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196-073
RECEIVED I II NI O\f 2 3 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLE ON REPORT AN `� • la.Well Status: Oil❑ Gas[1] SPLUG ❑ Other ❑ Abandoned [V Suspended L —lb.Well Class: 20nnc 25.105 ,,20AAc 25.11D Development ❑� Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: pr•d•t Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.: 10/11/2015 196-073 �31 S-$5 g 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 10/5/1996 50-133-20474-00-00 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 180'FSL&320'FEL Sec.7,T5N, R11W,SM 11/12/1996 Cannery Loop Unit(CLU)05 Top of Productive Interval: 9.Ref Elevations: KB: 55.1' 17.Field/Pool(s): Cannery Loop Field GL: 21' BF: 20.7' Beluga&Upper Tyonek Gas Pools • Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 2177'FSL,2524'FWL,Sec.8,T5N, R11 W,SM 11,288'MD/10,106'TVD ADL-324602, FEE-TR73 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 272700.5 y- 2388612.8 Zone- 4 •11,424'MD/10,238'TVD• N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 275437.5 y- 2390622.8 Zone- 4 N/A N/A 5.Directional or Inclination Survey: Yes ❑(attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) -MA-- 22. 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 NA cloq+y� I 2:i i 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20" 129 Surf 142' Surf 142' Driven Driven 13-3/8" 61 K-55 Surf 2,970' Surf 2,583' 17-1/2" 1,790 sx 9-5/8" 53.5 L80 Surf 1,212' Surf 1,199' 12-1/4" 1,919 sx 9-5/8" 47 P110 1,212' 9,178' 1,199' 8,003' 12-1/4" 7" 29 N-80 8,974' 11,421' 7,799' 10,245' 8-1/2" 750 sx 24.Open to production or injection? Yes ❑ No ❑✓ 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): N/A N/A 9,655'MD/7,819'ND 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No E• Per 20 AAC 25.283(i)(2)attach electronic and printed information 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: N/A Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate Form 10-407 Revised 11/201594-1Z-10 CONTINUED ON PAGE 2 Submit ORIGINIAL only i #-Xt, rz_10—/ RBDMS':.� NOV 3 0 2015 ,, f� 28.CORE DATA Conventional Co s): Yes ❑ No Q Sidewall Cores: Yes ❑ No 0 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 N/A N/A Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: 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. Contact: Taylor Nasse-777-8354 Email: tnaSSeta7hiIcorp.Com Printed Name: Chad Helgeson Title: Operations Manager P 1 Signature: Phone: 907-777-8405 Date: 1//Z.;V 5 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 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: 09/12/2015 -Saturday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high. RiH w/2-1/2" x 10' bailer and tag at 9,925' KB. Made couple runs out the tubing tail to make sure we had the right pin in to shear bailer bottom.TP- 125 psi. RIH w/2-1/2" x 25' dump bailer with 5 gals of frac sand and tagged bottom at 9,925'. Worked tools and pull out of hole. Bailer did not shear. Rig for standby . 09/13/2015-Sunday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high. RiH w/2-1/2" x 25' bailer with 1-3/4" blind box on bottom and tag at 9,925' KB. Work tools and shear pin. POOH and still had 1.25 gal in bailer. Wait on detergent. RiH w/2-1/2" x 25' bailer with 5 gal sand mixed with detergent with 1-3/4" blind box on bottom and tag at 9,925' KB. Work tools and and broke thru a bridge and set down at 10,009'. Sheared pin but tools were pulling heavy. POOH and bailer was caked with mud. No dump. Cleaned bailer. Ran it again with the same results. Getting different sand. Rig for standby. 09/14/2015 - Monday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. RIH with crushed pebbles and dump bailed 4-1/4 gals at 10,009'. POOH and had 3/4 gal left in bailer. Had couple tight spots in tubings. RIH with braided line brush out the tubing tail to check on obstructions. Clear. POOH. Rig for standby and get different bailer bottom built. 09/15/2015-Tuesday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high. TP 125 psi. RIH with 2-1/2" x 25' crushed pebbles with glass bailer bottom and dump bailed 5 gals at 10,005'. POOH. Good dump. Made 6 more dumps with sand top at 9,957'. Rig for standby. 09/16/2015 -Wednesday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. Dump bailed gravel from 9,957' KB to 9,944' KB-7 dumps. Rig for standby. 09/17/2015 -Thursday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. Dump bailed gravel from 9,938'to 9,920' in 6 runs. Rig for standby. 09/18/2015- Friday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high. TP 125 psi. Dump bail gravel from 9,920' to 9,898' KB in 10 runs. Rig for standby. 09/19/2015 -Saturday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. Dump bail sand from 9,896' KB to 9,850' KB. Ran tubing tail locator and determined that sand top was at 9,850' KB in line with the schematic . Rig for standby. 09/20/2015 -Sunday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. Dump bail sand from 9870' KB to 9,846 KB. 9 runs. Rig for stand by . 09/21/2015- Monday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. Dump bail cement from 9,850' KB to 9,825' KB. 8 runs (40 gals). Rig for standby. 09/23/2015 -Wednesday Meet at office. Mobe to location. PTW and JSA. Rig up lubricator and PT to 250 psi low and 2,500 psi high.TP 125 psi. (Called in by Chris W to do this work). RIH w/tubing tail locator and locate tubing tail and adjusted to schematic. Went down and tag TOC at 9,815' RKB (schematic). RIH w/2.75" GR in short string to 7,100' KB for drift. POOH. Prep to pressure test plug. Rig down lubricator and turn well over to field. 09/24/2015-Thursday Hold safety meeting. Discuss job procedure. Rig up flange X1502 on long string flow line. Open SSV. Install 0-3,000 lb Crystal gauge. Cooling down N2. Pressure test N2 lines to 2,000 psi. Open long string master swab and wing valve. Open N2 valve initial WHP 136 psi. Online down 3.5" tubing at 1,500 scf/min. Close in wing valve 1,553 psi on well. Start 30 minute test @ 1626. 30 minutes pressure at 1706 hrs 1521 psi. Loss of 32 psi. Leave pressure on well. Bleed down N2 lines. RDMO CTU12. Secure gate. Deliver Crystal gauge to Mike Chivers lead operator. 09/25/2015- Friday Pressure on L.S. tubing was 1,532 psi at 0900 hrs. 09/27/2015-Sunday Meet at office and sign in. Mobe to location. PTW,ISA and SIMOPS. Spot equipment and rig up lubricator. Pressure test lubricator to 250 psi low and 2,500 psi high.Arm tubing punch. LS- 320 psi and SS- 135 psi. RIH in long string w/ 1-11/16" x 3' (10 shots)tubing punch and tie into schematic. Run correlation log and send to town. Spot punch from 8,950' to 8,953'. Fired shot and pressure went to 0 psi and then on a vac. Short string stayed the same at 135 psi. POOH, all shots fired. Bled short string to 0 psi. Bled off in about 10 seconds. Rigged up Pollard pump truck (loaded with 55 bbls/6% KCL) to long string and short string to choke then to tank with gas buster. After approx 7 bbls (rate at 1/2 bpm) without any gas or returns from SS, pump pressure increased from 250 psi to 2,000 psi.Talked it over with field foreman/town and brought pressure up to 3,500 psi where it looked like it was moving fluid. Found that it was leaking by pop-off valve back into tank and wasn't moving any fluid. Long string pressure tested to 2,500 psi. During all pumping down long string, the short string never pressured up. Short string stayed at 0 psi. Rigged pump truck up to short string and pumped approx 13 bbls of 6% KCL before SS string pressured up. Bled long string to 0 psi. Secured well and rig all equipment for stand by. Will start again in the morning. LS-0 psi, SS- 35 psi. 09/28/2015 - Monday • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Meet and sign in at office. Mobe to location. SIMOPS, PTW and JSA. Rig up pump truck to short string and pump approx 13 bbls 6% KCL down tubing before it pressured up. Rig up lubricator, pressure test to 250 psi low and 2,500 psi high. LS-0 psi and short string 35 psi after pumping 13 bbls. RIH w/ 1-11/16" x 2'tubing punch (10 holes)to 3,300' and got call to run jet cutter. POOH. RIH w 2.75"jet cutter and tie into long string tubing tally. Run correlation log and send to town. Get ok to jet cut tubing at 7,050'. Spot cutter at 7,050' and put 300 psi on tubing. Fired cutter and lost 300 psi. Picked up 30' and went back down hole slow.Tools set down at 7,050'. Looks like good cut. POOH. Started pumping 6% KCL down long string and got circulation out of short string approx 8 bbls in. Pumped 12 more bbls and ran out of fluid. Waiting on orders to see if we want to punch hole underneath packer on either string. Checked both strings and they are on a vac. Decision was made to tubing punch below packer on long string to get rid of gas. RIH on long string w/ 1-11/16" x 2' tubing punch (10 shots) and tied into long string tubing tally. Ran correlation log and spotted punch from 5,912' to 5,914'.Tubing was on a vac. Fired gun and pressure went to 200 psi and back down to 175 psi. POOH. Lubricator was fluid packed when we got out of hole.All shots fired. Rig down lubricator and turn well over to field. 09/29/2015 -Tuesday Arrive at KGF, meet and sign in. Complete permits and JSA. Take on 45 bbls of PW. RU pump on long string. Bleed tank connected to short string. Bleed 300 psi off short string. Long string pressure was 1,200 psi. Start bleed off of long string to tank, hose froze up, bled gas to system pressure, 70 psi. Then bled to tank and 0 psi. Start pump of 45 bbls on long string. Take on 60 bbls of PW. Pump down SS at 125 psi and got returns on long string at 15 bbls, pumped another 45 bbls. Wait for pressure to build, 100 psi in 1hr. Circulate another 60 bbls down SS to LS. SDFN. 10/03/2015 -Saturday Prep derrick for scoping dn and scope dn derrick. Prep back end of rig for trucks in morning. Clean out pump suction manifolds and cock valves in pumps. Lay over gas buster. Lower roofs on mud pits. Move extra gen set and all the drilling support buildings. Get the back end ready for trucks. 10/04/2015 -Sunday Cont to prep back yard for tear out. Peak trucks/cranes on location at 07:30 am. Held PJSM. Killed rig power and spooled up electric cords. Load and ship cement silos and service shacks, gen 3 and dumpsters. RD HandyBerm, tear out back yard, ship HPU to CLU pad,Total safety RD gas detection equip, RD water line, stage pump skids, pits and gen 3, remove rig mats and clean up liner/felt, lay derrick over, load and ship rig mats+ mud products, lower doghouse. Ship rig mats and poorboy degasser to CLU pad, load and ship Connexs, stage water tank off pad, stage catwalk, spot cranes and pick derrick house, centrifuge and iron roughneck. Cradle BOP stack with crane, pick derrick off carrier, pick carrier off sub, pick sub off pony walls. Load and ship pony walls and mats. Rig 100% RD, 10% moved. Clean up felt and liner around SRU 213B-15, police location for trash and debris. Peak hands layed plywood on south bridge. Rig crew headed to CLU-05RD to lay liner and mats at 2130 hrs. 2 peak hands stayed to finish cleaning and picking up location. Measure out and lay felt, liner, and mats on CLU- 05RD.Also got the pony subs set and the test pump and hydraulic pump spotted under the sub. 10/05/2015- Monday S • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Cont to load floats at Swanson field. Peak on location at 07:00. Held PJSM and began transport to highway. At 09:00 Peak on the highway with sub-base, derrick, doghouse, pits 1 and 3,gen skid and both cranes.Arrived at CLU Pad #1 at 10:00. Spotted cranes and set sub-base on pony walls, set carrier on sub, set derrick on carrier.Set cement barriers around CLU#13.Set water tank and raised doghouse. Spot and hung BOP stack, set HPU skid, set gen skid, set pit module#1. Spotted cmt silos. Transported catwalk, boiler skid, pit#2, upright water tank, iron roughneck, pump skids, rig mats and misc items. Spotted pit module#2 and#3. Cont transporting misc floats to CLU pad.Set boiler skid, cmt water tank, derrick house on board, centrifuge, and pin gas buster skid to pit. Raise roofs on pits. RU mud, air, water, and steam lines. Set stairs on shaker pit and hang gas buster return line. Prep and raise derrick. Spool drilling line back on drwks. Prep to scope up derrick. Pin lower TD rail and scope up derrick. Spot parts Connexs. Unload peak hoses from cuttings box. RU centrifuge lines. Prep derrick for picking up TD. Rig up standpipe manifold and rig tongs. [Put gauges on both long and short string and they both read 0 psi. SS on drillers side, and LS on off drillers side.] 10/06/2015-Tuesday Lay out felt and liner for catwalk. Set catwalk with crane, hang wind walls on pits with crane, hang wind walls on rig floor with crane.Total safety RU gas detection equipment, calibrated and tested same. Fill rig water tank with water, fill upright tank with water. RD and transported office trailers from Swanson field to CLU pad. HandyBerm installed berm around rig. Spot and RU office trailers. Crane released at 14:00. Tuboscope MPI'd topdrive components and torque tube "T". Installed "T" in derrick, MU torque tube. Hung torque bushing and PU MU topdive. Cont transporting excess rig mats and misc items from Swanson. Welder worked on various items in pits. Continue hooking up top drive and service loop. Orient and tighten Kelly hose. Test run TDS in derrick and adjust service loop. Function equipment. Finish rigging up pumps and pits. Cleanup and prep Swanson 213B-15 for handover to production. Check off rig acceptance checklist. Rig up gas buster and choke manifold. Rig accepted @ 03:00 hrs. R/U and test choke manifold. 250 low/4,000 high w/5/10 min hold. Chart and record same. 10/07/2015-Wednesday 410 • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Cont testing choke manifold at 250/4,000 psi for 5-10 minute intervals, on chart. 4 bolt double gate while testing, in prep to turn upper half of stack. RU circ hoses and valves. RU to pump down short string from mud line, and up long string to choke manifold. RU circ line from choke manifold to poorboy degasser. Held PJSM with rig crew on circulating dual string to kill well and potential gas. Broke circ at 135 gpm-242 psi.Took 9 bbls to get returns, some of which was filling degasser vessel, possum belly and ditch in pits. Circulated 2,020 strokes (surface to surface) with no indication of gas. Shut down pump and put gauges on both strings. Initially had 25 psi on long string, 15 psi on short string. Let well sit for 30 minutes while working on BOP stack. Short string bled to zero, long string bled to 15 psi. Bled off long string to zero, well is dead. Hilcorp wellhead rep installed BPV's in both hangers. ND dual string tree. Hanger threads in good shape. Installed protector plates on hanger top then blanking plugs in both hangers. MU 2' spacer spool on wellhead, stabbed BOP stack, NU HCR valves, choke and kill lines. Continue nippling up BOP equipment. Install catch can, bell nipple. M/U both test jt assy w/xo's on catwalk. Install flowline, hole fill & 2" bleeder lines. P/U and install both test jts. C/O upper pipe rams to dual 3-1/2" fixed body rams. Flood BOP stack and choke manifold. Bleed air from system. R/U and shell test equipment. 250 low held but 4,000 high test failed due to leaking connection on long string. Attempted to re-tq and re-test several times with no success. R/D other(short string) test jt and layout. Break and re-tq all connections in stump. P/U and M/U short string test jt. Re-tq connections on short string test jt. 10/08/2015-Thursday Tighten TIW/Dart valve connections on top of test joint. AOGCC Reps Jeff Jones and Guy Cook on location to witness testing. Held PJSM with rig crew on high pressure testing and testing with dual string test joints. Flood stack, choke manifold and lines with water. Test BOPE at 250 low 5 min/4,000 high 10 min.Tested annular at 250/2,500 psi. Had fail pass on CMV#7, /� cycled and re-tested ok. Had failures on 2 sets IBOP hydraulic valves. Koomey test: Sys Psi = 3,075, PSI after closure = 1,450„7D 200 psi attained = 21 sec, full psi attained = 101 sec, 4 bottles average = 2,600 psi. Replace IBOP a third time and failed, replaced IBOP fourth time and test passed. 250 low/4,000 high w/5-10 min hold. Chart and record same. C/O KRV due to fluctuating manifold psi on Koomey. Adjust to 1.500 psi. R/U long bails, Weatherford dual string 200k elevators, dual slips w/operator station. Function same (good). Pull BPV from both strings. Both strings on a vac. M/U both landing jts into dual string hanger. M/U both TIW w/ head pins and R/U to circulate short string. BOLDS on 11" dual string hanger. PJSM, P/U 180K several times before seeing slight movement (1-1/2"). Continue working pipe w/same 1-1/2" movement. Movement increased to 5" while working to a max up wt of 190k. P/U 200K and pulled hanger free w/34" free movement. Work pipe w/ max up wt 220k. Saw 15K wt loss and pulled free. Attempt to circulate w/no success. Pumped away 9.2 bbls total. Shut down and pulled hanger above table w/ 150K up wt. Work string attempting to relax packer element and obtain communication above and below packer. Max up wt 220K @ 7,000' MD (short string). Unable to work past 7,000'. Saw slight sticking when slacking off after picking up to max 220K. Continue working string attempting to relax packer as per ,,t . Baker Rep (Jeff Reed). v� ` V541"1 10/09/2015- Friday . • l ti Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Parked hangers just above the table and monitored well. Fluid dropping in wellbore. Lined up on short string, idled pump and got immediate returns. Shut down, closed rams and lined up to take returns through choke and degasser. 9 bbls into circ pump psi started steady climb and return flow tapered off. At 730 psi shut down pump. Lost 18 bbls. Cont to work pipe 190K up, 70K down. GT packer appears to be released but hanging up at 9-5/8" casing connection at 5,876'. Cont to work pipe with bleeder closed (string takes weight with less travel) and bleeder open (string does not take weight and more travel). Cont to circ down short string but cont to lose returns at 9 bbls away and pressure continues to build. Shut down pump each time at 600 psi. Swapped circ hose to long string. Fluid dropped out of sight in wellbore during that process. Able to fill hole but pressure built to 800 psi in doing so. Bled off and cont to work pipe. Next circulation flow show up from 7%to 10%, and able to circ 11 bbls before pressure built to 600#and returns died off. Filled hole from trip tank and began working pipe with bleeder closed. Had to get aggressive to slack off to usual depth, then on upstroke, pulled to 200K immediately then dropped off like packer is dragging. Cont to drag packer up hole approximately 20'. With packer at 5,876' string weight of 200K did not taper off. Pulled to 240K and held a short period, then it appeared packer drug through the casing collar. String weight dropped to 140K. Pulled up hole another 5', still at 140K up wt. Fluid in wellbore dropped out of sight pretty quick. Broke circ with pump at an idle. At both 9 bbls and 11 bbls into circ we still had good returns and no pressure increase on pump. Shut down pump, closed dual rams and lined up on choke. CBU one time at 135 gpm-349 psi with good returns. Pressure tapered off to 287 psi with no sign of gas at bottoms up. Did have 9.1 ppg fluid coming back with a good amount of foam. Lost 4 bbls over the entire circulation. Shut down pump. Swapped circ hose to short string and CBU one time (out WLEG at 7,025') at 135 gpm-420 psi. Pressure tapered off to 256 psi with no sign of gas at bottoms up. Lost another 4 bbls over entire circulation and no sign of gas. Shut down pump. Opened rams and monitored well for one hour. Initial 1 BPH flow tapered off to static. Held PJSM with rig crew and Weatherford on RU dual string handling tools and lay down tubing. Broke out landing joints and hangers. Broke TIW valves and XO's off landing joints. R/U to laydown dual string. Fluid loss to well for last 12 hours= 34.1 bbls. PJSM, TOH w/3.5" dual string F/7,025'to 5,552' MD. Initial up wt 125K. Saw slight increase (5K) while pulling w/ no significant overpull or hangups to 5,550' MD. Hole took 8.1 bbls over calculated disp. NORM test on tubing being layed down with no radiation detected over background. Shut down and monitor well via trip tank while repairing Weatherford hydraulic power unit due to failed belt on water pump. Continue TOH w/3.5" dual string F/5,552' -1/4,850' MD. Pulley failed on Weatherford power unit, swap out units (15 min). Continue TOH w/tubing F/4,850' -T/ 3,890'. Hole took 17.5 bbls over calculated disp. 10/10/2015 -Saturday • ! Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-05 50-133-20474-00 196-073 9/12/15 10/11/15 Daily Operations: Cont POOH LD 3-1/2" dual string completion from 3,890'to the Baker GT dual string packer at 1,278'. Attempt to backout pup joints below packer and in top of full length joints. Long string mandrel would not turn inside packer. Short string mandrel would turn.Were able to backout short string pup about half way but strings were in a bind in the short span between slips and packer bottom. Used pipe spreader to open up between strings and inserted 4" x 4" piece of wood, then used large tubing cutter to cut long string just above full joint. With entire assembly hanging on single joint elevator, we were able to back out pup joint and packer from short string with pipe wrench. Latched up the second single joint elevators onto long string above packer and laid entire assembly down. Cont to POOH LD remaining 3-1/2" dual string completion from 1,278'to WLEG on short string, and cut off tubing stub on long string. Cut off jt 26.95'. Est top long string left in hole @ 7,056' as per tubing tally. R/D and laydown Weatherford casing equipment (released Weatherford @ 23:00 hrs). Total fluid loss to well last 12 hrs= 24 bbls. 43.6 bbls loss for total trip out over calculated. Shut blind rams. C/O upper rams T/2-7/8" x 5"VBR's. Connect btm ram Koomey lines and function test. R/U test equipment. Set test plug and flood stack. Open annulus valve and test BOPE. Tested upper rams, lwr rams, annular,TIW and Dart (4.5" test jt used). 250/4,000 test psi w/5- 10 min hold chart and record same (test annular 250/2,500 psi). No failures. R/D test equipment and set 9" ID wear bushing. Rack in Pollard wireline. Make up tools and rig up same. P/U and M/U 10'4.5" DP pup w/oversize swedge on bottom,TIW on top w/XO and packoff(Pollard) for lubricator. PJSM, RIH w/8.15" GR. 10/11/2015-Sunday RIH with 8.16" gauge ring on Pollard e-line to 7,050' and tag fish (3-1/2" tubing stub). No issue getting to depth. POOH and remove GR. MU Baker CIBP, RIH and tag fish at 7,050'. CCL up hole. Have casing collar at 7,010', fish at 7,050', set CIBP at cOe 7,030'. POOH. MU 5" x 30' cement dump bailer, mix 26 gallons 17 ppg cement. RIH and dump same. POOH and mix 29 5y� gallons 17 ppg cement. RIH and dump same. POOH and mix 26 gallons 17 ppg cement. RIH and dump same. POOH LD dump bailer. Flood choke line and choke manifold with water. Close blinds.Test 9-5/8" casing and CIBP/cement plug at 1,5�siir for 30 minutes on chart. Good test. Bleed off and RD test equipment. MU CIBP, RIH. Correlate CCL w/9-5/8" pipe tally(no I discrepancy). Set CIBP @ 6,568' (5' above 9-5/8" connection) Fire setting tool w/good indication of firing. 650# line to G55 150#after firing. 55k shear stud on CIBP. Pull out of hole and RID Pollard. Service rig. Adjust crown saver, grease drawworks, crown, IR, Blocks and TDS. Rack in and tally HWDP, DP and stage milling assy after demob E-line truck. P/U and M/U 8-1/2" milling assy as per BOT rep (Jeff Reed). Starter mill, lower mill, flex DC, upper mill, and XO= 26.3'. Single in w/ milling assy F/26.3 -1/917.54' (total BHA length) w/29 jts 4.5" HWDP. Continue single in with 4.5", 16.6#S-135 DP F/ 917.54-T/ 6,194'. Drift all DP w/2.56". AOGCC waived witness for upcoming BOP test. Test choke manifold offline 250/4,000 psi. . 14 SCHEMATIC Kenai CLU Cannery Loop Unit-05 .. Last Completed: 12/26/1996 Hilcorp Alaska,LLC API: 50-133-20474-00 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 129/N/A/N/A N/A Surf 142' to 20" }, 13-3/8" Surface 61/K-55/BTC 12.515 Surf 2,970' '` 9-5/8" Production 53.5/L-80/BTC 8.535 Surf 1,212' t t, 47/P-110/BTC 8.681 1,212' 9,178' 7" Liner 29/N-80/BTC 6.184 8,974' 11,421' i' ,; Long String d. +<"' 3-1/2" LS 9.2/L-80/Butt-Mod 2.992 Surf 9,752' ]3-3/8"r Iii -,t i JEWELRY DETAIL BLAST JOINT DETAIL LS No Depth ID Item Top Btm Length 1 6,568' CIBP 7,119' 7,159' 40' 2 7,030' CIBP w/25'cement 7,223' 7,347' 124' +' 3 9,655' Baker F-1 Packer w/10'Sealbore LS 7,403' 7,443' 40' i. it _ 4 9,705' 2.813 X-Nipple in Long String 7,501' 7,572' 71' c`="`5ii, 5 9,746' 2.813 X-Nipple in Long String 7,750' 7,836' 86' ///4 6 9,752' Wireline Entry Guide Long String 7,841' 7,924' 83' t 7,996' 8,096' 100' r i41 8,115' 8,215' 100' 6- , 2 t. g PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Isolated 7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Isolated 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Isolated • 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Isolated -• 7,502' 7,522' 6,327' 6,347' 20' 6 11/29/1996 Isolated 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Isolated 0 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Isolated t + 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Isolated 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Isolated 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Isolated 9-5'/s' I ,. 9,860' 9,900' 8,685' 8,725' 40' 6 Reperf Isolated 8/2/2013 3 , 17 T-1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99&2/97 Isolated " T-1 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Isolated 10,276' 10,294' 9,101' 9,119' 18' 6 Aug-99 Squeezed 10,294' 10,319' 9,119' 9,144' 25' 6 Aug-99 Squeezed 4 i N i CEMENTING DETAIL 5 d Casing Detail Cement at 9,835' 6 13-3/8" Cmt w/1,790 sks of class G ""4"A Cmt w/850 sx lead, 1069 sx of class G tail,(total:1919 sks)of `j,A 9-5/8class GTOCE:2200 ft MD,estimated(25%excess) Cement plug 10,148' 7" Cmt w/750 sks of class G "'y to 10,935'KB FISH DETAIL TAG DETAIL '{. ' LS 7"Pkr 10,935'to 11,193' LS 2.5"GR @ 10,004'8/13/2013 ,- SS 38.6'x 2"-1/8"guns(11/96) SS 2"Bailer @ 7,919'4/28/06 T TD=11,424'MD/10,239'ND PBTD=11,288'MD/10,106'ND Updated by DMA 11-20-15 • .� OF ,30',1),\71//711_4",v,,30',1),\71//711_4",v,fp��� THE STATE Alaska Oil and Gas A o f Conservation Commission t _ LAsKAL 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *1. Main: 907.279.1433 QF ALAc��P Fax 907.276.7542 (_ a e O 5 www.aogcc.alaska.gov SCA*�� Taylor Nasse Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Cannery Loop Field, Beluga and Upper Tyonek Gas Pools, CLU 05 Sundry Number: 315-554 Dear Mr. Nasse: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/47 304 - Cathy P. Foerster / Chair DATED this /(O� of September, 2015 Encl. • • RE ED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 4 2015 APPLICATION FOR SUNDRY APPLICATI13-1 4 1,41i6 L-5 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations f . Fracture Stimulate ❑ Pull Tubing E . Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill Q - Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ " 196-073 - 3.Address: 6.API Number: Stratigraphic ❑ Service 3800 Centerpoint Drive,Anchorage AK,99503 50-133-20474-00-00 . 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 231.001 Will planned perforations require a spacing exception? Yes El No El Cannery Loop Unit 05 " 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL-324602,FEE-TR73 " Cannery Loop Field/Beluga&Upper Tyonek Gas Pools - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,424 . 10,239 • 10,148 8,964 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 142' 142' Surface 2,936' 13-3/8" 2,970' 2,576' 3,090psi 1,540psi Intermediate 1,178' 9-5/8" 1,212' 1,200' 7,930psi 6,620psi Production 7,966' 9-5/8" 9,178' 7,997' 9,440psi 5,300psi Liner 2,447' 7" 11,421' 10,239' 8,160psi 7,030psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2"SS and 3-1/2"LS 9.2#/L-80 7,025'SS and 9,752'LS Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker GT Dual&Baker F-1 Packer and N/A 5,898'(MD)/4,278'(TVD)&9,655'(MD)/7,819'(TVD)and N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development ❑� Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: September 18,2015 OIL p ❑ WINJ ❑ WDSPL ❑ Suspended - ❑✓ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasse@hilcorp.com Printed Name Taylor Nasse Title Operations Engineer (7-' Signature df� r Phone 907-777-8354 Date ) / r) ❑� ' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r::$- 315-55Lf Plug Integrity [ BOP Test- " Mechanical Integrity Test ❑ Location Clearance ❑ Other: 7 -600 p 51. C xJ P sr C .ts/0 ' 16 S-z) p Sc , y�4 1) 7r .1-e r A- p 1,4j /I lC G¢41...o.J- 4-pp fG t..,-F> O cult Z L .44c aS. i/4(..: - 0 t.e. _r t.6wt-d F'::1;- /Ei... 6kprr v.».0 _ AA-c 2- 03o C4)[,) Spacing Exception Required? Yes 111 , No l"1 Subsequent Form Required: / b— v APPROVED BY Approved by: f' COMMISSIONER THE COMMISSION Date:'</o /J Form 10-40 evised 5/2015ofiicepicNnAv lid f ' .��1}./ 5 Submit Form and v, - " ' O�ppr .r Attachments in Duplicate 0 %`- . i /f • Well:Well PrognosisCLU-05 Hilcorp Alaska,LL, Date:9/4/2015 Well Name: CLU-05 API Number: 50-133-20474-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: September 185t, 2015 Rig: Saxon 169 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 196-073 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) AFE Number: Maximum Expected BHP: -2,350 psi @ 7,000' MD (Based on static survey 6/23/13) Max. Allowable Surface Pressure: - 1,650 psi (Gas gradient to surface (0.1 psi/ft)) Brief Well Summary Cannery Loop#5 is a 3-1/2" dual-string completion that produced the Beluga sands in the short string and the Tyonek sands in the long string. The well was originally completed in December 1996.The well has not flowed productive gas since 2012.5 coy c.v✓, 0p7'1- we(/ qe0/f i / t-f 4 /.cmc/ o H 7-4e be* ,:ileo vu/ 00,7/ ofe f/etel .'y 7-41, /,/,/P/' Tc�alek RWO Objective: Pull dual completion and plug back well in preparation for sidetrack. RptPrytgW>°/hP� Notes Regarding Wellbore Condition Qio.ker j4( we // fesvlye ,n D.s/h,��F/� foo Pre-rig Procedure: • Tubing and casing will be filled full of produced fluid before the tubing is cut. //y0/4;„ y� fre// M' 1. MIRU Slickline on 3-1/2" Long-String, PT Lubricator to 250 psi low/2,500 psi high. f'dr 1// (Aov/J , 2. Make 2.85" GR run and tag bottom. POOH. U ?v%W" Pieq, 3. MU bailer and dump bail sand to 9„850' (approx. 235 gal). 7 ��/r q/ a. Alternatively, MIRU E-line on LS, PT lubricator to 250 psi low/2,500 psi high. 110A , b. RIH w/expandable bridge plug and set at 9,850'. I I''' p 4. Dump bail 25' of cement to 9,825'. — ' , — V()ra r C', ,Act. {� iLs Dy 105: 5. Move lubricator over to the 3-1/2” Short String. PT lubricator to 250 psi low/2,500 psi high. 6. Drift tubing to tubing tail at±7,025' MD. POOH. 7. RDMO SL. 8. MIRU E-line on LS, PT lubricator to 250 psi low/2,500 psi high. 9. RU 2-1/8"Tubing Punch. 10. RIH and punch tubing at+/-8,950' MD. POOH. 11. RU pump truck and circulate 6% KCL/PW by pumping down LS and taking returns up SS. 12. RU 2-1/2"jet cutter. 13. RIH and jet cut tubing at+/- 7,050' MD. POOH. 14. RD E-line. RWO Procedure: 1. MIRU Saxon 169 Rig. 1 • • • Well Prognosis Well: CLU-05 Hilcorp Alaska,LL Date:9/4/2015 2. Circulate well with 6% KCI/PW by pumping down the LS and taking returns up the SS. 3. Set BPV's. ND Tree. 4. NU BOPE with dual pipe rams in the upper ram cavity(see schematic). Make up blanking ported test sub to test joint to both tubing hangers. Test to 250 psi low/3 Ot7 psi high. LD test joints. Install TWC. Test blind rams. Record accumulator pre-charge pressures and chart tests. a. Note that th- ,nnular cann. . tested at this time due to the dual completion. The annular will be to -. f en the dual pipe rams are changed to the single pipe rams and the 11}"k- p dual string is •. of t' ; ole. g4 ? b. Noti - .GCC 24 hours prio • - ••: -t ht •: doa.alaska. ov o c forms estWitnessNotif.html // g / g / ;01/5. Pull TWC. 6. RU dual handling equipment. Ensure there are two TIW valves on location. 7. MU landing joints to the hangers. BOLDS. Latch elevators to the landing joints. 8. PU 40K over pickup weight of approx. 108K and hold. Continue picking up and holding in 5K increments to shear and release the 9-5/8" Baker GT dual packer(shear set at 80K when pulling both strings-40k release on single string pull) at 5,898' MD. Note: 100%Yield on the 3-1/2"9.2 U/ft tubing is 207,200 lbs. 80%=165,760 lbs L/ Do not exceed 80%yield of the tubing. 9. Pull tubing hanger to the floor. 10. POOH with the dual completion to the 9-5/8" Baker GT dual packer at 5,898' MD. Number and label each joint. Keep track of the short string and long strings. Lay down all the 3-1/2"tubing, dual bore packer with tailpipe, and completion jewelry. 11. Clean and clear floor. 12. Ensure well is full of fluid. 13. RU a-line. 14. RIH w/8.25" GR to 7,050'. a. If casing doesn't drift, MU bit and 9-5/8" scraper assembly on drill pipe to 7,050' MD. C-6 Circulate well clean. ,\44,. b. POOH w/drill pipe and lay down bit and scraper. 15. RIH with CIBP and set at 7,030'. 16. RIH with bailer and dump 25'of cement. (80 gallons) 51 S / 17.:1-ag top of cement and confirm TOC at 7,005 r,sr1 18. RIH w/CIBP and set at 6,620'. ��� � �� 19. RD e-line. 20. PT casing to 1,500 psig for 30 minutes./C.I1t 'i" '— O p 4-i 61.21. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** 111 I.14 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 2 SAXON 169 BOP TEST SEQUENCE for CLU #5 DECOMPLETION 14-Ilk 6 After nipple down of tree assy,left hand acme release blanking plugs will be installed in each hanger half in order to initiate BOP test on duals. • TEST#1–ANNULAR,DART VALVE,INSIDE KILL,INSIDE CHOKE—Screw into one side of hanger w/3'/2 test joint to surface o OPEN=ANNULUS VALVE,4"STD PIPE VALVE,2"BLEEDER ON RIG FLOOR,MEZZANINE KILL, KILL HCR,CHOKE HCR CM 1,4,5,6,8,9,10,12,ELECT./MANUAL CHOKES, HYD IBOP,LOWER IBOP, TIW VALVE o BLEED OFF ALL PRESSURE, LEAVE BLEEDER OPEN, OPEN ANNULAR, • TEST#2–UPPER Dual RAMS with 3 'A x 3'A test joint,CHOKE MANIFOLD C.M.#1,#3,#4,#5,#7, &MEZZANINE KILL VALVE,HYD.IBOP—Screw into other hanger w/3 '/Z test joint to have two joints coming to the rig floor o OPEN=ANNULUS VALVE,4"STD PIPE VALVE, 2"BLEEDER ON RIG FLOOR,INSIDE KILL,KILL HCR, INSIDE CHOKE,CHOKE HCR,CM 2,6,8,9,10,11,12,13,ELECT./MANUAL CHOKES,LOWER IBOP, TIW VALVE • TEST#3-UPPER Dual Rams with 3 'A x 3'A test joint,C.M.#2,#4,#5,#6,#8„KILL HCR,DART VALVE,LOWER IBOP o OPEN=ANNULUS VALVE,4" STD PIPE VALVE, 2"BLEEDER ON RIG FLOOR, INSIDE KILL,MEZZANINE KILL, INSIDE CHOKE,CHOKE HCR, CM 1,3,7,9,10,11,12,13,ELECT./MANUAL CHOKES, HYD IBOP,TIW VALVE o CLOSE=CM 2,3 DO NOT NEED TO OPEN AGAIN • TEST#4–UPPER Dual Rams with 3'A x 3'A test joint,ELECT/MAN CHOKES, INSIDE KILL,TIW VALVE,TEST AGAINST CHOKES VERIFYING HOLDS (DOES NOT HAVE TO BE A JUG) o OPEN=ANNULUS VALVE,4"STD PIPE VALVE, 2" BLEEDER ON RIG FLOOR,MEZZANINE KILL, KILL HCR,INSIDE CHOKE,CHOKE HCR, CM 1,4,5,6,8,9,10,11,12,13, HYD IBOP,LOWER IBOP • TEST#5–Upper Dual Rams with 3 '/Z x 3'h test joint,C.M.7,9,11,13,INSIDE KILL,TIW VALVE • • o OPEN=ANNULUS VALVE,4"STD PIPE VALVE, 2"BLEEDER ON RIG FLOOR,MEZZANINE KILL,KILL HCR,INSIDE CHOKE, CHOKE HCR, CM 1,4,5,6,8,10,12,ELECT./MANUAL CHOKES, HYD IBOP,LOWER IBOP o (WHILE TESTING VERIFY 0 PSI ON CASING GAUGE) o DISCONNECT/ISOLATE TOP DRIVE TEST HOSE • TEST#6-Upper Dual Rams with 3 'A x 3'/2 test joint,DART VALVE,INSIDE KILL,CHOKE HCR o OPEN=ANNULUS VALVE,4"STD PIPE VALVE, 2"BLEEDER ON RIG FLOOR,MEZZANINE KILL,KILL HCR,CM 1,4,5,6,8,9,10,12,ELECT./ MANUAL CHOKES,HYD IBOP, LOWER IBOP,TIW VALVE • TEST#7—Upper Dual Rams with 3 '/2 x 3'/z test joint,DART VALVE,INSIDE CHOKE,INSIDE KILL o OPEN=ANNULUS VALVE,4"STD PIPE VALVE, 2"BLEEDER ON RIG FLOOR,MEZZANINE KILL,KILL HCR,CHOKE HCR CM 1,4,5,6,8,9,10,12,ELECT./MANUAL CHOKES, HYD IBOP,LOWER IBOP, TIW VALVE • TEST#8-KOOMEY DRAW DOWN TEST o REMOVE TEST HOSE FROM TEST JOINT. CLOSE VALVE#11,REMOVE SENSOR FOR GAUGES FROM CHOKE MANIFOLD AND HOOK UP TEST HOSE, OPEN VALVE#11,BREAK OUT DART VALVE,BACK OUT TEST JOINTS FROM TUBING HANGER,PULL TO RIG FLOOR • TEST#9-CLOSE BLIND RAMS,C.M.