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180-104
' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 71 - Suspended r lb.Well Class: 20AAC 25.105 20AAC 25110 Development 0 ' Exploratory ❑ /l GINJ ❑ WINJ El WAGE] WDSPL El No. of Completions: /`. Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 2/18/2016 •180-104/316-046 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 11/18/1982 50-133-10099-01 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 2070'FNL,305 FWL, Sec.3,T7N, R9W, SM - 11/25/1982 Soldotna Creek Unit(SCU) 12A-03 - Top of Productive Interval: 9. Ref Elevations: KB: 164' 17. Field/Pool(s): GL: 144' BF: 164' Swanson River Field/Hemlock Oil - Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1951'FNL,210 FWL,Sec. 3,T7N, R9W,SM 10,699'MD/10,695'TVD FEDA028997 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 347,966.60 y- 2,459,122.20 Zone- 4 • 10,850'MD/10,845'TVD . N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 347,874.50 y- 2,459,246.80 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) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary 1X-516-°1 'Q.p1 ` N/A II I�',Qf ' RECEIVED er^ z"'S—$AR 3 0 2016 23. CASING, LINER AND CEMENTING RECORD ''IGC%-- WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 22" Surface 28' Surface 28' 13-3/8" 54.5 R-3 Surface 3,000' r Surface 3,000' 18-5/8" 1792 sx 7" 29 P-110 Surface 10,265' Surface 10,263' 10-5/8" 5" 18 N-80 10,045' 10,848' 10,043' 10,843' 6" 88sx 24.Open to production or injection? Yes ❑ No 0 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 N/A 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 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: Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate — Form 10-407 Revised 11/2015` CONTINUED ON PAGE 2 Sublet ORIGINIAL only ,� X70 RBDMS t- MAR 3 1 2016 .. 7,/ , 0 • 28.CORE DATA Conventional Co ): Yes ❑ No 0 Sidewall Cores•s ❑ 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. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports,per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary,Schematic 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: Joe Kaiser-777-8393 Email: jkaiser@hilcorp.corn Printed Name: Chad Helgeson Title: Operations Manager Signature:77----4( Phone: 777--?(C> Date: 'PO b 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 lb: 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 Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/07/2016-Sunday R/D mud pumps,TDS,change house, Pason lines to camp buildings. Change oil in TDS and swivel. Remove torque bushing and install TDS in shipping frame. Remove TDS from rig floor. Rebuild kill HCR and mezzanine kill line valve. Change out scoping lines on derrick. Rig down mud lines in pits and pumps. R/D electric cables. Spot and rig up office and quarters on 12-3 pad. Begin mud pump maintenance. Prepare and scope down derrick. Prepare derrick for lowering. Lower derrick. Lay out felt/liner and set mats on SCU 12-3 pad. 02/08/2016- Monday Rig move. Load out doghouse, combo building and catwalk. Crane BOP, iron roughneck,derrick carrier, sub base. Load out pony subs and sub-base equipment. Mobilize cranes to SCU 12-3. Set pony subs, sub-base equipment, carrier, derrick. Set HPU combo building. Removed BOP from cradle and hung off in sub-base with hydraulic chain hoist. Spot doghouse and combo building. Install iron roughneck on rig floor. Set remaining rig mats. Set pits#1 and#2. Set MP#1 and MP#2. Rig up pits and pumps suction and discharge lines. Miscellaneous ground rig up. Rig up electric, hydraulic and water lines. Prepare to raise derrick. Perform derrick inspection. Raise derrick. Spool drill line. Install torque tube. Scope derrick up. Continue with miscellaneous utilities rig up. Vacated pad is 50%cleaned up. 02/09/2016-Tuesday Continue RU. Install turn buckles on torque tube, spotted gen#3 and both boilers. Continue to hook up electric, water and mud lines. Continue to bring in miscellaneous from 322C-04 and staging pads as per permits and organize pad. Set crane and set centrifuge work on welding projects, install new section of HP mud line in pump house. Spot pipe skate and raised ramp. install rig floor wind walls. install rig floor mud manifold. Hook up and run Pason lines. Spot pit#3, level camp trailers and PU TDS. Install roof on camp's transformer. Had false LEL alarm, rig floor 22%, all hands mustered. Driller suited up SCBA and swept area w/handheld w/0%and disabled alarm,gave all clear(good drill). Continue to bring in miscellaneous from 322C-04 and staging pads as per permits and organize pad. Finish rigging up TD and function test same. RU rig floor equip. RU gas degasser. Finish hooking up accumulator lines to sub. Set, stand up and RU gas buster. Build containment for Weatherford hyd equip and other equip that contain hydrocarbons. Haul Weatherford equip, Connex parts, and test jt rack to rig. Straighten up and organize trailers on storage pad. Haul all the rest of the Connex parts from the storage pad and spot in place. Load containment dock w/ Weatherford equip. RU mud line from pumps to sub. RU line from choke manifold.Trim liner and felt around rig and dispose of small sections. Continue hauling assorted equip from old pad and storage pads. Rig is 100%set&90%rigged up. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/10/2016-Wednesday Continue RU and continue to bring miscellaneous from SCU 322C-04 and both staging pads. Continue hooking up Pason wires, replace bad steam lines,finish hooking up centrifuge lines,filled up liner wash and functioned test both water pumps for rig, finish install of ground rods and wires.Tested new section of HP mud line t/5,000 psi, re-tighten and change rubber, re-test good. Test all surfaced HP mud lines t/3,350 psi (good ).Tested rig ESD's-good,fill rig water tank,fill pits w/lease water.Total safety chk,gas system found two bad heads, replace same and calibrated and test system. Held refresher w/crew on gas system and SCBA training. Set cement silo. Change out camp gen-set. Change out crack set of forks on Saxon fork lift,continue work on rig acceptance list. RU and test lines to production tree to pump down tbg,taking returns on annulus thru wide open choke and gas buster. Well had slight vacuum on both sides, crew change. Finish RU,fill wet leg of gas buster. PJSM. Pump 128 bbls PW at 3 BPM with no pressure and no returns.Shut down and put another 102 bbls PW in the pits. Pump again at 5 BPM and we started to see pressure after pumping 9 bbls. Slow down to 4 BPM and pump another 20 bbls and we got returns. [157 bbls total] Continue pumping and dump 35 bbls oil to cuttings tank. Dump another 4.5 bbls oily water and take returns back to pits. Pump another 61 bbls with no losses. Shut down and monitor well. Well did not go on a vac or build any pressure. Put the dbl studded adaptor and the spacer spools together while circ and monitoring well. Start pumping again at 2.7 BPM and caught press and returns right away. Returns were dirty oily water so we continued circ dumping another 54 bbls until it cleaned up. Circ another 12 bbls to establish a loss rate. Well didn't take any fluid. Shut down and monitor well and it was static.Set BPV and blow down lines. Nipple down tree and remove from cellar. Clean up hanger and wellhead. Hanger neck sticks up 4-1/2" above flange. MU left handed blanking sub in hanger Nipple up dbl studded adaptor with spacer spools. Nipple up BOP stack. Nipple up choke line valves and choke line. MU kill line shock hose. Install flow nipple and flowline. Rig accepted at 0600 hrs on 2/11/2016. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/11/2016-Thursday Finish NU BOPS, install Koomey line, install tarp on cellar door. Re-chk all bolts. Pressure up accumulator,function test BOPs(ok). MU 2-7/8"test jt fill stack and choke w/ water and perform shell test 250-3,500 psi. TIW and safety valve failed. BLM inspector Amanda Eagle on location,site orientation and safety meeting. Pull test jt and chk out valves and while testing gas system (ok). Perform 2nd shell test,failed and confirmed hanger seals leaking. Isolated stack and test choke manifold and dart valve to 250 psi L and 3,500psi H 10/10. While testing discuss rolling test option w/BLM Amanda Eagle&town. Received verbal approval from AOGCC to conduct a rolling test on BOP w/conditions. Crew change and PJSM on rolling test. Perform rolling test on annular to 250 low and 2,500 psi high. Perform rolling test on upper rams, lower rams, manual kill and choke line valves,and HCR kill and choke line valves to 250 low and 3,500 psi high, LD test jt and break off subs. RU to test floor valve and TD valves.Tesco dual TD valves and floor valve failed. RD test equip. Made the decision to RU and circ well while changing out the TD valves. Blow down TD. MU head pin on landing jt. Pull BPV. MU landing jt and RU to circ down tbg taking return off annular valve to choke manifold. Got ready to circ and Pason locked up so we changed out the TD valve while trouble shooting Pason. Contacted Pason tech and they repaired it. Attempt to test Hyd upper TD valve. No test. Start to circ down tbg at 2.7 BPM 300 psi. Pumped 1-1/2 bbls and caught pressure. Pumped 2 more bbls and got returns. Dumped 29 bbls of oily water and then it cleaned up. Started taking water back to pits. Raised pump rate to 4 BPM at 600 psi and cir a total of 230 bbls. Tested lower TD valve and floor valve to 250 low and 2,500 high for 10& 10 while circ. Shut down pump and monitor well to let oil migrate up. Re-test upper hyd TD valve.Tested good. Circ well at 4.2 BPM 632 psi. Dump 86 bbls until it cleaned up good. Keep cir another 29 bbls taking returns back to pits. No losses to well. Blow down lines. Perform accumulator draw down tests. RU to pull hanger and see is anchor is free. Back out LDS. 02/12/2016- Friday Screw into top of landing jt w/TD. Pull 48K and hanger came off seat.Should have weighed 77K with tbg and block wt. PU 2' and check well for flow or loss.Well static. Continue PU bringing hanger to floor with no wt increase. LD landing jt. RU Weatherford power tongs and equip. LD tbg hanger with 6' pup. POOH, LD 2-7/8"tbg. Cleaning pipe and looking for holes or bad pipe. LD 216 jts. Should nut tQp of fish att aporo. 6.424'.,Bottom it hada split collar that looked like it had been rubbed into by a sucker rod. Problem was it was rubbed on the outside of the jt. Pictures in o-drive. Hole took 2 bbls over displacement. Rig down Weatherford equipment and clear floor. Rig up to test BOPs. Fill system w/water and purge air from system. Test BOPs on 4- 1/2".Test annular to 250 psi low and 2,500 psi high for 10 min on each. Test all other BOP equip except blind rams to 250 low and 3,500 high for 10 min ea. Perform accumulator draw down test. Had to grease choke HCR and re-test.Also had to bump the pressure up once on the annular high pressure test. Pull 4-1/2"test jt and test blind rams to 250 psi low and 3,500 psi high for 10 min each. Had issues getting air out of system and had to change out a blown sensor in choke house. Perform choke tests. MU 2- 7/8"test jt. Fill and purge air from system.Testing upper pipe rams. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/13/2016-Saturday Test BOPs on 2-7/8". Finish test on upper rams and test lower rams. Tested to 250 low and 3,500 psi high for 10 min ea.Test annular to 250 low and 2,500 psi high for 10 min ea. Had issues w/air and getting test plug to seat. RD and blow dn test equip and set 6-7/16"wear ring. Service rig PU fishing BHA#1=5-3/4" Bowen overshot, dressed w/3.09"grapple w/stop and plain control, bumper sub, oil jars,XO, 14 HWDP= 453.66#. Check torque on TD,tongs, and iron roughneck.All torques matched. Shimmed TD to center over well. Continue RIH picking up 4-1/2" DP to 6,400'. Continue RIH picking up pipe slow looking for the top of the fish.Tag top of fish at 6,882'. Set dn 12K on fish. PU and pull 30K over bleeding off jars on way up. MU TD and break circ. Pump 112 GPM, 218 psi. Work pipe down to neutral wt and PU 30K over. Increase pump rate to 225 GPM,805 psi in the attempt to help free fish. Work pipe several times picking up to 45K over up wt. Slow pump back down so we wouldn't wash out top of fish. Continue working pipe pulling up to 45K over several times. Cock jars and fire them at 30K over then PU to 50K over. Fire jars 2 more times at 40K over and PU to 50K over. Still no movement. Call town and discuss getting e-line out to cut tbg with chem cutter. Get E-line headed this way. Continue circ and dump 30 bbls oily water on bottoms up. Looks like we are circ at top of fish. Continue circ while waiting on E-line. RU E-line to run a tbg punch.Test lubricator.Test failed. Rebuild head. Re-test lubricator. 02/14/2016-Sunday Continue chg Pollard E-line packing head to grease head &test lubricator 250-2,500 psi (ok) monitor well w/little to no losses. RIH w/ 1-11/16"tbg punch gun w/3' loaded w/13 shots @ 0 deg phased w/ 3/8" exit hole and de-centralized w/no problem entering TOF. RIH logging and seen anchor and set dn and fill @ 10,012'WLM (23' below anchor in a 31'jt). Logged anchor and tied in and tbg punch f/9,967't/9,970'w/good indication of fire and log punches- Good. POOH, LD tbg punch, all shots fired. MU and arm 1.875" RTC. RIH w/no problem, log and tie into anchor and tbg punches and sever tbg @ 9,970' (right below tbg punches) leaving 16' stub of 31'jt on top of anchor w/good indication of fire. POOH, log few collars w/2' of movement. POOH, inspect cutter w/no sign of blow back. RD E-line. MU TDS, PU and verified tbg free w/14K of extra weight, circ surface to surface @ 1,990 psi and 387 GPM w/no chg in fluid, monitor static well w/no losses. POOH f/6,876' and rack back DP and HWDP. LD fishing tools. ID Baker grapple w/jt in tool and break out on catwalk.Top of the jt had a groove cut in it about 2' down that matched the jt we pulled out above it. Break out a couple jts w/pipe wrenches. Both jts had worn spot on one side of the collar like they had been drug across something or something had been drug across them. Service rig,grease TD, drwks, crown, and iron roughneck. Check bolts on drive line, and inspect drwks brakes. RU Weatherford tongs and equip. POOH, LD 2-7/8"tbg. Cleaning, inspecting and sucking nerf balls through the tubes. Started getting bent jts after pulling 26 jts. Continued getting bent jts but they started getting cork screwed on jt#63. All the rest of the jts were bent and cork screwed. Pictures in 0-drive. LD 97 jts and a 15.25" cut off with 13 holes punched in it. RD Weatherford and clear floor of tools. RU Pollard E-line. PU 7" lubricator, MU 6" GR junk basket, set bottom of lubricator just below bag. Close bag and pull lubricator up against bag. Chain down and test. RIH w/6" GR. Set down at 6,786' WLM. Tool hung up. Work 850 over several times to get free.Attempt to pass through but kept setting dn. POOH with GR and RD E-line. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/15/2016- Monday RD E-line. Gauge ring had 3/4"to 1" groove cut in the side about 1/2" long.Junk basket was empty. MU BHA#2. Silverback window mill, lower string mill,flex jt, upper string mill, bumper sub, oil jars,XO, 14 jts HWDP=469.00'. RIH to 6,795' and start taking wt. Attempt to ream through tight spot easy. Could tell we were on metal or bad csg due to increase in torque. Decision was made not to damage the csg any worse than it already was. RU to test csg. Pressure up to 1,500 psi. Pressure started bleeding dn. Call town and discuss options. Pressure bled f/1,500 psi to 1,325 in 50 min on a chart. POOH and LD fishing tools. Mill had 2 spots where the inserts had broken loose on the gauge of the mill. RU to PU 2-7/8"tbg cmt stinger BHA=2-7/8" mule shoe cut off, 19 jts 2-7/8"tbg,XO, XO=614.84'. RIH with 4-1/2" DP out of the derrick to 7,038'. Continue RIH picking up 4-1/2" DP to 7,721'. 02/16/2016-Tuesday Continue RIH picking up 4-1/2" DP. Ease down last joint from 9,916'to 9,957' and tagged up twice. Up wt 150K, dwn wt 158K. LD single, MU 10'and 15' pups, MU topdrive. CBU one time,then cont circ through choke to allow practice on holding 400 psi back pressure with manual choke on choke manifold. Shut down pump. MU 5' pup, closed TIW and pump in sub on stump (installed wiper ball above TIW valve), RU Schlumberger hardline and manifold. Held PJSM with rig team and SLB cementers. Prime SLB pump,flush hardline to cuttings box with 5 bbls water. SLB pumped 10 bbls water down DP,SLB PT lines at 1,750 and 3,000 psi (good tests). Installed wiper ball in pump in sub, SLB mixed and pumped 10 bbls (48 sx) 15.8 ppg cement at 2.6 bpm-500 psi while we held 420 psi backpressure on casing(with manual choke). Shut down SLB pump and closed choke. SLB flushed lines to cuttings box,then pumped 2 bbls fresh water to clear any cement from hardline and manifold. Rig opened TIW to launch second wiper ball and displaced cement with 125.85 bbls produce water. Initial rate of 2.7 bpm, up to 4 bpm-551 psi,again while holding 412 psi back pressure with manual choke. With 200 strokes to go we eased open manual choke holding 200 psi back pressure, and at pump shut down opened manual choke fully.At shut down we had 80 psi on drillstring. Bled off psi to zero with 5 bbls back to trip tank. FCP was 2.7 bpm-494 psi. 10 bbls cement= 269.25' of coverage,TOC should be+/-9,686'. Blew down hardline to SLB pump truck and RD same. Broke off TIW/pump in sub/5' pup and LD same. Pulled 10 stands from 9,957'to 9,300' slowly(1 minute per stand). Pipe pulling dry. At 9,300', installed 6" wiper ball in drill string, MU topdrive and performed one full circ at 391 gpm-1,464 psi and had no cement to surface. Shut down rig pump, blew down topdrive and choke lines, drained poorboy degasser. Cont POOH from 9,300'to 2-7/8"tubing at 614'. LD XOs. PU pups off walk and break them dn. Clear floor and RU to LD 2-7/8" tbg. LD 19 jts 2-7/8"tbg and mule shoe cut off. RD tbg equip. [Tbg stinger had slight cmt ring on collars but the rest was clean]. RU Pollard slick line. Had to steam their reel to get their brakes to release. Held PJSM. PU lubricator and get set in table, RU sheaves. Wt indicator line must of had water in it because it was froze or plugged.Thawed their line out. Finished rigging up. Test lubricator to 1,000 psi. RIH w/4.48" GR. 5,500' at report time. Hauled 70 bbls class II junk fluid to G&I. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Plug Back Saxon 169 50-133-10099-01 180-104 2/7/16 2/18/16 Daily Operations: 02/17/2016-Wednesday Cont RIH w/4.48" GR on slickline and tag cmt at 9,671'WLM. POOH, RD and released slickline. RU test equipment tied in to annulus valve on wellhead. Closed blind rams and attempt to test casing at 2,500 psi for 30 minutes. PSI bled off 300 psi over 30 minutes. Bad test. Called out Tri Point for RTTS. RD test equipment. Rig crew cut and slipped 94' of drill line and serviced rig while waiting on RTTS and plan forward from town. Decision made to set CIBP. Released Tri Point. Called out Pollard E-line crew and Baker Rep. Spot Pollard unit, held PJSM, RU sheaves and lubricator.Tested lubricator at 500 psi. RIH with CIBP on e-line to 6,570' with no issues. Obtained casing collar log from 6,570' up to 6,170' (to be used during liner hanger setting later). Set CIBP at 6,542' (5' above casing collar at 6,547'). POOH, RD Pollard. RU test equipment tied in to annulus valve on wellhead. Closed blind rams and tested casing at 2,500 psi for 30 minutes on chart.Good test. Pumped a total of 87.5 gallons to achieve 2,500 psi, bled back 87 gallons. RD test equipment. RD remainder of Pollard equipment. Staged Baker whipstock tools for PU. PU 6" window mill assembly as follows: 6" starter mill, 5-15/16" lower mill, 6'flex joint, 6.059" upper mill. Orientate UBHO sub. PU, inspect, and lower whipstock into stack. Install hanging clamps and set do on table. Install anchor bolt to silverback window mill. RIH slow and smooth with whipstock t/6,522'. MU topdrive and PU to 6,515'. Hold PJSM and get everything lined up to displace Displace pumping 10.5 ppg KCL Polymer mud down DP taking 8.5 ppg produced fluid back to cuttings tank. Displaced at 246 GPM, starting pressure of 347 psi and a final pressure of 1,068 psi. Mud came back on planned stks w/very little interface. Circ on short system at 112 GPM &422 psi. Finish hauling produced water to snake pit and haul 45 bbls mud contaminated fluid to G&I. Rinse out pits and build mud. Haul 6% KCL from storage pad and build mud. Class II fluid hauled to G&I =0 bbls. Total class II fluid hauled =70 bbls. 02/18/2016-Thursday Cont building 10.5 ppg 6% KCL mud while waiting on AOGCC approval to move forward with milling ops. Notified by Drilling Engineer we were approved to set whipstock and mill window at 9:45am. Had Pollard and Gyro Data on location at 09:00 hrs and E-line re-headed for gyro tool. Shut down rig pump, broke off topdrive. PU single, eased down and tagged CIBP with whipstock at 6,532' DPM. Down wt 114K. LD single, PU 15' pup jnt and parked whipstock 5' above CIBP. Held PJSM with Pollard, Gyro Data and rig crew. Hung sheave in derrick, RIH with gyro tool on E-line. Stung into UBHO sub 5 times with an orientation of 240 deg. Turned drill string 1/8 turn to the right and worked it one time. Re-seated gyro tool twice with a 281 deg orientation. POOH, RD Gyro Data and Pollard E-line. Slacked off on drill string from 114K to 102K as per Baker Rep and tripped anchor. PU and verified anchor set. SO to 86K and sheared bolt. PU and verified whipstock set, up wt 110K. LD 15' pup jnt and adjusted topdrive drilling torque to 15,000 ft/lbs., Mill 6"window from 6,514' (top of ramp)to 6,518', wob .5K, 197 gQm-822 psi, 65 rpm-4,900 ft/lbs on bott torque, 1-2 ft/hr ROP, MW 10.5 ppg/vis 48. At 6,518'topdrive started stalling out with little to no on bottom torque. Rack stand back. Troubleshoot topdrive rotating/torque issue. Will rollover to "Drilling" phase of wellez as of 18:00 hrs. No activity on pre-drill after 1800 hrs. .5(412-1- .- Scik • f ®o cr Soldotna Creek Unit H . • Well SCU 12A-03 SCHEMATIC Completion Ran:7/20/13 PTD: 180-104 Hacoru Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26'/New RKB=11' J L 22" CASING AND TUBING DETAIL Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' 5" 18 N-80 - 4.276 10,045' 10,848' 13-3/8" T- JEWELRY DETAIL No Depth ID OD Item 1 6,542' 7"Cast Iron Bridge Plug set for whipstock Fish in Hole: 1 A 2.441" 2.875" 2-7/8"6/5 ppf L-80 EUE 8 RD Tubing /� a e„(51,,�a d� 2.420" 5.530" Tubing Anchor 2.255" 2.875" Seating Nipple TOC 9,671' - Oy 2.441" 2.875" Slotted Flow Sub 1 ". of 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 3.500" Bull Plug Il. MI The following set on E-Line A `+▪ " 2 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' °" I 3 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long ' 4 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 5 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. A. a' Y' , 6 10,121' 1.995" 2.880" WLREG 1 47 10,555' - - Posiset Plug 2 , 8 10,699' - - Baker Mod.K-1 Retainer 3 `�> IIII 4 imb. 5 6 >- II t, L L 7„ = H-2 H-3 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date =- H-4 H-2 10,410' 10,428' 10,407' 10,425' 18' 10-14 7/9/1997 = H-5 H-3 10,442' 10,450' 10,439' 10,447' 8' 10 7/9/97 - H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 H-6 H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 7 *Mit H-8 10,560' 10,590' 10,556' 10,586' 30' 10 7/9/97 H 8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 Casing Split =- H-8 H-30 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 8 -H-10 4 h 5„ PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Updated by JEK 3/29/16 STATE OF ALAS R EU AL OIL AND GAS CONSERVATION COMOSION EC IV REPORT OF SUNDRY WELL OPERATIONS `BAR 0 1 2016 1.Operations Abandon H Plug Perforations A Fracture Stimulate _ Pull Tubing _J Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Pull Rods ❑✓ 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 180-104 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10099-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU) 12A-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,850 feet Plugs measured 10,555 feet true vertical 10,845 feet Junk measured N/A feet Effective Depth measured 10,555 feet Packer measured 10,095 feet true vertical 10,552 feet true vertical 10,093 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 9,989'MD 9,987'TVD Packers and SSSV(type,measured and true vertical depth) Baker"D"; N/A 10,095'MD 10,093'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A a �� Treatment descriptions including volumes used and final pressure: N/A //1r 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 0 Subsequent to operation: 0 0 0 0 30 14.Attachments(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-020 Contact Joe Kaiser-777-8393 Email jkaiser(a�hilcorp.com Printed Name Chad Helgeson Title Operations Manager 1/771 Signature �-- Phone 907-777-8405 Date 3/I/f 3 //'( Form 10-404 Revised 5/2015 �/!�/4 RBDMS i_t-- MAR 0 2 2016 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 12A-03 Pull Rods Moncla 401 50-133-10099-01 180-104 2/2/16 2/5/16 Daily Operations: 02/02/2016-Tuesday Mobe Moncla 401 from Kenai to SCU 12A-03 and associated equipment. Laid containment and seals, spotted beam, WOR heaters,generator and light plants. LD horsehead, MU rod elevators backed off stuffing box. Pickup on polish rod and unseated pump. SDFN. 02/03/2016-Wednesday Held PJSM. Prep to pull rods. Latched polish rod and BO/LD rod BOP's and_ stuffing boxes. String weight 28K PU and unseated pump 1K over string weight. MU stripper head and LD pony and 2 1" rods. MIRU hot oil unit and tested lines to 1K-test ok. Pumped 32 bbls of 180deg PW down tbg, stopped pumping due to burner going out on Unit. RDMU hot oil unit. TOOH w/rod string and pump LD same. No sign of visiable damage to string or pump. RD stripper head and rig floor. LD derrick and secured well head. SDFN. 02/04/2016-Thursday Held PJSA, RDMO MONCLA 401 and associated equipment to SCU 33-33. MIRU Peak 120 ton crane and removed beam and the A frame section of the Lufkin Unit, hauled section to P&S for temporary storage. SDFN. 02/05/2016- Friday Moved out Lukin Pumping Unit MIRU SL.Tested lubricator and RIH w/2.35" GR and tagged hard at 7,899'. POOH, metal marking on bottom of GR. PU/MU 2.25" LIB and RIH,tag and dropped thru @ 7,933', 8,598', 8,661', 8,756'. Continued RIH and tagged hard at 9,549', no-go. (POOH, LIB showed that the tbg has sections of rod being cut.) RDMO SL. Secured well. Soldotna Creek Unit • Well SCU 12A-03 ACTUAL SCHEMATIC Completion Ran:7/20/13 PTD: 180404 ffilcoro Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26'/New RKB=11' CASING AND TUBING DETAIL J 1 L 22" Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' 13-3/S" JEWELRY DETAIL 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line 8 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' 9 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 10 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 4 11 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. 12 10,121' 1.995" 2.880" WLREG 13 10,555' Posiset Plug 14 10,699' Baker Mod.K-1 Retainer 5 6 - 7 g CZ 10 11 12 > L L 7„ - H-2 = H-3 - H-4 PERFORATIONS = H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date - H-2 10,410' 10,428' _ 10,407' 10,425' 18' 10-14 7/9/1997 - H-6 H-3 10,442' 10,450' _ 10,439' 10,447' 8' 10 7/9/97 raj. H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 13 H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 _ U - H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 H-8 H-8 10,560' 10,590' _ 10,556' 10,586' 30' 10 7/9/97 - H 8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 14 ->"< Casing Split -H-10 H-10 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 D Q5" PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Updated byJEK 1/8/16 • SC�� ZA--v3 • P/1) 1601o4.c Regg, James B (DOA) From: Joe Kaiser <jkaiser@hilcorp.com> Q � 't Sent: Friday, February 19, 2016 1:37 PM To: Regg,James B (DOA); Shane Hauck; Eagle, Amanda (aeagle@blm.gov) (aeagle@blm.gov); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Paul Mazzolini; Monty Myers; Luke Keller; Marvin Rogers - (C); Rig169 (Rig169 @saxonservices.com) (Rig169@saxonservices.com) Subject: RE: Hilcorp SCU-12A-03 Jim, That is correct. It was for SCU 12A-03. Our apologies for the inconvenience. Joe Kaiser KEN Operations Engineer Swanson River Field jkaiserPhilcorp.corn SEP 2 3 2016 907-777-8393 Office s`pNNED 907-952-8897 Cell From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, February 19, 2016 1:21 PM To: Shane Hauck; Eagle, Amanda (aeagle@blm.gov) (aeagle@blm.gov); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Paul Mazzolini; Joe Kaiser; Monty Myers; Luke Keller; Marvin Rogers - (C); Rig169 (Rig169@saxonservices.com) (Rig 169@saxonservices.com) Subject: RE: Hilcorp SCU-12A-03 Saxon 169 BOPE Test 2/11 - 2/13/16 Pages titled "Hilcorp BOP Test Sheet" reference well name SCU 318-04; assume this is a typo and should be SCU 12A- 03. Do not need to resend,just confirm.Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Shane Hauck [mailto:shauck@hilcorp.com] Sent: Sunday, February 14, 2016 10:03 AM 1 • • • To: Regg, James B (DOA); Eagle, Amanda (aeagle@blm.gov) (aeagle@blm.gov); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Paul Mazzolini; Joe Kaiser; Monty Myers; Luke Keller; Marvin Rogers - (C); Rig169 (Rig169@saxonservices.com) (Rig169@saxonservices.com) Subject: Hilcorp SCU-12A-03 Mr. Regg and Amanda Eagle Here is our Bope test form and attached charts and documentation as requested Thanks liiI p , ,t:t.t;; Thanks, Shane R. Hauck Sr. Drilling Foreman Hilcorp Energy Company shauck@hilcorp.com Cell: 907-250-2713 Rig: 907-776-6776 2 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.reoqaalaska.gov AOGCC.Inspectors a(�.alaska.gov phoebe.brooks a(�•alaska.gov Contractor: Saxon Rig No.: 169 DATE: 2/13/16 Rig Rep.: Duggan/Van Evera Rig Phone: 907-776-6728 Operator: Hilcorp Alaska, LLC Op. Phone: 907-776-6776 Rep.: Hauck/Rogers E-Mail shauck@hilcorp.com Well Name: SCU 12A-03 PTD# 1801040 - Sundry# 316-046 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3500 - Annular: 250/2500 - Valves: 250/3500 - MASP: 184 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P ' Well Sign P Upper Kelly 1 - FP ,--- Housekeeping Housekeeping P - Rig P - Lower Kelly 1 P PTD On Location P - Hazard Sec. P Ball Type 1 - FP ✓ Standing Order Posted P Misc. NA Inside BOP 1 - FP FSV Misc 0 - NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P - P Annular Preventer 1 - 11" - P - Pit Level Indicators P P #1 Rams 1 - 2 7/8"x 5"vbr - P - Flow Indicator P - P #2 Rams 1 _ Blind - P - Meth Gas Detector P - P #3 Rams 1 , 2 7/8"x 5"vbr- P , H2S Gas Detector P - P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 - 3-1/8" - P - Inside Reel valves 0 NA HCR Valves 2 - 3-1/8" - FP ✓ Kill Line Valves 2 - 2-1/16" - P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3100 - P . CHOKE MANIFOLD: Pressure After Closure(psi) 1500 _ P - Quantity Test Result 200 psi Attained(sec) 18 P No.Valves 13 . P - Full Pressure Attained(sec) 88 P Manual Chokes 1 - P - Blind Switch Covers: All stations Yes • Hydraulic Chokes 1 • P - Nitgn. Bottles#&psi(Avg.): 4 @ 2650 - P • CH Misc 1 FP i- ACC Misc 0 NA Test Results Number of Failures: 5 ✓ Test Time: 33.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Preformed rolling bope test do to tbg hating that was witness by Amanda Eagle w/BLM with verbal approvel to pull tbg and set test plug and conduct full bope test and combined both test to a single bope test form and submit with / charts for both test and to update rolling bope test proceedure for Saxon rig 169 See attatched remarks and charts AOGCC Inspection 24 hr Notice Yes Date/Time 2-08-10:20 Waived By Jim Regg Test Start Date/Time: 1/11/2016 11:30 (date) (time) Witness Test Finish Date/Time: 2/13/2016 10:00 Form 10-424(Revised 11/2015) 2016-0213_BOP_Saxon 169_SCU_12A-03.xlsx •• SCU 12A-03 , Saxon # 169 2-13-16 Remarks of Initial Bope rolling test with leak at tubing hanger and full test of Bope after first tbg recovery was laid dn First shell test revealed Dart valve and safety valve failure Amanda Eagle w/BLM on location and witness tests. Tested all gas alarms good while pulling test jt and chg out both Dart valve and safety valve reinstalled test jt and attempt 2nd shell test failed with no surface indication of surface leak filled annulus and pressured up confirmed hanger leak. Isolated stack and tested choke manifold while Discussed rolling test option w/Amanda Eagle (BLM) and Hilcorp engineering and AOGCC. Received verbal approval to conduct rolling test from AOGCC w/conditions Amanda Eagle doubled checked BLM regulations with no reference to leaking hanger and agreed w/AOGCC and same conditions for BLM. Chart "A"dated 2-11-16 hard test of CMV's, floor valves and TDS and Hilcorp test sheets "A" and Hilcorp test notes "A" Had F/P of test#1 do to improper valve alinement Had F/P of test#7 back up TIW valve due to test hose to test jt leaking Had F/P of test#8 back up TIW valve due to Air in system and our Rig water tank getting too hot 130 degs r/up circ cold water thru tds an system cooled dn water to 65 degs Had F/P test#9 upper IBOP (HYD) chg out TDS IBOP valves Had F/P test#10 due to air Chart "B"dated 2-12-16 Rollie Bope test and Hilcorp test sheets "B"and Hilcorp test notes "B"preformed on 2-7/8"test jt Note: Tested as per attached Saxon rig #169 rolling bope test procedure Note: Test pump was constantly run at 10-12 GPM Note: Test#1 chart recorder on 12 hr(hard to see a good line but OK by Amanda Eagle w/ BLM) Note: test#2,#3,and #4 Chart recorder on 60 min drew a lot longer line to look at and OK by Amanda Eagle Chart "C"and "D" dated 2-13-16 full bope test after first tubing recovery and Hilcorp test sheets "C"and Hilcorp test notes "C"preformed on 4-1/2"test jt and 2-7/8"test jt Had F/P of test#4 function test and service Had F/P of test#8 (4)attempts trouble shooting air in system (found bad senator Blatter) chg/out same and re-seated test plug for good test Had F/P of test#11 improper valve alinement and air in system Had F/P of test# 13 trouble shoot air in system and reseattest plug (5) Equipment P/F .