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Home My WebLink About190-019 • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION la.Well StatuW ❑ Gas❑ G ELL COMPLETION OR RECOMPLETION REPORT AND LOG E1 Other ❑ Abandoned Rio- Suspended❑ lb.Well Class: 20MMC 25.105 20MMC 25.110 Development Q• Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 5/1/2017 # 190-019/317-088/317-129 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 March 23, 1990 50-733-20414-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1000'FNL,557'FWL, Sec 33,T9N, R13W, SM,AK May 26, 1990 TBU M-28 • Top of Productive Interval: 9. Ref Elevations: KB: 160' 17. Field/Pool(s):McArthur River Field GL: N/A BF:72' N/A Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 85'FNL,2331'FEL,Sec 28,T9N, R13W,SM,AK 8,549'MD/7,051'TVD • ADL018730• 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number Surface: x- 214174 y- 2499500 Zone- 4 13,000'MD/10,797'TVD ' N/A TPI: x- y- Zone- 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 216724 y- 2505629 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U (attached) No ❑✓ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 187' (ft MSL) -8,:.;4`J'MD 17,0.;1'TVD Lk- 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 SCANNED .JUL :I 12017RECEIVED JUN 2 2 2017 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM PULLED 26" 397# Surface 990' Surface 990' Conductor Conductor 16" 75# K-55 Surface 1,447' Surface 1,443' 22" 1800 sx 13-3/8" 61/68# K-55 Surface 4,590 Surface 4,030' 17-1/2" 2900 sx 9-5/8" 47# N-80 Surface 8,549' Surface 7,051' 12-1/4" 3360 sx 24. Open to production or injection? Yes ❑ No Q 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number;Date Perfd): j,; ,i I iC.»l 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. );,,M Was hydraulic fracturing used during completion? Yes ❑ No Q 5J)/17- Per 20 AAC 25.283(i)(2)attach electronic and printed information `?E+0=IF=D DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period jo.- Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate --111. Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIAL onl �;1A 'Oda' '�/� Z#-3a-J7 RBDMS w JUN 2 6 2017 • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑i Sidewall Cores: Yes ❑ No Q If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ 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, PreDrill 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: cdjnger(p hiIcorp.com Authorized MO 4"4 "A MI*r.S 5 e r Matt Contact Phone: 777-8389 Signatur Date: kt• 2")., Z01'7 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 TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • • Steelhead Platform II Schematic Well M 28 PTD: 190-019 API: 50-733-20414-00 Hilcorp Alaska,LLC Abandoned:5/1/2017 RKB-to TBG Head:71.4' J] L .1 [6 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13 3/8" 61/68 K-55 Buttress 12.415" Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604" Surf 497' ►1� 9-5/8" 47 N-80 Buttress 8.681" 497' 11,399' 7" 29 N-80 Buttress 6.184" 11,193' 12,448' TOW 8,545'MD 5" 18 N-80 FL4S 4.276" 12,368' 13,000' Tubing: sidetrack M-28RD tF' 8,573' ti' Jewelry Detail ' ' Cement Retainer Depth Depth 2 9,089' ixl/5NO (MDI ITVDI pp_ ID Item Jeeze t .s. 85'-9,977rfs -**^'1 : '•9r .y\e7 ( 1 8,573' CIBP(Set for whip stock) k t: 3 :,. {,,•• CasingLeak4. t„, 2 9,089' Cement Retainer '.* , s - ..r 10466'DIL 3 4'` T;_:*'►: Squeezed with 3 10,440' 8,541' 8.46 6 Baker 9-5/8"SC-1L '; `' '-'•,,..-1- 100 sx cement Isolation liner 4 jts and pup.7"29 rr. , 4 7 6.184 lb/ft L-80 Butt casing with Baker 4 , + Anchor Assy KBH-22(75 x 60) t*' Baker Model FA permanent packer 1C- 5 10,628' 8,689' 8.437 6 .�' {` Squeeze Perts (190FA75)with 6'tieback 5 .1 4.1 ' ' 10,620'-10,623' 6. 10,947' 8,941' 8.25 6.312 Baker ZXP liner packer 7"x 9-5/8" 7 7 6.184 Isolation Liner Sits and pup.7"29 ;'w G-zone lb/ft Butt L-80 casing 8 11,198' 9,144' 7 6.184 Baker Muleshoe Assy.into TIW TBE _ - + _ 9 12,351' 10,170' 5.875 4 Baker FB-1 Packer(Size 85-40) t 6 ►4 ' t,:.„.", '►� 10 12,357' 10,175' 5.156 3.813 Otis X landing nipple I 4 . TIW LG-6 Tie-back Seals with 41 "Bad"casing at 11 12,369' 10,187' 5.093 4.438 muleshoe 7 ,,t,-:, ',... .2.2• 11035' ,..4.01. 8 ` 1 . i.7.? • t Hemlock. W.Foreland 9 Jurassic ~, STRESSFRAC . t�..-:, Tool @12,880'. TD=13,000 PBTD=12,952 MAX HOLE ANGLE=41.8° Updated by:JLL 01/30/17 • • Hilcorp Energy Company Composite Report Well Name: MRF M-28RD Field: County/State: CIO,Alaska (LAT/LONG): Ovation(RKB): API#: 50-733-20414-01-00 Spud Date: Job Name: 1710804P M-28RD PreDrill Contractor AFE#: AFE$: Acfivi#y Oate ` : Ops Starr nary 4/19/2017 Prep for rig move,finish install of new cement hoses,replace accumulator 4-way valves,&remove ODS bottom stairs for rig move.SIMOPS tested M-29 tree to 250/3000 psi for 15 min&void to 250/5000 psi for 15 min.,Remove rotary table cover,free up rotary table,free up rotary lock&repair lever lock,&service/ grease table. Remove Kelly hose from TD&standpipe.Move hose to deck for storage.SIMOP continue work on 4-way accumulator valves.,Skid rig from M- 29A to M-28RD. Remove lower earthquake clamps,purge new hydraulic lines for skid cylinders&skid lower sub base.,Remove upper sub base earthquake clamps,lower HP mud hose from sub base&skid rig over M-28RD.,Install earthquake clamps on upper&lower sub base.Install HP mud line to sub base HP mud line.,Complete service/grease of rotary table&install cover.Take on FIW to pits&line up both mud pumps.Mobilize kelly hose to rig floor. Install lower stairs on ODS of sub base.,Rig up to circulate tubing&9-5/8"X3-1/2"annulus.SIMOPS install kelly hose.,Pressure test circulating lines to 250/3000 psi, good.SIMOPS installing safety clamps&cables on kelly hose. Rig accepted at 06:00 4/20/2017.,M-28 initial pressures @ 22:00 hrs on 04-19-17;9-5/8"X3- 1/2''=78 psi, 13-3/8"X9-5/8"=310 psi,16"X13-3/8"=260 psi,26"X16"=260 psi,31"X26"=144 psi. 4/20/2017 Finish pressure testing circulating lines. Line up to pump down tubing,taking returns from 9-5/8"X3-1/2"IA.,PJSM with rig crew&production. Pump FIW down tubing&taking returns from the IA,initial rate 2 bpm,50 psi,no returns. Pressure increase at 65 bbls away,to 630 psi at 3 bpm. Pressure stabilized at 2475 psi,3 bpm, 150 bbls away no returns.Pumped 1200 bbls, FCP 2470 psi at 3 bpm with no returns.,Rig down circulating hoses from tree&blow down.,Remove Otis connection flange from tree. Install flange X 4-1/2 IF,2 jts 5"DP, FOSV,&XO to wireline entry sub. PT 300/3000 psi,good. Blow down lines.,Rig up Pollard E-line,arm guns,and rig up pump-in sub to mud manifold.,TIH with guns on E-line,perf tubing f/10,006-10008'MD.SIMOP offload 5" DP to top deck.,TOH with E-line,stand back wire line head,&rig down.,Line up&circulate down tubing,with returns from IA to production.Circulate at 6 bpm =144 psi,7 bpm=366 psi,8 bpm=2049 psi.Pumped 1494 bbls to see returns to surface.While pumping surface to surface,observe 3.5 bpm returns while pumping at 8 bpm. FCP 8 bpm,2000 psi,total pumped 3400 bbls.SIMOP build 80 bbls salt pill.,Pump and spot 80 bbl,sized salt pill outside the tubing.Shut down to observe pressure on tubing&IA at 0 psi.Open to atmosphere to observe well on a vacuum,both tubing& IA.,Remove flange X 4-1/2 IF,2 jts 5"DP, FOSV,&head pin from top of tree. Install BPV.,Nipple down tree.,M-28 wellhead pressures @ 24:00 hrs;9-5/8"X3-1/2"=84 psi, 13-3/8"X9-5/8"=310 psi, 16"X13-3/8"=260 psi,26"X16"=260 psi,31"X26"=144 psi. 4/21/2017 Finish nipple down of tree&rack back in the upper well bay.,Nipple up BOP's,install high pressure risers,set BOP's,bolt up kill&choke hoses.SIMOP clean mud pumps&assist with off load of mud product to dry storage room.,Nipple up GOP's,install all Koomey lines,both air boot flanges,&flow riser.SIMOP grease choke manifold&mud cross valves.,Mobilize&make up 5"test tools. Energize Koomey system& Function Check Blind Rams,Annular, HCR kill& choke valves.,Line up to test kelly hose and find test manifold plugged off.Trace down plug&clear.,Attempt to test kelly hose to 5000 psi. Hammer union at top of stand pipe leaking.Tighten&attempt to retest several times.,Begin testing BOP's,observe gray locks leaking on 2nd test.Tighten&retest to find choke HCR leaking from rear seal.,Blow down choke line&stack. Repair choke HCR rear seal.SIMOP Begin work on kelly hose leak.,M-28 wellhead pressures;9- 5/8"X3-1/2"=65 psi, 13-3/8"X9-518"=280 psi, 16"X13-3/8"=260 psi,26"X16"=260 psi,31"X26"=150 psi. 4/22/2017 Pressure Testing Blow Out Equipment On 5"D.P.Test 1 Through 2 Pressure Testing to 250psi Low&3,500psi High(Sundry#317-0881-Had a Fail/Pass at The Hubbeed Connection That Lands Out In The Upper Well Bay-Also a Fail/Pass on Choke Line HCR -Kelly Hose Leaking at Connection To Stand Pipe- Blow Down Stack to Work On Choke Side HCR-Remove Kelly Hose At Stand Pipe Extension-Repack Choke Side HCR Stem.,Cont Pressure Testing 13 5/8 5M BOP Equipment-on 5"-Note Witness Of BOP Test Waived By AOGCC Mr.Mike Quick.,Prep to Change Out Test Joints-Koomey Drawdown Test ), While Rigging for 3 1/2"Test.,Lay Out 5"Test Joint and Equipment-Pick Up 3 1/2"IBT Test Joint and Equipment-Clean Up Hammer Unions on Stand Pipe rt Z Extension.,Cont Pressure Testing 13 5/8 5M BOPE-Re Hang Kelly Hose.,Cont Pressure Testing on 3 1/2"-Completed Pressure Test Of BOP Equipment.,Lay ,�jj Down 3 1/2"Test Joint And Equipment-Had to Turn Kelly Hose to Get The Correct Loop For Running in Derrick-Pressure Test Kelly Hose to 5,000psi.,Pick (1,/I Up 5"Landing Joint with 4 1/2"IBT Crossover For Hanger Lift Threads-Engage Hanger Lift Threads-Make Up Top Drive-Start Circulation to Production Test Separator-Worked Rate Up To 7Bb1/Min-Caught Pressure(300ps)i With 55Bbl Pumped(Cal 6,300'of Tubing)-Increased Rate to 8Bbl/Min with 1,500psi- Fluid Returns to Test with an additional 220Bbl of Fluid Pumped(Cal 3,588 of Annular Fill).,Rig up Summit Equipment For Pulling ESP While Circulating Well- Going Downhole at 8bbl/Min Rate With 3 to 3.5Bbl/Min Returns to Test- Pump 92bb1 Sized Salt Pill and Displaced Same Out Side D.P. Flow check,well on a vac.,PJSM discussing hazards,mitigation's,& bare pipe shut in. BOLDS&pull hanger free w/155K. Pull hanger to rig floor,PU 175K. Filling the back side static loss rate at 36 bph.Stand back landing joint,lay down XO's&hanger.,TOH w/3-112"tubing&ESP f/10107'-9974'MD, PU 170K,feeding ESP/control line down to spoolers on the deck. Hang sheaves in the derrick&secure ESP/control line to spoolers.,TnH w/'3-119"tiihind R FRP f/9g74'-779q'm n pU 152K. Loss rate increasing to 126 bph.,M-28 wellhead pressures;13-3/8"X9-5/8"=300 psi, 16"X13-3/8"=260 psi,26"X16"=280 psi,31"X26"=150 psi. 4/23/2017 Cont Laying Down 3 1/2"9.2#Super Max ESP Completion F/7729 to 5160-Losses Ranging From 115 to 154 Bbl/Hr Loss Rate-Keeping Hole Full-PU at 5,160'=120K,S.O. 100K.,Change Out Spool For ESP Elect Wire-1hr Loss Rate 128Bbl.,Rig Service.,Cont Laying Down 3 1/2"9.2#Super Max ESP Completion F/5,160' to 175'-Losses 118 to 135 bbl/hr.,Clear&clean rig floor to lay down ESP pumps.Mobilize Summit tools to rig floor.Rig down Weatherford tongs.,Lay down ESP pump assembly per Summit.Total clamp count: 156-2'cannon clamps, 1 -4'cannon clamp, 14-wide pump clamps,& 10-narrow pump clamps.,Clear&clean rig floor of all completion tools,clamps&equipment.,Mobilize wear bushing&setting tool to rig floor.Set 12-1/2"ID wear bushing&run in 2 lock down screws.,Begin picking up BHA 1:8 1/2"Mill Tooth Bit,9 5/8 47#Csng Scraper, Bit Sub With Float,4 1/2 IF Flex Joint, Upper String Mill, 1 Jnt 5"HW, Bumper Sub,Jar,&18 Jnts 5"HW.,M-28 wellhead pressures; 13-3/8"X9-5/8"=295 psi, 16"X13-318"=260 psi,26"X16"=280 psi,31"X26"=150 psi. Losses for 24 hrs 2926 bbls. • • 4/24/2017 Continue picking up BHA 1:8 1/2"Mill Tooth Bit,9 5/8 47#Csng Scraper,Bit Sub With Float,4 1/2 IF Flex Joint,Upper String Mill,1 Jnt 5"HW, Bumper Sub,&Jar.,Single in the hole w/18 Jnts 5"HW.,Single in the hole w/5",19.5#,S-135 DP;f/626'-1730'MD, PU 115K,SO 112K.,Service rig.,Single in the hole WI 5",19.5#,S-135 DP;f/1730'-5760'MD,PU 185K,SO 160K.,Found birds nest&excessive wear on cable to skate backstop.Developed plan to pick up DP from catwalk using rig floor air hoist. PJSM with crew.,Single in the hole w/5",19.5#,S-135 DP;f/5760'-6660'MD, PU 225K,SO 165K.,Single in the hole w/5",19.5#,S-135 DP;f/6660'-9249'MD,PU 274K,SO 192K.,TOH f/9249'-8207 MD,PU 265K.,Mobilize,strap&tally 5"DP to single in the hole.,M-28 wellhead pressures; 13-318"X9-5/8"=280 psi,16"X13-3/8"=260 psi,26"X16"=320 psi,31"X26"=150 psi.Losses for 24 hrs 2374 bbls. 4/2017 Single in the hole w/5",19.5#,S-135 DP;f/8207'-9249'MD, PU 274K,SO 192K.,TOH N 9249'-5080'MD racking 5"DP in derrick.,Cut&slip 65'of drill line. J'' Inspect brake bands&linkage.,Service top drive,blocks,drawworks,&crown.,TON f/5080'-70'MD,racking back 5"DP&HWDP.,Lay down BHA 1,clear U ,.'1paequipment from rig floor.,Mobilize E-Line tools&lubricator to rig floor. Rig up F-I inn shy-.