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Home My WebLink About180-144 • • RECEIVED STATE OF ALASKA JUL 2 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ Suspended❑ 1 b.Well Class: 20AAc 25.105 20AAc 25.110 Development ❑✓ - Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC (Aband�' 5/23/2017 • 180-144/316-610 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 February 21, 1981 50-733-20074-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 729'FSL, 130' FEL, Sec 17,T9N, R13W, SM,AK April 27, 1981 TBU K-03RD Top of Productive Interval: 9. Ref Elevations: KB: 122' 17. Field/Pool(s): McArthur RiverField N/A GL: N/A BF: 73.4' rf J<I -Pi*#141,14 14��4,16.; G.4, Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: ?I§ 1914' FSL,2152'FEL, Sec 19,T9N, R13W, SM,AK 9,570'MD/7,090'TVD ADL018777 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 213767 y- 2511793 Zone- 4 13,405'/9,831' N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 206365 y- 2507873 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 73' (ft MSL) 9,570'/7,090' 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 WED AUG 2 12017 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 61# K-55 Surface 2,506' Surface 2,346' 18" 1560 sx 9-5/8" 27# N-80 Surface 9,570' Surface 7,090' 12-1/4" 1000 sx 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; Date Perfd): - - .=•LCTION 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. AT 2.3�t.,} Was hydraulic fracturing used during completion? Yes ❑ No 0 VERIFIED Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED fr— 27 PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift, etc.): N/A 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 2017 ✓ 4ge Qi• TINUED ON PAGE 2 RDDMS LL' Jt.." 3 1 2017 Submit ORIGINIAL only N7 / i. • • 28.CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 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: Wellbore Schematic, Decomplete Reports. Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Paul Mazzolini Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: Cdinger4=A, COrp.com AuthorizedContact Phone: 777.8389 Signature: x C Date: 714-71140 , 7 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND 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 5/2017 Submit ORIGINAL Only • • Trading Bay Unit Schematic WeII # K-03RD Abandoned 5/23/17 Hilcrorn Alaska,LLC PTD: 180-144 API: 50-733-20074-01 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2506' S-95 BTC(170 jts) 8.681" Surf 9-5/8" 47 N-80 8rnd LTC(74 jts) 8.681" - - N-80 BTC(31 jts) 8.681" - 10,983' 7" 29 N-80/S-95 6.184" 10,660' 13,395' TUBING DETAIL L , 4 1/2" 13.55#Bare/ L 80 Polycore Lined 3.56" Surf 10,119' 14.55#Lined BTC 4-1/2" 11.6#Bare/ L 80 Polycore Lined 3.64" 10,119' 12,368' 12.55#Lined TPL-4040 3-1/2" 9.2# N-80 BTC 2.992" 12,368' 12,382' JEWELRY DETAIL epth No DMD Dh ND ID OD Item 1 9,591' CIBP(set for whipstock) .."- 2 2 12,368' 9,056' 3.000" 5.125" Baker 80-40 PBR w/30,000#shear 3 12,370' 9,057' 3.000" 5.968" Baker FHL w/70,000#shear TOW 9,570' WLM BOW 9,588' 4 12,382' 9,066' 2.992" Bottom of Eline cut tubig i _ 1 COI' 15'1 Ma 0 PERFORATION DETAIL X Zone Top Btm Top Btm Amt SPF Date Status L , (MD) (MD) (TVD) (TVD) 9/10/14& G-5 12,386' 12,462' 9,069' 9,126' 76 6 9/14/14 G-5 12,408' 12,460' 9,086' 9,124' 52' 2 6/20/1996 ' ':«417.44 G-7 12,532' 12,592' 9,178' 9,222' 60 6 9/10/14& ' 9/14/14 E-Line 3 B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 Cut Tail :e r #h 7.: B-1 12,592' 12,622' 9,222' 9,244' 30 6 9/14/14 . .rlxk: �'�Lt G-5 B-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 , y*d, , G 7 B-2 12,633' 12,649' 9,252' 9,264' 16 12 9/9/14 Cemented 1,+.v4 �';'. i y, � B-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 ,. B-0 B-2 12,680' 12,700' 9,287' 9,302' 20' 4 • ` •" ` B-1 B-3 12,745' 12,760' 9,335' 9,346' 15' 4/8 "4 .*v, ' B-3 12,769' 12,799' 9,353' 9,375' 30' 4 ..:4,41"r B-2 A B-4 12,808' 12,820' 9,382' 9,391' 12' sqzd - B-3 B-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 f B-4 B-7 13,134' 13,164' 9,626' 9,649' 30' ay. ' x+,''':4`1 a` B-7 PBTD=9,591' TD=13,413' MAX HOLE ANGLE=56°@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' Updated by: DEM 05/23/17 • • Hilcorp Energy Company Composite Report Well Name: MRF K-03RD2 Field: County/State: ,Alaska (LAT/LONG): :vation(RKB): API#: Spud Date: Job Name: 1711118P K-03RD2 PreDrill Contractor AFE#: 1711118P AFE$: t� 5/17/2017 No activity on this well during this time.,Prep to move rig to K-03rd2.Remove flowline and earthquake clamps from sub.Pull Hydril annular and replace with Shaffer annular.Trolly BOP back into sub.RU hyd pump to jacks.Pull down stairs and landings.Mix 25 bbl LCM pill and rig up all the lines to pump it.Load out boat w/extra equip.,Skid rig over well K-03RD2.,R/D jacking unit.Install stairs and Iandings.,Pump 25 bbl.LCM pill and displace with 149 bbl FIW down tubing.Saw pressure after-5 bbl pumped.(ICP=1850 psi @ 5 bpm. FCP=2200 psi @ 3 bpm.Shut down and pressure bled to 800 psi after 15 min.)Bleed off pressure and R/D circ lines. Continued to rig up during pumping operations.,Continue rigging up on K-03RD2. Install earthquake clamp,handrails,stairs,landings and flow lines.Run lite water line to sub and tighten panic line.Change out DSA on riser to GrayLock clamp and swap spools.,lnstall BPV and nipple down tree. 5/18/2017 Nipple dn tree and components.Cleanup wellhead and check hanger threads.Screw in blanking sub.,Nipple up riser. PU BOPs and slide 2'spool under and MU on riser.Nipple up BOPs.MU choke lines and tighten flanges from rams down.,MU Shaffer annular bolts. Install flow box and turn buckles.[Unload boat while nippling up]Hook up flowline.Install drip pan and seal off same.Install beaver slide and catwalk.,Modify drip pan for rotary pin installation.Circulate through flow lines to check for leaks(GOOD)Get RKB measurements Bag=8.48',UPR=12.30', BR=12.30', LPR=15.24', LDS=48.65'.,Build test jt.fill system with water and purge air from system.,Test BOPE with 4 1/2"pipe. Test annular with 250/2500 psi for 5 min ea.Test Rams and valves with 250/3500 psi for 5 min ea. Upper pipe ram test failed on initial attempts to test. Cycled valves and rams and retested (GOOD)Tested gas alarms all good,tested PVT and flow show all good.,Performed accumulator draw down test, pressure after function 1400 psi,200 psi recovery 27 seconds,full recovery 3000 psi 132 seconds.2500 psi N2 bottle average.Note:AOGCC witness of test waived by Jim Regg.,Pull test joint and break down same.,Pick up T-bar and pull BPV.,Make up landing joint and screw into hanger. P/U 55K to unseat hanger. Pick up tubing string 20'to unseat seals(PUW=90K).,Pump 15 bbl clean FIW to get returns. Rig up to test lines for shipping well bore fluids to production shipping line. 5/19/2017 Test shipping lines to production pipeline to 1500 psi.Pump FIW dn tbg w/#1 pump at 5 BPM,340 psi,taking returns to pit 5 and pumping to production pipeline w/#2 pump.at 4 to 5 BPM and 380 psi.Pumped 721 bbls FIW and pumped 728 bbls to production pipeline.,Pull hanger to rig floor and LD hanger and landing jt.,RU to cmt,MU XOs and tag top of packer w/pump on at 1 bpm,Observed pressure increase and flow decrease.Shut pump down and stab seal in 6'into packer.Establish injection rate.2 BPM=1900 psi,3 BPM=1950 psi,4 BPM=2145 psi.Shut down and press bled down to 1600 psi in 5 min.,RU Schlumberger lines.and have PJSM.,Prime up Schlumberger pumps.Pump 5 bbls water.Test lines to 800 and 4500 psi.Good test.Pump 10 more bbls water.Batch up and mix 15.8 ppg cmt.Pump 41.5 bbls of cmt and chase w/5 bbls water.Swap to rig pump and Chase with 141 bbls of FIW.Starting pressure of 450 psi and a final pressure of 2153 psi.Squeezed 30 bbls into pkr and left 10 bbls on top.,RD circ equip.Pull 6 stds and stand them back in the derrick.,Put wiper plug in the pipe and circ clean.8 BPM,680 psi.About 25 bbls from bottoms up we started getting cmt contaminated fluid back.Got back about 1 bbl of contaminated cmt.,R/D circ equipment(TIW,X/O,Side Entry, Pup Jts of tbg)Well out of balance.,Circulate to balance fluids in well.,POOH laying down 51 jts of 4 1/2"tbg. (PUW=89K)Well out of balance again.,RIH with 6 std tbg out of derrick, Rig up to circulate.,Circ well to ballance.Mix and pump dry job.,Continue to POOH laying down tbg.,Wellhead pressures:24"=60 psi,13 3/8"=62 psi Fluid loss to well today: 140 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. - Metal recovered today: 0.0 lbs. Total:0.0 lbs. CA' 5/20/2017 POH laying down 4 1/2 injection tbg. Lay dn seals.,RD Weatherford tongs and clear floor.,Test csg to 2600 psi.for 30 min on a chart.Lost 50 psi over the first 15 min then it held like a rock.Good test.,Break down tbg floor safety valves and PU BHA#1:8 1/2 bit,9 5/8 csg scrapper,bit sub,flex jt,8 1/2 upper string mill,xo, 1 jt HWDP,xo,bumper sub,oil jars,xo,&18 jts HWDP=632.89'.,Cut 150'drilling line.,Service blocks,top drive and drawworks.,RIH with BHA#1 picking up 4 1/2" DP.,Wellhead pressures:24"=58 psi, 13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs. 5/21/2017 Continue RIH with scraper assem while PU 4 1/2 CDS40 DP to 9,860'.,Circ hole clean at 414 GPM,967 psi.Got back black sledge and black tar balls. Had just a slight increase at bottoms up.,RU a-line and MU gyro tools.[Took 1 1/2 hrs to get tools headed in the hole.]RIH with gyro 9,715'.,POH w/Gyro slow. Break dn tools and RD e-line.,Pump dry job. POH w/scraper assembly from 9895'(PUW=130K)to 4545'(PUW=75K).,Service Drawworks,Top Drive,Blocks and Crown.,Continue POOH to BHA.,UD BHA and clear floor.,RU e-line to Bridge Plug(Bridge Plug has wrong upper slip segment for running on e-line).,Wait on correct slip segment to be delivered to heliport by Baker and flown out to platform.,Finish making up Bridge Plug and RIH on wireline.Set plug A 9591' WLM(5'above collar @ 9596').,POH with wireline.,Wellhead pressures:24"=60 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 0.0 lbs. Total:0.0 lbs. • 5/22/2017 POH w/e-line after setting the BP.RD a-line and clear floor.,Service rig and TD.,PU whipstock BHA#2=9 5/8 bottom trip anchor,9 5/8 gen II whipstock slide, 8 1/2 window mill,lower string mill,flex joint,upper string mill,XO sub,1 jt HWDP,XO sub,float sub,DM collar,TM HOC,XO sub,18 jts HWDP=654.38, BHA to window mill=632.66,RIH BHA and one std of DP to 685'.Test MWD and we got a good signal.,RIH w/whipstock U 3136'.,Continue RIH w/whipstock t/9534'.,MU TD and orientate whipstock to 58 deg left by working pipe.Tag top of BP at 9593'DPM on down stroke.PU another sng to give us room to set wt on whipstock.,Set down and see shear @ 12K down. PU to check for over pull,none observed,PUW=125K. Slack back off and set down 30K.Appears that the anchor and shear bolt both sheared at the same time.,Check rotation,10 rpm=8K free torque.Adjust TD torque to 10K.Slack off rotating and observe window mill stall out on the whipstock slide.Take a check shot with MWD and verify that the whipstock is still oriented at 58 deg left.,RU to displace well and lay down single.(reset the TD torque to 18K drilling and 21K max).,PJSM for displacing well. PT lines to production to 1500 psi.,Begin pumping FIW to production 3 bpm 310 psi. Pump 25 bbl spacer down drill pipe followed by OBM at 3 bpm 180 psi.,Continue displacing well to OBM @ 5 bpm FCP 610 psi. Shipping FIW down pipeline to Trading Bay.Total pumped 679 bbl @ 4 bpm 250 psi.,Suck out remaining FIW in pits,transfer OBM form ISO and upright tanks to pits.Remove blind flange from charge pump line,blow down shipping line and line up pumps to circulate downhole.,Circulate and condition mud while transferring OBM to pits,.Taq top of whipstock at 9569'and start milling window.,Wellhead pressures:24"=58 psi,13 3/8"=27 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. `Y`�~ Metal recovered today: 0.0 lbs. Total:0.0 lbs. 5/23/2017 Mill 8 1/2 window f/9570't/9588.410 GPM,2500 psi,90 RPM,6 to 13k Tq.,Mill formation ft 9588't/9613'.Mill 25'new hole to ensure we had gauge hole for drilling assem.,Circulate and condition mud to 9.0+ ppg in and out.,Perform FIT to 12.5 ppg EMW.Good test.,Pump dry job.POOH with window milling assembly from 9568'to 2375'.,Service Drawworks,Crown, Blocks and Top Drive.,Continue to POH with window milling assembly to BHA.,UD Window Milling BHA(BHA#2).,Change to Drilling AFE @ 2400 hours.,Wellhead pressures:24"=60 psi, 13 3/8"=26 psi Fluid loss to well today:0.0 bbls. Total:315 bbls. Code 8 today: 0.0 hrs Total:0.0 hrs. Metal recovered today: 300 lbs. Total:300 lbs. • �,• OF Ty • • y; I yy,' THE STATE Alaska Oil and Gas �� ►'�� OfnLnTn Conservation Commission £'=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �C l ° Main: 907.279.1433 P ALASl°' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager NS A P g 0 3 20i7, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: McArthur River Field, Hemlock& Middle Kenai G Oil Pools, TBU K-03RD Permit to Drill Number: 180-144 Sundry Number: 316-610 Dear Mr. Golis: 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. S. cerely, Daniel T. Seamount, Jr. Commissioner DATED this 4 day of December, 2016. RBDMS DEC - 8 2016 • 0 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OR L 0 5 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown CI Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 ' Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development ❑ 180-144 I 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service 0. 6.API Number. Anchorage,AK 99503 50-733-20074-01 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit/K-03RD k 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 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): 13,413 • 9,839 - 13,300 • 9,753 - 2,737 psi N/A 12,634 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,506' 13-3/8" 2,506' 2,346' 3,090 psi 1,540 psi Intermediate 10,983' 9-5/8" 10,983' 8,059' 5,750 psi 3,090 psi Production Liner 2,735' 7" 13,395' 9,825' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12,386-13,164 • 9,069-9,649 4-1/2" 14.55#&12.55#/ L-80 12,368 3-1/2" 9.2#/N-80 12,382 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FHL Packer and SSSV:N/A . 12,370'(MD)9,057'(TVD)and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: �/ Detailed Operations Program LI BOP Sketch 0 Exploratory LI Stratigraphic CI Development ' Service 11 14.Estimated Date for 15.Well Status after proposed work: 2/1/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 ' 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 Dan Marlowe(907)283-1329 Email dmarlowe(c hilcorD.com Printed Name Stan W.Golis Title Operations Manager Signature 41c..~' jr(4,, Phone (907)777-8356 Date t% II.i r"t0 t i► COMMISSION USE ONLY Conditions of approval: Notify Commissi n so that a representative may witness Sundry Number ter/ \Le- oo ' Plug Integrity Li BOP Test If?J Mechanical Integrity T�st ❑ Location Clearance ❑ Other: A- 3 50 0 tS a' C)P '—ie-..3-r" S::- 1 z—(-3 (1 Post Initial Injection MIT Req'd? Yes ❑ No ❑,_,l/d/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /o•..y �.®7 RBDMS t, - 8 2016 APPROVED BY Z( 7 Approved by: IA, / ) COMMISSIONER / THE COMMISSION Dte: I l I, �// �i /4/ � /2-6 -IC Submit Form and Form 10403 Revised 11/2015 0 RptedlatilknErlidRPtOtI*Ihhdhfm0m the date of approv Attachments in Duplicate • . Well Work Prognosis Well: K-03rd Hi[carp Alaska,LLC PTD:180-144 Date: 11/11/2016 Well Name: K-03`d API Number: 50-733-20074-01 Current Status: Injector Leg: Leg#4 (NW corner) Estimated Start Date: February 01, 2017 Rig: Kuukpik#5 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 180-144 First Call Engineer: Dan Marlowe (907)283-1329(0) (907) 398-9904(M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 3,644 psi @ 9,069'TVD 0.402 lbs/ft(7.37 ppg)based on 01/19/2016 SIBHP Maximum Expected BHP: 3,644 psi @ 9,069'TVD 0.402 lbs/ft(7.37 ppg)based on 01/19/2016 SIBHP Maximum Potential Surface Pressure:2,737 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary K-03rd is an injection well supporting the G and Hemlock sands. This workover will plug back the well in preparation for a sidetrack as an ESP producing well offset to the K-10rd2(lnjection support into this area will be developed in another wellbore workover–likely a K-11 sidetrack. co,cor. /)/46 Last Casing Test: 9/17/2014 MITIA to 2,400 psig @ 12,370' MD for 30 minutes Procedure: 1. Skid Rig into position above K-03rd. 2. Work over fluid is FIW&salt as needed to balance well, BOP's will be closed as needed to circulate the well. ,..� s,4- 3. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Un-sting seals from injection packer and circulate any hydrocarbons from well. 5. Lay down tubing hanger, sting back into injection packer and RU cementing equipment 0.1 6r Establish an injection rate with FIW. k 7. Mix and pump±30 bagels cement to isolate existing completion displacing with FIW. Un-sting from () injection packer spofan additional±10 barrels cement above packer, POOH above estimated top of cement at±12,100' and circulate hole clean. 8. POOH w/injection tubing 9. Pressure Test casing to 2,500 psig for 30 minutes and chart. 10. RU e-line and RIH w/CIBP to±9,017', ±5'above casing � connection. ' . ji4 11. RD e-line. �—� C.li i (j c c Jl Cd( - lis, ' 12. PU whipstock and mills and RIH to CIBP. 13. Orient and set whipstock. II m..(0. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 14. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. 15. PU directional BHA and TIH to window. 16. Swap well to drilling fluid • I Well Work Prognosis Well: K-03rd PTD:180-144 Hilcorp Alaska,LLC Date: 11/11/2016 Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form 0 • Trading Bay Unit . 11SCHEMATIC WeII # K-03RD Last Completed: 09/18/2014 Hilcorp Alaska,LLC PTD: 180-144 API: 50-733-20074-01 CASING DETAIL RKB to Hanger=35' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2506' S-95 BTC(170 jts) 8.681" Surf - 9-5/8" 47 N-80 8rnd LTC(74 jts) 8.681" - - N-80 BTC(31 jts) 8.681" - 10,983' 7" 29 N-80/S-95 6.184" 10,660' 13,395' TUBING DETAIL L13.55#Bare/ Polycore Lined 4-1/2" 14.55#Lined L-80 BTC 3.56" Surf 10,119' 4-1/2" 11.6#Bare/ L 80 Polycore Lined 3.64" 10,119' 12,368' 12.55#Lined TPL-4040 3-1/2" 9.2# N-80 BTC 2.992" 12,368' 12,382' ( JEWELRY DETAIL • No Depth Depth ID OD Item MD ND FMC Tubing Hanger,4-1/2"w/pup&X-O to 3-1/2"BTC 1 10,118' 7,470' Crossover from BTC Extended to TPL-4040 2 12,368' 9,056' 3.000" _ 5.125" Baker 80-40 PBR w/30,000#shear 3 1237 9,057' 3.000" 5.968" Baker FHL w/70,000#shear 4 12,382' 9,066' 2.992" Bottom of Eline cut tubig PERFORATION DETAIL Zone Top Btm Top Btm Amt SPF Date (MD) (MD) (TVD) (ND) 9/10/14& SLP G-5 12,386' 12,462' 9,069' 9,126' 76 6 9/14/14 Ili G-5 12,408' 12,460' 9,086' 9,124' 52' 2 6/20/1996 14) ,.9 0 : 2 � i?/ I Ow= 3 G-7 12,532' 12,592' 9,178' 9,222' 60 6 99/104%44 IT V 4 D� B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 'I.- E-Line Cut Tail 1` G-5 B-1 12,592' 12,622' 9,222' 9,244' 30 6 9/14/14 012 8-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 G-7 61„5B-2 12,633' 12,649' 9,252' 9,264' 16 12 9/9/14 6.,, . B-0 8-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 GL-41 B-1 B-2 12,680' 12,700' 9,287' 9,302' 20' 4 B-3 12,745' 12,760' 9,335' 9,346' 15' 4/8 B-2 A B-3 12,769' 12,799' 9,353' 9,375' 30' 4 B-3 B-4 12,808' 12,820' 9,382' 9,391' 12' sqzd B-4 8-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 B-7 13,134' 13,164' 9,626' 9,649' 30' 1111 B-7 Fill Tagged w/2.80"GR on 6/17/96 @ 13,156'WLM A) Tubing tail(45') 9/14/14 @ Approx.12,634' PBTD=13,300' TD=13,413' MAX HOLE ANGLE=56°@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' Updated by: DEM 11/07/15 • 0 0 Trading Bay Unit . 11PROPOSED Well# K-03RD Last Completed: FUTURE Hilcorp Alaska,LLC C PTD: 180-144 API: 50-733-20074-01 CASING DETAIL RKB to Hanger=35' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt LT&C 12.515" Surf 2506' S-95 BTC(170 jts) 8.681" Surf 9-5/8" 47 N-80 _ 8rnd LTC(74 jts) _ 8.681" - - N-80 BTC(31 jts) _ 8.681" - _ 10,983' 7" 29 N-80/S-95 6.184" 10,660' 13,395' TUBING DETAIL 4 4 1/2" 13.55#Bare/ L 80 Polycore Lined 3.56" Surf 10,119' 14.55#Lined BTC 4 1/2" 11.6#Bare/ L 80 Polycore Lined 3.64" 10,119' 12,368' 12.55#Lined TPL-4040 3-1/2" 9.2# N-80 BTC 2.992" 12,368' 12,382' JEWELRY DETAIL epth No DMD Dh ND ID OD Item 1 ±9,017' ±7,781' CIBP(set for whipstock) 11/ 2 12,368' 9,056' 3.000" 5.125" Baker 80-40 PBR w/30,000#shear 3 12,370' W LM 9,057' 3.000" 5.968" Baker FHL w/70,000#shear 4 12,382' 9,066' 2.992" Bottom of Eline cut tubig 1110 \/ PERFORATION DETAIL PI < Zone Top Btm Top Btm Amt SPF Date Status (MD) (MD) (ND) (ND) 9/10/14& G-5 12,386' 12,462' 9,069' 9,126' 76 6 9/14/14 G 5 12,408' 12,460' 9,086' 9,124' 52' 2 6/20/1996 4' G-7 12,532' 12,592' 9,178' 9,222' 60 6 9/10/14& ` � "- °', 3 9/14/14 E-Line « 'y• ( B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 Cut Tail ..4 B-1 12,592' 12,622' 9,222' 9,244' 30 6 9/14/14 r, G-5 B-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 B-2 12,633' 12,649' 9,252' 9,264' 16 12 9/9/14 Cemented G-7 itB-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 iB-0 B-2 12,680' 12,700' 9,287' 9,302' 20' 4 -+lr B-1 B-3 12,745' 12,760' 9,335' 9,346' 15' 4/8 B-3 12,769' 12,799' 9,353' 9,375' 30' 4 B-2 A B-4 12,808' 12,820' 9,382' 9,391' 12' sqzd « "2 R B-3 B-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 r1 • i' ". B-4 B-7 13,134' 13,164' 9,626' 9,649' 30' ,Ii;,..' ,' 0. B-7 Fill Tagged w/2.80"GR on 6/17/96 @ 13,156'WLM A) Tubing tail(45') 9/14/14 @ Approx.12,634' PBTD=13,300' TD=13,413' MAX HOLE ANGLE=56°@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' Updated by: JLL 11/17/16 • 0 King Salmon Platform K-03RD Current 09/02/2015 HiIragi Alaska.1.K King Salmon Tubing hanger,FMC-UH- K-03RD TC-IA-EN,13 5/8 5M X 4''A 24 X 13 3/8 X 9 5/8 X 4 1/2 TC-2 lift and susp,w/4" type H BPV,Non cont control line port,410 SS BHTA,Bowen,4 1/16 5M FE X 7"SA Bowen top,FF trim N ISI MI .11.— Valve,Swab,WKM-M, • U 4 1/16 5M FE,HWO,FF pr p• trim U v ' . Valve,Wing,SSV, WKM-M,4 1/16 5M FE, �� 15"Safeco oper,FF trim CIL .u--xri it Valve,Master,WKM-M, r1 4 1/16 5M FE,HWO,FE (tt j't trim - __i i 0 U v Void test good WE" ""e' Adapter,FMC-A5P,13 5/8 5M 250/5000psi P. s,1 __ 9/2/2015 API clamp X 4 1/16 5M,w/7" i extended neck pocket Unihead,OCT type 3,13 5/8 5M API hub top X 13 3/8 BTC casing bottom, [_i. .r e.4 w/1-2 1/16 5M SSO on lower section,1-2 1/16 5M SSO on middle section,3-2 1/16 5M SSO on upper •� - _ 4 ''Al.�.. section,IP internal lockpin assy 1::i. -_ 1%)"...111 Void test good - �) 250/2500psi �' (��'lei ra i•:', 9/2/2015 I i- ->~ -- C_ ' ;I _ Emergency slips and ill— on on 9 5/8 casing i ''7' p . „,„ _ _ (..,...,,,,, , T. Starting head,FMC, " ,41 .-_- Il�'r , H 21''A 2M X 24"SOW, itMilw/1-31/82MEF0 •.. 24" J13 3/8" r 9 5/8" 4'A" King Salmon Platform 2016 BOP Stack(Kuukpik) 06/22/2016 Hilrnrp Alnau.LL{. Rig Floor 16" Pipe i 1 I FEt-Il_1.RT11 I l ll vO O int*I(fel (fel (ffil rit 3.74' Shaffer 13 5/8 5M rffi rain Tr 1 Shaffer SL 2 7/8-5.5 Variables 2.83 135/z,85M 241 Blind — O 2 1/16 5M manual and i 1/16 5M manual and HCR valve 1.76 1 rNCO :i- . Jij J t 1 JJ 1jJJ .-. ' - 111 111 IilIfl.l11 4101 Shaffer SL 13 5 SM 2 7/8-5.5 Variables 1.44' O III III Iil I11 ill Drill deck 13.70' Riser 135/85MFEX 13 5/8 5M API hub • • Choke Manifold Valves 2 " To Shaker 3" Panic To Gasbuster 3 1/8"_ 21/16" `� __.....,c) 021/16" (IR i [El IR III zi` 21/1 + 21/16" N 3 1/8" i _ J 2 1/16" U 1/16" Manual Choke t Automatic Choke 2 1/16" Inlet Pressure Sensor 3„ 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold #7 \i- :....�.» #s #16 #5 # #1 #2 !• 40 ei , ilL#15 01,,• i C-1 4 , Kuukpik Drilling Rig 5 Choke Manifold • x' n 'CS r i vY• •••° .--0.- O W •-,• E. = -0 UG 1 1 1 1 1 1 1 1 1 C l0 00 J of i VI A W 1.1 a O I I I I I I I 1• I" _a ,,, 111111111 t () Cf4 I,J ji.. it.,44 j44 i1.1 i1.1 It I_I_1;.--,1,-;,.1,;,.-,1,-;.,-I_I",I", Us 1°'la lQ is la l°'l*=le'IQ 'I0t0I0,I0I0 j 0l i 0 i I0, I0 t0,0l0,0,o0l0'o'0'0 5 (° t t, f, f= f, rl fc, f, A 1010101010101010 ic, 1-1-1-1-1-1-1-1-1—• I III I I 1 1 1 b jo I.F.'6O!OkO4)VOg�O $ _ p _ I� IA10101c10to ,m ,m •o 01X X0) •-J i°is i i i i i 1 1 ° D4 Di 0 01 03 vs r. 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Rolling BOP Test Procedure: Kuukpik 5 — Oil/Gas Producers, Water/Gas Injectors Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile &lift threads were deemed good, but still unable to get good tests 1) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Guy Schwartz (AOGCC-guy.schwartz@alaska.gov),Jim Regg (AOGCC-jim.regg@alaska.gov) and Michael Quick (AOGCC—Michael.quick@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. If on Federal land contact BLM representative Amanda Eagle (aeagle@blm.com) and Mutasim Elganzoory(melganzoory@blm.com). AOGCC and BLM may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: 2) With stack out of the test path, test choke manifold per standard procedure 3) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Kill and choke line valve will also be tested during this time. 4) During these tests the test chart needs to be set to 60 min instead of 12 hours so chart shows a better graph. Need to station hands in cellar going over all connections on the BOPs looking for the slightest leak. Also need a man looking down the hole to confirm that the BOPs are not leaking. Test# 1=Annular, HCR Choke, and HCR Kill. Test#2=Upper Pipe Rams, HCR Choke, and HCR Kill. Test#3=Upper Pipe Rams, Manual Choke, and Manual Kill. Test#4=Lower Pipe Rams. 5) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. 6) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) 7) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 8) Pull hanger to surface. (Making tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid and sweep off any oil cap that may be present. 9) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE as per Kuukpik's standard test procedure. Or POOH laying down all the tubing and use the normal test plug to finish the tests that were not completed as per regulatory approval. • • • Kuukpik 5 BOP Test Procedure Raeorp nla.ka.i.►.c Attachment#1 If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree and test. May have to tap out if scaled up or paraffined up if well is not dead may have to be done w/pressure lubricator (diesel or acid could help) 2) If unsuccessful, or BPV profile is eroded and well is dead. Best practice is to have two barriers a. Fluid column b. Set wire line plug or tag fluid level with slick line to establish static fluid level or shoot fluid level with an echo meter gun. 3) Shoot off tubing very shallow ( 300-500' most likely just under SSSV if applicable) 4) Spear hanger w/upside down cup provided by fishing company 5) Proceed to get best test we can achieve against cup and confirm no visual leaks on all flanges of BOPE 6) Notify Hilcorp Anchorage Operations Engineer and AOGCC of situation 7) Pull hanger and cut off stub 8) P/U test plug and set same. 9) Perform complete BOPE test as per Kuukpik's standard procedure . 0 • 0 a Cl, > ¢ C C ai k-a0 R*< a § q2 Q ", J e = K " wri 0 R $ .4 x tCDCD / ¢ I n2 )< C1 IN r 0 —1 ■ — a \ § * / 13CA § O \ f p ° CD ■ n E A 0 73 < a m $ E < O CD Q. n m0. 2 � � Cl) co E 5. to / � § Q a CD 0 a) f Q 0 CD / 7 a ois- e, la ■ -0 % C 0 0 m 3 C m O. > = f C of (1) 0 00 ED a k = % m x CO 22 & CD / 13 C.4 O m n _ w0 Z k * o 'N » ,- CD / t X =2 � f * § $ CD % k CI CD \g C rd R / C 13 I kal a 7-1: � Oro LIX 70. o. cif a o § ci3a _ D d *. . 2 I <to kk / / rn ■ - U / ] D c § 22 » 0" & Ro § g § 5° / 0.OM2 CD INZ co C • • 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 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 Geojogist work)the initial reviewer will cross out that erroneous entry and initial 7 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. • • Pi() L %019-9—cO Hilcorp Alaska,LLC I WelI:IK-03RD I Field:IKing Salmon 101/27/2016 Pressure (psia) SCANNED FEB 1 6 2017, 0 500 1000 1500 2000 2500 3000 3500 4000 0 1000 Pressure-Temperature Profile 1. RIH 1/19 vs 1/27 Overlay 2. Well Shut-in 2000 3000 4000 5000 CD6000 D \ 2 t 7000 O. d 8000 9000 10000 11000 I ' 12000 13000 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) 1-27-16 Pressure — Perfs x Packer —13 3/8" —9 5/8" 7" 4 1/2" 3 1/2" —1-27-16 Temp —1-19-16 Temp • �v ®r ?At,777 ,v STATE • / Alaska Oil and Gas ? 2 o f CGnservati n C.mmi scion -J — 333 West Seventh Avenue u, x - Anchorage, Alaska 99501 3572 »_, GOVERNOR BILL WALKER Main: 907.279.1433 ®�-ALAS Fax 907.276.7542 www.aogcc.alaska.gov January 7, 2016 Certified Return Receipt 7015 1660 0000 1487 7098 Mr. David Wilkins Senior Vice President Hilcorp Alaska LLC SCANNED KAP,. ( i 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket OTH-15-023 Investigation of reporting a pressure communication to AOGCC Trading Bay Unit K-03RD (PTD 1801440) Area Injection Order(AIO) 05.000 Trading Bay Unit(TBU), McArthur River Field, Hemlock and Middle Kenai G Oil Pools King Salmon Platform Dear Mr. Wilkins: The Alaska Oil and Gas Conservation Commission (AOGCC) issued a notice of investigation dated September 3, 2015 requesting information relating to the reporting of a potential pressure communication on well TBU K-03RD. Hilcorp Alaska LLC (Hilcorp) responded with a letter dated October 16, 2015 which outlined the timeline of TBU K-03RD and the pressure responses to changes in waterflood operations, as well as pressure information and reporting on all other wells authorized by AIO 5. The AOGCC is satisfied with Hilcorp's response as provided on October 16, 2015. The data provided by Hilcorp showed that the K-03RD pressure fluctuations could be attributed to thermal influences and that Hilcorp's reporting to AOGCC was appropriate. The AOGCC closes its review and action regarding the September 3, 2015 notice of investigation. Hilcorp has requested that K-03RD be allowed to return to injection so thermal stability can be re-established and further diagnostics can be conducted, including an AOGCC witnessed MIT-IA. AOGCC GRANTS the Hilcorp request to return the well to injection as per AIO 5. Sincerely, P Cathy P. oerster Chair, ommissioner cc: Jim Regg AOGCC Inspectors U.S. Postal Service.' • CERTIFIED MAIL° RECEIPT 43 Domestic Mail Only O For delivery information,visit our website at www.usps.com'. • ..r „. ro Certified Mail Fee $ r 9 Extra Services&Fees(check box,add fee as appropriate) o Return Receipt(hardcopy) $ ® ❑Return Receipt(electronic) Postmark 0 Certified Mail Restricted Delivery $ Here ❑Adult Signature Required $_ ❑Adult Signature Restricted Delivery$ im Postage •� 1 Mr. David Wilkins i Senior Vice President r4 ': Hilcorp Alaska, LLC r- 3800 Centerpoint Dr.,Ste. 1400 ( Anchorage,AK 99503 • SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2,and 3. A. Signature • Print your name and address on the reverse X • I 0 Agent so that we can return the card to you. ' • ' ❑Addressee 111 Attach this card to the back of the mailpiece, B. Received by(Printed Na C. Date of Delivery or on the front if space permits. — — + Avir..r..A - 'ivery address different from item 1? • Yes 3,enter delivery address below: ❑No Mr. David Wilkins Senior Vice President Hilcorp Alaska, LLC 3800 Centerpoint Dr.,Ste. 1400 Anchorage,AK 99503 11111111111111111111111 111111110111111111 3. Service Type Adult Signature Cl Priority Mail Express® ❑Registered Mail'. ❑Adult Signature Restricted Delivery 0 Registered Mail Restricted l•Gertified Mail® Delivery 9590 9403 0910 5223 5238 74 0 Certified Mail Restricted Delivery Return Receipt for ❑Collect on Delivery Merchandise 0 Collect on Delivery Restricted Delivery El Signature Confirmationle 2. Article Number(Transfer from service label) i Mail 0 Signature Confirmation 7 015 1660 0000 1487 7098 i MailRestricted Delivery Restricted Delivery .•500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • t .......: . Hilcorp Alaska, LLC David S. Wilkins t" Post Office Box 244027 f� Anchorage,AK 99524-4027 I)�` 2 Q i 3800 Centerpoint Drive Suite 100 October 16, 2015 AOGCC Anchorage,AK 99503 Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3 572 Re: Investigation of reporting a pressure communication to AOGCC Trading Bay Unit K-03RD (PTD 1801440) Area Injection Order(AIO) 05.000 Trading Bay Unit(TBU), McArthur River Field, Hemlock and Middle Kenai G Oil Pool Docket Number: OTH-15-023 Dear Chair Foerster: We respond to the AOGCC's September 3, 2015, request for additional information concerning Hilcorp Alaska LLC (Hilcorp Alaska)operations and the operation of TBU K-03RD. 1. AOGCC Request: "12 month TIO raw data(excel format) and pressure plot identifying TIO pressures, injection rate, injection temperatures, and any bleed events." Hilcorp Alaska Response: Please see Attachment 1 (CD with Plot; Data in Excel format). Note: Injection temperatures for seawater are not recorded in the database as the temperature of injected seawater remains fairly constant throughout the year. The bleed events are included in the Timeline of K-03RD Well Events, Attachment 2. 