17:30 3.50 RURD COIL CMPSTM 17:30 - 18:00 0.50 TEST BOPE CMPSTM 18:00 - 00:00 6.00 JET N2 CMPSTM 00:00 - 02:00 2.00 JET N2 CMPSTM 02:00 - 0230 0.50 PERF CSG CMPSTM 02:30 - 06:00 3.50 JET N2 CMPSTM 9/13/2007 I 06:00 - 06:00 I 24.001 FLOW I TEST I CMPFLW 9/14/2007 I 06:00 - 06:00 I 24.001 FLOW I TEST I CMPFLW 9/16/2007 08:00 - 08:15 0.25 SAFETY MTG PR1 EVL 08:15 - 09:45 1.50 RURD ELEC PRIEVL 09:45 - 10:00 0.25 TEST EQIP PR1EVL 10:00 - 12:00 2.00 RUNPU ELEC PRIEVL 12:00 - 13:40 1.67 PRIEVL 13:40 - 14:30 0.83 PR1 EVL 9/18/2007 09:00 - 09:30 0.50 SAFETY MTG PR1 EVL 09:30 - 10:30 1.00 RURD SLIK PR1EVL 10:30 - 10:40 0.17 RURD SLIK PRIEVL 10:40-10:50 0.17 TEST WLHD PR1EVL 10:50-11:20 0.50 RUNPU SLIK PR1EVL 11:20 - 11:25 0.08 RUNPU SLIK PR1EVL 11:25 - 11:50 0.42 RUNPU SLIK PR1EVL 11:50 - 12:00 0.17 RUNPU SLIK PR1 EVL 12:00 - 12:15 0.25 TEST WLHD PR1EVL 12:15-12:25 0.17 RUNPU SLIK PRIEVL 12:25 - 12:50 0.42 RUNPU SLIK PRIEVL ~ SLIK PR1EVL 13:05 - 13:25 0.33 RUNPUL SLIK PR1EVL pump 61 BBL 10# slurry @15 bpm and 16 BBL Lightning 1800 ftac fluid flush @15 bpm. Screen out with 72 barrels of 8/ 10# slurry and 16 BBL frac fluid in hole. Average frac press 7100 # and screen out pressure 9259# Total 289 BBL fluid and 44,021# white Ottawa frac sand. Open well to flow back to sand buster through wing valve Frac crew clean-up safery meeting Rig CTU and pull test nozzle to 18K psi Pressure test CTU to 3018# Wash down to 11,557 feet MD. Engage Nitrogen - 500 scf / min, circulate for 20 minutes and pull tubing back to 9900 feet MD above top perforations. Increase Nitrogen to 750 scf / min and cut 6% KCL water when retums clean up and no sand returns. Jet well dry until pumping pressure drops and well head pressure stabilizes. Perforate Module 1( fired at 4750 psi) - 17,480 -11,527 feet MD - ull coii out of hole. Shut in coil, lay down injector head. Flow well to production testers through wing valve. Flow well to tank. Expro Well Testers onsite. Flowtesting well and ~ entina Gas. 24Hr Ops. At 6:00 9-13-07 Inc rate 1654mmcfd @ 218psi with 85 bbls of water (373 bbl water produced) Flow well to tank. Expro Well Testers onsite. Flowtesting well and Venting Gas. 24Hr Ops. At 6:00 9-14-07 Inc rate 1788mmcfd @ 230psi with 21 bbls of water (426 bbl water produced) Gas Gravity = 0.562 Issue work permit. Hold PJSM with JSA MIRU E-line Unit, Crane Test lubricator to 3500 psi. Open well. 260 psi, 41 DegF. RIH P/T string. Tagged at 11,510' ELMD BHFP = 718 psia at 11,510' ELMD. T= 58 deg. Massive cooling in short interval in Tyonek and minor cooling in 2 Beluga modules. POH. RD and leave location. Arrive on location. Discuss Pollard JSA and job scope. Issue safe work permit. MIRU Slick-line Unit, and Crane. PU lubricator and tool string. Shut-in well. Switch flow from flair stack to gas buster. PTest lubricator to 3750 psi w/ water. Test good. RIH w/ 2-1/8" x 5' Drive Down dump bailer. Run #1. Tag fill @ 11,507" KB. Tap down to fill bailer. POOH. OOH. Bleed down lubricator. WHP 2200 psi. Bailer ful~ of formation fines and sand. Some frac sand. PTest lubricator to 3750 psi. Test good. RIH w/ bailer. Run #2. Tag fill @ 11,507' KB. Tap down to fill bailer. POOH. OOH. Close upper master valve (24 turns) Bleed down lubricator. WHP 3100 psi. Bailer full, blue-gray clay, formation fines, and some 13:25 - 13:35 0.17 TEST WLHD PR1 EVL PTest lubricator to 4500 psi. Test good. 13:35 - 13:55 0.33 RUNPU SLIK PR1 EVL RIH w/ bailer. Run #3. 13:55 - 14:12 0.28 RUNPU SLIK PR1EVL Tag fill @ 11,507' KB. 14:12 - 14:30 0.30 RUNPU SLIK PR1EVL POOH. 14:30 - 14:40 0.17 RUNPU SLIK PRIEVL OOH. Bleed off lubricator. WHP 3300 psi. Bailer full. Primarily Printed: 10/4/2007 12:50:24 PM ~ i I~lara#1~on O~I Co~~any ~age-~ ~.s Opecat~ons Su~r~rnary Report Legal Well Name: STERLING UNIT 41-15 Common Well Name: S7ERLING UNIT 41-15 Event Name: ORIGINAL COMPLETION Contractor Name: GLACIER DRILLING Rig Name: GLACIER DRILLING 17atp ~ ~rnm - Tn ~ 1-~Ini~rc 1 l'nrlp ~ ~~~~;-~ ~7 Spud Date: 9/1/1998 Start: 7/15/2007 End: Rig Release: 9/9/2003 Group: Rig Number: 1 9/18/2007 14:30 - 14:40 0.17 RUNPU~ SLIK ~ PR1EVL 14:40 - 15:00 0.33 TEST_ WLHD PRIEVL 15:00 - 15:15 I 0.25 I RUNPULI SLIK I PR1 EVL 15:15 - 15:35 0.33 RUNPU SLIK PR1EVL 15:35-15:50 0.25 RUNPU SLIK PR1EVL 15:50 - 16:10 0.33 RUNPU SLIK PRIEVL 16:10-16:35 0.42 TEST WLHD PR1EVL 16:35 - 17:00 0.42 RUNPU SLIK PRIEVL 17:00 - 17:15 0.25 RUNPU SLIK PR1EVL 17:15 - 17:35 0.33 RUNPU SLIK PRIEVL 17:35 - 17:45 0.17 RURD SLIK PR1EVL 17:45 - 18:00 0.25 RURD SLIK PRIEVL 9/19/2007 07:00 - 07:30 0.50 SAFETY MTG PR1 EVL 07:30 - 07:55 0.42 RURD_ SLIK PR1EVL 07:55 - 08:15 0.33 TEST_ EQIP PRIEVL 08:15 - 08:30 0.25 RUNPU SLIK PRIEVL 08:30 - 08:47 0.28 RUNPUL~ SLIK PR1 EVL 08:47 - 09:10 0.38 RUNPU~ I SLIK PR1 EVL 09:10 - 11:45 2.58 RUNPUa SLIK PR1 EVL 11:45 - 12:30 I 0.75 I RUNPULI SLIK I PR1 EVL 12:30- 12:45 0.25 TEST EQIP PR1EVL 12:45-13:07 0.37 RUNPU SLIK PR1EVL 13:07-13:15 0.13 RUNPU SLIK PR1EVL 13:15-13:35 0.33 RUNPU SLIK PR1EVL 13:35-13:45 0.17 RUNPU SLIK PR1EVL 13:45 - 14:00 0.25 RURD SLIK PR1EVL 14:00-14:15 0.25 TEST EQIP PR1EVL 14:15- 14:30 0.25 RUNPU SLIK PRIEVL 14:30- 15:10 0.67 RUNPU SLIK PR1EVL 15:10-15:25 0.25 RUNPU SLIK PR1EVL 15:25-15:30 0.08 TEST EQIP PR1EVL 15:30-15:45 0.25 RUNPU SLIK PR1EVL 15:45-16:00 0.25 RUNPU SLIK PRIEVL 16:00 - 16:20 0.33 RUNPU SLIK PR1EVL 16:20-16:40 0.33 RUNPU S~IK PRIEVL 16:40 - 16:45 0.08 TEST- I WLHD PR1EVL 16:45 - 17:10 0.42 RUNPUL~ SLIK PR1EVL formation sand, some frac sand, and Flex lock(walnut hulis). Total recovery for three runs 2-1/2 gallons. MU lubricator. Add 3-1/2' additional to bailer. PTest lubricator. Test good. RIH. Run #4. Tool not falling much below well head. Spud tool thru ice plug to RIH. Tag fill @ 11,508' KB. POOH. OOH. Bleed down lubricator. Recover primarily formation sand. PTest lubricator. Test good. Drop 5 gallons of inethanol into swab valve. Allow to fall into well. RIH. Run #5. Tag fill @ 11,511' KB. Tap down to fill bailer. POOH. OOH. Bleed lubricator. Drain bailer. Recover formation sand, some frac sand. Total sand bailed toda - a roximatel 5 allons. Lay down lu ricator and toolstring. Close master valves and wing valve. Install tree cap and secure well for the night. Tum in permit and sign out. Arrive on location. Discuss Pollard JSA and job scope. Issue safe work permit. PU lubricator and tool string. PTest lubricator to 4100 psi. with water. Test good. Open well, 3300 psi. WHP. RIH w/ 2-1/2" x8.5' Drive Down dump bailer. Run #1. RIH. Tag TD @ 11,512' KB. Tap down to fill bailer. POOH. Pull up into ice plug in WH. Stuck. RU methanol skid to Pollard pump unit. Pump won't pump against pressure. Repair discharge valves in pump. Pump methanol into WH. Pull tool up into lubricator. OOH. Bleed down lubricator. Bailer full of formation fines and sand. Some frac sand. Install 3-1/2" Quick test sub on lubricator. PTest lubricator. Test good. RIH w/ bailer. Run #2. Tag fill @ 11,514' KB. Tap down to fill bailer. POOH. OOH. Bleed down lubricator. Break down bailer. Bailer full of gray formation fines, and some frac sand. Recovered approx. 2 gallons of sand to this point today. Check tightness of individual tools in string. PTest QT sub to 3000 psi. Test good. RIH w/ bailer. Run #3. Tag fill @ 11,515' KB. Tap down to fill bailer. POOH. OOH. Bleed off lubricator. Bailer full. Primarily formation sand, some frac sand. PTest QT sub. Test good. RIH. Run #4. Tag fill @ 11,517' KB. POOH. OOH. Bleed down lubricator. Bailer about half full. Some water which is the first water we have recovered. PTest QT sub. Good test. RIH. Run #5. Printed: 10/4l2007 12:5024 PM i ~ ~ll~i~athar~. ~~l Cor~p~ny ~a~e 4 ot s Operations S~rnmary Report ; Legal Well Name: STERLING UNIT 41-15 Common Well Name: STERLING UNIT 41-15 Spud Date: 9/1/1998 Event Name: ORIGINAL COMPLETION Start: 7/15/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 9/9/2003 Group: Rig Name: GLACIER DRILLING Rig Number: 1 Dafe ~ :From - To ~ Hours ~ ~Code ~~,~~ ~ ; P~iasB ~ Descrap~ior~ ~f flp~r~atio~s ' 9/19/2007 17:10 -17:35 0.42 RUNPUL~ SLIK PR1 EVL 17:35 - 17:55 0.33 RUNPU~J SLIK PR1 EVL 17:55 - 18:10 0.25 RURD ~SLIK PR1EVL 18:10 - 18:30 0.33 RURD SLIK PRIEVL 9/20/2007 07:00 - 08:00 1.00 SAFETY MTG PR1 EVL 08:00 - 08:30 0.50 TEST ~EQIP PRIEVL 08:30 - 08:53 0.38 RUNPU SLIK PR1EVL 08:53 - 08:58 0.08 RUNPU SLIK PRIEVL 08:58 - 09:07 0.15 RUNPU SLIK PRIEVL 09:07 - 09:08 0.02 RUNPU SLIK PRIEVL 09:08 - 09:25 0.28 RUNPU SLIK PR1EVL 09:25 - 09:50 0.42 RURD SLIK PR1 EVL Tag fill @ 11,518' KB. Tap down to fill bailer. POOH. OOH. Bleed lubricator. Drain bailer. Recover small amount of water and formation sand, but bailer almost empty. Totai sand bailed today- approximately 4 gallons. Lay down lubricator and toolstring. Close master valves, swab, and wing valve. Install tree cap and secure weli for the night. Cut T50' of wire. Turn in permit and sign out. Arrive on location. Discuss Pollard JSA and job scope. Issue safe work permit. PU lubricator and tool string.Test lubriicator to 4200 psi. Test good. Open well, 3300 psi. WHP. RIH w/ 2-1/4" x5' Drive Down dump bailer. Run #1. RIH. Run #1. Tag TD @ 11,521' KB. Tap down to fill bailer. Bailer stuck. Must trip jars to free bailer. POOH. OOH. Vent lubricator. Drain bailer. Approximately 1' of sand and fines in bailer. Pinch marks accross mouth of mule shoe where bailer was 09:50 - 09:55 0.08 RURD SLIK PR1 EVL 09:55 - 10:00 0.08 TEST EQIP PRIEVL 10:00 - 10:45 0.75 RUNPU SLIK PR1EVL 10:45 - 11:15 0.50 RUNPU SLIK PR1EVL 11:15-11:25 0.17 RURD SLIK PRIEVL 11:25 - 12:05 0.67 REPAIR EQIP PRIEVL 12:05 - 12:20 0.25 RURD SLIK PRIEVL 12:20 - 12:25 0.08 TEST EQIP PRIEVL 12:25 - 13:15 0.83 RUNPU SLIK PRIEVL 13:15 - 13:40 0.42 RUNPU SLIK PRIEVL 13:40 - 14:00 0.33 RURD SLIK PR1EVL 14:00 - 14:15 0.25 RURD SLIK PRIEVL 14:15 - 15:55 1.67 FLOW TEST PR1EVL 15:55 - 16:00 0.08 FLOW TEST PR1EVL 16:00 - 16:05 0.08 TEST EQIP PR1EVL 16:05 - 16:07 0.03 RURD SLIK PR1EVL 16:07-16:22 0.25 RUNPU SLIK PR1EVL 16:22 - 16:37 0.25 RUNPU SLIK PR1EVL 16:37-17:00 I 0.38 RUNPU SLIK PR1EVL 17:00-17:05 i 0.08 RURD SLIK PR1EVL 17:05 - 17:10 i 0.08 TEST EQIP PR1EVL 17:10-1730 , 0.33 ~ RUNPU SLIK PR1EVL 17:30 - 17:40 ~ 0.17 RUNPU SLIK PR1EVL ~ ~ 18:00 - 18:3 0 ; 0.50 RURDU SLIK PR1 EVL Lay down bailer, PU 2-1/4" LIB. MU lubricator. Test Quick test sub. Test good. RIH w/ 2-1/4" LIB. Run #2. Tag early @ 11,501" KB. Suspect 2.73" fluted centralizere above LIB hanging up on perf nodes. POOH. OOH. No marks on LIB. Vetco-gray to grease valves on tree. Swab and master valves leaking, will not pressure test. Finish greasing tree. Break out 2-1/8" stem. PU 1-3/4" stem and 2-1/4" LIB. PTest QT sub to 3000 psi. Test good. RIH w/ 2-1/4" LIB. No fluted centralizer. Run #3. Tag eariy @ 10,218'KB. Tag again @ 11.519'KB. OOH. LIB has chaffing marks all the way around edge. No marks in center. Clear area is football shaped-like it wedged into a flatten section of casing. Casing appears to be pinched in, causing the obstruction. Shut down all hot work on location. Open well to flow testers. WHP 3300 psi. Well flowinq 350 osi. 2.5 MMcf. no water. Pump a couple gallons methanol into lubricator. RIH w/ 2-1/2" DD bailer. Run #4. Tag TD @ 11,510' KB. Tap down to fill bailer. POOH. OOH. Vent lubricator. Drain bailer. Recover 1 gallon Beluga fines, frac sand, and Flex Lock. Sample contains more frac sand and Flex Lock than seen previously. Test QTS. Test good. RIH. Run #5. Tag TD @ 11,511'KB. Tap down to fill bailer. POOH. OOH. Bailer full of frac sand, formation fines, and flex lock.l Lay down lubricator and toolstring. Close master valves, swab, and wing valve. Printed: 10/4/2007 12:50:24 PM • ~ l~larat~on Dil Company Pa9e.~ of~~ Op~:rat~~ns St~mmary R~por#` Legal Well Name: STERLING UNIT 41-15 Common Well Name: STERLING UNIT 41-15 Spud Date: 9/1/1998 Event Name: ORIGINAL COMPLETION Start: 7/15/2007 End: Contractor Name: GLACIER DRILLING Rig Release: 9/9/2003 Group: Rig Name: GLACIER DRILLING Rig Number: 1 ` Date ~ >From - T~ ~ Hours ~ ~o~e `~~,~~ ~ Phase ~; flescr~,p~ion ~f ~?per~~r±~~s ~ 9/20/2007 ~ 18:00 - 18:30 I 0.50 ( RURD I SLIK I PR1 EVL I 9/21/2007 I 07:00 - 07:30 I 0.50 ~ SAFETY ~ MTG_ ~ PR1 EVL 07:30 - 08:10 0.67 RURD ~ SLIK PR1 EVL 08:10 - 08:20 0.17 TEST_ EQIP PR1 EVL 08:20 - 08:40 0.33 RUNPU SLIK PR1 EVL 08:40 - 09:00 0.33 RUNPU SLIK PR1 EVL 09:00 - 09:20 0.33 RUNPU SLIK PR1 EVL 09:20 - 09:45 0.42 RUNPU SLIK PR1 EVL 09:45 - 10:00 0.25 RURD SLIK PR1EVL 10:00 - 10:05 0.08 TEST_ EQIP PR1 EVL 10:05 - 10:22 0.28 RUNPU SLIK PR1EVL 10:22 - 10:32 0.17 RUNPU SLIK PR1EVL 10:32 - 10:50 0.30 RUNPU SLIK PRIEVL 10:50 - 11:00 0.17 RURD SLIK PR1EVL 11:00 - 11:05 0.08 RURD SLIK PR1EVL 11:05 - 11:10 0.08 TEST EQIP PR1EVL 11:10 - 11:24 0.23 RUNPU SLIK PR1EVL 11:24 - 11:55 0.52 RUNPU SLIK PR1EVL 11:55 - 12:15 0.33 RUNPU SLIK PRIEVL 12:15 - 12:25 0.17 RURD SLIK PR1EVL 12:25 - 12:30 0.08 TEST EQIP PR1EVL 12:30 - 12:45 0.25 RUNPU SLIK PR1EVL 12:45 - 13:05 0.33 RUNPU SLIK PRIEVL 13:05 - 13:30 0.42 RUNPU SLIK PR1EVL 13:30 -13:35 0.08 RURD SLIK PR1 EVL 13:35 - 14:07 0.53 TEST EQIP PR1 EVL 14:07 - 14:25 0.30 RUNPU SIIK PR1 EVL 14:25 - 14:40 0.25 RUNPU SLIK PR1 EVL 14:40 - 14:55 0.25 RURD SLIK PR1 EVL 14:55 - 15:00 0.08 TEST EQIP PR1 EVL 15:00 - 15:20 0.33 RUNPU SLIK PR1 EVL 15:20 - 15:30 0.17 RUNPU SLIK PR1 EVL 15:30 - 15:50 0.33 RUNPU SLIK PR1EVL 15:50 - 16:30 0.67 RURD SLIK PR1 EVL 9/23/2007 08:00 - 08:30 0.50 SAFETY MTG CMPPRF 08:30 - 09:45 1.25 RURD ELEC CMPPRF 09:45 - 10:00 0.25 SAFETY MTG CMPPRF 10:00 - 11:00 1.00 TEST EQIP CMPPRF 11:00 - 11:15 I 0.25 TEST ~ EQIP CMPPRF 11:15 - 12:30 ( 1.25 RUNPU ELEC CMPPRF Install tree cap and secure well for the night. Turn in permit and sign out. Arrive on location. Discuss Pollard JSA and job scope. Issue safe work permit PU lubricator and tool string w/ 12' of 2-1/8" stem and 8.5' DD bailer. Test lubricator to 4200 psi. Test good. Open well, 3300 psi. WHP. RIH w/ 2-1/2" x8.5' Drive Down dump bailer. Run #1. RIH. Run #1. Tag TD @ 11,513' KB. Tap down to fill bailer. POOH. Bailer stuck. Jar to free bailer. POOH. OOH. Vent lubricator. Drain bailer. 3/4 full-formation sand, coal chips, frac sand. MU lubricator. PT QTS. Test good. Open well. RIH. Run #2. Tag up @ 11,514' KB. Sticky-PU often to free bailer. POOH. OOH. Vent lubricator. Drain lubricator-about 1/2 full. Rewver mostly frac sand, Flex Lock, Beluga fines, and small metal fragments. Down size to 2-1/4" bailer. PT QTS. Test good. Pump a couple gallons methanol. RIH. Run # 3. Tag 11,515'KB. POOH. OOH. Vent lubricator. Bailer fuil. Frac sand, formation fines. PT QTS. Test good. RIH. Run #4. Tag up 11,517'KB. POOH. OOH. Drain bailer. Recovery frac sand and perf debris, PT QTS. RIH. Run # 5. Tag 11,519'KB. Tap down to fill bailer. POOH. OOH. Vent lubricator. Drain lubricator. Recover frac sand and formation fines. PU 2-1l2" bailer. PT QTS. Test good. RIH w/ 2-1/2" bailer. Run # 6. Tag TD @ 11,520'KB. Tap down to fill bailer. POOH. OOH. Bailer ful~ of frac sand, formation fines, and flex lock. Lay down lubricator and toolstring. Close master valves, swab, and wing valve. Install tree cap and secure well for the night. Turn in permit and sign out. Hold PJSM and obtain safe work permit. Review high pressure work, testing lubricator to 3500# using methanol, trips, falls, etc Rig Up Expro Americas, Crane and Lubricator Hold Pre Job Explosive safety Meeting PT lubricator to 3500# - OK, Rig lubricator down and add additional high density weight bars (7'), Measure lubricator length (did not need to add any lubricator), rig lubricator back on weli. Quick Test lubricator union 3500# - OK RIH with 2-1/8" hollow steel carrier perforating gun, 6spf, 60 degree phasing. Tie into module #2 @ 10600' Tie into Module 1 Printed: 10/4/2007 12:50:24 PM ~ • 9/23/2007 12:30 - 12:45 0.25 PERF CSG CMPPRF Perforate 11489'-11506' (17') MD tied to Expro CBL dated 9-5-2007 12:45 - 13:30 0.75 RUNPU ELEC CMPPRF POOH with first gun run 13:30 - 73:45 0.25 RUNPU ELEC CMPPRF ~ay gun down 13:45 - 14:00 0.25 TEST_ EQIP CMPPRF Pick up 2nd gun and Quick Test lubricator union to 3500# - OK 14:00 - 14:06 0.10 BLOWD CSG_ CMPPRF Blow well down from shut in pressure of 3300# to 2300#, shut well in 14:06 - 15:15 1.15 RUNPU ELEC CMPPRF RIH with 2-1/8" hollow steel carrier perforating gun, 6spf, 60 degree phasing. Tie into module #2 @ 10600' Tie into Module 1 15:15 - 15:20 0.08 PERF CSG_ CMPPRF Perforate 11467'-11480 13') MD correlated to Expro CBL dated 9-5-2007. Run CCL across both perforated zones for log presentation 15:20 - 16:00 0.67 RUNPU ELEC CMPPRF POOH 16:00 - 16:30 0.50 RUNPU ELEC CMPPRF Gun at surface, shut master valves, bleed off pressure in lubricator, verify gun had gone off, rig down. 16:30 - 17:00 0.50 RURD_ ELEC CMPPRF Turn well over to Expro production testers. Finish rig down Expro perforating, sign out and leave location. (Total flow time to vent stack to date = 120 Hrs) Printed: 10/4/2007 12:50:24 PM ALASKA STERLING STERLING PAD 43-9 Design: SU 41-15 - Sidetrack Standard Survey Report July 27, 2007 ~ Marathon Oil Survey Report Company: ALASKA Project: STERLING Site: STERLING PAD 43-9 Well: SU 41-15 Wellbore: SU 41-15 - Sidetrack Design: SU 41-15 - Sidetrack Project: STERLING, Kenai, Alaska, USA Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well SU 41-15 Glacier KB @ 245.OOft (Glacier Rig #1) Glacier KB @ 245.OOft (Glacier Rig #1) True Minimum Curvature EDM 2003.16 Single User Db ~ Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Site: STERLING PAD 43-9, Site centered on well SU 43-9 Site Position: Northing: 2,390,138.40 ft Latitude: 60° 32' 17.977 N From: Map Easting: 314,652.09 ft Longitude: 151 ° 1' 45.472 W Position Uncertainty: 0.00 ft Slot Radius: 0 " Grid Convergence: -0.896 ° ~ ` Weii SU 41-15, 1998 Exploration Well Well Position +N/-S 0.00 ft Northing: 2,390,042.46 ft Latitude: 60° 32' 17.045 N +E/-W 0.00 ft Easting: 314,734.68 ft Longitude: 151 ° 1' 43.791 W Position Uncertainty: 0.00 ft Wellhead Elevation: ft Ground Level: 224.00 ft Wellbore SU 41-15 - Sidetrack Magnetics Model Sample Date Declination Dip Angle Field Strength ~°~ ~°) ~nT) IGRF200510 12/31/1999 21.239 73.381 55,325 Design: SU 41-15 - Sidetrack Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 6,275.00 Vertical Section: Depth From +N/-S +E/- Direction ~TVO) (ft) ~- (°) 0.00 0.00 0.00 121.458 Survey Program Date: 7/27l2007 From To (ft) (ft) Survey (Wellbore) Tool Name Description 154.00 6,275.00 MWD Survey (SU 41-15) MWD/GYRO 6,423.00 11,655.00 Original Survey (SU 41-15 - MWD/GYRO Survey Measured Vertical Depth Vertical Dogleg Build Turn Depth Inclination Azimuth (ft) +N/-S +E/-W Section Rate Rate Rate (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft~ 0.00 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0 0 49.00 0.191 115.000 49.00 -0.03 0.07 0.08 0.39 0.389610396 0 ~ 258.00 1.100 115.000 257.99 -0.99 2.13 2.33 0.48 0.480769227 0 460.00 1.800 183.000 459.93 -4.98 3.72 5.77 0.85 0.346534651 33.66336605 553.00 2.100 183.600 552.88 -8.14 3.54 7.27 0.32 0.322580642 0.645161285 729.00 2.100 164.400 728.76 -14.46 4.20 11.13 0.40 0 -10.90909002 815.00 1.900 145.800 814.71 -17.16 5.43 13.58 0.79 -0.232558138 -21.62790842 1,003.00 1.700 148.200 1,002.62 -22.11 8.65 18.91 0.11 -0.106382978 1.276595734 1,197.00 1.800 137.700 1,196.53 -26.81 12.21 24.41 0.17 0.051546391 -5.412371088 1,482.00 1.700 148.200 1,481.39 -33.83 17.60 32.67 0.17 -0.104166666 4.479166628 1,577.00 1.300 150.400 1,576.36 -35.96 18.88 34.87 0.43 -0.421052628 2.315789454 1,669.00 1.100 157.300 1,668.34 -37.69 19.73 36.50 0.27 -0.217391302 7.499999936 1,862.00 1.000 154.200 1,861.30 -40.91 21.18 39.42 0.06 -0.051813471 -1.606217603 2,210.00 0.350 163.600 2,209.28 -44.67 22.80 42.76 0.19 -0.186781608 2.701149402 2,262.00 0.363 161.065 2,261.28 -44.97 22.90 43.00 0.04 0.025180624 -4.874146912 2,648.00 1.800 117.000 2,647.22 -48.39 27.11 48.38 0.60 0.55776892 -15.25896401 ~ 2,785.00 4.800 115.200 2,783.98 -51.81 34.22 56.23 2.19 2.189781003 -1.313868602 2,881.00 7.400 120.500 2,879.43 -56.66 43.18 66.40 2.77 2.70833331 5.520833286 2,973.00 8.500 124.100 2,970.55 -63.48 53.92 79.12 1.31 1.195652164 3.913043445 3,071.00 9.900 126.500 3,067.28 -72.55 66.69 94.75 1.48 1.428571416 2.448979571 3,260.00 15.600 120.600 3,251.55 -95.17 101.65 136.38 3.09 3.01587299 -3.121693095 3,356.00 18.000 116.600 3,343.45 -108.39 126.03 164.07 2.77 2.499999979 -4.166666631 3,451.00 19.100 119.900 3,433.52 -122.71 152.63 194.23 1.60 1.157894727 3.473684181 3,547.00 21.300 125.800 3,523.62 -140.74 180.39 227.33 3.12 2.291666647 6.145833281 3,641.00 23.400 124.900 3,610.55 -161.41 209.55 262.99 2.26 2.234042534 -0.9574468 3,737.00 25.500 120.100 3,697.95 -182.68 243.07 302.68 3.01 2.187499981 -4.999999957 3,833.00 27.600 121.300 3,783.82 -204.60 279.96 345.59 2.26 2.187499981 1.249999989 3,928.00 29.800 121.600 3,867.14 -228.41 318.87 391.20 2.32 2.315789454 0.315789471 4,023.00 32.500 122.100 3,948.44 -254.34 360.61 440.34 2.86 2.842105239 0.526315785 4,118.00 35.500 123.500 4,027.19 -283.14 405.24 493.44 3.26 3.15789471 1.473684198 4,214.00 38.100 128.900 4,104.07 -317.14 451.55 550.69 4.32 2.70833331 5.624999952 4,310.00 40.200 124.110 4,178.53 -353.12 500.27 611.03 3.83 2.187499981 -4.989583291 4,435.00 42.900 122.600 4,272.07 -398.68 569.53 693.88 2.30 2.159999982 -1.20799999 4,501.00 43.600 126.400 4,320.15 -424.29 606.78 739.02 4.08 1.060606052 5.757575708 4,597.00 43.600 123.700 4,389.68 -462.30 660.96 805.08 1.94 0 -2.812499976 4,788.00 43.200 124.800 4,528.46 -536.15 769.44 936.15 0.45 -0.209424082 0.575916225 ! 