--- (3) Improper alinement P/F (3)Air/hot water P/F (1) test equipment We had unusual amount of air issues during testing. Will have mech. Go through test pump and check rod packing and pump for proper operation before next test • • , H HILCORP BOP TEST SHEET Test A DATE: 11-Feb-16 RIG CONTRACTOR: Saxon RIG # 169 " TIME: 12:00 HRS. WELL NAME: SCU.3*B U4 124--vs ,1-q--- TYPE r-`'TYPE OF OPERATION - (DRILLING /WORKOVER/ OTHER): HILCORP REP: HAUCK/ROGERS RIG SUPERVISOR: DUGGANSNAN EVERA SUPERINTENDENT: TESTING COMPANY: Saxon DP SIZES: 2 7/8" TUBING BOP SIZE & RATING: 11 5K Test# Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail 1 CMV 1,2,3,4,5, 10/10 250 3500 F/P 2 CMV 6,7,8 10/10 250 3500 P 3 CMV 9,13 10/10 250 3500 P 4 CMV 10,12, DART VALVE 10/10 250 3500 P 5 ELECTIC CHOKE 1500 P 6 MANUAL CHOKE 1500 P 7 TIW 10/10 250 3500 F ' 8 TIW 10/10 250 3500 F 9 UPPER IBOP 10/10 250 3500 F " 10 UPPER IBOP 10/10 250 3500 F 11 LOWER IBOP 10/10 250 3500 P 12 TIW 10/10 250 3500 P 13 UPPER IBOP 10/10 250 3500 P Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 3050 1500 1400 11" Annular 23 SEC. Final Pressure 1425 1425 1250 2 7/8"X5" VBR/UPPER 5 SEC. Re-charge Time 200 PSI 19 SEC. FULL RECOVERY 101 SEC. 2 7/8"X5" VBR/LOWER 5 SEC. NO2 AVG 4 BTLS @ 2,650 PSI 3 1/8" HCR 2 SEC. Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: N/A EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. • • HILCORP BOP TEST NOTES r 3 Test A TEST # 1 FAIL DUE TO IMPROPER VALVE ALINEMENT TEST # 7 FAIL DUE TO HOSE TO TEST JOINT LEAKING TEST # 8 FAIL DUE TO AIR/WATER TEMP TEST # 9 FAIL DUE TO BAD UPPER IBOP/CHANGE IBOP TEST # 10 FAIL DUE TO AIR f 5644011-l�P( huPE-7�s 5o 45 12 0 15 • Sa IZ:4--c 3 tis _ ~� r° (60 104-0 5500 is - 5000 ,__. ,`- • / r O t . s 4500 ` .--. 0• �`� ,: 5000 ^§) / �OOp ,t;,�.- � _4000 ..,_� q 0 � �� *.,:. O 350_0 400 /' I'' ' ' ' 0- ;-'' ': ' 300P_ '- 1--- 9P -- ' -- ''-'4 .0 i, /{4° ___---.257---_-1 f `_ `---,r,, �0 -'�� / O J - , It ., soo -2004 '_ --------------- \',. 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H HILCORP BOP TEST SHEET Test B DATE: 11-Feb-16 RIG CONTRACTOR: Saxon RIG # 169 ' TIME: 0-Jan-00 WELL NAME: SCU 31B-64' (7A-(L'-� -V-1--- TYPE �TYPE OF OPERATION - (DRILLING /WORKOVER/ OTHER): Drilling HILCORP REP: Shane Hauck/Marvin Rogers RIG SUPERVISOR: Kevin Duggans SUPERINTENDENT: TESTING COMPANY: Saxon Rig 169 DP SIZES: 2 7/8 BOP SIZE & RATING: 11 5K Test# Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail 1 ANNULAR, CHOKE HCR, KILL HCR 5min/5min 250 2500 P 2 UPPER PIPE RAMS,CHOKE HCR, KILL HCR 5min/5min 250 3500 P 3 UPPER PIPE RAMS, MANUAL 5min/5min 250 3500 P CHOKE,MANUAL KILL 4 LOWER PIPE RAMS 5min/5min 250 3500 P Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 3050 1500 1400 11" ANNULAR 23 sec Final Pressure 1425 1425 250 2 7/8"X5 UPPER RAMS 5 SEC Re-charge Time 200PSI 19 SEC 101 SEC FULL 2 7/8"X5 UPPER RAMS 5 SEC Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. • • HILCORP BOP TEST NOTES Test B ROLLING BOP TEST TEST #1 CHART RECORDER ON 12 HOUR TEST #2, 3, 4 CHART RECORDER ON 60MIN --41,-------- 15 -41,' 15 30 • W 45 12 pJ 5 — 0 7 .50 500 a0 10(i'd'---- _1_,- - !,:-------,--i:— ___ S000 ----;-___' 1111illibiRiiNk., . "400 1�-- –g5pp \ �� 40 a5oo g0oo °40404, 0 . © 40 iniiiiN 350p - N Ss,9 ! ph �' ° �� A 0Qligiff r-- 6000 `k' ¢ W 77�44,4A.,,1001.4,-, l ; �..a.. 3000 a �%�ir as0 41*°°° 4.000.. — -1 1�♦ °OO O hoso '' � __ 500 3s 0 / ,l' 10 I 2f V eirS.I.0'`°- 3411M5�=000 �,-�44KrA.vs,a_ 00. 0 Ij y/ii' °� X Zo° � __ �Spo .a�ys•,. I' h Vtt. ,� o 1__ o • • ♦♦♦ . lyl � 165). 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' S. ♦�`* �1"N � , o s! ; �� o-0ot a •'� QST ,'G;'+, i►, ► 00 !I� k4 !i `'� �♦ ♦ ����► � p0 ,,� 7 ant it O 0# • o, ,;!I v a • +' k ♦�•�4...4: �� boos ; .Isss s _ooz . � o° �y,� ���‘‘ oo � 10004074.41$2,- _,_=��� i ,o�2i ° 't �o� � ik NVill., 1 irst4 0004oosa—��0-1 = ! ' 100 o , 7tso ° ; ��y py 41*. -.—;V 0001^ �' Vii= Aoc, isp. p0 S ,� � <7 Orli=ia' � '-' ' �S� �� __ OSS .. O� -� p � — ��� 00 - _00pd 1 V ,a ,OS \\NNNN„N„. „,, ,,.. . 000 �\ 0 \ ' DOSS--- ,\ / o qv ; -;--- s1 S • • 0 . H HILCORP BOP TEST SHEET Tests C & D DATE: 13-Feb-16 RIG CONTRACTOR: Saxon RIG # 169 TIME: 20:00 hrs. WELL NAME: SCU 3.1-a="0-4' tz_4—C2> TYPE OF OPERATION - (DRILLING /WORKOVER/ OTHER): Drilling HILCORP REP: Shane Hauck/Marvin Rogers RIG SUPERVISOR: Kevin Duggans SUPERINTENDENT: TESTING COMPANY: Saxon Rig 169 DP SIZES: 4.5/2.875 BOP SIZE & RATING: 11 5K Test# Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail 1 UPPER RAMS, MEZ. KILL,DART 10 min/10 min 250 3500 P HYRA. IBOP, CMV 1,3,4,5,7 2 UPPER PIPE RAMS,CM 2,4,5,6,8 10 min/10 min 250 3500 P KILL HCR,TIW,LOWER IBOP 3 UPPER PIPE RAMS, INSIDE KILL, TIW 10 min/10 min 250 3500 P CM 7,9,11,13 4 UPPER PIPE RAMS,INSIDE KILL,TIW, 10 min/10 min 250 3500 F/P CHOKE HCR 5 UPPER PIPE RAM,INSIDE KILL,TIW, 10 min/10 min 250 3500 P INSIDE CHOKE 6 ANNULAR 10 min/10 min 250 2500 P 7 LOWER PIPE RAM,TIW VALVE 10 min/10 min 250 3500 P 8 BLIND RAMS,CM 7,10,12 10 min/10 min 250 3500 F/P INSIDE KILL 9 ELEC. CHOKE 1500 P 10 MANUAL CHOKE 1500 P 11 UPPER PIPE RAMS (2 7/8") 10 min/10 min 250 3500 F/P 12 LOWER PIPE RAMS (2 7/8") 10 min/10 min 250 3500 P 13 ANNULAR (2 7/8") 10 min/10 min 250 2500 F/P Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 3100 1600 1475 11" ANNULAR 23 Final Pressure 1500 1500 1375 2 7/8"X5 UPPER RAMS 5 Re-charge Time 200PSI 18 SEC 88 SEC FULL 2 7/8"X5 UPPER RAMS 5 Back up nitrogen average: 2650 psi Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. • • HILCORP BOP TEST NOTES Tests C & D TEST #4 FAIL/PASS CHOKE HCR FUNCTION TEST AND GREASE TEST #8 FAIL/PASS 4 ATTEMPTS TROUBLE SHOOTING AIR IN SYSTEM,FOUND BAD SENSATOR (CHANGED OUT),RESEATED TEST PLUG FOR A GOOD TEST TEST #11 FAIL/PASS INPROPER VALVE ALINMENT AND AIR IN THEST CHOKE TEST #13 FAIL/PASS TROUBLE SHOOT AIR IN THE SYSTEM RESET TEST PLUG • 45 12 0 15 „..- 50 3O - -- 5500 _ 1.......,,,,,,,,,,,„„,,,".........__ , ,,,,,_____" , 2 a // \\ ,_:40,,,, 5000 --2_77.:L_7717-_--7c:TL-- -2--_ • 1 woo 1� r -: ' CO45 -- _._- - S 00 0 1i �. 500:::,..,\ 5 p 41444. e • , ) p00 ,, , 4000 _ --___. o A7 t,I 1 0w.r .,�yi 0so-,200 _ �`: 0/0Str A 4‘ � ' oo' 2 00: _ y .' •`, } \pr0_,,x-,..oG ALP / �� ��' ►O�II�*et,' 0o:"o' tli,rc_.1.:_-_:..,,I .o , `iso . °o / //�� � ll��j��yIIj • **A 20° X04 -!_ r is":,,..-'--,.,,„N. 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I ,5? 0 . * 4,6144 4* 3, -..,s, 7E:- ,_ ,-_- = ._,_,_lis ., 1l sp a S �' ' 'lii �h a %G MP-6000-12H o — �--- r 0_ C - 0 i - %o: o o o_ o a ---- _ - - o 0 mi n1 Cr, z 4 454-1--- ----,---- _ _ --- N H� �HHII _;_ _.__ •,�r n�H MIt TAKEN OFF 1 - . j _ ___c- - ON '0.,' • ---- -� _ "" M . p �111 �i o T. Kj�� �neS �"— 0 1 1 ° O O ° •O LOCATION G U i Z_T D 3 p I�Q�'.�• M - � N : N ..S Qom;.- a. 1pL1 REMAR I� •iji I��LI ' a0 gr i g pu 111.111‘�maw% 1� • • 40.o + t t o 14 1 a. To*t •% _A• v„ #./eitto.2,, nohow toosty•ow.. *vv.- ,a4/ \� '►•- � '•�, oo • tO..a -44, s--- ,k so.•+'.11 #0 ♦G'G � ,� �a it& �� •o*44:00% sib •••��'►� 11,04,X 0091- CS:oo,S� ,.''SyL+►'y♦$64,o°� �IJJI�'I�tiI�I �/�� °oo \,-na �� .� �� 00, r..8222aC-0002- +r'1+ o ,/ I� �Ij►�I� I���j/I;... k. sOoS �. ..0s,\ .7.41�� 4►� , 0. ,4t Tr MIX _1 4-- 100.1700 x► -: COC' � j�/y I' '�� � � _. Vii' oa5z $G�� ► 4 a 7 I ��► • I �I `� © �� ��.ter 00� �� ° 4 �♦-. V / ., , 7 lt”- r'01.0110/ °Q '- * / & . °4'4•NiftliblaNalliw-liz:=4117 -°-?-_g_-v-L---41; -7:----71:- ...a -7''''' 41 �hOpOS —_-_ __::_i_00004100 00 ` ' � �I '" OOSSr11,0wo• f or oc sv 9 o r ',Cktm /(4f -1-3(f&- TEST- . • Zlit(t‘, TotarSafety U.S.,Inc. • 209 E.51st Avenue 11(_ 0), '.s _L..® Anchorage,AK 99503 7E,Vizz TOTAL SAFETY Phone:(907)743-9871 Fax:(907)743-9872 GAS DETEcTION,SYSTEM TEST SHEET Customer: /"14 , ,',, ' Onshore: ),,,,„ Offshore: Report Date: i Time: ° " AFE/Job#: i/670 f/./,c) Rig/Location: ,' 4 t. ' ,' ,', i." Drilling Company: Company Representitive: ), ), ,, ,, ..; - Telephone Number: Total Safety Technician: 'f- , ' '4 ,1 +'4, 4 t., Current Site Activity: Type of System: f) ',.; i" ),)).), Type of Test: Calibration .1/4, Bump Test „--/ Sensor#1 ' ' ' SenSork2 ' '. ',_ z , Sensor-#3 Type of Sensor: 1 I 7 , Type of Sensor: , 7°('' .4Type of Sensor: Location: ', Location: ' 7 : Location: Calibrated from: Calibrated from: -, 77,777' Calibrated from: Bumped at: ' Bumped at: -77 Bumped at: 55' ' Low alarm<30 seconds: ' -7 Low alarm<30 seconds: ,,,t,'" ., Low alarm <30 seconds: Battery Voltage: ,, ", Battery Voltage: ' ; '' Battery Voltage: — Comments: ' ' t t Comments: 77„ : t 7 Comments: 7.k. Sensor#4 ' Sensor#5 Sensor#6 Type of Sensor: 7 , , Type of Sensor: ,, t i: Type of Sensor: 7 Location: Location: Location: Calibrated from: ) Calibrated from: -,(2,7 Calibrated from: Bumped at: ' Bumped at: Bumped at: t '- Low alarm<30 seconds: 4, Low alarm<30 seconds: ,:,77 5 Low alarm<30 seconds: L4 . Battery Voltage: 7 „-' Battery Voltage: ,--,, .7,- Battery Voltage: Comments: 7, :t. Comments: :, 7 — Comments: 1 Sensor#7 . Sen,sor#8 ' - ' Sensor#9 Type of Sensor: 7 tt Type of Sensor: .7 r i Type of Sensor: Location: Location: Location: ,- Calibrated from: Calibrated from: Calibrated from: ---- Bumped at: -'t Bumped at: ° Bumped at: Low alarm<30 seconds: ' ,' t„, Low alarm<30 seconds: -.1 ' Low alarm<30 seconds: Battery Voltage: , -, t Battery Voltage: 4 i Battery Voltage: Comments: Comments: , t ,'7 Comments: k Sensor# 10 Sensor#1.1 Sensor#12 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm< 30 seconds: Low alarm<30 seconds: Low alarm<30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: "5 , ) ,„/ e'. 7-'-',./1--',---(27, Total Safety Technician Company Represenitive , , ,,, ,,,,, /1 ' / -; `' ''' Date: Date: White-Office Canary-Customer Pink-File - . • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, February 15, 2016 5:00 PM To: Joe Kaiser Cc: Quick, Michael J (DOA) Subject: Re: PTD: 180-104 Sundry 316-046 Update { ILA-°3 Joe, As per phone call you have approval to place balanced cement plug from 9770-9970ft. Plug will need to be tagged and pressure tested as we discussed. Please notify inspectors to witness tag and test. Also update MOC with changes. Regards, Guy Schwartz AOGCC SCANNED JUL 2 8 2016 Sent from my iPhone On Feb 15, 2016, at 3:30 PM,Joe Kaiser<jkaiser@hilcorp.com>wrote: Guy: To provide the latest update. It has bled down from 1,550 psi to 1,325psi in 50 min. Joe Kaiser KEN Operations Engineer Swanson River Field Ikaiser(a)hilcorp.corn 907-777-8393 Office 907-952-8897 Cell From: Joe Kaiser Sent: Monday, February 15, 2016 3:18 PM To: 'Schwartz, Guy L(DOA)' Cc: Chad Helgeson; Monty Myers; Shane Hauck; Luke Keller Subject: PTD: 180-104 Sundry 316-046 Update Guy: I left you a voice message. We ran in the hole with the window mill drift assembly of 6.059" mill top, 5.934" middle mill, 6.000" bottom mill.We touched down twice with 1,200 ft-lbs of torque. I am told the obstruction is a substantial piece of metal rather than a simple burr.They lift up, shut in the well,and pumped in the well bore.They staged up pressure w/test pump, 300 psi w/18 gal holding, 600 psi w/33 gals total holding, 1100 psi w/60.5 gal holding and 1550 psi with a total 82.5 gals. Pressure is currently being 1 • recorded on a chart. It appears to have bled down 50psi in 5min and still holding about—1500psi in 15min. We will hold the pressure for 30 min. I understand this is not the pressure test per the procedure (of 2500psig for 30 min), but it does show very poor to no injectivity.With the obstruction unknown and risk of mill through the casing,we would like to proceed with a 200' balance plug from 9,770'-9,970'. If you have any question or comments, please contact me on my cell phone 907-952-8897. Joe Kaiser KEN Operations Engineer Swanson River Field jkaiser(a)hilcorp.corn 907-777-8393 Office 907-952-8897 Cell 2 ••�OF T{� 0',\11/7 , s THE STATE• Alaska Oil and Gas ALAS KA Conservation Commission 333 West Seventh Avenue \TR' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS14 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager D J U L 2 7 2016, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 12A-03 Permit to Drill Number: 180-104 Sundry Number: 316-046 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this Z8'day of January, 2016. RBDMS t,k-- JAN 2 9 2016 • • RECEIVED • STATE OF ALASKA JAN 21 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION PTS J 2,G rib APPLICATION FOR SUNDRY APPROVALS ,AOG C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing O , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Prep4oi.Sidefrack—E. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Dnll Number: ` Exploratory ❑ Development ❑� - 180-104 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10099-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)12A-03 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028997 Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,850' ' 10,845' - 10,555' • 10,552' ' –184 10,555' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#,L-80 9,989' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker"D"Pkr;N/A 10,095'MD-10,093'TVD; N/A 12.Attachments: Proposal Summary ID Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0- Service ❑ 14. Estimated Date for 15.Well Status after proposed work: CommencingOperations: February 4,2016 OIL WINJ WDSPL P ❑ ❑ ❑ Suspended ❑' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ LI Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@.hilcorp.com _ Printed Name Chad Helgeson Title Operations Manager Signature (7 Phone 907-777-8405 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity IV BOP Test V Mechanical Integrity Test ❑ Location Clearance Cl Other: 3 s; - ,is:,, /30e (e 5f— '� / LL---,„...,/,,,,,,4-1 4_s if -: . Post Initial Injection MIT Req'd? Yes ❑ No ❑ r/ Spacing Exception Required? Yes El No Subsequent Form Required: / 0 ( 0 7'" RBDMS LA- iAtA2 9 2016 APPROVED BY / Approved by: , COMMISSIONER f)THE COMMISSIONfDate: /-2B--) fo aRvidGINAlfor -`a of p SubmitForm and Form 10-403 Revised 11/2015 12 months ffom the date of approval. Attachments in Duplicate (, vz. . f6 • • Well Prognosis Well: SCU 12A-03 Hilcor)Alaska,LL Date:01/21/2016 Well Name: SCU 12A-03 API Number: 50-133-10099-01 Current Status: SI Rod Pump Oil Well Leg: N �� Estimated Start Date: February 5th, 2016 Rig: Saxon 169 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 180-104 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: 1610111P Current Bottom Hole Pressure: — 1,232 psi @ 10,476' TVD (Static survey August 2012 mid perf of 10,479' MD) Maximum Expected BHP: — 1,232 psi @ 10,476' TVD (Static survey August 2012 mid perf of 10,479' MD) Max. Potential Surface Pressure: —184 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Soldotna Creek 12A-03 was drilled as a sidetrack of SCU 12-03 in 1982 to target H10 oil reserves in the lower part of the Hemlock formation. In 1984, a rig workover was conducted to isolate the H10 and run a tapered tubing string and complete the H8. The H2 and H4 were perforated through tubing in 1988, the H6 was perforated in 1991, and the H3 was perforated in 1995. A through tubing plug was set in 2000 to isolate the H8 and H10 sands and the H5 was perforated in 2000. The well was converted to rod pump in July 2013. A shallow rod part in the 1" rods was pulled and the rod replaced in December 2013. Parted rods in the 1" rods were found in May 2014 using the Aurora AWS #1 rig and then replaced in May 2014 with the Moncla #401. / November 5th, 2014 plunger rod broke at coupler attachment. Moncla #401 replaced downhole pump. Put back l ptlp in service on 11/8/2014. November 14th, 2014 a rod parted near the pump. Put back in service on 11/19/14. The well stopped pumping fluid to surface in late December 2014. The tubing did_not jug test, indicating a hole in the tubing. rte. +,✓ ,y- vje RWO Objective: Pull completion and plug back well in preparation for sidetrack. • � �,1:e49 �• ,� ` Notes Regarding Wellbore Condition v�` 6t,�''`'- • Rods to be pulled with Moncla #401 prior to work commencing under separate 10-403. °fC u c� Rig Work Procedure: 1. Blow-down any pressure on the well casing. 2. MIRU Saxon 169 Rig. 3. Kill well with 8.6 ppg PW by pumping down tubing. (may not circulate w/hole in tubing). 4. Set BPV. ND Tree. Notifications prior to BOP testing a. Notify BLM 48 hrs in advance of BOP test. b. AOGCC 24 hours athttp://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 5. N/U 11" x 5M BOP as follows: • • Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,Lb Date:01/21/2016 a. BOP configuration from Top down: 11" x 5M annular BOP/11" x 5M double ram/11" x 5M mud cross/11" x 5M single ram. b. Double ram should be dressed with 2-7/8" x 5"VBR in top cavity, blind ram in btm cavity. c. Single ram should be dressed with 2-7/8" x 5"VBR. d. N/U bell nipple, install flowline. 6. Run BOP test assy, land out test plug. a. Test BOP to 250/3500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. b. Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened. �5 c. Test VBRs on 4-1/2" test joint and 2-7/8" test joint. d. Ensure gas monitors are calibrated and tested in conjunction w/ BOPE. 7. R/D BOP test assy. 8. MU landing joints to the hanger. BOLDS. 9. Circulate well if possible. 10. Pull tubing hanger to the floor. 11. POOH with the completion string. Lay down all the 2-7/8" tubing, tubing anchor, and completion jewelry. 12. Clean and clear floor. 13. Ensure well is full of fluid. 14. RU E-line. 15. MU w/6.00" GR to 10,045'. RIH and tag top of 5" casing. POOH. LD GR assembly. a. If casing doesn't drift, RD E-line. MU bit and 7" scraper assembly on drill pipe and TIH to 10,045' MD. Circulate well clean. b. POOH w/drill pipe and lay down bit and scraper. 16. MU w/7" Cement Retainer and set at+/- 10,0E15''. POOH. 17. RD E-line 18. Hold a pre-job safety meeting over the upcoming squeeze operations. 19. TIH w/4-1/2" DP and sting into retainer. 20. Set down 10k- 15k lbs to verify retainer is set. 21. Establish an injection rate of 1 bbl/min. 22. Unsting from retainer and circulate hole clean. 23. Mix and pump 15 bbls of 15.8 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. 24. Displace DP with 122 bbls of 8.6 ppg PW. 25. Sting into retainer. 26. Displace DP with 10 bbls of 8.6 ppg PW effectively squeezing in 10 bbls of cement below retainer. 27. Unsting from retainer, break off top drive at the floor, pull 5 stands to -9,850',drop DP wiper ball and circulate a good surface to surface volume while slowly rotating DP. 28. POOH w/ DP standing back _ .- /�o'f-4 j CU '-v 29. PT casing to - t 0_ sig for 30 min w/chart. ,. Prete � 1s _z v . ia 30. RU E-Line to set CI P. g"` 31. RIH w/CIBP and set at 7,500' (5' above a collar). 32. RD E-Line. 33. PT Casing/CIBP to 2,5.00 psig for 30 min w/chart. - 34. PU whipstock, and mills.TIH to CIBP. II 0 • Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,LL Date:01/21/2016 35. Orient whipstock and set at 45 deg azimuth. Mill 6" window and 20'of new formation at 7,500'. 36. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** Calculations: Section: Calculation: Vol (BBLS) Vol (ft3) 7" Casing: 10,045' x .0371 bbl/ft = 373.2 2,095.2 5/I Casing to posiset plug: 510' x .0178 bbl/ft = t9•% 50.9 4.5" DP to Cmt Rtnr 10,005' x 0.0137 bbl/ft = 137.1 ,i 768.6 Slurry Information: System Conventional Density 15.8 lb/gal Yield 1.16 ft3/sk Mixed Water 4.829 gal/sk Mixed Fluid 5.168 gal/sk Expected Thickening 100 Bc at 05:48 hr:mn Expected ISO/API Fluid Loss 19 mL in 30.0 min at 170degF/ 1000 psi Code Description Concentration Additives G Cement 94 lb/sk D047 Anti Foam 0.2%BWOC D080 Dispersant 0.07% BWOC Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead Schematic 5. Blank RWO Procedure Change Form Soldotna Creek Unit H 0 • Well SCU 12A-03 ACTUAL SCHEMATIC Completion Ran:7/20/13 PTD: 180 104 Hibor',Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26'/New RKB=11' CASING AND TUBING DETAIL J 1 L 22" Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' 13-3/8" JEWELRY DETAIL tllIl 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line C _3) 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' 9 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 10 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin n S 11 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. c1 12 10,121' 1.995" 2.880" WLREG 13 10,555' Posiset Plug r14 10,699' - - Baker Mod.K-1 Retainer + 4 41 5 7 ZID 1 vct1 s- 8 8 E 9 ' , 10 11 , XN 12 > z J7" -- H-2 H-3 =- H-4 PERFORATIONS H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date H-2 10,410' 10,428' 10,407' 10,425' 18' 10-14 7/9/1997 It .-..d.„ =H -6 H-3 10,442' 10,450' 10,439' 10,447' 8' 10 7/9/97 C. H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 13 _ H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 - H-8 H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 - H-8 10,560' 10,590' 10,556' 10,586' 30' 10 7/9/97 = H-8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 14 �� Casing Split = H-10 H-10 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 J Q5„ PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Updated byJEK 1/8/16 Soldotna Creek Unit H 4) . Well SCU 12A-03 PROPOSED SCHEMATIC Completion Ran:7/20/13 PTD: 180-104 'blear.)Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26'/New RKB=11' CASING AND TUBING DETAIL J L 22" Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' 13 3/8" JEWELRY DETAIL No Depth ID OD Item 1 7,500' 7"Cast Iron Bridge Plug set for whipstock(proposed) • 2 10,005' HES"EZ"Drill Cmt Retainer(proposed) The following set on E-Line 3 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' 4 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 5 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 6 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. 7 10,121' 1.995" 2.880" WLREG 8 10,555' - - Posiset Plug 9 10,699' - - Baker Mod.K-1 Retainer w OC"9,870' • x!...TFI' = 2 L - e rE 3 > 1E 4 > s 5 .--------). 6 7 L J7" ''4, - H-2 H3k ..f" H-4 10,407'PERFORATIONS 7/9/1997 7H-5 Zone To10p4(M110D) Bt1m0,4(M228D) Top(TVD) Bt1m0,(4TV25D) Amt 1S0P-1F4 Comments Date " H 6 H-3 10,442' 10,450' 10,439' 10,447' 8' 10 7/9/97 r.- 4'+,6 H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 8 _ H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 H 8 H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 - H-8 10,560' 10,590' 10,556' 10,586' 30' 10 7/9/97 = H-8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 9 Casing Split -H-10 H-10 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 4 1 5" PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Updated by JEK 1/13/16 • ! • ifSoldotna Creek Unit ROPE SCHEMATIC SCU 12A-03 1/21/2016 Ild.ar 11.4. L1.1. Saxon 169 BOP stack SCU 12A-03 r 0 0 Min 1i1 Iii 1l 11$ di Model 6011i 11"-5000 , lfil Iii ill of 111 MP H giq I u 110 T-3 Energy2. '_ 4• ,to Model 7082 ., Blinds H CLI I 11"-5000 _ fl 1 r! Ow ij t, T-3 Energy .1i_:LID H [ •u�. e® Model 7082 H i 11"-5000 c-' 'L4 EW ,fa in rpt • . • llSwanson River WELLHEAD SCHEMATIC SCU12A-03 1/13/2016 Swanson River Tubing hanger,Seaboard, SCU 12A-03 ECO tension,7 1/16 5M X 2 133/8X7X27/8 7/8EUE lift and susp,w/2X type H BPV,3/8 control line, 5"slickneck,left to release, right to engage Full stainless steel for chemical injection Special Cross,2 9/16 5M FE X 2 7/8 EUE 8rd w/2-2 1/16 5M SSO Va15MF H,WO DD trim 16 11 \e ill r — - 07;41 1*/ 1 Valve, PE,g,W WK DD trim/16 , 5Mu' 24.00" • UIQ 0®® Grade Level Valve,master,WKM-M, 2 9/16 5M FE,HWO,DO trim ' t ;,•• nr— •r Adapter,Seaboard,7 1/16 111 1 SMFEX29/16SMw/S"PP - y,-�4. seal pocket,X control line ., exit,alloy material 411 I a jjj-_ Attachment spool,FMC-TC, , 7 1/16 5M X 7 1/16 5M 23"Overall length 1 I Iiilr_ Tubing head,Shaffer lit 1131 T55-LI,135/83M X - 71/165M w/2-21/165M It SSO,7"Type 1 secondary seal in head ;1011„ I , I oh%\• 1�� 111 Casing head,Shaffer KD, 135/83M X 133/8 SOW, 111 w/2-2"LPO,7"KD slips 111 I11 and packoff assy in head 01 0111 -g 1 .10,1-.' • • � � R / , � 2 / & Q 2 e c 2E ta 0oca / / 2 � ° § / < a E ® co E .4- 2 : § i 0 2 f ƒ . = 0 en / fl � > > 73 i 12 c \f a EO- § 112 .� el 13 ■ ■ ■ z CC 2 ® CO 0 $ / 0) Q o e- 77 ce @ v- k / B / 2 > Q) 9 2 \ 0 < / aa /� ci) "0 » g %/ a) 20 C J\ < .c L. L. E § a) a) o ° 0 .g 4 kf - \ 0 g la ±7 § ¢ § / / . co Qp c w > 2 @ en o § � § o a. k % Cd « @ ' 0 ca. u/ 2 § / E cu 0 _ e 2 � Q § 2 » R ® 0a) m .0 a) Q 2 .§ e $ ) 0 w 3 0 � < it / 0 ' .. 7 / • 5 q Q ■ ƒ r C fo 0 co 2 / 2 CO < <¢ • 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 Geologist )p. in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" 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 Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer 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 Stat Tech for 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 Stat Tech History tab 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 Stat Tech change 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 Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. • S Schwartz, Guy L (DOA) From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Tuesday,January 26, 2016 4:42 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson Subject: PTD: 180-104 SCU 12A-03 Decompletion RFI Guy: Per your request,the Geologist for Swanson River provided the following explanation for the Decompletion of SCU 12A- 03. The existing SCU 12A-03 is shut in due to a suspected hole in the tubing and a workover to repair this completion is considered sub-economic in the current price environment. However,the downhole directional orientation and casing depths of the existing well make it an optimal sidetrack candidate.The new well, SCU 31B-04, is designed to target the Hemlock sands and will be the producer drilled in parallel to the downdip SCU 322C-04 gas injection well. If you need anything further, please don't hesitate to contact me. Joe Kaiser KEN Operations Engineer Swanson River Field jkaiser(5)h it corp.com 907-777-8393 Office 907-952-8897 Cell 1 y OF Thy 110 wP //7, 7,�s THE STATE• Alaska Oil and Gas • � - � of j\ LASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA9�� Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNER FEB 2 4 2U6 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 12A-03 Permit to Drill Number: 180-104 Sundry Number: 316-020 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy ". Foerster Chair DATED this 21 s day of January, 2016. RBDMS '-‘-' JAN 2 2 2016 • • r RECEIVED STATE OF ALASKA JAN 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ,��,..' it 2 /4 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Rods E. 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development E. 180-104 , 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ii 6.API Number. Anchorage,Alaska 99503 50-133-10099-01 . 7. If perforating: 8,Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)12A-03 - Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 'Junk(MD): 10,850' 10,845' 10,555' 10,552' —184 10,555' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#,L-80 9,989' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker"D"Pkr;N/A 10,095'MD-10,093'TVD;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: January 25,2016 OIL . 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 the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@.hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature C�i�G G��/ '� ' Phone 907-777-8405 Date (ig/ )(v COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3\Le. — 020 Plug Integrity ❑ BOP Test 11 Mechanical Integrity Test ❑ Location Clearance n Other: Post Initial Injection MIT Req'd? fes ❑ No ❑ / Spacing Exception Required? Yes No d Subsequent Form Required: / 0 — L/ (9"--1 /) / APPROVED BY Approved by: _ _/,‘_„ 72.9,,.,4_,541/4._ COMMISSIONER THE COMMISSION Date:7— Z1—/w 7 ( —Z� --14, �'"" Submit Form and Form 10-403 Revised- /2015 I oJre tli <o V d for RBD Som the dlls Of t�r �!r / f , \\`\ LL J/1t� /// Attachments in Duplicate • • Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,LL Date: 1/8/2016 Well Name: SCU 12A-03 API Number: 50-133-10099-01 Current Status: SI Rod Pump Oil Well Leg: N/A Estimated Start Date: Jan 25th, 2016 Rig: Moncla#401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 180-104 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 1,232 psi @ 10,476' TVD (Static survey August 2012 mid perf of 10,479' MD) Maximum Expected BHP: — 1,232 psi @ 10,476' TVD (Static survey August 2012 mid perf of 10,479' MD) Max. Potential Surface Pressure: —184 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Soldotna Creek 12A-03 was drilled as a sidetrack of SCU 12-03 in 1982 to target H10 oil reserves in the lower part of the Hemlock formation. In 1984, a rig workover was conducted to isolate the H10 and run a tapered tubing string and complete the H8. The H2 and H4 were perforated through tubing in 1988, the H6 was perforated in 1991, and the H3 was perforated in 1995. A through tubing plug was set in 2000 to isolate the H8 and H10 sands and the H5 was perforated in 2000. The well was converted to rod pump in July 2013. The rods have parted several times and been replaced or repaired in December 2013, May 2014 and November 2014. The well stopped pumping fluid to surface in late December 2014 and was determined to be a/hole in the tubing and the well has been shut-in. RWO Objective: Pull rods in preparation for decompletion and plugback for a side track. / Notes Regarding Wellbore Condition • Rods are currently in the well with expected hole in tubing. • Lufkin Pumping Unit will be rigged down and removed prior to rig mobilization. RWO Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla #401 WO Rig. -- 3. Nipple up rod stripper head. 4. Unseat pump. Pull out of hole 2 rod joints. LD rod joints. 5. Pump 8.6 ppg hot water down tubing. Approximately 120 bbls (2 tubing volumes). Due to open perforations, no returns are anticipated to surface, but have tank on hand to take returns. 6. POOH with and LD rods, pump and sand screen. 7. LD memory gauge. Turn over to Weatherford to download data. 8. ND rod stripper head. 9. Shut and secure valves on Tree. 10. Rig down and move out Moncla#401 WO Rig 11. Turn well over to Operations • • Well Prognosis Well: SCU 12A-03 uae01) %Iaska.LL Date: 1/8/2016 Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Schematic 4. Blank RWO Change Order Form Soldotna Creek Unit H . • Well SCU 12A-03 ACTUAL SCHEMATIC Completion Ran:7/20/13 PTD:l 180404 • Hikoru Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26' New RKB=11' CASING AND TUBING DETAIL J A it, 1 L 22" Size WT Grade Conn ID Top Btm 22" Surface 28' 13-3/8" 54.5 - - 10.050 Surface _ 3,000' Suspected B 7" 29 P-110 - 6.184 Surface 10,265' Hole in 5" 18 N-80 - 4.276 10,045' 10,848' Tubing TUBING (Shallow) 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' 13-3/8" JEWELRY DETAIL 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line Tubing C 1 8 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' Anchor D 9 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long = 3 10 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin possibly unset * 11 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. I 12 10,121' 1.995" 2.880" WLREG E 1-- 13 10,555' 14 10,699' Posiset Plug Baker Mod.K-1 Retainer 4 e` 5 F € G ki 6 ROD DETAIL NIL 7 No Depth Length OD Item A 11' 26' 1-1/2" Polished Rod(New 6/18/14) B 37' 4' 1" 1"Pony Rods(4') 41' 2,725' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(109) 8 >Z. " 2,766' 2,900' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(116) 9 >1 ; 5,666' 3,900' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(156) 10 ---------). C 9,566' 350' 1-1/2" 1-1/2"x 25'K Bars(weight bars) 11 ______- xN D 9,916' 2.5' 1" 2-1/2"x 2.5'Stabilizer Bar w/3/4"Pins E 9,919' 25' 1-3/4" 1-3/4"x 25'Insert Pump,RHBC Pump w/PA Ring 12 > 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 24"x 24-1/2"x L J 7" 25'RHBC(New 11/06/14) F 9,944' 1' 1.315" Sand Screen H-2 G 9,945' 2.54' 1.250" 1-1/4"Memory Gauge(Welded coupling to screen) H-3 H-4 PERFORATIONS H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date H-2 10,410' 10,428' 10,407' 10,425' 18' 10-14 7/9/1997 H-6 H-3 10,442' 10,450' 10,439' 10,447' 8' 10 7/9/97 n 4 H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 13 H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 U H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 H-8 H-8 10,560' 10,590' 10,556' 10,586' 30' 10 7/9/97 H-8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 14 >••C Casing Split H-10 H-10 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 D k 5„ PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Downhole Revised:12/26/14 Updated by STP 12/31/14 Soldotna Creek Unit H . • Well SCU 12A-03 PROPOSED SCHEMATIC Completion PTD:D: 18CU-12 4 • Hilcora Alaska.LLC API: 50-133-10099-01 Orifi.RKB = 26'/New RKB=11' CASING AND TUBING DETAIL J 1 L 22" Size WT Grade Conn ID Top Btm 22" - _ - Surface 28' 13-3/8" 54.5 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' s 13-3/8" JEWELRY DETAIL 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub :Iiimp 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line 8 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' 9 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 10 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 11 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. 12 10,121' 1.995" 2.880" WLREG 13 10,555' - - Posiset Plug 14 10,699' - - Baker Mod.K-1 Retainer 4 r 5 6 ID 7 10 -- 11 -�f\N 12 > L L.7' -- H-2 H-3 - H-4 PERFORATIONS -_ H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date H-2 10,410' 10,428' 10,407' 10,425' 18' 10-14 7/9/1997 =H -6 H-3 10,442' 10,450' 10,439' 10,447' 8' 10 7/9/97 ri' *I H-4 10,460' 10,478' 10,457' 10,475' 18' 6-10-14 7/9/97 13 H-5 10,487' 10,530' 10,484' 10,527' 43' 6 3/11/00 U - H-6 10,540' 10,548' 10,536' 10,544' 8' 6 7/9/97 - = H-8 H-8 10,560' 10,590' 10,556' 10,586' 30' 10 7/9/97 = H-8 H-8 10,598' 10,602' 10,594' 10,598' 4' 4 2/84 141_ Casing Split - H-10 H-10 10,716' 10,730' 10,711' 10,725' 14' 4 (Isolated) 12/82 4 h s" PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Updated byJEK 1/8/16 • S Swanson River WELLHEAD SCHEMATIC SCU12A-03 If.h,:r1, U+r.r,.,.u.c 1/08/2016 Swanson River Tubing hanger,Seaboard, SCU 12A-03 ECO tension,7 1/16 5M X 2 133/8X7X27/8 7/8EUE lift and susp,w/2'4 type H BPV,3/8 control line, 5"slickneck,left to release, right to engage Full stainless steel for chemical injection Special Cross,2 9/16 5M FE X 2 7/8 EUE 8rd w/2-2 1/16 5M SSO Valve,wing,WKM-M,21/16 - 1-0,),410 Valve,wing,WKM-M,21/16 SM FE,HWO,DD trim 5M FE,HWO,DD trim 24.00" +®s' ono n a. 