2. AOGCC Request: "A timeline of well events since a passing State witnessed MIT-IA on October 7, 2014, to present, and how Hilcorp responded to each potential pressure communication indication or event." Hilcorp Alaska Response: Please see Attachment 2 (Timeline of K-03RD Well Events). Note that none of the events was sufficiently significant to require attention until the event on August 4, 2015. At the time of that waterflood shutdown, the IA pressure rose apparently due to the warming of the annular fluids by the formation. Upon restarting waterflood, the pressure fell as it would in response to cold water injection. During the waterflood shutdown on the next day, the pressure rose again, but fell when waterflood was restarted. On August 18 and 19, additional waterflood shutdowns and restarts occurred, with a similar rise and fall of pressures in the well. On August 29, a brief waterflood shutdown occurred and the well pressures climbed again. Upon restart, the pressures did not drop as anticipated, so the IA pressure was bled from 980 to 140 psig. Because the pressure did not remain at that level, • Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 2 of 13 and rose again, a decision was made to shut the well in on August 31, 2015, and reported the matter to the AOGCC. Hilcorp maintains that as soon as the K-03RD began behaving in a manner that indicated likely pressure communication or leakage, the well was shut in and the Commission was notified pursuant to 20 AAC 25.402(f) and Rule 6 of AIO 5. The TIO Plot for K-03RD shows three pressure increases on 8/4, 8/6 and on 8/19 on the IA. Each of these increases was preceded by short waterflood shutdowns the previous day due to a faulty fuel gas valve. Once the waterflood was brought back on line, the IA pressure began and continued to decrease until the next waterflood shutdown. This is indicative of thermal expansion and contraction due to the interaction of the relatively colder injection water and the relatively warmer formation. Thermal expansions are common if there is a tight and liquid-filled annulus. However, each well behaves differently. For comparison, we examined the TIO plot of another water injection well on the King Salmon Platform. The K-22 TIO plot(Attachment 3) also shows a thermal event on August 19. This spike occurred in both the IA and OA, and both the IA and OA were bled. Both declined in pressure after that event when water injection was restored. K-22 also shows a thermal pressure increase in the IA on September 24 due to a waterflood shut down. Since K-03RD was already shut in at this time, no corresponding spike was observed. As a further K-03RD check, on the August 6 pressure increase, a pressure bleed from 920 psi down to 800 psi was performed in order to confirm that the pressure was due to thermal expansion. Once the bleed was completed, the pressure was monitored to see if it would re- gain pressure or continue to decrease. The pressure on the IA continued to decline from the 800 psi down to 300 psi over the course of the next ten days. On August 31, 2015, the pressure in in the K-03RD IA again increased to 980 psi. The production operators performed a bleed down to 140 psi in order to confirm that this increase was again thermal expansion. This time the pressure did not stay the same or fall but came back up to 700 psi. The well was closely monitored throughout the night. The well was shut in, and at 1:58 PM on August 31, 2015, an email was sent to Jim Regg and Chris Wallace at the AOGCC advising them that there might be a mechanical integrity issue with K-03RD, telling them that the well had been shut in, and that we wished to place the well back on injection so that we could conduct further diagnostics. This was all consistent the requirements of both 20 AAC 25.402 (f) and Rule 6 of AIO 5.000 and good oilfield practice. 3. AOGCC Request: "A description of the procedures and reporting responsibilities on how pressures are diagnosed to confirm an effect is thermal rather than a pressure communication." • • Cathy P. Foerster Docket Number: OTH-15-023 October 16,2015 Page 3 of 13 Hilcorp Alaska Response: Below are the steps that occur when a pressure change is observed on a casing annulus: OBSERVATION Twice during each 12-hour shift, Operator makes rounds to observe well operations and conditions. If Operator observes a pressure anomaly,Operator notifies his/her supervisor. EVALUATION OF PRESSURE ANOMALY Supervisor and Operator discuss and work to determine the cause of the pressure anomaly. Typically, the two main causes of pressure changes are thermal (rate changes, shutdowns, fluid temperature changes, etc.) or pressure communication (tubing holes, packer leaks, etc.). The approach is determined by the nature of the change. LARGER OR FASTER CHANGE A larger or faster pressure change (especially if it approaches and/or tracks the tubing pressure) indicates a likely pressure communication or leakage. The well is shut in and notifications are made to the AOGCC and the Hilcorp Alaska office. SMALLER OR SLOWER CHANGE A smaller or slower pressure change is suspected to have a thermal cause. The pressure is bled and the well is monitored. The type of fluid that comes off the backside is noted. If the pressure remains the same or begins to decline, the pressure change is believed to be thermal. The well continues in operation and Operator monitors the well. If the pressure returns and starts tracking the tubing, the change indicates likely pressure communication or leakage. The well is shut in and notifications are made to the AOGCC and the Hilcorp Alaska office. 4. AOGCC Request: "A detailed description of the Underground Injection Control (UIC) regulatory compliance program, with particular emphasis placed on how a pressure communication is determined, reported, and actioned internally, and reported to AOGCC." Hilcorp Alaska Response: Hilcorp Alaska's Cook Inlet UIC program is a people-based program. The program operates under the premise that the operators know their wells better than anyone. Therefore, the operators are the front line in recognizing if there is a change in casing pressures on any of their wells. They then bring any variations to their supervisor. Any well with indications of pressure communication or leakage is shut in and is reported to the AOGCC and the Hilcorp Alaska office. (See response to Item #3 above for actual steps in pressure change recognition and reporting.) The written notification to the AOGCC includes a request for permission to return the well to injection and conduct further diagnostics. To reinforce operator awareness, Hilcorp Alaska is in the process of providing training to all operators and field supervisory personnel on"Wellhead Pressure Monitoring and Mechanical Integrity."A copy of the slide deck is included as Attachment 4. • • Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 4 of 13 In addition to the daily surveillance, our Regulatory Compliance Manager performs a monthly check of TIO plots for active and shut in injection wells. This work is reported as required to the AOGCC in a monthly and/or quarterly filing. 5. AOGCC Request: "Full root cause analysis, including results and conclusions, addressing the failure to notify AOGCC of indications of pressure communication or leakage on TBU K-03RD." Hilcorp Alaska Response: Hilcorp Alaska's root cause analysis concludes that the reporting of the potential communication on K-03RD was correct under the guidelines of both AOGCC regulation 20 AAC 25.402 (f) and Rule 6 of AIO 5. Both the AOGCC Regulation and the Area Injection Order 5, Rule 6, state that if"operating pressure observation or pressure tests indicates pressure communication or leakage of any casing, tubing, or packer, the Operator must immediately cease injection, notify the Commission, and obtain approval for corrective action." The question here is what"indicates pressure communication or leakage." The mere fact of a change in pressure on a casing string does not in itself indicate that there is a pressure communication or leak. One or more other components must also be present, such as: (1) The pressure must be tracking the tubing pressure; (2) The pressure must return after a bleed; or(3) The annulus must be fluid packed. None of these other components existed in TBU K-03RD during the month of August 2015 until August 31, 2015: (1) The pressure did not track the tubing; (2) The pressure did not return after a bleed, rather it continued to fall as if thermally cooling; and (3) The annulus was not fluid packed. On August 31, 2015, conditions in TBU K-03RD changed. The pressure returned after another waterflood shutdown. But this time, the back side was fluid packed and the pressure did return after the bleed. After this observation—which indicated pressure communication or leakage—the platform personnel shut in the well and notified the AOGCC and the Hilcorp Alaska office of possible tubing by IA communication. 6. AOGCC Request: "Results of a review of each of the Hilcorp injectors authorized by AIO 05.000 and information relating to potential pressure communication, including the identity of injectors that have had annuli bled in the last 6 months." Hilcorp Alaska Response: Please see Attachment 5 (CD containing an Excel spreadsheet). Further Steps to Diagnose Pressure Anomaly Hilcorp requested permission to place the well back on injection in order to perform further diagnostics. Permission to do so has not yet been received. Hilcorp has performed the following steps in an effort to determine if communication does exist: • S Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 5 of 13 1. Taken apart the gauge pressure line to remove any debris in the line that could be affecting the pressure reading of the gauge. Debris was found in the line, so step #2 was added. 2. Added a second gauge at a different location to the IA so Operators can compare pressures between the two gauges to insure they are reading the true IA pressure. 3. Performed two separate one-hour, in-house MIT-IAs on the well, checking for pressure communication. The first MIT-IA (09/02/2015) did not show pressure stabilization, whereas the second MIT-IA (09/03/2015) showed pressure stabilization during the test period. See Attachment 6, record of in-house MIT-IAs using the AOGCC Form 10-426. At the time of this writing, there is conflicting data as to whether K-03RD has tubing by IA communication. Evidence of communication is the bleed on August 31, 2015, that showed pressured water to surface on the IA. Evidence of a lack of communication is the second in- house MIT-IA pressure test that passed the AOGCC requirements for a successful MIT-IA. Summary Both 20 AAC 25.402 (f) and Rule 6 of AIO 5 require that operating pressure observation or pressure tests indicate pressure communication or leakage of any casing, tubing, or packer as a condition for shutting in and notifying the AOGCC. Until thermal causes (which are very common in McArthur River Field operations) are discounted, there is no "indication" that there is a mechanical integrity problem with the well. A small pressure anomaly alone is not such an indication. Good oilfield practice in the McArthur River Field requires a trained and experienced crew to identify pressure anomalies and take the prudent step to determine whether the anomalies are thermally induced. Without the ability to exercise this operational judgment, our crews would be shutting in wells and notifying AOGCC every time there is an interruption in the waterflood which causes thermal pressure changes. * * Further diagnostics of the K-03RD pressure anomaly are needed before a final determination of mechanical integrity can be made. We request that we be allowed to return K-03RD to injection so thermal stability can be re- established so further diagnostics can be conducted, including an AOGCC witnessed MIT-IA pressure test. i 0 Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 6 of 13 Should you have any additional questions, please contact Larry Greenstein (777-8322 or lgreenstein@hilcorp.com). Sincerely, HILCORP ALASKA, LLC r b$Uhd OliktilS A David%. Wi ins Sr. Vice President Attachments as described above cc: Chet Starkel (w/attachments) Stan Golis (w/attachments) Ted Kramer (w/attachments) David Myers (w/attachments) Wayne Johnson(w/attachments) Larry Greenstein (w/attachments) i Cathy P. Foerster Docket Number: OTH-15-023 October 16,2015 Page 7 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 1 Plots and Data for K-03RD [See attached CD] • • Cathy P. Foerster Docket Number:OTH-15-023 October 16,2015 Page 8 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 2 Time Line of K-03RD Well Events DATE EVENT 10/23/14 Shutdown due to waterflood shutdown—5 minutes 11/23/14 Shutdown due to waterflood shutdown— 10 minutes 12/04/14 Swapped out K-03RD flow transmitter 12/05/14 Shutdown due to waterflood shutdown— 13 hours 01/24/15 Waterflood shutdown—5 hours 01/25/15 Waterflood shutdown— 1.5 hours 2/28/15 Raise waterflood injection to 3150 psi 3/9/15 Waterflood shutdown 1.25 hours 3/11/15 Shutdown due to production— 12 hours 3/30/15 Shutdown/ SSV bleed valve change out—5 minutes 4/1/15 Waterflood shutdown 6:35 hours 4/16/15 Waterflood shutdown 4/25/15 Waterflood shutdown 7:25 hours 5/2/15 Waterflood shutdown 1 hour 5/5/15 Waterflood shutdown 2 hours 5/20/15 Drilling hooked up to K-03RD for bop test 6/6/15 Waterflood shutdown 11 hours 6/22/15 Waterflood shutdown 1 hour 7/7/15 Waterflood shutdown 1.5 hours 7/19/15 Waterflood shutdown 10 minutes 7/22/15 Waterflood shutdown 15 minutes 7/23/15 Waterflood shutdown 1.15 hours 8/3/15 Waterflood shutdown 20 minutes 8/4/15 Casing pressure up to 640 psi 8/5/15 Waterflood shutdown 20 minutes 8/8/15 Waterflood shutdown 5 minutes 8/18/15 Waterflood shutdown 3.5 hours 8/19/15 Waterflood shutdown 8/29/15 Waterflood shutdown 15 minutes 8/30/15 Bled casing 980 to 140 psi 8/31/15 Shutdown due to increase psi on casing 8/31/15 Start to run checks on IA 8/31/15 Bled IA pressure down; well continued to build back up pressure, added pressure to IA and it immediately climbed up. Pressure stayed up overnight. 9/1/15 Realized pressure came up too fast and installed additional gauge at different location of IA. The new gauge would equalize with original gauge when bled off, • S Cathy P. Foerster Docket Number:OTH-15-023 October 16,2015 Page 9 of 13 but it did not see the pressure increase when pressure added by the original IA gauge. Determined there must be a blockage in the line with the original IA gauge in it. Closed the second 2" valve that has a handle and bled down the remaining original IA gauge pressure. Then removed the Y2" fittings and cleaned the junk out of the lines and put it back together. Looked at the other valve, checked it and found it closed. (This valve should only be closed if the second valve would not hold or if you need a double block. It has no handle and a cap has to be removed to add a handle to actuate it or use a pipe wrench on it.) Then opened all valves and saw that pressure was reading the same on both gauges when pressure was bled off or added. Changed where water was pumped in to pressure up the IA to a spot down by the new gauge. 9/2/15 Pressured up IA and sent a copy of MIT results to engineer in town. IA bled off additional 400-500 psi over course of the night. Communicated findings to town. 9/3/15 Received an e-mail from town wanting a drawing of the tree and a time line explaining what had changed, when waterflood had gone down and came back up. Received email from town with a copy of a letter from the AOGCC. Completed another MIT on IA and sent information to town. Started gathering change out notes and morning reports to develop time line. Worked on drawing for K-03RD tree. The pressure on IA bled off an additional 400-500psi over night after completing MIT. 9/4/15 Sent drawing of K-03RD tree as found to town along with a sequence of events from 8/3 (when increase first noticed) to 8/31 (when well was shut in and AOGCC notified). 9/4/15 Sent report from 8/31 (when well was shut in) to 9/4 to town with drawing showing added gauge, valve that was shut, bleed point, and %2" piping which was cleaned out. • • Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 10 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 3 K-22 Plot and Data [See attached CD] • • Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 11 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 4 Wellhead Pressure Monitoring and Mechanical Integrity Training Slide Deck [See attached CD] • • Cathy P.Foerster Docket Number:OTH-15-023 October 16,2015 Page 12 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 5 Review of Injectors Authorized by AIO 5.000 [See attached CD] • • Cathy P.Foerster Docket Number: OTH-15-023 October 16,2015 Page 13 of 13 Trading Bay Unit K-03RD (PTD 1801440) Docket Number: OTH-15-023 Hilcorp Alaska Response Attachment 6 K-03RD Form 10-426 MIT Report(In-House) STATE CF ALASKA ALASKA C CIL AND GAS C CNS@RVAT)CN CCIVMSSICN Mecharical Integrity Test SLbrritto:jimreggMlaskagov,POOCC.Irspecicrs ralaskagw, phoebe.brodcsinelaskagov ctris.vellaoerlaskagov OPERATOR: HlaipAlaska,I I C FIB-D/UJT/PAD NLFrtltr liver Field'TEO King Salmon icidiktrri DATE: 92/2015&9'312015 CPB?A70R REP: fele Wite/Kyle Esset AOGCC REP: Packer Depth Rist Initial 15 Mn. 30 Mn. 45 Mn. OD Mn. V�dl 14-03RD Tjpelrj. N MAD 9,057 Ttbing 2O 195 195 195 195 193 Ind 0 P.TD. 1801440 Type test P Test psi 2264 Casing 700 2350 2330 2310 2300 zzdJ pFF F Notes:In hose MTiooldrgkcrpassibleeorrrrxricar on 04 51 51 51 51 51 51 VIII K03RD Type Irl. N 1M) 9,057' liking 140 140 140 140 140 140 Interval 0 P.T.D. 1801440 Type test P Test psi 2:64 Casing 2420 2400 2380 2360 2345 2335 p/F. p Notes:Ratest locking for possible cx rnmuicaton Oq 51 51 51 51 51 51 VIII TypeIrj. IND Tubing Ir al P.T..D Tjpetest Test psi Casing RF Notes: 04 VIII Type Irj. TVD Tubing Interval P.TD. Type lest Test psi Casing RF Notes: 04 VIII Type10. Ty,D Tubing Ind PTD. Type test Test psi Casir9 P/F Notes: 04 TYFEINJCodes 7YFETFSrCodes IM13a/ALCocies D=DillirgWaste M=Amlrslltrrtaing I=titiaiTest G=Gas P=San:lard RessrreTest 4=Far Yea Cycle I=t istrial VVstavater R=herd f ricedi a Tracer 3.rvey V=Racjire 1lar Variance N=N1 bjedirx. A=Tenpe a treAnor aiy Survey O=Ober(desate in rides) W=V1Eta D=Dfferertial Te-rperatureT t • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, September 22, 2015 9:53 AM To: 'Larry Greenstein' Cc: Colombie,Jody 1 (DOA) Subject: RE:TBU K-03RD (PTD# 1801440) Pressure Communication Investigation - Docket OTH-15-023 Larry, AOGCC wants to ensure we get the most complete and accurate response to this investigation and so we approve your request to extend the response to no later than October 16, 2015. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Larry Greenstein [mailto:lgreenstein©hilcorp.com] Sent: Saturday, September 19, 2015 8:47 AM To: Wallace, Chris D (DOA) Subject: TBU K-03RD (PTD# 1801440) Pressure Communication Investigation Hi Chris, We've talked about this response letter before, in particular the well review in item#6 (all AIO 5.000 injection wells). We're compiling the info for the six items included in AOGCC's letter and it's seeming more difficult than first appeared. With shift workers, hunting/vacation trips,the number of wells to review/research (item 6), etc we may need some more time to complete all the tasks. Would it be possible to extend the time frame for our response a bit?? It's currently due Wed 9/30,would it be possible to move the deadline to 10/16?? We want to make sure we've collected all of the available info from all parties involved during the time of this well's apparent pressure communication. Thank you for considering this request. Larry 1 • • From: Singh, Angela K(DOA) [mailto:angela.singh@alaska.gov] Sent: Thursday, September 03, 2015 10:47 AM To: David Myers; David Wilkins; Thor Cutler(cutler.thor@epamail.eoa.gov); DOA AOGCC Prudhoe Bay; Larry Greenstein Cc: Wallace, Chris D (DOA); Carlisle, Samantha 3 (DOA) Subject: (Letter Scan) Hilcorp -TBU K-03RD, Pressure Communication Investigation Hi all, Please see attached. Thank you, Angela Singh Office Assistant II Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501-3572 907.793.1230 (phone) 907.276.7542 (fax) 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 Angela Singh at (907) 793-1230 or Angela.Singh@alaska.gov. 2 yoF 71d 7,N\\I/7 4,, THE STATE Alaska Oil ani. Gas f -.7,,,,OlAcp- _ --_---4w , 1 ,<A Conservation Commission gfitf. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 94,ALAS�'� Fax: 907.276.7542 www.aogcc.alaska.gov September 3, 2015 Certified Return Receipt 7015 0640 0006 0779 5586 Mr. David Myers Production Foreman Hilcorp Alaska, LLC. P.O. Box 244027 Anchorage, AK 99524-4027 Re: Investigation of reporting a pressure communication to AOGCC Trading Bay Unit K-03RD (PTD 1801440) Area Injection Order (AIO) 05.000 Trading Bay Unit (TBU), McArthur River Field, Hemlock and Middle Kenai G Oil Pools King Salmon Platform Docket OTH-15-023 Dear Mr. Myers: On August 31, 2015 Hilcorp Alaska, LLC (Hilcorp) notified the Alaska Oil and Gas Conservation Commission (AOGCC) by email that the well was potentially exhibiting tubing (T) by inner annulus (IA) pressure communication while injecting water and that Hilcorp had shut in the well. Hilcorp requested permission to complete some testing and to return the well to injection while monitoring. On August 31, 2015 AOGCC requested a 90 day injection pressure plot and timeline for the proposed testing. Hilcorp supplied the TIO plot on September 1, 2015 and notified the AOGCC that the well will continue to be shut in while a plan forward is established. On reviewing the raw data of the 90 day tubing, inner annulus, outer annulus (TIO) plot, the inner annulus pressure increases from 185 psi on August 3 to 640 psi on August 4, then to 920 psi on August 6, 2015. It then appears to decrease over time before another pressure increase occurs from 300 to 640 psi on August 19. Hilcorp ultimately notified AOGCC on August 31, 2015. Investigation of reporting a pressure communication to AOGCC TBU K-03RD September 3,2015 Page 2 of 3 AOGCC regulation 20 AAC 25.402 (f) states "If an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing tubing or packer, the operator shall notify the commission by the next working day... " Rule 6 of AIO 5 states "Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing tubing or packer, the Operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. " Pursuant to 20 AAC 25.300, the AOGCC requests the following additional information be provided by Hilcorp regarding their operations and operation of TBU K-03RD: 1. 12 month TIO raw data (excel format) and pressure plot identifying TIO pressures, injection rate, injection temperatures, and any bleed events; 2. A timeline of well events since a passing state witnessed MITIA on October 7, 2014 to present, and how Hilcorp responded to each potential pressure communication indication or event; 3. A description of the procedures and reporting responsibilities on how pressures are diagnosed to confirm an effect is thermal rather than a pressure communication; 4. A detailed description of the Underground Injection Control (UIC) regulatory compliance program, with particular emphasis placed on how a pressure communication is determined, reported and actioned internally, and reported to AOGCC; 5. Full root cause analysis, including results and conclusions, addressing the failure to notify AOGCC of indications of pressure communication or leakage on TBU K-03RD; and 6. Results of a review of each of the Hilcorp injectors authorized by AIO 5.000 and information relating to potential pressure communication, including the identity of injectors that have had annuli bled in the last 6 months. The information listed above should be provided to the AOGCC no later than September 30, 2015. The Commission reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Failure to comply with this request is itself a regulatory violation. • • Investigation of reporting a pressure communication to AOGCC TBU K-03RD September 3,2015 Page 3 of 3 Should you have any questions, please contact Chris Wallace at 907-793-1250. Sincerely, t)14 1a €44it-"L-. Cathy P. Foerster Chair, Commissioner cc: Thor Cutler, USEPA, Region 10 AOGCC Inspectors Larry Greenstein, Hilcorp Regulatory Manager RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[tlhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. U.S. Postal Service' w CERTIFIED MAIL° RECEIPT .D Domestic Mail Only co Il') For delivery information,visit our website at www.usps.com t11 Certified Mail Fee r% $ ® Extra Services&Fees(check box,add fee as appropriate) El Return Receipt(hardcopy) .D [3 Return Receipt(electronic) $__ Postmark In ❑Certified Mail Restricted Delivery $ Here O ❑Adult Signature Required $ ❑Adult Signature Restncted Delivery$ ® Postage $ -D Total Postage and Fees CI Mr. David Myers $ trf Sent To Production Foreman Hilcorp® Street and Apt No.,or p Alaska, LLC r` P.O. Box 244027 City,State,ZIP+4a Anchorage,AK 99524-4027 PS Form 3800,April 2015 PSN? SENDER: COMPLETE THIS SECTION CO,I^Lt I t THIS SECTION ON DELIVERY ® Complete items 1,2,and 3. A. Si. . Tgent ® Print your name and address on the reverse X so that we can return the card to you. ❑Addressee • Attach this card to the back of the mailpiece, ed b `r ted ame) Da of Nwary or on the front if space permits. -- /3 D. Is delivery address different fro tem 1? Yes If YES,enter delivery address elow: ❑ No Mr. David Myers Production Foreman Hilcorp Alaska, LLC 3 2015 P.O. Box 244027 Anchorage,AK 99524-4027 3. Service Type ❑Priority Mail Express® I "I'I'I I'll I"ll Il l iiii III l III II I II I III III 0 Adult Signature ❑Registered Mail ❑ dult Signature Restricted Delivery ElR Registered Mail Restricted eCertified Mail® ,Delivery 9590 9401 0057 5071 012? 37 Certified Mail Restricted Delivery Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery ❑Signature Confirmation'. 'sured Mail ❑Signature Confirmation 7015 0640 0006 f�L! rry 7®J 5586 sured Mail Restricted Delivery Restricted Delivery ver$500) PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Singh, Angela K (DOA) From: Singh, Angela K(DOA) Sent: Thursday, September 03,2015 10:47 AM To: 'dmyers@hilcorp.com'; 'dwilkins@hilcorp.com';Thor Cutler (cutler.thor@epamaiiepa.gov);AOGCC Inspectors (aogcc.inspectors@alaska.gov); Larry Greenstein (Igreenstein@hilcorp.com) Cc: Wallace, Chris D (DOA) (chris.wallace@alaska.gov);Samantha Carlisle (samantha.carlisle@alaska.gov) Subject: (Letter Scan) Hilcorp -TBU K-03RD, Pressure Communication Investigation Attachments: Hilcorp -TBU K-03RD, Pressure Communication Investigation.pdf Hi all, Please see attached. Thank you, Angela Singh Office Assistant II Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501-3572 907.793.1230 (phone) 907.276.7542 (fax) 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 Angela Singh at (907) 793-1230 or Angela.Singh@alaska.gov. 1 i 41110 Wallace, Chris D (DOA) From: David Myers <dmyers@hilcorp.com> Sent: Tuesday, September 01,2015 5:50 AM To: Wallace, Chris D (DOA) Cc: Dan Marlowe;Ted Kramer;Jeff Allen; Stan Golis Subject: RE: K-3RD Injector PTD# 1801440 Attachments: K-3RD prod plot.xlsx Chris we are going to get our well head specialist out and check tree and surface stuff first.Will leave well shut in and once we decide plan forward with diagnostics down hole will let you know before we do anything and a time frame we will complete it in. David L Myers Production Foreman Hilcorp Alaska, LLC King Salmon Platform Work: (907)776-6690 Fax: (907)776-6695 dmyers*,hilcorp.com From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday, August 31, 2015 3:32 PM To: David Myers; Regg, James B (DOA) Subject: RE: K-3 Injector David, Please provide a TIO plot for the last 90 days for this well. What exactly is the plan forward with estimated timeframe for completing these actions? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: David Myers [mailto:dmvers@hilcorp.com] Sent: Monday, August 31, 2015 1:58 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Subject: K-3 Injector 1 • . Gentleman we believe we have a Mechanical Integrity problem with K-3 injector on the King Salmon.We have shut the well in and would like permission to do some testing on well to try and resolve the issue.This would require us to return well to injection while monitoring. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .~? ~_~- }/"Z/ ~/ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type ~ Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: BY: BEVERLY ROBIN VINCENT~)MARIA WINDY Project Proofing BY: ~~:~OBIN VINCENT SHERYL MARIA WINDY Sca~nning Preparation BY: BEVERLY ROBIN<~~HERYL MARIA WINDY [] Logs of various kinds [] Other '" 181 TOTAL PAGES Production Scanning /~ Stage l PAGE COUNT FROM SCANNED FILE: . PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~/"/YES f' NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked 12/10/02Rev3NOTScanned.wpd • �. OF Tb ,,91",'',1///>4',s, THE STATE Alaska Oil and Gas �fALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue nh OS�F• Anchorage, Alaska 99501-3572 Main: 907.279.1433 `1 �� p,t V\ Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer Hilcorp Alaska. LLC Q' 3800 Centerpoint Drive, Suite 100 Q Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools, Trading Bay Unit K-03RD Sundry Number: 313-632 Dear Mr. Kramer: 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, /977K- Cathy P. oerster Chair DATED this OUday of December, 2013. Encl. '''k t RECEIVED STATE OF ALASKA Okr DEC 0 6 201' ALASKA OIL AND GAS CONSERVATION COMMISSION frITS 121 I (3 APPLICATION FOR SUNDRY APPROVALS ,AOGC 2Q AAC25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate 0 Pull Tubing D • Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Aker Casing❑ Other. Convert to Infector 0 ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development E ' 180-144 • 3.Address: 3800 Centerpoint Drive,Suite 100Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20074-01 ' 7.If perforating: •7144 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? f4f - Cp c,/Zg'A Will planned perforations require a spacing exception? Yes ❑ No O I Trading Bay Unit/K-03RD 9.Property Designation(Lease Number): 10.Field/Pool(s): , ADL0018777 • McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 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): • 13,413 - 9,839 13,300 • 9,753 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,506' 13-3/8" 2,506' 2,346' Intermediate 10,983' 9-5/8" 10,983' 8,059' Production Liner 2,735' 7" 13,395' 9,825' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 3-1/2" 9.2#/N-80 12,470 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker FHL Packer&Camco TRDP 1-A SSSV 12,392'(MD)9,074'(ND)&265'(MD)265'(ND) 12.Attachments: Description Summary of Proposal 0 • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: 12/26/2013 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 , 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 Ted Kramer Email tkramer(a)hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature CSF d--7-----...--`,----... Phone (907)777-8420 Date 12/6/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \3 ^(1:1 3 Plug Integrity ❑ BOP Test iMechanical Integrity Test VLocation Clearance ❑ 'L Other: 4'2506 / 3c) 6%1P —r;:s+- RBD MAY Q 9 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /d — / 0 7 APPROVED BY Approved by: Ail, 7442474 COMMISSIONER THE COMMISSION Date: /Z -ZQ _ /3 J l Submit Form and Form 10-403(Revised 10/2012) Approv a pf\c ti iI li V /.r 1 nths from the date of approval. Attachments in Duplicate 11 Well Work Prognosis Well: K-03RD Application Date: 12/06/13 HilcorpAlaska,LU Well Name: K-03RD API Number: 50-733-20074-01 Current Status: Oil Producer(SI) _ Leg: Leg#4 (NW corner) Estimated Start Date: December 26, 2013 _ Rig: Moncla Rig 404 Reg.Approval Req'd? 10-403 _ Date 10-403 submitted: Regulatory Contact: Juanita Lovett Permit to Drill Number: 180-144 First Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Second Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: (907) 398-9904 Status: Shut In Gas-lift Producer Objective: Pull Gas-lift Completion, remove packer and screen,Clean out to PBTD. Perforate G-Zones 1 through 5 and 7,and Hemlock Zones 1, and 3 through 7. Run 4-1/2"tubing&packer for injection service Brief Well Summary: The K-03rd well is a Shut In GAS-LIFT producer that was shut-in in 2007 due to poor gaslift and low rates (<50 bopd & 98%water-cut). This well was last worked over in 1997 to recover a fish and access the upper G-zone. There has been /8 no injection support in the area since 2011. I cO"Gr/', Piool oct i pw dee( 4 M 20-30494 LI near too14 44,41 f4 €d n0 /1cc AOR(status of wells within 1/4 mile radius of injection zone): fie �,1. .'ha 1 , API_WeIlNo Permit WeilNumber CurrentStatus Zonal isolation(method) 50733200740100 1801440 K-03RD 1WINJ(proposed) Good cement, CBL/VDL 5/5/81 �(/ 50733201490100 1980990 G-15RD 1-OIL Good cement, USIT log 3/16/07 f �0� 50733202590000 1740080 K 19 1 OIL Estimated TOC@7370' bV? (1.t� 41/ The last calculated SBHP was completed in 1998. Slight reservoir voidage has occurred since then. it/ Estimated SBHP: 3499 psi @ 9636'(TVD) mid perf Max expected BHP:3583 psi(given higher wcut) Max.Anticipated Surface Pressure: 0 psi Well will not flow based on an expected oil and water gradient of.437 psi/ft. Procedure: 1. Jet-cut tubing just above packer(mid 8' pup at 12387') 2. Move In and Rig up Moncla 404 Pulling unit. 3. Circulate hydrocarbon off the well to production 4. ND Wellhead, NU bop and test to 250 psi low/ 2,500 psi high (Note: Notify AOGCC 24 hours prior to conducting BOP test to allow them the opportunity to witness). 