4,884.00 43.400 129.800 4,598.35 -576.03 821.77 1,001.61 3.58 0.208333332 5.208333289 4,980.00 43.200 126.500 4,668.22 -616.69 873.53 1,066.98 2.37 -0.208333332 -3.437499971 5,172.00 43.400 123.300 4, 807.97 -692.00 981.50 1,198.38 1.15 0.104166666 -1.666666652 5,268.00 43.700 128.000 4,877.57 -730.54 1,035.21 1,264.31 3.39 0.312499997 4.895833291 5,364.00 43.400 126.500 4,947.15 -770.57 1,087.86 1,330.11 1.12 -0.312499997 -1.562499987 5,458.00 43.200 123.800 5,015.56 -807.68 1,140.56 1,394.43 1.98 -0.212765956 -2.872340401 5, 554.00 43.300 127.700 5, 085.50 -846.10 1,193.92 1,460.00 2.79 0.104166666 4.062499965 5,746.00 42.900 127.000 5,225.69 -925.69 1,298.20 1,590.49 0.32 -0.208333332 -0.36458333 5,937.00 43.500 123.700 5,364.94 -1,001.30 1,404.83 1,720.90 1.22 0.314136123 -1.727748676 6,218.00 43.100 125.300 5,569.45 -1,110.44 1,563.64 1,913.33 0.42 -0.142348753 0.569395013 6,275.00 43.129 124.973 5,611.06 ~ -1,132.86 1,595.50 1,952.21 0.40 0.050152944 -0.573661702 6,423.00 48.690 121.570 5,714.01 -1,191.01 1,684.40 2,058.39 4.10 3.757711612 -2.299332258 6,487.00 50.170 121.440 5,755.64 -1,216.41 1,725.85 2,107.00 2.32 2.3125 -0.203125 6, 550.00 51.190 118.880 5, 795.56 -1,240.89 1, 767.98 2,155.72 3.54 1.619047619 -4.063492063 ~ 6,614.00 52.640 118.510 5,835.04 -1,265.08 1,812.17 2,206.03 2.31 2.265625 -0.578125 6,677.00 53.090 117.840 5,873.07 -1,288.79 1,856.44 2,256.17 1.11 0.714285714 -1.063492063 6,741.00 54.610 117.170 5,910.82 -1,312.65 1,902.28 2,307.73 2.52 2.375 -1.046875 6,804.00 56.690 116.010 5,946.37 -1,335.92 1,948.79 2,359.55 3.63 3.301587301 -1.841269841 6,868.00 56.820 116.890 5,981.46 -1,359.77 1,996.71 2,412.87 1.17 0.203125 1.375 6,931.00 56.640 116.090 6,016.02 -1,383.26 2,043.86 2,465.34 1.10 -0.285714286 -1.26984127 6,995.00 57.460 115.960 6,050.83 -1,406.82 2,092.12 2,518.81 1.29 1.28125 -0.203125 7,058.00 57.370 117.160 6,084.76 -1,430.56 2,139.60 2,571.69 1.61 -0.142857143 1.904761905 7,122.00 57.160 117.060 6,119.36 -1,455.09 2,187.52 2,625.38 0.35 -0.328125 -0.15625 7,185.00 56.770 117.180 6,153.71 -1,479.17 2,234.53 2,678.04 0.64 -0.619047619 0.19047619 7,249.00 56.530 116.160 6,188.89 -1,503.16 2,282.30 2,731.31 1.38 -0.375 -1.59375 7,312.00 57.050 116.470 6,223.40 -1,526.53 2,329.54 2,783.81 0.92 0.825396825 0.492063492 7,376.00 57.140 117.330 6,258.17 -1,550.84 2,377.46 2,837.37 1.14 0.140625 1.34375 7,439.00 56.990 117.580 6,292.42 -1,575.22 2,424.38 2,$90.12 0.41 -0.238095238 0.396825397 7,503.00 56.800 117.390 6,327.38 -1,599.96 2,471.94 2,943.60 0.39 -0.296875 -0.296875 7,566.Q0 56.360 117.800 6,362.07 -1,624.32 2,518.54 2,996.06 0.88 -0.698412698 0.650793651 7,630.00 56.640 117.320 6,397.40 -1,649.01 2,565.86 3,049.31 0.76 0.4375 -0.75 7,693.00 56.940 116.970 6,431.90 -1,673.06 2,612.76 3,101.87 0.67 0.476190476 -0.555555556 7,757.00 56.670 116.270 6,466.94 -1,697.06 2,660.64 3,155.23 1.01 -0.421875 -1.09375 . 7,820.00 57.460 115.950 6,501.20 -1,720.32 2,708.12 3,207.88 1.32 1.253968254 -0.507936508 7,883.00 57.660 117.290 6,534.99 -1,744.15 2,755.65 3,260.86 9.82 0.317460317 2.126984127 7,946.00 57.530 116.370 6,568.75 -1,768.15 2,803.11 3,313.87 1.25 -0.206349206 -1.46031746 8,010.00 57.170 117.590 6,603.28 -1,792.60 2,851.13 3,367.59 1.70 -0.5625 1.90625 8,072.00 56.920 117.610 6,637.01 -1,816.70 2,897.24 3,419.50 0.40 -0.403225806 0.032258065 8,136.00 56.700 117.370 6,672.04 -1,841.43 2,944.75 3,472.93 0.47 -0.34375 -0.375 8,198.00 56.240 117.700 6,706.29 -1,865.32 2,990.58 3,524.49 0.86 -0.741935484 0.532258064 8,261.00 56.250 118.160 6,741.30 -1,889.85 3,036.86 3,576.77 0.61 0.015873016 0.73015873 8,323.00 54.920 118.040 6,776.34 -1,913.94 3,081.97 3,627.83 2.15 -2.14516129 -0.193548387 8,387.00 54.400 118.080 6,813.36 -1,938.50 3,128.04 3,679.94 0.81 -0.8125 0.0625 8,450.00 53.040 117.250 6,850.63 -1,962.08 3,173.02 3,730.62 2.41 -2.158730159 -1.317460317 8,514.00 52.210 118.650 6,889.49 -1,985.92 3,217.95 3,781.38 2.17 -1.296875 2.1875 8,576.00 51.230 117.860 6,927.89 -2,008.96 3,260.82 3,829.97 1.87 -9.580645161 -1.274193548 8,640.00 50.690 118.250 6,968.21 -2,032.34 3,304.68 3,879.59 0.97 -0.84375 0.609375 • 8,703.00 50.030 118.700 7,008.40 -2,055.47 3,347.33 3,928.04 1.18 -1.047619048 0.714285714 8,764.00 48.210 118.070 7,048.32 -2,077.39 3,387.90 3,974.09 3.08 -2.983606557 -1.032786885 8,827.00 47.300 118.820 7,090.67 -2,099.60 3,428.91 4,020.67 1.69 -1.444444444 1.19047619 8,891.00 46.590 118.820 7,134.37 -2,122.15 3,469.88 4,067.38 1.11 -1.109375 0 8,954.00 46.220 119.960 7,177.81 -2,144.54 3,509.63 4,112.98 1.44 -0.587301587 1.809523809 9,017.00 45.510 119.430 7,221.68 -2,166.94 3,548.91 4,158.17 1.28 -1.1269$4127 -0.841269841 9,079.00 44.220 117.010 7,265.63 -2,187.62 3,587.44 4,201.83 3.45 -2.080645161 -3.903225806 9,141.00 42.090 116.300 7,310.85 -2,206.65 3,625.33 4,244.08 3.52 -3.435483871 -1.14516129 9,204.00 41.300 115.430 7,357.89 -2,224.93 3,663.04 4,285.79 1.55 -1.253968254 -1.380952381 9,267.00 39.710 116.390 7,405.80 -2,242.81 3,699.84 4,326.51 2.71 -2.523809524 1.523809524 9,330.00 37.760 116.980 7,454.94 -2,260.51 3,735.07 4,365.80 3.15 -3.095238095 0.936507936 9,393.00 35.790 116.910 7,505.40 -2,277.60 3,768.69 4,403.39 3.13 -3.126984127 -0.111111111 9,456.00 34.420 116.760 7,556.94 -2,293.95 3,801.01 4,439.50 2.18 -2.174603174 -0.238095238 9,518.00 34.060 116.640 7,608.19 -2,309.63 3,832.18 4,474.27 0.59 -0.580645161 -0.193548387 9,581.00 32.770 115.120 7,660.78 -2,324.78 3,863.39 4,508.80 2.44 -2.047619048 -2.412698413 9,644.00 31.750 115.210 7,714.05 -2,339.08 3,893.82 4,542.22 1.62 -1.619047619 0.142857143 9,707.00 29.940 116.000 7,768.14 -2,353.03 3,922.95 4,574.35 2.94 -2.873015873 1.253968254 9,770.00 28.470 118.480 7,823.13 -2,367.08 3,950.28 4,605.00 3.02 -2.333333333 3.936507936 9,833.00 27.530 120.360 7,878.76 -2,381.60 3,976.05 4,634.55 2.05 -1.492063492 2.984126984 • 9,896.00 27.130 121.030 7,934.72 -2,396.37 4,000.92 4,663.47 0.80 -0.634920635 1.063492063 9,959.00 26.590 120.680 7,990.93 -2,410.96 4,025.35 4,691.94 0.89 -0.857142857 -0.555555556 9,997.10 26.280 121.473 8,025.04 -2,419.72 4,039.88 4,708.90 1.23 -0.81332442 2.080325413 10,084.00 25.760 122.240 8,103.15 -2,439.91 4,072.18 4,746.98 0.54 -0.516129032 0.387096774 10,147.00 25.150 121.070 8,160.04 -2,454.12 4,095.22 4,774.06 1.25 -0.968253968 -1.857142857 10,210.00 25.130 122.710 8,217.07 -2,468.26 4,117.95 4,800.82 1.11 -0.031746032 2.603174603 10,272.00 24.900 122.470 8,273.25 -2,482.38 4,140.03 4,827.03 0.41 -0.370967742 -0.387096774 10,336.00 25.530 124.560 8,331.16 -2,497.44 4,162.76 4,854.27 1.70 0.984375 3.265625 10,400.00 25.720 126.320 8,388.86 -2,513.48 4,185.31 4,881.88 1.23 0.296875 2.75 10,462.00 26.300 127.110 8,444.58 -2,529.74 4,207.10 4,908.96 1.09 0.935483871 1.274193548 10,525.00 26.440 126.870 8,501.03 -2,546.58 4,229.45 4,936.81 0.28 0.222222222 -0.380952381 10,588.00 25.750 126.440 8,557.60 -2,563.12 4,251.68 4,964.41 1.14 -1.095238095 -0.682539683 10,652.00 26.350 126.090 8,615.10 -2,579.74 4,274.34 4,992.41 0.97 0.9375 -0.546875 10,713.00 26.280 126.460 8,669.78 -2,595.74 4,296.14 5,019.36 0.29 -0.114754098 0.606557377 ~ 10,776.00 25.550 125.510 8,726.45 -2,611.92 4,318.42 5,046.80 1.33 -1.158730159 -1.507936508 10,839.00 25.470 126.840 8,783.30 -2,627.94 4,340.32 5,073.84 0.92 -0.126984127 2.111111111 10,902.00 25.850 125.010 8,840.09 -2,643.94 4,362.41 5,101.04 1.39 0.603174603 -2.904761905 10,965.00 25.610 126.260 8,896.85 -2,659.87 4,384.64 5,128.31 0.94 -0.380952381 1.984126984 11,028.00 25.330 125.490 8,953.72 -2,675.75 4,406.59 5,155.33 0.69 -0.444444444 -1.222222222 11,091.00 24.910 124.540 9,010.76 -2,691.10 4,428.49 5,182.02 0.92 -0.666666667 -1.507936508 11,091.75 24.903 124.548 9,011.45 -2,691.28 4,428.75 5,182.33 0.99 -0.891122285 1.025777155 11,217.00 24.430 125.440 9,125.41 -2,721.15 4,471.26 5,234.18 0.20 0.126984127 0.380952381 11,280.00 24.510 125.300 9,182.75 -2,736.25 4,492.54 5,260.22 0.16 0.126984127 -0.222222222 11,583.14 24.510 125.300 9,458.57 -2,808.92 4,595.18 5,385.69 0.00 0.00 0.00 Targets Target Name - hit/miss Dip Dip TVD target Angl Dir. (ft) +N/-S +E/-W Northing Easting (ft) (ft) (ft) (ft) Latitude Longitude SU 41-15RD Ty~ 0.00 0.0055.00 -2,846.92 4,470.38?,387,126.00~19,160.001' 48.999 NI' 14.447 W - actual wellpath misses by 170.71ft at 11091.75ft MD (9011.45 TVD, -2691.28 N, 4428 , - Circle (radius 200.00) SU 41-15RD Lo~ 0.00 0.00 80.00 -2,429.72 3,903.78?,387,552.00 ~18,600.001' 53.110 N I' 25.768 W - actual wellpath misses by 147.11ft at 9997.67ft MD (8025.56 TVD, -2419.85 N, 4040.1 - Circle (radius 200.00) SU 41-15RD TC 0.00 0.00 95.00 -2,846.92 4,470.38 ?,387,126.00 ~19,160.001' 48.999 N-' 14.447 W - actual wellpath misses by 135.45ft at 11583.14ft MD (9458.57 TVD, -2808.92 N, 4595 - Circle (radius 200.00) Casing Points Measured Vertical Depth Depth i ~ft) ~ft) 49.00 49.00 20" 2,262.00 2,261.28 13 3/8" Checked By: 7/27/2007 Approved By: Casing Hole Diameter Diameter Name (~~) (~~~ 20 26 13-3/8 17-1 /2 Dat Page 5 COMPASS 2003.16 Build 42 f - SU 41-15RD Gas Venting extensio~quest ~ Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) ~ ' Sent: Friday, September 14, 2007 2:11 PM ~~~~ ~~ «~ ~~ To: 'Skiba, Kevin J.' Cc: Rang, Craig L.; Walsh, Ken; Mullin, Mickey Subject: RE: SU 41-15RD Gas Venting extension request Kevin and Craig - Thank you for taking the time ta further explain the challenges you are encountering with bringing SU 41-15RD on line. You are granted a time extension for venting not to exceed 144 hours total. Please contact me Monday, 9/17 with an update of the progress and results of the pressure-temperature survey that will be run over the weekend. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Skiba, Kevin J. [mailto:kskiba@marathonoil.com] Sent: Friday, September 14, 2007 11:49 AM To: Regg, James B (DOA) Cc: Rang, Craig L.; Walsh, Ken; Mullin, Mickey; Skiba, Kevin ). Subject: SU 41-15RD Gas Venting extension request Jim, This is a follow up email as per our telephone conversation. Marathon requests an extension of the gas venting period from 72 hours to 144 hours, for the SU 41-15RD well. The well is performing at a, less than expected, rate of (1.8mmcf / @ 237 psi well head pressure). Normally the frac fluid is recovered in less than 2 days, however only 30% has been recovered to date. Respectfully, Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 ~,i t~( 0 7~` J ~?~~ \ , ~~ i. :3t~P,,,~ ~ 2~~,~~.~c~ U„J ~<e~;~~;~ sk; ~. ~ C'r~.i ~,~ J - ~ f'PG~,,I ~.~. ~ ; r ~ ~ ~ I -15 2~ i s 5 - ~ M.~t sc. ~ ~~~ ~ ctiv~rc~~- !'~a.~e r S -N ~,~t~t.c sc ~(c(R.~.~ d ~e- S~{l~G~(Z, ~~J~,~~J~LC~- i.1Yl c~r~:~e; .~~ ~- ~., U ~,U.tsc~(~, ~ -F J ~ Z ~'~-5 f7l~fC. _ 'Z~)~ -30~ ~,~ ~~ +~~-~.~`'-6lee~ ;Gz~c ~c i~~,~ ~~,~ce~' ~ ~'~~~ ~e~~ t~J~c~l~~sc~,, ~~ ~z)a~7 CJ ~ ~ ~'•'tL J 1C-~,•~ ~. ~ ~2~~'z~S ~V~'i v+E'Pr) j ~ ~ '~-c ~ (~.L.r\ ~R°SS i.tr 2-~~.~~( f~~.~C1J`P Slri.r^IIeG J U'~r, v~%~~Q,~ -~o l,~~i. ~-f}tn,~G~ c~2.;~ z~~A-~AE~ ~~+~~~z~ ~~~ ~ w C~k C ' Lc ~ C~^'L Cvr~~ bc.c.~.~ ~-c ~~t,~ ~"~ ~ l~+~ a~L~ ,,~-e.~,~Cr ~ v„~.Q~r C~"t~' S~,U`~~ ~ ~ ~ l 44k ~S~ w: ~ 9i14i2oo~ ~- ~,~~,~,~ rn t~es~ ~~s~~ , ~~-6~ a.~~~ w~ ~,~w c~ ~- 5~~~ ~~~,~~ AAARATHON ~ Al~a Asset Team United States Production Operations M11'1#~1011 ~1' 171~91 August 23, 2007 Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7`i' Avenue, Suite 100 Anchorage, AK 99501 RE: Marathon SU #41-ISRD - API 50-233-20484-01 CONFIDENTIAL Dear Mr. Okland: P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-235-6322 Hand Delivery Enclosed is one CD containing confidential digital well data for the above referenced well, as described on the attached CD Contents document. Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead adclress or fax to 713-235-6322. Thank you, ~~~~~~~ ~~ Courtney McElmoyl °~b~ -~~ Received by: l~ ~ IS33~ ~ ~~~ ~ ~ Date: ~ _. ~ ~ ~ ~ ~~ ~{;'~ ~ ~ ~~ ~ ~~, ~°3,~ <~ Enclosures ,~~:~~ t~ ~: ;~ ~ ~~~'j~. ~.ai;`:~:?E~~1+~'d`@ ,~,i ~~'~~~~ ~ . ~ a ~ ~ SARAH PALIN, GOVERNOR ~ ~ ~ ~s~ Q~ ~~S 333 W. 7th AVENUE, SUITE 100 COI~TSER~A'1'I011T CO~'IIrIISSIOlIT ANCHORAGE,ALASKA 99501-3539 PHONE (907) 278-1433 FAX (907) 276-7542 Craig Meese Senior Technical Consultant Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 (~~ ~ ~~~~ Re: Sterling Gas Field, Sterling Gas Pool, Sterling Unit 41-15RD Sundry Number: 307-259 Dear Mr. Meese: 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, conta.ct 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. DATED trus ~ay of August, 2007 Encl. ~:~..,...,,,., ~ • • ° Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 . Kenai, AK 99611 MARATHON Oil Company Telephone 907/283-1326 Fax 907/283-1350 July 30, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission ~~~~~~ 333 W 7t~ Ave ~~~ ~ ~ ~~~~ Anchorage, Alaska 99501 !~e~35~€~ ~1~ c~,~ ~~~ ~,Lii3.`a. ~'r.? r~3'ds -~~"it;3; Reference: 10-403 Sundry Notice ~~;,~~; ,F ;t.; Field: Sterling Field Well: SU 41-15RD Dear Mr. Maunder, ~~~\~.h~~~ ~-1~~~ Enclosed please find an Application for Sundry Approvals form 10-403 for ~e~ag~ p~~ CJYiiiw~ell ~and associated attachments. This well has been completed cased hole ~~ with a 3.5" Excape monobore production string to surFace. Request for approval is being made to perforate, fracture stimulate the 6 Excape modules placed in the well, and vent gas during the initial post fracture treatment flowback period. Should you require further information, I can be contacted at (713) 296-2214 /(713) 725- 7114, or by email at cameese(c~marathonoil.com. Alternatively you may contact Kevin Skiba in our Kenai, AK field office at 907-283-1371 or by e-mail at kskiba@marathonoil.com. Sincerely, ~~ ~ ~x~~ Craig Meese Completions Engineer Enclosures: 10-403 Sundry Notice cc: AOGCC Well Schematic Houston Well File Description summary of proposal Kenai Well File Request for approval to vent gas KJS CAM ~~ T TE Cf~= ALASKA ~'~~,y ~~~~I~I~~ . r ALAS~ OIL AND GAS CONSERVATION COM~SlON ~ ~ (1G !~ ~ 2~J07 APPLICATION FOR SUNDRY APPROVALS 1z 20 AAC 25.280 '`~~~;$~~ ~5~~ ~~ ~~w ':` =+^~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q Waive~~4 ;:; <,, Other , ~ ~~_.~ Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate ~ Time Extension [] Change approved program ~ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ~ Exploratory ~ 207-0880 ' 3. Address: PO B 1949 Stratigraphic ~ Service ~ 6. API Number: ~~ 133 50 20484- ~ 00 ~ ox , Kenai Alaska, 99611-1949 - - - 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 ~ Sterling Unit 41-15RD ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~ ADL 2497 245' (21' AGL) Sterling Field / Beluga ~ Upper T onek Pools 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,655' 9,517' 17,585' 9,460' NA NA Casing Length Size MD ND Burst Collapse Structural Conductor 79' 20" 58' 58' 3,060 psi 1,500 psi Surface 2,292' 13/3/8" 2,271' 2,270' 3,450 psi 1,950 psi Intermediate 6,302' 9-5/8" 6,281' S,615' S,750 psi 3,090 psi Production 11,606' 3-1/2" 11,632' 9,499' 10,160 psi 10,540 psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,930' - 11,527' (Gross) 7,969' - 9,403' (Gross) 3-1/2" L- 80 11,585' 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 ^ BOP Sketch ~ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: 9/10/2007 g p 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 Craig Meese Title Senior Technical Consultant Signature Phone Date ~ e%t_ 7~~~ (713) 296-2214 7/30/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ~~ Plug Integrity ^ BOP Test ~~ Mechanical Integrity Test ^ Location Clearance ~ Other: `\ ~ ~O~P ~Q.r aD AI~C,aS.~~S~ R E ~ ~~~ ~Q~ ~ ~Z~~,~S~ ~~ '~ p~; ~ ~ S~S~e ~.~o c- ~~- ~` ~ .~~ 4 ~ ~ 1 ~ ~`~ ~~ ~~ ~ Subsequent Form Required: ,`~t~ ~~ ~~~ ~jJG o$ Zd~~ ~.1 ~ APPROVED BY A roved b : SIONER THE COMMISSION Date: g~ Z~ ~~ pp y Form 10-403 Revised 06/2006 p~ I N A L ~~~~bmit in Duplicate ~ • KBU 41-15RD Fracture Stimulation Desription Summary of Proposal Sterling Unit 41-15RD was drilled and cased as a 3.5" Monobore Excape completion containing six Excape perforating modules. Each Excape module will complete a different production interval. Fracture stimulation operations will commence with the perforating and treatment of Module 2 followed by modules 3 through 6 (Beluga). All fracture stimulation operations are typically concluded in one day, unless screenouts occur. After all treatments have been performed, coiled tubing will be utilized to cleanout the wellbore of module isolation flappers and frac proppant to PBTD. The well will then be jetted in with nitrogen via the coil tubing. Once the well is flowing on its own, coil tubing will be pulled from the well and rigged down. Well testing operations will then commence and continue until an acceptable gas rate is acheived and produced frac water load volumes are at manageable levels. Once well is adequately cleaned up, then Module 1(Tyonek) will be detonated and the well will be turned over to production. Request for Approval to Vent Gas Due to the nature of such fracture stimulations, large amounts of water are injected, along with the fracture proppant, that will have to be unloaded and cleaned up during the post fracture flowback/testing period. This unloading, or cleaning up period, requires the well to be vented to atmosphere until enough gas volume! is achieved to flow the well into the high pressure sales gas system. The duration of this venting operation can last as little as a few hours up to a number of days based upon reservoir pressures, permeability, well performance, tubing size, and fracture placement success. For Marathon's gas well operations in the Sterling Gas Field, typical vent times are less than 48 hours. However, due to the uncertainty of exactly how long SU 41-15RD will be required to vent to atmosphere, this request is for a maximum vent period of 72 hours with a maximum vent volume during that period of 6 MMCF of inethane gas. This volume is minimized due to the utilization of the Excape completion process which enables all intervals of interest to be fracture treated on the same day and unloaded together at one time, instead of multiple frac days with multiple flowback periods each requiring the venting of gas. If you have any questions regarding this gas venting request, please get in touch with the contact person indicated on the Form 10-403. ~ ~: 50-133-20484-00-00 ~erty Des: ADL 2497 21' AGL (245' KB Elevation) 314, 742.19 2,390,034.43 60° 32' 14.914" N ~151°01'51.643"W ~: 09:00 hrs 7/07/2007 ;eached: 7/20/2007 Released: 6:00 hrs 7/27/07 Tree cxn = 4-3/4" Otis Toq of Cement (MD) 600' above 9-5/8" window - Ceramic flapper valves below each module as follows: Flappers MD (RKB): Module 1 - NA Module 2 - NA Module 3 - 10,211' Module 4 - 10,167' Module 5 - 10,042' Module 6 - 9,941' Conductor 20" K-55 133 ppf PE T~ Bottom MD 0' S8' ND 0' S8' SurFace Casina 13-3/8" K-55 61 ppf BTC To~ Bottom MD 0' 2,271' ND 0' 2,270' Cmt w/ 1186 sks of Class G, Intermediate Casing 9-5/8" L-80 40 ppf BTC To~ Bottom MD 0' 6,281' ND 0' S,615' Cmt original well w/ 2284 sks of class G. Milled Sidetrack window 6,281' - 6,293' MD Production Tubinq 3-1/2" L-80 9.3 ppf EUE T~ Bottom MD 0' 11,632' ND 0' 9,499' 8rd with 6.25" OD control line protectors. 