'r, Grade Level Valve,master,WKM-M, g �, 2 9/16 5M FE,HWO,DD trim :e Adapter,Seaboard,71/16 rlr r�r SMFEX29/165Mw/5"PP seal pocket,Y:control line exit,alloy material ■riI_I -I Attachment spool,FMC-TC, 7 1/16 5M X 7 1/16 5M 23"Overall length r 1-1 :.'N f.■c Tubing head,Shaffer ILll T55-LI,13 5/8 3M X 7 Type 2-21/16 ary \ �. '•` SSO,7"Type 1 secondary !.n* �'_ seal in head Ii III 1#i Casing head,Shaffer KD, SOW, ir- 135/83MXi33/8 and packoff assy in head111 IMI SO MO . • 0 � 0 / S. C Q _ ■ 2& e § $ E 0o■ 0o 2 �� § / « � E ® EF Sy '0 t Zs \ ( 1 C� 2 \ cc k / tn / � 50.� �� F. > _ IQ � C \$ a gE § .\ CI -0 ■ ■ 3 \ � � � k k 4 S% 2� >- 077 Z g � k .- ao irl w o . / o «tft. cm k U 4. %- = 2 2 /� U) "CS R C MS0 & co 7 ? 2 Jc < _ 0 e E § C) c no 2 /o 'K 2 L � / / a) \ / a. g 0 ±7 § § § / / E 'En Gp co LU a) > 2 2 2 2 % @ 0 cm K � Cd « CO > 0CL - .2 CO ca 2 zQ ■ a 0 R e o (0 .0 a Q < § / a) e 0 2 6 0 •-• 2 - _ 5 ® E / 2 CO Cl) C < < • , Schwartz, Guy L (DOA) �17�0 From: Schwartz, Guy L(DOA) Sent: Monday,January 11, 2016 8:42 AM To: 'Donna Ambruz' Cc: Chad Helgeson;Joe Kaiser;samantha.carlisle@alaska.gov Subject: RE: Sundry Cancellation - Sundry# 315-002 - SCU 12A-03 (PTD 180-104) Trudi, AOGCC will withdraw approved sundry#315-002 to pull rod pump and tubing in well SCU 12A-03. Regards, Guy Schwartz Sr. Petroleum Engineer 'jc AOGCC M A 907-301-4533 cell RBD 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). From: Donna Ambruz [mailto:dambruz@ hilcorp.com] Sent: Friday, January 08, 2016 10:45 AM To: Schwartz, Guy L (DOA) Cc: Chad Helgeson; Joe Kaiser Subject: Sundry Cancellation - Sundry # 315-002 - SCU 12A-03 (PTD 180-104) Guy, Please withdraw the above mentioned sundry. Thank you. SCANNED MAR 1 7 2016 Omuta Qtnf wz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305 - Direct 907.777.8310- Fax dambruz@hilcorp.com 1 Imac. act Well History File Cover I~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. j .~ _~- J _~ ~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT~:~ MARIA WINDY Project Proofing BY: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds n Other OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation BY: ~~L ROBIN VINCENT SHERYL MARIA WINDY Production Scanning /~J~'-F Stage l PAGE COUNT FROM SCANNED FILE: - ,,,, PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BAS18 ~)UE TO QUALITY. GRAYECALE OR COLOR IMAGES) NO NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; ~si General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned,wpd 333 vve Severin Av, n:;e \ f 1�yc�R �EP��d I �- L�ELIAnchorage f ;arka 99501 3572 .P�d G . _ . � `in 90 /279 / 33 " A, ( DLI. Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field/Hemlock Oil Pool, Soldotna Creek Unit 12A-03 Sundry Number: 314-329 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this day of May, 2014. Encl. N�� �uL 6 'Z�'�14 S�aN STATE OF ALASKA r,' `'i k i "4 ALASKA OIL AND GAS CONSERVATION COMMISSION O 1�Z2�I ¢` APPLICATION FOR SUNDRY APPROVALS AO GCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate[I] Alter Casing❑ Other. Rod Pump Repair Q • 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development Q . 180-104 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic El Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10099-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B • CI Creek Unit(SCU)12A-03 • Will planned perforations require a spacing exception? Yes El No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997• Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,850' • 10,845' • 10,555' 10,695' 10,555' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate • Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530p si Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#,L-80 9,989 Packers and SSSV Type: Baker"D"Pkr;N/A Packers and SSSV MD(t)and ND(ft): 10,095 MD-10,093'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after prorosed work: 05/26/14 Commencing Operations: Oil Q . Gas ❑ 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 Stan Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.corr1 Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date SA COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t-t.- 2'k Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / l /- 0.1--; !.i S.n e<i11^ - ;r p r l'- f t "<1-1--6-4-1Isr(h S p C,'.e-47 Zi"' Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: , C - V 0 LI APPROVED BY _ Approved by:ffe ) COMMISSIONER THE COMMISSION Date: .) "2,2___—)I (Revised t0 `2/ pp �4�i4,4 A pp Submit Form and Form 10-403 Revised 1 2012 A r0 a i i f 1 months from the date of approval. Attachments in Duplicate Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,LL Date:5/21/2014 Well Name: SCU 12A-03 API Number: 50-133-10099-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 26th, 2014 Rig: Moncla#401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 180-104 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,232 psi @ 10,476' ND (Static survey August 2012 mid perf of 10,479' MD) Maximum Expected BHP: — 1,232 psi @ 10,476' ND (Static survey August 2012 mid perf of 10,479' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) Brief Well Summary Soldotna Creek 12A-03 was drilled as a sidetrack of SCU 12-03 in 1982 to target H10 oil reserves in the lower part of the Hemlock formation. In 1984,a rig workover was conducted to isolate the H10 and run a tapered tubing string and complete the H8.The H2 and H4 were perforated through tubing in 1988,the H6 was perforated in 1991,and the H3 was perforated in 1995.A through tubing plug was set in 2000 to isolate the H8 and H10 sands and the H5 was perforated in 2000.The well was converted to rod pump in July 2013.A shallow rod part in the 1" rods was pulled and the rod replaced in December 2013. Parted rods in the 1" rods were found in May 2014 using the Aurora AWS#1 rig.The rig was unable to fish the rods so a blind backoff was made in the 7/8" rods at 4,875' RKB.They were unable to screw back into these rods and the rig was moved off this well. The purpose of this work/sundry is to use the Moncla#401 to continue to fish out the rod string. ✓ Notes Regarding Wellbore Condition • The rod string is separated at 4,875' in the 7/8" rods with a box looking up. • Plan to pull and replace the failed rod and change out the pump. Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla#401 WO Rig. 3. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD parted rod (rods separated at 4,875'; 7/8" rod box). 6. PU overshot and fish parted rods and LD parted rod. 7. LD and inspect pump and dip tube and all pulled rods. 8. PU existing dip tube and new 1-3/4" rod pump, replace parted rod and RIH wit new rod s ng (sinker bars, 3/4", 7/8"and 1), space out the rods, install new polish rod. 9. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 10. Rig up Lufkin pumping unit head and connect bridle to polished rod. 11. RD Moncla#401 WO Rig. Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,LL Date:5/21/2014 12. Return to production with same surface safety system as previously installed. 13. Replace IA x OA pressure gauge if removed (7"x 13-3/8"). Attachments: 1. Actual Schematic Soldotna Creek Unit Well SCU 12A-03 ACTUAL SCHEMATIC PTPTD: 18D: 180-104-104 7/20/13 Nikon.Alaska.LLC API: 50-133-10099-01 1 Orig.RKB = 26' New RKB=11' CASING AND TUBING DETAIL J A 1 1 L22 Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' B 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' —.._ \ '13-3/8" JEWELRY DETAIL 2 No Depth ID OD Item Backed Off I 1141 1 24' - _ - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 7/8" 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub Rod Box @ \ .. 3 9,918' 2.420" 5.530" Tubing Anchor 4,875' 4 9,951' 2.255" 2.875" Seating Nipple I 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line C 13 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' D 14 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 15 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 16 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. t17 10,121' 1.995" 2.880" WLREG E 18 10,555' _- Posiset Plug 4 19 10,699' - Baker Mod.K-1 Retainer d 5 F t 6 s: 7 ZROX D DETAIL No Depth Length OD Item A 0' 26' 1-1/2" Polished Rod 13 1 ' B 26' 24' 1" 1"Pony Rods(2,4,4,6,8) 14 > 50' 2,825' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(113) 15 ® 2,875' 2,900' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(116) 16 . 5,775' 3,725' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(149) 17 >MN C 9,500' 350' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,850' 2.5' 1" 2-1/2"x 2.5'Stabilizer Bar w/'A"Pins G ,7" E 9,853' 25' 1-3/4" 1-3/4"x 25'Insert Pump,RHBC Pump w/PA Ring -- H-2 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 24"x 24-1/2"x 25'RHBC - H-3 F 9,878' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom = H-4 PERFORATIONS = H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date - H-6 H-2 10,410' 10,428' 18' 10-14 7/9/1997 H-3 10,442' 10,450' 8' 10 7/9/97 H-4 10,460' 10,478' 18' 6-10-14 7/9/97 18 � H-5 10,487' 10,530' 43' 6 3/11/00 U — H-6 10,540' 10,548' 8' 6 7/9/97 = H-8 . — H-8 10,560' 10,590' 30' 10 7/9/97 = H-8 H-8 10,598' 10,602' 4' 4 _ 2/84 19 ">".< Casing Split =H-10 H-30 10,716' 10,730' 14' 4 (Isolated) 12/82 LR 5" PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Downhole Revised:5/08/14 Updated by STP 5/21/14 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM SON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Repair Well H Plug Perforations U Perforate LJ Other U Rod Pump Repair 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 Q Exploratory ❑ • 180-104 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 ' 50-133-10099-01 7.Property Designation(Lease Number): 8.Well Name and Number: • FEDA028997 " Soldotna Creek Unit(SCU)12A-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: +„ 0. Total Depth measured a 10,850 feet Plugs measured 10,555 feet ' true vertical 10,845 feet Junk measured N/A feet Effective Depth measured I 10,555 feet Packer measured 10,095 feet true vertical 10,552 feet true vertical 10,093 feet 1 1,- , -. Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED MAY 2 7 2014 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 9,989'MD 9,987'TVD Packers and SSSV(type,measured and true vertical depth) Baker"D";N/A 10,095'MD 10,093'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A RBDMskmAY 2 0 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 175 175 Subsequent to operation: 0 0 0 175 175 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q• Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil t 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-264 Contact Stan Porhola Email Sporhola(CDhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature l Phone 907-777-8412 Date Vi....///t j'�( I'( Form 10-404 Revised 10/2012 f Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-03 50-133-10099-01 180-104 5/4/14 5/8/14 Daily Operations: 05/04/2014-Sunday j Rig down from SCU 12A-04, MOB rig and equipment to SCU 12A-03,Rig 100%moved to new location. Rig up berms set light plant,fuel tank, position rig over well,bleed down well. Lay down polish rod, pups, pick up two rods and tag fish,TOF at 1,080'. POOH, lay down rod with broken box. Pick up 2-5/16" Series 10 over shot with 2"spiral grapple. RIH, latch onto fish, took 37 turns to left to get rods to back off. Lay down two rods and shut well in. SDFN. 05/05/2014- Monday Bleed down well, pull 14 std rods, lay down overshot. POOH with 14 stds rods. TOF at 4,875'. P/U 2-5/16"overshot with 1.875"spiral grapple. RIH,tag top of fish at 4,875',did not pick up any wt. POOH, no recovery, RIH with 7/8" rod pin,to top of fish at 4,875'. Try to screw in torque up, pickup 5K overweight then dropped off, broke ratigan with back torgue,strip off ratigan, remove flange, replace flange, install new ratigan. SDFN. 05/06/2014-Tuesday Bleed down well,change out pup on rod table. POOH with 2-5/16"overshot with 1.875" spiral grapple. 36 stands 1' rods,29 stands 7/8' rods. Wait on 2-5/16" overshot from Knight Oil Tools. Make up 2-5/16"overshot with 1.875"spiral grapple, RIH with (2)9-7/8" rods, (36)1' 1' rods,try to work overshot over fish at 4,875', no weight gain. POOH with 2-5/16"overshot with 1.875"spiral grapple. 36 stands 1' rods, 29 stands 7/8' rods. lay down overshot. Wait on Pollard Wireline to run LIB. Run LIB shows rod box looking up. Make up 2-5/16" overshot with 1.750" spiral grapple, RIH with(2) 9-7/8' rods, (36) 1' 1' rods. Try to work overshot over fish at 4,875', no weight gain. SDFN. 05/07/2014-Wednesday Change out hyd. rod tongs. POOH with overshot. Lay down overshot. RIH with 7/8" rod pin down,try to engage fish at 4,875' by rotating down. Rig up BJ tubing tongs to rotate rods. Did not screw into fish. POOH. Make up 2.125" series 10 overshot with 1.813"grapple to 4,875'. Did not engage fish. Laydown pups secure well. 05/08/2014-Thursday Pickup polish rod,shut in well, Rig down. Suspend operations. r'1 qt.!I i�, s i.1,)-° Soldotna Creek Unit , ii Well SCU 12A-03 ACTUAL SCHEMATIC Completion WellSCU12A-n:7/20/13 nil�Orn Alaska.LLC PTD: 180-104 API: 50-133-10099-01 Orig.RKB = 26' New RKB=11' CASING AND TUBING DETAIL J A E r. 1 L_22 Size WT Grade Conn ID Top Btm 22" Surface 28' 13 3/8" 54.5 10.050 Surface 3,000' 7" 29 P-110 _ - 6.184 Surface 10,265' B 5" 18 N-80 - 4.276 10,045' 10,848' TUBING 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' 13-3/8" JEWELRY DETAIL 2 No Depth ID OD Item Backed Off 111 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 7/8" 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub Rod Box @ 3 9,918' 2.420" 5.530" Tubing Anchor 4,875' 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line C 13 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' D 14 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long in ik. 3 15 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 16 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. 17 10,121' 1.995" 2.880" WLREG E 118I 10,555' - - Posiset Plug 19 10,699' - - Baker Mod.K-1 Retainer i 4 5 F 6 7 ROD DETAIL No Depth Length OD Item 13 ,z�7 A 0' 26' 1-1/2" Polished Rod . B 26' 24' 1" 1"Pony Rods(2',4',4',6',8') 14 L'L' 50' 2,825' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(113) 15 —� 2,875' 2,900' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(116) 16 , xH 5,775' 3,725' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(149) 17 > C 9,500' 350' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,850' 2.5' 1" 2-1/2"x 2.5'Stabilizer Bar w/'/,"Pins L `,7" E 9,853' 25' 1-3/4" 1-3/4"x 25'Insert Pump,RHBC Pump w/PA Ring _ H 2 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 24"x 24-1/2"x 25'RHBC _= H-3 F 9,878' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom = H-4 PERFORATIONS H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date = H-6 H-2 10,410' 10,428' 18' 10-14 7/9/1997 H-3 10,442' 10,450' 8' 10 7/9/97 18 � i'l H-4 10,460' 10,478' 18' 6-10-14 7/9/97 MEE H-5 10,487' 10,530' 43' 6 3/11/00 _ LI — H-6 10,540' 10,548' 8' 6 7/9/97 = H-8 — H-8 10,560' 10,590' 30' 10 7/9/97 =_ H-8 H-8 10,598' 10,602' 4' 4 2/84 19 �� Casing Split =H-10 H-10 10,716' 10,730' 14' 4 (Isolated) 12/82 A Q 5" PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Downhole Revised:5/08/14 Updated by STP 5/21/14 STATE OF ALASKA ALA. t OIL AND GAS CONSERVATION COMMI. JN , - a I Z013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other pi Rod Pump Repair 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 Q Exploratory ❑ • 180-104 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 • 50-133-10099-01 7.Property Designation(Lease Number): 8.Well Name and Number: • FEDA028997 • Soldotna Creek Unit(SCU)12A-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,850 feet Plugs measured 10,555 feet true vertical 10,845 feet Junk measured N/A feet Effective Depth measured • 10,555 feet Packer measured 10,095 feet true vertical 10,552 feet true vertical 10,093 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic NES MAY 2 ` 2014 SCAN Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 9,989'MD 9,987'TVD Packers and SSSV(type,measured and true vertical depth) Baker"D";N/A 10,095'MD 10,093'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A RBDMS�MAY 16 2014 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: 39 65 170 158 158 Subsequent to operation: 25 35 163 140 140 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q i Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil •Ei Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-628 Contact Stan Porhola Email sporhola(c hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature "l �l...___ Phone 907-777-8412 Date /7/2_7//3 /L, S-7z -l`-( Form 10-404 Revised 10/2012 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 12A-03 50-133-10099-01 180-104 12/6/13 12/7/13 Daily Operations: 12/06/2013 - Friday Rigging up. Rig over to pull rods. Pull 30 triple and double= 2,300 Ft. of 1" rods. 1" Rod box parted. Clean up,work on tools. Waiting on fishing tool. Fish rods pull pump off seat. Pull 2 rods out run polish in well for night. SDFN. 12/07/2013 -Saturday Pump field water down well 35bbls. Pull up to fish, lay down fish, used a overshot with a 2" GR to fish a 2" box. POOH, lay down pump, was beating bottom, break down fishing tools. RIH, change out 2 = 1"x 25' rods and lay down 1 = 1" x 8' pony rod pump 40" off bottom, hang horse head, test stuffing box 500 psi. Rig down rig, turn well over to production. Soldotna Creek Unit II Well SCU 12A-03 • ACTUAL SCHEMATIC Completion WellSCU12A-n:7/20/13 !Worn Alaska.r.�.c PTD: 180-104 API: 50-133-10099-01 Orig.RKB = 26' New RKB=11' CASING AND TUBING DETAIL J A 1 L 1 1 L22" Size WT Grade Conn ID Top Btm 22" - - - Surface 28' 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' B 5" 18 N-80 - 4.276 10,045' 10,848' Suspect TUBING Rod part @ 2-7/8" 6.5 L-80 EUE 8RD 2.441 Surface 9,989' +/-2,000' 13 3/8" JEWELRY DETAIL 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug The following set on E-Line C 13 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' D _ 14 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 15 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin 16 10,114' 1.875" 2.700" `XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. 17 10,121' 1.995" 2.880" WLREG E 18 10,555' - - Posiset Plug 19 10,699' - - Baker Mod.K-1 Retainer 4 = 5 F 'l ` 6 7 z r ROD DETAIL No Depth Length OD Item �7 A 0' 26' 1-1/2" Polished Rod 13 X B 26' 24' 1" 1"Pony Rods(2',4',4',6',8') 14 L->�i 50' 2,825' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(113) 15 - i 2,875' 2,900' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(116) 16 sw 5,775' 3,725' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(149) 17 > C 9,500' 350' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,850' 2.5' 1" 2-1/2"x 2.5'Stabilizer Bar w/''A"Pins L L.7,. E 9,853' 25' 1-3/4" 1-3/4"x 25'Insert Pump,RHBC Pump w/PA Ring H-2 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 24"x 24-1/2"x 25'RHBC H-3 F 9,878' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom H-4 PERFORATIONS H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date H-2 10,410' 10,428' 18' 10-14 7/9/1997 H-6 H-3 10,442' 10,450' 8' 10 7/9/97 r H-4 10,460' 10,478' 18' 6-10-14 7/9/97 18 H-5 10,487' 10,530' 43' 6 3/11/00 H-8 H-6 10,540' 10,548' 8' 6 7/9/97 H-8 10,560' 10,590' 30' 10 7/9/97 H-8 H-8 10,598' 10,602' 4' 4 2/84 19 Casing Split H-10 H-10 10,716' 10,730' 14' 4 (Isolated) 12/82 a ih. 5„ PBTD= 10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Downhole Revised:12/02/13 Updated by STP 12/04/13 • \ I%% sv THE STATE Alaska Oil and Gas ofALl 1VKl 1 Conservation seIi Tatio Como Ilssion GOVERNOR SEAN PARNELL TR. 333 West Seventh Avenue OF .,,nr ;,', p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 n Fax: 907.276.7542 Stan Porhola Sat NEB 1SV Operation Engineer I Hilcorp Alaska, LLC � l� 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 12A-03 Sundry Number: 313-628 Dear Mr. Porhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a 1,6 P9qt-,44__ Cathy P. Foerster Chair DATED this ay of December, 2013. Encl. III Ex) y RECEIVED j STATE OF ALASKA 1t DEC 0 401 ALASKA OIL AND GAS CONSERVATION COMMISSION p-T-s 1244 13 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well El Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Rod Pump Repair El r 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 • 180-104 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10099-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)12A-03 _ Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,850' • 10,845' • 10,555' 10,695' 10,555' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,265' 7" 10,265' 10,263' 9,520 psi 8,530 psi Liner 845' 5" 10,844' 10,839' 9,910 psi 10,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#,L-80 9,989' Packers and SSSV Type: Baker"D"Pkr;N/A Packers and SSSV MD(t)and ND(ft): 10,095 MD-10,093'ND;N/A 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: . Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphirn Development n Service n 14.Estimated Date for 15.Well Status after proKosed work: 12/05/13 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: a...f.r 3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: t✓ S-G I-Y-- GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing ii true and correct to the best of my knowledge. Contact Stan Porhda Phone: 907-777-8412 Email sOOrholat hilcorD.cortl Printed Name Stan Porhola Title Operations Engineer Signature A /L/9rL ._ Phone 907-777-8412 Date (2 0 y//3 COMMISSION USE ONLY >� l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `3V3.. C,a2lf Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: Jo —'Yo y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /2 —G _ /3 __47 1 � 1 - NAIL a� Submit Form and P� .�I Form 10-403(Revised 10/2012) App °, i months from tpq teAf?pproyll.0 1 3 �ij Attachments in Duplicate D ,`,� 1 j'"( i�J]Za IX JlJ`� / (.24f0/ \1'1 • • Well Prognosis Well: SCU 12A-03 Hilcorp Alaska,Lb Date:12/04/2013 Well Name: SCU 12A-03 API Number: 50-133-10099-01 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: December 4, 2013 Rig: Moncla 405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 180-104 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: 1353414 Current Bottom Hole Pressure: — 1,232 psi @ 10,476' TVD (Static survey August 2012 mid perf of 10,479' MD) Maximum Expected BHP: — 1,232 psi @ 10,476' ND (Static survey August 2012 mid perf of 10,479' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) Brief Well Summary Soldotna Creek 12A-03 was drilled as a sidetrack of SCU 12-03 in 1982 to target H10 oil reserves in the lower part of the Hemlock formation. In 1984,a rig workover was conducted to isolate the H10 and run a tapered tubing string and complete the H8.The H2 and H4 were perforated through tubing in 1988,the H6 was perforated in 1991,and the H3 was perforated in 1995.A through tubing plug was set in 2000 to isolate the H8 and H10 sands and the H5 was perforated in 2000.The well was converted to rod pump in July 2013. Notes Regarding Wellbore Condition • The rod string is showing 6,000 Ibs, indicating parted rods at approx. 2,000' in the 1" rods. • Plan to pull and replace the failed rod and change out the pump. Brief Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. MIRU Moncla#405 WO Rig. 3. Rig down Lufkin pumping unit head. Nipple up rod stripper head. 4. LD polish rod and pull EL rods. Rack back the rods in basket. 5. LD parted rod (suspected part depth at+/-2,000'; 1" rods). 6. PU overshot and fish parted rods and LD parted rod. 7. LD and inspect pump and dip tube and all pulled rods. 8. PU existing dip tube and new 1-3/4"rod pump, replace parted rod and RIH with existing tapered rod string(sinker bars, 3/4",7/8" and 1), space out the rods, install polish rod. 9. ND rod stripper, install surface equipment onto well and test to 3,000 psi. 10. Rig up Lufkin pumping unit head and connect bridle to polished rod. 11. RD Moncla#405 WO Rig. 12. Return to production with same surface safety system as previously installed. 13. Replace IA x OA pressure gauge if removed (7"x 13-3/8"). Attachments: 1. Actual Schematic Soldotna Creek Unit •+ • • Well SCU 12A-03 ACTUAL SCHEMATIC Completion n:7/20/13 PTD: 180-104 104 Hileoro Alaska.LLC API: 50-133-10099-01 Orig.RKB = 26' New RKB=11' CASING AND TUBING DETAIL J A a'l! 1 L 22" Size WT Grade Conn ID Top Btm r 22" - - - Surface 28' ( 13-3/8" 54.5 - - 10.050 Surface 3,000' 7" 29 P-110 - 6.184 Surface 10,265' B 5" 18 N-80 4.276 10,045' 10,848' Suspect TUBING Rod part @ 2-7/8" I 6.5 L-80 I EUE 8RD 1 2.441 Surface I 9,989' +/-2,000' 13 3/8" JEWELRY DETAIL 2 No Depth ID OD Item 1 24' - - 2-7/8"Seaboard Tubing Hanger,Type'H'BPV 2 4,297' 2.441" 5.000" 2-7/8"Depth Indicator Sub 3 9,918' 2.420" 5.530" Tubing Anchor 4 9,951' 2.255" 2.875" Seating Nipple 5 9,952' 2.441" 2.875" Slotted Flow Sub 6 9,956' 2.992" 3.500" 1 joint 3-1/2"tubing,EUE 8RD(Gas Anchor) 7 9,988' - 3.500" Bull Plug l The following set on E-Line C I 13 10,095' 2.688" 3.968" Packer,2-7/8 x 5"Baker Mod.'D' D ` 14 10,097' 2.688" 3.650" Seal Bore Extension,9.45'Long 3 15 10,107' 1.995" 3.750" Crossover,Seal Bore Extension x 2-3/8"Butt Pin I 16 10,114' 1.875" 2.700" 'XN'Nipple,2-3/8"EUE 8rd,2.313 w/2.25"N.G. I 17 10,121' 1.995" 2.880" WLREG E ' 18 10,555' - - Posiset Plug 19 10,699' - - Baker Mod.K-1 Retainer 1 14 5 F ig6 7 ROD DETAIL No Depth Length OD Item A 0' 26' 1-1/2" Polished Rod 13 = " B 26' 24' 1" 1"Pony Rods(2',4',4',6',8') 14 > 50' 2,825' 1" 1"x 25'EL Sucker rods w/4 XL guides per rod(113) 15 > 2,875' 2,900' 7/8" 7/8"x 25'EL Sucker rods w/4 XL guides per rod(116) 16 ,® 5,775' 3,725' 3/4" 3/4"x 25'EL Sucker rods w/4 XL guides per rod(149) 17 > C 9,500' 350' 1-1/2" 1-1/2"x 25'K Bars(weight bars) D 9,850' 2.5' 1" 2-1/2"x 2.5'Stabilizer Bar w/'/"Pins Z ' 7" E 9,853' 25' 1-3/4" 1-3/4"x 25'Insert Pump,RHBC Pump w/PA Ring H 2 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 24"x 24-1/2"x 25'RHBC H-3 F 9,878' 20' 1.315" Dip Tube,bottom 1'ported,bull plug on bottom H-4 PERFORATIONS H-5 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date H-2 10,410' 10,428' 18' 10-14 7/9/1997 H-6 H-3 10,442' 10,450' 8' 10 7/9/97 I's H-4 10,460' 10,478' 18' 6-10-14 7/9/97 18 H-5 10,487' 10,530' 43' 6 3/11/00 T H-6 10,540' 10,548' 8' 6 7/9/97 H-8 H-8 10,560' 10,590' 30' 10 7/9/97 H-8 H-8 10,598' 10,602' 4' 4 2/84 19 . 'l Casing Split H-10 H-30 10,716' 10,730' 14' 4 (Isolated) 12/82 A \ 5„ PBTD=10,699' TD= 10,850' MAX HOLE ANGLE=7 deg.At 10,700' Downhole Revised:12/02/13 Updated by STP 12/04/13 • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Wednesday, December 04, 2013 10:43 AM To: 'Stan Porhola' Subject: RE:Verbal Approval Request for fixing parted rods in SCU 12A-03 (PTD 180-104) Stan, You have verbal approval to proceed with rod and pump change out in SCU 12A-03 as proposed in your attached procedure. As stated you already have sundry in route to our office. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Stan Porhola [mailto_sporhola(n hilcorp,com] Sent: Wednesday, December 04, 2013 10:07 AM To: Schwartz, Guy L(DOA) Subject: Verbal Approval Request for fixing parted rods in SCU 12A-03 (PTD 180-104) Guy, Can I get a verbal approval to pull and fish parted rods in SCU 12A-03(PTD 180-104)?The scope of the work and schematic is attached. A 10-403 will be submitted today.The Moncla#405 should be available to move onto this well as early as tomorrow, Dec 5`h This is one of the wells that was converted to a Lufkin Rod Pump back in July. Regards, Stan Porhola ! Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC s110rho!@hilcobp. On1 Office: (907) 777-8412 Mobile: ( 07) 331-8228 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg cZee6 *51(3 DATE: August 09, 2013 P. I. Supervisor ( FROM: Lou Grimaldi SUBJECT: No Flow Verification Petroleum Inspector Hilcorp Alaska LLC `LC,)\` SCU 12A-03 N� �.�. PTD #1801040 Soldotna Creek Unit Friday, August 09, 2013; I witnessed the No-Flow test on Hilcorp's Soldotna Creek Unit 12A-03 in the Swanson River Field. This test was performed today in conjunction with routine SVS and another No Flow test on SCU 12A-04. The well numbers are deceiving as the two wells are a few miles from each other and definitely not on the same pad. Marty Guth (Instrument Tech) and Micah Robertson (Production Operator) performed the tests today. The flow rates were read on a new, factory calibrated, Erdco, Armor- Flo resistance style gas flow meter, range of 150 scf-1500 scf and a 30 psi test gage w/0.1 psi increments having a current calibration. The well is lifted by a reciprocating rod pump driven by one of the new Lufkin beam style jacks that Hilcorp has brought to the Swanson Field. The well was being lifted when I arrived with approximately 140 psi on the tubing and 130 psi on the annulus. The annulus was in communication with the tubing. I had Chris Walgenburg (Field Lead) turn the pump drive off and start bleeding the tubing/annulus to an open top tank that was staged next to the well. I moved on to the miscellaneous SVS test and allowed this well to be bled to the tank while I was gone. When I returned the well was lined up to the open top tank and barely breathing gas. I had the operator shut in the well for what would be a 31/2 hour buildup period. During this time I went back to the other No-Flow candidate well, 12A-04, and witnessed the flowing down of that well. I returned to this well, 12A-03, finding that the tubing pressure had risen to 9.6 psi and stabilized there. I again felt this may have been the inflow from the formation and decided it to be "blown down" to the open top tank for exactly five minutes at which time the flow was routed through the flow meter. When the well was lined up to the meter the pressure was at 1.2 psi and 500scf/hour. Within 40 minutes the flow and pressure were below the instruments measureable capacity. observed the well for a total of 1.5 hours with pressure below measurable range and flow being a bare whisper. I released the well to be put back into production. The well exhibited parameters for a no-flow status. 2013-0809_No-Flow_SCU_12A-031g.docx 1 of 3 1 . • • The following table contains the steps, pressures and flow rates observed. Time Notes Pressure Flow Rate 12:15 Shut In for Buildup 0 --- 12:30 Shut In for Buildup 0.2 --- 12:45 Shut In for Buildup 0.5 --- 13:00 Shut In for Buildup 0.9 --- 13:15 Shut In for Buildup 1.6 --- 13:30 Shut In for Buildup 2.3 --- 13:45 Shut In for Buildup 3.8 --- 14:00 Shut In for Buildup 4.8 --- 14:15 Shut In for Buildup 5.7 --- 14:30 Shut In for Buildup 6.6 --- 14:45 Shut In for Buildup 7.2 - --- 15:00 Shut In for Buildup 8 --- 15:15 Shut In for Buildup 8.6 --- 15:30 Shut In for Buildup 9.2 --- 15:45 Open to Open Top Tank for 5 Minutes 9.6 - --- 15:50 Flowing Through Meter 1.2 500 15:55 Flowing Through Meter 0.7 350 16:00 Flowing Through Meter 0.4 300 16:15 Flowing Through Meter 0 <150 16:30 Flowing Through Meter 0 <150 16:45 Flowing Through Meter 0 Whisper 17:00 Flowing Through Meter 0 Whisper 17:15 Flowing Through Meter 0 Whisper Attachments: photos (2) ' Non-Confidential 2013-0809_No-Flow_SCU_12A-03_lg.docx 2 of 3 , • • No Flow Test - SCU 12A-03 (PTD 1801040) Photos by AOGCC Inspector L. Grimaldi 9/9/2013 , r . gam Irak iiii II 1 1. t____ ,,,_ ,f' ' „' Reciprocating Rod • Pump—Lukfkin Beam } .�. ..• „� -- Style Jack 4i �- ,�--' _. No Flow Test 'l' , e. Equipment At is r. \ Cf L- -.--- . " 2013-0809_No-Flow_SCU_12A-03_lg.docx 3 of 3 Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-math childersd@.unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 To: Lori Taylor 3001 Porcupine A.nchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK Unocal i i J 99519-6247 Transmitting the following items: ~:.SCAEE~,: ~EOG~.: ::~, INTER~ Ei~;-:,'~, ~!.COP,:IES~ :'~'~.~. ~:,M~i~'~' ~.~,~.Well ,~:~ ,~. , ~[OG~RE~,,:, ~,~< ~,~ · - .,./ ...~r,~,~'.,~.~;~,*-:,,*..~.._~,~'--. ~ ..' ,.,. ~. ,,,..- '.'.,'.. ?...... :~ ~. :-,'. ',....' .'. ~' ~4', . '~;~'.'~, ", ','~ ':'-'..,'~ '~'~:/~rmal Deca~ 'rime L~ ....:5 in'oh 9/6/99J6400-10714' ~ ! B-.Line gZ~ SCU 12-9 Pedoratin9 Record 5 inch N3/00..]..9].~.:!..9~.9 ................ j .......................................................................... !..,..~.:F~q.~ ................. ................ ........... F,m SCU 12-9 ,,~.~,?~ti_~g_~or~_~o~rz~9~i?_L~_g- 5 inch 1/16/00 10000-10500 ..i. 1 Film ~CU 12A-3 Pedorating Recor~Correlation Log 5 inch 3/15/00 10200-10550 l~B-Line SCU 12A-3 Pe~orating Recor~Correlation Log 5inch i 3/15/00 ~10200-10550 , 1 Film ~ ........................................... l ..................... ; ............................ '; .................................................................. ; ................................ i ........................................ " ..................................................... , ................................................................ ': ............... : .......................... ~ SCU 12A-3 , Posslset Plug 5 Cement 5 tach ~ 3/11/00 10200-10545 , 11 B-Line ~ SCU 12A-3 ~ Possiset Plug 5 Cement 5 inch ~ 3/11/00i 10200-10545 1 Film ~ I "i~0'"'i'i':i ................. [~'~'~'iii'~'~'"~'~'~'~i~'~'~iiiii~'"G'g~'""'~'i'"i~'~ .............................. i')'i'i~66'"i'6666:i6ii'6 ................. ~ ........................................................................... i""~ii~ ............................. f [ ; ............................... ' ...................................... ~ ......................................................................................................................................................................... L~.