5. POOH with tubing string and GAS-LIFT mandrels laying down the same. V 6. PU Workstring. RIH with assembly to mill packer&recover tail-pipe. " 7. RIH with 9-5/8"clean out assembly and cleanout to 13394' (bottom perf=13167'). POOH with C/O Assembly. . 8. PU RIH with Test Pkr.To 11,780' +/-(8,618 TVD). Set PKR.And pressure test casing to 2,200 psi. for 30 min. Chart same. POOH with RTTS. 9. Change hole over to clean fluid, PU TCP guns and RIH with same. 10. RU E-line and Run in tubing with GR,CCL and correlate TCP guns on depth. (top= 12408') Fire Guns. " 11. Pick up guns above perforations. Shut down(+/-) 1 hour monitoring fluid level with Echometer. 12. Once the well is stable, POOH with TCP guns. 13. PU RIW W/4-1/2"x 9-5/8" packer on 4-1/2"polycor production tubing to 11,800'and set injection packer. 14. Pressure test back side t psi. a_—)' Z.Zoo P Sc. 1 3 p p..v,.., 15. Hang off tubing. ND BOP,NU wellhead and test. 71 /2-47./.? . LSPs y - Well Work Prognosis Well: K-03RD Flilcorp Alaska,LLC Application Date: 12/06/13 16. Turn well over to operations. z. 0 pfd Tisa 17. RDMO Moncla 404 Pulling unit. 18. Within 2 weeks of stable injection, schedule an Initial MIT to test upper packer with AOGCC. Provide the AOGCC 24 hour notice prior to the MIT test. All pressure test results and completed 10-426 are to be provided to Larry Greenstein immediately following the test. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current/Proposed Wellhead Diagram 4. BOP Drawing N a, Y to N C u E o co O 0 m LL ao oo N V ti N C O _.-•O m O m "p 0- O (.9C .E coC ._ a, C to J V J 3 O to CD C J c C @ fl Y 0 0 p 0 0 a, V 4U ilU p td, iU J O -oof ttl v m - Y «+ 9 7 F— O (.4 O V Y N i F- i i m 1 o U p I Q LL LL��i;yu+ N N W a` Yg R >_ r cv f S a w 0, 8 o = N iii r 1 to 0 �'' t 21 U o S 2 :ai \ .- Y . N Y • J a C _ A. �r s W I N Y I tea.- -- —_ ---1- -_-- -- - - - ----I-- - -_ - - Y ao 1 Y /c.5 IA Y O: K I I I 7 I I I 1 McArther River Field, TBU 14 SCHEMATIC Well: K-3RD As Completed: 3/26/1985 Hulcorp Alaska,LU. CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to Hanger=35' 13-3/8" 61 K-55 Butt LT&C 12.515 38' 2506' 9-5/8" 47 N-80/S-95 LTC/BTC 8.681 38' 10983' o t- 1 7 29 N-80/S-96 6.184 10660' 13395' 3111, �� , TUBING DETAIL • ''jV�V 3-1/2" 9.2 N-80 BTC 2.992 38' 12470' JEWELRY DETAIL 2 No Depth ID Item 0 FMC Tubing Hanger,4-1/2"w/pup&X-O to 3-1/2"BTC 3 1 265' 2.817 3-1/2"Camco TRDP 1-A SCSSV 2 2,639' 2.867 3-1/2"Otis type TRU w/1/4"Port w/R-20 valve w/RA Latch 4 3 5,728' 2.867 3-1/2"Otis type TRU w/1/4"Port w/R-20 valve w/RA Latch 4 7,906' 2.867 3-1/2"Otis type TRU w/5/16"Port w/R-20 valve w/RA Latch 5 5 9,589' 2.867 3-1/2"Otis type TRU w/5/16"Port w/R-20 valve w/RA Latch III 61.6G 6 10,423' 2.867 3-1/2"Otis type TRU w/5/16"Port w/R-20 valve w/RA Latch X r 7 / \X 7 10,830' 2.867 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch 11 V 8 L 8 10,867' 2.867 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch MID � 9 9 11,456' 2.867 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch — 10 - 11 04/4„ 10 11,494' 2.867 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch -? , 1.4 _ 11 11,931' 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch 13 14 Paler depth is 12 11,968' 3-1/2"Camco type KBUG w/5/16"Port w/BK-2 valve w/BK Latch X 12,356'CBL c 15 13 12,368' Baker PBR w/X-O's 14'long. \ x\ /f 1 14 12,383' 8'X 3-1/2"BTC pup jt. 7-- � ,4 0 Restriction tagged on 15 ' 12,392' Top of Packer,7"Baker FHL w/70,0008 shear 7-- /O<G @t2 2.65'LIB w/'265WLM 16 12,399' Btm of Packer ','•mset 17 12,461' 2.75 3-1/2"'D'Nipple,Camco 16 _ — 12,470' 3 Btm of tbg tail G-5 177 PERFORATION DETAIL B-0 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 0-5 12408 12460 9086 9124 52' 2 6/20/1996 B-1 B-0 12530 12565 9176 9202 35' 4/8 B-2 8-1 12605 12620 9232 9243 15' 4/8 8-2 12634 12664 9253 9275 30' 4/8 B-3 12680 12700 9287 9302 20' 4 B-4 8-3 12745 12760 9335 9346 15' 4/8 r -- B-7 • 12769 12799 9353 9375 30' 4 8-4 12808 12820 9382 9391 12' sqzd V 12820 12880 9391 .9435 60' 4/8 PBTD=13,300' TD=13,413' 8-7 13134 13164 9626 9649 30' 4/8 MAX HOLE ANGLE=56°@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' .. li PROPOSED Trading Bay Unit Well # K-3RD Completion Date 3/26/85 Ililcorp Alaska,LLC CASING DETAIL RKB to Hanger=35' SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt LT&C12.515 38' 2506' 1 9-5/8" 47 N-80/5-95 LTC/BTC 8.681 38' 10983' 7" 29 N-80/S-96 6.184 10660' 13395' TUBING DETAIL Poly4-1/2" 12.6# L-80 3.40 38' ±11,818' Linedrosy BTC JEWELRY DETAIL No _ Depth ID Item 0 FMC Tubing Hanger,4-1/2"w/pup&X-O to 3-1/2"BTC 1 ±300' 2.817 SS5V 2 ±11,800' Packer 3 ±11,808' Pup Joint 4 ±11,809' X-Nipple 5 ±11,817' Pup Joint 6 ±11,818' WLEG PERFORATION DETAIL Zone Top Btm Top Btm Amt SPF Date L , (MD) (MD) (TVD) (ND) ,. G-1 ±11,986' ±12,003' ±8,771' ±8,783' 17 Future G-1 ±12,018' ±12,081' ±8,795' ±8,842' 63 Future G-3 ±12,168' ±12,212' ±8,907' ±8,940' 44 Future ' G-4 ±12,212' ±12,283' ±8,940' ±8,993' 71 Future +56 '`�‘� G-5 ±12,375' ±12,462' ±9,061' ±9,126' 87Future G-5 12,408' 12,460' 9,086' 9,124' S2' 2 6/20/1996 G-7 ±12,533' ±12,592' ±9,178' ±9,222' S9 Future -G-1 B-0 12,530' 12,565' 9,176' 9,202' 35' 4/8 G-3 B-1 ±12,592' ±12,622' ±9,222' ±9,244' 30 Future G4. B-1 12,605' 12,620' 9,232' 9,243' 15' 4/8 B-2 ±12,633' ±12,714' ±9,252' ±9,312' 81 Future G-5 B-2 12,634' 12,664' 9,253' 9,275' 30' 4/8 G-7 B-2 12,680' 12,700' 9,287' 9,302' 20' 4 B-0 B-3 ±12,743' ±12,804' ±9,334' ±9,379' 61 Future __ B 1 8-3 12,745' 12,760' 9,335' 9,346' 15' 4/8 - 6-3 12,769' 12,799' 9,353' 9,375' 30' 4 B-2 = 8-4 ±12,804' ±12,910' ±9,379' ±9,458' 106 Future B-3 8-4 12,808' 12,820' 9,382' 9,391' 12' sqzd B 4 B-4 12,820' 12,880' 9,391' 9,435' 60' 4/8 B-5 ±12,938' ±13,007' ±9,479' ±9,530' 69 Future B-5 B-6 ±13,025' ±13,116' ±9,544' ±9,613' 91 Future B-6 - B-7 13,134' 13,164' 9,626' 9,649' 30' Re-Pert B-7 PBTD=13,300' TD=13,413' Fill Tagged w/2.80"GR on 6/17/96 @ 13,156'WLM MAX HOLE ANGLE=56°@ 4,100'MD ANGLE @ PERFS.=43° KOP @ 300' Updated by: JLL 12/03/13 . El King Salmon Platform K-03RD Current Hikorp Akukr.LUL 12/06/2013 King Salmon Tubing hanger,FMC-UH- K-03R0 TC-1A-EN,13 5/8 5M X 4'A 24 X 13 3/8 X 9 5/8 X 3 1/2 IBT lift and susp,w/4"type IS BPV,Non cont control line port,Alloy BHTA,B-11-A-0, 41/16 SM FE iilligr. ,:;1616 cipiii..,,•••, Valve,Swab,WKM-M, 41/16 5M FE,HWO,EE trim 1,176 Valve,Wing,SSV, OCT-75,4 1/16 5M FE, 13"MHA oper,EE trim N /° _ / Valve,Master,WKM-M, 7.... 4 1/16 5M FE,HWO,EE trimisitTaft MI Adapter,FMC-ASP,13 5/8 5M API clamp X 41/16 5M,w/7" Iextended neck pocket Unihead,OCT type 3,13 5/8 SM API _ hub top X 13 3/8 BTC casing bottom, =, I w/1-2 1/16 5M SSO on lower ' section,1-2 1/16 5M SSO on middle section,3-2 1/16 5M 5SO on upper IIli -velli = ?' section,IP internal lockpin assy Ii SIM 11.. ' 1:, I' _ ' " Asir ' - i :e.'11101111,:-.11! '2 Emergency slips and packoff 1.Ld _I on 9 5/8 casing _ S'I • 41. Fill k :ill 1 Starting head,FMC, !6o- - 21''A2MX24"SOW, I w/1-31/82MEF0 1.1 WI��'.0 lU24" 13 3/8" L _ 9 5/8" 3'A" King Salmon Platform K-03RD Proposed 12/06/2013 Hilcarp Alaska.1.IA: King Salmon Tubing hanger,FMC-UH- K-03RD TC-1A-EN,13 5/8 5M X 4 24 X 13 3/8 X 9 5/8 X 4 1/2 TC-2 lift and susp,w/4" type H BPV,Non cont control line port,410 SS BHTA,Bowen,4 1/16 5M FE X 7"SA Bowen top,FF trim —8-- 1•114114.11111.1.1 1.1110114 Mt Valve,Swab,WKM-M, 41/16 SM FE,HWO,FF trim Valve,Wing,SSV, WKM-M,41/16 5M FE, 1■01■ 11.1 _ 15"Safeco oper,FF trim N . J P.S. l.. Valve,Master,WKM-M, 41/16 5M FE,HWO,FF OA trim - IIuI -T�inn Adapter,FMC-A5P,13 5/8 5M API clamp X 4 1/16 5M,w/7" 4 A`_ • E extended neck pocket �/ IN Unihead,OCT type 3,13 5/8 SM API I hub top X 13 3/8 BTC casing bottom, I I w/1-2 1/16 5M SSO on lower section,1-2 1/16 5M SSO on middle �� ' section,3-2 1/16 SM SSO on upper ti ', section,IP internal lockpin assy i' II iI� �� la I' • a„ - �• CjlMp. 1 Emergency slips and packoff = It/ ` on 9 5/8 casing II ji C. . i: ) 4 Starting head,FMC, _ u – o 1F3 212MX24"SOW, w/1-3 1/8 2M EFO Y.. 1 `/ ss r , Ami I. 24" _133/8" _ 9 5/8" 4'A" Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program —Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP.As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross)and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each,as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. Moncla Rig 404 BOP Test Procedure Hileorp Alaska,►Lc Attachment#1 ii) Valves, 3,4,9. After test,open valves 3&4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5&6, leave 9 closed. iv) Valves,7,8,9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR,close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2,and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW(or Lower Kelly Valve)and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. c . . Moncla Rig 404 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 Diagram A-1: King Salmon BOP stack and Riser Arrangement—Typical for Single Completion 0 0 1 111 III III Ill ill ill III i 3.74• Shaffer 13 5/8 5M I I 1 111 111 - WRIT LIT t ening CIW-U • Variable 2 7/8-5 46 7' IIi.II __13 5/8-5000 Blind Rams fit.I • Ell if h ithifli Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses I- - ///LLLiii 135/8-Soon =i: 2.00' i� , 4��=74I ' — = ' �Q: i, IF I 6111 11.111 liJilij[1=li Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' II Moncla Rig 404 BOP Test Procedure HileorpAlaska,LLC Attachment#1 Diagram B: King Salmon Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves ■„ iiIm ,il !drai 3.• _______ „,..,:, ,i, II, 1O 1' Chokes are 90 degrees off :411 . in drawing in order to show 1 detail 1m„ _ II : .I��: .1 I_ III rinillitil I III 161614 161.6 Swaco :,Mi: 061 I 11E41 HIM li -I \ WM ' II Olir MN O.' 1:1 7. t" From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 1/4' Ball port,6000psi working pressure #2 National Ball Valve B3260, 3 IA" Ball port,6000psi working pressure #3 National Ball Valve B2650,2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 'A" Ball port,6000psi working pressure #10 National Ball Valve B1560, 1 '/2" Ball port, 6000psi working pressure i .. II Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 U Je$ is,• Vw 2 2 ,, a I .. •7 ,T('l' it' M. A f �. • � m j ` 1 II lit?—: `-am ` CI o a H L- E zo Q r r U E µ 111. u_ 0 a zco_ H 00 H ❑ O U 0_ b — 0.Dd DO 0 Z_ s0 ou O_ C- H c' M� aU` HZJ DO (>4 OW aX a o W V U dct l O O U Q O N (,w D oa - r D 411 JOZW Xa LLZHa Q J D U a U Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 04 tx1 /J4 V w z � J "i T U w dG Ft 1 I=II II ., Q a ry E a d = J J r z • o0 (7 — D4 D4 0 Q z V ,;V Mo 011' - Ll 5- O V az a c� � S- Q m0--0 < txWzo sa - z A m opo c, LL Fw �w = a. a=z _J0p g .� I J i . Ei King Salmon Platform 2013 BOP Stack(Moncla) Hach Moats,IAA: 09/19/2013 . ;, it i1 tfn al tfll al II 3.74' Shaffer I11 111 111111 Iii I 11111 III III IIIIIill _ -L cMr-u 4.67' ■ _... _�I 13 5/8-5000 f 8,llil r= Blind Rams Ali, Iil.1i1 Iii iil 111 Choke and Kill Valves 2 1/16 5M w/Unibolt connections for �� III 111 I1I I11 III hoses it 2.00• �I. 4ii 0111i19.641• _ - }1 :01111; `� • lil lil lil lil til ' III III III 111 III Riser,13 5/8 5M FE X 13 5/8 SM API#13 hub 13.70' ììrE í J ;1 i[, LJL::J fþ ,þ U FRANK H. MURKOWSK/, GOVERNOR AI,ASKA OIL AlVD GAS CONSERVATION COMMISSION February 25, 2005 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit K-03RD, PTD 180-144 Dear Mr. Johnson: On January 10, 2005 AOGCC Petroleum Inspector Chuck Scheve witnessed a "no flow test" at Unocal's King Salmon platform, Trading Bay Unit Well K-03RD. The well was opened to atmosphere through flow measurement equipment with suitàble range and accuracy and monitored for several hours. The well demonstrated no flow at surface. The subsurface safety valve may be removed from service in Well K-03RD based on this no-flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platform. Sincerely, ~ ---- :~ ~"" \: \ , ~\6.~q JamesB.Regg II Petroleum Inspection Supervisor cc: Bob Fleckenstein SCANNE[) FEB 2 8 2005 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg?~1 tlZA/th P. I. Supervisor DATE: January 10, 2005 FROM: Chuck Scheve, Petroleum Inspector King Salmon Platform SUBJECT: No Flow Trading Bay Unit K3RD PTD# 1801440 Mondav, Januarv 10, 2005: I traveled to Unocal's King Salmon Platform and witnessed a no-flow test'on well K3RD. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was shut in and observed for several hours with no pressure build up observed and no flow when reopened. I recommend Well K3RD on the King Salmon Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well K3RD meets the AOGCC requirements for no flow status. SCANNED MAR 11 2DD~s Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Friday, July 28, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well K-3rd APl No. 50-733-20074-01 10-404 Reperforate Hemlock and G-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the reperforation of the G5 HBO and HB1 benches in well K-3rd. The following intervals were perforated on 7112~00: Bench Top Bottom Feet HB1 12,605 12,620 15 HBO 12,530 12,565 35 G5 12,408 12,460 52 Total: 102 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager RECEIVED AUG 1 7 2000 Aiaska 0~'~ ~ ~as Cons. Comn~i~ion .... 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 COMPANY OF CALIFORNIA (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-6247 Stratigraphic: Trading Bay Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 729' FSL & 130' FEL, Sec. 17, T9N, R13W, SM K-3RD At top of productive interval 9. Permit number/approval number 2168' FSL & 1633' FEL, Sec. 19, T9N, R13W, SM 80-144 At effective depth 10. APl number 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM 50- 733-20074-01 At total depth 11. Field/Pool 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13,405 feet Plugs (measured) 13,282' true vertical 9,831 feet Effective depth: measUred 13,282 feet Junk (measured) 13,168' true vertical 9,739 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,506' 13-3/8" Yes 2,506' 2,346' Intermediate 10,983' 9-5/8" Yes 10,983' 8,059' Production Liner 2,735' 7" Yes 13,395 9,823' Perforation depth: measured 12408'-12460'; 12530'-12565'; 12605'-12620'; 12634'-12664'; 12680'-12700' 12745'-12760'; 12820'-12880'; 12945'-13012'; 12134'-13164' true vertical 9085'-9124'; 9176'-9202'; 9232'-9242'; 9253'-9275'; 9287'-9302' 9335'-9346'; 9390'-9435'; 9470'-9521 '; 9626'-9649' Tubing (size, grade, and measured depth) RECE VEO 3-1/2", 9.2#, N-80 BTC @ 12,470' Packers and SSSV (type and measured depth) Oamco TRDP I-A-SSSV @ 265', Baker FHL packer @ 12,399 13. Stimulation or cement squeeze summary AUG Intervals treated (measured) AJas. k~ 0~i & Gas Co~,s. Com:13Js=ion An. ch0cage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 133 258 1510 220 130 Subsequent to operation 109 246 1204 220 130 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed:~A Title: ~//4t,/~//~'t~/4 ,~i~, Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzeil, -~.~. ,.a~,'~FILE NO: P. I. Supervisor ~, Chuck Scheve, ~ $ SUBJECT: Petroleum Inspector DATE: April 18, 1997 lujkdree. DOC No Flow Test McArthur River Field King Salmon Platform Wells K-2, K-3 & K-23 ~-~'l~, ~ ~ .{ ~{ rt Friday April 18,1997: I traveled to Unocals King Salmon Platform and a NO-FLOW test on Wells K-2, K-3 & K-23. The subject Wells had been bled down prior to my arrival on the platform. The wells were lined up to open top drums via a 1/2" hose and observed for !_h0ur with no fluid flow observed. Well K-2 had a minor amount of gas flowing from the hose~it was then shut in and slowly built 30 PSI over a 1 hour period. The pressure bleed off instantly when opened to atmosphere. I recommend approval of NO-FLOW status for these Three wells SUMMARY: I witnessed a successful NO-FLOW test on Unocals K-2, K-3 & K-23 Wells ( King Salmon Platform ) in the McA~hur River Field. X Unclassified Classified Unclassified with Document Removed Unocal Corporation P.O. Box 196247 AnChorage, Alaska 99519 907-263-7676 UNOCAL ) G. Russell $chmidt Drilling Manager Tuesday, March 26, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell' KING SALMON WELL K-3RD Attached, please find form 10-404 detailing the recent coil tubing operations on the subject well. If you have any questions, please contact the undersigned at 263-7676 or Dan Williamson at 263-7677. G. Russell Schmidt Drilling Manager GRS/leg STATE OF ALASKA ALASKA 0IL)AND GAS CONSERVATION MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-6247 Stratigraphic: Trading Bay Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 729' FSL & 130' FEL, Sec. 17, TgN, R13W, SM K-3RD At top of productive interval 9. Permit number/approval number 2168' FSL & 1633' FEL, Sec. 19, T9N, R13W, SM 80-144 At effective depth 0RiGIN,/ L 10. APl number 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM 50- 733-20074-01 · At total depth 11. Field/Pool 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13,405 feet Plugs (measured) 13,282' true vertical 9,831 feet Effective depth: measured 13,282 feet Junk (measured) 13,168' true vertical 9,739 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,506' 13-3/8" Yes 2,506' 2,346' Intermediate 10,983' 9-5/8" Yes 10,983' 8,059' Production Liner 2,735' 7" Yes 13,395 9,823' Perforation depth: measured 12408'-12460'; 12530'-12565'; 12605'-12620'; 12634'-12664'; 12680'-12700' 12745'-12760'; 12820'-12880'; 12945'-13012'; 12134'-13164' true vertical 9085'-9124'; 9176'-9202'; 9232'-9242'; 9253'-9275'; 9287'-9302' 9335'-9346'; 9390'-9435'; 9470'-9521 '; 9626'-9649' Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 BTC ~ 12,470' Packers and SSSV (type and measured depth) Camco TRDP I-A-SSSV @ 265', Baker FHL packer @ 12,399 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 3/12/96 83 40 1 460 1220 100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Servi ~ ~ ~, ~., 17. I ,hereby certify that the foregoing is true and correct to the best of my knowledge: , Signed: Title ~-t (_,L. t~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE K-03RD DAY 01 (2/28/96) TRAVEL TO PLATFORM AND BEGIN PREPARATIONS FOR CTU CLEANOUT/FISHING OPERATION. CLEARING DECKAREA. CTU EQUIPMENT TO ARRIVE VIA BOAT THIS AFTERNOON. DAY 02 (2/29/96) CONTINUE PREPARATIONS FOR CTU WORKOVER. CLEAR WORKING AREA. UNLOAD BOAT AND SPOT EQUIPMENT. DAY 03 - 05 (3/01-02/96) RIG UP AND PRESSURE TEST EQUIPMENT PER UNOCAL SPECS. MU BHA #1 (2.8" BIT, MOTOR, CIRC. SUB AND DISCONNECT) AND RIH. HAD DIFFICULTY PASSING 2682' CTM (GLM @ 2639'). STOP CIRCULATING, SLACK OFF 2000 # AND PASS THROUGH. CONTINUE IN HOLE AND TAG FISH @ 11379' CTM. SHEAR REVERSING SUB, CIRCULATE BOTTOMS UP AND POOH. UNABLE TO PASS 2653' CTM. RIH TO LEAVE BHA ON TOP FISH. UNABLE TO PASS 10750' CTM (NEAREST GLM$10423' AND 10830'). DISCONNECT AND POOH WI CT. NO PROBLEMS PASSING 2653'. SHUT DOWN FOR NIGHT. DAY 06 (3/04/96) POOH W/NO RECOVERY. RE-RAN PULLING TOOL AND ATTEMPTED TO RECOVER FISH W/O SUCCESS. REPAIRED PACK-OFF. PICKED UP HALLIBURTON/OTIS PULLING TOOL (NEWER CONDITION). TAG FISH @ 10758' AND CHASE TO 11353'. RECOVERED ENTIRE COIL TUBING BHA FISH. RAN COIL TUBING WASH PIPE ASS'Y W/2.8" SHOE AND TAG W.L. FISH AT 11390'. CHASE AND PUSH TO 11740'. DAY 07 (3/05/96) CHASE W.L. FISH TO 11740' AND WASHOVER W/VVASH ASSY. POOH. SLICKLINE PULLED PRONG AND PLUG BODY. DAY 08 (3/06/96) RAN 2.7" GAUGE RING THRU TBG TAIL AND TAG FILL @ 12539' WLM. RECEiv A~&¢-:2 .nF & 6~,s Cor!~. Oil & Gas Operations 909 West 9th Avenue, x 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) October 19, 1995 Alaska Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: King Salmon Platform Well No. K-3RD APl Number $0-733-20074-01 On June 7, 1995 the following intervals were perforated in Well K-3RD: BENCH TOP (MD) BOTTOM (MD) FEET HB5 12,945 13,012 67 H B 7 13,134 13,164 30 TOTAL 97 Very truly yours, 0CT 2 $ ~995 /? , /~ AisSk~ 0il & Gas Cons. Commissi0, /~, ~/:~'~- ~ ~ Anchorage Candace Williams Attachment ~) STATE OF ALASKA Mi~! ALASKA O.iL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Operations performed: Operation shutdown Stimulate Plugging =iiii ~ iiii Pull tubin~l After casin~l Repair well 5. Type of Well: Development ~ UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory m 3. Address Stratigraphic __ P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service 4. Location of well at surface 729' FSL & 130' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 2168' FSL & 1633' FEL, Sec. 19, T9N, R13W, SM At effective depth 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM At total depth 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM 12. Present well condition summary Total depth: measured 13,405 true vertical 9,831 feet Plugs (measured) feet Perforate X Pull tubing Other 6. Datum elevation (DF or KB) 100' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number K-3RD 9. Permit number 80-144 10. APl number 50-733-20074-01 11. Field/Pool MoArthur River/Hemlock 13,282' Effective depth: measured 13,282 feet true vertical 9,739 feet Junk (measured) 13,168' Casing Length Size Cemented Measured depth True vertical depth Conductor Surface 2,506' 13-318" Yes Intermediate 10,983' 9-5/8" Yes 10,983' 8,059 Production Liner 2,735' 7" Yes 13,395' 9,823' 13. 14. Perforation depth: measured true vertical 12,408'-12,460'; 12,530'-12,565'; 12,605'-12,620'; 12,634'-12,664'; 12,680'-12,700'; 12,745'- 12,760'; 12,820'- 12,880'; 12,945'- 13,012'; 13,134'- 13,164' 9,085'-9,124'; 9,176'-9,202'; 9,232'-9,242'; 9,253'-9,275'; 9,287'-9,302'; 9,335'-9,346'; 9,390'-9,435'; 9,470'-9,521'; 9,626'-9,649' Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 BTC ~ 12,470' Packers and SSSV (type and measured depth) Camco TRDP 1-A SSSV (~ 265'; Baker FHL pkr. ~ 12,399' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OCT 2,5 i99,5 Alsska 0il & Gas Cons. C0mmiss' Anchorage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Pdor to well operation 6/7195 293 63 875 1100 110 Subsequent to operation 6115/95 381 23 1,476 1180 1- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the for~in~lis tru~Tlc~rr<:_~t~..~est of my knowledge. ISigned G. Russell Schmidt ~ ./~,~.¢)i.,%Ir~e Ddlling Manager Form 10-404 Rev 06/15188 120 Service SUBMIT IN DUPLICATE Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 March 7, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ORISINAL Dear Mr. Douglas: On August 26, 1994 the following intervals were perforated in well K-3RD (AP150-733-20074-01) in the McArthur River Field: BENCH TOP (MD) BOTTOM (MD) FEET G5 12,408 12,460 52 TOTAL 52 Sincerely, STATE OF ALASKA REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X_ Pull tubing __ Alter casing__ Repair well __ Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 Location of well at surface 729' FSL & 130' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 2168' FSL & 1633' FELl, Sec. 19, T9N, R13W, SM At effective depth 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM At total depth 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KB 100' above MSL 7. Unit or Property name Trading Bay Unit 8. Well number K-3RD feet 9. Permit number/approval number 80-144 10. APl number 50-733-20074-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13405 true vertical 9831 Effective depth: measured 13282 true vertical 9739 feet Plugs(measured) 13282 feet feet Junk (measured) 13168 feet ORIGINAL Casing Length Structural Conductor Surface 2506' Intermediate 10983' Production Liner 2735' Perforation depth: measured Size Cemented Measured depth True vertical depth 13-3/8" Yes 2506' 2346' 9-5/8" Yes 10983' 8059' 7" Yes 13395' 9823' 12408 - 12460, 12530 - 12565, 12605 - 12620, 12634 - 12664, 12680 - 12700, 12745 - 12760, 12820 - 12880, 13134 - 13164 13. true vertical 9085 - 9124, 9176 - 9202, 9232 - 9242, 9253 - 9275, 9287 - 9302, 9335 - 9346, 9390 - 9435, 9626 - 9649 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 BTC @ 12470' Packers and SSSV (type and measured depth) E FI: ! V I: 13 Camco TRDP 1 -A SSSV @ 265'; Baker FHL pkr. @ 12399' . ....... Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR 2 0 ]995 AJaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Represent~NeDailyAverage Production orl~ection Data OiI-Bbl Gas-Mcf W~er-Bbl Casing Pressure 172 ~/103 534 1030 480 .~188 1296 1150 Tubing Pressure 140 150 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run__ I Daily Report of Well Operations __ Oil X_ Gas ~ Suspended __ 1Si~ieh~re~e~r e~~rrec~t~ IO~ h .~e b e s~~fL~y~, kc~n~i~l ~,~g eA~ ~-i~ Form 10-404 Rev 06/15/88 Service SUBMITIN DUPLICATE ~/ Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL( Alaska Region Ralph P. Holmaa Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 15, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well K-3RD (API# 50-733-20074-01) on the King platform. BENCH .TOP (MD) BOTFOM (MD) G5 12,408 12,460 FEET TOTAL 52 RECEIVED AUG 2 4 1994 Alaska Oil & Gas Cons. Commission Anchorage ~' STATE OF ALASKA . ALASI~~ '~IL AND GAS CONSERVATION COq, MISSION APPLIC . 'ION FOR SUNDRY Al ) ROVALS 1. Type of reqUest: Ab;~don ~ Suspend __ Operatior~ shutdown __ Re-enter suspended well__ Alter casing__ Repair well __ Plugging M Time extensionm Stimulate __ Change approved program m Pull tubing ~ Variance __ Perforate X_ Other 2. Name of Operat(x 5. Type of Well: 6. Datum ele~/ation (DF or KB) Unocal Oevaopment X_ KB: 100' above MSL ~to./~ feet. 3. Address SuaUgraph~ __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 sense __ Trading Bay Unit 4'. LocatiOn of well at s~rface ' ' '8. Well number 729' FSL, 130' FEL, Sec. 17, T9N, R13W, SM K-3RD At top of productive Interval R E C E iV E D 9. Permit number 2168' FSL, 1633' FEL, Sec. 19, T9N, R13W, SM 80-144 At effective depth AUG 2 4 1994 10. AP~number 1948' FSL, 2080' FEL, Sec. 19, T9N, R13W, SM 50-733-20074-01 At total depth Alaska 0ii & Gas Cons. Commission 11. Field/Pool 1914' FSL, 2152' FEL, Sec. 19, T9N, R13W, SM Anchorage McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13405 feet Plugs (measured) 13282 true vertical 9831 feet Effective depth: measured feet Junk(measured) 13168 ORIGINAL true vertical feet Casing Length Size Cemented Measured depth True vertiCal depth Structural Conductor Surface 2506' 13-3/8' Yes 2506' 2346' Intermediate 10983' 9-5/8' Yes 10983' 8059' Production Liner 2735' 7' Yes 13395' 9823' Perforation depth: measured 12530-12565, 12605-12620, 12634-12664, 12680-12700, 12745-12760, 12820-12880, 13134-13164 true vertical 9176-9202, 9232-9242, 9253-9275, 9287-9302, 9335-9346, 9390-9435, 9626-9649 Tubing (size, grade, and measured depth) 3-1/2', 9.2#, N-80 BTC @ 12470' Packers and SSSV (type and measured depth) Camco TRDP 1 -A SSSV @ 265'; Baker FHL pkr. @ 12399' 13. Attachments Description summary of Proposal X_ "Detailed operations programX__ BOP sketch __ Questions? Call John Paul McKee @ 263-7680 or Ralph Holman @ 263-7838 14. Estimated date for commencing operatiOn 15. Status of well classificatiOn as: August 26, 1994 16. If proposal was verbally approved Oil X_ Gas ~ Suspended __ Name of approver Date approved Service 17. I hereb, f certi~/that the_ ~qreg~ing j~ true and c^orrect to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify CommissiOn so representative may witness I Appro~N?; Plug Integrity _ BOP Test LocatiOn clearance _I -/'-( - Mechanical Integrity Te~__. S-'~bsequent form required 10- ~ Original Signed By Approved by the order of the Commission 'avid W. Johnston CommissiOner Date ~/"~-~/~ Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT I~ 'UCATE August 19, 1994 King Platform, Well K-3RD Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. e Pressure test lubricator to 2500 psi for five minutes... Note: A pump-in sub with a valve is required. 4, 5~ . Shut down all welding and radio transmissions. ,Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) e Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL ~ G-5 12,408-12,460 52 TOTAL: 52 Unocal North American Oil & Gas Division ~"· Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region November 5, 1993 Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Ms. Miller: This is to inform you that ~ell K-3RD on the King platform (API# 50-733-20074-01) was perforated in the following int~ BENCH TOP-MD BOTTOM-MD HBO 12,540' 12,560' HBI 12,605' 12,620' HB2 12,634' 12,664' HB2 12,680' 12,700' HB3 12,745' 12,760' HB3 12,770' 12,800' HB4 12,830' 12,870' Ralph P. Holman Engineer Technician ~xas~,a D~ & Gas Cons. commission Anchorao~e ~. STATE OF ALASKA ~ ALASKA' ,l. AND GAS CONSERVATION CO ~ISSION - REPORT OF SUNDRY WELL OPERATIONS 1. Operabons performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X_ Pull tubing __ Alter casingm Repair well m Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 729' FSL & 130' FEL, Sec. 17, T9N, R13W, SM At top of productive interval 2168' FSL & 1633' FELl, Sec. 19, T9N, R13W, SM At effective depth 1948' FSL & 2080' FEL, Sec. 19, T9N, R13W, SM At total depth 1914' FSL & 2152' FEL, Sec. 19, T9N, R13W, SM 5. Type of Well: Development X_ Exploratmy Slmtigraphic __ 6. Datum elevation (DF or KB) KB 100' above MSL 7. Unit or Property name Trading Bay Unit 8. Well number K-3RD 9. Permit number/approval number 80-144 10. APl number 50 -733-20074-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured 13405 true vertical 9831 feet feet Plugs(measured) 13282 Effective depth: measured 13282 true vertical 9739 feet Junk (measured) 13168 feet Casing Length Structural Conductor Surface 2506' Intermediate 10983' Production Liner 2735' Perforation depth: measured Size Cemented Measured depth 13-3/8" Yes 2506' 9-5/8" Yes 10983' 7" Yes 13395' 12530 - 12565, 12605 - 12620, 12634 - 12664, 12680 - 12700, 12745- 12760, 12820 - 12880, 13134- 13164 True vertical depth 2346' 8059' 9823' true vertical 9176 - 9202, 9232 - 9242, 9253 - 9275, 9287 - 9302, 9335 - 9346, 9390 - 9435, 9626 - 9649 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 BTC @ 12470' Packers and SSSV (type and measured depth) Camco TRDP 1 -A SSSV @ 265'; Baker FHL pkr. @ 12399' 13. Stimulation or cement squeeze summary RECEIVED NOV 1 5 199;5 Intervals treated (measured) Treatment description including volumes used and final pressure Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representmive DailyAverage Productionorlnjection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 299 580 583 952 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_ Gas __ Suspended __ Service 17. I herq~y certify that the foregoing is true and correct to the best of my knowledge. Signed ~_.!~~ Title'~tL, Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, , · In conducting an audit of well files i have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. To be in compliance with AS' 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversati.~ concerning the subject, it had beeq~explained to me that either ARCO or Marathon had been th6 ~'~operatOr on the majodty of the work proposed; however, itis the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on file can'be marked accordingly..'., ._ . Sincerely, · · Statistical Technician {~) p~inled on rec%,~:led paper b y .. ~i'**'.' .;-'.. " Well Permit No. No. D-4 82-41 D-5RD 80-65 D-26 74-9 D-27 75-24 D-40' ' 82-83 D-42 D-46 83-53 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit Description Perforate 2-91 Perforate 5-91 Workover 4a91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 . Scale Cleano~t 6-20-91 Berf 5-91 Reperf EB-2 11-91 10-403 Signed By. G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush · G. Bush 'G-5 67-71 G-6 82-33 3/15-91, 91-086' 10-30-91, 91-325 4-21,92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this well. Perf. 10-19-91 Perf 4-92 G. Bush -. G..Bush G. Bush G-17 78-3 G-19 69-17 G-21 72-42 · . G-27 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 '80-144 K-9 68-38 11-1-91, 912331 11-10-92, 92,238 4-21192, '92-094 6-17-93, 93-154 4-21'92, 92-95 1-6-93, 92-203 · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate G. Bush Temp. log 10-15-92 Perf. 4-92 Coil tubing cleanout Perforate Convert to inj. G. Bush. Production profile G. Bush Perforate 2/90 R. Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSIO~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 AUGUST 3, 1992 GARY BUSH UNION OIL COMPANY OF CALIFORNIA P O BOX 190247 ANCHORAGE, ALASKA 99519 DEAR~MR. BUSH, OUR FILES INDICATE THAT UNION OIL COMPANY OF CALIFORNIA IS THE. OPERATOR OF THE FOLLOWING WELLS MENTIONED IN THIS LETTER. WE .ARE REVEIWING WELL FILES FOR MISSING 404 SUNDRY WELL OPERATION FORMS. SEVERAL 403 (SUNDRY APPROVALS) HAVE BEEN APPROVED FOR WORK ON THESE WELLS AND OUR FILES DO NOT REFLECT THAT THE WORK WAS ACCOMPLISHED. WOULD YOU PLEASE LOOK INTO THESE WELL SUNDRYS SO WE CAN CLOSE THEM OUT EITHER BY SUBMITTING THE APPROPRIATE 404 FORM WITH ATTACHMENTS FOR COMPLETED WORK OR A NOTE STATING THAT THE 403 APPROVAL NUMBER IS VOID. THE APPROVAL NUMBER IS ON THE SIGNED COPY OF THE 403 THAT AOGCC SENT BACK TO THE OPERATOR. WELLNAME PERMIT' 403 APPROVAL # TRADING BAY UNIT D-5RD TRADING BAY UNIT D-12RD GRANITE PT ST 17568 8 TRADING BAY UNIT K-3RD 80-0065 91-163/7-514 80-0082 92-054 80-0084 91-87 80-0144 90-081 PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THE PROPER FORM IN A TIMELY MANNER. IF THERE IS SOMEONE ON YOUR STAFF THAT I COULD CONTACT PLEASE GIVE ME THERE NAME AND PHONE NUMBER. THIS IS GOING TO BE AN ON GOING PROCESS JUST LIKE THE PLUG AND ABANDON WELLS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST Unocal No~h Ameri Oil & Gas Division Unocal Comor~lon P.O. Box 19024? Anchorage. AlasKa 99519-02,*7 Teiepnone tg0~ Alaska Re~j~on April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, kK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, ~a ~S.c~Ush. ' Regional Drilling Manager GSB/lew ~ OIL AND GAS CONSERVATION COMM ~ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend _ Operation Shutdown _ Re-enter suspended well Repair well _ Plugging _ Time extension _ Stimulate _ Alter casing _ Change approved program 2. Name of Operator UNOCAL Corporation Pull tubing _ Variance _ Perforate _~. Other _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ (ARCO Alaska. Inc. is sub-oDeratorl 3. Address I P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 729' FSL & 130' FEL, Sec. 17-T9N-R13W-SM At top of productive interval 2168' FSL & 1633' FEL, At effective depth 1948' FSL & 2080' FEL, At total depth 1914' FSL & 2152' FEL, Sec. 19-T9N-R13W-SM 12. Present well condition summary Total Depth: Sec. 19-T9N-R13W-SM Sec. 19-T9N-R13W-SM 6. Datum elevation (DF or KB) measured 1 3 4 0 5' feet true vertical 9 8 31 ' feet Effective depth: measured 1 3 2 8 2' feet true vertical 9 73 9' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) Junk (measured) Length Size Cemented 2506' 1 3-3/8" yes 1 0 9 8 3' 9-5/8" yes 100' KB above MS[, 7. Unit or Property name Trading Ba~t Unit 8. Well number K-3RD 9. Permit number 8o-144 10. APl number 50-733-20074-01 11. Field/Pool Hemlock 2735' 7" yes measured 12530-12565' ; 12605-12620' ; 12745-12760'; 12820-12880'; true vertical 13282' 13168' Measured depth 9176-9202'; 9232-9242'; 9253-9275'; 9287-9302'; 9335-9346'; Tubing (size, grade, and measured depth 3-1/2", 9.2#, N-80 BTC @ 12470' MD Packers and SSSV (type and measured depth) Camco TRDP 1-A SSSV @ 265' MD; Baker FHL packer ~ 12399' MD 13. Attachments Description summary of proposal _ Detailed operation program Proposed perforations attached. 14. Estimated date for commencing operation 15. February, 1990 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~, ~.~ Title Envi ronmental Engi neet Ro,yz D~ Rol~erts FOR ~ISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test t Location clearance m Mechanical Integrity Test m Subsequent form require 10-~-~/~ feet 2506' 10983' 13395' 12634-12664' ; 13134-13164' 9390-9435'; Status of well classification as: Oil X Gas 2346' 8O59' 9823' 12680-12700' 9626-9649' TVD BOP sketch Suspended _ Date 2/8/90 IApproval No . Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED B'v LON~,.I. e, Approved Copy J~et~rned zlq iqO Commissioner SUBMIT IN TRIPLIC^TE SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-3RD (February, 1990) 1. RU E-line unit. 2. Perforate the following intervals under draw-down conditions: Run No. Bench lnterv~l (MD-CBLI Interval (MD-DIL) I 7 13131-13161' 13134-13164 2 4 I 2847-1 2867' 12850-12870 3 4 I 2827-1 2847' 12830-12850 4 3 I 2767-1 2797' 12770-12800 5 3 I 2742-1 2757' 12745-12760 6 2 I 2677-1 2697' 12680-12700 7 2 I 2631 -1 2661 ' 12634-12664 8 1 I 2602-1 261 7' 12605-12620' 9 0 I 2537-1 2557' 12540-12560' Note: 3. Lubricator will be pressure tested to 2500 psig prior to each run. RD E-line unit and lubricator. Lenath* -- 30 20 20 30 15 20 3O 15 20' 200' SPF RECEIVED ;:Eu 0 8 Anchoraga E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead DML 7/22/88 STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COM, ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator UNOCAL (ARC0 Alaska, Inc. is sub-operator) 3. Address Post Of f i ce Box 190247 4. Location of well at surface 729' FSL & 130'FEL, Sec. 17-TgN-R13W-SM At top of productive interval 2168' FSL & 1633' FEL, Sec. 19-TgN-R13W-SM At effective depth 1948' FSL & 1633" FEL, Sec. 19-TgN-R13W-SM At total depth 1914' FSL & 2152' FEL, Sec. 19-TgN-R13W-SM Anchorage, AK 99519 5. Datum elevation(DF or KB) 100' KB above HSL 6. UnitorPropertyname Trading Bay Unit 7. Well number K-3I~D 8. Approval number 7-999 9. APl number 50--733-20074 10. Pool Hem lock Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2506' Intermediate 10983 ' Production Liner ": i"~2735 ' Perforation depth: measured 13405' feet 9831' feet 13282' feet 9739' feet Size true vertical Tubing (size, grade and measured depth) 13-3/8" Plugs (measured) 13282 ' Junk (measured) 13'i96' Cemented Measured depth True Vertical depth 9-5/8" 7" yes 2506' 2346' ,yes 10983' 8059' yes 13395' 9823' (see attached) RECEIVED 12. -l./2"hn~SVB-80 BTC @ 124.70' MD acKers ~Type ana measurea aepth)- ,Camco TRDPI-A SSSV @ 265' MD; Baker FHL Packer @ 12399' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 151 94 85 500 724 502 425 960 Tubing Pressure 80 140 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Roy D. Roberts Signed Title Env i romenta I En,q i neer Form 10-404 Rljv. 124-85 Submit in Duplicate DAILY REPORT OF WELL OPERATIONS TBU WELL K-3RD The following perforations were added to well TBU K-3RD in January, 1988: Re-Perforations Zone Interval {MD) Length {MD) Interval (TVD) 0 12530-12560' 30' 9176-9198' 1 12606-12620' 14' 9232-9242' 2 12634-12654' 20' 9253-9268' TOTAL = 64' New Perforations Zone Interval (MD) Length (MD) 0 12560-12565' 5' 1 12605-12606' 1' 2 12654-12664' 10' 2 12680-12700' 20' 3 12745-12760' 15' 7 13134-13164' 30' TOTAL = 81' TOTAL FOOTAGE = 145' Interval (TVD) 9198-9202' 9231-9232' 9268-9275' 9287-9302' 9335-9346' 9626-9649' FEB - NOTE: Lubricator was pressure tested to 2500 psi prior to perforating. ,/ STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well Fq, Alter casing ,~ Time extension [] Change approved program I-] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate I~ Other [] 2. Name of Operator UNOCAL (ARCO Alaska, Inc. 3. Address Post Office Box 190247 is sub-operator) Anchorage, AK Location of wellatsurface 729' FSL & 130' FEL, Sec. Attop of productiveinterval 2168' FSL & 1633' FEL, Sec. At effective depth 1948' FSL & 2080' FEL, Sec. Attotaldepth 1914' FSL & 2152' FEL, Sec. 17-T9N-R13W-SM 19-T9N-R13W-SM 19-T9N-R13W-SM 19-T9N-R13W-SM 99519 5. Datum elevation(DF or KB) 100' KB above MSL 6. Unit or Property name Tradin9 Bay Unit 7. Wellnumber K-3RD 8. Permitnumber 80-144 9. APInumber 50-- 733-20074 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 13405' feet 9831' feet Plugs (measured) 13282 ' Effective depth: measured 13282 ' feet true vertical 9739 ' feet Casing Length Size Structural Conductor Surface 2506 ' 13-3/8" Intermediate 10983 ' 9-5/8" Production .... Liner 2735' 7" Perforation depth: Measured: 12530'-'12560'; 12606'-12620'; Junk (measured) 13196 ' Cemented Measured depth Rue Verticaldepth yes 2506' 2346' yes 10983' 8059' yes 13395 ' 9823 ' 12634'-12654'; 12820'-1~.,(~~ True 9176'-9198'; 9232'-9242' 9268'; 9390'-9435' TubingV~lTzte! ~ld~ and measured depth) , 9253'- 3-1/2", 9.2//, N-80 BTC @ 12470' MD Packers and SSSV (type and measured depth) Camco TRDPI-A SSSV @ 265' MD; Baker FHL [~acker 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Proposed perforations attached. 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Date approved Form 10-403 Rev 12-1-85 15. I hereby certify that the fore~q~ng is true and correct to the best of my knowledge _ Roy D. Roberts · '~-"~'---- ~ Signed ~/~¢./¢_~¢_~,'-~]./~,:Z:,,~ ~ Title Environmental Engineer Date /2 ~/¢~--'7 ~ ~/~ Commission Use Only Conditions of approval ~otify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearanceI ~"' ? ~'¢'~ Approved Copy ~1~' ~ ~ , ,~ ,1. .I Retu FRed ~ SI611ED BY by order of Approved by I _ta*~._ C. ~ Commissioner the commission Date/~,~-~,~/&: ~ (.~.~._~:~. Submit in tril SUMMARY OF PROPOSED PERFORATIONS TBU WELL K-3RD (December, 1987) Re-Perforations Zone Interval (MD) Length (MD) Interval (TVD) 0 12530-12560' 30' 9176-9198' 1 12606-12620' 14' 9232-9242' 2 12634-12654' 20' 9253-9268' TOTAL = 64' New Perforations Zone Interval (MD) Length (MD) 0 12560-12565' 5' 1 12605-12606' 1' 2 12654-12664' 10' 2 12680-12700' 20' 3 12745-12760' 15' 7 13134-13164' 30' TOTAL = 81' TOTAL FOOTAGE = 145' Interval (TVD) 9198-9202' 9231-9232' 9268-9275' 9287-9302' 9335-9346' 9626-9649' NOTE: Lubricator will be pressure tested to 2500 psi prior to perforating. '~' .... NIL STATE OF ALASKA...... ~ ~~ ~L ALASKA AND GAS CONSERVATION C~r~UlSSlOU L COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o{ Well. . ~ Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ...... , · 2. Name Of Operator 7. Permit Number Union 0il Company (ARCO Alaska, lnc. is sub-operator) 80-144 3. Address 8. Apl Number . 909 W. 9th Ave., Anchorage, AK 99501 50- 133-20074 4. Location of well at surface King Salmon P1 atform, Leg #4, Conductor #32 9. unit or Lease Name 729' FSL, 130' FEL, Sec.17, TON, R13W, SM Trading Bay Unit At Top Producing Interval 1'01 We'll Number 3226' FNL, 1628' FEL, Sec.19, TON, R13W, SM K-3 RD At Totai Depth 11. Field .and Pool 3481' FNL, 2152' FEL, Sec.19, T9N, R13W, SM McArthur River Field 5. ElevatiOn in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. I-leml ock KB 100 'MLLW ADL 18777 12. Date Spudded 13. Date T.D; Reached 14. Date Comp., Su-~p. or Aband. IlS. Water Depth, if offshore t16. No. of Completions 02/21/81 04/27/81 05/22/81'I N/A .... feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back DePth (MD+TVD) 19. Directional Survey 20, Depth where sssv ~et 21. Thickness of Permafrost 13,413'MD 9839'TVD 13,300'MD 9752'TVD YES [] NO [] 254' feet MD N/A 22. Type Electric Or Other Logs Run See attached. 23.. ....... CASING, LINER AND CEMEN.~!NG RECORd.. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 9-5/8" 47.0# N-80 ........ Ol.d..We] ] bot.;r" 2646' 9-5/8" 47.0# ~-80/S-95 0 10,983, . !2-1/4" 1000 sx Class G. None 7" ,29.0# ~-80/S-95 10,559' 13,395~ 871/2" .800 SX,C1 ass G None ..~ , ~. ,,, ..., , ,.. , . , . - ~ -., ................. ,. *, ~ ...... 24. Perforations open to Production iMD+TvD of Top and Bottom and 25. TUBING RECORD , 'interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 12,824'-1 2,854'MD 3-1/2,' 12~470' .. .12,391 ' (9393 '-9416'TVD) w/4 spf, 180° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD). AMOUNT & KIND OF MATERIAL USED 12,859'-12,871'HD See attached for. W~l] Hi.story, 9419'-9428'MD) for Frac~ur.e data ..... w/4 spf, 120° phasing Soueeze data eon'c'rl ~n ~eeR~.h~_H , 27. N/A PRODUCTION TEST Date First Production Me~hod of Operation (Flowing, gas lift, etc.) 05/21/81 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE SIZE I GAS-OIL RATIO 05/22/81 12 TEST PERIOD I~ 7.52 2.27 0 OpenI 302 SCF/STB Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF W~,TER~BBL OIL GRAVITY-APl (corr) Press. 120 1075 24-HOUR RATE I~ 15.04 4.54 0 34.7 . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED z, 1987 ~laska 0. ~ oas Cons. Com~ssion ~Note: We]] was worked over & perforated 03/29/85. Anchorage , Form 10-407 Rev. 7-1-80 WC2:031 :DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~ 29. :, 3©. GEOLOGIC MARKE'RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovere~:i MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G Marker 11,565' 8477' None G-1 Bench 11,979' 8780' Hemlock 12,528 ' 9192 ' West Foreland 13,170' 9672' ,:. ,, 31. LIST OF ATTACHMENTS Workover Well Hi story. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge '?''' Signed 7'f'~.~"Y.?-"~' Title Enviro~tal F~g]I~ate. 3/2/87 · '~C- ~' 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-;tern 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 the location of the cementing tool. 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 Well Completion or Recompletion Report Trading Bay Unit Well Number K-3 (cont.) RD Item 22. Type Electric or Other Logs Run (cont.) DIL/Sonic/Cal, CNL/FDC/GR, CBL, FDC/DIL/BHC/GR, DIL/BHC/GR, Computer Processed Log, BHC/Sonic/DIL/GR, BHC/Sonic/DIL/GR, FDC/CNL/GR, Baseline Temp Log/GR/CCL, GR/CCL CNL/DIL/BHCZCal, CNL/ DIL/SP, CNL/DIL/BHC/GR, Multishot gyro (3 methods) Item 26. Depth Interval (MD) 10,750 13,342 10,395 10,560 12,710 12,767 12,808 -12,797' & -12,877' Amount & Kind of Material Used 135 sx Class G 45 bbl s mud 58 bbls mud 195 sx Class G 100 sx Class G 275 sx Class G WC2/031 'ARCO 011 and Gas Company Well History - Initial Report - Dally Instruction: Prepare and submit the "Initial RelN~rt" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field MacAr thur River Auth. or W.O, no. APE 496219 PDC/.ARCO #58 0 pe rat o r ARCO Alaska, Inc. Spudded or W.O. begun ICounty, perish or borough North Slope Borough Lease or Unit ADL # 18777 Title Workover API # 50-733-20074 IState Alaska jWell no. [-3RD IARCO W.I. 12.90% Prior status if a W.~.. Workover IHour 3/13/85 0930 Hrs. Date and depth as of 8:00 a.m, Complete record for each day reported 3/14/85 3/15/85 3/16/85 thru 3/18/85 3/19/85 3/20/85 7" Lnr @ 13,393' Accept ri$ @ 0930 hrs, 3/13/85. Kill well pmp'g dn ann thru GLV up tbg. ND tree, NU BOPE, pull BPV, MU tst jr. 7" Lnr @ 13,393' 13,293' PBTD, PU DP 8.5 FIW NU & tst BOPE. Unsting tbg f/pkr, circ, POH, LD tbg. DP. RU to PU 7" Lnr @ 13,393' 13,293' PBTD, POOH w/pkr 8.5 FIW MU pkr milling assy, RIH, mill on pkr, POOH & LD pkr. RIH w/6" bit & scrprs, CO well to 13,232' PBTD, POOH. MIRU WL unit, rn gage ring to 13-270' WLM. Set retnr @ 12,940' WLM. RD WL unit. MU cmt sqz assy, RIH, spot 100 sx C1 "G" cmt plug on retnr @ 12,950' DPM. Bradenhead sqz well w/50 sx of cmt, leaving 50 sx in csg. Max sqz press = 5000 psi. POOH w/cmt sqz assy. 7" Lnr @ 13,393' 13,293' PBTD, WOC 8.5 FIW POOH w/sqz assy; btm 7 jts of tbg cmt'd, pack-off was not in safety jr. RIH w/bit & scrpr, tag cmt @ 12,337' -- too high. Drl soft cmt to 12,748', circ & WOC. 7" Lnr @ 13,393' 13,232' PBTD, RIH w/RTTS 8.5 FIW WOC. Drl firm cmt f/12,748'-12,810'. Tst upper perfs to 3000 psi; OK. Drl firm cmt f/12,810'-12,920'. Tst upper & lower perfs to 3000 psi; OK, POOH. RIH w/RTTS, set pkr bet upper & lower perfs @ 12,815' DPM. Tst backside to 3000 psi; OK. Tst below to 4200 psi, took 1/4 BPM. POOH, PU 2-7/8" tbg & RTTS, RIH. The abovo is correct For form preparation and dlstributl~t~, see Procedures Manual, Section 10F Drilling, Psges 86 and 87. Date [ Title 4/Ol/85 Drilling Superintendent ' ~ ARCO Oil and Gas Company {~. Daily Well History--Interim Instructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska ICounty or Parish IState North Slope Borough Alaska ILease or Unit IWell no. ADL #18777 [ K-3RD MacAr thur River Date and depth as of 8:00 a.m, 3/21/85 3/22/85 3/23/85 thru 3/25/85 3/26/85 Complete record for each day while drilling or workover in progress 7" Lnr @ 13,393' 13,232' PBTD, WOC 8.5 FIW RIH w/RTTS cmt sqz assy, spot cmt plug w/75 sx C1 "G" w/l% D-28, .3% D-31 & .1% D-6. POOH 6 stds, rev circ DP dln. Set RTTS @ 11,845', sqz away 1.5 bbls of cmt @ 6000 psi -- held 6000 psi f/1.5 hrs. Bleed press, POOH w/cmt sqz assy. RIH w/CO assy, RU frac equip while WOC. 7" Lnr @ 13,393' 13,232' PBTD, Rn GR log 8.7 w/3% KCL RIH w/CO assy, tag top of cmt @ 12,546' DPM, wsh & rm cmt to 12,586', drl firm cmt to 12,810'. Press tst csg & Bench #3 perfs (12,767'-12,797') to 3000 psi; OK. Drl cmt to 12,920', press tst csg & Bench perfs #3 & #4 (12,767'-12,797' & 12,808'-12,877') to 3000 psi; OK. Rev circ hole cln. RU & rn TemP/GR/CCL tl f/11,400'-12,904', rn GR f/12,904'-12,000'. 7" Lnr @ 13,393' 13,232' PBTD, POOH 8.7 w/3% KCL Fin rn'g GR f/12,000-11,400', RD loggers. PU 4", 4 SPF, 120° phasing perf gun, perf 12,864'-12,871' & 12,859'-12,864'. RIH w/Champ II pkr, set @ 12,845', tst to 2500 psi; OK. Acid wash well by pmp'g 24 bbls 15% HC1 acid dn DP @ 4 BPM/1300 psi, followed by 15 bbls KC1 fluid & 75 bbls WF5 gel. Unseat pkr & reset bet Bench 3 & Bench 4 perfs @ 12,815'; press tst ann & DP. Set pkr above Bench 3 perfs @ 12,667' , press tst ann & DP. Reset pkr @ 12,815'. Treat w/5 stage invertafrac treatment (235 bbls total. Frac Bench 4 perfs (12,859'-12,871') w/448 bbls gel pad, followed by 7 stage frac w/279 bbls, 3700# sand & 18,250# ISP. Displ w/FIW @ 5.5 BPM/6800 psi. Rn post frac Temp/GR/CCL logs, tag sand @ 12,590', POOH. Open by-pass, rev circ, POH w/Champ II pkr & LD. RIH w/bit & JB, tag 20/40.sand @ 12,851'. Wsh sand f/12,851'-12,920', drl cmt to 12,950', DO 7" EZSV retnr f/12,950'-12,952'. POH f/post frac logging. 7" Lnr @ 13,393' 13,282' PBTD, Off load compl string 8.7 w/3% KCL POH. RU WL unit, rn Temp/CCL f/11,400'-13,100' WLM. Rn GR/CCL f/13,100'-12,500' WLM, RD WL unit. RIH w/bit & scrpr to 13,282' PBTD, POOH, LD DP. Offload completion string. The above is correct Signature ~~ For form preparation and dij~ribution see Procedures Manual Section 10, Drilling, Pages 86 and 87' [Date ]Title ~ :"~ £' ~ ' .~,,,~ ~ ' ,~ 0il & Gas Cu~. ~m~u Anch0ra0o ARCO Oil and Gas Company Daily Well History--Interim Instru'ctiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and dept, as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit MacArthur River ADL # 18777 Complete record for each day while drilling or workover in progress 3/27/85 3/28/85 3/29/84 IState Alaska JWell no. 7" Lnr @ 13,393' 13,282' PBTD, MU Camco SSSV & tst same 8.7 w/3% KCL Offload compl equip. POOH, LD DP. RU & rn 395 jts, 3½" compl assy. 7" Lnr @ 13,393' 13,282' PBTD, RR 7~/~ Rn 402 jts, 3½", 9.2#, N-80 BTC tbg w/Il GLM's & TT @ t-2~'. Lnd tbg. Set pkr & tst. PU & shear PBR. Re-lnd tbg & re-tst. ND BOPE, NU tree. Turn well over to Production @ 1900 hrs, 3/27/85. FHL Pkr @~,~-,~' PBR @ 12,369', "D" Nipple @ 12,460', SSSV @ 254' IZ~ ~1' 7" Lnr @ 13,393' 13,282' PBTD, Rig Repair Lift & unload well f/drawdn. MIRU WL unit. RIH, perf f/12,824'-12,854' w/2-5/8", 4 SPF, 120° guns. RD WL unit. Compressor dn, unable to lift well. RFC, iVED Gas Cons. C0mm,.s,~.n The above is correct Signature For form preparation and distribu~n see Procedures Manual Section 1~, Drilling. Pages 86 and 87 ID ate 4/01/85 ITitle Drilling Superintendent ARCO Oil. and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District 1County or Parish Alaska I North Slope Borough Field ~Lease or Unit MacArthur River I ADL #18'777 Auth, or W.O. no. ~ Title AFE 496219 I Workover PDC/ARCO #58 API # Operator [A.R.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun ~Date Workover I 3 / 13 / 85 Date and depth Complete record for each day reported as of 8:00 a.m. 4/01/85 Old TD 0900 Hrs. Released rig Classifications (oil, gas, etc.) O±l Producing method Flowing Potential test data IAccounting cost center code State Alaska Well no. I otal number of wells (active or inactive) on this cst center prior to plugging and bandonment of this well our I Prior status if a W,O, 0930 Hrs. 7" Lnr @ 13,393' 13,282' PBRD, RR Flow tst well. RR @ 0900 hrs, 3/29/85. RF.C .iV F-D 4 lS 7 Alaska 0il & Gas Cons. c0m~ss~0n Anchor=ge INew IPB 13,282 ' TO I Depth Date I Kind of rig 3/29/85 I Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Hemlock Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and ~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent Union Oil and Gas ' '~sion: Western Region ? Union Oil Company O'f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Hay 6, 1985 · Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE'S Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of intention'for K-3RD, and Subsequent's for,:i,D-11. & D-29, Trading Bay Unit. Rlease return the approved Sundry Notice to the undersigned. LOC/tj Attachments Very truly yours, Lawrenc~ . Cutting ENVIRONMENTAL SPECIALIST A~asV,8 0~ & ~s Cons. ALASKA u'IL AND GAS CONSERVATION CL.,, ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLxI~ OTHER [] 2. Name of Operator Union 0il Company(ARCO Alaska~ Inc., is sub-operator) 3. Address 909 W. 9th Avenue~ Anchoraqe~ AK 99501 4. Location of Well King Salmon Platform Leg #/+, Conductor #32 729' FSL, 130' FEL, Sec.17, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' NLLW 6. Lease Designation and Serial No. ADL 18777 7. Permit No. 80-!~. 8. APl Number 50- 733_2007~; 9, Unit or Lease Name Trading Bay Unit '10. Well Number K-3RD 11. Field and Pool McArthur Field Hell ock 12. (~t 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.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: 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). ARCO Alaskas Inc. s as sub-operators proposes to perforate select, intervals within the Hemlock. ~ 3GGG--p~; "~,. _,_"/°' ........ ;icc'.: ;;'iH. . =eL '-'~L A 3000 psi WP wireline lubricator will be used on all wire line work. ~T~- ~/['~, ~//~c,~' ~,-/~/~,j-- Estimated Start: May 8, 1985 RECEIVED MAY 0 7 1985 Alaska 0ii & Gas Cons. C0~]missJ0t3 Anchorage certify that the foregoing is, true and correct to the best of my knowledge. 14. I hereby ~ ~5;~ ~'.~W'.~.;/~ "~>~ Signed Law~'ence O. Cutting ~:~ Title ENVIRONHENTAL SPECIALIST The space below for Commission use Date 0_5-06-85 Conditions of Approval, if any: Approved by 9RII~III~[ SI$1iEl COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 (KJG) 5N/052 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas [ ~1on' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union 6ecember 17, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, Alaska 9~502 Dear Mr. Chatterton: SUNDRY NOTICE'S - K-3RD& GPS 32-13 Attached for your approval is a Sundry Notice to workover K-3RD, Trading Bay Unit & Subsequent Report for GRS-32-13, Union-Mobil State #1 for your information and file. Please return the approved Sundry Notice to the undersigned. Very truly yours, LawreO~.~utting ENVIRONMENTAL TECHNICIAN LOC/tj Attachment p. ECEIV£1) OEC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-I COMPLETED WELI~ OTHER [] 2. Nq~ of Ogp(at~r 7. Permit No. union ull company (ARCO Alaska, Inc., is sub-operator) 80-164 ddres 8. APl Number 3. A~s~. 9th Avenue~ Anchorage~ AK 99501 §0- 733-20076 0. Unit or Lease Name Trading Bay Unit 4. Lqcption~of.Well R3ng ~almon Platform Leg #6, Conductor #32 729' FSL, 130' FEL, Sec.17, TgN, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' NLLW 12. 6. Lease Designation and Serial No. ADL 18777 10. Well Number K-3RD 11. Field and Pool McArthur Field 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 I-] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing I-] (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). ARCO Alaska~ Inc.~ as .sub-operator, proposes to perform the following workover on K-3RD: 1. Rig up over Leg #6, Conductor #32. 2. Perforate tubing and kill well. 3. Pull completion assy. Mill packer. 6. Clean out well to PBTD. 5. Cement squeeze existing perforations. 6. Perforate and fracture Hemlock Bench 6. 7. Complete well with a 3-1/2" completion assy. 8. Reperforate select Hemlock intervals under drawdown conditions. A 3000 psi 13-5/8" SRRA BOP stack will be used during the workover. A 3000 psi WP wireline lubricator will be used on all wireline work. A new sub-surface safety valve will be installed and tested upon conclusion of the job. Estimated Start: January 10, 1985 14. I hereby c~ertify that the foregoing is true and correct to the best of my knowled The space below for Commission,(~se ~# ~ RECEIVED DEC ! 8 Alaska 0il & Gas Cons. Commission Anchorage Title ENVIRONMENTAl TF£HNTCTAN Date 1:)/17/R/1 ----I --.Iv' Conditions of Approval, if any: Approved Cop? Returned aY LON,IIE I. $111TI By Order of Approved by COMMISSIONER the Commission Date __ i -/? Form 10-403 Rev. 7-1-80 GRU3/SN01 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA '~)AND GAS CONSERVATION E ~'~v11SSION 1. DRILLING WELL[] COMPLETED WELL~ OTHER [] 2. Name of Operator Union Oil Company * 3. Address P.O. Box 6247 Anchorage, Ak 99502 4. Location of Well King Salmon Platform, Cook Inlet Top Hemlock: 3250' FNL, 1800 FEL, Sec 17, T9N, R13W. SM 5. Elevation in feet (indicate KB, DF, etc.) KB-100 ' MSL I 6 . Lease Designation and Serial No. ADL- 18777 12. 7. Permit No. 8. APl Number 50- 733-P-007~_-0! 9. Unit or Lease Name Tradinq Bay Unit 10. Well Number K-3RD 11. Field and Pool M~Arthur River Field Hemlock Pool 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). K-3RD as perforated at 4SPF ,. DIL depth: Bench 3 Bench 4 April 16 & 17, 1983. 12769 ft. - 12799 ft. 12810 ft. - 12880 ft. * ARCO Alaska, Inc. Suboperator MAY 0 5 1983 Alaska 0il &a.~Gas Cons. .... Commission 14. I hereby certify t_hat the foregoing is true and correct to the best of' my knowledge. The space below for Commission use Conditions of Approval, if any: Date By Order of Approved by COM,MISSIONER the Commission Dato ........................ Form 10-403 Rev. 7-1 Submit "Intentions" in Tripl.ic~te and "Subsequent Reports" in Duplicat~e STATE OF ALASKA ~ALASKA O'"~AND GAS CONSERVA~TION CO~--~{.41SSION 1. DRILl_lNG WELL [] COMPLETED WELL OTHER 2. Name of Operator Union Oil Company * 3. Address P.O. Bo× 624? Anchorage, _AK 99502 4. Location of Well 7. Permit No. 8. APl Number 50-- 9. Unit or Lease Name Surface: Leg 4, Conductor #32, King Salmon Platform, Cook Inlet Top Hemlock:. 3250' FNL. 1800' FEL' Sec. 17. TgN: R]3W:. ,g~ 5. Elevation in feet (indicate KB, DF, etc.) ' I 6. Lease DeSignation and Sgrial No. I 100' KB 12. ~rprac]~ng FLay fTnit-, 10. Well Number K-3RD 11. Field and Pool ~ Arthur River Field I~emlock Pool 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 [] Per[orations [] Altering Casing Stimulate ~ Abandon [] S.Smulation [] Abandonmen~ 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 p¢oposed work, for Abandonment see 20 AAC 25.105-170). We proL:x~se to ac±di~.e ~efrfl. ock Be~ches 3 and ~ during late February 1,.9~3. The treatment is described below. Pre[lush: 50 gal/ft. 7%% HC£ Acid: 100 gal/ft.' 6%-1½% M~d Acid Spacer: 10 gal/ft. 3% NH4 C£ ACID: 100 gal/ft. Clay Acid Over[lush: Diesel R E C E IV E !) FEB 1 0 11963 Alaska Oil & Gas Cons. Commission Anchorage * A~20 Alaska, Inc. Subo[~_rator _. 14. I hereby certify that the foregoing is true and correct to the best of my know!edge. Signed, , ~ Title The space below for Commission use Date Conditions of Approval, if any: 0RI~!NA[ SIGNEll Jif LONNIE C. SMITll Approved bV, COM M IS S ', 0 N E R Approved Returned By Order of the Cornmission Form 10-4 03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate. Document Transmi~ ..... ~ Union Oil Company of C, Jrnia union DATE SUBMITTED ACCOUNTING MONTH 6-29-82 TO FROM Mr. William Van Alen R.C. Warthen AT AT State Oil and Gas CC PO Box 6247 Anchorage, Alaska Anchorage, AK 95902 TELEPHONE NO. traNSMITTING ThE FOLLOWING: K-3 RD: 1 ea. Daily well history - fina report ..... PLEASE SIGN AND RETURN ON COPY RECEIVED: DATE: /. // - // .:~ FORM 1-2M02 (REV. 11-72) PRINTED iN U $.A. ALASKA OIL STATE OF ALASKA AND GAS CONSERVATION COMMISSION 3~00.1 Porcupine Drive Anchorage, Alaska 99.501 (907) 279-1433 Receipt of the following material QUANT I TY which was transmitted via is hereby acknowledged: DESCRI PT ION DATED: Copy sent YES to sender R. C. Warthen District Development Geologist Alaska District Union Oil and Gas ~)sion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union April 27, 1982 [~i~i'i.STAT TEC ~IE l STAT TEC l'l i[F~FER: Mr. William Van Alen State Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill' Enclosed is the data you requested as per your letter of 4-22-82. As you check the document of transmittal, you will note several items are missing. They. are as follows' TBU D-9 RD Library tape; this tape is currently being redone..and rep.roduced by Schlumberger.. Well History; Union Oil as TBU Operator has no receipt of receiving this history from ARCo - suboperator. We. are currently checking with ARCo on this matter. Cannery Loop Unit #3 Library tape; as a confidential well, the logs have never been composited by Schlumberger and therefore a library tape is not available. When available, the tape will be delivered to the Oil and Gas Commission. KU 34-32 Test reports; these test reports have not been delivered to Union Oil Co. from Haliburton at this time. R. C. Warthen RCW'nd Mr. Robert C. Wart'hen Union Oil Comgany of California P. O. Box 6247 .Anchorage. AlaSka 99502 April 22, 1982 Missing Information - Completed Wells Dear Bob: Wa wish to bring to your attention that the b'elow-indicated material on the following Union Oil Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: Well Complet ion Date Missing Material Granite Pt. ~33-14RD 3/6181 -DIL/SP & CBL/VDL Elec. Logs. Trading Bay Unit ~D-9RD 3/2/82 -Digitized E. Log Tape Trading Bay Unit #D-16RD 5/8181 Tradin~ Bay Unit #D-17RD 6/22/81 fading Bay Uni #K-3R 5/22/81 Trading Bay-..St. ~A-9RD '" 5/6/81 ,. -Directional Survey -Elec. Logs -Directional Survey -Well History -Directional Survey -Digitized E. Log Tape Trading Bay St. ~A-lYRD 7/3/81 -Digitized E. Log Tape Cannery Loop Unit ~3 9/13/81 -Digitized E. Log Tape Kenai Unit #34-32 1/z8/82 -Digitized E. Log Tape -Certified'Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit 12/13/80 -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Admin- istrative Code. Vezy t .,uly l ours, William Van Alen Petroleum Geologist WVA:vdl i.)L~ STATE OF ALASKA ALASK, . AND GAS CONSERVATION MISSION 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] _ ,. '2'} Name of Operator 7. Permit No. Un±on O±1 Company of Calif.* 80144 3. Address 8. APl Number P. O. Box 6247, Anchorage, AK 99502 50- 733-20074-01 4. Location of Well Surf: 729'N, 130'W Fr SE Cr Sec 17, T19N, Bottomhol'e: 3250'S, 1800'W Fr NE Cr sec 19, T9N, R13.W, SM R13W, SM 9, Unit or Lease Name Trading Bay Unit 10. Well Number TBU K-3Rd 11. Field and Pool McArthUr River 12', Check Appropriate Box To Indicate NaCure 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 E] 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 following intervals were perforated DIL Depth Feet Perforated Phase 12769-12799 29 180° 12810-12816 6 180° 12816-12879 60 0° 4 SPF NOV. 5,6, & 7, 1981: Bench 95' *ARCO Alaska, Inc., Suboperator RECEIgEO DEC-2 19P. Gas Cons. Commission /~chorage · 14. I he~regoing is true and correct to the best of my knowledge. Signed~"--"' l-- -- ~'- Title DISTRICT ENGINEER Date 11/30/81 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 ALASKA OIL AND GAS CONSERVATION COMMISSION November 18, 1981 JAY S. HAMMOND, GOVERNOR 3001 PORCUPINE DRI VE-ANCHORAGE, ALASKA 99501 Mr. Jim R. Callender District Drilling Superintendent Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Re: Trading Bay Unit , TBU K-3 RD, Approval of SUNDRY NOTICES AND REPORTS ON WELLS (Form 10-403). Dear Mr. Callender: Last week this office received from you the subject notice of intention to reperforate well TBU K-3 RD for the intervals 12,808' - 12,877'; 12,767' - 12,797'; and 12,748' - 12,758'. This Sundry Notice was .for work to be performed November 5, 1981, but was dated November 9, 1981, the same day it was received at this office. Upon telephone inquiry we were informed by your office on November 16, 1981 that the work has already been completed without approval. Due to the after-the fact submittal the Commission considers this a violation of our well-known practice of approving all well WOrk prior to commencement of such work. Since there appears to be no danger, waste, or violation of safety regula- tions during this act, the Commission will not take any action on this violation. However, if there are future violations the Commission may cOnsider fines or other action. If emergencies arise where it is impossible to submit a Sundry Notice in time for approval it may be possible to obtain a verbal approval by telephone, with a follow-up submittal of the Sundry Notice as soon as possible. Sincerely, ~nie C ~ · Smith Commissioner ALASK, ANDGAS CONSERVATION ... . MISSION 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Un±on O±1 Company of Cai±lorn&a* 80-144 3. Address 8. APl Number P. O. Box 6247 Anchorage, AK 99502 50-733-20074-01 9. Unit or Lease Name OTHER.