&_make un 9-5/8"cement retainer,TIH w/9-5/8"cement retainer tl�C on E-Linp Set too of retainer at 9098'MD,Perform logs&TOH.Circulate across the top of the hole,observe losses stop after retainer set.,Rig down E-Line v1/45 tools,sheave,&lubricator.,Mobilize cementing BHA to rig floor.Make up BHA 2,407'MD;Shift/stab-in tool,pup w/bowspring,XO 2-7/8"EUE X 3-1/2"EUE, (xp XO 3-1/2"EUE X 3-1/2"SM; 12-3-1/2"Tubing;XO 3-1/2"SM X 4-1/2"IF.,TIH f/407'-2777'MD w/cementing string on 5"DP.,M-28 wellhead pressures; 13- 3!8"X9-518"=320 psi,16"X13-318"=260 psi,26"X16"=325 psi,31"X26"=150 psi.Losses for 24 hrs 1581 bbls. 4/26/2017 TIH f/2777'-6623'MD w/cementing string on 5"DP..Repair hose leaking on Iron Roughneck.,TIH fl 6623'-7961'MD w/cementing string on 5"DP.,De- energize SCR&remove air conditioner from top of SCR house with crane.,TIH f/7961'-9029'MD w/cementing string on 5"DP.,Circulate string volume at 9029'MD, PU 252K,SO 185K.Record baseline circulating rates 2-8 bpm,50-420 psi.,TIH f/9029'-9102'MD,tag up on retainer @ 9102'MD,sting into retainer to measure spaceout for cementing.,Service rig,top drive,blocks&drawworks.,Rig up cementing equipment on rig floor,fluid pack lines,PT lines 600/4000 psi.Sting into retainer&attempt to establish baseline injection rate/psi with cement pump,pressure up not consistent with previous baseline.Swap ipack to rig pump&observe same pressure build up.Unsting from retainer&observe pressure bleed off.Wash down,stinging into retainer to see psi drop off& no returns to confirm success •. -'i '..- Ion rate with cement pump 2-6 bpm,45-450 psi,pumping 18 bbls fresh H2• I . Batch up&pump 164 bbls of 15.8 ppg,class G,plug blend cement at 2-3 bpm,75-125 psi.Pump 20..s o res - • . - - , psi.Swap to rig&displace cement wi''t 37 \t bbls of FIW;ICP 7-8 bpm=120-160 psi.,Caught pressure at 93 bbls away&reduce rate to 3.5 bpm=215 psi; 100 bbls away 3 bpm=400 psi;120 bbls away 2 bpm=1650 psi;FCP 1 bpm=2000 psi Shut down&unstina from retainer.TOH f/9102'-8610'MD, PU 262K,lana 5 bbl of cement on ton of rt tainnr While pumping cement pump pressure jacked up&down throughout job making pressure difficult to read&interfered with stroke counter accurately reading bbls pumped.,We were able to verify bbls pumped with H2O/cement ratio.Flow meter for H2O matched manual strap during the job.Calculations at completion of job verified correct bbls of cement pumped.HES cementers also had an issue with the water knife valve,controlling water to cement ratio.CIP @ 18:25 hrs.,Circulate surface to surface at 9 bpm,540 psi with nerf ball dropped to wipe cementing string.,PJSM,shut down SCR's,install new air conditioner with k crane on SCR house.,TOH f/8610'-4545'MD,PU 152K,SO 135K.,Service rig,top drive,drawworks,&iron roughneck.,TOH f/4545-407'MD.,Lay down BHA A2,cementing assembly.,Rig up&trouble shoot test equipment for casing test.,Test 9-518",47#, N-80 casing to cement retainer @ 9102'MD.Pumped 6 bbls at G5) 8 spm to 2700psi&shut in.Test charted for 30 minutes.Bled back 6 bbls.,M-28 wellhead pressures;13-3/8"X9-518"=320 psi,16"X13-318"=260 psi,26"X16"= 325 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls. 4/27/2017 Rig up E-line,make up&TIH w/7.71"cast iron bridge plug,set same at 8573'MD.TOH&rig down E-line.,Remove wear bushing.,Mobilize whipstock&BHA 3 to rig floor.Make up whipstock&orient w/MWD,RFO 194.,Shallow hole test MWD at 420 gpm,650 psi,good signal.,lnstall BHA mill assembly to Gen II whipstock.,TIH w/BHA#3 f/97'-8513'MD,PU 275K,SO 190K,fill pipe every 20 stands.,Stage up pumps to 550 gpm, 1500 psi, PU 275K,SO 190.Orient whipstock working turns with reciprocation to 53 degrees left.Tag top of CIBP at 8572'MD with 3K down weight.Observe anchor set wI 15K WOB, 175K.Pull 15K over to verify anchor set.Slack off to observe brass bolt shear w/30K WOB, 160K.Top of ramp at 8550'MD,bottom of ramp 8567'MD.,TOH f/8550'- 8300'MD,PU 275K,SO 185K.,Remove subs&handling equipment that are not needed from rig floor.Clear all rig floor drains&water test same.Work on rigging up pressure washer w/base oil to shakers&rig floor.Test spare lower kelly valve.Clean out SCR house.Test vac system for rig.Flush return line for# 2 hopper so line can be replaced by welder.,M-28 wellhead pressures;13-3/8"X9-5/8"=360 psi, 16"X13-3/8"=260 psi,26"X16"=330 psi,31"X26"=140 psi. Losses for 24 hrs 0 bbls. 4/28/2017 Re-route steam condensate lines to drain on upper deck. Rig up Geospan unit to mud manifold&bleed off line to pits.Begin removal of#2 hopper discharge line.Repair centrifuge feed pump.Continue cleaning rig floor.Continue research&troubleshoot air conditioner install.,TIH&space out ft 8300'-8549'MD,PU 275,SO 180,above whipstock for E-line Gyro logging run.,Trouble shoot leak between trip tanks, continue removal of#2 hopper discharge line,continue work on centrifuge feed pump,rig up&test vac system for rig floor.,Log 9-5/8"casing ft 8475'to surface.Test gas detection system with AOGCC Rep Guy Cook. Continue removal of#2 hopper discharge line,continue work on centrifuge feed pump&punch list for drilling w/OBM.,Rig down E-line&lay down Gyro tools. TOH ft 8549'-8394'MD, PU 275K,SO 180K.,Install new section of#2 hopper discharge line.Transfer base OBM to upright tanks from pits.Clean drums from mixing mud.Test Geospan unit 250/3500 psi,good.,Continue cleaning around rig.Seal up cracks&holes around rig floor.Finish 2nd batch of 247 bbls of OBM. Hook up lines&transfer OBM from pits to uprights on top deck.Finish installation of#2 hopper discharge line.Grease choke valves&service rig.,M-28 wellhead pressures;13-318"X9-518"=380 psi,16"X13-3/8"=260 psi,26"X16"=325 psi,31"X26"=140 psi.Losses for 24 hrs 0 bbls. 4/29/2017 Rig up to install landing extention on east side rig floor stairway.Torque up flange on#2 hopper discharge line.Make manifolds for LVT uprights. Install skate camera system.Continue building 230 bbls of OBM.,Continue install of landing extention on east side rig floor stairway. Flood test rig floor&seal up leaks to prevent OBM from leaking to lower levels.Change out cable for skate backstop. Lay out felt around rig.,Rig up to test BOP's;mobilize test tools to rig floor. Pull 2 singles PU 275K ISO 180K,install test plug,hang off string,&make up test equipment.Fluid pack all lines&shell test.,Test BOP's with 5"test joint.All tests to 250/3500 psi for 5 minutes each,recorded on chart.#1 Annular,CMV 1,2,3,12,13,14,dart valve, demco kill line valve,upper IBOP;#2 Upper pipe rams, FOSV,CMV's 4,5,6,kill line HCR,lower IBOP;#3 CMV 7,8,9,Manual Kill;#4 CMV's 10,11;#5 Super-choke&manual choke bleed down f/1500 psi; #6 Choke HCR;#7 Manual choke line valve;#8 Lower rams;#9 Blind rams;,Accumulator System:Initial system pressure 3000 psi; Pressure After Closure 1400 psi;Attained 200 psi in 35 seconds;Attained Full Pressure in 197 seconds;8 Nitrogen Bottles Averaged Pressure 2500 psi.Tested pit level alarms&flow indicator.Witness waived by AOGCC Rep.Jim Regg.,Lay down test equipment,blow down all lines,&pull test plug to rig floor.TIH w/2 joints to 8395'MD PU275K,SO 180K.,Continue pre-OBM punch list.,M-28 wellhead pressures;13-318"X9-5/8"=380 psi, 16"X13-3t8"=260 psi,26"X16"=320 psi,31"X26"=145 psi.Losses for 24 hrs 0 bbls. 4/30/2017 Change out expanded metal cover over SCR's,change out isolation valve between trip tanks,plumb in centrifuge feed line,assist crane crew with jore flats for iso-tanks,install 12"dump valve below shakers.weight up OBM f/7.6-8.9 ppg.,Continue work on 12"dump line,modify rig floor mats for better traction/fit, clean SCR house roof,install softeners for cement hose&HP pressure mud line,lay out hoses for displacement,&start hooking up flow box hose.,Continue welding/install 12"dump line,install 10"drain line in lower BOP deck,&continue pre-OBM checklist.,Trouble shoot drawworks electrical.SIMOPS:PJSM for displacement from FIW to 8.9 ppg OBM.,M-28 wellhead pressures; 13-318"X9-5/8"=400 psi, 16"X13-3/8"=260 psi,26"X16"=325 psi,31"X26"=140 psi. Losses for 24 hrs 0 bbls. 5/1/2017 Trouble shoot drawworks SCR's,traction motors will not go into assignment.SIMOPS:service air tuggers,Canrig tech reroute cables to drillers console,install air slips foot pedal actuator,change out screens on shakers,&Canrig mudlogger rig up logging system.,Trouble shoot drawworks SCR's;diagnose traction motor air sensor switch&resolve.,PJSM,TIH f/8397'-8545'MD,PU 275K,SO 185K, ROT 225K.Displace well from FIW to 8.9 ppg OBM,pump 23 bbls spacer&580bbls of OBM at 500 gpm, ICP 1400 psi, FCP 1660 psi,40 rpm intial Tq 15K/final Tq 9K, PU 245K,SO 205K,ROT 223K.,TOH f/8545-8492' MD,racking back 1 stand. Pick up 1 single 5"DP,to space out for milling,TIH f/8492'-8519'MD,PU 245K,SO 205K.,Transfer FIW from pits to production, clean&pump out trip tanks of spacer/interface to dirty iso-tank,clean pits to tranfer OBM from uprights for drilling ops.,Service rig equipment grease drawworks.SIMOPS ship FIW to production.,Clean pits of FIW debris for OBM&ship FIW to production.,Transfer OBM from uprights to mud pits.,TIH to 8550'MD&obtain parameters PU 245K,SO 205K,ROT 220K,500 gpm, 1680 psi,80 rpm,Tq 9K.Fill lines&shaker pits.Obtain at 8549'MD,7053'TVD, MW 8.9 PPG SPR#1 @ 30=160psi,@ 40=200psi;#2 @ 30=150psi,@40=200psi.,Mill window f/8549'-8554'MD,PU 245K,SO 205K ROT 220K,500 gpm, 1670 psi,100 rpm,Tq 11-15K,FO 73%,catching metal swarf at shakers.,M-28 wellhead pressures; 13-3/8"X9-5/8"=400 psi, 16"X13-3/8"=260 psi,26"X16"= 340 psi,31"X26"=145 psi.Losses for 24 hrs 0 bbls. t) IIIIIIIIMMMIMMIMIEIIIIIII.MINMIIIIITIMIMMMIEIII=MININMMIIIIIII.1 vOF TA ofP I//7:. THE STATE Alaska Oil and Gas F "t-s Of A A 1�1C� Conservation Commission .:,.�, - 1 l�l 1�JL`tel 1 Sf£= !� 333 West Seventh Avenue ''" iii c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ,., �� Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Managerr -, Hilcorp Alaska, LLC % 4t MAR 2 0 all' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock, Middle Kenai G, West Foreland, and Undefined Oil Pools, TBU M-28 Permit to Drill Number: 190-019 Sundry Number: 317-088 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. Sincerely, ••=c),4' Daniel T. Seamount, Jr. Commissioner r-cl DATED this Z3 day of February, 2017. RBDMS L`'Fcv L 7 2u17 • 0R E C EIVE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 1 2017 APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations El Fracture Stimulate ❑ Repa'r Well ❑ Operations shutdown El Suspend 0 Perforate 0 Other Stimulate El Pull Tubing ❑ Change Approved Program Plug for Redrill 2 • 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 LI . 190-019 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic CI Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20414-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No E / Trading Bay Unit M-28 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 ' McArthur River Field/Hemlock Oil,Middle Kenai G Oil,West Foreland Oil,Undefined 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): 13,000 10,797 • 11,665 ` 9,533 - 2,753 psi N/A ' 11,655 Casing Length Size MD TVD Burst Collapse Conductor 990' 26" 990' 989' Surface 1,445' 16" 1,445' 1,442' 2,630 psi 1,020 psi Intermediate 4,590' 13-3/8" 4,590' 4,031' 3,090 psi 1,540 psi Production 497' 10-3/4" 497' 496' 5,860 psi 3,220 psi Production 10,902' 9-5/8" 11,399' 9,311' 6,870 psi 4,750 psi Liner 1,255' 7" 12,448' 10,261' 8,160 psi 7,020 psi Liner 632' 5" 13,000' 10,797' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,632-12,900 ' 8.692-10,700 3-1/2" 9.2#/L-80 10,044 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See Schematic See Schematic / 12.Attachments: Proposal Summary 2 Wellbore schematic 2 113.