#7,#10,#12,INSIDE KILL o OPEN=ANNULUS VALVE,4"STD PIPE VALVE,2"BLEEDER ON RIG FLOOR,MEZZANINE KILL,KILL HCR,CHOKE HCR,INSIDE CHOKE, CM 1,4,5,6,8,9,13,ELECT. /MANUAL CHOKES,HYD IBOP, LOWER IBOP, TIW VALVE o After test is done remove blanking plugs from hanger halves by screwing into the left hand acme until sub backs from the 3 '/z EUE lift threads in the hanger. • After pulling completion will need to set test plug in well,change out dual rams and then test double gate and single gate before proceeding . . L N " j r+ Z l • V , (x .ter 4r 1... i_.. -�_L4 —L ✓✓✓III J L ., ri � T �._ 1 w'+ 0 rra. v! 1 bV 7-sr- ...., i Illtit''''':- .:;:::: r:* WILL r nib 0 _ 1 c n T wy tt 4 _ co,'et r. • Kenai CLU 14 • Well: Cannery Loop Unit-05 SCHEMATIC Last Completed: 12/26/1996 Hilcorp Alaska,LLC API: 50-133-20474-00 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 129/N/A/N/A N/A Surf 142' 20'r f 13-3/8" Surface 61/K-55/BTC 12.515 Surf 1,970' w; 53.5/L-80/BTC 8.535 Surf 1,212' 9-5/8" Production #+ # 47/P-110/BTC 8.681 1,212' 9,178' U' 7" Liner 29/N-80/BTC 6.184 8,974' 11,421' Long String ' 3-1/2" LS 9.2/L-80/Butt-Mod 2.992 Surf 9,752' an .414 Short String 1338" - c. 3-1/2" SS 9.2/L 80/Butt-Mod 2.992 Surf 7,025' '` JEWELRY DETAIL BLAST JOINT DETAIL LS i • %i No Depth ID Item Top Btm Length q 1771 1 5,898' Baker GT Dual Packer 7,119' 7,159' 40' 1 t 2 5,943' 2.813 X-Nipple in Short String 7,223' 7,347' 124' "F 3 5,985' 2.813 X-Nipple in Short String 7,403' 7,443' 40' k 4 6,980' 2.813 X-Nipple in Short String 7,501' 7,572' 71' 2 c, ! 5 7,020' 2.813 X-Nipple in Short String 7,750' 7,836' 86' _ + 6 7,025' Wireline Entry Guide Short String 7,841' 7,924' 83' 3 r 7 9,655' Baker F-1 Packer w/10'Sealbore LS 7,996' 8,096' 100' t 8 9,705' 2.813 X-Nipple in Long String 8,115' 8,215' 100' v, 9 9,746' 2.813 X-Nipple in Long String 4i 10 9,752' Wireline Entry Guide Long String a Sto I !I ,: PERFORATION DETAIL s " Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Open .. 7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Open .. r 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Open 5 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Open ' 7,502' 7,522' 6,327' 6,347' 20' 6 11/29/1996 Open .. .,T 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Open tl,." 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Open :_ 4 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Open D 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Open r 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Open 9-5/r r t1' r- 9,860' 9,900' 8,685' 8,725' 40' 6 Reperf 8/2/2013 Open 7$ T. ,' 5 T-1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99&2/97 Open 11 __ V'/ T-1 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Open 1 10,276' 10,294' 9,101' 9,119' 18' 6 Aug-99 Squeezed IL- 10,294' 10,319' 9,119' 9,144' 25' 6 Aug-99 Squeezed ij CEMENTING DETAIL 8 9 i. I:.I Casing Detail I 13-3/8" Cmt w/1,790 sks of class G 10 9-5/8„ Cmt w/850 sx lead, 1069 sx of class G tail, (total:1919 sks)of class GTOCE:2200 ft MD,estimated(25%excess) Tag TOF@1o,000w Cement plug 10,148' 7" Cmt w/750 sks of class G 2.25088/13/2013 • to 10,935'KB " FISH DETAIL TAG DETAIL '` LS 7"Pkr 10,935'to 11,193' LS 2.5"GR @ 10,004'8/13/2013 SS 38.6'x 2"-1/8"guns(11/96) SS 2"Bailer @ 7,919'4/28/06 T' TD=11,424' Revised By:TDF 8-13-2013 0 PROPOSED . Kenai CLU 14 Well: Cannery Loop Unit-05 SCHEMATIC Last Completed: 12/26/1996 Hilcorp Alaska,LLC API: 50-133-20474-00 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 129/N/A/N/A N/A Surf 142' za' 1, 13-3/8" Surface 61/K-55/BTC 12.515 Surf 1,970' 9 5/8" Production 53.5/L-80/BTC 8.535 Surf 1,212' 47/P-110/BTC 8.681 1,212' 9,178' 7" Liner 29/N-80/BTC 6.184 8,974' 11,421' Long String s,,, 3-1/2" LS 9.2/L-80/Butt-Mod 2.992 Surf 9,752' 13-3/8" JEWELRY DETAIL BLAST JOINT DETAIL LS » No Depth ID Item Top Btm Length !• 7 9,655' Baker F-1 Packer w/10'Sealbore LS 7,119' 7,159' 40' 1141*r'r� 8 9,705' 2.813 X-Nipple in Long String 7,223' 7,347' 124' x• ! 9 9,746' 2.813 X-Nipple in Long String 7,403' 7,443' 40' CIBP at 6,620' 10 9,752' Wireline Entry Guide Long String 7,501' 7,572' 71' - 7,750' 7,836' 86' S tr 7,841' 7,924' 83' 7,996' 8,096' 100' 8,115' 8,215' 100' CI BP at 7 w/ 2 25'cement 4 PERFORATION DETAIL M Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Isolated lim7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Isolated iliN r 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Isolated 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Isolated 7,502' 7,522' 6,327 6,347' 20' 6 11/29/1996 Isolated a 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Isolated ,r 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Isolated , 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Isolated 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Isolated ' t2 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Isolated w Reperf 9-s/8 �, 9,860' 9,900' 8,685' 8,725' 40' 6 8/2/2013 Isolated 7,: T-1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99&2/97 Isolated w. T-1 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Isolated I ' t 10,276' 10,294' 9,101' 9,119' 18' 6 Aug-99 Squeezed 10,294' 10,319' 9,119' 9,144' 25' 6 Aug 99 Squeezed 8 k s _ Casing CEMENTING DETAIL t 10 Detail Cement at 9,835 13-3/8" Cmt W/1,790 sks of class G °4/" '' 9-5/8" Cmt w/850 sx lead, 1069 sx of class G tail, (total:1919 sks)of class GTOCE:2200 ft MD,estimated(25%excess) Cement plug 10,148' 7" Cmt w/750 sks of class G to 10,935'KB fA FISH DETAIL TAG DETAIL *err LS 7"Pkr 10,935'to 11,193' LS 2.5"GR @ 10,004'8/13/2013 5S 38.6'x 2"-1/8"guns(11/96) SS 2"Bailer @ 7,919'4/28/06 7' TD=11,424' Revised By:TDF 8-13-2013 • • . II Cannery Loop Unit CLU #05 BOP 08/28/2015 1144-.9. 11n d,n.1.1 1 Saxon 169 BOP stack CLU #5 1 0 0 III Iii III 11 1!I III I i .0 Model 6011i 11"-5000 La n 11 1 i -� Dual 3 %2x3 %2 H I ,� �Yk r"® r T-3 Energy L I p J H � r - Model 7082 Blinds N 11"-5000 I H a 1 r, r, ri 4 ., i k '6;g) 1i i it O J �� can a tams. _ �� '1� . __ _ _ - , Variable 2 7/8-5 T-3 Energy tj; I HCA-T— ''-- U3 Model 7082 H -- ® 11"-5000 P I r 'U ji LL1J UJJ -SI' , 1111111M • • n • Cannery Loop Unit CLU #05 08/28/2015 11J.-1, \L,•t..,. III Cannery Loop Tubing hanger, Dual, CIW- CLU#05 DCB, 11 X 3 1/2 EUE lift X 20x133/8x95/8x31/2x31/2 3 1/2,w/3"type H BPV profile, 5 3/64 centers 3 1/8 5M 5 bolt segmented top :- 0._ , 41 .. '® , _, . . j ' E -.6 i r . ;.*41) . , e, ,® __,, _._ Ko .:, _ ©�. =+lo�� Tree, block, dual, Cameron type F,11 5M X 3 1/8 5M X 3 1/8 5M,EE trim,5 3/64 Irtrk:41.!. centers, double master swab, �1 3 1/8 5M SSO Tubing head, CIW-DCB-S, ii! 13 5/8 5M X 11 5M,w/2- :41 I li;_.: 2 1/16 5M SSO,X-bottomIII — SII Valve,WKM-M, 2 1/16 prep, N type pins 5M FE, HWO,AA aty 2 F ' 11:(,' -111 milk Th-6--mc _ c in !_,,. rn.!.. -ii. Casing head,McEvoy, -i 13 5/8 SM X 13 3/8"SOWIE. 21. Valve,McEvoy-C, bottom,w/2-2 1/16 5M Ill -- 'r 1E1 2 1/16 5M FE, HWO,AA EFO _ �;i. iu111uIE1iO4:II E lik a_ i _ I- , • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 16, 2015 8:56 AM To: 'Taylor Nasse' Cc: mmyers@hilcorp.com Subject: RE: CLU 5 BOPE testing for P &A (PTD 196-073) Thanks ..this is perfect . Lower ram single VBR may be tested once the completion is pulled. Annular is tested on a single joint in first test so we have single joint coverage there. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Taylor Nasse [mailto:tnasse@hilcorp.com] Sent: Tuesday, September 15, 2015 6:17 PM To: Schwartz, Guy L (DOA) Cc: Regg, James B (DOA); Chad Helgeson; Donna Ambruz; Monty Myers Subject: RE: CLU 5 BOPE testing for P &A (PTD 196-073) Hi Guy- Attached is the detailed BOP testing procedure the Saxon 169 rig for de-completing the CLU-5 dual string in preparation for the sidetrack. An item to note is that the height of the rig sub base relative to the wellhead height does not allow the installation of a riser between the wellhead and the BOPE. For this reason,the concern with testing the VBR ram is that there isn't enough flexibility in an offset test joint to close the VBR without potentially damaging it. I hope this information helps. If you have any questions or require further information, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907)903-0341 cell From: Schwartz, Guy L(DOA) [rnailto:guy.schwartz@talaska.gov] Sent: Wednesday, September 09, 2015 9:45 AM 1 • • • To: Taylor Nasse Cc: Regg, James B (DOA) Subject: CLU 5 BOPE testing for P &A (PTD 196-073) Taylor, Looking at the procedure for testing the BOPE with dual rams ... have question. I don't see where you are testing the single lower VBR ram in the BOPE testing procedure. What about setting a TWC(check valve) in one string and testing the lower Ram (2 7/8"X 5" ) and the annular on a 3"A"test joint then doing the dual rams by replacing the TWC with the blanking plug/test joint. The annular/lower ram should be tested as there could be a situation where you are laying down tubing and the well kicks with one joint in elevators. Also,as Hilcorp does several dual completions per year it would be very beneficial to have a standard BOPE testing procedure for dual completions. (for both 2 and 3 ram stacks) Since this rig(Saxon 169) is not familiar with this operation (pulling duals) even more reason to have a detailed BOPE test. In step 4 of pre—rig the first plug in the LS side needs to be pressure tested to 1500 psi In step 17 of the RWO procedure is where the main pressure test should be to 1500 psi and charted. Step 20 pressure test is optional after the 2"d CIBP is set. Reagrds, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" V boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then v check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. I XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l c;/~ -. ©'7'~File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Page'_ Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages' [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds/No. Other Scanned by: Beverly~Vincent Nathan Lowell Date: ~ ._ i~r- ,s,~ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent ~Lowell UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ,J 1~ b'~~3 FILE # ~,~ Lo C~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 tittotivcial STATE OF ALASKA S E P 0 9 2013 ALA.OIL AND GAS CONSERVATION COMMIOON REPORT OF SUNDRY WELL OPERATIONS AOGCC n.,*(5 1.Operations Abandon L] Repair Well Li Plug Perforations L] Perforate [f' Other U. Install/Remove Capstring Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 119 . Exploratory ❑ 196-073 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number:. Anchorage,Alaska 99503 50-133-20474-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-324602 , FEE.-re.-Ts Cannery Loop Unit 05 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Cannery Loop Field/Beluga&Upper Tyonek Gas Pools • 11.Present Well Condition Summary: Total Depth measured 11,424 feet Plugs measured 10,148 feet true vertical 10,239 feet Junk measured 10,000(sand) feet 5,898' Effective Depth measured 10,148 feet Packer measured 9,655 feet 4,278 true vertical 8,964 feet true vertical 7,819 feet . Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 142' 142' Surface 2,936' 13-3/8" 2,970' 2,576' 3,090psi 1,540psi Intermediate 1,178' 9-5/8" 1,212' 1,200' 7,930psi 6,620psi Production 7,966' 9-5/8" 9,178' 7,997' 9,440psi 5,300psi Liner 2,447' 7" 11,421' 10,239' 8,160psi 7,030psi Perforation depth Measured depth See Attached Schematic NE�p �� , c 2,r1 i' True Vertical depth See Attached Schematic 1ldd 3-1/2"55 9.2#/L-80 7,025'SS 5,851'SS Tubing(size,grade,measured and true vertical depth) 3-1/2"LS 9.2#/L-80 9,752'LS 8,577'LS Baker GT Dual Pkr 5,898'MD/4,278'TVD Packers and SSSV(type,measured and true vertical depth) Baker F-1 Pkr N/A 9,655'MD/7,819'TVD 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 87 Subsequent to operation: 0 0 0 0 41 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development Ell • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 , WDSPL U GSTOR ❑ WINJ El WAG ii 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: 313-405 Contact Jeremy Mardambek Email 1mardambek @hi1c0rp.00m Printed Name Jeremy Mardambek Title Reservoir Engineer Signature ��/��/'�/ ---- Phone 907-777-8388 Date 9/9/2013 Form 10-4 Reviled 10/2012 4 y_' © rpif■ gir �Qnly ���y�� I'7 nn r 1 2 20S 14 Kenai CLU • Well: Cannery Loop Unit-05 SCHEMATIC Last Completed: 12/26/1996 Hilcorp Alaska,LLC API: 50-133-20474-00 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 1 1 20" Conductor 129/N/A/N/A N/A Surf 142' 20' 1 i 13-3/8" Surface 61/K-55/BTC 12.515 Surf 1,970' i i 53,5/L-80/BTC 8.535 Surf 1,212' 9-5/8" Production 47/P-110/BTC 8.681 1,212' 9,178' 4 1 ,t, 7" Liner 29/N-80/BTC 6.184 8,974' 11,421' Long String 3-1/2" I LS 9.2/L-80/Butt-Mod I 2.992 Surf 9,752' 133/8' i Short String � 3-1/2" SS 9.2/L-80/Butt-Mod 2.992 Surf 7,025' i JEWELRY DETAIL BLAST JOINT DETAIL LS No Depth ID Item Top Btm Length 1 5,898' Baker GT Dual Packer 7,119' 7,159' 40' 1 [ 2 5,943' 2.813 X-Nipple in Short String 7,223' 7,347' 124' 4I 3 5,985' 2.813 X-Nipple in Short String 7,403' 7,443' 40' ; 4 6,980' 2.813 X-Nipple in Short String 7,501' 7,572' 71' 2? , ' 5 7,020' 2.813 X-Nipple in Short String 7,750' 7,836' 86' ' " < 6 7,025' Wireline Entry Guide Short String 7,841' 7,924' 83' 3 ..M kf 7 9,655' Baker F-1 Packer w/10'Sealbore LS 7,996' 8,096' 100' 8 9,705' 2.813 X-Nipple in Long String 8,115' 8,215' 100' k'r 9 9,746' 2.813 X-Nipple in Long String 4t 10 9,752' Wireline Entry Guide Long String r ,s 5,4 PERFORATION DETAIL 6 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Open 7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Open 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Open 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Open 7,502' 7,522' 6,327' 6,347' 20' 6 11/29/1996 Open 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Open i 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Open f 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Open 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Open 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Open 9-5/8" % ( ` 9,860' 9,900' 8,685' 8,725' 40' 6 8/2/2013 Open 1 T-1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99&2/97 Open 7t � : Ti- 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Open d` 10,276' 10,294' 9,101' 9,119' 18' 6 Aug-99 Squeezed 10,294' 10,319' 9,119' 9,144' 25' 6 Aug-99 Squeezed ICEMENTING DETAIL 8, ; Casing Detail IF 9` 13-3/8" Cmt w/1,790 sks of class G Cmt w/850 sx lead, 1069 sx of class G tail,(total:1919 sks)of 10 9-5/8" class GTOCE:2200 ft MD,estimated(25%excess) 7" Cmt w/750 sks of class G Tag TCF @ 10,000'w/ `„ Cement plug 10,148' 2.25088/132013 , to 10,935'KB FISH DETAIL TAG DETAIL i LS 7"Pkr 10,935'to 11,193' LS 2.5"GR @ 10,002'7/1/2011 , ` SS 38.6'x 2"-1/8"guns(11/96) SS 2"Bailer @ 7,919'4/28/06 7 TD=11,424' Revised By:TDF 8-13-2013 • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date CLU-5 50-133-20474-00 196-073 8/2/13 8/2/13 ta Dail Operations; Ohll6l;i 7/31/2013-Wednesday No operations to report. 8/1/2013-Thursday No operations to report. 8/2/2013 - Friday SITP 600psi. RU Priority Eline unit. RIH(1)w/GPT,junk basket, and 2.75" GR,fluid level at 9,590' BHP at 9,800 is 800psi.Tag TD at 9,970'. POOH. RIH w/ 1-11/16" Gamma Ray/CCL,shock sub, and 20'x 2-1/2"Titan Super deep penitrating charges loaded 6 SPF 60 degree phased. Flow well down to 360psi. Appox 25% underbalance. Estimated Formatiom pressure 730psi. Run correlation passed to get on depth to Digitized Perforation Log for CLU 5 provided. Pull up into position CCL @ 9,870.5' (9.5'to top shot) Perforate 9,880'to 9,900'. Fire guns. No change in WHP 360. RIH w/ 1-11/16" Gamma Ray/CCL, shock sub, and 20'x 2-1/2"Titan Super deep penitrating charges loaded 6 SPF 60 degree phased. WHP still 360psi. Appox 25% underbalance. Estimated Formatiom pressure 730psi. Run correlation passed to get on depth to Digitized Perforation Log for CLU 5 provided. Pull up into position CCL @ 9,850.5' (9.5'to top shot) Perforate 9,860'to 9,880'. Fire guns. No change in WHP 360psi. OOHWHP still 360psi. Rig down Priority Eline unit. Turn well over to operations. 8/3/2013 -Saturday No operations to report. 8/4/2013 Sunday No operations to report. 8/5/2013- Monday operations to report. 8/6/2013 -Tuesday No operations to report. HILCORP MEL SERVICE REPOR Date: 5-13-.1.1 Well Number: ) Work being done: rci- c* t i Location: .r yN .,r- ;..r Supervisor: S v l Charge Code: Wire line Unit Number: 1 1 Pollard Wireline Crew: iti 0 r. Tree Connection Size/Type •s`I ' .1)2L.,ct Total Wire line Miles: Tree condition Wire Test: Fluid Level if Identified u"„ . ; , Max Depth (KB): t c: Zero Wireline at:-r. t_ Y_ c�. Well KB: Z--t Minimum Tubing ID: °� Max Tool OD: a. Start Tbg. & Csg PSI 2_c:10 --o Ending Tbg & Csg PSI c Time 0 aeration Details WiL valve 11 ri+t �C" t `C c 5, W14 "SIN tv r r't t A . 0C` -a mot' - k 4.w v u C' 12--lo 00 CLt e,.w r 1 o k tcI 1 � Z,s``', c (1.144- t%-1 Work String Detail: I Size and Length C " 1t ' ' '' t i "- ' Description of any rxQPtt° tools or debris left. in the hole: Brief Summary of -1 It:' - fop & kLt3 . can' 4x Fe V>ci r rck►ra. Total Work k c-r"' Completed otat Flours Worked Total Cool Cost 3,1` 1 `r Total Hour Cost Ticket# : Day# D Cost: Cumulative Cost: Well Downtime Hr. Shun H2S PPM Approved by: c Code: \ I //7 :s∎ THE STATE Alaska O11 and Gas LAsK1 1 Conservation Commission 1 / 4 ,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA. Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Shane Bennett ° O Operations Engineer - P g � Hilcorp Alaska, LLC 3800 Centerpoint Drive SCANNED MAR 212013 Anchorage, AK 99503 Re: Cannery Loop Field, Beluga & Upper Tyonek Gas Pool, Cannery Loop Unit 05 Sundry Number: 313 -140 Dear Mr. Bennett: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 . Foerster Chair DATED this day of March, 2013. Encl. ,�3 RECEIVED os 3(�tr STATE OF ALASKA 3�ti a r, , -? f a' W; 1 i ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC • 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install Cap String all ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development la • 196 -073 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, Anchorage AK, 99503 50- 133 - 20474 -00 -00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No p Cannery Loop Unit 05 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 324602 Cannery Loop Field / Beluga & Upper Tyonek Gas Pols ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,424 10,239 - 10,148 8,964 N/A N/A Casing Length i Size MD TVD Burst Collapse Structural Conductor 108' 20" 142' 142' _ Surface 2,936' 13 -3/8" 2,970' 2,576' 3,090psi 1,540psi r Intermediate 1,178' 9 -5/8" 1,212' 1,200' 7,930psi 6,620psi I Production 7,966' 9 -5/8" 9,178' 7,997' 9,440psi 5,300psi Liner 2,447' 7" 11,421' 10,239' 8,160psi 7,030psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3- 1 /2 "SS and 3- 1 /2 "LS L -80 and L -80 7,025'SS and 9,752'LS Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker GT Dual & Baker F -1 Packer and N/A 5,898'(MD)/4,278'(TVD) & 9,655'(MD)/7,819'(TVD) and N/A 12. Attachments: Description Summary of Proposal 12 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development lel Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/21/2013 Oil ❑ Gas 0 , WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Bennett Email sbennett @hilcorp.com 1 rinted Name Shane B-•- t Title Operations Engineer gnature IL / ritilf Phone 907-777-8425 Date 3/18/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission sc that a representative may witness Sundry Number: 3 ` 1 4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Ciher: RB MS MAR 21 201 n Saacing Exception Required? Yes ❑ No L,1 Subsequent Form Required: l d * Yd L i • G AO APPROVED BY Approved by: 2irtL A, * / COMMISSIONER THE COMMISSION Date: 3 - az (J — /3 Submit Form and 117- x •15 � C -1s1\j/)L Approved application is valid for 12 months from the date of approval. Attachme is in Duplicate 0 • • Install Capstring Well: CLU -05 Ililcora Alaska, LL Date: 3/18/2013 Well Name: CLU -05 API Number: 50- 133 - 20474 -00 -00 Current Status: Leg: Estimated Start Date: March 18 2013 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 196 -073 First CaII Engineer: Shane Bennett (907) 777 -8425 (0) (325) 203 -7487 (C) Second Call Engineer: Jeremy Mardambek (907) 777 -8388 (0) (561) 512 -8690 (C) AFE Number: Current Bottom Hole Pressure: — 880 psi @ 5930 TVD (7110' MD) Based on static FL Maximum Expected BHP: — 880 psi @ 5930 TVD Max. Anticipated Surface Pressure: —830 psi Surface corrected BHP Brief Well Summary CLU -05S was originally drilled in 1995 as a dual Beluga /Tyonek producer. The Beluga has been producing excessive amounts of water loading up the well. Currently the well responds positively to batch soap treatments but continuous soap injection will allow the perforations to stay unloaded. Notes Regarding Wellbore Condition CLU -05 should be flowed with as little draw down as possible as it is completed in the Beluga formation and makes lots of water. The challenge is to flow the well without excess solid production. The CLU -05 has a Surface Safety Valve on the horizontal portion of the tree. Brief Procedure: 1. Install WHA 2. Check Fluid Control Valve using hand pump. If required, set FCV (making sure it is the "new" model) Pressure such that the CICM surface line pressure equals BHP. 3. Install valve on the end of coil string. , 4. P/U Dyna -coil injector with crane. 5. Lower Injector head carefully on to the pack -off (line up slot with the pack-off 'A" x 4" nipple.) . 6. Attach hydraulic hoses to hydraulic rams and insert snubbing guides. Prepare to pressure test. 7. Wrap wellhead and pack -off with absorbents to catch drips. Clear wellhead. 8. Pressure hydraulic rams (top seal, 1/4" nipple) on pack -off to 3,000psi. • 9. Open Rattiguns all the way. Watch for pressure leaks. 10. Open slips. Monitor weight indicator to ensure injector is holding weight. • 11. Adjust hydraulic rams pressure to minimum level (100psi — 500psi.) 12. Open swab valve. Watch for leaks at pack -off. • 13. Set Depth counter. 14. RIH at 100 fpm, to set depth of 7,000'. • 15. Set slips. Set Rattiguns. Release pressure on upper hydraulic seal to protect operator. 16. Lift injector head off and away from well. 17. Pressure hydraulic rams (top seal) on pack -off to 2 onns;.. Close needle valve and insert hydraulic plug. • • Install Capstring Well: CLU -05 Hil«,ra Alaska, LI) Date: 3/18/2013 18. Pull tubing excess through injector, or split injector head to remove tubing if over 500' of excess coil. 19. Connect tubing to swagelock injection manifold (valve, guage, filter, guage, valve) to CICM line. 20. Lockout Swab, Upper Master, and Lower Master as per Capstring Lock -out Procedure. 21. Pump foamer into capstring until fluid packed (if not already full.) 22. Hook -up injection line to CICM. Start foamer at 1 gallon per day. 23. Replace well house. Be careful of the tubing "bend" as it goes back inside if it extends through the roof. 24. RDMO. Clean -up site. Attachments: 1. As -built Schematic 2. Proposed Schematic . • Kenai CLU Well: Cannery Loop Unit -05 SCHEMATIC Last Completed: 12/26/1996 Hilcor) Alaska, LLC API: 50- 133 - 20474 -00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 129 / N/A / N/A N/A Surf 142' 20' "' 13 -3/8" Surface 61 / K -55 / BTC 12.515 Surf 1,970' t' 53.5 / L -80 / BTC 8.535 Surf 1,212' 9 5/8" Production 47 / P -110 / BTC 8.681 1,212' 9,178' 4s t ; 7" Liner 29 / N -80 / BTC 6.184 8,974' 11,421' V Long String i, a 3 -1/2" LS I 9.2 / L -80 / Butt -Mod 2.992 Surf I 9,752' 13 € ° 'f 1 t Short String i 3 -1/2" SS 9.2 / L -80 / Butt -Mod I 2.992 Surf 7,025' i 4E JEWELRY DETAIL BLAST JOINT DETAIL LS e # No Depth ID Item Top Btm Length 13 1 5,898' Baker GT Dual Packer 7,119' 7,159' 40' 1 "` 2 5,943' 2.813 X- Nipple in Short String 7,223' 7,347' 124' ',, 3 5,985' 2.813 X- Nipple in Short String 7,403' 7,443' 40' _, 4 6,980' 2.813 X- Nipple in Short String 7,501' 7,572' 71' 5 7,020' 2.813 X- Nipple in Short String 7,750' 7,836' 86' e 6 7,025' Wireline Entry Guide Short String 7,841' 7,924' 83' 7 9,655' Baker F -1 Packer w/ 10' Sealbore LS 7,996' 8,096' 100' ,4 , 8 9,705' 2.813 X- Nipple in Long String 8,115' 8,215' 100' ,. 9 9,746' 2.813 X- Nipple in Long String 4 10 9,752' Wireline Entry Guide Long String PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Open 7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Open 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Open li - 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Open 7,502' 7,522' 6,327' 6,347' 20' 6 11/29/1996 Open I 1 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Open 0 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Open ` 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Open i A 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Open ' 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Open 9 / T -1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99 & 2/97 Open ;'s T -1 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Open 10,276' 10,294' 9,101' 9,119' 18' 6 Aug -99 Squeezed 10,294' 10,319' 9,119' 9,144' 25' 6 Aug -99 Squeezed CEMENTING DETAIL Casing Detail I 13 - 3/8" Cmt w/ 1,790 sks of class G I I , Cmt w/ 850 sx lead, 1069 sx of class G tail, (total:1919 sks )of 9 - 5/8 class GTOCE: 2200 ft MD, estimated (25% excess) ( 7" Cmt w/ 750 sks of class G . Cement plug 10,148' FISH DETAIL TAG DETAIL to 10,935'KB LS 7" Pkr 10,935' to 11,193' LS 2.5" GR @ 10,002' 7/1/2011 ;' , SS 38.6' x 2" - 1/8" guns (11/96) SS 2" Bailer @ 7,919' 4/28/06 I T' TD = 11,424' Revised By: TDF 1 -28 -2013 Kenai CLU ,,. .n • • Well: Cannery Loop Unit -05 PROPOSED Last Completed: 12/26/1996 Ililcorp Alaska, LLC API: 50- 133 - 20474 -00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 129 / N/A / N/A N/A Surf 142' 2n" e 13 - 3/8" Surface 61 / K -55 /BTC 12.515 Surf 1,970' % 53.5 / L -80 / BTC 8.535 Surf 1,212' 9 -5/8" Production 47 / P -110 / BTC 8.681 1,212' 9,178' ? 7" Liner 29 / N -80 / BTC 6.184 8,974' 11,421' `" Long String , A' 3 - 1/2" 1 LS 9.2 / L - 80 / Butt - Mod 2.992 I Surf I 9,752' a' 1 Short String 13 3/8„ ∎' o. 1 3 -1/2" SS 9.2 / L -80 / Butt -Mod I 2.992 Surf 7,025' 4 1 4x 11 ac JEWELRY DETAIL BLAST JOINT DETAIL LS No Depth ID Item Top Btm Length 1 5,898' Baker GT Dual Packer 7,119' 7,159' 40' � z * 2 5,943' 2.813 X- Nipple in Short String 7,223' 7,347' 124' ; 3 5,985' 2.813 X- Nipple in Short String 7,403' 7,443' 40' 4 6,980' 2.813 X- Nipple in Short String 7,501' 7,572' 71' , , 4 5 7,020' 2.813 X- Nipple in Short String 7,750' 7,836' 86' 6 7,025' Wireline Entry Guide Short String 7,841' 7,924' 83' I f 7 9,655' Baker F -1 Packer w/ 10' Sealbore LS 7,996' 8,096' 100' r 8 9,705' 2.813 X- Nipple in Long String 8,115' 8,215' 100' 9 9,746' 2.813 X- Nipple in Long String Baker 3r8' Cap Stnng 10 9,752' Wireline Entry Guide Long String Installed to ±7,000' . I fi ' l PERFORATION DETAIL . Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Date Status 7,110' 7,118' 5,936' 5,944' 8' 6 11/29/1996 Open 7,228' 7,248' 6,054' 6,074' 20' 6 11/29/1996 Open 7,264' 7,298' 6,089' 6,123' 34' 6 11/29/1996 Open s; 7,392' 7,405' 6,217' 6,230' 13' 6 11/29/1996 Open 7,502' 7,522' 6,327' 6,347' 20' 6 11/29/1996 Open 7,752' 7,786' 6,577' 6,611' 34' 6 11/29/1996 Open . / 7,844' 7,874' 6,669' 6,699' 30' 6 11/30/1996 Open 7,980' 8,000' 6,805' 6,825' 20' 6 12/1/1996 Open . 4,4 8,104' 8,118' 6,929' 6,943' 14' 6 12/2/1996 Open ` Ja 8,146' 8,170' 6,971' 6,995' 24' 6 12/3/1996 Open 9-5/8" I {• � t T -1 9,860' 9,900' 8,685' 8,725' 40' 6 9/99 & 2/97 Open F yi T -1 9,860' 9,900' 8,685' 8,725' 40' 5 Reperf 5/03 Open + 10,276' 10,294' 9,101' 9,119' 18' 6 Aug -99 Squeezed r 10,294' 10,319' 9,119' 9,144' 25' 6 Aug 99 Squeezed 4 CEMENTING DETAIL Casing Detail 13 - 3/8" Cmt w/ 1,790 sks of class G 1 t : Cmt w/ 850 sx lead, 1069 sx of class G tail, (total:1919 sks )of 9-5/8" class GTOCE: 2200 ft MD, estimated (25% excess) 7" Cmt w/ 750 sks of class G I. Cement plug 10,148' FISH DETAIL TAG DETAIL p, _ to 10,935'KB LS 7" Pkr 10,935' to 11,193' LS 2.5" GR @ 10,002' 7/1/2011 a.' SS 38.6' x 2" - 1/8" guns (11/96) SS 2" Bailer @ 7,919' 4/28/06 lib 7" TD = 11,424' Revised By: TDF 3 -18 -2013 • Marathon Alaska Production LLC 1'84\ /, Alaska Asset Team - Marathon /�il P.O. Box 1949 t.f Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 March 30, 2012 Cathy Foerster Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10 -404 Report of Sundry Well Operations 7��si r �+� Field: Cannery Loop Field 4 nchor � � G��+missi0 Well: Cannery Loop Unit #5 61d 073 Dear Ms Foerster, Attached for your records is the10 -404 Report of Sundry Well Operations for CLU -5 well. This report covers the MIT testing work performed in preparation for gas injection into the CINGSA Gas Storage project. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 4 .11/v1A-ts - Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File MIT Test form Kenai Well File (2) KJS • STATE OF ALASKA _ ALA. OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon H Repair Well U Plug Perforations U Stimulate H Other U MIT Test Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver El Time Extension ❑ 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 Productio LLC Development el Exploratory — 196 - 073 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 - 1949 — 50 - 133 - 20474 - 00 - 00 7. Property Designation (Lease Number): - 5'�' Well Name and Number: ADL - 324602 E -yi 74 41 , Cannery Loop Unit #5 9. Field /Pool(s): Cannery Loop Unit / Beluga & Upper Tyonek Gcs Pools 10. Present Well Condition Summary: RECFNED Total Depth measured 11,424' feet Plugs measured NA feet true vertical 10,239' feet Junk measured NA M El 3 �' fi' 4' eAe t. i ,� Effective Depth measured 10,148' feet Packer measured 5,39 fe 65 Cca,. Commission true vertical 8,964' feet true vertical 4278' & 7,819' frLrici .ay{L, Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 142' 142' Surface 2,936' 13 -3/8" 2,970' 2,576' 3,090 psi 1,540 psi Intermediate 1,178' 9 -5/8" 1,212' 1,200' 7,930 psi 6,620 psi Production 7,966' 9 -5/8" 9,178' 7,997' 9,440 psi 5,300 psi Liner 2,447' 7" 11,421' 10,239' 8,160 psi 7,030 psi Perforation depth: Measured depth: 7,110' - 9,900' feet True Vertical depth: 5,927' - 8,716' feet Short String 3 -1/2" L -80 7,025' MD 5,843' TVD Tubing (size, grade, MD & TVD): Long String 3 -1/2" L -80 9,752' MD 8,568' TVD Upper Packer: Baker GT Dual 5,898' MD 4,278' ND Packers and SSSV (type, MD & TVD): Lower Packer: Baker F -1 9,655' MD 7,819' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Performed MIT test in preparation for the CINGSA gas storage project. Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 1,100 Subsequent to operation: 0 0 0 1 1,100 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development si ^ Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil U Gas "'ILI WDSPL ❑ GSTOR WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 - 026 Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature 4< ,...12N.A4a P Phone (907) 283 -1371 Date March 30, 2012 RBDM APR 04 2012 Y_' /Z Form 10 -404 Revised 10/2010 Submit Original Only • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoq(aialaska.00v; doa. aoocc.prudhoe.bavCaialaska.gov; phoebe.brooks(a)alaska.gov; tom.maunder(ialaska.gov OPERATOR: Marathon Oil Co. FIELD 1 UNIT 1 PAD: KGF /Cannery Loop DATE: 03/01/12 OPERATOR REP: Mike Sulley AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CLU 5 Type Inj. NA TVD 5,177' Tubing zero zero zero zero Interval 0 / P.T.D. 196 -073 Type test P Test psi 500 psi Casing zero 550 550 550 P/F P y Notes: Took 29 gas to fill. Recovered 26 gals. OA 0 0 0 0 Well Type In]. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) This well is shut in. Testing 3 -1/2 x 9 -5/8" annulus. Test was performed in accordance w/ Storage Injection Order NO. 9, Rule 5 Sundry Number 312 -026 1 s Form 10 -426 (Revised 06/2010) MIT CLU 03 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 12, 2012 TO: Jim Regg ��, 31 1 3I iv P.I. Supervisor 1 f ft I I SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 05 FROM: Matt Herrera CANNERY LOOP UNIT 05 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: CANNERY LOOP UNIT 05 API Well Number: 50 -133- 20474 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH120307102811 Permit Number: 196 - 073 - Inspection Date: 3/1/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 05 Type Inj. N TVD IA 0 555 , 545 543 PTD 1960730 - TypeTest SPT Test psi 500 - OA Interva MOTHER - P/F P - Tubing ° - 0 0 0 - Notes: Monobore completion NO OA. MIT performed for CINGSA order no. 9 Sundry 312 -026. - Monday, March 12, 2012 Page 1 of 1 • • R J _' .t SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production, LLC 6,07 PO Box 1949 Kenai, AK 99611 Re: Cannery Loop Unit, Beluga Pool, Cannery Loop Unit #5 Sundry Number: 312 -026 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. 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 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, Daniel T. Seamount, Jr. 2:K1 Chair DATED thisfrf day of February, 2012. Encl. III Marathon Alaska Production LLC • fi �1`,�,� Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 January 19, 2012 RFCFNFD Mr. Daniel Seamount JAN < 2017 Alaska Oil & Gas Conservation Commission 333 W 7 Ave .t S a 9:i Oat i ✓ciis. OMITISSiar Anchorage, Alaska 99501 err °mr ,t�fi Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #05 Dear Mr. Seamount, Submitted for your approval is the10 -403 Application for Sundry Approvals for CLU -05 well. Marathon proposes to perform a Mechanical Integrity Test of the wellbore to comply with the Storage Injection Order No. 9, Rule 5: Demonstration of Mechanical Integrity. Please find attached the Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Mechanical Test Plan which provides a summary and background for the test, the details that relate to the subject well, and a current wellbore schematic, depicting the Sterling C1 interval depths. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 0_4 -6)ji-eti Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC CINGSA SIO 9 Mechanical Integrity Test Plan Houston Well File Current Well Schematic Kenai Well File (2) KJS • STATE OF ALASKA � p,j•` ,\41J� WED ALAS•IL AND GAS CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 °i 3 ;� '.1. 11 LIAX [AMR 1 .Onp'r i info 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ p r ved program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: "Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Perform MIT Test . 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development El Exploratory ❑ 196 -073 . 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 50 - 133 - 20474 - 00 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Cannery Loop Unit #5 • Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): L. _ 10. Field / Pool(s): q i"" a. l�.