[] 4. LOcation of Well Surf: 729'N, 130'W Fr SE Cr Sec 17, T19N,R13W, SM B.ottomhole: 3250'S, 1800'W Fr NE Cr Sec 19, T9N, Ri3W, SM 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' MSL 6. Lease Designation and Serial No. ADL - 18777 Trading Bay Unit 10. Well Number TBU K'3Rd 11. Field and Pool McArthur River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE QF 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 E] 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). We propose to run a gauge ring and on November 5, 19~1: DIL' Feet Depth Perforated reperforate the following intervals Bench 12,808' 12,767' 12,748' - 12,877' - 12,797' - 12,758' 66 4 30 3 10 ~ 3 106 ,~~uent Work Reported ~ ~ Nu. -------- Dated ---/---/-- *ARCO Alaska, Inc. SubOperator NOV o 9 Alaska Oil & Gas Coas 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed(../]/~ Tit~e DIS1 DRLG SUPI /- The space below for Commission use Date 11/9/81 Conditions of Approval, if any: SEE A~TAC/qED O0VER LETTER By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-14t0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate WELL COMPLETI OR RECOMPLETIOh .EPORT AND LOG 1. Status of Well Classification of Service Well oILX-~_, GAS FTM SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union Oil Company of California* 80-144 3. Address 8. APl Number 909 West 9th Avenue, Anchorage, Alaska 99501 50-133-.20074 4. Location of well at surface King Salaon Platform, Leg ~4, Conductor 932, 9. Unit or tease Name 729 'N,130 'W f/SE Corner, Sec 17, T9N, R13W, Trading Bay Unit At Top Producing interval SM 10. Well Number 3226' S & 1628'W f/NE Corner, Sec 19, T9N, R13W, SM' " K-3 RD (12-20) At Total Depth 11. Field and Pool 3481' S & 2152'W f/NE Corner, Sec 19, T9N, R13W, SM McArthur River- 5. Elevation in feet (indicate KB, DF,,etc.) 6. Lease Designation and Serial No. Hemlock KB 100' MT.T.W ADL 18777 12. Date Spudded2/21/81 !3. Date T.D. Reached4/27/81 114' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mDleti°ns5/22/81 86' feet MSL Single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV Set I 21.Thickness of Permafrost 13,413'MD,9.839'TVD 13, 300 'MD, 9752 'T~D'ES [~" NO [] 2771 feet MD NA 22. Type Electric or Other Logs Run DIL/Sonic/Calliper, CNL/FDC/Gr, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEIWT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 9-5/8" 47~ N-80 Old Wellbore 2,646' 9-5/8" 47~ N-80/S-9!5 0 10,983' 12-1/4" 1000 sx "G" cement .None 7" 299 N-80/S-9!5 10,660' 13,395' 8-1/2" 800 .sx ':,G'.' c..e~.t.,. None ,. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4 SPF w/2-5/8" gun 3-1/2" 10,473' ) 12,430' 12,814'-12,877' MD (63') 4-1/2" 12,497' ) (9,386'-9,433' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 12,767'-12,797' MD (30') 10,750' 135 sx "G" cement (9,351'-9,373' TVD) 13,342' 45 bbl mud 10,395' 58 bbl mud 10,560' 195 sx "G" cement 27. PRODUCTION TEST 12,710' 100 SX "G" ce~_nt Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/21/81I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 5/22/81 12 TEST PERIOD I1~ 7.52 2.27 0 OpenI 302 SCF/STB PloW Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 120 1,075 24-HOUR RATE ~ 15.04 4.54 0 34.7 28. CORE DATA , Brief description of litholog¥, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None R E C E IV E O JUL 0 7 1981 Alaska 0il & Gas Cons. Commission Anchorage L Form 10-407 Rev. 7-1-80 *AlqCO Alaska, Inc. is S~~OQ~ON REVERSE SIDE Submit in duplicate 29. 30. ~ : GEOLOGIC MARKERS FOr:~:~,:'! ,:~": ,,: ,:'! T!:.~."T :"~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G Marker 11,565' 8,477' None G-1 Bench 11,979' 8,780' Hemlock 12,528 ' 9,192 ' West Foreland 13,170' 9,672' 31. /~ST OF ATIAC~tMENTS FDC/DIL/BHC/GR, CNL/DIL/BHC/Calip, CNL/DIL/BHC/GR, Computer Processed Log, 3'2 DIL/SP_, CNL/DIL/BHC/~GR,. BHC/Soni~ DIL/.GR, BHC/Sonic/DIL/Gr~ FDC/CNL/~r . · . ~ ~ · ./ ...... , ......... ~ · . · Multlshot g~ro survey (3methods) . /~/~/z~' ,~~~/~ ~ TitleDist'Drlg'Supt' Date , Signed 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 tool. 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". ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comp/etion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ot oil string until completion. District Field Date and depth as of 8:00 a.m. o2/26/8 02/27/81 02/28/8x o3/ol/sl Alaska McArthur River o3/o2/81 County or Parish Cook Inlet Istate Lease or Unit Trading Bay Alaska JWell no. K-3K !Complete record for each day while drilling or workover in progress (cont.) 2915' PBD, prep to spot cmt POOH, LD DP, PU 8-1/2" bit, 9-5/8" csg scrpr, 3-DC, RIH to 3000' SLM, circ BU, POOH, LD bit & scrpr. PU 9-5/8" bridge plug, RIH & set @ 2915'. RU & press tst w/2000 psi f/10 min. POOH, LD setting tl. PU 2 stds, 3-1/2" DP & RIH. 2765' PBD, POH w/csg cutter Wt. 8.7, Vis 44 Tst cmt lines to 1000 psi, pump 10 bbls H20, 50 sx "G" + 2% CaC1 @ 1S.8 ppg & 4 bbls H20. Displ w/45 bbls Inlet wtr. CIP @ 0640, 02/26/81. Pulled 2 stds & rev circ @ 2720'. Displ FW w/gel H20, POOH. PU 9-5/8" csg cutter & cut csg @ 2650', POOH. PU spear. Unable to BO 2 csg packoff lockdown screws. Heated & drl out. Set spear, pulled & worked csg, unable to pull free. Rel spear & POOH, PU cutter & cut csg 6' below hgr. RU spear & unable to pull free. RU to circ. Had communication bet 9-5/8" x 13-3/8". Cont to work fsh. POOH w/spear & retrieved spacer spool & 9-5/8" packoff. RU & free pointed 9-5/8" csg using Dialog. RIH & cut csg @ 2480', POOH to PU spear (Tri-State). 2486', cut 9-5/8" csg Wt. 8.7, Vis 51, PV 15, YP 11, Gels 21/29, PH 11, WL 13, Cake 2 CL 1000, Sol 2, Oil 0 PU spear & work pipe. PU jars + 3 stds HWDP & RIH to 1020'. Jarred pipe & press up to 800 psi w/no circ. POOH, LD spear & jars. PU Servco csg cutter, RIH & cut csg @ 2485'. POOH, PU spear & pull 9-5/8" csg free. RU csg crew & POOH, LD 58 jts, 9-5/8" N-80 BTC csg. RD csg crew (Triple D). PU Tri-State spear & multi-string csg cutter RIH to 2520'. Jar on csg (no movement). RIH & cut 9-5/8" @ 2646'. , '2646' PBD, cut 9-5/8" csg Wt 9.0, Vis 46, PV 11, YP 4, Gels 8/14, PH 10, WL 15.6, Cake 2, GL 2000, Sol 6, Oil 0 - Engage spear & jar fish. Pull up to 2S82'. Make 2nd csg cut. POOH & LD spear. PU new spear & acc jars. RIH, jar, work fsh (248S'-2S82'), no movement. POOH, LD cutting ti & spear. PU 11-3/4" washpipe & RIH, wsh over fsh. Circ & POOH, PU spear, RIH & engaged fsh. POOH, LD fsh & Tri-State tls. PU under reamer & RIH. 2250' PBD, WOC Wt 9.1, Vis 38, PV i0, YP 6, Gels 8/14, PH 9, WL 12, Cake 2, CL 2100 Sol 6, Oil 0 Bit #1, 12-1/4" Sec, S33S, #211916. Open (CO run) 100', 3 hr. Underreamer 2506'-2526' (20'). PU to shoe, could not go dn. POOH w/underreamer & 2 arms broke, 1 cone lost, 3rd cone bearing gone. PU spear & jars, RIH, engage fsh @ 2582', POOH. LD fsh (64' of 9-5/8" & fshg tls. "PU 8" DC & 12-1/4" bit & RIH. Ream 2506'-2646'. C&C mud, POOH & stand back BHA. PU 5 stds 3-1/2" DP, RIH to 2700'. RU, tst cmt The above is correct 3ignature :or form preparh'tion and distribution ee Procedures Manual Section 10, )tilling, Pages 86 and 87 JDate ITitle 6/4/82 fcontinued) Drilling Superintendent JUN 3. 6 1982 Oil & Gas Cons, Commission imc~orage R3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. Page no. 2 _ AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field McArthur River Field Auth. or W,O, no, AFE 397831 County or Parish Cook Inlet Lease or Unit Trading Bay IState Alaska IWell no. K-3RI 'itle Redrill Operator ARCO Alaska, Inc. King Salmon Platform IA.R.Co's W.I. Prior status if a W,O. Spudded or W.O. begun IDate tHour Redr il 1 02/21/81 0600 Date and depth as of 8:00 a,m. 02/20/81 02/21/81 02/22/81 02/23/81 o2/24/81 02/25/82 o2/26/81 Complete record for each day reported 11,734' PBD, Skid rig Skid rig f/Leg 2- Leg 3- Leg 4. Prep to RU on K3. 11,734' PBD, RU General RU. Filled 4-3/4" x 9-5/8" ann w/filtered Inlet water. RU to pump dn tbg w/rig pump. 11,734' PBD ~ccept.rig @ 0600 hrs., 02/21/81. Bullhead dn tbg w/175 bbls. Filtered Inlet H20, max 2100 psi @ 4 BPMw/rig pump. Tbg & ann dead.. Unloaded boat & set dry sack room, pump unit & D.A. unit. RU cmt equip, Camco & tst lub. Retrieve dummy ball valve, RD. RUDresser Atlas & perf 3-1/2" tbg w/8 holes @ 10,778'. RD, circ 700 bbls Inlet H20 spm/1000 psi to, prod seperator. Set BPV, ND prod tree & NU BOPE. 11,734' PBD, LD prod string Wt. 8.4 FIW RU mouse hole, B.J. & gas buster. Tst BOPE, cir¢, complete volume S0 bbls to prod & lost 158 bbl. Unlnd tbg, RU & LD 180 jts, 4-1/2" tbg. Lost 112 bbls @ 12/hr, 52,000 lbs overpull to release pkr. Max drag 82,000 lbs. Tbg breakout tight using small csg tongs. 11,734' PBD, PU 5" DP Wt. 8.3 FIW LD total 85 jts, 3-1/2", 272 its 4-1/2", 7 4-1/2" GLM's, 1 Otis ball valve & dummy 1 XO (3-1/2" x 4-1/2"), 1 Otis RH, 1 pkr, Q nipple & shear-out sub. Lost 248 bbls. RD, chg Kelly cock (would not tst) & pipe rams. Tstd, TIW valve & inside BOP, blind rams, 5" pipe rams to 3000 psi. PU 6" bit, 7" csg.scrpr, 6 4-3/4" DC's, 95 jts, 3-1/2" DP, .S" DP. 11,734' PBD, GIH w/retainer (7" lnr @ 8300')) Wt. 8.3 FIW RIH, PU DP, hit tight spot @ 11,270'. Circ & cln hole, POOH. Tst upper Kelly cock to 3000 psi, RU Camco & Eastman gyro & run gyro to 11,365'. TI stopped (acted like fill). POOH, RD Camco & Eastman, PU Baker retainer, RIH, cut drl line. RIH to 10,750', RU to circ. 2915' PBD, prep to spot cmt (7" lnr @ 8300') Wt. 8.3 FIW RIH w/Baker 7" ret & set @ 10,750'. Tst cmt lines to 5000 psi, DP & csg, ann to 2000 psi. Broke dn form @ 8 BPM & 2700 psi. Pull out of ret, pump 20 bbl H20, 160 sx "G" w/.75% D-31L + 0.2% D-19 + 0.1% D-6L @ 15.8 ppg, followed.by 5 bbls H20. Displ w/filtered Inlet H20 while holding 500 psi on ann. No returns to surf after 90 bbls. Displ, stabbed into ret, sqz perf's w/135 sx cmt. Pull out of ret, left 25 sx on TO ret. Pulled 5 stds & rev circ. CIP @ 0925, 02/25/81. (continued) The above is correct Signaturfr"--'~ "~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, AR3B-459-1-B IDate Title 06/04/82 ] Drilling ~~Y~nt JUN 1 6 1982 At~ska 0il & Gas Cons. C0mmissior~ :.:~.~'~ Anchorage JNuknber all daily well history forms consecutively as they are prepared for each well. jPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a~l dri{l stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form, 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) On Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptl~ as of 8:00 a.m. o3/o2/81 o3/o3/81 o3/o4/81 o3/os/81 County or Parish Alaska Cook Inlet Lease or Unit McArthur River Trading Bay !Complete record for each day while drilling or workover in progress State Alaska IWe. ,o. K- 3RD (cont.) 2250' PBD, WOC lines. Pump 60 bbls caustic H20 + 20 bbl FW + 340 sx "G" w/D-31L @ 17.5 ppg + 5 bbls FW. Displ w/35 bbls mud. CIP @ 2400, 03/01/81. Pull 5 stds, rev out 3 bbl FW + 60 bbl Caustic H20, no cmt. Closed Hydril & press up to 1000 psi. Press bled to 700 psi in 1 min. Pumped 3 bbls to press to 950 psi. Bled to 525 psi & stabilized. Held 20 min & bled off. POOH, LD excess DP & DC f/derrick. Cut & slip DL. Realign mouse hole. 2530' PBD, RU steering ti Wt 9, Vis 41, PV 12, YP 7, Gels 7/18, PH 11, WL 18, Cake 2, CL 1800 Sand 1, Sol 7, Oil 0 Bit #1 (cont) 100', 3 hfs, 100 RPM, Wt. 10/20, 1-1-I (w/133) Bit #2, 12-1/4" Sec, S335, #211876, 203 WO mud pumps, tst BOPE, repair check valve & choke line valve. RIH & tag, TOC @ 2430'. C&C mud, drl 2430'-2530' (100') hard cmt. Tst choke manifold. C&C mud prior to DD run. POOH, LD 16 its, 5" DP & instl wear bushing. PU DD + 4 Monel DC's + 15 jts HWDP, tst DD & RU Kelly hose. RIH, MU, circ head. RU Dresser Atlas to run DOT. 2929' (300'), Survg Wt 9, Vis 41, .PV 12, YP 7, Gels 7/18, PH 11, WL 18, Cake 2, CL 1800 Sand 1, Sol 7, Oil 0 Bit #2 (cont) 141',~7-1/2 hrs., DD, 5/10 wt., 2-2-1 Surveys: 2566', 35~, S53W 2703', 36-3/4°, S55W 2861', 43°, S49W 2500'-2566' -- 4.9 Dogleg Ran DA DOT DD 2530'-2671' (7-1/2 hfs). Orient tl & SS @ 2671' f/final check. POOH, LD DD & Tls. RIH w/bld assy, ream f/2506'-2671', circ, surv @ 2770'. Drlg 2771 '-2929'. Circ f/surv. 3487' (558'), Survg Wt 9.3, Vis 48, PV 18, YP 7, Gels 9/25, PH 10.5, WL 11, Cake 2, CL 2000 Sand 3, Sol 7, Oil 0 Bit #3, 12-1/4" Sec, S335, #211919, 123, 275', 3-3/4 hrs., 90 RPM, 35/40 2-1-1 Bit #4, 12-1/4" Sec, S335, #969161, 123, (OBD) Surveys' 3017', 48-1/2~°, S48-1/2W 3186', 52-1/4~, S48W Surv @ 2929', drl to 3087' circ & surv @ 3087' POOH, RIH w/locked assy, RD DA, drl to 3362', circ g surv @ 3186'. Drl ~ough & slow, POOH, chg bits, RIH, check closure w/Eastman OFC, OK. Drl hard spot 3362'-3364'- 3487'. Circ. The above is correct Signature 6/04/82 ITM For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Drilling Superintendent INumber all daily well history forms consecutively 1Page no. as they are prepared for each well. I 3 ARCO Oil and Gas Company Daily Well History---Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frecluently than every 30 days. or (9) on Wednesday of the week in which Oil string iS set. Submit weekly for workovers and following setting of oil strincj until completion. District Field Date and dept, as of 8:00 a.m. o3/o6/81 o3/o7/81 03/08/81 o3/o9/81 Alaska McArthur River County or Parish Lease or Unit Cook Inlet !State Trading Bay Complete record for each day while drilling or workover in progress Alaska iWell no. K-3RD 4030', (543'), Drlg Wt 9.4, Vis 44, PV 16, YP 8, Gels 6/32, PH 10, WL 12, Cake 2, CL 2000 Sand 2, Sol 8, Oil 0 Bit # 4 (cont) 609', 13-3/4 hr., 90 RPM, 40 wt, 8-4-1 Surveys' 3406', 52-1/2°, S48W 3563', 53-3/4°, S48W 3719', 54°, S47W 3878', 54-3/4°, S46-1/2W Drl to 3941', circ & surv. POOH, chg bits & PU 2 DC's & 6 jts HWDP. RIH, ream btm 30'. Drl to 4030'. 4773', (743'), Drl & surv Wt 9.5, Vis 42, PV'IT, YP 5, Gels 4/14, PH 10, WL 7.8, Cake 2, CL 1700 Sand 2, Sol 9, Oil 0 Surveys: 4060', 56°, S47W 4282', 56°, S48W 4469', 56-1/4°, S46W 4691 ', 56-1/4°, S48W Drl to 4773', Circ 4 hrs., Surv 3-3/4 hrs, Conn 2, hrs., RR 3/4 hrs. 4868', (95'), Drl & surv Wt 9.4, Vis 49, PV 19, YP 9, Gels 7/18, PH 10, WL 7.8, Cake 2, CL 1700 Sand 3/4, Sol 9, Oil 0 Bit #5, 12-1/4" Sec, S33S' #839136, 123 817', 14-1/2 hr, 90, 40, 6-3-1 Bit #6, 12-1/4" Sec, S44G, #968204, 203[ 134', 7 hrs, DD, 8/10, 6-4-1 Surveys: 4282', 56°, S48W 4469', 56-1/4O, S46W 4691', 56-1/4°, S48W 4787', 56-1/4°, S46W Drl to 4868', drop surv, Pmp pill, POOH, LD BHA, PU DD & BHA, RIH & DD 4868'-5002'. Probe stuck inseat & pulled out of rope socket. POOH, probe was sanded in. 5340', (472'), POH Wt 9.6, Vis 47, PV 20, YP 11, Gels 4/22, PH 10, WL 6.8, Cake 2, CL 1700 Sand 1, Sol 8, Oil 0 Bit #3RR, 122-13, 338', 7-3/4 hrs., 90, 55, 7-4-1 Surveys: 5130', 50°, S53W 5226', 50-3/4o, s53-1/zw PU BHA, RIHw/bit #3RR, rm 4868'-5002'. Drl, circ& surv @ 5245', drl 5340', circ, drop surv & pmp pill. POOH, LD stab & lead colt, PU DD & BHA, RIHw/#7, bridge @ 2660', could not work thru w/o pump, POOH. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Drilling Superintendent JUN 1 6 982 Alaska 0il & (~as Cons, Commission Anchorag9 I N umber all daily well history forms consecutively as they are prepared for each well. IPage no. 4 ARCO Oil and Gas Company ,~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests secluentially, Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when fiJled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. O3/lO/81 o3/11/81 District Date and depth as of 8:00 a.m. o /12/81 o3/13/81 I County or Parish A. laska /Lease or Unit Cook Inlet McArthur River I Trading Bay Complete record for each day while drilling or workover in progress IState Alaska JWe. no. K- 3RD 5382' (42'), DD Wt. 9.6, Vis 55, PV 20, YP 15, Gels 7/36, PH 10, ~FL 5.8, Cake 2, CL 1700 Sand 3/4, Sol 8, Oil 0 Bit #2RR, CO & circ, 2-2-1 Cut drl line & LD BHA, tst BOP & choke. Reinstl wear bushing. PU locked assy & RIH, worked thru bridge. C&C mud, added 4#/bbl Soltex & Lube 106 f/drag. Pmp pill, POOH, LD BHA, PU DD #3 & Bit #7, RIH, RU, circ head & ran DOT. DD 5340'-5382' . 5989', (607'), Circ Wt. 10, Vis 48, PV 22, YP 11, Gels 8/22, PH 9.5, WL 42, Cake 2, CL 1300 Sand 2, Sol 10, Oil 0 Bit #7, 12-1/4" STC, SDS, #BN9380, 203, 65', 5-1/2 hrs., DD S/10, 1-1-I Surveys' 5510', 46-3/4°, S56W 5668', 46°, SSSW Drlg 5382'-5403', DOT stuck. Pull out of rope socket, POO~ RD Dresser, LD DD & DOT, MU new BHA, RIH, rm 40' btm. Drl 5403'-5593', circ & surv, drl 5593'-5752', circ & surv, drl 5752'-5989', circ, drop surv & pmp pill. 6103', (114'), prig Wt. 9.9+, Vis 49, PV 21, YP 10, Gels 8/17, PH 11, WL 4.8, Cake 2, CL 1200 Sand 1-1/4, Sol 11, Oil 0 Bit #8, 12-1/4" STC, SDS, #BP0038, 122-13, S86', 7-1/2 hrs, 80/100, SS/60, 3-4-I . Bit #9, 12-1/4" STC, SDS, #BN9269, 203, 114', 6 hrs, DD 8/10, 2-2-1 Survey: 5889', 44-1/2o, S56W Drop survey, POOH, LD stab, lead colr, 6 pt Rrm, RR & lube. PU DD & orient sub. RIH w/DD, rn DOT & orient. DD #4, 5989'-6103', (114'). POOH w/DOT, RD DA, POOH, LD DD, MU new BHA. RIH, rm 125' to btm. 6325', (22'), prep to rm Wt. 10, Vis 50, PV 25, YP 15, Gels 8/15, PH 10, WL 4.4, Cake 2, CL 1200 Sand 1-1/2, Sol 12, Oil 0 Bit #10, 12-1/4" STC, SDS, #BN9377, 122-13, 222', 2-3/4 Hrs, 90/130, 60, 6-2-1 Surveys: 6145', 44-1/4°, S67W 6240', 44-1/4°, S68W Drl 6103'-6325' (222'), surv, pmp pill, POOH, chg BHA. RIH, hit tight spot @ 5340', rm 5340'-5440', RIH to 6000', rm 6000'-6190', circ while w/o generator (burned out). POOH to 13-3/8" shoe (tight). Circ w/o gen, RIH to 6190', circ & unplug jet. Prep to ream. The above is correct Signature / .., Date ~ '~'--.- ~'. ........ .... 2... --or form preparation and distribution ~ee Procedures Manual Section 10, Drilling, Pages 86 and 87 ~R3B-459~2-B 6/04/82 !Title Drilling Superintendent INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number al~ drili stem tests sequendaHy. Attac, description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. 03/14/81 03/15/81 o3/16/81 District Field Date and dept, as of 8:00 a.m. 03/17/81 03/18/81 I County or Parish Alaska Lease or Unit Cook Inlet McArthur River I Trading Bay Complete record for each day while drilling or workover in progress IState Alaska Iwe, .o. K- 3RD 6865', (540'), Drlg Wt. 10.2, Vis 45, PV 19, YP 7, Gels 8/14, PH 9, WL 6, Cake 2, CL 1100 Sand 3/4, Sol 11, Oil 0 Bit #11, 12-1/4" Sec M44NG, #943529, 122-13, 495', 13-3/4 Hr., 125, 60, 6-7-1 Surveys' 6440', 44-1/2° S68W 6750', 45 3/4°~ S.69W Ream 6190'-6325' (130'). Drlg to 6440', circ& surv. Drlg to 6750', drop surv, POOH, chg bit, RIH, drlg to 6865'. 6945', (80'), Drlg Wt. 10.2, Vis 45, PV 20, YP 10, Gels 8/15,. PH 10, WL 5.6, Cake 2, CL 1100, Sand 3/4, Sol 11, Oil 0 Bit #12, 12-1/4" Sec M44NG, #943456, 122-13, 402, 11-1/4 Hr., 140/150, 55, 3-6-I Surveys: 6945', 46°, S68-1/2W 7155', 47°, S68-1/2W Drlg to 6945', circ& surv, drlg break. Drlg, circ& drop surv, pump pill, POOH, chg BHA, RIH, wsh & rm 45' to btm. 7937', (992'), tSt BOPE Wt. 10.2, Vis 43, PV 18, YP 12, Gels 7/12, PH 11, WL 6, Cake 2, CL 1000, Sand 3/4, Sol 11, Oil 0 Bit #13, 12-1/4" STC 2JS, #BE0215, 132-12, 716', 19 Hrs., 125/150, 55/60, 1-SF-I Survey' 7865', 45-1/2° S70W Drlg, drop surv, pmp pill (7937'), POOH, pull wear bushings, tst BOPE. 8400', (463'), Drlg Wt. 10.4, Vis 43, PV 17, YP 11, Gels 8/14, PH 10, WL 6, Cake 2, CL 1100, Sand 1-1/4, Sol 11 Fin BOPE tst, OK. Instl wear bushings, pull kelly bushing & repair broken pen. RIH w/bit #14, slip & cut 75' drl line. RIH, rm 60' to btm. Drlg, RR pmp (new swab rubber). Drlg to 8400'. 8602'1~ (202'), RIH Wt. .2, Vis 43, PV 20, YP 11, Gels 4/14, PH 10, ~L 6.8, Cake 2, CL 1100, Sand 1, Sol 11 Bit #14, 12-1/4" STC, Z.IS, #BE0319, 12-132· 179' 9 Hrs., 150, 60, 4-2-1/8 Bit #15, 12-1/4" SEC, S84F, #972776, 12-152, 179~, 9 hfs, 150, 60, 8-3-1/8 Surveys' 8360', 45-5/4°, S72W 8535, 46°, S72-1/2W Drlg 8400'-8423', drop surv, pmp pill, POOH, chg bits, RIH, rm 60' to btm. Drlg 8423'-8602' POOH to chg bit The above is correct Signature ; . IDate jTitle .... " .~.. .... . 6/04/82 Drilling Superintendent For form preparation and distribution see Procedures Manual Section 10, Drilling. Pages 86 and 87 JUN 1 6 1982 Alaska Oil 8, Gas Cons. Commis¢on ~nchorag~ AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. Page no. 6 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Num~3er a;~ dritl sfem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m, 03/19/81 03/20/81 03/21/81 03/22/81 o3/23/81 Alaska McArthur River County or Parish Lease or Unit Cook Inlet iState Trading Bay Alaska JWell no. K- 3RD Complete record for each day while drilling or workover in progress 8937', (335'), RIH . Wt. 10.2, Vis 41, lA/ 19, YP 7, Gels 4/12, PH 10, WL 6.6, Cake 2/32, CL 1100, Sand 3/4, Sol 11 Bit #16, 12-1/4" STC, F2,'~BJ9152, 12-132, 335', 10-1/2 Hr., 150, 60, 2-4-1 Survey: 8875', 46°, S73W Chg bits, RIH w/bit #16, rm 60' to btm. Drlg 8646'-8937', drop surv, pmp pill, POOH, chg bit, RIH w/bit #17, rm 60' to btm. 9165', (228'), Orienting DD W.t; 10.2, Vis 42 Bit #17 Sec, S44F, #963505, 12-1o2, 228', 12-1/2 Hrs., 150', 60, 8-8-1/8 Survey: 9100', 44-3/4°, S78W Drlg 8937'-9165', drop surv, pmp pill, POOH, LD stab & MU DD. RIH w/bit #17 & DD #5. Run DOT on Dresser line, orient DD, probe not seated, unable to pull, pmp & shutoff, working probe. 9208', (44'), DD Wt. 10.3, Vis 43, IA/ 20, YP 11, Gels 5/18, PH 10, WL 5.6, Cake 2/32, gL 1100, Sand 3/4, Sol 12 Bit #18, 12-1/4" Sec, M44NG, #943312, 203, 15, 5-1/2, DD, 6/10, 2-1/SF-I DD #5, 9165'-9180'. Pull WL & pmp pill. POOH, chg bit & check BHA. RIH w/#19 & DD #6. Tight @ 7024'. RU, circ head & WL, circ. RIH w/probe on WL, DD #6 9180'-9208'. 9250', (42'), PD wt. 10.2, Vis 42, PV 18, YP 8, Gels 4/12, PH 10, WL 5.4, CL 1200, Sand 3/4, Sol 12 Bit #19, 12-1/4" Sec, M44G, #972358, 203, 63', 7-1/2 Hrs., DD, 6/10 2-SE-I Pull DOT, corm, run DOT. DD #6 9208'-9243'. H20 leak in Worthington heat exchg @ 1050 hrs, salt H20 in DC panel PUtl jr, shut off all DC power, transformer damaged. Limit power to rig @ 1220 hrs. PU kelly &circ, work pipe, prop pill, POOH, rep power loss (7-1/2 Hrs). RIH w/#20, DD #7, run DOT, DD 9243'-9250'. 9357' (107'), , Surv Wt. 10.2, Vis 42, PV 19, YP 8, Gels S/12, PH 10, WL 4.8, Cake 2/32, CL 1100, Sand 1, Sol 15 Bit #20, 12-1/4" Sec, M44NG, #943575, 203, 54', 8 Hrs, DD, 6/10, 2-SE-I Survey: 9297', 42-3/4°, S72W DD #7 9250'-9297'. Pull DOT, pmp pill, POOH, chg B~L&. RIH w/#21, rm' 9165'-9297' (high torq). Drlg 9297'-9357', circ, attm to surv, failed. Parker hoist not operating. Prod AC turbine dh, no backup power f/drlg. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2~B IDate 6/04/82 ITitle Drilling Superintendent ias they are prepared for each well. Page no. 7 Number ail daily well history forms consecutively ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final comotetion. Reoort o~'ficiat or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a,m. 03/Z4/81 o3/2s/81 o3/26/81 03/27/81 o3/28/81 I County or Parish Alaska Lease or Unit Cook Inlet McArthur River I Trading Bay Complete record for each day while drilling or workover in progress IState Alaska IWell no. K- 3RD 9374', (17'), GIH Wt. 9.1, Vis 38, [Y 10, YP 6, Gels 5/16, PH 9.5, WL 5, Cake 2/32, CL 1200, Sand 3/4, Sol 13 Bit #21, 12-1/4" RTC, S13G, #346210, 12-152, 60', 7-1/2 Hr., 110, 60. 2-SE-I Survey: 9280', 42°, S69-1/2W Drlg 9357'-9374' (#1 gert failed). Drop surv, pmp pill, POOH, repair gen (7 hrs.), tst BOPE, LD BHA & ~J new BHA, RIH w/#22. 9374', (0'), GIH Wt. 10.3, Vis 45, PV 22, YP 12, Gels 6/17, PH 8.S, 5~L 4.4, Cake 2/52, CL 1200, Sand 1, Sol 13 Rm 9140'-9328', POOH S stds & WO kelly bushings. POOH to 15-3/8" shoe @ 2506'. LD junk kelly, WO kelly (10 hrs.) PU rental kelly & rebuild bushings. RIH & br circ @ 7000'. ~std choke manifold. 9480' (106'), Magnaflux BHA Wt. 1~.2, Vis 44, PV 15, YP 9, Gels 6/14, PH 10.5, WL 4' 6, Cake 2/32, GL 1100, Sand 3/4, Sol 12 Survey' 9430 ',. 41-1/4° , S7 OW Drl 9374'-9480' circ& surv @ 9430'. POOH to rn DOT, RR drum clutch (2-1/2 hrs.), POOH. 9510', (30'), GIH w/Dyna Drl Wt. 10.2, Vis 44, PV 14, YP 6, Gels 7/12, PH 10.5, WL 4.8, Cake 2/32, CL 1200, Sand 1, Sol 11 Bit #22, 12-1/4" STC, F2, #BJ9134, 12-132 106', 9 Hr. 80/90, 45, 2-SE-I Bit #23, 12-1/4" SEC, M44NG, #861832, 203,, 30', 6-1/2 Hr., DD, 10, 2-SE-I RIH w/#23, DD #8. Circ DOT on DAWL, tl quit. PO DOT, repair short. RIH, orient DD, DD 9480'-9510'. POOH w/DOT. LD, circ head, pmp, POOH, chg bit. RIH w/#24, DD #9. 9524', (14'), RIH, rm Wt. 10.2, Vis 40, PV 13, YP 6, Gels 6/1i, PH 10.5, WI, 4.4, Cake 2/32, CL 1100, Sand 1, Sol 12 Bit #24, 12-1/4" RTC, S13G, #346205, 203 14', 6 hrs., DD 10, 1-1-I DOT & orient DD, DD 9516'-9520', DOT qui~. POOH w/DOT (WL damaged in jars, rehead). RIH, DD 9520'-9524'. DOT unseated, would not reseat. POOH w/DOT. Prop pill, POOH, chg BHA, RIH w/#25 (bridge @ 7500'). Pun & wsh thru bridge, rm 9470'-9524'. The above is correct Signature · i.~ IDate ITitle / t_~. _ .... . ~ 6/04/82 Drilling Superintendent For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B RECC IYEi) JUN 1 6 1982 0il & Gas Cons. Commission Anch0rag9 I Number all dally well history forms consecutively as they are prepared for each well. jPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish Field Alaska McAr thur River Lease or Unit I State Cook Inlet Trading Bay Date and depth as of 8:00 a.m. !Complete record for each day while drilling or workover in progress 03/29/81 o3/3o/81 o3/31/81 04/01/81 04/02/81 Alaska JWell no. Wt. 10.2, Vis 43, PV 20, YP 7, Gels 5/9, PH 10, WL 5, Cake 2/32, CL 1200, Sand 3/4, Sol 12 Bit #25, 12-1/4" RTC, S13G, #346209, 12-132, 101', 6-1/2 hrs, 140/150, 55, 8-SE-1/8 9645', (121'), DD Drl 9524'-9625' (add Lube 106 - hi torq), drop surv, pmp pill, POOH, tight @ 5200'-5424'. Rm tight area, LD stab, PU DD #10, RIH. RU circ head & RIH w/DOT. DD (lost DOT). POOH, cut & rehead WL, RIH w/DOT. DD 9625'-9645'. Survey: 9570', 42-3/4°, S69W Wt. 10.3, Vis 44, PV 18, YP 10, Gels 8/14, PH 10, WL 4.6, Cake 2/32 CL 1100, Sand 3/4, Sol 12 Bit #26, 12-1/4" RTC, S13G, #346204, 203~ 21' 6 hfs, DD 10, 1-SF-I Bit #27, 12-1/4" SEC, M44NG, #943187, 203, 57~, 6-1/2 hr, DD 10, 8-SF-t/8 9703', (58'), Tst BOPE DD #10 9625'-9646', POOH w/DOT, prop pill, POOH, chg bit, ck BHA. RIH w/#27, DD #11, RIH w/DOT, orient, DD 9646'-9671'. Re-orient to DD 9671'-9703'. POOH w/DOT. POOH w/#11 DD. Pull wear bushings, set tst plub & tst BOPE. Wt. 10.3, Vis 45, PV 18, YP 10, Gels 8/14, PH 10,.WL 4.6, Cake 2/32, CL 1200, Sand 1/2, Sol 12 Bit #28, 12-1/4 RIC, S13G, #346206, 12-132, 160', 7 hr, 120, 50/55, 2-SE-I 9863', (160'), ?OH LD Hex kelly, PU new sq kelly & chg kelly bushings. Tst V & L, kelly cocks & safety valve. ~fO BHA, RIH, lost tong die in DP, recovered @ crow's foot. Rm 9625'-9703'. Drl 9?03'- 9863', circ, drop surv, POOH. Wt. 10.3, Vis 40, tn/ 15, YP 5, Gels 3/8, PH 9.5, WL 5, Cake 2/32, CL 1300, Sand 3/4, Sol 13 10,033', (170'), Drlg Chg BHA, RIH w/Bit #29, slip & cut DL, rm 40' to btm. Hole cln. Drlg 9863'-10,033' · Wt. 10.4, Vis 42, PV 15, YP 5, Gels 3/6, PH 9.S, ~FL 5.2, Cake 2/32, CL 1300, Sand 3/4, Sol 13 Bit #29, 12-1/4" SEC, S84F #963558, 12-132 183' 16-1/2 hr, 110' , ' , ' 50, 3-SF- I 10,180', (147'), Drlg. Drl 10,033'-10,046' , drop surv, POOH, chg BHA, ID HWDP (elec fixed gen 1-1 & rep ~W-60 unit). RIH w/#30, rm 40' to btm. Drlg 10,046'- 10,180' . Survey: 9990'-47°, S63W The above is correct Signature '& ,'; '"" ' For form preparation and distribution see Proced. ures Manual Section 10, Drilling, Pages 86 and 87 Date .[Title 6/o4/82 Drilling Superintendent JUN 1. 6 982 Alaska 0il & Gas Cons, Commission Anchorage AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. 9 ARCO Oil and Gas Company ,~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Alaska McAr thur River County or Parish Lease or Unit Cook Inlet Istate Trading Bay Alaska Iwe. no. K-3RD Date and depth as of 8:00 a.m. 04/03/81 04/04/81 04/05/81 04/06/81 04/07/81 Complete record for each day while drilling or workover in progress Wt. 10.5, Vis 46, PV 26, YP 10, Gels 3/14, PH 9.5, WL 5, Cake 2/32, CL 1300, Sand 3/4, Sol 14 Bit #30, 12-1/4" SEC, S84F, #972738, 12-132, 179' '15-1/4 hr 90 50, 3-1/SF- I 10,225', (145'), MU BHA Drl 10,160'-10,225', drop surv, prop pill, POOH, tight @ 8729'. RIH, cond mud, POOH, LD Hwdp & BHA. Survey' 10,170', 47-1/4°, S63W Wt. 10.5, Vis 46, PV 24, YP 9, Gels 3/12, PH 9.5, WL 5, Cake 2/32, CL 1300, Sand 3/4, Sol 14 10,323', (98'), RIH Rep gert 1Gl, LD 30 jts "E" DP, cut DL, PU 30 "S" DP, string 10 Ins, pull wear bushing, tst BOPE, rep I~<M valve on stnd pipe. RIH w/#31, tight @ 6050'. Wt. 10.6, Vis 51, PV 26, YP 14, Gels 6/18, PH 9.5, WL 4.2, Cake 2/32, CL 1300, Sand 3/4, Sol 16 Bit #31, 12-1/4" SEC, M44NG, #861529, 12-132, 98' 11 hr 90 50 4-SE-I 10,327', (0')~ Drlg Drl 10,225'-10,283', short trip, 16 stds, tight, Lube 106. Drl 10,283'-10,323', drop surv, pmp pill, POOH (6 tight areas). Chg BHA, RIH w/#32, tight @ 7239'. Rm tight areas & 60' to btm. Drl 10,323'- 10,327'. (Tight areas @ 8519', 8435', 7298', 7202", 5972', 5875'). Survey: 10,265', 47°, S68W Wt. 10.5, Vis 43, PV 19, YP 6, Gels 4/12, PH 9.5, WL 4.2, Cake 2/32, CL 1300, Sand 3/4, Sol 16 10,560', (237'), Drlg Drlg 10,327'-10,560' (torq decreased last 100'). Wt. 10.5, Vis 46, PV 23, YP 9, Gels 4/12, PH 10, WL 4.4, Cake 2/32, CL 1300, Sand 3/4, Sol 16 Bit #32, 12-1/4" SEC, S84F, #963559, 13-122, 242', 23-3/4, 90, 50, 3-1/SF-Z 10,690', (130'), Drlg Drl 10,560'-10,565', circ& drop surv, pmp pill, POOH, tight @ 8485'. Pull to 13-3/8" shoe 0VO pmp mtr), RIH w/#33, tight @ 5042'. WO pmp, rm 60' to btm. WO pump,^drl 10,565'-10,690'. Survey' 10,510', 46-3/4u, S66W The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Date 06/04/82 Drilling Superintendent JUN 1 6 1982 Alaska Oil & Ga~ Cons, (:;u~i~i~is~iv. Anchorage INumber all daily well history forms consecutively IPage no. as they are prepared for each well. I 10 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when fi]]ed out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for work@vets and following setting of oil strinG until completion. District Field Date and depth as of 8:00 a.m. 04/08/81 o4/o9/81 O4/lO/81 o4/11/81 o4/12/81 o4/13/81 04/14/81 he above is correct !County or Parish Alaska Cook Inlet Lease or Unit McArthur River Trading Bay lC@replete record for each day while drilling or workover in progress IState Alaska Well no. K-3RD Wt. 10.5, Vis 44 Bit #33, 12-1/4" SEC, S84F, #963506, 122-13, 225', 20 hr, 100, 50 3/BT- 2/SF-1/8 10,790', (100'), Ring Drl 10,690'-10,790', replace rib hose. POOH, tight @ S990' & 5950'. Chg bit, RIH, cut DL, RIH w/#34, rm 5950'. Survey: 10,735', 46-3/4°, S6SW ll,00S', (215'), POH Wt. 10.5, Vis 43 RIH, rm 40' to btm. Drl 10,790'-11,005,. Circ & drop surv, prop pill. POOH, tight @ 10,350', jars did not wk. PU kelly & circ loose. Wt. 10.5, Vis 41 Bit #34, 12-1/4" SEC, S84F, #972739, 122-13, 215' 17-1/2 hr 110 50, 3/BT-1/SF-1/8 11,045', (40'), Wk stuck DP POOH, chg BHA, RIH w/#35, rm 8545' (tlght), 60' to btm. Dr1 30' in 30 min, 10' in 35 mln, 100% coal. POOH tight 11 stds off btm. Stuck 18-1/3 stds out. Wk plpe, clrc, no jarring action. Bit @ 9300'. Survey: 10,950', 46-1/2©, S68W Wt. 10.5, Vis 40, PV 14, YP 7, Gels 6/9, PH 10, WL 4.8, Cake 2/32, CL 1300, Sand 1, Sol 14 11,045', (0'), Fsh Wk stuck pipe. PU surf jars, wkd pipe & jarred free. PU kelly & circ, prop pill, POOH, tight @ bit @ 8635', stuck. RU DiaLog on DA, free point @ 7762'. BO @ 7700', POOH, LD 10 ]ts, bent DP. PU 2-DC's & fshg tls, RIH, engage to fsh @ 7700'. Wkd fsh loose dnwards. 11,045', (0'), C&C Wt. 10.6, Vis 43 POOH (tight), tried to unplug bit (unsuccessful). RD DA, LD fshg tls & fsh. RIH w/new BHA & Bit #24 RR. Slip & cut 75' DL, circ BV. RIH, wsh 50' to btm, C&C mud. Wt. 10.6, Vis 43 Bit #24 RR, 12-1/4" RTC, S13G, #346205, Open (C&C rn), 1-1-I 11,045', (0'), Rng 9-5/8" csg. POOH, tight @ 8540'. Circ& rotate. Wk out of key seat, POOH, LD BHA. Pull wear bushings & chg rams to 9-5/8". 