~.~:9~[~pra~i~_g. Record 5 inch [ N1/00 10500-10700 j 1 Film ~CU 22-4 ~MD Composite Field Print 5 inch ~ 10/8/99 10340-11140 ~ 1 B-Line , SCU 22-4 ~TVD Comnoslte Reid Pnnt 5 inch ~ 10/8/99~ 10340-11140 ~ 1 ~ Rim I~0 ,,,,~ ~SCU 24A.5 ........................................................ z{ Completion Record"' ..................................................................................................... ' ........................................... 5 inch I 3/13/00~10200-10640 ~' 1~ B-Line [SOU24A-5 )Completion Record ~5inch ~ 3/13/00j10200-10640 i llFilm ........................................................ f ............................................................................................................................ ~ ......................................... ~ ................................................................................................... ~ .................................................................. ~ ........................................... SCU43B-8 ~Com~etlon Record ,5inch , 1/14/00110200-10570 ~ l/B-Line 'fit ................................................................................................................................................................................................... ~ ........................................ ~ ............................................... ' ..................................................................... ~ ............................................................................................................... LSCU 43B-8 '"~Com~letion Record 15 inch i 1/14/00~'10200-10570 ~ 1!Film ~ ................. F i~.~-~..~.~i;5~;.~;~5~.~.~.~.5~`i.~...~`~.~.~.;`b~"G./~i.~..~.~.~.~.&.~5~...~F~.~.~`~...~;~.~.i~i~.i:~.~%~.~)~.~6~:~.: ............... Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Ddlling Manager Thursday, March 30, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 12A-3 APl No. 50-133-10099-01 10-404 Perforate H5 bench Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H5 bench in well SCU 12A-3. The following intervals were perforated on 3114/00: Bench Top Bottom Feet H5 10,487 10,530 43 Total: 43 If you have any questions, please contact Ralph Holman at 263-7838. ORIGINAL RECEIVED 10 .000 S,~p~erely, AlalklO# & Gas Coils. Drilling Manager (' 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 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of Califomia (Unocal) Development: X 166' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: ., 4. Location of well at surface 8. Well number 2070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM SCU 12A-3 At top of productive interval 9. Permit number/approval number 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 80-0104 At effective depth 10. APl number 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 50-133-10099-01 At total depth 11. Field/Pool 1951' FNL, 210' FWL, Sec. 3, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10850 feet Plugs (measured) 10699 true vertical 10844 feet 10555 Effective depth: measured 10699 feet Junk (measured) true vertical 10694 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" Yes 28' 28' Surface 3000' 13-3/8" 1792 sx 3000' 3000' Intermediate.. ';.' *' ~'~ Production .2 10265' 7" 2608 sx 10265' 10262' Liner 845' 5" 860 sx 10844' 10841' Perforation depth: measured 10410-10428, 10442-10450, 10460-10478, 10487-10530, 10540-10548, 10560-10590, 10598-10602 true vertical 10408-10425, 10439-10447, 10457-10475, 10484-10527, 10536-10544, 10556-10586, 10594-10999 - , Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 @ 10035'; 2-3/8", 4.6#, N-80 @ 10121' Packers and SSSV (type and measured depth) Baker "FHL" pkr. @ 9978', Baker"D" pkr. @ 10095' RECEIVED 13. Stimulation or cement squeeze summary 10 Intervals treated (measured) Treatment description including volumes used and final pressure ~(~ D I ~! ~! AL ~~&~~$'~~ 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 17 21 819 1000 250 Subsequent to operation 68 3200 120 750 390 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: . Daily Report of Well Operations: ~ Oil: A Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the b~st of my knowledge: Signed: .~_ ~,~/~~ Title: ~~~~ Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE AND GAS CONSERVATIO OMMISSION ALASKA O,*- APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: ,, Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 166' R.KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotha Creek Unit 4. Location of well at surface 8. Well number 2,070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM SCU 12A-3 O, I At top of productive interval 9. Permit number 1,983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 8-585 ,,,, At effective depth 10. APl number 1,983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 50- 133-10099-01 At total depth 11. Field/Pool 1,951' FNL, 210' FWL, Sec. ,3, T7N, R9W, SM Swnason River Field / Hemlock ..... 12. Present well condition summary Total depth: measured 10,850' feet Plugs (measured) 10,699' true vertical 10,844' feet Effective depth: measured 10,699' feet Junk (meaSured) true vertical 10,694' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" Yes 28' 28' Surface 3,000' 13-3/8" 1,792 sx in 2 stages 3,000' 3,000' Intermediate . Production 10,265' 7" 2,608 sx 10,265' 10,262' Liner 845' 5" 860 sx 10,844' 10,841 ' Perforation depth: measured See Attached ORIGINAL true vertical ~'-~ ~ ED Tubing (size, grade, and measured depth) . ~ ,~. 3-1/2", 9.2#, N-80, Buttress SC @ 10,035'; 2-3/8", 4.6#, N-80 Buttress SC @ 10,121' ~,~[!~R ~J 'J(-OUOn Packers and SSSV (type and measured depth) Baker Mod. "FHL" Retrievable @ 9,978' and Baker Mod. 'D' @ 10,095' ,~8~,~ OiJ.&~c.~""~ CO~. 13. Attachements Description summary of proposal: X Detailed operations program: BOP sk~, ..... 14. Estimated date for commencing operation 15. Status of well classification as: 3/2/00 16. If proposal well verbally approved: Oil: X Gas: ...... Suspended: Name of approver Date approved Service: 17. I hereb~fy_that t~f~)i~.g, is true and c°rrect t° the best °f mY kn°wlodge' Signed~illiamson Title: Drilling Manager Date: __~"',~, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative maywitness IAppr°val ~) Plug integrity BOP Test Location clearance -__ Mechanical Integrity Test Subsequent form required 1 o- A~3p~.ove(~ CoPY ' ORIGINAL SIGNED. BY Robert N. Christenson'-'"~-mrnissioner Date ~.-~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCU 12A-3 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments H-2 10,41 O' 10,428' 10,408' 10,425' 18' H-3 10,442' 10,450' 10,439' 10,447' 8' H-4 10,460' 10,478' 10,457' 10,475' 18' H-6 10,540' 10,548' 10,536' 10,544' 8' H-8 10,560' 10,590' 10,556' 10,586' 30' H-8 10,598' 10,602' 10,594' 10,998' 4' H-10 10,716' 10,730' 10,712' 10,708' 14' Isolated 100' UNOCAL .... Ori RKB = 26' 15 18¸ 19 20 21 22 23 A H-2 H-3 H-4 H-6 H-8 H-8 H-10 SIZE WT f Soldotna Creek Unit Well No. 12A-3 Actual Completion 5/10/97 II I CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 54.5 - 7" 29 P-110 5" 18 N-80 Tubing 3-1/2" 9.2# N-80 2-3/8" 4.6 · N-80 Surface 28' 10.050 Surface 3,000' 6.184 Surface 10,265' 4.276 10,045' 10,948' BTC 2.992 Surface 10,035' BTC 1.995 10,035' 10,121' JEWELRY DETAIL NO. Depth ID OD Item 22' - - 3-1/2", Single Tubing Hanger CIW Type 'H' BPVP 1 1,749' 2.850 Camco, 3-1/2", KBUG 1" GLM · 2 3,149' 2.850 Camco, 3-1/2", KBUG 1" GLM 3 4,192' 2.850 Camco, 3-1/2", KBUG 1" GLM 4 4,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 5 5,451' 2..850 Camco, 3-1/2", KBUG 1" GLM 6 5,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 7 6,448' 2.850 Camco, 3-1/2", KBUG 1" GLM 8 6,938' 2.850 Camco, 3-1/2', KBUG 1" GLM 9 7,448' 2.850 Camco, 3-1/2", KBUG 1" GLM 10 7,946' 2.850 Camco, 3-1/2", KBUG 1" GLM 11 8,438' 2.850 Camco, 3-1/2", K. BUG 1" GLM 12 8,949' 2.850 Camco, 3-1/2", KBUG 1" GLM 13 9,443' 2.850 Camco, 3-1/2", KBUG 1" GLM 14 9,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 15 9,978' 3.000 5.968 Packer, Baker FHL (50k Pull Release) 16 10,028' 2.813 'X' Nipple, 3-1/2" Buttress 17 10,029' 1.995 3.937 Crossover, 3-1/2" Butt Box x 2-3/8" Butt Pin . 18 10,094' 1.968 2.875 Baker Seal Assy. The following set on E-Line 19 10,095' 2.688 3.968 Packer, 2-9/8 x 5" Baker Mod. 'D' 20 10,097' 2.688 3.650 Seal Bore Extension, 9.45' Long 21 10,107' 1.995 3.750 Crossover, Seal Bore Extension x 2-3/8" Butt Pin 22 10,114' 1.875 2.700 'X' Nipple, 2-3/8" EUE 8rd, 2.313 w/2.25" N.G. 23 10,121' 1.995 2.880 WLREG ~ ~ (~ E ~'~f ED Notes: ~.~AR lO "1 2.000 A Baker Mod. K-1 Retainer set at 10,699' PERFORATION HISTORY g~-_'2~0!'E~ Date Zone Top Btm Ant: spt Commnts 7/9/97 H-2 I 10,410' I0,428' 18' 10-14 7/9/97 H-3 10,442' 10,450' 8' 10 7/9/97 H-4 10,460' 10,478' 18' 6-10-14 7/9/97 H-6 10,540' 10,548' 8' 6' 7/9/97 H-8 10,560' 10,590' 30' 10 2/84 H-8 10,598' 10,602' 4' 4 , 12/82 H-10 10,716' 10,730' 14' 4 Casing Split (Isolated) PBTD = 10,699' TD = 10,850' MAX HOLE ANGLE = 7 deg. At 10,700' SCU 12A-3 Draw 5-10-97 DRAWN BY: tcb REVISED: 8/20/98 Unocal Alaska Business Unit Swanson River Well No. SCU 12A-3 Prepared by: Tim Brandenburg ~ ~1~ Plug Back and Add Hemlock Bench 5 Ul~OCA No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Plug Back 1 MIRU Schlumberger E-Line. 4.0 4 0.2 2 Pressure test Lubricator to 2,500psi. 1.0 5 0.2 3 Pick up PosiSet Plug for 5", 18# Casing. 1.0 6 0.3 4 RIH with CCL/PosiSet Plug. ' ..... 2.0 8 0.3 5 Set Plug at 10,555' MD. 3.0 11 0.5 6 POOH. 0.5 12 0.5 7 MU 1-11/16" Bailer/Mix Cement. 2.0 14 0.6 8 RIH making runs as requires to dump bail 5' of cement. 16.0 30 1.2 9- Allow cement to cure for 24 hours. 24.0 54 2.2 Perforate 10 [Perforate Hemlock Bench 5 from 10,487'-10,530' 3.0 56.5 2.4 12A-3 Reperf Attach Page 1 of 1 2/28/00 ' UNOCAL Ori RKB = 26' 15 18./ 19 20 21 22 23 A H-2 H-3 H-4 H-5 H-6 H-8 H-10 · Soldotna Creek Unit Well No. 12A-3 Proposed SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 54.5 - 7" 29 P-Il0 5" 18 N-80 Tubing 3-1/2" 9.2# N-80 2-3/8" 4.6 N-80 Surface 28' 10.050 Surface 3,000' 6.184 Surface 10,265' 4.276 10,045' 10,948' BTC 2.992 Surface 10,035' BTC 1.995 10,035' 10,121' JEWELRY DETAIL NO. Depth ID ,OD ,Item 22' - - 3-1/2", Single Tubing Hanger CIW Type 'H' BPVP 1 1,749' 2.850 Camco, 3-1/2", KBUG 1" GLM 2 3,149' 2.850 Camco, 3-1/2", KBUG 1" GLM 3 4,192' 2.850 Camco, 3-1/2", KBUG 1" GLM 4 4,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 5 5,451' 2.850 Camco, 3-1/2", KBUG 1" GLM 6 5,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 7 6,448' 2.850 Camco, 3-1/2", K.BUG 1" GLM 8 6,938' 2.850 Camco, 3-1/2", KBUG 1" GLM 9 7,448' 2.850 Camco, 3-1/2", KBUG 1" GLM 10 7,946' 2.850 Camco, 3-1/2", KBUG 1" GLM 11 8,438' 2.850 Camco, 3-1/2", KBUG 1" GLM 12 8,949' 2.850 Camco, 3-1/2", KBUG 1" GLM 13 9,443' 2.850 Camco, 3-1/2", KBUG 1" GLM 14 9,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 15 9,978' 3.000 5.968 Packer, Baker FHL (50k Pull Release) 16 10,028' 2..813 'X' Nipple, 3-1/2" Buttress 17 10,029' 1.995 3.937 Crossover, 3-1/2" Butt Box x 2-3/8" Butt Pin 18 10,094' 1.968 2.875 Baker Seal Assy. The following set on E-Line 19 10,095' 2.688 3.968 Packer, 2-9/8 x 5" Baker Mod. 'D' 20 10,097' 2.688 3.650 SealBore Extension, 9.45' Long 21 10,107' 1.995 3.750 Crossover, Seal Bore Extension x 2-3/8" Butt Pin 22 10,1'14' 1.875 2.700 'X' Nipple, 2-3/8" EUE 8r . 3 /.. " G. Notes: A' Proposed Posiset set at 10,555' w/5' Cement Dump Bailed B Baker Mod. K-1 Retainer set at 10,699' PERFORATION HISTORY Interval Acct~ 7/9/97 H-2 10,410' 10,428' 18' 10.14 7/9/97 H-3 10,442' 10,450' 8' 10 7/9/97 H-4 10,460' 10,478' 18' 6-10-14 I~5 10,487' 10,530' 43' 4 Proposed 7/9/97 H~ 10,5~0' 10,~4~' 8' 6 7/9/97 H-8 10,5~0' 10,590' 30' l0 2/84 H-8 10,598' 10,602' 4" 4 , 12/82 H-10 10,716' 10,730' 14' 4 Casing Split (Isolated) PBTD = 10,699' TD -' 10.850' MAX HOLE ANGLE = 7 deg. At 10,700' SCU 12A-3 Prop Draw DRAWN BY: tcb REVISED: 8[20/98 SCU 12A-3 Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Arnt Comments H-2 10,41 O' 10,428' 10,408' 10,425' 18' H-3 10,442' 10,450' 10,439', 10,447' 8' H-4 10,460' 10,478' 10,457' 10,475' 18' H-F, 10,487' 10,530' 10,483' 10,526' 43' Proposed Add H-6 10,540' 10,548' 10,536' 10,544' 8' H-8 10,560' 10,590' 10,556' 10,586' 30' Proposed Isolate H-8 10,598' 10,602' 10,594' 10,998' 4' Proposed Isolate H-10 10,716' 10,730' 10,712' 10,708' 14' Isolated 143' STATE OF ALASKA OMMiSSiON ALASKA AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved'program: Pull tubing: Variance: X Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 166' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Soldotna Creek Unit 4. Location of well at surface ,~ ~' ,/ 8. Well number 2,070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM SCU 12A-3 At top of productive interval 9. Permit number 1,983' FNL, 218' FWL, Sec. 3, 'r7N, R9W, SM ~ At effective depth 10. APl number 1,983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 50- 133-10099-01 At total depth 11. Field/Pool 1,951' FNL, 210' FWL, Sec. 3, T7N, R9W, SM Swnason River Field / Hemlock 12. Present well condition summary Total depth: measured 10,850' ~, feet Plugs (measured) 10,699' true vertical 10,844' feet Effective depth: measured 10,699' feet Junk (measured) true vertical 10,694' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 22" Yes 28' 28' Surface 3,000' 13-3/8" 1,792 sx in 2 stages 3,000' 3,000' Intermediate Production 10,265' 7" 2,608 sx 10,265' 10,262' Liner 845' 5" 860 sx 10,844' 10,841' Perforation depth: measured See Attached R~~.=~ .~i ~ ED true vertical ORIG/NAL [;~ 0 Tubing (size, grade, and measured depth) A~CcS!'~ O J] & ~5.$ OOT~S. 3-1/2", 9.2#, N-80, Buttress SC @ 10,035'; 2-3/8", 4.6#, N-80 Buttress SC @ 10,121' Packers and SSSV (type and measured depth) Baker Mod. "FHL" Retrievable @ 9,978' and Baker Mod. 'D' @ 10,095' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: .... 14. Estimated date for commencing operation 15. Status of well classification as: 3/2/00 16. If roposal well verbally approved: Oil: X Gas: Suspended: ~)~ Date approved Service: 17. I hereb~'e~fy_that t~e~f~'~Pl~.g, is true and correct to the best of mY knowledge. Signed~illiamson Title: Drilling Manager Date: v -- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IAppro~ Plug integrity.~ BOP Test Location clearanceI ~.~_.~' Mechanical Integrity Test Subsequent form required 10-t4~- ~-~'['¢k~3~ ' ',t;A~,O0~:)~ (~~ ; ?(~ ~) Approved by order of the Commissioner Robert N. Christenson Commissioner Date ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager February 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commisioner Robert N. Christenson Application for Sundry Approval (Form 10-403) Swanson River Field Soldotna Creek Unit No. 12A-3 Commissioner Christenson: Enclosed is the Sundry Notice (10-403) relating to the plug back and perforation of Soldotna Creek Unit Well No. 12A-3. The intent of this work is to isolate the wet Hemlock H-8 with a through tubing bridge plug. The plug will be set at 10,555' between the H-8 (Top perf at 10,560') and the H-6 (Bottom perf at 10,548'). Due to the limited distance between the plug and the H-6 perforations, a variance is requested to allow for the placement of only 5' of cement ontop of the plug so as to not impede H-6 production. Hemlock Bench 5 will be perforated from 10,487'-10,530' after the isolation work is completed. This work will commence as soon as Sundry approval is grantred, so expedient consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Ralph Holman at 263-7838. Dan Williamson Drilling Manager Unocal Alaska Business Unit Swanson River Well No. SCU 12A-3 Prepared by: Tim Brandenburg CAL~ Plug Back and Add Hemlock Bench 5 UNO No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Plug Back 1 MIRU Schlumberger E-Line. 4.0 4 0.2 2 Pressure test Lubricator to 2,500psi. 1.0 5 0.2 3 Pick up PosiSet Plug for 5", 18# Casing. 1.0 6 0.3 4 RIH with CCL/PosiSet Plug. 2.0 8 0.3 5 Set Plug at 10,555' MD. 3.0 11 0.5 6 POOH. 0.5 12 0.5 7 MU 1-11/16" Bailer/Mix Cement. 2.0 14 0.6 8 RIH making runs as requires to dump bail 5' of cement. 16.0 30 1.2 9 Allow cement to cure for 24 hours. 24.0 54 2.2 Perforate 10 IPerforate Hemlock Bench 5 from 10,487'-10,530' 3.0 56.5 2.4 12A-3 Reperf Attach Page 1 of 1 2/28/00 UNOCAL Ori = 26' 15 1.8 19 20 21. 22 23 H-2 H-3 H-4 H-6 H-8 H-8 H-10 Soldotna Creek Unit Well No. 12A-3 Actual Completion 5/10/97 SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 54.5 - 7" 29 P-110 5" 18 N-80 Tubing 3-1/2" 9.2# N-80 2-3/8" 4.6 N-80 Surface 28' 10.050 Surface 3,000' 6.184 Surface 10,265' 4.276 10,045' 10,948' BTC 2.992 Surface 10,035' BTC 1.995 10,035' 10,121' JEWELRY DETAIL NO. Depth Ii~D OD ,Item 22' - 3-1/2", Single Tubing Hanger CIW Type 'H' BPVP 1 1,749' 2.850 Camco, 3-1/2", KBUG 1" GLM 2 3,149' 2.850 Camco, 3-1/2", KBUG 1" GLM 3 4,192' 2.850 Camco, 3-1/2", KBUG 1" GLM 4 4,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 5 5,451' 2.850 Camco, 3-1/2", KBUG 1" GLM 6 5,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 7 6,448' 2.850 Camco, 3-1/2", KBUG 1" GLM 8 6,938' 2.850 Camco, 3-1/2", KBUG 1" GLM 9 7,448' 2.850 Camco, 3-1/2", KBUG 1" GLM 10 7,946' 2.850 Camco, 3-1/2", KBUG 1" GLM 11 8,438' 2.850 Camco, 3-1/2", KBUG 1" GLM 12 8,949' 2.850 Camco, 3-1/2", KBUG 1" GLM 13 9,443' 2.850 Camco, 3-1/2", KBUG 1" GLM 14 9,937' 2.850 Camco, 3-1/2", KBUG 1" GLM 15 9,978' 3.000 5.968 Packer, Baker FHL (50k Pull Release) 16 10,028' 2.813 'X' Nipple, 3-1/2" Buttress 17 10,029' 1.995 3.937 Crossover, 3-1/2" Butt Box x 2-3/8" Butt Pin 18 10,094' 1.968 2.875 Baker SealAssy. The following set on E-Line 19 10,095' 2.688 3.968 Packer, 2-9/8 x 5" Baker Mod. 'D' 20 10,097' 2.688 3.650 Seal Bore Extension, 9.45' Long 21 10,107' 1.995 3.750 Crossover, Seal Bore Extension x 2-3/8" Butt Pin ~.~'~*/.~ · , . 22 10,114' 1.875 2.700 'x' Nipple, 2-3/8"EUE~,ii.~ 23 10,121' 1.995 2.880 WLREG Notes: A B~er Mod. K-1 Retainer set at 10,699' ~,}a~;~<: PERFORATION HISTORY ,,,,,, ~e~ A<~ ~ ~m Top B~ ~ ~ , ..... 7/9/~ H-2 10,410' 10,4~' 18' 1¢14 7/9/~ H-3 10,~2' 10,450' 8' 10 7/9/~ H4 10,~' 10,478' 18' ~1~14 7/9/~ H~ 10,5~' 10,548' 8' 6 7/9/97 H-8 10,5~' 10,5~' 30' 10 ~M H-8 10,598' 10,~' 4' 4 1~82 H-10 10,716' 10,730' 14' 4 ~ing Sp~t ~olat~) PBTD = 10,699' TD = 10,850' MAX HOLE ANGLE = 7 deg. At 10,700' SCU 12A-3 Draw 5-10-97 DRAWN BY: tcb REVISED: 8/20/98 SCU 12A-3 Actual Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments H-2 10,41 O' 10,428' 10,408' 10,425' 18' H-3 10,442' 10,450' 10,439' 10,447' 8' H-4 10,460' 10,478' 10,457' 10,475' 18' H-6 10,540' 10,548' 10,536' 10,544' 8' H-8 10,560' 10,590' 10,556' 10,586' 30' H-8 10,598' 10,602' 10,594' 10,998' 4' H-lO 10,716' 10,730' 10,712' 10,708' 14' Isolated 100' UNOCAL Ori RKB = 26' 15 18 19 20 21 22 23 H-2 H-3 H-4 H-5 H-6 A H-8 H-10 SIZE WT Soldotna Creek Unit Well No. 12A-3 Proposed CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8" 7" 5" Tubing 3-1/2" 2-3/8" 54.5 29 18 9.2# 4.6 P-110 N-80 N-80 N-80 BTC BTC Surface 28' 10.050 Surface 3,000' 6.184 Surface 10,265' 4.276 10,045' 10,948' 2.992 Surface 10,035' 1.995 10,035' 10,121' NO. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Depth 22' 1,749' 3,149' 4,192' 4,937' 5,451' 5,937' 6,448' 6,938' 7,448' 7,946' 8,438' 8,949' 9,44Y 9,937' 9,978' 10,028' 10,029' 10,094' 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 2.850 3.000 2.813 1.995 1.968 JEWELRY DETAIL oq 5.968 3.937 2.875 It,em 3-1/2", BPVP Camco, Camco Camco Camco Camco Camco Camco Camco. Camco. Camco. Camco. Camco. Camco. Camco. 19 10,095' 2.688 3.968 20 10,097' 2.688 3.650 21 10,107' 1.995 3.750 22 10,114' 1~875 2.700 23 10,121' 1.995 2.880 Single Tubing Hanger CIW Type 'H' 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM 3-1/2", KBUG 1" GLM Packer Baker FHL (50k Pull Release) 'X' Nipple, 3-1/2" Buttress Crossover, 3-1/2" Butt Box x 2-3/8" Butt Pin Baker Seal Assy. The following set on E-Line Packer, 2-9/8 x 5" Baker Mod. 'D' Seal Bore Extension, 9.45' Long Crossover, Seal Bore Extension x 2-3/8" Butt Pin 'X' Nipple, 2-3/8" EUE 8rd, 2.313 w/2.25" N.G. WLREG Notes: A B Proposed Posiset set at 10,555' w/5' Cement Dump Bailed Baker Mod. K-1 Retainer set at 10,699' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Ant spf Conlmnts 7/9/97 H-2 10,410' 10,428' 18' 10-14 7/9/97 H-3 10,442' 10,450' 8' 10 7/9/97 H-4 10,460' 10,478' 18' 6-10-14 H-5 10,487' 10,530' 43' 4 Proposed 7/9/97 H-6 10,540' 10,548' 8' 6 7/9/97 H-8 10,560' 10,590' 30' 10 2/84 H-8 10,598' 10,602' 4' 4 12/82 H-10 10,716' 10,730' 14' 4 Casing Split (Isolated) PBTD = 10,699' TD = 10 850' MAX HOLE ANGLE = 7 deg. At 10,700' SCU 12A-3 Prop Draw DRAWN BY: tcb REVISED: 8/20/98 SCU 12A-3 Proposed Perforations Measured Depth True Vertical Depth Zone Top Btm Top Btm Amt Comments H-2 10,41 O' 10,428' 10,408' 10,425' 18' H-3 10,442' 10,450' 10,439' 10,447' 8' H-4 10,460' 10,478' 10,457' 10,475' 18' H-5 10,487' 10,530' 10,483' 10,526' 43' Proposed Add H-6 10,540' 10,548' 10,536' 10,544' 8' H-8 10,560' 10,590' 10,556' 10,586' 30' Proposed Isolate H-8 10,598' 10,602' 10,594' 10,998' 4' Proposed Isolate H-lO 10,716' 10,730' 10,712' 10,708' 14' Isolated 143' RECEIVED Ancho~'~e Unocal Corporation O(~ Oil & Gas Operations 909 West 9th Avenue, P. . ax 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL October 23, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: ORIGINAL Re: Soldotna Creek Unit-SCU 12A-3 APl Number $0-133-10099-01 On April 12, 1995 the following intervals were reperforated in Well SCU 12A-3: BENCH TOP (MD) BOTTOM (MD) FEET H8 10,561 10,576 15 TOTAL 15 Attachment Very truly yours, Candace Williams 1. Operations performed: Operation shutdown Stimulate Plug~g ...- Perforate X Pull tubing After casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development x UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Explomto~ 166.7' KB feet 3. Address Stmfigraphic __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Service Soldotna Creek Unit 4. Location of well at surface 8. Well number 2070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM SCU 12A-3 Attop of productive interval 9. Permit number 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 8-585 At effective depth 10. APl number 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM 50-133-10099-01 At total depth 11. Field/Pool 1951' FNL~ 210' FWL~ Sec. 3~ T7N~ R9W~ SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10850' feet Plugs (measured) true vertical 10844' feat Effective depth: measured 10700' feet Junk(measured) ORIGINAL ~Je vertical 10694' feet Casing Length Size Cemented Measured depth True vertical depth Structural 28' 22" to surface 28' 28' Conductor Surface 3,000' 13-3/8" 1792 sx in 2 stages 3000' 3000' Intermediate Production 10265' 7" 2608 sx 10265' 10262' Liner 845' 5" 860 sx 10844' 10841' Perforation depth: measured 10420'-10428'; 10470'-10476'; 10542'-10550'; 10561 '-10576'; 10579'-10590'; 1 0598'-10602' true vertical 10418'-10425'; 10467'-10473'; 10538'-10546'; 10577'-10573'; 10575'-10586'; 10594'-10598' Tubing (size, grade, and measured depth) 3-1/2" 9.3~ J55 tbg ~} 10042'; 2-3/8" 4.7# N-80 10042'-10288' Packers and SSSV (type and measured depth) Baker 3-112" FH pkr ~ 10033'; Baker 2-3~8" FH ~ 10105' ~ 3.' Stimulation or cement squeeze summary ~! 0 V Intervals treated (measured) ~1~,$~[ ~[[ .& GaS Co,qs. C011~i$~ : ~ch0mg(i Treatment description including volumes used and final pressure , 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 4/6/95 242 18,386 666 50 1925 --Subsequent to operation 4/20/95 205 19,410 477 50 2200 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Ope~ fio~s Oil X Gas Suspended Service 17., hereby certify that the for~ ~r ~,s tme~d ~est of my knowledge. _Signed. _ ._G; _Russ_ell..S_c.h__midt. ~, ~ !~-'~'~Ti~e Drilling Manager Date //'. Form 10-404 Rev 08115/88 :i SUBMIT IN DU Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O 8ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOOtL October 31, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: " R/GINAL Soldotna Creek Unit - SCU 12A-3 APl Number 50-133-10099-01 On May 11, 1995 the following intervals were reperforated & perforated in Well SCU 12A-3: BENCH TOP (MD) BOTTOM (MD) FEET H2 10,410 10,428 18 H3 10,442 10,450 8 H4 10,468 10,478 10 TOTAL 36 Very truly yours, Candace Williams Attachment (i,NDSTATE OF ALASKA ~, ALASKA OI GAS CONSERVATION CO "~SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ ~. Stimulate__ ..-- Plugging -... Pull tubin~l After casin~l Repair well 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 4. Location of well at surface 2070' FNL, 305' FWL, Sec. 3, T7N, R9W, SMK At top of productive interval 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM At effective depth 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM At total depth 1951' FNL, 210' FWL, Sec. 3, T7N, R9W, SM 12. Present well condition summary Total depth: measured 10850' true vertical 10844' Effective depth: measured 10700' true vertical 10694' 5. Type of Well: Development Exploratory Stratigraphic Service Perforate X Pull tubin~l Other 6. Datum elevation (DF or KB) 166.7' KB feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 12A-3 9. Permit number ,--~ 8-585 10. APl number 50-133-10099-01 11. Field/Pool Swanson River/Hemlock feet feet feet feet Plugs (measured) Junk (measured) Oi iGINAL Casing Length Size Cemented Measured depth True vertical depth Structural 28' 22" to surface 28' ' 28' Conductor Surface 3,000' 13-3/8" 1792 sx in 2 stages 3000' 3000' Intermediate Production 10265' 7" 2608 sx 10265' 10262' Liner 845' 5" 860 sx 10844' 10841' 13. 14. Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 10410'-10428'; 10442'-10450'; 10468'-10478'; 10542'-10550'; 10561 '-10577'; 10579'-10590'; 10598'-10602' 10407'-10425'; 10439'-10447'; 10465'-10475'; 10538'-10546'; 10557'-10573'; 10575'-10586'; 1 0594'-10598' 3-112" 9.3# J55 tbg ~., 10042'; 2-3/8" 4.7# N-80 10042'-10268' Packers and SSSV (type and measured depth) Baker 3-112" FH pkr (~ 10033'; Baker 2-3/8" FH i~ 10105' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ...Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data I~0V 'i ,~ A!as~:z. ~lil ~& Gas Cor~s, C0m~is~io. Tubing Procure Pdor to well operation 5/5195 203 15,970 ' 641 60 844 Subsequent to operation 5114195 201 16,663 571 65 772 1- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 117' I hereby certify that the f°r~j~ir~'/s :e~ ~'~est °f my kn°wledge' ISigned G. Russell Schmidt/~~~le Drilling Manager Date [{ ~- Form 10-404 Rev 06/15/88 ' ' - SUBMIT IN DUP~.IC~,TE ARCO Alaska, Inc. f~ Post Office Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 29, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 12A-3. Dear Mr. Smith: On 8/30/91 ARCO Alaska, Inc. successfully completed the perforation of SCU 12A-3 H6 sands. The intervals shot were from 10542'- 10550'. Please refer to the attached submittal of the Subsequent Report and Well Service Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, Acting Regional Engineer JCW:DRH:dh:0124 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED -- 1 !99,?. Alaska Oil 8, Gas Cons. Commissi0~ Anchorage. ARCO Alaska, Inc. is a Subsidiary' of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Type of Request: Operation Shutdown Stimulate Plugging m Perforate ~ Pull tubing Alter casing Repair well Pull tubing Other Z. Name of Operator ARCO Alaska. Inc. 3. Address P. O. 8ox 100360r Anchora~er AK 99510 4. Location of well at surface 2070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM At top of productive interval 1983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM At effective depth 1983' FNL, 218' FWL, Sec. 3, T7N, Rgw, SM At total depth 1951' FNL~ 210' FWL~ Sec. 3~ T7N~ R9W~ SM 12. Present well condition summary Total Depth: measured 10850' true vertical 10844' 5. Type of Well: Development Exploratory Stratigraphic 6. Datum elevation (DF or KB) 166.7' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 12A-3 9. Permit number/approval ~mber 10. APl number 50-133-10099-01 11. Field/Pool Swanson River/Hemlock feet Plugs (measured) feet Effective depth: measured 10700' feet Junk (measured) true vertical 10694' feet !13. Casing Length Size Cemented Measured depth Structural 28' 22" to Surface 28' Conductor Surface 3000' 13-3/8" 1792 SX in 2 stages 3000' Intermediate Production 10265' 7" 2608 SX 10265' Liner 845' 5" 860 SX 10844' Perforation depth: measured ~ue vertical depth 28' 3000' 10262' 10841' 10420'-10428', 10470'-10476', 10542'-10550', 10561 '-10577', 10579'-10590', 10598'-10602' true vertical 10418'-10425', 10467'-10473', 10538'-10546', 10557'-10573', 10575'-10586', 10594'-10598' Tubing (size, grade, and measured depth) 3-1/2" 9.3# J55 tbg @ 10042'; 2-3/8" 4.7# N-80 10042'-10268' Packers and SSSV (type and measured depth) Baker 3-1/2" FH pkr @ 10033'; Baker 2-3/8" FH @ 10105' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED N/A MAY - 1 1992 Alaska 0it & Gas Cons. Comm~ss~o~ Anchorage 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 120 14327 23 175 3300 Subsec~uent to operation 155 22328 49 160 2900 1.5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~:/~'~~ ~ Title Cook Inlet Re~lional En~lineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. REMARKS WELL SERVICE REPORT FIELD - DI$IHIG~ · ~r'A~F. ' ' iOPE~AT REIK:)RT TiME tDAY$ IOAI'E m, ,,,, · ii ___ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK /? , Alaska Inc.- Swanson l "gr Field Well- scu 12A-3 ~. APl#: 50-133-10099-01 ~ Well TyPe:Producer Spud Date: 11/9/82 Completion Date: 12/1/82 Last Workover: Original RKB: 26' Hanger Type-Shaffer Hanger: Shaffer Top of Hemlock:10,387'MDMax. Hole Angle: 7° Angle @Hemlock' o All Depths are RKB MD to Top of Equipment. 1 3 4 5 6 7 8 9 10 11 12 Jewelry I 1487' 2 2729' 3 3750' 4 4486' 5 5292' 6 5812' 7 6111' 8 6505' 9 9985' 10 10034' 11 10040' 12 10042' 13 10106' 14 10268' 15 10699' Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM Cartmo 3 1/2" KBUG GLM Camco 3 !/2" ~BUG GLM Camco 3 1/2" ~f~BUG GLM Camco 3 ! ~2" KBUG GLM Camco 3 'i I2~' v/l" EK Equal. Valve Baker 7" x .3 i/i~" Packer Otis "$" N~ppt~? Position 2 ( I.Di= 2.875") X-Over 3 ~:/2 r~, ': 2 3/8" 4.1875" O.D. Baker 5" x 2 ?~3" FH Packer 4.125" O.D. Baker Mule Shoe Shear Sub Baker K-l, Wi~eline Set Retainer Casing and Tubing Size Weigf'~ Grade ~ Bottom Descriotion 13 14 22" !ine pipe 0 28? 13 3/8" 54.5# ;:~-3 0 3000' 7" 29# :~-110 0 10265' 5" 18# i'~-80 10045' 10848' 3 1/2" 9.3# N,L-80 0' 10042' 2 3/8" 4.7# N-80 10042' 10267' Cunductor Pipe Surface Casing ProductionCasing Liner Tubing Tubing S.T. H10 Perforation Interval ~ 0,~ -~;~10,420'-10,428' H2 10,470'-10,476' H4 10,561'-10,577' H8 10,579'-10,590' H8 10,598'-10,602' He 10,716'-10,730' HI[; 15 6/20/89 Data Zon~ ,FT SPF Date 8' 4 8/88 6' 4 8/88 16' 4 2/84 11' 4 2/84 4' 4 2/84 14' 4 12/82 Below Retainer L~D00" GR Tag (~ 10.586'M D PBTD = 10,806' TD = 10,850' R~.C~./V~ Well SOU 12A-3 By: JLB 8/7/91 Rev. N~ka Oil ,& Bas (;0~s, u ' ,A~chora~e ARCO ALASKA INC. Cook Inlet Engineering #556 TRANSMISSION TO: Blair Wondzell FROM: COMPANY: AOGCC DATE: 1/2/92 Victoria Ferguson COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following Blue" Sepia Sepia raPe & Line. Folded!Rolled M~,lar listing TemparatUre Log- SRU 31-33WD 1 1 Perf Record - SCU 12A-3 '" 1 "l , , , , , Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATtI~I~/~ IV ~ D Post Office Box 100360 Anchorage, AK 99510-036~)/~N _ ~ ~005~. S, laska Oil & Gas Cons. C0mrnisslo~ Anchorage ARCO Alaska, Inc.[ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering August 21, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H6 Sand in Swanson River Field well $CU 12A-3. We propose to add 8' of new perforations in the H6 Sand with 1- 11/16" strip guns. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Murray Hamilton at 263-4384. Sincerely, T. Wellman TW:MOH:czm:0120 Attachment CC' Mr. W, Watson Marathon Oil Company Mr. B. C. Dehn UNOCAL Corporation SCU 12A-3 Well Files RE¢'EIVED · . AUG 2 1991 Alaska Oil & Gas Cons. ComallB$lJ~ 7~.nchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF AI.ASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc. 3. Address Operation Shutdown _ Re-enter suspended well _ Plugging_ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate ~ Other _ P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface . 2070' FNL, 305' FWL, Sec. 3, T7N, Rgw, SM RECEIVED At top of productive interval 1983' FNL, 218' FWL, Sec. 3, T7N, Rgw, SM At effective depth AU G 2 1991 1983' FNL, 218' FWL, SEC. 3, T7N, R9W, {~l~$j~1.0Jj & 6as Cons. C0mmissien At total depth 1951' FNL, 210' FWL, Sec. 3, T7N, R9W, SM ~lcJ~Orag8~ 12. Present well condition summary Total Depth: measured 1 0,850 feet true vertical 1 0,844 feet Plugs (measured) 6. Datum elevation (DF or KB) 166.7' KB 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 12A-3 9. Permit number 10. APl number 5o-133-10099-Q1 11. Field/Pool Swanson River/Hemlock Effective depth: measured 10,700 feet Junk (measured) true vertical 1 0,6 94 feet 13. Casing Length Size Cemented Structural 28' 2 2" to surface Conductor Surface 3,000' 1 3-3/8" 1,792 SX in Intermediate 2 stages Production 1 0,265' 7" 2,608 SX Liner 845' 5" 860 SX Perforation depth: measured Measured depth True vertical depth 28' MD 28' TVD 3,000' MD 3,000' TVD 10,265' MD 10,262' TVD 10,844' MD 10,841' TVD Current: 10,420'-10,428'; 10,470'-10,476'; 10,561'-10,577'; true vertical Current: 10,418'-10,425'; 10467'-10,473'; 10,557'-10,573'; Tubing (size, grade, and measured depth 3-1/2", 9.3# J55 @ 10,042'; 2-3/8" 4.7# N-80 10,042' TO 10,268' Packers and SSSV (type and measured depth) Baker 3-1/2" FH @ 10,033'; Baker 2-3/8" FH @ 1,0,105' Attachments Description summary of proposal X Detailed operation program 10,579'-10,590'; 10,598'-10,602'; MD 10,575'-10,586'; 10,594'-10,598'; ; TVD BOP sketch X. 14. 16. Estimated date for commencing operation AUoust. 1991 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas_ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned '~,M~7.,_.. Title Cook Inlet Recjional En~r. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~-~Zl' Approved by the order of the Commission ORIGINAL SiGNE0 BY LONNIE C. SMITH IApproval No. ogro~ed O°P~J Commissioner Date ~::~'"c~ ~ --- ~'/ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE ' Arc(x/' ,laska Inc.