- .t � S FFE -C11l1 3 221 ' '2 - 1 / • 2- - ; 12--- Cannery Loop Unit / Beluga & ols /Pi-27./7_- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,424' 10,239' ' 10,148' 8,964' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 142' 142' Surface 2,936' 13 -3/8" 2,970' 2,576' 3,090 psi 1,540 psi Intermediate 1,178' 9 -5/8" 1,212' 1,200' 7,930 psi 6,620 psi Production 7,966' 9 -5/8" 9,178' 7,997' 9,440 psi 5,300 psi Liner 2,447' 7" 11,421' 10,239' 8,160 psi 7,030 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,110' - 9,900' 5,927' - 8,716' Short String 3 -1/2" L -80 7,025' Long String 3 -1/2" L -80 9,178' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): SSSV: NA Packers: Baker GT Dual & F - 1 5,898' & 9,655' 4,278' & 7,819' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 19 BOP Sketch ❑ Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: February 1, 2012 Commencing Operations: Oil ❑ Gas 151 - 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 Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature -� 6 - Phone (907) 283 -1371 Date January 19, 2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �l 2 O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: ` 5oo p4 Avi 1 -- Subse Form Required: / 0 _ 1101 APPROVED BY � r � � � �� Approved by: COMMISSIONER THE COMMISSION Date: 11 z • ,6 . , RBDMS FE B 14 2012 - ,,,/ tNAL R 1 _ ,,,,, Form 10 -403 Revised 1/2010 S ubmit in Duplicate • Cook Inlet Natural Gas Storage Alaska, LLC Proposed Mechanical Integrity Test Plan Cannery Loop Sterling C Gas Storage Pool Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) requested by application dated July 27, 2010, a storage injection order from the Alaska Oil and Gas Conservation Commission (AOGCC) authorizing injection for the underground storage of natural gas in the Sterling C Gas Storage Pool of the Cannery Loop Unit. The AOGCC held a public hearing on October 19 -20, 2010 during which CINGSA presented oral and written testimony concerning the project. By Order, the AOGCC issued Storage Injection Order No. 9 (SIO 9) dated November 19, 2010, granting CINGSA the authority to commence the injection of gas for underground storage subject to certain Conclusions and Rules, all as more fully outlined in SIO 9. Two of the key requirements imposed on CINGSA as a condition of SIO 9 are that CINGSA 1) demonstrate the mechanical integrity of all storage injection wells and existing pool wells before injection commences (Rule 5 Demonstration of Mechanical Integrity), and 2) maintain surveillance of operating parameters for storage and offset wells to provide continued assurance that gas remains confined to the Sterling C Gas Storage Pool (Conclusion 8). Following, is the methodology CINGSA proposes to employ to demonstrate the mechanical integrity of all existing pool wells and maintain continued surveillance of the Pool to assure that gas remains confined to the Sterling C Pool. All new gas storage wells will be tested in accordance with 20 AAC 25.412 (c)(d). CINGSA proposes to satisfy the requirements of Conclusion 8 and Rule 5 of SIO 9 through routine monitoring of the annulus pressure of existing wells, and via pressure testing the annulus of certain wells to demonstrate their mechanical integrity, plus the tubing string of certain other wells. Table 1 provides a summary of the scope of CINGSA's proposed measures to satisfy the requirements of Conclusion 8 and Rule 5. The rationale for monitoring pressure of certain annuli and performing a mechanical integrity test is more fully summarized for each individual well below. Table 2 provides a depth reference to the Sterling C1 interval, from Sterling C1 Top to U. Beluga Top, by well. Routine monitoring and recording of annulus pressure will help identify whether any gas may be leaking from the Sterling C Pool or other formations. CINGSA proposes a monthly monitoring and reporting frequency to satisfy the requirements of Conclusion 8. CINGSA proposes to conduct a mechanical integrity pressure tests on the annulus of the wells listed in Table 1 to satisfy the requirements of Rule 5. CINGSA proposes a maximum test pressure of 500 psi for 30 minutes since most of the wells are not completed with tubing set on a packer, and thus, are not in the same configuration contemplated in 20 AAC 252. • • Table 1 Proposed Routine Monitoring and Mechanical Integrity Test Plan Cook Inlet Natural Gas Storage Alaska, LLC Well Name Current Status Annulus for MIT Routine Monitor Annulus CLU 1RD Producing 4 1/2 x 7 4 1/2 x 7 and 7 x 9 5/8 CLU 3 Inactive 3 1/2 x 9 5/8 3 1/2 x 9 5/8 CLU 4 Inactive 3 1/2 x 13 5/8 3 1/2 Tbg, 3 1/2 x 13 5/8, and 13 5/8 x 20 CLU 5 Inactive 3 1/2 Tbg x 9 5/8 3 1/2 Tbg, 3 1/2 x 9 5/8, and 9 5/8 x 13 3/8 CLU 6 P & A Sterling C 4 1/2 Tbg 4 1/2 tbg and 4 1/2 x 7 CLU 7 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 8 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 9 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 10 Planned P & A 3 1/2 Tbg and 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 11 Producing 3 1/2 x 9 5/8 3 1/2 x 9 5/8 and 9 5/8 x 13 3/8 CLU 12 P & A'd Sterling C None 9 5/8 Csg Table 2 Cannery Loop Wells, Sterling C interval, Sterling C1 Top to U. Beluga Top Well Name Sterling C depth interval, MD Sterling C depth interval, TVDSS CLU 1RD 5815 -6155 -4927 to -5155 CLU 3 5313 -5574 -4963 to -5205 CLU 4 5171 -5409 -4971 to -5198 CLU 5 6063 -6300 -4856 to -5081 CLU 6 7782 -8114 -4876 to -5099 CLU 7 7700 -7965 -4858 to -5095 CLU 8 6690 -6945 -4871 to -5101 CLU 9 5942 -6195 -4860 to -5102 CLU 10 5372 -5614 -4883 to -5125 CLU 11 6281 -6537 -4876 to -5113 CLU 12 7264 -7522 -4920 to -5158 • • • CLU 5 CLU 5 is completed with dual 3 -1/2" tubing strings, both set on a packer inside of 9 5/8" casing, which was set at a depth of 9176 ft MD. One of the 3 %2 strings is currently completed to the Beluga and the other to the Tyonek interval. The packer is at a depth of 5898 ft MD and the Sterling interval extends from 6063 -6300 ft MD, below the packer. Proposed Annuli to configure for routine pressure monitoring: • Need to monitor pressure on both 3 tubing strings • Dual 3- 1/2 "x9 -5/8" tubing head • 9 -5/8 "x 13 -3/8" casing head Proposed Mechanical Integrity Test Procedure: • Perform a 500 psi test of the dual 3 -1/2" x 9 -5/8" annulus being mindful of the low pressure on the inside of the tubing and of collapse (packer at 5898 ft MD). CINGSA proposes a 30 minute test duration with no more than a 10 percent change in pressure during that time interval being required for a valid test. • The proposed pressure test will apply an approximate differential of 2059 psi at 5898 ft MD/4755 ft TVD, per the following assumptions: an approximate 500 psi internal tubing pressure at TVD; a fresh water hydrostatic gradient in the annulus, and the 500 psi of applied surface pressure. • Testing of the 9 5/8" x 13 3/8" annulus is not recommended since it would most likely serve as a leak off test of the surface casing shoe at 2970 ft MD. M • • CLU -5 !lI' ill Pad 1 API #: 50- 133 - 20474 -00 -00 270' FEL, 180' FSL, Marathon Oil Permit #: 196 -073 Sec. 7,T5N, R11W, S.M. Alaska Production LLC.. RT -GL: 34.2' Tree cxn = 3 -1/2" EUE 8rd t 3 ", 5 -bolt crescent flange cap 1 Conductor: Lift threads = ? 20 ", 129ppf @ 142' Surface Casing: 13 -3/8 ", 61 ppf, K -55, BTC Y @ 2970' Cmt w/ 1790 sks of class G • r Longstrinq 3 -1/2 ", 9.2 #, L -80, Butt -Mod Baker GT dual packer @ 5,898' el ti Mt) X - nipple at 9705' ID = 2.813" X nipple at 9746' ID = 2.813" Shortstrinq: y �� Wireline re -entry guide at 9752' 3 -1/2 ", 9.2 #, L -80, Butt-Mod "' 11i tl Steel & Carbide Blast Joints X - nipple at 5943' ID = 2.813" ".' Sterling C1 7119'- 7159', 7223'- 7347', 7403'- 7443', X - nipple at 5985' ID = 2.813 "' '' Interval: 7501'- 7572', 7750'- 7836', 7841'- 7924', X - nipple at 6980' ID = 2.813" f`- f 6063 -6300 ft MD 7996'- 8096', 8115' -8215' X- nipple at 7020' ID = 2.813" r Wireline re -entry guide at 7025' # V t Prod. Casing: 9 -5/8" @ 9,178' BTC ;_ L -80 53.5ppf 0' - 1212' P -110 47 ppf 1212' - 9178' Cmt w/ 850 sx lead, 1069 sx of class G tail, (total:1919 sks )of class G TOCE: 2200 ft MD, estimated (25% excess) Perforating Record: ' Liner: Shortstrinq Perfs (Beluga) 4, 7" 29 ppf N -80 BTC 7110' -7118' (6spf, 11/29/96) i @ 8,974' - 11,421' 7228' -7248' (6spf, 11/29/96) i • ? Cmt w/ 750 sks of class G 7264' -7298' (6spf, 11/29/96) I , 1 7392' -7405' (6spf, 11/28/96) 7502' -7522' (6spf, 11/28/96) 11--------_ Baker F -1 packer w/ 10' sealbore @ 9,655' 7752' -7786' (6spf, 11/27/96) 7844' -7874' (6spf, 11/27/96) 7980' -8000' (6spf, 11/26/96) Fish: 8104'-8118' (6spf, 11/26/96) ;' 8146' 8170'(6spf, 11/25/96) 1 LS: 7" pkr 11,193'- 10,935' SS: 38.6'x2 -1/8" guns (11/96) Longstrinq Perfs (Tyonek) T -1: 9,860' - 9,900' (6 spf, 9/99 &2/97) T -1: 9,860' - 9,900' (Reperf 5spf, 5/03) Tag Fill: ' LS: 10,276' -294' (sqzd 8/99) = - 10,148' DIL 9/99 10,294' -319' (sqzd 7/99) 10, 145' WLM 1/02 10,146' WLM 1/03 10,015' WLM 9/10 2.25" GR , SS: . 7,756' KB 7/04 b Cement plug: 10,148'- 10,935' KB I TD = 11,424 Well Name & Number: Cannery Loop Unit #5 Lease: Cannery Loop Field County or Parish: Kenai Peninsula Borough State: Alaska I Country:I USA Perforations (MD): (TVD): Angle /Perfs: Angle @ KOP and Depth: Dated Completed: 3/24/2003 Completion Fluid: Prepared By: Kevin Skiba Last Revison Date: Mike Sulley, 10/31/2011 • • SIIKE (1[F SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kevin J. Skiba Regulatory Compliance Representative r t7 3 Marathon Alaska Production, LLC 1 j (9 P.O. Box 1949 Anchorage, AK 99611 -1949 Re: Cannery Loop Field, Beluga 8; Tyonek Pool, Cannery Loop Unit #5 Sundry Number: 311 -260 Dear Mr. Skiba: SEP t 1 MI 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, `. / Daniel T. Seamount, Jr. .,G_ Chair DATED this day of September, 2011. Encl. • • ? •w` Marathon Alaska Production LLC Alaska Asset Team Marathon Oil P.O. Box 1949 Kenai, AK 99611 Telephone (907) 283 -1371 Fax (907) 283 -1350 August 24, 2011 Mr. Winton Aubert RECEIVED Alaska Oil & Gas Conservation Commission AUG 2 5 2011 333 W 7 Ave Anchorage, Alaska 99501 A*a*ka 011 & Gas Cant. Gomm jj Anchorage Reference: 10 -403 Application for Sundry Approvals Field: Cannery Loop Field Well: Cannery Loop Unit #5 Dear Mr. Aubert, Submitted for your approval is the10 -403 Application for Sundry Approvals for j CLU -5 well. Marathon proposes to install a 3/8" capillary string in CLU -5 short strio a target setting depth of 7,020' MD. The capillary string will be used as a conduit place foamer near the wellbore perforations to assist in fluid removal. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, 4<ku-vki Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File (2) KJS i. t� i o STATE OF ALASKA r ALASKA* AND GAS CONSERVATION COMMISSI r';Y AUG 2 5 111 `` �?9 -,// APPLICATION FOR SUNDRY APPROVALS r��.. 20 AAC 25.280 At oka ON & 'gas C!• Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Charrogram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Install capillary string = El f 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development 0 Exploratory ❑ `. 196 -073 " 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 . 50 - 133 - 20474 - 00 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes ❑ No El Loop Unit #5 (Short String)' 9. Property Designation (Lease (lumber): 10. Field / Pool(s): • • iger,*i �+ S'69 FEE - CIRI ,33L -j (QQ) Cannery Loop Unit / Beluga & Tyonek Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,424' • 10,239' • 10,148' 8,964' NA NA / Casing Length Size MD l TVD Burst Collapse Structural Conductor 108' 20" 142' 142' Surface 2,936' 13 -3/8" 2,970' 2,576' 3,090 psi 1,540 psi Intermediate 1,178' 9 -5/8" 1,212' 1,200' 7,930 psi 6,620 psi Production 7,966' 9 -5/8" 9,178' 7,997' 9,440 psi 5,300 psi Liner 2,447' 7" 11,421' 10,239' 8,160 psi 7,030 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,110' - 9,900' ; - 5,927' - 8,716' SS 3 -1/2" L -80 7,025' // LS 3 -1/2" / L -80 9,178' Packers and SSSV Type: SSSV: NA Packers and SSSV MD (ft) and TVD (ft): SSSV: NA Packers: Baker GT Dual & F - 1 5,898' & 9,655' r 4,278' & 7,819' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development . 1511 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Se4. 2071 Commencing Operations: Oil ❑ Gas • el - 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 Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature Phone Date (907) 283 -1371 August 24, 2011 COMMISSION USE ONLY ((�� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 I ��W 0 1 I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 10 — C!. pt4 APPROVED BY / 1' Approved by: COMMISSIONER THE COMMISSION Date: %‘ RBDMS SEP 01 201 Form 10 -403 Revised 1/2010 ' ii S i A L Submit in Duplicate . . Marathon Oil CLU 5S Capstring Install Cannery Loop Unit Capstring Installation Procedures WBS: WO.11.23540.EXP.001 APPROVALS: Michael Dammeyer 8 -24 -2011 Program Writer Michael Ellis Lyndon Ibele Well Status: CLU 5S is SI, but will soon be brought back on line, and it makes lots of water. Obiective: Install cap string in CLU 5S. Justification: CLU 5S should be flowed with as little drawdown as possible as it is completed in the Beluga formation and makes lots of water (and it has had water covering the perfs for years now while SI) so it will be challenging to accomplish flowing the well without excess solid production. Procedure: Install Cap String in CLU 5S: Note: Before running capstring, there must be a) an approved Sundry (see Kevin Skiba) and b) the wellbore must be clear (slickline tag & PT). 1. Install WHA. 2. Check Fluid Control Valve using hand pump. If required, set FCV (making sure it is the "new" model). Pressure such that CICM surface line pressure equals BHP (check with '' BJ for CICM history, as required pressures may change): (Guideline setting TVD 5838 fCLU 8 = 5193'l)(0.433 psi /ft H20)(1.036 foamer SG) = 2620 psi 3. Install valve on the end of coil string. 4. P/U Dyna -Coil injector with crane. 5. Lower injector head carefully on to the pack -off (line up slot with the pack -off's IA" x 4" nipple). 6. Attach hydraulic hoses to hydraulic rams and Insert snubbing guides. Prepare to pressure test. 7. Wrap wellhead and packoff with absorbents to catch drips. Clear wellhead 8. Pressure hydraulic rams (top seal, 1 /4" nipple) on pack -off to 3000 psi. 9. Open Rattiguns all the way. Watch for pressure leaks. 10. Open slips. Monitor weight indicator to ensure injector is holding weight. 11. Adjust hydraulic rams pressure to minimum level (100 — 500 psi). 12. Open swab valve. Watch for leaks at pack -off. 13. Set depth counter. 14. RIH at 100 fpm, to set depth of 7020'. i \ \kgfrs600.mgroupnet.com \bmq$ \My Documents \Well Forms \Cannery Loop \CLU- 05 \Capstring Install CLU 5S 08-22 - 11.docx -2- • 15. Set slips. Set Rattiguns. Release pressure on upper hydraulic seal (to protect operator). Watch for leaks. 16. Lift injector head off and away from well. 17. Pressure hydraulic rams (top seal) on pack -off to 2500 psi. Close needle valve and insert hydraulic plug. 18. Pull tubing excess through injector, or split injector head to remove tubing if over 500' of excess coil. 19. Connect tubing to Swagelok injection manifold (valve, gauge, filter, gauge, valve) to CICM line. 20. Lockout Swab, Upper Master, and Lower Master as per Capstring Lockout Procedure. 21. Pump foamer into capstring until fluid packed (if not already full). 22. Hookup injection line to CICM. Start foamer at 1 gpd. 23. Replace well house. Be careful of the tubing "bend" as it goes back inside if it extends through the roof. 24. RDMO. Cleanup site. Sign -out. Fill out Well Ops Transfer Sheet. \ \kgfrs600.mgroupnet.com \bmq$ \My Documents \Well Forms \Cannery Loop \CLU- 05 \Capstring Install CLU 5S 08-22 - 11.docx -3- • • CLU -5 Pad 1 API #: 50- 133 - 20474 -00 -00 270' FEL, 180' FSL, Permit #: 196 -073 Sec. 7,T5N, R11W, S.M. Ailk RT -GL: 34.2' M ARATHON Tree cxn = 3 -1/2" EUE 8rd II 3 ", 5 -bolt crescent flange cap Conductor: Lift threads = ? 20 ", 129ppf @ 142' Surface Casing: 13 -3/8 ", 61 ppf, K -55, BTC @ 2970' i Cmt w/ 1790 sks of class G I Longstrinq 3 -1/2 ", 9.2 #, L -80, Butt -Mod ' " X- nipple at 9705' ID = 2.813" Baker GT dual packer @ 5,898' - X- nipple at 9746' ID = 2.813" ti' Wireline re -entry guide at 9752' Shortstrinq: k 3 -1/2 ", 9.2 #, L -80, Butt -Mods Steel & Carbide Blast Joints 7119'- 7159', 7223' -7347', 7403'- 7443', X- nipple at 5943' ID = 2.813" 1: - - 7501' 7572', 7750' - 7836', 7841'- 7924', X- nipple at 5985' ID = 2.813" t Fn 7996'- 8096', 8115' -8215' X- nipple at 6980' ID = 2.813" -+ 1I 1 X- nipple at 7020' ID = 2.813" Wireline re-entry guide at 7025' ,,(. �`it b; , to Prod. Casing: i� . t" 9 -5/8" @ 9,178' BTC i L -80 53.5ppf 0' - 1212' P -110 47 ppf 1212' - 9178' MN MINIM Cmt w/ 1919 sks of class G t i w Perforating Record: 1 Liner: Shortstrinq Perfs (Beluga) / 7110' -7118' (6spf, 11/29/96) Jite 7" 29 ppf N -80 BTC @ 8,974' - 11,421' Cmtw/ 750 sks of class G 7228' -7248' (6spf, 11/29/96) 7264' -7298' (6spf, 11/29/96) 7392' -7405' (6spf, 11/28/96) -I Baker F -1 packer w/ 10' sealbore @ 9655' 7502' -7522' (6spf, 11/28/96) 7752' -7786' (6spf, 11/27/96) }' 7844' -7874' (6spf, 11/27/96) 7980' -8000' (6spf, 11/26/96) Fish: 8104' -8118' (6spf, 11/26/96) 8146' -8170' (6spf, 11/25/96) k i LS: 7" pkr 11,193' 10,935' Longstrinq Perfs(Tyonek) I SS: 38.6'x2 - 1/8" guns (11/96) T -1: 9,860' - 9,900' (6 spf, 9/99 &2/97) Taq Fill: T -1: 9,860' - 9,900' (Reperf 5spf, 5/03) , - LS: 10,276' -294' (sgzd 8/99) 10,118' DIL 0 /99 10,294'- 319'(sgzd 7/99) 10, 115' WLM 1/02 T'! 10,116' WLM 1/03 ,", 10,015' WLM 9/10 2.25" GR t 4 a SS: 7,756' KB 7/04 ; ' i s a :- 0 Cement plug: 10,148'- 10,935' KB ii TD = 11,424 Well Name & Number: Cannery Loop Unit #5 Lease: Cannery Loop Field County or Parish: Kenai Peninsula Borough State: Alaska I Country:I USA Perforations (MD): (TVD): Angle / Perfs. Angle © KOP and Depth Dated Completed: 3/24/2003 Completion Fluid: Prepared By: Kevin Skiba Last Revison Date: 9/10/2010 M Marathon MARATHON Oil Company August 22, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th 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 ~E~`~~~ AUG 2 ~ 2008 Alaska Oil & Gas Cans, Car,~mission Anchorage Reference: 10-404 Report of Sundry Well Operations ~ ~ ~ w ~ + `~ Field: Cannery Loop Unit Well: Cannery Loop Unit #5L Dear Mr. Maunder: ~.~~~~~ ~~? ~ ~' ZQO Attached for your records is the Report of Sundry Well Operations 10-404 for CLU-5L. This sundry covers the reperforation of the Tyonek formation completed through the long string of CLU-5 well Please contact me at (907) 283 -1371 if you have any questions or need additional information. Please return any correspondences to me utilizing the address in the above letterhead. Sincerely, Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Current Well Schematic KJS 9~~ STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSION RG.~~I V G~ AUG 2 5 200$ REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Carnmission 1. Operations Abandon Repair Well Plug Perforations Stimulate Other orate Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name; Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Development^ Exploratory^ 196-073 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20474-00-00 7. KB Elevation (ft): 9. Well Name and Number: 34' AGL Canne Loo Unit #5L 8. Property Designation: 10. Field/Pool(s): ADL - 60568 Cannery Loop Unit /Beluga 8~ Tyonek Pools 11. Present Well Condition Summary: Total Depth measured 11,424' feet Plugs (measured) NA true vertical 10,239' feet Junk (measured) NA Effective Depth measured 10,148' feet true vertical 8,964' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1Og' 20" 142' 142' Surface 2,936' 13-3/8" 2,970' 2,576' 3,090 psi 1,540 psi Production 1,178' 9-5/8" 1,212' 1,200' 7,930 psi 6,620 psi Production 7,966' 9-5/8" 9,178' 7,997' 9,440 psi 5,300 psi Liner 2,447' 7" 11,421' 10,239' 8,160 psi 7,030 psi Perforation depth: Measured depth: 7,110' - 9,900' True Vertical depth: 5,927' - 8,716' LS = 3-112" L-80 9,178' Tubing: (size, grade, and MD) SS = 3-1/2" L-80 7,025' Baker GT Dual Packer 5,898' Packers and SSSV (type and measured depth) Baker F-1 Packer 9,655' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 2 Subsequent to operation: 0 0 0 1 4 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work : Oil ^ Gas 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: NA Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineer Technician i Signature Y Phcne (907) 283-1371 ~~~ t ~~ Date August 22, 2008 Form 10-404 Revised 04/2006 Submit Original Only ~'-~~~ • • ,^ Ma ra h t on Operations Summary Report r , ,~ ~,~ .,,.~~, Qj~ I`~"" Ya~ Well Name: CANNERY LOOP UNIT 05 wily Operations port Date: 5f2812008 Jab Category. R&M MAINTENANCE 4 Hr Summary RU Pollard to tag TD (10,055' KB} and run PT Survey. WHP 580 psi. Stm Tme Fnd Tune bur s Code Activi Code SYxus rouble Code ~~~ 08:45 09:45 1.00 SAFETY MTG AF Hold PJSM. Discuss Pollard JSA, alarms, emergency response, and muster area. Obtain SW Permit. 09:45 11:00 1.25 RURD SLIK AF Spot equipment. PU lubricator. MU tool string. Cary lubricator to WH. 11:00 11:15 0.25 TEST EQIP AF FTest lubricator. Test good. 11:15 12:15 1.00 RURD SLIK AF RIH (1) w/ 2.17" GR. Tag TD @ 10,055KB. Below perfs @ 9860'- 9900'. POOH. 12:15 12:34 0.33 RURD SLIK AF FV pressure temperature gauges, Test QTS. 12:34 15:46 3.20 LOG OTHR Af Open swab. Hold at surface for 5 min bench. RIH @ 120 fpm to 10,000'. Stop for 10 min bench. POOH @ 120 fpm with 3 min stops @ 9880', and 5000'. Continue POOH @ 120 fpm with 5 min stop at surface. 15:46 16:31 0.75 RURD SLIK AF RD slick line unit. 16:31 16:46 0.25 SECURE LL f Close swab and upper mastervalve SS'r^s already closed. Turn in Permit. Sign out and leave loc. ort Date: 7l23f2008 Job Category. RbM MAINTENANCE 24 Hr Summary MIRU Expro eline RIH repertorate from 9860'- 9900', produce to sales. scan r.,re rTd rune a,r s code JMivi code s sxus Trouble Code Carrrnent 07:00 08:00 1.00 SAFETY MTG AF Held FJSM, discussed operations with personnel. Discussed muster area, eye wash stations and crane safety. 08:00 09:15 1.25 RVRD ELEC AF Spot equipment. RU lubricator, equipment. B~vvire line BOP. 09:15 12:30 3.25 RVRD ELEC AF Held Explosive safety meeting prior to arming gun. Shut down all phones and placed man on gate. Armed 2 3f8" 40' gun, loaded @ 4 SPF, 0 deg phased. PTest lubricator to 1500 psig. Test good. Problem with cable from digital depth read out to computer. Trouble shot for 2.5 hours. Found problem continue with electric line task. 12:30 13:30 1.00 WORK ELEC AF RIH wlpertorating gun. Verifed on depth with Sch open hole log dated 11-19-96. Made 37' depth correction. Tag TD @ 10,015'. Pull gun into re perforating position. 13:30 13:49 0.33 PERF CSG AF Re perforate from 9860'- 9900'. WHP= 460 psig. No change in WHP. POOH v~ith gun. 13:49 15:19 1.50 WORK ELEC Af OOH with gun. All shots fired. Gun was split around perforations, indicative of shooting gun in dry gas. No fluid in spent perforated gun when it was laid down. RD wire line unit. Open well to flow back tank. Well went down to Of10 psig making some gas to tank. Extimate of 100 MMCFPD, No fluid. www.peloton.com Report Prirded: 8.?02008 • • -- Marathon Operations Summary Report ^~.~ ~ „,Oil Company Well Name: CANNERY LOOP UNIT 05 Stan Tine 6d Time Dur s Code Pctiv't Code 4 Staus rouble Cade Comniern 15:19 16'04 0.75 RURD ELEC AF Complete rip down, Expro IeR lease. Shut in well to build pressure over nitght. Plan to blow down again in AM. ally Operations port Date: 7262006 Job Category. RB.M MAINTENANCE ?4 Hr Summary MIRU Expro, ran PT survey and tagged fill. Stan Tme rid Tane Dur s Code Activit Lode Status rouble Code Commem 09:00 10:00 1.00 SAFETY MTG AF Held safety meeting discussed safety concerns and JSA. 10:00 12:00 2.OD RVRD ELEC MIRU electric line unit. PU logging tools and PT lubricatorto 1500 psig, good test. Open well, RIH logging at 50 FPM. 12:00 15:00 3.00 LOG OTHR HP = 14 si .Continue logging down to 10,000'. PUH logging, tool struck. Work tools pick weight up to 2700 Ibs before started moving. Tools pulling OOH heavy. 15:00 18:00 3.00 LOG OTHR OOH with logging tool. Shut well in, secured well. RD Expro. Expro left lease. No fluid indicated by oressure gradient MPP = 121 psi. Some cooling across from bottom of perforations at 9690'. www.peloton.com Report Printed: 8202008 196-073 34.2' ee cxn = 3-1/2" EUE 8rd 5-bolt crescent flange cap t threads = ? M MARATM OM Conductor: 20", 129ppf @ 142' Surface Casing: 13-3/8", 61 ppf, K-55, BTC @ 2970' Cmt w/ 1790 sks of class G 3-1/2", 9.2#, L-80, Butt-Mod Cannery Loop 5 Pad 1 270' FEL, 180' FSL, Sec.7,T5N, R11W, S.M. Baker GT dual packer @ 5898' 3-1/2", 9.2#, L-80, Butt-Mod at 5943' ID = 2.813" at 5985' ID = 2.813" at 6980' ID = 2.813" at 7020' ID = 2.813" re-entry guide at 7025' at 9705' ID = 2.813" at 9746' ID = 2.813" re-entry guide at 9752' gel & Carbide Blast Joints 19'-7159', 7223'-7347', 7403'-7443', 01'-7572', 7750'-7836', 7841'-7924', 96'-8096', 8115'-8215' 9-5/8" @ 9,178' BTC L-80 53.5ppf 0' - 1212' P-110 47 ppf 1212' - 9178' Cmt w/ 1919 sks of class G Liner: 7" 29 ppf N-80 BTC @ 8,974' - 11,421' Cmt w/ 750 sks of class G Baker F-1 packer w/ 10' sealbore @ 9655' Fish: LS: 7" pkr 11,193'-10,935' SS: 38.6'x2-1/8" guns (11/96) Tag Fill: LS: 10,146' WLM 1/03 SS: 7,756' KB 7/04 Cement plug: 10,148'-10,935' KB Well Name & Number: Beaver Creek 6 Lease: Beaver Creek Field County or Parish: Kenai Peninsula Borough State: Alaska Country: USA Perforations (MD): (TVD): Angle/Perfs: Angle @ KOP and Depth: Dated Completed: 312412003 Completion Fluid: Prepared By: Kevin Skiba Last Revison Date: 812 212 0 0 8 TD = 11,424 . . Alaska ~._aion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 September 8, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Report of Sundry Well Operations Wells C.L.U~-51, K.___U__U 14_-6_1 and KU 13-61 Dear Mr. Wondzell' Enclosed are the Reports of Sundry Well Operations for the above-referenced wells. If you have any questions, please call me at 564-6315. Sincerely, ~, JP'roGd~'er Engineer M:~I RSDocs~)rilling~jg eclaog.doc Enclosure CC: CEF Well File G. A. Laughlin M. H. Chauffee, Lafayette A subsidiary of USX Corporation Environmentally aware for the long run. ~ . g:\cmn\drlCkgf~wells~kull-Ss~,AOGCC02A.xl$ ~.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate ~ Plugging ~ Perforate X Pull Tubing Alter Casing __ Repair Well ~ Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 180' FSL, 270' FEL, Sec. 7, T5N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective Depth lRecomplete to T-1 Sand At Total Depth 2177' FSL, 2524' FWL, Sec. 8, T5N, R11W, S.M. 6. Datum Elevation (DF or KB) 34.1' KB feet 7. Unit or Property Name Cannery Loop Unit 8. Well Number CLU-51 9. Permit Number 96-73 10. APl Number 50- 133-20474-00 11. Field/Pool Cannery Loop/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 11424 feet Plugs (measured) 10238 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 142 20" driven 2970' 13-3/8" 1790 sx 9178' 9-5/8" 1919 sx 2447 7" 750 sx T-1: 9860' - 9900' (Iongstring only) true vertical T-1: 8679' - 8719' (Iongstring only) Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 9726' Packers and SSSV (type and measured depth) Baker GT dual packer @ 5873' MD Baker F-1 packer @ 9629' MD cement plug 10,148'- 10,935' Measured Depth True Vertical Depth 142' 142' 2970' 2576' 9178' 7997' 11421' 10239' ORIGINAL 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Perforated 9860' - 9900' DIL Treatment Description Including Volumes Used and Final Pressure Plugged perfs 10276' - 10294' DIL with 25 sks of cement. Top of cement at 10,148'. 14. OiI-Bbl Prior to Well Operation well dead Subsequent to Operation 0 Representative Daily Avera.qe Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 46O0 0 0 95O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas X Suspended Service fore 17. I hereby certify that the going. Form 10-404 Re¥. 06/1 . is true and correct to the best of my knowledge. J. Gary Eller Title Production Engineer Date 9/7/99 Submit in Dupli~ Cannery Loop Field Well CLU-5 Maratho n Oil Co., Alaska Region API 50-133-20474 KB-GL: 34.2' 270' FEL, 180' FSL See. 7, T5N, R11W, S.M. Baker model GT Dual Packer C~ 5898' X-Nipple ~.. 5943' 112)=2.813" X-Nipple ~ 5985' ID = 2.813" X-Nipple ~ 6980' ID = 2.813" X-Nipple ~.. 7020' ID = 2.813'' Re-Ent~ Guide ~ 7025' Beluga Sand Perfs 7110'- 7118' (6 spf, 7228'- 7248' (6 spf, 7264' - 7298' (6 spf, 7392'- 7405' (6 spf, 7502'- 7522' (6 spf, 7752' - 7786' (6 spf, 7844' - 7874' (6 spf, 7980'- 8000'(6 spf, 8025' - 8050' (6 spf, 8104'- 8118' (6 spf, 8146' - 8170' (6 spry, 11/29/96) 11/29/96) 11/29/96) 11/28/96) 11/28/96) 11/27/96) 11/27/96) 11/26/96) 11/26/96) 11/26/96) 11/25/96) Fish: 38.6' of 2-1/8" guns (11/28/96)'~ Tyonek S~nd Perfs T-I' 9860'- 9900' (6 spf, 9/3/99) 91-2: 10,276'- 294' (sqzd 8/99) 10,294' - 319' {.sqzd 7/99) TD = 11,424' 20", 129#, Drive Pipe ~ 142' 13-3/8", 61#, K-55, BTC Casing ~ 2970' Cmt w/1790 sks of class G Tubing (Shortstring & Longstring) 3-1/2", 9.2#, L-80, Butt-Mod Steel & C~bide BlastJoint 7119'-7159' 7223'-7347' 7403'-7443' 7501'-7572' 7750'-7836' 7841'-7924' 7996'-8096' 8115'-8215' 7" Liner Top Q¢ 8974' w/TIW S-6 liner-top packer 9-5/8", BTC casingS9178' 0'-1212':53.5#, L-80 1212'-9178':47#,P-110 Cmt w/1919 sksofClass G Baker "F-1" Packer w/ 10' sealbore ~ 9655' X Nipple (~t) 9705' ID= 2.813" X Nipple (/_~ 9746'. ID = 2.813" Wireline re-entry guide (~ 9752' Tag fill ~ 10,148' DIL (9/3/99) Cement plug: 10148'- 10935'KB Fish: 7" packer 11193'- 11288' (12/22/96) 7", 29#, N-80, BTC liner ~ 8974' - 11421' Cmt w/750 sks Last Rev: JGE, 9/8/99 990903.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 9/3/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10,304' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Perforate T-1 Sand OTHER: Day #3, AFE 9700899 - Recomplete to the T-1 Sand WELL #: CLU-51 7", 29#, N-80 good none SUMMARY OF OPERATIONS MIRU electric line. Test lubricator and BOPs to 2600 psig using methanol. MU 40' of 2-1/8", 6 spf, +/- 4,5 deg phased strip guns with 14.4 gm Enerjetcharges. nIH with guns. Tag cement at 10,148' DIL, and tie in with GR/CCL. Position guns and perforate theTyonekT-1 Sand 9860' - 9900' DILwith estimated 1500 psi underbalance. After firing, tubing pressure increased from 250 psig to 1300 psig. POOH. All shots fired. RDMO electric line. .= Vendor Equipment Daily Cost Cumulative Cost Air Liquide bulk nitrogen $0 $2,643 Dowell coil tubing, nitrogen unit $10,000 $37,400 Doyle's Fuel diesel $0 $191 Misc. car rental, airline $500 $2,000 R&K Construction vac truck $0 $800 Schlumberger perforating $18,800 $18,800 Toloff Crane $1,950 $4,550 Trucking $1,500 $3,500 DAILY COST: $32,750 CUM: $69,884 REPORTED BY: J.G. Bier 990828.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8~28~99 FIELD: FILL DEPTH/DATE: 10,304' KB TUBING: DATE LAST WL WORK: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Tag cement plug, blow well dry OTHER: Day #2, AFE 9700899 - Recomplete to the T-1 Sand Cannery Loop WELL #: CLU-51 3-1/2", 9.2#, L-80 CASING: 7", 29#, N-80 TREE CONDITION: good none SUMMARY OF OPERATIONS RU 1-1/2" coil tubing. Test lubricator to 4200 psig. SITP = 0 psig. RIH with coil tubing. Tag cement plug at 10,186' CTM (correlates to approximately 10,195 KB,). Begin circulating nitrogen down coil while taking fluid returns on tubing. Continue until well jetted dry (only required 51,200 SCF nitrogen). Recovered 104 bbl of fluid from tubing. Shut down nitrogen. POOH with coil tubing while letting surface pressure bleed to 250 psig. RDMO coil tubing. Vendor Equipment Daily Cost Cumulative Cost Air Liquide bulk nitrogen $2,643 $2,643 Dowell coil tubing, nitrogen unit $10,000 $27,400 'iDoyle's Fuel diesel $0 $19 1 Misc. car rental, airline $500 $1,500 R&K Construction vac truck $400 $800 Toloff Crane $1,170 $2,600 Trucking $0 $2,000 DALLY COST: $14,713 CUM: $37,134 REPORTED BY: J.G. Eller 990827.xls MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 8/27/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10,304' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: TREE CONDITION: WORK DONE: BENCHES OPEN: PRESENT OPERATION: Lay-in cement plug OTHER: Day #1, AFE 9700899 - Recomplete to the T-1 Sand WELL #: CLU-51 7", 29#, N-80 good Ty0nek 91-2 Sand SUMMARY OF OPERATIONS MIRU 1-1/2" coil tubing. Fill 500 bbl tank with fresh water. Test BOPE and lines to 4200 psig. Held safety and operations meeting. SITP = 450 psig. Open up well, pressure bled right off. RIH with coil tubing circulating at minimum rate. Tag up at 10,295' CTM. Blend 25 sacks of 15.8 ppg cement (5 bbl of slurry) and pump downhole. Displace with fresh water. L_ayin cement plug from 10,304' KB to 10,166' KB. Continue to circulate out of the hole to 9900' CTM. Stop circulating, and finish POOH. RD coil tubing. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing, cement $17,400 $17,400 Doyle's Fuel diesel $191 $191 Misc. car rental, airline $500 $1,000 R&K Construction vac truck $400 $400 Toloff Crane $1,430 $1,430 Trucking $2,000 $2,000 DAILY COST: $21,921 CUM: $22,421 REPORTED BY: J.G. Eller Alaska R on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 26, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Application for Sundry Approvals Well CLU-51 Dear Mr. Wondzell: Enclosed is the Application for Sundry Approvals for Well CLU-51. If you have any questions, please call me at 564-6315. Sincerely,\ Engineer M:',N RSDocs'~Ddlling~jgeclaog.doc Enclosure CC: CEF Well File G. A. Laughlin M. H. Chauffee, Lafayette Alaska Oil ~ Gas Cons. uo~ .... ' ' AnchoraGe, A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS n:~drlg~clu'~clu51'tAogccO2.xls~.,~ 1. Type of Request: Abandon Suspend ~ Operation Shutdown Alter Casing Repair Well ~ Plugging. X Change Approved Program Pull Tubing Variance Re-enter Suspended Well Time Extension Stimulate Perforate X Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 180' FSL, 270' FEL, Sec. 7, T5N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic__ Service At Effective Depth lPlug the Tyonek 91-2, per[ the T-1 At Total Depth 2177' FSL, 2524' FWL, Sec. 8, T5N, R11W, S.M. 6. Datum Elevation (DF or KB) 34.1' KB feet 7. Unit or Property Name Cannery Loop Unit 8. Well Number CLU-51 9. Permit Number 96-73 10. APl Number 50- 133-20474-00 11. Field/Pool Cannery Loop/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 11424 feet Plugs (measured) 10238 feet Cement plug @ 10294' MD Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size 142 20" 2970' 13-3/8" 9178' 9°5/8" 2447 7" measured 91-2 Sand: 10276' - 10294' (Iongstring only) true vertical 91-2 Sand: 9095' - 9113' (Iongstring only) Tubing (size, grade, and measured depth) 3-1/2", 9.2~, L-80 @ 9726' Packers and SSSV (type and measured depth) Baker GT dual packer @ 5873' MD Baker F-1 packer @ 9629' MD Cemented driven 1790 sx 1919 sx 750 sx 0RI61NAL Measured Depth 142' 2970' 9178' 11421' True Vertical Depth 142' 2576' 7997' 10239' Oil & Gas Cons. Con~issior~ Anchorage 13. Attachments Description Summary of Proposal~ Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 115. Status of Well Classification as: 9/10/99 16. If Proposal was Verbally Approved Oil__ Gas X Name of Approver Date Approved Service 17. I hereby~ that the for%o~ is true and correct to the best of my knowledge. Signed ~ "~~ ~ Gary Eller Title Production Engineer -- ~, FOR COMMISSION USE ONLY Conditions of Approval: Notif.~Commission so representative may witness BOP Test ~/ Location Clearance Suspended Date 7/30/99 I A P pr°va I N~..~..~/¢<~ Plug Integrity Mechanical Integrity Test Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. 06/15/88 . =~iG!NAL S!GNED. BY F~obert N. Chdsten~l Commissioner Date Submit in Triplicate 990706.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/6/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10935' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/11/99 TREE CONDITION: WORK DONE: Static BHP, tag fill BENCHES OPEN: PRESENT OPERATION: Re-perforate 91-2 Sand OTHER: Day #4, AFE 9700799 - Squeeze & reperf 91-2 Sand WELL #: CLU-51 7", 29#, N-80 good Tyonek 91-2 Sand SUMMARY OF OPERATIONS MIRU electric line on CLU-51. SITP = 1850 psig. Test BOPs and lubricator to 2500 psig. RIHwith 18' of 2-1/8", 0-degree phase, 4 spf, strip guns loaded with 14.3 gram Power Jet charges. Correlate depth with CBL of 11/19/96, and tag PBTD at 10,304' DIL. Bled wellhead pressure down from 1850 psig to 200 psig to apply a 1800 psi underbalance at the perforations. Tie in guns and perforate 10,276' - 10,294' DIL. Only indication of firing was by weight change on the tool string; never saw any pressure build at surface. POOH, all shots fired. RDMO electric line. Vendor Equipment Daily Cost Cumulative Cost Misc. car rental, airline $500 $2,500 Schlumberger perforating $16,000 $16,000 DAILY COST: $16,500 CUM: $98,437 REPORTED BY: J.G. Eller 990701 .xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 7/1/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10935' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/11/99 TREE CONDITION: WORK DONE: Static BHP, tag fill BENCHES OPEN: PRESENT OPERATION: Drill out cement OTHER: Day #3, AFE 9700799 - Squeeze & reperf 91-2 Sand WELL #: CLU-51 7", 29#, N-80 good Tyonek 91-2 Sand SUMMARY OF OPERATIONS RU coil tubing. PU 2-1/8" Mach-1 motor and 2-3/8" underreamer (5.8" blade OD). Total BHA length = 8.79'. Pull tested BHA, internal tested BHAto4500 psig, tested lubricator to 3500 psig. SlTP = 0 psig. RIHwith coil tubing. Dry tag cement at 10,002' CTM and mark pipe. PU and circulate at 1.8 bpm. Drill cement from 10,O02' CTM to 1 0,265' CTM (calculate to be 1 0,O41 ' - 1 0,304' DIL). Easy drilling most of the way until in the vicinity of the perfs, wherethe cement got much harder. Verified total depth reached with a dry tag. SD pumps, POOH to 9700' CTM. Drop 1/2" ball to open circulating sub. POOH to 2600' CTM. Had some difficulty getting the undereamer past the X-nipple at 9746' MD, but eventually able to work through. RU nitrogen unit and test lines. Pump nitrogen down coil at maximum rate. Jet well dry from 2600' CTM. Left well with 2000 psig SITP. Finish POOH with coil tubing. RDMO coil tubing, nitrogen, and crane. Note: Plan to RU electric line to perforate on July 6, 1999. Vendor Equipment Daily Cost Cumulative Cost Baker Oil Tools motor, underreamer $4,201 $4,201 Dowell coil tubing, cement $30,000 $61,600 Doyle's Fuel diesel $0 $414 M-I Drilling fluids KCI, biozan $0 $1,978 i Misc. car rental, airline $500 $2,000 R&K Construction vac truck $1,204 $2,004 Toloff Crane $2,340 $6,240 =Trucking $1,500 $3,500 DAILY COST: $39,745 CUM: $81,937 REPORTED BY: J.G. Eller 990630.