11,045', (0'), Lndg 9-5/8" csg Wt. 10.5, Vis 51 Rn 9-5/8" as follows: Btm up, 31-N-80 BTC, XO, 74-N80, 8RD, LTC, XO, 170-S-95 BTC. FS @ 10,983', FC @ 10,885'. Unable to circ any deeper. RU to cmt, tstd cmt ins & pmp 35 bbl H20 pre-flush, dropped btm plug, pmp 200 sx C1 G + .75% D-31L + .3% D-19 + .1% D-6L. Mx H?0 contaminated w/mud. Switch to FW & pmp 800 sx C1 G neat @ 15.8 ppg. Displ cmt w/mud. Bumped plug @ 2000 psi. Flts held. CIP @ 0015 hrs, 04/14/81. Cut flowline off, break BOP stack, instl emer slips, cut & remove 9-5/8" stub. Prep to instl seal a$sy. ;gnature ' · ),., ~"--4' '' / \)"~ ' ' form preparation and distribution Procedures Manual Section 10, illing, Pages 86 and 87 IDate 06/04/82 ITM Dril 1 lng Super int endent Alaska Oil & Gas cons. Commission Anch0rag~ ~3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Page no. 11 AtlanticRichfieldCompany.,., , .)aily Well History-Interim Instructions: This form iS used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. o4/15/81 I County or Parish Alaska ILease or Unit Cook Inlet · McArthur River Trading Bay Complete record for each day while drilling or workover in progress 11,045', (0'), Rep gen& heat exchg IState Alaska IWe!l no. K. 3RD 04/16/81 04/17/81 o4/18/51 04/19/81 04/20/81 04/21/81 04/22/81 04/23/81 Instl packoff & 7" spacer, tst to 3000 psi. NU BOP, LD kelly (spinner bad), chg rams to 5". Shut dn gen 16 hrs to chg heat exch. 11,045', (0'), GIH Repair gen, tst BOPE, PU BHA, RIH w/#36. Wt. 10.3, Vis 44, PV 18, YP 5, Gels 4/12, PH 10.5, WL 4.2, Cake 2/32, CL 1500, Sand 3/4, Sol 15 Bit #36, 8-1/2" SEC, M44NG, #216628, 102-11, 149', 8-1/2 hr., 40/60, 20/40, 6-2-I. 11,120', (75'), Drl cmt & flt equip Tag FC @ 10,885', tst 9-5/8" csg to 2500 psi, 15 min. Set voltage & adjust EMD2. Drl FC & cmt to 10,983' (FS), CO to 11,045' , tst csg @ 10,963'. Drl 10' new hole to 11,055". Leakoff tst to 16.6 ppg, drl to 11,120'. 11,257', (137'), Drlg Wt 10.5 Drl 11,120'-11,239', SLM, POOH, operate BOP f/remote cntrl (would not retract). RIH 2/#37, drl 11,239'-11,257' (no inc. in torq w/pipe rubbers). Survey' 11,190', 46-3/4°, S70W 11,566' , (329') Drlg 11,257'-11,566' . Bit #37, 8-1/2" Sec, S84F, #974298, 102_-11, 565', 34 hr., 50/60, 35/40, 11,836', (270'), Drlg Wt. 10.2, Vis 50 Drl 11,566'-11,804', drop surv, POOH. RIH w/#38, fill pipe @ 7000', rm 30' to btm. Drlg 11,804'-11,836'. Survey: 11,750', 42-3/4°, S72W Bit #38, 8-1/2" Sec, S84F, #974270, 102-11, 436', 19-1/2 hrs, 50, 40, 12,240', (4049, RIH Wt. 10.2, Vis 45 Drlg 11,836'-12,240', circ, drop surv, pmp pill, POOH, RIH w/#39. Survey: 12,190', 41-3/4©, S72W Wt. 10.2, Vis 40, PV 18, YP 5, Gels 4/9, PH 10.5, WL 4.2, Cake 2/32, CL 1400, Sand trace, Sol 15 12,530', (290'), POH RIH, rm 30' to btm, drl 12,240'-12,530', circ & surv @ 12,530'. Bit #39, 8-1/2" SEC, S84F, #972'286, 102-11, 290', 17 hr, 60, 45, 7-6-1 12,800', (270'), POH Wt. 10.2, Vis 42 RIH w/#40, rm to btm, drl 12,530'-12,800', circ & surv. Survey: 12,480', 41-3/4°, S72W 2-7-1 5-3-1 The above is correct Signature 06/04/82 For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent JUN 1 6 !9B2 0it & Gas' Cons. Commission AR3B-459-2-A INumber all daily well history forms consecutively as they are prepared for each well. Page no. 12 AflanticRichfieldCompany Daily Well History-Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tesls se(luen~ially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final cornoletion, ReDort official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting oi~ oil string until completion. District Field Alaska McArthur River County or Parish Lease or Unit Cook Inlet Trading Bay Alaska no. K- 3RD Date and depth as of 8:00 a.m. 04/24/81 04/25/81 04/26/81 04/27/81 04/28/82 o4/29/81 Complete record for each day while drilling or workover in progress Wt. 10.2, Vis 47 Bit #40, 8-1/2" Sec, S84F, #972284, 102-11, 270', 14-1/2 hrs, 60, 45, 8-6-1/4 12,898', (98'), POH Pull wear bushing & tst BOPE, RIH w/#41, cut 100' DL, rm 60' to btm. SU · Drl 12,800'-12,898'~._1/7' S68W Survey: 12,750', 4 Wt 10.2 Bit #41, 8-1/2" STC, F2, #RL4721, 102-½1, 98', 4,-3/4 hr., 60 45 8~8_-1/4 Bit #42, 8 1/2" SEC, S84F, #100444, 10 -11, 77' 3-1/2 hr, 6~, 4~, 4-1/4 12,990', (92'), Drlg RIH'w/#42, drl 12,898'-12,975', circ, POOH, RIH w/#42, rm 120' to btm & cond mud. Drl 12,975'-12,990'. Survey'' 12,850', 42°, S68W · Wt 10.2 Bit #43, 8-1/2" Sec, H77SG, #911077, 102-11, 15 hrs, 2 60, 45, 6-2-1 13,232', (242'), Drlg POOH, chg BHA, RIH w/#44, rm 60' to btm. Drlg 12,990'-13,232'. Survey: 12,950', 40-3/4°, S67W Wt. 10.3, Vis 53 13,413', (181'), POH to log Drlg 13,232'-13,413', circ, POOH to 9-5/8" shoe, cut & slip DL. RIH to btm, C&C mud f/E log. Surv, pmp pill & POOH. Surveys: 12,850', 42°, S68W 12,950', 40-3/4°, S67W Wt. 10.3, Vis 47 Bit #44, 8-1/2" Sec, S86F, #100799, 103, 423', 24 hr, 60, 45, 4-4-1 13,413', (0'), Circ f/lnr RU Schl, run DIL/Sonic/CAL - CNL/FDC/GR. RD Schl, RIH w/#44, C&C mud, short trip, C&C hole f/7" lnr. Wt. 10.2, Vis 47 13,413', (0'), Rev out above lnr RU ~ ran 2734' of 7" lnr 29#N & S-95. RIH w/DP to shoe @ 13,395', circ BU. RU head, drop ball & shear-out @ 2400 psi. Press drop to 2000 psi/5 min. Shear-out ball & seat @ 2800 psi. Rel f/lnr TOL @ 10,660'. Tst cmt In to 3000 psi, pmp 70 bbls pre-flush + 800 sx cmt Displ w/296 bbl mud, bumped plug @ 3000 psi, flts held. CIP @ 0630 ~rs. POOH 2 stds & rev circ. The above is correct Signature ../ 06/04/82 For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-A Drilling Superintendent RECEIVEO JUN 1 6 1982 Alaska Oil & Gas Cons, Commission Anchorage INumber ail daily well history forms consecutively as they are prepared for each well. Page no. 13 Atla nticRichfieldCom pa "-Daily Well History-Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests secluent~ally, Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or represenialive test on "Final" form, l) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string iS set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptr~ as of 8:00 a,m, County or Parish Alaska Cook Inlet Lease or Unit McArthur River Trading Bay Complete record for each day while drilling or workover in progress 04/30/81 05/01/81 05/02/81 os/o3/81 o5/o4/81 JState Alaska JWe..o. K- 3RD Wt. 10, Vis 54 13,413', (0'), GIH PU 3-1/2" DP Pmp pill, POOH w/lnr setting tl. LD tls, PU BHA, RIH to TOL @ 10,660'. Circ, trc of cmt. POOH w/#45, PU6" bit, csg scrpr, bit sub & 6 4-3/4" DC's. Wt. 1.0.1, Vis 54 Bit #45, 8-1/2" Sec, M44NG, #220291, 123, CO, 1-1-I 13,413', (0'), Setting retainer PU 3-1/2" DP, then 5" DP, re-check 3-1/2" meas. RIH to LD colr @ 13,311', no cmt. Press tst csg to 3000 psi. Broke dn @ 3000 psi @ 2 BPM (-2800). DO LD clr, slip to FC @ 13,352', DO FC, slid to shoe @ 13,393'. DO shoe & wsh to 13,405', circ BU. POOH w/#46, RIH w/Halib. 7" cmt rtnr/EZ Drl. Break circ. Wt. 10, Vis 47, PV 26, YP 7, Gels 6/14, PH 11.5, WL 8, Cake 2/32, CL 4500, Sand 3/4, Sol 13 13,413' PBD RIH to TO cmt. Set Hall. 7" rtnr @ 13,342', szq 200 sx cmt. CIP @ 0800, 05/01/81. Rev cir¢, POOH 30 stds, tst lnr lap (leaked). POOH, RIH w/Hall. 9-5/8" RTTS & set @ 10,395', sqz 7"x 9-5/8" ann w/120 sx cmt. CIP @ 2015 hrs, 05/01/81. Rel tl & POOH 1 std & rev circ (no cmt). POOH ~/ RTTS, RIH to TO cmt @ 10,562'. Wt 10, Vis 41 13,413' BPD, tst csg & lnr lap Drl cmt 10,562'-10,660', C&C mud, POOH, LD 6-1/4" DC. Ck DC mtrs on drawworks. RIH w/6" bit, 7" csg scrpr & locate cmt in 7" @ 13,176'. Drl hard cmt 13,176'-13,300', circ. POOH, slip & cut DL. Tst csg & lnr lap to 3000 psi/15 min. PU Hali. WSO tl, RIH to 3100', fill DP w/FW. Wt. 10, Vis 41 13,413' PBD, Rng lnr lap tst tls Ran WSO tst on 7" x 9-5/8" lap. POOH, LD tls. Tst no good (tl would not open). Ran Eastman gyro while WO new tl. #1-220', #2, 13,300'. RD, MU Hall. WSO tl w/ann press rel valve instead of hydrospring. RIH 43 stds w/FW cushion. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-A JDate ITitle 06/04/87. Drilling Superintendent JUN 1 6 i982 Abska 0il & ga,~ 0ohs, C0i~/rnl~st0n Anchorage J N umber all daily well history forms consecutively as they are prepared for each well. IPage no. 14 AflanticRichfieldCompany Daily Well History- Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill slem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final complehon, Report official or representative test on "Final" form, 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Weclnesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. os/os/el os/o /81 os/o7/81 os/o8/81 I County or Parish Alaska JLease or Unit Cook Inlet McArthur River I Trading Bay Complete record for each day while drilling or workover in progress State Alaska IWe,, no. K-3RD Wt. 10, Vis 45 13,300 ' PBD, Rng CBL Ran #2 WSO tst on 7" x 9-5/8" lap. POOH 2 stds, came to fluid. Unable to open, Rev out sub, POOH wet, LD tls, charts OK. RU Dresser & tst lub to 1000 psi. RIH, stopped @ 11,160'. POOH & chg rubber stab on tl to spring type. Log dn all free pipe @ 11,450'. Btm @ 12,394' WLM (CBL). Wt. 10, Vis 45, PV 17, YP 6, Gels 4/12, PH 11.5, WL 8.4, Cake 2/32, CL 4200, Sand 3/4, Sol 12 13,300' PBD, Serv rig Ran CBL w/1000 psi. POOH, RIH w/jk bskt gage ring to TOL. RIH w/Hall. EZ Drl rtnr & set @ 10,560' w/WL. RD DA, PU stinger & RIH. Circ & MU ~ tst cmt Ins to 5000 psi. Stab into rtnr, close pipe rams & press ann to 2000 psi. Est in] rate @ 3 BPM w/3050 psi (max 3600). PO of rtnr, pmp 50 b FW + 200 sx C1 G + .8% D=31L @ 15.8 ppg, followed w/5 bbls FW. Displ w/10 BFW, stab in, put 2000 psi on ann & szq w/ 40 FBW & 195 sx cmt. Final press, 2800 psi. CIP @ 2040 hrs, 05/05/81. POOH 2 stds, rev out, left 5 sx cmt on TO rtnr (no cmt rev out). POOH, string f/10-8 lines. Repair kelly spinner. Wt 9.4, Vis 44 13,300' PBD, GIH RIH w/8-1/2" bit & 9-5/8" csg scrpr. Tag TO cmt @ 10,490'. Drl cra'c, rtnr & cmt to 10,660'. CBU, POOH, LD BHA, PU 6" bit & 7" csg scrpr. RIH, tag cmt in 7" @ 10,979'-11,090'. RIH to 13,300' PBTD. C&C mud, cut back to 9.4 ppg). Spot KCL (8.8 ppg pill, 12,000'-13,300'). POOH. Wt. 9.4, Vis 37, PV 11, YP 4, Gels 5/12, PH 11.5, WL 12.8, Cake 2/32, CL 4500, Sand 1/2, Sol 12 13,300 ' PBD, POH w/WL RIH w/Hall. WSO tl w/3100' H20 cushion. Set RTT's @ 10,600', open tl & had weak blow, 15 min intervals. Shut in 15 min, open 3 min, weak blow, dead f/30 ff. Took 1 hr Isl. POOH, LD WSO tls, press csg to 3000 psi f/30 min (lost 50 psi). RU DA tst lub 500 psi. RIH w/4" mag, orient, shot 4 holes @ 12,720'-12,721' on 120°, then turned 60o & shot 4 holes 12,720'-12,721'. POOH. RIH w/jk bskt & gage ring to 13,300'. RIH w/EZ Drl rtnr & set @ 12,710' CBL/DIL. POOH The above is correct Signature ', ,, , IDate [Title .,/ ....... 06/04/82 For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Superintendent JUN 1 6 1982 Oil & Gas Cons. Commission /~chorage AR3B-459-2-A I Number all daily well history forms consecutively as they are prepared for each well. Page no. 15 A tla nticRichfieldCom pa n - aily Well History-Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or {2) On Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District I County or Parish IState Alaska ILease or unit Cook Inlet McArthur River I . Trading Bay Alaska IWell no. K-3RD Field Date and depth as of 8:00 a.m. 05/09/81 os/lo/sz '0S/il/S1 0S/12/81 05/13/81 Complete record for each day while drilling or workover in progress 0S/14/81 13,300' PBD, RIH RD DA, RIH w/DP to 12,710'. RU & tstd cmt ins to 5500 psi. Spot 50 bbls KCL pill @ 12,710', stab in w/2000 psi on ann, broke dn perfs @ 12,720'- 12,721' w/5400 psi. Est inj rate @ 2 BPM w/4000 psi. Inj 30 bbl KCL. PO of rtnr. M&P 10b KCL, 125 sx C1 G + .5% KCL, 35 gal/100 sx D45L, 7 gal/100 sx R12L, 10b KCL. Spotted cmt to 5 bbls of ret, stab in & sqz 5b KCL + 100 sx 15.8 ppg cmt. Final press 5200 psi. CIP @ 1335, 05/08/81. Press bld to 3000 psi in 5 min. PO of rtnr & spot 25 sx cmt on TO rtrLr. POOH 1 std & rev out 3-5 bbls cmt. POOH, WO gen, WO cmt. RIH w/bit, cut & slip 75' DL. Tag cmt @ 12,603', circ, drl 107' cmt on TO rtnr & 12' below rtnr. RIH to 13,300' PBTD. Pmp hi-vis pill, followed by filtered Inlet H20. H20 pmp dn (Prod repairing). Wt. 9, Vis 90, PV 16, YP 44, Gels 42/48, PH 10, WL 3.2 13,300' PBD, Rng pkr Displ mud w/filtered Inlet H~0, spot 150 bbl. Drl 13:.300'-9950', POOH, LD DP. RU & rn pkr on WL. Unable to get below 11,450'. POOH to ck pkr & make jk bskt/gage ring rn. 13,300' PBD, fsh pkr F-1 Pkr stuck @ 11,300', unable to wk free (max pull). Free pkr, POOH to TOL w/JB/GR. POOH @ 720', PO of rope socket. RU WL overshot. RIH w/JB & 5.7" GR to 13,300'. POOH (recovered jk). RIH w/ pkr, stuck @ 11,860'. PO of rope socket, POOH, RD DA, MU WL overshot on tbg. RIH w/3-1/2" & 4-1/2" tbg @ 12,440' w/overshot. Have not found pkr. 13,300' PBD, FIH-FIW Locate pkr @ 12,800', stuck. Sheared WL rng tl out of'pkr. Pkr set. POOH, LD tbg (recovered all WL tls & pkr rng tls). Pkr set @ 12,800' RIH w/Tri-State pkr, milling BHA. PU DP. 13,300' PBD, RIH-FIW RIH to 12,800', repl valve bet stand pipe & kill manifold. Rev circ & save drl solids from TO pkr. Pull 400,000# (130,000 overpull) on pkr. Would not move. Mill over pkr. POOH w/FIW, LD fsh, RIH w/DP. 13,300' PBD, RIH w/pkr mill-FIW RIH w/DP to 13,293', circ, rev 2 circ & ahead 2 circ. Spot Drl S pill 13,293'-12,000'. POOH, MU & rn Baker F-1 pkr & preset @ 12,088' on DP. Pull loose f/pkr & rev circ. Drl S pill, POOH w/pkr rng tls, MU Tri- State pkr plucker & RIH, cut DL. The above is correct Signature .,) ; ",. For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-A IDate ITitle 06/04/82 Drilling Superintendent RECEIVET) JUN 1 6 19B2 Git & Gas Cons, (~0mmission Anchorage INumber all daily well history forms consecutively as they are prepared for each well. Page no. 16 AflanticRichfieldCompany Daily Well History -Interim instructions: This form is used during drilling or workover operatiens. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests secluentiall,./. Attach description of all cores. Work i~erformed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m, 05/1S/81 os/16/81 os/17/81 05/18/81 0S/19/S1 0S/20/81 0S/21/81 County or Parish Alaska Cook Inlet Lease or Unit McArthur River Trading Bay Complete record for each day while drilling or workover in progress JState Alaska IWell no. K-3RD 13,300' PBD, tst 7" pkr-FIW Mill pkr @ 12,088', POOH & LD fsh. Tst BOPE, PU scrpr & jk sub on 4-3/4" DC & RIH to 10,660'. Rev circ @ TOL, RIH to 13,000'. Rev circ & catch Drl S slug. 13,300' PBD, POOH Spot Drl S pill @ 13,000'-12,000', POOH. GR/JB, could not get into TOL, POOH. Rn /cR (9,s/8"), run 13,300' PBD, Rn 9-5/8" Tst BOPE, repl Hydrl GK rubber, 3000 psi tst. RIH w/DP to 13,293' rev circ@ TOL. Circ, hi-vis pill. Received much rubber & trash. Drl S pill @ 10,460', 200' above TOL. POOH, rn DA J~/GR 9-5/8". Spot 13,300' PBD, tst 7" pkr Lost JB/GR in 9-5/8" in hole. Fshd out f/TOL. Rn 7" JB/GR to btm of 7", RIH w/Brown pkr w/Baker setting tl on 3-1/2" DP. Set Pkr w/2500 psi, set dn 20,000#. POOH, LD tls, RIH w/seal assy & tst pkr to 2000 psi f/ 20 min. Pkr set @ 12,430'. 13,000' PBD, Rn 4-1/2" tbg Rev circ, Drl S pill, circ hi-vis pill, POOH, LD DP, chg rams & tst to 3000 psi. RU to rn tbg, rn shear out sub, seal assy w/2 jts 3-1/2" 9.2# N-80 tbg, 4-1/2" N-80 tbg. 13,300' PBD, prep to perf Rn 63 jts, 3-1/2", 9.2# N-80 BTC tbg + 338 jts, 4-1/2", 12.6#, N-80 BTC tbg w/Camco TRB-8 SSSV. Tst cntrl in to 5000 psi. Stab in to pkr @ 12,430', space out, lnd tbg w/locator sub 1' above pkr. Drop ball & tstd comp string to 3000 psi f/15 min. PreSs to 3500 psi to shear out. Pkr held, set BPV, ND BOPE, NU tree & tst to 5000 psi. Turned well over to production f/gas lift prior to perf, 0600 hrs, 05/20/81. 335 bbls unloaded. 13,293' PBD, tstg well Cont to gas lift & unload well. RU DA & Perf: #1: 12,856'-12,877' (21') #2: 12,835'-12,856' (21') #3: 12,814'-12,835' (21') #4: 12,808'-12,814' (6') - 4 SPF - 4 SPF - 4 SPF - 4 SPF Flow well f/prod tst of perf'd intervals. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date 06/04/82 AR3B-459-2-A ITitle Drilling Superintendent JUN 1 6 i982 A13ska 0il & Gas 0OHS. Commission Anchorage INumber alt daily well history forms consecutively as they are prepared for each well. IPage no. 17 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon comDletion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Field Auth. or W.O. no. Alaska McAr thur River AFE 397831 County or Parish · Lease or Unit Title Cook Inlet Trading Bay Redrill State Alaska iWel, no. K-3RD Operator A.R.Co. W.I.. ARCO Alaska, Inc. Spudded or W.O. begun Redrill Date 02/21/81 Date and depth as of 8:00 a.m. Complete record for each day reported 'rl'otal number of wells (active or inactive) on this i Icost center prior to plugging and ~ labandonment of this well ! IHour . ' I Prior status if a W,O. / ' 0 00 I os/2z/s1 Perf #S 12,787'-23,797' (10')-4-SPF.. RD DA, flow well. Flow tst well, 4 hfs, actual tst after well' clnd up. RU DA, #6 12,.767'-12,878' (20')-4-SPF. INew TD I PB Depth Date IKind of-rig 05/22/81 Type completion (single, dual, etc.) Single Official reservoir name(s) McArthur River RR @ 0600 hrs., 05/22/81. Old TD 11,734' PBD Released rig os/22/81 Classifications (oil, gas, etc.) O±1 Producing method Flowing 13,300' Platform Potential test data rWell no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date · corrected ,. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C ' Date ITitle 06/04/82 Drilling Superintende. nt JUN 1 6 i982 INumber all daily well history forms consecutively as. they are prepared for each well. iPage no. 1 8 Division of AtlanticRIchfieldCompany A PETROLANE COVCPANY o¢ D#~EC T#ON~ £ Arco Alaska, Inc. COMPANY K-3 - RD WELL NAME COOK INLET, ALASKA LOCATION JOB NUMBER A581G0328 SURVEY BY Ahdy Hickman/Tom Breen TYPE OF SURVEY Gyro Multishot II. C. Wanhcn DATE 5-3-81 RECEIVE JUL 0 ! 1981 OFFICE A ~:'TROLANE P. O. Box 4-1970/Anchorage, Atas'/.r.a 99509/(907) 349-4617 TWX 910-851-506$/Cab/e: EASTCO May 7, 1981 Arco Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: K-3 - RD Location: Cook Inlet, Alaska Type of Survey: Gyro Multishot Date: 5-3-81 Method of Computation: Radius of Curvature Surveyor: Andy Hickman/Tom Breen Job Number: A581G0328 Attn: Marion Brooks Dear Mr. Brooks: I am enclosing the original and one cop~ of the Gryo Multishot Survey run on the ~bove mentioned well. We wish to take this opportunity to thank'you for calling on our services and trust that we may continue to serve you in the future. ones Di ct Technical Coordinator Alaska District TJ/kp enclosure RECEIVED JUL 0 11981 011 & (las Co~s, ~o~ Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sa.es...'Worldwide RCO ALASKA, INC. ING SALMON F't, TFM, ()OK INLEI', ALASKA I,,JEi. L NO",* K-3 GMS/GMS JOB A581G0328 COMF'UTATI ON '.: TIME · r;A'rE 12:41 ::!,2 07--MAY-81 PAGE .2 EASURE;'~ DRIFT DEF'TH ANGLE F E E T D M 3000. h9 0 3100, ~ ,.~,:. 15 3200, 53 0 ggO0, 52.g0 3400. 52 45 3500. 53 0 ~600. 53 45 ~700· 54 45 ~800. 55 0 ~900. 55 0 TRUE DRIFT COURSE VERTICAL VERTICAL DIRECTION LENGTH BEF'TH SECTION D FEET FEET F'EET S 48 W 100· 2724.64 910.65 S 49 W 100. 2788.07 985,83 S ,17 W 100; 2848.77 1062,96 S 47 W 100. 2909.~0 1139·88 S 48 W 100· 2970,00 1216,85 S 48 W 100. 8 48 W 100· S 47 W 100· S 48 W 100. S 48 W 100· SUBSEA TVD FEET 2624.64 2688,07 2748'.77 2809.30 2870.00 3030·36 1294.24 2930.36 3090.01 1372.14 2990.01 3148·44 1450.74 3048.44 3205.97 1529.95.. 3105.97 3263.33 1609.46 3163.33 RECTANGULAR C 0 0 R D.I N A. T E S FEET 707.79 S... 759. O0 S ' 81° .1.8 S 866.47 S. 920,15 S 654 712 771 829 888 ,51 .40 ,45 .67 ,26 ,52 .16 975.51 S .... 947 1027·21 S 1007 1082.04 S 1066 1137.29 S ..1127 1192.10 S 1188 C L 0 S U R E EIISTANCE DIRECTION FEET D M W 964.03' S 42 46 W W 10,40·96 S 43 11 W W 1120.17 S 43 32 W W 1199.63 S 43 45 W ld 1278.9'1 S 43 59 W W j.~o ~.49 S 44 13 W W 14~8.58 S 44 26 W W 1519.63 S 44 36 W W 1601.32 ~ 44 45 W W ].~8~ 11 S 44 54 W DOGLE SEVER t r~G/100 4.00 1.76 0.50 0.83 0.75 0,86 0,00 4000. 55 15 4100, 56 15 4200, 56 0 4300, 56 0 4400. 56 30 S 48 W 100, S 47 W 100· S 48 W 100, S 49 W :[00, S 48 W 100, 3J20.51 1689.10 3220.51 J376.79 1769.15 3276.79 3432,53 1849,56 3332.53 3488. 4'~ 1930.20 3388.45~ ~544.01 2011.08 3444.01 1247,00 S 1.249,14 W 1765,04 .S 45 3 W 1302',84 S IJ10·08 W 1847·62 S 45 10 W 1358.9'3 S 1571·29 W 19.30.58 S 45 16 W 1413,87 S 1433 38 W 7013 35 S 45 "'4 W 1468,96 S 1495,65 W o096... .7:;P S 4"o 31 W 0.25 0,87' O· 0.97' ,;500. ":' · ,J6 0 4600. 56 30 4700. 56 0 ';800. 56 15 4900. 53 45 S 50 W 100. S 48 W 100. S 48 W 100. S 49 W 100. S 50 W 100. 3655,12 217J,15 3710,68 2253,86 3766,42 2334,62 3823,77 2414.61 3499,='6~ 3555.12 3610,68 3666,42 3723·77 1523.51 S 1558,40 1578.06 S 1621.14 1633.69 S 1682.93 1688,70 S 1745,11 1741,90 S 1807,40 (,,; ,..?179.';' c',., ,.., S 45 S9 W ':""~":' 38 S 45 46 W ~.. ~-.. ~1 .~... W ,..03,.15. 47 S .,1~'',..., 51 W W' ,...'>'.1 .,-,.,° c:,, 40 S 45 56 W W o ,'.-- ~oi0.16 S 46 3 W 1 1.7z: ,J C 8~ '~6 ;'~ 5000, 50 0 5100. 50 30 =000, 50 45 5300. 50 0 5400. 47 30 5500· 47 15 5600. 46 45;' 5700, 46 0 5800. 44 45 5900. 44 15 S 56 W J. O0., S 56 W 100. S 55 W 100, S 55 W 100, S 58 W 100· S 59 W 100· S 60 W 100. S 60 W 100. S 59 W 100. S 60 W 100. 3885,50 2492 3949.44 2568 4012.88 2645 4076,65 2722 4142.58 2796 ,28 3785,50 1789,21 ,75 3849.44 1832,21 · 57 3912,88 1875,99 ,03. 3976,~. 1920.17 °86 4042.58 1961.66 4210,30 2870,31 4278.50 29'13,38 4347.50 3015.73 4417.74 30'~z 00,83 4489,07' 3156·86 S 1870 S 1935 S 1997 S 2060 S 2!23 · 4110,30 2000.10 S 2186 4178.50 2037.22 S 2249 4247·50 2073.41 S 2311 4317.74 2109.53 S 237~ 4389.07 2145,11 S 2433 ,18 ,93 ,63 ,72 ,40 .14 .16 .85 ,17 .56 W g.,oo,_~"='""" oo S 46 16 W W 2664.03 S 46 33.W · W 2740,41 S 46 48 W W 2816.67 S 47 1 W W 2890.84 S 47 16 W W 2963·04 ·s 47 33 W W 3034,63 S 47 50 W W 310,, 43 S .o ' =. 4,.) 7 W W '3175 2~ S 48 oo W W 3244·02 S 48 36 W 6,02 0.5¢ 0.8! O,7E O,7E 0.89 0.7=,_ 1 , 4 ,! 0,86 RCO ALASKA, INCo lNG SAL. NON PLI'FM, WE'LL 'N~: OOK INLET~ ALASKA K-3 GHS/GttS JOB NO: COMPU]'ATION " ;:'AGE NO A581GO328 TINE DATE' 12;41~12 07-NAY-81 EASURED [;RIFT DRIFT DEF'TH ANGLE DIRECTION FEE T D N D TRUE COURSE VERTICAL VERTICAL LENGTH DE:P]'H SECTION FEET FEE]' FEET SUBSEA TVD FEET R E C T A N G U L A R C L 0 S U R E DOGL. E C O 0 R I'~ ~I-,.N A T E S DISTANCE BIRECTION SEVER! FEET FEET D M DG/100 9000. 45 0 S 78 W 9100, 44 30 S 78 W 9200. 42 30 S 72 W 9300. 42 0 S 68 W 9400. 41 0 S 69 W 9500, '42 0 S 68 W 9600. 44 30 S 68 W 9'700, 41 30 S 64 W 9800. 43 0 S 62 W 9900, 46 0 S 62 W 100. 6662.92 5326.34 6562,92 100. 6733.94 5393.98 6633.94 100. 6806.47 5461.00 6706.47 100, 6880.49 5527.55 6780.49 100. 6955.39 559~.37 6855,39 100. 7030.28 5659.20 6930,28 100, 7103,11 ='~ _ .u7~7.~o 7003.11 100. 7176.24 '5795.33 7076.24 100. 7250.26 5862.55 7150.26 100. 7321.58 5932.63 7221,58 2819.51 S ...... 45~2.70 W 5338.07 S 58 7 W 2834.14 S 4601,56 W 5404.~3 S 58.22 W 851.95 S 4668.02 W 5470',29 S 58 35 W 2874.94,.S .... 4731.19 W 5536.19 S 58 43 W 2899.23 S 4792,84 W 5601.50 S 58 50 W =9=3,51'..S .... 2949,18 S 2976,91S · 3007,43 S · 3040.33 S 4854.49 W 5666.83 S 58 57 W 4918.01 W ~,734.50 S 59 3 W 4980,29 W. 5802.18 S 59 8 W 5040.00 W .~o69.96 S =-o ...... ~ 11 W 5102,08 W 5939.26 S 59 13 W 0.71 0.50 4.59 2.74 1,2C ~2C 400E 2,01 3,0C 10000. 47 30 S 63 W 10100. 48 0 S 63 W 10200, 47 30 S 63 W 10300, 47 30 S 63 W ' 10400, 47 30 S 63 W 100, 100, 100, 100, 100, 7390.09 7457.33 7524.57 7592.13 7659.69 6005,46 7290,09 6079.47 . 7357,33 6153.48 7424,57 6227.19 7492,1~ 6300.91 7559.69 3073.96 S .,5~66.68 W 3107'.57 S' ~o~,~,64 W · 3141.17-S- 5298.59 W 317,t,64 S 5364,28 W 3208.12 S 5429.97 W 6011,97 S 59 15 6085,84 S 59 18 6i59,71 S 59 20 6233.29 S 59 23 6306.87 S 59 25 W 1.67 W 0.50 W. 0~5C W O,OC W O.OC I050'0. 46 0 S 61 W 10600. 46 30 S 63 W 10700. 47 15 S 64 W J. 0.~00 47 0 S 64 W 10900° 47 0 S 64 W 100. 100, 100, 100. 100, 7728.20 7797.35 ~ C; c:' 7933. .... :' it ~.) 8001,95 6373.74 7628,20 3242,31 S · 6445~97 7497.35~ 3o76.~_ ~ S 65180.9~ 776'5.71 3308.79 S 6592.17 7833.75 3340.91 S 6665~25 7901.95 3372.97 S 5494.28 5623.37 5689.24 5754~98 6370 63. S 5° ~7 W · · . · 6451.79 S 59 29 W 652'1.6/)~ S. 59 S"~ W 6597.66 c ~:'-~-~:; .... , ~ .... 6670,58 S 59 S8 W 2.05 .~. -,,.,¥ 0 c 11000, ,;6 4='~, S 6,1 I,,J 11100. 46 0 S 66 W 11200. 47 0 S 65 W 11300. 46 30 S 66 W 11400. 45 30 S 66 W 100. 100, 100, 100, 100, 8070,31 8139.31 8208.14 8276.66 8346.12 6738.19 7970,31 3404.97 S 6810.47 8039.31 3435.56 S ~ooo 86 8108,14 3465.64 S 6955.55 8176.66 3495.84 S 7027.30 824A.1~ 3~'~ 5820,57 W 5886,17 W 5952.18 W .6018.45 W 6084.17 W 67,13.343 S 5'f;' ,I0 W 681 '::; 4 S '" ":'" ~..~ C) . 6887.60 S 59 47 W- 6960 08 S ~' 703i.60 S ='9 ...., 0.2E 1.6J I .2': 11500, 45 0 S 68 W 11600. 44 0 S 66 W 11700, ,;3 0 S 67 W 11800. 42 30 S 66 W 11900. 43 0 S 66 W 100, 100. 100. 100, 100, 8416.52 8487.85 8560.:$8 8707.'~= 7098.04 8316,52 3552,85 S .. 7167,85 8387.85 3580,23 S 7236.46 8460.38 3607,68 S 7304.12 8533.82 3634.74 S ... 7371.83 8607,~5~ 3662,35 - S 6149.54 W 6214.05 W 6277.18 W 6339.43 W 6401.44 W 7102.08' S 59 59 W 7171.6=.., ,~ 60 3 W 7240.05 S 60 7 W 7307.5~. S 60 10 W 7375.04 S 60 1,1 W 1.51 '1,72 1.2! 0. E~ 0.5C RCO ALASKA, INC, iNG SALMON F'L. TFH, OOK INt..ET, ALASKA WELL NO: K-3 · GMS/GMS JOB NO: A58130328 COMF'U'rATI ON " TIME DATE 12141:12,' 07-MAy.-.81 PAGE NO ,. ,... EASURED [;RIFT DRI DEF'TH ANGLE DIREC FEET D M D TRUE FT COURSE'VERTICAL TION LENGTH DEF'TH FEET FEET VERTICAL SUBSEA SECTION TV[; FEET FEET R EC T A N G U l_ A C 0 O R D I..N A T E FEE]" R C L 0 S U R E DOGLE S BISTANCE DIRECTION SEVERI FEET n M DG/10C 6000. 43 30 S 63 6100, 43 0 S 68 6200. 4~ 15 S 69 6300, 44 15 S 68 6400, 45 30 S 68 W 100, 4561,15 W 100, 4633.99 W 100, 4706,97 W 100, 4779,21 W 100, 4850,07 3226,16 4461,15 .2178.18 S ....... 2494.46 W 3~94.... 52 4533.99 ,.°206.58 S ,,o556.79 W 3362,43 4606,97 2231,6~ S 2620,39 W 3431.1.o 4679,Ol ~- ~6~ ~,98 S 73 W ~u01, ~8 4750.07 '>~ ~ ,,,.85,41 S 2750.15 W 331~.61 S 48 52 W 2.21 S377...'z0 S 49 12 W 3.4~ 3441,90 S 49 S5 W 0.73 3507,..Z8 S 49 57 W 1.~...¢.°c 3574053 S 50 18 W' 1.2~ 6500. 44 0 S 70 6600. 45 0 S 70 6700. 45 30 S 72 6800° 45 0 S 71 6900, 46 0 S 71 7000. 46 0 S 70 7100, 47 30 S 70 7200. 47 30 S 71 730(), 46 45 S 71 7400. 46' S0 S 71 W 100. 4921.09 W 100o 4992.41 W 1000 5062.81 W 100. 5133.~1~ W 100, 5203.30 W 100. W 100. W 100. 100. W 100. 5571.14 4821.09 2308.64_S ..... 2815.87 5640.53 4892,41 2332.61 S 2881.75 3710.66 4962,81 2355.73 S 2948.88 3780,69 5033.21 .2378,26. S_._3016,22 3851.12 5103.30 2401.48 S 3083.66 5272,77 3922.24 5172'~77'~2425o50..S ...,.~151,47 5341,29 3994,35. '5241,29 ~ 2450,41"S"-"=3219o91 5,108.84 4067,26 5~08.84 2475.02"'S,~ 3289,41 5476.88 4139,62 5~76.88 2498.88 S 3358.70 o~,15.56 4°11.40 5445,56 2522.54' S 3427.43 W S641.28 S 50 39 W '~,,W~O~ W 3707,48 S 51 I W 1.0( W. ~774030 S 51 23 W 1.5] W ~841,06 S 51 45 W 0.87 W 3908,47 S 52 5 W 1.0£ W 3976.78 S 52 25 W 0.75. W 4046.27 S 52 44 W 1.5( W 4116.54 S 53 2 W 0.7,' W 4:1.86.32 S 53 21 W 0.7[ W 42"'5.,.,. 64 S ,...'"',S 39 W 0. .'p''.., 7500, 7600. 7700. 7800. 7900, 46 30 S 7]. · ';~' ,1'"' S 73 ~.I ~.), 46 0 S 74 o 15 S 73 :15 15 ~" o 73 W .1.00. 100. W 100. L,J :L 00, W 100. 56].4,40 4283.02 5514.40' 2546,16 S 5683.71 4353.99 5583.71 2568.43 S 5753.33 4424.31 5653.33 2588,82 S .::c>.'>-- 96 4494,33 = .... ~ 26 o609 19 S ,.,~, ,..,. 66 4564.02 ~ o -> o793,66 ~,6,..9,88 S 3496,02 3564.57 3633.39 3701.92 3769,8.4 8000, 8100, 8200, 8300. 8400, 45 45 S 75 46 0 S 75 47 0 S · 45 0 S 76 45 45 S 76 W 100. W 100. W 100, W 100. W 100, 5963.75 6033.38 6102.21 6171.67 6241.92 4633.77 5863,7"'o 4703.68 5933.38 4774,34 6002,21 4844,26 60,71 , 67 4913,29 614.1 °92 2649,54 S 2668.12 S 2686,89 S 2704,90 S 2722.12 S 38~8 3907 3977 4047 4116 ,40 .73 ,80 .44 .50 8500. 46 0 S 76 ~J600. 45 30 S 76 8700. 46 0 S 78 8800. 44 45 S 77 8900. 45 0 S 77 W 100. W 100. W 100. W 100. W. 100. 6311.54 : ' ,"'I ,~. o3o.1.. So 641;1.10 652.1.. 3,1' 6592,21 4982,91 6211.54 o,~ ,,.~:, 39 6281 , 32 5121 · 55 6351 · 10 51~P0.10 6421.~4 5"~=;~ 23 6490,21 2739,49 S 2756.81S 2772.93 S 2788.33 S 2804,20 S 4186 4255 4325 4394 4463 .14 .65 .44 .92 W W W ~'W 5002,86- S 56 48 W 0,2: ": W 0,5, 5070,56 S o7 4 5137.95 S [57 20 W 1.":'o 5204.82 S 57 36 W 1.4. 5271.42 S 57 52 W 0.2: , , ARCO AL. ASKA, INC. KING SALMON PLTFM, W~LoL N~]: K-S GMS/GMS COOK INLE]', ALASKA TRUE HEASURED DRIFI' DRIFT COURSE VERTICAL VERTICAL DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTION FEET II M D FEET FEEl' FEET JOB NO: A581GOS28 · SUBSEA R E C T A TVD C 0 0 R D FEET FEET COMPUTA¥ION 4'; TIME [ ~-~ T ~' '12;41:.1.2' 07-MAY-81 NGULAR C L OS U I._N A T E S DIe STANCE FEET . PAGE R E IIOGL [;IRECTION SEVER D M DG/iO 0,. 0 0 0 ~. O..~ 0.00 0.00 100. 0 0 0 100. 100.00 0.00 200. 0 0 0 100. 200.00 0.00 300. 0 45 S 37 E 100. 300,00 -0.10 400. 1 0 S 61 E 100. 399.99 -.0.64 ..-100,00 ............0.00 .............. ........ 0,00 0.00 0,00 0.00 100.00 0.00 0.00 ~00.00 O,o~..S ._.'.0.~9 299.99 1.52 S 1.54 0,00 0 0 0.0 0,00 0 0 0,00 0 0 0.66 S S7 0 E 0.7 2.16 500. 2 O. S 76 E 600. 2 15 S 49 E 700. 2 0 S 68 E 00. o 45 S ,)o E 900. 4 SO S 15 W 1000. 8 0 S ~4 W 1.100. 12 0 S 41 W 1200. 14 .1.5 S 40 W 1300. 1.6 SO S 40 W 1400. 18 45 S 4! W 100. 100, 100. ..... 100. 100. 100. 100. 100. 100. 100, 499,95 599,88 699.81 ...... 799.7S 899,52 -4.87 : 998.91;" ...... ~,74 ,1097.S7''::'~ 19.54 1194.75 40.67 1291.17 65.27 1S86,47~ 9S.46 -2.ss. 'sgs ,95 -4.41 499.88 -6.28 599.81 -7.45 ...... 699.7S 799.52 .. 898.91 997'.37 1094.75 1191.17 1286.47 2,47 S _. 4.17 S 6,10 S ...8.95 S.. 15,15 S 25,01.S 38.78 S 56.04 S. 76,35 S 99.37 S 7.~0 10.~7 1B.22 13.60 9.11 1.45 16.20 5:3.24 52.90 4.67 S 58 8.54 S 60 0 E 12.03 S 59 SS E 15.97 S == , ~ 54 E 1.c 20.S6 S 41 55 E 26.62 58.7,4 8~.q7 11 i:,.>. 58 1500. 21 0 S 40 W 1600. 23 45 S 42 W 1700. 26 0 S 42 W 1800. 28 15 S 43 W 1900. '31 0 S 44 W 2500. 33 0 S 44 W 2600. 34 0 S 45 W ..o700. 37 1,., =' S 48 W 2800. 41 0 S ,18 W 29'00. 45 0 S 48' W 100. 1480.51 125,10 100. 1572,97 160.66 100. 1663.69 200.20 100. 1752,68 243.20 100, 1839.60 290.09 100, 100. 100. 100. 100. 1924,28 ~40.69 2007.67 393.21 2090~94 445.90 2174.33 498,42 2257.60 551.11 100. 2341.10 603.45 100. 2424.49 656,11 100. 2505.77 719.~5~ ~ 100. 2583.33 773.49 100. 2656.45 8S9.67 1380.51, 1472.97 1563~69 !652,68 1739.60 1824,28 1907.67 1990.94 2074.33 2157.60 2241,10 2~ 49 2405.77 2556.45 125.22 S 1=~d . 95 S 185.21S ~q18.8o , S 254..67 S 292.92 S 33.q, 63 "' .,.. C..* 372.46 S 412.16 S 452.00 S 491.57 S 530,94 S 571'.02 S 61S,24 S 658.86 S 74.'98 99.95 1m ~8.J.O 158.90 192.9'2 2'29. 136 · 268. :?.0 306.67 345.01 383.48 421,.69 460.37 ~0~ ~ ~.62 549.50 600.1'7 W W W W W ,L45.96 S 30 183.==~o ~ $3 0 W · ~ ~ · ~5.19 S 34 40 W 270.42 S 35 59 W 319,49 S 37 9 37::> 2;4 ,.>38 7 W 427.28 S 38 53 W . 482,46 S 39 '28 W ,5S7.50 S 59 56 W 592,75 S 40 19 W 647.66 -' 0 ~> /,~.o74 760.72 823.41 891,24 S 40 37 W S 40 56 W S ,11 21 W S 41 ~-'~ S 42 20 W 2, O, 0, O, O. . AR13(:) ALASKA, INC, NJ. KG S~.;/..~iOt~ F'LI'F:'H, WE:EL. NO; K-~ 'GMS,/G~S ' COOK INL. EI', ,JOB-NOI A581GOS28' GMS, 0-2200 MD, SURVEYOR: A HICKHAf~, DATE I-"(UN,~ 25--FEI.)-131 [;MS, 2:~!00--1;37;00 MI), ,:,URVEYOR; t.IICI'(MAN/BREEN, I)ATE: RUN: ~.~--MAY-..81 LEG 4, SLOT ~2, WELL NO; K-'3RD S];GI-ITING TO ['~AIt'ER F'LAI'FORN: S 5~ E VERTICAL SECTION CALCULATEI]-~ IN'F'LANE OF F'ROF'OSAL f-~IRECTJ:ON: S ~$1 DE:G. 55 MINo W RE CDF;D. Of:: ::"'UI;,'VE:Y F,'ADIUS OF CURVATUI:cE ~dETFIOD ~RCO ALASKA, INC. 'ING SAI. MON F'LTFM, rOOK INI-.E]', ALASKA · W~LL Nb~ K-3 GMS/GMS iEASURED DRIFT DEPTH ANGLE Fr E E T D M T R U E DRIFT COURSE VERTICAL DIRECTION LENGTH DEF'I'H D FEET FEEl' 12000°. 12100. 1 °°00, 12300, 12400. 42 .0 S 65 W ........... 100, 41 0 S 65 W 100. 42 0 S 64 W 100, 42 0 S0~"= W 100. 42 0 S 64 W 100. _8780.98 8855.87 8930.77 9005.08 9079.39 12500. 42 0 S 66 W 100. 12600. 42 ~0 S 65 W 100. 12700. 42 30 S 65 W 100. 12800. 42 0 S 63 W . . .100, 12900. 42 0 S 63 W 100. 9153, 9227. 9S01, .9375, 9449, 71 7.5 46 48 79 13000, 41 0 S 63 W 100, 15100, 41 0 S 63 W i00, 15200. 40 JO S 64 W 100, 1S300, 40 0 S 65 W 100, 9524, 9600, 9675, 9752, 69 16. 92 24 FINAL CLOSURE -- DIRECTION~ DISTANCE; <: 60 8304,33 JOB NO: A581GOS28 COMPUTATION " TIME DATE 12~41~'12 07-MAY-81 PAGE N.O ~ VERI'ICAL SECT I ON FREE]· SLJBSEA R E C'T A N G U L A R T VD C 0.0 R l) ....I .... N A. T E S FEEl' FEET CLOSURE DISTANCE DIRECTI Oi',l FEEl' D Pi 7439,25 8680,98.. 3690,3Z_..S .... 6462,.91. W 7505,42 8755,87 3718,37 S 6522.96 W 7571.61 8830.77 3746,90 S 6582,77 W 7638,46 8905,08 .3775,70._.S.~..6643017 W 7705,30 8979,39 3804,51 S 6705,56 W 7772,12 7839,22 7906,68 7973,87 8040.77 8107.02 8172,61 8237,87 830~ 4 :[ 9053,71 3832,79...S ......... 6764°20 W 9127,73 3860,67 S 6825,38 W 9201,46 3889,22 S 6886.61 W. 9275.48 3918,.70...S ....~.6947.04 W 9~49,79' ~949,07 S 7006.66 W 9424,69 3979,16...S...:7065,70 W 9500.16 4008.94-'S':'-"'7124.16 W 9575.92 4038.07'~S, 7182.57 W · ~'~ " 72 960~.,~4 4065,88 S 40,89 W · , · · DE:GS 41 i"ilNS 6 SECS W F" E E: 'f.' BOG[~~ SEVER: DG/1 O( 7442,31 S 60 16 W 1.2: 7508,35 S 60 19 W 1,0( 7574.44 S 60 21 W 1.2( 7641.18 S 60 23 W 0.6: 7707.92 S 60 25 W 0.6~ 7774,62 S 60 ~" 7841,60 S 60 30 W 7908.95 S 60 7976.06 S 60 34 b! 1.4' 804~,~o92 ~ 60 ~_ W 0.0( 8109.12 S 60 37 W 1.0( 8174.67 S 60 38 W 0.0( 8239.86 S 60 39 W 8304,33 S 60 4! W ARC[.1 ALAS[(A, IMCo KING SALPION P[..TF~'I, WELL NO; K-~ GMS/GMS COOK' ]~t~LET, ALASK'A JOB NO: A581GO~28 GMS, 0-2200 MI), SURVEYOR; A I-'IIC~'~iAN, DATE RUN: 25--FEB-81 Gi~IS, ~.-.00 13300 l'iI'l, SURVEYOR: HIC[(HAN/BREEN, [;ATE RUN: 3-1~lAY'81 LEG 4, SLOT 32, WELL NO~ K-3RD SIGHTING TO BAt(ER F'LATFORM.