- Swanson Rive( :ield Well- $cu 12A-3 APl#: 50-133-10099-01 Well Type:Producer Spud Date: 11/9/82 Completion Date: 12/1/82 Last Workover: Original RKB' 26' Hanger Type' Shaffer Hanger: Shaffer Top of Hemlock:10,387'UD Max. Hole Angle' 7° Angle @Hemlock · o All Depths are RKB MD to Top of Equipment. 1 2 3 4 5 6 7 8 9 10 11 12 Jewelry I 1487' 2 2729' 3 3750' 4 4486' 5 5292' 6 5812' 7 6111' 8 6505' 9 9985' 10 10034' 11 10040' 12 10042' 13 10106' 14 10268' 15 10699' Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM Camco 3 1,2" KBUG GLM RECEIVED Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM Camco 3 1/2" KBUG GLM AUG 2 31991 Camco 3 1/2" KBUG GLM ~!a-~,Oil&-. Camco 3 1/2" KBUG GLM Cons Camco 3 1/2" w/l" EK Equal. Valve Baker 7" x 3 1/2" Packer Otis "$" Nipple Position 2 ( I.D.= 2.875") X-Over 3 1/2" x 2 3/8" 4.1875" O.D. Baker 5" x 2 3/8" FH Packer 4.125" O.D. Baker Mule Shoe Shear Sub Baker K-l, Wireline Set Retainer Minimum I.D.: 2-3/8" tbo (I.D.= 1.995") Casing and Tubing Size Weight Grade Top Bottom Descri~3tlon _ 13 14 22" 13 3/8" 7" 5" 3 1/2" 2 3/8" line pipe 0 28' Cunductor Pipe 54.5# R-3 0 3000' Surface Casing 29# P-110 0 10265' ProductionCasing 18# N-80 10045' 10848' Liner 9.3# N,L-80 0' 10042' Tubing 4.7# N-80 10042' 10267' Tubing s.m, HIO 15 Perforation Data Interval Zone 10,420'-10 428' 10,470'-10 476' 10,561'-10 577' 10,579'-10 590' 10,598'-10 602' 10,716'-10 730' H2 H4 H8 H8 H8 H10 F_[[[._D..~g~: 6/20/89 PBTD = 10,806' TD -- 10,850' FT SPF Date Comments 8' 4 8/88 6' 4 8/88 16' 4 2/84 11' 4 2/84 4' 4 2/84 14' 4 12/82 Below Retainer 1.600" GR Taa (~ 10.586'M D Well SCU 12A-3 By: JLB 8/7/91 Rev. E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension RECEIVED AUG ~ ~ 1991 Alas.~.Oil .& Gas Cons. Commisslen ~Orage Manual Rams < Swab Valve Double Master Valves Wellhead MOH 6/1/91 SUMMARY OF PROPOSED WELL OPERATIONS WELL SCU 12A-3 (August 15, 1991) 1. RU E-line unit and lubricator. 2. Pressure test lubricator. 3. Perforate the following intervals: Run No. Bench 5. H6 Interval (MD,DILl 10542'- 10550' 4. RD E-line unit and lubricator. Leneth SPF 4 RECEIVE AUG ~ ,~ 1991 .Oil & Gas Cons. ~,umm~s$~t~:, Anchorage ARCO Alaska, Inc. ~ Post Office Bo~( 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 14, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Subsequent Sundry Notice for SCU 12A-3 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations for SCU 12A-3. This well was perforated in the H2 and H4 interval of the Hemlock Reservoir on August 6 and 7, 1988. Sincerely, T. S. McCorkle Engineering Manager TSM:WMP:cmk:0019 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA_~ "--, OIL AND GAS CONSERVATION CO~r~' SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate I'-] Alter Casing [] Other ID .2. Name of Operator ARCO A]asEa Inc. __ 3. Address · Post Office Box 100360 Anchorage, AK 99510-0360 Plugging El Pedorate I~ Pull tubing [] 5~..~¥~]~evation (DF or KB) 6. Unit or __Pro~ert_v name Soldotna Creetc IYnit Feet 4. Location of well at surface 2,070' FNL, 305' FWL, Sec. 3, T7N, R9W, SM At top of productive interval 1,983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM At effective depth 2,983' FNL, 218' FWL, Sec. 3, T7N, R9W, SM At total depth ' 1,951' FNL, 210' FWL, Sec. 3, T7N, R9W, SM 11. Present well condition summary Total depth: measured true vertical ]0,$44' feet feet 8~_A5~rov, l number 9. APl number 50-- 133-10099-01 10. Pool Swanson River-Hemlock Effective depth: measured 10,700' MD feet true vertical 10,694' TVD feet Plugs (measured) Junk (measured) none none Casing Length Size Cemented Structural 2 8' 22" To surface Conductor Surface 3,000' 13-3/8" 1,792 SX in two stages Intermediate 10,265' 7" 2,608 SX Production Liner 845' 5" 860 SX Perforation depth: MD: 10,598'-10,602' 10,579'-10,590' 10,561-10~577' TVD: 10,594'-10,598' 10,575'-10,586' 10,557'-10,573' Measured depth 28'MD 3,000' MD 10,265' MD 10,844' MD True Vertical depth 28' TVD 3,000' TVD 10,262' TVD 10,841' TVD Tubi~-gl-~;e'~e~'~r~a~[~'l~/8" 4.7# N-80 10,042' to 10,268' PaC~e~nS~S~ (~e~)n(~0q~.~rej~a~:e&t~-3/8" m @ 10,105' 12. Stimulation or cement squeeze summary 1~,tF1~~s tJ'~,~{mel_~,~lP~) - 10,476' Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 230 24,500 100 1500 Subsequent to operation 14. Attachments x Daily Report of Well Operations [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge 230 24,500 100 1650 Tubing Pressure 2400 2400 Copies of Logs and Surveys Run ~ Signed~,,~ L~~~..~ ,(~ T5 tlc e~ YJ.e._ Form 10-404 Rev. 12-1-85 Title Cook Inlet Engineering Manager Date Submit in Duplicate¢. ARCO Alaska, Inc. CONTRACTOR ~MAIRKI~ TEL N0:158~ WELL SERVICE REPOI I FIELD- DII~TRIOT - $TATE [OAYS IOPERATION AT REPORT TIME ,! __ cor~ .ey.. ~_ -* ,,i CrV ?~--~t" .t AUG-86-' 88 ~1: 55 ID: SWANSON TEL N0:1383 .082 ARCO Alaska, Inc. <~ WELL SERVICE REPOF Sul~14y of AIII~IIe Rl~l~fllld ~~~ ..... ?~_~,_n tt~t~o~c, to:v~~6~ B~E~?d~ _b-?'_ _, ,. ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMrI~AL #239 TO: Commissioner FROM: Tom Wellman "COMPANY: AOGCC 'COMPANY: ARCO Alaska, InC ?ATE: Aug. 19, i988 ' . ...... WELL NAME: SCU 12A-3 · Transmitted herewith are the following: I~LEASE NOTE: BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy "1 BL 1 Sepia Gamma Ray Collar Log '2'1 BL 1 Sepia Perforating Depth Record Receipt Acknowledgement: D / { / Anchorage Rem ~iept A~: Judy 3~A Post Office Box 100360 Anchorage, AK 99510 ARCO Alaska, Inc. Post Office Bo× 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering July 25, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notice for SCU 12A-3 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the casing in Well SCU 12A-3. We propose to perforate the H2 interval from 10,420' to 10,428' MD and the H4 interval from 10,470' to 10,476' MD with 1-11/16" hollow carrier perforating guns at 4 SPF. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Wes Peirce at 263-4228. Sincerely, T. Wellman Interim Manager TW:DAP:ch:0003 Attachments RECEIVED j U L 2 8 1988 Alaska Oil & 6as Cons, CommissiOn! Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALA OIL AND GAS CONSERVATION CO ,~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator ARCO Alaska, Inc. · 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface A{070' FNL, 305' FWL. Sec. 3 T7N, R9W SM top of productive interval' ' ' 1,983' FNL, 218' FWL, Sec. 3, T7N, Rgw, SM At effective depth 1,983' FNL, 218' FWL, Sec. 3, T7N, Rgw, SM At total depth 1,951' FNL, 210' FWL, Sec. 3, T7N, Rgw, SM 5. Datum elevation (DF or KB) 166.7' RKB feet 6. Unit or Property name Soldotna Creek Unit 8. Permit number 9. APl number 50-- 133- 10099-01 10. Pool Swanson River - Hem lock 11. Present well condition summary Total depth: measured true vertical 1 O, 850 feet plUgs (measured) 1 O, 844 feet Effective depth: measured 1 O, 700 feet Junk (measured) true vertical 1 O, 694 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 28' 22" to surface 28' MD 28' TVD Surface 3,000' 13-3/8" 1,792 SX i n 3,000 ' MD 3,000' TVD I){ ~Y,i~a~;~ YeXe 2 stages Production 10,265' 7" 2,608 SX 10,265' MD 10,262' TVD Liner 845' 5" 860 SX 10,844' MD 10,841' TVD Perforation depth: Measured: 10,598' - 10,602'; 10,579' - 10,590'; 10,561' - 10,5_77' True Vertical: 10,594'-10,598'; 10,575'-10,586; 10,557'-~~V~U Tubing (size, grade and measured depth) J UL 2 8198 _5-1/2". 9.3// J55 @ 10,042'; 2-3/8" 4.7// N-80 10,042' to 10,268' Packers and SSSV (type and measured depth) A)aska Oil & Gas Cons. Commissi0~ Baker 3-1/2" FH @ 10.033': Baker 2-3/8" FH ~ 10.105' · Anch0raqe 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July, 1988 14. If proposal was verbally approved Name of approver Subsequent Work Reportecl on Form No. [~- qoq Dated ~_._/~.~g ~'~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ r.{/~~._~ Title Cook I n let Inter im Manager Commission Use Only Date Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity []'~BOP Test [] Location clearance Approved Copy Returned £ Commissioner Approval No. the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Procedure SCU 12A-3 Perforation . 2. 3. 4. 5. 6. 7. , 10. 11. 12. 13. Before proceeding - confirm with Anchorage that both the BLM and the AOGCC sundry notices have been approved. Safety meeting with all personnel involved in the procedme. MIRU slickline unit. Pressure test lubricator to 4000 psi. RIH with a 1.8" gauge ring to top of fitl. RDMO slickline unit. SI well just prior to MIRU wireline unit. MIRU wireline unit. Pressure test lubricator to 4000 psig. Rill with tool string consisting of, from the bottom, a bull plug, a 10' 1 9/16" hollow carrier perforating gun loaded with 6 feet of 4 SPF (0° phase) perforating charges, a firing head, a GR-CCL, weight bar, and a cable head. The onsite Operations Engineer should tie-in the perforating guns. Position the gun so that the bottom shot perforates the 5" liner at 4-10,476' RKB. Perforate the easing with thc gun described in step #5. POOH with the spent perforating gun. RIH with tool string consisting of, from the bottom, a bull plug, a 10; 1 9/16" hollow carrier perforating gun loaded with 8 feet of 4 SPF (0° phase) perforating charges, a firing head, a GR-CCL, weight bar, and a cable head. The onsite Operations Engineer should tie-in the perforating guns. Position the gun so that the bottom shot perforates the 5" liner at +10,428' RKB. Perforate the casing with the gun described in step #8. POOH with the spent perforating gun. RDMO wireline unit. Test the well on the following days after perforating is complete: 1,3,6,10 & 15. AR38.~001.A E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension L Manual Rams Swab Valve DOuble Maste~ Valves Wellhead DML 7/22/88 TRANSMITTAL 'AND ACKNOWLWrX~IT OF RECEIPT OF MATERIALE EXP-140 Date Under separate cover, we are forwarding the following material, via If material is not received within five days, please advise ~mmediately. Received and checked by: B~~~~ ~~~-~ Date: " RECEIVED hOV 2 1 l~ Alaska Oil & Gas Cons. Commission Anchorage EXP-140 (2~-CD-8-61) Printed in U.S.A. ALA.SI[A OIL ,4Nil ilA~ ~,OIISEIIYATIOII . ~,OIINISSION TO.' Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE.ALASKA gg$01.1-31g 2 TEL EPHONE (907) 279'- 1433 We wish to bring to your attention that the Commission has no~ yet received the following required items on the subject, well which our records indicated was completedL //-g/~-'o~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. Chairman '1c:C.024 OIL ,4ND ~AS ~,ONSEII¥,JTION . ~,OMMISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 095014-31'02 TELEPHONE (907) 270,-1433 We ~sh to b~ng ~o you~ attention that the Co~ss~on has yet ~ece~ved the Eo~o~n~ ~equ~ed ~tems on the subject which our records indicated was completed /~-~/-~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. Chairman lc:C.024 ALASKA OIL AND GAS CONSERVATION.COMMISSION Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501~3192 TELEPHONE (907) 279--1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed /~2 "0 (2~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code', stipulates that this material shall be filed within 30 days after completion of a drilled well. Please 'submit the above missing material. Sincerely, C. V. Chat~ Chairman CHEVRON U.S.A. INC..~ DATE A~,CT 2J, {~ PLACE: THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. , RECEIVED BY BY i i - (I[IEYMON U. S3~ INC. BOX 7-839 gELL SURVEY Pro-312 WELL gl~.* J"c~ /,~'-.3' COUNTY OF ~,ew/' CITY OF SECTION NO.. J ,, TOIIN~ilIP, 74/ RANGE .~ ~ [~ S. ByB'. & 14. r-~M.D.B. & M. TRACT NO. ~ PROPOSED r-1 PRELIMINARY J]~ FI NAL LOT NO. FI ELD ,-~-,~,,,,,,-~,w ,,~/ ELEVATION: ~ROUND ,,/'SZJ- ~ CONCRETE MAT DERRICK FLOOR ALTERNATE OR SURVEYED LOCATION LOCAT I OR DESIGNATION LOCATION COORDINATES HOVE' RD4ARKS , · ~. , , , , NORTH --~-- - -F ...... -f- .... ed.. I ,..,~,= ~. ~ I I .... + 4 4---- I I, BENCH HARK IS: SKETCH OR RENARKS RECF. VED AUG 2 1 ]984 Alaska. 0il & Gas Cons, CommJss[o, Anchorage STATION,,'" SEARIRG- DISTARCE SINE COSINE NORTH SOUTH EAST WEST /z-.r .d, ~',,;,f 7~,,. /t/ /,.~ "...c-z" '/_c-"u./ ~ & ,~ . ~- E ,_F.,/. ,P 7 ~. I ' .~ ~ ~ / : ~ z ~,~ . 7..~ '~"~ ' / · .,:")-,,v/ C.C. DIV. ENGR. FI LE PBINTED IN U.S.A. SURVEYOR C. ,e'~,-.,-od,/,o,/I4AINT. FRli. DATE /z ,.~,,.,.,, /?~'/ DATE NAINT. SUPT. DATE PR0.312 (2500.CD. 1 - 58) ALASKA OIL AND GAS CONSERVATION COMMISSION Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 '-319= TEL EPHONE (907) 279-1433 We wish t.o bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed' /~--~/--~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman Chevron Chevron U.S.A. Inc. July 20, ]984 Alaska 0il & Gas Consv. 3001 Porcupine Drive Anchorage, AK. 99501 Combo Gen:~lemen: Enclosed for your records are well histories and SCU 2~9/321-9. Sincerely, RECEIVED J U L 2 o 1984 Alaska OiJ & Gas Aflchora~e 100 Years Helping to Create the Future AREA: COMPLETION REPORT CHEVRON U.S.A., INC. Swanson River Field LAND OFFICE: Anchorage PROPERTY: Soldotna Creek Unit LEASE NO: A-028997 WELL NO: sou 12A-3 APl NO: 50-133-1009-01 LOCATION:AT SURFACE: 2,070' s & 305' E of the N.W. Cot., Section 3' ..... T7N, R9W, $.M. LOCATION AT TOTAL DEPTH: 119' N & 95' W of the surface location. ELEVATION: DATE: 2/84 140.5' G.L. ._~A SUPERVISOR WORK PERFORMED BY: Brinkerhoff Signal Inc., Rig ~58 DATE COMMENCED WORK: 2/8/84 ' DATE COMPLETED WORK: 2/24/84 t ECEIVEO JUI. 2 0 ]984 Alaska Oil & Gas Cons. Anchorage TOTAL DEPTH: 10,850' EFFECTIVE DEPTH: 10,806' CASING: 22" at 28' 13 3/8" at 3,000' 7" at 10,265' 5" liner 10,848' - 10,045' SUMMARY PERFORATIONS: PLUG: 10,716' - 10,730' 10,598' - 10,602' 10,579' - 10,590' 10,561' - 10,577' 10,850' - 10,806' Tagged fill at 9,224' with W.L. Shot a $ shot circulating charge from 9193.5 to 9,195'. Moved Brinkerhoff Rig #58 from SCU 23B-3 to SCU 12A-3 and rigged up. ,2/8/84 Completed rigging up Brinkerhoff Rig #58. Attempted to bleed 200 psi off annulus without success. Could not pump mud down tubing - tubing held 3,000 psi. Nippled down tree,, nippled up Class III 5000# BOPE. Accepted rig at 6:30 p.m. .. . ........... !/9/84 Tested Hydril to 2,500 psi - all other rams, valves, liners, and choke manifold to 5,000 psi. Joe Russell (BLM) and Blair Wondzell (AOGCC) waived witnessing test. 2/10/8t '- RIH with 2 1/8" perforating gun and shot 4-t" circulating holes in 3t" tubing at 9,190'. Pumped 10 ppg. mud down the tubing. 2/11/84 Pulled packer, at 10,006' with 60,000# overpull. stands. POOH. Broke circulation every 10 -15 2/1~./84 While backing off sand filled tubing, pressure was seen leaking out threads. With four threads remaining the tubing stripped out of box releasing trapped pressure. Sand, gravel and rocks were blown out tubing injuring two people with eye and ear lacerations Continued pulling tubing as follows: Located sand bridges with wireline. POOH to sand bridge. Drilled hole in tubing below sand bridge to relieve pressure. Released pressure on 11 sand bridges while pulling out of the hole. Total fill was +700'. Recovered 45 joints 9.3# L-80 8rd, 268 joints 9.3# N-80 8rd, and 10 joints 9.3# N-80 Seal Lok. 2/1,,3/84 Tagged top of liner at 10,045' - no fill. Bit plugged - unable to circulate. Well bubbling, but not flowing. Reverse circulated and unplugged bit. Circulated bottoms up - recovered gas and gas cut mud. 2/14/84 RIH to top of liner - no restrictions. Circulated bottoms up. Cleaned out fill from 10,539'- 10,790'. Fill inside liner appeared to be occasional boulders with a sand-clay matrix. Could not get deeper than 10,790' due to drill string torquing up. POOH. D Note: Add 9' to DP measurements to correlate with redrill depths. ~ J U L 2 0 1984 Alaska Oil & Gas Cons. Commission Anchorage 2/15/84 RIH and cleaned out fill 10,755' - 10,790'. POOH. DIA-LOG ran casing calliper tool which stopped at 5" 8rd x Butt. X-over at 10,388'. Recovered packer rubbers and small rocks with the tool. Ran DIA-LOG's minimum I.D. tool which stopped at 10,388'. Recovered small rocks with the tool. RIH with 4 1/8" BIT - no indication of tight spot at 10,388', but encountered tight spot at 10,707'. 12/16/84 Had to reverse circulate twice to unplug bit. Mixed and pumped a 40 bbl., 150 sec. vis sweep. Pulled up to 10,393' then mixed and pumped a 70 bbl., 200 see. vis. sweep. POOH. Ran DIA-LOG's minimum I.D. tool through the 5" liner. The log indicated the 5" liner from 10,045' to 10,388' to be 15# rather than 18#, a ¼ reduction in I.D. from 10,720' to 10,736', and a possible enlarged diameter at the top perf. Attempted to run the casing, caliper tool twice unsuccessfully. 2/ ?/84 Ran DIA-LOG's casing caliper tool - log showed bad pipe through the perforated interval 10,716'- 10,730' DIL. RIH with a 5", 18# Baker K-1 wireline set retainer - retainer stopped at 10,558'. POOH. RIH with 4" junk basket to 10,700'. POOH. Set retainer at 10,700' DIL. Tested retainer to 3,000 psi for 30 min. Changed!well oyer to lease crude. 2/].8/84 Ran production string while hydrotesting to 5,000 psi as follows: Note: Ail measurements are from an original 26' K.B. Actual BSI Rig #58 DF is 17'. Tubing hanger is 4' below GL. Top as Mess. Item F/Orig. 26' D.I~. Mule Shoe (Shear out Sub) 5 Jts., 2 3/8", 4.7#/ft., N-80, EUE, 8rd tubing Baker 5"x 2 3/8" FH Pkr. 2 Jts., 2 3/8", 4.7#/ft., N-80, EUE, 8rd XO: 3~, EUE, 8rd Box 2 3/8", 8rd, Pin Otis .Pos. 2 "S" Nipple Baker 7" x 3~" FH Pkr. i Jt., 3~", 9.3#/ft., L-80, EUE, 8rd tubing Camco G/L Mandrel w/l" EK valve 110 Jts., 3~", 9.3#, N-80 & L-80, EUE, 8rd tubing 10,267.88 10,105.90 10,042.15 10,040.48 10,033.50 9,984.89 RECEIVED 'JUL ~aska Oil & 6as ~/18/84 (Contel.) Top as Meas. Item F/O~ig. 26' D.F. Camco G/L Mandrel w/l" Dummy 12 Jts., 3~", 9.3#/ft., N-80 & L-80 EUE, 8rd tubing 6,505.05 Cameo G/L Mandrel w/l" Dummy 6,110.70 9 Jts., 3 ~", 8rd tubing Cameo G/L Mandrel w/l" Dummy 5,812.44 16 Jts., 3~", 8rd tubing Camco G/L Mandrel w/l" Dummy 5,291.87 25 Jts., 3 ~", 8rd tubing Camco G/L Mandrel w/l" Dummy 4,486.40 23 Jts., 3 ~", 8rd tubing Camco G/L Mandrel w/l" Dummy 3,749.83 32 Jts., 3~", 8rd tubing Camco G/L Mandrel w/l" Dummy 2,728.64 39 Jts., 3 ~" 8rd tubing Cameo G/L Mandrel w/l" Dummy 1,487.10 46 Jts., 3~", 8rd tubing Tubing hanger bored for a 3~" Cossasco BPV. 30.00 Tbg. Hanger to GL 4.00 G.L. to D.F. 26.00 All gas lift mandrels are 3~", EUE, 8rd KBUG, Camco, mandrels w/a 1" side pocket. 2/19/84 Nippled~ up tree and tested to 5,000 psi. Cossasco BPV would not pass through top flange. Removed flange and BPV. Dresser-Atlas perforated 4 JHPF on 90° phasing from 10,598' to 10,602' DIL using i 11/16" link kone charges. POOH. Could not get past 2,925' with second link kone charges. POOH. Left 43 perforating charges (10 3/4') in hole. Put rig on standby at 12:00 midnight. .2,p.o/84 C.A. White recovered 6 perforating charges. Remaining fish moved down hole to 3,546'. Discontinued fishing due to debris on top of fish. Attempted to pump 100 bbls. 8.6 ppg NaC1 water down tubing - tubing held 3,000 psi. Rig on day rate at 12:00 midnight. 2/2]./84 Nippled down tree - nippled up Class III 5,000# BOPE. Tested Hydril to 2,500 psi - all other rams, valves, lines, and choke manifold to 5,000 psi. Witnessing of test waived by Joe Russell (BLM) and Harold Aeelund (AOGCC). Released packers with 140,000# overpull. Displaced lease crude with salt water by pumping down tubing. Circulated bottoms up until well dead. 2/22/8.4 POOH with 2 3/8" and 3~" tubing string. Recovered 24 perforating charges from mandrel at 6,110'. 13 charges remain in well. Replaced Baker shear sub, 5" packer and 7" packer. Re-ran tubing identical to detail of 2/18/84. RECEIVED J U L 2 0 1984 Alaska Oil & Gas Cons. Commissiofl Anchorage ~/23/8¢ Displaced salt water in well with lease crude. Tested packers to 3,000 psi, N.D. BOPE, NU tree and tested to 5,000 psi. 2/24/84 Schlumberger perforated 10,579' - 10,590' and 10,561' - 10,577' DIL with 4 JHPF at 0o phasing using a i 11/16" Enerjet gun. Turned well over to produetion. Rigged down Rig #58. Released rig at 4:30 p.m. RECEIVED ~J U L 2 0 1904 Alaska Oil & Gas Cons, Commission Anchorage Bill Sheffield Governor AL.4$K,4 OIL .4HD G~t$ 30~1 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.;-319 TELEPHONE (907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed _/~?-~:~/-~'~,~, Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well.. Please submit the above missing material. Sincerely, C. V. Chatt~rMpn Chairman Form 3160-5 (November 1983) (Formerly 9--331) I('~' ~"TED STATES DEPART~NT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUBMIT IN ~'*" 'CAT~* (Other Instruct~ on re* verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form f.o~., bas, amis to drill or to deepen or plug back to · different reservoir. Use APPLICATION FOR PERMIT--" for such Form approved. Budget Bureau No. 1004--0135 Expires_ August 31, 1985 I. o,L ·olds·ha Creek Unit 2. ,,,Ms om ors--Tom 8. m--a om ,,,as. ,,&Mm Chevron U.S.A. Inc. 3. ADDI.~· Of oIm'BB~TO· P.O. Box 107839, Anchorage, Alaska 99510 4. ~OCATIOM Of WECL (Report location clearly and tn accordance with any State require·entre See also space 17 below.) At surface 2070' S & 305' E from the N.W. Car., Sec. 3, TTN, R9W, S.M. 15. BI3VATION8 (Show whether DIP. IrT, Git, eM.) 166.7' K.B. 14. Pal[MIT NO. 80-104 9. wmbL i~O. SCU 12A-3 10. FI~D AND POOL, OB WILDCAT Swanson River - Hemlock 11. 8~.., ~** I.. iq OB aLL AID · UBVBY OB ABRA . Sec. 3, T7N, R9W, S.M. is. co~m,, o, ,--mai la, .T,,. Kens·[ AK. 16. Check Ap~omiate Box To Indicate Nature of Notice, Report, or Other Data NOTICB Of IIqTBHTIOIq TO: TEST WATBI 8HUT-OF~ PULL 0R ALTER CASINO fRACTURe TREAT MULTIPLS COMPLRTE SHOOT OB ACID~B ABAN~Ne (Other) (No'em: Report results of multiple completion on Well Completion or Rccompletion Report and Log fora.) !7. oEscazn£ I'IIOI'OSED sa CO.~IPLETED oPgaATIONS (Clearly state all ~rtlne.t details, and give ~rtinent date~ lncludl~ ~flmat~ date of.l~ prooos~ work. If w~i ~ di~tion~ driH~, give s~e l~fions and meam~r~ and true verti~ dept~ for ~1 marhe~ aaa ~a~ ~m- nent ~ ~is wor~) * 1. Moved in and rigged up Brinkerhoff Signal Rig ~58 2-8-84. 2. Killed well, removed tree. 3. In·Called and Ces~ed Class III B0~l. ~, t. Recovered all o~ 3~" production string. 5. Cleaned out casing and liner to 10,799'. Alaska0[l a Gas 6. Ran DIA-L~ minimum O.D. and casing caliper tools from 10,730' to liner t~}~: Located split casing from 10,716' - 10,730'. 7. Ran and set retainer at 10,700' and tested to 3,000 psi. 8. Ran 3~" x 2 3/8" production tub·ns. RemOved BOPE and installed production tree and tested tree to 5,000 psi. 9. Perforated interval 10,598' - 10,602' 4JHPF 90° phasing. Stuck perforating gun in tubing on next run. 10. Removed tree, installed ROPE and pulled tubing. Recovered perforating gun from tubing. 11. Removed BOPE,.~.installed production tree and tested tree to 5,000 psi. 12 Perforated interval 10,579' - 10,590' and 10 561' - 10 577' with 4JHPF 0O phasing 13. Released rig om 2-2~-8~. Placed well om production 2-26-8~. 18.8IGNEDI hereby ~and correct TITLE Area Engineer (This space for Federal or State alee use) APPROVED BY CONDITIONS OF APPROVAL, 1]' ~: TITLE DAT~ 'See Instructions on Reveae Side Title 1S U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. Form' 3160--5 (November 1983) (Formerly 9--331) ~ :TED STATES DF. PARTIVJLNT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUBMIT IN T~ .... :CA~e (Otiter tustrnet~< on re- verse sid~) SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for Itropoeals to drill or to deepen or pluw bask to a different reservoir. Use "APPLICATION FOR PERMIT--" for sueh propose) Form approvecL ~ Budget Bureau No. 1004-0135 Expires_ August 31, 1985 5. LIAII OBSIGNATIOIq AND 8B~I~L I~O. A-028997.. ........ 3. ADDEr,18 Ol' OI'BBATOR P. 0. Box 107839, Anchorage, Alaska 99510 4. LOCAT,O~ of WELL (Report location clearly and in accordance with any State requirements.· See also space 17 below.) At surface 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. ECU 12A-3 10. ~,~M~ AND I~OOL, OIt WILIN~AT ~wanson River - Hemlock Il. SB~, T., L, Mq OR ~L~. A~O · UIVB! OI A~UA Sec. 3, T7N R9W, S.M. 14. PERMIT NO. IS. ILBVA~O~ (S~w whether Df. ~, ~ et&) 12. d~OUMTY OI P~IEH! l~ ~A~ 80-104 166.7' K.B. Kenai AK. xe. Check Ap~o~iateBox Tolndicate Nature oF Notice, Repod, orO therData NOTICE Of INTENTION TO: TEST WATER 8HUT-OFF I I PULL OR ALTER CASI.'~O [ [ FRACTUEm TRSAT MULTIPLE COMPI,ETF SHOOT OR ACIDrY-B ABAMD'~e REPAIR WELL CH&NGI PLANS (Other) EUBEBqUBI~T RBI'OBI OF: ~Nom°'ep~etiRoenI~orrtRret~u~ll~l~on Rei~lh an~igI~, form ) D~:SCaXUE I'I1OI'OSED OR COMPLETED OPtaATIONS (Clearly state all pertiue,t details, and give pertinent dates, including e~tlmated date of startinw any proposed work. If well ia dir~ctionatly drilled, give subsurface locations and mess, red and true vertical depths for off markers and ~iouem perti- nent to this work.) ~ 10. 11. 12. 13. 1. Moved in and rigged up Brinkerhoff Signal Rig #58 2-8-84. 2. Killed well, removed tree. 3. Installed and tested Class III BOPE. 4. Recovered all of 3½" production string. 5. Cleaned out casing and liner to 10,799'. 6. Ran DIA-LOG minimum O.D. and casing caliper tools from 10,730' to liner top. Located split casing from 10,716' - 10,730'. 7. Ran and set retainer at 10,700' and tested to 3,000 psi. 8. Ran 3½" x 2 3/8" production tubing. Removed BOPE and installed production tree and tested tree to 5,000 psi. 9. Perforated interval 10,598' - 10,602' 4JHPF 90© phasing. Stuck perforating gun in tubing on next run. Removed tree, installed BOPE and pulled tubing. Recovered perforating gun from tubing. Removed BOPE,:.installed production tree and tested tree to 5,000 psi. Perforated interval 10,579' - 10,590', and 10,561' - 10,577' with 4JHPF 0° phasing. Released rig on 2-24-84. Placed well on production 2-26-84. 18. I hereby certify and eorreet SIGNED ~ TITLE Area Engineer D&TB~ (This space for Federal or AJta~ o1~ use) COHDITION. O~APPR~L, IF ~:/ Joseph A. Dygas TX~'LE Chief, Branch of Solids and Fluids DATE 1 6 MAR 984 *See Insl, uctio.5 on Reverie Side Title 15 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. K(~,~iOi STATE OF ALASKA (j ALAS L AND GAS CONSERVATION MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchorage~ Alaska 4. Location of Well 99510 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 166.7' K.B. 6. Lease Designation and Serial No. A-028997 7. Permit No. 80-104 8. APl Number 5o- 133-1009-01 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11. Field and Pool Swanson River - Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: ' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) [] [] 13. Describe 'Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting'any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Moved in and rigged up Brinkerhoff Signal Rig ~58 2-8-84. 2. Killed well, removed tree. 3. Installed and tested Class III BOPE. 4. Recovered all of 3½" production string. 5. Cleaned out casing and liner to 10,799'. 6. Ran DIA-LOG minimum O.D. and casing caliper tools from 10,730' to liner top. Located split casing from 10,716' - 10,730'. 7. Ran and set retainer at 10,700' and tested to 3,000 psi. · 8. Ran 3½" x 2 3/8" production tubing. Removed BOPE and installed production tree and tested tree to 5,000 psi. 9. Perforated interval 10,598' - 10,602' 4JHPF 90© phasing. Stuck perforating gun in tubing on next run. 10. Removed tree, installed BOPE and pulled tubing. Recovered perforating gun from tubing. 11. Removed BOPE, installed production tree and tested tree to 5,000 psi. ~ 12. Perforated interval 10,579' - 10,590', and 10,561' - 10,577' with 4JHPF 0© phasing. 13. Released rig on 2-24-84. Placed well on production 2-26-84. RECEIVED MAR 1 21984 14., hereby ce7 that the f°reg°ing is true and c°rrect t° the best °f mY kn°wledge'~. ~ Abs~ 0il & ~,"*Gas"'"*"~n~Ccns'~,~ov C0mmi~b.~..~ ]~/~'Y Signed ¢ Title Area F.n~ineer Date The space below for Commission use ~1/[~ ~..~__ Conditions of Approval, if any: Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate. and "Subsequent Reports" in Duplicate DEPT.: :~ ' ' ' · '*TB~ FOLLO~,~I"INGIS A LISI'/'OF MA.TlgP,.IALF..NCLOSED HEKEIN. -. ** co. 4/'J"4 WE L L SC~//12~ - 3 ////~/~ TUB/~/~ ~ / ~. ..... LOCATIOI~ Pe/~ldlT ?0. I~RILI. . ' / MONTHLY NOTIC~ i ii ~ SIO~ WA ~ SARABAND ~IST~G ~ BOT. HOLE APP~fl DPN. or ASA ~o.c. eu,,.aY,,o ,m _ , Ct.U:~TER PROPOSE:D PROGR A M t.__ d~/d_~.~.coMpt.~TtO~ ~:Pont F - F£1m ~ FD - Folded X - Xerox R - Rolled B - Bluel£nei S - Sepia PLEASE CHECK AND ADVISE I~fl~EDIATELY. t 2 $ 4 S.6 ?.'' .WELl. ·LOGS .__ .INoucrton S FL ~ · 'U'L. INoucT,o. W,?HL'~'''' .... --' .... INOUCTION FOCUSED LOG ............. DVAL IN~C~tON ~&T~LOG ............. ~_ HL AC T~LO.. ' ....... : .... ': ~ ;~ ~. ~ ......... .ous __ __ .BOREHOL[ CO~[HS ! BORENOLE COM~. SONIC WtCAk~' ..... ~ -- -- - - -- ~ONTINUOU~ ~IPMgTrR NIGH RES ....... ~ m- ~OM PokvwOO P~or ~_, ' .' ' __ -- -- -- - -- CO[~AN LOG. . -- -- -- OL~A~ OG ~'~'~'~0~ ........... -- -- eec ee · e e ~ e e~ e~-- ~ .~ COM~(NSAT(O FO~MATION D~H~rr ..... _ ':C~PUTER PAOC[~S[D ~OO(.CYB~RDtPI.] ~ -- ~ · OM~gR Pnoc~s.eo Loe (CYOgRLOOK)~ -- -- -- 'DSTHDT . , ~ ....... Ft~O~ETE~ .... FOaMATION ANALYSIS ~oa ~GAMMA RAY -~ A."* R~, ~o. ..................... -- -- -- -- -- ........ ~AT gROLOG M,CR~ Loe ......................... ~,c.oLAtE,b~g~. ' .................. MuD Loe ~ ~ ~ ",,~,A, '¢L~G~'.':': i ............... ~ ..... NEUTRON ' ~ ~ ~ ~ Pl~lltl ~ALIPIR. ' ................. PROOUCTIQK .O. .~ -- --,= SARAlA.O ................... . -----~' ~-- ~ -- ISONIN LOI j- - __ i Tg~PENATURE ... -- -- ,TOT-M · . · -- -- )W~ ~o.s ....... , , ~ .... vo~ REMARKS ON OTHER SIDE, THIS SHE'~T · tr. ANCHORAGE, ALASKA 99510 Form 0-430 (Rev..~3) UNITED STATES ~ TM ~uc.~* (See other tn- DEPARTMENT Of THE INTERIOR ,,~.c,io.so. reverse side) GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG * ,, Ia., TYPE OF WET-L: OILWELT. ~ WELL°AS ~ DRY ~ Other ~E OF coMpL~ON: OVE~ EN WELL 2. ~AME OF OPERATO~ . CH[~RO~ ~.S.~. IRC. -" .... . 3. ADDRESS OF OPERATOR .......... P. O. Box 7-839, gnchora~e, ~laska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At,,~f, ce 2070' S & 305'E from the N.W. Corner, Sec. 3, T7N, At top prod. i~r~pj~ ~e~o~ n 100' N & 85i W'.~ Surface z~ to~ep~ 119' N & 95' W of Surface .... 14. PERMIT NO. DATS ISSUED ._ -- ]0/9/80 R9W, Form aoproved. Budfet Bureau No. 42-R3SS.S. LEASE DESIGNATION AND REP. IAL NO. A-028997 6. IF INDIAN, ALLOTTEE OR TRIBE NAME .. 7. UNIT AGREEMENT NAME Soldotna Creek $. FARM OR LEASE NAME . 9. WELL NO. :..._ · . SCU 12~'.A-3 " · 10. FIELD AND POOL, OR WILDCAT Swanson River- Hemlock 11. SEC., T., a., M., OR BLOCK AND SURVEY Se~. ~, T7N, R9W, S'.I4. 12.COUNTY OR 13.STATE PARISH Kenai AK 15. DaTE SPUDDED ] 16. DATE T.D. REACHED 17. DATE COMPL. (Ready to prod.) 15. ELEVATIONS iDF, RI~B, RT, OR, ETC.)* 19. ELEV. CASINGHEAD 11/18/82 K.01 11/25/82 12/1/82 K.B. 26' 10,850 MD 10,844 TVD 10,806MD 10,801TVD. How .',A.~Y* DRILLE..Y> ) '. 24. PEOD~C,NO ,NTE.,'*L(S), OF ~,~ COM~,O.--~O~, ~o~o~...~,~ I RVEY MADE ~ H-10 10,670' M.D. 10,666' TVD 10,751' M.D. 10,746' TVD ~6. TT~E ELECTRIC AND OTHE~ LOGS ~ ~ 27. W~ WE~L CO~ DIL - SP - SONIC, FDL - CNL - GR, CCL - CBL - CNL - CC ~ N0 '':' ~.--- . 22" I 28' mm13 3/8" . 54' 5# 3000' 7" 29# 1 0,'265' __ 18 5/8" 10 5/8" 1792 SX ---- 29. LINER RECORD SIZE I BOTTO,%! (MD) ] SACKS CEMENT' T0P ('~ID) 1"]0,848, I 1'0,03/ 88 31. PERFORATION RECORD (£nterval, size and number) 33.* Hemlock 10,730' - 10,716' - 4 HPF 10,725 10,711 TVD .33 30. TUBING RECORD SIZE 3 1/2 DEPTH SET (~D) 10,345 10,006' . . 32. ACID. SHOT. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH 'INTERVAL (MD) A.%IOUNT AND KIND OF MATERIAL USED J PRODUCTION DATE FIRST PRODUCTION 12/1/82 PRODUCTION METHOD (Flowing, gas lift, pumping--size and type o! pump) ~/~ WELL STATUS (Producing or shut-in~ roouclng . · DATE OF TEST HOURS TESTED 12/22/82 4 CHOKE SIZE IPROD'N. FOR {OIL~-BBL, [GAS--MCF. TEST PERIOD sp ------,. 6 18 WATER--BBL. J °AS-0IL RATIO 18 I 2900 'LO~'250 ~'"° PENS. l] CASXNO880 PRESS~'RE }~.~-HO~RO~LCULATED_ >RATE [ O,L--R.L.38 34. DISPOSITION OF CAS (,~old, used/or !t~el, vented, etc.) GAS--~ICF. l IlO I WATER--BBL. 51 35. LI8T OF ATTACH.tIENTS TEST WITNESSED BI 36' I hereby ~t~fore~dinformation ts complete and correet as determined from all available rec6~d~-,'r. SIGNED TITLE' Area Engineer DATE *(See Instructions and Spaces ~or Additional Data on Reverse Side) · i / r~ INSTRUCTI'ONS General: This form is designed for submitting a complete and correct ~ell completion report and log on all types of lands and lease~ to either a Federal agency or a Slmte agency, or both, puf.~liant to applicable Federal and/or State laws and regulations. Any necessary special Instructions concerning the use of this form and the number of copies to be Snbluitted; particularly with regard to local, area, or regional I)ro¢~dures and practices, either are shown below or will be issued by, or may be obtained from, the local Federal and/or State oilice. See instructions On items 22 and 24, and 33, below regarding separate reports for separate completions. If not.filed l~yior to the time this summary rem)rd is submitted, copies of all currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion ami pres.~ure 'tests,:and: directional surveys, should be attached hereto, to the exten~ required by aiq)llcable Federal and/or State laws and regulations. All attachments shonhl be listed on'this form, see item 35. item .4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. C6nsult local State or Petit;fsi oIli(:e for.specific instructions. II¢m 18: 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.. I~¢m$ 22 and,'24: If this well is completed for separate production from more than one interval zone (multiple completion), so state in Item 22, and la lte-i 24 show the producing h~terval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported In item 33. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. JJcm 29: "Siicizs Ccmc.nt!': Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 33: Submit a separate completion report on this form for each Interval to be separately produced. (See instruction for items 22 and 24 above.) 37. 