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/30/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10935' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/11/99 TREE CONDITION: WORK DONE: Static BHP, tag fill BENCHES OPEN: PRESENT OPERATION: Lay-in cement plug, squeeze, contaminate leftover cement OTHER: Day #2, AFE 9700799 - Squeeze & reperf 91-2 Sand WELL #: CLU-51 7", 29#, N-80 good Tyonek 91-2 Sand SUMMARY OF OPERATIONS RU pump truck. SITP = 535 psig (had left 1150 psi on the well last night). Bled pressure to zero; holding good. Pressure up to 1450 psig, squeeze is also holding. Bled pressure to zero. RD pump truck. MIRU slickline unit. Test BOPs & lubricator to SITP. RIH with 2-1/2" gauge ring and tubing-end Iocator. Locate EOT at 9754'WLM (9752' MD), tag cement at 10,072'WLM (10,070' MD). POOH, RDMO slickline. Note: In the morning, plan to PU motor and undereamer for coil tubing. Will drill out cement to proper depth, then jet with nitrogen to achieve perforating underbalance. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing, cement $1,500 $31,600 R&K Construction vac truck $0 $800 Misc. car rental, airline $500 $1,500 Trucking $0 $2,000 Toloff Crane $520 $3,900 ~M-I Drilling fluids KCI, biozan $0 $1,978 i Doyle's Fuel diesel $0 $414 DAILY COST: $2,520 CUM: $42,192 REPORTED BY: J.G. Eller Alaska h~o,on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 26, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Report of Sundry Well Operations Well CLU-51 Dear Mr. Wondzell' Enclosed is the Report for Sundry Well Operations for Well CLU-,5(. If you have any questions, please call me at 564-6315. Sincerely, jp.r.~Ec~i~rn Engineer M:~lRSDocs~DdllinCjgeClaog.doc Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. --- g:~cmn~drlg~kgf~wells~kul 1-8s~OGCCO1A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate X Pull Tubing Alter Casing Repair Well Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 180' FSL, 270' FEL, Sec. 7, T5N, R11W, S.M. At top of Productive Interval At Effective Depth [Squeeze off water, reperforate At Total Depth 2177' FSL, 2524' FWL, Sec. 8, TSN, R11W, S.M. 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum Elevation (DF or KB) 34.1' KB feet 7. Unit or Property Name Cannery Loop Unit 8. Well Number C CU-~'.~ ,~ Permit Number 96-73 10. APl Number 50- 133-20474--00 11. Field/Pool Cannery Loop/Tyonek 12. Present Well Condition Summary Total Depth: measured true vertical 11424 feet Plugs (measured) 10238 feet Effective Depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented 142 20" driven 2970' 13-3/8" 1790 sx 9178' 9-5/8" 1919 sx 2447 7" 750 sx 10276' - 10319' (Iongstring only) Measured Depth 142' 2970' 9178' 11421' True Vertical Depth 113 142' 257 427 799 88O 1023 890 true vertical 9095' - 9138' (Iongstring only) Tubing (size, grade, and measured depth) 3-1/2", 9.211, L-80 @ 9726' Packers and SSSV (type and measured depth) Baker GT dual packer @ 5873' MD Baker F-1 packer @ 9629' MD 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Squeezed perfs 10294' - 10319' 0ii & 6as Cor~'. C0rr~missio:'~ ~"-1,1 Iht IIJ', Treatment Description Including Volumes Used and Final Pressure Tested squeeze perfs to 1500 psig at surface (13.6 ppg EMW) 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation well dead Subsequent to Operation well dead 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil ~'~Gas X Suspended . %%, si,.ed ,i,.e ,roduc,,o , ,i e r Form 10-404 Rev. 06/15~ ' Service Date 7/30/99 Submit in Duplicat!~, 990629.xls MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 6/29/99 FIELD: Cannery Loop FILL DEPTH/DATE: 10935' KB TUBING: 3-1/2", 9.2#, L-80 CASING: DATE LAST WL WORK: 5/11/99 TREE CONDITION: WORK DONE: Static BHP, tag fill BENCHES OPEN: PRESENT OPERATION: Lay-in cement plug, squeeze, contaminate leftover cement OTHER: Day 1, AFE 9700799 - Squeeze & reperf 91-2 Sand WELL #: CLU-51 7", 29#, N-80 good Tyonek 91-2 Sand SUMMARY OF OPERATIONS MIRU 1-3/4" coil tubing. Fill 500 bbl tank with fresh water. 6/29/99 Finish RU coil tubing. Held safety & operations meeting. Test BOPs to 4500 psig. SITP = 1100 psig. RIH with coil tubing. Tag up at 10,921' CTM (was expecting 10,935' KB). PUto 10,800'. Drag is very high (SKover pipe weight). Circulate hole volume with 3% KCIto purge well of gas. Blend 26 bbl (125 sacks) of 15.8 ppg class "G" cement with 0.13 gal/sk of D-145A, 0.75 gal/sk of D-159, 0.05 gal/skof D-47, and 0.01 gal/skof D-110. Prepare to pump cement, but booster pump down. Swap booster pumps. While trying to get booster pump working, inadvertantly allowed 9 bbl of fresh water to flow into cement tub. It brought the cement weight from 15.8 ppg to 14.1 ppg. Pumped off 10 bbl of diluted cement to pits, followed by 10 bbl of contaminant and flush. Added additional cement and additives to bring slurry to 15.6 ppg. Prepared to pump downhole. Begin pumping cement downholewith much difficulty. Coil nozzle at 10,8OO' CTM. PU while laying cement plug. Pump 25 bbl cement plug up to 10,261' KB while PU coil to 10,150'. Displace cement with 5 bbl fresh water, 10 bbl 3% KCI, and biozan pill (contaminant). When cement finished leaving the coil, shut-in returns and applied squeeze pressure. Applied hesitations up to 18OO psig wellhead pressure; pressure bled to 1100 psig within 30 minutes. Repeated until calculated top of cement is in the vicinity of the top perf. Decided to POOH and let cement set overnight. Note: In the morning will pressure test cement squeeze then tag cement with slickline. If squeeze tests, will PU motor and undereamer and drill cement. If the squeeze doesn't test, will be prepared to lay another cement plug with coil. Vendor Equipment Daily Cost Cumulative Cost Dowell coil tubing, cement $30,100 $30,100 R&K Construction vac truck $800 $800 Misc. car rental, airline $500 $1,000 Trucking $2,000 $2,000 Toloff Crane $3,380 $3,380 M-I Drilling fluids KCI, biozan $1,978 $1,978 Doyle's Fuel diesel $414 $414 DAILY COST: $39,172 CUM: $39,672 REPORTED BY: J.G. Eller R[C iV D 0 O 2 1999 WELL CLU-51- AFE 9700899 CANNERY LOOP FIELD RECOMPLETE TO THE T-1 SAND Objective: Abandon perforations in the Tyonek 91-2 Sand, and perforate the T-1 Sand. Procedure: 1. Shut in both sides of well CLU-5. MIRU 13¼'' coil tubing on CLU-51. Capture 300 bbl fresh water for coil operations. Test BOPs to 4000 psig. R1H with coil tubing. Dry tag top of cement at 10,294' MD. Lay a cement plug from 10, 166' - 10,294' (110' above top perf). Keep coil tubing moving while spotting plug. 2. When cement is displaced from coil, continue to circulate 3% KCI while POOH to 10,000'. Circulate well clean with 3% KC1. When clean, POOH. SDFN. 3. RIH with coil tubing to 10,000'. MIRU nitrogen unit. Blow well dry from 10,000' using nitrogen. Leave well with 200 to 250 psig SITP aPrer blowing dry. POOH, RDMO coil tubing and nitrogen. ri 1 " 4. MIRU elect 'c line Test BOPs and lubricator to 2000 psig RIH with 2/8 strip guns 6 spf, o ' ' ' ' ' +45 phased with 14.4 gm PowerJet charges. Tie m with CCL. Perforate the Tyonek T-Il Sand from 9860' - 9900' DIL with a 1 $00 psi underbalance. {Note: Perforate the interval 9880' - 9900' first to get the most benefit of the underbalance.) POOH, RDMO electric line. 5. Flow well as per instructions of Production Foreman. JGE July 30, 1999 N:\DRLG\CLU~CLU-5IkecompI.\VPD Cannery Loop Field Well CLU-5 Marathon Oil Co., Alaska Region APl 50-133-20474 KB-GL: 34.2' 270' FEL, 180' FSL Sec. 7, T5N, R11W, S.M. Baker model GT Dual Packer ~ 5898' X-Nipple ~ 5943' 1I)=2.813" X-Nipple ~9~ 5985' ID= 2.813'' X-Nipple (~ 6980' 1I)=2.813" X-Nipple (~ 7020' 1I)=2.813" Re-Entry, Guide (¢ 7025' Beluga Sand Peris 7110'- 7118' (6 spt',, 11/29/96) 7228' - 7248' (6 spt', 11/29/96) 7264' - 7298' (6 spt', 11/29/96) 7392'- 7405' (6 spf, 11/28/96) 7502'- 7522' (6 spf, 11/28/96) 7752' - 7786' (6 spt; 11/27/96) 7844'- 7874' (6 spl; 11/27/96) 7980'~ 8000' (6 spt; 11/26/96) 8025'- 8050' (6 spf, 11/26/96) 8104'- 8118' (6 spt', 11/26/96) 8146'- 8170' (6 spf, 11/25/96) Fish: 38.6' of 2-1/8" guns ( 11/28/96) T¥onek Sand Peris 91-2: 10,276'- 294' (2-1/8", 4 spf; 7/6/99) 10,294'- 319' (sqzd 7/99) ~, 20", 129#, Drive Pipe (c~3 142' 13-./8 , 61#, K-55, BTC Casing (¢ 2970' Cmt w~ 1790 sks of class G Tubing_(Shortstrii_A~g_&_ Lo~_l!g~ostring) 3-1/2", 9.2#, L-80, Butt-Mod Steel & Carbide Blast Joint 7119'-7159' 7223'-7347' 740Y-7443' 7501'-7572' 7750'-7836' 7841'-7924' 7996'-8O96' 8115'-8215' 7" Liner Top (al 8974' w/TIW S-4 liner-top packer 9-5/8", BTC casing (~1 9178' I)'- 1212': 53.5#, L-80 1212'- 9178': 47#, P-110 Cmt w/1919 sks of Class G Baker "F-1" Packer w/10' sealbore (,qg 9655' X Nipple ((i) 9705' ID = 2.813" X Nipple ((~) 9746' ID = 2.~13" Wireline re-entry guide ((_} 9752' Tag fill (c})~ 10,304' DIL (7/6/99) Cement plug: 10304'- 10935' KB Fish: 7" packer 11193'- 11288'(12/22/96) 7", 29#, N-80, BTC liner (??)~ 8974'- 11421' Cmt w~ 750 sks Last Rev: JGE, 7/22/99 Alaska ~..,,on Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 7, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: Application for Sundry Approval CLU-51 Dear Mr. Wondzell: Enclosed is the Application for Sundry Approval for CLU-51. If you have any questions, please call me at 564-6315. Sincerely, ~.~ltion Engineer M:~"J RSDocs~Drillingtjge57.doc OR G , AL Enclosure A subsidiary of USX Corporation Environmentally aware for the long run. n:lddglctulclu5JlAogcc01 ,x~s ~,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown Alter Casing Repair Well Plugging Change Approved Program Pull Tubing ~ Variance Re-enter Suspended Well Time Extension Stimulate Perforate X Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 180' FSL, 270' FEL, Sec. 7, T5N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective Depth I Squeeze off water, reperforate At Total Depth 2177' FSL, 2524' FWL, Sec. 8, T5N, R11W, S.M. 12. Present Well Condition Summary Total Depth: measured true vertical 11424 feet Plugs (measured) 10238 feet Effective Depth: measured true vertical 11288 feet Junk (measured) 10106 feet 6. Datum Elevation (DF or KB) 34.1' KB feet 7. Unit or Property Name Cannery Loop Unit 8. Well Number CLU-51 9. Permit Number 96-73 10. APl Number 50- 133-20474-00 11. Field/Pool Cannery Loop/Tyonek ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size Cemented Measured Depth 142 20" driven 142' 2970' 13-3/8" 1790 sx 2970' 9178' 2447 measured 10276' - 10319' (Iongstring only) true vertical 9095' - 9138' (Iongstring only) 9-5/8" 1919 sx 9178' 7" 750 sx 11421' Tubing (size, grade, and measured depth) 3-1/2", 9.2~, L-80 @ 9726' Packers and SSSV (type and measured depth) Baker GT dual packer @ 5873' MD Baker F-1 packer @ 9629' MD True Vertical Depth 142' 2576' 7997' 10239' 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch 14. Estimated Date for Commencing Operation 15. Status of Well Classification as: 6/15/99 16. If:Proposal was Verbally ApProved Oil Gas X Name of~prover ~ Date Approved Service 17. I hereby (~.~the foregoin.~e and correct to the best of my knowledge. Signed ~,,,~.. ~~ ~,~,..,,-~ Gary EIler Title Production Engineer '~"-..._) ~, FOR COMMISSION USE ONLY Conditions of Approval: N~mmission so representative may witness Suspended Date 5/6/99 IAppr°val N°'~'~- Plug Integrity Mechanical Integrity Test Approved by Order of the Commission Form 10-403 Rev. 06/15/88 BOP Test !~' Location Clearance Subsequent Form Required 10- 'Orlglna[ ...... David W, J0hnstor, Commissioner S~lb~it ir{Tripli~;ate WELL CLU-51- AFE 9700799 CANNERY LOOP FIELD SQUEEZE OFF WATER & REPERF Objective: Cement squeeze excess water production from the Tyonek 91-2 perfs, and reperfthe upper portion of that sand to reestablish production. Procedure: 1. Shut in both sides of well CLU-5. MIRU 13A'' coil tubing on CLU-51. Mix 200 bbl of 10.6 ppg CaC1 fluid. Test BOPs to 5000 psig. RIH with coil tubing to 10,800' CTM. Circulate hole full of 10.6 ppg CaC1 to kill well. 2. When the well is dead, lay a cement plug from the. PBTD up across the perfs at 10,276'. Include 1 bbl fresh water spacer ahead and behind cement. Keep coil tubing moving while spotting plug. Top of cement should be at 10 220' MD. When cement is displaced from coil, continue to circulate while PU coil tubing to 9800'. 3. Apply hesitation squeeze in 50 - 100 psi increments. Final desired squeeze pressure is 500 psi over SITP. 4. Circulate contaminant down coil at max pump rate. Wash down through cement plug with contaminant. Slow down the pump while washing across perfs. Wash to a depth of 10,314' CTM. POOH. Drop ball to allow circulation out side-jets when end of coil is above perfs. POOH to 9800' circulating at max rate. 5. Stop circulating. Retest squeeze to 500 psig. Resqueeze if test fails. Otherwise, POOH circulating to 2500' MD. SDFN. 6. MIRU nitrogen unit. Blow well dry from 2500' using nitrogen. POOH, RDMO coil tubing and nitrogen. 7. MIRU electric line. Test BOPs and lubricator to 2000 psig. RIH with 21/8" strip guns, 6 spf, 0© phased with 14.4 gm PowerJet charges. Tie in with GR/CCL. Re-perforate the Tyonek 91-2 Sand from 10288'- 10294' DIL with approximately 1,000 psig underbalance. POOH, RDMO electric line. 8. Produce CLU-51 as per instructions of Production Foreman. May 6, 1999 N:XDRLG\CLU~CLU-51\sqzprog. VCPD i ,": ', : ~". · ,. Cannery Loop Field Well CLU-5 Marathon Oil Co., Alaska Region AP150-133-20474 KB-GL: 34.2' 270' FEL, 180' FSL Sec. 7, T5N, R11W, S.M. Baker model GT Dual Packer ~ 5898' X-Nipple ~ 5943' 11)=2.813" X-Nipple ~ 5985' ID = 2.813" X-Nipple @ 6980' ID = 2.813" X-Nipple ~ 7020' ID = 2.813" Re-Entry Guide @ 7025' Beluga Sand Perfs 7110' - 7118' (6 spf, 11/29/96) 7228' - 7248' (6 spf, 11/29/96) 7264' - 7298' (6 spf, 11/29/96) 7392' - 7405' (6 spf, 11/28/96) 7502' - 7522' (6 spf, 11/28/96) 7752' - 7786' (6 spf, 11/27/96) 7844' - 7874' (6 spf, 11/27/96) 7980' - 8000' (6 spf, 11/26/96) 8025' - 8050' (6 spf, 11/26/96) 8104' - 8118' (6 spf, 11/26/96) 8146' - 8170' (6 spf, 11/25/96) Fish: 38.6' of 2-1/8" guns (11/28/96) Tyonek Sand Perfs 91-2: 10,276'- 319' (2-1/8", 6 spf, 4/3/97) Last Rev: JGE, 4/19/99 PBTD = 11,288' TD = 11,424' 20", 129#, Drive Pipe ~ 142' 13-3/8", 61#, K-55, BTC Casing @ 2970' Cmt w/1790 sks of class G Tubing (Shortstring & Longstring) 3-1/2", 9.2#, L-80, Butt-Mod Steel & Carbide Blast Joint 7119'-7159' 7223'-7347' 7403'-7443' 7501'-7572' 7750'-7836' 7841'-7924' 7996'-8096' 8115'-8215' 7" Liner Top c((}, 8974' w/TIW S-6 liner-top packer 9-5/8", BTC casing@9178' 0'-1212':53.5#, L-80 1212'-9178':47#,P-110 Cmt w/1919 sks ofClass G -- tOt'~ T6 ' Baker "F-1" Packer w/10' sealbore ~ 9655' X Nipple @ 9705' ID = 2.813" X Nipple @ 9746' ID = 2.813'' Wireline re-entry guide @ 9752' Tag fill 5'3,, l1,088' WLM (5/19/97) Fish: 7" packer I 1193'- 11288' (12/22/96) 7", 29#, N-80, BTC liner ~ 8974'- 11421' Cmt xv/750 sks PERMIT 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 96-073 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS ~L~Y~ 2800-8949 USIT/CEMENT COMP RCD 11/24 COMP RCD 11/27 COMP RCD 11/26 PROD PACK 11/21 CBT NGR/SPEC DSI AIT/GR AIT/GR LDT/N DSI NGR/SPEC LDT/N PACK GR/CCL COMP RCD 4/3/97 DIR SRVY 7~~8 ~0-8200 /~000-7350 ~7650- 7900 ~2968-9124 ~968-9196 ~"~9158-11242 96-073 96-073 96-073 96-073 DRY DITCH FMT , . HSD DIP COMP FR_AC CAD E GRAD. 96-073 96-073 FP~ACCADE PRESS. 8561 Page: 1 Date: 11/25/98 RUN RECVD ~2968-9186 ~9158-11375 ~158-11343 ~9400-9618 ~00-11200 ~/~0200-10~70 /BH 0-11420 S 3000-11424 #974 ~/BL (C) 3000-11424 &L~/BL (C) 9800-11400 ~'BL (C) 6850-8400 ~/B~ (C) .SCHLUM 6850-8400 PEX- DS I/NGT 1 12/19/96 1 12/19/96 1 12/19/96 1 12/19/96 1 12/19/96 1 12/19/96 1 12/19/96 I 12/19/96 1 12/19/96 2 12/19/96 1 12/19/96 2 12/19/96 2 12/19/96 2 12/19/96 2 01/15/97 i 01/15/97 1 04/15/97 04/23/97 04/02/97 07/10/97 1 07/10/97 i 07/10/97 1 07/10/97 2 07/28/98 AOGCC Individual Well Geological Materials Inventory Page: 2 Date: 11/25/98 PERMIT DATA T DATA PLUS RUN RECVD ~ COMPLE?IO~ DATE ! ~/,~ ~/%/ ~. o-4 o ? 4/~?/':? .;7 DAZ~,¥ W~,~,~, OPS R , / / TO / ~ _ / Are dry ditch samples required? yes ~nd received? ~no Was the well cored? yes ~?~A~alysis & description received? Are well tests required? yes ~.-Received? Well is in compliance Initial COMMENTS Alaska R~,on Domestic Production Marathon Oil Company July 28. 1998 P.O. Box 196168 Anchorage. AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3120 The following logs are enclosed: Tape Description -. Cannel-v Loop Unit #5 -~jr,5", t.- Enclosed is the following Schlumberger tape and Correspondence' 1) Cannery. Loop #5 Marathon Oil Company DS1/NGT and Platform Express Data Kenai. Alaska LDWG Format KB ELEV: 55.1 Run: Txvo Start: 11227.7 Stop: 9158.0 Job 96343 Log: 12-Nov-96 1600 BPI Please sign and return confirming you have received these documents. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures -._ Received B~ ....,¢ ., .... ,'., ~ ,---:. Date: A ~h.~iclinrv nf I I.qN ¢.,qrnc~rnticm Environmentally aware for the long run. Marathon Oil Company .. July 10, 1997 Alaska. .3ion Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive .'Anchorage, AK 99501-3192 The folloxving logs are enclosed: Kenai Gas Field TAPE # 1) Schlumberger tape: Marathon Oil Company KBU 41-7 Kenai Gas Field Log: 1-May-1996 Tape: 15- May- 1996 Multiple Isotope Tracer Survey APl #50-133-20327 LIS Format Run: # 1 Start: 7129.5' Stop' 6670.0' Corea Creek Federal #1 TAPES - ,# 1) Schlumberger tape: Marathon Oil Company Corea Creek Federal #1 3-April-96 File-24 DSI-AIT Select Curves BPI: 6250 #2) Schlumberger tape: Marathon Oil Company C°rea Creek Federal # 1 3-April- 1996 A subsidiary of USX Corporation Environmentally aware for the long run. Marathon Oil Company Alaska. _gion Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 File- 26 LDT- CNL- NGT Select Curves BPI: 6250 LOG Description 1) Cannery Loop Unit #5 MSD Dip Computation SHDT HILT/DSST NGT Nov 12, 1996 2) Cannery Loop Unit #5 Gradient Presentation Platform Express DSI/NGT Oct 26. 1995 Print Film 3) Cannery Loop Unit #5 Pressure Presentation Platform Express DSI/NGT Oct 26. 1995 4) Cannery Loop Unit #5 Mudlog Epoch Well Logging, Inc. 5) cannery Loop Unit #5 Mudlog Epoch Well Logging, Inc. 1 1 1 Color This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures · "~}, :a~ :W1.2;%I c; A subsidiary of USX Corporation Environmentally aware for the long run. Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 6, 1997 Mr. Jack Hartz Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hartz: Please find attached a completed Gas Well Open Flow Potential Test Report for Cannery Loop Unit Well CLU-5. The test was conducted May 4 through May 5, 1997 on the select open Beluga intervals (short-string). Marathon respectively requests this information be kept confidential for a period of two years for strategic planning purposes. Sincerely yours, Michael J. Stover Advanced Reservoir Engineer attachments A subsidiary of USX Corporation Environmentally aware for the long run. ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPO~ 8 1997 ~laska 0il & Ga.~ c ANNUAL MULTIPOINT ~-~ CONSTANT~'~TIME ~.. SPECIAL OTHER ISOCHRONAL 2. Name of Operator 7. Permit No. Marathon Oil Company 96-73 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20474-00 4. Location of Well 9. Unit or Lease Name At surface Cannery Loop Unit 180' FSL, 270' FEL, Sec. 7, T5N, R11W, SM 10. Well Number At TD CLU-5 (short-string) 2177' FSL, 2524' FWL, Sec. 8, TSN, R11W, SM, @ 10238' TVD 11. Field and Pool Cannery Loop 5. Elevation in feet (KB, DF etc.) 16. Lease Designation and Serial No. Beluga 34.1' KB above datumI ADL 60568 12' C°mpleti°n Date 113' T°tal Depth 114' Plugback T'D' 115' Type C°mpleti°n (Describe), 12/26/96 111424'md, 10238'tvd 11288'md, 10106'tvd Dual completion 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. IPerforations: From To 7" Liner 29 6.184 11421' MD 7110'-7118' 7502'-7522' 8025'-8050' 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 7264'-7298' 7752'-7786' 8104'-8118' 3 1/2" 9.2 2.992 7000' MD 7228'-7248' 7844'-7874' 8146'-8170' (short string) 7392'-7405' 7980'-8000' 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 5873' MD Short stringI ......I 0.558 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg.~---~ Csg. ['-3 122 33 14.73 23. Length of flow channel (L)5873, I Vertica' Depth (H)14701' Ga. %CO~ 1%"~ °/°H2S I Pr°ver Meterrunl Taps0 x 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3.826 X 2" 40.0 2.0 114 2,177 60 .... 4.78 2. 3.826 X 2" 136.9 3.7 114 2,047 59 .... 5.37 3. 3.826 X 2" 313.6 5.6 114 1,866 59 .... 5.04 4. 3.826 X 2" 705.6 8.4 114 1,791 60 .... 4.98 5. 3.826 X 2" 902.5 9.5 114 1,732 62 .... 5.00 Basic Coefficient (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 177.8 8.9 54.7 0.9518 1.338699 1.002173 1,590 2. 130.6 22.5 151.6 0.9518 1.338699 1.007446 2,940 3. 107.0 41.9 328.3 0.9518 1.338699 1.017061 4,484 4. 86.5 77.0 720.3 0.9518 1.338699 1.037948 6,661 5. 81.2 92.6 917.2 0.9518 1.338699 1.047887 7,520 Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 0.080137 573.6 1.682 0.995667 0.558 2. 0.222098 573.6 1.682 0.985273 3. 0.480968 573.6 1.682 0.966732 Critical Pressure 682.58 4. 1.055259 573.6 1.682 0.928215 Critical Temperature 341.1801 ~,~'~.'~,: I."~o~43723 573.6 1.682 0.910692 kz~AOGCCGAS.XLS CONTINUED ON REVERSE SIDE Submit in duplicate Pc 2,315 Pc~ 5,359,225 Pf Pf= No. Pt Pt2 Pc2 - Pt~ Pw Pw~ Pc~ - Pw~ Ps Ps~ Pff- Ps2 1. 2,177 4,739,329 619,896 ...... 2. 2,047 4,190,209 1,169,016 ...... 3. 1,866 3,481,956 1,877,269 ...... 4. 1,791 3,207,681 2,151,544 ...... 5. 1,732 2,999,824 2,359,401 25. AOF (Mcfd) 14,786 n 1 Remarks: Surface data only was collected during test. Water rates of 0, 4.9, 33.3, 67 and 47.5 bwpd recorded at the respective test rates. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .//j~/J,_~ ~ Title Advanced Reservoir Engineer Date 5/6/97 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z 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. Basic orifice factor Mcfd/ ',~ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = ~ 1/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless ECE VED Form 10-421 Rev. 7-1-80 kz~AOGCCGAS.XLS Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma CONTINUED ON REVERSE SIDE Submit in duplicate CLU-5S BELUGA 4-Point Test Results Q FTHP (mscfd) (psia) (Surface data - Spider Gauge) Delta S.I. THP Pres. Actual Calc. Regression Flow Period (psia) (psia) (Pr^2-Pwf^2) C (Q) (hrs.) Qw (bwpd) 1,590 2,177 2,940 2,047 4,343 1,866 6,500 1,791 7,520 1,732 l/m=n= AOF = 2,315 138 619,896 0.0026 1,710 4.781 2,315 268 1,169,016 0.0025 3,226 5.369 2,315 449 1,877,269 0.0023 5,180 5.044 2,315 524 2,151,544 0.0030 5,937 4.975 2,315 583 2,359,401 0.0032 6,510 5.000 Ave. Coeff. C 0.00276 1.0000 (mcf/psi^2) 14,786 mscfpd 0.0 4.9 33.3 67.1 47.5 10,000,000 10,000 CLU-5S - BELUGA 5~4~97 lOO 1 ooo 1 oooo 1 ooooo · 4-Pt. Test ~Regression] M-/ Y 8 i997-- h:\excel\clu5\clu5sCLU5S4PT.XLS 5/6/97 Alask~ ;~ion Domes,,~ Production Marathon Oil Company C NFIUENTIAL P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 23, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: Please find attached Form 10-407, Well Completion Report and Log, for the CLU-5 completion. If you have any questions, Sincerely, Michael R. Olson Production Engineer Attachments cc: CEF please contact me at or Recompletion 564-6315. APR 24 1997 Anchorage. A subsidiary of USX Corporation Environmentally aware for the long run. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OlLF'-I GAS F2-I SUSPENDEDI"~I ABANDONEDI~I SERVICEr--1 2. Name of Operator 7. Permit Number MARATHON OIL COMPANY 96-73 3. Address 8. APl Number P. O. Box 196168, Anchorage, AK 99519-6168 50--133-20474-00 4. Location of Well at Surface ~ ....... ~ ............-~m,-~.~,~__' ...... 9. Unit or Lease Name 180'FSL, 270'FEL, Sec. 7, TSN, R11W, SM ~ "-'-;3~",!:~!:!'',:~;~ ~ ~~~ Cannery Loop Unit At top of Producing Interval ; /.~._.~_,?.~_~"' t '~~' i 10. Well Number 2158 FSL, 2459' FWL, Sec. 8, T5N, R11W, SM, @ 5930' TVD i!!-;-ih'-'h::~ ~ '.: At Total Depth and Pool "-~ : ; ~-,~-~~ Cannery Loop 2177' FSL, 2524' FWL, Sec. 8, T5N, R11W, SM, @ 10238' TV -- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Beluga/Tyonek 34.1' KB above permanent datumI ADL 60568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. orAband. IlS. Water Depth. if offshore ]16, No. of Completions 10/5/96 11/12/96 12/26/96I N/A feet MSL] Dual Completion 17. Total Depth 0V1D+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Surveyr~ [~ [2o. Depth where SSSV set 121. Thickness of Permafrost 11424' md + 10238' tvd 11288' md + 10106' tvd Yes,__ ,No, , N/A feet MD N/A 22. Type Electric or Other Logs Run AIT/LDT/CNT/MSFL/GR/SP, DSI/NGT, CBL, Sonic Imager 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 129 B 0' 142' - ..... Driven 13-3/8" 61 K-55 0' 2970' 17-1/2" 1790 SX 9-5/8" 47/53.5 L-80/P-110 0' 9178' 12-1/4" 1919 SX 7" 29 N-80 8974' 11421' 8-1/2" 750 SX 24. Perforations open to Production (MD+TVD or Top and Bottom and 25. TUBING RECORD interval, size and number) !..SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7000 5873' md tvd md tvd 3-1/2" 9726' 9629' 7110-7118' 5930-5938' 7844-7874' 6663-6693' 7228-7248' 6047-6067' 7980-8000' 6799-6819' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7264-7298' 6083-6117' 8025-8050' 6~44-6869' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7392-7405 6211-6224' 8104-8118' 6923-6937' N/A 7502-7522' 6321-6341' 8146-8170' 6965-6989' 7752-7786' 6571-6605' 10276-10319' 9095-9138' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) SS: 1/3/97, LS: 4/3/97 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 4/16/97, 4/23/97 24, 24 TEST PERIOD --.~. 6000, 5800 30, 320 I FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1850, 2900 360 24-HOUR RATE --~ 6000, 5800 30, 320 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No cores taken RE EtV D Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in Triplicate 2 4 1997 Alaska 0il & Gas Cons. 60rr~miss~'- Anchorage C0 FIBENTtAL 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. Middle Beluga 6980' 5807' Intervals: 7110-18', 7228-48', 7264-98', 7392-7405', 7502-22', 7752-86', 7844-74', 7980-8000', 8025-50, 8104-8118', 8146-70' Test: 6000 mscfpd, 30 bwpd, THP = 1850 psi Lower Beluga 7732' 6559' Intervals: 7752-86', 7844-74', 7980-8000', 8025-50', 8104-18', 8146-8170' Test: 4000 mscfpd, 36 bwpd, THP = 1500 psi Tyonek 91-2 10273' 9105' Interval: 10276-10319' Test: 5800 mscfpd, 320 bwpd, THP = 2900 psi 31. LIST OF ATTACHMENTS Operation Summary Report, Directional Survey, Wellbore Diagram 32. I hereby cedify that the for oing is true and correct to the best of my knowledge Signed .,~~~.~'~ Title Production Engineer Date 4/23/97 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Form 10-407 H:\EXCEL\NRSFORMS~AOGCOMPL.XLW Alaska 0il & Gas Cons. 60mmiss~' Anchorage CONFIBENTIAL OPERATION SUMMARY REPORT WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY 10/04/96 1 0 8.700 ACCEPTED RIG FROM MOBILIZATION AT 0600 HRS 10-3-96. CUT DRIVE PIPE AND WELDED UP STARTING HEAD. N/U DIVERTER. SPOTTED CEMENT TANKS, CUTTINGS HANDLING EQUIP AND SOLIDS CONTROL VAN. N/U DIVERTER AND HYDRAULIC LINES. 10/05/96 2 296 9.000 FINISHED N/U DIVERTER SYSTEM AND BELLNIPPLE. FUNCTION TESTED DIVERTER AND ACCUMULATOR. P/U BHA, TAGGED AT 36'. SPUDDED WELL AT 0100 HRS 10-5-96. DRILLED FRC~4 36' TO 296'. 10/06/96 3 1654 9.200 DIRECTIONALLY DRILLED FROM 296' TO 1532'. POOH TO WIPE NEW HOLE. CHANGED MWO. RIH. DRILLED FROM 1532' TO 1654' 10/07/96 4 29<20 9.400 DIRECTIONALLY DRILLED FROM 1654' TO 29<20'. CBU. MADE 16 STAND SHORT TRIP. CIRCULATED. 10/08/96 5 2990 9.600 CIRCULATED AND CONDITIONED MUD. POOH. R/U AND RUN 13 3/8" SURFACE CASING. CIRCULATE AND CONDITION MUD. 10/09/96 6 29<20 9.450 CIRCULATED AND CONDITIONED MUD WHILE RECIPROCATING CASING. RUN IN W/ STAB IN STRING. CIRCULATED. CEMENTED 13 3/8" CASING WITH 1390 SX LEAD CEMENT AND 400 SX TAIL CEMENT. HAD 140 BBLS CEMENT TO SURFACE. POOH W/ STABIN STRING. N/D DIVERTER. MADE ROUGH CUT. CONTINUE N/D DIVERTER. 10/10/96 7 2990 9.500 FINISHED N/D DIVERTER. CUT OFF STARTING FLANGE. MADE FINAL CUTS ON 20" AND 13 3/8" CASINGS. WELDED ON 13 5/8" CASING HEAD AND TESTED TO 1000 PSI. N/U BOPE. 10/11/96 8 29<20 9.500 N/U BOPE. TESTED BOPE. CHANGED OOT UPPER RAMS. FINISHED TESTING BOPE. RIH WITH 14 STDS OF DRILL PIPE. LEVELED DERRICK. L/D 14 STDS OF DRILL PIPE. L/D 17 1/2" BHA. P/U 12 1/4" BHA. 10/12/96 9 3000 8.700 FINISHED P/U 12 1/4" DRILLING ASSEMBLY. RIH AND TAGGED CMT AT 26,B4'. L/D 2 STDS OF DRILL PIPE AND RUN 2 STDS FROM DERRICK. DRILLED CMT TO 2929'. TESTED CSG TO 1500 PSI. DRILLED FLOATS, CMT AND 10' OF NEW FORMATION TO 3000'. CBU. TESTED SHOE TO 12.2 PPG EMW. CLEANED MUD PITS. 10/13/96 10 3000 9.050 FINISHED CLEANING MUD PITS. MIXED NEW MUD. DISPLACED WELL WITH NEW MUD. POOH. M/U 12 1/4" DIRECTIONAL ASSEMBLY. RIH TO SHOE. 10/14/96 11 449<2 9.400 CUT DRILL LINE. RIH TO 3000'.CBU. DRILLED TO 3047'. REPAIRED SHAKER. DRILLED TO 4499', CBU. MADE WIPER TRIP TO SHOE. 10/15/96 12 5210 9.200 RIH FROM WIPER TRIP. DRILLED FROM 4499' TO 4852'. REPAIRED DRAWWORKS . DRILLED TO 5210'. CIRCULATED HOLE CLEAN. POOH FOR MWI). M/U NEW BIT, MOTOR AND MWD. RIH. 10/16/96 13 6291 9.350 RIH TO 4394'. REAMED FROM 4394' TO 4474m. RIH TO 5~))'~"!~1~ ~~? FROM 5210' TO 6228'. CBU. MADE WIPER TRIP TO 3717'~bR~LL~R(~M~ = 199 Alaska 0il .& Gas Cons. Anchorage g 3NF gENTIAL WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY 6228' TO 6291' 10/17/96 14 6877' 9.550 DRILLED FROM 6291' TO 6815'. CBU. MADE 11 STAND WIPER TRIP. DRILLED FROM 6815' TO 6877'. CBU. STARTED POOH. 10/18/96 15 7044 9.550 POOH. TESTED BOP'S. P/U NEW BIT AND RIH. REAMED 6807' TO 6877'. DRILLED FROM 6877' TO 7044'. 10/19/96 16 7746 9.700 DRILLED FROM 7044' TO 7401'. MADE 21 STAND WIPER TRIP. DRILLED FROM 7401' TO 7746'. 10/20/96 17 7777 9.500 DRILLED FROM 7746' TO 7777'. CIRCULATED. POOH, WET. L/D MUD MOTOR AND PICKED UP ROTARY ASSEMBLY. RIH. WORKED TIGHT HOLE. REAMED 3429' TO 3675'. RIH. WORKED THROLIGH TIGHT SPOTS FROM 4160' TO 5820' 10/21/96 18 8203 9.650 RIH, WORKING THRO(JGH TIGHT SPOTS. DRILLED FROM 7777' TO 8203' 10/22/96 19 8488 9.650 DRILLED FROM 8203' TO 8263'. CIRCULATED. SHORT TRIPPED TO 5097', HOLE TIGHT. HIT LEDGE AT 7944'. REAMED TO 8263'. DRILLED FROM 8263' TO 8488'. 10/23/96 20 8655 9.750 DRILLED FROM 8488'-8546'. CBU. POOH. L/D MWD, M/U NEW BIT. RIH. DRILLED FROM 8546' TO 8655' 10/24/96 21 9081 9.900 DRILLED FROM 8655' TO 9081' 10/25/96 22 9220 10.100 DRILLED FROM 9081' TO 9220'. CBU. CIRCULATED AND RAISED MUD WEIGHT FROM 9.9 TO 10.1 PPG TO CONTROL GAS. MADE WIPER TRIP TO 6394'. 10/26/96 23 9220 10.250 RIH. REAMED FROM 9140' TO 9220'. CBU. CIRCULATED OUT GAS AND CONDITIONED MUD FOR LOGGING. REPLACED KELLY HOSE. DROPPED SURVEY. POOH. BHA. 10/27/96 24 9220 10.300 BHA. R/U TO LOG. RUN 1. LOGGED FROM 9220' TO 2970' WITH AIT/LDT/CNT/ MSFL/GR/SP. RUN 2. LOGGED FROM 9220' TO 2970' WITH DSI/NGT. R/D FROM LOGGING. BHA. RIH TO 2963'. CUT DRILL LINE. RIH. 10/28/96 25 9220 10.150 FINISHED RIH TO 9220'. CIRCULATED AND CONDITIONED MUD. POOH. L/D BHA. INSTALLED CASING RAMS IN BOP AND TESTED. R/U TO RUN 9 5/8" CASING. RAN CASING. 10/29/96 26 9220 10.200 RAN 9 5/8" CASING TO SHOE. CBU. FINISHED RUNNING 9 5/8" CASING WITH SHOE AT 9178'. CIRCULATED AND CONDITIONED HOLE FOR CEMENTING. CEMENTED WITH 850 SACKS OF LEAD AND 1069 SACKS OF TAIL. CIP AT 0600 HRS. 10/30/96 27 9220 10.150 R/D FROM CEMENT JOB. FLUSHED BOP STACK AND WELLHEAD. N/D BOP STACK. INSTALLED CASING SLIPS.MADE CASING CUTS. N/U TUBING SPOOL AND TESTED TO 4500 PSI. N/U BOP STACK. TESTED BOPE. CDNFIDENTtAL WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY 10/31/96 28 9230 10.300 TESTED BOP'S. M/U 8 1/2" DRLG ASSEMBLY AND RIH. TAGGED CEMENT AT 8931'. TESTED CASING TO 3000 PSI. DRILLED CEMENT TO 9087'. TESTED CASING TO 3000 PSI. DRILL OUT CEMENT, AND 10' OF NEW HOLE TO 9230'. TESTED SHOE TO 13.3 PPG EMW. PUMP DOWN ACTIVE PITS AND MIX NEW MUD. 11/01/96 29 9591 10.400 FINISHED BUILDING 400 BBLS OF MUD. CIRCULATED ENTIRE SYSTEM. DRILLED FROM 9230' TO 9591' 11/02/96 30 9774 10.750 DRILLED FROM 9591' TO 9774'. CBU. POOH 5 STD. NOT TAKING PROPER FILL RIH, HAD TO REAM 30' TO BOTTOM. CBU. MAX GAS 782 U. CIRCULATED AND RAISED MUD WT TO 10.7PPG. POOH TO SHOE. RETRIEVED SURVEY. POOH W/ 34 STDS. L/D 45 JTS 'G' PIPE. RIH WITH DP. STARTED P/U 'S' DRILLPIPE 11/03/96 31 10090 10.900 FINISHED RIH P/U DP. CBU. SURVEYED. DRILLED FROM 9774' TO 10,090' 11/04/96 32 10167 10.800 DRILLED FROM 10,090' TO 10,100'. CBU. SHORT TRIP TO SHOE. CBU. TRIPPED FOR BIT. RIH. DRILLED FROM 10,100' TO 10,167'. 11/05/96 33 10541 10.850 DRILLED FROM 10,167' TO 10,541' 11/06/96 34 10541 11.100 CBU. POOH. HIT TIGHT SPOT AT 9984'. WORKED SAME, WELL FLOWED. CIRCULATED ON CHOKE. RIH TO 10,541'. CIRCULATED AND RAISED MW TO 11.1 PPG. POOH TO SHOE. RETRIEVED SURVEY. RIH TO 10,541'. CBU. 11/07/96 35 10782 11.150 CBU. DRILLED FROM 10541' TO 10782' 11/08/96 36 10789 11.500 DRILLED FROM 10782' TO 10789'. CBU. MADE 10 STAND WIPER TRIP TO 9800'. CBU. WELL FLOWED. CIRCULATED OUT ON CHOKE. CIRCULATED AND RAISED MUD WEIGHT FROM 11.2 TO 11.5 PPG. MADE WIPER TRIP TO SHOE. CBU. DROPPED SURVEY AND POOH. STARTED TESTING BOPE. 11/09/96 37 10972 11.500 TESTED BOPE. RIH. CBU. DRILLED FROM 10789' TO 10972' 11/10/96 38 11158 11.500 DRILLED FROM 10972' TO 11104'. CBU. DROPPED SURVEY. PUMPED SLUG. POOH TO SHOE. RETRIEVED SURVEY. RIH. DRILLED FROM 11104' TO 11158' 11/11/96 39 11265 11.550 DRILLED FROM 11158' TO 11265'. CBU. TRIPPED FOR NEW BIT. CBU. 11/12/96 40 11424 11.550 CBU. DRILLED FROM 11265' TO 11289'. REPLACED WASHPIPE ON KELLY. DRILLED FROM 11289' TO 11424'. CBU. MADE WIPER TRIP TO SHOE. CBU. 11/13/96 41 11424 11.550 CBU. DROPPED SURVEY AND POOH. LOGGED FROM 11246' TO 9158' WLM WITH AIT/LDT/CNL/GR. LOGGED FROM 10645' TO 9158' WLM WITH DSI/NGT. RIH FOR WIPER TRIP. 11/14/96 42 11424 11.650 RIH, HIT TIGHT SPOT AT 11,263'. REAMED 11,263'T0 11,424'. CBU. POOH TO 10,500w HOLE NOT TAKING PROPER FILL, RIH TO 11,424. CBU. POOH. R/U SCHLUMBERGER. RIH W/DSI NGT AMS AND LOGGED FROM 11,424' TO 9178' POOH. M/U SHDT AND RIH. LOGGED FROM 11,424 TO 9178'. POOH. C NFI ENTIAL OPERATION SUMMARY REPORT WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY 11/15/96 43 11424 11.600 POOH W/ SHDT, R/D E LINE. RIH. CIRCULATED AND CONDITIONED MUD. POOH. L/D BHA. CHANGED TOP SET OF RAMS TO 7". R/U TO RUN LINER. 11/16/96 44 11424 11.550 R/U AND RUN 7" PROOUCTION LINER. RIH W/ LINER ON DP TO 9150'. CBU. RIH W/ LINER ON DP TO 11,420'. CIRCULATED AND CONDITIONED MUD. STARTED CEMENTING LINER. 11/17/96 45 11288 11.650 CEMENTED LINER WITH 750SX CEMENT. SET HYDRAULIC HANGER AND PACKER. POOH 10 STDS. CBU, HAD 80 8BLS CEMENT CONTAMINATED MUD TO SURFACE. POOH. CHANGED TOP SET PIPE RAMS. TESTED BOP'S. M/U BIT AND SCRAPER AND RIH. 11/18/96 46 11208 11.550 RIH TO 8000'. WASHED/REAMED FROM 8000' TO 8892'. DRILLED CEMENT TO 8961', WASHED TO TOP OF LINER AT 8974'. CBU. TESTED LINER LAP TO 2500 PSI. POOH. P/U 6" BIT AND 7" CASING SCRAPER, 3 1/2" DP TO CLEAN O~JT LINER. 11/19/96 47 11288 11.650 RIH W/ BIT AND SCRAPER TO LANDING COLLAR AT 11,288'. CBU. TESTED CASING, LINER AND LINER LAP TO 2500 PSI. POOH. R/U E LINE. RIH W/CBL TOOLS TO 10,350'. TOOLS QUIT WORKING, PC)OH W/SAME. CHANGED OUT TOOLS AND STARTED RIH W/ CBL TOOLS. 11/20/96 48 112~,B 11.600 RAN CBL FROM 11,200' TO 8974'. RIH W/ CBL AND LOGGED 11,200' TO 5600' UNDER PRESSURE. POOH. M/U SONIC IMAGER AND RIH TO 8974' LOGGED FROM 8974' TO 2750'. POOH, R/D E LINE. RIH W/ 6" BIT, 7" CASING SCRAPER AND 9 5/8" CASING SCRAPER. 