~ S 59 E VERTICAL SECTION CALCULATED IN PLANE OF PROF'OSAL I)IRECTION: S ~41 r_~EGo 55 ~41N, W RECORD OF SURVEY ANGI. E' ~:~VERAGING ~E'IFHOD RCO ALASKA, INC. ING SALMON F'LI'FH, OOK INLFT, ALASKA li.".A SURE D DRIFT IiEF'TH ANGLE FEET I'~ M TRUE: [;RIFT COURSE VERTICAL VERTICAL I)IRECTION LENGTH DEF'TH SECTION D FEEl' FEET FEET O. 100. 200, 300, 400, 0 0 0 45 0 0 ............ O, ...... 0,00 0 100, 100,00 0 100, 200,00 S 37 E 100, 300,00 S 61 E 100. 399,99 0,00 0.00 0.00 -0.10 -0.65 500. 600. 700, 800. 900, 0 15 0 45 30 S 76 E S 49 E S 68 E S 22 E S 15 W 100. 499.95 100. 599.88 100. 699.81 100. 799.73 100. 899.53 -2 -4 -6 -7 -4 ,44 .52 .89 1000. 1100. 1200. 1300. 1400. 8 12 14 16 .1.8 0 0 15 45 S 34 S 41 S 40 S 40 S 41 100. 998.93 i00. 1097.42 100. '1194.80 100. 1291.22 100, '1386.53 19 40 65 93 .75 .57 .71 ,30 .49 .1.500. 1600. 1.700. 1800. 1900. 2000. 2100. 2200. ~'300. 2400. 2500. 2500. 2700. ~800. 2900. '> .1. 2 '$ :?.6 28 31 33 33 3;3 34 37 41 45 0 45 0 15 0 :[5 45 3O 30 45 0 0 15 0 0 ("~ ,:> 40 W S 42 W S 42 W S 43 W S 44 W S 44 W S 44 ld S 44 W ' S 44 W S 44 W S 44 W S 45 W S 48 W S 48 W S. 48 W 100, 1480.57 100. 1573.04 100. 1663.77 100. 1752,77 100. 1839.70 100. 1924.39 100. 2007.77 100. 2091.04 100. 2174.43 100. 2257.70 100. '2341,21 100. 2424.60 100. 2505,88 100. 2583,46 100. 2656.59 125,i4 160.70 200.25 243.25 290.15 340.7=' 393.26 445.95 498,47 551.16 603.50 656.17 712.32 773.57 839.77 JOB NO: SUE oE.A I'VD F' E E T -100.00 0.00 100.00 200.00 299.99 399.95 499.88 o97.81 699.73 799.53 098.93 997.42 1094.80 1191.22 1286.53 1380.57 1473. O 4 J. 563.77 1652.7'7 1739,70 1824,39 1907.77 1991.04 2074,43 2157.70 2241,21 2324.60 2405.88 ~4E'~ 46 2556.59 A581G0328 · COMF'UI'AT ION ' T I ME DATE 12:51:40 O7--HAY-81 PAGE NO.. ,1 RECTANGULAR CL 0 C 0 0 R D I N A T E S DISTANCE FEET FEET S U R E DOGLE DIRECTION SEVERI D M DG/IO0 0.00 ..... 0.0'0. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.52.S 0.39.E. 0.65 .~2 S 1,55 E 2.17 2.48 S 4.20 S 6,13 S 9,06 S 15,37 S 0 0 0.00 0 0 0.00 0 0 S 37 0 E 0.75 'S 45 24 E' 3.98 E 4.69 S 58 3 E "'1"~.07 7.27 E o."'" 39 S 60 1 E 1 10,,43 E . 12.10 S 59 33 E 0.74 13.36 E 16,15 S 55 51 E 1.9E. 13.75 E 20.63 ,~ 41 48 E ..o.84 25.28 S 39.06 S 56.3o ~ 76.64 S 99.66 S 9.23 E 26.91 S 20 4 E 4.02 1.34 W 39.08 S 1 58 W 4.17 16.08 W 58.58 S 1= =' 33.13 W 83.49 S 23 23 W 2.23 52,79 W 112.78 S 27 55 W 2,27 125.51 S 15,1.24 S 185.50 S 219.11 S. 25,1,97 S 74.87 W 1'16..1.,,, =S 30 49 W ~.,:.') '>E 99.84 W 183.74 S 32 55 W' '2.6'~: 127.99 ld ':; ''~ =' S · -,'..-,.3)7. 34 3;6 W '2.'''>'::,`.,-. 158,79 W..-':>70.,:,0 S 3.., 56 W SC 192.82 W 319.67 S 37 6 [.J -,,.,,¢7,c 293,22 S 332,93 S 372.76 S 412.46 S 452.30 S 491.87 S 531,24 S 571.33 S 613.55 S 659.19 S 968.10 W 4~7.46 q 38 51 W ' 0 .~( S06.57 W 482~63 S 59 26 W 0.2~: S44.91 W 537.67 ~.° 59 ~%,1 W 0.0C ~83.38 W 592.92 S 40 17 W 0,2[ · 421,59 W 647,~ 460.28 W 702.90 S 40 54 W 1.14 502.53 W 760.09 S 41 20 ld 0.65 549.4o~ W .... 823.60 S 41 o=1W 3.75 600.10 W 891.43 S 4°~ 19 W 4.00 ;I"~C.'.O ALASKA, INC. 'lNG SALMON f:'LI'FM, )OOK INLEI', AI.ASKA iEASLJRED DRIFT DR! DIFF'TH ANGLE: DIREC F E E T D M ri 3000, 49 0 S 48 3100, 52 15 S 49 3200. 53 0 S 47 3300. 52 30 S 47 3400, 52 45 S 48 3500, 53 0 S 48 3600, 53 45 S 48 3700. 54 45 S 47 3800, 55 0 S 48 3900, 55 0 S 48 4000, 55 15 S 48 4100, 56 15 S 47 4200, 56 0 S 48 .1300. 56 0 S 49 ,1400. ~' S .~6 ~0 48 4500. 56 0 S 50 4600, 56 SO S ';8 4700. 56 0 S ';8 .;800. 56 15 S 49 4900, 53 45 S 50 5000, 50 0 S 56 5100, 50 30 S 56 5200. 50 4=. .~ S 55 5300. 50 0 S "::' 5400, 47 30 S 58 5500, 47 15 S 59 5600. ,;6 45 S 60 5700. 46 0 S 60 5000. 44 45 S [55' 5900. 44 1=~ S 60 WE~L NO': K-S GHS/GHS TRUE FT COURSE VERTICAL TION LENGTFI DE:F'I'H FEET FEET W 100,.. 2724,79 W 100. 2788.23 W 100, 2848,94 W 100, 290'9,47 W 100, 2970.17 W 100, 3030,52 W 100. 3090,18 W 100, 3148,61 W 100, 3206,14 W 100. 3263.50 W 100. 3320.68 W 100. 3376,96 W 100. 3432.70 W 100. 3488.62 W 100. 3544,17 W 100. 3599.73 W EO0, 3655,29 W 100, 3710.85 W 100, 3766.58 W 100. 3823.94 W i00, 3885.68 W 100, 3949~62 IV 100, 4013,06 W 100. 4076,84 W 100, 4142,77 W · 100, 4210.49 W 100.. 4278,69 W 100. ,;347.69 W 100, 4417,5'3 W 100, 4489,26 VERTICAL SECTION FEET -910,75 985,95 1063.08 1140,00 1216.96 1294,36 1372.26 1450,86 1530,07 1609,58 1689.21 1769.27 1849.68 1930,32 2011.20 2092,24 2173. ,:.9 2253,99 2334,75 2414.75 2492.47 2568.94 26,;5.76 2722,22 2797.07 2870,52 2~ ¥43,59 3015,94 3087,05 ~157.07 JOB NC..) SUBSEA TVD' FEET · 2624.79 2688.23 2748.94 2809.47 ~o70,17 2930,52 2990,18 3048.61 3106.14 3163.~0 3220.68 3276.96 3332.70 3388.62 3444.17 3499.73 7o.5. 9 .,.',":'5. 2 36 :i.'0,85 3666.5""':',., 3723.94 3785,68 38,;9,62 3913.06 3976.84 4042,77 4110,49 4178.69 4247.69 4317.93- 4389.26 ,..,81G0328 COMF'UI'ATI ON " T I H E D A T E 12:51:40 07-HAY-81 PAGE NO .. 2 RECTANGULAR C 0 0 R D I N A T E S FEET C L 0 S U R E DOGLE DISTANCE I)IRECTION SEVER] F'"EET D M DG/iO( 708.13 S .... 654,45 W · 759.35 S 712,35 W 812,52 S 771,40 W 866.81 S 829.62 W 9'~0.50~ S 888.~1~. W 973,85 S 1027,55 S 1082,38 S 1137,64 S 1192,45 S 964,24 S 42 45 W 1041.18 8 43 10 W 1120.38 S 43 31 W 1199.84 S 43 45 W 1279.15 S 43 59 W' 947,46 W 1358,70 S 44 13 W 1007,10 W 1438.79 S 44 25 W 1066.94 W 1519.84 S 44 35 W 1127,24 W 1601,53 S 44 44 W 1188.12 W 1683.32 S 44 54 W 4.0( 3.33 0.5( 0.7~ · 0.8,.' 0.0( 1247.34 S 1303, 19 S 1359,-..8 S 1414,21 S 1469,31 S 1249.08 W 1310~03 W 1371,24 W 1433.33 W 1495.60 W 1765.24 S 45 2 W 1847,83 S 45 9 W 1930.79 S 45 15 W 2013.56 S 45 23 W 2096.59 S 45 30 W 1'.3( 0.87 0.8~ 0,9', 1523.86 S 1558.36 W 1578.40 S 1621,11 W 1634.04 S 1682.90 W 1689.06 S ..1745.08 ~ 1742.26 S 1807,37 W 2179,59 S 45 38 tO 2262.60 S 45 46 W 2345,68 S 45 51 W o4'~8.6q .S 45 56 W 9510.o9 tS 46 3 W 1.7, 0.5( .. 1789,60 S 1832,59 S 1876,37 S 1920,55 S 1962,05 S 1870.19 W 1933.93 tO 1997.64 W 2060.73 U 2123.43 W 2588,49 S 46 16'W 6,0; .::664.30 S 46 32. W ~ 0.5~ ,=~'740.68 S 46 48 W 0.8', 2816.94 S '47 I W 0.7: 2891.12 S ,;7 16 W 3.3' 2000,50 S 52037.62 S 2073,81 S 2109,93 S -2145,50 S 2186.17 2249.18 2311,87 2373,20 2433.59 W 2963,33- S 47 32 W W 3034,91 S 47 50 W W 3105.71 S 48 6 W · :;1 S 48 oo W W 3175, ...... W 3244.31 S 48 36 W 0.7~ O~ C'~ O. 7: 1,4- 0 , RCO ALASKA, INC. 'ING SALPION F'LTFM, 'C)OK INLET, ALASKA · WELL NO: K-3 . GPIS/GPIS iEASURED DRIFT I)EF'TH ANGLE FEET 1] Pi TRUE DRIFT COURSE VERTICAL VERTICAL DIRECTION LENGTH DEF'TH SECTION B FEET FEET FEET 6000°. 43 30 6100, 43 0 6200, 43 15 6300, 44 15 6400, 45 30 S 63 W 100, S 68 W 100, S 69 W 100, S 68 W 100, S 68 W 100, JOB NO; 6500, 44 0 6600, 45 0 6700, 45 30 6800, 45 0 6900, 46 0 7000, 46 0 7100, 47 30 7200, 47 30 7300. 46 45 7400, 46 30 S 70 W 100, S 70 W 100, S 72 W 100. S 71W .100. S 71W 100, S 70 W 100, S 70 W 100, S 71W 100, S 71W 100, S 71 ~ 100, SUBSEA TVD FEET 4561,34 3226,38 4461,34 4634,18 3294,77 4534,18 4707,17 3362,67 4607,17 4779.40 3431,37 4679,40 4850,27 3501.53 4750,27 3571,39 3640,79 3710,91 3780,94 3851,37 7500, 46 30 7600, 45 45 7700. 46 0 7800° 45 15 7900, 45 15 S 71 W 100. S 73 W 100. S 74 W 100. S 73 [4 J. 00. S 73 [4 J. O0. 4921,29 4992.61 5063,01 5133.41 5203,50 : 5272.97 5341,49 5409.05 5477,09 5545,77 3922,50 3994,61 4067,52 4139,88 4211,66 8000, 45 45 8100 ,. ,l 6 0 8200. 47 0 8300. 45 0 8400, ',..,45 S 75 W 100. S 75 W J. 00. S 75 W 100, S 76 W 100. S 76 W 100, 5614 .'60 5683.91 5753.53 582 ;3,47 5893.87 4283.29 4354.96 44 ') 4 . '::' ~.o 4'q94 . 60 4564,29'- 8500, 46 0 8600.. 45 30 8700, 46 0 8800, 44 45 8900, 45 0 S 76 W 100; S 76 W 100, S 78 W 100, S 77 W 100., S 77 W 100, 5963,96 6033.58 6102,42 6171,88 6242,13 4634,04 4703,96 4774,61 4844,53 4913,57 6311,75 6381,53 6451,51 6521.56 6592.42 A581G0328 COPIF'UT A'F I [)N TlttE DAI'E 12.'51 .'40 07-..MAY-81 PAGE .NO, 4983,19 5052.67 5121 · 83 5190,39 5°58,51 RECTANGULAR C 0 0 R D I. N.A T Ec'o FEET 2178,58 S...2494,50 2206.99 S 2556,85 93° 04 S ' 9690,45 2257,39._S ..... 2684,79 2283,82 S 2750,21 4821 4892 4963 5033 5103 5172 5241 5309 5377 5445 .29 .61 .01 ,41 ,50 ,97 .49 ,05 .09 .77 2309,05.S .... 2815 2333,02 S 2881 ~3o6.14 S 2948 2378,'68 S .3016 2401.90 S 3083 2425,91S 3151 2450.82 S 3219 2475,43 S 3289 2.499.29 S 3358 2522.96 S 3427 .93 ,80 .95 ,29 ,73 .54 .99 .48 .78 .50 CLOSURE I)ISI'ANCE DIRECTION FEET B M W 3311.90 S 48 52 W W 3377,61 S 49 12 W W 3442,20' S 49' 35 W W 3507,69 S 49 57 W W ~574.84 S 50 18 W' 5514 5583 5653 572 ;'3 5793 · 60 . 2546,57 S 3496 . 91 o .-568.8=''',., S 3564 ':' 2 ' ,2 3 .o3 ..589 3 S 363 .47 2609,5'1 S '5702 ,87 2630.30 S 3769 .09 .65 . 47 ,01 ,92 .W 3641,59 W 3707,79 W 3774,6J. W S841,37 W 3908,78 5863,96 ,,,,~o.58 6002,42 6071,88 6142,13 6211,75 6281,53 6351,31 6421,56 6492,42 2649,96 S 2668.54 S 2687,31S 2705,32 S 2722.54 S 2739,91S. 2757,24 S 2773,35 S 2788,75 S 2804,63 S 3838,,18 3907,82 3977,.89 4047,53 4116,59 4186,24 4255,74 4325.53 4395.02 4463,77 W 3977.09 W 4046.58 W 4116,85 W 4186,63 W 4255,95 4325,24 4393,82 4,16 :l.. 64 4 % ''> <'' 30 4596.82 4664-. 36 ,1732.04 4800,5'4 4868.39 4935.44 W 5003.17- W 00/0,86 W 5138.26 W 5205,13 W 5271,7.3 S 50' 39 W S 51 0 W S 51 23 W S 51 44 W S 52 5 W S 52 25 S 52 43 S ....32 S 53 2.'I. S 53 39 S 56 48 W S 57 4 W S 57 20 W S 57 S6 W S 57 52 W DOGL£ SEVER] DG/IO( 2.2: 3.4c 0.71 1,2: 1.2.~ 1.0( 1.5: 0.8; O. 7: 1 0.7, 0.7~ 0.2', 1 0.7~ '...4 o( 1.5' O. "~' 1.0~ 1' . . 0,5( 0 ~ .'=~ ~ .~%. ,. RCO ALASKA, ~NG SAI. MON OOK INLE]', INC. . F'LTFM, WELL ALASKA EASURED DRIFI' DEF'I't4 ANGLE F E E T D M DRIFT D I RECT I ON B 9000. 45 0 S 78 W 9].00. 44 30 S 78 W 9200. 42 30 S 72 W 9300. 42 0 S 68 W 9400. 41 0 S 69 W 9500. 42 0 S 68 W 9600, 44 30 S 68 W 9700, 41 30 S 64 W 9800, 43 0 S 62 W 9900, 46 0 S 62 W 10000, 47 30 1.0100, 48 0 10200, 47 30 :[0300, 47 SO 10400, 47 S0 :[0500. 46 0 10600. 46 30 :1.0700. 47 15 ].0800. 47 0 10900. 47 0 11000. 46 45 11100. 46 0 ].1200. 47 0 11300. 46 30 11400. 45 30 S 63 W S 63 W S 63 W S 63 W S 63 W S 61 W S 63 W ~,-,, S 64 W S 64 W S 64 W S 66 W S 65 W S 66 W S 66 W 11500, 45 0 S 68 W 11600, 44 0 S 66 W 11700. 43 .0 S 67 W 11800, 4'2 SO S 66 W 11900, 43 0 S 66 W NO1 K-S GMS/GHS TRUE COURSE VERTICAL VERTICAL LENGTH DEF'TH SECTION FEEl' FEET' FEET .JOB NO: A581GO328 COHF'UTAT I C)N .'- T I M E D A T E 1~. ,~ 5 J. :40 07.--MAY-81 SUBSEA R E C T A N G U L A R C L 0 TVI) C 0 0 R D I N A T E S DISTANCE FEET FEET FEET 10.0, 6663.13 5326,62 6563,13 100, 6734.15 5394,27 6634,15 100, 6806,69 5461,32 6706,69 100. 6880.71 5527.89 6780.71 100. 6955.60 5593.71 6855,60 '100. 7030.50 5659.54 6930.50 100. 7103.34 5727.67 7005,34 100. 7176.47 5795.70 7076.47 100. 7250.49 5862.92 7150.49 100. 7321.82 5933.01 7221.82 100. 7390.34 6005.85 7290.34 100. 7457.57 6079.85 7357°57 100. 7524.81 6153.86 7424.81 100. 7599.37_ 62"~7.58~. 7492.37 100, 7659.93 6301.29 7559,93 100. 7728.45 6374.15 7628,45 · 100, 7797.60 6446,37 7697,60 100. 7865,96 6':19,5?o .. 7765.96 1.00. 7934. O0 6592.56 7834. O0 100. 8002.20 6665.65 7902.20 100. 8070.56 100. 8139.55 100. .8208.39 100. 8276.91 100. 8346,37 6738,58 6810,87 6883,26 6955,96 7027.71 F'AGE NO., . 4 100. 8416.77 7098.45 100. 8488.10 7168.26 100. 8560.63 '7236.88 100, 8634,07 7304.54 t00. 8707.50 7372.25 U R E DOGLE DIRECTION SEVER] D M D G / 10 ( 2819.93 S .4532.80 W 5338.38 2834.57 S 4601.66 W 5404.64 2852.~8 S 4668.15 W 5470.63 2875.38 S .4731.~4 W 5536.55 2899,66 S 4792.99 W 5601.86 ,.~9,~3.95 S -. 4854,64 W 5667 1.9 2949.62 S 4918.17 W 5734,86 2977. ;36 S 4980.47 W ,.=;.qn'~,,~,.. ,.,~6 3007.88 S .... 5040.38 W 5869.65 ~040,79 S 5102,.~7 W 5939 66 S 58. 7 W S 58 22 W 0.5( S 58 S4 W 4.5~. S 58 43 W ,,.'~ 7' S 58 50 W 1.2( s 58 56 w '~2( S 59 '3 W 2,5( S 59 8 W 4.0,~ S 59 10 W 2.0' S 59 12 W ;3.0( 3074.42 S. 5166.87 W 6012.37 ;3108.02.S'" 5232.83 W 6086.24 3141.63 S 5298.78 W 6160.11 3175.10 S 5364.47 W 6~33.69 3208.57 S. .,430.17 W 6307'.~:7" S 59 15 W 1.6~ S 59 18 W 0.5~ S 59 20 W 0.5, S 59 23 W 0.0, S 59 '~:' .... ., W 0.0 3242.77 S 3276.68 S 3309.'~~: 3341.37 S 337;3,43 S 5494.48 W 6380,03 5558.26 W 645'),`..20 5623.58 W 6525.01 5689.44 6.1 65°c'; 57=~' ~ o~.18 W 6~7().o9 S 59 27' W 2.0 ~ 5° 0o ;,4 1.=- .,... · ,~. · .,..I S 59 32 W 1.0 S 59 37 W -~-~.0 7970,56 8039.55 8108,39 8176.91 8246,37 3.405.43 S 5820.78 W 67'13.77 3436.02 S 5886.38 W 6815.84 ~466.10 S 595~ ~.39 W .0'9 ' ~ C) C:, C) 3496,31 S 6018,67 g 6960,50 ~o.o7 S 6084.38 W 7032 02 S 59 ,!0 W 0.2 S 59 44. W , 1.6 S 59 47 W 1.2 S 59 51 W 0.8 S '--0 .,. .,..-, W 1.0 8316,77 3553. 8388.10 3580, 8460,63 3608, 8534,07 3635, 8607,50" 3662, 31 S 70 S 15 S 2"~ S a:.. .. 83 S 6149.'75.W 6214.27 W 6277.40 W 6339.65 W 6401.66 W 7102.50-' S ,..':9 59 W 1.5 717~..07 S 60 3 W 1.7 7,-~ ~ z40.,18 S 60 / W 1..-"" 7307.94 S 60 10 W 0.8 7375.,17 S 60 13 W 0.5 ~RCO ALASKA, INC. ' ~ING SALMON PI.I'FM, WELL N6: ~OOK INLET, ALASKA GMS/GMS iEA~,URED PRIFT DRIFT DEF'TH ANGLE OIRECTION FEET D M D TRLJE COURSE VERTICAL LENGTH DEF'TFI FEEl' FEET 12000. 42 0 S 65 W 12100. 41 0 S 65 W 1"o00. 42 0 S 64 W 123:00, 42 0 S 65 W 12400, 42 0 S 64 W 100.. 8781.23: 100. 8856..12 100. 893:1.02 100.. 9005.~3: 100. 9079.65 12500. 42 0 S 66 W 100. 12600. 42 3:0 S 65 W 100. 12700. 42 30 S 65 W 100. 12800.. 42 · 0 S 63:.W ....... 100. ..... 12900. 42 0 S 63 W 100. VERTICAL SECI'I ON FEEl' 13000. 41 0 S 63: W 100. ;L3100. 41 0 S 63 W ' 100. :1.3"'"00,... . 40 3:0 S 64 W 100. .'1.3300. 40 0 S 65 W 100. 7439.68 7505.84 7572.04 7638.88 7705.75 9153.96 7772.54 9227.98 7839.65 9301.71 7907.11 9375.73. 7974.30 9450.0'5 8041.20 9524.94 8107.45 .9600.41 '8173:.05 '9676.17 8238.30 ~.,~..49 830'~, 8,., JOB NO: SUBSEA TVD FEET A581G03:28 COMF'UTATION TIME DATE 12:51:40 07-MAY-81 PAGE NO~ R E C T A N G U L A R C C 0 0 R.D I..N.A 1' E S DIST FEET F'E L 0 S U R E ANCE DIRECTION ET D M I"iOGL.[ SEVER; DG/1 O( 8681.23: 3690.84. S .......6463.14 W 744 8756.12 3718.85 S 6523.19 W 750 8831.02 3:747.37 S 6583.00 W 757 8905.33: 3776..18_.S ......6643.3:9.W 764 8979.65 3:804.99 S 6703:.79 W 770 ~83:~,26...S .... ~6764.43: W 777 9127.98 3861.15 S 6825.61W 784 9201.71 3889.70 S 6886.84 W 790 9275.73 .3:919.17...S ..... 6947.28 W 797 9350.05 3:949.55 S 7006.90 W 804 2.75 S 60 16 W 8.78 S 60 19 W 4,87 S 60 21W 1,61 S 60 23 W 8.35 S 60 25 W 5.05 2.03 9.39 6.50 3.35 S 60 28 W S 60 30 W S 60 33 W S 60 34 I,d S 60 35 W t,0,, 1.2( 0.6' 0.6~ 0.8. 0.0, 1.4: 9424.94' :3:979.63: S .... 7065.94 W 810 9500.41 4009.42'S .... 7124.39 W 817 9576.17 4038.54 'S. 7182.81W 824 9652,49 4066.36 S .7241.13 W 830 9.56 5,11 0.30 4,77 S 60 37 S 60 38 S 60 39 S 60 41 W W W 0.0, 0.8 FINAL CLOSURE -- DIRECTION: DISTANCE: .S 60 [lEGS 40 HINS 59 SECS W 8304,77 F'EE:I' ARCO ALASKA, ;liNC, KING SALMON F'LTFi'I, WIZLI. NO; K-;3 GMS/GMS JOB NO; A581GOS28 COOK INI.ET, ALASKA GMS, 0:-2200 MD, SURVEYOR; A HICKMAN, DATE RUN,~ ..-~-FEB-'81 GMS, 2200-1S:300 HI.;, SURVEYOR; HICKHAN/BREEN, DATE RUN; ~-MAY-81 ......... LEG 4, SLOT S2, WELL NO,' I~:-~RD SIGHTING TO BAKER PLATF'ORH: S 59 E VERTICAL SECTION CALCULATE[; IN PLANE OF PROPOSAL OIRECTION~' S 61 OEGo 55 HIN, W RECORD OF SURVEY TANGENTIAL METHOD RCO 7. NG OOK ALASKA, SAI, MON INI, E]', INC. ' . F'L..I'FH, WELL NO; K-3 GMS/GMS ALASKA 1.'.-. A S URE.'D DRIFT DEF'TH ANGLE F'E E T D M TRUE [;RIFT COURSE VERTICAL DIRECTION LENGTH DEF'TH D FEET FEE]' 100. 200. 300. 400. 0 0 0 45 0 0 ........ O, .... 0.00 0 100. 100.00 0 100. 200.O0 S 37 E 100. 299.99 S 61 E 100.. 399°98 500, 600. 700. 800. 900. 1000. 1100, 1200. 1300, 1400. 2 2 2 2 4 8 12 14 16 18 0 15 0 45 SO 0 0 15 45 S 76 E 100, 499,92 S 49 E 100, 599.84 S 68 E 100. 699.78 S 22 E 100. 799.66 S 15 W 100. 899.35 S 34 W 100. 998.38 S 41 W 100. 1096.20 S 40 W 100. ~1193,12 S .'10W 100. 1289.00 S 41 W 100. 1383.69 :1.500. 1600, 1700, 1800. 1900. 21 0 4'..:..; 0 1[.. 0 S 40 W 100. 1477.05 S 42 W 100. 1568.58 S 42 W 100. 1658.46 S 43 W 100. 1746.55 S 44 W 100. 1832.27 ~~000. 2100. _~00. 2300; ~o400. 2500. 2600. 2700. 2800. 2900. S3 ~7 41 45 15 0 0 15 0 . 0 S 44 W 100. 1915.90 S 44' W 100. 1999,04 S 44 W 100. 2082.43 S 44 W 100. 2165.82 S 44 W 100. 2248.97 S 44 U 100. 2332,83 S 45 W 100. 2415.74 '3 48 W 100. 2495.34 S 48 W 100. 2570.81 S 48 W 100.' 2641,52 VERTICAL SECTION FEET 0.00 0.00 0.00 -0.20 -1.15 -3,74 -5.14 -7,38 -6,87 -1.51 10.78 30.20 56o04 79.39 109.41 142,66 ," ,..~ ,..) 1 d O, ":'-' 221 . 74 266...,""' "'~ 315,52 S67.69 420.56 473.07 525.59 578.45 630.28 683.78 742.55 806.~1~ 874,84 JOB NO: SUBSEA T V I) F E E T -100.00 0.00 100.00 199.99 299.98 A581GO328 COMF'UTAI*I ON " T I ME DATE 12;46:54 07-.MA'¢-81 R E C T A N G U L A C 0 O R D I N A T E FEET F A[.,E NO.. Ir,: C L 0 S U R E. 8 DISTANCE DIRECI'ION F E E T l"l M 0.00 .............. 0.00 . 0.00 0,00 0.00 '0.00 ..... 1.05..S ................... 0..79 E . 1.89 S 2.31 E 399.92 2,74 S ..... 5.70 E 499.84 5.31 S 8.66 E 599.78 6.62 S 11.90 E 699.66 11.07 S ...... 13.70 E 799.35 18.65 S 11.67 E 898.68 996.20 1093.12 1189.00 128Z.69 ,.1 1677.05 ~1468.58 1£~, ~:. ~.~ 1646,55 1732,27 1815.90 1899.04 1982.43 zq 0~.82 .~148.97 30.18 S 3.88 E. 45.88 S" ' 9,76 W 64.73'S- 25,58 W 86.49 S' 4J.84 W 110.75 S 64.92 W 138.20 S 168.13 S 200.71S 235,32 S 2-~ .7~.37 S 311.81S 351.78 S 391.48 S 431.18 S 471.15 S 87.96 W 114,91 W 144,24 W 176.52 W 212.30 W ~ , 2~- ~0.39 W 288.98 W 327.32 W 365,66 W. 40.,-t . n=" 510.33 S 549,87 S 590,37 S 634,27 S 681,58 S 442.09 48!.63 526,61 575.57 627.91 2232.83 2315.74 2395.34 2470.81 -2541.52 0.00. 0 0 0.00 0 0 0.00 0 0 1.31 S 37 0 2.99 S 50 44 E 6.=° S 64 oo E 10,16 S 58 29 E 13.62 S 60 55 E 17.61 S 51 ,1 E 21.99 S S2 2 E 30.43 q 7 20 E 46.90 S 12 0 W 69.60 S 21 34 W 96.96 S 26 53 W 128,38 S SO 26 W ~ 6 S. '"' S ':.; ':> .,. 203.65 S 24'7.16 S S5 42 W ~ 94 17 S 345.34 S S7 56 W 399.90 S 38 46 W 455 "~ .,,.,_. S 39 04 i,d 510.29 6 39 5q W 565.36 tS 40 18 W 620,81 W 675.19- S 40 54 W W 730.97 S 41 13 W W 791.11 S 41 44 W W 856 · 3'"' ' .., S 42 W oo~; 73 S 4':' 39 W DOGLE SEVER DG/IOC 0.0¢ O.OC 0.0¢ 0.73 0.4z .~,0 } 1.0~ 0,7,. 1,9~ 4.0.5 4,15 2.24 2.2~ 2.2~. 2. it! ~ 2. S(. ~ -"~." 7 ':, 0.5( O. 0.0( 0,7[ 1.i' .'~ -5' r 4 . O( '-IRCO ALASK°A, INC. '~ING SALHON PLTFM, WELL NO: "OOE INLET, AL. ASEA GMS/GMS A S U R E P T I--i FEEl' TRUE EB DRIFT DRIFT COURSE VERTICAL VERTICAL ANGLE DIRECTION LENGTH DEPTH SECTION D M I) FEET FEEl' FEET 3000 3100 3200 3300 3400 . 49 0 S48 W 100· . 52 15 S 49 W 100. · 53 0 S 47 W 100· . 52 30 S 47 W 100· . 52 ,;5 S 48 W 100. 2707·13 948·10 2768.35 1025·17 2828·53 1102,54 2889.41 1179·00 2949,94 1256.27 3500 3600 3700 3800 3900 · 53 0 S 48 W 100. . 53 45 S 48. W 100. . 54 45 S 47 W 100· , 55 0 S 48 W 100. · 55 0 S 48 W 100· 3010,12 3069,25 3126.96 3184.32 3241,68 JOB NO: A581G0328 4000 4100 4200 4300 4400 · 55 15 S 48 W 100. . 56 15 S 47 W 100· .. 56 0 S 48 W 100, . 56 0 S 49 W 100. . 56 30 S 48 W 100. 3298.6'8 3354.23 3410.15 3466,07 3521.27 COMF'UTATION ' TIME DATE 12:46:34' 07-MAY-81 4500 4600 4700 4800 4900 5000 51.00 5200 5300 5400 5500 5600 5700 5800 5900 . 56 0 S 50 W 100. . 56 30 S 48 W 100. . 56 0 S 48 W 100. . 56 15 S 49 W 100. . 53 45 S 50 W 100. . 50 0 S 56 W 100. ":0 30 S 56 W 100, . 50 45 S 55 W 100. . 50 0 S 55 W 100. , ,17 30 S 58 W 100. ' . 47 15 S 59 W 100. . 46 ,15 S 60 W 100. , 46 0 S 60 W 100, · '44 45 S 59 W 100. . 44 15 S 60 W 100. 3572.19 3632.38 3688.30 3743.86 3802.99 3867.26 3930.87 3994.14 4058·42 4125,98 4193.86 4262.38 4331.84 4402,86 4474,49 SUBSEA R E C T A N G U L A R C TVD C 0 0 R B I N A l' [: S DISTA FEET FEET FEE 2607,13 732,08 S .... 684.00 W 1001 2668,35 783.96 S 743,67 W 1080 ~°7o8.53_ 838,42 S 802.08 W 1160 2789.41 892,53 S ..... 860,10 -W 1239 2849.94 945.79 S . 919.26 W 1318 1333,79 2910,12 999,23 S.. 978,61 o~ 25 1055.19 S 1038,54 1412.06 ,.~69. 1490.98 3026.96 1108.89 S 1098.27 1570.49 3084.32 1163.70 S 1159.14 1650.00 3141,68 1218.51 S 1220.01 i729,75 1810.09 1890.56 1971.57 2052,51 2133.43 2214.37 2294,84 2375.88 2454,79 PAGE NO. .~a0.99 2607.74 2684,61 2760.66 2834.2:2 L 0 S U R E DOGL. NCE DIRECTION SEVER T D M BG/iO 2907,'55 ~o~·35 3052,24 ~ · 55 ~122, 3192.29 W 1398 W 1479 W 1560 W 1642 W 1724 .90 S 43 3 W 4.0 ,57 S 43 29 W 3.3 · 30 S 43 44 W 1,7 · 51 S 43 56 W 0.5 .92 S 44 11 W 0.8 .62 S 44 24 W ""~.2 · 12 S 44 36 W 0.7 · 71 S 44 43 W 1~2 .50 S 44 53 W 0,8 .30 S 45~.~ W 0.0 3198,68 1273,49 S 1281,08 W 1806 3254.23 1330.20 S 1341.89 W 1889 3310.15 1385·67 S 1403.49 W 1972 3366.07 1440.06 S 1466.06 W 2655 3421.27 1495.86 S 1528,03 W 2138 .36 S 45 10 W 0.2 · 47 S 45 15 W 1.3 .28 S 45 22 W 0.8 · 02 S 45 31 W .34 S 45 37 W 0.9 3477,19 . 1549.15 S 1591,54 W 3532,38 1604.95 S 1653,51 W 3588.30 1660.42 S 1715,12 W 3643.86 1714.97 S --1777,87 W 3702·99 1766.81' S 1839o65 W 2221 2304 2387 2470 ~v .00 .18 .21 .67 S 45 4,5 tO 1.7 S 45 51 W :1.,7' S 45 56 W O.= o 46 "" :"" S 46 9 W 3767,26 3830.87 3894,14 3958.42 4025,98 180'9.64 S 1903,16 W 1852.79 S 1967,13 W 1897.21S 2030.56 W 1941.15 S 2095.51W 1980·22 S 2155.84 W 2626.18 S 46. 27 W 6.6 2702.30 S 46 43 ~ ~ 7/8.95 S 46.57 --'854.82 S 47 I0 W O. 2927,27 S 47 " 4093.86 4162.38 4231.84 4302.86 4374,49 2018·04 S. 2218,78 W 2999 2054,46 S 2281.86 W 3070 2090.42 S 2344,16 W 3140 2126,68 S 2404,50 W 3210 2161.57 S 2464.93 W 3278 .24 .45 .85 .,05 .46 S 47 43 W 0.7 S 48 0 W O, S 48 16 W S 48 31 W S 48 45 W ,RCO ALASKA, 'lNG SALMON ;OOK INLET, INC. - F'LI'FM, WELL NO: K-3 GMS/GHS ALASKA IEASL;RED DRIFT DEPTH ANGLE F E E T D M DRIFT COURSE DIRECTION LENGTH D FEET TRUE VERTICAL VERTICAL DEF'TH SECTION FEET FEET 6000. 43 30 6100. 43 0 6200. 43 15 6300. 44 15 6400. 45 30 S 63 W ..100. 4547.03 S 6'8 W 100.. 4620.17 S 69 W 100. 4693.00 S 68 W 100. 4764,63 S 68 W 100, 4834,72 3261.12 3328.93 3396.93 3466.31 3537.24 6500, 44 0 6600, 45 0 6700, 45 30 6800, 45 0 6900, 46 0 S 70 W 100. 4906,66 S 70 W 100. 4977.37 S 72 W 100. 5047.46 S 71 W 100. 5118.17. S 71 W 100. 5187.64 3606,01 3676,02 3746,24 3816,07 3887,10 7000, 46 0 7100. 47 30 7200, 47 30 7300, 46 45 7400. 46 30 $ 70 W 100. ~257.10 3958.32 S 70 W 100. 5324.66 4031.31 S 71 W 100. 5392.22 4104.12 S 71 W 100. 5460,74 4176·04 S 71 W 100 · .... ~9,57 4247.67 7500. 46 30 7600. 45 45 7700. 46 0 7800. 45 15 7900. 45 15 S 71 W S 73 W S 74 W S 73 W S 73 W 100. 5598.41 4319.30 100· 5668.].9 4389,59 I00. 5737.65 . 4459.93 100. 5808.06. 4529.63 100. 5878.46 4599.32 8000. 45 45 8100. 46 0 8200. 47 0 %-, E.,oO0. 45 0 8400. 45 45 S 75 W S 75 W S 75 W S 76 W S 76 W 100. 5948,24 4669.09 100. 6017.70 4739.16 100. 6085.90 4810.39 100, 6156.61... 4878,~8 100. 6226.39 4948.46 8500, 46 0 S 76 W 8600, 45 30 S 76 W 8700. 46 0 S 78 W o 44 45 S 77 W o800, 8900. 45 0 S 77 W 100. 6295.86 5018.23 100, 6365,95 5087.41 100. 6435.41 5156.53 100, 6506.43 5224.50 100. 6577.14 5292.78 JOB NO: A581G0328 COMF'UI'AI' I ON T I HE [;ATE · ':[2:46:34 07-'HAY-81 F'AGE NO, ~ SUBSEA R E C T A N G U L A T VD C O 0 R D I. N..A.T. E FEET FEET R C L 0 S U R E DOGL[ S DISTANCE DIRECTION SEVER' FEET D M DG/1 O( 4447.03 2192.82 S ..... 2526.27 4520.17 2218.37 S 2589.50 4593.00 .2242.93 S 2653.47 4664.63 ...2269.07..S .......2~18.16 4734.72 2295.78 S 2784.30 4806,66 4877,37 4947,46 5018,17 5087.64 2319.54 S ..2849.57 2343.73 S 2916.02 2365.77 S 2983.85 2388.79 S .... 3050.71 2412.21 S 3118.73 W 3345.22 W 3409.79 W 3474.42 W 3540.7,7 W 3608.73 3674.28 3741.15 3807.92 3874.68 3942,74 5157.10 2436.81 S 3186.32 W 5224.66 2462,03 S -3255.60 W 5292.22 2486.03 S.. 3325,31 W 5360.74 2509.74 S 3394.18 W 5429'57 2533,36 S 3462.77 W 4011.32 4081.73 4151,88 4221,'29 4290.53 S 49 3 W ..°.')'~.. S 49 25 W 3.4, S 49 48 W 0.7: S 50 9 W 1.'"'.., S 50 30 W' 1.2~ S 50 51W S 51 13 W 1.0 S 51 S5 W 1,5 S 51 56 W 0.8 S 52 17 W 1.0 S 52 36 W 0.7 S 52 54 W 1.5 S 53 13 W 0.7 S ~ ~3 31 W 0.7 S 53 49 W 0.2 5498.41' 5568,19 5637,65 5708.06 5778,46 2556,98 S 3531.35 2577.92 S 3599.85 2597.75 S 3669.00 2618,51 S,..3736,92 2639.27 S 3804,83 4359.88 4427.71 4495.54 4563.02 4650.61 S 54 6 W 0.0 S 54 24 W 1.6 S 54 42 W 0.7 S ~4 59 W 0 S 55 15 W 5848.24 5917.70 5985.90 6056.61. 6126.39 2657.81 S 3874,02 W 26'76.4~ S 3943.o0 W 2695.36 S 4014.15 W 2712.47 S 4082.76 W 2729.80 S 4152.26 W 4698.09 4/6,,.~8 4835.12 4901.67 4969.21 S 55 33 W 1.5 S · ....,.., 50 W ' O. S 56 7 .W 1.0 S 56 24 W '2.1 S 56 41 W 0.7 6195.86 2747.20 S 4222.'06 W 5037.15 6265.95 2764.45 S 4291.27 W 5104,62 6335.41 2779.41 S 4361 63 W = · ,,171.93 6406.43 ~795 25 oo W 5238.35 ~ . S 4430._- 6477,14 2811,15 S '4499.12 W 5305,16 S 56 57 W O.'',: S~,=7 13 W O.='.., S 57 30 W 1·5 S 57 45 W I, 4 S 58 O W 0,"'..- RCO I NG OOK ALASKA, SALMON INLET, INC. F'L. TFM, ALASKA JOB NO: A581G0328 COHPUI'ATION .- TIME DATE 12146:54' 07-MAY-81 PAGE IEASURED DRIFI' [m E F:' T H A N G L.. E F E E l' D M 9000, 45 0 9100, 44 30 9200. 42 30 9300..42 0 9400. 41 0 9500. 42 0 9600. 44 30 9700. 41 30 9800. 43 0 9900. 46 0 TRUE [;RIFT COURSE VERTICAL. DIRECI'ION LENGTH DE:F'I'H D FEET FEEl' S 78 S 78 S 72 S 68 S 69 S 68 S 68 S 64 S 62 S 62 W 100. 6647.85 W 100. 6719.18 W 100. 6792.90 W 100. 6867.22 W 100. 6942.69 W 100. 7017.00 W 100. 7088.33 W 100. 7163.23 W 100. 7236.36 W 100. 7305.83 VERTICAL o E. C T .[ 0 N FE:ET 5360.72 5428.07 5494.58 5561.12 5626.23 5692.76 5762.46 5828.68 5896.88 5968.81 SUBSEA TVD FEET 6547,85 6619.18 6.692.90 6767.22 6842.69 6917.00 6988.33 7063.23 7136.36 7205.83 R E C T A N G U L C 0 0 R D I N A l' FEET 2825.85 S -- 4568.29 W 2840.43 S 4636.85 W 2861.30 S 4701.10 W ..2886.37..S 4763.14 W 2909.88 S 4824,39 W 2934. 95 S .. 2961 · 20 S 2990.,,.~ S ~o 27 S-:- 3056.04 S A R E S 4886.43 W 4951.42 W 5010.97 W 5071.19 W 5134.70 W C L 0 S U R E' DOGLE I) I..:~TANCE I)IRECI'ION ~' oEVEIr( ] FEET D H . DG/iO( ~371 66 S 58 16 W 0 7J 5437.68 S 58 31 W 0.5( 5503.40 S 58 40 ld 4.55 5569.44 .S 58 47 W 2.7~ 5634.02 S 58 54 W' 1.2( 5700.10 S 59 I W ~.2( · 5769.34 S 59 7 W 2.5( 5835.36 S 59 10 W 4.0~ 5903,48 S 59 12 W '2.0: 5975.33 S 59 14 W 3.0( 10000 10100 10200 10300 10400 47 48 47 47 47 30 0 30 30 30 S 63 'S 63 S 63 S 63 S 63 W 100. .7373.39. W 100. 7440.30 bi 100. 7507.86 W, 100. 7575.42 W 100. 7642.98 6042.53 6116.83 6190.54 6264.26 6337.97 7273.39 7340.30 7407.86 7475.42 7542.98 3089.51.S · 3123.25'S 3156.72 S 3190.19 S 3223.67 S 5200.40 5266.61 5397,99 · 5463.69 6048.90 6123,06 6196.64 6~70.oo · .. ~.~ 6343.81 .S ~9 17 W S 59 20 W S 59 22 W S 59 25 W S 59 28 W I .6; 0.5( 0.5( 0.0~, 0.0~ :[0500 10600 10700 10800 10900 46 46 47 47 47 0 30 15 0 0 S 61 S 63 S 64 S 64 S 64 W 100. 7712 W 100. 7781 W 100. 7849 W 100. 7917 W 100. 7985 .44 6409.90 .,~8 6482.42 .36 66'28.89 .56' 6701.98 7612.44. 3258.54 7681.28 3291.47 7749.16 3323.66' S 7817.36 3355.72 7885,56 3387.78 5526.60 5591.23 5657.23 5722.97 5788.70 6415.71 S 59 29 W · ~,P 31W 64° . o8.12 S 6561.3~ S 59 34 W 663,1,75 S o9 37 W 6707,17 S 59 40 W 1.0' 11000 11100 11200 11300 11400 46 46 47 46 45 45 0 0 30 30 S 64 S 66 S 65 S 66 S 66 W 100. 8054..07 W 100. 8123.54 W 100. 8191.74 W 100, 8260.58 W 100. 8330.67 677,1.77 7954.07 6846.52 8023.54 6919.55 8091.74 6991.90 8160.58 7063.04 8230.67 3419.71S 3448.97 S 3479.88 S, 3509.38 S .... 3538.39 S o85,1.16 W 5919.88 W 5986,16 W 6052.43 W 6117.59 W 6779,80 6851,30 6924,14 6996.26 7067,19 S 59 43 W S 59 46 W S 59 50 .W S 59 54 W S 59 57 W 0,8~ 1 11500 11600 11700 11800 11900 45 44 43 42 43 0 0 0 30 0 S 68 S '66 S 67 S 66 S 66 100. 8401 100. 8473 100. 8546 100. 8620 100. 8693 .38. 7133.36 .31 7202. ,~d~ .45. 7270.58 · 17 7337.97 .31 7405.99 8301.38 8373,31 8446.45 8520.i7 8593.31 3564.88 'S 3619.78 S 3647.26 S 3675. O0 S 6183.15 W 6246.61W 6309.39 W 6371.11W 6433,41W 7137,21- S 60 2 W 1,5. 7~n~ SO S 60 6 W 1,7: 7274.01 S 60 9 W ' 1.21 7341.9o S 60 13 W 0 o 7409.08 S 60 16 W 0.5~ ,;:(CO ALASKA, INC. ~ING SALMON F'LTFM, )OOK INLET, AL. ASKA WELL NO: K--3 GMS/GMS tEASURED ORIFT DEF'TH ANGLE FEET D M TRUE DRIFT COURSE VERTICAL VERTICAL DIRECTION LENGTH DEF'TH SECTION D FEET FEE7' FEET JOB NO: SUBSEA TVD FEET A581G0328 CO~F'UTATI ON " TIME DATE 12:46:54' 07-MAY-81 PAGE R E C T A N G U L A R C 00'R D I. N A T E S [;IS FEET F C l.. '0 S U R E DOGLt TANCE DIRECTION SEVERi EET D M DG/IO~ 12000, 42 0 S 65 W .100, 8767,63' 12100, 41 0 S 65 W 100, 8843.10 12200, 42 0 S 64 W 100. 8917,41 12~00o 42 0 S 65 W 100, 87~1,72 12400, 42 0 S 64 W 100, 90~,04 7472,81 86&7,~ .3703,28...S ..... 6494,05 W 7538,32 8743,10 37~1,01 S &553,51 W 7605.19 8817,41 3760.~4 S 661~,65 W 7672,00 .8891,72. ~788,62__S ...... 6674,30 W 7738,87 8966,04 3817,95 S 6734.44 W 7475,7~ S 60 i8 W 1,2 7541,15 S 60 21 W 7607,93 S 60 23 W 1.2~ 7674.63 S 60 25 W 0,6' 7741,41 S ~0 27 W' 12500, 42 0 S 66 W 100, 12600'. 42 30 S 65 W 100, 12700, 42 30 S 65 W 100, 12800, 42 0 S 63 W ..100. 12900, 42 0 S 63 W 100, 13000, 41 0 S 63 W 100, 13100. 41 0 S 63 W 100, 13200. 40 30 S 64 W 100. 13300, 40 0 S 65 W 100. 9140,35 7805,62 9040.35 9214,08 7873,08 9114,08 928.7,81 7940,54 9187,81 9362,12_ 8007,44.. 9262,12 9436.44 8074.34 9536.44 ,.. 9587.38' 9663,42 9740,02 3845,17.S.. 6795,57 W 7808,01 3873,72 S 6856,80 W 7875.36 3902,27 S 6918,03 W. 7942,72 3932,65..S 6977,65 W 8009,57 3963,03 S 7037,27 W 8076,43 :3992,81S 8205,53 . 9487,38' 4022,60'S' 8270,43 9563,42 ..4051.07 S 8334.62 9640,02 4078,23 S S 60 30 W S 60 32 W 0,~) S 60 ~4 W 0.0 S 60 36 W 1,4 S 60 37 W 0.0 7095,72 W 8141,98 S 60 38 W 1,0 7154,18 W 8207,53 S 60 39 W 0,0 7212.55 W 8272,56 S 60 41 7270,81 W 83~6..16 S 60 43 W 0.8 FINAL CLOSURE - DIRECTION: DISTANCE: S 60 DEGS 42 MINS 42 SECS W 8336.46 FEET · ARCO ALAS~A, INC. KING SAI_MON F'L. TFM, WELL NO; K-~ GMS/GMS JOB NO: A581G0328 COOK INI. ET, ALA~'A GMS, 0-2200 MD, SURVEYOR; A HICK'MAN, D'ATE.RUN; 25-FEB-81 GMS, 2200-13300 MD, SURVEYORS HIC~<MAN/BREEN, DATE RUN; 3-MAY-81 LEG 4, SLOT 32, WELL NO; K-3RD SIGHTING TO BAKER PLATFORM; S 59 E RECORD Of: INTERPOLAI'ED SURVEY ' ~RCO ALASKA, IMCo - {ING SALMON F'LTFM, WELL NO1K-~ GMS/GMS 'OOK INLET, ALASEA MAREER-- ..... CODE .......... NAME JOB NO: A581G0328 COMPUTATION PAGE NO; ~ ' TIME DATE ' 13:01:13 07-MAY-B1 TRUE SUBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL DEPTH DEF'TH F_;IFF' DEF'TH C 0 0 R D.I N A T E S DI~TANCE DIRECTION THICKNES'. FEET FEET FEET' FFET FEET FEEl' D N 7 INCH LINER TOP 9 5/8 CASING TOP OF HEMLOCK BOTTOM OF HEMLOCK 10660.00 7838.61 2821.4 7738.61 ~296.22 S 5597.45 W 10983.00 8058.94 2924.1 7958.94 ~399.99 S 5809,62 W 12530.00 9176.17 3353.8 9076.17 ~841.63 S 6782.79 W 13200.00 9676.17 3523,8 9576.17 4038.54 S 7182.81 W 6495.88 S 59 30 W 6731.~9 S 59 40 W 7795.15 S 60 28 W 8240.30 S 60 ~9 W · "KING SRLMON PLTFM;'~NELL. NO: K:3 IE;MS/I~MS ' ": ..... ' .... ' .... :!li -',..'-!-SCRLE iE',:':: =:'-':iO00.'FEETi '.-. . ', .'.-!'.':'. i'-.'}-.'i''':.!-. -':' :' ': i .: :.: ....... i ..... . ..... ~ ..... ; .. , ~ ...... ; ...... . . .| · - ' COOK ~INLET., - RLRSKR ' ' ~ : ....... DEPTH ',INDICRTDR:.'. T. VD..i..:.~,.: ;:t" ..~...: ...... ~. ..... :... .............................. ' ~ ........ : ' ' i ............ : .......~' ' '' ' ; .............. ' ....... ~ ....~" ' ' ~ . ~ ', : ...... t ' , . , { ! 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'"".J."-- ;' .'.-8~00;'- u ' .... .:~--,..-:..~..~:.,~.=-~-~-.~ ........... ,~,'--~.',.-~-..~-~-l-~,.,:,~-.~.~.~.:-~--.:-I.. ,.,~ .......... . ',. ....... . - ........ ~.~-~-....,~-:...~-,.,-~.~.~,~.,~.~-:..,..~.,~- ........ , .... ~'r'-': .... , ....... ~"~-~-~'~*-~'='~'?'~-'-, ...... ~ .... ~ ~ 000. ...................... !-.. ...................... ~ ........... ~ ..... ........ j" :'~--~'i-~*"~':'-k~","~-~-[-'~'-~"~'~'"]': ..... ~ : '. ~ -' , ~'~ '- .... ~': ...... : "~-": .... :' i.-~-~-~ .... ',.'~. .. ~ ................... , ......... ?. ~ ........ ~ ..... ~. %-,..., -~..~ -: ,.. ~.... . . . ~ .... ] · ~ ............. . .......... ~ .~ _~. ..... ~._~..~ . : .~..~ ~ . ..: ..... .......,.... -, ..... ............. ........... , ..................... , ....... .... .......... '-' ...... ":~-~"~"~l'" :" ~ , '~000 ..... ~:..:--.,-:-t ~--~-,-.- .... ' .... '-I ........................ ,' '''~ .L~;i;.~- L ~. L..~..;.' ; .... " $CRLE !1. IN.'-= 2000 FEET'i---:.-- ........ '~ .......... : ........~ ................. . ,... , . .: .... '! - . ~... ,, · . . . *..... ; .. . , .... :..~..-! , ..... :, .....: :.; ..... ; .... · ~-.i..,-! ' . ..... . ...... ~ ...... .-"':: ..... : .... i'-:7:-~.-'~::-': . . : · ~ .......... ; ......... '_ _'~.~ . ........ : ................. ; ....'....: !: .... ~.; ..... · . ,~ .... ; ; .. ' ....'.. ........ ~, ~ .... · ' '7' ~ ~'r'~~' .... ~ ; ...... ; ...... ~ -.- ;--.~..;. -' - t ........ "' ........ ~ ", ...... ~'!- :' ..... ~ - .:. ** ; ..... *. ....... '..~ _. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Operator, Well Name and Number Reports and Materials to be received by: ,,~ i Date Required Date Received Remarks __ Ccmpletion Report Yes Wel 1 Hist°ry ~/"~~-i~~~_.- ~ Yes Mud Log Core Chips Registered Su~ey P i~[ ~%'~U';n "Inclinati'6n Su~.y ..... ~--~~ Dire~ional ~ey Drill St~ Test Re. ms ~d ~. - . Pr~u~ion T~t Re~s ye~ ~s R~ Yes Digitiz~ ~ta Document Transmittal t CO~M,/,~~ Union Oil Company of Ca!lifor~iCoM~ TO Alaska Oil and Gas Conservation Commission TRANSMITTING THE FOLLOWING: DATE SUBMITTED 6- 30-8] ,~,- 2 ENG FROM . __ ', 4 ENG Pouch 6247 Anchora TELEPHONE NO. ,~T ,,.. TBU K-3 redri 11: =: · sepia and blueline of the foll c cement bond log VI)L formation dens 5" borehole comp. sonic 1 .cyber 1 ook 1 og 5" comp. neutron form. den: i ty comp. neutron form. den! i ty -.:'"' 2" TVD /A;/2'' dual induction SFL tion SFL formation dens' ty log girectional Survey gnetic tapes -t- - PLEASE SiGN AND RETURN ONE COPY /./¢ RECEIVED: DATE' T- ¢ ...... .JUL 0 i i.9 ,i , .~ 0i~ & Gas cons. ~chomgo FORM 1-2M02 'REV II-72) PRINTED IN U.S.A. ,'~ STATE OF ALASKA ALASKA O AND GAS CONSERVATION COMMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well .r~ Workover operation [] ~ 2. Name of operator 7. Permit No. ,/ Union Oil company of California* 80-144 3. Address 8. APl Number 909 West 9th Avenue, Anchorage, Alaska 99501 50-133-20074 4. Location of Well at surface King Salmon Platform Leg #4, Conductor #32 729'N, 130' W f/SE Corner, 5. Elevation in feet (indicate KB, DF, etc.) KB 100' MLLW Sec 17, T9N, R13W, SM 6. Lease Designation and Serial No. ADL 18777 9. Unit or Lease Name Trading Bay Unit 10. Well No'. K-3 RD (12-20) 11. Field and Pool McArthur River Hemlock For the Month of May ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks (See attached) 13. Casing or liner run and quantities of cement, results of pressur9 tests (See attached) 14. Coring resume and brief description None 15. Logs run and depth where run 13,413' MD - DIL/S0nic/Calliper CNL/FDC/Gr 13,300' (PBD) - CBL ,JUN 0;i L~: G~s Cons. C0mm~s~,~n Anchorage 16. DST data, perforating data, shows of H2S, miscellaneous data 4" Mag.oriented @' 4 SPF 4 SPF 12,720-21 on 120° 12,856"-12,877' (21') 12,720-21 on 60° 12,835'-12,856'(21') 12,814'-12,835' (21') 12,808'-12,814' (6') 4 SPF 12,787-12,797' (10') 12,767-12,787' (20') 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OTE--~qep~)/t0n t is orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commis,sion by_the 15th of the ~ucceeding nlonth unless otherwise directed. ...... *A~n A]~.~Ka, ±nc. rs suD-o~era~or' Monthly Report of Drilling and Workover Operations May 1981 K-3 RD (12-20) Page Two RIH w/6" bit and 7" casing scraper. No cement inside top of 7" liner. Located landing collar @ 13,311'. Pressure tested casing @ 3,000 psi. Hole took fluid @ 2 BPM. Drilled out float collar and ran into shoe @ 13,393'. Drilled shoe and washed to 13,405'. Ran and set 7" E-Z drill retainer @ 13,342'. Tested lines to 5,300 psi. Obtained breakdown @ 5,000 psi. Hole took fluid @ 2 BPM. Preflushed w/20 bbl fresh water. Pumped 200 sx of class "G" cement, w/.3% D-.19, .75% D-31L and .1% DL @ 15.6 ppg. Displaced w/5 bbls fresh water and 154 bbls 10.0 ppg mud. Squeezed 45 bbl mud. CIP @' '0800 hrs, 5/1/81 Reversed out. Tested liner lap--leaked. ~Tested cement lines @ 4,300 psi. Hole took fluid @ 2.5 BPM under 1,000 psi. Held 900 psi for 5 min. Pressured up again. Hole took fluid @ 2.5 BPM under 2,650 psi. Set 9-5/8" RTTS tool @ 10,395'. Tested cement lines @ 5,000 psi. Hole took fluid @ 3 BPM under 3,000 psi (tool by- passed). Preflushed w/10 bbl fresh water and 15 bbl KCl water. Pumped 120 sx class "G" cement w/.3% D-19, .75% D-31L and .1% DL @ 16.1 ppg. Displaced w/3 bbl fresh water and 143 bbl 10.1 ppg mud. Squeezed 58 bbl mud. CIP @ 2015 hours, 5/1/81. Top of cement estimated @ 10,610'. Final squeeze pressure @ 3,250 psi. Held pressure 35 minutes and dropped to 2,100 psi. Held for 10 minutes. RIH w/9-5/8" casing scraper and 8-I/2" bit, Cleaned out solid cement from !0~562~-10,660'o Pressured up to 5~@00 psi and held. Circ and condition mud. RIH w/6" bit and 7" casing scraper. Cleaned out solid cement from 13,176'-13,300'. Tested casing and liner lap @ 3,000 psi--OK. Filled drill pipe w/4,200' vertical water cushion. Ran WSO tools to test liner lap. No good--tool did not open. Reran test. Showed strong salt water flow up through lap. Ran CBL. Set EZSV retainer @ 10,560 on WL. Tested cement lines to 5,000 psi. Stabbed into retainer and pumped 3 BPM @ 3,050 psi. Preflushed w/50 bbl water. Pumped 200 sx class "G" cement w/.8% D-31L @ 15.8 ppg, followed by 5 bbl water. Displaced 10 bbl water on retainer. Stabbed in a~ put 2,000 psi on annulus. Squeezed liner lap w/40 bbl wa~~~Q preflush and 195 sx cement. CIP @ 2040 hours, 5/5/81. No cement. Reversed out. 3U~!~z~]~i.~ Monthly Report of Drilling and Workover Operations May 1981 K-3 RD (12-20) Page Three RIH w/8-1/2" bit and 9-5/8" casing scraper. Cleaned out solid cement from 10,490'-10,660' (TOL). RIH w/6" bit and 7" casing scraper. Cleaned out cement from 10,979'-11,090'. Displaced and conditioned mud to 9.4 ppg. Spotted 8.8 ppg KC1 from 12,000'-13,300'. Filled drill pipe w/3,100' vertical water cushion. Set RTTS @ 10,600'. Ran water shut-off test w/no entry. Tested casing to 3,000 psi, w/50 psi drop in 30 minutes. Perforated 7" liner on wireline @ 12,720'. Set EZSV retainer @ 12,710'. Tested cement lines to 5,500 psi. Spotted 50 bbl KCL pill and stabbed into EZSV retainer. Put 2,000 psi on annulus. Broke down perforations @ 12,720-.21 w/5,400 psi. Established injection rate of 2 BPM @ 4,000 psi. Injected total of 30 bbl KC1. Pulled out of EZSV retainer. Preflushed w/10 bbl KC1. Pumped 125 sx class "G" cement w/5% KCl, 35 gals/100 sx D45L, 7 gal/100 sx R12L, fOllowed by 10 bbl KC1. Squeezed perforations w/5 bbl KCL and 100 sx cement @ 15.8 ppg w/final injection pressure of 5,20~0 psi. CIP @ 1335 hrs, 5/8/81. Pressure bled to 3,0~00 psi in 5 minutes. Left 25 sx cement on.retainer. Reversed out 3 bbl cement. Tagged cement @ 12,603'. Cleaned out to 13,300'. Displaced mud w/filtered inlet water. Spotted 150 bbl Dril-S pill from 13,300'-9,950'. Ran 7" Baker F-1 packer on wireline, Stopped @ 11,450'. Ran 9-.5/8'' and 7" junk baskets recovering rubber. Reran packer and stuck @ 11,860'. Packer pUlled out of rope socket. RIH ~/overshot. Located packer @ 12,800'. Sheared WL running tool out of packer & packer set. RIH w/fishing tool. Milled over packer and recovered fish. RIH w/OE 3-1/2" DP. Spot Dril-S pill from 13,293'-12,000'. RIH w/Baker F-1 packer. Packer preset @ 12,088. Milled over packer and recovered fish. Ran 7" casing scraper and junk mill. Washed top of liner @ 10,660'. RIH to 13,000~ and reversed out. Ran 9-5/8" and 7" gauge ring to clear hole of rubber. · i t Ran Brown BD-1 packer @ 12,430' on 3-1/2" DP Ran 63 jo n 3-1/2" 9 2# N-80 BTC and 338 joints 4-1/2" 12 6~ N-80 BTC tubing. Installed Camco TRB-8 SSSV. Tested control line to~ 5,000 psi. Landed tubing w/locater sub 1' above packer @ 12,429'. Tested completion string to 3,000 psi-OK. Packer held @ 3,500 psi. NU and tested tree and all wing valves to 5,000 psi. Gas lifted well. Perforated. Flow tested well. Released rig @ 0600 hrs, 5/22/81· Well turned over to Production / STATE OF ALASKA ALASKA:' ";~IL AND GAS CONSERVATION'-'~,MMISSION SUNDRY OTICES AND REPOR'i ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Union Oil Company of California* West 9th Avenue, Anchorage, Alaska 99501 '4. Location of Well King Salmon Platform Leg #4, Conductor ~32 729'N, 130'W f/SE Corner, Sec 17, T9N, R13W, SM 5. Elevation in feet (indicate KB, D'F, etc.) K.B 100' HLLW 6. Lease Designation Md Serial No. ADL 18777 7. Permit No. 80-,144 8. APl Number 50-~33-20074-~! 9. Unit or Lease Name Trading Bay Unit 10. Well Number 11. Field and Po01 McArthur 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 [] Set 9-5/8" casin (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). Drilled 12-1/4" hole to 11,045'. Ran 31 joints of 9-5/8" 47#, 74 joints of 9-5/8" 47# N-80 8rd LTC, and. 170 joints of 9-5/8" with shoe @ 10,983 and float collar @ 10,885'. Tested cement lines. Pumped 35 bbls fresh water preflush. Dropped bottom plug and pumped 200 class "G" cement w/.75% D-31L, .3% D-19 and .1% D-6L. Pumped 800 sx class "G" neat cement @ 15.8 ppg. Displaced with mud and bumped plug. Pressured up to 2000 psi. Bled off pressure--floats held. CIP @ 0015 hrs., 4/14/81. N-80 BTC, 47~, S-95 BTC, SX Tested casing @ 2500 psi--OK. Drilled out float collar and shoe. Cleaned out to 11,045'. Tested casing @ 2500 psi--OK. Drilled 10' of new hole (11,055') and ran leak-off test @ 2580 psi (16.6 E~). ify that thp.~or_efl~ing is true and correct toh / Signed/~ ,//.~~//' Title Dist. Drlg. Supt. Th~ce below for Commission use RECEIVED Alaska Oil &*Gas Cons. Comm./on Anchorage Date 4/24/81 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 *ARCO Alaska, Inc. is sub-operator. Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR "Y" COOR. "X" COOR. WELL #- LEG ~1: · 1 2,511,762 213,819 K-21 & RD 2 2,511,761 213,815 K-30 3 2,511,764 213,811 K-18 4 2,511,768 213,810 K-17 5 2,511,772 213,812 K-23 (23-19) 6 2,511,773 213,817 K-19. 7 2,511,770 213,821 K-22 & RD 8 2,511,766 213,822 K-20 LEG #2: 2,511,690 213,768 9 2,511,686 213,772 l0 2,511,684 '-213,768 ll 2,511,687 213,763 12 2,511,691 213,762 13 2,511,695 213,765 14 2,511,696 213,769 15 2,511,694 213,776 16 2,511,689 213,774 LEG #3: 17 2,511,723 213,712 18 2,511,721 213,708 19 2,511,724 213,703 20 2,511,728 213,702 21 2,511,732 213,705 22 2,511,733 ' 213,709 23 2,511,731 213,713 24 2,511,726 213,714 Leg #4: 25 2,511,799 213,760 26 2,511,798 213,756 27 2,511,801 213,752 28 2,511,805 213,751 29 2,511,809 213,753 30 2,511,810 213,758 31 2,51 l, 807 213,762 32 2,511,803 213,763 K-15 & RD K-9 K-4 & RD K-11 K-13 & RD K-2 & RD K-7 & RD K-5 K-8 K-1 & RD K-10 &' RD K-16 K-12 & RD K-6 & 24 K-3 & RD FNL 688 687 690 694 698 699 696 692 611 610 613 617 621 622 619 615 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130. 131 128 124 120 l!9 133 135 !41 142 140 135 130 -. -~- STA.TE Or; ALASKA , z/~ ~ ALASKa ')IL AND GAS CONSERVATION C "yvlMISSlON MONTHLY REPORT OF DRILLING AND WO KOVER OPERATIONS 1. Drilling vvell]~] Workover operation [] 2. Name of operator Union Oil Company of California* 3. Address 909 West 9th Avenue, Anchorage, Alaska 99501 j7. Permit No, 80-144 so- - 0074 4. Location of Well at surface King Salmon Platform Leg ~4, Conductor ~32 729'N, !30'W f/SE Corner, 5. ElevationKBin feetl 0 (indicate0 ' YILLwKB' DF, etc.) J 6. Lease Designaz~sni~n%S~r.J~Tr~o. I For the Month of. Sec 17, T9N, R13W, SM 9. Unit or Lease Name Trading Bay Unit 10. Well No. K-3 RD (12-20) 11. Field and Pool ~cArthur River - -'Hemlock March ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks (See attached) 13. Casing or liner run and quantities of cement, results of pressure tests None · 14. Coring resume and brief description None 15. Logs run and depth where Fun None 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. 5 ~ '(~. 0r~.~- ~ ,TL~District Drillin9 Supt. 4/6/8] SIGNED ... ~\ ,' . DATE .... NOTE--Repo'~ on this form is required 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 Monthly Report of Drilling and Workover Operations March 1981 Page Two 12. Finished cutting 9-5/8" casing @ 2646'. Engaged spear and jarred on fish. No movement. Pulled up to 2582' and cut casing. Engaged fish (97') and POOH. Underreamed hole to 15" from 2506' - 2526' (20'). Recovered fish down to cut @ 2646' (64'). Washed .and reamed.2506' - 2646' (~-5/8" casing stub). POOH. RIH to 2700'. Tested Cement-linesl Pumped 60 bbl caustic water, 20 bbl water, 340 sx Class "G" cement w/D-31L @ 17.5 ppg, followed by 5 bbl water, displaced w/35 bbl mud. CIP @ 2400 hrs., 3/1/81. Tagged top of cement @ 2430'. Drilled 100' hard cement. Drilled 2530' - 10,033'. ALASKA IL AND GAS CONSERVATION C~, MISSION SUNDRY NOTICES AND' REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER r-] 2. Name of Operator Union Oil Company of California* 3. Address 909 West 9th Avenue, Anchorage, AK 99501 4. Location of Well King Salmon Platform Leg #4, Conductor #32 729'N, 130'W f/SE Corner, Sec 17, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) - ~R ]OO~ MLLW 12. I 6 . Lease Designation and Serial No. ADL 18777 7. Permit No. 80-144 8. APl Number ' 50- 133-20074 9. Unit or Lease Name 10. Well Number K-3 (12-20) 11. Eield and Pool McArthur 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). On 2/21/81, finished rigging up over Leg ~4, Conductor #32. Pumped into perforations w/175 bbl filtered inlet water. Perf'd tubing @ 10,778' and circulated well to production system. ND tree, NU BOPE and tested same - ok w/D.O.G, witness (H. Hawkins). LD production assembly. Ran gyro survey to~. Set 7" Baker retainer @ 10,750'. Tested cement lines to 5000 psi - ok. Tested DP and casing annulus to 2000 psi - ok. Preflushed w/20 bbl water. Cemented w/160 sx Class "G" cement w/.75% D31L, 0.2% D-19 and 0.1% D-6L @ 15.8 ppg, followed by 5 bbl water. After 90 bbl displaced, squeezed perfs W/135 sx cement. Left 25 sx cement on top retainer. CIP @ 0925 hrs., 2./25/81 Set bridge plug @ 2915'. Tested w/2000 psi - ok. Tested cement lines to 1000 psi - ok. Preflushed w/10 bbl water. Cemented w/50 sx Class "G" cement w/2% CaC1 @ 15.8 ppg, followed by 4 bbl water. Displaced w/45 bbl to spot. CIP @ 0640 hrs., 2/26/81. (continued - see attached) RE C E IVED UAE 1 1981 ~Jaska 0il & Gas r, nn~ ~......,._, 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Anchorage %~',,~-,. ~. (~~ /~S(~ Title~/~-~. b~/~, ~ ~/, Date ~/////~'/ Signed The space b~w for Commission use / ~ - O' ¥ ' -' Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1~0 *ARCO --- -Alaska, Inc. is sup-operator Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Sundry Notices and Reports on Wells 13. (continued) Displaced filtered inlet water w/gel water. Cut casing @ 2485'. LD 58 joints 9-5/8" N-80 BTC casing. Cut csg @ 2646' and 2582'. Could not recover. Washed over fish. Recovered fish down to cut @ 2582' (97'). Underreamed hole to 15" from 2506'-2526'. Recovered fish down to cut @ 2646'(64'). Reamed 2506'-2646' w/12'/4" bit. Circ and condition mud. RIH w/~3-1/2" DP to 2700~ Test cement lines. Preflushed w/60 bbl caustic water, 20 bbl water. Cemented w/340 sx Class "G" cement w/D-31L @ 17.5 ppg, followed by 5 bbl water. Displaced w/35 bbl mud. CIP @ 2400 hrs., 3/1/81. REC IYED Alaska Oil & Gas Cons. Anchorage ALASKA OIL AND ~S CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman Thru: Lonnie C. Smith //'~' ~ Commissioner Harold R. Hawkins PetrOleum Inspector~~ February 24, 1981 B.O..P.E. Test on ARCO K-3 Redr il 1 Sec. 19, TgN, R13W, SM Permit #80-144. February 2.2, .19_81= I left Anchorage at 6:45 am, by A.A.I., to Kehai. I arrived in Kenai and drove to ERA Helliport, on North Kenai road. I went to the King Salmon Platform, where I witnes- sed a BOPE test. There was a joint of drill pipe screwed into the tubing hanger so we could not test the blind rams and the upper and lower kelly valves. Of the equipment tested, there was 1 failure, a flange leaked on the choke manifold, this was tightened and tested ok. I filled oUt an A.O.G.C.C. report (attached). In s~mary, I witnessed the BOPE test on the King salmon Plat- form that Parker Drilling performed. Test's that were performed were satisfactory. (see A.O.G.C.C. report attached). Attachment: 8:30 am - February 24, 1981, Jack Murray, Arco Supervisor called, the blind rams, the lower kelly, the ball & dart valve tested ok. The new upper kelly would not test. Arco has ordered another upper kelly. Attachment: 3515 pm - February 24, .1981, Bart Richardson, Arco 'superVisor called. The upper kelly was replaced and tested to 3000 p.s.i.g. OK. HRH :mm O&G 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator /~ ~L- 0 Representative Well /~-- 3 ~ L/~-20~ Permit # ~ Location: Sec /~ T~ R/~ ~$~ ' . ~ ~Casing Set Drilling Contractor ~F~ ~ ...... Representat iv~ Test Pres sure Well Sign General Housekeeping Reserve pit Rig 0/'~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ACCUMULATOR SYSTEM Full Charge Pres sure ~ %~ ~ psig Pressure After Closure /~-d) psig 200 psig Above Precharge Attained: -- min~.~, sec. Full Charge Pressure Attained:. ~3 min --- sec N2 / ?0~ ~,~.~ ~' 0.9 ~,~ ~,/,~.'~ psig Controls: Master ~/~ Remote O/~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly '. Test Pressure Lower ..... 3~,~?~r~st Pres sure Ball 'rype~a~p~.,~,~l'esn Pressure Inside BOP~ ~~est Pressure Choke Manifold ~/~ Test Pressure No. Valves !/ No. flanges ~ ~dj ustable Chokes Hydrauically operated choke, TeSt Results: Failures ~~ ~ Test Time ~ hrs. Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. / Distribution orig. - AO&GCC cc cc - Operator - Supervisor December 22, 1980 Mr. Robert T. ~nderson District Land Manager Union.Oil Company of California P. O. Box 6247 Anchorage, Alaska 99505 Re: Trading Bay Unit K-3 RD Union Oil Company of California Permit No. 80-144 Sur. Loc.: 729'N, I30'W fr SE cr Sec 17, T9N, R13W, SM. Bottomhole Loc.: 3250'S, 1800'W fr NE cr Sec 19, T9N, R13W, SM. Dear Mr. Anderson: 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 5, 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. Robert T. Anderson Trading Bay Unit ~-3 RD -2- December 22, 1980 c~ncing operations you may be contacted by a representative. of the Department of Environ~ental Conservation. ursuant to AS 3.8.40, Local Hire Under ~tate Leases, the Alaska pertinent' of Labor is being notified o~ the tssuan&e of this permit to dril 1. 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 abandonment, please give this office ads,sate advance notification so that we may have a witness present. Very truly yours, HoyL H. Hamil ton Chairma~ of BY ORDER OF THF. COMMiSSiON Alaska Oil & Gas Conservation Co~mission Enclosure cc.. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o eno1. HHI~: be Union Oil and Gas Di~ison: Western Region Union Oil CompanY '"'i/California) P.O, Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager December 17, 1980 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Permit to Drill or Deepen TBUS K-3 Rd. (12-20) King Salmon Platform, McArthur River Field, State Lease No. ADL-18777 Dear Mr. Hamilton: Per your request concerning the above captioned. Permit to Drill TBUS K-3 Rd., we have redone and are enclosing for your review a more complete'Permit along with a plat and a sketch of the BOPE. If there is any additional information required, please let us know. sk Enclosures Very truly yours, Form 10-401 REV, 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TB'""~CATE (Other instru }on reverse ~. ! RECEIVED DEC 8 .t=o,o PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK ~ DRILL ~ b. TYPE OF WELL OIL GAS DEEPEN [--] Alaska Oil & Gas Cons. Commi Anchorage SINGLE MULTIPLE OTHER ZONE r-x1 ZONE F1 API %50-733-20074-01 6. LEASE DESIGNATION AND SERIAL NO. ...AJQ_L-18777 ~5}.~I INDIAN, ALLOTTEE OR TRIBE NAME None 8. UNIT FARM OR LEASE NAME 2. NAME OF OPERATOR Union Oil Company of California * 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 4. LOCATION Ot~_WELL - At surface ~Klng ,, S. a ~l/!~on .P1 .atform ~eg ~4, conductor 932 99501 Trading Bay Unit 9. WELL NO. K-3 RD (12-20) 10. FIELD AND POOL, OR WILDCAT McAr~hur River (Hemlock) 11. SEC., T., R., M., (BOTTOM At proposed prod. zone 729' N, 130' W f/SE Corner, Sec 17, T9N, R13W, SM 3250' S, 1800' W f/NE Corner, Sec 19, T9N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 24 miles NW of Kenai 14. BOND INFORMA1~IQN: Statewide TYPE Surety and/or No. Federal Insurance Co. %8011-34-40 HOLE OBJECTIVE) Sec 19, T9N, R13W, SM 12. Amount $500,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 325' I8. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1,100' SE of K-19 21. ELEVATIONS (Show whether DF, RT, CR, etc.) RKB 100' MSL 16. No. OF ACRES IN LEASE 1902 19. PROPOSED DE~H 9,650' TVD 13r400' MD 17. NO,ACRES ASSIGNED TO THIS WELL 72 20. ROTARY OR CABLE TOOLS ' Rotary 22. APPROX. DATE WORK WILL START January 15, 1980 23. PRO~)SED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE~ING DE~H Quantity of cement Existing 24" Cond. Drive Pipe 394' .......... Existing 13-3/8" 61% J-55 2,506' ..... 12-1/4" 9-5/8" 47% N-80 11,000' 3450 sx Class G 8-1/2" 7" 29~ N-SO 13,400' 350 sx Class G Propose to move subsurface location. Cut and pull 9-5/8" casing at 2,650' ~.~D. Lay kick-off plug and drill 12-1/4" hole to 11,000' MD (8070' TVD). Cement 9-5/8" casing at 11,000' MD. Log. Drill 8-1/2" hole to 13,400' MD (9,650' TVD). Log. Cement 7" liner at 13,400' ~D. Log. Set permanent packer, run completion string and complete as Hemlock producer. BOPE: 3000 psi double-gate Shaffer and GK Hydril. .Anticipated maxim~ bottom hole pressure is 3700 psi. Anticipated maximum surface pressure is 2878 psi (calculated surface pressure with full column of gas in well~&..)l bore ~to~/~~~. TheAboe~m hclc location will not come within 200' of another well.~s bc, tt,~.,"--~ holc t~. The closest bottom hole location is 1100' away at K-19. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subdurface locations and measured and true vertical depths. Give blowout preventer program. Richfield C pany is sub-operator. SIG~----~A~/A -~/~/t~/~/,~ DATE. December 17, 1980 Robert T.' Anderson - / U (This space for State office use) / ! CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED [ MUD LOG OTHER REQUIREMENTS: u LNO ] [] NO DIRECHONAL SURVEY REQUIRED eYES [] NO PERMIT NO. 5 0- / q ~Y ORDE~q THE A.P.I. NUMERICAL CODE APPROVAL DATE TITLE Ch~i~ *See Instruction On Reverse Side nTLE District Land Mgr. December 22, 1980 DATE 12/22/80 vo Io.ooo TOP HEMLOCK FORMATION STRUCTURE CONTOURS 100' I I t ! 13,771 VO 10,~30 WFU-3 K-19, 'o''"~ I I I I I I*l I"~11,1 I I TD VD 9876 f' -tO K-l?_ 0 0 RECEIVED D~=C,~ 8 !,980 · Oil & 6as Cons. Comm/ss/o ' Anchor~go .SWACO ~i~A - D E if'-- 5000 PSI DIAPHRAGM U.I U,I CHOKE LINE S Q (M ADJ. CHOKE L (K Flow ~ . Nipple Shaffer Type "E" 3000 psi Double Rams Pipe Rams: Top Blind Rams P N O Z CHECK VALVE W. Z < O9 __ ~ECE~VED DEC ! 8 Oil & Gas Cons. Commission Anchorago TEST SEQUENCE ON VALVES # 1 A-K-P-Q-E-M-T #2 B-G-F-D-S-R #3 H-SWACO CHOKE-C- ADJUST CHOKE-O #4 J-I #5 L #6 N CHOKE MANIFOLD & KILL LINE W/B.O.P. ON KING PLATFORM e~s'~z-7'a~ z~o' ) ._.~ ALASKA OIL AND GAS CONSERVATION COMMISSION JAY S. HAMMOND, 60VERNOR 3001 PORCUPINE DR/VE-ANCHORAGE, ALASKA 99501 December 4, 1980 ADMINISTRATIVE APPROVAL NO. 80.37 Re: Application of Union Oil Company of California, operator of ~_i,:___,_~o redrill, complete and produce the ~~well as a part of the pressure main- tenance project approved by Conservation Order No. 80. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on December 3, 1980 and stated that the drilling, completion and production of the Trading Bay Unit K-3RD well will provide a crestal final with- drawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kugle~ Commi ss ioner BY THE ORDER OF THE COMMISSION Union Oil and Gas Divison: Western Region Union Oil Compal.. )of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager · December 3, 1980 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Complete Trading Bay Unit K-3RD Gentlemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in the Hemlock Formation at a crestal final withdrawal point, pursuant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the K-3 location on the King Salmon Platform by ARCO Oil and Gas Company, suboperator. Very truly yours, RECEIVED DEC- 3 ]980 ~,laska Oil & Gas Cons. Commission Anchorage Form 10-401 i ~EV. 1-1-71 STAT E 0 F A LAS KA SUBMIT IN TRIX OIL AND GAS CONSERVATION COMMITTEDEc ~: 1980 PERMIT TO DRILL OR DEEPE.~..,j~ 0!! g_ n~ I~one: ~. TYPE o~ WOR~ Anchorage RE DRILL [] DEEPEN [~] b. TYPE OF WELL OIL ~] GAS SINGLE ~ MULTIPLE r--I WELL WELL ~--] OTHER ZONE IKI ZONE 2. NAME OF OPERATOR Union Oil Company of California * 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface 6. LEASE DESIGNATION AND SERIAL NO. :)tl ADL-18777 7. IF. INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Tradinq Bay Unit 9. WELL NO. K-3RD (12-20) King Salmon Platform Leg 4, .Conductor #32 729' N, 130' W f/SE Corner, Sec 17, T9N, R13W, SM At proposed prod. zone 3250' S, 1800' W f/NE Corner, Sec 19, T9N, R13W, S~ 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. Approximately 24 miles NW of Kenai 10. FIELD AND POOL, OR WILDCAT McArthur River-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N, R13W, SM 14. BOND INFORMATION: ~E Statewide Surety and/or No. I5. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) Federal Insurance Co. #8011-34-40 325' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1 .lf~fl' Rlq. nE R'-IQ 21. ELEV~¥10-N-S ~Show whether DF,-~T, ~I~,, etc.) RKB 100' MSL 16. No. OF ACRES IN LEASE 1902 19. PROPOSED DEPTH 9,650' TVD 13'400' MD $500,000 Amount 17. NO°ACRES ASSIGNED TO'THIS WELL 72 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START January 15, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM ExistingSIZE OF HOLE 24"SIZE OFcond.CASING Drive.WEIGHT PER FOOT PipeGRADE ~ETTING394DEPTHI Existinq 13-3/8" 61# J-55 ~2'506' 12-1/4 9-5/8" 47~t N-80 11,000' 8-1/2 7 29~ N-80 13,400' Propose to move subsurface location. Cut and pull casing at 2,.650' MD. Lay kick-off plug and drill 12-1/4" hole to 11 9-5/8" casing at 11,000' MD. Log. Drill 8-1 Log. Cement 7" liner at 13,400' MD.' Log. string and complete as Hemlock Producer. and GHHydril. ' MD (8070' TVD). Cement hole to 13,400' MD (9650' TVD). permanent packer, run completion psi double gate Shaffer * ARCO Oil and Gas Company is IN ABOVE SPACE DESCRIBE ~ new productive zone. If give: [ J vertical depths. Give blowout preventer 24.1 hex~y ce~y that the. For~~e a~C~ct df. , 980 ce for State office use) /"' CONDITIONS OF APPROVAL, IF ANY: --~ SAMPLES AND CORE CHIPS REQUIRED I MUD LOG OTHER REQUIREMENTS: 'lu I DI~ONAL SURVEY REQUIRED / A.P.I. NUMERICAL CODE zone and proposed neasured and true TITLE Dist. Drlg. Supt. PERMIT NO. y 0 ' / '/~ APPROVAL DATE APPOVED BY TITLE *See Instruction On Reverse Side DATE ARCO Oil and Gas Company 4> 32-~ No_ ! 8 2 $19 Division of AtlanticRichfieldComoany 1110 · Field Office Account First, National Bank in Dallas D&llas, Texas Pay TO THE r'- ORDER OF STATE OF ALASKA DEPT. OF REVENUE VOID AFTER 90 DAYS DATE NOVEMBER 22 "~ 19 8_.....~0 ' DOLLARS $ 100.00 NOT VALID FOR MORE THAN $25,000 REQUIRES TWO SIGNATURES IF DRAWN FOR MORE THAN $2,OOO L ,' ~8 25 ~ct,' ~: ~0000 ~2~: Or. 2780 INVOICE NUMBER INVOICE DATE AMOUNT VR 11-20-80 100.00 IN PAYMENT OF: ,,, INVOICE NUMBER INVOICE DATE AMOUNT Application fee for permit to drill or deepen K-3 RD REMARKS ARCO Oil and Gas Comoanv - P.O. BOX 2819 - DALLAS. TEXAS 75221 No 182519 C%~.CK LIST FOR NEW WELL PERMITS Item (1) Fee Approve Date . ~s, No /.'~/~F-- !=- 3 ..~. ~. 1. Is the permit fee attaChed .................................. F /b~! -- 2 Is w~ll to be located in a def ed pool .......... ,~ . 3. Is a registered survey plat attached ................................. / ~%-..%~ 4. Is well located proper distance frcm property line .................. / ~5. Is ~11 located proper distance from other wells .. .:I~ 6. Is sufficient undedicated acreage available in this pool ............ / 7. Is well to be deviated .............................................. 8. Is operator the only affected party ................................. ~. ,, .. 9. Can permit be approved before ten-day wait ............. . ..... . ...... ~ .... . · (3) A~nin.~ , ~-~ 10 Does operator have a bond in force .......... , ......... . ...... ~11. Is a conservation order needed .................................... 12 Is administrative approval needed .... i o i - 13 Is conductor string provided ................... 14. Is enough cement used to circulate on conductor and surface ........ (4) Casg. ~ /~//~'~ 15. Will c~ment tie in surface and intermediate or production strings ... ~. 6 Will cement cover all known Productive horizons .................... (2) Loc. Lease & Well No. Remarks t 17. Will surface casing protect fresh water zones ....................... 18. Will all casing give adequate safety in collapse, tension and burst.. ~~ (5)BOPE ~ ?&/Jfj6'~ 19. Does BOPE have sufficient pressure rating - Test to ~69~P~ psig .. \ ,Approval Reccmmended: ; A~ditional ReqUirements: ~pill /~_,~/ ~ //~/~/c~ ,4~f/-/C/~~b .,770~.~ /~ Jk7-_~,'//~,,~/i/~/F~Geology: Eng~ring: .... - .~/~),z~--,~-l~ bZ~5o~ ~i~'/D~ 2 ~D O ~' J~-T_tf;~/~'~,-~./.~&/~o HWK - ------~._?~-~. SEW ,- ~ ~,,r ~' ' ~' ' ' ' -------- JKT 'RAD ~ ~)/~~ ~ " rev: 03~05~80 -- /z /l ? da. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting. Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. .o ********************** RECEIVED ~UL 0 ~ lgS! 011 & t3as Oons. Oommlssio~ bV'P 009,H03 VERIFICA?ION bISTfNG PAGE ** REEL HEAPER ** SERVICE NAME. ISERVIC DATE =81/05/27 OR!G,IN t REEL NAME IREEb ID CONTINUATION,.# ~01- PREVIOUS REE~ { COMMENTS IREEb COMMENTS *~ TAPE HEADER SERVI~.E, NAME, ISERVIC DATE 181/05/27 , R~GZN ,NAM{ TAPENAHE CONTINUATION # PREVIOUS' TAPE o 0 COMMENTS ,TAPE C ** FIbE HEADER FtbE NAME SERVICE NAM~ VERSION # DATE l MAXIMUM bEN,TH I -I024 FIbE TYPE~ l PREVIOUS Elbe MNEM CONTENTS CN I ARCO _ ~N I TBU K-3 RD FN I MCAR HUR-RIVER RANG~ RANG~ TONNI TOWNSHIP COUNI STATI ~ENAI bASKA CTRYI USA MNEM CONTENTS DIb RUN # 1, bOGGED 27'APR"81 UNIT TYPE CATE SIZE CODE m{mm mmmm 00 000 005 065 00 000 010 065 000 000 0~5 065 000 000 O0 5 065 00 000 008 065 O0 000 007 065 00 000 005 065 O0 000 0~0 065 000 000 005 065 UNIT TYPE CATE SIZE CODE mmmm mmmm mmmm mmmm mmmm 000 000 003 065 ~v~ oo~.~o3 CASING LOGGER BIT SIZE FLUID IN THE DENS VISC FLUID bOSS RMF RMC " POROSITY MATRIX ~* DATA FORMAT RECORD': ENTRY BLOCKS ID ORDER DEPT SP GR tSN DT ISN SP GR XSN R~OB IS . 0 G/C3 O' 35 ~ 0 0 .4 0 PAGE REPR CODE 68 RECEIVED J U L 0 1 1981 d~mska 0il & 6as C~ns. ~mmiss}on bYP 009,H03 VERIFiCATiON LISTING PAOE 3 DRHO GR SN CAb! NRAT NCNb FCNL SN G/¢3~: O- 44 _ 0 -0 ~ 0 4 OAPI 0 3i 32 0 0 4, 4 4 0 0 0 0 · 0 0 DATA DEPT SP GR GR FCNL 250 ~-99~;'~50,,.99 50 'RHOB-NRAT 88 ~50 DRHO 50 NCNL DEPT Se GR GR FCNL 134,00 ,.I. 2 1287 bU I NRAT · 6.641 ': I'laP 72;188 SP 54 NCNb EPT P GR FCNL 89 1-7,883 ILD 06 NCN~ DEPT SP GR GR FCNL 13200 -37 8 2058 lO0 :$ GU , 69 GRF SPILP 06 NCNb DEPT GR GR FCNL 13100 -69 U t0,825 ~XL~ 43 ,656 DT ,44'? RHO 1.842 ~CNL DEPT SP FCNL 13000 0 0 SF 4) PHI 3l-~'ft ALI {;9,984 IL, D 67;000 SP '<,2, 522 DRXO 1.,526 NCNb DEPT SP FCNL 1:2900 2?28 000 -SFGU 219 GR 438 CALX 000 ,500 DT ~,646 RHOB ,586 NRAT 469 lbD 375 SP 488 DRHO 590 NCNb DEPT GR 12800,00-0 SFLU.. 61 '69.219 OR 42 42.556 NPHI ' 13- ~1'781 7,1,,375 SP 465 DRHO I 68 ! 68 1 68 68 ! 68 81 6"728 -999,250 6.797 3868,000 8.055 '5.000 0.107 3064.000 8 336 -37.469 0.077 4404,000 12.gg2 -69,625 0,040 4576.000 23,047 -59,594 0,004 5164,000 50,750 -71,219 0.008 4964,000 $6,688 "69,219 0,009 LV'P 009.H03 OR FCNL DEPT SP GR GR FCNL DEPT rCNL DEPT bP FCNL DE:PT GR GR FCNL OR D£PT FCNL DE:PT P FCNL DE:P? GR FCNL DEPT R GR 43,969 2750,000 12700500~0 -76 6 8 2900 12600,000 ' "60.625 39,875 41',28t 2698.000 12500 0~0 60 I -il2, 44.24806 44, 2708"00~ 00.000 ,000 12200,000 '86.875 .969 1783,000 12100,000 "58.063, 61,375 52.750 1957.000 12000.000 ' "83,28t 48.250 41~.0 11900.000 ~"90.4 49.5~) 41.28X PAOE: CALl SrbU NPHI CALl srhu GR NPH! CALX SrbU NPHX CALX $FLU GR NPHI CALX ,,26,656 ,.00! '000 ,18,938 ,078 NCNb 4336[,000 19,.7:19 .000 SFLU GR NPHI CAb! .10,234 '"".19;~328 0,054 ,000 srbu CALI NPHI CALX 6.7 5"8½5 008 , i:ooo 6 0:5 SFbU GR NPHI CALX $rbu GR NPHI CALX 035 4 ;' ;ooo .i7 ,030 .000 RECEIVED JUL 0 1 1981 Oil & Sas Cons. Comm~ [aVP O0~,H03 PCNb DEPT GR ~¢Nh DEPT GR GR rCNb DEPT SP GR GR DEPT SP rCNb DEPT GR. GR FCNb DEPT SP D/PT Sp GR GR DEPT GR GR FCNb DEPT SP GR GR FCNb~ VERIFICATION b-ISTING PAGE. 5 1906.000 11~00.000 &rbU 85.563 CALI ?02,.000 -~. o ' .563 NPHI, 41,:~56 CA[a! ~652.000 ~600.000 -92'750 49 39.78/, .t822.000 lt500,O!O "25.3 85.:,3 67.6~ 416,500 164 O0 ~ 300 000 102~ 625 000 0 0 44 906 88O 629e500 GR NPHI 8rbU GR NPHI. CA[aZ SrbU GR CAb]:; GR NPHI CAbl ar[au GR NPHI: CAbI SrbU GR NPH CA[al GR )00 ~00 391 OEP? SP GR GR FCNL DE:PT SP GR GR FCNb DEPT SP GR GR rCNb SP GR GR FCNL DEPT SP GR DEPT rCNb DEPT R GR rCgb DE:PT GR FCNL DE:PT SP GR GR FCNL 1!90 ,000 99~,250 999'250 ,000 .!800 000 I 999 250 999 ,250 34 250 745 500 10700 000 ~-999 250 -999 250 45 938 423 750 1~600,000 .999,250 i999.250 '5~,688 426,250 t~500,000 .999.250 396'250 ~56 ,250 .250 ~ 28,969 891,000 ,, 10200 000 --999 ~0 ~ 50 -999 44 875 321 750 10100,000 '999.~50 373,500 SrbU GR NPH! CALX SrbU GR NPH]: CALl OR NPH! CALX GR CALl, SFLU GR NPHZ CALX SFLU GR NPH! CALX srbu GR NPHX CALX OR NPHZ CALl OR NPH! CALX, "99 PAGE:: 6 -999 250 '999 250 -0 6 9 '999,250 '99.~'250 i99g,250 .664 ,000- :999.250 ;250 '613, 784'000 -99' 250 N ~ ~ :': ~'1490 000 !50 -999 250 ~,'999 250 -0 643 -000 '999,250 ' -0, 48'7,~0. LVP D£PT ~CNL DE'PT GR rCNb DEPT GR GR FCNL DEFT St:' FCNL DE, PT 6P GR GR rCNb DE'PT SP GR GR FCNL DEFT St:' GR FCNb DEPT ~R FCNL DE,FT FCNL DE'PT 009.H03 100 m9 4 .250 9.250 59~,000 9800 000 -999 250 -9~9 250 34~ .156 000 9,250 25.55~ 463,500 .250 999,250 5~ '703 .500 4~'.5~ 245.000 ~400,000 999.250 ,250 -999 40.7~9 433'500 ~200.00 .g99,25~ 999,250 36. 2 422.~0 9100.000 00.000 SFLU. ,:I o I: oo GR NPH! CRUZ -999 SrbU GR NFl'IX. CALX NRA~ NCNi 8FLU GR NFHX. CALX 15 SFLU GR cNPHX: ALX GR. NPHX~ CALX SFLU GR ' N P H X CALX FLU- R NPHZ: CALX SFLU GR NPH! 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