8lJMMARY OF POROUS ZONES: I'$110~.V AI, h IMI'OItT~NT ZON};S OF l'Oil08l~J IND eONTJ~T8 TII~R~OF; CORJD INTJRVAL$; AND ALL DRILL-STeM T~STa, INCLUDING 38. ~EO~OOIC MARKERS , .~ ¥OItMAT]ON TOP. BOTTOM DgSCRIPTION, CONTgNT$, gTC. TOP . . .. : . . F ~ . ' NONE ~ : H-1..-"' 10,385 10','382' - "~ " H-2, · 10,409 10,407 ' " . ,-3 . .. 10,~2 10,439 , H'4 ,., 10,467 10,464... - - · .. .': "H-5 ':.. 10,486 10,483 ~ ..~ H-6 ]0,542 10,538 .- · ' ' H-8 .. 10,558 10,554 ' '. . . : : . .~ . . : . . .. - . .H-9 ... 10,636 10,632. ; . ~ . ' H-10- : ... 10,670 10,666'' .. . .. . .- . .. . , . .. . , ~ .' . . I . I : . . . . ,. . . . , . "' . U.S, GoVERNIdLq'IT I'tllNTING OFFI~: 10~l-.O--O83~30 . i -~ : J 871 * 2 3 3 . . /:ii7 ~ ' · : .... (~%'~ { '[' STATE OF ALASKA ( .... " ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS [-1 SUSPENDED I-1 ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator CHEVRON U.S.A. ][NC. 3. Address P. 0. Box 7-839, Anchorage, Alaska 99510 4. Location of well at surface ~07[J' S & 305' E from the N.W. Co'rner, Sec. 3, TTN, Rgw, Seward Meridian At Top Producing Interval I 00' N & 85' W of Surface AtTo,al Depth ll 9' N & 95' W of surface 7. Permit Number 80-104 8. APl Number 50- 133-1099-01 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12 A-3 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation.and Serial No. K.B. 26' I A-028997 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. i 11/18/82 K.O.I 11/25/82 12/1/82 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I __ 22. Type Electric or Other Logs Run DIL - SP - SONIC, FDL-CNL-GR, CCL-CBL-CNL-CC 23. CASING, LINER AND ~EMENTING RECORD SETTING DEPTH MD 15. Water Depth, iffeetOffshoreMSL I 16. No.1 of ComPletions 21. Thickness of Permafrost CASING SIZE 77" TOP Surface BOTTOM 28' WT. PER FT. GRADE 54.54 29# 18# HOLE SIZE CEMENTING RECORD AMOUNT PULLED 8 5/8" 1792 SX. 1 3 3/8" R-3 Surface 3000' 7" P-110 Surface 10,265' 11 10,037' N-,8o 10 848' 24. Perforations open to Production (MD+TVD of Top and Bottom and 5/8" -- 11 88 SX. 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) I interval, size and number) Hemlock '- 10,730' - 10,716' - 4 HPF .33 10,725' - lO,711' tvd 3 1/2" 10,345' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAl_ USED 27. PRODUCTION TEST Date First Production 12/1/82 Date of Test I Hours Tested 12/22/82 I 4 Flow Tu. bing Casing Pressure Press._ 250 I 880. 28. I Method of Operation (Flowing, gas lift, etc.) G/L , '., PRODUCTION FOR IOIL-BBL I GAS-MCF TEST~.ER,OD I~ 16 I 18 CALCULATED =k.[OIL'BBL J GAS-MCF 24-HOUR RATE '~j38 J l 10 CORE DATA WATER-BBL8 J CHOKEsp SIZE J 2900GAS'OILRATIO WATER-BBL JOILGRAVITY-API (corr) 51 Brief descriPtion of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. J ECEiYED JAN 2 6 1984 A'~'"~ 0ii & Gas Cons. Co ...... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,,. 29. 30. GEOLOGIC MARKERS FORMATION TESTS · , NAME Include interval tested, pressure data, all fluids recovered and graviw, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..... H-1 1 0,385 1 0,832 H-2 10,409 ~ 10,407 NONE H-3 10,442 10,439 H-4 10,467 10,464 H- 5 10,486 10,.483 H-6 10,542 10,538 H-8 10,558 10,554 H-9 10,636 10,632 H-10 10,670 10,666 ,, 31. LIST OF ATTACHMENTS · , , , .............. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 cement- lng and the location of the cementing tOOlo Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water'ln- .-.,Form 10-407 , · . COMPLETION REPORT - REDP?lI:j C~tEVRON U.S.A. INC. AREA: Soldotna Creek Unit LAND OFFICE: Anchorage, Alaska · PROPERTY: Swanson P~ver Field LEASE NO: A-028997 WELL NO: SCU 12A-3 ~z NO: 50-133-14)99-Bi-- LOCATION AT SURFACE: 2070' S & 305' E from the N.W. Cor., Sec. 3, TTN, R9W, S.M. LOCATION AT TOTAL DEPTH: ELEVATION: K.B. 26.5' 119' N & 95' W of surface DATE: 1/83 BY: AREA SUPERVISOR DRILLED BY: Brinkerhoff-Signal Inc. Rig #54 DATE COMMENCED REDP, TI,T, WORK: 11/9/82 DATE COMPLETED PuF~DR~ WORK: 12/1/82 RETURNED TO PRODUCTION: 12/1/82 RECEIYEO JAN 2 6 198 SUMMARY Alaska Oii & Gas Co.s. 'Comm~ion Anchorage TOTAL DEPTH: 10,850' EFFECTIVE DEPTH: 10,806' (cmt) PLUGS: Absmdonment (O.H.) 10,324'-10,268'(KOP) CAS IN G: 22" at 28' PERFORATIONS: 13 3/8" at 3000' 7" aC 10,265' (window milled 10,265'-10,307') 5" liner 10,045' -10,848' 4 HPF - 10,716'-10,730' 11/9-11/11/82 Move & rig up Brinkerhoff Signal Inc. Rig ~/54. Nipple up and test BOPE to 5000 psi. 11/12/82 Tagged bottom at 10,306' (old K.B. ). Rmversed crude oil out of hole. 11/13/82 9.3 ppg 1.tilled window in 7" casing 10,265'-10,269' (S.L. minas.) (10,250'-10,254' CBL maas.) NOTE - SCU 12-3 K.B. 18.5'-SCU 12A-3 K.B. 26.5' 11/14/82 ~iilled window in 7" casing 10,269'-10,283' 9.2 ppg 11/15/82 Milled window in 7" casing 10,283'-10,300'. 11/16/82 9.0 ppg Milled window in 7" casing 10,300'-10,307'. Tool started to torque. Circulated hole clean, Pulled out of hole with worn out section mill, Underresmed ·8 3/4" hole to 11" from 10,265'-10,307'. Run in hole with 3 1/2" plug catcher. NOTE - Ran CCL- Tied into CBL run 3/19/61 and found bottom 15 feet W.L. maas. to S.L. maas. Used rig m~asuremmnt. ~.~st subtract 15' to correct back to CBL maas. 11/17/82 Laid kick off plug across 7" casing window as follows: mixed and 'pumped 10 bbls of 10 f;/bbl caustic, 84 sx. Class G ~t with D31 and D6L (16.8 ppg, 1.014 C.F/sx) total slurry 15.2 bbls. Displaced with 5 bbls of 10..'f;PBL caustic flush followed with 62 bbls of drilling mud. Pumped 2 bbls over displacement without bumping plug. Bled back pressure.~ 12 bbls flowed back. Raversed out contaminated cement. · - ~;~ ~ ~squ~zed 16 c.f. of ceamnt and shut in with 2000 psi pressure. Pressure bled down to 1800 after 1/2 hr. Tested BOPE. Washed green c~mnt 9852'-10,150'. Waited on cenmnt. (btm at 10,324') 11/18/82 9.0 ppg Drilled out cement 10,150'-10,268'. 11/19/82 9.0 ppg Dyna drilled 10,268'-10,357'. 11/20/82 9.2 ppg Drilled 10,357'-10,398'. 11/21/82 9.2 ppg Drilled 10,398'-10,410' - hole sticky. Rmamsd open hole 10,265'-10,410 (very tight in spots). Circulate and conditioned hole - returns of coal and shale. Drilled 10,410'-10,430' (hole good) 11/22/82 Drilled 10,430'-10,515' with difficulty maintaining direction due to coal and shale. 11/23/82 9.3 ppg Drilled 10,515'-10,519'. 11/24/82 9.3 ppg Reammd tight hole 10,509'-10,519'. Drilled 6" hole to 10,540'. Wireline parted. Retrieved with overshot. Drilled to 10,628'. 11/25 / 82 9.3 ppg Drilled 6" hole to ~0,819' wireline parted. Unable to retrieve with overshot. Drilled to 10,850'. Conditioned mud for logs. Rmcovered fish. 11/26/82 9.4 ppg Ran DIL-SP-Sonic, FDC-~NL-GR logs from 10,850'-10,265'. Ran 20 joints of 5", 18#, N-80 butt and 8RD liner 10,848'-10,045'. 11/27/82 Ceraented 5" liner with 10 bbls water ahead, 88 sx Class "G" cement mixed with . 75% CFR2, 3% KCL. Displaced with 81 bbls mud to bump plug with 3000 psi. Reversed out trace of cenmnt. Tested liner to 3000 psi. Drilled out cemmnt 10,723' -10,806'. 11/28/82 Ran CCL-CBL-CNL-GR logs 10,806'-10,000'. Displaced hole fluid with lease crude. RECEIVED ,JAN 2 6 ]984 Alaska Oil & Gas Cons. Commission Anchorage 11/29/82 Ran 326 jts 3 1/2" 9.3 8RD N-80 and L-80 tubing with tail at 10,345', Backer Packer at 10,006' and ~-~nndrels at 9964, 6494, 6100, 5806, 5293, 4495, 3762, 2743, 1503. Test seal assembly. Spaced out tubing and reseated seal assembly. Rmtested to 600 psi. Set Backer Packer at 10,006. Imnd tubing and shear bull plug pins. Installed back pressure valve. 11/30/82 Nippled down BOPE. Nippled up 3 1/2" X-mas tree and tested to 5000 psi. 12/1/82 Perforated with 2 1/8" hollow carrier gun at 0" phasing 4 H.P.F. 10,730'-10,716' Rigged down. Placed rig on standby. _ I ii i ii i iiiiiii ii i · · ............. ~1 ~ i i 22" 10045' ~' PUP JT. SJ~ 9.5~ SRO L-OOTgG. 3.69' ~ 47 JTS. 3~ 9.5' 8.eO L-60 T~;. 1480.97' -~2743.ZB'~CAMCO 3r~ KGUG MANOR~L W/I CEV. ' , ~" ~ JTS.~ PUP 3~z .9.3~ N-80 TOG. ~012.56' ~ 3762.28 ~ CAMCO ~z KGUG MANOREL W/l" CEV. 6 .~' . ',~ 23 JTS.+PUP 3~ 9.~' N-80 ~8G. 727.0~' ~ 4~9s.~ ~CA~CO 5~z KBUG MANOREL W/I' CEV. 6.46', ~ 25 dTS.~PUP ~ 9.~* N-80 TBG. 791.43 ~sz93.6~' ~CAMCO 3~ KBUG MANOREL W/I"CEV.. . 6.43' , ~ 16 dTS.+PUP 3Pz 9.3~ N-80,TBG. 506.41 ~seo&.46 ~CAMCO 3Vz KBUG MANOREL W/I CEV. 6.~4~ ,~ 9 JTS.+PUP 3v~ 9.~· N-80 TBG. [87.7~ ~S~qO..GI~CAMCO 3~z KBUG MANOREL W/I'CEV. · 6.43. ,~ 12,,.dTS.~ PUP 5~a 9.3* N-80 TBG. 380.4Z~ -- 6467. 53 ~CAMCO 3Vz K BUG MANOREL W/I'CEV. .~ .... , t ~ I10 JTS. 4PUP 3~ ~3' N-OO~BG. 3470.Z~ ---'''"ca ~CAMCO 3'/z KBUG MANOREL W/I CEV ,o ...... ~ ,, I JT.+PuP ~z 9.5~' N-'80 TOG. - ~.~~7 29 ~z BAKER FHL PACKER 5.60 ~--' ~OTIS $ NIPPLE ~/2.075 iO POS. 2 _~oo~s.oo,~[ . I JT. 3~z 9.~~ N-80 TgG. 31.5i TUBING AS OF tl-29-8~ S.C.U. 12A-3 CASIN'G 8~ TUBING DETA'~L- SECTION 3 T. TN.RgW. CHEVRON USA INC. A(Oi STATE OF ALASKA ~ ALASK L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator 7. Permit No. CHEVRON U.S.A. INC. 80-104 3. Address 8. APl Number ?.0. BO× 107839, Anchorage, Alaska 99510 50- 133-1009-0z'i 4. Location of Well 2070' S. & 305' E. from the N.W. Cor., Sec. 3, T7N., R9W., S.M. 5. Elevation in feet (indicate KB, DF, etc.) 166.7' K.B. I 6. Lease Designation and Serial No. 12. A-0289~7 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11. Field and Pool Swanson River - Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations E~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The procedure proposed on the sundry notice dated April 12, 1983 has been cancelled. RE£E ¥ED J A N 0 Alaska, 0il & Gas C0r~s:~,~m~s~t0r~ '~'~ "~ ' A~]ch0rage 14. I hereby ~fy~.t the ~'~s_tr,~ue ~/~d ~orrect to the best of my knowledge. Signed f \. o ~,,~/'/~,~'~'~/~t.,,~ Title Area F, ngineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA {r / ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~c OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-104 3. Address 8. APl Number ?. O. SOX 107839, Anchorage, Alaska 99510 50- 133-1009-01 4. Location of Well 2070' S & 305' E from the N.W. Cor., Sec. 3 5. Elevation in feet (indicate KB, DF, etc.) 166.7' K.B. 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11. Field and Pool Swanson River, Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). -- See attached program. This work will commence on or about December 1, 1983. Approved Cop~ Returned- Signed~-~~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions'; in Triplicate and "Subsequent Reports" in Ouplic~. 9-~31 1973 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or I~lug back to a different reservoir. Use Form 9-331-C for such proposals,) 1. oil gas well ~:: well [] other 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. O. Box 107839, Anchora§e~ Alaska 99510 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE: 2070' S & 305' E from the AT TOP PROD. INTERVAL: CDr. , Sec. 3, TTN, R9W, 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF*. TEST WATER SHUT-OFF [-] [] FRACTURE TREAT ["] ['-] SHOOT OR ACIDIZE ~ [] REPAIR WELL [] [] PULL OR ALTER CASING ['-] [] MULTIPLE COMPLETE ~ [] CHANGE ZONES [--] [] ABANDON* [] [] (other) Form Approved. Budget Bureau No. 42.R1424 5. LEASE '* .. .' .'. ._ A-028997 : " 6. IF INDIAN, ALLOTTEE OR TRIBE NAME -. 7. UNIT AGREEMENT NAME $oldotna. Creek 8. FARM OR LEASE NAME . __ .. 9. WELL NO. ." : '~ SCU 12A-3 . '~' ' ' 10. FIELD OR WILDCAT NAME . Swanson River ' 11. SEC., T., R., M.,.OR BLK. AND SURVEY OR AREA '* *' ~- ~ - - .~ ' ;:i' :' 12. COUNTY OR PARISHI 13. STATE Kenai ' '* "{ Alaska 14. APl NO. '_~ ; = .. .: 50-133-1009-9i .-- -- 15. ELEVATIONS (SHOW DF,';KDB; AND WD) 166.7' KB-h:.- _ (NOTE: Report results of multipl~: zone change on Form 9-330,) - '- '"; :'- !!5;.- ... ,- (~ 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, ~nd give perti,ent dates-7 including estimated date of starting any proposed work. If well is directionally drilled, gi~e subsurface 16¢ations and measuredandtrueve~icaldept~sforallmarkersandzonespertinenttothiswork.)* See attached program. This work will begin on or about December 1, 1983. Note: This notice supersedes notice dated 4-12-83. DATE DATE ,Subsequ~.t Work Reported Subsurface Safety Valve: Menu. and Type 18. I herebTi~t~g,i~tru~ and correct SmN[D _~x' ~'i- ~ TITLE Area Engineer APPROVED BY .~----'- ~_~/~'/~'""~ (This space for Fed;/ra, or S.,ate office use,TiTLE/~////~ ~' CONDITIO~//~AP[ROVAL.-/ IF ANY: · See Inetru~tion~ on Reverse Side ...~ --. ~. ., ~:.,...-- .g SCU 12A-3 Section 3, T/N, R9W, S.B&M Swanson River, Alaska SCU 12A-3 WORKOVER PROGRAM . Prior to moving in workover rig fill annulus with produced water and then perforate tubing at 9200' with 4-i" JHPF. Use Gearhart circulating charges. 2. Move in and rig up workover rig. 3. Kill well using 72-73 pcf mud as detailed in attached workover fluid program. 4. Install Cossasco plug and remove tree. . o Install Class III BOPE and test to 5000 psi. Remove Cossasco plug. Recover 3½" tubing and production equipment as per attached tubing detail. Visually inspect all tubing and equipment for damage and note any erosion or irregularities, especially in the packer and seal bore assembly. Pull tubing slowly to minimize swabbing and note that tubing-_and liner may be all or partially filled with rocks and gravel below 9261'. Clean and test mandrels. Replace gas lift valves with dummy valves. 7. Clean out casing and liner to top of plug at 10806'. 8. Run tandem scrapers (5" 18#) to 10806'. . Rig up and run Dia-log multifinger casing caliper from 9800' to 10806'. Anchorage engineering to witness. Note: If log results show damage other than in existing perforated interval, a supplemental program will be submitted. 10. Run wireline set cement retainer and set with top of retainer at DIL depth of 10710'. Depth is critical. Tie into collars at 10558', 10601', 10643', 10686', · and 10730'. Note: DIL is on depth with CBL. 11. Run in hole with open ended drill pipe to +10' above retainer. 12. 13. Displace drill pipe with fresh water and stab into retainer. o. Obtain pump in rate using fresh water. Note: If unable to establish rate proceed to step 16. 14. Cement squeeze existing perforations using Class G cement as required. 15. Clean out 5" liner to top of cement retainer at 10710'. 16. 17. 18. 19. 20. 21. 22. 23. 24. · SCU 12A-3 Section 3, ~/N, R9W, S.B&M Swanson River, Alaska Circulate well clean to 10710'. Ch'angeover well fluid to lease crude. Run 3~" tubing per attached tubing detail dated 11-2-83 (Figure 2). Hydrotest all tubing and equipment to 5000 psig. Stab into polished bore recepticle and pressure liner lap to 600 psi. Drop ball and pressure up tubing to set Hydraulic packer. Nipple down BOPE, and nipple up tree. Test tree to 5000 psi. Hook up flowline. With rig over hole, rig up Schlumberger and perforate DIL depths 10682'- 10700' with'4 JHPF 0o phasing using Schlumberger's 2 1/8" Enerjet guns. Locate collars at 10.686', 10643', 10601', 1055.8', 10530', and 10487'. Place well on production as directed by area foreman. Obtain several gauges within first 48 hours of production. Pending results of flow test rig down and move out workover rig. Anchorage engineering will submit supplemental program if required. ., Move in rig up Schlumberger perforators and perforate DIL depths 10598'- 10602', 10579'-10590', and 10561' - 10577' (total 31') with 4 JHPF using 0° phasing and Schlumberger's 2 1/8" Enerjet guns. Locate collars at 10686', 10643', 10601', 10558', 10530', 10487', 10457', and 10431'. Place well on production as directed by area foreman. frequently. · Gauge well J. B. LOGAN 11/8/83 WORKOVER s S.C.U. 12A'3 j Well: SCU 12A-3 SCU 12A-3 Section 3, T/N, R9W S.B&M Swanson River PRO 316-1 PROPOSAL FOR WELL OPERATIONS SCU 12A-3 Field: Swanson River Location: At surface: 2070' south and 305' east from the northwest corner of section 3, T7N, R9W, S. B&M At T.D.: 50.98' north & 4.97' east of surface location. Elevation: 140.5' G.L. All measurements based on redrill KB of 26.2'. Present Status: T.D.: 10850' Plugs: 10806'- 10850' Casing: 22" cemented at 28' 13 3/8" cemented at 3000' 7" 29, 26, 23# N-80, P-110 milled window at 10,265'- 10,307' 5", 18#, N-80 cemented at 10898' with top Et 10,045' Perforations: 10716 - 10730 Perforated 4-~" JHPF 0° phasing 12-1-82 Reperforated 4-½" JHPF 180° phasing 2-16-83 Tubing: See attached detail (Figure 2). Note: Fill was last found at 9261' (Figure 3). Unable to go below this depth with coiled tubing due to large gravel and rocks. Junk: None Blowout Considerations: 1) Gas: Well has produced up to 2500 MCFD. times not to swab well. Care must be exercised at 2) 3) Lost Circulation: None anticipated ~ but lost circulation material should be kept on location at all times. · Precautions: Any kicks should be handled by normal procedures. Rig crews should be made aware of these methods and care must be exercised at all times. The hole must be kept full at all times. 4) Maximum anticipated formation pressure: 4940 psi Programmed mud weight of 70-73 pcf will provide 273 - 497 psi over balance at the top of the perforations. 5) Maximum anticipated surface pressure: 3980 psi. 6) Blowout Prevention Equipment: Class III- 5000 psi. SCU 12A-3 Section 3, TTN, R9W, S.B&M Swanson River, ~lR~ka SCU 12A-3 WORKOVER PROGRAM . . . . . . 10. Prior to moving in workover rig fill annulus with produced water and then perforate tubing at 9200' with 4-i" JHPF. Use Gearhart circulating charges. Move in and rig up workover rig. Kill well using 72-73 pcf mud as detailed in attached workover fluid program. Install Cossasco plug and remove tree. Install Class III BOPE and test to 5000 psi. Remove Cossaseo plug. Recover 3-}" tubing and production equipment as per attached tubing detail. Visually inspect all tubing and equipment for damage and note any erosion or irregularities, especially in the packer and seal bore assembly. Pull tubing slowly to minimize swabbing and note that tubing _and liner may be all or partially filled with rocks and graVel below 9261'. (?lean and test mandrels. Replace gas lift valves with dummy valves. Clean out casing and liner to top of plug at 10806'. Run tandem scrapers (5" 18#) to 10806'. Rig up and run Dia-log multifinger casing caliper from 9800' to 10806'. Anchorage engineering to witness. Note: If log results show damage other than in existing perforated interval, a supplemental program will be submitted. Run wireline.set cement retainer and set with top of retainer at DIL depth 10710'. Depth is critical. Tie into collars at 10558', 10601', 10643', ~0686', and 10730'. Note: DIL is on depth with CBL. 11. Run in hole with open ended drill pipe to +10' above retainer. 12. D~splace dr~ll p~pe with fresh water and stab into retainer. 13. Obtmn pump ~n rate Using fresh water. Note: If unable to establish proceed to step 16. . 14. Cement squeeze existing perforations using Class G cement as required. 15. Clean out 5" liner to top of cement retainer at 10710'. 16. 17. SCU 12A-3 Section 3, T~N, R9W, S.I~cM Swanson River, Alaska Circulate well clean to 10710'. Ch'angeover well fluid to lease crude. Run 3~" tubing per attached tubing detail dated 11-2-83 (Figure 2). Hydrotest all tubing and equipment to 5000 psig. Stab into polished bore recepticle and pressure liner lap to 600 psi. 18. Drop ball and pressure up tubing to set Hydraulic packer. 19. 20. 21. 22. 23. 24. Nipple down BOPE, and nipple up tree. Test tree to 5000 psi. Hook up flowline. With rig over hole, rig up Schlumberger and perforate DIL depths 10682' - 10700' with 4 JHPF 0o phasing using Schlumberger's 2 1/8" Enerjet guns. Locate collars at 10686', 10643', 10601', 10558', 10530', and 10487'. Place well on production as directed by area foreman. Obtain several gauges within first 48 hours of production. Pending results of flow test rig down and move out workover rig. Anchorage engineering will submit supplemental program if requ{red. Move in rig up Schlumberger perforators and perforate DIL depths 10598'- 10602', 10579'-10590', and 10561'- 10577' (total 31') with 4 JHPF using 0° phasing and Schlumberger's 2 1/8" Enerjet guns. Locate collars at 10686', 10643', 10601', 10558', 10530', 10487', 10457', and 10431'. Place well on production as directed by area foreman. Gauge well frequently. J. B. LOGAN 11/8/83 -2- SCU 12A-3 Section 3, T~N, R9W S~B&M Swanson River WORKOVER FLUID PROGRAM SCU 12A-3 B .asic...System Medium treated Lignosulfonate mud. Fluid Properties Weight - pef Viscosity - sec/qt API Fluid loss - cc API Plastic Viscosity - CPS Yield Point -lbs/100 ft pH Solids - Vol % 70-73 30-35 less than 10 10-14 6-8 9.0 - 9.5 6-10 Remarks . 72-73 pcf mud will be required to kill well at 9260'. 70-72 pcf mud may be used when well cleaned out closer to perforations. Maintain adequate supply of lost circulation material. 22" CEM. 28' 10045' · I DERRICK FLOOR ' ,19.2 ~ _ PUP JT. 3J~ 9.5~ 8RD L- 80 TBG. $.6 ,,. - ' . ~ -- EL W/I CEV. . --- 2743 28' ---[-- 39 JTS. +PUP 3~'2" 9.3~ N-80. TBG. 1233.C - ' 1""-,CAMCO SYz KBUG MANOREL W/I CEV. . 6.4 .... 3762 28' '-~' 32 JTS.-i- PUP 3~z .9.3~' N-80 TBG. I0 12.5 - '..'.. f, CAMCO 3~'z KBUG MANDREL W/I"CEV. 6.' -- ~.49~5 7~'~--~'- 2.~ JTS.+ PUP 3~'z 9.3' N-SO ,,TAG. 727.(: ' ~)---CAMCO 3~/z KBUG MANDREL W/I'CEV. 6.4 . I-'- 25 JTS.+PUP 3~ 9,3e N-80,,TBG. 79 1.4 --5293.62 "'~CAMCO 3~z KBUG MANDREL W/I CEV. : 6.4 _ , ~ 16 JTS.+PUP $~z 9'3~ N-80 TBG ' 506_z --3806.46 '-"~CAMCO 3kz KBUG MANDREL W/I'CE~.' 6:3 --6100,68'----~ -.. ?_J_TS.+PUP 3vz 9..¥' .N'80 TBG. 2,87.7 6487 5.'.'.'3' f'''''- 12:~;JTS.-I. PUP 3/z 9.5 N'BO TBG. 380.Z -- ' ""~CAMCO 3)1/z KBUG MANDREL W/I"CEV. 6.~1 ---:~6~ ~'-J. ~... !m_o_j~,?.. ~ Pup ~ ~. N-SO T~G. 3~7o.; ' ' ~.~Ara~u ,~/z KBUG MANDREL W/I CEV 6:4 --mOOD ' ,, I JT.-I. PUP 3~'z 9 3~' N-'80 TRG ~ '7 5.39 --[. 7 29 3~ ..... ' .... '"""' -- ~-- z MAKER FHL PACKER 5.6, ~OTIS S NIPPLE W/2.875 ID POS. ~_ I., _1oo45.oo,.._.I - I JT. 5Yz 9.3~' N-80 TBG. ,'31.( I"1Gur4~ Z S.C.U. I?_.A-3 ' .,. CASIN~3' 8~'TUBING DETA'~L SECTION :5 T. 7N.R9W..~, II-Z -83 I I I 22,094,500---~ I II -t- WORKOVER S. C.U. 12A-3 SECTION 3, T. 7 N.,R. 9/W. SM · r i I I IIIIII ~-- I I -' Il I ! .5'H,4FF~'~ ,L 'i /0"- d-O 0 0;~ · ~" ' 5000 i ItI WELL HEAD HOOK UP S. C.U. 12A-3 · STATE OF ALASKA ' ALASKA ,.AND GAS CONSERVATION C ISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER DRILLING WELL [] COMPLETED WELL 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839~ Anchorage, Alaska 4. Location of Well 99510 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 166.7' K.B. 12. I 6 . Lease Designation and Serial No. A-028997 7. Permit No. 80-104 $. APl Number 50-133-1009-91 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11. Field and Pool Swanson River Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). l) 2) 3) 4) Rigged up coiled tubing unit (9/9/83). Cleaned out tubing to 9249'. Unable to circulate deeper. Rigged down. Rigged up Dyna Drill with 1 3/4" mill on coiled tubing unit (10/7/83). Tagged fill at 9249'. Unable to mill deeper. Rigged down. Discontinued attempts to clean out well with coiled tubing unit. Signed . ~, Title Area Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~80 Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate ALASK~('-~(i"'L STATE OF ALASKA AND GAS CONSERVATION ~,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L ;1~,,. OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-104 3. Address P. O. Box 107839, Anchorage, Alaska 4. Location of Well 99510 2070' S & 305' E from the N.W. Corner Sec. 3 T7N, R9W, 5. Elevation in feet (indicate KB, DF, etc.) 166.7' KB 12. Perforate Stimulate Repair Well Pull Tubing I 6, Lease Designation and Serial No. A-028997 8. APl Number 50-133-1009-91 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11. Field and Pool Swanson River, Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] ~ Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] Repairs Made [] Other [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed worE, for Abandonment see 20 AAC 25.105-170). 1. Rig up coiled tubing unit. 2. Clean out tubing and casing to 10806'. 3. Return well to production. This work will be done the week of September 5, 1983. RECEIVE. I) AUG 2 Alaska 0it & Gas Cons, Commission Anchorage Signed Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Si, Iii[Il LOHHIE I;. SI~]TR Approved by. COMMISSIONER Approved Cop~ R®turned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL Iit OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-104 3. Address P. O. Box 107839, Anchorage, Alaska 99510 4. Location of Well 2070' S & 305' E from the N.W. Cor. Sec 3 T7N R9W S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 166.7' KB I 6. Lease Designation and Serial No. A-028997 12. 8. APl Number 50- 133-1009-9t01 9. Unit or Lease Name Soldotna Creek 10. Well Number SCU 12A-3 11. Field and Pool Swanson River Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate k--I Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give. pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Shut in well. 2. Perforate H10 interval 10682 - 10700 with 4 JHPF and 0© phasing using "2 5/8" carrier guns. '3. Return well to production from all zones. This work will be done during the week of April 18, 1983. SuI~e~tnent Worl~ Iteporte~l oa l~orm No. ~ated 14. I hereby certify that the foregoing is true and correct to the best of my kno .wledge. The space below for Commission use Date Conditions of Approval, if any: IIIIlGINAL StGltElJ BY [OH.q!E C. SMITH Approved by COMMISSIONER Approved Copy _eturned ..... By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate U.S.A. Inc. ./IS~ Est. Depth _t~SO Est. Orig. Days Classification: Proposal for Well Operadons PRO-31 Date Field Area Est. Compl. Rig Days Accession No.: · Total Days O APl No. Information Release: Routine r~ Confidential[--] Classified'r-'] Budget Category Type of Approvals Required: Div.~"l S.F.I-'] D.O.G.F-] U.S.G.S.F-~ State Lands[_] Charge Code Title Clearance We Recommend: Contract Drilling ......... .. Company Drilling Expense ...... Fuel & Utilities .......... Rigup & Tear Out (Including Moving Cost) Drilling Fluids -Well Supplies (Non-Salvable) Transportation Expense ....... Contract Services - Rentals & Miscellaneous Formation Evaluation ....... Sub Surface Tangible Equipment .... Contract Cementing Services ...... Site Preparation . . Artificial Lift Equipment (Surface) .... · · / Sul~pl;m;nt ( ~ Traps Lines and Other Surface Equip. ,,, ,ral & Administrative Expense at Operator's Compensation at~ % . $ Total Estimated Expense ...... $ Other Participants' Share .... Chevron Estimated Amount Jt. Op. Basis XXXXXXX XXXXXXX C-946-2 Line 1&2 $ 3,4&5 $ 6 $ 8 $ 9&10 $ 11 $ 12, 13, 14 & 15 $ 20, 21,22 & 23 $ 30 & 31 $ 32 $ 51 &52 $ 53 $ 54 Original $ 62 Jr. Op. Basis $ $ $ $ $ XXXXXXX $ XXXXXXX $ Reasons for Expenditure: ,.-~J~:cT uuc~.c ~ ~ /,~.~'¢~ ~ ~c~,.2~./, .--- XXXXXXX Z7~-7 7,27% XXXXXXX XXXXXXX Participation & Authorization Original Authorization $ Previous Supplements $ This Supplement - No. $ Totals $ Economic Data: First Yr. Oil Price $ 1~.72 /Bbl. First Yr. Gas Price $ - /MCF P.O. .~%~ Yrs. R.O.R.. ~ ~' % D.P.I. @ 15% ?'). ;'~s Life ~ Yrs. Net Disct'd Profit $ ~ Reserves (Bbl. orMCF) ~07 ?~; ~ ..ommended by: -~'~-- date .... ~ ~ date ,4/-#- date date M.qr. Dev. Geol. Total Partner's 51,5t~1~ % Share Company Share $ 7z 7 $ $ $ $ $ $ $ Budget Cod( I Production Data' Initial BID or MCF/D Req'd for: BOPD 2oo 4.0 Yr. P.O. /-/! ~oP~ MCF/D - 30%R.O.R. WZ 3~?~ °APl - 1.5 D.P.I.015% ~3 ~>;3 Decline Rates .ZS DPC Endorsement Ch. Dev. Geol. date Ass't. Ch. Enqr. date Ch. En.qr. date Ass't. Gen. Mgr. date Partner's Approval- Approved · ' - /date: x/_ .1/. ~3 PR0-316 (CD-2-8: date' WELL' FIELD ' JOB NO' t CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELI,,W(~ PROCEDURE SUMMARY TYPE WELL' TYPE dOB' ORIGINAL SUMMARY I~1 SUPPLEMENTAL SUMMARY I~ NO. OBdECTIVE' ~-D~_!-~c~-{~ C,:.j~(,.-~.;L.,rji ~ei~i'o~,L~. lO %u,,~,_~' ~-a ~ ¢. :'~ c, ;. (: WELl DATA' CASING' PBTD IOEo/o' LINER ' S" ' PROGRAM DETAILS ATTACHED Distribution: Original to Well Flle w.o. Sauer (3) Field Office(I) Preparer (I) D.M. Wilson(I) Prepared by ~ Date CALCULATION SHEET OO-144-2 35 33 32 31 30 29 28 27 26 25 24 23 22 21 '20 19 18 16 15 1 1 1 1 1 C34 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 {8 19 20 ~21 22 23 24 25 26 27 .28 2? ~ 3 INITIALS --'"J ~;~ /'-'' PROJECT No. '-... DATE IZ- Z~- ~.Z SUBJECT ~--0 SHEET , ,{ OF J - · I ENGR. REQUESTING: -~.~. P~"' ~RITY: ~ICIPATED ~S~TS: ~R GOR ~R: DETAIL B~OW wm.n Sou /z4-3 DATED REQUESTED: /2° 29 o ~Z 2 WEEKS 1 MONTH LOWER WOR HIGHER RATE STATUS OF WELL: DATE RECENT GAUGE (%-t2 - ~. S . I . G. INJ . WTRINJ OIL WTR GOR GI %%' I~ !~o1~o I WI GLR ~2 ~0 CC-/~,Sc- GL ONLY' SANDS OPEN PERTINENT DEPTHS: Attach Mech. Cond Schematic cJC ,3 ~ (2) Sleeves (3) Ldg. Nips. (4) Other ~% 4~( PROG~: ~. C~a~,~,q pr~:~,,c .... ~.a~ ~ ~ g hoofs ~c~ APPROVAL: AREA ENGINEER CHARGE TO: .L,0 ~ 0 ~. 7_~.~ RESULTS: (By Foreman) FOREMAN: Please acknowledge work request upon completion: If unable to complete work, please furnish detail. 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I; l llll,'. l ~I~,' ~ Illll · t , , 11 ,i , IzAc/~ t50 ~,c~ - SZ~ .~1 3 Z7 Zql ~o 3~ - .?-'.-~' "7-: ' 3 ........... ,, , - ~.._. ~1~ ,, , ~ 73 :' ~cs z7 % ~1 3oo, - .~:;~'. ',,,'..,., o~ .. -. . , .... j, , ~ - . ,, ,, - z/e ' ,, - ~% .SZ ~7 33 lEI.... G7o0 - .' ' , 'i 311 ,.'.. . - · .,, ~,.. el~1 ,, - .. ISq '~g 5q 100 .. 570 .& ~so z~o Ifl33 ... ' r ~ ~ ' '" zlzI ,, S 9o .51 57 ~ iq~ ~7zo - ':' 1:9~7 ....... , ,, ,. ....... , 3/to ,.. z zz/ .~7 75 ~S~ 573 .e~70 - :~'c -~:~.Z qqo ............. ~ : ' , . . ,.,- ~ · :.: ........... ............ ...... . 2 ' . ...... ,, ..... ~. ~ . : .: , ...... : ...... .......... ~ - ,, .... , _ .......... · ...... ,, "::~'~..~e" - - ,.,. - ..., .. ....... .- . . ; . ' _-' : ~ . [' "- '.-' - :..4.-.:- "'./" ~ ..... 7.:.,'..... ~_, - :-._~. . .... ' " : .... ' ,,:.-.:'-. .... _,.-?v'<"~.: :': ". ~_ " ,': ,:~ : _l ~~,c..-'~'~'L- t ..Il .. .... .- . . , .'.t~'';~t-:'-~ .... ; ....~,. ,.,..... '. .. ,., ~...,. .... . ~...:'~ .... · POROSITY BULK VOLUME ANALYSIS FORMATION CHARACTERISTICS HYDROCARBON ANALYSIS % OF % OF BULK VOLUME BULK VOLUME ~ .--.--....m,,m m~m ~ ' ~-Z-Z- ~.--.---~ T-., .--..-=..--.' i. :, :. :. :., ~ clean Matrix Permeability ~_._-_-Z_-Z.'--_.-_-_-].'.'-._-'.-._-?._-.-'.'::::::::::: . Fractional ' ,~'Z'----'"'"-'"---~, ..:..:..: .-_-_-_, ~?...]-._~. :. :. :. :. ;. Canstituents ~-,, ~! Water Kw "-. t~ -_--_-_ :_-_-_.-~ ~-':'.-'-='-_.'. ;. :-:. :-:, "-.... ~ Saturation ~ O m ~ -n ' j 100 % 0 HYDROCARBON -" CZ -' "" ' o ,.o t I g ~ - ~ V1 Hydrocarbon ~ ~ ~ > ! - m Intrinsic Volume · · > m 1.0 0 ~e' Shr o V3 104103 102101 1 ,1 i i ~ ! ~ ~ 0 % 25 ~e 0 ~ = Sand < ~< < Hydrocarbon D - ~- i!' ": ' ~] - Lime Effective To Weight Hydrocarbon ,, ~J'~ '~- Dolomite ~De · Shr · Ph 04 .1 0 % 25 2O ~ = Effective ' _20 ....... To Water CALIPER- (BIT SIZE) I Shale & Matrix , o o % ...... ;. r) s APPARENT GRAIN DENSITY3 :2.6 · ./4 GAMMA RAY 0 ~ 60 ~oo · . . ~,,, ~- ~ -- ..... ' ~ ~'_I , i : " ' ' ~ " '! ' ~ ' ' -:----- ....... , 2'. ~ ' ~ : ' "----- "' -- '"~'"~"'"~"" , " . .,, , ~ .... --- - .,~.'.--. ~.'.':'..'.'4~.~.'..[.':~.!.~ ' ' ', ~ ' '.'-1.'.'.'i.'.'.'~'.i.' i.'.i~:.i.i.,:.:.:-.. "' ....... I , , , ,~ _--._--_ _ ~_~ ~,.~_.z.~............ ~ ~ , , / ' ~ ~ _--.........,..:.::.:.:,:.:.......,.! ' ~ I , . .'.'.'.'!.' · '~ ..... .'~'.'..'.~.';'. ~ ~ ~,: . / '~ '~'""~'"'""""'~""' ""'~"'"~'"'~ ~ ' "~'i ' : -'-~- -- - -'.: =-~-.~-'~-'-'-~'-'-'.? i . , ~ ~~ ~'.~.'.-..'.-.'.~ -- -. ----~.~ii:i:i ..~.... .... /~~ ~ ----~ ...................:..:.i~:-:.:~:.:.:.[.:.:.!:.:. - - .~ - . · -:-]-i.:.:.]-:-~-:-]']-i':']':: I ,-. .... , -, · ~, , ~-:.:!:-:.:!:.:.:-~:.:.]-:-:-:., .,.., ......... .:-:.].:-:.:!,:-:-:,~....,, -... : _ ! :.'.:::.:.: <.:.:.;:.i.:.:.:.:. ,.....~......:,.,...L~ i i i i ::::::::::::::::::::::::: . oj '-.~ il,. . . , ..:......:...............,............ ..... ~. , . ~ ; ~-~ . .... . ..... ~.:~,:~ ..... ; ~ _- -.:.'.'.'.'.'.'r'.'.' -...- -.-.-..-.-. ~: ~ .~ !,~: -~..~......:......,..........~......~..,.~ · : I I - ' ''4 ...... ; ....... I~". ', i ¢ ~ : ' ....... ' ............. "':"' i : : '. -.-...'.'.'L'.'.','.'.' '.'.']'.'.'.r,'.. ia J . ! i , ~ ; ~ i _~ .11~'-~ .... i. · . ~ .... 4. · 'L%-"~ ug _ ~ ¢ : . : i , "'~'"'"~""'"'"", '.'.'-'.'.', , ~' , ,.:. , , ~_ ,___~_~ _i~,::.~.:.:.:;.:.:.:~;.: :::.;.:!:.:.:.Ic.:jJJJ. 10600 , ..... · ; -i- · . 1 10700 ; NRTER SRTUR'RT-ION'vs. EFFECTIVE PROSITY CROSS PLOT o 10698,10655. TNTERVRL 5ET**7 'T- I...bl Z i_._o lB 20 30: t~O 50 , · , · 'm 8O o 9O r;O. O0 0 25 0.50 0'.75 t.O0 t 25 t.50 EFFECTIVE POROSITY (PHIE) 10 TO THE N'TH 1.75 2 O0 PU CHEVRON USA INC., SOLDOTNR CREEK UNIT 12R-3, LOGGED 25 NOV 82. ¢¢- 5~ ~TEB S~TUB~T I ON VS. FFFECT [ YE PBOS ITT CBOSS PLOT o ]0788 ~0705 INTEBVFtL o CD Z o 1D 20 ~01 ~0 50 , , 10'711,- 1073 0 // 80 90 O0 0 25 0.50 0.75 1.00 1 25 1 50 i 75 2.00 EFFECTIVE POROSITT [PHIE] 10 TO THE N'TH ?U CHEVRON USA INC., SOLDOTNR CREEK UNIT 12R-3,LOGGED 25 NOV 82. :: ~::~-:'~ : :_::' :J.::':::: ::':..:..~ . · . · t · ~ · ~ - ........ ~ ...... ~ ........ ~ . · i · · 1 ::::~::':i::'::' £ :':"': ' : ':::: ":':: ::::::::::::::::::::::::::::::::::::::::::: :::~-.- ..... ' ....: ....I ....... i ....... I ........ t ......... : ...... :::-::::"i::!:'::: :::'::::: :: ::!i:!'::' ':::~' .... , .. · ~ . . .. ...... ::j::.::::::: ......... _ . __ ' .......... :'":'"l ..... -_L: " ' ....... ,I "': ': :t'~" ............. ::.~:_.:..:.: : :: ' ~ I ...... J~ ' : ' ;'.':'::': ................. /~ .... :':,r- ' ..... i'" ::'::".': ::::::'::i': :::::'. .' ...... · . , · : ........... :: .... !::':':::"::::~' "~"::: :~::~":':'::~' :':':::~:-I:::::-:':::':: '::-:'::'::*::::::" '? ::': '~':: :~ ' ..... :' :::'::::: '::::::-:~ ::::::::::::::::::::: :~: ':::::: "::~;~:::!ii;:,~,::: :: ::5 ::: :::' :. ...... ~ .... ~ ...... - t::..::::::--i:::: :::::::::::::::::::::::::::: -, · 't ..... * J ......... ~' ................. , ....... :_.'. ..... :L:.: ..................~ .......... -..-:, ' ...... +~._. :..L.