11/21/96 49 11288 8.500 RIH WITH BIT AND SCRAPERS TO 11284)'. CIRCULATED AND EMPTIED ACTIVE MUD PITS. CLEANED MUD PITS. MIXED 3% KCL. DISPLACED WELL WITH 3% KCL. CLEANED SHAKERS AND MIXED 3% KCL. 11/22/96 50 11208 8.500 FINISHED CLEANING SHAKERS. POOH WITH BIT AND SCRAPERS. R/U E LINE. M/U ISOLATION PACKER. RIH AND SET PACKER AT 9700' WLM. POOH AND R/D E LINE. L/D BHA AND 3 1/2" DRILL PIPE FROM DERRICK. M/U AND RIH WITH RETRIEVEABLE BRIDGE PLUG TO 8500'. ATTEMPTED TO SET RBP AT 8500'. 11/23/96 51 11208 8.600 SET RETRIEVABLE BRIDGE PLUG AT 8495'. POOH TO 8370' AND SPOTTED 100' OF SAND ON TOP OF RBP. POOH L/D DRILL PIPE. TESTED BOPE. M/U TEST TREE ON JOINT OF DRILL PIPE AND L/D. STARTED P/U FRAC STRING. 11/24/96 52 11288 8.600 RIH P/U 5" FRAC STRING. R/U 3" TEST TREE. SET PACKER AT 5597' WITH TAIL PIPE AT 6900'. TESTED BACKSIDE TO 3000 PSI AND STRING TO 7500 PSI. R/U COIL TUBING. 11/25/96 53 11208 8.600 FINISHED R/U COIL TUBING. RIH AND DISPLACED KCL WITH NITROGEN TO 6900'. POOH AND R/D COIL. R/U E LINE TO PERFORATE. THAWED FROZEN MUD LINE. PERF RUN #1. 8146'-8170'. M/U GUNS FOR RUN #2. WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUHHARY 11/26/96 54 11288 8.600 MADE PERF RUN #2. SHOT FROM 8104' TO 8118'. RUN #3. SHOT FROM 8025' TO 8050'. RUN #-4. SHOT FROM 7980' TO 8000'. ALL GUNS 6 SPF. R/D E LINE. FLOWED WELL TO TEST EQUIPMENT. STARTED FLARING GAS AT MIDNIGHT. SHUT WELL IN AT 0400 HRS. THAWED GAS SCRUBBER DUMP LINE. FLOWED WELL TO TEST EQUIPMENT AND STARTED FLARING AT 0600 HRS. 11/27/96 55 11288 8.600 FLO~/ TESTED WELL. SHUT IN AND R/U TO PERF. RIH WITH PERF RUN # 5 AND PERFORATED FROM 7844' TO 7874' WITH 6 SPF. MADE PERF RUN #6. PERFORATED FRC~M 77'52' TO ~86' WITH 6 SPF. R/D. FLOW TESTED WELL. 11/28/96 56 11288 8.600 FLOr4 TESTED WELL. SHUT IN WELL. PUMPED 80 BBLS KCL DOWN DP FOR PERFORATING. R/U E LINE. RIH W/ PERF RUN #7. PERFORATED 7502'-7522'. POOH. TOOLS STUCK AT BOTTOM OF WL LUBRICATOR. THAW OUT SAME. TOOLS PARTED AT ROPE SOCKET. MADE DUMMY RUN W/ 2" SINKER BARS TO 7000'. R/U E LINE. RIH W/ PERF RUN #8. PERFORATED 7392'-7405' POOH. 11/29/96 57 112E.!~ 8.600 RIH W/ PERF RUN #9~ PERF'D 7264'-7298'. PERF RUN #10, PERF'D 7228' 7248'. PERF RUN #11, PERFED 7110'-7118'. R/D E LINE. FLOt4ED WELL TO FLARE, THEN SWITCHED TO PROOUCTION. 11/30/96 58 1128~ 8.900 FLO~I TESTED WELL. SHUT IN WELL AND MONITERED PRESSURE, STABILIZED AT 2350 PSI. R/D LUBRICATOR AND FLOWHEAD. R/U TO KILL WELL. REVERSE CIRCULATED TO KILL WELL. CIRCULATED LONG WAY ON CHOKE. OPEN WELL AND OBSERVED NO FLOW. CIRCULATE WITH WELL OPEN. 08SERVED SLIGHT FLOt4 W/ PUMPS OFF. SHUT IN AND RAISED MW TO 8.9PPG. CIRCULATED ARO(JND ON CHOKE. RIH, P/U DP TO 8243'. CIRCULATED ON OPEN CHOKE. 12/01/96 59 11288 9.100 CHECKED WELL FOR FL014. OPENED HYDRIL AND CBU. HAD 150 UNITS GAS FROM FLOW CHECK. MONITERED WELL. CBU, 140 UNITS OF GAS. RAISED MUD WT FROM 8.9 PPG TO 9.1 PPG. POOH. R/U SLICKLINE LUBRICATOR. RIH W/3.7" OVERSHOT ON SLICK LINE TO FISH FOR LOST PERF GUN. POOH, NO RECOVERY. RIH W/ 2.27" OVERSHOT. POOH, NO RECOVERY. R/D SLICKLINE. MAKE 8.5" OVERSHOT AND FISHING BHA, STARTED RIH W/ DP. 12/02/96 60 11288 9.100 FINISHED RIH W/ DP TO 8244'. CBU. MAX GAS 90 UNITS. WORKED OVER FISH TO 83~'. POOH. NO RECOVERY. M/U ROLLING DOG OVERSHOT. RIH, CBU. MAX GAS 117 UNITS. WORKED OVER FISH TO 8388'. POOH. NO RECOVERY. TESTED BOP'S. M/U JUNK BASKET HEAD AND WASHPIPE. STARTED RIH. 12/03/96 61 112E~ 9.100 CBU. WASHED OVER FISH FROM 8388' TO 8418'. CIRCULATED HI VIS SWEEP ARO~JND. STARTED POOHv TIGHT. CIRCULATED HI VIS SWEEP AROLIND. POOH. RECOVERED APPROX. 3' OF WADDED UP STRIP GUNS. M/U ROLLING DOG OVER SHOT AND RIH.CBU AT 8386'. WORKED OVER FISH TO 8418'. POOH. BHA. RECOVERED 13' OF 1 11/16" STEM, 9' OF STRIP GUN. 12/04/96 62 11288 9.100 FINISH L/D FISH. M/U JET BASKET AND RIH. CBU. DROP BALL. JETTED FROM 8418' TO 8420'. POOH. RECOVERED 3.5 GALLONS OF PERF GUN DEBRIS. M/U JET BASKET AND RIH. CBU. DROP BALL. JETTED FROM 8419' WELL: CLU #5 . i DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY TO 8421'. POOH. RECOVERED 3.5 GALLONS OF PERF DEBRIS. RU WIREL[NE AND RIH W/ 8" MAGNET. 12/05/96 63 112E, B 9.100 MADE 2 RUNS W/ 8" MAGNET ON W/L. RECOVERED TOTAL 4 CUPS IRON PERF DEBRIS AND 3 PERF WASHERS. RIH W JET BASKET TO 8418'. CBU. WOULD NOT JET. POOH. RIH W/ CRIPPLED MILL SHOE AND BOOT BASKETS. CBU. WASHED FROM 8418' TO 8425'. P/U, PIPE STUCK AND PACKED OFF. JARRED FREE. STARTED POOH. 12/06/96 64 11288 9.100 POOH. RECOVERED 2 GALLONS PERF GUN DEBRIS. RIH W/ JUNK BASKET HEAD. CBU. REV CIRC FROM 8423' TO 8431'. POOH. RECOVERED 5'8" PERF GUN STRIP, 5 GALLONS PERF GUN DEBRIS, 3 BRASS KNIVES. RIH W/ SAME. CBU. REV CIRC FROM 8431' TO 8439'. REV CBU. 12/07/96 65 11288 9.100 REV CBU. POOH. RECOVERED 2'2" PERF STRIP GUN, 15 WASHERS, 1 BRASS FINGER, 2 CUPS PERF DEBRIS. RIH W/ SAME JUNK BASKET HEAD. CBU. PUMP HIGH VIS PILL. REV CIRC FROM 8439' TO 8447'. POOH. RECOVERED 1'6" PERF STRIP GUN~ 33 WASHERS~ 4 SCREWS, 11 BRASS KNIVES, 2 CUPS PERF DEBRIS. RIH W/ SAME JUNK BASKET HEAD. CBU. PUMP HIGH VIS PILL. REV CIRC FROM 8447' TO 8455'. POOH. 12/08/96 ~ 11288 9.100 POOH. CLEANED JUNK OUT OF BASKET. RIH. CBU. REVERSE CIRCULATED OVER JUNK FROM 8455' TO 8463'. REVERSED O~JT SAND. POOH. CLEANED JUNK FROM BASKET. R/U WIRELINE AND MADE TWO MAGNET RUNS. RIH WITH JUNK BASKET. CBU. R/U TO REVERSE CIRCULATE OVER JUNK. 12/09/96 67 11288 9.140 R/U TO REVERSE CIRCULATE. REVERSE CIRCULATED OVER JUNK FROM 8463' TO 8471'. REVERSED OUT SAND. POOH. BHA. NO RECOVERY. RIH. CBU. CUT DRY CORE FROM 8471' TO 8475'. POOH. BHA. NO RECOVERY. MADE 8" MAGNET RUN WITH NO RECOVERY. BHA. R[H TO 8461'. CBU. 12/10/96 68 11288 9.100 CBU. CIRC HIGH VIS PILL. REV CIRC FROM 8475' TO 8595'. REV CIRC SAND OUT UNTIL CLEAN. POOH. L/D BHA. TEST BOPS. M/U RETRIEVABLE BRIDGE PLUG RETRIEVING TOOL AND RIH. CBU. DISPLACE FLUID OUT OF PITS. CLEAN PITS. MU NEW 9.1KCL FLUID. 12/11/96 69 11288 9.100 MIX 9.1 PPG KCL. DISPLACE HOLE W/ CLEAN KCL. LATCH RBP. POOH. HUNG UP AT 1208'. M/U SCRAPER. RIH TO 1208'. POOH. RBP HANGING UP AT 1208'. SET RBP AT 1325'. RELEASE SAME. POOH. M/U STRING MILL AND BOOT BASKET. RIH AND WORK MILL FROM 1200' TO 1300'. DID NOT SEE ANYTHING. POOH AND L/D BHA ASSEMBLY. M/U RETRIEVING TOOL. RIH. LATCH RBP AT 1325'. POOH TO 1208'. COULD NOT WORK PAST 1208'. CIRC ON TOP OF PLUG. 12/12/96 70 11288 9.100 MADE SEVERAL ATTEMPTS TO WORK RBP PAST 1208'. SET RBP AT 1228' TO COCK JARS. COULDN'T UNSET RBP. WORKED RBP, CAME UP TO 1208', BUT WID(JLD NOT GO PAST 1208'. DROPPED DOWN, COULDN'T COME UP. SET RBP AT 1244', UNABLE TO UNSET W/ TORQUE OR JARRING. GET OFF RBP, POOH. RIH W/ BIT AND VISCOSIFIED KCL. POOH. M/U MILLING BHA AND RIH. WORK OVER RBP AT 1244', AND STARTED MILLING ON RBP BEX)Y AT 1246'. I ONFIE)EN iAL -. OPERATION SUMMARY REPORT WELL: CLU #5 . DATE RPT DEPTH MUD WT. DAILY OPERATIONS SUMMARY ,,. 12/13/96 71 11288 9.100 MILLED ON RBP AT 1246'. TRIPPED TO INSPECT MILL. MILLED ON RBP FROM 1246' TO 1248'. POOH. M/U 8 1/8" X 7" MILL SHOE. RIH, MILLED WEIGHT SET PLATE ON TOP OR RBP. RIH W/ 8 1/2" X 7 3/4" MILL SHOE. MILLED RBP FROM 1248' TO 1249'. RBP FELL DOWNHOLE. CBU. POOH. RIH W/ RBP RETRIEVING TOOL TO 8963'. R/U TO CIRCULATE. 12/14/96 72 11288 9.100 CBU. LATCHED RBP AND POOH W/SAME. L/D RBP, 1 1/2 PACKER RUBBERS WERE MISSING. M/U 8 1/2" BIT AND SCRAPER. RIM TO TOP OF LINER AT 8974'. PUMPED SWEEP AND CBU. POOH. M/U 6" BIT AND 7" CASING SCRAPER. P/U 3 1/2" DP. 12/15/96 73 11288 9.100 RIH W/ 6" BIT AND CASING SCRAPER. TAGGED PACKER AT 9717' DPM. cau. POOH. P/U SEALS AND RIH. CBU. STUNG IN AND TESTED SEALS TO 1000 PSI. R/U SLICKLINE AND RIH W/ 1.5" TAPERED SWAGE. SET DOWN AT 9740' SLM. POOH, R/D SLICKLINE. POOH W/ DP. 12/16/96 74 11288 9.100 POOH W/ SEAL ASSEMBLY, FO(JND TWO BIG PIECES OF RUBBER INSIDE SEALS. TESTED BOP'S. RIH WITH 2.75 GAUGE RING ON SLICK LINE TO 9743', UNABLE TO WORK DEEPER. R/D SLICKLINE. M/U PACKER MILL AND BHA. RIH TO 9717'. MILLED PACKER FROM 9717' TO 9719'. CBU. POOH. 12/17/96 75 11288 9.100 L/D MILLING ASSEMBLY. M/U SPEAR, RIH TO 9722'. CBU. RIH TO 11,162'. CBU. SPEARED FISH AT 11,207'. POOH. L/D FISH, FULL RECOVERY. M/U 6" BIT AND RIH TO LINER TOP. WORKED INSIDE OF LINER, CBU. 12/18/96 76 112E, B 9.100 RIH TO 11,288m. PUMPED HI ViS SWEEP AND CIRCULATED HOLE CLEAN. POOH. L/D BHA. M/U 3" TEST TREE AND TESTED SAME TO 5000 PSI. L/D TEST TREE M/U AND RIH W/ TEST STRING, SET PAKCER AT 5874'. R/U TEST TREE AND LINES AND TESTED SAME. DISPLACED DP W/ NITROGEN. OPENED WELL TO TESTERS. 12/19/96 77 11288 9.100 FLOW TESTED WELL. REVERSE CIRC ABOVE PACKER AT 5874'. UNSET PACKER AND REV CIRC AT 6992'. RIH WITH TAIL PIPE AT 8225'. CBU. POOH SLOW WITH PACKER. 12/20/96 78 11288 9.100 POOH. L/D PACKER ASSY. P/U 7" & 9-5/8" SCRAPERS AND RIH TO 11288'. CBU. POOH. L/D SCRAPER ASSY. M/U 7" PACKER ASSY. RIH TO 9719'. DROP BALL TO SET PACKER. BALL WOULD NOT SEAT. CBU. POOH WITH 7" PROOUCTION PACKER ASSEMBLY. 12/21/96 79 11288 9.100 POOH WITH PRODUCTION PACKER. FOUND PIECE OF METAL IN 3 1//2" DRILL PIPE. CHECKED PACKER. RIH WITH PACKER. SET PACKER AT 9719' DPM. CBU. POOH L/D DRILL PIPE. REPAIRED DRAWWORKS. POOH L/D DRILL PIPE. 12/22/96 80 11288 9.100 POOH L/D DRILL PIPE. L/D DRILL PIPE AND COLLARS FROM DERRICK. SET STORM PACKER AT 90'. CHANGED RAMS IN BOPE. RETRIEVED PACKER AT 90'. MADE E LINE RUN WITH GAMMA RAY/CCL TO CONFIRM PACKER DEPTH. FOUND PRODUCTION PACKER HAD FELL TO BOTTOM AT 11288'. POOH. R/D . gAITED CFJiNFiBENTiAL WELL: CLU #5 . DATE RpT: :DEPTH MUD'wT. DAILy OPERATIONS SUMMARY ON NEW PACKER ASSEMBLY. 12/23/96 81 11288 9.100 WAITED ON NEW PACKER ASSEMBLY. M/U PACKER ASSEMBLY AND RIH ON E LINE. SET PACKER AT 9629'. POOH. RIH WITH G RAY/CCL. LOGGED THROUGH PACKER ASSEMBLY. POOH AND R/D. R/U TO RUN AND HYDRO TEST 3 1/2" TUBING. STARTED RUNNING AND TESTING LONG STRING. 12/24/96 82 11208 CONTINUED RUNNING AND HYDRO TESTING 3 1/2" LONG STRING. R/U AND MADE WIRELINE GUAGE RUN AFTER FINDING OVER TORQED CONNECTION. CONTINUED RUNNING LONG STRING. R/D SINGLE STRING RUNNING TOOLS AND R/U DUAL STRING RUNNING TOOLS. RAN DUAL 3 1/2" TUBING STRINGS HYDRO TESTING TO 5000 PSI. 12/25/96 83 11288 9.100 CONTINUED RUNNING DUAL 3 1/2" TUBING STRINGS INTERNALLY TESTING TO 5000 PSI. 12/26/96 84 11280 9.100 CONTINUED RUNNING DUAL 3 1/2" TUBING STRINGS, INTERNALLY TESTING TO 5000 PSI. STABBED LONG STRING SEALS INTO PACKER AND TESTED SAME TO 2500 PSI. CBU. POOH, SPACED OUT. P/U HANGERS, STABBED SEALS INTO PACKER AND LANDED HANGERS. TESTED SEALS TO 2500 PSI. SPOT INHIBITED FLUID ON BACKSIDE. R/U SLICKLINE. SET PLUG IN SHORT STRING BEL(Td DUAL PACKER. SET PRONG IN PLUG. SET PACKER WITH 2500 PSI ON SHORT STRING. 12/27/96 85 11288 R/U SLICKLINE. RIH, PULLED EQUALIZING PRONG. PULLED TBG PLUG. R/D SLICKLINES. TESTED ANNULUS AND DUAL PACKER TO 1000 PSI. BACKED OUT LANDING JOINTS. SET BPV'S. N/D BOP'S. N/U TREE AND TESTED SAME. STARTED CLEANING UP CELLAR AND PITS. 12/28/96 86 11288 CLEANED MUD PITS. R/D RIG FLOOR AND MISC ITEMS TO PREP RIG FOR STACK OUT WHILE WAITING ON COILED TUBING UNIT. -- OPERATION SUMMARY REPORT: POST RIG WELL: CANNERY LOOP 5S 1/3/97 9629 RU 1-1/2" CTU. PT (iT to 3000 psig. RIH to 5500' and displace completion fluid w/ N2. POOH. Produced 46 bbls completion fluid. Flow test well through portable test eqttipment. Q = 6{500 mscfpd, 13 bwpd, 1550 psig WH P. 4/2/97 9629 Facility installation complete. 4/9/97 9629 Flow test well. 4/16/97 9629 Flow test well. Q = 4800 mscfpd, 30 bwpd, 1850 psig WHP. OPERATION SUbR4AS~Y REPORT: POST RIG WELL: CANNERY LOOP 5L 1/3/97 11191 RU 1-1/2" CTU. PT to 2500 psig. RIH to 7500' and displace completion fluid w/ N2. POOH. Produced 58.5 bbls fluid. POOH. SI well w/ 1500 psig WHP. SI well. 4/2/97 11191 Facility installation complete. 4/3/97 11191 RU SWS. PT to SI WHF (1500 psig). RIH and perforate 91-2 sand (10,299-10,319', 10,276-10,299') w/ 2-1/8" retrievable EJ3 guns, 1400-1500 psig underbala~%ce. Begin flow testing well. Well SI due to hydrate:~: in tubing and flowline. Begin injecting methanol . 4/12/97 11191 Hydrate plug thawed. Begi,~ flow testing well. 4/21/97 11191 Q = 5800 mscfpd, 320 bwpd, 2900 psig WHP. MARATHON Oi t Company Pad #1 CLU-5 CLU-5 Cannery Loop Unit Cook Inlet, ALaska S U R V E Y L I S T I N G by Baker Hughes INTEQ Your ref : Conioosite Survey ,0 - 11420'> Our ref : svy5534 License : Date printed : 23-Jan-97 Date created : 23-Jan-97 Last revised : 23-Jan-97 Field is centred on n60 31 54.076,w151 15 37.735 Structure is centred on n60 31 54.076,w151 15 37.735 SLot Location is n60 31 55.849,w151 15 43.131 Slot Grid coordinates are N 2388621.339, E 272712.411 Slot Local coordinates are 180.00 N 270.00 ~ Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North MARATHON Oil Co~l~any Pad #1,CLU-5 Cannery Loop Unit,Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D ! N A T E S SURVEY LISTING Page 1 Your ref : Dipmeter <8600-11420'> Last revised : 23-Jan-97 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 215.00 0.86 38.54 214.99 1.26 N 1.01 E 0.40 1.55 399.00 1.20 55.40 398.96 3.44 N 3.45 E 0.25 4.81 461.00 2.10 48.20 460.94 4.56 N 4.8~ E 1.49 6.59 523.00 2.80 48.80 522.88 6.32 N 6.82 E 1.13 9.22 585.00 4.10 50.90 584.77 8.71 N 9.68 E 2.11 12.94 677.00 5.80 50.40 676.42 13.75 N 15.81 E 1.85 20.87 770.00 7.90 55.30 768.75 20.38 N 24.69 E 2.34 31.95 863.00 9.90 58.60 860.63 28.19 N 36.77 E 2.22 46.31 955.00 11.30 58.20 951.05 37.06 N 51.18 E 1.52 63.19 1048.00 13.90 55.90 1041.81 48.13 N 68.18 E 2.85 83.45 1141.00 15.70 54.40 1131.72 61.71 N 87.66 E 1.98 107.20 1234.00 17.90 53.80 1220.74 77.48 N 109.43 E 2.37 134.08 1296.00 18.90 54.10 1279.57 89.00 N 125.25 E 1.62 153.65 1389.00 21.50 54.40 1366.85 107.75 N 151.31 E 2.80 185.76 1482.00 24.10 54.10 1452.57 128.81 N 180.56 E 2.80 221.79 1574.00 25.20 54.10 1536.19 151.31 N 211.64 E 1.20 260.16 1665.00 27.80 54.20 1617.62 175.09 N 244.55 E 2.86 300.76 1757.00 31.10 54.70 1697.72 201.37 N 281.35 E 3.60 345.99 1850.00 33.40 53.90 1776.37 230.34 N 321.64 E 2.52 395.61 1943.00 35.40 54.70 1853.10 260.99 N 364.31 E 2.20 448.15 2036.00 38.40 55.00 1927.46 293.13 N 409.97 E 3.23 503.98 2128.00 40.30 54.00 1998.60 327.01 N 457.45 E 2.18 562.31 2221.00 42.10 53.70 2068.57 363.15 N 506.91 E 1.95 623.56 2314.00 45.60 53.90 2135.63 401.19 N 558.89 E 3.77 68?.98 2406.00 46.70 53.50 2199.37 440.47 N 612.36 E 1.24 754.32 2499.00 48.40 55.00 2262.14 480.55 N 668.05 E 2.18 822.93 2591.00 48.41 55.40 2323.21 519.81 N 724.55 E 0.33 891.73 2685.00 48.20 55.60 2385.74 559.57 N 782.39 E 0.27 961.90 27'~7.00 48.30 54.90 244?.00 598.69 N 838.79 E 0.58 1030.53 2870.00 47.80 55.50 2509.17 638.17 N 895.58 E 0.72 1099.69 2940.00 48.30 55.30 2555.96 667.73 N 938.44 E 0.75 1151.74 3058.00 46.37 55.88 2635.93 716.77 N 1010.01 E 1.68 1238.48 3149.00 48.16 56.28 2697.68 754.06 N 1065.48 E 1.99 1305.28 3242.00 48.41 56.93 2759.56 792.27 N 1123.44 E 0.59 1374.65 3336.00 48.83 55.05 2821.70 831.72 N 1181.90 E 1.57 1445.14 3428.00 48.92 54.61 2882.21 871.64 N 1238.55 E 0.37 1514.44 3520.00 48.73 54.88 2942.78 911.61 N 1295.10 E 0.30 1583.68 3614.00 48.78 55.02 3004.75 952.20 N 1352.96 E 0.12 1654.36 3705.00 48.75 54.89 3064.74 991.50 N 1408.98 E 0.11 1722.79 37~8.00 48.63 54.50 3126.13 1031.87 N 1465.99 E 0.34 1792.64 3891.00 48.71 54.73 3187.55 1072.31 N 1522.93 E 0.20 1862.48 3982.00 48.62 54.68 3247.65 1111.79 N 1578.70 E 0.11 1930.80 4076.00 48.56 54.5? 3309.82 1152.60 N 1636.18 E 0.11 2001.30 4138.00 48.54 54.65 3350.8? 1179.51 N 1674.06 E 0.10 2047.77 4231.00 47.30 54.72 3413.19 1219.42 N 1730.39 E 1.33 2116.79 4324.00 46.10 53.40 3476.97 1259.13 N 1785.19 E 1.65 2184.47 4420.00 44.66 53.35 3544.40 1299.90 N 1840.02 E 1.50 2252.79 4510.00 43.40 52.80 3609.11 1337.47 N 1890.03 E 1.46 2315.33 4603.00 42.20 52.70 3677.34 1375.72 N 1940.33 E 1.29 2378.49 AIl data is in feet unless otherwise stated. Coordinates from CLU-5 and TVD from Estimated RKB (70.00 Ft above mean sea [eve[). Bottom hole distance is 3433.70 on azimuth 54.45 degrees from wellhead. Vertical section is fro~ wellhead on azimuth 54.28 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ G(]i FIDENTIAL MARATHON Oil Ccx~Dany Pad #1,CLU-5 Cannery Loop Unit,Cook Inlet, Alaska Measured lnclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 4697.00 41.10 51.90 3747.58 1413.92 N 1989.76 E 4790.00 39.82 52.06 3818.34 1451.09 N 2037.30 E 4882.00 38.54 52.63 38~9.65 1486.60 N 2083.31 E 4972.00 37.73 52.13 3960.44 1520.52 N 2127.33 E 5068.00 36.20 52.28 4037.15 1555.90 N 2172.95 E 5160.00 35.29 51.29 4111.81 1589.14 N 2215.18 E 5253.00 33.90 51.32 4188.37 1622.15 N 2256.39 E 5345.00 31.97 51.98 4265.58 1653.19 N 2295.61 E 5436.00 29.77 52.42 4343.68 1681.81 N 2332.49 E 5530.00 28.32 53.13 4425.86 170~.42 N 2368.83 E 5621.00 26.90 53.67 4506.50 171~4.57 N 2402.68 E 5713.00 25.72 53.59 4588.96 1758.75 N 2435.51 E 5805.00 24.01 54.85 4672.43 1781.37 N 2466.89 E 5898.00 23.05 53.83 4757.70 1803.01 N 2497.06 E 5992.00 21.49 53.52 4844.68 1824.11 N 2525.76 E 6084.00 20.06 51.89 4930.70 1843.87 N 2551.72 E 6179.00 18.72 51.80 5020.31 1863.35 N 2576.52 E 6271.00 16.89 50.74 5107.90 1880.94 N 2598.48 E 6365.00 15.40 53.67 5198.19 1896.98 N 2619. ~E 6457.00 13.96 55.29 5287.19 1910.54 N 2638.07 E 6549.00 12.82 55.36 5376.69 1922.66 N 2655.59 E 6641.00 11.93 53.40 546~.55 1934.13 N 2671.62 E 67'54.00 10.91 54.02 5557.71 1945.03 N 26~6.46 E 6827.00 9.8~ 50.61 5649.19 1955.24 N 2699.72 E 6921.00 8.26 52.47 5742.01 1964.45 N 2711.28 E 7014.00 6.99 51.27 5834.19 1972.06 N 27"20.99 E 7106.00 5.87 51.53 5925.61 1978.48 N 2729.04 E 7198.00 4.24 53.71 6017.25 1983.42 N 27'55.46 E 7290.00 2.66 61.62 6109.08 1986.45 N 2740.08 E 738~.00 1.06 24.43 6202.03 198~.26 N 2742.34 E 7476.00 1.11 14.38 6295.01 1989.92 N 2742.92 E 7574.00 0.59 45.14 6393.00 1991.19 N 2743.51 E 7664.00 0.76 21.82 6483.00 1992.07 N 2744.06 E 7727.00 0.43 59.77 6545.99 1992.58 N 2744.42 E 7794.00 0.25 11.30 6612.99 1992.85 N 2744.67 E 7887.00 0.13 42.80 6705.9<) 1993.13 N 2744.78 E 7980.00 0.21 36.68 6798.99 1993.34 N 2744.95 E 80~'5.00 0.36 34.30 6891.99 1993.72 N 2745.22 E 8166.00 0.32 59.71 6984.99 1994.09 N 2745.61 E 8259.00 0.40 45.93 7077.99 1994.45 N 2746.07 E SURVEY LISTING Page 2 Your ref : Dil:x~eter <8600-11420'> Last revised : 23-Jan-97 Dogleg Vert Deg/lOOft Sect 1.30 2440.92 1.38 2501.22 1.45 2559.31 0.96 2614.85 1.60 2672.54 1.17 2726.23 1.49 2778.96 2.13 2828.93 2.43 2875.58 1.59 2921.20 1.58 2963.37 1.28 3004.14 1.95 3042.82 1.12 3079.95 1.66 3115.57 1.68 3148.19 1.41 3179.70 2.02 3207.79 1.81 3233.90 1.63 3257.21 1.24 3278.51 1.07 3298.23 1.10 3316.64 1.34 3333.36 1.70 3348.12 1.38 3360.45 1.22 3370.74 1.78 3378.84 1.79 3384.36 2.07 3387.24 0.21 3388.68 0.69 3389.91 0.36 3390.87 0.79 3391.46 0.48 3391.81 0.17 3392.07 0.09 3392.33 0.16 3392.77 0.17 3393.30 0.13 3393.88 8352.00 0.41 4.29 7170.98 1995.01 N 2746.32 E 8444.00 0.49 36.94 7262.98 1995.65 N 2746.58 E 8511.00 0.38 22.69 7329.98 1996.08 N 2746.84 E 8600.00 0.27 202.59 7418.98 1996.16 N 2746.88 E 8700.00 0.23 238.78 7518.98 199~.84 N 2746.61 E 8800.00 0.23 240.79 7618.98 1995.64 N 2746.27 E 8900.00 0.09 161.13 7718.98 1995.47 N 2746.12 E 9000.00 0.27 186.52 7818.98 1995.16 N 2746.12 E 9100.00 0.17 260.14 7918.98 1994.89 N 2745.95 E 9160.00 0.60 0.00 7978.98 1995.19 N 2745.86 E 0.31 3394.42 0.29 3395.00 0.23 3395.47 0.~'5 3395.54 0.16 3395.14 0.01 3394.74 0.23 3394.52 0.20 3394.34 0.28 3394.05 1.08 3394.15 All data is in feet unless otherwise stated. Coordinates from CLU-5 and TVD from Estimated RKB (70.00 Ft above mean sea level). Bottom hole distance is 3433.70 on azimuth 54.45 degrees from wellhead. Vertical section is from wellhead on azimuth 54.28 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ C i' iFiBENTiAL MARATHON OiL Company Pad #1,CLU-5 Cannery Loop Unit,Cook Inter, Ataska Measured [nc[in. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D [ N A T E S SURVEY LISTING Page 3 Your ref : Dipmeter <8600-11420'> Last revised : 23-Jan-97 Dogleg Vert Deg/lOOft Sect 9200.00 0.29 61.99 8018.97 1995.45 N 2745.95 E 1.32 3394.37 9300.00 0.56 91.33 8118.97 1995.56 N 2746.67 E 0.34 3395.02 9400.00 0.56 102.84 8218.97 1995.44 N 2747.64 E 0.11 3395.74 9500.00 0,81 95.32 8318.96 1995.26 N 2748.83 E 0.27 3396.60 9600.00 0.90 97.25 8418.95 1995.10 N 2750.32 E 0.09 3397.71 9700.00 1.00 105.48 8518.93 1994.76 N 2751.94 E 0.17 3398.84 9T27.00 1.00 0.00 8545.93 1994.94 N 2752.17 E 5.91 3399.13 9800.00 1.80 101.28 8618.92 1995.35 N 2753.30 E 3.05 3400.28 9900.00 1.28 103.54 8718.8~ 1994.78 N 2755.92 E 0.53 3402.08 10000.00 1.16 92.38 8818.86 1994.48 N 2758.02 E 0.26 3403.61 10065.00 1.00 0.00 88~3.85 1995.02 N 2758.68 E 2.41 3404.46 10100.00 1.19 98.7'2 8918.85 1995.27 N 2759.04 E 4.76 3404.90 10200.00 1.65 94.47 9018.82 1995.00 N 2761.50 E 0.48 3406.74 10300.00 1.48 97.13 9118.78 1994.72 N 2764.23 E 0.18 3408.79 10400.00 1.59 77.52 9218.74 1994.86 N 2766.87 E 0.54 3411.02 10500.00 1.17 81.98 9318.71 1995.31 N 2769.24 E 0.44 3413.20 10600.00 1.58 79.21 9418.68 1995.71 N 2771.60 E 0.41 3415.35 10700.00 1.83 95.01 9518.64 1995.83 N 2774.54 E 0.53 3417.81 10T79.00 1.50 0.00 9597.62 1996.75 N 2775.79 E 3.12 3419.36 10800.00 1.76 96.14 9618.61 1996.99 N 2776.12 E 11.59 3419.76 10900.00 1.70 89.97 9718.57 1996.83 N 2779.12 E 0.20 3422.11 11000.00 1.68 107.51 9818.53 1996.39 N 2782.00 E 0.51 3424.19 110~2.00 1.25 0.00 9890.51 1996.86 N 2783.01 E 3.30 3425.28 11100.00 1.59 99.98 9918.51 1997.09 N 2783.39 E 7.81 3425.73 11200.00 1.79 94.71 10018.46 1996.72 N 2786.31 E 0.25 3427.89 11300.00 1.78 89.92 10118.42 1996.60 N 2789.42 E 0.15 3430.34 11400.00 2.14 91.20 10218.36 1996.56 N 2792.84 E 0.36 3433.09 11420.00 2.14 91.20 10238.34 1996.55 N 2793.59 E 0.00 3433.69 AIl data is in feet un[ess otherwise stated. Coordinates from CLU-5 and TV~ from Estimated RKB (70.00 Ft above mean sea [eve[). Sottom hole distance is 3433.70 on azimuth 54.45 degrees from we[thead. Vertical section is from we[[head on azimuth 54.28 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Co~ny Pad #1,CLU-5 Cannery Loop Unit,Cook Inlet, Alaska SURVEY LISTING Page 4 Your ref : Dip~neter <8600-11420'> Last revised : 23-Jan-97 Targets associated with this we[lpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised CLU~ Tgt#1 1-Mar-96 4020.00 1559.00N 2158.00E 1-Mar-96 CLU#5 Tgt#2 1-Mar-96 10250.00 1970.00N 2740.00E 1-Mar-96 BENT AL Perf (71100-71180) Joint (7093 8-71335, OD:4 250, ID:2 992) Blast Joint (74752 74951, ©D:4 250, ID:2 992) Blast Ring (7495 %7526 8, OD:4 050, ID:2 992) Perf (7502075220) Blast Joint (7526 8-7546 7 OD:4 250, ID2 992} Blast Joint (7878 7-7898 6, OD:4 250, ID:2 992) CLU 5 MB-2U MB-3 MB-$L MB-4U MB-4L MB-5 LB-2 91 2 APl 50-133-20474-00 4/15/97 Alaska ion Domes :roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 14. 1997 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Lori Taylor The following logs are enclosed: Description Cannery Loop ~5~(..O ' O7~ Cannery Loop Unit #5 Completion Record 4/3/97 Print 1 1 Reproducible Film This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures Received Date: A subsidiary of USX Corporation Environmentally aware for the long run. Alaska .lion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 April 2, 1997 LETTER OF TRANSMITTAL AOGCC 3001 Porcupine Drive Anchorage, AK 99510 Attn: Howard Oakland Enclosed are samples of materials collected from Cannery Loop #5, Section: 7 Township: 5 Range: 11 West. If you have any questions please ~ont-~c-f'iSi~ or Matt McCullough at (907) 546-6401. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures A subsidiary of USX Corporation Environmentally aware for the long run. 4/2/97 Sample Materials for Cannery Loop #5 Section: 7 Township: 5 North Range: 11 West Sample Depths Company Well Name Field Type From: Depths To: 1) Marathon Oil Company Cannery Loop #5 Cannery Loop ~ Dry 3000 4200 2) Marathon Oil Company Cannery Loop #5 Cannery Loop Dry 4200 5580 3) Marathon Oil Company Cannery Loop #5 Cannery Loop Dry 5580 6870 4) Marathon Oil Company Cannery Loop #5 Cannery Loop , Dry 6870 8160 5) Marathon Oil Company Cannery Loop #5 Cannery Loop ' Dry 8160 9450 6) Marathon Oil Company Cannery Loop #5 Cannery Loop ! Dry 9450 10,620 7) Marathon Oil Company Cannery Loop #5 Cannery Loop ~ Dry 10,620 11,424 Book1 Alaska F, .)n Domestic ,' roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 18, 1996 LETTER OF TRANSMITTAL Alaska Oil &'Gas Conservation Commission Attn' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed' Description Cannery Loop Unit #5 Print Reproducible Film 1) Gamma/Ray Collar Log Cannery Loop #5 Dec 21, 1996 2) Packer ';-et Cannery Loop #5 Dec 22, 1996 1 1 1 I Kenai Gas Field 3) Completion Record KTU 43-6XRD Dec 16, 1996 Beaver Creek 4) Completion Record BCU-6 Dec 26, 1996 1 Received D at e: This data is considered confidential until the normal released date. MARATHON OIL COMPANY Kirsten K. Gamel Enclosures A subsidiary of USX Corporation Environmentally aware for the long run. ~'1' ~¥:~ara~non Oil uompany ' 1- u-u'/ AIIC flOF age~ Alaska Region Domestic Production P.O_ Box 196168 Anchorage, Alaske 99519 Telephone (907) 561-.$$11 FAX # 564-64~9 nli .., .... DATE: 1/6/97' TIME: 8:48 AM PLEASE DELIVER THE FOLLOWING PAGES TO: NAME: Blair Wondzell COMPANY/FIRM: AOGCC FAX NUMBER: 276-7642 FROM: NAME: Michael R, Ol$on EXTENSION: 5~4.6316 I AM TRANSMITTING 2 PAGES INCLUDING THIS COVER PAGE. IF TRANSMISSION IS NOT COMPLETE, PLEASE CALL: (907) .~1-$311. NOTE: Notification leffer: flowing CLU 5S ,_'_'5NN'I' B¥:i~laFa'tlloI1 till Uompany ; t-t~-u/ ' u:,~oAtvi ; Alaska Region Domestic Production Marathon OilCompany P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 6, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commis;ion 3001 porcupine Drive Anchorage, AK 99501-3192 Dear Blair; Marathon oil Company began flowing CLU 5S at approximately 1800 hours on 1/3/97. The short string is currently flowing 6.6 mmscfpd at 1550 psig WHP from t~e Middle and Lower Beluga formations. Plans are to continu~ flowing the well until the formation has cleaned up. The short string' will then be shut In until permanent surface production equipment can be installed - approximately 1 month. The long string will be perforated in the Upper Tyonek following installation of the surface equipment. I plan to submit the subsequent sundry following perforation of the upper Tyonek. If you have any questions, please contact me at 564-6315. Sincerely, ,¢,,~/' ....,/" /, . . '-) ..... :.," ./,- .... /.:.- /,...'" .... ,, Michael R. Ol$on Production Engineer Attachments cc: CEF Loretta Ribaul (Lafayette) A subsidiary of USX Corporallon Environmentally aware for the long mn, Alask~ 3ion Domes,.. Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 18, 1996 LETTER OF TRANSMITTAL Alaska Oil & Gas Conservation Commission Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501-3192 The following logs are enclosed: Description Cannery_ Loop Unit #5 ~' 1) Platform Express Litho- Density/Nuetron Run #1 October 26, 1996 1 /2) Platform Express Array Induction/GR Run #1 October 26, 1996 1 ~-3) Natural Gamma Ray Spectrometry Log Run #1 October 26, 1996 1 · -- 4) Diphole Sonic Imager Cannery Loop Unit #5 Run #1 October 26, 1996 1 '~ 5) Platform Express Litho Density/Nuetron Run '7__ November 12, 1996 1 '-' 6) Platform Express Array Induction/GR Run #2 November 12, 1996 1 -'- 7) Natural Gamma Ray Spectrometrylog Run #2 November 13, 1996 1 t 8) Dipole Sonic Imager Cannery Loop Unit #5 Run #2 November 13, 1996 ,/9) Ultrasonic Imager/Cement Cannery Loop Unit #5 1 Run # 1 November 19, 1996 .,- 10) Cement Bond Log Cannery Loop Unit #5 Run #1 1 November 19, 1996 ,/11) Production Packer Cannery Loop Unit #5. 1 November 21, 1996 ,~- 12) Completion Record Cannery Loop Unit #5 1 November 26, 1996 · ~"13) Completion Record Cannery Loop Unit #5 1 November 27, 199 ~ 14) Completion Record Cannery Loop Unit #5 1 November 24, 1996 Print Reproducible Film This data is considered confidential until the normal released date. MARATHON OIL COMPANY Received By: '-~ L('~''`, Kirsten K. Gamel Date: Encl°Auget~bsidiary of USX Corporation Environmentally aware for the long run. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John..s~~ DATE: November 23, 1996 Chairman "~ THRU: Blair Wondzell, 03¢.4~ FILE NO: P. I. Supervisor ~/' ?-'r -3C~/ FROM' Lou Grimaldi, Lo~ SUBJECT: Petroleum Inspector A9QJKWDD.doc BOPE Test, Pool rig #122 Marathon Well #CLU #5 Kenai Gas Field PTD #96-73 Saturday, November 23, 1996' I traveled to Marathon's Kenai Gas field to witness the weekly BOPE test on Pool rig #122, which is drilling CLU #5. I arrived at 2230 of the previous day, the test got underway at 0130 and ended at approximately 0530. Ail BOPE equipment was tested with no failures observed. It was apparent to me that the BOPE equipment was well taken care of. Darrell Greene (POOL toolpusher) provided a good check of the equipment and seemed dedicated to operating a safe rig. The rig will be completing this well soon and then production testing will begin. A return visit is recommended during this operation. The area surrounding the rig was orderly and well kept. Summary: I witnessed a BOPE test on Pool rig #122 drilling well #CLU-5. The test lasted 4 hours and there were no failures. Attachment: A9QJKWDD.XLS cc; Terry Kovasovitch (Marathon Anchorage) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Operator: Marathon Well Name: Cannery Loop Unit #5 Casing Size: Set @ Test: Initial Weekly X Rig No. '/22 PTD # Rep.: Rig Rep.: Location: Sec. Other DATE: 11/23/96 96-73 Rig Ph.# 283-2883 Pete Berga Darrefl Greene 7 T. 5N R. 11W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 1 25O/3OO0 P I 250/5, 000 P '1 250/5,000 P '1 250/5,000 P 1 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A 250/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 250/5,000 250/5, 000 250/5, 000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 250/5,000 F 34 250/5,000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 1850 Average 3,000 I P ~,500 P minutes 24 sec. minutes 8 sec. P Remote: P Psig. TEST RESULTS Number of Failures: 0 ,Test Time: ~Hours. Number of valves tested '/9 Repair or Replacement of Failed Equipment will be made within N/A d-~'~. Notify the Inspector and follow with Written or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Kelly not needed, test if picked up. Good test procedure. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Lou Grimaldi FI-021L (Rev.12/94) A9QJKWDD.XLS MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 2, 1996 THRU: Blair Wondzell, P. I. Supervisor FROM' Lou Grimaldi, ~.<~.,. SUBJECT: Petroleum Inspector FILE NO: Q99JKBDD.doc RIG/BOPE inspection Pool rig#122 Marathon CLU #5 Kenai Gas Field PTD #96-73 Saturday, November 2, 1996: I traveled to Marathon's Kenai Gas field to make a Rig/BOPE inspection on Pool rig #122 which is drilling CLU #5. I arrived to find the rig running single shot surveys for inclination. I made a thorough inspection of the rig and found all BOP equipment to be in well maintained condition. The rig was well heated with a additional Tioga type heater. The area surrounding the rig was well maintained and very clean. Summary: I made a Rig/BOPE inspection on Pool rig #122 drilling well CLU #5. The rig was in good shape and the location was very clean and organized. Attachment: Q99JKBDD.XLS cc; Terry Kovasavich (Marathon Oil Co.) AL, --' STATE OF ALASKA ~A OIL AND GAS CONSERVATION C(~ .... ~IISSION RIG / BPS INSPECTION REPORT OPERATION: Drilling X Workover Compl. UIC DATE: 11/2/96 Well Name: CLU #5 PTD# 96-73 Drig Contractor: Pool Arctic Rig# 122 Rep. Holly Waldron Operator: Marathon Oil Co. Rep. Lance Lamens Rig Ph.# 227-0421 Location: Section 7 T. 5 N R. 11W M. S INSPECTION ITEMS IN COMPLIANCE INSPECTION ITEMS IN COMPLIANCE (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill Ln.) X INSPECTION ITEMS IN COMPLIANCE 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level INSPECTION ITEMS IN COMPLIANCE indicators, gauges) (B.) CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) 18 Operating pressure X 43 Hydraulic choke panel I X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X INSPECTION ITEMS IN COMPLIANCE 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures X 50 H2S probes X 51 Rig housekeeping X* REMARKS: Rig in good shape. Housekeeping around location is Outstanding. RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? Yes Kill Sheet Current? Yes Distribution: orig - Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector AOGCC REP: Louis R. Grimaldi OPERATOR REP: Q99JKBDD.XLS (Rev. 12/92) MEMORANDUM TO: David JohP~n, Chairman" State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 18, 1996 THRU: Blair Wondzell, ~ FILE NO: P. !. Supervisor a99hjqdd.doc Confidential: Yes _, No_X, Attachment Only . FROM: Doug Amos, ~~, ,~ SUBJECT: Petroleum Inspector BOPE Test, PAA 122 Marathon Kenai Gas Field Well #CLU #5 PTD #96-0073 Thursday, October 17, 1996: ! traveled to Marathon's Kenai Gas field to witness the weekly BOPE test on Pool Rig No. !22, on Cannery Loop Well No. 5. As the attached AOGCC BOPE Test Report, indicates there were two failures. The Lower Kelly cock failed and was replaced with the floor Safety Valve. A new floor valve was rented to replace the existing one. Also the Manual Choke on the Choke Manifold could not be functioned tested, this valve was removed, cleaned and reinstalled. Both failures were repaired during the course of this test. ! found the rig ,,vas in good condition and the crew very knowledgeable about the test procedure and their equipment. The location has a small foot print with the rig and other production equipment occupying most of the pad area. There is road access on two boundaries of the pad which would allow emergency equipment access to the location should the need arise. Summary: ! witnessed a BOPE test on Pool rig #122 at Marathon's Cannery Loop Well No. 5 Attachment: A99HJQDD.XLS ST ^'r= OF ALASKA AND GAS CONSEP3.tATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor:. Pool Arctic Alaska kDrilling Rig No. Operator: Marathon 0il Co. Well Name: CLU No. 5 Casing Size: ./3,3iR" Set @ 2,970 Test: Initial Weekly X Other ./22 PTD # Rep.: Rig Rep.: Location: Sec,. 96-0073 DATE: 10/17/96 Rig Ph.# 283~2883 Lance Lamons H. Waldon 7 T. 5N R. 11W Meridian Seward MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign Yes Upper Kelly / IBOP Housekeeping: OK (Gen) I U ton Location Yes Standing Order Posted Yes i Drl. Rig OK Lower Kelly / IBOP '/ I Hazard Sec. Yes Bail Type '/ I ! Inside BOP '/ BOP STACK: Annular D ...... I I ~:;v~;;l i1.~;~1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. uO0i % uuO 500/5, 000 i 500/5,000 ./ 500/5, 000 2 500/5,000 500/5,000 P/F P P P P P PiP P N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK , n,.,k.a,o, OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves '/5 No. Flanges 34 Manual Chokes '/ Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Test Quan. Pressure P/F '/ 500/5, 000 P 500/5,000 500/5,000 500/5, 000 Test Pressure P/F 5CCi5,000 I P 500/5,000 P .... Functioned F Functioned P 3,'/50 I P '/,800 P , mlflutes 21 sec. minutes 49 see. Yes Remote: Yes Nitgn. Btl's: . 6 @ 2,000 p,s/g Psig. Number of Failures: 2 ,Test Time: 7.0 Hours. Number ef valves tested 21 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to Ith~ lO~C Commission Office at: Pax Ho. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your ca!! is not returned by the inspector within !2 hours please contact the P. !. Supervisor at 279-1433 [ I I REMARKS: The lower kelly cock failed and the manual choke could not be functioned. The lower kelly was replaced with the floor valve and the floor valve was replaced with a rental unit. The manual choke was removed cleaned and replaced. Both failures were corrected before drilling ahead. Distribution: ! STATE WITNESS REQUIRED? orig-Weli File ]1 y~ X I~} c - Oper./Rig j I c - Database J ~J P.~IJIJ I~'llOJ Ilia# J c - Trip Rpt File J YES X #0 I c-lns[)ector j ~ I I I · FI-021L (Rev. 12/94) A99HJQDD,XLS Waived By: Witnessed By: Doug Amos MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh nst_~~, Chairma~ P. I. Supervisor FROM: Lou Grimaldi, ~o..~ Petroleum Inspector DATE: FILE NO: SUBJECT: October 4, 1996 EQ8JJDDD.DOC Diverter inspection Marathon CLU #5 Kenai Gas Field PTD 96-073 Friday, October .4, .1996: I traveled to Marathon's Cannery Loop gas production facility to witness the Diverter function test on Pool rig #122 which was preparing to drill surface hole on well #CLU #5. The Diverter assembly had to be wet down and functioned several times in order to get the annular preventer to close completely, this was due to dried mud left in it from the last time it was used. The 16 inch knife valve used on the vent line operated quickly and was open well before the annular closed. The accumulator had a recharge time of 2 minutes 36 seconds, the air pumps were not operating and will be repaired before the rig drills surface hole. The gas detection system was tested and although they operated properly I found a plastic cap over the sensor for methane on the floor. This was removed. I walked the vent line and found a good solid construction. The line terminated in the reserve pit and although it terminated slightly close to a nearby production there was enough directional clearance to allow this configuration. I discussed the directive from the A.