8-1/2" hole, Cmt w/ 545 sks (176 bbls) 13.5 ppg Class G cmt lead and 1456 sks (300 bbls) 15.8 ppg Class G cmt tail. - 6 Excape modules placed - Green control line for bottom 2 module - Red control line for top 4 modules - Ceramic flapper valves below each module except for modules 1& 2. Perfs MD (RKB) (Beluga/Tvonek Zonesl: Module 1 - 11,479' - 11,527' (Tyonek) Module 2 - 10,571' - 10,581' (Beluga) Module 3 - 10,201' - 10,211' (Beluga) Module 4 - 10,157' - 10,167' (Beluga) Module 5 - 10,031' - 10,041' (Beluga) Module 6 - 9,930' - 9,940' (Beluga) TD - 11,655' (MD) / 9,517 (TVD) PBTD - 11,585' (MD) / 9,460 (TVD) Well Name & Number: SU 41-15RD Lease: Sterling Gas Field County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Perforations (MD): 9,930' - 11,527' Perf (TVD): 7,965' - 9,408' Angle/Perfs: 25 deg Angl e Q KOP and Depth: BHP: BHT: Completion Fluid: 6% KCL Dated Completed: Ground Level (MSL): 224' Prepared By: Craig Meese Last Revison Date: 7/30/2007 SU 41-15RD Pad 43-9 2327' FSL, 437' FEL Sec. 9, T5N, R10W, S.M. 7/30/2007 8:47 AM ~ ~ ~ ~ ~ a SARAH PAUN, GOVERNOR ~ ~~ Q~ ~D ~~ 333 W. 7thAVENUE, SUITE 100 CO~L+~1R~'~-~O1~T ~O~rII<+L+IO~ ANCHORAGE,ALASKA 99501-3539 Willard Tank ~'r~ " " PHONE (907) 279-1433 FAX (907) 276-7542 Advanced Senior Drilling Engineer Marathon Oil Company 3201 C. Street, Suite 800 Anchorage, AK 99503 Re: Sterling Gas Field, Sterling Pool, SU 41-15RD Marathon Oil Company Permit No: 207-088 Surface Location: 2327' FSL, 437' FEL, SEC. 9, TSN, R10W, S.M. Bottomhole Location: 474' FNL, 4194' FWL, SEC. 15, TSN, R10W, S.M. Dear Mr. Tank: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval requixed by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Under separate cover, you have requested two employ one pipe ram rather than the two required when the calculated maximum anticipated surface pressure exceeds 3000 psi. There is insufficient height under the rig to allow employing two pipe rams. An exception to the requirements has been granted previously to allow drilling and equipping wells with the Excape system. Your request is approved as allowed by 20 AAC 25.035 (h) (1). Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revoca ' n r suspension of the permit. When providing notice for a representative of the C mi sion to witness any required test, contact the Commission's petroleum field ins ecto at (907) 659-3607 (pager). DATED this .~day of June, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. • • M Marathon MARATH~N Oil Company June 19, 2007 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Ave, Suite 100 Anchorage, AK 99501 Reference: Drilling Permit Application - Re-Drill SU 41-15 Permit No: 98-41 Field: Sterling Field Well: SU 41-15RD Dear Mr. Norman Worldwide Drilling North America P.O. Box 3128 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 ~~~~~ V ~~ ~u~v ~ ~ ~~a~ ~I~sk~ ~lii ~ G~~ ~an~, ~'~r~~s~ian Aii~har~~e Enclosed please find the PERMIT TO DRILL application, along with the associated attachments and filing fee of $100. The intent is to sidetrack out of the existing wellbore at SU 41-15 and drill a Beluga / Upper Tyonek pool well in the Sterling Field, utilizing an EXCAPE completion. No completion is desired in the Sterling pool. Please note that the surface coordinates for this well and the directional plan are now utilizing North American Datum 1983 (NAD 83) as required in the latest BLM 43 CFR Part 3160, Onshore Order No. 1, dated March 7, 2007. On the PERMIT TO DRILL we have included surface coordinates in NAD 27 in order to allow the commission to put the well in their database. All other attachments reference NAD 83. If you require further information, I can be reached at 713-296-3273 or by e-mail at wjtank@ marathonoil.com. Sincerely, C~~~e~ ~--i wTT Willard J. Tank Advanced Senior Drilling Engineer Enclosures (~ ~''~"~ ~ ,~,D R~~~~~/`~C~ STATE OF ALASKA ALAS4W OIL AND GAS CONSERVATION COMMI -ION ~: PERMIT TO DRILL ~~~ ~~~~ 1 g 2007 20 AAC 25.005 ~lask~ ~~~ ~ uas Gons. C~r~mi$sion 1a. Type of Work: Drill ~ Redrill Q Re-entry ~ ib. Current Well Class: Exploratory ~ Development Oil ~ Stratigraphic Test ~ Service ~ Development Gas Q Multiple Zone Q Single Zone ~ ic. Specify if well is proposed for: fYC (~T3~+E Coalbed Methane ~ Gas Hydrates ~ Shale Gas ^ 2. Operator Name: Marathon Oil Company 5. Bond: Blanket Q Single Well ~ Bond No. 5194234 11. Well Name and Number: SU 41-15 RD 3. Address 3201 C. Street, Suite 800, Anchorage, AK 99503 6. Proposed Depth: MD: 11,634 TVD: 9,495 12. Field/Pool(s): Sterling Field 4a. Location of Well (Governmental Section): Surface: 2,327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. 7. Property Designation: ADL 2497 Beluga/Upper Tyonek Pool Top of Productive Horizon: 115' FNL, 3,641' FWL, Sec. 15, T5N, R10W, S.M. 8. Land Use Permit: 13. Approximate Spud Date: Jul 2, 2007 Total Depth: 474' FNL, 4,194' FWL, Sec. 15, T5N, R10W, S.M. 9. Acres in Property: 2,471.60 14. Distance to Nearest Property: 137 ft 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 314,742.189 y- 2,390,034.428 Zone - 4 10. KB Elevation (Height above GL): (21' AGL) 245 feet 15. Distance to Nearest Well Within Pool: 475 ft to SU 41-15 16. Deviated wells: Kickoff depth: 6,275 feet Maximum Hole Angle: 57.43 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5,332 Surface: 3,038 18. Casing Program: Specifications To p - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 1/2" 3 1/2" 9.3 L-80 EUE - 8rd 11,613' 0' 0' 11,634' 9,495' 2,259 sacks 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): 12,600 (Old KB 254') Total Depth TVD (ft): 10,559 (Old KB 254') Plugs (measured): 9,850 (Old KB 254') Effect. Depth MD (ft): 9,850 (Old KB 254') Effect. Depth TVD (ft): 8,198 (Old KB 254') Junk (measured): N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 58' 20" Driven 58' 58' Surface 2,241' 13 3/8" 1,186 sacks 2,271' 2,270' Intermediate 10,282' 9 5/8" 2,284 sacks 10,312' 8,544' Production Liner 2,482' 7" 708 sacks 12,590' 10,550' Perforation Depth MD (ft): 9,440' - 10,942' (plugged) Perforation Depth TVD (ft): 7,905' - 9,054' (plugged) 20. Attachments: Filing Fee Q BOP Sketch Q Drilling Program Q Time v. Depth Plot ~ Shallow Hazard Analysis ~ Property Plat Q Diverter Sketch Q Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Willard J. Tank Title Advanced Senior Drilling Engineer ~ Signature ~ wJ7- Phone 713-296-3273 Date June 19, 2007 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ~°'~ ~ 50•~~:~lf.f(~l~.Q/ QD Date: , -(~ requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, g s hydrates, or gas contained in shales: Other: Samples req'd: Yes~ No~ Mud log req'd: Yes~ No[~ ~(1~ ~S~ ~~~ ~~~ HZS measures: Yes~ No[~] Directional svy req'd: Yes~ No~ '.~. ~~~. cR~ ~. ~. ~~c~'t-t~.dj\~ , 7'~ ~ t~L -~~ ~C~3 ~ 1,~~ ~,1~ . APPROVED BY THE COMMISSION DATE: ~` Z ~~~ , COMMISSIONER Form 10-401 Revised 12/2005 p R{ G I N A L Submit in Duplicate ~ Sll 41-15RD Drilling Program fViara4hon Oil Company Alaska MARATHON OIL COMPANY DRILLING PROGRAM Sterling Field SU 41-15RD Originator: Will Tank Reviewed by: Pete Berqa June 19. 2007 Date Date Brian Rov Date ~ 6/19/2007 ~~~h1~IL7~ht~'[1~~,,, i`~lA,°f`~F~~~E,. Page 1 of 17 SU 41-15RD • ~ Marathon Oil Company Drilling Program Alaska TABLE OF CONTENTS 1. Emergency Response Information ................................................................................................................ ..4 1.1 Directions to Location .................................................................................................................................... ..4 1.2 Rig Contact Numbers .................................................................................................................................... ..4 1.3 Marathon Emergency Response Contacts ................................................................................................... .. 4 1.4 Outside Emergency Response ..................................................................................................................... .. 4 1.5 Marathon Contact List ................................................................................................................................... .. 5 2. Regulatory Agency Contacts ......................................................................................................................... .. 5 2.1.1. Internal Regulatory Contact .......................................................................................................................... .. 5 2.1.2. External Regulatory Contact ......................................................................................................................... .. 5 3. Regulatory Compliance ................................................................................................................................. .. 5 4. Drilling Program Summary ............................................................................................................................ ..6 4.1 General Well Data ......................................................................................................................................... .. 6 4.2 Working Interest Owners Information ............................................................................................................ .. 6 4.3 Geologic Program Summary ......................................................................................................................... ..6 4.4 Summary of Potential Drilling Hazards ......................................................................................................... .. 7 4.5 Formation Evaluation Summary .................................................................................................................... .. 7 4.6 Drilling Program Summary ............................................................................................................................ ..8 4.7 Casing Program Summary ............................................................................................................................ ..9 4.8 Casing Design ............................................................................................................................................... .. 9 4.9 Calculation of Maximum Anticipated Pressures (MAWP and MASP) ........................................................... 10 4.10 Casing Test Pressure Calculations ............................................................................................................... 11 4.11 Blowout Prevention Equipment, Testing and General Procedures ............................................................... 11 4.11.1. Function Testing ........................................................................................................................... ................. 11 4.11.2. Pressure Testing ........................................................................................................................................... 12 4.12 Wellhead Equipment Summary .................................................................................................................... 12 4.13 Directional Program Summary ...................................................................................................................... 12 4.14 Directional Surveying Summary .................................................................................................................... 13 4.15 Drilling Fluid Program Summary ................................................................................................................... 14 4.16 Drilling Fluid Specifications ........................................................................................................................... 14 4.17 Solids Control Equipment .............................................................................................................................. 15 4.18 Cement Program Summary ........................................................................................................................... 15 4.19 Bit Summary .................................................................................................................................................. 16 4.20 Hydraulics Summary ..................................................................................................................................... 16 4.21 Formation Integrity Test Procedure ............................................................................................................... 16 6/22/2007 Page 2 of 17 ~ ~ SU 41-15RD Marathon Oil Company Drilling Program Alaska ~~~~~ ~~ ~~~~~~~~ 1. Emergency Response Inforrnation .......................................... :: 4 1 1 ...................................................................... Directions to Location . ~.2 ............................................................................................................................ ........ Rig Contact Numbers 4 ....................................................................................................................... .............. 4 1.3 Marathon Emergency Response Contacts ..................:............................................................. ................... 4 1.4 Outside Emergency Response ...e ..............................:.......................................................... ........................ 4 1.5 Marathon Contact List ...................................................................................................... :............................ 5 2. Regulatory Agency Contacts ....................................................... . . . 5 2.1.1. ... .. ......................... . ................................ Internal Regulatory Contact .......e ............................................................................. ...................................... 5 2.1.2. External Regulatory Contact ........................................................ . . 5 3. .. .. ................. .......................................... Regulatory Compliance 4. ................................................................................... :.............................................. Drilling Program Summary 5 4 1 .........................................................................; . .................................................. General Well Data 5 . ................................................................................... ...................................................... 5 4.2 Working Interest Owners Information ................................................. ................... 5 4.3 ..o.................................... Geologic Program Summary ............................................................ .............................................................. 5 4.4 Summary of Potential Drilling Hazards .............................. . .... . ............ 5 4.5 Formation Evaluation Summary ....................... ~. ~. .... .~51.. .................................................... .. .. . .. . ..... . 5 4.6 ~ Drilling Program Summary ..................... ......~- .. ..... . ............. ,........ ..........,.,.. ..._ .. ~ ......................................... 5 4.7 Casing Program Summary ................................................ . ...................................... ..................................... 5 4.8 Casing Design ................................................................ .........................................................:...................... 5 4.9 Calculation of Maximum Anticipated Pressures (MA and MASP) ............................................................. 5 4.10 Casing Test Pressure Calculations ......................... .:..................................................................................... 5 4.11 Blowout Prevention Equipment, Testing and Ge ral Procedures ................................................................. 5 4.11.1. Function Testing ............................................... ............................................................................................. 5 4.11.2. Pressure Testing ........................................... ::............................................................................................... 5 4.12 Wellhead Equipment Summary ................ :................................................................................................... 5 4.13 Directional Program Summary ............... ........................................ .. 5 4.14 ... .......................................................... Directional Surveying Summary .......... ........................................................................................................... 5 4.15 Drilling Fluid Program Summary ...... ............................................. . 5 4.16 ... ............................................................. Drilling Fluid Specifications .......... ......................................... 5 4.17 ........................................................................ Solids Control Equipment 4.18 .......... ..................................................................................................................... Cement Program Summary ... ........................................................................................................................ 5 5 4.19 Bit Summary ....................... ........................................................................................................................... 5 4.20 Hydraulics Summary ....... ......................................................... 5 4.21 ..................................................................... Formation Integrity Tes rocedure ................................................................................................................ 