-: ....................................................................... P.O. Box 7-83g, Anchar~, AK .cg510 I TRA N S,"A ITT ED ·ilE FOLLOWING IS A LEST OF MATERIAL ENCLOSED HER£IN. PLEASE CtlECK AND ADVISE I}~----~IA'... · 'PL~'A$£ SIGN ANO RECEIVE:D BY Date ~'~' 19 3;3 f_ Il I STATE OF ALASKA ALASKA LANDGAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING .WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-104 3. Address $. APl Number P.O. Box 7-839, Anchorage, Alaska 99510 50-133--14~-~t 4. Location of Well 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 166.7 K.B. 6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A- 3 11. Field and Pool Swanson River Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Shut in well.. Reperforated existing interval 10716 - 10730 with 4 JHPF and 180© phasing. Returned well to production. This work was completed on 2/1 6/83. FEB 2 19 3 Alaska 0il & Gas Cons, O0mmissi0r Anchorage 14. I hereby certify that t~d correct to the best of my knowledge. Signed - Title Area Engineer The space below for Commission use Date 2/16/83 ~ ~-- ~F3 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 9-331 1973 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ,, SUNDRY NOTICES AND REPORTS ON WELLS (OD not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1, oil gas F1 well [] well other 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. 4. ADDRESS OF OPERATOR P.O. Box 7-839, Anchorage, Alaska 99510 LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE: 2070' S & 305' E from the AT TOP PROD. INTERVAL: N.W. CDr., Sec. 3, T7N, AT TOTAL DEPTH: R9W, S.M. 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: Form Approved. Budget Bureau No. 42-R1424 5. LEASE :' ~ -' ' ' ~L '~ -~ A~028997 --- '~ :~ :'- ** *~ - 6. IF INDIAN, ALLO~ OR TRIBE'NAME 7. UNIT AGREEMENT NAME Soldotna ~ree~ 8. FARM OR LEASE NAME · 9. WELL NO. SCU 12A-3' -' _ 10. FIELD OR WILDC/~T ~IAME' ' ' ~ ' .o Swanson River 11. SEC., T., R., M., OR BLK. AND SURVEY OR s c. Kenai ~-.~?~-~ ' ~[~ka ~- APl NO. " ' ' "?- ':. 50-133-1009-91 ~. ~. iL ?,'_ ~ -. 15. ELEVATIONS (SHOW DF,'_KDB,. AND WD) 166.7' K.B. ' SUBSEQUENT REPORT Of: TEST WATER SHUT-OFF [-'l E] '~ = - ': - .. '- . --: =..: ~-.~ FRACTURE TREAT F-] r--] = -.- :; ~ _ SHOOT OR ACIDIZE r'-] I~ "- ;--:: --:- "-':- .... -~ '-- REPAIR WELL ~ [-] (NOTE: Report results of rnultil31e completion Or zone PULL OR ALTER CASING F'-] [-~ change on Form 9--330.) .,_.'" MULTIPLE COMPLETE [] F'I :: .j j ~_, CHANGE ZONES I-'] [~] .:~. ABANDON* ~ [~ ._' "". (other) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details,' and give pertineNt, dates;-, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locat|ohs and measured and true vertical depths for all markers and zones pertinent to this work.)* 1. Shut in well. "2. - --~ . ,'~ 2. ReperEor~ted exist£~c; interval 10716 10730 with - _. ~asin~. 3. Returned well to production. - This work was completed on 2/1.6/83 ~ DEP~ MINE~LS'~A~OE~ = ~ ~ _ FEB 2 2 ~m [o ' · INERALS MANAGEMENT, Subsudace Safety Valve: Manu. and Type ~ ~e~ ~.~ Ft. 18. I hereby cR~i~ that the f~egoing is true and correct · SIGNED · . _ TITLE Area Engineer DATE ...... .... (This space for Federal or State office use) CONDITIONS OF APPROVAL, IF ANY: Chev~om is :emi~ded ChiC, acco:ding ~o 30 C~R 221.27(a), app~ova1 [~:-d~e~c~ op~io~s to redr[ll, deepen, perform cas[nE repairs, pluE-back, alter cas[nE-,~3~.~aT, · .'~ etc., must be obtaiaed i~ advance oE actu~[ ope~atioas. · See Instructions on Reverse Side . . .' ~.~: - ~_, SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator . Chevron U.S,^. Inc, 3. Address P, O. Box 7-839, Anchorage, Alaska 99510 4. Location of Well 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.H. 5. Elevation in feet (indicate KB, DF, etc.) 166.7 .K.B. 6. Lease Desionation and Serial No. A-028997 7. Permit No. 80-104 8. APl Number 50- 1 9. Uni:t or Lease Name Soldotna Creek Unit 10. Well Number SCU 12A-3 11, Field and Pool Swanson River Hem]ock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] - Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Shut in well. 2. Rep.erforate existing interval 10716 - 10730 with 4 JHPF and 1800 phasing. 3. Return well to pro'duction. This wOrk will commence on or about 2-15-83. ~bsequeat Work l~epo~te(1 RECEIVED FEB - 9 ~983 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that t~nd correct to the best of my knowledge. Signed j~- ~-~ Title Area Engineer The space below for Commission use Date 2/8/83 Conditions of Approval, if any: ORIGiflA[ SIGNED BY Lt),NNIE C. SMITH Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate February 4, 1983 Mr. T. L. Perryman Area Operations Superintendent Chevron U.S.A., Inc. P. O. Box 7-839 Anchorage, Alaska 99410 Dear Mr. Perryman:' The Alaska Oil a~d Gas Conservation Commission has recently checked the records of wells completed since January 1, 1979. This review has revealed that the digitized data for certain logs run in a well is not on file with the Commission. The Oil and Gas Regulations require the operator to file, 'within' 30 days after completion, suspension, or abandonment of a drilling well, the digitized data, if available, for copying, for all logs run in the well except velocity surveys, experimental logs and dip- meter surveys. We would request that you check your records to see if the data has been submitted to the Commission and, if not, that you comply with the regulation with regard to the following wells~ Swanson River Unit No. 31-33 WD Soldotna Creek Unit No. 44-8A Pretty Creek Unit No. 2. Soldotna Creek Unit .No. 12-3A Soldotna Creek Unit No. 41-9A Thank you for your cooperation in this matter. Yours very truly, Harry W. Kugler. Commissioner BY ORDER OF THE COMMISSION be COMPLETION REPORT C~tEVRON U.S.A. INC. AREA: Soldotna Creek Unit LAND OFFICE: Anchorage, Alaska PROPERTY: Swanson ?civer Field LEASE NO: A-028997 WELL NO: SCU 123t-3 API NO: 50-133-t~ LOCATION AT SURFACE: 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. LOCATION AT TOTAL DEPTH: ELEVATION: K.B. 26.5' DATE: 1/83 119' N & 95' W of Surface DRILLED BY: Brinkerhoff Signal Inc. Rig #54 DATE COMMENCED REDRII.L WORK: 11/9/82 DATE COMPLETED P~I)PJ_I~ WORK: 12/1/82 RETURNED TO PRODUCTION: 12/1/82 SUMMARY TOTAL DEPTH: 10,850' EFFECTIVE DEPTH: 10,806' (cmt) PLUGS: Abandonment (old hole) 10,150' - 10,268' CAS ING: 22" at 28' PERFORATIONS: 4 HPF - 10,716'-10,730' 13 3/8" at 3000' 7" at 10,265' (window milled 10,265'-10,307') 5" liner 10,045'-10,848' 11/9-11/11/82 I-{ove & rig up Brinkerhoff Signal Inc. Rig #54. Nipple up and test BOPE to 5000 psi. 11/12/82 Tagged bottom at 10,306' (old K.B. ). Reversed crude oil out of hole. 11/13/82 9.3 ppg Iiilled window in 7" casing 10,265'-10,269' (S.L. mmas.) (10,250'-10,254' CBL nmas.) NOTE - SCU 12-3 K.B. 18.5'-SCU 12A-3 K.B. 26.5' 11/14/82 9.2 ppg ~iilled window in 7" casing 10,269'-10,283'. 11/15 / 82 Milled window in 7" casing 10,283'-10,300'. 11/16/82 9.0 ppg Milled window in 7" casing 10,300'-10,307'. Tool started to torque. Circulated hole clean. Pulled out of hole with worn out section mill. Underreamed 8 3/4" hole to 11" from 10,265'-10,307'. Run in hole with 3 1/2" plug catcher. NOTE - Ran CCL - Tied into CBL- run 3/19/61 and found bottom 15 feet W.L. maas. to S.L. maas. Used rig maasurement. 1.~st subtract 15' to correct back to CBL meas. 11/17/82 Laid kick off plug across 7" casing window as follows: mixed and pumped 10 bbls of 10 #/bbl caustic, 84 sx. Class G cement with D31 and D6L (16.8 ppg, 1.014 C.F/sx) total slurry 15.2 bbls. Displaced with 5 bbls of 10..#PBL caustic flush followed with 62 bbls of drilling mud. Pumped 2 bbls over displacemmnt without bumping plug.. Bled back pressure. 12 bbls flowed back. Reversed out contaminated cement. Down squeezed 16 c.f. of cement and shut in with 2000 psi pressure. Pressure bled down to 1800 after 1/2 hr. Tested BOPE. Washed green cement 9852' -10,150'. Waited on cemant. 11/18/82 9.0 ppg Drilled out cemmnt 10,150'-10,268'. RECEIVED Alaska 0;I & Gas Coss~ Comrn;$$ior~ Anchorage 11/19/82 9.0 ppg Dyna drilled 10,268'-10,357'. 11/20/82 9.2 ppg Drilled 10,357'-10,398'. 11/21/82 9.2 ppg Drilled 10,398'-10,410' - hole sticky. Reammd open hole 10,265'-10,410 (very tight in spots). Circulate and conditioned hole - returns of coal and shale. Drilled 10,410'-10,430' (hole good) 11/22/82 Drilled 10,430'-10,515' with difficulty m~ntaining direction due to coal and shale. 11/23/82 9.3 ppg Drilled 10,515' -10,519'. 11/24/82 Raamed tight hole 10,509'-10,519' parted. Retrieved with overshot. 9.3 ppg Drilled 6" hole to 10,540'. Drilled to 10,628'. Wireline 11/25 / 82 9.3 ppg Drilled 6" hole to 10,819' wireline parted. Unable to retrieve with overshot. Drilled to 10,850'.. Conditioned mud for logs. Recovered fish. 11/26/82 9.4 ppg Ran DIL-SP-Sonic, FDC-~NL-GR logs from 10,850'-10,265'. Ran 20 joints of 5", 18#, N-80 butt~and 8RD liner 10,848'-10,045'. 11/27/82 Cenmnted 5" liner with 10 bbls water ahead, 88 sx Class "G" cement mixed with .75% CFR2, 3% KCL. Displaced with 81 bbls mud to bump plug with 3000 psi. Reversed out trace of cenmnt. Tested liner to 3000 psi. Drilled out cemmnt 10,723' -10,806'. 11/28/82 Ran CCL-CBL-CNL-GR logs 10,806'-10,000'. Displaced hole fluid with lease crude. J4htl ~Chorage C°/~ei~lo/~ 11/29/82 Ran 326 jts 3 1/2" 9.3 8RD N-80 and L-80 tubing with tail at 10,345', Backer Packer at 10,006' and 1.~ndrels at 9964,. 6494, 6100, 5806, 5293, 4495, 3762, 2743, 1503. Test seal assembly. Spaced out tubing and reseated seal assembly. Rmtested to 600 psi. Set Backer Packer at 10,006. Land tubing and shear bull plug pins. Installed back pressure valve. 11/30/82 Nippled down BOPE. Nippled up 3 1/2" X-mas tree and tested to 5000 psi. 12/1/82 Perforated with 2 1/8" hollow carrier gun at 0" phasing 4 H.P.Fo 10,730' -10,716'. Rigged down. Placed rig on standby. ALASKA~-L AND GAS CONSERVATION C~. MISSION WELL COMPLETION OR RECOMpLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I'~ GAS [] SUSPENDED [] ABANDONED [] SERVlCE'~ 2. Name of Operator /'~ 7. Permit Number CHEVRON U.S.A. INC. 80-104 ,. 3. Address 8. APl Number /~:~)~)?~- P. 0. Box 7-839, Anchorage, Alaska 995]0 50- 133-q-19~-~ 4. Location of well at surface 2070' S & 305' E from the N.W. Corner, 9. unit or Lease Name Sec. 3, T7N, R9W, Seward Meridian So]dotna Creek Unit At Top Producing Interval I 00' N & 85' W Of Surface lO. Well Number SCU 12 A-3 At Total Depth 119' N & 95' W of surface 11. Field and Pool Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation.and Serial No. K.B. 26' A-028997 12. Date Spuddedll/18/82 K.0. 13. Date T.D. Reached .ll/25/82 14' Date C°mp"Susp' °r Aband' 115'Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns12/1/82 feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 0,850MD 10,844TVD 10,806,M.D.10.,801 YES~] NO[]]I _= feetMD __ 22. Type Electric or Other Logs Runl L)V DIL - SP - SONIC. FDL-CNL-GR. CCL-CBL-CNL-CC - 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22,, ,, Surface 28' - __ 13 3/8" 54.54 R-3 . Surface 3000' 8 5/8" 1792 SX. , '1 IN I IIMUW I'1 I I I l~t.I 7" 29# P-110 Surface l0 5 10 5/8" -- in e~,_ln ~nT,, 5" 18# N-80 10,037' 10,848' 6" 88 SX. , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25, TUBING RECORD · interval, size and number) S'[ZE DEPTH SET (MD) PACKER SET (MD) Hemlock 3 1/2" 10,345' 10,006' 10,730' - 10 716' 4 HPF 33 10,725 ' - 1 0,711 ' tvd 26'. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , . ...:!.. ~ , ., ~, , ~ DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ... . ',~i:,: ' '. , ~' . , '... " .... .. · . ~ · 27. PRODUCTION TEST Date:First Pr.o. duction .. ..I :Method of. Operation (Flowing, gas lift, etc.) 12/1/82J ~ G/L '' . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS-OILRATIO '1 · 12/22/82-, 4,...TEST. PERIOD I~ 6 ., 18 8 . spI 2900 FlowTubing Casing Pressure CALCULATED ,.~ ..OIL]BBL ' . , ' . GAS/McF WATER-BBL oIL GRAVITY-APl (corr) Press.250. 880...: 2~HOUR RATE~ 38 ~: 110 51. 28. COP E DATA ' ! " " Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , , " " ': " '""":"::" .. RECEIVED · ". :.' · ,· - DE0291982 ', Alaska 0il & Gas Cons. Commission a~Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ...... 'MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. H-1 1 0,385 1 0,~2.~- H-2 10,409 10,407 NONE H-3 10,442 10,439 H-4 10,467 10,464 H-5 10,486 10,483 H-6 10,542 10,538 H-8 10,558 10,554 H-9 10,636 10,632 H-10 10,670 10,666 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . _ Title Area Fngin~mr Date /~ ~l,_ 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 cement- ing and *~ ' ^~+; ..... ; +^"' u,u ,o~o~,on of the ng ue.I I1~1 I LI L~./k.~ I , Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB.SURFACE DIRECTIONAL SURVEY CHEVRON COMPANY 12A - 3 WELL NAME KENAI, ALASKA LOCATION ALllB2DB6 SINGLE SHOT 11-30-82 JOB NUMGER TYPE SURVEY OATE DON BURGESS ENGINEER NAME TITLE SIGNATURE 10268 10850 DEPTH INTERNAL FROM TO 11-16-82 11-25-82 DATES SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB.SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any blueprint company. RE£E V£D JAN2 11984 'AT~sk~ 0ii & Gas ConS. Comm]s~]m~ ii GREATLAND DIRECTIONAL DRILLING C:OMPLETION REF'ORT OPliZ'LI-I'ED ON 11-30-82 U'._:;ING RADIIJ$ OF CLIRVAi-tJRE TIECHNIQIJE --ROM F;URVEY DATA TAKEN I 1-25-:-3.2 :INAL CLFISI_IRE DIRECTION N 0.0() E 3INGLE :_:;HOT SORVEY RECORI-~ OF SURVEY (WELL ASSU['~ED VERTICAL TO 0.0) CHEVRON U.$.A. CHEVRON Lt.E;.A. 12A-3 .~lt-- A'.S DR I F T I'RUVERT SUBSEA SECT I ON D I REC1- I ON ]EF'-FH DO MN DEPTH DEPTH D I ST ANGLE n 0 O O. 00 -166.70 O. 00 O. 00 -166.70 O, 00 0 0 0 0.00 O. O0 RELAI-IVE COORDINATES FROM WELL-HEAD 0.00 0. O0 O. O0 O. 00 CLOSURE DISTANCE DG MN S 0. O0 0 0 0 0.00 0 0 0 DOG LEG de~/lO0 0. 000 O. 000 IuC) O 15 100.00 -66.70 0,2(:) N 22.00 W 200 0:30 200.00 :3:3.:30 O.72 N 51.00 W :300 0 20 27'F/. $/'~ 13:3.29 1.00 N 64.00 W 400 0 15 3'~?. '?'~ 2:3:3.29 1. 1:3 N 65.0() W ~](JO (il 15 479. 'F/9 3:33.2? 1.4,E: N 4.00 W E. OO 0 O 57'9. '?? 4:3:3. ?9 I. 6'P N 4.00 W 7<iA ....... O ::lA E,':]':~ .99.. = ~":'._,.~._,. 29. 1 . 34 S 35.O0_ W :300 O 30 79'F~.99 6:3:3.2'~ 0.82 S 71.O0 W ?L)O C) 2:0 F;9'e.9~ 7:33.28 1.00 N 46.00 W 100() 0 15 '9'F/'~.'78 83:3.28 1.56 N 12.00 W 110() 0 0 1 ()'~'F;. 9 E: 9:33.28 1.7:3 N 12.00 W 1200 0 15 Il'F/?.?8 10:3:3.28 1.74 S :31.00 E 1300 0 :30 12'??.'?B 11:33.28 1.25 S 64.00 W 1400 0 20 l:3'~'/y.'F, 8 12:3:3.2:3 0.71 S 16.00 W 15o(_~ 0 2() 14'F/'F/.'~/7 1:3:3:3.27 0.61 N 41.00 W lc..,') 0 20 15'FT?~.'P7 143:3.27 1.16 N 20.00 E ]700 0 15 167'.2.97 1533.27 1.5'~ N 40:00 E 1:3o0 0 15 17t)'~.97 16:33.27 1.60 S 4:3.00 E 1'900 0 .30 1:39'~>.77 1733.27 1.7:3 N 16.00 E 2c~(~0 ..... 0 30 1':~':~'~,,. .76 18:33.26 2..-.~1 N 35.00 E 210U 0 15 20'F~'F].'F]6 1933.26 2.'~7 N 55.00 E 2200 0:30 2179.'~6 203:3.26 3.3'~ N 46.00 E 2300 0 15 229'~.76 21:33.26 3.66 N E:5.00 E 2400 0 0 23':)'2.96 223:3.26 :3.6:3 N :35. O0 E ::'.S()O 0 15 2~'P?.ge 23:33.26 3.49 S 30.00 E 0.2(:) N 0.08 W 0.72 N 0.47 W 1.00 N 1. 1.]: W 1.1:3 N 1.62 W 1.48 N 1.:::5 W 1.6'.2 N 1.87 W 1.:34 N 2.12 W 0.:32 N 2.80 W I. 00 N 3.61 W 1.56 N 3.'.2:3 W 1.78 N :3.'F/7 W 1.74 N :3.76 W 1.25 N :3.68 W O. 71 N 4. 14 W 0.61 N 4.60 W 1.16 N 4.70 W 1.5'.2 N 4.45 W 1.60 N 4.(]6 W 1.73 N 3.54 W 2.51 N :3.17 W 2.'B7 N 2,71 W :3.:3'? N 2.20 W :3.66 N 1,62 W :3.6:3 N 1,40 W 3.4'2 N 1.29 W 0.22 N 22 0 0 W 0.86 N 32 51 37 W 1.51 N 48 33 2'.2 W 1.97 N 55 0 10 W 2.37 N 51 28 35 W 2.52 N 47 4'~ 14 W 2.50 N 57 46 23 W 2.92 N 73 43 2 W 3.75 N 74 33 12 W 4.23 N 68 17 57 W 4.35 N 65 54 30 W 4. 14 N 65 7 21 W 3.8'-2 N 71 11 56 W 4.20 N 80 13 13 W 4.64 N 82 26 57 W 4.84 N 76 11 54 W 4.73 N 70 17 36 W 4.37 N 68 27 43 W 3.'~4 N 63 57 12 W 4.04 N 51 32 48 W 4.02 N 42 17 18 W 4.04 N 32 5? 29 W 4.00 N 23 51 17 W 3.93 N 20 50 45 W 3.72 N 20 18 40 W 0,250 O, 250 O. 167 0.08:3 O. 001 il). 250 O. 5(i)0 0.00:3 O. 005 O. 250 O. 250 0. 250 O. 250 O. 167 O. 004 O. 002 O. 083 O. 002 O. 250 O. 001 O. 250 O. 250 O. ~_._,O O. 250 U. ~._,L ~EVRON U.S.A. 12A-3 AS DRIFT TRUVERT ~.~PTH DG MN DEPTH SUBSEA DEPTH 2600 0 0 2599.96 2700 0 0 2699.96 2800 0 30 2799.96 2~00 0 30 2899.95 :3000 0 25 2999.95 100 0 30 3099.94 _£00 0 0 3199.94 '3300 0 10 3299.94 3400 0 30 3399.94 3500 '0 35 3499.94 3~00 0 35 3599.93 3700 0 50 3699,92 3800 0 50 3799.91 3900 0 30 3899.91 4000 1 0 3999.90 4100 0 45 4099.89 4200 I 0 4199.87 4:300 0 55 4299.86 4400 0 50 4399.85 4500 0 45 4499.84 4600 0 35 4599.83 4700 0 55 4699.82 4800 0 30 4799.82 ~900 0 30 4899.81 5000 1 10 4~9.80 5100 0 30 5099.79 5200 ! 40 5199.77 5300 I 50 5299,72 5400 2 0 5399.67 5500 2 30 5499,59 5600 2 15 5599.50 5700 2 30 5699.42 5800 2 35 5799.32 5900 2 15 5899,23 6000 2 55 5999.13 6100 i 40 6099,05 2433,26 2533,26 2633,26 2733,25 2833.25 2933.24 3033,24 3133.24 3233.24 3333,24 3433.23 3533.22 3633.21 3733.21 3833.20 3933.1~ 4033.17 4133.16 4233.15 4333.14 4433.13 4533.12 4633.12 4733.11 483:3.10 4~33.0~ 5033.07 5133.02 5232,97 5332.8~ 5432,80 5532.72 5632.62 5732.53 5832,43 5~32.35 RECORD OF SURVEY SECTION DIRECTION D I ST ANGLE 3.30 S 30.00 E 3.30 S 30.00 E 3.02 S 51.00 E 2,52 S 58.00 E 2.40 N 75.00 E 2,58 N 79.00 E 2.67 N 79.00 E 2,53 S 20·00 E 2.65 N 19.00 W 3.56 N 15.00 W 4~41 N 48,00 W 5.22 N 50,00 W ~.36 N 26.00 W 7.48 N 5.00 W 8.75 N 21.00 W 10. 1'4 N 27.00 W 11.48 N 31.00 W 12.89 N 34.00 W 14.06 N 45.00 W 15.25 N 15.00 W 16.29 N 36.00 W 17.38 N 31.00 W 18.56 N 1.00 W 19.43 N 10.00 E 20.:36 N 20.,00 W 22.27 N 8. O0 W 24.12 N 14:00 W 26.98 N 27.00 W 29.'~:B N 25,00 W 33.66 N 16.00 W 37.25 N 42.00 W 40.60 N 30.00 W 44.79 N 5. O0 W 48.54 N 45.00 W 52.21 N 25.00 W 55.77 N 29.00 W RELATIVE COORDINATES FROM WELL-HEAD ~ - 3.30 N 1.18 W 3.30 N 1.18 W 3.02 N 0.84 W 2.52 N 0.13 W 2.40 N O. 64 E 2.58 N 1.42 E 2.67 N 1.84 E 2 53 N 1,8~ E 2.65 N 2,25 E 3.56 N 1.97 E 4.41 N 1.44 E 5.22 N 0.51 E 6,36 N 0.38 W 7,48 N 0.69 W 8.75 N 0.98 W 10.14 N 1.60 W 11.48 N 2.34 W 12.89 N 3.24 W 14.06 N 4.21 W 15.25 N 4.8~ W 16.29 N 5.39 W 17.38 N 6.11 W 18.56 N 6.45 W 19.43 N 6.38 W 20.86 N 6,51 W 22,27 N 6.86 W 24.12 N 7.22 W 26, 98 N 8.29 W 29.98 N '-2.75 W 33,66 N 11.13 W 37.25 N 13.12 W 40.60 N 15.55 W 44.79 N 16.87 W 48.54 N 18.62 W 52.21 N 21.19 W 55,77 N 23.00 W CLOSURE DISTANCE DO MN S 3.50 N 19 42 38 W 3.50 N 19 42 38 W 3.14 N 15 34 11 W 2.52 N 3 0 41 W 2.48 N 14 50 52 E 2.~4 N 28 44 35 E 3.24 N 34 41 & E 3.16 N 36 50 16 E 3.48 N 40 14 36 E 4.07 N 28 58 3 E 4.64 N 18 7 19 E 5.25 N 5 35 22 E 6,37 N 3 23 51 W 7.51 N 5 14 57 W 8,80 N 6 23 40 W 10.27 N 8 58 18 W 11.71 N 11 31 49 W 13.29 N 14 6 41 W 14.68 N 16 39 49 W 16.01 N 17 47 28 W 17.16 N 18 18 34 W 18.43 N 19 22 32 W 19.65 N 19 9 57 W 20.45 N 18 11 8 W 21.85 N 17 19 32 W 23.30 N 17 7 7 W 25.18 N 16 39 37 W 28.22 N 17 4 28 W 31.53 N 18 I 3 W 35.45 N 18 17 31W 39.49 N 19 23 59 W 43.47 N 20 57 27 W 47.86 N 20 38 23 W 51.98 N 20 59 10 W 56.35 N 22 5 25 W 60.33 N 22 24 55 W -30-82 DOO LEO de~/lO0 0.250 0.000 0.500 0.001 0.083 0.083 0,500 0.167 0.334 0.083 0.003 0,250 0,005 0,333 0,500 0,250 0.250 0,083 0,083 0.083 0.167 0.333 0.417 0.001 0.667 0.667 1.167 0.167 0.167 0.500 0.253 0.251 0.098 0,339 1.250 u, ~ ii I III _ II ~J _ _ I !~ _ I '-IEVRON U. E;. A. 'qEA::; [iR I FT 3EF'TH [ii3 MN 6200 I :35 6300 2 15 6400 1 5 6500 2 15 6600 2 30 6700 1 15 6,:300 0 55 6900 1 20 7000 0 30 71 O0 0:30 7200 0 55 730 () 1 0 7400 ~ 0 7600 0:30 77 00 0 .30 7?00 0 30 :3000 0:30 :310U 0:30 ;3200 1 0 :3.:::OU 0 45 ~:/:,OC) 0 45 .3700 1 3t) :3:300 0:30 :3':~ O0 1 :30 '?000 I 5 ':>200 1 45 '? :300 2 5 '?400 0 50 9600 1 0 9700 2 30 12A-:3 TRUVERT S;UBSEA SEC:TION DIRECTION DEPTH DEPTH D I ST ANOLE 619'2.01 60:32. :31 57.9:3 6298.95 6,1:2:2.25 60.7:3 6:3'P:3.91 6232.21 6:3.21 64'78.86 e, 332. 16 65.38 6598.78 64:32.0:3 6:3.24 6698.72 65:32.02 70.05 679:3 7o ~ '-", . . . . :,6.J~. 00 71 02 6.:.9o 68 6731 98 72.49 6998.67 6831.97 73. 18 709:3.67 6931.97 7:3.74 719:3.66 7031.96 74.47 7298.64 71:31.94 74.01 7:398.6:3 7231.9:3 73. '?6 74'?8.62 7:331.92 7:3.5:3 759:3.62 74:31.92 7:3.7.5 7698.61 7531.91 74.02 77'?8.61 76:31.91 7:3.37 78'F~:3.60 77:31.90 72.77 7'?'?:3.59 7:3:31. 39 71.97 :309:3.59 7931.8'~ 71.72 :31'?:3.5:3 :3031. :38 71.22 E:27~8.57 :3131. :37 71.07 :33'78.56 :32:31.86 70.65 :349:3.55 83:31. :35 69.6:3 :35'9:3.54 84:31.84 6:3.89 E:6'F]:3.52 :35:31.82 67. 11 879:3.~. = 1 8631. :31 66. A. 'P. 8:3'?8.49 8731.7'? 66. 11 3'?'[~ 3.46 88:31.76 66.40 9098.42 89:31.72 65.74 919:3.36 9031.66 65.5:3 929E:. :31 9131.61 65.09 '~:3'?:3.27 '7231.57 65.74 949:3.26 9:3:31.56 66.5:3 '~5'?:3.25 '?4:31.55 66.37 9698.20 95:31.50 66.65 RECORD OF SURVEY N 51.00 W N 12,00 W N 48.00 W N G:5.00 W N 57,00 W N 56.00 W N 62.00 W N 18.00 W S 75.00 W N 46.00 E S 67.00 W S 81.00 W N 84. O0 W E; 39.00 W N 9.00 E S 40.00 W N 58. O0 E S 21.00 W S 27.00 W N 65.00 W S 14.00 W N 29.00 W E; 20.00 E 'S 62.00 E '.3 22.00 E '.S 51.00 W S 5'7'. 00 W N 55.00 W 'S 70.00 W S 83.00 W S 90.00 W S 75.00 W N 44.00 W N 76.00 W S 65.00 W N 54.00 W RELATIVE C:OCIRDINATES FROM WELL-HEAD CLC'E;URE D I STANCE DG 57.9:3 N 24.:32 W 63.02 60.7::: N 26·53 W 66.27 63.21 N 27.96 W 69. 11 65.38 N 29·:38 W 71·88 68.24 N 32.85 W 75.73 70.05 N 35.57 W 78.56 71.02 N 37. 19 W 80. 17 72.49 N :38.4:3 W 82.04 7:3· 1:3 N :39·70 W 83.25 73,74 N 40.02 W 83,89 74,47 N 40,50 W 84,77 74,01 N 42. ICl W 85. 15 7:3.96 N 43.:_::4 W 85.98 73.53 N 44.87 W 86. 15 7:3.75 N 45.36 W 86.59 74.02 N 45.95 W 87. 13 73.:37 N 45.3'F~ W 86.27 72.77 N 44.66 W 85.38 7t.97 N 45,02 W 84,89 71.72 N 45.76 W 85.07 71.22 N 46.:E:0 W 85,2'2 71,07 N 47.'.98 W :::5o75 70.65 N 4:3.90 W 85.92 67/.68 N 48.06 W 84.65 68. E:'-2 N 47. :35 W 8:3.59 67.11 N 47,81 W 82,40 66.09 N 49.22 W :32.40 66. 11 N 50.86 W 8:3.42 66.40 N 53.01 W 84.'77 65.74 N 55.76 W 86.20 65.5:3 N 59. 17 W :3:3,29 65.09 N 62.48 W 90·23 65.74 N 64.82 W 92.32 66.5:3 N 66· 19 W 93.85 66.37 N 67.:-::'? W 94..94 66.65 N 70.79 W 97.22 MN S N 23 l l 22 N 23 35 57 N 2:3 51 49 N 24 3:3 52 N 25 42 12 N 26 55 30 N 27 3:3 32 N 27 55 43 N 28 28 50 N 28 29 18 N 28 32 25 N 29 38 iO N 30 3'2 32 N 31 23 37 N 31 35 43 N 31 49 57 N 3i 44 28 N 31 32 18 N 32 I 26 N 32 32 30 N 3:3 1:3 2')... N 34 1 17 N 34 41:32 N 34 35 50 N 34 30 10 N 35 27 54 N 36 40 40 N 37 34 19 N 38 36 17 N 40 18 29 N 42 4 58 N 43 49 36 N 44 35 42 N 44 51 4 N 45 38 60 N 46 43 34 1 1-30-82 DO0 LEG dee / 1 O0 O. 085 O. 1. 167 1. 167 O. 253 1 · 250 O. 333 O. 417 O. :333 0.011 O. 419 O, 083 0 · 005 0.667 O. 167 O. 011 O. 41'~ O. 417 O, 000 0.007 0.501 0,251 O, 255 0. 500 0. 250 0 · 752 1. 000 1. O. 417 1. 083 0.417 O. 3.34 I, 250 O, 167 0.012 1. 504 I ~EVRON U.S.A. 12A-3 MEAS DR I FT TRUVERT DEPTH DG MN DEPTH SUBSEA DEPTH SECTION DIST ~800 I 30 9798.13 9908 2 50 9906.05 10268 2 50 10265.61 1£)358 4 45 10355.41 10410 7 0 10407.14 10435 5 45 10431.'98 10483 6 0 10479.73 10510 6 0 10506~58 10541 6 0 10537.41 10572 6 0 10568.24 10603 6 15 10599.07 10665 6 30 10660.68 10728 7 0 1072:3.24 10790 6 45 10784.80 10850 7 0 10844.37 9631.43 9739.35 10098.91 10188.71 10240.44 10265.28 10313.03 10339.88 10370.71 1,0401.54 10432.:37 10493.98 10556.54 10618.10 10677.67 RECORD OF SURVEY DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 68.96 N 43.00 W 68.96 N 73.40 W 70.23 S 81.00 W 70.23 N 77.11W 67.45 S 81.00 W 67.45 N 94.68 W 71.39 N 30.50 E 71.39 N 97.36 W 75.97 N 30.50 E 75.97 N 94.66 W 78.21 N 41.50 E 78.21N ~3.03 W 81.98 N 3:3.50 E 81.98 N 89.88 W 84.34 N 27.50 E 84.34 N 88.34 W 87.25 N 24.50 E 87.25 N 86.92 W 90.31 N 14.00 E 90.31 N 85.85 W 93.54 N 10.00 E 9:3.54 N 85.17 W 100.40 N 6.00 W 100.40 N -84.93 W 107.53 N 2:3.50 W 107.53 N 86.80 W 113.91 N 37.50 W 113.91N 90.56 W 119.29 N 45.50 W 119.29 N 95.32 W CLOSURE DISTANCE DG MN S 100.71 N 46 47 15 W 104.30 N 47 40 17 W 116.25 N 54 32 7 W 120.73 N 53 45 ~ W 121.38 N 51 15 4 W 121.54 N 49 56 46 W 121.65 N 47 37 53 W 122.14 N 46 19 37 W 123.16 N 44 53 27 W 124.60 N 43 33 6 W 126.50 N 42 18 59 W 131.50 N 40 13 38 W 138.20 N 38 54 42 W 145.52 N 38 29 7 W 152.69 N 38 37 37 W 11-30-82 DOG LEG deg/lO0 1.000 1.241 0.000 2.347 4.327 5.019 0.525 0.445 0.106 0.370 0.821 0.521 0.894 0.510 0.461 tEVRON U.S.A. 12A-3 DATA INTERPOLATED FOR EVEN 1(10 FEET OF SUBSEA DEPTH 11-30-82 4EAS. TRU VERT SUB '.SEA MD-TVD [~E F'-F H DEPTH DEF'TH [I I FF. 267 267 100 0 :367 .36, 7 200 0 4/.:,7 4/.,7 300 (.1 567 567 400 6.67 66. 7 500 0 767 76, 7 600 0 :36, 7 8/., 7 7 (~ 0 0 'F~6. 7 ':7~6 7 800 1067 1067 'F.~O0 0 1167 116,7 1000 0 126,7 1267 11 O0 1 367 1:367 1200 0 14/:,7 146.7 1:300 0 156. 7 1 $67 1400 16.6, 7 1667 15CIO .0 176.7 1767 1600 1 ::: 67 1:367 17 O0 0 1 '.;, ~. 7 1967 1800 0 2067 ,' 067 1 'FY 00 0 216.7 2167 2000 0 :" 2,::, 7 2267 21 O0 0 2 ::e. 7 2:2,67 2200 0 :_:46.7 2467 2300 0 256. 7 2567 2400 0 26.6 7 2/-.67 2500 0 2 Y 67 27 L-, 7 2600 0 2":_:', E, 7 2',E: 67 2700 0 2 ':) 6, 7 2'? 67 2:300 0 :306, 7 :3067 2'FY 00 0 :3: 67 :316,7 :3000 0 :2,26.7 :2:267 5:100 0 · 3 .?, 6, 7 :2', 367 3200 0 :34' 7 :3467 :3:300 0 3-5 c. 7 :--: 567 :3400 0 :36,6.7 3667 :3500 0 VERT i CAL I::ORREC'F 0 0 l) 0 0 0 0 0 0 0 (.) 0 U (_) .) _) 0 0 0 0 0 0 RELAI'IVE C:OORDINATES FROM WELL-HEAh 0.96 N 0.92 W 1.07 N 1.48 W 1.34 N 1.82 W 1.67 N 1.87 W 1.67 N 2.06 W O. 94 N 2.54 W 0.84 N 3.3'7 W 1.40 N 3.8S' W 1.75 N 3.97 W 1.68 N :3.9:3 W 1.45 N :3.57 W 0.91 N 4.06 W 0.52 N 4.44 W 0.97 ~ 4.74 W 1.47 N 4.54 W 1.72 N 4.59 W 1.7-28 N 4.23 W 2.27 N :3.32 W 2.8;~, N 2. L:24 W 23.21 N 2.40 W 3.64 N 1.79 W :3./:,7 N 1.42 W 3.(:,4 N 1.49 W :3. :32 N i. 19 W 3.30 N 1. 123 W :3. 16 N 1.05 W 2.623 N 0. :38 W 2.:::0 N O. 16 E 2.52 N 1.14 E 2.66 N 1.80 E 2.65 N 1.78 E 2.33 N 1.72 E 3.24 N 2.06 E - 4.16 N 1.67 E 4.':?23 N 0.86 E ~EVRON U.S.A. 12A-3 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 11-30-82 EA$. TRU VERT SUB SEA MD-TVD VERTICAL EPTH DEPTH DEPTH DIFF. CORRECT 3767 3767 3600 0 3867 3867 3700 0 3967 3967 3800 0 4067 4067 3900 0 4167 4167 4000 0 4267 4267 4100 0 4367 4367 4200 0 4467 4467 4300 0 4567 4567 4400 0 46.6,7 46,67 4500 0 4767 476.7 4600 0 4.'_::6,7 4:-i:67 47(:)0 0 4';?67 4967 4:5:,06) 0 5656,7 5067 4'900 0 51/-,7 5167 50A0 .0 526,7 526.7 5100 5368 5:367 5200 5468 546.7 53(i)0 1 5568 5567 5400 5668 56,67 5500 1 5768 576.7 5600 1 5868 5867 5700 1 5'5/6::': 5?.)67 586:)6) I 6068 6067 5900 1 6168 6167 6000 6268 6267 6100 1 6368 6367 6200 1 646::: 6467 6300 1 6568 6567 6400 1 6668 6667 6500 1 6768 6767 6600 1 686'.--/ 6:36.7 6700 2 696'F/ 6967 6:.1:00 2 7069 7067 6900 2 716'-9 7167 7000 2 RELATIVE COORDINATES FROM WELL-HEAD 5.94 N 0.14 W 7.16 N 0.65 W 8.24 N 0.83 W ~.73 N 1.40 W ll. O0 N 2.06 W 12.44 N 2.94 W 13.71 N 3.87 W 14.83 N 4.75 W 16.00 N 5.20 W 16.96 N 5.85 W 18.23 N 6.44 W . 1~.14 N 6.42 W 20.27 N 6.38 W 21.92 N 6.81W 23.29 N 7.04 W 26.03 N 7.85 W 28.96 N 9.27 W 32.33 N 10.70 W 36.22 N 12.:31W 39.41N 14.80 W 43.35 N 16.64 W 47.52 N 17.79 W 50.82 m 20.42 W 54.85 N 22.50 W 57.32 N 24.15 W 5~.61N 26.12 W 62.71 N 27.42 W 64.47 N 29.17 W 67.41N 31.75 W 69.59 N 34.90 W 70.76 N 36.72 W 71.87 N 38.10 W 73.29 N 39.31W · 73.49 N 40.12 W 74.38 N 40.11W .. ~FVRON U.~B.A. 12A-3 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH -30-82 EAt_--:. TRLI VERT SLIB E;EA MD-1VD VERTICAL E P-I'M DEP 1 H DEPTH D IFF. E:ARREP:T t0772 10767 10600 5 0 RELATIVE COEIRDINATES FROM WELL-~tEAD 112.16 N :3'~.31W J tEVRON U.S.A. 12A-3 DATA INTERPOLATED FOR EVEN 100 FEEl' OF :31JBSEA DEPTH 11-30-82 MEA'._:;. DEF'TH 7269 7:369 7469 7569 7669 7769 7869 7S.~6:'.-~ 806':-/ 8169 8269 8369 8469 8569 :366'9 876'.~ ':-./06 '.:~ 91 z_,9 9269 9:2/: 'P 9469 9569 976'.-.) 1006':} 10169 1027r~ 10370 10470 10571 10672 TRU VERT SlOB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT 7267 7100 2 0 7367 7200 2 0 7467 7300 2 0 7567 7400 2 0 7667 7500 2 0 7767 7600 2 0 7867 7700 2 0 7967 7800 2 0 8067 7900 2 0 8167 8000 2 0 8267 8100 2 0 8367 8200 2 0 8467 8300 2 0 8567 8400 2 0 8667 8500 ~ 0 8767 8600 '2 0 8867 8700 2 0 8967 8800 2 0 9067 8900 2 0 9167 9000 2 0 9267 9100 2 0 9367 9200 2 0 9467 9300 2 0 9567 9400 2 0 9667 9500 2 0 9767 9600 2 0 ~867 9700 2 ~ 0 9967 9800 2 0 10067 9900 2 0 10167 10000 2 0 10267 10100 3 1 1036'7 10200 3 0 10467 10300 3 0 10567 10400 4 1 10667 10500 5 1 RELATIVE COORDINATES FROM WELL-HEAD I 74.12 N 41.56 W 73.93 N 43.29 W 73.75 N 44.72 W 73.53 N 45.28 W 74.14 N 45.71W 74.20 N 46.52 W 74.03 N 45.57 W 72.22 N 44.89 W 71.67 N 45.49 W 71.60 N 46.50 W 70.75 N 47.64 W 71.11N 48.81W 69.84 N 48.35 W 6~.22 N 47.55 W 67.73 N 47.41W 66.28 N 48.91W 65.92 N 50.18 W 66.56 N 52.39 W 65.93 N 54.68 W 65.54 N 58.17 W 65.33 N 61.39 W 65.2~ N 64.40 W 66.35 N 65.68 W 66.54 N 67.37 W 66.24 N 69.65 W 68.30 N 72.77 W 70.06 N 75.38 W 69.76 N 80.07 W 68.99 N 84.96 W 68.21N 89.85 W 67.44 N 94.74 W 72.24 N 96.86 W 80.92 N 90.73 W ~0.15 N 85.89 W 101.08 N 85.01W _1 EVRAN U.S.A. 12A-3 I-IAI'A INTERPFtLATED FOR EVEN 10()0 FEET F~F MEASURED DEPTH MEA'.S. TRU VERT SUB SEA RELATIVE COORDINATES DEF'TH DEPTH DEPTH FROM WEkL-HEAD 2000 2000 i:B:B:~ 2.51 N E;. 17 W 2,000 3000 28:3:3 2.40 N O. 64 E 4000 4000 :38:3:3 :3.75 N 0.98 W 5000 5000 4:3:33 2C).86 N 6.51 W 6000 5'~/S/F/ 5:3:32 52.21 N 21. 1'~ W 7000 6'?'F/'~ 6:3~:2 7:B. 1:3 N :B'?.70 W :~:000 7'F/'F~'~ 7:332 71 .'F/7 N 45.02 W '~/000 ?,':~'?:~: :~:~::2:1 66.4C) N 5:3. C) 1 W 10000 '~':/'T~:q ....... 'F/:B:31 ~.'~. ~ '~ N 81.60 W I 1 - .2: O- :2:2 II I II II HORIZONTAL VIEW CHEVRON U.S.A. WELL 12A- $ RADIUS OF CURVATURE MAGNETIC SINGLE-SHOT SCALE 1"=50' DEC. I~ 1982 TV D = 10~844' TMD= 10~850' · vo ,o,~ ,o,;o~ ~ooo--~ ~o~ ° oo ooo ALL DEPTHS SHOWN ARE TVD 800 1200 - 1600 2000 ~400 '2800 - 3200 :5600 4000 4400 -4800 5200 5600 6O00 6400 6800 7200 7600 8000 8400 8800 9200 9600 I0,000 10,400 10,800 TVD = I0,B44' WELL 12A-,5 RADIUS OF CUPVATURE MAGNETIC SID,' '--SHOT SCALE I"= IOOu' DEC. I, 1982 ALL DEPTHS SHOWN ARE TVD GREATLAND DIRECTIONAL DRILLING COMPLETION REPORT COMPUTED ON 11-24-82 USING RADIUS OF CURVATURE TECHNIQUE FROM SURVEY DATA TAKEN 11-24-82 PLANNED WEdL DIRECTION N 0.00 E ISINGLE SHOT SURVEY MEAS ~ DEPTH 0 DRIFT TRUVERT SUBSEA SECI'ION DO MN DEPTH DEPTH DIST 0 0 0.00 0.00 0.00 REC:ORD OF :SURVEY (WELL ASSUMED VERTICAL TO 10268.0) DIRECTION ANGLE CHEVRON U.S.A. CHEVRON U.S.A. 12-3A RELATIVE COORDINATES CLOSURE FROM WELL-HEAD DISTANCE DG MN 0.00 O. O0 0. O0 0.00 0 0 DOG LEG S deg/lO0 0 O. 000 14)26:3 10358 10410 10435 10483 10510 10541 10572 10603 lo-/q o 0 0 10268.00 1026:3.00 4 45 10357.90 10357.90 7 0 10409.62 10409.62 5 45 10434.47 10434.47 6 0 10482.21 10482.21 0 10509.07 10509.07 0 10539.90 10539.90 0 10570.73 10570.73 6 15 10601.55 10601.55 0. O0 0.00 O. O0 0.00 3.21 N 30.50 E 3.21 N 1.89 E 7.80 N 34).50 E 7.80 N 4.5'2 E · 10.04 N 41.50 E 10.04 N 6.22 E 13.80 N 3:3.50 E 13.80 N 9.38 E 16.17 N 27.50 E 16.17 N 10.92 E 19.0:3 N 24.50 E 19.08 N 12.34 E 22.13 N 14.00 E 22.13 N 13.40 E 2~' 37 N 10.00 E 25.37 N 14.0~ E so.fl~ H ~s ~ So.fl~ 4,ql E O. O0 0 0 0 3.7;3 N 30 30 0 E 9.05 N 30 30 0 E 11.81 N 31 47 19 E 16.~9 N 34 11 53 E lC/.51 N 34 I 30 E 22.72 N 32 53 3 E 25.8:3 N ;31 11 42 E 29.02 N 29 2 52 E O. 000 5.278 4.327 5.019 0.525 0.445 0.106 0.370 0.821 .m to be inserted in each "Act "well folder to d~eck for timely compliance with our z~ulations. '' ~perator, Well Name and Number Reports and Materials to be received by: _ /'~ "3/--_~c~, Date Require .d Date Received Remarks -. Cc~ple~on Report Yes / ~, _,~.~_.~3_ 6/~,'~ ~.. . , o r e . .: :.,. '-.~; ............. Inclina~on Su~ey Drill St~ Test Re~=s R~ · ' ' UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use Form 9-331-C for such proposals.) 1. oil gas we, r"l well other 2, NAME OF OPERATOR CHEVRON U.S.A. INC.. 3. ADDRESS OF OPERATOR P. '0. Box 7-839, Anchorage, AK 995]0 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) AT SURFACE:2070' S & 305' E from the N.W. AT TOP PROD. INTERVAL: Corner, Sec. 3, T7N, RDW, AT TOTAL DEPTH: Seward Meridian 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA REQUEST FOR APPROVAL TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF r-1 FRACTURE TREAT I"-I [] SHOOT OR ACIDIZE [] r'-] REPAIR WELL [] PULL OR ALTER CASING I--] r-] MULTIPLE COMPLETE [] [] CHANGE ZONES n"] ABANDON* [] Form Approved. . Budget Bureau No, 42-R1424 5. LEASE - : - . ' ' A-028997 --: -; '~ - 6. IF INDIAN, ALLOTI'EE OR TRIBE NAME 7. UNIT AGREEMENT NAME Soldotna Creek ' * ~* 'T 8. FARM OR LEASE NAME '~ ~' (-;']~"~/- .., ,. -. .~ -" 1982 9. WELL NO .... -r "~ "' 2:'~ SCU-12-3 .: ~-'. ~ - · . .; ..-, . ., 10, FIELD OR WILDCAT NAME Swanson River · ANCHORAGE, 11. SEC., T., R., M.,*OR BLK. AND SURVEY OR AREA T7Ni: R'9~ '" "::'"':- Sec. 3, " ..... 12.KenaiCOUNTY OR PARISH. Z3.AlaskaSTATE,' 14. APl NO. :- .- ¥ .~-" 15. ELEVATIONS (SHOW DF, KDB, AND WD) K.B~ ]64' ..... _..-: ~c~vs9 . -? · DEPUTY MINE~AL$ MANA~ ONSHORE F/ELD ~ T ' '~r zone (NOTE: Repo~ results of change_on Form ~330.) .. ,.- ~ ~ . - . MINERALS tv~N'AGEMENT'SERvtc'~ - .:: *'_ (other) 411 W.'4(H..~VE.' SUITE 2A 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pea~nent details, and g~ve ~nent dates, including estimated date of sta~ing.any proposed work. If well is directionally drilled, give subsu~ace lo~tions and measured and true ve~ical depths for all markers and zones pe~inent to this work.)* ; ~ ~ ~ ~.~'F 7 t,~ell SCU 12-3, Swanson River ·Field was abandoned as followS:. ,. _ 1. Milled window in 7" casing from 10,265' - 10,307'. .- .-,:. :.~. 2. Laid an 84 sx K.O.P. at 10,324'. DrJ11ed out CMT 10,1~0' · .::. DATE off with Dyne Drill for redrill at 10,268' See Sundry Notice dated 6/8/82 Subsurface Safety Valve: Menu. and Type 18. I hereby~_ rt_i..~th~ingj~s~true and correct SIGNED :/\° (~/~,. / ..... w.~.~ TITLE Ar~a FnginePr CONO,T,ONS . - 1.0,268' .... ., .I '7 . ,*..) · .. -, ,-j- . .; o..-. ., - ., · ; .-: :, :; .---- - ._ : - : .i '.' :_ .'. _ ..: - - _- L.::, ' ...... , 2.~-~. ; T. .-.. · . . ', .~ . .,, .... ;. ..- ~ ,.,) -,~ : .-, if .;2. ~ -'"' · - Set @ .... - , I Kicked Ft. ., DEC2 7 1982 - 'See Instructions on Reverse Side - ' ;~ STATE OF ALASKA ,: 0~ ALASKA ( . AND GAS CONSERVATION CO(' ~IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [X 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 7-839, Anchorage, AK 4. Location of Well at surface Workover operation [] 99510 2070' S & 305' E from the N.W. Cor., Sec. 3, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 164' K.B. '1 A-028997 7. Permit No. ~ ¢ !-oo,t~ 8. AP, Numberl~rb~/t --D/ so- 133-~ 9. U.it or Lease Na~ Soldotna Creek ~t 10. Well No. SCU12-][3 ~t 1 1. Field an~rl~ool Swanson River-Hemlock For the Month of November .19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Cormmnced rigging up 11/9/82. N.U. Bope. Built and conditioned mud .volume_. Tagged hard cmt. at 10,406'. Tested csg. to 3000 psi-o.k. Milled window in 7" csg. from 10,265'- 10,307'. Laid an 84 sx. K.O.P. at 10,324'. Drilling out cmt. 10,150'-10,268'. DYNA drilled 6" hole from 10,,268'-10,850'. Ran DIL-SPTSONIC,. FDL-CNL-GR 10,850'-10,265'. Ran 20 JTS 5" 18~f N-80 BIIIT. & 8 RD liner from 10,848 -10,037' and' c~ted with 88 sx. class "G". Drilled out cmt. to 10,806'. Ran CCL-CBL-.CNL-CC logs 10,806'-10,000'. Displaced hole fluid with lease crude. Ran 3 1/2" tubing to 10,345' X-Mas tree. -tested to 5,000 p.s.i. Released rig 11/29/821 .N.D. Bope. N.U. 14. Coring resume and brief description /o 7,z'~ -/o 73'0 15. Logs run and depth where run See above. 