©.G.C.C. commissioners concerning surface casing cementing with Lance Lamens (drilling foreman). SUMMARY: I witnessed the Diverter function test on Pool rig #122. One failure noted, the air pumps on the accumulator. Attachments: EQ8JJDDD.XLS cc; Terry Kevasovich (Marathon Oil Co.) NON-CONFIDENTIAL Contractor: rator: Name: ~ation: Sec. TATE OF ALASKA ALASKA OIL ANu GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Pool Arctic Marathon CLU #5 Operation: Rig No. Development 122 PTD # Date: X Exploratory: 96-73 Rig Ph. # Lance Lamens 5N R. Oper. Rep.: Rig Rep.: 11W 10/4/96 283-2883 Holly Waldron Merdian Seward TEST DATA /llSC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: 21 1/4 P P 16 120 N/A P P N/A P P N/A in. in, ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3000 1750 min. 29 2 min. 36 6 Bottles psig psig sec. sec. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: 1900 Average psig Light Alarm P P GAS DETECTORS: Methane Hydrogen Sulfide: P P P P Light Alarm P P P P DIVERTER SCHEMATIC /' MOTORS iI GRAVEL PITi TO BLUFF OF COOK INLET Non Compliance Items 1 Repair Items Within N/A Day (s),..And contact the Inspector @ 659-3607 Remarks: Air pumps on Accumulator inoperative, repair before spudding. Annular preventer had dried mud inside that prevented proper operation until washed and cycled. Distribution orig. - Well File c - OpedRep c- Database c - Trip Rpt File c- Inspector AOGCC REP.: OPERATOR REP.: Louis R Gfimaldi F1-022 (Rev. 7193 EQ8JJDDD.XLS TONY KNOWLE$, GOVEF~NOR AI~ASKA OIL AND GAS CONSERVATION CO~VlM~SSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 2, 1996 Terry J. Kovacevich Operations Superintendent Marathon Oil Company P O Box 196168 Anchorage, AK 99519-6168 P~e~ Well # Company Permit # Surf Loc Btmhole Loc Cannery Loop Unit #5 Marathon Oil Company 96-073 180'FSL, 320'FEL, Sec 07, T05N, R11W, SM 2150'FSL, 2470'FWL, Sec 08, T05N, R11W, SM Dear Mr Kovacevich: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman -~' BY ORDER OF THE COMMISSION ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation- w/o encl ._ O:IEXCEL'tAOGCCPTD.XLW STATE OF ALASKA ALA;....~, OIL AND GAS CONSERVATION COMM,~SION PERMIT TO DRILL 210 AAC 25.005 'la. Typo of Work DrillE~] Re-DrillF"~ lb. Type of well. Exploratory['--'] Stratigraphic TestE~ Development oilE~ Re-Entry[-'-I Deepen[-'-'~ ServiceE~ Development Gas[~ Single Zone['~ Multiple ZoneE~] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool MARATHON OIL COMPANY EST. 50 feet CANNERY LOOP 3. Address 6. Property Designation BELUGA- TYONEK P. O. Box 196168, Anchorage, AK 99519-6168 ,¢ADL 60568 CANNERY LOOP FIELD 4. Location of Well at Surface 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) 180' FSL& 320' FEL SEC 7, T5N, R11W, SM CANNERY LOOP UNIT At top of Productive Interval 8. Well Number Number 1739' FSL & 1888' FWL SEC 8, T5N, R11W, SM @4020'TVD ! CLU #5 ; 5194234 At Total Depth 9. Approximate Spud Date Amount 2150' FSL & 2470' FWL SEC 8,T5N,R11W,SM @10,250'TVD SEPT. 1, 1996 $200,000.00 12. Distance to Nearest 13. Distance to Nearest Well 14. Number of Acres in Property 15. Proposed Depth (MD and TVD) Property Line 1739 feet EST 900 feet 640 AC DRILLING BLOCK 11,467' MD/10,250' TVD feet 16. To be Completed for Deviated Wells 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Kickoff Depth 500 feet Maximum Hole Angle 49 o Maximum Surface 5000 psig at Total Depth (TVD) 10,250' psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) DRIVEN 20" 133 B PR-BEV 80' 0' 0' 80' 80' DRIVEN 17-1/2" 13-3/8" 61 K-55 BTC 3000' 0' 0' 3000' 2582' 2350 SX 12-1/4" 9-5/8" 47 N-80 BTC 9217' 0' 0' 9217' 8000' 2500 SX 8-1/2" 7" 29 N-80 BTC 2467' 9000' 7783' 11,467' 10,250' 400 SX 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present Well Condition Summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor Surface Intermediate Production Liner APR 0 1 1996 Perforation Depth: measured Naska0it & 6a~ Coos. ~ true vertical 20. Attachments Filing FeeE~] Property PlatE~] BOP SketchE~ Diverter Sketch[-~'] Drilling ProgramE~ Drilling Fluid Program~'] Time vs Depth Plotr'--~ Refraction Analysis~ Seabed Report[~ 20 AAC 25.050 Requirements[~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'"'"' ] ~'~, ~ Commission Use Only Permit Number IAPI Number IApproval Date / See Cover Letter ?O~'''' 7,j~ 50--//,~,_,~ ,-.- 2._4:~ ~,5'.,~ ~Z ,~'/~ j/~ ~. For Other Requirements Conditions of Approval Samples Required [~Yes r~No Mud Log Required E~Yes J~No Hydrogen Sulfide Measures F-~Yes [~No Directional Survey Required [~Yes F']No Required Working Pressure for BOPE E]2M F~3M ~5M E~10M E~15M Other: .~¢~9~rlat Signed By by order of Approved by ~.avid W, Johnston Commissioner the Commission Date .,~ Form 10-401 Rev. 12-1-85 Submit in Triplicate I" IU. ING AND COMPLETION PROGRAM ~ MARATHON OIL COMPANY ALASKA REGION WELL: PAD: SLOT: Cannery Loop Unit #5 1 NA REVISION NO.: 1 SURFACE LOCATION: TARGETS: Sterling BOTTOMHOLE LOCATION: KB ELEVATION: GL ELEVATION: FIELD: Cannery Loop Unit AFE No.: TYPE: Development DATE: 3/18/96 180' FSL,320' FEL,Sec.7,T5N,R11W, S.M. 1739' FSL, 1888' FWL, Sec 8, T5N, R11W @ 4020' TVD 2150' FSL, 2470' FWL, Sec 8, TSN, R11W @ 10250' TVD 50 ft. mean S.L. (est.) 20 ft. mean S.L. (est.) I. IMPORTANT-GEOLOGIC HORIZONS: FORMATION DEPTH(MD) DEPTH(TVD) Sterling 5088 4020 Beluga 6330 5130 Tyonek 9017 7790 II. ESTIMATED FORMATION TOPS AND CONTENT: FORMATION Sterling A8 Beluga Tyonek Tyonek T1 Tyonek D6 DEPTH(MD) 5088 6330 9017 9887 11229 DEPTH(TVD) 4O2O 5130 7790 8670 10012 POTENTIAL CONTENT Gas Gas(depleted) Gas Gas(depleted) Gas APR 0 7 1996 page 1 III. WELL CONTROL EQUIPMENT 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 outfitted with blind rams in the bottom and pipe rams in the top, a 13 5/8" x 5000 psi drilling spool (mud cross) equipped with a 3-1/16" x 5000 psi outlets, and a 13 5/8" x 5000 psi single gate ram type preventer outfitted with pipe rams. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mudpits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. WELLHEAD SYSTEM STARTING HEAD: 13-5/8" 3000 PSI top x 13-3/8' sow with base plate for 20· TUBING HEAD.'__ 11 ' 5000 PSI top x 13-5/8' 3000 PSI bottom CHRISTMAS TREE: 3-1/16' - 5000 psi single christmas tree including two master valves, one flow tee, one swab valve, wing valve, manumatic and manually adjustable choke. IV. CASING PROGRAM: CASING DESCRIPTION SET TYPE SIZE VVT. GRADE THREAD FROM Drive pipe 20' 133 B PE Surf Surface 13 3/8" 61 K-55 BTC Surf Intermediate 9 5/8' 47 N-80 BTC Surf Production 7 · 29 N-80 BTC 9000' CASING DESIGN SETTING FRAC GRD FORM PRSS SIZE WEIGHT GRADE DEPTH,TVD @ SHOE @ SHOE MASP 13 3/8" 61 K-55 2582' 12 ppg 1208 1403 9 5/8" 47 N-80 8000' 13 ppg 3744 4904 7" 29 ppf N-80 10250' 5000 5000 SET TO(rnd/tvd) 80'-100' 3OOO'/2582' 9217'/8000' 11467'/10250' HOLE SIZE 17 1/2' 12 1/4· 8 1/2" DESIGN FACTORS TENSION COLL. BURST 2.25 1.34 7,35 1.49 3.97 3.42 1.62 4.49 9.45 page 2 V. CEMENTING PROGRAM SURFACE LEAD SLURRY: 13 3/8' @ 3000'MD CLASS G + ADDITIVES AS REQUIRED TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME Surface 13.3 ppg. 1.97 cu. ft./sk 10.27 gal/sk hrs:min 100 % in open hole. 1750 sk TAIL SLURRY: CLASS G + ADDITIVES AS REQUIRED _TOP OF CEMENT: 2500 WEIGHT: 15.8 ppg YIELD: 1.17 cu. ft./sk WATER REQ.: 5.1 gal/sk PUMPING TIME: hrs:min EXCESS (%): 100 % in open hole ESTIMATED VOLUME 600 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections. 2. Make up float shoe, one jt., and float collar. Check floats. Fill pipe until circulating. 3. Run remaining casing. 4. Circulate until no gains in circulating efficiency is made. 5. Pump spacer as follows: 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 6. Mix and pump lead slurry followed by tail slurry.. 7. Displace drill pipe with mud. 8. Washout between 20' and 13-3/8'. 9. Nipple down diverter. 10. Install slip on well head. Test. N/U BOPE. Test. page 3 INTERMEDIATE LEAD SLURRY: 9 5/8" @ 9217'MD CLASS G + additives as required TOP OF CEMENT: WEIGHT: YIELD: WATER REQ,: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 3500 ft. 13.3 ppg. 1,97 cu, ft./sk 10.27 gal/sk hrs:min 100 % in open hole, 800 sk TAIL. SLURRY: CLASS G + 0.02 GAL/SK D110 + 0.04 GAL/SK D145A TOP OF CEMENT: 6000 ft, WEIGHT: 15,8 ppg. YIELD: 1.17 cu. ft./sk __WATER REQ,: 5,1 gal/sk PUMPING TIME: 4:20 hrs:min EXCESS (%): 100 % ESTIMATED VOLUME 1700 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections, 2, Make up float shoe and 2 shoe joints. Check float, Fill pipe until circulating, 3, M/U float collar. (Baker-lok all connections to top of float collar) 4, Fill pipe until circulating, 5, Run remaining casing, Secure in slips, 6, Circulate until on gain in efficiency is observed, 7, Pump spacer as follows: 20 bbls drill water 20 bbls Super Flush 20 bbls drill water 8. Mix and pump Lead slurry, 9, Mix and pump Tail slurry, 10. Displace casing with mud, 11, P/U BOPE, Set slips. N/U casing spool. N/U BOP stack. 1 2. Test BOPE, page 4 PRODUCTION: 7" Liner @ 467'MD STAGE 1 SLURRY: CLASS G + ADDITIVES AS REQUIRED TOP OF CEMENT: WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS (%): ESTIMATED VOLUME 9000 ft 15.8 ppg. 1.17 cu. ft./sk 4.40 gal/sk hrs:min 50 % in open hole. 400 sk RUNNING AND CEMENTING DETAILS: ENSURE WEAR BUSHING IS REMOVED! 1. Remove thread protectors and visually inspect connections, 2, Make up float shoe and 2 shoe joints, Check float, Fill pipe until circulating. 3, M/U float collar. (Baker-lok all connections to top of float collar) 4. Fill pipe until circulating, 5. Run remaining casing. Pick up hanger, RIH with drillpipe. 6. Circulate and reciprocate until no gains in circulating efficiency is made, 7, Set hanger, Release setting tool from hanger. 8. With as little shut down as possible, drop bottom plug and begin pumping spacer. Pump spacer as follows: 20 bbls drill water 20 bbls 20 bbls drill water 9. Mix and pump Stage 1 slurry. 10, Displace cement. Reciprocate as long as possible. 11. Bump plug w/500-1000 psi over final cirCulating pressure. Check floats. 12. Pick up out hanger. POOH with 5 stands. 13. Pump slug and POOH. page 5 VI. MUD PROGRAM MUD PROPERTIES DEPTH DEPTH WEIGHT VISCOSITY WATER MUD FROM TO ppg sec/qt LOSS TYPE 0' 2500' 8.6-9.0 40-80 10-15 Gel/Water 3000' 9217' 9.0-9.5 40-60 5-10 FLO PRO/KCL 9217' 11467' 11.0-12.0 40-60 <5 FLO PRO/KCL MUD EQUIPMENT The solids control equipment will consist of two derdck floline cleaners, a 2-cone desander, a mudcleaner, and a Swaco 518 centrifuge. VII. LOGGING, TESTING, AND CORING PROGRAMS LOGGING PROGRAM SURFACE HOLE: None. INTERMEDIATE: PRODUCTION: AIT/DSI/SP and LDT/CNL/NGT. FMI/GR. CST. CMR/GR. AIT/DSI/SP and LDT/CNL/NGT. FMI/GR. CST. CMR/GR. COMPLETION: A Cement Bond Log (CET/GR) will be run prior to completion and testing. CORING PROGRAM None planned. TESTING PROGRAM None planned. VIII. BOTTOMHOLE PRESSURES AND POTENTIAL HAZARDS Hydrogen sulfide gas is not anticipated to be encountered. The upper part of the Tyonek zone is expected to be abnormally pressured. No other known hazards. TVD, ft. Est. pressure, psi Gradient, ppg. Sterling A8 4020 1777 8.5 Beluga 5130 1326 5,0 Tyonek 7790 4455 11,0 Tyonek T1 8670 2023 4,5 Tyonek D6 10012 4505 8,7 page 6 IX. OTHER INFORMATION DIRECTIONAL PLAN NORTH EAST VERT DESC MD TVD INCL AZIM COORD COORD SECTION RKB 0 0 0.00 0 0 0 0 KICKOFF, (Tie-in) 500 500 0.00 0 0 0 0 END OF BUILD 2473 2238 49,32 55 460 652 798 END OF HOLD 4170 3345 49.32 55 1203 1704 2085 END OF DROP 7458 6241 0,00 0 1970 2790 3415 TOTAL DEPTH 11467 10250 0,00 0 1970 2790 3415 POTENTIAL INTERFERENCE: DRILLING WELL CLU//1 DISTANCE (ft.) DEPTH (MD) To be determine after final surface location. DRILLING PROGRAM Mobilize rig to location and rig up. Drive 20" casing to refusal (80-100'). Weld on starting flange. N/U diverter and test. Clean out 20" casing and directionally drill 17 1/2" hole to 3000', Run and cement 13 3/8" casing. Weld on slip on head. Test. N/U BOPE and test. Test casing to 1500 psi. Drill out 13 3/8" casing, Test shoe to 12.0 ppg, Directionally drill 12 1/4" hole to 8000' TVD, Log. Run and cement 9 5/8" casing. Set slips and packoff, N/U BOPE and test. RIH with 8 1/2" bit and drilling assembly, Test casing to 2000 psi, Drill out and test shoe to 13,0 ppg EMW, Drill to 10250' TVD. Log, Run and cement 7" liner, Set slips and ~ackoff, N/U tubing spool and test, Test BOPE, Run CET, :omplete and test per program. COMPLETION: Cleanout casing to PBTD. Run CET/GR. Complete as per completion program, page 7 Alaska, on Domesti~-~ ;'roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 29, 1996 Mr. Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference' Cannery Loop Unit #5 Dear Mr. Johnston: Enclosed is the application for permit to drill the referenced well. Please advise if additional information is required. Sincerely, T. J. K'O'Vacevich Operations Superintendent /nr~ H:\WP\OPNS~8\TJKCLU5 Enclosure ErG ivED APR 0 1 1996 oil & ~ Ocs. Oofaraiss~ A subsidiary of USX Corporation Environmentally aware for the long run. .. 50O ~e on KOP 2.50 7.50 0 1000 12.50 03 - _ 2 1500 _ _ 2000 _ _ _ _ 3500 _ 4000 _ _ 45OO _ _ 5000 _ _ 5500 _ 6000 6500 _ _ 7000 _ _ 7500 _ _ 8000 _ _ 8500 9000 9500 _ 10000_ _ 10500 I I I 0 500 S~le 1:250.00 25OO I 0__ 3000 I I V 27,50 32.50 57.5O 42.50 47.50 MARATHON Oil Company I Structure : Pad #1 Well : CLU-5 Field : Cannery Loop Unit Location : Cook Inlet, Alaska WELL PROFILE DATA MD Inc Dir 'JYD NoAh 0 0.00 54,77 0 0 500 0.00 54.77 500 0 2473 49.32 54.77 2238 460 4171 49.32 54.77 3345 1205 5088 35.56 54.77 4020 1559 7458 0.00 54.77 6241 1970 11467 0.00 54.77 10250 1970 ITt Point e on KOP End of Build lend of Hold Target End of Drop ITara_ et East Deg/lOC 0 O.OC 0 O.OC 652 2.5C 1704 0.00 2208 1.50 2790 1.50 2790 0.00 EOC Created by : jones For: M SINCLAIR Dote plotted : 4-Mar-96 Plot Reference is CLU~5 Version Coordinates ore in feet reference CLU-5. True Vertical Depths are reference RKB not Set. Begin Angle Drop48.O0 45.00 42.00 39.00 CLU#5 TgtJ/1 1-1dar-96 36.00 TARGET ~1 53.00 30.00 27.00 24.00 1 .oo 18.00 15.00 12,00 9.00 6.00 3.00 End Angle Drop CLUJ5 TgtJt2 1--Mar--96 ~ TD 0 400 800 1200 1600 2000 2400 2800 CLU~5 Tgt~2 1~ CLU~5 Tgt#l - - _2000 _ _1600 _ _1200 8O0 _ 4OO _ _ 0 I I Z I I I I I I I I I I I I 1000 1500 2000 2500 3000 $500 Vedlcal Section on 54.77 azimuth with reference 0.00 N, 0.00 E from CLU-5 MARATHON Oil Company Pad #1 CLU-5 CLU-5 Cannery Loop Unit Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : CLU~5 Version Our ref : prop1564 License : Date printed : 7-Mar-96 Date created : 1-Mar-96 Last revised : 4-Mar-96 Field is centred on n60 31 54.076,w151 15 37.735 Structure is centred on n60 31 54.076,w151 15 37.735 Slot location is n60 31 55.849,w151 15 44.130 Slot Grid coordinates are N 2388622.296, E 272662.423 Slot local coordinates are 180.00 N 320.00 W Reference North is True North NARATHON Oil Company Pad #1,CLU-5 Cannery Loop Unit,Cook Inlet, ALaska Measured Depth 0.00 500.00 600.00 700.00 800.00 PROPOSAL LISTING Page 1 Your ref : CLU#5 Version #3 Last revised : 4-Mar-96 [nclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2472.64 2500.00 3000.00 3500.00 4000.00 4170.62 4258.35 4358.35 4458.35 4558.35 4658.35 4758.35 4858.35 4958.35 5058.35 5087.68 5158.35 5258.35 5358.35 5458.35 5558.35 5658.35 5758.35 5858.35 5958.35 6058.35 6158.35 6258.35 6358.35 0.00 54.77 0.00 180.00 N 320.00 W 0.00 0.00 0.00 54.77 500.00 180.00 N 320.00 W 0.00 0.00 KOP 2.50 54.77 599.97 181.26 N 318.22 ~ 2.50 2.18 5.00 54.77 699.75 185.03 N 312.88 W 2.50 8.72 7.50 54.77 799.14 191.31 N 303.98 ~ 2.50 19.61 10.00 54.77 897.97 200.08 N 291.56 W 2.50 34.82 12.50 54.77 996.04 211.33 N 275.62 W 2.50 54.32 15.00 54.77 1093.17 225.04 N 256.21 ~ 2.50 78.09 17.50 54.77 1189.17 241.18 N 233.35 ~ 2.50 106.07 20.00 54.77 1283.85 259.72 N 207.09 W 2.50 138.21 22.50 54.77 1377.04 280.62 N 177.49 ~ 2.50 174.46 25.00 54.77 1468.57 303.85 N 144.59 W 2.50 214.73 27.50 54.77 1558.25 329.36 N 108.46 ~ 2.50 258.95 30.00 54.77 1645.92 357.10 N 69.18 ~ 2.50 307.05 32.50 54.77 1731.40 387.02 N 26.80 ~ 2.50 358.92 35.00 54.77 1814.54 419.07 N 18.58 E 2.50 414.47 37.50 54.77 1895.18 453.17 N 66.88 E 2.50 473.60 40.00 54.77 1973.16 489.27 N 118.00 E 2.50 536.19 42.50 54.77 2048.34 527.30 N 171.86 E 2.50 602.12 45.00 54.77 2120.57 567.18 N 228.34 E 2.50 671.26 47.50 54.77 2189.72 608.84 N 287.35 E 2.50 743.49 49.32 54.77 2237.93 640.18 N 331.72 E 2.50 797.82 EOC 49.32 54.77 2255.77 652.15 N 348.67 E 0.00 818.56 49.32 54.77 2581.71 870.84 N 658.40 E 0.00 1197.72 49.32 54.77 2907.66 1089.54 N 968.13 E 0.00 1576.88 49.32 54.77 3233.60 1308.24 N 1277.86 E 0.00 1956.04 49.32 54.77 3344.82 1382.87 N 1383.55 E 0.00 2085.42 Begin Angle Drop 48.00 54.77 3402.77 1420.86 N 1437.36 E 1.50 2151.28 46.50 54.77 3470.65 1463.21N 1497.34 E 1.50 2224.72 45.00 54.77 3540.43 1504.53 N 1555.85 E 1.50 2296.34 43.50 54.77 3612.06 1544.78 N 1612.85 E 1.50 2366.12 42.00 54.77 3685.49 1583.93 N 1668.30 E 1.50 2434.00 40.50 54.77 3760.67 1621.96 N 1722.16 E 1.50 2499.93 39.00 54.77 3837.55 1658.84 N 1774.39 E 1.50 2563.87 37.50 54.77 3916.08 1694.55 N 1824.96 E 1.50 2625.78 36.00 54.7-/ 3996.20 1729.06 N 1873.84 E 1.50 2685.61 35.56 54.77 4020.00 1738.95 N 1887.85 E 1.50 2702.76 TARGET #1 34.50 54.7'/ 4077.86 1762.35 N 1920.98 E 1.50 2743.32 33.00 54.77 4161.01 1794.39 N 1966.37 E 1.50 2798.88 31.50 54.77 4245.58 1825.17 N 2009.96 E 1.50 2852.24 30.00 54.77 4331.52 1854.66 N 2051.72 E 1.50 2903.37 28.50 54.77 4418.76 1882.84 N 2091.64 E 1.50 2952.23 27.00 54.77 4507.26 1909.70 N 2129.67 E 1.50 2998.79 25.50 54.77 4596.94 1935.21N 2165.80 E 1.50 3043.02 24.00 54.77 4687.76 1959.36 N 2200.00 E 1.50 3084.88 22.50 54.77 4779.63 1982.12 N 2232.24 E 1.50 3124.35 21.00 54.77 4872.51 2003.50 N 2262.51E 1.50 3161.41 19.50 54.77 4966.33 2023.46 N 2290.78 E 1.50 3196.02 18.00 54.77 5061.02 2042.00 N 2317.04 E 1.50 3228.16 16.50 54.77 5156.52 2059.10 N 2341.26 E 1.50 3257.82 All data is in feet unless otherwise stated Coordinates from SE Corner of Sec. 7, T5N, Rl1~, SM and TVD from wellhead. Vertical section is from wellhead on azimuth 54.77 degrees. Declination is 0.00 degrees, Convergence is -1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ HARATHON Oil Company Pad #1,CLU-5 Cannery Loop Unit,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : CLU#5 Version Last revised : 4-Hat-96 Heasured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 6458.35 15.00 54.77 5252.76 2074.76 N 2363.44 E 1.50 3284.96 6558.35 13.50 54.77 5349.68 2088.96 N 2383.55 E 1.50 3309.57 6658.35 12.00 54.77 5447.21 2101.69 N 2401.57 E 1.50 3331.64 6758.35 10.50 54.77 5545.29 2112.94 N 2417.51 E 1.50 3351.15 6858.35 9.00 54.77 5643.84 2122.71 N 2431.34 E 1.50 3368.09 6958.35 7.50 54.7-/ 5742.80 2130.98 N 2443.06 E 1.50 3382.44 7058.35 6.00 54.77 5842.11 2137.76 N 2452.67 E 1.50 3394.19 7158.35 4.50 54.77 5941.68 2143.04 N 2460.14 E 1.50 3403.34 7258.35 3.00 54.77 6041.47 2146.81 N 2465.48 E 1.50 3409.88 7358.35 1.50 54.77 6141.39 2149.08 N 2468.69 E 1.50 3413.80 7458.07 0.00 54.77 6241.10 2149.83 N 2469.76 E 1.50 7500.00 0.00 54.77 6283.03 2149.83 N 2469.76 E 0.00 8000.00 0.00 54.77 6783.03 2149.86 N 2469.79 E 0.00 8500.00 0.00 54.77 7283.03 2149.88 N 2469.82 E 0.00 9000.00 0.00 54.77 ~783.03 2149.90 N 2469.85 E 0.00 3415.11 End Angte Drop 3415.12 3415.15 3415.19 3415.23 9500.00 0.00 54.77 8283.03 2149.92 N 2469.88 E 0.00 3415.26 10000.00 0.00 54.77 8783.03 2149.94 N 2469.91 E 0.00 3415.30 10500.00 0.00 54.77' 9283.03 2149.96 N 2469.94 E 0.00 3415.34 11000.00 0.00 54.7-/ 9783.03 2149.98 N 2469.97 E 0.00 3415.37 11466.97 0.00 54.77 10250.00 2150.00 N 2470.00 E 0.00 3415.41 TD All data is in feet unless otherwise stated Coordinates from SE Corner of Sec. 7, T5N, R11W, SM and TVD from wellhead. Vertical section is from wellhead on azimuth 54.77 degrees. Declination is 0.00 degrees, Convergence is -1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ MARATHON Oil Company PROPOSAL L[STZNG Page 3 Pad #1,CLU-5 Your ref : CLU#5 Version Cannery Loop Unit,Cook Intel, Alaska Last revised : 4-Mar-g6 Comments in wet[path ND TVD Rectangular Coords. Comment 500.00 500.00 180.00 N 320.00 W KOP 2472.64 2237.93 640.18 N 331.72 E EOC 4170.62 3344.82 1382.87 N 1383.55 E Begin Angle Drop 5087.68 4020.00 1738.95 N 1887.85 E TARGET #1 7458.07 6241.10 2149.83 N 2469.76 E End Angle Drop 11466.97 10250.00 2150.00 N 2470.00 E TD Targets associated with this wetlpath Target name Position T.V.D. Local rectangular coords. Date revised CLU#5 Tgt#1 1-Mar-96 not specified 4020.00 1750.00N 1880.00E 1-Nar-96 CLU#5 Tgt#2 1-Mar-96 not specified 10250.00 2150.00N 2470.00E 1-Mar-96 f E =ivED 0 ] 'i 96 Oil & ~ Corm t;emmi~ Alt data is in feet unless otherwise stated Coordinates from SE Corner of Sec. 7, T5N, R11W, SM and TVD from wellhead. Bottom hole distance is 3415.41 on azimuth 54.77 degrees from wellhead. Total Dogleg for weLlpath is 98.63 degrees. Vertical section is from wellhead on azimuth 54.77 degrees. Declination is 0.00 degrees, Convergence is -1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ! I I'-3000PSI i ! BALL VALVES i : I : ........ -rim · I · , J ' I '~ I LINE I0' LINE I I I : I i I ! · I I : I I I · I · I · · I i ' CLOSE CLOSE FABRI-VALVE FIG. 36 KNIFE VALVE I0' UNE ANSI JO0 FLANGES TiP 3 PLC$ OPE]V CLOSE I i HYDRIL MSP 2000PSI ANNULAR PAA RIG 122 D 21 1/4" - 2M DIVERTER STACK I. DIVERTER ANNULAR NORMALLY OPEN· 2. VALVE "A" NORMALLY CLOSED. 5. VALVE "B''NORMALLY OPEN. 4. VALVE 'C'"NORMALLY CLOSED. 5. SYSTEM DESIGNED SO THAT WHEN THE ANNULAR IS CLOSED, VALVE "A" AUTO- MATICALL Y OPENS. 6. WHEN VALVE 'C' IS OPENED, VALVE 'B' AUTOMATICALLY CLOSES. 7. USING BALL VALVES "D" & "E", VALVE "B' CAN BE ISOLATED TO REMAIN OPEN WHEN OPENING VALVE 'C". ~OP ~TACK CONF'ISURATION 5/8 P, SP,,F~A CHOKE WING MeEVOY 4 TYPE E GA~ VALVE. j ' 5/8"-5,000 PSI ~UB -~ Jla'-5.000 P~l FLG. '! HYgffit 13 518"-5000PS1 CX 4teVuukq 80P SCREW HF. AO 1.1 5/8'-5.~ HUB 80TTOu HYOffiL 1.1 5/8'-5,000PS1 ~RAUSOP HU8~ '* ~ /~6"-5,000~ Sg~F. OUTLETS wrrH laAI~ALL~ Kill WING ~rvo~ 3 ~ E GATE VALVE ~ 13 5/8"-5.000PSl ~ ~ 8Go HUB COtVNECTIOt,'S ~ 1/16'-5.O(X)PSq SIDE OUT1.EfS BLOW-OUT PREVENTER STACK Rig 722 D ,:HOKE MANIFOLD I)AA RIO 122 SCHEMATIC 1. McEVOY TYPE C 5. 1/§"-5000 PSI GAlE VALVE 2. McEVO¥ IYPE C 2 I/! 6'-5000 PSI GATE VALVE 3. 'SWACO 2 1/16-5000 PSI REMOTE CHOKE 4. THORNtilLL-CRAVER ,] I/8"-5000 PSI MANUAl. CHOKE 5. FLANGED lEE 2 1/16" X 2 1/1~' X 2 1/16"-5000 PSI 6. 5 WAY FLOW BLOCK 3 1/8" X 3 1/8" X 2 1/16" X 2 i/16" X 2 1/16"-5000 PSI 7. 5 WAY FLOW BLOCK 3 1/8" X 3 1/6" X ,t I/8" X 3 i/§" X 2 1/16"-5000 PSI 8. 4 WAY FLOW BLOCK 2 1/16" X 2 1/16" X 2 1/16" X 2 1/16"-5000 PSI 9. 2 1/16"-5000 PSI SENSOR BLOCK 10. 2 1/16"-IO,O00PSI X 2 1/16"-5000 PSi SPOOL 11. 3 1/~' X 2 1/16"-5000 PSI SPOOL 12. 2 1/16' X 2 1/16"-5000 PSI SPOOL 1,1. .1 I/8"-5000 PSI X 2 1/16"-5000 PSI SPOOL .... 14. 2 1/16"-10,000 PSi X 2 1/16"-5000 PSI DOUBLE SilII) AUAI'IuR 15. 2 1/16"-5000 PSi IARGET FLANGE 15. ~t I/8"-5000 PSI IARGET fLANGE 17. ,1 I/8"-5000 PSi × 2 1/16"-5000 PSI DOUBLE SIUD ADAi.'IUt~ 18. ,1 I/8" X 5 I/8 5000 PSI SPOOL 19. ,1 WAY FLOW BLOCK ,~ 1/8" X 3 1/6~ X 3 I/§"-5000 PSI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF UNION ) OIL COMPANY OF CALIFORNIA ) requesting issuance of an ) order establishing pool ) rules to govern operation ) of the Cannery Loop Unit. ) Conservation Order No. 231 Kenai Gas Field Beluga Gas Pool, Upper Tyonek Gas Pool, and Tyonek "D" Gas Pool August 3, 1987 IT APPEARING THAT: · Union Oil Company of California as operator of the Cannery Loop Unit, requested the Alaska Oil and Gas Conservation Commission by letter dated April 30, 1987 to issue an order establishing pool rules to govern the operation of the Beluga Gas Pool, the Upper Tyonek Gas Pool, and the Tyonek "D" gas pool, all lying beneath the Cannery Loop Unit. · Notice of Public Hearing was published in the Anchorage Daily News on June 2, 1987. · A public hearing was held on July 8, 1987 in the conference room of the Commission at 3001 Porcupine Drive, Anchorage, Alaska. · Members of the staff of Union Oil Company of California presented testimony including exhibits. The hearing record was closed at the end of the public hearing. FINDINGS: · The Kenai Gas Field was extended to the north beneath the Cannery Loop Unit by the drilling of Cannery Loop Unit #1 (CLU #1) in 1979, and subsequently confirmed by the drilling of Cannery Loop Unit #3 (CLU #3) in 1981. · Wells CLU #1 and CLU #3 established the presence of dry gas bearing reservoir strata within three separate and distinct lithologic units. oonservation Order No. 231 August 3, 1987 Page 3 CONCLUSIONS: · The area overlying the three gas pools north of the Cannery Loop Fault may be logically considered a northerly extension of the Kenai Gas Field, and may be appropriately defined as the Cannery Loop Extension of the Kenai Gas Field. · The Cannery Loop Fault is a sealing fault and establishes the southern boundary of at least the shallowest gas pool encountered. ~ Gas pools encountered north of the Cannery Loop Fault are not pressure connected with the developed gas pools south of the Cannery Loop Fault. 1 Rules set forth for the area affected by Conservation Order No. 82 do not appropriately apply for governing the drilling, development, and production of the three gas pools found north of the Cannery Loop Fault trace. NOW, THEREFORE, IT IS ORDERED THAT those portions of Sections 17, 19 and 20, T5N, RllW, SM, lying to the north of the Cannery Loop Fault trace as depicted on Exhibit "C" of the July 8, 1987 Public Hearing Record, Structure Contours Top Beluga Formation, are excluded from the area described by Conservation Order No. 82 as the affected area. IT IS FURTHER ORDERED THAT the rules hereinafter set forth apply to an affected area which is described as follows: T6N, RllW, SM Sections 32, 33 and 34. T5N, RllW, SM Sections 3, 4, 5, 6, 7, 8, 9, 10 and 18. T5N, RllW, SM Those portions of Sections 16, 17, 19 and 20 lying to the north of the Cannery Loop Fault trace as depicted on Exhibit "C" of the July 8, 1987 Public Hearing Record, Structure Contours Top Beluga Formation. onservation Order No. 231 August 3, 1987 Page 5 Rule 6 Administrative Approval Upon request the Commission may administratively amend this Order so long as the operator demonstrates to the Commission's satis- faction that sound engineering practices are maintained and the amendment will not result in physical waste or the impairment of correlative rights. DONE at Anchorage, Alaska, and dated August 3, 1987. ACiasV~aCohil ~n on, ..... an ion Commission LonnW'e C. Sm±th, 'L',a~±ss'ioner Alaska 0±1 and Gas Conservat±on Comm±ss±on Id. Id. Barnwel'l, 'Comm±ss±oh'er Alaska 0±1 and Gas Conservat±on Comm±ss±on PERMIT CHECKLIST WELL NAME C L ~ ~"~'"" PROGRAM~ exp [] der ~ redrll [] serv [] wellbore seg [] GEOL ~ ~?"U UN=~ /0 3 2 0 O~OF~' SHOE ADMINISTRATION 1. Permit fee attached .................. ~_~ N 2. Lease number appropriate ................ N.~ 3. Unique well name and number .............. ~N 4. Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ N Operator only affected party .............. N 5o 6. 7. 8. 9. 10. 11. 12. 13. ENGINEERING Operator has appropriate bond in force ......... Y~N Permit can be issued without conservation order .... ~ N Permit can be issued without administrative approval. N Can permit be approved before 15-day wait ....... N REMARKS 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~d~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 2 31. Data presented on potential overpressure zones ..... Y/ ~) ~ 32. Seismic analysis of shallow gas zones .......... /~ N /I/6/ ~ 33. Seabed condition survey (if off-shore) ....... ~ Y N ' 34. Contact name/phone for weekly progress reports . .//.. Y N [exploratory only] GEOLOGY: ENGINEERING: BEW COMMI SS ION: DWJ JDN ~ ~ ':~ ~.,:.~- Comments/Instructions: Z Z O m "'i~t rev 11/95 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS Tape ~_ification Listing Schlumberger Alaska Computing Center 15-NOV-1996 O1:51 PAGE: **** REEL HEADER **** SERVICE NAME : SNAM DATE : ORIGIN : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** TAPE HEADER **** SERVICE NAME : FSNAM DA TE : ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY **** FILE HEADER **** FILE NAME : DSSTA . 023 SERVICE : DEPTH- VERSION : 7C0-427 DATE : 96/11/13 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 316 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .1 IN 11 66 25 12 68 -999. 13 66 1 14 65 . liN 15 66 73 16 66 1 0 66 LIS Tape ~ification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01:51 PAGE: 2 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS IN 60 282 O1 0 33 1 1 4 68 0000000000 CS F/HR 60 636 21 0 33 1 1 4 68 0000000000 CVEL F/~IN 60 636 O0 0 33 1 1 4 68 0000000000 TENS LBF 60 635 21 0 33 1 1 4 68 0000000000 ETIM S 60 636 21 0 33 1 1 4 68 0000000000 MARK F 60 150 O1 0 33 1 1 4 68 0000000000 STIA F 60 000 O0 0 33 1 1 4 68 0000000000 STIT F 60 000 O0 0 33 1 1 4 68 0000000000 ITT S 60 529 82 0 33 1 1 4 68 0000000000 SVEL FT/S 60 890 41 0 33 1 1 4 68 0000000000 SSVE FT/S 60 890 41 0 33 1 1 4 68 0000000000 DTD2 F 60 000 O0 0 33 1 1 4 68 0000000000 DTD4 F 60 000 O0 0 33 1 1 4 68 0000000000 SArR2 DB 60 000 O0 0 33 1 1 4 68 0000000000 DTCO US/F 60 520 80 0 33 1 1 4 68 0000000000 DTSM US/F 60 520 80 0 33 1 1 4 68 0000000000 PR 60 000 O0 0 33 1 1 4 68 0000000000 VPVS 60 000 O0 0 33 1 1 4 68 0000000000 CHR2 60 000 O0 0 33 1 1 4 68 0000000000 ENR2 DB 60 000 O0 0 33 1 1 4 68 0000000000 TER2 US 60 000 O0 0 33 1 1 4 68 0000000000 CER2 60 000 O0 0 33 1 1 4 68 0000000000 LFR2 60 000 O0 0 33 1 1 4 68 0000000000 EER2 DB 60 000 O0 0 33 1 1 4 68 0000000000 DT2R US/F 60 520 80 0 33 1 1 4 68 0000000000 TTR2 US 60 000 O0 0 33 1 1 4 68 0000000000 DTRP US/F 60 520 80 0 33 1 1 4 68 0000000000 TTRP US 60 000 O0 0 33 1 1 4 68 0000000000 CHRP 60 000 O0 0 33 1 1 4 68 0000000000 ENRP DB 60 000 O0 0 33 1 1 4 68 0000000000 TERP US 60 000 O0 0 33 1 1 4 68 0000000000 CERP 60 000 O0 0 33 1 1 4 68 0000000000 EERP DB 60 000 O0 0 33 1 1 4 68 0000000000 L?RP 60 000 O0 0 33 1 1 4 68 0000000000 DTRS US/F 60 520 80 0 33 1 1 4 68 0000000000 TTRS US 60 000 O0 0 33 1 1 4 68 0000000000 CHRS 60 000 O0 0 33 1 1 4 68 0000000000 ENRS DB 60 000 O0 0 33 1 1 4 68 0000000000 TERS US 60 000 O0 0 33 1 1 4 68 0000000000 CERS 60 000 O0 0 33 1 1 4 68 0000000000 EERS DB 60 000 O0 0 33 1 1 4 68 0000000000 LFRS 60 000 O0 0 33 1 1 4 68 0000000000 DT2 US/F 60 520 80 0 33 1 1 4 68 0000000000 DT4P US/F 60 520 80 0 33 1 1 4 68 0000000000 DT4S US/F 60 520 80 0 33 1 1 4 68 0000000000 CGR GAPI 60 310 O1 0 33 1 1 4 68 0000000000 POTA 60 719 50 0 33 1 1 4 68 0000000000 SGR GAPI 60 310 O1 0 33 1 1 4 68 0000000000 THOR PPM 60 790 50 0 33 1 1 4 68 0000000000 TPRA 60 000 O0 0 33 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 3 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TURA 60 000 O0 0 33 1 1 4 68 0000000000 URAN PPM 60 792 50 0 33 1 1 4 68 0000000000 UPRA 60 000 O0 0 33 1 1 4 68 0000000000 WiNG CPS 60 310 02 0 33 1 1 4 68 0000020000 W2NG CPS 60 310 02 0 33 1 1 4 68 0000020000 W3NG CPS 60 310 02 0 33 1 1 4 68 0000020000 W4NG CPS 60 310 02 0 33 1 1 4 68 0000020000 WSNG CPS 60 310 02 0 33 1 1 4 68 0000020000 RSGR GAPI 60 310 O1 0 33 1 1 4 68 0000000000 HV V 60 000 O0 0 33 1 1 4 68 0000000000 HTEN LBF 60 000 O0 0 33 1 1 4 68 0000000000 FIRES OtlM~I 60 000 O0 0 33 1 1 4 68 0000000000 TIME MS 60 636 21 0 33 1 1 4 68 0000000000 PSCS 60 000 O0 0 33 1 1 4 73 0000000000 PSRS 60 000 O0 0 33 1 1 4 73 0000000000 PSXS 60 000 O0 0 33 1 1 4 73 0000000000 PSHS 60 000 O0 0 33 1 1 4 73 0000000000 TACT 60 000 O0 0 33 1 1 4 73 0000000000 ETYP 60 000 O0 0 33 1 1 4 73 0000000000 NPR2 60 000 O0 0 33 1 1 4 73 0000000000 NPR4 60 000 O0 0 33 1 1 4 73 0000000000 SAS2 60 000 O0 0 33 1 1 4 73 0000000000 SAS4 60 000 O0 0 33 1 1 4 73 0000000000 SPHI PU 60 890 O1 0 33 1 1 4 68 0000000000 CTE~I DEGF 60 000 O0 0 33 1 1 4 68 0000000000 RMTE DEGF 60 000 O0 0 33 1 1 4 68 0000000000 MTE~ DEGF 60 000 O0 0 33 1 1 4 68 0000000000 DTEM DFHF 60 000 O0 0 33 1 1 4 68 0000000000 AMTE DEGF 60 000 O0 0 33 1 1 4 68 0000000000 ** DATA ** ** DEPTH = 10431.500 FEET ** BS. 8. 500 CS. ETIM. O. 000 MARK. ITT. O. 000 SVEL. DTD4 . 1 . 685 SNR2. PR. O. 326 VPVS. TER2. 3400. 000 CER2. DT2R. 165. 761 TTR2. CHRP. O. 956 ENRP. EERP. 31 . 195 LFRP. CHRS. O . 672 ENRS. EERS. 26. 873 LFRS. DT4S. 157. 144 CGR . THOR. -3. 995 TPRA. UPRA. 74.388 WING. W4NG. O. 000 WSNG. 2990. 033 CVEL. 71. 000 STIA. 12061 . 977 SSVE. 32. 951 DTCO. 1. 968 CHR2. O. 951 LFR2. 2800. 000 DTRP. 26. 663 TERP. O. 000 DTRS. 26. 873 TERS. O. 000 DT2. -17. 604 POTA. -39. 946 TURA . 150. 376 W2NG. O. 000 RSGR. -49.834 TENS. 0 000 STIT. 6127 760 DTD2. 82 905 DTSM. 0 987 ENR2. 0 000 EER2. 82 905 TTRP. 1200 000 CERP. 157 144 TTRS. 2000 000 CERS. 163 192 DT4P. -0 002 SGR. -0 537 URAN. 30 075 W3NG. 35 989 HV. 7455.000 0.000 1.051 163.192 32.051 35.943 1000.000 0.866 2000.000 0.670 82.905 36.630 7.439 15.038 250.620 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: HTEN. 1017.927 ~/fl~ES. PSRS. 0 PSXS. ETYP. 0 NPR2. SAS4. 255 SPHI. MTEM. 153.194 DTEM. ** DEPTH = BS. 8. 500 ETIM. 35. 054 ITT. O. 003 DTD4. 4.817 PR. O. 324 TER2. 3 600. 000 DT2R. 164. 453 CHRP. O. 940 EERP. 29. 419 CHRS . O . 764 EERS. 27. 402 DT4S. 164.517 THOR. -3. 996 UPRA. 74. 406 W4NG. O. 000 HTEN. 1026. 447 PSRS. 0 ETYP. 0 SAS4. 255 MTEM. 153.194 ** DEPTH = 0.057 TIME. 0 PSHS. 3 NPR4. 20.283 CTEM. 0.000 AMTE. 10400.000 FEET ** CS. MARK. SVEL . SNR2 . VPVS. CER2. TTR2. ENRP. LFRP. ENRS. LFRS . CGR. TPRA . WING. WSNG. MRE$. PSXS. NPR2. SPHI. D T EM . 3406.143 71 000 12075 068 24 644 1 959 0 917 3000 000 24 664 0 000 26 614 O. 000 -17. 615 -39. 957 150. 376 O. 000 O. 057 0 3 20. 237 O. 000 10233.000 FEET ** BS. 8.500 CS. 3570.006 ETIM. 205.169 MARK. 59.000 ITT. 0.016 SVEL. 11987.766 DTD4. -999.250 SN-R2. 21.113 PR. 0.319 VPVS. 1.940 TER2. 3600.000 CER2. 0.933 DT2R. 164.049 TTR2. 3000.000 CHRP. 0.973 ENRP. 33.031 EERP. 34.271 LFRP. 0.000 CHRS. 0.385 ENRS. 20.404 EERS. 21.070 LFRS. 0.000 DT4S. 161.996 CGR. 60.543 THOR. 5.444 TPRA. 2.117 UPRA. 0.581 W1NG. 233.405 W4NG. 4.283 WSNG. 10.707 HTEN. 1077.624 ~L~ES. 0.057 PSRS. 0 PSXS. 0 ETYP. 0 NPR2. 2 SAS4. 255 SPHI. 20.543 MTEM. 152.984 DTEM. 0.000 CVEL. STIA. SSVE. DTCO. CHR2. LFR2 . DTRP. TERP. DTRS . TERS. DT2 . POTA . TURA . W2NG. RSGR. TIME. PSHS. NPR4. CTEM. AMTE. CVEL. STIA. SSVE. DTCO. CHR2. LFR2 . DTRP. TERP. DTRS. TERS. DT2 . POTA . TURA. W2NG . RSGR . TIME. PSHS. NPR4. AMTE. 0.000 0 3 184. 100 153.194 -56.769 0.000 6163.986 82.815 0.981 0.000 82.815 1200.000 164.517 2000.000 162. 233 -0. 002 -0. 537 30. 075 35.989 526.000 0 4 184.100 153.194 -59.500 0.000 6179.165 83.418 0 979 0 000 83 777 1250 000 161 996 2050 000 161 834 O. 026 3. 644 109.208 72.930 501.000 0 2 179.600 152.984 PSCS. TACT. SAS2. RMTE. TENS. STIT. DTD2 . DTSM. ENR2. EER2 . TTRP. CERP. TTRS . CERS. DT4P. SGR. URAN. W3NG. HV. PSCS. TACT. SAS2. RMTE. TENS. STIT. DTD2 . DTSM. ENR2. EER2. TTRP. CERP. TTRS . CERS. DT4 P. SGR. URAN. W3NG. HV. PSCS. TACT. SAS2. RMTE. 0 2 255 153. 194 7495.000 0.000 4.051 162.233 35.117 38.051 1000.000 0.834 2250.000 0.742 82.815 36.633 7.441 15.038 249.450 0 0 255 153.194 7515.000 0.000 -999.250 161.834 30.118 33.145 1050.000 0.941 2150.000 0.339 83.777 71.434 1.494 38.544 254.130 0 2 255 152.984 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.51 PAGE: * * * * FILE TRAILER * * * FILE NA~E : DSSTA .023 SERVICE : DEPTH- VERSION · 7C0-427 DATE : 96/11/13 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : DSSTA .031 SERVICE : DEPTH- VERSION : 7C0-427 DATE : 96/11/13 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 316 4 66 1 $ 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 25 12 68 -999. 