5 6/19/2007 t~`~~i'~~I~~ !; ~k~ Page 2 of i7 ~ SU 41~i5RD Drilling Program ~ f~arathon Oil Company Alaska QttlC~lt11~11#S Grou Attachment Attached Commercial Information AFE Da s/Cost vs. De th Curves X Pro'ect Objectives and Scorecard RSO Codin Information X Re uisitions Vendor List Bonus Pro ram Drillin Contract Re ulato / HES Information Emer enc Evacuation Plan X H2S Contin enc Plan n/a Re ulato Permits X Re ulato Rules and Re ulations Risk Anal sis Miscellaneous Pro rams (Vendors) Bit Proposal X Cement Pro osal X Directional Plan X Fluids Pro ram X Wellhead E ui ment - Descri tionlDrawin s Drill Strin and BHA Summa Ri Mobilization/Moorin Procedure n/a Geoio ical Information Location Ma w/ offsets X Offset Data Pro osed Formation Pore Pressure, Mud Wt & Fracture Gradient X Tem erature Curves Geolo ic Structure Ma s Geolo ic Cross Section Bath met Map n/a Anal sis Riser Anal sis n/a Station Kee in Anal sis - Moorin /DP n/a Stress Check Casin Desi n File X Maximum Allowable Over ull Miscelianeous Information Wellbore Dia ram n/a Ri Elevations X Well Location Dia ram X BOP Schematic X BOP Well Control Brid in Document Detailed Casin S ecifications X Detailed Drill Pi e S ecifications 6/19/2007 ~R~1~1~~Ct~El-~~A~ ~f~'~~~tAt Page 3 of 17 • ~ SU 41-15RD Drilling Program 11~arathon Oil Company Alaska 1. Err~erqe~cv Response Information 1.9 Directions to Location Method Directions Air Latitude - 60°32'14.914"N Longitude - 151 °01'51.643"W From the Kenai airport, go 0.4 mile South on fVorth Willow Street. Turn East on Airport Way, go 0.5 miles. Turn East on Kenai Ground Spur Highway and go 7.8 miles. Turn East on Sports Lake Road and go 0.9 miles. Turn North on Conner Road and go 2.5 miles to Sterling pad 43-9. 1.2 Riq Contact Numbers Contact Office Cell Glacier Drilling Rig 1 Inlet Drilling Tool Pusher 907-283-1314 907-394-1321 Marathon Supervisor 907-283-1312 907-394-1317 1.3 Marathon Emerqencv Response Contacts Individual Postion Main Phone Alternative Kenai Gas Field Emergency Number 907-283-6465 CERT 24 hrs Notification 1-800-MOC-CERT CERT Crisis Center Houston 713-296-4230 713-296-4237 1.4 Outside Emerqencv Response Location Contact Phone Fire Kenai / Sotdotna, Alaska 907-262-4792 Ambulance Hospital Kenai / Soldotna, Alaska Central Peninsula Hospital 907-262-4404 Police Kenai / Soldotna, Alaska Kenai Police Soldotna Police State Police 907_2Bg7879 907-262-4455 907-262-4453 Coast Guard 800-478-5555 Spill and Contamination Alaska Alaska State Spill Reporting National Response Center Oil / Toxic Chemical Spills 800-424-8802 Best Practices: 1 Policy: Post emergency notification information on rig floor, company man's and tool pushers' office Comments: 6/19/2007 4;f~t~~l~k~P~'E`i~~. N~~,~~F~B~~ Page 4 of 17 ~ ~ SU 41-15P,D Drilling Program 1.5 Marathora Contact Lost Marathon Oil Company Aiaska Contact Title Office Mobile Facsimile Home Wifl Tank Drilling Engineer 713-296-3273 713-203-8398 713-499-6737 832-934-2617 Pete Berga Drilling Superintendent 907-565-3032 907-529-0551 907-565-3076 907-346-3763 Bryan Roy Drilling Manager 713-296-3256 832-444-4772 713-499-6707 281-246-4686 Jennifer Enos Geologist 713-296-3319 713-408-3583 Moksh Dani Reservoir Engineer 713-296-3140 832-692-4700 Craig Meese Completion Engineer 713-296-2214 713-725-7114 Ken Walsh Production Engineer 907-283-1311 907-394-3060 907-283-3050 John Nicholson Drilling Supervisor 907-283-1312 907-394-2641 907-283-1313 Dan Byrd Drilling Supenrisor 907-283-13i2 907-394-2641 907-283-1313 Mike Feketi Drilling Supervisor 907-283-1312 907-394-2641 907-283-1313 Rowland Lawson Dri~ling Supervisor 907-283-1312 907-394-0953 907-283-1313 2. Requlatorv Aqencv Contacts 2.1.1. Internal Repulatorv Contact Contact Title Office Phone Cetl Phone Home Phone Facsimile Chick Underwood Re ulato Com liance 713-296-3254 979-830-7927 979-836-9390 713-499-6748 2.1.2. External Requlatorv Contact Contact Title Office Phone Facsimile 24 hr Emer enc Pager AOGCC 907-793-1236 BLM 907-267-1442 3. Requlatorv Compliance Regulation Requirement 20 AAC 25.035 e 10 A BOP testing interval requirement is now 14 days. 20 AAC 25.035 e 10 F Requirement for a 24 hour notice to AOGCC prior to BOP test. C0111i11@f1tS 6/19/2007 f~~,~N~IC~~~~ ILVk, i~16~c~'~Ft~~k, Page 5 of 17 ~ . SU 49 -15RD Drilling Program Marathon Oil Company Alaska 4m Drillinq Proqrarn Surnrnarv 4.1 General Well Data Well Name SU 41-15RD Lease / License Surface Location 2,327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. WBS Code DD.07.15067.CAP.DRL SlobPad Sterling Pad 43-9 Field Sterling Field Spud Date 07/02/07 (est.j KB (above MSL) 245' County/Province Kenai Peninsula API No. GL (above MSL) 224' State / Country Alaska Permit No. Perm. Datum KB Total MD 11,634' Well Class Development Water Depth N/A Total TVD 9,495' Rig Contractor Glacier Drilling Water Protection Depth Rig Name Glacier Rig 1 Best Practices: 1 Commentse 4.2 Workinq Interest Owners Information Compan Workin Interest Address Phone Facsimile Marathon 1 ppq, P.O. Box 196168 g07-561-5311 907-565-3076 Anchora e, AK 99519-6168 4.3 Geolopic Proqram Summarv Surface Location Coordinates - NAD 83 From Lease/Block Lines 2,327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. Latitude 60° 32' 14.914" N Longitude 151° 01' 51.643" W UTM North (Y) 2,389,795.70' UTM East (x) 1,454,762.52' Tolerance Formation MD - RKB (ft) TVD - RKB (ft) Pore Pressure (psi) Pore Pressure (ppg) Lithology Possible Fluid Content Beluga (Primary Target) 6,309 5,635 5.8 - 8.5 Sandstone Gas Lower Beluga (Primary Target) 10,073 8,080 8.5 Sandstone Gas Tyonek (Primary Target) 11,038 8,955 8.5 - 10.8 Sandstone Gas 6/19/2007 ~:.,~[VF!(~~~7~fAi~ N~~T~l~1~1~ Page 6 of 17 ~ SU 41-i5RD Drilling Program ~ Marathon Oil Company Alaska Depth (KB) Horizontal Displacement (ft) Target MD (ft) TVD (ft) Location +N/-S (Y) +E/-W (X) Tolerance (ft) Lower Beluga 10,073 8,080 115' FNL, 3,641' FWL, Sec. i5, T5N, R10W, S.M. -2,442 4,078 Circle 200' radius l"yonek 11,038 8,955 337' FNL, 3,983' FWL, Sec. 15, TSN, R10W, S.M. -2,664 4,420 Circle 200' radius TD 11,634 9,495 474' FNL, 4,194' FWL, Sec. 15, T5N, R10W, S.M. -2,801 4,631 Circle 200' radius 4.4 Summarv of Potential Drillinp Hazards Hazard Event Depth KB Discussion Precautions (TVD) Lost Circulation in Upper Beluga Production Control losses by using sufficiently sized LCM, Take care not to surge the hole during sands Hole including fibrous and calcium carbonate types. tripping operations. High pore pressure in Tyonek sands Production Control pressure by weighting material Watch for pit gains as we approach the Hole . Tyonek to prevent a significant gas l~ick. Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the driller's 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 +/- 6,275' MD (5,611' TVD) to total depth of the well. These sands will run from slightly depleted to above normal pressure. Lost circulation and differential sticking are potential hazards in some of the Beluga sands. Above normal pore pressure with associated gas entry are a potential hazard in the Tyonek. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materiais will be on location. Weighting material will available on location for proper well control. Best Practices: 1 Comments: 4.5 Formation Evaluation Summarv Interval LWD Electric Logs Mud Logs Surface / Intermediate (Existing) None None None Sidetrack Production 6,275' -11,634' MD None Reeves Quad Combo. Pull GR-Neutron to surface. Basic with GCA, shale density, temperature in and out, sample collection (10' samples). Completion N/A GR, CCL, CBL N/A Comments: 6/19/2007 ~.~IN~i~~i'~TN~L ~/l~T~F~IA,L Page 7 of 17 SU 41-15RD ~ ~ Marathon Oil Company Drilling Program Alaska 4.6 Drillinq Proqram Summarv WELLBORE PREPARTION: (See abandonment procedure for details) 1. Glacier 1 will already be rigged up over the well. The 2 3/8" tubing will have been pulied, the perforations will have been cement squeezed, and the 7" casing will have been cut above the tubing anchor and permanent packer and will have been pulled. 2. Test BOP to 250/3,500 psi. Set wear bushing. 3. PU 9 5/8" bridge plug and TIH, setting at approximately 6,293' MD. 4. MU and RIH with bottom trip whipstock. RU and run MWD to set whipstock for - 45° left of highside tool face orientation. Cut window and ensure that all mills are worked thru window. CBU and perForm FIT at KOP to -- 15.0 ppg Best Practices: 1 Comments: Production: Drill 8 1/2" hole to +/- 11,634' set 3-1/2" EXCAPE string. 1. PU 8 1/2" bit and directional BHA. 2. Drill 8 1/2" hole to an anticipated TD of 11,634' MD (9,495' ND) as per the directional program, short tripping as required. 3. At TD circulate hole clean. Make wiper trip. TOOH. 4. RU Precision. Run open hole logs as per plan. RD logging company. 5. TIH w! 8 1/2" bit to TD for wiper trip. TOOH back through the 9 5/8" window and circulate until log evaluation is complete for picking EXCAPE modules. After picks are made, trip to TD and circulate clean. TOOH and lay down BHA and drill pipe. Pull wear bushing. 6. RU and run 3 1/2" EXCAPE casing string. RU logging company to correlate EXCAPE modules to open hole logs. RD logging company. 7. Cement 3 1/2" casing while reciprocating. Bump plug with 500 psi over displacement pressure. WOC. 8. , PU 3 1/2" casing. PU BOP stack. Make control line and electric line connections to tubing bonnet assembly. Set slips. Cut 3 1/2" casing. 9. LD BOP. Set 3 1/2" packoff. NU 11" 10M X 3 1/16" 10M tubing head adapter and 3 1/16" 10M tree. Test tree to 5,000 psi. 10. Rig down and move out drilling rig. Nofe: Drilt the production hole section with 4" drillpipe. Perforating guns will be run on the outside of the 3 1/2" production casing with a flapper valve just below each perForating gun. Guns to be activated by control line to surface. Best Practices: 1 Drill the production hole section with 4" drillpipe due to the rig's top drive limits on torque. 2 Do not circulate on bottom longer than 1 hour prior to moving pipe on a short trip to minimize hole washout. This is important when waiting on log analysis to give EXCAPE module placement points. 3 Plan on using the Anderguage Agitator for better slide drilling. 4 Put lubricant in prior to drill out of intermediate window. 5% Lubetex is normally required, possibly more depending on solids in the mud. Comments: Completion: Completion will be done without a rig. Best Practices: 1 Comments: 6/22/2007 7.:~Mi ~ '~? i ~.Q ~ 0.'~ \ \ ~ ~:'r~ l Page 8 of 17 ~ SlJ 49-15RD Drilling ('rogram 4.7 Casinq Proqrarn Surnmarv ~ Marathon Oil Gompany Alaska MD (ft) Connection API Ratings Casing Size (in) Top Bottom Weight (Ibs/ft) ID (in) Drift (in) Grade Type O. D. (in) Makeup Torque (ft-Ibs) Hole Size (in) i,N m 8 Q~ 0°~ U o~, ~ s ~ (Old KB = 254') 20 0 58 K-55 12.515 12.359 13 3/8 0 2,271 61 K-55 8.535 8.500 " BTC 14.375 N/A ` 17 1/2 3,090 1,540 1,169 9 5/8 0 3,038 53.5 P-110 8.681 8.525 BTC 10.625 N/A ` 12 1/4 10,900 7,930 1,718 9 5/8 3,038 9,866 47 P-110 8.681 8.525 BTC 10.625 N/A' 12 1/4 9,440 5,310 1,500 95/8 9,866 10,312 47 L-80 6.184 6.059 BTC 10.625 N/A' 121/4 6,870 4,750 1,161 7 10,108 12,590 29 L-80 12.515 12.359 BTC 7.656 N/A " 81/2 8,160 7,020 746 Glacier KB = 245' 31/2 0 11,634 9.3 2.992 2.867 L-80 8rd 4.5 3,200 81/2 10,160 10,530 207 Best Practices: 1 Have float equipment made up at Tubescope's yard prior to bringing casing to location. Buck on all equipment to the pin end and not make up to box below, due to rig height restrictions. 2*~ IVlake up buttress connection to proper mark, not to a torque valuea Comments: 4.8 Casinp Desiqn Casing Shoe Safety Factors Casing Size (in) Weight (Ib/ft) rade Setting Depth TVD (ft) Mud Wt When Set (Ib/gal) Frac. Grad (Ib/gai) Form Press (Ib/gal) Maximum Surface Pressure (psi) ~ m Q o U o ~ ~ (Old KB = 254') 13 3/8 61 K-55 2,270 Existing Casing String 9 5/8 53.5 / 47 P-110/L-80 8,544 F~cisting Casing - N/A 3,038 Existing Casing - N/A 7 29 L-80 10,550 Existing Casing Liner, Plugged Glacier KB = 245' 31/2 9.3 L-80 9,495 11.0 17.7 10.8 3,038 1.15 1.94 1.30 Comments: Maximum overpull on the full string of 3 1/2" production casing needs to be limited to 84,000 Ibf to avoid parting the pipe. 6/19/2007 ~(~~`~~i~~~NTR~~., ~~TE~B~4~ Page 9 of 17 SU 41-i5RD Drilling Program ~ ~ Marathon Oil Company Alaska 4.9 Calculation of Maximurn Anticipated Pressures (IIAAWP and MASP) Casing Size (in) Setting Depth TVD (ft) MAWP' (psi) MASP'* (psi) Mud/Gas Percentage 13 3/8 2,270 Not applicable, 13 3/8" production casing is already in place. 9 5~$ 8,544 4,517 3,038 30/70 7 10,550 Not applicable, 7" casing liner has been plugged and abandoned. 3 1/2 9,495 7,112 3,038 30/70 iviHVVr = nnaximum allowable working pressure "" MASP = Maximum anticipated surface pressure The calculation method for MASPBHP has been modified from the standard AOGCC use of a Bottom Hole Pressure - 0.1 psi/~t gas gradient to what Marathon considers a more accurate ~ottom Hole Pressure - 30% Mud Column - 70% Gas Column. This method follows the MMS standard for any well with a TVD of 12,000' or less. Marathon believes that constant gas monitoring and proper rig supervisor well control training will prevent the possibility of a wellbore laeing completely evacuated with only a gas gradient remaining. Intermediate casinq: 9 5/8" (6 275' (VID 5 611' TVDI IVIASPfrac =((FCac#uYe gI'adient ~t shoe) x.052 x TVDsnoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac =(15.0 ppg X.052 x 5,611') -(0.1 psi/fi x 5,611') MASPfrac = 4,377 psi - 561 psi MASPfrac = 3,816 psi. MASPbnP = BHPape„ noieta - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbnP =(10.80 ppg x.052 x 9,495') -(0.3 x 11.0 ppg x.052 x 9,495') -(0.7 x 0.1 psi/ft x 9,495') MASPbnP = 5,332 psi -1,629 psi - 665 psi ~ a MASPbhP = 3,038 psi ~t~~ ~C,a'7 '~J~ ~ - ~~~~ ~S ~ MASP = MASPbnP = 3,038 psi ~~~~ ~,~~~ MAW P=(0.7 x Casing Burst) -(Mud Wt. - Backup Fluid Wt.) x.052 x TVD MAWP =(0.7 x 6,870) -(11.0 -10.0) x.052 x 5,611' MAW P= 4,809 psi - 292 psi = 4,517 psi Production casinq: 3 1/2" (11 634' MD 9 495' TVD) MASPf,a~ _((Fracture gradient at shoe) x.052 x TVDsnoe) - Hydrostatic pressure of gas column at the shoe. MASPfrac =(17.7 ppg x.052 x 9,495') -(0.1 psl/ft x 9,495') MASPfrac = 8,739 psl - 950 pSi MASPfrac = 7,789 psl. MASPbnP = BHPoPe~ noieca - Hydrostatic pressure of mud portion - Hydrostatic pressure of gas portion MASPbnP =(10.80 ppg x.052 x 9,495') -(0.3 x 11.0 ppg x.052 x 9,495') -(0.7 x 0.1 psi/ft x 9,495') MASPbnp = 5,332 psi -1,629 psi - 665 psi MASPbnp = 3,038 psi MASP = MASPbnp = 3,038 psi MAWP =(0.7 x Casing Burst) -(Mud Wt. - Backup Fluid Wt.) x.052 x TVD MAWP =(0.7 x 10,160) -(11.0 - 11.0) x.052 x 9,495' MAWP = 7,112 psi - 0 psi = 7,112 psi 6/19/2007 g`;:(.~~~~~}~N°~Ipl- ~,~lT'~F~V~s~. Page 10 of 17 SU 41-15RD Drilling Program ~~S# ~P1CtICeS: ~ C0171 i71 G'iltS: • ~ 4010 Casinq Test Pressure Calculations Marathon Oil Company Alaska Casing test pressure calculations are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used durirrg the test less a 8.3 ppg back-up unless otherwise noted. AOGCC regulations state that casing pressures must be 50% of the BOP working pressure documented on the approved permit to drill. Best Practices: 1 Comments: 4.11 Blowout Prevention Eauipment, Testinq and General Procedures BOP PROGRAM Casin g Test Test Casing Test Fluid Pressure Size MAWP MASP , press Density BOPS Low/High Casing (in) (psi) (psi) (psi) (Ib/gal) Size & Ratin 9 (psi) (1) 13-5/8" 5M annular Intermediate 95/8 4,517 3,038 1,500 9 ~ ~i) 13-5/8" 5M pipe ram 250/3,500 (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets (1) 13-5/8" 5M annular Production 3 1/2 7,112 3,038 1,500 1~ ~ ~~) ~3-5/8" 5M pipe ram 250/3,500 (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-1/8" 5M outlets 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 and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets. 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 mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. 4.11.1. Function Testinq Function Regularly. 6/19/2007 C,~~fVl~{l:~~~~`1~1~ Idi(~t'Tl~~i~k. Page 11 of 17 • ~ SU 41-95RD Drilling Program 4.11.2, Pressure Testinq Marathon Oil Company Alaska The Marathon Drilling Supervisor will verify all pressure tests of BOP's, surface lines, seals, casings and FIT or LOT tests. All tests are to be recorded on the IADC and daily drilling reports. Best Practiceso 1 Comments: 4.12 Wellhead Epuipment Summarv Component Description Casing Hanger Type Casing Head 13-5/8" 5M X 13-3/8" Slip-On Weld 13 5/8" x 9 5/8" Manual Slips Tubing Head 11" 5M X 13-5/8" 5M 11" x 7" Mandrel Hanger Tubing Spool 11" 10M X 11" 5M 11" x 2-3/8" Mandrel Hanger Adapter Flange 11 ° 5M X 2 1/16" 10M W/ Seal Pocket and 3" H BPV Threads Best Practices: 1 Comments: Control lines and electric cable for the EXCAPE system will be routed through the adapter flange ports. 4.13 Directional Proqram Summarv Build Turn Coordinates Sec. (Vo. Description MD (ft) TVD (ft) Rate (°/100') Rate (°/100') Dogleg (°/100') Inclination (deg) Azimuth (deg) +N/-S ~ft~ +E/-W ~ft~ VS (ftj 1 Tie On / KOP 6,275.00 5,611.06 0 0 0 43.129 124.973 -1,132.88 1,595.55 1,951.55 2 6~[~Y~i,z>_~:i~::~~_:l•~ Sectrt~r, 8.61 -12.03 12.00 3 End of Build 6,295.99 5,625.45 8.61 -12.03 12.00 44.851 122.567 -1,140.59 1,607.09 1,965.42 4 ~~ri1c~ ;i}i S~~:ti~rr 2.84 -1.17 3.00' 5 End of Build 6,742.70 5,905.94 2.84 -1.17 3.00 57.428 116.477 -1,310.46 1,910.39 2,312.85 6 ~~'}~~~-~~~X~~}r? 0 0 0 57.428 116.477 7 End of Hold 8,205.74 6,693.58 0 0 0 57.428 116.477 -1,860.14 3,014.00 3,541.66 8 tn ~~ .-~:_~ ir_u t -1 J2 0.69 i.75 9 End of Drop 10,072.81 8,080.00 -1.72 0.69 1.75 25.000 123.000 -2,441.61 4,078.07 4,753.07 10 TD 11,634.09 9,495.00 0 0 0 25.000 123.000 -2,800.98 4,631.45 5,412.56 6/19/2007 ~;C~~[~I~,l~h!°TI,A~,. ~/i/~°~~Fil~~. Page 12 of 17 i • SU 49-15R~ Drilling Program Marathon ~il Company Alaska zo° 0 ,oao 9000 zooo 0 ~ 3000 ~ _ o ~ p 4000 O ~ ~-1000 ~ ..~ Q 5000 + t ~ 6000 ~ ~ z-2000 ~ 7000 r ~ ~ 0 ~ 8~~~ ~ -3000 9000 10000 -4000 -2000 -9000 0 1000 2000 3000 4000 5000 6000 7000 0 1000 2000 3000 4000 Vertical Section at 121.16° (3000 ft/in) West(-)/East(+) (1500 ~n) Comments Verticai section calculated from a reference azimuth of 121.16° taken from surface location to bottom hole location. Potential Well Interference: Well Distance (ftl Depth (MD) SU 43-9 2,038.87 6,275 SU 32-9 3,525.41 6,275 SU 43-9X 4,522.20 6,275 Except for exiting the existing wellbore, SU 41-15, no serious interference exists. See attached directional plan and anticollision analysis for more details. Best Practices: 1 Comments: 4.14 Directional Survevinq Summarv Interval MD (ft) MWD Survey Magnetic Multishot Gyro Multishot Other Survey Remarks Tool Surface / Use existing MWD Intermediate 0- 6,275' surveys, set whipstock with MWD tool. Production 6,275' - 11,634' X Best Practices: 1 ~-.- -- ~ ~ ~ ; i ~ ;I ~ 'i T , - ~ ~ i = ~ r ~ , ~~ - -- ~ r - i i~ ~ ~ - _ j~ ~ ; . i ~ ~ ~ . '; ___~ -- ~ .._i i f ;- -~- ~ ~ -- ~! ~ 933/8 ;- l, ~ - I - - ~ , -- ~~ ~ ~ - ~ ~ ~ -- ' ; ~ ~, - ~ ~ - I - I- - ~ ~_ 3 i I - i I ' _ _ - I ~ , I I u - --- I_ ; I 1 i ~ i __ + ~ i_ .._ __.~ I ~ I ~ I_J ~ i f~ --- -- I ~- t_7 1__ ,- ~ __ - ~~ ~ ~ I _'_ - T j -=- ~ , i ~_ ~i 1 - 1 ~ i ~~ U _~ i- ~, ; - - - -~ i---- ~ -- s ~ ~ ~- ~ i ~ - ~ ~ -- -- ~ J -~ ~ ~- ~ ~ ~ ~ I ~ ~ ~ ~-- ~ --- i -- ~ - -~ 9 5/8' ~- - I I i L i- - ~ ~ ~ t_ I I 1 I ~ J -- --- -- ---_ -- - - - - -- I- - I i_ ~ - - ~ - -- _ ~ - - ~ 7 , -.-_ - -- -- -- --- ! - ~-_- L_ f----- ,- - _ - ~ - - ~- --• - - , L - -- - ' !t _~ --I -- - - __- -- SU41-15RD Lower Bel - _- ,_ - - -_ _ ~ ---i SU D y I ~ ~ I - - -- ---.- -- . - 41-15R ._- ~ ~ ~ ~ ~ ---SU41-15RDT0 -- = -- - - -- - - - - -- -- - - --= - 31 /2 - --- - - i Comments: ; --- ~ ~---- - -- - ~ - , f -- ~ -- , --- f ~- -- - _. _.__ ---__ ____ ,--- , - i --~ -- -; ---- ~ -f ! ~ I , ~ - _.--- ~--- ~ ~' ~_ 1 j - - ~ ~ -+ i ~ - -- -- ~ , --- ~ I- -- - ~ ~ I -- - } - ---- - I , SU 41 -15RD Lowe , r B eluga ' - :, - -- ---- - --- i ~ ------ --- - ~ ---- - - ---- I ~ - - ~ I - ~ --- ~ -I ;- ! -- - ----- -- - - --- --- -- --- ; ~ ---- -- --- ~- -~ --- _~. - --- - I ' SU41-15RDTyon k ~ -- - -- -- - - ----I - ----- - ~ - i SU41-1 5RDTD I ---- --- --~--- - ----- ~-- 6/19/2007 ~.,~1N~I~~~~~`~~~ [~~~EF~E~~. Page 13 of 17 Sl1 41-15FiD Drilling Program i • fVlara4hon Oil Company Alaska 4.15 Drillinq Flraid Pro~rann Sumrnarv Interva l - TVD Minimum Inventory From To Density Gel (ft) (ft) (Ib/gal) Fluid Description Additives Viscosifier Barite 0 5,611 8.45 Milling Fluid Flo-Vis, Sodium Meta Bisulfate Flo-Vis, PolyPac Supreme UL, KCI, SafeCarb, 5,611 9,495 9.1 - 11.0 6% Flo-Pro NT w/ Safecarb Barite, Caustic, Conqor 404, Sodium Meta Bisulfate, LubeYex, Klagard ~eSt PYaCtIC@S: 1 Comments: 4.16 Drillina Fluid Specifications Interval - TVD LSRV Drill From (ft) To (ft) Density (Ib/gal) Vis (sec/qt) 1 min (Ib./100ftz) PV (cP) YP (Ib/100 ft2) Fluid Loss (cc) pH Solids (%) 0 5,611 8.45 30,000 +/- 8- 12 N/A +/- 9.5 N/A 5,611 9,495 9.1 - 11.0 40,000 +/- 12 - 20 6- 8 +/- 9.5 +/- 5 Best Practices: 1 As a standard practice for long string completions, the drilling mud that will remain above the top of cement on the 31/2" production casing will be treated with corrosion inhibitor (Conqor 303A) at a concentration of 1 drum per 100 barrels of drilling fluid. Comments: See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to control leakoff. 6/19/2007 (::~~i~kl[~~~~i~L Ntif~'~~FtiAti~, Page 14 of 57 • • su 41-15RD Drilling Program 4017 Solids Cantrol Equipment Marathon Oil Company Alaska ~ o ~, N N U ~ ~ N ~ 01 ~ C U Y ~ ~ ~ ~ V ~ - ~ ~ ~ c ~ ~ c ~ ~ .c a~i a~i ~ a~i ~ ~ o Interval ~ ~ ~ ~ v v U N Comments 0- 11,634' MD X X X X Closed Loop System, Full Containment, Run shakers with finest screens possible Item Equipment Specifications (quantity, design type, brand, model, flow capacity, etc) Shaker 2- Swaco Mongoose PT Desander N/A Desilter 1- Derrick Model 0522 Mud Cleaner N/A Centrifuge 2 - MI/Swaco units Cuttings Dryer N/A Cuttings lnjection Marathon G&I Facility Zero Discharge N/A Best Practices: 1 Have vacuum trucks pull fiuids from trough above slop pit to more efficiently pull fluids for disposal. This minimizes water added to the solids to suspend for pickup by the trucks, thus minimizing total volume to be disposed of. Comments: 4.18 Cement Proqram Summarv Depth Gauge Top of Cement Gauge Ann Vol Slurry Casing Hole Ann Vol With OH Density Open Hole Thickening Size MD TVD Size MD TVD To TOC Excess Lead/Tail Excess Time ~~~~ (ft) (ft) (~~) (ft) (ft) (n3) (ft3) (PP9) (%) (hrs) 31/2 11,634 9,495 81/2 5,700 5,192 1,942 2,643 15.8 40 N/A Mix Water Compressive Casing Size Density Qty Yield Slurry Vol TOC MD Qty WL FW Strength (pS~) (in) Slurry Cement Description (Ib/gal) (sx) (ft3/sx) (ft3) (ft) (gal/sx) Type (cc) (%) 8 hr 24 hr 3 1/2 Tail Class "G" 15.8 2,259 1.17 2,643 5,700 4.97 Fresh 24 0 226 2,632 ~est Practices: 1 Purnp several fluid calipers at TD to help with the hole volume determination from the open hole caliper log. Comments: See cement prognosis for details and spacer specifications. 6/19/2007 ~C~C~l~1C~~IVTi,~E.: NI~QT`ER~~$L Page 15 of 17 . • Sl) 41-15RD Drilling Program Marathon Oil Company Alaska 4.19 ~it Surr~marv Intenral - MD ~Ype Recommended Estim t d a e From (~t) To (ft) Size (in) Manufacturer Model No. IADC WOB (kips) RPM Rotating Hours Expected Minimum ROP (fUhr) 6,275 11,634 8 1/2 Christensen HCM 605 M323 Up to 25 Motor B@St ~f 1CtICe3e ' Comments: See bit prognosis for additional intormation. Back up bits for the 8~h" hole section will consist of mill tooth and TCI tricone bits. 4.20 Hvdraulics Summarv Qty Make Model Liner ID (in) Stroke (in) Max Press ~ gpo~o Wp (psi) Displacement @ g5% Vol. eff (gal/stroke) Max Rate C 95°/a Vol. eff (spm/gpm) Hole Sections Used On 5 $ 2,597 2.04 125 / 255 Surface 3 National Oil Well A600PT 5 8 2,597 2.04 125 / 255 Intermediate 5 $ 2,597 2.04 125 / 255 Production Est. Hole Pump Standpipe Openhole Nozzle Depth-MD Size Rate Pressure Min AV MW ECD Size ~P at ft ~ ) (i~) (gpm) (psi) (fpm) (ppg) (ppg) (32"s) bit si Remarks (Drill string configuration) 0- 6,275 8 1/2 Abandonment Section - Pump rates will vary based on activity. 6,275 - 11,634 8 1/2 500 217 11 •0 5- 15's Try to maintain 500 gpm or greater. Best Practices: 1 Comments: See separate hydraulics calculations. Annular velocity in the 8 1/2" hole was calculated using 4" drillpipe. 4.21 Formation Inteqritv Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and 4ime after shut-in for 10 minutes or until the shut-in pressure stabilizes. 6/19/2007 ~1C~F-~1~l~f~~'~!~`I,~#~. MA'~'~~i,F~t~, Page 16 of 17 • • SU 41-15RD Drilling Program ~~St PI°aC~lCeS: COf71171@f1fS: fUlaraYhon Oil Company Alaska 6/19/2007 t~f;?~~I~,~~I`~TI~~., ~f{~;TE~t~~:~ Page 17 of 17 • Marathon Oil Well SU 41-15RD BOP Stack Flow Nipple 13 5/8" 5M Annular Preventer -• 13 5/8" 5M Double Pipe Ram Ram Preventer ~~ 2 1/16" 5M . Blind Ram Check Valve 2 1/16" 5M Manually Operated Valves ~~ ~LN-~~-~LJLI~--f~~LJ Kill 13 5/8" 5M Cross ~ Pipe Ram 13 5/8" 5M Single Ram Preventer C~ 3 1/8" 5M Manualiy Operated Valve ~ ~/11IIII I~IIII I 3 1/8" 5M Hydraulically Operated Valve Bottom of Single gate must be 24-45"from groundlevelfor Glacier 1 rig placement. I 13 5/8" 5M x 13 5/8" 5M I Drilling Spool ~ 11 " 10M x 13 5/8" 5M DSA I ~ To Gas Buster X ~ ~~~ ~ X x x ~ ~ 3" 5M Valves 1 2 9/16" 10M Swaco Hydraulically Operated Choke Marathon Oi! Well SU 41-15RD Choke Manifold To Blooey Line X ~ °~~ ~ • Bieed off Line to Shakers X ~ °~~ ~ X ,~ x x 0 0 °°~ x x x I 3 y/8" 5M Manually Adjustable Choke From BOP Stack --- • ~ Operator Certification Field: Sterling Well: SU 41-15RD Surface Location: 2,327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. I hereby certify that I, or someone under my direct supervision, have inspected the drill site and access route proposed herein; that I am familiar with the conditions which currently exist; that I have full knowledge of state and Federal laws applicable to this operation; that the statements made in this APD package are, to the best of my knowledge, true and correct; and that the work associated with the operations proposed herein will be performed in conformity with this APD package and the terms and conditions under which it is approved. I also certify that I, or the company I represent, am responsible for the operations conducted under this application. These statements are subject to the provisions of 18 U.S.C. 1001 for the filing of false statements. Executed this 19"' day of June , 20 07 Name Willard J. Tank l` W~ r ~-~ y-o7 Position Title Advanced Senior Drilling Engineer Address P.O. Box 3128. Houston. TX 77253-3128 Telephone 713-296-3273 Field Representative Pete Berga (Drilling Superintendent) (if not above signature) Address 3201 C Street. Suite 800 Anchorage Alaska 99503 (if different from above) Telephone 907-565-3032 (if different from above) E-mail wjtankCmarathonoil.com (optional) i • Surface Use Plan for Sterling Unit, well SU 41-15RD Surface Location: 2,327' FSL, 437' FEL, Sec. 9, T5N, R10W, S.M. 1) Existing Roads Existing roads which will be used for access to SU 41-15RD are shown on the attached map. Soldotna, 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 SU 41-15RD. 3) Location of existing wells Well SU 41-15RD will be drilled on Sterling Field pad 43-9. A pad drawing is enclosed that shows existing wells and the proposed location of SU 41-15RD. 4) Location of existing and/or proposed facilities The locations of existing production facilities on Sterling pad 43-9 are shown on the enclosed pad drawing. A new flowline will be installed from the existing SU 41-15RD wellhead. 5) Location of Water Supply A water supply well exists on the pad that SU 41-15RD will be drilled from. 6) Construction Materials No major construction is planned on the pad at this time. Leveling of the pad for this work will be done with minimal materials needed. 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 24-7RD, 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 hauled to Pad 41-18 of the Kenai Gas field and injected in Well KU 24- 7RD, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). 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& R will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9) Plans for reclamation of the surface SU 41-15RD will be drilled from an existing pad. Reclamation of the pad will occur after the abandonment of SU 41-15RD and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from Salamatof Native Association prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land in the Sterling Unit is the Salamatof Native Association. NORTH PRWECT ~ ~ a„~ GLO / ~ . ~~NAIN +i+ ~ Tp f QeR~ ~~\c\ sals,o ss ~o 1937 ~~~ TOP ~ =~.~ X=1455203.89 I I ED~E ~ EPM ~='~~ Y=2390102.78 I ~ AD~ ° ~~ I I~ ~ x \ ~ ~ S'TERLIN(~ UN1T DRiLL PAD ~ ~. ~ ~ S.U. 43-9 S&7flOri 9. 7~ RIOW. S,bt TO ~~NNER R~qD ~ ` O I ~ I ~ OO SU 43-9X ~ ~ l~ I ~ ~ I~ I ~ ~ ~~ ~ ~ 437' FEL N S.U. 32-09 O AS-BUILT ~ S.U. 41-15RD I ~ ~ . N= 2389795.70 I = I ~ E=1454762.52 ~ I' ~ Lat:60'32'14.914"N I ~ I N Long:151'01'S1.643"W I ~ ~ ~ N Elev.=224.4' Q I ~ o ' II ( ~ i ~ ~ ^ i~ ') ~a _~~#__ - ~ I _ , _#~~ ~ \ ~ G!0 ~ ~ ~ T5Pl R10W {~~_~.~rs/" - S9+S10 S16 S15 1937 X=1455167.16 --- - _ SECTION LINE Y=2387462.89 S9 S10 NOTE: SECTION LINE5 - NorTOSCn~ S16 S15 NOTES 1. BASIS OF COORDINATES IS NGS STA. AUDRY. NAD83 ALASKA STATE PLANE ZONE 4. 2. BASIS OF VERTICAL CONTROL IS NGS BENCH MARK MONUMENT U 80, ELEVATION = 181.16 FEET (NGVD 29). M MARATHON w~-n~oN ~II. COMPANY . ~n~ ~o~t ConsuLtin ~nC ENGINEERING-TESTINGSURVEYING-MNPPING B P.O. BOX 4B8 30~DOTNA, AK 99869 ~ voice: ~sw~ za3-az~e Fnx: ~eo~~ ze3azss WWW.MCLANECO.CAM ~ SCALE 0 9 W 200 FEET STERLING UNIT PAD SU 41-15RD AS-BUILT ~ocnnoN SURFACE LOCATION DIAGRAM SECTION 9, T5N, R10W,SEWARD MERIDIAN, ALASKA REVISION: WA DATE: 524/07 DRAWNBV: JLW 3~: ,~,~~ PROJECT NO. 07305 BOOK NO. 07-OS SHEET I 1 °F ~ ~ ~ Top of Lower Beluga Str Sterling Field, AK CI = 25 ft 0.25 m i • ~ TOPO! map printed on 04/26/07 1S1"Ub.UUU' VV 151°04.000' W 151°02.000' W 151°00.000' W WG584 150°58.000' W .9 •~,~ ~( 1 ~{ w;; ••t~"q'. ~..~ ..~ t __i ~ , ~ ~ ~~ ~ ~~ `~a~ ~ ~ ~ _ ~; ~'` _ c ~ ~: ~ # ~ ~~ *` _ . ; ,¢ _ ~ ,~ ~.., ~ ~, ~ ~ ~,J~ ~~, ~ : :~ ~~`~ o ~: = ~` ~~ ~ ~ ~~ ~~ ~~ ~ E 33 34 , 35 '~ ~ t "' : F`' ' ~ '~. `- _,~ y/ ~ `';1 I ~ , ' J , tp S- P,..-r~.. h~> .e....r..,.e,~ . .. . ~ .. ~ ... rR .. d~.i. ;~ ~ . ~., ~~ ~C Y 4., .. 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FSt ~ j Sec 9 T 5 N fi 1Q ~fi', S.1~L '~ n ~ ' ~ ~ . ~ °• i l ~ ,~~ } , - -ff a ~ • ~"~ ; ~s M ! ° ,.~ - l s y- ~. ..~ o ~"'' ~4 : ~ ~ f r ° _ . _ - ._. .. , ~i'i~' ' ~ i ~ i ~y, ~ t ~, r~ , ~ ! ' ' •+' ' °"~~,,.~' . _ _ _ :t , ~ ~ ~. . ~ ~.~, _ y .~}8L1~~ _ I' a$' ~_ ;. „s' ~~1S~C,{~v~j/~' ;+~iU~1~eS ~_-~. , -- s .: ~ ~1 ~\ . x>~ ~f' Kenai S ur y 1 v ~ ~ ~. - * ~IGtLtBB v ,~ , v e , ~ . `~. •~ ~. , ~ '~~, i}i! ~t'~ + _ ' ~•?k~ ~ I t 3 ~ ~'~ ` ~~ : ~ xWeO ~ ~' ~ q - =s " ~„ ~9pS ~ " : ~ -a ' ~. ~.~ f1- ~' Ster ' Pad 23-,15 (5 ended Cras Well) ~~ z ~.l y ~ ~ ~ ~ _ nt4J~ ' 1 ~. ~ ' , ~ :, ~ ~ti~iE - . ~ a •:'~~ . °o ~ `~ ;''~, ~ a ~ 1 j~ i: i ~.. ~-' ~~4~' ~`*~~ o ~~ . . ~ 1 _ ~ ~ i ~ n' r'7 F } ~ _ ~ . .* ~,-@ :.' . f.y o ~ ~ ~~.~~s .~~, ~~ ~~ •i .! ~ S~ortsLalxBnad ~~CP~ ~t~~ ~~ ~, ~~. e y~~x'SIti~7a•:, p - _ i' I ~ ~ _ }~ , r-'_ $ .. . ,~ ..'I!' ~ r ' 1 - @~ .~ .~ ~R~i '~ ~ ~~ - . .. .. - ~ t ~ , i ~~ ~ ~ ~ ~ ~ ~ ~~'~ ` a ' v f11 _~,~ . ~ . w ` v~ ~` ~ ~ ~ ii~c~~ ",lR~ ~F'~J~ . '~-yyt~' n~ ~ ~ ~3 ~, ~ ~"'~~~+ + :'~~ G~ ~r :~`ke~ ~ ,~nilP :~~~ -_':~ ~~ _~ ~ ~y~ ~~p~pElklE_ . ~ 1 ,r-~ . ~ t :: ~ :. _.~sm~~c~a-4~..- ' ~Q . . • ~I ~~ ~~~~ '.t~ F •. _-t,...~ _ . ~+4 ~~:. t ~.. _IL,. --'~ ~fdV~ . ~- -- ' 't~ i . . ry ~ ~~~ ~ ` ~ -- ~~ ~ . , - ? ~:' j ~ .:~ ~ ~PitS ~q I . - GO - ~ L~ y _, _ . ~ ~ ! -.x. ; ~`~_ ` '~~~ .~ i ~ ~ ~., N ~.f a i . r - _- ~ .,~. , ~ __ ---- , . <.. _ _ -,,,; - ` ..~ . , . ~ , ~ ~ ~'1 ; ' . 29 . ,~ ~~ Solsiotria , -~,2 ~ ~ ,~ ~ - -.:;J~ ?~ ; D ~ ~ ~~+~-1_` ~~~~' • -~CUR~",~i~lA'fE~~ BDY ., d° _~ ~ r,Cs, ~ I$u65-~f~3 ` ` ~i ~ : . . ~~ :~ , ~- ,~ ~ r_ ~ . ~ .~ .. , ,,~~~~ T . ~, ~ ~~ = ~ ~ ; t ~ i ' s~ j _ "~ .,'~ ~- ~( ~ t,.,.-~ - "[. r ~-.,, ~, ~'-; • ~- a t ,1 ~~ ~ ~"r ~ < ~ ` ~',~o , - • , - - ~S" --t""1a~J`~ . ._ . ~, ~ h~~~ ~r ! ~ i l " ` ~'~ '-~ ' `" n .~#' . • , , + . ;~ • ~Qi~' - ~ ` ~~ , ~ _ ,. / t~ ~ . ~ • f j i i : . . . ~ , ~ ' ~t'~ ~.,a! ` : ~ac,.l"?`~ . _ - ~ `' i r. ~ , y ,r~~ . . ~ , ~ ~ ~: ~ • . ~~ ; .,.. > > P '~' ~Y ~u~!'ta ~ ~j ~,~,'°~~`,,4 ~ ~+;%~ 1% ~ ~ ~ ~[ n i : . ~ • f • ,ti,t~? ` k ~ G /~ - ~`?•~'~,~.`., ~ ~' . ~.? S. i ~ ~ • ~_'.~~ . `~V-~ ~-..~, ~~4~~ -f ~ ': i '~\1y'. .~` "" ~ /. • -~ ~~ -~ -P's-f i i b ~.`~ 1 ~f ~' f J I 1 , ~ Y_-V,P • _ J "_ c"1..~ ~ il ` ~ . ~ ~ ; ~ `; ~~ ti ` ,.; f .. ~ 't,-.--'-fi -~ ---"_' ~ ' ~ , i 3 ; \ ~ iaa ` ~4 `_?~ c, 1 ~ ~- ~ k` • 1Fr i 1 ~" \ ' ~. 32 , ~ ~ ~ , ti -. _. - _ j ; _ ~, ~ " ~ ~~ ;,s~ , _ , .., ... _ _ . ~ ~ ~~~~. _. _ ,~~. , ,- ~ „ , . : - ~ -, -- - - - 4 ~_~,.. +~ '~m~• , ~-~ - ~ ~ T: x __ ~ ~~~ - U~nd~ng ~ ILBIl11, C-: uach:v 61e 4 ~~~'' M1 p.~ed.bvith`Uo° p~pcZ006N'ationalGeogr.aphic ~_: ~~!~~'~~~!~"~_ g'~?U~~'~-~~ ~~S~P ~ -~ - 151°06.000' W L51°04.000' W 151°02.000' W 151°00.000' W WGS84 150°58.000' W 1'~il1T~V~/'U~ TN MN 0.0 0.5 1.0 1.5 miles lqyz~ GEUGRAPNI~ ~ , ' 0.0 0.5 1.0 1.5 2.0 2.5 km p4/z6/07 ~ 0 0 O V M O ~ Z D 0 0 ~ ~ ~ a ~ ~ ~ ~ V n 0 ~ ~ ~ • ~ ~ ~ ~ > ~ ~ ~ ) ) ) J ) ~ GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT ~ , ~ • ~ a,'~ Marathon Oil Company ~ Well Name: SU 41-15 RD Ver. 2 _ Location: Kenai, Alaska. ~.~~~~~~~~ ~~ II ~~~ ~~~~I~~~F~.~~I~~ ~ - i~t3.~E~~~ P~~, ~: . _ _ --:IFE Rrepared FoF: MARATHON OIL COMPANY Prepared by: Tony Tykalsky Reviewed by: Jim Dwyer Presented to: Will Tank June 18th, 2007 ~ ~ Well SU 41-15 RD Kenai Peninsula, Alaska ~ ~ Marathon Oil Company ~ ~ Well Iolame: 5U 41-151~D Ver ~~ ~ r Location: Kenai, Alaska. 1Vlarathon Oil Comp~ny PO ~ox 19016~ Anchorage, Alaska 99519 ATT'N: Will Tank Will: Enclosed is the recommended drilling fluid program for the SU 41-15 RD well to be drill this year. The following is a brief synopsis of the program. Overview: SU 41-15 RD is a sidetrack of an existing well. The plan is to kill and abandon the existing well, drill a 8-1f2" sidetrack to +/- 11642' MD, run and cement 3-1/299 EXCAPE completion. The major concern for this sidetrack is well control as the original well required 11,3+ ppG in the Tyonek T1 sand. Abandonment & Milling: 'The existing tubing pulled will be pulled and a whipstock will be set @+/- 6275' MD. Flovis and drill water will be used .for the milling fluid. Ditch magnets will be installed to capture metal cuttings. A LOT will be performed prior to drilling ahead. Sidetrack Interval: The milling fluid will be displaced to a new "Excape" F1oPro fluid. Connection and trip gas should be monitorted constantly to prevent a well control issue. A 3-1/2" EXCAPE completion will be run and cemented in place. Completion: After logging, the 3-1/2" EXCAPE completion will be run and cemented. Corrosion control will be added to the packer fluid and the cement will be displaced with 6% KCl brine. Tony Tykalsky Project Engineer /M-I SWACO NOTE: This program is provided as a~uide onlv. Well conditions. will alwavs dictate fluid ~roperties requ~°ed. ~ • ~ ~'~ Marathon Oil Company ~ - Well Name: SU 41-15 RD Ver _ Location: Kenai, Alaska. Pro,~ ect Su mmary C~si~ Hole Cas~ng D~pth T~ ~vl~.~d ~la~~ Sum in4erval axa ~i~~ !?r~z~rarja Sr~#srr ~~i~h3 Da~s ~a~a9 Cms3 , ~~oa? Q~) ~ffk) Sol~r9s r'~ntrz~il' {~'9~ 9-5/8" 12-1/4" 6275' S611' Flovis for milling (or Biozan if pH is 8.4 6 $21,604 high) / Shale Shakers / ditch magnets 3-1/2" 8/1/2" 11634' 9495' Flo-Pro 7 w/SafeCarb 9.2 - 11.3 $188,672 Shale Shakers / Desilter N/A 3" Completion 11634' 9495' 6% KCl Brine 8.55 4 $13,926 - Insure magnets are in proper location prior to milling out of 9-5/8" casing. - Cost does not account for any losses of fluid to the formation. ~ ~~~ • ~ Marathon Oil Company s`~~~' Well IVame: SU 41-15 I:I~ Ver. 2 _ Location: Kenai, Alaska. ~~~ ~>~~ ~ ~u~.~-~~ ~a ~f~~~t ~r~u H~~ta~~ ; s ~d ~at~ ~~ 'Well i H~le Size MD ',.~ TVD .PPG P'Y.YP I FL jCamments i 19~Bf193& ; SU 41-15 12.25 6136 : 5511 , 9.1 1~,26 E 0 iDrilling ahead, 1Z-1/4" intenr~l i ~~r E 6471 '~ 5757 t 9.1 1~~27 BA ~Drilling ahead, solids increusing ~ s , i 7164 ~ 6200 ; 9.1 7~ 22 i 16 0~Flwd loss clim6ing (bacteria7) € ~. ~. _ j - . . .. .~ -.. ..._ ... . ~ _ . .. _. .. . .. . .. .. .. , ... .. ... . ... . . . . . ~. . . !, 7725 ; 6800 ?9.05 10 24 ~ B 8~Drilling ahead, working on fluid I~ss ; , _. __ _. ' ~ ; . ; _. , _ . _ _. _._.. _ _ _ 1 _. 7860 ~ 6925 ; 9 11 24' 7 8;POH for new bit, ream to hottam (ti~ht spots) drlg ahead j _ _ ~ ~~ _ ,. : ~ i } ~ ; ~ 8070 ~ 7065 ; 9 9<2., 7 2~Change bit, RIH drlg ahead ( , _.. , __._. ~ . _ ' ` < I ( f ! 8751 ; 7500 ' 9.1 11 25 E d Drilliiri~ ahead _ , _. ... _,.E ... .. _ _ _ _ -. . ... ._ . .. - 5 j S ~ ._. w.., . ._ Ci_~_ .. . . ... . . .. .. _ . . . .,, ....i .._... : _. ~ 9348 ' 7810 9.15 15 30 { 6 2~Short Yn OK, drill ahead ~ _ , , ,. _ _ , ~ : ~ . : ,. . _.: _ _ _ . _ _. ; = 9909 ; 82d1 , 9.d 76?23 $0'~~I Uu~~jirn~ ~cdi.i i,~_reR i t~ ~ ' , ..._ __ ___.. _ .. . _...._ , . ~ ~ ~, ~ .. . . . .. _ ' ' 10121 ` 8396 ~ 9.45 16¥ 21 8 0 Drillin~ ahead, working on fluid loss i ~ ._ ~ .. --. ___ _ _ . ... _ ~ ; , ~ _ . __. _. _ _. ! _.. _. ; ? 10330; 8549 . 90 1 15; 17' 7 2 Drill to casing point, solids increasing, run & cmt casmg OK ~ i ~ _ ,_,. , .,_ .._ _..__ _.. _ _ ; ,. ~ ;,.. . __...... .. . . _ . _ _ _ _ . . . . . : . ° , a.5 10570=, 8678 ~ 9.7 12-17 B 8~Drill out, treat mud, LOT, drill ahead ? i. ( ~. ~ . . . .. .. . . ,, . _.._ ~_ . . ._ ...... i ~ 11105?: 9~63 ; 9_7 97 37 $ 4 Carilli ~ ' . _ _ _ _ , . . .. . ,..... . rllF!:ilj (" i"lill% [IJY .~:3:"~ Ifl ~'.~r~~~ . . .. . . .. .. . . i. . . . ?. . _. . .. '... :.... . `."_ . . . . . , , , . . ... _ _ .. . . . . . ° ` ,71391 ; 9443 i 11 22.'38 76 ,:~i~ Hi~l rcl i uc ' 1 ,. ._~.`_ ~-E -~[J I 1:~):iJ ~f ..i.•. i ~ ~IEi~=' I l~Y'.=: ..~ ~ ~ . . .. .... ...... .. ~. . . ... . .'. . __. .. 1 v.... % ;...__ _ '. ... _.,. ... .._... . ...~ ... . . . ...... . .. . . . .. .. .. ..... .. ......... E 11435' 9482 `91.A 97:39 7.8 inc e:,. _ F'P~ i_ 1'i.~j .:it~, b~r~t-. ~ ~ , , , _ _ , _.._ -- --_..._ . _ _ _ .. _ . . , : ; . € s _ _.. ; ; 11670, 9693 11 3 20 29 6 8,Orlg ahead, work on fluid loss , , _ _. _ _ 3 ! .... . . ..._. ~ ,_ . , . _. . _.. ... . _. ..._. ..._ . ._.._. . ....... _.... _. _ ; ;, 11832': 9863 11 3 24; 34 6 4 Working on fluid loss solids increasing ; _ ;. _ .. ~.. . .._ . , ., , _.,.. .. _. _ _.. _ . . . . _ ... _ 3 11B75'. 9883 ~ 11.4 21 ~34 6.2 !'e ~t~itu-~~~~d-r rr. ~•.iJ~ i ~ e~:~ :i,u.~ , ~ € . _ , _. .._ _ ~. _ . . _ . _. _ _ .. ..,_ . ;_ _ . . . . ~ 12193'70103 _ . ~~~_~ ' _ ~ . ~ ~ 11.3 20~24 6.$ .CiiiA .~si~=irj, i~(7~~r~i~~,~ i ~ r _ .;i~r_:i , _,_ _. . . . __ .. ._ _ ~ i ~ . 12288:10278 11.3 20 27- 6.8 ~~i~Jtrir n~~:l ~{i(ut u~ r~~ii~r~. ;j~:ilf .~P_~; ~ , , , , _ _ _ _. _ _ ~ ' _ _ _ 123~6 103d6 91.5 20 35 E.4 ='- ~ , ~.. ~ ~ E , ~ :: F : - , c =s~: u ., . s, . ~ ~ ~ ' ~ l2 = 1260~' 10559 11 J 22' 30 6.8 [!r;[ t =. ~ c ~ ~ ; - ? ` ~a = i = r ~_ --: ~ ~ ~ 12600 70559 8.6 ~~ ~ ~, :=; =;. -= i;r.: i i ~,.i.,r_ ' ~ ?`=. - - .~ ~. - ' ,. ' ~ ; E 726~0 10~59 8.8 Fefi ,til; ft~ z~iie~:, i n rt~~:e. tui~2 Pr~ z i; ,~ritroi y.as. I '~ ~~ • • . ~?"~t17-Il~;T~T _ x - `iNillii~= ~~et~a~~:' '' +C~~p~4.a~ - T~~ ~~a~ ~ ~.- :~~~~~ _ - ;} Ta~~l ~€~~t _~._ti M-I Bar 0 2605 0 2605 9.87 Soda Ash 0 12 0 12 010 Caustic Soda 0 35 0 35 0.72 Conqor 404 0 6 0 6 3.91 Sodium Meta Bisulfate 9 24 4 37 1.17 Bicarb 0 12 0 12 0.10 Conqor 303 0 0 4 4 1.00 F1oVis 37 1$9 0 226 22.52 Biozan ? ? ? Asphasol Supreme 0 47 0 47 1.93 KCl 376 993 184 1553 13.83 Polypac Supreme UL 0 95 0 95 7.14 SafeCarb 10 0 532 0 532 4.95 ~ SafeCarb 40 0 532 0 532 4.95 Lubetex 0 36 0 36 12.76 SteelLube 0 18 0 18 7.97 KlaGard 0 10 0 10 3.45 Defoam X 0 5 0 5 0.24 Freight Surcharge 3.56 Engineer Service 6 7 4 17 ~~ ~..1~.~ ~ • ~ Marathon Oil Company ~°`~ Well Name: SU 41-151~ Ver. 2 ~~~ _ Location: Kenai, Alaska. ~~ ~ ~~' ~ ~ ~ ~~~ +/- 6275' ~~'~~~~~~ ~'~~i~~ ~~~t~~ Milling Fluid (utilize brine from de-completion operations) ~~~% ~~°~~~~~~ F1oVis / Sodium Meta Bisulfate Shale Shakers / Ditch Magnets Recommended shaker screens - 180/180/150 mesh Patenti~l P~c~~l~r~s Birds Nests hole cleanin nt~rval Drilling Flu~d Pr4perties IS~pth Mx~d Plastic LSRV A~'~ lYIeta~ I~te~°~~1 ~~~igl~t ~is~~sity 1 min ~'l~i~ L~~~ ~" ~~nt~r~t (f~~ ~Ppg) ~'~P•~ ~~P~~ ~nr~iJ3fl~ni~) (~1a} +/-6275 8.45 8- 12 +-/ 30,000 N/A 0 0 - Build 6% KCl brine for kill operations: - After kill operations and cementing check pH of brine prior to building milling fluid. NOTE: If pH of brine is 10.5 or less then use Flovis for viscosity. If pH is above 10.5 then Biozan is recommended for viscosifying the brine. - Viscosify the brine with 1.5 - 2.25 PPB of Flovis prior to milling the window of the 9-5/8" casing. - Insure ditch magnets are in place at shale shakers. - Mill out window and circulate hole clean. - Displace wellbore to drill-in fluid prior to POH. - Estimated volume usage for milling/kill operations - 917 barrels. ~~ ~ ~~ • ~ Marathon Oil Company ~~~~ 1 Well Name: SU 41-15 RI) Ver. 2 ~..:~ _ _ Location: Kenai, Alaska. ~ ~ ~~,, ..~ ~ ~ ~~ 6275 -11634' ~~~~~~~~ ~'~~~~~~ 5~~~~~~ Flo-Pro Fluid I~~y ~~°~~u~~~~ FloVis / Caustic Soda / MI Bar / Polypac Supreme UL / Conqor 404 Sodium Meta Bisulfate / KCl / K1aGard / SafeCarb ~~~~~~ ~t~r~tr~l Shale Shakers / Desilter / Centrifuge Recommended shaker screens - 210 - 230 mesh P~t~~~~~~ Fr~~le~~ Lost circulation / differential sticking / swab-surge / Well control in yonek T 1 sands nterva~ Drilling Fluid Properties _ ` T~ep~h ~.l1teA'~a~ ~~~3 lO~Iud ~'d'1~~1$ (P~~) Plastic ~T1SCO31~ ECp•) LSRV ~ 1l1lll {cps) A~'I ~~1111C~ ~.,~5$ {m1130rnin) ~~~s~ Drill ~ti~lE~S (°/Q} 6275 - 11,000' 9.1 - 10.0 12 - 18 +/- 40,000 < 8 < 8 < 5 11,000 - 11,634 11.0+ 15 - 20 +/- 40,000 <6 <g <6 - Build drill-in fluid according to the below formula. - Run as fine of shaker screens as possible to minimize drill solids buildup. - Utilize SteelLube initially if torque is an issue (this will reduce metal to metal friction first). Only after a concentration of 1% SteelLube is achieved should Lubetex be added as needed. - Run daily check on K+ of the mud. If K+ begins to decrease, raise concentration with additions of K1aGard. ~ - Watch for gas increases on connections as hole is drilled. Be prepared to increase mud weight to above 11.0 PPG to control gas below 11,000' MD. - Condition fluid prior to running Excape completion. - Estimated volume usage 2423 barrels. NOTE: Follow BOSCO guidelines when adding biocide, oxygen scavenger and corrosion inhibitor. ~~ CJ1~ ~ '" ti-. ~ • Marathon Oil Company ~. ~' Well Name: SU 41-15 RD Ver. 2 ~~ ~ ~ ~e' Location: Kenai, Alaska. ~~~~~ ~'~~°~~1~~ ~~~ ~~" ~~~~~~~.1 8-/12" Interval from 6275 - 1 1634' ~., ..~ Descri tion SU 41-15 RD Mud Wei ht 9.1 - 11.7 Preh drated Get` No Wei ht Material Code MI BaR Preh drated Gei Conc. Wei ht Material SG 4.2 KCI Wt% 6 Out ut -1 bb l 'Order of Products Concentration ' Volurne Product Addition Fie1d, Ib Lab, m Field, bbl Lab, ml Usa e 1 Water 325.19 325.19 0.929 325.19 2 Soda Ash 0.25 0.25 0.000 0.10 Reduce Hardness 3 FloVis Plus 2.00 2.00 0.005 1.34 Viscosit 4 Pol ac Su reme UL 2.00 2.00 0.004 1.33 Fluid Loss Control 5a SafeCarb 10 15.00 22.50 0.017 5.67 Brid in A ent 5b SafeCarb 40 5.00 7.50 0.006 1.89 Brid in A ent 6 Potassium Chloride 20.76 20.76 0.025 8.68 Inhibition 7 CONQOR 404 2.00 2.00 0.004 1.43 Corrosion Control 8 Caustic Soda 0.50 0.50 0.001 0.23 H Control 9 Sodium Meta Bisulfate 0.50 0.25 0.001 0.25 Ox en Scaven er If hi h tor ue in incured while drillin out t he 9-5/8" casi n add 0.5 -1.0 % SteelLube 10 SteelLube 3.50 3.50 1.500 3.50 Metal to Metal Lub If slidin or hi h tor ue becomes a roblem add 1- 3% of the followin 11 Lubetex 7.00 7.00 0.021 7.00 Lubricit If sloughing coals become a roblem add 2- 4 b of the followin 12 As hasol Su reme 2.00 2.00 0.004 1.33 Wellbore Stabilit NOTE: Be re ared to weight up for well control below 9400' TVD Total 380.1 380.1 Estimated Volume Usa e 2423 Barrels Calculated Mud Wei ht 9.050 Total Chloride 29600 ~ ~ ~ • ~ _ ~:'~ Marathon Oil Company ° Well Name: SU 41-15 RD Ver. 2 _ Location: Kenai, Alaslca. Int~rval ~ummar~~ =-- ~omplet~o~ Pro~edures Corrosion Control Additive in Casing x Tubing Annulus Well SU 41-15 RD Volumes: Tubing Volume 3-112" Tubing 101.21 barrels 3.50 x 2.992 x 11634 ft Annular Volume Casing x Tubtng 384.85 barrels Open Hole x Tbg 120.23 barrels 9.625 x 8.681 @ 6275 ft MD ~ 8.500 x 3.50 @ 11634 ft MD Treatment Procedures. Total Annular Volume 505.09 Tubing Volume 107.21 Total Hole Volume sos.3o 1. After the 3-1/2" tubing is run and the drilling fluid is circulated and conditioned for the cement job, circulate ; additional 385 barrels of drilling fluid. 2. Add 1 drum of Conqor 303A and 1 sack of Sodium Meta Bisulfate for each 95 barrels of drilling fluid pumped (4 drums & 4 sacks total) 3. After the 385 barrels of drilling fluid with treatment have been pumped downhole, begin the cement job. This procedure will place corrosion control in the 3-1/2" x 9-5/8" annulus. ~~ ~ • ~ Marathon Oil Company ~~~' Well Name: SU 41-15 RD ~Ier. 2 ~~~t,~,:~ _ Location: Kenai, Alaska. ~ ~~>7~~~~ H~-NDLING OF DRILLIIVG FLUID PRODUCTS WEALTFI AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, diums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centrifuge solids van, insure all hoses and connections between the van and the rig are secure. ~ G~..1...a • ~ ~Z'~ Marathon Oil Company Well Name: SU 41-15 RD Ver. _ Location: Kenai, Alaska. Produ~~ t~~~it~~ and Safety R~#~r~n~e 1-Ii~AI~ HAZARD R1f-TINf=.S Product Function Health Fiammabilit Reactivit PPE ASPHASOL SUPREME Shale Inhibitor 1 1 0 J BORAX Inorganic Borate ~ 0 0 E CALCIUM CHLORIDE Densifier 1 0 0 E CIRTIC ACID pH Adjuster 1 0 0 E CONCOR 303A Corrosion Inhibitor 2 1 0 E CONCOR 404 Corrosion Inhibitor ~ 1 0 J D-D CWT Fluids Additive 2 1 0 .1 DEFOAM X Defoamer 1 1 0 J DESCO CF Dispersant ~ 1 0 E DUAL-FLO Fluids loss reducer 1 1 0 E FORM-A-SET AK Loss circulation Material 1 1 0 E FORM-A-SET XL Fluids Additive 2 1 0 E FORM-A-SET RET Loss circulation Material 1 1 0 J HEC-10 Viscosifier 1 1 0 E FLO-VIS PLUS Viscosifier 1 1 0 E STEEL LUBE EP Oil well additive Lubricant ~ 2 0 J SODIUM BICARB Alkalinity control 1 0 0 E SODIUM META Oxygen Scavenger 1 1 0 J SPERSENE CF Dispersant 1 1 0 E GELEX Bentonite Extender ~ 0 0 E G-SEAL Graphite LCM 1 1 0 E KLAGARD Shale Control 0 1 0 J LUBETEX Lubricant 1 1 0 J MI BAR Weighting Agent *1 1 0 E MI GEL Viscosifiet *1 1 0 E MI SEAL F, M, C LCM *1 1 O ~ ~ • ~ ~ ~~'~ Marathon Oil Company Well Name: SU 41-15 RD Ver. 2 ~e Location: Kenai, Alaska. Product kl~alth and Safety Re#erer~~e HIV!!~ HAZARD RATiNGS HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard 0 - Minimal hazard ''' An asterisk next to the health rating indicates that a chronic hazard is associated with the material. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C- Safety Glasses, Gloves, Synthetic Apron D- Face Shield, Gloves, Synthetic Apron E- Safety Glasses, Gloves, Dust Respirator F- Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G- Safety Glasses, Gloves, Vapor Respirator H- Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I- Safety Glasses, Gloves, Dust and Vapor Respirator J- Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator It - Air Line Hood or Mask, Gloves, Full Suit, Boots X- Consult your supervisor for special handling directions MIX II F, M, C LCM *'~ 1 O E NUT PLUG F, M, C LCM *~ 1 O E POLYPAC'S Fluid Loss Control *1 1 0 E Potassium Chloride Shale Inhibitor, Densi~er 1 0 0 E SafeCarbs (all) Bridging * weighting agent *1 0 0 E SAFEKLEEN Surfactant 1 1 0 J SALT Densifier 1 0 0 E SAPP Dispersant *1 0 0 E SODA ASH Calcium precipitation 1 1 0 E DRILLZONE ROP Enhancer 1 1 0 .l SCREENKLEEN Dispersant/Emulsifyer 1 1 0 J BIOBAN BP-PLUS Biocide 2 1 1 J GREENCIDE 2~r Biocide 3 0 0 .1 CAUSTIC POTASH Alkalinity Control 3 0 1 X ~' r' ° A"~wC SODA Alkalinity Control 3 0 1 X 1~ ~ ~ ~ e: ~' ~: ~~~~' u Marathon Oil Company Well A1ame: SU 41-15 RD Ver. 2 Location: Kenai, Alaska. ~ : ~ ~ ~ Contact ~i~1e e-mail Work Cellular Pete Berga Drilling pkberga@marathonoil.com 907 565-3032 907 231-0663 Marathon Superintendent Will Tank Drilling Engineer wjtank@marathonoil.com 713 296-3273 713 203~8398 Marathon Tony Tykalsky Project Engineer ttykalsky@miswaco.com 907 274-5011 907 227-2412 MI SWACO Bob Myles Warehouse Manager rmyles@miswaco.com 907 776-8722 907 252-4218 MI SWACO Oliver Amend Field Engineer amend@acsalaska.net 907 283-0895 907 398-9474 MI SWACO (home) Locke Rooney Field Engineer lrooneyl@alaska.net 907 235-0598 907 398-9474 MI S~VACO (horne) John Nicholson / Dan Drilling Foremen alaska_drilling@marathon 907 283-1312 Byrd / Rovvland oil.com Lawson / Mike Feketti Marathon ~esp~nsibili~ies - MI Project Engineer and will coordinate daily between the Marathon office, rig, warehouse, and the M-I field engineers. - Well progress will be monitored to look for any changes, which will improve the efficiency of the operation or avert trouble. - Field Engineers will monitor and supervise product inventory to include re-palletizing any products for shipment to other locations at the end of the well. - Field Engineers will communicate with office personnel (Marathon & MI SWACO) for approval of any changes in the mud program (including introduction of new products). - Field Engineers will produce a recap at the end of the well based on daily activities. Recap should include any lessons learned that may be used to provide better service on future welis. Lessons learned can include changes in procedures, product additions, equipment usage, and/or utilization of any third party service. ~~ MARATHON MARATHON Oil Company Location: Cook Inlet, Alaska (Kenai Penninsula) Slot: slot#SU41-15 Field: Sterling Gas Field (NAD83) Well: SU41-15 ; ,,q~ ~~ BAKER Hu6NEs INTEQ Plot reference wellpath is SU41-15Rd Version #5 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4(5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #1 (RKB) to mean sea level: 245 feet Scale: True distance mean sea level to Mud line (Facility - Pad 43-9): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: michwilg on 6/15/2007 ~ L d N ~ N U ~ N ~ N 7 ~ Vertical Section (ft) s°'a„"`"'s°°" Azimuth '12'I.~ 6° with referenca 0.00 N, 0.00 E from wellhead ~~ MARATHON Targets Nama M~ (fl) NO (fl) ocal N(11) oial E(/i) GnJ Easl (lISX) GnE NoN~ (USfI) LaYluOe Lqqilutle at-15RE Tap lnwar etlupe 15Jw~01 8080.00 -2429.12 3903."!9 105867I.51 2381305.21 e0' 31' S0.980'N 151' 00' 3J.633'W <t-15RE TW Tyamk 15JUrv0) 8955.00 -2866.9] d4]03B 10.5918~l.C] 2386819.]'/ fip• 31' 66.869'N 15~• 00' 22.303'W 41-15RE TO 15JUm0) 9a95.00 -26a6.92 44]0.38 10.591874] 2386819.2] 60' 31' 68.889'N 151' W' 22.303'W • ~250 1500 T750 -2000 p • ~ 3 7 ~ -2250 '~"~'- -2500 -2750 -3000 MARATHON Oil Company LoCation: Cook Inlet, Alaska (Kenai Penninsula) Slot: slot #SU41-15 Field: Sterling Gas Field (NAD83) Well: SU41-15 Facilit : Pad 43-9 Wellbore: SU41-15Rd ~'~~ BAKER Nu~HEs INTEQ Plot reference wellpath is SU41-15Rd Version #5 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4(5004), US feet Measured depths are rafarenced to Glacier #1 (RKB) North Reference: True north Glacier #'I (RKB) to mean sea level: 245 feet Scale: True distance mean sea level to Mud line (Facility - Pad 43-9): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: michwilg on 6/15/2007 sub,m~-~~ Easting (ft) ! ~- ;i~A1i'A'T~#aN Planned Wellpath Report SU41-15Rd Version #5 Page 1 of 4 ~ Y~~~ ~ ~ Nl1~1~'A"~I~#t}t1 Planned Wellpath Report SU41-15Rd Version #5 Page 2 of 4 _ _ _ _ _ _.._ WELLPATH DATA (60 stations) ~- = interpolated/extrapolated station _ _, - MD Inclinafion Azimuth : TVD ; Vert Sect ; Narth East Grid East Grid North = DLS [feetJ [°] , [°] [feet] (feet] ,'_ [feet] [feet] (us survey feet] ~us survey feet] ;[°/100ft: - -_.. 6275.00 , 43.129 124.973 5611.06 1951 55 -1132.88 ;1595.55 ' 1456340.02 2388638.04 ~ 0.00 ~ ~ , ~ ____. _ _ __ _ _ _ , _ -- -- _ ~ 6295.00 : 44.851{ 122.567, 5625 45 1965 42 '-1140.59 ,1607.09 145635 L45 2388630.14 12.00 __. __... .__._. ._...._._ ~.., . ~ ~_.. . __.. ._..... ,. ._.._.. ..._"_. ..._._".- _, .-__~ ,.._ _.__ 47.074,121.30515681 06 ; 2022 92' 1171.00 ° 1655.90 ~ 1456399.77 ? 2388598 97 3 3.00 ~, ,. ~.._.~., _. 6475.OOt' 49.869a 119.851~5747 35 ~2097.77 ;-1209.06 r 1720.35 ; 1456463.61 1 238855991 ; 3.00 ~~~ BAKE~ NVt~-1~~~ ~~~E~ Rate iTurn Rate 8.61j -12 2.78~ -1 2.80~ -1 6675.OOt; . . 55.508Y 117.271 ~ 5868.55 ' 2256.58 ;-1284.95 ~ 1860.05 ~~ 1456602.10 ~ 2388481.84 ~ _ . 3 00 g 2.83~ -1.2 I , a z ~ ~ 8 2 8455 56 ~ 3 00 r _... 2.84~ ...,.. 1.1 6775.00 ~ fi LL _ ~ _..,., _. _ _ . , ~_ .._.... _... 57.428`,116.477t5923.33'2339,98 ~-132 2.59 I1934.76 i , ..,...--'-- 1456676. 0 i y.u,~`~.,., 238 8443.04 ~ 0 00 ~ _ 0.00~ __._... 0.a _ _ 6875 OOt~ ------ __..___ ___ _ _ _. 57 428,116.477 5977.17 2423 97 1360 16 ;2010.19 __ 1456751.03 ----- ---_ 2388404 30 ~ _ . 0 00 ~ _ 0.00~ 0.0 ~~'~~~ ~~~:116.477 6031.00 2~~~~ =~~~~`~ ~~~~2 ~; - - - 1456825 $~ " -~ ~~~'t~~~~-~ ~~ ~ ~ ~ ~~~~ ` ~ ~' ~__ _O.a -- 7075.OOT 57.428~ 116.477 6084.84 2591 95 1435 31 s2161.05 . 1456900.69 , __u 2388326 80 ; .. , 0 00 : _~~_~ 0 00, 0.0 7175.00 j- 57.428 116 477 6138 67 2675 94 , 1472 88 ;2236.49 1456975.52 ; __ 2388288 06 0 00 0 00 0 0 7275.00 j~ ` 57.428~ 116 477° 6192 51 2759 93 !-1510 45 ~2311.92 ,' 1457050.35 2388249 31 0 OO r~ ~ 0 00, 0.0 7375 00~, ~ - " ` ~ 57.428~ 116~477 6246 34 2843 92 a-1548 02 ~2387 35 ~ ' ~~~ ~ 1457125 18 2388210 56 ~ 0 00 r 0.00~ 0 0 ~ , ~ ~ 7575.OOt~ ~~ S ~ E 4 17~ ~~~~ ~ ,,~ ~~~~~~~~'~9 ~ 57.428~ 116.477 6354.02 3011 90 1623.17 ~2538.22 , :14572~t~~ ~ 1457274.84 ; ,~~~ ~ 2388133.07 ; ~ 0.00 ° 0.00; ~ ~ 0.a 675.OOt~ - 7'175 00 ' _ .. _ . __ 57 ~ - ~ ' 57 428~ 116 477 6461 69 31079 88 ; 169 ~ i ~ ~ 4 , . . __ 2388094 32 ; _ ~ ~ ~ ° __o ~ _ - . 0 00 ; O.OOd , _.._, ° _._,_ _ 0.a .._.... . 1 . . . : . - 8.31 2689.08 4. 145742 0 238g055 58 g 0 00 0 00 0 a 7875 00 fi~ " 57 428 116 477 6515 52 3263 87 1735 88 32764 52 ~ ,~ ~ ~ ~ 1457499 33 2388016 83 ' 0 00 ~ 0 00~ 0.0 ~ ~ .... ~ z ; ~, _ . _ ~ ~ ~, jj ~. ~~~~ ~k ~s`~r~~~~ ~: W .: " ': -~ ~~~Y~ ~~}~~~ ~ ~ ~~~ry ~~~~ ~~ ~ 8075 00~, ...... . . .. .,~ ... _~~.~ .. 57.428 116.477 6623 19 3431 85 -18ll 02 ~2915 38 , ~ ........ 145 ~ .... y .... 8175 00~, 57.428 116.477 6677 03 3515 84 -1848 60 ~2990.82 ~ 1457~23 82 ~ 2387900 59 ~~ 0 00 <~~ 0 00~ 0.0 8205.74 57.428~ ll6.477,~ 6693.58 : 3541 66 ;-1860.14 ~ 3014.00 ~ __ _ 1457746.82 ~ 2387888 68 ~ 0 00 : 0 00 O.a 8275.00~: 56.221;116.607 6731.48 3599.44 :-1886.05 ?3065.86 ! 1457798.27 ~ 2387861.97'= 1.75 ` -1.74~ 0.1 8475.00~- 52.736' 117.003 6847.66 3761.72 ;-1959.43 ; 3211.14 ; 145794236' 238778632 ' 1.75 ; -1.74; 0.20 _ _._ .__ . _.__~_ __.._.,. . _~_., . _ ___. 8575.00 j-. 50.994 117.215 6909.41 3840.18 -1995.27 € 3281.15 , 1458011.80 2387749.40 ` 1.75 '; -1.74~ 0.21 -- --- _ _ _ __ _ __ _._. : -_. _ _ _ _ __ _.. -_._ __ _; _ _ _.._~.~_.„~.~ _ .. 8675.00 j-, 49.252~ 117.438 6973.52 3916.74 ~-2030.50 ! 334932 ' 1458079.41 238771311 1.75 ' 1.74' 0.22 - ___ __-- _ - 8775.00j~ 47.511 117.672 7039.94 3991.35 -2065.08 3415.60 1458145.14 2387677.50 1.75 ' -1.74 0.23 8975.00 j-' 44.030 118.184 7179.42 ' 4134.41 -213217 ` 3542.21 '! 1458270.67 2387608.43 1.75 '! -1. , -- 9075.OOj~; 42.291,118.464 '725236 4202.73 "-2164.62 ~3602.42 ° 1458330.36 2387575.04' 1.75 ' -1. . . . . . .._ 9175.00 j~" 40.552;118.764 7327.35 4268.82 -2196.30 ; 3660.50 1458387.93 2387542.46 1.75 -1. _ . 9275.00~`, 38.814' 119.086 7404.30 4332.62 -2227.18 ; 3716.39 1458443.33 2387510.71 '. 1.75 ' -1. ; 9475.00 j~°', 35.341' 119.809 7563.84 445312 -2286.43 ! 382139 ` 1458547.38 ' 2387449.83 1.75 I -1.74 0.38 _ . __. ... _ 9575.00j~ 33.607 120.218 7646.28 4509.71 -2314.74 -3870.40 1458595.94 2387420.76 1.75 -1.73 0.41 9675.00 j~, 31.874 120.667 7730.39 4563.79 -2342.13 ; 3917.03 ' 1458642.13 2387392.64 I 1.75 ' -1.73 0.45 • .. _ . _ ~.._.. ; 9775.00 j~ 30.142 121.162' 7816.09 461530 ,-2368.59 3961.23 1458685.91 2387365.49 1.75 -1.73 0.49 [n / KOP WS Window of Curve ~ ~ lIAARATHt3~1 Planned Wellpath Report SU41-15Rd Version #5 Page 3 of 4 ___ HOLE & CASING SECTIONS Ref Wellbore: SU41-15Rd String/Diameter ; Start MD End MD ':' Interval [feet] [feet] [feet] _ __ _ . 20in Conductar -9.00; ` 49.00: _. . 58.00 ,.. . .~.. _. 13.375in Casing Surface _. _.. -- ____ ~ -9 00; . 2262.00' 2271.00 - --- ~ _. _ 9.625in Casing Intermediate .._ ...._.. _ ~ -9.00' - -.- , 6275.00 ___.. . _ 6284.00 _ _ . --- _ ._ , 3.Sin Casing Production 0.00 : _ . _ . 11634.09 ,_ _--- 11634.09 8.Sin Open Hole . 6275.00` 11634.09~ ..__._ -_ _ 5359.09 ~ ~~~~ ~~ sAtCE~ KUCNE~ INTEQ . . Ref Wellpath: SU41-15Rd Version #5 __ _ _~ --~~ ---._._ _ Start TVD ; End TVD ' Start N/S Start E/W e .. _. ..r_~. End N/S [feet] (feet] [feet] [feet] [feet] _,w _, __. ... -9.00; . - ~~ . _-~_ . . _ _._,. _. . ; 49.00; 0.00; 0.00' - . ._,_., 0.05 _ _ .. _.._ . 9.00 ...-- -- --- __ .~.. _.. 2261.28' 0.00 0 00 _ _. _~.__~.. 44.99 ..~ . _ _ ...._ -9.00 -- -- -. .._ .. .._ , , 5611.06 0.00, 0.004 _ =- - 1132.88 ~ 0.00 - . .- _. . 9494.99 0.00 0.00; . --- -2800.98 - - 5611.06 9494.99' -1132.88 1595.55' -- -2800.98 End E/W 0.10 1595.55 4631.44 --- - 4631.44 ~ ~ ~A~ATHIJM Planned Wellpath Report SU41-15Rd Version #5 Page 4 of 4 ~~ 8~~~~ ~~~~~~ T~~~~ 'ARGETS . _ ~ .~_ ~ .~. m. ..~._a . ~ ..~~ .. _ .~_ fame ~ MD ~ TVD ~ North ~ East ~ Grid East ~ Grid North ~~ Latitude n Longitude ~Shape ~ [feet] ~ [feet] ~ [feet] [feet] ; (us survey feet] ~ [us survey feet] ~ [°l 3 [~] ~ _ ,. . .. _ ~~. n . e ._. . ~ _ ~_~. ~__, , ) 41-15Rd Top Lower Beluga ` s 8080 00~ 2429 72( 3903 78 1458627 51 j 2387305 27~60 31 50 980N~151 00 33.623W;circle ,. . ... ~. w~~ m_.. ~_ _, 5-Jun-07 .~„ ,,,.~.M. ..e....,~ .,.... _~ . ..m._w., _ ~ ~ ~ ~ ~ 8955 00 2846 92{4470 38~ 1459187 47~ 2386879 27~60 31 46 869N~ 151 00 22.303Wicircle 1-15Rd Top Tyonek 15-Jun-07 . _~-_~ _ y~ ~~ .a _ ~. ~,~. ~ 4. _.e~.~ ~. . n..,, _. ~ ~~, ._~~,~.~. ,~~ ~~ ,_~~~ ~a,~., ~ mr.~,~_ ~, _~,~ ~..,.. ~~ ` ~9495.00~-2846.92~4470.38~ 1459187.47! 2386879.27~ 60 31 46.869N~ 151 0022.303W~circle ~ _~...... _. 1-15Rd TD 15-Jun-07 ~ ~ ~ . _ ._ , ~_ _ .... . ,~ __ __~ d, , .. . ~ _. __.~. ~ .~ . _. ~, _..~ v._ ~ ...~, ~ , a _~, _ . __. .... N.~w ., _~,~~..~ ..,_.w,__ RVEY PROGRAM Ref Wellbore SU41 15Rd Ref Wellpath: SU41-15Rd Version #5 ~.. ..w.., . ..._.,._ _ __.~ . ...,,~_ ..m.,_~= ._.,__,. ~_~~~... ~.. . ..~_.:m.~ ~~ ..~....g ~ .~e_ ~_„~...,~__.~ ..M.:.. ~..,__~~~ __. ~~. Start MD ~ End MD ~ Positional Uncertain Model ~ Lo Name/Comment ~ Wellbore [feet] . . ~ . _ ... Ifeet] . ~ ~ 3 ~ ~ ~ ~ ...ze~ e. ew~ ~ ....~.~~.~~_.~._..___ ..~.._~,. 9 00~ 6275 OO~NaviTrak (Standard) ~ SU41-15 . _ _, .._. _~ ~._....~_ ___... . ..W_._..._ _....m.. 6275 00; 11634.09~IaviTrak Standard ~~~ ~" '°'~°"~~ ...., _ ~__~ _~..~.~ . ~~ _,~.a_ ~___~ .~_ W~~~.~.~._._~~ __ .._ ._.__ . ___ _ _ ~ ) ~ ~SU41-15Rd ~ ~ LPATH DATA (7 stations) MD ~ Inclinat~on ~ Azimuth [feet] ' . ~_..._~~~ `- ~~~ 6275 00 [ _w ,_. 43 129a , _. ~ ._ ., _ 1249'7. rv 6295.00 ~ ,` 44.851;: 122.56 „6742.70 ~; ~ 57.428°~~ 116.47~ 8205 74 r 57 428 116.47' . . ~~ ~ - ~ ~ ~ ~_~ 11038 27 ; ~ ~ -~ _._ ~ 25.000- ~ ,.. -:.~. 123.OOi 11634 09 '~ ~ 25.000 ~ 123.OOi TVD 's~ Vert SecY ~~ ~ North ~~~a East ~ DLS~ ~Design ~~~ ~ [feet ' . ~ feet7 ~ ~ I [feet ~ °` [feet] [°/100ft] Comments ..s.,. 5611 06 ~ ~ ..,.,_,. 1951 55 ~ ._,.. 1132 88 ~ .,PJ..,,..:..~.. 1595 55 ....,a_ 0 00 Tie In / KOP ~_.~ 5625.45 ~ ~.Y_~ 1965 42 ~ ____~. _ 1140 59 ` 1607 09 ~ ~~~ ___...~. _~.___..___ 12 00 End WS Window 5905.94 ~2312.85 j -1310.46 , 1910 39 ; 3.00 ~End of Curve~ ~~~~ 6693~ 58 ~ 3541 66 ~ 1860 14 ~ 3014 00 . _~ ._ ~ a, ~~m__e..~ ~~. 0.00 ~Begm Drop/Turn , ~ 8080 001 ~' ;~ ~~ ~__ _~__W.. 2441 61 ~ _u .._ ~ ~~~~ ~-~- ~ 4078 07 - ~ ,~~. ~ - 8955 00 ' _ Mw_ ~, ~ ~ _ _ . .. . . . _ S160 88 , .y.. ~ e ~ .. .. .. -2663 83 ; _~~ 4 . 4420 26 ', ,~, _ . , ~ ~..~ _ _ 4.._. r_ _ 0 00 aTyonek .. _ . 9495.00 { 5412.56 ; -2800 98 ; 4631.45 ~~ . . . ~. ~ ~, , _ ~~ .~. ~ ..a~. 0.00 'TD HOLE & CASING SECTIONS Ref Wellbore: SU41-15Rd Ref Wellpath: SU41-15Rd Version #5 String/Diameter Start MD a End MD ~ Interval ~ ~ Start TVD ~: End TVD ~ Start N/S ~ Start E/W ; ---- ----_ ____ End N/S ;: End E/W _ . , „ ` [feet] _ _. . ,v,. r. [feet] ~. ..~, [feet] , . ~ [feet] .,~. ~~. _ [feet] .m,~~ ~v._..~~ [feet] _ ..~,.~ [feet] ; Ifeet] [feet] 20in Conductor y _ s,v~ ~, ~ -9 00" r 49.00 58 00~ _ 9.00 49 00 ~ . 0.00, . _~~. ~ 0 OOQ _~ ~ 0.05 __,_m_~ _~ 0.10 13 375in Casing Surface _ _ _ -9 00 ~ _. ~ , 2262.00~ ~ .~ _~ 2271.00~ " :~. . __.~ .~. -9.OOG ..~~ ~ 2261 28 .... ., ~.. ._ 0.00= . ~ .. . ~ 0 00 _ . ~.~~ ~ 44.99~ ~e r~ ,~ 22 94 9 625m Casmg Intermediate _,.. _ _., _._..__ _..._ .~ ~ . ,. .. r . -9 00= __ ~ ~ _~_ _ 6275 00 . .___ - 6284 00` __. ~ . _~ . -9.00~ ~.~_ ~.» - 5611.06 . ~ . 0.00; W ._ _ 0 00~ ~ _ -1132.88~ .__ _ _ .._ 1595.55 . 3.Sin Casing Production .. _ . . . ,~. . ` 0.00; ~v ~._. ~. 11634.09r _~... _. 11634 09~ _._, . _.~~ 0.00~ ___~ e_,~ 9494.99: _n ~._. w. 0.00 .____ ~ 0.00=' _~~... .. 2800.98- .~.____w_.. 4631.44 .~...~ . .. . ._ . . __.r B.Sin Open Hole ~, . .~ 6275.00~ ~~ ~ ..,, ll634.09~ ~w. .. ~ 5359 09~ ,_x . 56ll.06{ ~._ . . ~ 9494.99~ 1132.88, :~~.. _~ .;.~ 1595.55~ , M ~.,,o~.... 2800.98` . w.~.. yx., 4631.44 ~ Wellpath Design Summary Report ~~~~~ Wellpath: SU41-15Rd Version #5 ~V~"ji~~„~ ~;~~~~~'~~ Page 1 of 2 ~~,r~.,~~ ~ ~ TARGETS __.._... ___ _ _ . ... ___w.. . _ .___ ,. . .~_~, _._ RVEY PROGRAM Ref Wellbore SU41 15Rd Ref Wellpath: SU41-15Rd Version #5 _.......,._ _v.» .~ ~...~,~_~ ~ ~~~.w _._ ~ ~.~~~ ..~m ~..~..._~~ Start MD ~ End MD s~a Positional Uncertainty Model ~~~~~ ~ Log Name/Comment m~~ ~~ Wellbore [feet] ~ [feet] _ ~~., ..a:. ~ ~., . .. . ., ~. 9 00~ 6275 OO~NaviTrak (Standard) ~ ~SU41-15 ~ w ar~ ~. ~._~~~.~ ~ __~ ~. , .. ~.v_ _ ~ _.e~~.~~,~..~..W ~.~ ~., 6275.00~ 11634.09~NaviTrak (Standard) ~~~ ~ ~ ~ ~ ~~' ~~~ ~~~~ ~ ~ ~ ~ ~~SU41-15Rd~~~~~~~~~~~ ~ ~~ Wellpath Design Summary Report B~~(~~ Wellpath: SU41-15Rd Version #5 ~u~ii~~ „`t ~;~~'~~`~Q~ Page 2 of 2 ~~,~,~~ ~ ~ ~~R~~~i~~i . MARATHON Oil Company Location: Cook Inlet, Alaska (Kenai Penninsula) SIOt: slot#SU41-15 Field: Sterling Gas Field (NAD83) Well: SU41-15 Facili ~ Pad 43-9 el re: U 1-15Rd ~/~ u~~s INTEQ Plot reference wellpath is SU41-15Rd Version #5 True vertical depths are referenced to Glacier #1 (RKB) Grid System: NAD83 / TM Alaska State Plane, Zone 4(5004), US feet Measured depths are referenced to Glacier #1 (RKB) North Reference: True north Glacier #'I (RKB) to mean sea IeveL 245 feet Scale: True distance ~ mean sea level to Mud line (Facility - Pad 43-9): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: michwilg on 6/15/2007 Traveling Cylinder: Map North MD range is 6275 ft fo 11634.'I ft ~ Srale t inM = 30 R L _J M~ARATHt3~ Clearance Report Closest Approach SU41-15Rd Version #5 Page 1 of 7 POSITIONAL UNCERTAINTY CALCULATION SETTINGS I~T`~Q ~ .., r .... .,.....~ Elhpse Confidence Limit ~ - ._ . ...m.._. _~ . __. 3 00 Std Dev _ ~r..~ ~ .~.~~,,~~,~~,.,~...s _ Ellipse Start Depth ~~_~..~. .~. .~.,,_ .~__.._~..~,._awM.~.._.~_~~. , ....~ .. ~ ~ ~~~.~.~.._~,~ x._~ ~ 0 00 feet ' Surface Position Uncertamty ~mcluded - ....._, Declmation ,~ ~_.~ ~,~- , , .P_~ ._ ~ r :~_ ~ ~~ z..._.~ ,~ A ... ..,_~ 19 28° East of TN .~.~. ~, ~~~ r,.. n. ~ ~ ~ =_. .e ~.~ W ,~ ~.~..~._~.~. ~.~ vu~a.~e...=~. . ...._ x.. ..«.._ ~~, a,v~~~=~~. ~ ~Dip Angle ' 7 8° ~Magneric Field Strength ; 55487 nT _, ...~.~, ~ ~.~ ~.~ , ~_.~ ~~ 3 4 „r~~, ~ . . .,~~,._~.~.~~. ANTI-COLLISION R ULE Rule Name ~ ,E-type Closest Approach w/Hole&Csg Limit :O~StdDev:3.00 m~Rule Based On m~ ~~Ellipsoid Separation ~ ~w/Surface Uncert ~ .~. ~ . ~ _. .. . -w Plane of Rule ~.~. .n. . .~ _ r._ . j Closest Approach v,. _ _~ ~.w : .. ...~ ~z_. .~ . .~a w _~_ . .~ . ~ ., ,~..., ..,.. . ~. ~ ~Threshold Value ~0.00 feet Subtract Casing & Hole~Size:yes ~~ ~ ~" ~ ~ ~~~ ~° ~~~~ ~~ ~~~~~~~ ~ ~~~ ~~~ ~~~~~~~~~Apply Cone of Safety„no HOLE & CASING SECTIONS Ref Wellborec SU41-15Rd Ref Wellpath: SU41 15Rd Versian #5 String/Diameter ~ Start MD ( End MD ~ Interval i Start TVD ~ End TVD ~ StartN/S £ Start E/W ~ End N/S ; End E1W ~ [feet] __ -- -_ :,.... ~ _._ [feet] a ... . .. . . . [feet] - . . . .. . [feet] [feet] [feet]~ ~ [feet] _.. .. . :~._ ._ _~ . ~ . , . ...,,. ....w. [feet] [feet] ..._ .µ._~_ru ,. ., ..... .. .,,.. , 3.Sin Casing Production 0.00~ , ll634.09i 11634.09° A . , 0.00' 9494 99~ 0.00' 0 00~ 2800.98' 4631.44 . .. , . ~ _ . _ ..... 8.Sin Open Hole 6275.00° .,, 11634.09? .. 5359.09' , : --. ~ ..._._; .~ S611.06, 9494.99 -1132.88: 1595.55' _ .._ .... . . . ..... ... -2800.98 4631.44 ~ c i ~a~~~r~a~ CALCULATION RANGE & CUTOFF Clearance Report Closest Approach SU41-15Rd Version #5 Page 2 of 7 OFFSET WELL CLEARANCE SUMMARY (4 Offset Wellpaths selected) ~ ~ ~ ~~~cE~ r~uc~~~~ I~T'T~Q Offset Offset Offset Offset Offset Ref Min GC Diverging Ref MD of Min GC Min GC ACR Facility Slot Well Wellbore WeRpath MD Clear Dist from MD Min GC Ell Sep Ell Sep Status [feet] [feet] [feet] Ell Sep [feet] Dvrg from (feet] [feet] , __ m, r_,. Pad 43 9 Slot #SU43 9X ~ SU43 9X ~ SU43-9X ~ a . . .~. .", ._ aviTrak <151 1943 > _ _.. 3 ~ w~. _.. 275 00 ~ _.... ~. 522 20 . _~_ 275 00 , u~ 6275 00 ; __~,~ 4496.28 ~ . . eK~ ._ ~Y. 6275 00 ~ PASS Pad 43 9~ slot #SU32 9' SU32 9 E SU32 9 ti_ _.. ~MWD <0 6858> ~, i 6275 00 ~ 3525 41 ~ ,. 6275 00 € _~.m u. 6275 00 „ 3474 60 ! 6275 00 I PASS Pad 43 9~ slot #SU41 15 ~ SU41 15 ~ SU41 15 ~ 1 MWD <0 12600> ~ 6275 00 ~ t 0 00 ~ 11375 00 E 6283 03 ` ~:~~ ~ 11591 00 ~~'AT~, ; ` _....__, ~., .,_ .~ _ ,, _ _...~ . , Pad 43-9 ~ sloY #SU43 9; SU43-9 ; SU43-9 ~_ _._ ~.....m ._.. ..,.. .. ~Totco Incl. Surveys <0 6202 > 4 6275.00 ~ 2038.87 ~ 6275.00 ; 6275.00 1766.55 ; _."..r.,:..~.p..,,...d. 6275.00 j PASS SURVEY PROGRAM Ref Wellbore: 5U41-15Rd Ref Wellpath: SU41-15Rd Version #5 ~ ; ~ ~ ~._ _ ~ . , _~_r ~ _ ~.~ .. , , ._w e ~ 4, . ~ ~ ~ _ ~~r ~ _ ,~ .. . . _ ~,. ~. _ F Start MD ~ End MD iv~ i positional Uncertainty Model ~ Log Name/Comment i Wellbore ~ [feet] ~ [feet] ~ ~ ._ . . , ~,m u .; . r . . _... _ . __~._. . _ . . ... , _ 9 ~. .. . ,.e - _ ., _, ~ m ,..~, ~ ,a; € 9 00; 6275.001NaviTrak (Standard) ' °,SU41 15 . ~~._~~ ti yx~~ ,~. _.r_ _.~~ ... =.~a _Y.~ ~. M_ _~ _ ..,~ ..~. a~. ~~. ~ .~~. ~ .,~., .~~~~.~ .r.._ ~,..v~F~. . ,~_~., ; 6275 OOa ll634.09~1aviTrak (Standard) ~ ~SU41-15Rd ~ ~ +MARATHt~N Clearance Report Closest Approach SU41-15Rd Version #5 Page 3 of 7 EiATHON Oil Company k Inlet, Alaska (Kenai Penninsula) ling Gas Field (NAD83) ~ ~ ._5..~ ..:r-. . v_- _.-_ . ~~~v.-_ 43-9 ot ~slot #SU41-15 ~ ell. ._ , ,. _ __ 'SU41-15 ~~._ ~u. e _. ~.,.~ ., . ~_.. , . . . .~. . a v . .~ ... .. ~~ . . . __~. . .. ... ellbore =SU41-15Rd ~etrack from~SU41-15 at 6269.50 MD CLEARANCE DATA - Offset Wellbore: SU43-9X Offset Wellpath: NaviTrak <151-1943'> Facility: Pad 43-9 Slot: Slot #SU43-9X Well: SU43-9X Threshold Value=0.00 feet ~' = interpolated/extrapolated station ~~ B~t~(ER ~uc~~~~ Il'~'~`'EQ Ref Ref Ref Ref Offset Offset Offset Offset Horiz C-C Clear Dist Ellipse ACR MASD ACR MD TVD North East MD TVD North East Bearing [feet] Sep [feet] Statu~ [feet] [feet] [feet] [feet] [feet] [feet] [feet] [feet] [°1 [feet] 6275 00 ~ 56ll 06j 1132 88; 1595 55~ 1943 00~ 1831 16~ ~~~~ ~~~~~~~ ~ 74 73' ~~~~~ ~~~ Ry , _vLL`} „ , µ ~y= v , ~ 206 32~ 313 46! 4522 20~ 4496 28~ ~~ ~ ~~~~~ _ . ~_..~~ ~.._.~ 25 91~ PASS GC Clearance Distance Cutoff: 1000.00 feet ~~~~~ ~~~~~~~~~~~~~~~~ ~~~~~~~~'~' ~~~~~~ WELLPATH COMPOSITION Offset Wellbore. S ~. ..__~,~, ~ , _..,~,. U43-9X Offset Wellpath: NaviTrak <151-1943'> ~~, -. ~ru._ ~.. „~.,. Start MD ~ End MD ~ Positional Uncert _ ..~ . ain Model ~' v~ u__~,~h..~ ~...vY_w~ ~.,~~.~,y.~z, _ ~,wz ~~f~ ~~~Lo Name/Comment g . a., ~..._...:,~ ~ ~ Wellbore feet ~ l ~ [feet] ~ ~ ~s .~ ~_ ~.~~ ~~ ~~. .~., ~...x 0 00 ~ 1943.00 ~NaviTrak (Magcorrl) ~uP_.. _ ._ ~ _~~.~~, ...wr_. ~~v~,.~.~, a.~-s,~ .,, ~..._,~.~e. ~~ u ~NaviTrak <151-2000'> mb _.,..~~~ ,~u~~ SU43-9X ~~ ~ OFFSET WELLPATH MD REFERENCE Offset Wellbore: SU43-9X Offset Wellpath: NaviTrak <151-1943'> ~ ~ ~ns ~~ ~:.~ ~.~~,y ~ _ ~ ..~. ~,a ~._~_~ ~.,_~.w..~. ~_ .~,_v_~ ~. _.~.-. .~ ~.~,~ ~_.~,.~. ~~~~a~~.~.,,, ,~.~~as..~. MD Reference: Glacier #1 (RKB) ~Offset TVD & local coordinates use Reference Wellpath settings ~(See WELLPATHDATUMon pa,ge 1 ofthis report) ~ ~1{t~'ATHt~~ Clearance Report Closest Approach SU41-15Rd Version #5 Page 4 of 7 ~ B~-K~R ~u~~~s II~T'~`E(~- CLEARANCE DATA - Offset Wellbore: SU32-9 Offset Wellpath: MWD <0-6858> Facility: Pad 43-9 Slot: slot #SU32-9 Well: SU32-9 Threshold Value=0.00 feet ~' = interpolated/extrapolated station Ref Ref Ref Ref Offset Offset Offset Offset Horiz GC Clear Dist Ellipse ACR MASD ACR MD TVD North East MD TVD North East Bearing [feet] Sep [feet] Status 6275 00 ~ 5611 06; 1132 88j 1595 55; 4525 19~ 4215 53a 236 36' 1338 09, 295 02; 3525 413 3474 60' S0 82~ PASS ,~ ~~~.~ ~~~..~~~ ~~,~.<. ,~~,~.~, .~~...~ _~,,d v G~.~..M-~. ~ GC Clearance Distance Cutoff. 1000.00 feet ~'~~ ` ~~ ~ ` " " „` "`~'~`~. .v.~,..E ~__~~~: __~. .. ~~~z~w ,~ ~ _,~. ~.,~, .~~~ ,r„.a~_~~~.~,.~,,~ a~,e~ WELLPATH COMPOSITION Offset Wellbore. SU32-9 Offset Wellpath: MWD <0-6858> ~ _.~..~, __ _ x~ ,. ., ~ ~ e~ _ ~ ~~~_~ ~ _.- ~ Start MD~$ ~ End MD Positional Uncertainty Model ~~f ` ML~i~ -x Log Name/Comment 0.00 ~ 6858.00 j NaviTrak (Standard) ; MWD <0-6858> OFFSET WELLPATH MD REFERENCE - Offset Wellbore: SU32-9 Offset Wellpath: MWD <0-6858> MD Reference: Nabors #160 (RKB) Offset TVD ~& local coordinates use Reference Wellpath settings ~ ~(See WELLPATHDATUMon page 1 of this report) . Wellbore SU32-9 MARATH01~ ltATHON Oil ~ k Inlet, Alaska ling Gas Fie-d _._ ~ - 43-9 _ ;Well t #SU41-15 _ _, __. 41-IS _ __ 41-15Rd ,__. - .-. . _. - - 41-15 at 6269.50 MD ~~~ ~AKER _ ~~~~~~ ~~~~Q CLEARANCE DATA - Offset Wellbore: SU41-15 Offset Wellpath: MWD <0-12600> Facility: Pad 43-9 Slot: slot #SU41-15 Well: SU41-15 Threshold Value=0.00 feet -~ = interpolated/extrapolated station Ref Ref Ref Ref Offset Offset Offset Offset Horiz C-C Clear Dist Ellipse ACR MASD ACR MD TVD North East MD TVD North East Bearing [feet] Sep [feet] Status [feet] [feet]. [feet] [feet] [feet], F. [feet] [feet] [feet] . [°] , , eS . [feet] _ - ~_ _ ___ ~6275 00 ; 5611.06~ -1132 883 1595.55; 6275.00~ 5611.06~ -1132 88~ 1595.55~ 124 971 0.00~ L40g 1.40~ RAIL ~~ . ~ _ ~ __ , _~._ .., , _ Nrt.~ _;~ ,~~w,~_. -. '6283.03 ; 5616.89~ -1136 00: 160010~ 6283.03; 5616.92 -1136 02i 1600.04~ 252 92~ 0 07 2.35 2.47. FAIL ~ _ q . . ._ __ . .. ... ~_. ~ ._ . ...., _. . .~,._ ~m~.~ ._. ~,.._ ~_ ~ - _.. ?6295.00 ; 5625.45; -1140 59; 1607.09~ 6294.99{ 5625.65: 1140.70' 1606.76, 251 91~ 0.41° -1.53~ 1.94 FATL ;6375 00 f( 5681 06+ 1171 00 1655 90 6374 86 5683.91 1171 75~ 1651 71 ~ 259 91 ~ 5 12, 1 13; 4 00 PASS ~~~;~~~~"7:~~` ~~b6, ~~~~ ~~~~=: 575~:._ ~~~~'~~ r. ~ ~~ -~~~~ ~ ~~ ~ t. i ~ . , ~ .~. _, ~ .:~ _r~ ~ ~ ~~~;~~~~+,~~ _._ , .. ...~.: ~,. . _ .. '6575.OOt; 5809.91 1247 08 1788.47` 6572.98' S82834~ -1248.63~ 1763 43r 266 47~ ~J 31 13~ ~ 20.50, 10 63 PASS ~ , . ~. _. _.... .__.,~~_____, _ .~__ ._. . ___._._ . .___,_, ~. , .._ .. f j E __ 6742.~70 } 5905.94 -1380 46? 191039f 6735.78~ 5947.02 -13g333~ 1854.16~ ~ 267 073 69 70~ 53.61~ 16.09~ PASS ~ ~PASS _ ,~ _. ;6775.OOj-; 592333 -1322 59 1934.76; 6766.72; 5969.57p -1325.84~~ 1871 25< 267 07: 78 63~ 61.SSj 17.07j PASS F ~ 6875.OQ±!: 5977.17 ~~Q I~ ~~~~~ ~£?S~a~~`~~~~.~~~~~{ j ~,,;~I~G~ ~~~..~ ~~~ ~ ~ L ~ ~ ~ ~~~, - -_ - _- - ~ - ~ - - -- -~. ~-r - - ,6975.00 j- 6031.00 -1397 74; 2085 62, 6954 19, 6106.04~ -1406.47 1971.27~ 265 63: 137.05j 112.72} 24.33( PASS ;7075 00 j~!, 6084.84 1435 31 2161 OS 7050 07; 6175.59- 1450 79 2020.21 263 73 168 27; 139.44~ 28 82~ PASS ~ _ __ -_ . ~- - f __- i._ --{ - - ~ - __ - _ ---- - _ - -- --- ;7175 00~} 6138.67 -1472 88 2236 49; 7148 47' 6246.84: 1494.77= 2071.89~ 262 42 198 17~ 164.99~ 33 17( PASS _ ,. ~-- -- --- __ _. __, _.._~ ;_... ~ . . ..._._ - - - - - °-°-- ~7275 OOt~ 6192.51 -1510 45; 2311.92: 7243 84; 6315.81; -1536 36! 2122.931, 262 19; 227.14j 190.13~ 37 O1, PASS '~~~'~~~~~ ~~~ ~~~~ ='~~~ ~ > t~~~~~W _ 1~ ~ ~,+ ~~ £ ~ ~~ :~ ~~SS,; _ _ _ ~_ _.._ __...:_ ~.. ~ _ _~_ . !7475 00~-, 6300 18; 1585 59 2462 79; 7434 21; 6453 87~ -1620 61% 222337 261.68; 286.65, 241.94~i ~ 44 71; PASS , ~_~ ... . . , _ _.~~ ----~ __. _. _.,v _~_ _~ .. ~ . . ._.,~,_~_ ,-_ - -°°---- -- 575 00 r 6354 02 1623.17. 2538.22 7532 57 6525.41 -1662 79~ 2275 98; 261.4L 315 78 26739~ , 48 38 PASS , . ~a. _..... . . _ . . _ . _ ___.., _ _. w _ _._ _.._. ___ .~_ _ ..~ . ~. . . 7675 00 i 6407.85 1660 74: 2613 65 7627 73 6594 ~ ~'~ 86~ -1702.67- 2327 46i 261 67i 344.44~ 292.68~ 51 76~' PASS - ~. , _. i7775 00 6461 69 1698 31 2689 08 7721 48 6663 42, 1742 13 2377 74~ 261 99 373 57 318 4 "~~`~~~..~1, ~~~~~ ~ ~~~ ~f~,~~ ~~~~~~ ~3 ~r~~~ 17$1 1~+ ~ ~~Q ~ ~ k ~~ ~ ~~~ ~-~ _. r..~ ~~ -... . :" ~ ~'.~ '~~ ~ ~~ ~ ~ ~~~ ~~~~~~~'~Sg 55 12 PASS ~~ ~ ~~ . _. _... ~~ ' 975 00~' 656936= -1773.45 2839.95 7909.97 6801.60~ -1822.57' 2477.56; 262.28~ ~ 433 21~ 371.12~ 62.09° PASS _ ~ ~. __. . ,. ._ ...~... I8075 OOj-~ 6623 19, -1811 02 291538 ~ 8005 89~ 6871.13~ -1865 30' ~ 2527 99 262 02 ~463 14 397 ll` 66 03~ PASS , -.. _ ., ~ .. ... . _ ~,.__ _ .__~. ~.„ ;._~. .~..,... !8175 00 ~ ((> € _ 77 03 1848 60 2990 82" 8102 86 6940.59~ -1909.95- 2578.80 261.53 492 94 422 64? 70 30 PASS . _ _ _. __ .~ _.. _ __ __ « ~ ~~_ ~._ . _ _ .__.___.,. ~8205.74 ; 6693.58 1860 14 3014 00; 8133 38 6962.39; -1924.01' 2594.88 26134, 502 00; 430.35~ 71.65° PASS ~~'~~:Q(1 '; f~~~~~ ~ ~~~r~~i~ ~Q6~~ ~~; ~~t~.~~';~. "" ~ ~~~.~~~'~~~ -1955 6A ~tiF~~~~~'~~~ .~~~~,~~~~'~.~ ~~~_ ~'~~~~-~~Ft~~~~~°~~~~ ~ _ ~_ ._ ~ 1 '. ~ 8375 00 ~ _.v: ~.. _ a_. . ~~ _ ,8475.00 6788.33 -1923 01 313935. 8302 44: 7083.09' -2000.54 2685 23 260.31 546 92: 467.78' 79.14 PASS - _ . _ _ _ . _- _ _ _ __ . __ ~-, 6847.66 -1959.43 3211.14 8402.09; 7154.61? -2043.95 273930 259.84 569.20~ 485.74~ 83.46, PASS -- _ . . _ __---- -----..._. 8575.00j~; 6909.41 -1995.27 3281.15 8501.9&' 7226.80; -2086.08 2794.02 259.44 588.45° 500.76, 87.69,PASS _ . _ --- -- - - -- --.. ,8675.00 j~; 6973.52' -2030.50 334932 8601.93; 7299.26; -2127.431 2849.08 259.03 604.77; 512.84; 91.94'; PASS 8775.~j~ '~{13~.94 ~~55.08 ~~~~, $T#~~.~~" ~ ~~'~'~-.~3'. '. ~~°~~$.~~ 2904.6ti ~~~~ _: ~~~~ - ~~'~~~~ ~~__ '~`~v~~~ 8875.00~ 7108.59 -2098.98 347992` 8798.11?; 7441.72' -2207.68'~' 2957.49 258.25 629.06' S2830. 100.75; PASS ,. .. _ _ . __..... _ ._ _ . __ - - _ __ - - - - ~ - -__ '8975.OOf, 7179.42 -2132.17 3542.21 8893.52` 7510.42, -2248.57 3009.47 257.68 637.90; 532.133 105.77~ PASS - _ ___ _ - - '9075.OOt 7252.36 -2164.62 3602.42 9000.82 758733 -2295.40 3067.86 256.25 644.26 532.58' 111.67 PASS __ _ __ -- _ 9175.00 j 7327.35 -2196.30 3660.50 9116.74 7670.63 -2342.46 3133.33 254.50 645.85. 528.28 117.57 PASS - 427S.QO~t 7~t(I~1.30 -2~22.18 37I~.3~ ~~~ 7745.14 -2382.48 3193.42 2~~~#6 - ~~'_ 52~}~ _~2.98 PASS _ .._.--- - . __ - 9375.OOj~ 7483.16 -2257.23 3770.04 9322.44 7818.09 -2421.62 3252.91 25237 637.67 509.00 128.66 PASS _. 9475.00~ 7563.84 -2286.43 382139 9416.08 7885.10 -2457.87 330736 251.56 629.94 495.41. 134.53 PASS 9575.00~ 7646.28 -2314.74 3870.40' 9509.51; 7952.12 -2494.69 3361.05 250.54 620.77 479.89; 140.89 PASS _ - - - -- - __ _ _ . _ . _ _ - ~_ - - _ _ 9675.00~ 773039 -2342.13 3917.03 9608A1 8022.76 -2533.92 341739 249.00 609.84r 461.87 147.97 PASS • • Clearance Report Closest Approach SU41-15Rd Version #5 Page 5 of 7 C-C Clearance Distance Cutoff: 1000.00 feet ~~a~-~r~oN ItATHON Oil Company _ ,.....w__ .~_.__.. k Inlet, Alaska (Kenai Penninsula) ~ .~....__ .... ling Gas Field (NAD83) _ _ - - -- -- ,--._ ~.~v__.~_.~. 43-9 ~ • Clearance Report Closest Approach SU41-15Rd Version #5 Page 6 of 7 ~~ BA~Et~ _.~ue~NES~ ~1~11T~Q ?slot #SU41-15 __ __......_~_~~_..,_.__. 'SU41-15 _ _ . ......,W. , SU41-15Rd --- : ,. - --x~ -.. c from'SU41-15 at 6269.50 MD CLEARANCE DATA - Offset Wellbore: SU41-15 Offset Wellpath: MWD <0-12600> Facility: Pad 43-9 Slot: slot #SU41-15 Well: SU41-15 Threshold Value=0.00 feet -~ = interpolated/extrapolated station Ref MD Ref Ref Ref Offset Offset Offset Offset Horiz C-C Clear Dist Ellipse ACR MASD ACR [feet] TVD North East MD TVD North East Bearing [feet] Sep [feet] Statu~ [feet] [feet] [feet] [feet] [feet] [feet] [feet] (°] ~feet] _ ~ _ . _ n . ., ,., _~. . ~ _. A. ~ _.. r. ,. _ . 9875.00~-: 7903.32, 2394 09~ 4002 96~ 9788.55; 8151.46~ -2607.90~ 3520.02~ 246.12; 583.54; 420.00~ 163 54; PASS ; ~ _ , . . o.~. . . . ., , < _ ... ,.i ... . ... , p . ., . -~ . , ~ ... 9975.00~ 7991.97 2418 61 4042 17 9884 87 .~ . , . ,. _, _ r._ . .. _ . _ .. m .. 3 1 . _ . .. _ ,..... , 10072.81 8080.00 2441 61s 4078 07; 9980.32I 8220.26; -2648.96; 3573.53~ 243 82a 569 929 397.31j 172.60~ PASS ; 8289.77~ -2687.27~ 3626.41 ~ 241 46; 555.29~ 373.84~ 181.453 PASS 10075 00~, 8081.98 2442 11 4078 85 9982 29 8291.28~ -2688.07; 3627 55~ 24] 41 554 95 373 31 ~ 181 64~ PASS ~~~~~i~~~~~~a~~~~~~~~s ~~`~ ~~~r~~~`~~~~~~ ~~~:~~`, -z~~1.~~~`~~~~~'~~~~~ ~ ~_,~~ ~ ~~'~z ,~~~ > ._~~~~~~°~~ ~ ~ ~ ~ ..~ ~ . .. . 10275.00-~~ 8263.24~ -2488 15` 4149 73 10164.28; 8427.86` -2757.50 3725.72, 237 58~ 528.62~ 330.26s 198.36' PASS _ _ ...._ - . . __ __~ . _,_ _.. 10375.00 8353.88 251 ~ ~ ~ ~ ~- ~ ~ ~ ~ ~ ~~ -~~ `- 1 17~ 4185.18" 10260 91Il 8502.28~ -279212~ 3776.SSt 235 49~ 517 62; 31132~ 206 30;~ PASS _, _ ~ _ __ . _. -- - - ~_ , 10475.00-~E 8444_51 -2534.18' 4220.62' 10349.65- 8571.52i -2823.55' 3822.47~ 233.99- 50832; 294.77~ 21~.55=PASS _. _ _ . _ _ _ . 10575.00-~; 8535.14 2557 20 4256.06 10438 64 8641.12 -2856 12 3867.37 232 44 501 66 280 88; 220 78< PASS ~~~~ s~~~fi~ ~~ir~ ~~gi.si ias3~~ ~~~~; --zs~1 ~a;'.,~~~1~:~~~ - ~ =~~~,=~ ~~~~~~~~'~~ - - - - - _ - 10775 00t~ 8716.40; -2603.24' 4326.95~ 10639 15; 8800.80; -2927.11; 3965.60~ 228 13' 492 54j 257.80~ 234 74; PASS - - 10875 00-~ 8807.03 -2626.25 4362.40 10734 73; 887934; -2957.45I 4010.83~ 226 71; 488 38' 247.93~ 240 46i PASS _-~ - _ _ _- - - -- . _ __ 10975.00~ 8897.66, -2649.27 4397.84 1083031y 8958.96` -2987.17; 4054.55~ 22545= 485.57; 239.85~ 245.72~PASS ll 038 27 8955.00; -2663.83. 4420 26' 10893.711 9012.21 -3006.42~ 4083.08~ 224.55'Y~ ~ 484.08' 235.14~ 248.95~ PASS ~~~~~ ~~~~ '~~~~~ ~4~~~~ ~~~~~+~= ~{1k4~~~~ ~-3U1'~ ~i,'~_ 409 :~ ~ '"-~~~~~`~~~`~'~ ~ .~~_....~.__ ~r'~~~~r~~ ~ , _ _. _ - _ _. -~. _ . ._. .,~ ~ . _.__ k_~ ~~~,~~ w._F_ - _ ... M. 11175 00 j~, 9078.92~ 2695 31 4468 73 11029 96~ 9127.76; -3046 22i 4143.38~ 222 83, 481 02~ 225.56~ 255.46; PASS _ _.> > .. _ ~ __ _-- °. ~~ ~r . .. ~. ~ _. . . ~ ,~...~.. ~ _..~~.~_. ~_ 11275 00 j- 9169.55 2718 32 4504 17 11127 75~ 9211.93 -3073 38' 4185.02 221 95 479.29 219.56~ 259 73~PASS _ ~ m ~ _ . .... ..._ m~,. , ~ _._ _ _ _ 11375 00~- 9260.18: -2741.34' 4539.61' 1122039; 9292.74$ -3098.25~ 4222 86~ 221 59: 478 31~ 214.75~ 263.56g PASS 11475 OOt 9350.81 2764 36, 4575 06 11309 33' 9370.93 312~y3 19i 4257 16, 221 54 479 82 2yy12 81! 267 O1~ PASS ~~~~~~~R'~1+~'~~ ~~~~ ~~i~h,~i`JV~~ ~~ ~1~~~~ 7"fv2~*<~~~~~ ~i.~~lW~~~~.~ h ~ ~ ~ ~~ ~ ~~L~ a'., ~ iY~;M1~~qv+'4~Wk~.y~~~+~ ~~~$: 11634.09 9495.00 -2800.98 4631.45 ll466.74~ 9510.79- -3167.03; 4314.51 ~220.89 484.46 212.20` 272.26: PASS _ ~ . =. _, ~ . . ,:. . _,. .. ,- --- - -- ==-,>- : _ GC Clearance Distance Cutoff: 1000.00 feet HOLE & CASING SECTIONS Offset Wellbore: SU41-15 Offset Wellpath: MWD <0-12600> ~ --__ ._ ~__. - -- v~. _- __ ___ . _ - -- - ---- _ . _ _~ __ _ ~ ~~~ ~~ ~ ;String/Diameter Start MD End MD 3 Interval : Start TVD End TVD Start N/S ' Start E/W End N/S End E/W : ; [feet] [feetj r [feet] ' [feetJ [feet] (feet] [feet] ~ [feet] [feet] ~ ,- --- - -- _ _ _ ~ --- - _ _ :_, __ .: _ _ _ ..__.~ :- - : ;20in Conductor -9.00 49.00 58.00; -9.00 49.00 0.00 0.00 -0.01, 0.03 ,, _ _ _ . - --- _. . _~ ..._. . __ ~._.. ---~_ ~ ;13.375in Casing Surface -9.00 2262.00 2271.00; -9.00 2261.28 0.00 0.00: -13.71, 6.99 - . _ _ __ __ ----- -- ___ _ _ _ _ __ _ --- - - -- ;9.625in Casing Intermediate -9.00 10303.00° 10312.00'i -9.00- 8535.13 0.00 0.00' -855.55~ 1157.78 ,.. _ __ _ - ,.. ;7m Liner 10099.00 12581.00: 2482.00 8378.30 10540.62 -833.05 1125.00 -1037.89` 1421.98; WELLPATH COMPOSITION Offset Wellbore: SU41-15 Offset Wellpath: MWD <0-12600> ' _ , __. _ _ _ _ _ .. _____ ..._.. .. _ _6 . , ~. ` St~ft~MD E~ d~MD Positional Uncertainty Model Lo Name/Comment ~ Welibore ; . ._....~ . _ .._ ..._ .._ . _ ~....:. . ,.. r,,. , ...... . . __~ ....... . .:.:.~. j'-.. 9.00 12591.00 NaviTrak Standard MWD <0 - 126 - ( ) ' 00> .SU41 15 Q -- ..- . ~ OFFSET WELLPATH MD REFERENCE - Offset Wellbore: SU41-15 Offset Wellpath: MWD <0-12600> ~ ___. _ _ _. _ _ _r :MD Reference: Glacier #1 (RKB) Offset TVD & local coordinates use Reference Wellpath settings ~ ;(See WELLPATHDATUMon page 1 of this report) ? =- _-_ _ _ _ ___ _ . . , _ - _ _ ._: _ :_ - -- ,~~ ~ ~ ;N1AR,A-1'MQ~ Clearance Report Closest Approach SU41-15Rd Version #5 Page 7 of 7 ~~ B~I(Ei~ ~~~~~~ I~T~~ CLEARANCE DATA - Offset Wellbore: SU43-9 Offset Wellpath: Totco Incl. Surveys <0-6202'> Facility: Pad 43-9 Slot: slot #SU43-9 Well: SU43-9 Threshold Value=0.00 feet ~ = interpolated/extrapolated station Ref Ref Ref Ref Offset Offset Offset Offset Horiz C-C Clear Dist Ellipse ACR MASD ACR MD TVD North East MD TVD North East Bearing [feet] Sep (feet] Status 6275 00 , 5611 06~ 1132 88! 1595 55~ 5618.47 C C Clearance Distance Cutoff: 1000.00 feet zet] [°] [feet] ~a.,r{ _ y_~..~_v. ~.N . _...._,.M ._u, e .~. , ...~_~...W_,. 1I15; 308OO~T~~m 2038.87~~ 1766.55, ~~ 272.33~PASS HOLE & CASING SECTIONS Offset Wellbore: SU43-9 Offset Wellpath; Totco Incl. Surveys <0 -6202'> uw z ~ String/D-ameter ~ , ~ Start MD ' ~_ End MD ~ Interval ~ ~ Start TVD ~End TVD ~ Start N/S ~St art E/W ~ . .. .u .~._~ End N/S ` End E/W .~.., ~ ~ ~ ~ [feet] ~ ,~ , ~_< [feet] ~ - [feet] ~ _. [feet] ~ [feet] ~ ._.._.. .~x ,..,.. . ..:. [feet] ~ ,~.uwy, ~ (feet] ~ ~ ~ .~ [feet] ~ ~~_n., [feet] ._....~w ___., 12 25in Open Hole i 0.00' 1272 00~ 1272 00~ 18 30? 1290 27~ ~ 57 69 _ 52 99~ 58 61 ~ _ 50.46 .~. ~ 8 625m Casmg Surface _ ... -N ~ 0 00~ 1272 00~ ~ u , 1272 00~ w .. - -~~.~.~„~_ ~ ~ 18 30 B 1290 27; ~ ~ ~ s~.~ w - 57 69 ~ ,,~~ a~~ 52 99 ~ a, ~,. = r g . 58 61 ~ _nW ~ ti _~a 50.46 875in Open Hole _ _ ~ 0.00~ 202 00 _~ 6202 00~ ~_..._ ov ~..~ 18 30~ 6219 28~ ~~ .. ~ 57 69~ _._ ~ -52 99~ ... 66 90~ E ._ ~_. 27 70 w. ....li_ ._.._~ _.. .._a_ S.Sin Casing Production ., .__ . ,_ ~.... ; 0.00; .._ M~ e 6202.00 j .. . ._._. 6202.00 ~ ., ..., _._.~ 18.30 ~ 6219.28 ~ v.~.~~,_ ~ . .. ~ 57.69, ~.. __. ~ -52.99 ~ ~ ..__.._ M 66.90 i ... _~__.._..~ -27.70 WELLPATH COMPOSITION Offset Wellbore: SU43-9 Offset Wellpath: Totco Incl. 5urveys <0-6202'> ~ ~...~m.. _~ ~~.~ w._~. ~_.~. _~~_~_ ~ _.___~ _.~...... w~~ w.,_.___~~~ _~__ ~ y._~ ~ . _ € Start MD ~ End MD ~ Positional Uncertainty~Model ~ ~ Log Name/Comment w~v~~ ~ -~~ Wellbore s [feet] __5...:.. n ~feet] _ ..~ `. ._. . _ m.._ ___ _. ~m.m,.~_., ~ -._ ~..~, ... ~_ ~_.__._ . ~~.~ ~ _ ~. .~_ , ...._.~.~ ._ . _.__. .M .._,,.., ; 0 00 ~ 6202 00 , Alaska, Drift Indicator Surveys j Totco Surveys <0-6202'> ~ SU43-9 OFFSET WELLPATH MD REFERENCE - Offset Weltbore: SU43-9 Offset Wellpath: Totco Incl. Surveys <0-6202'> .~~. ~.. ~~. ~ _,....~ . ~,~~,_ .. ~A.._,._ .,,.,_.. ~~, ~~_~ ,...~. ~~ .~„~,.~~ ~MD Reference: Santa Fe Drilling(1963) (RKB) ~Offset TVD & local coordinates use Reference Wellpath settings ` ;(See WELLPATHDATUMon paQe 1 ofthis revort) • <Alaska Department of Natural Resources Land Administration System Page 1 of 5 • • state cabir,s ~ ~ ~~ ~ ....._...._ r File Type: AD~ ' File Number: 2497 ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~:~~ ~, ° ~~~,; ~~ ~` Yes r No http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2497&... 6/21 /2007 ~ Alaska Department of Natural Resources Land Administration System Page 2 of 5 • • http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2497&... 6/21 /2007 • Alaska Department of Natural Resources Land Administration System Page 3 of 5 • i http://www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=2497&... 6/21 /2007 a•~ R Alaska Department of Natural Resources Land Administration System Page 4 of 5 • • 5~ ~' Last updated on 06/21/2007. Not sure who to contact? Have a question about DNR? Visit the Public Tr~forrr~atic~n Cent~r. Report technical problems with this page to the Webrnaster. Site optimized for Netscape 7, IE 6 or above. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2497&... 6/21 /2007 ~ ~ M arathan MARATHON Oil Company June 21, 2007 John Norman Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Ave, Suite 100 Anchorage, AK 99501 Reference: Waiver for BOP Regulation 20 ACC 25.035 (e) (1) (b) Field: Sterling Field Well: SU 41-15RD Dear-Mr. Norman Worldwide Drilling North America P.O. Box 31Z8 Houston, TX 77253-3128 Telephone 713-629-6600 Fax 713-499-6737 ~~~~~vE~ .JUN 2 2 2007 ~~aska qil ~ Gas Cnn~. Commissio~ Ancharap~ Marathon is requesting a waiver from the above regulation for SU 41-15RD. We are requesting that the BOP stack be configured with one pipe ram instead of two, due to rig height restrictions in the running of the 3 1/2" production casing. The height restriction involves having rig crew members routing control line and electrical line through the tree adapter flange after the 3 1/2" casing is cemented and the BOP stack is picked up. This is prior to setting the casing on slips and cutting the casing sticking up. These lines control firing of the perForating guns and the monitoring of downhole pressure and temperature in our EXCAPE completion system. Similar waivers have been requested for EXCAPE completion wells in the Kenai Gas Field, Cannery Loop Unit, and Beaver Creek Field and were granted. No problems were encountered while doing this operation on any of the wells. Utilizing the 13 5/8" 5M stack currently found on the Glacier Drilling #1 rig is more than sufficient for the pressures to be encountered. If you require further information, I can be reached at 713-296-3273 or by e-mail at wjtank@marathonoil.com. Sincerely, ~~~ ~- ~'r' Willard J. Tank Advanced Senior Drilling Engineer ~~ ~~~~~~ ~ ~ ~~ ~ ~''~~`~( ~-~ v 3_U~~l SU 41-15RD ~ • Subject: SU 41-15RD From: Thomas Maunder <tom maunder@admin.state.ak.us> D$te: Fri, 22 Jun 2007 11:48:51 -0800 To: Will Tank <wjtank@marathonoil.com> CC: pete Berga <PKBerga@marathonoil.com> Will and Pete, I am finishing review of the sundry to piug 41-15 and was checking the PTD application for the RD. Need one of you to adc3ress a couple of things. 1. On the table of contents, everything is listed as being on page 5. Not really a "big thing". 2. Little bigger thing. Page 8 of 17 is missing. Based on the section numbering this would be 4.6, the drilling program summary. I'd appreciate if you would send in the missing paqe. Email is fine. Tom Maunder, PE ~~ ~ AOGCC ~ ~`~ f~~ `r /~ ~~;Cv'C.:'1~--`~/~~f ~~ ~ ~~~ 1 of 1 6/22/2007 11:49 AM SU 41-15RD Drilling Prognosis.doc ~ • Subject: SU 41-15RD Drilling Prognosis.doc From: "Berga, Pete" <pkberga@marathanoil.com> Date: Fri, 22 Jun 2007 16:29:39 -0500 To: tom maunder@admin.state.ak.us «SU 41-15RD Dritling Prognosis.doc» Not sure how the table of corrtents printed that way. The printer might have eaten page 8. Thanks. Content-Description: SU 41-15RD Drilling Prognosis.doc SU 41-15RD Drilling Prognosis.doc Content-Type: application/msword Content-Encoding: base64 _ __ . . 1 of 1 6/22/2007 3:24 PM cr,~kr,o CheckDate s~~k e~,kr,o v~~ Marathon Oil Company a~~~ uiriesto: Hf1CII Ba ACCOU~S PAYABLE DEPAR7MENT g P. O. Box 22184 Accts Payable Contact Center 1273886 06/12/2007 NCBAS 7780 5001123 ~ Tulsa, OK 74121-2164 0~..,,... o~ o~~ ~~~ HS 1 ~.00~ I 100. 100.00 100. (FOLD ON PERFOflAT10N BELOW AND DETACH CHECK STUB BEFORE DEP0.SITING) ~~^nnn L a~~AU c.~~~ ~~f1 L L afl ~R q~~' fl lR ~ LA Ln~ ~ ~ ~'RAiYS1d[I~'~'A~. L~~"'~'ER CI-~~CKLIST ~%EI.L NAttiiE - ~-~f- /~'.eD P~'D# ~4 ~0~8~ . ~ Devetopment Service E~ lorato ~ ~Yo~e-Conventional We![ P ~' Stratigraphic Z'est Circ[e Appropriate Letter / Paragraphs to be [nclud~d ia "fransmittal Getter ' CEIECK ~ w~r APPLIES ADD-Oi~IS (OPTIOlV S) MULTI LATERAL T'EXT FOR APPROVAL LETTER i ~ i I i t~e per~nit i; for a new we{[bore segment oEexistin~ I O j(IF last two di~its in ~`~etl ~ ~~P[ number are : Pe~it Yo. , APC No. 50- _ _ ; between 60-69) ~ Production shoutd continue to be reported as a function of the ? ~ ~ originat 4P[ number stated above. PILOT f{OLE SPACING EXCEPTION ; DRY DCTCH i SA.tiIPLE i ; I t~ton-Conventional i Wal1 i i[n accordance with ZO A.,4C 2~.OU5(~, a!t record;, data and lo~s ; acquired far the piiot ho(e must be clear(y differentiated in both ; well name ( PE~ and API ~tumber ~~~~~ _____) from records, data and logs ~ acquired for well The perrrtit is approved subje~t to fuli compliactce with 2Q pqC I ; 2~~~». Approval to perforate and aroduce / iniect is contingent ; I upon issuance of a conservation ocder approving a spacing ~ ; exception. assumes the ' ~ Iiabiiity of any protest to the spacing exception that may occur. i ~ Ali dry ditch sacnple sets submitted to the-Eomrnission must be in ; ~ no greater than 30' samQte intecvals &om betow the pecma&ost or ; ( from whece sampies are fnt caught and i0' samp(e interv~als ; ~ through tar~et zones. I j Please note the fo[lawing. specia! condition oP thi; perm~t; ~ productioR or production testing of coa! bed methane is not a1(owed ~ for (name of welI) untit after (Cocnaanv Name) has designed and ~~mpfemented a water weti testing program to provide basetine data ; on water quality and quantity. fComDanY Name} must contact the ! Commission to obtain advance approvat of such water we![ testing cogram, Rev: [!2ji06 C:'jody~tractsmitta!_checki ist Field & Pool STERLING, TYONEK UNDEFINED GAS - 76854 Well Name: STERLING UNIT 41-15rd Program DEV Well bore seg ^ PTD#:2070880 Company MARATHON OIL CO Initial ClassfType DEV 1 PEND GeoArea 820 Unit 51962 On/Off Shore On Annular Disposai ^ Administration 1 Permitfeeattached - Yes - 2 Leasenumberappropriate_________________________________________ Yes__ ___.._____________ 3 Uni_quewell_nameandnumber______ -- Yes_ _____________________________ 4 Welllocatedin_a_d_efined.pool______, - Yes__ _____________________ 5 Welllocatedproperdistan~ef[omdrillingunit_boundary__________________ _____ Yes__ ____.________________.______________________________.___________..___ 6 Well located proper distance f[om other wells_ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ 7 Su_fficientacreageayail_ablein_drillingunit___________________„_____ _____ Yes__ ____. 8 If_deyiated,is_wellboreplat_includetl------------ ------------------ Yes-- ------------------------------------.----------------------- 9 Operator only affe~ted party - - - Yes - - - - - - - - 10 Ope[akorhas_appr_oqriate_bondinforce_________________________________ Yes__ _____BlanketBond#5194234__._________________ ________..___.__________ _____ 11 Permit can be issued without co_nservatign order_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ . . Requires_Spacinq Exception; End Public Comment on July 1,_2007.. _ _ . . . _ _ _ . _ _ _ _ 12 Permikcanbeissuedwithoutadministrative_appr_oval_________________________ Yes _ ________ _ Appr Date 13 Canpermitbeapprovedbefore15-daywait_.____________________________ _ Yes__ .,._.__, ___________________________ ______.____„_______.__,.__._____________ -- ACS 6121l2007 14 Well located within area and_sirata authorized by Injection Ofder # (put 10# in_c_omments)_(For_ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- - 15 Allwellswithin1l4_milearea_ofreviewidentifiQd(Fotservicewellqnly)._________._._ NA___ _____________________________________________________._ 16 Pre-produced injector; duration of pr_e production less than_ 3 months_ (For_se[vice well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - 17 Nonconven.ga_sconformstoA$31,05,030(~.1.A),(~.2.A-D)_____.___________.___ NA___ _______________________________ 18 Conduckorstring_provided___________ ____________________________ InCmp_t ___.__.______ - Engineering 19 Su_rfacecasing.protectsafl_kn4wnUSDW&______________________________ InCmpt .______________. - - -- 20 CMT_v_olade~uate_toci[cul_ateonconductor_&surf_csg_______________________ InCmpf ______________________ - - 21 CMT_v_oladeguate,totie-inlongstringtosurfcsg___________________________ InCmp_t _______._ 22 CMT_willcoyeraliknown_productivehonzons-------__------_-------_-- InCmp_t -----_-----_---------------------------------_------- 23 CasingdesignsadequaSeforC,TB&_permafrost___________________________ InCmp_t ____.__. - - - 24 Adequate tankage_or reserv~ pik - - - - InCmpt - - - - . . . - - - 25 If a_re-d[ill, has.a_ 10-403 for abandonment been apprqved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ InCmpt _ _ _ _ _ _ _ _ _ _ _ -- 26 Adequatewellboreseparation_proposed_________________________.______ InCmpt _,_..______ - 27 Ifdiverterrequired,doesitmeetregulations______________________________ InCmpt _________._____.___ - - - 28 _D_rillingfluid_programschematic&equiplistadequate___._ _________________ InCmpt _______________________________________ - Appr Date 29 BOPEs,_dolhey meet regulation - ~ - - InCmpt - - - - - - - - 30 BOPE_ptess[atingappropriate;testto_(putpsigincomments)_._,_________.____ InCmp_t __________________________________________________.________________.___ 31 Choke_manifoldcomp_lieswlAPl_RP-53(May84)___________ _______________ InCmpt .________,____.,________._____._.._,________.___,__ 32 Workwilloccu[wi~houtoperationshutdown--_------_.-,-_------_----- InCmpt ------_--------------_-----_----_-_-.------------------_---,-,- 33 Is presence_of H2S gas_probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ InCmpt . _ _ _ . . . . . _ 34 MechanicalconditionofwellswithinAORu~rified(Fo[servicewelipnly)______________ InCmpt ___-_--_______.____ -_---__.._.._..__________.__.....__. __________ __ 35 Permit_can bg issued wlo hydrogen_s_u~de measu[es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - Geology 36 Data_presentedonpotentialoverpressurezqnes_________________._________ NA_._ ______,_______.____________________,_________ -- - -- --------- -- - 37 Seismic_analysis_ofshallowgas_zones_________________„___,________.._ NA___ ___.________.______,____ - -- -- Appr Date 38 Seabed.c4ndi6onsurvey_(ifoff_-shoCe)-------- ~ NA--- - -------------- ------------------------- - - ACS 6I2112007 39 Contact namelphone for weekly_p_rogress repprts_ [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ ----- _ _ _ _ _ Will Tank -.713-2~6-3273_ _ , _ _ _ _ _ _ _ _ _ _ _ _ , _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Geologic Engineering Public Commissioner: Date: Co~ ner: Date Commissioner Date ~ d-L~t~ i ~ ~ ~ ^^ ~ N , ~ , , , , , , , , , , , , , , m o m a , , , ~ , , , , , , N N , , , , , a~ ~ , , , ~ , o ~ ~ 3 ~ , ~ ~ ~ ~ ~ ~ ~ , , , , ~ ~ , , , , , ~ , , ~, , ~ ~ ~ a, , w a, ~ ~ N~ ~ ~ , , ~ . . ~ ~ C ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . , ~ ~ , , ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ C ~ ~ ~ ~ , ~j > Q ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ( ~ ~ ~ ~ ~ ~ . _ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ , , ~ ~ ~ ~ ~ , ~ ~ ~~ , ~ ~ ~ , ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ , ~ ~ ~ ~ ~ , ~ ~ ~ ~ %~ ~ ~ ~ , ~ , O~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ , , ~ ~ , ~ ~ , ~ 3~ ~~ N ~ ~~ ~ ~ ~ ~ ~ ~ , ~ O ~ , , ~ , N 0 , N o c~ rn o a~, ~- ~,. 'a °~ i m o , , , , , , , , , ~ ~ a N c, 4 ~ ° Q, o , , , ~ t , ~ , , , , , , , ~ a ~, ~ , ~ , , , 0 ~ O ' , , ' , , , , , , ~ ~ ; V O ° Q- , a , , , ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ ~ ~ ~ ~ ~~ 4~' ~~ ~ , O' ~' ~ ~ ~ ~ ~ ~ Q ~ ~ , ~ , ~ ~ , ~ ~ ~ , , ~ ~ ~ , ~ ~ ~i , , ~ ~ ~ , C , ~ ~ ~' a a' ~ , ~ ~ ~ ~ o ; ; , , , ,~ ; a , , o ~ , ~, ~' ~; m; ; a ; a ~ o N , , , , , ~ , , ~~ , , m , p, ~, ~, o o ,~ , ' 3 , 3' ~ ~ ' ~„ , ; >, ; ; ° ; ~' a ~ °' M' ° ' , co ~ , ~ ~ , ~ ¢ - a, ~, ~ _ , ~ ~ , ~ , , ~ , ~ ~ ~ O, ~ , ~ ~ ~ ~~ ~ ~ ~ ~ ~~ ~ Q, ~ ~~ L, y~ ~ ~ ~ ~ , , , ~ ~ , ~ ~ , ~ , , ~ , , , ~ ~ ~, ~ ~ ~ ~ p: , ~ ~ ~~ ~, ~ ~ ~ ~ ~, ~ C~ ~ f6, ~~ W~ Oi O , ~ tq~ ~~~ N~ , ~ . ~ ~ ~ , ~ , , ~ , j ~ , , ~ E~ ~ ~ X , ~ 4 "_' c~~ o, ~ ~~ ~ ~ ~ , ~ , , , , , o ~ , i '°a rn ~' «° ~ ~' , -O ~ ~ ~ ~ ~ ~ , ~ ~ ~ U~ ~ ~ ~ ' ~ , a~ o ~ ~ ~ ~ N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~, ~ ~~~ ~ ~ ~ ~ 7~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ y~ ~ ~ ~ T~q~ ~ ~ ~ ~ N~ ~ ~~ O~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ , , ~ , ~ ~ ~ ~ , ~ , , ~ ~ ~ ~ ~ ~ 3~ ~ ~ ' ~ ~ ~ , ~ , ~ ~ •~ ~ ~ ~ ~ ~ O ¢ ~ ~ ~ N~ , , , N, , 7~ ~ ~ , L ~ ~ N N I ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ d~ ~ ~ , , ~ , ~ , , ~ ~ ~ , , Z~ ~ ~ ~, ~ ~ ~ ~ ~ Z ~ ~ ~ , ~ Z _ ~ ~ ~ , ~ ~ ~ ~ W~ ~ , , , ~ ~ , ~ , ~~ ~~ ~~ ~~ ~~ ~ ~ , ~ ~ ~~~ ~ ~ ' ~ N ; ~ ~ ~ _~ a. ~ ~ ~ ~ ~ ~ ~ ~ , ~ , ~ ' O, ~ ~ ~ , ~ ~j~ O ~ ~, ~~ ~ ~ ~; ~ ~ N ~~ N, ~ Q; O' ~ ~ i ~ ~ ~ ~ ~ ~ Z J ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ , , ~ ~ , , N ~ ~ ~ ~ , ~ ~~ N~ ~~ .S~ ~ ~ ~~ ~ U o O ~~ py ~~ y, O~ ~ ~ , ~ , ~ , N~ O W~ ~ W tlU c a~ 4~ o o, N , , , , cq ~ ~ p y ~ , ~, ~ cn, ~ ~ .~ •3 N~ ~ ~ ~ m ~ N, ~ , ~ ~ ~ ~ , u i v i c O ; ~ ~r/D fp~ U~ ~ N ~ ~ ~ ~ ~ , ~ ~ ~k~ U~ ~ ~ ~ ~ '~ Di O1 N~ , ~ ~~ , >f N~ N~ . ~ j~ ~ ~ ~ ~ ~ ~ ~ ~ M~ N O ~ , , ~ ~ ~ , ~ ~ ~ ~~ a ~ ~~ ~~ ~ , ~ ~ ~ , , ~ N~ .N~ .~~ V~ , f6~ t6 C . , ~ p_ , , Q ~ ~~ ~~ d~~ ~, ~ ~ ~, Y, N~ ~p~ L, ~ ~ ~ ~ . ~ ~ ~ ~ ~~~ ~ ~ ~ ~ m C9 Z ~ , ~ m, ~, N ~ a cN a' o' 7 ~ V U ' '~' 6 ~ m; ~' o~ 3~ ~ ~ f t ~ ~ ~ ~ c~ ~ a ~ , ~ , ~ , , ~ ~ ~ ~ ~ ~, 'a, ~ ~ ~ ~ , , ~ ~ ~ ~ ~ ~, ~ ~ , y~ N~ , • , ~~ /1~ ~~ ~ a~ m, ~ •X a • ~- ~ ~ ~ Z , m, ~, , , o~~ o rn o , x o, ~ m m, Q , , ,- W , , , ,m,~, , , v ~~,a ~,~, a,m ~ ~,g ,~ a , , , , , , , , , , , , , , ~ ~ ~ , , , , , , , , , , , , , , , , , , , W , ~ , , ~ ~ , , , , , , o , ~ , , , , , , , , , , Q fp~ N N~ f/1~ VA Vi~ N N, N N VJ~ N U)~ U)~ N N y~ N~ ~ N N O ~p~ N~ M N , f ~ , Q Q, Q, ~~ ~ tll~ N Q Q ~ ~ ~~ ~ N~ N, Vl~ f~~ fp~ N, N N tA~ fp~ N~ M~ fp~ Vl~ N Q, N~ N~ N N N ~ ~ ~ O, Q ~ y~ N ~ ~ g~ ~ ~ V1~ Q~ Q~ N~ _ }, }, }, }, ~', }, r, }, }, }, Z, } } Z~ ~ Z~ Z Z Z ~ ~ ~ ~ ~ } , } ~" ~' , ~ ~ ~ Z ~ ~ .~ ~ ~, ~ , ~ ~ ~ ~ Z Z ~ ~ ~ Z ~ Z Z ~' , ~ T ~ ' ~ , ~ a ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ , , ~ ~ ~ ~ ~ ~ ~ , ~ ' ~ y f6 ~ ~ ~ ~ , ~ ~ , , ~ , ~ " ~ T ~ , ~ ~ ~ ~ (~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ ~ W, ~ C O' , ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ . .~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ V, , V~ , ~ ~ ~ , ~ ~ , , ~ ~ ~ ~ ~ ~ , , ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .~ ~ N~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ , ~ ~ ~ , , ~ , ~ , ~ , ~ , , , , , , ~ ~, N, Q, , p, ~ ~ ~ ~ , ~ , ~ ~ ~ , , , , , , ~ ~ ~ , ~ ~ ~ ~ c o V'tA c~ o ; ; ' ; ; ; ~ Q x N; , ; ; ; ~ ; a'~ ~ ~ , , ~, L, , , , , o , , ~ ~ ~ ~ ~ U ~ ;~ ~~ ~, ; ~~ , ~~ ~~ ~~ , ~~ ; ~' 3~ M~~ ,~ ~ ~ , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ 3 ' ~ ~ ~ ° ~ W , , , , O, ~, U C' ~ , , ~ ~ , ~ , , , , , ~' , ~ ~ , , , ~ ~,O' Z , , , ` , , , , , , , o, Z, ~, ~ ' , ai, , , , ~, N: ~ ~, o ~ ~ , Z , ~ , , , , , , , ~' ~r u~i, y, Q a> ~~ N ' m u~ , ~ ~ Q , , , ~ , a; ~, , o, ~ ~ a ? , , ~ , ~ ~ ` , c o, ~ Q , m ~ , a~ ~ ~ , ~ - o . ~ -a, o Q, ~ , N, °? ~ o , c , ~ , m .d; • a~i m u~ , , ~ ~ Y W , ~; , , N - , o ~ ~ , ~ ~ -a a~~ ~ , ~, c , ~ a~ v N ao, , , !«_. a~ ~ , o , ~ M , y~ U~ , N~ ~~ ~ ~~ ~ ~ iA ~ ~ . 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