1 6. DST data, perforating data, shows of H2S, miscellaneous data DEC ~ 1982 Alaska 0il & Gas Cons. Commission Anchorage S,GNE~~' ~;~..¢.~.--7.~/z..., T'~/LE Area Operations Supt DATE /,~ / , --- - .,- ./ w ,~ ~ " · ' - ? . NOTE--Report on this form is req,~d for each calendar month, regardless of the Status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ....' CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPERATOR WELL NO, ~IELD COUNTY Chevron, U. S. A. 12-A-3 STATE DAT~ December 5, lq82. LAB NO. 1411-1 LOCATION FORMATION INTERVAT- , .... 8AMPLE FRO¥ REMARES & CONCLU$IOIqS: cat~m __m~,/..[ m,qn ~ m~n mq/z 8odhnn - 3495 1 52.03 8u]bt, .... 1 5 . 0.31 Po*aodmn ..... 40 1 .02 Cbkx4ao ...... 5300 149.46 Cakhnn ...... 330 16.47 C~bemte ..... 0 0 Mqnmhnn 35 .2.88 ,, Sicarb0mte ..... 1380 22.63 l,,m ....... - - - HFd,oztd, ..... 0 0 To~d Camxu .... .172.40 .. ro, d ~ ,eM,. ,,~1 ..... 9895 ,, NsC1 oquivamm~ m4/1 95~9 O~ pH ...... 7.1 172.40_ Specific resisunc- ~ 6~*Y.: O~ .... 0.68 ohm,=muru 0.72 obm.~ N, WATER ANALYSIS PATTERN Scab ME(~ per Unit CI 50 Na HCOa 5 Ca SO, 5 Mg CO. 5 Fe Sample 8bo~e described , III llllll ] llllll iAi]Ill! i I/lIlllllllIllll ' ' t I lllllllIlIIIilIii[IlllIIllllll [lllllIi [iltiil! i illlilllllllllllr:[llIIllllllIl lt{|lill ~ | ||l|ll||||||~ll [lll||l:|:|:| ; ~l, ~ ]~I~III~IIILllI I,,llllltlt~ L.&~l .... ,,,~ r ........................... [1111111, iii|1:1[:[' }.! i,~||::::::::::::l!,,,,,,, ............. ;]llllll:~ jr ' llllllllIl]lllll IIII?I11 i:i I l~lll:llll~|l||| ! ~,,,,,,,,,,, , lIlllllilii : [flilill [,: I ] lIilIlllllilAlll~,illlllllllt]l ] tlllilll, t IllIIIll/llIllll tlllZlI Ill Lllllll] r: []llllllllllllllll[,[llll[llllill [I111111rr][ .lll~lllllililIllllr, llllllllilll [1111111, [ :III3IIIII!1 Iso'r~: Ifs/l=lfEisru~ par Bear Mq/l= Mb ~ per am Cl HCO, COo T?,..'..:;S:-:ITTAL AND ACK?;O:;LEDGE:.',E:;T OF RECEIPT OF MATERIAL - (AL,~KA) FD - Folded R - Rolled S ':" Sepia F - Film X'- Xerox B - Blueline ~IE FOLLOUING IS A LIST OF MATERIAL ENCLOSED HER£ZN. PLEASE CHECK AND ADVISE I~D~nlATELY. RECEIVED BY December 15, 1980 Mr. R. W. Magee Area Engineer Chevron U.S.A., Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re: Soldotna Creek SCU 12-3A Chevron U.S.A., Inc. Permit No. 80-104 Sur. Loc.: 2070'S, 305'E of NE cr Sec 3, T7N, R9W, SBM. Bottomhole Loc.: 71'N, 76'W of the surface location. Dear Mr. Magee: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. ~. W. Magee Soldotna Creek SCU 12-3A -2- December 15, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, .the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded.. We' would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abando~nment, please give this office adequate advance notification so that we may have a witness l~resent. Very truly yours~ Ho~ e H. Hamilton Chairman of BY O~2~ O? ~'~..{~ O©~;~:~$~O~ Alaska .Oil & Gas Conservation Commission Enclosure cc~ Department of Fish & Game, ~abitat SeCtion w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o eno1. ,I ~'h~evron chevron U.S.~' Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 l--l?.:..-x:. ~ .... October 16 1980 -2 O~.OL ~--" ~ STAT TEC S~DETRACK~NG 0F F~VE (5) SCU NELLS ~ STATT~C SWANSON RIVER FIELD - ALASKA Mr. Harry W. Kugler Commi ssi oner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Kugler' Please find attached Form 10-403 for abandonment of SCU wells 21-4, 12-3, 42-5, 44-8, and 41-9. Form 10-401 is also submitted for the sidetracking and recompletion of SCU wells 21A-4, 12A=3, 42A-5, 44A-8, and'41A-9. Separate application for abandonment and recom- pletion was requested by your office. Mr. B. E. Wondzell has advised us that resubmission of well programs and technical information as included in our original application will not be necessary. Very truly yours, Area Engineer 'MJA:sj At%achment s ' ~ECEIVED DEC 1 2 1980 Alaska Oil & Gas Cons. Commission Anchorage Alaska 0il & Gas Cons. Commission Anchorage 100 Years Helping to Create the Future Form 10.-401 SUBMIT IN TR aTE R[¥. 1-1-?1 (Other instructiona on revere ~de) API ~50-133-10099-01 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN 6. LEASE DESIGNATION AND SER1AL NO. la. TYPE OF WORK A-028997 DRILL [-~ DEEPEN [~] 7. IFINDIAN, ALLOTrEE OR TRIBE NAME b. TYPE OF WELL OIL [~ GAS SINGLE MULTIPLE I~! WELL WELL O OTHER ZONE [--] ZONE I I 8. UNIT FARM OR LEASE NAME 2. NAMEOF OPERATOR Soldotna Creek (2.hovrnn 11..q.A.: Inn. 9. WELLNO. 3. ~DDRESS OFOPERATOR SCU 12-3 P.O. Boc 7-839, Anchorage, Alaska lo. FIELD AND POOL, ORWILDCAT 4. LOCATIONOFWELL 2070' South and 305' East from the Northwest corner Swanson River At surface of Sec. 3, T7N, R9W, SB&M ll. SEC.,T.,R.,M.,(BOTTOM At proposed prod. zone 71' North and 76' West of the surface location ~ HOLE OBJECTIVE) Sec. 3, T7N, ROW,SB&M 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* .. 12. Approximately 16.5 miles from Kenai 14. BOND INFORMATION: T~ENationwides~etyand/orNo.. SL 6205862 . ~ . ~. Amouut$150,000 , ~ 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 3020' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1320~ 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 164~ KB 116 No. OF ACRES IN LEASE 1120 PROPOSED DEPTH 10830' PROPOSED CASING AND CEMENTING PROGRAM 23. 17.NO ACRES ASSIGNED ' TO THIS WELL · /,0 ~' 20. ROTARy OR CABLE TOOLS Rotary' 22, APPROX. DATE WORK WILL START ,, lO/8O ; SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity~ ~o[ cement. . ..: . ...... · l,q in ox~..~rin,¢,, well, :',cU 12-3 We 'propose to sidetrack SCU 12-3 to within 50' of the existing location per the attached program. RECEIVED IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. SAMPLES AND CORE CHIPS REQUIRED [] YES '~NO DIRECTIONAL SURVEY REQUIRED, gYES [] NO MUD LOG [] YES eNO ' Area Engineer DATE ~ "~ ~O TITLE CONDITIONS OF APPROX?AL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE ,;0'-/33 - I o o 7 o/ PERMIT NO. g O ~ / 0 ~ APPROVAL DATE APPOVED BY ~~~ TITLE C~&i~ - // ' *See Instruction On Reverse Side BY ORDF, i~ OF THE COMMISSION Dec~mber 15, 1980 DATE 12/15/80 PROPOSAL FOR WELL OPEP, JITIO,"IS PRO 316-1 Field' Swanson River. Property and Well No.' Soldotna Creek Unit 12-3. - Surface Location' 2~070 feet South and .305 feet East from the Northwest corner .of Section 3, 'T7N, R9W, SB & M. Bottom Hole Location: 71 feet North and 76 feet West of the surface location. Total Depth' 10,851 feet. Plugs' 10,851' - 10,802'. Casing: 22" Conductor cemented at 28 feet. 13-3/8" cemented at 3,000 feet.. 7" 23~~ · , ~-,26#, '&]29# cemented at 10,849 feet. Note' 12 feet pup joint 10,302' - 10,314' Perforations: 5 - ~" jet holes at 10,390 feet (sqUeezed). 4 - ~" jet holes per footat the following intervals: 10,397'-10,414'; 10,454'-10,466'; 10,474'-10,518'' 10,530'-10,536'; 10,544'-10;613-'; 10-624'-10;637'; and 10-656'-10'680' Tubing' See attached tubing detail. Junk: 1-5/8" bailer st6ps in tubing at 10,566 feet.. Tubing is plugged with asphatines. 4/80 could not pump in'to.' tubing With 4000 psi. i Datum' 20 feet above ground level at original KB elevation of 164 feet~ : ; . . · ., Blowout Prevention Considerations' For killing and redrilling . 1. Potential Problems' A. Gas may be encountered after Packers are released~while cleaning out the 7" prior to abandonment and while redrilling. Shut in tubing pressure is approximately 3000 psi. Care must be exercised not to swab the well while tripping or pulling production equipment. B. Extreme caution must be exercised while redrilling due to the possibility of high pressure water entries.~' The first 100 feet of int&rval'to be ~edrill&~ is normally drilled ~ith 98 pcf mud. The programmed mud weight of 77-79_pcf will overbalance a 5350 psi ,pressure by 175-320 psi. C. A mud weight of 77-79 pcf should minimize potential for iost circu- lation while drilling the Hemlock. However, LCM should be kept on hand at all times. , · D. Any kicks should be handled by normal procedures. All personnel should be made aware of these methods and care must be exercised at all 'times. The hole is to be kept full at all times. 2. Maximum anticipated fOrmation pressure' A. 5350 psi in the "G'~ at ~indow depth 10,258 feet. B. 4600 psi in the Hemlock. Top Hemlock 10,390 feet. o , Maximum possible surface pressure' 3500 psi. Blowout prevention equipment' Class III - 5000 psi for all work. o o . . . o . . o 10. 11. 12. 13. 15. ]_6. PROGRAM Pull CEV at 10 299 feet and 10~477 feet Move in drilling rig and kill well with 66-68~-~cf mud. 4' ,, Install safety plug in donut, remove xmas tree Insta'll and test Class III, 5000 psi BOPE, including 5000 psi and kill lines. Division of Oil & Gas Conservation and U.S.G.S. to witness test. Remove plug. Release packers. Uppermost packer is a br'own HS-'16=i at 10~3~l~feet. Remaining hydraulic packer is also, an HS-16-1 at 10,521 feet,with a "cc,' Safety joint at lO,~90'.feeff2 ~ - ........ Pull tubing and production equipment. Clean out 7" casing to top of Baker model "D" packer at 10,642 feet (E-log depth). . . ~ Run packer mill and recover Model "D" packer. Make note of E-log - drill pipe depth correlation. Clean out to 10~802 feet. COndition mud for logging. Take % gallon sample before pulling out. Run Dresser-Atlas D~al Spaced Compensated Neutron - GR log.from cleanout depth to 10,260 feet. Use 0-60% porosity scale and 0-100 GR scale. Run drill pipe to 10,802 feet, equalize necessary, of Class "G" cement. 550 lineal feet, in stages if Pull out of cement~ close pipe rams and down-squeeze to leave top of cement at + 10,350 feet. Run bit and tag top of plug. If below 10,350 feet, recement. Division of Oil & Gas Conservation and U.S°G.S. to witness the location and hardness of plu'g. Pressure test 7" casing to 3000 psi for ].5 minutes. Condition mud to 77-79 Pcf. Run a 7" section mill and cut a minimum 40' window in the 7" 29~ Pll0 casing from 10,258'-10,298' Casing collars are located at 10,219 feet, 1~,260 feet, 10,302 feet and 10,314 feet, .E-log depths. Continually monitor mud system for possible high pressure flu{d entry during milling and redrilling operations. This interval is norma]].y drilled with 98 pcf mud. BE PREPARED TO SllUT WELL IN AND RAISE ,~IUD WEICltTS API>ROPRIATELY. 17. Plug window and 7" casing stub with 'densificd Class "G" cement (126 pcf) pre-mixed with 3/4% CFR-2. Pull out of ce'ment and Braden- head squeeze + 10 cu. ft. Top of plug to be a-t or above + 10,235 feet. 18. Clean out cement plug to + 10,264 feet. 19. Sidetrack original ~ole; precise directional control is not ~-equired. Run single shots as necessary to ensure adequate deviation from original hole. Preferred direction of move' North. Deviation from present loCation to be 25-50 feet. 20. Drill 6" hole to + 10,830 feet (depth equivalent to 10,830 feet in SCU 12-3 original hole). 21. Condition hole for logs. Obtain ½ g.allon sample of drilling fluid prior ~ to pulling out of hole. 22. Run Dresser Atlas Dual Induction Focused log with SP and GR. . A. Run linear scale for 2" DIFL and logorithmic for 5" D!FL ., B. Use + 10 MV SP scale and 0-50 ohm-meters for the linear DIFL. C. Use 0-100 GR scale. 23. Condition hole to run 5" liner. 24. Run and cement approximately 750 feet of 5", l$/J N-SO Buttress casing with special clearance Pi].0 couplings at + 10~830 feet with sufficient densifiad Class "G" cement prcmixed with 3/4% CFR-2 to obtain returns above top of .liner. Equip liner with 5" x 7" Burns' liner ban%er 'grooved for cementing. Use float collar and float, shoe. Float collar to be one joint above shoe. · 25. Clean out cement to float collar. · 26. Run I)resser At:].as V}~L-CIIL-Noutron-CCL log and Dual. Detector Lifeti~'::c - CR log from effective depth to above top of liner l~anger: 27. Pressure test 7" casing, 5" x 7" liner lap and 5" liner to 3000 psi for 15 minutes. Jet perforate and 1:o l~e J.s,s~)~.d aft:er 29. Re:::ove ]~(')PE and 'i~l,';t:n!]. :,:~:las (:l'ee. l'res,'~t~):e test' ti:ce to 5000 ps{_. Displace c~)~':~:)].cLJ.,.:)n f!t,{d do~.'n tile anjou]us and t)p t:he t:ul)~.n.q witl~ lease crude. · .,et,ease DRILLING FLUID PROGRA>! · Sidetrack of SCU 12-3 - Swanson River'-Field Basic Drilling Fluid System Medium treated lignosulfonate mud. Optimum Drilling Fluid Properties .. 'tn 7" While Redrilling Weight.- pcf Viscosity-sec/qt.s API Fluid loss cc, API Plastic viscosity cps 2 Yield point lb/100 ft. Gel strength lb/100 ft. Calcium ppm Solids content % vol. 66-68 77-100 43247 43-47 4-7 4-7 18-24 18-24 8-12 8-12 0-5 10 Max. 9-10 9-10 50 Max 50 Max 7-~ 14-25 . Remarks 1. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate supply of barite and LCM on location. o During milling and redrilling continually monitor (on 24-hour basis) mud system for evidence of high pressure water entry. BE PREPARED TO SHUT WELL IN AND RAISE WEIGHT AS REQUIRED. 274 J~. " ~" I J. ~U~ ~/~G CHECK LIST FOR NEW ?~LL PERMITS Comfy d,~_~,~-,-~- Item Date , Yes No (1) Fee ?--/:¥' ~ 1. Is the permit fee attached .............................................. ~' 2. Is roll to he locatod in a defined 1:~ool ............................. ~ ~i~_ ~ (2) ~cx~. ?' (4) Casg. ~ Lease & Well No..,. ~,c ~1~ / %- -~ 27- Remarks e %. Is a registered survey plat attached ................................ Is well located proper distance frcm property line .................. ~- Is roll located proper distance frc~n other rolls ..................... 6. Is sufficient undedicated acreage available in this pool ............ ~ 7. Is well to he deviated ............... , .............................. ~?~ ,,. 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... ,,~/~,~80~ 15. Will cement tie in surface and intermediate or pro~uction strings.. ~6. Will cement cover all known prcductive horizons ................. _. 8. Is operator the only affected party ................................. J~ 9. Can permit be approved before ten-day wait .......................... ~_~ ~, 10 Does operator have a bond in force ...... '. ............. ........../~ .... ' ~11. Is a conservation order needed ...................................... ; 17,. Will surface casing protect ,fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst. (5)B OPE ~ .,~ ~ 19. Does BOPE have sufficient pressure rating - Test to __~-~o~ psig .. " Approval Recommended: Additional Requirements ~ ~ Geology: ~gin~_~ing: rev: 03/05/80 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 APPEN, DIXi .. No special'effort has been made to chronologically organize this category of information. ~' ~ ,*** MSP JOB BESEAL3@ HAVING EXTENDED TASK NAME H3/84 306/10:08:03 HAS 5 DATA STRINGS LISTED BELOW *(IWN~) * * * NO. * * * * * INCR * *RECS* * *********************************************************************************************************************************** 1 NPHIPSll 9995.50 10805.50 0.50 3.27148 78.7109 3 LISEDT 10084306 1 NRATPSll ' 9995.50 10805.50 0.50 1.12793 5.71875 3 LISEDT 10084306 ~:.:.:~:.:~:<.>:.:~:~:.:.~.:~;<.;~>:.:.:.:.;.:~>...;~:.>:<...<.;.:.:~:.;<.>:.~`:.:.>:<.:.:.;.:.;~:~:~;.;.;.~.:.:.~:<.:.>~<~;.:.:.:~;<<>>;.>>:.>;<~:.:~.;<.;~:.:.:<.>~>~.~.:<~:~>;<<~<.:<~:~:<~:~:;:~`;.~<~;.>> J:->>:;:::<<:?:.>;,;<<.:. >:<<<,>;.;c->>>:.;<<<.;<<<<<,:<<:> > :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: > >>>:::<<:>;<. ::::::::::::::::::::::::: > >:h:<c.. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :;j ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::: ~a~i~::~::~a~ ::::::::::::::::::::::::::::: '~i~ i~:'~:; i~:'i :~a ~?:~ ~i~i::~::~;'::ii~:~::~:'::~::~i ::~:':::: ~i~::~~- :~ :-~ ~:':':' ~i?':::' ::~;'~:<~::~i~:: ~ ~:';:~;;:~ :;~ i~;~~ ~:' ;;;~ ~ ~ ~ ~; ::~:.:'::':'~ :': ~ ~?:~:: ~ :'~;~:::~?~:? ~; :'~ ~:~ ~ :'~:;::: ~ ~::: ~;~?-~:-~?::<'~ ~::~ ~ ::::::::::::::::::::: ~:'~:: ?:~::~;:<~?::':':.~?:~::?::-~:'~ ::::::::::::::::::::::: :'~::~:: :::':~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: TOTAG NUMBER OF H~ADER AND DATA RECORDS IN THE DATA FI~E = 15 ~ AVAI~ABLg RECORDS = 3?66 ........................................................ ~:i.~ ............ PbO~:::.:N:UMBgR.:.:.AT.:.:.~B~!NA~!ON.:.:.~,:.:,:Ta:I:&.::.~.OS.:.:.!S ................. 0 ............ ~.~:.~ ............................................................ ~ ....................................................................... . ................................................................ · ........................................................................................................................................................ ................................. ~hh:~:::':~:~:::'::~:~::~::X~'i:~:::~::~X~¥::~:i::~: ...................... :6: ................................................................................................................ ====================== ............. ~:~:~ ~:~?? ~ ~: ?:: ......... ~:~ ~:::~:~:~ ~:~::~ ~:~: ~:~:~:~: ~:~:~: ~::::: :: ~:~:~: ~:~::~' :: :~:~ ~ :~ :: ::~ ~'~:: ~:? '::~ ~:~?~: '::~ ~:~:~:~ ~:~:~:':?'~:~: :~:~:~:' ~ ~:~:~:: ~:~:~: ~?~:~:~:~:~:~:~: ~:~:~:~: ~:~: ~:~:~:~: ~:~:~: ~:~ ~:::~ ~:~:~? ~:~:~: :~:~: ~:~:~: ~:~:~:~:~:~:~:~:~:~:~:%~:~ **MSPOFF** COMPLETION CODES : iiil!i!iiiiiiiiiiil!iiiiiiiiiiiiiiii!ii!i!iiiiiiiiilliiiii!ii!iiiiiiii iiii!iiii!fliiiiiiiiiiii i!iiiii!i!iiii fil!fliiiiiilil!ili!iiiii!!il!i iii ii iiii iiil i!?ii?!!iiiii!ii!i!iiiiiliiii iiiiiiiiiiil iliii iiiiii! iliii ?iiiiiiii!!ii ililliii iiiiiiii iii!ii i; i?ii::iii!iiiiilfii !i;ili;iiiiil ii!ii f! fii iiii!i!!ii!iii; !!!i;iiii!iii!iiiil !i iii ?ii!iii! iii!ii f!i!i:: ;f i!ili ii;ii ii if! ii !!ii! ':;i i!ii;;;!i ii!iiiil;ifili iii ?:iiiii; iii!i !!iil!;i;!iiil iiiiiiiii;i !!i i! ii iii! ii ii!i i!ii!iii~ ill ~!~i~i~i~ i~ iii~ i~i~i !~ ? !~ JOB BESEAL3@ WITH CHRGE NO. S7,00435 STEP NO. 4 ON SYSTEM C033 AT 10:8:51 USING 344K/5656K BYTES MEMORY PROCEDURE MSPJOB COMPLETED AT 10.08.54 ON 11/01/84 26 *** START OF MSP PROGRAM MSPOFF FROM LIBRARY EPD.VSMSP.TESTLI PROGRAM STATUS INDEX= 13184174 MSP TASK ID C8F3840306100803 *** CONTENTS 567890'i234567890i23¢5678g01234567890t 234567890 CARD 1 o &MSPOFF SLIST=2 ~ &END ***** PROGRAM = MSPOFF NUMBER = S99 SETSSI = 13184174 25 *~* MSP JOB WLSTST HAVING EXTENDED TASK NAME H8/84.307/12:22:35 HAS 0 DATA STRINGS LISTED BELOW ***** NO DATA STRINGS STORED FOR THIS MSP TASK *** PRO(}RAM SL~LIX COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS2@ WITH CHRGE NO. S7,00666 STEP NO. 3 oN SYSTEM HDCH AT 12:24:17 USING 22¢K/6776K BYTES MEMORY 29 *** FT42F001 CLOSED *** 28 LENGTH: 6¢ BYTES FILE NAblE: AoA~.~r a MAXIMUM PHYSICAL RECORD LENGTH: BYTES END OF FILE MARKER NO. 2 TAPE TRAILER LENGTH: 132 BYTES TAPE NAHE: SERVICE NAME: SERVIC TAPE CONTINUATION NUMBER: NEXT TAPE NAME: COMHENTS: LIBRARY TAPE REEL TRAILER LENGTH: 132 BYTES REEL NAME: SERVICE NAME: SERVIC REEL CONTINUATION NUMBER: NEXT REEL NAME: COf~4ENTS: LIBRARY TAPE END OF FILE MARKER NO. END OF FILE MARKER NO. 01 01 DATE: DATE: 82/12/ 3 82/12/ 3 27 DEPTH 10805.500 10800.000 10750.000 10700.000 10650.000 10600.000 10550.000 10500.000 10450.000 10400.000 10350.000 10300.000 10250.000 10200.000 10150.000 10100.000 10050.000 10000.000 9995.500 MNEMONIC NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPHI GR NPH! GR NPHI GR NPHI GR NPHI GR NPHI GR NPH! GR NPHI GR VALUE 19.824 83.313 19.824 83.313 17.432 36.531 14.063 50.094 69.629 48.281 19.824 49.906 24.316 71.000 7.617 30.281 23.242 77.625 22.070 70.375 21.777 35.125 31.836 42.969 63.135 30.703 41.064 31.781 45.508 22.984 45.947 25.063 42.578 23.750 33.496 24.563 23.340 20.703 MNEMONIC NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT NRAT VALUE 2.471 2.471 2.313 2.072 5.223 2.473 2.736 1.550 2.676 2.613 2.598 3.150 4.863 3.656 3.898 3.924 3.738 3.240 2.684 MNEMONIC NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL NCNL VALUE 2214.000 2214.000 2976.000 2622.000 1397.000 2654.000 2228.000 3994.000 2216.000 2154.000 2039.000 1880.000 1296.000 1189.000 1324.000 1149.000 1230.000 1836.000 1635.000 MNEMONIC FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL FCNL VALUE 840.000 840.000 1253.000 1200.000 220.625 982.000 761.000 2478.000 781.000 804.000 709.500 593.500 241.250 317.000 315.750 261.000 307.500 517.000 621.500 FILE TRAILER 26 DATUM SPECIFICATION BLOCKS: ENTRY IC TOOL SVORD# UNITS API API API API FILE# SIZE EXP PROC'~AM REP DEPT SHIFT 1 DEPT FT 00 00 00 00 0000 0004 0000 00 ~1 44 00 00000000 2 NPHI PS1 PU 00 44 02 00 0000 0004 0000 00 01 44 00 00000000 3 NRAT PSI 00 2A 01 00 0000 0004 0000 00 01 44 00 00000000 4 NCNL PS1 00 22 5C 00 0000 0004 0000 00 01 44 00 00000000 5 FCNL PS1 00 22 5D 00 0000 0004 0000 00 01 44 00 00000000 6 GR PS1 GAPI 00 IF 20 00 0000 0004 0000 00 01 44 00 00000000 WLS TRACE DATA STRINGS FROM FILE 1 DEPTH UNITS ARE: FT DATA STRING >NPHI PS1 < IN UNITS OF >PU < HAS AWLS NAME OF >NPHIPSll< DATA STRING >NRAT PS1 < IN UNITS OF > < HAS AWLS NAME OF >NRATPSll< DATA STRING >NCNL PS1 < IN UNITS OF > < HAS AWLS NAME OF >NCNLPSll< DATA STRING >FCNL PSi < IN UNITS OF > < HAS AWLS NAME OF >FCNLPSll< DATA STRING >GR PSI < IN UNITS OF >GAPI< HAS AWLS NAME OF >GRPSll < 25 THE TRACE DATA STRINGS WILL HAVE THEIR NAMES DERIVED FROM SCHLUMBERGER FIELD NAMES. GENERATION NUMBER =-2048 START SEQUENCE = 1 *** FT42F001 OPENED *** REEL HEADER LENGTH: 132 BYTES REEL NAME: SERVICE NAME: SERVIC REEL CONTINUATION NUMBER: PREVIOUS REEL NAME: COMMENTS: LIBRARY TAPE TAPE HEADER LENGTH: 132 BYTES TAPE NAME: SERVICE NAME: SERVIC TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: LIBRARY TAPE END OF FILE MARKER NO. 01 01 DATE: 82/12/ 3 DATE: 82/12/ 3 1 FILE HEADER LENGTH: 64 BYTES FILE NAME: SERVIC.001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SITE INFORMATION RECORD *** COMPANY: WELL: FIELD: CHEVRON U.S.A. INC. SOLDOTNA CREEK UNIT 12A-3 SWANSON RIVER DATA FORMAT SPECIFICATION LENGTH: 268 BYTES ENTRY BLOCKS TYPE SIZE REP CODE 66 73 65 ENTRY 1 60 .liN 24 *** START OF MSP PROGRAM SLMLIS FROM LIBRARY PSD.XLIB PROGRAM STATUS INDEX= 12084240 MSP TASK ID C8F8840307122235 *** THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 3) , PROJECT NAME = WLSTST CARD 1 CARD 2 CARD 3 CONTENTS ]_>~ · 1 2 3 4 5 6 7 8 · ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ · &SLMLIX &END · &SLMLIS TAPE=2,&END DICTN,NREC FILE · &PARM SCAN=i,&END GEN=1066815,START=-l,PRINT=l, XSAMP,TOP OR BOT MINIT COMPLETED AFTER READING 3 CARD(S) ***** PROGRAM = SLMLIS NUMBER = A06 SETSSI = 12084240 *** MSP SYSTEM PRINT FLAG SET EQUAL TO -1 AT THIS POINT IN PROGRAM **** DDNAME=FT49F001 NUMTRK= 38 TRKSIZ=13030 DEVTYP= 4 UNIADR= 955 CURVAL=MS4629 ITYPE= 2 23 *** START OF MSP PROGRAM MSPON FROM LIBRARY EPD.SYSTEM PROGRAM STATUS INDEX= 17183053 MSP TASK ID 0000000000000000 *** THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM (MSP STEP NUMBER 2) , PROJECT NAME = WLSTST CARD 1 CONTENTS · · 1 2 3 4 5 6 7 8 ~23456789~~234567890~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ · &MSPON &END MINIT COMPLETED AFTER READING 1 CARD(S) ***** PROGRAM = MSPON NUMBER = S33 SETSSI = 17183053 PINT INTERFACE PLOTTING HAS BEEN SELECTED FOR HOST PLOTTER = ACROSS = 23.0, ALONG =********, PAPER NUMBER = 500 , PEN1 = 4BLK, PEN2 = 3RED, PEN3 = 2BLU, PEN4 = 1GRN, PINT/VAMP PARAMETERS ARE: WIDTH = 23.0 PROD =P CORD =Y VERSATEC *** DATA FILE ALLOCATION FOR THIS JOB (NREC) IS 4337 MSP RECORDS. *** ***** MSP JOB WLSTST STARTED HAVING EXTENDED TASK NAME H8/84.307/12:22:35 CURRENT NUMBER OF ACTIVE TASKS IS 1 *** PROGRAM MSPON COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS2@ WITH CHRGE NO. S7,00666 STEP NO. 2 ON SYSTEM HDCH AT 12:22:39 USING 224K/6776K BYTES MEMORY *** 22 STEP PROCESS ELAPSED CPU SETSS I L I BRARY NUMBER NAf4E TItlE(SEC) TIME(SEC) TOTALS 9¢.6 2.18 *** MSP JOB BESEAL4@ HAVING EXTENDED TASK NAME H8/84.306/09:58:32 HAS 16 DATA STRINGS LISTED BELOW i!!i!~i?~i?~!?!~ii!!ii!~ii~!iiiii!i!i!~ii!ii!i!i!~i~i!!!<!:iDiaTE!::ii~!! ~pE!~i~!!! ~p~i~ ~!! !~!!!i~i:t D-? !i~ UN~ T, U~ t~ ~ *'i: iT@P ~ i , BOTTOM. · SAMPnE* MI N I MUM · i~:~ MAX I ~M * OF '~ · pR@GRAM, i DATE , · (IWNAME) * * * NO. * * * * * INCR * *RECS* * * *********************************************************************************************************************************** 1 SFLUDIL1 10251.00 10869.00 1 ILMDIL1 10251.00 10869.00 ........... ! GRj~HCi ...... : ~ ':' 10251.00 10869.00 i CALIBHCl 10251.00 1O869.00 1 SPBHCl 1O251.O0 10869.O0 i NP~IFDN~ 10251.OO 10869.O0 .................................... ~....,.~m~O.~DN~. 102~.00 1O869.00 ~::::~' :: ~ ~ ' ~ i0251~:00 10869.00 ::::::: ~?.??:~::?:?:~ ::?:~ :-?:~::~::::~~Ni:~ ::: ~:~ ~::::.~ ::::~ ~: : : ~ 0:25~ ~ 00: ~ 0869 ~ 0 o ~?:~?:~::::::::::::' ~::~:~:?::?:~::~ ~::~D~?:~ ?. ~?:~ :: ~:~ :: :: :: 1025t ~ 00 10869 ~ 00 1 GRFDN1 10251.00 10869.00 NUMBER OF TRACE DATA STRING HEADER AND DATA RECORDS IN THE DATA FILE = 48 0.50-999.250 2000.00 3 LISEDT 09584306 0.50-999.250 2000.00 3 LISEDT 09584306 0.50-999 250:'2000:,00 :iii:i: 3 L~SEDT !.09:584:306 0,50.999.250 9.08594 3:LiSEDT0958~306 0,50-999 250! 'i37;125 ~i3 LtSEDT : 0958~306 1 0,50-999 250 i i23,375 3 LiSEDT 09584306 0.50-999.250 137.125 3 LiSEDT 09584306 0.50-999.250 0.50-999.250 0.50-999.250 0.50-999.250 0,50~999.250 0,50;6556,00 0,50~688,00 ~ 0~50-999~250 0.50-999.250 8.46094 3 LISEDT 09584306 9.08594 3 LISEDT 09584306 71.5820 3 LISEDT 09584306 0.436523 3. LISEDT 09584.306 39,1563 131LISEDT !09584306 7388~25 3 iL:ISEDT ~! i 09584306 i6492~00 :::ii!! 3iLiSEDT: i!0958:4:306 ' 12.3398 3 LISEDT :0958:4:306 151.875 3 LISEDT 09584306 :i:!:i:!:~:i:~!:!%:iT~T~.5..:!:~NUMBER~:!:~F:!:i::H~ADE~:!:iANDi:!:DATAi:i:iREC~RDS: :~[Ni :THE: DATA:i:F:I LE= 48 , AVAILABLE RECORDS = 3733 ***** MSP JOB BESEAL4@ HAVING TASK NAME C8F8840306095832 HAS BEEN DELETED CURRENT NUMBER OF ACTIVE TASKS IS 0 ................... MSP. FF ........................ ..o~r~ET:~ON.: :CODES :! :.:: .... : : : JJ* PROGRAM MSPOFF COMPLETED WITH A CODE OF 0 **** *** JOB BESEAL4~ WITH CHRGE NO. S7,00435 STEP NO. 4 ON SYSTEM HDCH ::::::~:~::::::::::~R~D~RE::::.::::~SPJOB: ::: :CO~SETED: :~T :l:O;O0j~8 ON t:I/01/8~ AT 10: 0:9 USING 344K/5656K BYTES MEMORY *** : 27 *** FT42F001 CLOSED *** 29 LENGTH: 132 BYTES REEL NAME: SERVICE NAME: SERVIC REEL CONTINUATION NUMBER: NEXT REEL NAME: COMMENTS: LIBRARY TAPE END OF FILE MARKER NO. END OF FILE MARKER NO. 4 01 DATE: 82/12/ 1 28 DEPTH 10869.000 o 10850.000 10800.OO0 10750.000 10700.000 10650.000 10600.OO0 10550.000 10500.000 MNEMONIC SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP NCNL SFLU GR SP VALUE 8.352 114.062 -37.594 -999.250 8.336 114.062 -30.688 3780.000 18.453 108.250 -8.289 3008.000 14.906 59.219 -33.281 4308.500 8.656 72.875 -43.063 3784.000 37.719 68.250 -15.250 1835.000 14.641 77.688 -54.125 3886.000 8.078 109.000 -18.484 30'14.000 105.750 36.969 -22.359 MN EMON I C ILM DT NPHI FCNL I LM DT NPHI FCNL ILM DT NPHI FCNL DT NPHI FCNL I LM DT NPHI FCNL ILM DT NPHI FCNL DT NPHI FCNL ILM DT HI FCNL ILM DT NpHI VALUE 6.465 83.750 -999.250 -999.250 6.438 83.750 25.391 1600.000 10.727 71.188 27.295 1146.000 7.793 82.750 22.895 1876.625 9.164 76.375 23.096 1655.000 11.523 109.375 24.399 825.000 10.633 86.000 26.660 1598.000 7.754 77.750 27.783 1155.000 59.906 73.750 13.953 MNEMONIC ILD GR DRHO cALI' ILD GR DRHO cALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO VALUE 6.289 114.062 -999.250 -999.250 6.449 114.062 0.062 4.625 10.766 108.250 0.238 7.535 7.223 59.219 0.006 5.934 10.172 72.875 0.085 6.020 10.609 68.250 -0.005 6.912 10.602 77.688 0.037 5.754 8.703 109.000 0.276 6.363 88.938 36.969 0.026 MNEMONIC SP CALl RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB GR SP CALI RHOB VALUE -37.594 6.000 -999.250 -999.250 -30.688 6.711 2.363 82.563 -8.289 6.137 2.498 104.563 -33.281 6.027 2.268 57.824 -43.063 5.973 2.514 83.313 -15.250 6.012 1.611 106.328 -54.125 6.004 2.402 81.750 -18.484 6.OO8 2.502 120.312 -22.359 5.984 2.360 26 NCNL 5622.000 10450.000 SFLU 12.617 GR 123.125 SP -9.352 NCNL 2958.000 10400.000 SFLU 9.984 GR 109.813 SP 0.031 NCNL 3258.000 10350.000 SFLU 9.797 GR 48.375 SP -3.254 NCNL 2867.750 10300.000 SFLU 4.293 GR 64.188 SP 3.729 NCNL 2753.594 10251.000 SFLU -999.250 GR -999.250 SP -999.250 NCNL 1685.000 FILE TRAILER LENGTH: 64 BYTES FILE NAME: Ao~Z~ a MAXIMUM PHYSICAL RECORD LENGTH: NEXT FILE NAME: tttttttttt FCNL 352 ILM DT 7 NPHI 2 FCNL 116 ILM DT 7 NPHI 2 FCNL 125 ILM DT 7 NPHI 2 FCNL 106 ILM DT 8 NPHI 3 FCNL 90 ILM -99 DT -99 NPHI 4 FCNL 48 La ~6 BYTES 4.656 9.352 6.375 7.002 5.000 7.117 6.563 7.197 4.000 7.871 7.563 4.014 7.734 4.406 1.375 0.704 2.844 9.250 9.250 2.627 5.000 CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALI ILD GR DRHO CALl 5.776 9.750 123.125 0.246 6.340 7.207 109.813 0.041 7.438 7.895 48.375 0.129 9.875 4.438 64.188 -0.017 9.800 -999.250 -999.250 -0.525 6.277 GR SP CALI RHOB GR SP CALl RHOB GR SP CALl RHOB GR SP CALI RHOB GR SP CALI RHOB GR END OF FILE MARKER NO. 2 DATE: 01 82/12/ 1 TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: SERVICE NAME: SERVIC TAPE CONTINUATION NUMBER: NEXT TAPE NAME: COMMENTS: LIBRARY TAPE REEL TRAILER 47.751 -9.352 5.984 2.418 125.125 0.031 6.152 2.574 111.813 -3.254 6.727 2.356 48.344 3.729 6.926 1.608 69.148 -999.250 -999.250 2.166 49.656 27 *** START OF MSP PROGRAM SLMLIS FROM LIBRARY PSD.XLIB PROGRAM STATUS INDEX= 12084240 MSP TASK ID C8F8840307145128 *** THE ~OLLOWlNG CARDS HAVE BEEN INPUT TO THIS PROGRAM CONTENTS NAME = WLSTST 1 2 3 4 5 6 7 8 · ~234567890~23456789~~234567890~23456789~~234567890~234567890~23456789~~23456789~ CARD 1 CARD 2 CARD 3 · &SLMLIX &END , &SLMLIS TAPE=2,&END DICTN,NREC FILE · &PARM SCAN=I,&END GEN=1066815,START=-l,PRINT=l, MINIT COMPLETED AFTER READING 3 CARD(S) XSAMP,TOP OR BOT ***** PROGRAM = SLMLIS NUMBER = A06 SETSSI = 12084240 *** MSP SYSTEM PRINT FLAG SET EQUAL TO -1 AT THIS POINT IN PROGRAM **** DDNAME=FT49F001 NUMTRK= 57 TRKSIZ=13030 DEVTYP= 4 UNIADR= 97F CURVAL=MS¢629 ITYPE= 2 23 *** START OF MSP PROGRAM MSPON FROM LIBRARY EPD.SYST]~M THE FOLLOWING CARDS HAVE BEEN INPUT TO THIS PROGRAM PROGRAM STATUS INDEX= 17183053 MSP TASK ID 0000000000000000 *** (MSP STEP NUMBER 2) , PROJECT NAME = WLSTST CONTENTS · · 1 2 3 4 5 6 7 8 · ~23¢56789~23456789~23456789~23~56789~23456789~23456789~23456789~23456789~ CARD 1 . &MSPON &END MINIT COMPLETED AFTER READING 1 CARD(S) ***** PROGRAM = MSPON NUMBER = S33 SETSSI = 17183053 PINT INTERFACE PLOTTING HAS BEEN SELECTED FOR HOST PLOTTER = ACROSS = 23.0, ALONG =********, PAPER NUMBER = 500 , PEN1 = 4BLK, PEN2 = 3RED, PEN3 = 2BLU, PEN4 = 1GRN, PINT/VAMP PARAMETERS ARE: WIDTH = 23.0 PROD =P CORD =Y VERSATEC *** DATA FILE ALLOCATION FOR THIS JOB (NREC) IS 3781 MSP RECORDS. *** ***** MSP JOB WLSTST STARTED HAVING EXTENDED TASK NAME H8/84.307/14:51:28 CURRENT NUMBER OF ACTIVE TASKS IS 1 *** PROGRAM MSPON COMPLETED WITH A CODE OF 0 **** *** JOB BESEAS5@ WITH CHRGE NO. S7,00666 STEP NO. 2 ON SYSTEM HDCH AT 14:51:29 USING 224K/6776K BYTES MEMORY *** · 22 DATUM SPECIFICATION BLOCKS: 1 DEPT 2 SFLU DIL 3 ILM DIL 4 ILD DIL 5 SP DIL 6 GR DIL 7 DT BHC 8 GR BHC 9 CALI BHC 10 SP BHC 11 NPHI FDN 12 DRHO FDN ~ 13 RHOB FDN 14 NCNL FDN 15 FCNL FDN 16 CALI FDN 17 GR FDN ENTRY IC TOOL SVORD# UNITS API API API API FILE# SIZE EXP PROC SAM REP DEPT SHIFT FT 00 00 00 00 0000 0004 0000 00 01 44 00 00000000 OflMM 00 00 00 00 0000 0004 0000 00 0I 44 00 00000000 O~ 00 00 00 00 0000 0004 0000 00 O1 44 O0 00000000 O1/]~ 00 0C 2E 00 0000 0004 0000 00 01 44 00 00000000 MV 00 01 00 00 0000 0004 0000 00 01 44 00 00000000 GAPI 00 1F 20 00 0000 0004 0000 00 01 44 00 00000000 US/F 4C 34 20 00 0000 0004 0000 00 01 44 00 00000000 GAPI ¢C 1F 20 00 0000 0004 0000 00 01 44 00 00000000 IN 4C lC 03 00 0000 0004 0000 00 01 44 00 00000000 MV 4C 01 00 00 0000 0004 0000 00 01 44 00 00000000 PU 5C 44 02 00 .0000 0004 0000 00 01 44 00 00000000 G/C3 5C 2C 00 00 0000 0004 0000 00 01 44 00 00000000 G/C3 5C 23 01 00 0000 0004 0000 00 01 44 00 00000000 5C 22 5C 00 0000 0004 0000 00 01 44 00 00000000 5C 22 5D 00 0000 0004 0000 00 01 44 00 00000000 IN 5C 1C 03 00 0000 0004 0000 00 01 44 00 00000000 GAPI 5C 1F 20 00 0000 0004 0000 00 01 44 00 00000000 WLS TRACE DATA STRINGS FROM FILE I DEPTH UNITS ARE: FT DATA STRING >SFLU DIL < IN UNITS OF >O~< HAS AWLS NAME OF >SFLUDILI< DATA STRING >ILM DIL < IN UNITS OF >O~< HAS AWLS NAME OF >ILMDIL1 < DATA STRING >ILD DIL < IN UNITS OF >O~< HAS AWLS NAME OF >ILDDIL1 < DATA STRING >SP DIL < IN UNITS OF >MV < HAS AWLS NAME OF >SPDIL1 < DATA STRING >GR DIL < IN UNITS OF >GAPI< HAS AWLS NkME OF >GRDIL1 < DATA STRING >DT BHC < IN UNITS OF >US/F< HAS AWLS NAME OF >DTBHC1 < DATA STRING >GR BHC < IN UNITS OF >GAPI< HAS AWLS NAME OF >GRBHC1 < DATA STRING >CALl BHC < IN UNITS OF >IN < HAS AWLS NAME OF >CALIBHCI< DATA STRING >SP BHC < IN UNITS OF >MV < HAS AWLS NAME OF >SPBHC1 < DATA STRING >NPHI FDN < IN UNITS OF >PU < HAS AWLS NAME OF >NPHIFDNi< DATA STRING >DRHO FDN < IN UNITS OF >G/C3< HAS AWLS NAME OF >DRHOFDNI< DATA STRING >RHOB FDN < IN UNITS OF >G/C3< HAS AWLS NAME OF >RHOBFDNI< DATA STRING >NCNL FDN < IN UNITS OF > < HAS AWLS NAME OF >NCNLFDNi< DATA STRING >FCNL FDN < IN UNITS OF > < HAS AWLS NAME OF >FCNLFDNi< ° DATA STRING >CALI FDN < IN UNITS OF >IN < HAS AWLS NAME OF >CALIFDNi< DATA STRING >GR FDN < IN UNITS OF >GAPI< HAS AWLS NAME OF >GRFDN1 < 25 THE TRACE DATA STRINGS WILL HAVE THEIR NAMES DERIVED FROM SCHLUMBERGER FIELD NAMES. GENERATION NUMBER =-2048 START SEQUENCE = 1 *** FT42F001 OPENED *** REEL HEADER LENGTH: 132 BYTES REEL NAME: SERVICE NAME: SERVIC REEL CONTINUATION NUMBER: PREVIOUS REEL NAME: COMMENTS: LIBRARY TAPE 01 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: SERVICE NAME: SERVIC TAPE CONTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: LIBRARY TAPE 01 DATE: 82/12/ 1 DATE: 82/12/ 1 END OF FILE MARKER NO. 1 FILE HEADER LENGTH: 64 BYTES FILE NAME: SERVIC.001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SITE INFORMATION RECORD *** COMPANY: WELL: FIELD: CHEVRON U.S.A. INC. SOLDOTNA CREEK UNIT 12A-3 SWANSON RIVER DATA FORMAT SPECIFICATION LENGTH: 708 BYTES ENTRY BLOCKS TYPE SIZE REP CODE 66 73 65 ENTRY 1 60 .lin 24