13 66 1 14 65 .liN 15 66 73 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS IN 60 282 O1 0 45 1 1 4 68 0000000000 CS F/HR 60 636 21 0 45 1 1 4 68 0000000000 CVEL F/~N 60 636 O0 0 45 1 1 4 68 0000000000 TENS LBF 60 635 21 0 45 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 Ok. ~1 PAGE: 6 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ETIM S 60 636 21 0 45 1 1 4 68 0000000000 MARK F 60 150 O1 0 45 1 1 4 68 0000000000 ITT S 60 529 82 0 45 1 1 4 68 0000000000 SVEL FT/S 60 890 41 0 45 1 1 4 68 0000000000 SSVE FT/S 60 890 41 0 45 1 1 4 68 0000000000 DTD2 F 60 000 O0 0 45 1 1 4 68 0000000000 DTD4 F 60 000 O0 0 45 1 1 4 68 0000000000 SNR2 DB 60 000 O0 0 45 1 1 4 68 0000000000 DTCO US/F 60 520 80 0 45 1 1 4 68 0000000000 DTSM US/F 60 520 80 0 45 1 1 4 68 0000000000 PR 60 000 O0 0 45 1 1 4 68 0000000000 VPVS 60 000 O0 0 45 1 1 4 68 0000000000 CHR2 60 000 O0 0 45 1 1 4 68 0000000000 ENR2 DB 60 000 O0 0 45 1 1 4 68 0000000000 TER2 US 60 000 O0 0 45 1 1 4 68 0000000000 CER2 60 000 O0 0 45 1 1 4 68 0000000000 LFR2 60 000 O0 0 45 1 1 4 68 0000000000 EER2 DB 60 000 O0 0 45 1 1 4 68 0000000000 DT2R US/F 60 520 80 0 45 1 1 4 68 0000000000 TTR2 US 60 000 O0 0 45 1 1 4 68 0000000000 DTRP US/F 60 520 80 0 45 1 1 4 68 0000000000 TTRP US 60 000 O0 0 45 1 1 4 68 0000000000 CHRP 60 000 O0 0 45 1 1 4 68 0000000000 ENRP DB 60 000 O0 0 45 1 1 4 68 0000000000 TERP US 60 000 O0 0 45 1 1 4 68 0000000000 CERP 60 000 O0 0 45 1 1 4 68 0000000000 EERP DB 60 000 O0 0 45 1 1 4 68 0000000000 LFRP 60 000 O0 0 45 1 1 4 68 0000000000 DTRS US/F 60 520 80 0 45 1 1 4 68 0000000000 TTRS US 60 000 00 0 45 1 1 4 68 0000000000 CHRS 60 000 O0 0 45 1 1 4 68 0000000000 ENRS DB 60 000 O0 0 45 1 1 4 68 0000000000 TERS US 60 000 O0 0 45 1 1 4 68 0000000000 CERS 60 000 O0 0 45 1 1 4 68 0000000000 EERS DB 60 000 O0 0 45 1 1 4 68 0000000000 LFRS 60 000 O0 0 45 1 1 4 68 0000000000 DT2 US/F 60 520 80 0 45 1 1 4 68 0000000000 DT4P US/F 60 520 80 0 45 1 1 4 68 0000000000 DT4S US/F 60 520 80 0 45 1 1 4 68 0000000000 CGR GAPI 60 310 O1 0 45 1 1 4 68 0000000000 POTA 60 719 50 0 45 1 1 4 68 0000000000 SGR GAPI 60 310 O1 0 45 1 1 4 68 0000000000 THOR PPM 60 790 50 0 45 1 1 4 68 0000000000 TPRA 60 000 O0 0 45 1 1 4 68 0000000000 TURA 60 000 O0 0 45 1 1 4 68 0000000000 ~ PPM 60 792 50 0 45 1 1 4 68 0000000000 UPRA 60 000 O0 0 45 1 1 4 68 0000000000 WiNG CPS 60 310 02 0 45 1 1 4 68 0000020000 W2NG CPS 60 310 02 0 45 1 1 4 68 0000020000 W3NG CPS 60 310 02 0 45 1 1 4 68 0000020000 W4NG CPS 60 310 02 0 45 1 1 4 68 0000020000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 7 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) WSNG CPS 60 310 02 0 45 1 1 4 68 0000020000 RSGR GAPI 60 310 O1 0 45 1 1 4 68 0000000000 HV V 60 000 O0 0 45 1 1 4 68 0000000000 HTEN LBF 60 000 O0 0 45 1 1 4 68 0000000000 FIRES OH~M 60 000 O0 0 45 1 1 4 68 0000000000 STIA F 60 000 O0 0 45 1 1 4 68 0000000000 TIME MS 60 636 21 0 45 1 1 4 68 0000000000 PSCS 60 000 O0 0 45 1 1 4 73 0000000000 PSRS 60 000 O0 0 45 1 1 4 73 0000000000 PSXS 60 000 O0 0 45 1 1 4 73 0000000000 PSHS 60 000 O0 0 45 1 1 4 73 0000000000 TACT 60 000 O0 0 45 1 1 4 73 0000000000 ETYP 60 000 O0 0 45 1 1 4 73 0000000000 NPR2 60 000 O0 0 45 1 1 4 73 0000000000 NPR4 60 000 O0 0 45 1 1 4 73 0000000000 SAS2 60 000 O0 0 45 1 1 4 73 0000000000 SAS4 60 000 O0 0 45 1 1 4 73 0000000000 SPHI PU 60 890 O1 0 45 1 1 4 68 0000000000 CTEM DEGF 60 000 O0 0 45 1 1 4 68 0000000000 RMTE DEGF 60 000 O0 0 45 1 1 4 68 0000000000 MTE~ DEGF 60 000 O0 0 45 1 1 4 68 0000000000 AMTE DEGF 60 000 O0 0 45 1 1 4 68 0000000000 DTEM DFHF 60 000 O0 0 45 1 1 4 68 0000000000 STIT F 60 000 O0 0 45 1 1 4 68 0000000000 ** DATA ** ** DEPTH = 11422.500 FEET ** BS. 8.500 CS. ETIM. 0.000 MARK. SSVE. 4199.681 DTD2. DTCO. 105.058 DTSM. CHR2. 0.749 EiFR2. LFR2. 0.000 EER2. DTRP. 105.058 TTRP. TERP. 1000.000 CERP. DTRS. 172.746 TTRS. TERS. 2600. 000 CERS. DT2. 238.113 DT4P. POTA. -0.034 SGR. TURA. 1.743 URAN. W2NG. 105.263 W3NG. RSGR. 66.442 HV. STIA. 3.778 TIME. PSXS. 0 PSHS. NPR2. 5 NPR4. SPHI. 29.185 CTE~. AMTE. 149.302 DTEM. 1500.000 CVEL. 51.000 ITT. 0.326 DTD4. 238.113 PR. 20.763 TER2. 29.731 DT2R. 800.000 CHRP. 0.533 EERP. 2850.000 CHRS. O. 380 EERS. 105. 058 DT4S. 67. 628 THOR. 8. 640 UPRA . 15.038 W4NG. 249.450 HTEN. 0.000 PSCS. 0 TACT. 2 SAS2. 175.100 RMTE. 0.000 STIT. -25 000 TENS. 0 000 SVEL. -0 324 SNR2. 0 379 VPVS. 3200 000 CER2. 245 275 TTR2. 0 565 ENRP. 19 139 LFRP. 0 535 ENRS. 23.416 LFRS. 172.746 CGR. 15.064 TPRA. 86.404 WING. 45.113 W5NG. -162.379 MRES. 0 PSRS. 2 ETYP. 255 SAS4. 149. 302 MTEM. 3.778 2125.000 9518.525 39.477 2.266 0.556 2600.000 -6.707 0.000 22.204 0.000 4.633 150.640 180.451 15. 038 O. 062 0 0 255 149.302 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: ** DEPTH = 11400.000 FEET BS. 8.500 CS. ETIM. 42.159 MARK. SSVE. 4199.681 DTD2. DTCO. 105.058 DTSM. CHR2. 0.749 ENR2. LFR2. 0.000 EER2. DTRP. 105.058 TTRP. TERP. i000.000 CERP. DTRS. 172.746 TTRS. TERS. 2600.000 CERS. DT2. 238.113 DT4P. POTA. -0.034 SGR. TURA. 1.742 URAN. W2NG. 105.263 W3NG. RSGR. 66.442 HV. STIA. 17.508 TIME. PSXS. 0 PSHS. NPR2. 5 NPR4. SPHI. 29.185 CTEM. AMTE. 149.302 DTE~. BS. ETIM. SSVE. DTCO . CHR2. LFR2 . DTRP. TERP. DTRS . TERS . DT2 . POTA . TURA . W2NG. RSGR. STIA . PSXS. NPR2 . SPHI. AMTE. ** DEPTH = 11250.500 FEET 8.500 306.656 6511.987 79.074 0.971 0 000 79 599 1100 000 148 788 2050 000 153 563 0 025 3 160 109 510 77 672 0.000 0 3 18.238 150.451 CS. MARK. DTD2 . DTSM. ENR2. EER2. TTRP . CERP. TTRS . CERS. DT4P. SGR. URAN . W3NG. HV. TI~E. PSHS. NPR4 . CTE~. DTE~. 2012. 825 51. 000 2. 584 238.113 20. 763 29. 731 800. 000 O. 533 2850. 000 0.380 105. 058 67. 629 8. 646 15. 038 251. 790 884. 000 0 2 175.100 O. 000 2036.217 52. 000 2. 601 153. 563 36.101 39. 056 900. 000 O. 654 1950. 000 O. 775 79.599 68.402 1.504 50. 720 251. 790 883.500 0 4 175.100 O. 000 CVEL. ITT. DTD4 . PR. TER2. DT2R CHRP EERP CHRS EERS DT4S THOR UPRA W4NG H TEN . PSCS . TACT. SAS2. RMTE. STIT. CVEL. ITT. DTD4 . PR. TER2. DT2R . CHRP. EERP. CHRS. EERS. DT4S. THOR. W4 NG . HTEN. PSCS. TACT. SAS2. RMTE. STIT. -33 547 0 002 3 034 0 379 3200 000 245 275 0 565 19 139 0 535 23 416 172. 746 15. 059 86. 459 45. 113 970.260 0 0 255 149. 302 17. 508 -33. 937 O. 014 3. 051 O. 320 3400. 000 155. 664 O. 915 29. 648 O. 817 33. 292 148. 788 4. 754 O. 593 4. 611 980. 885 0 2 255 150. 440 O. 000 TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS. LFRS. CGR. TPRA. WI NG. WSNG. MRES. PSRS. ETYP . SAS4. MTEM. TENS. SVEL . SNR2 . VPVS. CER2. TTR2 . ENRP. LFRP. ENRS. LFRS . CGR TPRA WiNG WSNG MRES PSRS ETYP. SAS4. MTEM. 7965.000 9518.525 39.477 2.266 0.556 2600.000 -6.707 0.000 22.204 0.000 4.594 150.590 180.451 15. 038 O. 062 0 0 255 149.302 8215.000 12646.352 39.216 1.942 0.963 2800.000 17.837 0.000 33.100 0.000 57.433 1.872 254.755 2. 305 O. 063 0 0 255 150.440 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i~1 PAGE: * * * * FILE TRAILER * * * * FILE NAME : DSSTA .031 SERVICE : DEPTH- VERSION : 7C0-427 DATE : 96/11/13 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : DSSTA .035 SERVICE : PLAYBA VERSION : 7C0-427 DATE : 96/11/14 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 316 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 25 12 68 -999. 13 66 1 14 65 .liN 15 66 73 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BS IN 60 282 O1 0 51 1 1 4 68 0000000000 CS F/HR 60 636 21 0 51 1 1 4 68 0000000000 CVEL F/f4N 60 636 O0 0 51 1 1 4 68 0000000000 TENS LBF 60 635 21 0 51 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~1 PAGE: 10 NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ETIM S 60 636 21 0 51 1 1 4 68 0000000000 MARK F 60 150 O1 0 51 1 1 4 68 0000000000 ITT S 60 529 82 0 51 1 1 4 68 0000000000 SVEL FT/S 60 890 41 0 51 1 1 4 68 0000000000 SSVE FT/S 60 890 41 0 51 1 1 4 68 0000000000 DTD2 F 60 000 O0 0 51 1 1 4 68 0000000000 DTD4 F 60 000 O0 0 51 1 1 4 68 0000000000 SNR2 DB 60 000 O0 0 51 1 1 4 68 0000000000 DTCO US/F 60 520 80 0 51 1 1 4 68 0000000000 DTSM US/F 60 520 80 0 51 1 1 4 68 0000000000 PR 60 000 O0 0 51 1 1 4 68 0000000000 VPVS 60 000 O0 0 51 1 1 4 68 0000000000 CHR2 60 000 O0 0 51 1 1 4 68 0000000000 ENR2 DB 60 000 O0 0 51 1 1 4 68 0000000000 TER2 US 60 000 O0 0 51 1 1 4 68 0000000000 CER2 60 000 O0 0 51 1 1 4 68 0000000000 LFR2 60 000 O0 0 51 1 1 4 68 0000000000 EER2 DB 60 000 O0 0 51 1 1 4 68 0000000000 DT2R US/F 60 520 80 0 51 1 1 4 68 0000000000 TTR2 US 60 000 O0 0 51 1 1 4 68 0000000000 DTRP US/F 60 520 80 0 51 1 1 4 68 0000000000 TTRP US 60 000 O0 0 51 1 1 4 68 0000000000 CHRP 60 000 O0 0 51 1 1 4 68 0000000000 ENRP DB 60 000 O0 0 51 1 1 4 68 0000000000 TERP US 60 000 O0 0 51 1 1 4 68 0000000000 CERP 60 000 O0 0 51 1 1 4 68 0000000000 EERP DB 60 000 O0 0 51 1 1 4 68 0000000000 LFRP 60 000 O0 0 51 1 1 4 68 0000000000 DTRS US/F 60 520 80 0 51 1 1 4 68 0000000000 TTRS US 60 000 O0 0 51 1 1 4 68 0000000000 CHRS 60 000 O0 0 51 1 1 4 68 0000000000 ENRS DB 60 000 O0 0 51 1 1 4 68 0000000000 TERS US 60 000 O0 0 51 1 1 4 68 0000000000 CERS 60 000 O0 0 51 1 1 4 68 0000000000 EERS DB 60 000 O0 0 51 1 1 4 68 0000000000 LFRS 60 000 O0 0 51 1 1 4 68 0000000000 DT2 US/F 60 520 80 0 51 1 1 4 68 0000000000 DT4P US/F 60 520 80 0 51 1 1 4 68 0000000000 DT4S US/F 60 520 80 0 51 1 1 4 68 0000000000 CGR GAPI 60 310 O1 0 51 1 1 4 68 0000000000 POTA 60 719 50 0 51 1 1 4 68 0000000000 SGR GAPI 60 310 O1 0 51 1 1 4 68 0000000000 THOR PPM 60 790 50 0 51 1 1 4 68 0000000000 TPRA 60 000 O0 0 51 1 1 4 68 0000000000 TURA 60 000 O0 0 51 1 1 4 68 0000000000 URAN PPM 60 792 50 0 51 1 1 4 68 0000000000 UPRA 60 000 O0 0 51 1 1 4 68 0000000000 WiNG CPS 60 310 02 0 51 1 1 4 68 0000020000 W2NG CPS 60 310 02 0 51 1 1 4 68 0000020000 W3NG CPS 60 310 02 0 51 1 1 4 68 0000020000 W4NG CPS 60 310 02 0 51 1 1 4 68 0000020000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i~31 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) WSNG CPS 60 310 02 0 51 1 1 4 68 0000020000 RSGR GAPI 60 310 O1 0 51 1 1 4 68 0000000000 HV V 60 000 O0 0 51 1 1 4 68 0000000000 HTEN LBF 60 000 O0 0 51 1 1 4 68 0000000000 IV~RES OH~/~4 60 000 O0 0 51 1 1 4 68 0000000000 STIA F 60 000 O0 0 51 1 1 4 68 0000000000 TIME MS 60 636 21 0 51 1 1 4 68 0000000000 PSCS 60 000 O0 0 51 1 1 4 73 0000000000 PSRS 60 000 O0 0 51 1 1 4 73 0000000000 PSXS 60 000 O0 0 51 1 1 4 73 0000000000 PSHS 60 000 O0 0 51 1 1 4 73 0000000000 TACT 60 000 O0 0 51 1 1 4 73 0000000000 ETYP 60 000 O0 0 51 1 1 4 73 0000000000 NPR2 60 000 O0 0 51 1 1 4 73 0000000000 NPR4 60 000 O0 0 51 1 1 4 73 0000000000 SAS2 60 000 O0 0 51 1 1 4 73 0000000000 SAS4 60 000 O0 0 51 1 1 4 73 0000000000 SPHI PU 60 890 O1 0 51 1 1 4 68 0000000000 CTEM DEGF 60 000 O0 0 51 1 1 4 68 0000000000 RMTE DEGF 60 000 O0 0 51 1 1 4 68 0000000000 MTEM DEGF 60 000 O0 0 51 1 1 4 68 0000000000 AMTE DEGF 60 000 O0 0 51 1 1 4 68 0000000000 DTE~ DFHF 60 000 O0 0 51 1 1 4 68 0000000000 STIT F 60 000 O0 0 51 1 1 4 68 0000000000 ** DATA ** ** DEPTH = 11420.500 FEET ** BS. ETIM. SSVE. DTCO. CHR2 . LFR2 . DTRP. TERP. DTRS . TERS . DT2 . POTA. TURA. W2NG. RSGR . STIA . PSXS. NPR2 . SPHI. AMTE. 8. 500 CS. O . 967 MARK. 4471. 566 DTD2. 109. 012 DTSM. O. 831 ENR2. 0 000 EER2. 109 012 TTRP. 1250 000 CERP. 164 032 TTRS. 2350 000 CERS. 223 635 DT4P. 0 033 SGR. -0 835 URAN. 75. 188 W3NG. 49. 832 HV. 2. 731 TIME. 0 PSHS. 5 NPR4. 30. 393 CTE~. 149. 704 DTE~. 1869. 906 CVEL. 52. 000 ITT. O. 492 DTD4. 223. 635 PR. 18. 023 TER2. 26. 514 DT2R. 1050. 000 CHRP. 0 202 EERP. 2600 000 CHRS. 0 196 EERS. 109 012 DT4S. 50 722 THOR. 0 040 UPRA. 45.113 W4NG. 249. 450 HTEN. O. 000 PSCS. 0 TACT. 7 SAS2. 175.100 RMTE . O. 000 STIT. - 31.165 TENS. O. 000 SVEL. O. 834 SNR2. O. 344 VPVS. 3200. 000 CER2. 229. 676 TTR2. O. 459 ENRP. 23. 333 LFRP. O. 331 ENRS. 22. 507 LFRS. 164. 032 CGR. -0. 417 TPRA. O. 149 WING. O. 000 WSNG. -154. 244 MRES. 0 PSRS. 0 ETYP. 255 SAS4. 149. 704 MTE~. 2. 731 2170.000 9173.309 41.154 2.051 0 528 2600 000 20 592 0 000 20 447 0 000 50 431 -0 125 150 376 0 000 0 062 0 0 255 149.704 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01~1 PAGE: 12 ** DEPTH = 11400.000 FEET BS. 8.500 CS. ETIM. 38.570 MARK. SSVE. 4471.566 DTD2. DTCO. 109.012 DTSM. CHR2. 0.831 ENR2. LFR2. 0.000 EER2. DTRP. 109.012 TTRP. TERP. 1250.000 CERP. DTRS. 164.032 TTRS. TERS. 2350.000 CERS. DT2. 223.635 DT4P. POTA. 0.033 SGR. 2~JRA. -0.834 URAN. W2NG. 75.188 W3NG. RSGR. 49.832 HV. STIA. 17.073 TIME. PSXS. 0 PSHS. NPR2. 5 NPR4. SPHI. 30.393 CTE~f. AMTE. 149.704 DTE~I. BS. ETIM. SSVE. DTCO. CHR2. LFR2 . DTRP. TERP. DTRS . TERS. DT2 . POTA . TURA. W2NG. RSGR . STIA. PSXS. NPR2. SPHI. AMTE. BS. ETIM. SSVE. DTCO. CHR2 . LFR2 . ** DEPTH = 11200.000 FEET 8 500 422 518 8067 041 79 705 0 832 0 000 79 705 1400 000 159 803 -999 250 123. 961 O. 028 8. 647 97.430 62.089 0.000 0 1 18.588 148.618 DEPTH = 8.500 800.076 7487.170 78.125 0.939 0.000 CS. MARK. DTD2 . DTSM. ENR2. EER2. TTRP . CERP. TTRS . CERS. DT4P. SGR. URAN . W3NG. HV. TIM. PSHS. NPR 4. CTEM. DTE~. 11000.000 FEET CS. MARK. DTD2 . DTSM. ENR2. EER2. 1941.765 52.000 2.201 223.635 18.023 26.514 1050 000 0 202 2600 000 0 196 109 012 50 722 0 040 45 113 247 110 949 000 0 7 175. 100 O. 000 1890.129 52.000 2.651 123.961 19.210 23.290 1200.000 0.308 -999.250 0.000 79.705 62.620 0.331 44.968 249.450 951.000 0 3 175. 100 0.000 1939.167 53.000 2.385 133.562 28.309 34.480 CVEL. ITT. DTD4 . PR. TER2. DT2R . CHRP . EERP. CHRS EERS DT4S THOR UPRA W4NG HTEN. PSCS. TACT. SAS2. RMTE . STIT. CVEL . ITT. DTD4 . PR. TER2. DT2R . CHRP. EERP . CHRS . EERS. DT4 S. THOR. W4NG . HTEN. PSCS. TACT. SAS2. RMTE. STIT. CVEL. ITT. DTD4 . PR. TER2. DT2R . -32.363 0,002 2.635 0.344 3200.000 229,676 0.459 23.333 0.331 22.507 164.032 -0.417 0.149 0.000 959.811 0 0 255 149.704 17.073 -31.502 O. 020 2. 226 0.148 3800.000 125.137 0.579 27.914 0.000 -999.250 159.803 4.323 0.177 4.283 967. 910 0 2 255 148.664 0.000 -32. 319 O. 036 2. 817 0.240 2800. 000 134. 829 TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS . LFRS. CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP. SAS4. MTEM. TENS. SVEL . SNR2. VPVS. CER2. TTR2 . ENRP. LFRP. ENRS. LFRS. CGR. TPRA . WING. WSNG. MRES. PSRS . ETYP . SAS4. MTEM . TENS. SVEL . SNR2. VPVS. CER2. TTR2 . 8095.000 9173.309 41.154 2.051 0.528 2600.000 20.592 0.000 20.447 0.000 50.431 -0.125 150.376 0.000 O. 062 0 0 255 149.704 8125.000 12546.297 21.176 1.555 0.629 3200.000 22.352 0.000 -999.250 -8.000 60.203 1.532 186.296 4. 283 O. 063 0 0 255 148.664 7765.000 12799.949 32.123 1.710 0.915 2200.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 13 DTRP. 78. 125 TTRP. TERP. 1100. 000 CERP. DTRS. 141 . 505 TTRS. TERS. 1800. 000 CERS. DT2. 133. 562 DT4P. POTA. O. 025 SGR. TURA . 7.271 URAN. W2NG. 86. 724 W3NG. RSGR. 49. 672 HV. STIA. O. 000 TIME. PSXS. 0 PSHS. NPR2. 5 NPR4. SPHI. 17.700 CTEM. AMTE. 149. 878 DTEM. BS. ETIM. SSVE. DTCO. CHR2. LFR2. DTRP . TERP . DTRS. TERS . DT2 . POTA . TURA. W2NG. RSGR . STIA . PSXS. NPR2. SPHI. AMTE. BS. ETIM. SSVE. DTCO. CHR2 . LFR2 . DTRP . TERP . DTRS . TERS. DT2 . POTA . TURA . W2NG. RSGR . ** DEPTH = 8.500 1172.446 3294.882 121.943 0.911 0.000 121.943 1450.000 178.743 2400.000 303 501 0 016 3 388 47 134 35 499 0 000 0 3 33.798 147.569 DEPTH = 8.500 1544.551 6412.479 79.764 0.980 0.000 79.764 1050.000 152.355 1900.000 155.946 0.032 2.352 189.507 113.929 10800.000 FEET CS. MARK. DTD2 . DTSM. ENR2. EER2 . TTRP . CERP . TTRS . CERS . DT4P. SGR . URAN . W3 NG . HV. TIME. PSHS. NPR 4. DTEM. 10600.000 FEET CS. MARK. DTD2 . DTSM. ENR2. EER2. TTRP . CERP . TTRS . CERS . DT4P. SGR . URAN. W3NG. HV. 900. 000 CHRP. O. 840 EERP. 1800. 000 CHRS. O. 662 EERS. 78. 125 DT4S. 50. 826 THOR. - O. 253 UPRA. 36. 403 W4NG. 249. 450 HTEN. 923. 500 PSCS. 0 TACT. 2 SAS2. 179. 600 RMTE. O. 000 STIT. 1929. 219 CVEL. 53. 000 ITT. 2. 651 DTD4 . 303. 501 PR. 26. 678 TER2. 29. 950 DT2R. 1250. 000 CHRP. O . 518 EERP. 2450. 000 CHRS. O . 610 EERS. 121. 943 DT4S. 35.419 THOR. 0.518 UPRA . 33. 208 W4NG. 251 . 790 HTEN. 936. 000 PSCS. 0 TACT. 3 SAS2. 179. 600 RMTE. O. 000 STIT. 193 O. 660 CVEL. 52. 000 ITT. 2. 834 DTD4. 155. 946 PR. 34. 397 TER2. 39.516 DT2R. 850. 000 CHRP. O. 798 EERP. 1750. 000 CHRS. O. 756 EERS. 79. 764 DT4S. 115. 039 THOR. 4. 073 UPRA. 54. 604 W4NG. 254.130 HTEN. 0 865 35 065 0 662 36 130 141 505 3 636 0 200 3 212 952 377 0 0 255 149. 854 O. 000 -32. 154 O. 053 2. 226 O. 404 4400. 000 312. 565 O. 700 27. 664 O. 616 24. 034 178. 743 1. 753 O. 322 2.142 982. 701 0 2 255 147.509 O. 000 -32. 178 0 070 2 401 0 323 3200 000 158 080 0 898 27 310 0 775 30. 610 152. 355 9.579 1.289 12. 848 978.535 ENRP. LFRP. ENRS . LFRS. CGR. TPRA . WING. WSNG. MRES. PSRS. ETYP. SAS4. MTEM. TENS. SVEL. SNR2. VPVS . CER2. TTR2. ENRP. LFRP. ENRS. LFRS. CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP . SAS4. MTEM. TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS . LFRS. CGR. TPRA. WING. WSNG . MRES. 32.566 0.000 36.130 0.000 52.670 1.452 139.186 4. 283 O. 062 0 0 255 149.854 7925.000 8200.551 29.044 2.489 0.824 3800 000 21 536 0 000 23 991 0 000 31 645 1 089 109 266 1 071 0 064 0 0 255 147.509 7560.000 12536.949 38.524 1.955 0.969 2600.000 14.927 0.000 29.735 0.000 85.344 3.030 352.248 9.636 0.063 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 ~_..51 PAGE: 14 STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 2 NPR4. SPHI. 18.621 CTEM. AMTE. 147.049 DTEM. ** DEPTH = 10400.000 FEET BS. 8.500 CS. ETIM. 1919.865 MARK. SSVE. 6358.975 DTD2. DTCO. 80.638 DTSM. CHR2. 0.989 EN-R2. LFR2. 0.000 EER2. DTRP. 80.638 TTRP. TERP. 1100.000 CERP. DTRS. 165.498 TTRS. TERS. 2200.000 CERS. DT2. 157.258 DT4P. POTA. 0.027 SGR. TURA. 3.386 URAN. W2NG. 104.813 W3NG. RSGR. 71.868 HV. STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 5 NPR4. SPHI. 19.096 CTEM. AMTE. 145.135 DTEM. 934. 000 PSCS. 0 TACT. 3 SAS2. 175.100 RMTE. O. 000 STIT. 1924.790 52.000 2.151 157.258 31.868 38.125 900.000 0.761 2200 000 0 746 80 638 73 260 1 576 44 920 247 110 952 000 0 4 175.100 0.000 ** DEPTH = 10200.000 FEET ** BS. 8.500 CS. 1983.978 ETIM. 2284.031 MARK. 53.000 SSVE. 7372.334 DTD2. 2.451 DTCO. 82.759 DTSM. 135.642 CHR2. 0.904 EIVR2. 24.613 LFR2. 0.000 EER2. 30.769 DTRP. 82.759 TTRP. 950.000 TERP. 1150.000 CERP. 0.436 DTRS. 175.332 TTRS. 2500.000 TERS. 2400.000 CERS. 0.310 DT2. 135.642 DT4P. 82.759 POTA. 0.021 SGR. 49.701 TURA. 7.711 URAN. 0.285 W2NG. 79.229 W3NG. 28.908 RSGR. 47.306 HV. 251.790 STIA. 0.000 TIME. 907.000 PSXS. 0 PSHS. 0 NPR2. 3 NPR4. 3 SPHI. 20.209 CTEM. 175.100 AMTE. 144.049 DTEM. 0.000 CVEL . ITT. DTD4 . PR. TER2. DT2R . CHRP. EERP . CHRS . EERS. DT4S. THOR. W4NG. HTEN. PSCS. TACT. SAS2. RMTE. STIT. CVEL. ITT. DTD4 . PR. TER2. DT2R . CHRP. EERP. CHRS. EERS . DT4 S. THOR. UPRA. W4NG. HTEN. PSCS. TACT. SAS2. RMTE. STIT. 0 0 255 147.091 0.000 -32 080 0 088 2 584 0 322 3400 000 159 410 O. 830 26.200 0.747 29.604 165.498 5.337 0.589 6.417 1000.879 0 2 255 145.180 0.000 -33.066 0.106 2.893 0.203 3400.000 137.082 0.559 36.034 0 373 21 234 175 332 3 856 0 235 2 141 1004 788 0 0 255 144.043 0.000 PSRS. ETYP . SAS4. MTEM. TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENR P . LFRP. ENRS . LFRS . CGR. TPRA. WING. W5NG. MRES. PSRS. ETYP. SAS4. MTEM. TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS . LFRS. CGR. TPRA. WING. WSNG . MRES. PSRS. ETYP . SAS4. MTEM. 0 0 255 147. 091 7525.000 12401.084 35.720 1.950 0.953 2800.000 10.679 0 000 29 604 0 000 61 767 1 995 228 877 5 348 0 064 0 0 255 145.180 7315.000 12083.256 28. 797 1. 639 O. 826 2800.000 1.638 0.000 20.141 0.000 47.622 1.813 140.257 6.424 O. 065 0 0 255 144.043 ** DEPTH= 10000.000 FEET ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~51 PAGE: 15 BS. 8.500 CS. ETIM. 1308.773 MARK. SSVE. 3674.197 DTD2. DTCO. 118.960 DTSM. CHR2. 0.637 ENR2. LFR2. 0.000 EER2. DTRP. 118.960 TTRP. TERP. 1400.000 CERP. DTRS. 167.049 TTRS. TERS. 2450.000 CERS. DT2. 272.168 DT4P. POTA. 0.018 SGR. TURA. 2.675 URAN. W2NG. 48.128 W3NG. RSGR. 31.110 HV. STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 6 NPR4. SPHI. 33.078 CTEM. AMTE. 151.504 DTEM. ** DEPTH = BS. 8.500 ETIM. 1696.247 SSVE. 5558.680 DTCO. 87.688 CHR2. 0.977 LFR2. 0.000 DTRP. 87.688 TERP. 1300.000 DTRS. 163.300 TERS. 2200.000 DT2. 179.899 POTA. 0.026 TURA. 4.316 W2NG. 105.882 RSGR. 66.355 STIA. 0.000 PSXS. 0 NPR2. 2 SPHI. 22.586 AMTE. 150.190 ** DEPTH = 9800.000 FEET CS. MARK. DTD2 . DTSM. ENR2. EER2. TTRP. CERP. TTRS . CERS . DT4P. SGR. URAN . W3NG. HV. TIME. PSHS. NPR4. DTEM. 9600.000 FEET BS. 8.500 CS. ETIM. 2082. 490 MARK. SSVE. 3369. 264 DTD2. DTCO. 122. 085 DTSM. CHR2. O. 878 ENR2. LFR2. O. 000 EER2. DTRP. 122. 085 TTRP. TERP. 1250. 000 CERP. DTRS. - 999. 250 TTRS. 1853. 801 CVEL. 59. 000 ITT. 2. 226 DTD4. 272.168 PR. 18. 620 TER2. 19. 322 DT2R. 1200. 000 CHRP. 0.386 EERP. 2650. 000 CHRS. O. 208 EERS. 118. 960 DT4S. 31. 044 THOR. - O. 200 UPRA. 27. 807 W4NG. 254. 130 HTEN. 983. 000 PSCS. 0 TACT. 3 SAS2. 184.100 PdVlTE. O. 000 STIT. 1848.873 59.000 2.643 179.899 35.446 38.806 1100.000 0.966 2000.000 0.475 87.688 68.327 1.160 40.642 255.300 968.000 0 2 179.600 0.000 1899.919 59.000 2.534 296.801 32.198 36.522 1050.000 0.539 -999.250 CVEL. ITT. DTD4. PR. TER2. DT2R CHRP. EERP CHRS. EERS DT4S. THOR W4NG HTEN. PSCS TACT. SAS2 RMTE. STIT. CVEL. ITT. DTD4. PR. TER2. DT2R. CHRP. EERP. CHRS. -30.897 0.124 2.643 0.382 4800 000 280 470 0 877 22 018 0 281 14 320 167 049 1 338 0 283 3 209 989 668 0 2 255 151.508 0.000 -30.815 0.141 2.234 0.344 3800 000 183 103 0 979 31 046 0 573 24 875 163 300 5.008 0.441 5.348 999.120 0 2 255 150.200 0.000 -31.665 0.159 2.117 0.398 4200.000 305.665 0.710 25.425 0.000 TENS. SVEL. SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS. LFRS. CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP. SAS4. MTEM. TENS. SVEL. SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS . LFRS . CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP. SAS4. MTEM. TENS. SVEL . SNR2 . VPVS. CER2. TTR2 . ENRP. LFRP . ENRS. 7230. 000 8406. 199 12. 965 2.288 O. 591 4200. 000 1.376 O. 000 13. 806 O. 000 32. 499 O. 757 89. 840 O. 000 O. 058 0 0 255 151. 508 7055. 000 11404. 096 36. 938 2. 052 O. 950 3200. 000 27. 929 O. 000 23. 736 O. 000 59. 866 1. 902 202. 139 6. 417 O. 058 0 0 255 150.200 6970.000 8191.036 26.239 2.431 0.845 3600. 000 8.401 O. 000 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 O~. 51 PAGE: 16 TERS. -999. 250 CERS. DT2. 296. 801 DT4P. POTA . O . 028 SGR . TURA. 2. 432 URAN. W2NG. 102. 897 W3NG. RSGR. 70. 256 HV. STIA. O. 000 TIME. PSXS. 0 PSHS. NPR2 . 4 NPR 4. SPHI. 33. 831 CTE~I. AMTE. 148. 897 DTE~I. ** DEPTH = 9400.000 FEET BS. 8.500 CS. ETIM. 2465.180 MARK. SSVE. 5386.829 DTD2. DTCO. 88.364 DTSM. CHR2. 0.896 ENR2. LFR2. 0.000 EER2. DTRP. 88.364 TTRP. TERP. 1200.000 CERP. DTRS. 164.320 TTRS. TERS. -999.250 CERS. DT2. 185.638 DT4P. POTA. 0.026 SGR. TURA. 2.288 URAN. W2NG. 110.043 W3NG. RSGR. 67.857 HV. STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 3 NPR4. SPHI. 22.891 CTE~. AMTE. 147.595 DTEM. * * DEPTH = 9200.000 FEET BS. 8.500 CS. ETIM. 2843.556 MARK. SSVE. 4803.303 DTD2. DTCO. 106.486 DTSM. CHR2. 0.826 ENR2. LFR2. 0.000 EER2. DTRP. 106.486 TTRP. TERP. 1150.000 CERP. DTRS. 157.269 TTRS. TERS. -999.250 CERS. DT2. 208. 190 DT4P. POTA . O . 027 SGR . TURA . 9. 946 URAN. W2NG. 101. 713 W3NG. RSGR. 64. 060 HV. STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 2 NPR4. 0.000 EERS. 122.085 DT4S. 68.601 THOR. 1.566 UPRA. 53.946 W4NG. 255.300 HTEN. 947.000 PSCS. 0 TACT. 3 SAS2. 179.600 RMTE. 0.000 STIT. 1903.804 CVEL. 59.000 ITT. 2.176 DTD4. 185.638 PR. 20.968 TER2. 34.900 DT2R. 1000.000 CHRP. 0.688 EERP. -999.250 CHRS. 0.000 EERS. 88.364 DT4S. 71.252 THOR. 1.889 UPRA. 37.393 W4NG. 251.790 HTEN. 952.000 PSCS. 0 TACT. 2 SAS2. 179.600 RMTE. 0.000 STIT. 1893 237 59 000 2 867 208 190 24 853 28 238 950 000 0 475 -999 250 0 000 106 486 64.823 0.451 39.615 252.960 952.000 0 5 CVEL. ITT. DTD4. PR. TER2. DT2R. CHRP. EERP. CHRS. EERS. DT4S. THOR. W4NG. HTEN. PSCS. TACT. SAS2. -999.250 -999.250 3.807 0.569 4.995 987.215 0 2 255 148.895 0.000 -31.730 0.177 2.601 0.354 3200.000 189.349 0.830 29.504 0.000 -999.250 164.320 4.323 0.714 13.889 996.664 0 0 255 147.594 0.000 -31.554 0.196 2.442 0.323 3600.000 213.178 0.695 27.665 0.000 -999.250 157. 269 4. 973 O. 182 3.212 971. 965 0 2 255 LFRS . CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP . SAS4. MTE~. TENS. SVEL . SNR2. VPVS. CER2. TTR2. ENRP. LFRP. ENRS. LFRS . CGR. TPRA. WING. WSNG. MRES . PSRS. ETYP . SAS4. MTEM. TENS. SVEL . SNR2 . VPVS. CER2. TTR2. ENRP. LFRP. ENRS . LFRS . CGR. TPRA. WING. WSNG. MRES. PSRS. ETYP. SAS4. 10 000 57 187 1 382 217 782 1 998 0 058 0 0 255 148. 895 6790. 000 11316. 844 43. 669 2.101 O. 840 2600. 000 16. 037 O. 000 -999.250 -5. 000 57. 478 1. 633 204. 060 3.205 O. 059 0 0 255 147. 594 6565. 000 9390. 934 35. 174 1 955 0 749 3000 000 12 495 0 000 -999 250 -5 000 61 533 1 809 201. 285 2.141 O. 059 0 0 255 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.51 PAGE: 17 SPHI. 29. 632 CTEM. AMTE . 146.22 6 DTEM . ** DEPTH = 9045.000 FEET BS. 8.500 CS. ETIM. 3136.816 MARK. SSVE. 5290.048 DTD2. DTCO. 54.399 DTSM. CHR2. 0.973 ENR2. LFR2. 0.000 EER2. DTRP. 56.268 TTRP. TERP. 1000.000 CERP. DTRS. 88.263 TTRS. TERS. 1500.000 CERS. DT2. 189.034 DT4P. POTA. 0.020 SGR. TURA. 8.276 URAN. W2NG. 72.727 W3NG. RSGR. 44.105 HV. STIA. 0.000 TIME. PSXS. 0 PSHS. NPR2. 1 NPR4. SPHI. -1.840 CTEM. AMTE. 144.835 DTEM. 179.600 RMTE. 0.000 STIT. 1902.506 CVEL. 59.000 ITT. 2.751 DTD4. 189.034 PR. 31.868 TER2. 36.223 DT2R. 800.000 CHRP. 0.719 EERP. 1300.000 CHRS. 0.744 EERS. 56.268 DT4S. 49.558 THOR. 0.374 UPRA. 31.016 W4NG. 254.130 HTEN. 945.000 PSCS. 0 TACT. 2 SAS2. 175.100 RMTE. 0.000 STIT. 146.248 MTEM. 0.000 -31.708 TENS. 0.206 SVEL. 2.326 SNR2. 0.455 VPVS. 4000.000 CER2. 192.813 TTR2. 0.728 ENRP. 0 402 LFRP. 0 832 ENRS. 27 575 LFRS. 88 263 CGR. 4 138 TPRA. 0 249 WING. 2 139 WSNG. 1023.519 MRES. 0 PSRS. 2 ETYP. 255 SAS4. 144.849 MTEM. 0.000 146.248 6565. 000 18382. 762 39. 387 3. 475 O. 912 3400. 000 - 4. 925 O. 000 26. 624 O. 000 46. 832 2. 062 130. 481 3.209 O. 060 0 0 255 144. 849 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : DSSTA .035 SERVICE : PLAYBA VERSION · 7C0-427 DATE : 96/11/14 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : HILTB .015 SERVICE : DEPTH- VERSION : 7C0-427 DATE : 96/11/12 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 2712 4 66 1 5 66 1 6 73 0 7 65 IN 8 73 60 9 65 .1 IN 11 66 3 12 68 -999. 13 66 1 14 65 . liN 15 66 73 16 66 1 0 66 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS IN O0 282 O1 0 21 1 1 4 68 0000000000 CS F/HR O0 636 21 0 21 1 1 4 68 0000000000 CVEL F/~4N O0 636 O0 0 21 1 1 4 68 0000000000 TENS LBF O0 635 21 0 21 1 1 4 68 0000000000 ETIM S O0 636 21 0 21 1 1 4 68 0000000000 MARK F O0 150 O1 0 21 1 1 4 68 0000000000 HSCF O0 000 O0 0 21 1 1 4 68 0000000000 iA O0 000 O0 0 21 1 1 4 68 0000020000 STIA F O0 000 O0 0 21 1 1 4 68 0000000000 STIT F O0 000 O0 0 21 1 1 4 68 0000000000 RT OH~M O0 935 O1 0 21 1 1 4 68 0000000000 iOA MV O0 000 O0 0 21 1 1 4 68 0000000000 llA MV O0 000 O0 0 21 1 1 4 68 0000000000 RSP MV O0 010 O1 0 21 1 1 4 68 0000020000 RSPA MV O0 010 O1 0 21 1 1 4 68 0000020000 SP MV O0 010 O1 0 21 1 1 4 68 0000000000 SPAR MV O0 010 O1 0 21 1 1 4 68 0000000000 12A O0 000 O0 0 21 1 1 4 68 0000020000 13A O0 000 O0 0 21 1 1 4 68 0000020000 CNTC CPS O0 000 O0 0 21 1 1 4 68 0000000000 CFTC CPS O0 000 O0 0 21 1 1 4 68 0000000000 RGCN CPS O0 000 O0 0 21 1 1 4 68 0000000000 TNRA O0 000 O0 0 21 1 1 4 68 0000000000 GR GAPI O0 000 O0 0 21 1 1 4 68 0000000000 ECGR GAPI O0 000 O0 0 21 1 1 4 68 0000000000 CFGR O0 000 O0 0 21 1 1 4 68 0000020000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0=.~1 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DRTA 17A TA L P RCFT CPS RCNT CPS GDEV DEG HV V HTEN LBF N~{ES OHM~ AREA FT2 AFCD FT2 ABS FT2 FCD IN ttDAR IN IHV F3 ICV F3 18A MV TIME MS NPHI PU NPL PU DNPH PU TNPH PU NPOR PU CTEM DEGF RMTE DEGF MTEM DEGF AMTE DEGF 22A DEGF HWEC D/F HWER F TGST F/S2 DTEM DFHF ASFI MV 24A MS 25A RXOI HCAL IN FCBR TSCV F/MnV BSW CPS LSW CPS SSW CPS 27A MS 28A MS 32A MS DSOZ IN HUM S/C3 HPRA PEFZ QCRH O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 280 04 0 21 1 1 4 O0 282 O1 0 21 1 1 4 O0 282 O1 0 21 1 1 4 O0 282 O1 0 21 1 1 4 O0 280 O1 0 21 1 1 4 O0 282 O1 0 21 1 1 4 O0 282 O1 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 636 21 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 000 O0 0 21 1 1 4 O0 636 21 0 21 6 1 O0 000 O0 0 21 6 1 O0 000 O0 0 21 6 1 O0 000 O0 0 21 6 1 O0 000 O0 0 21 6 1 O0 000 O0 0 21 6 3 O0 000 O0 0 21 6 1 O0 000 O0 0 21 6 4 O0 000 O0 0 21 6 4 O0 000 O0 0 21 6 4 O0 636 21 0 21 60 1 O0 636 21 0 21 30 1 O0 636 21 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 68 0000020000 68 0000020000 68 0000020000 68 0000020000 68 0000020000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000020000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000020000 68 0000000000 68 0000000000 24 68 0000000000 24 68 0000020000 24 68 0000020000 24 68 0000000000 24 68 0000000000 72 68 0000000000 24 68 0000020000 96 68 0000020000 96 68 0000020000 96 68 0000020000 240 68 0000000000 120 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 20 NAFiE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 33A RHOZ G/C3 UZ H~I I N O H~M HMNO RXOZ OH~4 RSOZ IN RX08 OH~I RS08 IN HCNT CPS HCFT CPS RGHN CPS HGR GAPI EHGR GAPI HDRT HTAL RHFT CPS PJ{NT CPS DPHZ PU HTNP PU HNPO PU aaz F/S2 34A MS 35A 3 6A PSI AIBD IN 37A OH~ 38A 39A IN 40A 4lA 42A I~4/M ATCO MM/M AT10 OH~k4 AT20 OH~4 AT30 O HP~4 AT60 OH~4 AT90 OH~4 AFCO MM/M 43A M~4/M AFl 0 AF2 0 0h74~4 AF3 0 0H~94 AF 6 0 OHMS4 AF90 OH~4 AFO0 AFD1 IN AFD2 IN AFRT OtH~4 AFRX ATO0 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 890 O1 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 000 O0 0 21 3 1 O0 636 21 0 21 12 1 O0 000 O0 0 21 12 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000020000 12 68 0000020000 12 68 0000020000 12 68 0000020000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000020000 48 68 0000000000 48 73 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~1 PAGE: 21 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 636 21 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 1 O0 000 O0 0 21 2 8 O0 000 O0 0 21 2 8 O0 000 O0 0 21 2 8 O0 000 O0 0 21 2 5 O0 000 O0 0 21 2 5 O0 000 O0 0 21 2 5 O0 000 O0 0 21 2 5 O0 000 O0 0 21 2 1 O0 636 21 0 21 1 1 O0 000 O0 0 21 1 4 O0 000 O0 0 21 1 1 O0 636 21 0 21 1 1 1 8 68 0000000000 1 8 68 0000000000 1 8 68 0000000000 1 8 68 0000000000 1 8 68 0000000000 1 8 68 0000000000 16 128 68 0000020000 16 128 68 0000020000 16 128 68 0000020000 16 128 68 0000020000 8 68 0000000000 8 68 0000000000 64 68 0000000000 64 68 0000000000 64 68 0000000000 40 68 0000000000 40 68 0000000000 40 68 0000000000 40 68 0000000000 8 68 0000000000 4 68 0000000000 16 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** ** DEPTH = 9432.000 FEET BS. 8.500 CS. ETIM. 0.000 MARK. STIA. 10.000 STIT. llA. -99.063 RSP. SPAR. -97.563 12A. CFTC. 321.628 RGCN. ECGR. 71.061 CFGR. TALP. 0.688 RCFT. HV. 251.790 HTEN. AFCD. 0.267 ABS. IHV. 0.047 ICV. NPHI. 54.534 NPL. NPOR. 45.636 CTEM. AMTE. 146.263 22A. TGST. 32.138 DTE~. HDRX. -999.250 25A. FCBR. -999.250 TSCV. SSW. -999.250 27A. DSOZ. -999.250 P~DRA. QCRH. -999.250 33A. 1890.756 CVEL. 39.000 HSCF. 10.000 RT. -97.563 RSPA. 0.000 13A. 1228.214 TNRA. 0.834 DRTA. 310.049 RCNT. 722.311 MRES. 0.394 FCD. -0.087 18A. 46.835 DNPH. 166.100 RMTE. 149.955 HWEC. 0 000 ASFI. -999 250 RXOI. -999 250 BSW. -999 250 28A. -999 250 HPRA. -999 250 RHOZ. -31 513 TENS. 1 000 IA. 34 053 IOA. 0 938 SP. 0 000 CNTC. 3 841 GR. 0 000 17A. 1177 912 GDEV. 0 057 AREA. 7.000 HDAR. 58.435 TIME. -0.338 TNPH. 146.263 MTEM. -9.993 HWER. -99.321 24A. -999.250 HCAL. -999.250 LSW. -999.250 32A. -999.250 PEFZ. -999.250 UZ. 5985.000 1. 000 -99. 063 -97. 563 1203. 403 85.171 0.000 -999.250 0.094 4.148 0.000 46.678 146.263 -3278.379 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 22 H~qIN. RX08. RGHlV. HTAL . HTNP . 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA. llA. SPAR. CFTC. ECGR. TAL P . HV. AFCD . IHV. NPHI. NPOR . AMTE. TGST. FCBR . SSW. DSOZ . HMIN. RX©8. RGHN. H TAL . HTNP . 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. -999.250 -999.250 -999.250 -999.250 -999.250 0 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 0.000 DEPTH = 8.500 40.994 0.000 -102. 870 -102. 000 437. 910 75.602 0.744 251.790 0.267 3.087 46.759 42.489 146.263 32.141 0.983 0.431 12803.658 0.627 0.000 0.127 0.408 1361.361 0.763 42.867 0 2.888 174. 967 4. 405 160. 645 6. 757 13.071 12.106 0.000 HMNO. RS08. HGR. RHFT . HNPO. 36A. 39A. ATCO. AT60. AFl 0. AF90 . AFR T . ATD2 . 44A. 49A. 53A. 57A. AH~C. 9400.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEMo 22A. DTEM. 25A. TSCV. 27A. 33A. HMNO. RS08. HGR. RHFT. HNP©. 36A. 39A. ATCO. AT60. AFl 0. AFgO. AFRT. ATD2 . 44A. -999.250 RXOZ. -999.250 HCNT. -999.250 EHGR. -999.250 RHNT. -999.250 HAZ. -999.250 AIBD. -999.250 40A. -999.250 ATiO. -999.250 AT90. -999.250 AF20. -999.250 AFO0. -999.250 AFRX. -999.250 ATRT. -999.250 45A. -999.250 50A. -999.250 54A. -999.250 58A. 0.074 RMUD. 3094.939 39.000 0.000 -102.000 0 000 1417 558 0 888 363 706 965 934 0 394 -5 598 40 333 166.100 149.837 0.000 0.000 36.286 10.000 O. 001 O. 000 O. 172 0.508 85.171 332.755 45.713 5664.929 0.454 183. 820 5. 715 1.101 6.225 6.455 15.924 284.000 CVEL. HSCF. RT. RSPA . 13A. TNRA. DRTA . RCNT. MRES. FCD . 18A. DNPH. RMTE . HWEC . ASFI. RX©I. BSW. 28A. HPRA . RH©Z. RXOZ. H CNT . EHGR. RHNT. HAZ . AIBD. 40A. AT10. AT90. AF20. AFO0. AFRX. ATRT. 45A. -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.070 -51 582 1 000 4 820 0 875 0 000 3 459 -0 020 1286.709 0.057 7.000 55.356 -0.354 146.263 -9.993 -102.134 0.424 108513.893 34.000 -1.849 1.675 0.367 1441.936 74.187 1252.660 33.504 4.537 24.243 1 099 5 440 5 171 0 000 0 894 5 730 2971.943 RSOZ . HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO . AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. TENS. IA. 10A. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL . LSW. 32A. PEFZ . UZ. RSOZ. HCFT. HDR T . DPHZ. 34A. 37A. 4lA. AT20. AFCO . AF30. AFD1. ATO0. A TRX . 46A. -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 6690.000 0.000 -102.870 -102.000 1474.465 85.171 0.000 -999.250 0.128 4.853 580.000 40.629 146.263 -3278.379 192.000 4.584 1230.674 396.000 8.151 14.189 0.521 411.219 0.012 59.082 46.000 0.070 0.000 4.103 148.003 5.789 13.071 0.000 0.809 12.372 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01.ol PAGE: 23 48A. 3119.693 49A. 52A. 2.000 53A. 56A. 138.172 57A. 59A. 1145.000 AH~C. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR. AMTE . TGST. FCBR . SSW. DSOZ . QCRH. H~IN. RX©8. RGPZN. HTAL . HTNP . 35A. 3 SA. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . ** DEPTH = 8.500 276.618 0.000 -79.400 -79.250 324.533 89.141 O. ;31 252 960 0 267 133 580 46 238 39 025 146 333 32 149 0 864 0 255 14208 821 0 307 0 000 0 141 0 266 1142 192 0 581 40 722 0 8. 617 30.521 11.855 64.152 20.567 21.938 17. 385 3.158 4811.1 O1 1.000 134.631 1184.000 ** DEPTH = 8.500 513.968 0.000 -83.938 -83.938 409.498 40.735 9200. 000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEbl. 22A. DTEM. 25A. TSCV. 27A. 33A. Ht4NO. RS08. HGR. RHFT. HNP©. 36A. 39A. ATCO. AT60. AFl O . AF90. AFRT. ATD2 . 44A. 49A. 53A. 57A. Ab~4C. 9000.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. 3119.405 50A. 2872.250 54A. 908.079 58A. 0.074 RMUD. 3040.773 CVEL. 39.000 HSCF. 0.000 RT. -79.250 RSPA. 0.000 13A. 1088.867 TNRA. 1.491 DRTA. 305.684 RCNT. 914.150 [fiRES. 0.394 FCD. 71.446 18A. 39.897 DNPH. 166.100 RMTE. 149.766 HWEC. 0.000 ASFI. 0.000 RXOI. 51.854 BSW. 20.000 28A. 0.035 HPRA. 0.000 RHOZ. 0.162 RXOZ. 0.319 HCNT. 58.313 EHGR. 324.727 RHNT. 40.953 HAZ. 5544.404 AIBD. 1.984 40A. 37.778 ATiO. 32.764 ATgO. 2.347 AF20. 15.588 AFO0. 15.255 AFRX. 21.702 ATRT. 296.000 45A. 4792.487 50A. 153.644 54A. 426.151 58A. 0.073 RMUD. 3028.893 CVEL. 39.000 HSCF. 0.000 RT. -83.938 RSPA. 0.000 13A. 1397.574 TNRA. 1.123 DRTA. 186.494 2799.739 138.172 0.070 -50.680 1 000 13 620 0 938 0 000 4 003 -0 079 1044 273 0 058 7 000 29 222 -5 187 146 263 0 017 -70.277 0.220 146579.692 38.000 -2.732 2.104 0.294 1147.860 86.341 1083.683 32.476 16.017 43.905 2.458 26.471 6.755 0.000 1.678 19.816 4650.590 183.973 160.053 134.631 0.069 -50.482 1.000 4.632 0.938 1.000 3.355 -0.002 5lA. 55A. ATVM. 63A. TENS. IA. 10A. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL. LSW. 32A. PEFZ. UZ. RSOZ . HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. A FD1. ATO0. A TRX. 46A. 5lA. 55A. ATVM. 63A. TENS. IA. 10A. SP. CNTC. GR. 17A. 58.840 909.989 2.380 1729.000 6690.000 0.000 -79.400 -79.250 1127.063 59.794 0.000 1.345 1.522 16.707 592.000 37.489 146.263 3329.872 190.000 16 232 503 737 388 000 7 268 15 566 0 298 314 356 0 008 33 082 48 000 0 069 0 000 7 534 48 621 11 870 17 597 0 000 1 836 12 370 34 067 406.820 2.955 1784.000 6440.000 0.000 -83.938 -83.938 1392.991 36.268 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 O1:31 PAGE: 24 TAL P . HV. AFCD . IHV. NPHI. NPOR . AMTE. TGST. HDRX. FCBR . SSW. DSOZ . H~IN. RX©8 . RGHN. HTAL . HTNP. 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TALP . HV. AFCD . IHV. NPHI. NPOR . AMTE. TGST. FCBR . SSW. DSOZ . QCRH. H~IN. O. 711 252. 960 O. 267 261. 184 40. 517 41. O10 145. 344 32. 142 O. 618 O. 131 2963.23 6 0.305 1. 000 O. 093 0.119 1401. 787 O. 668 37. 941 64 320096 696 137 309 4 951 217 023 7 240 8 560 8 560 0 000 -1925 939 1 000 168 080 1183 000 DEPTH = RCFT. HTEN. ABS. ICV. NPL . CTEM. 22A. DTEM. 25A. TSCV. 27A. 33A. H~NO. RS08. HGR . RHFT. 3 6A. 39A. ATCO. AT60. AFl O . AF90 . AFR T . ATD2 . 44A. 49A. 53A. 57A. AH~C. 376.179 RCNT. 889. 422 ~RES. O . 394 FCD. 145. 602 18A. 35.111 DNPH. 166.100 RMTE. 149. 711 HWEC. O. 000 ASFI. O. 000 RXOI. 49. 131 BSW. 20. 000 28A. 1. 542 HPRA. 1. 000 RHOZ. O. 095 RXOZ. O. 384 HCNT. 39.550 EHGR. 420.158 RHiVT. 38. 017 HAZ. 5423. 881 AIBD. O. 000 40A. 215. 904 AT10. 7. 283 AT90. 2. 323 AF20. 4. 608 AFO0. 4. 608 AFRX. 8. 560 ATRT. 296. 000 45A. -1925. 209 50A. -1051. 357 54A. 43 O. 569 58A. O . 073 RMUD . 8971.000 FEET ** 8.500 CS. 3032.178 548.395 MARK. 39.000 0.000 STIT. 0.000 -82.883 RSP. -85.500 -85.500 12A. 0.000 411.759 RGCN. 1394.545 39.576 CFGR. 1.124 0.638 RCFT. 370.520 252.960 HTEN. 876.687 0.267 ABS. 0.394 265.555 ICV. 147.032 40.502 NPL. 35.099 36.216 CTt~4. 166.100 145.136 22A. 149.697 32.133 DTEM. 0.000 0.764 25A. 8.000 0.065 TSCV. 50.619 3155.319 27A. 22.000 0.303 t{DRA. 1.658 1.000 33A. 1.000 0.056 H~!NO. 0.045 CVEL. HSCF. RT. RSPA . 13A. TNRA . DRTA . RCNT. ~4RES. FCD . 18A. DNPH. RMTE. HWEC . ASFI . RX©I. BSW. 28A. HPRA . RH©Zo RXOZ. 1340.336 0.058 7.000 41.410 -0.373 145.332 0 011 -83 976 0 081 141466 317 38 000 -2 116 4 421 0 090 1404 197 44 420 1344 377 32 165 8 515 4345 524 2.323 4.632 3.937 1.000 2.323 4.632 -2246.968 181.452 -1451.315 168.080 0.069 -50.536 1.000 4.632 0.875 1.000 3.355 -0.011 1227.167 0.058 7.000 35.334 -0.385 145.076 0.021 -85.137 0.050 141552.848 44.000 -2.236 4.462 0.053 GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ . HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO . AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. A TVM. 63A. TENS. IA. iOA. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. LSW. 32A. PEFZ. UZ. RSOZ. 1.366 0.397 8.528 592.000 41.164 145.332 4996.718 192.000 8.538 115.943 400.000 7.884 33.948 0.247 438. 982 -0. 061 -107.310 48.000 O. 069 O. 000 3. 937 138.119 6. 390 8.560 1. 000 2.323 12.351 0.177 430.484 0.000 1785.000 6435 000 0 000 -82 883 -85 500 1328 160 35 217 0 000 0 923 0 398 8 538 599 000 38 349 145 076 2738 726 206.000 8 560 27 565 398 000 7 764 33 731 0 O45 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 25 RX08. 0.055 RS08. RGP~N. 1312.152 HGR. HTAL. 0.689 RHFT. HTNP. 42.146 PZNPO. 35A. 64 36A. 38A. 320096.696 39A. 42A. 137.309 ATCO. AT30. 4.951 AT60. 43A. 217.023 AFIO. AF60. 7.240 AF90. AFD2. 8.560 AFRT. ATD1. 8.560 ATD2. AFVM. 0.000 44A. 48A. -1818.840 49A. 52A. 1.000 53A. 56A. 168.080 57A. 59A. 1192.000 AHMC. 0.082 33.203 381.857 47.469 5422.073 0.000 215 904 7 283 2 323 4 608 4 608 8 560 301 000 -1819 583 -1051 357 430 569 0 073 HCNT. EHGR. RHNT. HAZ. AIBD. 40A. AT10. AT90. AF20. AFO0. AFRX. ATRT. 45A. 50A. 54A. 58A. RMUD . 1315 37 1277 32 8 4345 2 4 3 1. 2. 4. -2295. 181. -1451. 168. O. 062 HCFT. 312 HDRT. 683 DPHZ. 046 34A. 515 37A. 524 4lA. 323 AT20. 632 AFCO. 937 AF30. 000 AFD1. 323 ATO0. 632 ATRX. 136 46A. 414 5lA. 315 55A. 080 ATVM. 069 63A. 379.853 -0.131 -109.812 55.000 0.069 0.000 3.937 138.119 6.390 8.560 1.000 2.323 12.350 0.177 430.484 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : HILTB .015 SERVICE · DEPTH- VERSION : 7C0-427 DATE . 96/11/12 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** FILE HEADER **** FILE NAME : HILTB .018 SERVICE · P~YBA VERSION : 7C0-427 DATE : 96/11/12 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 2712 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 OX.mi PAGE: 26 TYPE REPR CODE VALUE $ 66 1 6 73 0 7 65 IN 8 73 60 9 65 .liN 11 66 3 12 68 -999. 13 66 1 14 65 .liN 15 66 73 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS IN cs FlOR CVEL F/~N TENS LBF ETIM S MARK F HSCF iA STIA F STIT F RT Otff4M iOA MV llA MV RSP MV RSPA MV SP MV SPAR MV 12A 13A CNTC CPS CFTC CPS RGCN CPS GR GAPI ECGR GAPI CFGR DRTA 17A TALP RCFT CPS RCNT CPS GDEV DEG HV V O0 282 O1 0 25 1 1 4 68 0000000000 O0 636 21 0 25 1 1 4 68 0000000000 O0 636 O0 0 25 1 1 4 68 0000000000 O0 635 21 0 25 I 1 4 68 0000000000 O0 636 21 0 25 1 1 4 68 0000000000 O0 150 O1 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 935 O1 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 010 O1 0 25 1 1 4 68 0000020000 O0 010 O1 0 25 1 1 4 68 0000020000 O0 010 O1 0 25 1 1 4 68 0000000000 O0 010 O1 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000020000 O0 000 O0 0 25 1 1 4 68 0000000000 O0 000 O0 0 25 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01.~1 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) HTEN LBF MRES AREA FT2 AFCD FT2 ABS FT2 FCD IN HDAR IN IHV F3 I CV F3 18A MV TIME MS NPHI PU NPL PU DNPH PU TNPH PU NPOR PU CTEM DEGF RMTE DEGF MTE~ DEGF AMTE DEGF 22A DEGF HWEC D/F HWER F TGST F/S2 DTEM DFHF ASFI MV 24A MS 25A RXOI OP~4~ HCAL IN FCBR OP~4~ TSCV BSW CPS LSW CPS SSW CPS 27A MS 28A MS 32A MS DSOZ IN HDRA G/C3 HPRA PEFZ QCRH 33A RHOZ G/C3 UZ ~IN OHMM H~NO OHM~ RX O Z O IliVi~ RSOZ IN O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 280 04 0 25 1 1 4 O0 282 O1 0 25 1 1 4 O0 282 O1 0 25 1 1 4 O0 282 O1 0 25 1 1 4 O0 280 O1 0 25 1 1 4 O0 282 O1 0 25 1 1 4 O0 282 O1 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 636 21 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 000 O0 0 25 1 1 4 O0 636 21 0 25 6 1 O0 000 O0 0 25 6 1 O0 000 O0 0 25 6 1 O0 000 O0 0 25 6 1 O0 000 O0 0 25 6 1 O0 000 O0 0 25 6 3 O0 000 O0 0 25 6 1 O0 000 O0 0 25 6 4 O0 000 O0 0 25 6 4 O0 000 O0 0 25 6 4 O0 636 21 0 25 60 1 O0 636 21 0 25 30 1 O0 636 21 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000020000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000020000 68 0000000000 68 0000000000 24 68 0000000000 24 68 0000020000 24 68 0000020000 24 68 0000000000 24 68 0000000000 72 68 0000000000 24 . 68 0000020000 96 68 0000020000 96 68 0000020000 96 68 0000020000 240 68 0000000000 120 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01.~1 PAGE: 28 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RX08 OHMM RS08 IN HCNT CPS HCFT CPS RGHN CPS HGR GAPI EHGR GAPI HDRT HTAL RHFT CPS RHNT CPS DPHZ PU HTNP PU HNPO PU HAZ F/S2 34A MS 35A 3 6A PSI AIBD IN 37A OPk4~ 38A 39A IN 40A 4lA 42A ~k4/M A T C O M~I /M AT10 0H~94 AT20 OP~4M AT30 AT60 OH~M AT90 0 H~94 m~co ~/M 43A Fk4/M AFl 0 OH~I AF2 0 OPi~ AF3 0 OHMM AF 6 0 OH~q AF9 0 OH~4 AFO0 AFD1 IN A3JD2 IN AFRT OH~k4 AFRX ©H~M ATO0 ATD1 IN ATD2 IN A TR T OH~M ATRX OH~4 m~VM G/FT 44A MS 45A MM/M O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 890 O1 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 000 O0 0 25 3 1 O0 636 21 0 25 12 1 O0 000 O0 0 25 12 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 000 O0 0 25 2 1 O0 636 21 0 25 2 1 O0 000 O0 0 25 2 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000020000 12 68 0000020000 12 68 0000020000 12 68 0000020000 12 68 0000000000 12 68 0000000000 12 68 0000000000 12 68 0000020000 48 68 0000000000 48 73 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 8 68 0000000000 16 128 68 0000020000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 O1. ~1 PAGE: 29 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 46A ~4~/M O0 000 O0 0 25 2 16 128 68 0000020000 48A ~/M O0 000 O0 0 25 2 16 128 68 0000020000 49A F~4/M O0 000 O0 0 25 2 16 128 68 0000020000 50A DEGF O0 000 O0 0 25 2 1 8 68 0000000000 5lA PU O0 000 O0 0 25 2 1 8 68 0000000000 52A O0 000 O0 0 25 2 8 64 68 0000000000 53A ~/M O0 000 O0 0 25 2 8 64 68 0000000000 54A Fk~/M O0 000 O0 0 25 2 8 64 68 0000000000 55A M~/M O0 000 O0 0 25 2 5 40 68 0000000000 56A F~I/M O0 000 O0 0 25 2 5 40 68 0000000000 57A MM/M O0 000 O0 0 25 2 5 40 68 0000000000 58A f4~I/M O0 000 O0 0 25 2 5 40 68 0000000000 ATVM G/FT O0 000 O0 0 25 2 1 8 68 0000000000 59A MS O0 636 21 0 25 1 1 4 68 0000000000 APiMC OH~ O0 000 O0 0 25 1 4 16 68 0000000000 RMUD OP~4~ O0 000 O0 0 25 1 1 4 68 0000000000 63A MS O0 636 21 0 25 1 1 4 68 0000000000 ** DATA ** ** DEPTH = 11268.000 FEET ** BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR. AMTE . TGST. FCBR . SSW. DSOZ . H~IN. RX08. RGHN. HTAL . HTNP . 35A. 38A. 8.500 CS. 0.000 MARK. 10.000 STIT. -123.125 RSP. -120.375 12A. 788.824 RGCN. 97.777 CFGR. 1.338 RCFT. 249.450 HTEN. O . 267 ABS. O. 047 ICV. 46. 303 NPL. 40.136 CTE~. 157.143 22A. 32.140 DTEM. -999.250 25A. -999.250 TSCV. -999.250 27A. -999.250 RDRA. -999.250 33A. -999.250 H~iNO. -999.250 RS08. -999.250 HGR. -999.250 RHFT. -999.250 HNPO. 0 36A. -999.250 39A. 3370.787 CVEL. 37.000 HSCF. 10.000 RT. -120.375 RSPA. 0.000 13A. 2677. 736 TNRA. O. 836 DRTA. 723. 048 RCNT. -155. 501 ~RES. O. 394 FCD. -0. 086 18A. 39.951 DNPH. 170.600 RMTE. 151.358 HWEC. 0.000 ASFI. -999.250 RXOI. -999.250 BSW. -999.250 28A. -999.250 HPRA. -999.250 RHOZ. -999.250 RXOZ. -999.250 HCNT. -999.250 EHGR. -999.250 RHNT. -999.250 HAZ. -999.250 AIBD. -999.250 40A. -56.180 TENS. 1.000 iA 4.632 IOA 0.875 SP 0.000 CNTC 3 393 GR 0 000 17A 2568 069 GDEV 0 060 AREA 7 000 HDAR. 77 590 TIME. -0 354 TNPH. 157 143 MTEM. -9 993 HWER. -120 742 24A. -999.250 HCAL. -999.250 LSW. -999.250 32A. -999.250 PEFZ. -999.250 UZ. -999.250 RSOZ. -999.250 HCFT. -999.250 HDRT. -999.250 DPHZ. -999.250 34A. -999.250 37A. -999.250 4lA. 3765.000 1.000 -123.125 -120.375 2652.925 116.951 0.000 -999.250 0.095 4.170 0.000 40.567 157.143 -3278.379 -999250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 30 42A. -999. 250 ATCO. AT30. -999.250 AT60. 43A. -999.250 AFiO. AF60. -999. 250 AF90. AFD2. -999. 250 AFRT. ATD1 . -999. 250 ATD2. AFVM. -999. 250 44A. 48A. -999. 250 49A. 52A. -999. 250 53A. 56A. -999. 250 57A. 59A. O. 000 AHMC. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR. AMTE. TGST. FCBR . SSW. DSOZ. HMIN. RX©8. RGHN. HTAL. HTNP. 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. ** DEPTH = 11200.000 FEET 8 500 85 0 -97 -97 1247 68 0 249 0 CS. 148 MARK. 000 STIT. 219 RSP. 250 12A. 477 RGCN. 929 CFGR. 899 RCFT. 450 HTEN. 267 ABS. 10.569 ICV. 25.246 NPL. 22.785 CTEM. 157.178 22A. 32.139 DTEM. 0.965 25A. 2.683 TSCV. 17835.700 27A. 0.138 HDRA. 0.000 33A. 1.566 H~INO. 2.753 RS08. 2826.218 HGR. 0.936 RHFT. 22.952 P~NPO. 0 36A. 47.274 39A. 136.326 ATCO. 5.202 AT60. 155.122 AFiO. 6.652 AF90. 33.467 AFRT. 16.737 ATD2. 4.763 44A. 2297.461 49A. 3.000 53A. 161.208 57A. 1240.000 AHMC. -999.250 ATiO. -999.250 AT90. -999.250 AF20. -999.250 AFO0. -999.250 AFRX. -999.250 ATRT. -999.250 45A. -999.250 50A. -999.250 54A. -999.250 58A. 0.306 RMUD. 2883.446 CVEL. 39.000 HSCF. 0.000 RT. -97.250 RSPA. 0.000 13A. 2823.811 TNRA. 1.118 DRTA. 1144.648 RCNT. 813.385 MRES. 0.394 FCD. -7.737 18A. 21.077 DNPH. 170.600 RMTE. 151.554 HWEC. 0.000 ASFI. 0.000 RXOI. 60.455 BSW. 20. 672 28A. O. 011 HPRA. O. 000 RHOZ. 1.375 RXOZ. 0.022 HCNT. 61.574 EHGR. 1274.179 RHNT. 24.056 HAZ. 6749.645 AIBD. 2.352 40A. 144.969 ATiO. 7.335 AT90. 3.903 AF20. 6.447 AFO0. 6.340 AFRX. 19.290 ATRT. 310.000 45A. 2303.890 50A. 2147.058 54A. 256.186 58A. 0.097 RMUD. -999.250 AT20. -999.250 AFCO. -999.250 AF30. -999.250 AFD1. -999.250 ATO0. -999.250 ATRX. -999.250 46A. -999.250 5lA. -999.250 55A. -999.250 ATVM. 0.290 63A. -48.057 TENS. 1.000 iA. 5.579 iOA. 0.938 SP. 0.000 CNTC. 2.416 GR. -0.068 17A. 2696.953 GDEV. 0.060 AREA. 7.000 HDAR. 70.610 TIME. -0.345 TNPH. 157.196 MTEM. 0.000 HWER. -97.885 24A. 2.589 HCAL. 185653 754 LSW. 41 328 32A. -2 199 PEFZ. 2 412 UZ. 2 855 RSOZ. 2924 105 HCFT. 68 596 HDRT. 2682 293 DPHZ. 32 045 34A. 8 366 37A. 18.254 4lA. 3.823 AT20. 6.898 AFCO. 4.060 AF30. 0.000 AFD1. 3.528 ATO0. 7.235 ATRX. 2285.233 46A. 209.183 5lA. 278.597 55A. 161.208 ATVM. 0.092 63A. -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 8125 000 0 000 -97 219 -97 250 2792 125 61 673 0 000 0 000 0 387 8 425 620.000 23.146 157.196 9842.520 206.672 8.365 580.443 413.328 2.911 7.071 0.044 1314.033 -0.072 14.438 51.664 0.092 0.000 3.513 150 321 4 730 24 052 1 000 3 453 12 618 14 544 261 586 1.600 1868.000 ** DEPTH = 11000.000 FEET ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i.~1 PAGE: 31 BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR. AMTE. TGS T. FCBR . SSW. DSOZ, H~IN. RX©8. RGHiN. HTAL . HTNP . 35A. 38A, 42A, AT30, 43A. AF60. AFD2. ATD1, AFVM. 48A. 52A, 56A, 59A, BS, ETIM. STIA , llA, SPAR. CFTC, ECGR , TAL P , HV. AFCD . IHV. NPHI, NPOR . AMTE . 8.500 316.700 0.000 -96.335 -97.063 1972.294 60.988 0,991 249.450 0.267 90.945 16.685 16.667 157.773 32.125 0.971 35.116 19205.579 0.289 0.000 0,844 8.340 4276.148 0.947 15.266 0 121,050 34.556 25,242 58 640 17 842 30 963 17 626 4 633 2704 605 3 000 139,767 1126.000 DEPTH= 8.500 548.423 0.000 -110.866 -110.250 245,380 38.458 O. 898 250. 620 0.267 192. 320 57. 896 66.690 156.881 CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEM. 22A. DTE~. 25A. TSCVo 27A. 33A. H~NO. RS08. HGR. RHFT. 36A. 39A. ATCO. AT60. AFl O . AF90. AFR T . ATD2 . 44A. 49A. 53A. 57A. AHMC. 10800.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEM. 22A. 3196. 960 39. 000 O. 000 -97. 063 O. 000 3834. 598 1.118 1658. 433 1161. 574 0,394 19. 190 12. 585 170. 600 152. 699 O. 000 O. 000 9. 740 18. 750 0. 074 O. 000 1. 072 O. 076 52. 709 2194 274 12 782 6629 120 2 261 33 193 28 938 3 708 17 053 15. 658 23.187 281.500 2705. 599 690. 801 269. 679 O. 097 3116.696 38.000 0.000 -110.250 0.000 1121.566 1.274 263. 783 935. 556 .0.394 67,117 49.648 170,600 153.483 CVEL. HSCF. RT. RSPA . 13A. TNRA. DRTA . RCNT. FIRES. FCD . 18A. DNPH. RMTE . HWEC . ASFI . RX©Io BSW. 28A. HPRA . RH©Z. RXOZ. HCNT. EHGR. RHNT. HAZ. AIBD. 40A. AT10. ATgO . AF20 . AFO0. AFRX . ATRT. 45A. 50A. 54A. 58A. RMUD . CVEL. HSCF. RT. RSPA . 13A. TNRA. DRTA . RCNT. MRES. FCD . 18A. DNPH. RMTE. HWEC . -53. 283 1. 000 29. 293 0 938 0 000 1 846 0 030 3733 217 0 059 7 000 93 978 -0 326 157 779 0 066 -96 668 34. 083 186770. 911 37. 563 -2. 990 2. 485 6. 268 3865. 985 59. 188 4143. 384 31 . 806 8. 563 23. 992 4. 855 30.127 7. 620 O. 000 2. 764 29. 028 2690. 321 206. 662 642. 402 139. 767 O. 091 -51. 945 1. 000 390.571 O. 938 O. 000 4. 502 0.108 1042. 621 O. 059 7,000 80. 360 -1.986 156. 881 O. 038 TENS. iA. 10A. SP. CNTC . GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. H CAL . LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. ATRX. 46A. 5lA. 55A. ATVM. 63A. TENS. IA. iOA. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 7960.000 0,000 -96.335 -97,063 3691.282 54.548 0.000 1.509 0,388 8.433 563.000 17.705 157.779 862.082 187.688 8.574 545.987 375.313 2.590 6,469 0.154 2264.290 0.066 10.008 46.906 0.091 0.000 14.698 56.047 10.340 23.609 0.000 4,004 12.786 9.089 205.966 2.159 1680.000 8005.000 0.000 -110.866 -110.250 1131.083 30.182 0.000 1.471 0,719 11.479 573.000 66,118 156.881 1518.401 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 32 TGST. HDRX. FCBR . SSW. DSOZ . QCRH. HMIN. RX08. RGHN. HTAL. HTNP . 35A. 38A. 42A. AT30. 43A. AF60 . AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR. AMTE . TGST. FCBR . SSW. DSOZ. QCRH. HMIN. RX©8. RGHN. HTAL. HTNP . 35A. 38A. 42A. 32. 141 1. 493 1. 374 18589. 809 0 523 0 000 0 163 1 596 1129 620 0 748 55 409 0 2 585 7 197 282 206 15 100 70 234 105 684 30. 884 6. 613 2914. 063 2. 000 80. 908 1146. 000 DEPTH = 8.500 780.602 0.000 -110.875 -110.938 756.360 131.741 0.871 249.450 0.267 300.212 29.980 29.857 155.333 32.126 1.321 1.680 13448.545 0.696 0.000 0.152 1.776 2226.308 O. 842 30.137 0 42.146 118.197 DTEM. 25A. TSCV. 27A. HDRA. 33A. H~NO. RS08. HGR . RHFT. HNPO. 36A. 39A. ATCO. AT60. AFl O. AF90. AFRT. A TD2 . 44A. 49A. 53A. 57A. AH~C. 10600.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR . RCFT. HTEN. ABS. ICV. NPL . 22A. D TEM . 25A. T$CV. 27A. 33A. HMNO. RS08. HGR . RHFT. HNP©. 36A. 39A. ATCO. 0.000 ASFI. 0.000 RXOI. 57.697 BSW. 19.125 28A. 0.031 HPRA. 0.000 RHOZ. 0.280 RXOZ. 0.636 HCNT. 32.649 EHGR. 269.584 RHNT. 54.767 HAZ. 6508.597 AIBD. 1. 931 40A. 6. 956 ATiO. 138. 947 AT90. 343.876 AF20. 66.225 AFO0. 44.159 AFRX. 36.547 ATRT. 286.500 45A. 2921.343 50A. 163.821 54A. 2.908 58A. 0.093 RMUD. 2988 727 37 000 0 000 -110 938 0 000 2229 827 1 180 705 143 1139 822 0 394 121 560 25 774 170.600 153.517 0.000 0.000 9.488 19.750 0.207 0.000 0.268 0.708 115.505 717.981 28.684 6388.072 2.068 116.421 CVEL . HSCF. RT. RSPA . 13A. TNRA . DRTA . RCNT. Izfl~ES. FCD. 18A. DNPH . RMTE. HWEC. ASFI. RX©I. BSW. 28A. HPRA . RH©Z. Ri&OZ. HCNT. EHGR. RHNT . HAZ . AIBD. 40A. AT10. -110.530 2.053 130504.237 38.250 -1.797 1.623 0.972 1117.256 41.754 1108.849 31.962 11.625 54.781 312.693 143.758 326.682 0.000 186.344 83.624 3089.906 204.141 106.599 80.908 0.088 -49.812 1.000 8.393 0 938 0 000 2 828 0 013 2137 442 0 058 7 000 81 081 -1 153 155 403 0 089 -110 436 2 219 116447 190 39 500 -6.702 2 393 1 860 2141 170 138 842 2137 147 32 296 10 330 27 627 1950 000 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ . HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. TENS. IA. iOA. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL. LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. 191.000 11.601 1724. 856 382. 000 7. 621 12.896 0.610 259.976 -0.015 62.244 47.750 0.088 0.000 297.058 14 238 310 348 82 462 1 000 298 265 12 886 62 198 3 198 0 625 1719 000 7500 000 0 000 -110 875 -110 938 2141 600 111 658 0.000 1.537 0.502 9.598 593.000 31.402 155.403 641.166 197.625 10.139 588.626 395.375 3.298 7.952 0.704 769.602 -0.015 15.600 49.438 0.089 0.000 8.729 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 01.~1 PAGE: 33 AT30. 10.148 AT60. 43A. 117.146 AFiO. AF60. 8. 377 AF90. AFD2 . 40. 734 AFRT. ATD1 . 9. 963 ATD2 . AFVM. O. 306 44A. 48A. 2908. 467 49A. 52A. 1 . 000 53A. 56A. 128. 499 57A. 59A. 1194. 000 AH~4C. BS. ETIM. STIA. llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR . AMTE . TGS T. FCBR . SSW. DSOZ. OCRH. H~IN. RX©8 . RGHN. HTAL . HTNP . 35A. 38A. 42A. AT30. 43A. AF60 o AFD2 . ATD1. AFVM . 48A. 52A. 56A. 59A. ** DEPTH = 8.500 1023.930 O. 000 -88. 821 -88. 750 741. 658 84. 702 O. 833 250. 620 O. 267 420. 620 28. 690 29.571 153. 963 32.137 1.185 0.504 14550. 471 O. 613 O. 000 0.136 O. 743 1893. 584 O. 825 30. 698 0 18 869 197 399 4 8O3 243 064 4 311 20 259 9 664 1 242 3063 531 1 000 176. 399 1213. 000 10400.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL . CTE~. 22A. DTEM. 25A. TSCV. 27A. 33A. HMNO. RS08. HGR . RHFT. 36A. 39A. ATCO. AT60. AFl O. AF90. AFRT. ATD2 . 44A. 49A. 53A. 57A. At~4C. 8.460 AT90. 1950.000 AF20. 8.536 AFO0. 8.375 AFRX. 9.963 ATRT. 296.500 45A. 2913.343 50A. 573.062 54A. 0.500 58A. 0.094 RMUD. 2969.271 CVEL. 39.000 HSCF. 0.000 RT. -88.750 RSPA. 0.000 13A. 2150.392 TNRA. 1.208 DRTA. 663.393 RCNT. 930.636 MRES. 0.394 FCD. 188.519 18A. 24.494 DNPH. 175.100 RMTE. 153.497 HWEC. 0.000 ASFI. 2.000 RXOI. 55.654 BSW. 20.125 28A. 0.156 HPRA. 0.000 RHOZ. 0.214 RXOZ. 0.800 HCNT. 80.310 EHGR. 660.538 RHNT. 34.151 HAZ. 6267.549 AIBD. 2.420 40A. 211.411 ATiO. 5.066 AT90. 6.615 AF20. 4.114 AFO0. 4.238 AFRX. 9.949 ATRT. 301.000 45A. 3063.051 50A. 460.707 54A. 151.171 58A. 0.096 RMUD. 8.590 10.281 0.000 1950.000 8.661 2912.478 201.620 145.730 128.499 0.089 -49.488 1 000 4 444 0 875 0 000 2 786 0 057 2125 202 0 058 7 000 95 537 -1 535 153. 928 O. 024 -89.098 0.597 130139.424 40.125 -3. 226 2.274 O. 922 2065.503 97.597 2100.558 31.483 10.225 14.654 11.235 4.730 4.814 0.000 7.312 4.821 3046.604 199.099 254.214 176.399 0.091 AFCO. AF30 . AFD1. ATO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. TENS. iA. iOA. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTE~. HWER. 24A. LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. 119 379 9 419 30 701 1 000 1950 000 12 889 15 404 0 500 0 000 1812 000 7475.000 0.000 -88.821 -88.750 2085.893 70.121 0.000 1.607 0.561 10.143 602.000 30.725 153.928 2381.051 200.625 10.291 484.079 401.375 6.774 15.585 0.782 733.976 -0.017 22.758 50.188 0.091 0.000 5.871 231.979 4.450 17.425 1.000 8.467 12.884 23.021 89.010 0.278 1815.000 ** DEPTH = 10200.000 FEET ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i.~1 PAGE: 34 BS. 8.500 CS. ETIM. 1259.894 MARK. STIA. 0.000 STIT. llA. -110.759 RSP. SPAR. -110.063 12A. CFTC. 2165.985 RGCN. ECGR. 58.599 CFGR. TALP. 0.951 RCFT. HV. 250.620 HTEN. AFCD. 0.267 ABS. IHV. 529.684 ICV. NPHI. 16.206 NPL. NPOR. 13.663 CTEM. AMTE. 152.900 22A. TGST. 32.145 DTEM. PZDRX. 1.265 25A. FCBR. 4.983 TSCV. SSW. 15143.998 27A. DSOZ. 0.458 HDRA. QCRH. 0.000 33A. HMIN. 0.229 H~iNO. RX08. 5.488 RS08. RGHN. 4186. 068 HGR. HTAL . 0. 882 RHFT. HTNP . 16.231 HNPO . 35A. 0 36A. 38A. 320096.696 39A. 42A. 162. 629 ATCO. AT30. 6. 039 AT60. 43A. 121 . 824 AFiO. AF60. 8.592 AF90. A~FD2. 14.194 AFRT. ATD1. 9.705 ATD2. AFVM. 0.780 44A. 48A. 3173.878 49A. 52A. 1.000 53A. 56A. 171.005 57A. 59A. 1165.000 AHMC. ** DEPTH = 10000.000 FEET BS. 8.500 CS. ETIM. 1519.426 MARK. STIA. 0.000 STIT. llA. -90.750 RSP. SPAR. -90.750 12A. CFTC. 392.189 RGCN. ECGR. 44.159 CFGR. TALP. 0.684 RCFT. HV. 251.790 HTEN. AFCD. 0.267 ABS. IHV. 652.405 ICV. NPHI. 36.592 NPL. NPOR. 35.486 CTEM. AMTE. 151.688 22A. 3068 031 CVEL. 39 000 HSCF. 0 000 RT. -110 063 RSPA. 0 000 13A. 4138 017 TNRA. 1.151 DRTA. 2210.348 RCNT. 926.591 MRES. 0.394 FCD. 244.135 18A. 12.109 DNPH. 170.600 RMTE. 153.324 HWEC. 0.000 ASFI. 0.000 RXOI. 43.683 BSW. 19.500 28A. 0.239 HPRA. 0.000 RHOZ. 0.416 RXOZ. 0.494 HCNT. 49.456 EHGR. 2242.577 RHNT. 11.636 HAZ. 6147.025 AIBD. 2. 352 40A. 168. 923 ATiO. 6. 149 AT90. 4 915 AF20. 8 209 AFO0. 8 131 AFRX. 9 705 ATRT. 291 500 45A. 3154 314 50A. 659 101 54A. 203.471 58A. 0.099 RMUD. 2883.203 CVEL. 38.000 HSCF. 0.000 RT. -90.750 RSPA. 0.000 13A. 1521.501 TNRA. 1.520 DRTA. 381.219 RCNT. 1007.924 MRES. 0.394 FCD. 313.407 18A. 31.828 DNPH. 170.600 RMTE. 152.934 HWEC. -51.134 TENS. 1.000 iA. 7.437 iOA. 0.938 SP. 0.000 CNTC. 1.865 GR. 0.022 17A. 3991.867 GDEV. 0.059 AREA. 7.000 HDAR. 68.986 TIME. -0.671 TNPH. 152.876 MTEM. 0.195 HWER. -110.365 24A. 6.304 HCAL. 143116.817 LSW. 38.750 32A. -5.312 PEFZ. 2.651 UZ. 4.704 RSOZ. 3470.923 HCFT. 57.279 HDRT. 3875 989 DPHZ 32 575 34A 8 926 37A 19 123 4lA 7 888 AT20 5 920 AFCO 6 623 AF30 1.000 AFD1. 4.518 ATO0. 5.948 ATRX. 2990.211 46A. 196.578 5lA. 729.216 55A. 171.005 ATVM. 0.094 63A. -48.053 TENS. 1.000 IA. 1010.040 iOA. 0.938 SP. 0.000 CNTC. 3.499 GR. 0 085 17A. 1463 379 GDEV. 0 059 AREA. 7 000 HDAR. 78 704 TIME. -5 545 TNPH. 151 722 MTEM. 0 286 HWER. 7610.000 0.000 -110.759 -110 063 3812 844 50 904 0 000 1 694 0 447 9 052 583 000 15 725 152 876 294 193 194 250 9 050 400.797 388.750 2.341 6.210 0.501 1939.513 O. 018 -0. 072 48. 625 0.094 0.000 12.195 116.394 7.676 12.862 1.000 6.431 12.861 0.177 126.770 0.000 1747.000 7245.000 0.000 -90.750 -90.750 1405.976 29.056 0.000 2.665 1.685 17.577 621.000 38.935 151.722 200.340 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 O1:51 PAGE: 35 BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR . AMTE . TEST. FCBR . SSW. DSOZ. QCRH. H~IN. RX©8 . RGHN. HTAL . HTNP. 35A. 38A. 42A. 32.123 1. 008 O. 361 12120.588 0.591 0.000 0.105 O. 364 1368. 627 O. 683 38. 920 0 2 067 1 389 5 457 31 099 537 790 13 208 22 220 0 000 4117 952 1. 000 132. 902 1238. 000 DEPTH = 8.500 1752. 772 O. 000 -108. 429 -108. 375 703.148 83. 987 O. 861 251 790 0 267 765 137 29 638 36 407 150 571 32.133 1. 014 O. 538 12060. 725 O. 614 O. 000 0.119 0.533 1916. 349 O. 887 33.916 0 19. 487 194. 855 DTE~. 25A. TSCV. 27A. HDRA. 33A. H~NO. RS08. HER. RHFT . HNPO . 36A. 39A. ATCO. AT60. AFl O. AF90 . AFRT. A TD2 . 44A. 49A. 53A. 57A. AHMC. 9800.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEM. 22A. DTE~. 25A. TSCV. 27A. 33A. H~NO. RS08. HGR . RHFT. HNP©. 36A. 39A. ATCO. 0.000 0.000 27. 715 20. 750 -0 067 1 000 0 148 0 667 29 901 389 997 40 094 6026.501 0.752 1.491 719.825 2.040 32.155 30.995 25.744 310.500 4033.705 192.423 490.095 0.072 3105.579 38.000 0.000 -108.375 0.000 1873.879 1.214 581.670 991.725 0.394 372.690 25.435 170.600 152.820 0.000 0.000 49.419 19.500 0.137 0.000 0.179 O. 614 59. 281 561. 800 36. 738 5905.977 1.467 204.059 ASFI. RXOI. BSW. 28A. HPRA . RHOZ. RXOZ. HCNT. EHGR. RHNT. HAZ. AIBD. 40A. AT10. AT90. AF2 0 . AF©O. ATRT. 45A. 50A. 54A. 58A. RMUD . CVEL. HSCF. RT. RSPA . 13A. TNRA. DRTA. RCNT. MRES. FCD . 18A. DNPH. RMTE . HWEC. ASFI. BSW. 28A. HPRA . RHOZ. RXOZ. HCNT. EHGR. RHNT. HAZ . AIBD. 40A. AT10. -89. 116 O. 363 111989. 987 41.500 O. 000 1. 493 0.363 1404. 364 45. 442 1303. 323 32. 804 17.576 37.598 1. 679 670. 805 4.243 1. 000 2.297 399.497 2945. 811 194. 057 291. 594 132. 902 O. 068 -51. 760 1. 000 4. 037 O. 938 1. 000 2. 859 -0. 016 1817. 604 O. 059 7. 000 67. 850 -1. 616 150.570 O. 071 -108. 641 0.546 126081. 424 38. 750 -3.550 2. 254 0.584 2049.115 72. 659 1780. 351 32. 031 10. 195 22. 685 3.157 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ . HCFT. HDRT. DPHZ . 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. A TRX. 46A. 5lA. 55A. ATVM. 63A. TENS. iA. 10A. SP. CNTC. GR. 17A. EDEV. AREA. HDAR. TIME. TNPH. MTEM . HWER. 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. 207.000 17.576 1759.175 414.000 10.000 15.704 0 667 391 844 -0 002 70 144 51 750 0 068 0 000 3 359 1 859 12 650 13 208 0.000 1.341 12.814 69.558 595.463 4.740 1860.000 7090.000 0.000 -108.429 -108 375 2060 488 69 175 0 000 0 487 0 575 10 264 582 000 32 478 150.570 811.281 194.000 10.271 746.510 388.000 6.449 14.715 0.578 678.642 -0.020 24.003 48.500 0.069 0.000 5.886 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i:51 PAGE 36 AT30. 6. 254 AT60. 43A. 175. 972 AFIO. AF60 . 6.144 AF90 . AFD2. 11.037 AFRT. ATD1. 11. 766 ATD2. AFVM. O. 531 44A. 48A. 3132. 497 49A. 52A. 3. 000 53A. 56A. 144. 262 57A. 59A. 1162. 000 AH~C. ** DEPTH = 9600.000 FEET BS. 8.500 CS. ETIM. 1985.478 MARK. STIA. 0.000 STIT. llA. -88.446 RSP. SPAR. -87.000 12A. CFTC. 597.455 RGCN. ECGR. 72.946 CFGR. TALP. 0.671 RCFT. AU/. 251.790 HTEN. AFCD. 0.267 ABS. IHV. 901.452 ICV. NPHI. 31.857 NPL. NPOR. 26.933 CTEM. Ai~TE. 149.421 22A. TGST. 32.113 DTEM. HDRX. 0.936 25A. FCBR. 0.973 TSCV. SSW. 12923.545 27A. DSOZ. 0.437 t{DRA. QCRH. 0.000 33A. HMIN. 0.170 t~4iNO. RX08. 0.911 RS08. RGHN. 1916.478 HGR. HTAL. 0.704 RHFT. HTNP. 30.459 HNPO. 35A. 0 36A. 38A. 14.791 39A. 42A. 273.853 ATCO. AT30. 4.793 AT60. 43A. 203.107 AFIO. AF60. 5.590 AFgO. AFD2. 10.999 AFRT. ATD1. 11.389 ATD2. AFVM. 0.621 44A. 48A. 3228.442 49A. 52A. 3.000 53A. 56A. 141.594 57A. 59A. 1205.000 AHMC. 5.132 AT90. 3.260 AF20. 5.683 AFO0. 5.719 AFRX. 12.075 ATRT. 291.000 45A. 3133.601 50A. 145.299 54A. 306.772 58A. 0.072 RMUD. 3056.171 CVEL. 38.000 HSCF. 0.000 RT. -87.000 RSPA. 0.000 13A. 1862. 455 TNRA. 1.197 DRTA. 570. 582 RCNT. 1329.165 MRES. 0.394 FCD. 455.558 18A. 27.636 DNPH. 170.600 RMTE. 152.469 HWEC. 0.000 ASFI. 0.000 RXOI. -7.768 BSW. 20.000 28A. 0.117 HPRA. 0.000 RHOZ. 0.258 RXOZ. 0.421 HCNT. 65.504 EHGR. 606.171 RHNT. 27.625 HAZ. 5785.452 AIBD. 1. 474 40A. 295. 113 AT10. 3. 652 AT90. 2. 702 AF20. 4. 924 AFO0 . 5.235 AFRX. 11.521 ATRT. 301.500 45A. 3230.844 50A. 173.029 54A. 370.121 58A. 0.073 RMUD. 4.901 6.357 0.000 3.659 5.077 3085.877 191.536 148.319 144.262 0.068 -50.936 1.000 3 583 1 000 0 000 2 979 0 000 1844 916 0.059 7.000 72.171 -1.386 149.420 0.035 -87.333 0.911 165793.942 40.250 -3.229 2.196 0.838 1775.029 78.581 1849.502 32.380 10.559 39.143 2.798 3.389 6.147 1.000 2.674 3.685 3224.328 189. 015 189.167 141.594 0.070 AFCO. AF30. AFD1. ATO0. ATRX. 46A. 5lA. 55A. ATVM. 63A. TENS. iA. 10A. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ . HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. A TVM. 63A. 162.756 6.685 10 969 1 000 3 128 12 791 22 653 316 752 0 687 1740.000 7165.000 0.000 -88.446 -87.000 1677.123 60.964 0.000 1.392 0.537 9.921 603.000 30.791 149.420 1659.473 201.000 10.242 837.246 402.000 5.332 11.874 0.424 631.116 0.012 27.544 50.250 0.069 0.000 5.615 178.902 7.126 10.866 1.000 2.811 12.746 26.002 357.459 0.664 1797.000 ** DEPTH = 9400.000 FEET ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~;51 PAGE: 37 BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TAL P . HV. AFCD . IHV. NPHI. NPOR . AMTE. TGST. FCBR . SSW. DSOZ. QCRH. HMIN. RX©8. RG~N. HTAL. HTNP . 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA. llA. SPAR. CFTC. ECGR . TA L P . HV. AFCD . IHV. NPHI. NPOR . AMTE. 8.500 CS. 2228.872 MARK. 0.000 STIT. -90.839 RSP. -91.250 12A. 309.110 RGCN. 66.665 CFGR. 0.724 RCFT. 252.960 HTEN. 0.267 ABS. 1027.898 ICV. 56.234 NPL. 49.736 CTEM. 148.242 22A. 32.149 DTEM. 0.945 25A. 0.287 TSCV. 13149 774 27A. 0 599 HDRA. 0 000 33A. 0 114 H~!NO. 0 310 RS08. 1192 870 HGR. 0 735 RHFT. 48 464 HNPO. 0 36A. 3.442 39A. 225.817 ATCO. 4.612 AT60. 193.057 AFIO. 5.514 AF90. 12.544 AFRT. 13.307 ATD2. 0.760 44A. 2751.747 49A. 3.000 53A. 125.334 57A. 1209.000 AP~IC. ** DEPTH = 9200.000 FEET 8.500 CS. 2472.772 MARK. 0 000 STIT. -93 982 RSP. -94 000 12A. 319 073 RGCN. 85 700 CFGR. 0 547 RCFT. 252.960 HTEN. 0.267 ABS. 1154.582 ICV. 38.339 NPL. 37.533 CTEM. 147.019 22A. 2967.420 CVEL. 39.000 HSCF. 0.000 RT. -91.250 RSPA. 0.000 13A. 1195. 750 TArRA. 1.173 DRTA. 325. 812 RCNT. 932.471 MRES. 0.394 FCD. 528.555 18A. 48.258 DNPH. 170.600 RMTE. 152.045 HWEC. 0.000 ASFI. 0.000 RXOI. 54.081 BSW. 20.000 28A. 0.009 HPRA. 0.000 RHOZ. 0.150 RXOZ. 0.560 HCNT. 56.559 EHGR. 299.652 RHNT. 50.660 HAZ. 5664. 929 AIBD. 1.205 40A. 233. 236 ATiO. 4. 428 AT90. 2 995 AF20. 5 180 AFO0. 5 329 AFRX. 13 307 ATRT. 300 500 45A. 2751 982 50A. 158 660 54A. 333 879 58A. 0.074 RMUD. 2972.419 CVEL. 39.000 HSCF. 0.000 RT. -94.000 RSPA. 0.000 13A. 1160.146 TNRA. 1.480 DRTA. 303.500 RCNT. 963. 257 MRES. O. 394 FCD. 601. 791 18A. 33.289 DNPH. 170.600 RMTE. 151.553 HWEC. -49.457 TENS. 1.000 iA. 4.227 iOA. 0.938 SP. 1.000 CNTC. 4.290 GR. -0.012 17A. 1127.961 GDEV. 0.060 AREA. 7.000 HDAR. 56.308 TIME. -0. 961 TNPH. 148.278 MTEM. O. 022 HWER. -90.376 24A. 0.271 HCAL. 106538.877 LSW. 40.000 32A. -5.513 PEFZ. 1.733 UZ. 0.454 RSOZ. 1242.535 HCFT. 68.249 HDRT. 1176.098 DPHZ 31.971 34A 9.864 37A 22.342 4lA 3.138 AT20 4. 287 AFCO 5. 688 AF30. 1.000 AFD1. 3.052 ATO0. 4.441 ATRX. 2735.652 46A. 186.494 5lA. 184.943 55A. 125.334 ATVM. 0.070 63A. -49.540 TENS. 1.000 IA. 18.196 iOA. 0.875 SP. 0.000 CNTC. 3.564 GR. 0.016 17A. 1112 587 GDEV. 0 060 AREA. 7 000 HDAR. 79 296 TIME. -5 040 TNPH. 147 028 MTEM. 0 213 HWER. 6800.000 0.000 -90.839 -91.250 1212.293 56.835 0 000 1 130 0 489 9 466 601 000 48 999 148 278 2637 052 200,500 10086 1605418 400,500 4.406 7.909 0.561 318.149 -0.041 55.583 50.000 0.070 0.000 7.385 181. 360 6.113 12.484 1 000 3 082 12 682 53 904 318 644 0 000 1830 000 6595.000 0.000 -93.982 -94.000 1129.601 57.891 0.000 0.000 1.468 16.409 601.000 38.719 147.028 269.079 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~51 PAGE: 38 TGST. ~DRX. FCBR . SSW. DSOZ . QCRH. HMIN. RX©8 o RGP~N. HTAL . HTNP . 35A. 38A. 42A. AT30. 43A. AF60. AFD2. ATD1. AFVM. 48A. 52A. 56A. 59A. BS. ETIM. STIA. llA. SPAR. CFTC. ECGR. TAL P . HV. AFCD. IHV. NPHI. NPOR . AMTE. TGST. FCBR . SSW. DSOZ . H~IN. RX©8. RGP~N. HTAL . HTNP . 35A. 38A. 42A. 32. 143 O. 943 O. 420 14542. 430 0 484 0 000 0 163 0 413 1118 920 0 521 36 582 0 9. 199 23. 388 7.183 72. 080 16. 392 21. 929 18 154 3 083 4975 094 1 000 134 942 1202 000 DEPTH = 8.500 2716. 566 O. 000 -78. 374 -78. 375 363.260 43. 375 O. 714 255. 300 0.267 1280. 023 40.290 40. 832 145. 724 32.133 O. 885 O. 057 3394. 871 0.303 1. 000 O. 048 O. 052 1227. 447 O. 676 41. 425 64 320096. 696 19. 065 DTEM. 25A. TSCV. 27A. t{DRA. 33A. H~4NO. RS08. HGR. RHFT. HNPO . 36A. 39A. ATCO. AT60. AFl O . AF90 . AFRT. ATD2 . 44A. 49A. 53A. 57A. AHMC. 9000.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEM. 22A. D T EM . 25A. TSCV. 27A. 33A. H~NO. RS08. HGR . RHFT. 36A. 39A. ATCO. O. 000 ASFI. O. 000 RXOI. 43. 830 BSW. 20. 000 28A. O. 063 HPRA. O. 000 RHOZ. O. 203 Ri~OZ. O. 330 HCNT. 58. 443 EHGR. 302. 676 RH_NT. 37. 001 HAZ. 5544. 404 AIBD. 2.207 40A. 25.726 AT10. 42. 758 AT90. 2. 240 AF20. 13. 874 AFO0. 11. 702 AFRX. 19. 647 ATRT. 300. 500 45A. 4980. 020 50A. 160.294 54A. 446. 444 58A. O. 074 RMUD. 2966.634 40.000 0.000 -78.375 0 000 1408 317 1 124 336 775 835 449 0 394 673 790 34 922 170 600 151 233 0 000 8 000 48 682 20 000 1 644 1 000 0 045 0 000 34 027 376 809 44 831 5423 881 0 000 30 861 CVEL . HSCF. RT. RSPA . 13A. TNRA. DRTA . R CNT. MRES. FCD . 18A. DNPH. RMTE. HWEC. ASFI. RX©I. BSW. 28A. HPRA . RHOZ. RXOZ. HCNT. EHGR. RHNT. HAZ . AIBD. 40A. AT10. -93.538 0.396 132195.379 40.000 -2.271 2.122 0.363 1129.772 85.708 1109.334 32.880 16.143 51.357 2.778 38.871 6.648 0.000 1. 757 28. 923 4914. 019 183. 973 193.212 134.942 0.070 -49.444 1.000 32.697 0.875 1.000 3.343 0.176 1350.639 0.060 7.000 42.983 -0.372 145.733 0.011 -75.285 0.050 141962.754 40.000 -1.455 4.362 0.052 1316.693 38.237 1177.177 32.151 8.538 2197.508 1950.000 24A. HCAL . LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO . AF30. AFD1. ATO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. TENS. lA. 10A. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. H CAL . LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. 200.500 16.053 468.975 400.500 7.729 16.683 0.334 332.134 -0.009 31.992 50.000 0.070 0.000 9.966 61 005 10 865 18 804 1 000 2 460 12 609 32.971 360.006 2.092 1814.000 6345 000 0 000 -78 374 -78 375 1308 298 38 599 0 000 1 306 0 398 8 538 603 000 44 376 145 733 5417 747 201 000 8 538 111.929 402.000 8.545 36.323 0 000 385 178 0 027 -103 744 50 250 0 07O 0 000 1950 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0i~31 PAGE: 39 AT30. 1950. 000 AT60. 43A. 7. 325 AFl O. AF60. 131.127 AF90. AFD2. 130. 543 AFRT. ATD1 . 113 . 465 ATD2. AFVM. 3.302 44A. 48A. -644. 513 49A. 52A. 1 . 000 53A. 56A. -53. 787 57A. 59A. 1214. 000 AH~C. BS. ETIM. STIA . llA. SPAR. CFTC. ECGR . TALP. HV. AFCD . IHV. NPHI. NPOR . AMTE. TGST. FCBR . SSW. DSOZ. QCRH. HMIN. RGHN. HTAL . HTNP . 35A. 38A. 42A. AT30. 43A. AF60. AFD2 ATD1 48A 52A 56A 59A. ** DEPTH = 8.500 2842.521 0.000 -83.813 -84.750 266.003 33. 699 O. 711 252. 960 0.267 1292.223 61.307 51.341 145.012 32.139 1.087 0.046 7752 693 0 390 0 000 0 054 0 050 937 856 0 823 64 981 64 67.249 25.342 1950.000 15.042 29. 568 4.127 97. 364 0.000 -1848.265 2.000 -37.529 -999.250 8896.000 FEET CS. MARK. STIT. RSP. 12A. RGCN. CFGR. RCFT. HTEN. ABS. ICV. NPL. CTEM. 22A. DT~M. 25A. TSCV. 27A. 33A. H~NO. RS08. HGR. RHFT. HNP©. 36A. 39A. ATCO. AT60. At~i O . AF90 . AFRT. ATD2 . 44A. 49A. 53A. 57A. AH~C. 52 451 1950 000 136 520 82 591 145 233 301 500 -646 953 -864 543 0 451 0 074 2974.747 39.000 0.000 -84.750 0.000 1140.514 0.833 291.783 836.275 0.394 658.333 52.501 166.100 150.818 0.000 8.000 48.513 20.500 0.022 0.000 0.042 0.055 42.519 291.081 73.171 5365.427 0.000 34.245 39.461 1950.000 66.480 63.228 161.407 304.O00 -1847.827 -2650.314 0.451 -999.250 AT90. AF20. AFO0. AFRX. ATRT. 45A. 50A. 54A. 58A. RMUD . CVEL. HSCF. RT. RSPA. 13A. TNRA. DR TA . RCNT. f4RES. FCD . 18A. DNPH. RMTE. HWEC. ASFI. RX©I. BSW. 28A. HPRA . RH©Z. RXOZ. HCNT. EHGR. RHNT. HAZ. AIBD. 40A. AT10. AT90. AF20. AFO0. AFRX. ATRT. 45A. 50A. 54A. 58A. RMUD . 32.403 1950.000 0.000 1950.000 39.088 -948.606 181.452 123.215 -53.787 0.070 -49.579 1.000 29.201 0.938 0.000 4.210 0.000 1110.879 0.060 7.000 34.154 -0.332 145.010 0.012 -85.987 0.050 112827.643 40.500 -1.389 2.449 0.050 1054.626 35.406 1134.387 32.123 4.126 15542.514 1950.000 29.201 1950 000 1 000 1950 000 30 755 -2460 029 180 229 -2219 758 -37 529 -999 250 AFCO. AF30. AFD1. A TO0. A TRX . 46A. 5lA. 55A. ATVM. 63A. TENS. iA. iOA. SP. CNTC. GR. 17A. GDEV. AREA. HDAR. TIME. TNPH. MTEM. HWER. 24A. HCAL. LSW. 32A. PEFZ. UZ. RSOZ. HCFT. HDRT. DPHZ. 34A. 37A. 4lA. AT20. AFCO. AF30. AFD1. ATO0. ATRX. 46A. 5lA. 55A. ATVM. 63A. 7.626 1950.000 102.065 0.000 1950.000 12.555 0.177 0.451 4.087 1825.000 6190 000 0 000 -83 813 -84 750 1099 406 40 470 0 000 1 255 0 093 4 126 608 000 53 401 145 010 4897 697 202 500 4 126 184 984 4O5 50O 8 611 21.219 0.055 232.564 0.000 12.168 50.750 0.070 0.000 1950.000 33.820 1950.000 4.127 0.000 1950.000 12.519 12.194 0.451 5.059 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-NOV-1996 0~.~1 PAGE: 40 **** FILE TRAILER **** FILE NAME : HILTB . O18 SERVICE : PLA YBA VERSION : 7C0-427 DATE : 96/11/12 MAX REC SIZE : 8192 FILE TYPE : DL LAST FILE : **** TAPE TRAILER **** SERVICE NAME : FSNAM DA TE ORIGIN : DLIS TAPE NAME : CONTINUATION # : 1 PREVIOUS TAPE : CO~T : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY * * * * REEL TRAILER SERVICE NAME : SNAM DA TE : ORIGIN · : DLIS REEL NAME : CONTINUATION # : 1 PREVIOUS REEL : COI~4ENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY