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development D , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/7/2017 OIL El WINJ El WDSPL ❑ Suspended El • 16.Verbal Approval: Date: GAS ❑ WAG Cl GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El 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 dmarlowenhilcorp.com Printed Name Stan W.Golis Title Operations Manager r Signature O'c.,+ - ( Phone (907)777 8356 Date 2 I Z•c' ( �o t 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test 127 Mechanical Integrity Test ElLocation Clearance I=IZ-IL.;IR Other: A 3 5 0 f 5 ` #6(...7.1e /. f - A t+. h l i"-3p ik.�.e,,.-, t rt /2-1?-1- 2 �� . //L Ct Post Initial Injection MIT Req'd? Yes El No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / 0 — 1•-1 0 RBDNIS L t' FLU t 7 2317 APPROVED BY �/ / Approved by: COMMISSIONER THE COMMISSION Date: C.r-f 2. `)7 gr"U q��/' RH4iAs6lid JaFm 10- 3 Revise2015 for 2 months from the date of approval. Attachments in Duplicate • Well Work Prognosis Well: M-28 Hilcnrp Alaska,LLC Date: 02/20/2017 Well Name: M-28 API Number: 50-733-20414-00 Current Status: ESP Producer Leg: B-1 Estimated Start Date: 03/07/17 Rig: Steelhead Rig#51 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 190-019 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: 3,622 psi @ 8,692'ND 0.417 lbs/ft(8.01 ppg)based on ESP Gauge Maximum Expected BHP: 3,622 psi @ 8,692'ND 0.417 lbs/ft(8.01 ppg)based on ESP Gauge Maximum Potential Surface Pressure: 2,753 psi Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) **Note this is a No-Flow Well(08/08/2014) Brief Well Summary M-28 is a G / Hemlock/West Foreland Producer completed with an ESP July 2014. This well is in close proximity to several other wells and is competing with them for reservgs. This workover will plug back the existing completion and prepare the well to sidetria into the West Foreland Sands with a fall back option of adding the G and Hemlock again at a later date. ✓ Last Casing Test: 07/26/14—tested at 9,147'to 1,500 psi for 30 minutes on chart Procedure: 1. MIRU Rig. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+/-10,020'and punch tubing. Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 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'j. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. RIH with bit and scraper to±9,150', circulate clean. POOH. r,`< 7. RIH with cement retainer and set at±9,100'."- (Z :>'' a. Due to known casing leak at 9,147',We request a variance to 20AAC25.112(c)(1)to set the retainer>500'above top perforation. 8. RIH and sting into cement retainer. 9. RU cementing equipment and establish an injection rate with FIW. 014— a. If able to pump into well-Mix and pump±155 barrels cement to isolate existing completion. Un-sting from retainer and circulate hole clean. /l%,.1.=4,7 AC)4 L. t b. If unable to pump into well unsting from retainer and spot a >100' balanced plug if "'"" bbls on top of the retainer. 4 c. POOH w/workstring 10. Pressure Test casing to 2.500 osig for 30 minutes and chart. '17 11. RU e-line and RIH w/CIBP to±8,500', ±5' above casing connection. POOH 12. PU whipstock and mills and RIH to CIBP. 13. Orient and set whipstock in 9-5/8". 14. Swap well to OBM drilling fluid. ,1 concur. riff ,,,,e!/ i'l c v/rei f f fa .-c/'sd y ,(O lOrr v' R �,.q t�� C,r over Q S� . / �i►d' /�l/,f A.&/' ,4- Fede '/f .4(od 4 RA- Tom 1.4e" d f(CC)1i' j *4,3 fO'1/ i vi' :!e fi'dot 07/7 Well Work Prognosis Well: M-28 Hilrurp Alaska,LLC Date: 02/20/2017 15. Mill 8-1/2" window and 20' of new formation. POOH and LD mills. ***Remaining Procedure to be included on the Permit to Drill Sundry for the sidetrack*** General sequence of operations pertaining to drilling procedure: (informational only) 1. PU directional BHA and TIH to window. 2. Drill 8-1/2" hole to West Forelands sands. 3. Run and cement 7" or 7-5/8" casing. 4. Swap to completion sundry. 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 Steelhead Platform SCHEMATIC well Last Compomp leted 07/31/2014 Hilcorp Alaska,LLC RKB-to TBG Head:71.4' J] L' 1 .1.1 LL CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' Bleak EL 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 9,14'-9,15 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: Squeeze Perfs 3-1/2" 9.2 L-80 Supermax 2.992 Surf 10,044' 9,965-9,977' I2 JEWELRY DETAIL int3 No Depth OD ID Item 1111. lir 4 1 71.80' Tubing Hanger 5 2 10,044' 5.130 Bolt On Head Casing Leak 6v 10466'DIL 3 10,045' 5.130 Summit 513 Pump(x3) 7 $ O Squeezed with 4 10,104' 5.130 Summit BPBSL Upper/Lower Tandem 100 sx cement 5 10,121' 5.625 Summit 562 Series KMP1 340 HP Motor 6 10,185' 5.620 GLM Centralizer Anode 8 7 10,440 8.460 6.000 Baker 9-5/8"SC-1L 8 7.00 6.184 Isolation liner 4 jts and pup.7"29 lb/ft L-80 Butt casing with =Squeeze Perfs Baker Anchor Assy KBH-22(75 x 60) 9 ® 10,620'-10,623' 9 10,628' 8.437 6.000 Baker Model FA permanent packer(190FA75)with 6'tieback 10 10,947' 8.25 6.312 Baker ZXP liner packer 7"x 9-5/8" G-Zone 11 7.00 6.184 Isolation Liner 5 jts and pup.7"29 lb/ft Butt L-80 casing = 12 11,198' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE I 13 12,351' 5.875 4.00 Baker FB-1 Packer(Size 85-40) 10 ® .f ® 14 12,357' 5.156 3.813 Otis X landing nipple 15 12,369' 5.093 4.438 TIW LG-6 Tie-back Seals with IA muleshoe "Bad"casing at 11 11035' 12® 8= Fish/Fill Information: L A. 11931'—14.37'Fish(5-7/8"junk mill,bit sub,6-1/16"string mill,x-o) (September 03,1999) Hemlock. B. 11665'—Cleaned out to 11665'w/6"bit on 7/24/14 "0 W.Foreland ,-.4‘."6,2.- t4 . . 13 �� Perforation Data T'. l , ,-fit (See Next Page) :4,,-„,;,;.+ r Jurassic _ ` (cr ) =�',',i STRESSFRAC 'j6I11�J- ,f 7 S7 . Tool @12,880' sG 5- - x .'.<. ,irl t U TD=13,000 PBTD=12,952 MAX HOLE ANGLE=41.8° Updated by:JLL 08/26/14 • • II Steelhead Platform SCHEMATIC well Last Compomp leted 07/31/2014 Hilcorp Alaska,LLC PERFORATION DATA Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Date G-1 10,632' 10,658' 8,692' 8,712' 12/5/1997 G-2 10,684' 10,710' 8,732' 8'752' 12/5/1997 G-2 10,720' 10,774' 8,760' 8,803' 12/5/1997 G-3 10,792' 10,822' 8,817' 8,841' 12/5/1997 G-4 10,840' 10,850' 8,855' 8,863' 11/9/1993 G-4 10,858' 10,888' 8,869' 8,893' 11/9/1993 G-5 10,964' 10,994' 8,954' 8,978' 11/7/1993 G-5 11,012' 11,037' 8,993' 9,013' 11/7/1993 G-1 10,638' 10,658' 8,696' 8,712' 9/13/1999 G-2 10,690' 10,705' 8,737' 8,749' 9/13/1999 G-2 10,720' 10,740' 8,760' 8,776' 9/13/1999 G-3 10,790' 10,820' 8,815' 8,839' 9/13/1999 G-4 10,840' 10,850' 8,855' 8,863' 9/13/1999 6-4 10,858' 10,888' 8,869' 8,893' 9/13/1999 G-5 10,965' 10,990' 8,955' 8,975' 9/13/1999 HK-1 11,206' 11,246' 9,149' 9,182' 9/13/1999 HK-1 11,207' 11,217' 9,150' 9,159' 7/27/2014 HK-1 11,226' 11,232' 9,166' 9,171' 7/27/2014 HK-2 11,266' 11,276' 9,199' 9,208' 9/13/1999 HK-2 11,263' 11,295' 9,197' 9,223' 7/27/2014 HK-2 11,302' 11,316' 9,229' 9,241' 7/27/2014 HK-2 11,325' 11,341' 9,248' 9,262' 7/27/2014 HK-3 11,378' 11,412' 9,293' 9,322' 7/27/2014 HK-3 11,430' 11,470' 9,337' 9,371' 9/13/1999 HK-3 11,436' 11,463' 9,342' 9,365' 7/27/2014 HK-4 11,480' 11,500' 9,380' 9,397' 9/13/1999 HK-4 11,481' 11,494' 9,381' 9,365' 7/27/2014 HK-4 11,510' 11,530' 9,406' 9,423' 9/13/1999 HK-4 11,508' 11,524' 9,404' 9,418' 7/27/2014 HK-4 11,540' 11,550' 9,432' 9,440' 9/13/1999 HK-4 11,538' 11,543' 9,430' 9,434' 7/27/2014 HK-4 11,563' 11,580' 9,452' 9,467' 7/27/2014 HK-5 11,570' 11,590' 9,548' 9,475' 9/13/1999 HK-5 11,596' 11,614' 9,481' 9,496' 7/27/2014 HK-5 11,628' 11,632' 9,509' 9,513' 7/27/2014 HK-6 11,722' 11,742' 9,592' 9,610' 9/13/1999 HK-7 11,764' 11,788' 9,629' 9,651' 9/13/1999 WF-0 11,815' 11,831' 9,675' 9,689' 8/14/1992 WF-0 11,836' 11,841' 9,693' 9,698' 8/14/1992 WF-0 11,848' 11,858' 9,704' 9,713' 8/14/1992 WF-0 11,865' 11,875' 9,720' 9,729' 8/14/1992 WF-1 11,912' 11,922' 9,763' 9,772' 8/14/1992 WF-1 11,930 11,950' 9,779' 9,797' 8/14/1992 WF-2 11,966' 11,976' 9,812' 9,821' 8/14/1992 Jurassic 12,655' 12,675' 10,461' 10,480' 1/2/1992 Jurassic 12,675' 12,748' 10,480' 10,551' 1/2/1992 Jurassic 12,748' 12,808' 10,551' 10,609' 1/2/1992 Jurassic 12,810' 12,900' 10,611' 10,700' 1/2/1992 Updated by:JLL 08/26/14 0 • II Steelhead Platform PROPOSED Well M 28 PTD: 190-019 API: 50-733-20414-00 Hilcorp Alaska,LLC Completed: FUTURE RKB-to TBG Head:71.4' CASING TUBING DETAIL SIZE WT GRADE AND CONN ID TOP BTM. .1 Li. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13 3/8" 61/68 K-55 Buttress 12.415" Surf 4,590' A 51 10-3/4" 51/55 N-80 Buttress 9.604" Surf 497' este@ leak -5/8" 47 N-80 Buttress 8.681" 497' 11,399' tar-e,isr 7" 29 N 80 Buttress 6.184" 11,193' 12,448' A 5" 18 N-80 FL4S 4.276" 12,368' 13,000 Tubing: i CIBP ±8,500' 5(( -ement Retainer±9,100 Jewelry Detail 2No Depth Depth OD ID Item a,, (MD) (ND) ieeze Perfs x *.i.v, 1 ±8,500' ±7,017' CIBP(Set for whip stock) 35'-9,977 „, �p4 t;� 1 2 ±9,100' ±7,477' Cement Retainer r0 ingL -k s`` �' 1 'DIL 3 '�,,rr ' ' ^}2 ?3«. S1 ueersx. ed h 3 10,440' 8,541' 8.46 6 Baker 9-5/8"SC-1L �k4 . ay Isolation liner 4 jts and pup.7"29 4 • Oe0. 4 7 6.184 lb/ft L-80 Butt casing with Baker • ,, + Anchor Assy KBH-22(75 x 60) ` le � 5 10,628' 8,689' 8.437 6 Baker Model FA permanent packer lis , ueeze Peds (190FA75)with 6'tieback '� (a a �" 7 0,620'-10,623' 6 10,947' 8,941' 8.25 6.312 Baker ZXP liner packer 7"x 9-5/8" 5 >,,,,4 `_' H 7 7 6.184 Isolation Liner 5 jts and pup.7"29 ,e '. ,., GZone lb/ft Butt L-80 casing 8 11,198' 9,144' 7 6.184 Baker Muleshoe Assy.into TIW TBE �*'f ( .. 9 12,351' 10,170' 5.875 4 Baker FB-1 Packer(Size 85-40) K..1%, � ,�k�� ''" 10 12,357 10,175' 5.156 3.813 Otis X landing nipple �, B casing at 11 12,369' 10,187' 5.093 4.438 TIW LG-6 Tie-back Seals with 7 ,rrl„'� ,a,, 11d35, muleshoe 4,,,r . ,, : 8 ) . (0, ,� k 4<'; Si.,,,;, l 4_+ Hemlock. " ' .gay, -�t" µ ;``rv ,. f Fish/Fill Information: 1,`t „,,'r : W.Foreland A. 11931'-14.37'Fish(5-7/8"junk mill,bit sub,6-1/16"string mill,x-o) (September 03,1999) . b''� B. 11665'-Cleaned out to 11665'w/6"bit on 7/24/14 - '' ' ,, ,:',1 , '6,7": , , 9 t,1 - t,.'; ;,,,„ Jurassic Perforation Data "f (See Next Page) I ' STRESSFRAC Tool @12,880' 4 TD=13,000 PBTD=12,952 MAX HOLE ANGLE=41.8° Updated by:1LL 01/30/17 • • Steelhead Platform PROPOSED well M-28 Last Completed: FUTURE llilcorp Alaska,LLC PERFORATION DATA Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Date G-1 10,632' 10,658' 8,692' 8,712' 12/5/1997 G-2 10,684' 10,710' 8,732' 8'752' 12/5/1997 G-2 10,720' 10,774' 8,760' 8,803' 12/5/1997 G-3 10,792' 10,822' 8,817' 8,841' 12/5/1997 G-4 10,840' 10,850' 8,855' 8,863' 11/9/1993 G-4 10,858' 10,888' 8,869' 8,893' 11/9/1993 G-5 10,964' 10,994' 8,954' 8,978' 11/7/1993 G-5 11,012' 11,037' 8,993' 9,013' 11/7/1993 G-1 10,638' 10,658' 8,696' 8,712' 9/13/1999 G-2 10,690' 10,705' 8,737' 8,749' 9/13/1999 G-2 10,720' 10,740' 8,760' 8,776' 9/13/1999 G-3 10,790' 10,820' 8,815' 8,839' 9/13/1999 G-4 10,840' 10,850' 8,855' 8,863' 9/13/1999 G-4 10,858' 10,888' 8,869' 8,893' 9/13/1999 G-5 10,965' 10,990' 8,955' 8,975' 9/13/1999 HK-1 11,206' 11,246' 9,149' 9,182' 9/13/1999 HK-1 11,207' 11,217' 9,150' 9,159' 7/27/2014 HK-1 11,226' 11,232' 9,166' 9,171' 7/27/2014 HK-2 11,266' 11,276' 9,199' 9,208' 9/13/1999 HK-2 11,263' 11,295' 9,197' 9,223' 7/27/2014 HK-2 11,302' 11,316' 9,229' 9,241' 7/27/2014 HK-2 11,325' 11,341' 9,248' 9,262' 7/27/2014 HK-3 11,378' 11,412' 9,293' 9,322' 7/27/2014 HK-3 11,430' 11,470' 9,337' 9,371' 9/13/1999 HK-3 11,436' 11,463' 9,342' 9,365' 7/27/2014 HK-4 11,480' 11,500' 9,380' 9,397' 9/13/1999 HK-4 11,481' 11,494' 9,381' 9,365' 7/27/2014 HK-4 11,510' 11,530' 9,406' 9,423' 9/13/1999 HK-4 11,508' 11,524' 9,404' 9,418' 7/27/2014 HK-4 11,540' 11,550' 9,432' 9,440' 9/13/1999 HK-4 11,538' 11,543' 9,430' 9,434' 7/27/2014 HK-4 11,563' 11,580' 9,452' 9,467' 7/27/2014 HK-5 11,570' 11,590' 9,548' 9,475' 9/13/1999 HK-5 11,596' 11,614' 9,481' 9,496' 7/27/2014 HK-5 11,628' 11,632' 9,509' 9,513' 7/27/2014 HK-6 11,722' 11,742' 9,592' 9,610' 9/13/1999 HK-7 11,764' 11,788' 9,629' 9,651' 9/13/1999 WF-0 11,815' 11,831' 9,675' 9,689' 8/14/1992 WF-0 11,836' 11,841' 9,693' 9,698' 8/14/1992 WF-0 11,848' 11,858' 9,704' 9,713' 8/14/1992 WF-0 11,865' 11,875' 9,720' 9,729' 8/14/1992 WF-1 11,912' 11,922' 9,763' 9,772' 8/14/1992 WF-1 11,930' 11,950' 9,779' 9,797' 8/14/1992 WF-2 11,966' 11,976' 9,812' 9,821' 8/14/1992 Jurassic 12,655' 12,675' 10,461' 10,480' 1/2/1992 Jurassic 12,675' 12,748' 10,480' 10,551' 1/2/1992 Jurassic 12,748' 12,808' 10,551' 10,609' 1/2/1992 Jurassic 12,810' 12,900' 10,611' 10,700' 1/2/1992 Updated by:JLL 01/30/17 • • Steelhead Platform M-28 Current 07/11/2014 Hik'nrp:Alaska,LI I Steelhead Platform Tubing hanger,McEvoySL- M-28 EP-ESP,13 5/8 X 4%IBT lift 26 X16 X 133/8 X103/4 X and scup,w/4"Type H BPV 41/2 profile,2-3/8 continuous control lines BHTA,FMC,8-11-A0, 4 1/16 5M FE MA. a 3 's 'PP Valve,Swab,FMC-120, s, 41/165M FE,HWO,DD r' (1b // •/au / 5 .k .. .e. a ..i Valve,upper master, O el". WKM-M,SSV,41/165M FE,w/18"Omni operator,EE � Valve,wing,FMC-120, 41/165M FE,HWO,DD el 2 Valve,Master,FMC-120, • 41/16SKI FE,HWO,DD IO r 1.1" 1M1 jEl Tubing head,McEvoy SL-P,135/85M 1 "[ 111(t:FEtop%16%SM FE bottom,w/2-21/165M 550013o_ : tr jai r c I • Tubing head,FMC-TC-60,spec for r EN, uniheod,16%5M FE top X 16%5M Odd bottom,w/2-21/16 5M SSO el ii _ 4 •H. Valve,FMC-120, Unihead,FMC Type 2,16%5M 21/165M FE,HWO,AA FE top X 21%2M FMC speedlock bottom,w/4-2 1/16 SM SSO III I ' p !I .* 1 E_1' . . _,1 ; Adapter spool,FMC-A-S-S 30"MSS � aIIII I ' " atdd bottom X21%2M FMC p speedlock top,w/2-2"LPO IF• Starting head,FMC,30"MSS III 0 FE X 26"butt weld J 26" —16" 13 3/8" 9 5/8" 41/2 • Steelhead Platform 13 5/8 5M BOP (Oil Leg) 01/30/2017 IIilrorla il:ala. Rig floor Bottom of drip pan all Ail 6.75' 22"X16"for air boot sleeve, 19'in length 10.92' 26.23' Moon pool deck to rig floor it.111111 Ill Ill • 4.54' ' Hydril • GK 135/8-5000 III ill 111111111U Ill Ill 111 Ill 111 06u — 4.67' • 111111111 111111 Top of Moonpool Moonpool deck top@ 55.95' deck 55.38' la 9.60' !1 ulli! ! I! ! Total BOP assembly I h1j1.1�t,1L11UK: {r¢.i®.. 2.26' • 111 I!I i!I 111 111 2.83' Oil III 111111111 1.25' III,.Ill Ill " — –_ 3.86'flange above rig su b grating Rig sub grating Upper Wellhead Roo to Rig Sub Grating 23.47' I 5.08'clamp above floor Upper wellhead room floor Wellhead floor to Upper Wellhead Roo 22.88' itl ii1 Top of wellhead • 0 I -----(1.1asne WO 1-.A .r U 01 U D4 U0 ii Lu H Y v n 8 co 0 0x w v D4 D4 D4 Qw > o U aN M E O 8 LI- U Z#N W!dial_ U U '� -J W rrI-0n 6#�iNV1(112:11V Q 2U LCL CC G CC Ct I— J< F_0��\NE a a v _o m m 3 _ ii ii ii Q a.W W TIIIIII iii LIJ Cl. II 1=11111101211011e1 Iff 1; ill W + W O n = IJ W = i. U U)/^' U m � _ F �./J v J w Lc.L w G _, m D CL O U o W D 0 U N 1 0 • • 14 Steelhead Rig#51 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Steelhead Rig# 51 WO Program —Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Production Vessel 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) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static Monitoring for any pressure Build Up Or if Well Is Still On A Strong Vacuum ( I do not think that We Often Shoot Fluid Levels) Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV, ND Tree 2) Clean/Inspect/And Confirm By Screwing Into Lift Threads(Counting Turns) Remove Sub—Check all Lock Down Pins to Ensure they Will Back Out Far Enough To Clear Hanger—Plug Penetrations Through Hanger—Put a Sealing Cap On Penetrator—Leave BPV Installed & If Needed Install Adaptor to Test Joint, Might Be Using a Left Hand Blank Ported Sub or a Combo Tool Of Various Types NU BOP. 3) MU landing joint With On/Off Tool Adaptor. 4) Set slips, mark same. Test per standard Steelhead Rig#51 Test Procedure. 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. If unsuccessful, establish static fluid level. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV,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) MU Left Hand Blanking Plug d) Plug penetrations in hanger. For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) 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), Mr.Guy Schwartz(AOGCC-guy.schwartz@alaska.gov)and Mr. • • Steelhead Rig#51 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 Jim Regg(AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.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.) 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 /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) 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. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Pull Wear Bushing, Make up Test Plug and Test Joint—Land Same Measuring in the hole getting a Good Mark when Landed . 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) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after Isolation Plug is Set) 1) Make up Test Joint as per diagram. Insure all connections above test plug are torque. 2) Pull Wear Bushing and install Test Plug 3) Make up Side-Entry Sub, (2)TIW valves and IBOP to top of Test Jt. 4) Make up Test Hose#1 to Side-Entry Sub and Test Hose#2 to Top Drive Test Sub. 5) Verify Annulus valve is open and monitored. 6) Fill BOP and Choke Manifold with water. Purge air from system through Choke manifold top valve and IBOP. • • Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 7) Close Annular and set closing pressure to 800 psi. (pressure can be increased as necessary to seal element) Perform full body BOP test to check integrity of system. Note: When testing, pressure up with pump to desired pressure,close MP1 and/or MP2 to trap pressure and read same with chart recorder. 8) Referencing the attached schematics test BOP as per Permit and Regulations as follows. a) Close W1 (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) Open W1. 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 Flow Diagram) d) Test#1-Annular, IBOP, Upper TD Valve, Kill Line Demco,Cl, C2,C3,C12, C13,C14. e) Test#2—Test VBRs,Top TIW, Lower TD valve, HCR2,C4,C5, C6. f) Test#3—Test VBRs,W2,C7,C8,C9 g) Test#4.—Test Lower Pipe Rams, Bottom TIW. h) 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 2"d set of pipe rams if installed (e.g.dual pipe rams). 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. 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. j) Back out Test joint and pull to rig floor. Connect test hose to C13. Pressure up on Manual and Hydraulic Chokes to 1,000 psi. Function Chokes to bleed pressure and verify operation. k) Test#5. —Test Blinds and C10,C11. I) Make up 2nd Test Joint if running two string sizes m) RIH with 2nd Test Joint and test plug. Make up Side-Entry Sub, (1)TIW valve and IBOP to Test Joint.Connect#1 Test Hose to Side-Entry Sub and#2 Test Hose to suspended TIW w/test sub. • Steelhead Rig#51 BOP Test Procedure Hilcorp Alaska,LLC c Attachment#1 Purge air from system. (always verify lengths needed when compared to RKB and add pups if necessary) n) Test#6-Test Annular, IBOP, suspended TIW and HCR1. o) Test#7-Test VBRs, Upper TIW and Manual Choke. p) Rig down test equipment. Blow down lines. Close Annulus valve. Pull test plug. Install Wear Bushing. Rig down,or stand back Test Stand. q) Back out test joint& pull,close blinds,close valves C7,C8,C9,open HCR1, and W1 r) Open all rams and annular and close HCR2 to place BOPE back into operating position for well work. s) 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. Document both the rolling test and the follow up tests. • • a - � / > � 2 2 & Toc 2E moo © � / 2 � 6 § ) « E E - . E 01 CC 2 •717- = § X 0. » -o \ / $ 2 < \ �. > -0 x2� C 0/ a g7 § \ CO -0o a R ■ .4 ■ 2 iv e $ c 3 .Z O O E� 2W 3 as � . . L. 9 o Q � � 7 a) 2 e U 2 eL O a . 03> 14. 2 Ek a) » § Clii = -a ..ccQ Q Z -2 (9 ■ o13. k ‹ 11) 0 E § © 2 0 2 0ƒ a .* o / ie a os al ( c-0f ® E Cl) k0 . C w k / A 2 as / AC)Q § a. Xa. E t . E 0 Q $ 9 R a ■ g k c a_ $ a ID 0 2 7 2 ss v .. E. v 0 a) •i••4 .0 c >.O 0 O. C. ZZ 0 k2a) ¢ 0 • • 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 Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill"box, they 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, they 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, they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA A c L F'.„; V _... • ALA ,OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS ' `` 1.Operations Abandon❑ Repair Well 0 Plug Perforations ❑ Perforate❑ Other❑ �`" ' Performed: Alter Casing 0 Pull Tubing❑ Stimulate-Frac 0 Waiver❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other Q Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory❑ 190-019 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service 0 6.API Number: Anchorage,AK 99503 50-733-20414-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 • Trading Bay Unit M-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kenai McArthur River Field/Hemlock Oil,Middle Kenai G Oil,West Foreland Oil,Undefines Oil Pools 11.Present Well Condition Summary: Total Depth measured 13,000 feet Plugs measured feet true vertical 10,797 feet Junk measured 11,655 feet Effective Depth measured 11,665 feet Packer measured See Schematic feet true vertical 9,533 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 989' Conductor 989' 16" 1,445' 1,442' 2,630 psi 1,020 psi Surface 4,590' 13-3/8" 4,590' 4,031' 3,090 psi 1,540 psi Intermediate 497' 10-3/4" 497' 496' 5,860 psi 3,220 psi Production 10,902' 9-5/8" 11,399' 9,311' 6,870 psi 4,750 psi Production 1,255' 7" 12,448' 10,261' 8,160 psi 7,020 psi Liner 632' 5" 13,000' 10,797' 10,140 psi 10,490 psi 2 Perforation depth Measured depth See Schematic feet SCANNED MAY7 2014 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#L-80 10,351'(MD) 8,471'(ND) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): 1 Treated tubulars to 10,351',perforations from 10,632'to 11,788' RBDM MAY § 201 Treatment descriptions including volumes used and final pressure: Pumped 55 gallons Baker Petrolite WAW-5206(Mutual Solvent),330 gallon Xylene preflush,4500 gallon 15%HCL Acid,displaced with 100 bbls FIW/Max treatment pressure 200 psi/Ending Pressure 0 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 93 208 1179 77 80 Subsequent to operation: 120 191 1395 81 89 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil `0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-132 Contact Dan Marlowe Email dmarlowe(chilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature. � 4y Do.-�, 144-14.,•.. ie (907)283-1329 Date 4/17/2014 Form 0-404 Revised 10/2012 Submit Original Univ s-.z.-"I A r/ • Steelhead Platform II SCHEMATIC wellM 28 Last Completed 12/19/2011 Hilcorp Alaska,LLC CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' RKB-to TBG Head:71.4' 16" 75 K-55 Buttress Surf 1,445' ` 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,i J 590' I ,J LL 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 1 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 3-1/2" 9.2 L-80 Hydril563,SCC 3.958 Surf 10,351' in JEWELRY DETAIL Air M. y No Depth OD ID Item 44.1 'x. 1 72.06' 13.625 3.902 Cameron Tubing Hanger w/two 3/8"injection lines ler f 1,610'3,142' •Squeeze Perfs m "•J 4,424' 9,965'-9,977' 3 '4"' 5,526' la uZ 2 6,426' 5.968 2.867 3-1/2"SFO-2 RK Latch gas lift mandrel 4 7,139' in 5 f+ 7,819' t+l.' 8,468' 41 6 + 3 10,136' 4.55 XD Sliding Sleeve . -$7 ) 4 10,190' 3.97 XN Nipple 5 10,245' 6.53 Centrilift ESP Casing Leak 6 10,300' 5.13 Pump Intake p, pp 10466'DIL 7 10,348' 3.75 Phoenix 9!� tGf Squeezed with 8 10,351' 6.00 Bull nose 100 sx cement 9 10,440 8.460 6.000 Baker 9-5/8"SC-1L 10 7.00 6.184 Isolation liner 4jts and pup.7"29 lb/ft L-80 Butt casing with Baker 10 Anchor Assy KBH-22(75 x 60) 11 10,628' 8.437 6.000 Baker Model FA permanent packer(190FA75)with 6'tieback Squeeze Perfs 10,947' 8.25 6.312 Baker ZXP liner packer 7"x 9-5/8" 10,620'-10,623' 13 7.00 6.184 Isolation Liner 5 jts and pup.7"29 lb/ft Butt L-80 casing 11 ® 14 11,198' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE 15 12,351' 5.875 4.00 Baker FB-1 Packer(Size 85-40) _-G-Zone 16 12,357' 5.156 3.813 Otis X landing nipple 17 12,369' 5.093 4.438 TIW LG-6 Tie-back Seals with Y:muleshoe 12 IN Cit Fish/Fill Information: A. 11931'-14.37'Fish(5-7/8"junk mill,bit sub,6-1/16"string mill,x-o) (September 03,1999) "Bad"casing at 13 11035' r PERFORATION DATA 140 Zone Interval(MD) Interval(TVD) Date Zone Interval(MD) Interval(TVD) Date 5-1 10,632'-10,658' 8,692'-8,712' 12/5/97 HB-1 11,206'-11,246' 9,149'-9,182' 9/13/99 5-2 10,684'-10,710' 8,732'-8'752' 12/5/97 HB-2 11,266-11,276' 9,199'-9,208' 9/13/99 5-2 10,720'-10,774' 8,760'-8,803' 12/5/97 HB-3 11,430'-11,470' 9,337'-9,371' 9/13/99 Hemlock. G-3 10,792'-10,822' 8,817'-8,841' 12/5/97 H8-4 11,480'-11,500' 9,380'-9,397' 9/13/99 L Fill @ 11,655' 5-4 10,840'-10,850' 8,855'-8,863' 11/9/93 HB-4 11,510'-11,530' 9,406'-9,423' 9/13/99 5-4 10,858'-10,888' 8,869'-8,893' 11/9/93 HB-4 11,540'-11,550' 9,432'-9,440' 9/13/99 kr t; 5-5 10,964'40,994' 8,954'-8,978' 11/7/93 HB-5 11,570'41,590' 9,548'-9,475' 9/13/99 te W.Foreland G-5 11,012'-11,037 8,993'-9,013' 11/7/93 HB-6 11,722'-11,742' 9,592'-9,610' 9/13/99 �',. r, 5-1 10,638'-10,658' 8,696'-8,712' 9/13/99 HB-7 11,764'-11,788' 9,629'-9,651' 9/13/99 . _tr," 5- 2 10,690'-10,705' 8,737'-8,749' 9/13/99 WF-0 11,815'-11,831' 9,675'-9,689' 8/14/92 G acx 5-2 10,720'-10,740' 8,760'-8,776' 9/13/99 WF-0 11,836'-11,841' 9,693'-9,698' 8/14/92 •`O' G-3 10,790'-10,820' 8,815'-8,839' 9/13/99 WF-0 11,848'-11,858' 9,704'-9,713' 8/14/92 G-4 10,840'-10,850' 8,855'-8,863' 9/13/99 WF-0 11,865'-11,875' 9,720'-9,729' 8/14/92 a 5-4 10,858'40,888' 8,869'-8,893' 9/13/99 WF-1 11,912'41,922' 9,763'-9,772' 8/14/92 S .Y Jurassic G-5 10,965'40,990' 8,955'-8,975' 9/13/99 WF-1 11,930'41,950' 9,779'-9,797' 8/14/92 WF-2 11,966'-11,976' 9,812'-9,821' 8/14/92 Jurassic 12,655'-12,675' 10,461'-10,480' 1/2/92 Jurassic 12,675'-12,748' 10,480'-10,551' 1/2/92 Jurassic 12,748'-12,808' 10,551'-10,609' 1/2/92 Jurassic 12,810'-12,900' 10,611-10,700' 1/2/92 STRESSFRAC Tool @12,880' TD=13,000 PBTD=12,952 MAX HOLE ANGLE=41.8° Updated by:JLL 06/21/13 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-28 50-733-20414-00 190-019 3/19/14 3/19/14 Daily Operations: 03/19/14-Wednesday Fly to Rig. Meet with Production and Rig Up. Pressure Test lines to 2000 psig. Begin pumping 55 gallons Baker Petrolite WAW-5206 & 330 Gallon Xylene Blend. Begin pumping 4,500 Gallons 15% Hydrochloric Acid U-Tubing down tubing and out casing to production. Close Casing valve after 80 bbls and begin bullheading chemical pill. Displace with 100 bbls FIW. Begining Pressure 100 psig. Final Pressure 200 psig. Shut-in well to soak for 8 hours, then return to production. Rig down pump and treating lines. `t .` . STATE OF ALASKA � ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 9 2.0 13 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El icieke, Re-enter Suspended WePI❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 190-019 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20414-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit M-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil,Middle Kenai G Oil,West Foreland Oil,Undefines Oil Pools 11.Present Well Condition Summary: Total Depth measured 13,000 feet ' Plugs measured feet true vertical 10,797 feet Junk measured 11,655 feet Effective Depth measured 11,665 feet Packer measured See Schematic feet true vertical 9,533 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 989' Conductor 989' 16" 1,445' 1,442' 2,630 psi 1,020 psi Surface 4,590' 13-3/8" 4,590' 4,031' 3,090 psi 1,540 psi Intermediate 497' 10-3/4" 497' 496' 5,860 psi 3,220 psi Production 10,902' 9-5/8" 11,399' 9,311' 6,870 psi 4,750 psi Production 1,255' 7" 12,448' 10,261' 8,160 psi 7,020 psi Liner 632' 5" 13,000' 10,797' 10,140 psi 10,490 psi Perforation depth Measured depth See Schematic feet swamp 0 `� True Vertical depth See Schematic feet P NE DEL 0 ZUid Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#L-80 10,351'(MD) 8,471'(ND) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treated tubulars to 10,351',perforations from 10,632'to 11,788' Treatment descriptions including volumes used and final pressure: Pumped 330 gallon Xylene preflush,4500 gallon 15%HCL Acid,displaced with 100 bbls FIW/Max treatment pressure 1300 psi/Ending Pressure 0 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 55 20 1020 88 84 Subsequent to operation: 80 20 1000 88 83 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p , Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-328 Contact #Dan Marlowe Email dmarlowe @hilcorp.com Printed Name Dan Marlowe Title Operations Engineer ✓°emZZ Signature G..--- .2‘ . ---2‘ �r f �. Phone (907)283-1329 Date 8/8/2013 Form 10-404 Revised 10/2012 g,Pi1. I U31.311AS AUG 2 0 20 bmit Ofiginal Only i . III • El Steelhead Platform SCHEMATIC Well 8 Last Completed 12/19/2011 Hilcorp Alaska,LLC CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' RKB-to 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' J 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 1 + 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' i 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4 Et 3-1/2" 9.2 L-80 _ Hydril 563,SCC 3.958 Surf 10,351' ■;,l min JEWELRY DETAIL • i Depth 2 ID Item i i 1 72.06' 13.625 3.902 Cameron Tubing Hanger w/two 3/8"injection lines 6171 Mt j" 1,610'3,142' .. Ittt ueeze Peas B- .; 1 4,424' 165'-9,977' 3 "."�, 2 6,426' 5.968 2.867 3-1/2"SFO-2 RK Latch gas lift mandrel 4 "4 7,139' 5 s; 7,819' 4P, 8,468' 6 �,.- 3 10,136' 4.55 XD Sliding Sleeve 87 4 10,190' 3.97 XN Nipple 5 10,245' 6.53 Centrilift ESP Casing Leak 6 10,300' 5.13 Pump Intake 9-t um 10466'DIL 7 10,348' 3.75 Phoenix GIS Squeezed with 8 10,351' 6.00 Bull nose 100 sx cement 9 10,440 8.460 6.000 Baker 9-5/8"SC-1L 10 7.00 6.184 Isolation liner 4 jts and pup.7"29 lb/ft L-80 Butt casing with Baker 10 Anchor Assy KBH-22(75 x 60) 11 10,628' 8.437 6.000 Baker Model FA permanent packer(190FA75)with 6'tieback Squeeze Perfs 12 10,947' 8.25 6.312 Baker ZXP liner packer 7"x 9-5/8" 10,620'-10,623' 13 7.00 6.184 Isolation Liner 5jts and pup.7"29 lb/ft Butt L-80 casing 11 ►: 14 11,198' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE 15 12,351' 5.875 4.00 Baker FB-1 Packer(Size 85-40) G-Zone 16 12,357' 5.156 3.813 Otis X landing nipple 17 12,369' 5.093 4.438 TIW LG-6 Tie-back Seals with Y.muleshoe 12 '= ►' Fish/Fill Information: A. 11931'-14.37'Fish(5-7/8"junk mill,bit sub,6-1/16"string mill,x-o) (September 03,1999) "Bad"casing at 13 11035' PERFORATION DATA 14 ■:' Zone Interval(MD) Interval(TVD) Date Zone Interval(MD) Interval(TVD) Date 0-1 10,632'-10,658' 8,692'-8,712' 12/5/97 HB-1 11,206'-11,246' 9,149'-9,182' 9/13/99 G-2 10,684'-10,710' 8,732'-8'752' 12/5/97 HB-2 11,266-11,276' 9,199'-9,208' 9/13/99 G-2 10,720'-10,774' 8,760-8,803' 12/5/97 HB-3 11,430'-11,470' 9,337'-9,371' 9/13/99 _ Hemlock. 0-3 10,792'-10,822' 8,817'-8,841' 12/5/97 HB-4 11,480'-11,500' 9,380'-9,397' 9/13/99 A Fill @ 11,655' -= G-4 10,840'-10,850' 8,855'-8,863' 11/9/93 HB-4 11,510'-11,530' 9,406'-9,423' 9/13/99 #•, �? G-4 10,858'-10,888' 8,869'-8,893' 11/9/93 HB-4 11,540'-11,550' 9,432'-9,440' 9/13/99 0-5 10,964'-10,994' 8,954'-8,978' 11/7/93 HB-5 11,570'-11,590' 9,548'-9,475' 9/13/99 I.,-4 1 W.Foreland G-5 11,012'-11,037' 8,993'-9,013' 11/7/93 HB-6 11,722'-11,742' 9,592'-9,610' 9/13/99 0-1 10,638'-10,658' 8,696'-8,712' 9/13/99 HB-7 11,764'11,788' 9,629'-9,651' 9/13/99 G-2 10,690'-10,705' 8,737'-8,749' 9/13/99 WF-0 11,815'41,831' 9,675'-9,689' 8/14/92 G 15 0-2 10,720'-10,740' 8,760'-8,776' 9/13/99 WF-0 11,836'11,841' 9,693'-9,698' 8/14/92 ��, s v1^,r'� m`IIMI■ G-3 10,790'-10,820' 8,815'-8,839' 9/13/99 WF-0 11,848'-11,858' 9,704'-9,713' 8/14/92 r 11' 0-4 10,840'-10,850' 8,855'-8,863' 9/13/99 WF-0 11,865'41,875' 9,720'-9,729' 8/14/92 ., 0-4 10,858'-10,888' 8,869'-8,893' 9/13/99 WF-1 11,912'-11,922' 9,763'-9,772' 8/14/92 !_' Jurassic G-5 10,965'-10,990' 8,955'-8,975' 9/13/99 WF-1 11,930'-11,950' 9,779'-9,797' 8/14/92 1 j WF-2 11,966'41,976 9,812'-9,821' 8/14/92 Jurassic 12,655'42,675' 10,461'-10,480' 1/2/92 Jurassic 12,675'42,748' 10,480'-10,551' 1/2/92 I' �', Jurassic 12,748'-12,808' 10,551'-10,609' 1/2/92 Jurassic 12,810'-12,900' 10,611-10,700' 1/2/92 STRESSFRAC 4!' Tool @12,880' TD=13,000 PBTDr=12,952 MAX HOLE ANGLE=41.8° Updated by:JLL 06/21/13 • it Alaska LLC Hilcorp as Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-28 50-733-20414-00 190-019 7/12/13 7/12/13 Daily Operations: 7/12/2013 - Friday Rig up and pressure test lubricator. Begin pumping FIW down tubing. Returns routed to separator. Pumped 490 bbls FIW 1300 psi 2.5 bbl +/- rate. Closed annulus and pumped the tote of Xylene. Pumped 107 bbls of 15% HCL at negative pressures due to leaking pump seal. Began displacing with FIW. Pumped 100 bbls FIW. Shut well in for 6-8 hours soak time. Rig down and turn well over to production. STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMISS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 1_ j Repair Well Li Plug Perforations Li Stimulate U Other U Replace ESP Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 190 -019 - 3. Address: P.O. Box 196247, Anchorage, Alaska 99519 Stratigraphic El Service ❑ 6. API Number: 50- 733 - 20414 -00 .F o 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 [Steelhead Platform] Trading Bay Unit M -28 9. Field /Pool(s): g•bl*Vt.._ McArthur River Field / Hemlock Oil, Middle Denai G Oil & West Foreland Oil Pool U.R.4) nct 01 L 11) l 10. Present Well Condition Summary: Total Depth measured 13,000 feet Plugs measured N/A feet ue vertical 10,797 feet Junk measured 11,655 (Fill) feet 10,440; 10,628; Effective Depth sured 11,655 feet Packer measured 10,947; 12,351 feet 8,541; 8,689; true vertical 9,533 feet true vertical 8,941; 10,170 feet Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 989' Conductor 989' 16" 1,445' 1,442' 2,630 psi 1,020 psi Surface 4,590' 13 -3/8" 4,590' 4,031' 3,090 psi 1,540 psi Intermediate 497' 10 -3/4" 497' 496' 5,860 psi 3,220 psi Intermediate 10,902' 9 -5/8" 11,399' 9,311' 6,870 psi 4,750 psi Production 1,255' 7" 12,448' 10,261' 8,160 psi 7,020 psi Liner 632' 5" 13,000' 10,797' 10,140 psi 10,490 psi Perforation depth Measured depth See WBD feet �p True Vertical depth See WBD feet SENE ,IAN 3 0 2012 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6#/ L -80 10,245' MD 8,242' TVD Baker SC -1L 10,440MD, 8,541TVD; Baker FA 10,628MD, 8,688TVD; Baker ZXP 10,947M • : • • I D Packers and SSSV (type, measured and true vertical depth) Baker FB -1 12,3 1 MD, 10,169T \aeG \ .0 N/A 11. Stimulation or cement squeeze summary: 2®12 Intervals treated (measured): 9,965' - 9,977' 1 M 21 Treatment descriptions including volumes used and final pressure: • mm;SS Spot 65 Bbls of synthetic acid across perforations. r C c5C1g. L,O 12. Representative Daily Av agpP 1nje QR to Oil -Bbl Gas -Mcf ter -Bbl "' Casa re Tubing Pressure Prior to well operation: 0 0 s 0 _ - - --- — 210 psi 70 psi Subsequent to operation: 159 67 3591 23 psi 120 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run na Exploratory Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations na 15. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -353 Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager I Signature /-�-� Phone 276 -7600 Date 1/25/2012 41111 Arm 4b 1-Z712 Form 10 -404 Revise PEBTAAS JAN 2 1012 i7 Submit Original Only r evro Steelhead Platform Stee ead Platform Well M -28 "4"144.0,000.1 Last Completed 12/19/2011 M -28 Actual Oil Well Producer PoCB4o TBG Head: 71.4' M I 1 ' '� CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril -Quip Surf 990' 16" 75 K -55 Buttress Surf 1,445' al 13 -3/8" 61/68 K -55 Buttress 12.415 Surf 4,590' 4 • 10 -3/4" 51 /55 N -80 Buttress 9.604 Surf 497' 9 -5/8" 47 N -80 Buttress 8.681 497' 11,399' Arg a I 2 B 7" 29 N -80 Buttress 6.184 11,193' 12,448' �, 5" 18 N -80 FL4S 4.276 12,368' 13,000' * Tubing: �. + 3 -1/2" 9.2 L -80 Hydril 563 , 3.958 Surf 10,351' Squeeze Perts - �� ' SCC 9,965' - 9,97' - 3 i MD JEWELRY DETAIL imk 4 i No Depth OD ID Item 5 w. 1 72.06' 13.625 3.902 Cameron Tubing Hanger w/ two 3/8" injection lines 6 ' 1,610' $7 ' � l 3,142' 4,424' Casing Leak 2 6,426' 5,526' ng 5.968 2.867 3 -1/2 " SFO -2 RK Latch gas lift mandrel 10465 DIL 9 Squeezed wth 7,139' 100sx cement 7,819' 8,468' 10 3 10,136' 4.55 XD Sliding Sleeve 4 10,190' 3.97 XN Nipple Squeeze Pals 5 10,245' 6.53 Centrilift ESP 10,62C1 10,623' 6 10,300' 5.13 Pump Intake 11 g 7 10,348' 3.75 Phoenix 8 10,351' 6.00 Bull nose ° G 9 10,440 8.460 6.000 Baker 9 -5/8" SC -1L 10 7.00 6.184 Isolation liner 4 jts and pup. 7" 29 lb /ft L -80 Butt casing with 12 is 2 Baker Anchor Assy KBH -22 (75 x 60) 11 10,628' 8.437 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 12 10,947' 8.25 6.312 Baker ZXP liner packer 7" x 9 -5/8" Sad" casing at 13 11036' 13 7.00 6.184 Isolation Liner 5 jts and pup. 7" 29 lb /ft Butt L -80 casing 14 11,198' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE 15 12,351' 5.875 4.00 Baker FB -1 Packer (Size 85 -40) 14 ® 53 16 12,357' 5.156 3.813 Otis X landing nipple 17 12,369' 5.093 4.438 TIW LG -6 Tie -back Seals with 'A muleshoe - Flembck. Fish /Fill Information: L Fii @ 11,655 A. 11931' - 14.37' Fish (5 -7/8" junk mill, bit sub, 6- 1/16" string mill, x -o) , (September 03, 1999) W.Fonaand PERFORATION DATA ti ` Zone Interval (MD) Interval (TVD) Date Zone Interval (MD) Interval (TVD) Date e G -1 10,632' - 10,658' 8,692' - 8,712' 12/5/97 HB -1 11,206'- 11,246' 9,149'- 9,182' 9/13/99 16 15 0-2 10,684'- 10,710' 8,732' - 8'752' 12/5/97 HB -2 11,266'- 11,276' 9,199'- 9,208' 9/13/99 __ _SD_ _..J , G -2 10,720' - 10,774' 8,760' - 8,803' 12/5/97 1 11,430'- 11,470' 9,337'- 9,371' 9/13/99 17 - G -3 10,792' - 10,822' 8,817' - 8,841' 12/5/97 HB -4 11,480'- 11,500' 9,380'- 9,397' 9/13/99 0-4 10,840' - 10,850' 8,855' - 8,863' 11/9/93 HB -4 11,510'- 11,530' 9,406'- 9,423' 9/13/99 Jurassic G -4 10,858'- 10,888' 8,869' - 8,893' 11/9/93 HB -4 11,540'- 11,550' 9,432'- 9,440' 9/13/99 G -5 10,964'- 10,994' 8,954' - 8,978' 11/7/93 HB -5 11,570'- 11,590' 9,548'- 9,475' 9/13/99 G -5 11,012'- 11,037' 8,993'- 9,013' 11/7/93 1-1B -6 11,722'- 11,742' 9,592'- 9,610' 9/13/99 G -1 10,638'- 10,658' 8,696' - 8,712' 9/13/99 HB -7 11,764' - 11,788' 9,629'- 9,651' 9/13/99 Ill 4 S1RESSFRAC G -2 10,690' - 10,705' 8,737' - 8,749' 9/13/99 WF -0 11,815' - 11,831' 9,675'- 9,689' 8/14/92 Tool @12,880' 0-2 10,720' - 10,740' 8,760' - 8,776' 9/13/99 WF -0 11,836'- 11,841' 9,693'- 9,698' 8/14/92 G -3 10,790'- 10,820' 8,815' - 8,839' 9/13/99 WF -0 11,848' - 11,858' 9,704'- 9,713' 8/14/92 G -4 10,840' - 10,850' 8,855' - 8,863' 9/13/99 WF -0 11,865' - 11,875' 9,720'- 9,729' 8/14/92 TD =13,000 PBTD = 12,952 G -4 10,858'- 10,888' 8,869' - 8,893' 9/13/99 WF -1 11,912' - 11,922' 9,763'- 9,772' 8/14/92 G -5 10,965'- 10,990' 8,955' - 8,975' 9/13/99 WF -1 11,930' - 11,950' 9,779'- 9,797' 8/14/92 MAX HOLE ANGLE = 41.8° WF -2 11,966' - 11,976' 9,812'- 9,821' 8/14/92 Jurassic 12,655'- 12,675' 10,461'- 10,480' 1/2/92 Jurassic 12,675'- 12,748' 10,480'- 10,551' 1/2/92 Jurassic 12,748'- 12,808' 10,551'- 10,609' 1/2/92 Jurassic 12,810'- 12,900' 10,611- 10,700' 1/2/92 Actual WBD M -28 Rev 1.doc Updated by TDF 1/24/2012 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -28 TRADING BAY UNIT M -28 ADL0018730 5073320414 0Q0093 152.00 160.00 Primary Job Type Job Objective Actual Start Date Actual En . ... r d Date Tubing Repair Major Rig 12/3/2011 12/24/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number M -28 507332041400 1900190 • 12/3/2011 00:00.12/4/2011 00:00 Operations Summary Skid Rig to M -28 • 12/4/2011 00:00 - 12/5/2011 00:00 Operations Summary Continue to skid rig to M -28 12/512011 00:00 - 1216/2011 00:00 Operations Summary Continue to skid rig and center up over M -28, begin rigging up. 12/612011 00:00 - 12/7/2011 00:00 Operations Summary MIRU Pollard wire -line, pressure test lubricator 250psi low/ 3,000psi high, RIH w13.79" GR to 9,985', POOH. MU 4" braided brush and RIH to 8,810'. POOH add more weight and RIH w /4" braided brush and brush the nipple at 9,994'. 12/7/2011 00:00 - 12/8/2011 00:00 Operations Summary RIH with a 4" braided brush to 10,064', POOH. RIH w/ 3.79" GR & SD @ 9,993' on XO above 'Y' block. RIH w/ 1- 7/16" tubing puncher and punch 46 holes @ 9,965' - 9,977' all shots fired. Begin circulation of well bore to 3% KCL. 12/8/2011 00:00 - 12/9/2011 00:00 Operations Summary Continue to circulate 3% KCL until clean. Pump 50 Bbl LCM sized salt pill and spot across zone. set 4" BPV and ND tree. NU BOPE, charge accumulator system and function test BOPE. 12/9/2011 00:00 - 12/10/2011 00:00 Operations Summary Test BOPE, Test annular to 250 psi low / 2,500 psi high. Test remaining BOPE to 250 psi low /3,000 psi high. Witness waived by Chuck Sheve of AOGCC. 12/10/2011 00:00 - 12/11/2011 00:00 Operations Summary Continue to test BOPE. Circulate 820 Bbls of KCL until returns are clean, BOLDS and bring hanger to rig floor with 205K #'s up weight. 12/11/2011 00:00 - 12/12/2011 00:00 Operations Summary Spot 60 Bbl sized salt pill across perforated interval and decrease loss rate from 54 BPH to 12 BPH. POOH with 4 -1/2" ESP completion to 7,700' 12/12/2011 00:00 - 12/13/2011 00:00 Operations Summary Continue to POOH with ESP completion from 7,700' to 1,463'. Change out ESP cable spool. 12/13/201100:00.12 /1412011 00:00 Operations Summary Continue to POOH with ESP Completion from 1,463'. Note: all clamps and bands accounted for when compared to notes on original run tally. PUMU clean out BHA. 12/14/2011 00:00 - 12/15/2011 00:00 Operations Summary RIH w/ clean out BHA to 8,900'. 12/15/2011 00:00 - 12/18/2011 00:00 Operations Summary Continue to RIH w/ clean out BHA to 9,850, wash and ream through scab line and tag obstruction at 11,655'. POOH with cleanout BHA to 10,426', circulate Hi Vis sweep, TIH to 11,560'. Notified AOGCC of upcoming BOP test. 12/16/2011 00:00 - 12/17/2011 00:00 Operations Summary Pump 65 Bbls Oil Safe AR (synthetic acid) and spot across perforations with 3% KCL. POOH from 11,560' with clean out BHA, LD same. Test BOPE,,- Test annular to 250 psi low / 2,500 psi high. Test remaining BOPE to 250 psi low /3,000 psi high. BOP test witness waived by AOGCC Bob Noble. 12/17/2011 00:00 - 12/18/2011 00:00 Operations Summary RD test euipment, RU ESP running equipment. Begin RIH w/ ESP assembly. 12/18/2011 00:00 - 12/19/2011 00:00 Operations Summary Continue to RIH with ESP completion on 3 -1/2" tubing. 12/19/201100:00.12 /20/201100:00 Operations Summary Continue to RIH with ESP completion on 3 -1/2" 9.3# L -80 ESP completion and land same at 10,351'. LD landing joint and ND BOPE A , Chevron • • 11 10 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M-28 TRADING BAY UNIT M-28 ADL0018730 5073320414 0Q0093 152.00 160.00 12/20/2011 00:00 - 12/21/2011 00:00 Operations Summary Rig down and turn well over to production. 12121/2011 00:00 - 12/22/2011 00:00 Operations Summary Continue to demobe. 12/22/2011 00:00 - 12/23/2011 00:00 Operations Summary Continue to demobe. 12/23/2011 00:00 - 12/24/2011 00:00 Operations Summary Complete demobe. • • SITERE DrEF [1\11:LSKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 January 9, 2012 Mr. Chris Myers Field Superintendent Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524 -4027 RE: No -Flow Verification X L £U)L Trading Bay Unit M -28 D t PTD 1900190 4. Dear Mr. Myers: On January 4, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Trading Bay Unit well M -28 located on the Steelhead Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC ( Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail -safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that Hilcorp verified no obstruction exists in the wellbore, the electric submersible pump was shut down, and calibrated flow measurement equipment with suitable range and accuracy was installed. The Trading Bay Unit M -28 no -flow test consisted of 3 separate hour -long shut in periods separated by brief periods of flow monitoring accomplished by opening the well to atmosphere through calibrated flow measurement equipment. During the flow monitoring periods, only a slight movement of gas was detected which stopped after 30 seconds. There was no liquid production to surface. The subsurface safety valve must be returned to service if Trading Bay Unit M -28 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 Steelhead Platform. Sincerely, --„Ctutt.ev . Qi 7 - 7 James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �eil '1 DATE: 1/4/2012 P. I. Supervisor FROM: Bob Noble SUBJECT: No -Flow Petroleum Inspector Hilcorp Energy Co. TBU M -28, PTD 190 -0190 — Jan 4 2012: On arrival I met with Hillcorp Rep Mike Chivers and we discussed the no -flow on M- 28. He told me that the well had been on line for about 14 days, to clean it up after work -over operations. He said they had shut the ESP pump down at midnight and opened the tubing and the IA to bleed the well down. By the time I was ready to start the no -flow test it had been open to atmosphere for 14 hours. My test went as following: I made sure SSV master and swab were open. - 14:00: I shut in well to let it pressure up. 15:00: 0 psi on gauge, opened well up; no flow detected on flow meter. I went down to the drain and felt no gas coming out of hose. 15:05: I shut the well in again. 17:00: 0 psi on gauge; disconnected the bleed hose at the flow meter; opened up well. The needle on flow meter just vibrated, but not enough to say to say there was any flow. I put my hand over the bleed and could just barely feel air movement. The air movement stopped within 30 sec. 17:05: I shut the well in again. 19:00: 0 psi on gauge; opened up well. The needle on flow meter just vibrated, but not enough to say to say there was any flow. I put my hand over the bleed and could just barely feel air movement. The air movement stopped within 30 sec. As far as I can tell this well was dead and would not flow to surface un- assisted. Attachments: none No Flow Test TBU M -28 1 -4 -12 • • 2`e P 1b._cAci Regg, James B (DOA) From: Leslie, Mike [lesliegm @chevron.com] Sent: Thursday, December 15, 2011 9:35 PM To: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Nienhaus, Doug R; Lott, James C. [Swift Technical Services]; Brandenburg, Tim C Subject: BOP usage 12 -15 -11 To All, Notification for use of BOP to prevent flow of fluids from Well Bore. 12- 15 -11, 09:00 and 12- 15 -11, 13:45 Well # M -28, Steelhead Platform, PTD # 190 -019 ✓ Rig # 51, BOP used: 13 5/8, 5M Annular Preventer Fluid: 8.6 ppg KCL Last BOP test: Dec. 10, 2011 BOP test due date: Dec. 17, 2011 Depth 10,900 - We were performing "clean out" operations and were circulating out a high vis sweep below the G- Zone, prior to entering the lower scab liner. The A.M. Driller noticed an increase in "flow out" and a 5 bbl pit gain. Driller shut down the pump and we checked for flow. Well was flowing, so Annular was shut. 0 psi recorded on Choke gauge. Continued to circulate high vis sweep out of hole through fully opened choke. Shut down pumps after sweep returned to surface and verified no trapped pressure. Opened Annular and verified "no flow" from Well Bore. Depth 11,300 — We had cleaned out the lower scab liner and 94 ft of the Hemlock perforations when the P.M. Driller noticed an increase in "flow out ", but no pit gain. Driller shut down the pump and we checked for flow. Well was flowing, so Annular was shut. 20 psi registered on Choke gauge. Circulated the remaining annular volume to clear gas from well. Shut down pumps and verified no trapped pressure. Opened Annular and verified "no flow" from Well Bore. Continued clean out operations to 11,655 ft with no other issues. Gary M. Leslie (Mike) Drill Site Manager Iesliegm a,chevron.com Chevron North America Exploration and Production Anchorage Alaska, 99501 -3322 Cell # 907 - 382 -3057 Fax # 1- 866 - 480 -5390 Steelhead Platform 907 - 776 -6833 CAI : GLEX 1 • 0 SITAILE gr ALASIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager 0 19 Union Oil Company of California i P.O. Box 196247 1 Anchorage, AK 99519 Re: McArthur River Field, hemlock Oil Pool, Trading Bay Unit M -28 Sundry Number: 311 -353 Dear Mr. Brandenburg: . y "' , /tit' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, AP / Daniel T. Seamount, Jr. Chair DATED this fday of November, 2011. Encl. • ; Te � tt ► .te' `' . C1 ,}' STATE OF ALASKA � Nay 0 9 ?(OV A OIL AND GAS CONSERVATION COMMISSION llc APPLICATION FOR SUNDRY APPROVALS Aitska 011 & Gas Cons. commission 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChanAcOWL4Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 51 - Alter Casing ❑ Other: ESP Remove/ Replace El • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of Califomia Development 0 • Exploratory ❑ 190 -019 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20414 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No SI Trading Bay Unit M -28 • 9. Property Designation (Lease Number): 10. Field / Pool(s): , ADL0018730 (Steelhead Platform) McArthur River Field/ Hemlock oil, Middle Kenai G oil & West Foreland Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,000 • 10,797 • 11,645 9,523 N/A 11,645' (Fill) Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 989' Conductor 989' 16" 1,445' 1,442' 2,630psi 1,020psi Surface 4,590' 13 -3/8" 4,590' 4,031' 3,090psi 1,540psi Intermediate 497' 10 -3/4" 497' 496' 5,860psi 3,220psi Intermediate 10,902' 9 -5/8" 11,399' 9,311 6,870psi 4,750psi Production 1,255' 7" 12,448' 10,261' 8,160psi 7,020psi Liner 632' 5" 13,000' 10,797' 10,140psi 10,490psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Current Schematic See Current Schematic 4 -1/2" 12.6 # /L -80 10,064 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FA, Baker ZXP, Baker SC-1L & Baker FB -1 Packer and N/A 10,627.5(MD)/8,688'(TVD); 10,946(MD)/8,940(TVD); 10,440.3(MD)/8,541'(TVD); 12,351(MD)/10,169(TVD) and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/28/2011 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Amjad Chaudhry Phone: 263 -7637 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature (' C j> Phone 276 -7600 Date 11/8/2011 � - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31/ - 353 Plug Integrity ❑ BOP Test K Mechanical Integrity Test El Location Clearance ❑ Other: ' i V Ck M. -kt -7 0. , Q 4N „ 0 9Q to tt--.--, \.--- U.C.Cc . '4 4 t r 0 npCSC \l a P v�')cA---°\c c31/4. r `Pc- okoc o \ two 'F\o •... _,,k ,i4(, V %v ys oA eN'v k--- .). \\ \-a QccS >, :or. )0 R0.(-as:X S%) Subsequent Form Required: rA� / APPROVED BY 1fl 4 / )) Approved by: �1I / RBD MISSIONER THE COMMISSION Date: G NOV h 11 �� Form 10 -403 Revised 1/2Q1 Nu r 1 I L° R 1 6 1 N A bmit in Du licate ( I Eigtriiredemi Stead UN0CAL'6 Well No. M -28 Actual Completion 9 -24 -05 PKR fn TLC: HPa = 71 4' 1 I CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. G r , 26" 267/397 Dril -Quip Surf 990' L , 16" 75 K -55 Buttress Surf 1,445' 40 c-32 © , 13 -3/8" 61/68 K -55 Buttress 12.415 Surf 4,590' L 10 -3/4" 51/55 N -80 Buttress 9.604 Surf 497' 9 -5/8" 47 N -80 Buttress 8.681 497' 11,399' 7" 29 N -80 Buttress 6.184 11,193' 12,448' \ 5" 18 N -80 FL4S 4.276 12,368' 13,000' 4 Tubing: 4 -1/2" 12.6 L -80 AB Mod 3.958 Surf 10,064' 6 Casing Leak 7 10466'DIL Squeezed with JEWELRY DETAIL 8 . MI 100 sx cement No Depth OD ID Item • 1 72.06' 13.625 3.902 Cameron Tubing Hanger w/ two 3/8" injection lines 2 2,196' 4.500 3.958 4 -1/2" 12.6 lb/ft L -80 AB Modified tbg 9 3 7.031 3.833 4 -1/2" Gas Lift Mandrels: 2017', 3448', 4735', 5813', 6489', _ Squeeze Perfs 7075', 7599', 8144', 8550' - 10620- 10623' 4 10,073' 8.250 3.5 Phoenix "Y" Block with 155' of 2 -3/8" FJP Tubing (EOT at 10 M 10,219') 5 10,086' 5.130 Centrilift ESP (213 stage GC 4100 and 418 hp motor) G - Zone 6 10,139' 5.13 N/A Pump Intake 11 MI 7 10,188' 5.42 N/A Phoenix 8 10,440.3' 8.460 6.000 Baker 9 -5/8" SC -IL "Bad" casing at 9 7.00 6.184 Isolation liner 4 jts and pup. 7" 29 lb/ft L-80 Butt casing with 12 11035' Baker Anchor Assy KBH-22 (75 x 60) 10 10,627.5' 8.437 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 13 II 11 10,945.7' 8.25 6.312 Baker ZXP liner packer 7" x 9-5/8" 12 7.00 6.184 Isolation Liner 5 jts and pup. 7" 29 lb/ft Butt L-80 casing - 9/05 WO: Ran 13 11,197.6' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE L Hemlock. 14 12,351' 5.875 4.00 Baker FB -1 Packer (Size 85 -40) bit to 11645'. 15 12,357' 5.156 3.813 Otis X landing nipple W. Foreland Fish/Fill Information: A. 11931' - 14.37' Fish (5 -7/8" junk mill, bit sub, 6- 1/16" string mill, x -o) CIIIIIZ 15 14 Z. PERFORATION DATA 16 Zone Interval(MD) Interval(TVD) Date Zone Interval(MD) Interval(TVD) Date G -1 10,632'- 10,658' 8,692' - 8,712' 12/5/97 HB -1 11,206'- 11,246' 9,149'- 9,182' 9/13/99 G -2 10,684'- 10,710' 8,732' - 8'752' 12/5/97 HB -2 11,266'- 11,276' 9,199'- 9,208' 9/13/99 e G -2 10,720'- 10,774' 8,760' - 8,803' 12/5/97 HB -3 11,430' - 11,470' 9,337'- 9,371' 9/13/99 G -3 10,792'- 10,822' 8,817' - 8,841' 12/5/97 HB -4 11,480'- 11,500' 9,380'- 9,397' 9/13/99 _ • G -4 10,840'- 10,850' 8,855' - 8,863' 11/9/93 HB -4 11,510' - 11,530' 9,406'- 9,423' 9/13/99 G -4 10,858'- 10,888' 8,869' - 8,893' 11/9/93 HB -4 11,540'- 11,550' 9,432'- 9,440' 9/13/99 G -5 10,964'- 10,994' 8,954' - 8,978' 11/7/93 HB -5 11,570' - 11,590' 9,548'- 9,475' 9/13/99 G -5 11,012'- 11,037' 8,993'- 9,013' 11/7/93 HB -6 11,722'- 11,742' 9,592'- 9,610' 9/13/99 O G-1 10,638'- 10,658' 8,696' - 8,712' 9/13/99 HB -7 11,764'- 11,788' 9,629'- 9,651' 9/13/99 G -2 10,690'- 10,705' 8,737'- 8,749' 9/13/99 WF -0 11,815'- 11,831' 9,675'- 9,689' 8/14/92 G -2 10,720'- 10,740' 8,760'- 8,776' 9/13/99 WF -0 11,836'- 11,841' 9,693'- 9,698' 8/14/92 Tool @12,880' G -3 10,790'- 10,820' 8,815' - 8,839' 9/13/99 WF -0 11,848' - 11,858' 9,704'- 9,713' 8/14/92 G -4 10,840'- 10,850' 8,855' - 8,863' 9/13/99 WF -0 11,865'- 11,875' 9,720'- 9,729' 8/14/92 G -4 10,858'- 10,888' 8,869' - 8,893' 9/13/99 WF -1 11,912' - 11,922' 9,763'- 9,772' 8/14/92 G -5 10,965' - 10,990' 8,955' - 8,975' 9/13/99 WF -1 11,930'- 11,950' 9,779'- 9,797' 8/14/92 PBTD = 12,952'; TD = 13,000' WF -2 11,966' - 11,976' 9,812'- 9,821' 8/14/92 MAX HOLE ANGLE = 41.8° Jurassic 12,655'- 12,675' 10,461' - 10,480' 1/2/92 Jurassic 12,675'- 12,748' 10,480'- 10,551' 1/2/92 Jurassic 12,748' - 12,808' 10,551'- 10,609' 1/2/92 Jurassic 12,810'- 12,900' 10,611- 10,700' 1/2/92 O:\ NAU \MCBU\Alaska \Depts \CI_Oil_Ops\ Fields \TBU\Steelhead\Wells \Oil Wells\M -28 \Schematics\M -28 Schematic 09- 24- 05.doc Modified 10 -24 -2011 TDF 41 evro Steelheacc ,atform Steelhea • Platform Well M -28 4411'"■■••••".° Last Completed 9/24/2005 M -28 (Proposed) Oil Well Producer> Shut in I(B - to TBG Head: 71.4' CASING AND TUBING DETAIL j L' '� SIZE WT GRADE CONN ID TOP BTM. 1 a 26" 267/397 Dril -Quip Surf 990' 2 d 16" 75 K -55 Buttress Surf 1,445' 13 -3/8" 61/68 K -55 Buttress 12.415 Surf 4,590' It 26" 10 -3/4" 51/55 N -80 Buttress 9.604 Surf 497' @990' 9 -5/8" 47 N -80 Buttress 8.681 497' 11,399' © Er 7" 29 N -80 Buttress 6.184 11,193' 12,448' 16" @ 5" 18 N -80 FL4S 4.276 12,368' 13,000' i 3 1448 Tubing: II 3 -1/2" 9.2 L - 80 Ilydril563, 3.958 Surf +10,100' ® SCC Mi 133/8 "@ Mr 4 4,590' JEWELRY DETAIL -I No Depth 72.06' OD ID Item 5 1 13.625 3.902 Cameron Tubing Hanger w/ two 3/8" injection lines 2 +2196' 3.500 3 -1/2" Hydril 563 SCC, 9.2 #, L -80 Tubing 7 - - 6 3 7.031 3.833 3 -1/2" Gas Lift Mandrels: TBD 4 TBD 4.55 2.813 XD Sliding Sleeve 8 5 TBD 4.00 2.75" XN Nipple Casng Leak 10466' CIL 6 TBD 5.130 Centrilift ESP 1 0440,3 9 & . Squeezed Hith 7 ±10300 5.13 N/A Pump Intake 100sxcement 8 TBD 5.42 N/A Phoenix 9 10,440.3' 8.460 6.000 Baker 9 -5/8" SC -1L 10 10 7.00 6.184 Isolation liner 4 jts and pup. 7" 29 lb /ft L -80 Butt casing with Squeeze Pets Baker Anchor Assy KBH -22 (75 x 60) 10620 10623' 11 10,627.5' 8.437 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 12 10,946.7' 8.25 6.312 Baker ZXP liner packer 7" x 9 -5/8" 10,627.5 111 X 13 7.00 6.184 Isolation Liner 5 jts and pup. 7" 29 lb /ft Butt L -80 casing 14 11,197.6' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE = G 15 12,351 5.875 4.00 Baker FB -1 Packer (Size 85 -40) 16 12,357' 5.156 3.813 Otis X landing nipple I 112 17 12,369' 5.093 .4.438 TIW LG -6 Tie -back Seals with '/2 muleshoe 10,945.7 "Bad' casing at 13 11035 Fish /Fill Information: A. 11931' - 14.37' Fish (5 -7/8" junk mill, bit sub, 6- 1/16" string mill, x -o) 114 Ig 11,797.5 Henlock. 95/13' @ PERFORATION DATA L II tryto ! _ ,900'w/6" 11,389' Zone Interval(MD) Interval(TVD) Date Zone Interval(MD) Interval(TVD) Date leanout G -1 10,632'- 10,658' 8,692' - 8,712' 12/5/97 HB -1 11,206'- 11,246' 11 G -2 10,684'- 10,710' 8,732' - 8'752' 12/5/97 HB -2 11,266'- 11,276' 9,199'- 9,208' 9/13/99 9/13/99 it . G -2 10,720' - 10,774' 8,760'- 8,803' 12/5/97 HB -3 11,430' - 11,470' 9,149'- 9,182' 9,337'- 9,371' 9/13/99 W. Foreland 7 - G -3 10,792'- 10,822' 8,817' - 8,841' 12/5/97 HB -4 11,480 %11,500' 9,380'- 9,397' 9/13/99 15 G -4 10,840'- 10,850' 8,855' - 8,863' 11/9/93 HB -4 11,510'- 11,530' 9,406'- 9,423' 9/13/99 A rt _' '"1" G -4 10,858'- 10,888' 8,869'-8,893' 11/9/93 HB -4 11,540'- 11,550' 9,432'- 9,440' 9/13/99 c , r 4o.", T Liner G -5 10,964'40,994' 8,954'4,978' 11/7/93 HB -5 11,570'41,590' 9,548'- 9,475' 9/13/99 ' - 7t 4 ' =s 11,193 - t� G -5 11,012' - 11,037' 8,993'- 9,013' 11/7/93 HB -6 11,722' - 11,742' 9,592'- 9,610' 9/13/99 as 1F : s '-' w 12,448 G -1 10,638'- 10,658' 8,696'- 8,712' 9/13/99 HB -7 11,764'- 11,788' 9,629' - 9,651' 9/13/99 4 A=' G -2 10,690'-10,705' 8,737'4,749' 9/13/99 WF -0 11,815'- 1 1,831' 9,675'- 9,689' 8/14/92 G -2 10,720'- 10,740' 8,760' - 8,776' 9/13/99 WF -0 11,836'- 11,841' 9,693'- 9,698' 8/14/92 , d Witt G -3 10,790'- 10,820' 8,815'-8,839' 9/13/99 WF -0 11,848'-11,858' 9,704'- 9,713' 8/14/92 A ,hr,' G -4 10,840'- 10,850' 8,855' - 8,863' 9/13/99 WF -0 11,865'- 11,875' 9,720'- 9,729' 8/14/92 5" Liner t. "`;' , G -4 10,858'- 10,888' 8,869' - 8,893' 9/13/99 WF -1 11,912' - 11,922' 9,763'- 9,772' 8/14/92 12,368'- e I S1RFSSFRAC G -5 10,965'40,990' 8,955'4,975' 9/13/99 WF -1 11,930'41,950' 9,779'- 9,797' 8/14/92 13,000' ti Tool @12,880' WF -2 11,966'41,976' 9,812'- 9,821' 8/14/92 M A ;44,'. Jurassic 12,655'- 12,675' 10,461'- 10,480' 1/2/92 Jurassic 12,675'- 12,748' 10,480'- 10,551' 1/2/92 TD =13 000 PBTD =12 952 Jurassic 12,748' - 12,808' 10,551'- 10,609' 1/2/92 Jurassic 12,810'- 12,900' 10,611- 10,700' 1/2/92 MAX HOLE ANGLE = 41.8 Proposed WBD M -28 Rev 1.doc Updated by AC V Chevron • Trading 1410Unit M -28 ESP Replacement WO 10/20/2011 OBJECTIVE: Recover current ESP completion — Cleanout wellbore and spot acid across perfs. — Run new ESP • completion on 3 -1/2" Tubing with gas lift mandrels — Return well to production as producing oil well. Current BHP: 3450psi @ 9072' TVD Max BHP: 3450psi @ 9072' TVD (Based on previous actual Phoenix Reading) MASP: 1265 PSI Surface Pressure based on historical shut in pressure. PROCEDURE SUMMARY: • Set BPV and ND Tree - NU BOPE - TEST BOPE Equipment to 250psi low /3,000psi high. Test Annular to 250psi low/ 1,500psi high. • Circulate well bore with 3% KCL/ filtered inlet water — Pump designed salt pill as required to control static fluid loss rate. • POOH with 4 -1/2" ESP Completion. Visually inspect & L/D singles while POH. • RIH with 6" clean -out assembly clean out across existing perforations 10,632' to 11,900'. • Circulate well clean. Spot synthetic acid across perfs. POOH • PU new ESP on 3 -1/2" Tubing and RIH and place pump intake ±10,300' MD — land hanger. • ND BOP, NU Tree and test to 250psi low /5,000psi high. • TURN OVER TO OPERATIONS. M- 28_WO_Objective_a nd_Procedu re_S ummary.doc Chevron • Steelhead Platform • M -28 10/15/2011 Rig dd floor Bottom of p pa n ni nl 6.75 22" X 16" for air boot sleeve, 19' in length At Tuboscope 10.92 26.23 Moon pool deck to rig floor 111 til '111iuii • 4.54' ' Hydril ' GK 13 98 -5000 Iii 1.1 oil 1111,1 H 4.67' • mole • hi. I11 .111 i1 L1 Top of Moonpool Moonpool deck lop @ 55.95' deck 55.38' 9.60' L. in m ui m Total BOP assembly • 1 i i l., „ . l II III 2.26' I. ❑iI.I 111 III 2.83' ■11 i11.I1 41 11 1.25' 3.86' flange above rig sub grating V A Rig sub grating Upper Wellhead Room to Rig Sub Gratrg 23.47 5.08' damp above floor y Upper wellhead room floor • Nkllhead floor to Upper 5\ Ahead Room 22.85 111 ul • Ill 111 S000I 13 58 5M FE X FE 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing 0 Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of Califomia Name: STATE OF ALASKA . ALAe OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas èons. Commission Stimulate U Other l:Ahch~ece failed Waiver D Time Extension D .- ESP Re-enter Suspended Well D 5. Permit to Drill Number: RECEIVED OCT 0 7 Z005 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Ctass: Development 0 - Stratigraphic D ExploratoryD 1~19 (¡¡. ServiceD 6. API Number: 50-733-20414 9. Well Name and Number: 7. KB Elevation (ft): 160' KB to MSL 8. Property Designation: Trading Bay UniUSteelhead Platform 11. Present Well Condition Summary: M-28 10. Field/Pool(s): McArthur River Field/G-Zone, Hemolock, West Foreland Total Depth measured 13,000 feet true vertical 10,801 feet Effective Depth measured 12,952 feet true vertical 10,751' feet Casing Length Size MD Structural Conductor 1,447' 16" 1,447' Surface 4,590' 13.3/8" 4,590' Intermediate 11,399' 10-3/8"/9-5/8" 11,399' Production 1,255' 7" 12,448' Liner 632' 5" 13,000' Plugs (measured) none Junk (measured) logging tool 12,880' TVD Burst Collapse 1,443' 4,030' 3,090 psi 1,540 psi 9,333' 6,870 psi 4,760 psi 10,265' 8,160 psi 7,020 psi 10,801' 9,910 psi 10,490 psi Perforation depth: Measured depth: see attached schematic True Vertical depth: see attached schematic 'I[;."lr' J'i li<.ìMlt:r ~vb"Îß\5~\'j&- ' r /, Tubing: (size, grade, and measured depth) 4-1/2",12.6#, L-80 @ 10,064' Packers and SSSV (type and measured depth) nla 12. Stimulation or cement squeeze summary: Intervals treated (measured): nla RBDMS 8Fl 0 CT 1 0 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 20 1,476 86 110 2,627 71 15. Well Class after proposed work: ExploratoryD Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 39 225 Tubing Pressure 78 76 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D x GINJ D WINJ D WDSPL D I Sundry Number or NIA if C.O. Exempt: 305-262 Contact Larry Buster: 263-7853 Pri"::::~ T;m;; ~.6- ~... Ph::: ::;::::e, Form 10-404 Revise/~004 ~ AFE 164491 Date /()...:;;- () s Submit Original Only = 714' ¿L ~ ~ ~ ~ ~ 5 6 Casing Leak 10466' DIL Squeezed with 100 sx cement II = Squeeze Perfs - 10620-10623' 8 G 9 "Bad" casing at 11035' L W. Foreland Perf. STRESSFRAC Tool @12,880' Jurassic Perfs 12655-12675 1/2/92 12675-127481/2/92 12748-12808 1/2/92 12810-12900 1/2/92 PBTD = 12,952'; TD = 13,000' MAX HOLE ANGLE = 41.7 26" 267/397 Dri1-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,064' 2 3 4 5 6 2196' 10,073' 10,086' 10,192' 13.625 4.500 7.031 Cameron Tubing Hanger PIN 2161723-01-0113-5/8" NOM 4-l/2" Butt Top x Bottom with Cameron Type H BPV profile w/ two 3/8" injection lines. SN 11317538 4-l/2" 12.6 lb/ft L-80 AB Modified tbg Gas Lift Mandrels 4-1/2" SFO-2 (see Below) 3.5 PERfORATION DATA Zone Interval HB-l HB-2 HB-3 HB-4 HB-4 HB-4 HB-5 HB-6 HB-7 WF-O WF-O WF-O WF-O WF-l WF-l WF-2 Phoenix "Y" Block SEE SETTING DETAILS CentríJift ESP GC 4100 Assembly (304 hp) N/ A Anode, Motor Centralizer, Phoenix Motor Base Plug Motor Seals, Intake, Pump. See Tbg Setting for Details. 6.000 Baker 9-5/8" SC-IL 6.184 Isolation liner 4 jts and pup. T' 29 Ib/ft L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) 7 10,627.5' 8.437 6.000 Baker Model FA permanent packer (l90FA75) with 6' tieback 8 10,945.7' 8.25 6.312 Baker ZXP liner packer T' x 9-5/8" 9 7.00 6.184 Isolation Liner 5 jts and pup. 7" 291b/ft Butt L-80 casing 10 1l,197,6' 7.00 6.184 Baker Muleshoe Assy.into TIWTBE II 12,351 5.875 4.00 Baker FB-l Packer (Size 85-40) 12 10,537' 5.156 3.813 Otis X landing nipple 13 12,369' 5.093 4.438 TIW LG-6 Tie-back Seals with 'l2 muleshoe GAS LIFT MANDRELS (GLM 4-1/2" OD = 7.063 lD = 3.833): 2,017'; 3,448'; 4,735'; 5,813'; 6,489'; 7,075'; 7,599'; 8,144'; 8,550'; 10,440.3 ' Zone G-l G-2 G-2 G-3 G-4 G-4 G-5 G-5 G-l G-2 G-2 G-3 G-4 G-4 G·5 Interval 10632-10658 10684-10710 10720-10774 10792-10822 10840-10850 10858-10888 10964-10994 1l012-11037 10638-10658 10690-10705 10720-10740 10790-10820 10840-10850 10858-10888 10965-10990 5A 6A 8,250 5.130 3 8.460 7.00 Date 12/5/97 12/5/97 12/5/97 12/5/97 11/9/93 11/9/93 1l/7/93 11/7/93 9/13/99 9/l3/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 3,958 3.833 Date 11206-11246 Jl266-11276 lJ 430-lJ 470 lJ480-11500 Jl51O-11530 lJ540-11550 11570-11590 11722-11742 11764-11788 11815-11831 11836-11841 lJ 848-11858 11865-11875 11912-11922 lJ 930-11950 11966-11976 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 .. Well Name M-28 Primary Job Type ESP Jobs ADL0018730 I Primary Well bore Affected Original Hole Daily Operations 9/11/200500:00 - 9/12/2005 00:00 Operations Summary Start Rig-Up Operations. 9/12/200500:00 - 9/13/2005 00:00 Summary Continue Rig-Up Operations. 9/13/200500:00 - 9/14/2005 00:00 Summary Continue Rig-Up Operaions. 9/14/200500:00 - 9/15/2005 00:00 Summary New crew orientation. Continue Rig-Up Opera ions. 9/15/200500:00·9/16/200500:00 Summary Mix 3% KCL fluid. Hook-up choke lines. 9/16/200500:00·9/17/200500:00 Summary ¡ Attempt to circulate well thru ESP assembly. Low pump rate. R/U to punch holes in tubing. 19/17/200500:00 - 9/1812005 00:00 '.. Operations Summary Punch holes in tubing from 10,020'-26. Circulate well to 3% KCL FIW. 9/18/200500:00 - 9/19/2005 00:00 t Operations Summary 1 Test BOPE to 3000/250 psi OK. Hold floor drills, Pull 4-1/2" tubing and ESP assembly filling hole with 3% KCL FIW. J 9/19/200500:00 - 9/20/2005 00:00 . Operations Summary Œ POOH with ESP assembly. ~ 9/20/200500:00 - 9/21/2005 00:00 rl Operations Summary t Reconfigure BOP stack for drill pipe clean-out and re-test BOPE to 3000/250 psi OK. ¡ , 9/21/2005 00:00 ·9/22/2005 00:00 Operations Summary : P/U 5" drill pipe. 9/22/2005 00:00 ·9/23/2005 00:00 Summary RIH and clean-out casing to 11,645' with 3% KCL FIW. 9/23/2005 00:00 - 9/24/2005 00:00 Summary Change top rams from 5" to 4-1/2" and test to 3000/250 psi OK. P/U ESP assembly and RIH on 4-112" tubing. 9/24/2005 00:00 - 9/25/2005 00:00 I Operations Summary Continue running ESP assembly. 9/25/2005 00:00 - 9/26/2005 00:00 ~ Operations Summary ~ Land and test tubing hanger. N/D BOPE. N/U and test tree to 5000/250 psi OK. Start to rig down. ~ 9/26/200500:00 - 9/27/200500:00 :j Operations Summary ì RD/MO 9/27/200500:00 - 9/28/200500:00 Summary RD/MO 9/28/200500:00 - 9/29/2005 00:00 Summary RD/MO Re: e e .~~..;.;~" Sub.iect: Re: From: James Regg <jim_rcgg@admin.state.ak.lls> ~q q(~1oÇ Date: Fri, 30 Scp 2005 14:09:25 -0800 To: "Payment,Glcn A" <paymega@unocal.cQm>' ......... . .':::' .... . CC: Boh Fleckenstein <hoh _ flcckenstein@admin.state.ak.us:>,Admin AOGqC Prudhoe Bay <aogcc -prudhoe _ baY@admin.statc.ak.lls> ' We are waiving witness of the SSV test on M-28. Please send us a copy of the report when finished testing. Jim Regg AOGCC Payment, Glen A wrote: Jim I Robert We need to do a surface safety valve test for M-28, which is an ESP oil well on the Steelhead that was down the last time your guys were out to witness safety valves. It was brought on 9-27-05 and is now stable. If you need it witnessed, please let one of your guys know so we can make arrangements. We plan to test it tomorrow afternoon. Glen Payment Production Foreman, Steel head Union Oil Company of California Chevron North America Exploration and Production Company 909 West 9th Avenue, Anchorage AK 99501 Tel 907 776-6836 Fax 907 776-6835 .Q£Ymeqa@chevron.com . ... .. . Çj 2l1\.Y5 M~Ç-'\ t~û\l CJ 5>ç~~-.¡¡&t . 1 of 1 9/30/2005 2:09 PM ( STATE OF ALASKA r- '1-:8 ;Of}!::f''''\r-" 1.- ALA~.,A OIL AND GAS CONSERVATION COMMI::.$ION ~- ~,. 1:.: j VE: f(c:..{ f( APPLICATION FOR SUNDRY APPROVAL SfP () 6 2005«<'.,1 20 AAC 25.280 "i~b,,,',, ...... ' Operational shutdown U Perforate U '-.¡"'~ UWáìvi¥::tl_ ..,. ", Other LJ Plug Perforations D Stimulate D Time Extensj~n,:,d-:'.·"."'~R~MQ~)kåii~ Perforate New Pool D Re-enter Suspended Well 0-';';; ESP 4. Current Well Class: 5. Permit to Drill Number: Exploratory D 190-019 ,~ Service D 6. API Number: V 50-733-20414 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: 1. Type of Request: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 160' KB to MSL 8. Property Designation: Trading Bay Unit, Steel head Platform 11. Total Depth MD (ft): 13,000' Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 10,801' Length Suspend U Repair well D Pull Tubing 0 Development Stratigraphic o D 9. Well Name and Number: M-28 10. Field/Pools( s): McArthur River Field. G/Hemlock/West Foreland PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12,952 10,751 None TVD Bu~t Size MD 16" 1,447' 13-3/8" 4,590' 10-3/8"/9-5/8" 11,399' 7" 12,448' 5" 13,000' 1 ,447' 4,590' 11,399' 1,255' 632' Perforation Depth TVD (ft): See attached schematic Perforation Depth MD (ft): See attached schematic Packers and SSSV Type: None 12. Attachments: Description Summary of Proposal LJ Schematic 0 BOP Sketch 0 Junk (measured): logging tool 12,880' Collapse 1 ,443' 4,030' 9,333' 10,265' 10,801' Tubing Grade: 3,090 psi 1,540 psi 6,870 psi 4,760 psi 8,160 psi 7,020 psi 9,910 psi 10,490 psi Tubing MD (ft): 10167' L-80 Packers and SSSV MD (ft): N/A 13. Well Class after proposed work: Exploratory D Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas D Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D 14. Estimated Date for Commencing Operations: 9/15/2005 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster 907-263-7853 Printed Name Tim Brandenburg Title Drilling Manager Signature ·7.... ~~I ~ Phone 907-276-7600 Date '7 -7 -oS ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ~ ~ Sundry Number: :9 C> ~ -- db :1-. Ù ~\~,,~~~ &~~~ Otê..~\~J Plug Integrity D BOP Test A. Mechanical Integrity Test D Location Clearance D Other. ()~~l.\o....,,> .1,0 \"rt.CJ:>~ \~ Ú.L'O~.......' D~ ~'::> ~ S'? \No~~ \' ~ Uc.~ ,.H.....Ic. . Ö ~.;\ ~ ~ -\e,,::>~ o...,,~\ o.~. APPROVED BY ~ COMMISSIONER THE COMMISSION o RIG I N A L ~\ RB£Yn-S ~~ I Date: . r; ¡,4r P, ¡~ Form 10-403 Revised 11/2004 Submit in Duplicate UNOCALe ~ Steelhead Platform Well M-28 Well Clean-Out OBJECTIVE: Pull the ESP. RIH with clean-out assembly. Re-Run ESP assembly. PROCEDURE SUMMARY: 1. Turn off cathodic protection system. 2. Circulate well with filtered inlet water. 3. Set BPV and N/D tree on Well M-28. N/U and test 16-3/4" BOPE (see attached diagram) to 25013,000 psi. Note: To streamline and optimize the rig up, we would like to use 2" 5K flanged rubber hoses for our choke and kill lines to the stack. We would like to run blind rams not blind/shear rams in the lower double gate (we do not have nor have any blind/shear rams been manufactured for the 16-3/4" stack) 4. Verify well dead. 5. POH wi tubing, cable & ESP. Visually inspect tubing & LID singles while POH. 6. RIH with 6" clean-out assembly to knock out bridge and clean out across existing perforations. Circulate well clean. POOH. 7. Rill wi Y-block and ESP assembly. 8. Install BPV. N/D BOPE. N/U & test tree. 9. Install flow line and surface facilities & turn well over to Production. Turn platfonn cathodic protection back on. 10. Startup ESP. AOGCC M-28 ESP Workover Summary 1 of 1 September 1, 2005 71.81' Rig Sub Grating Upper well Bay Floor M-28 16 3/4" BOP Stack up Top of Rotarv Table KB= 71.81' Drip Pan 36.25' -.~. 5.85 . ~ r 163J4"5M" 6.75' Hydril Annular 15.98 5.40' 21.22 23.45 ~....,., ....... 1:':jt3i4¡ti~~f;~.. '.":..'.. . :'," ,,.',"1',, ",I,. l', ~':' '·':·.·:.1;,.'I,I'M'I~J~I'ê'I,.':";r,I""':'·II,, ¡::'. . ".: ,:, "i' .,'"',;::',,,',,':., ',"........ ',.': ,,, ,', t.',,', I ,." "'\,',f;"i~~;4~:~;~\;':; '. '" : I.·.·'.··,,}, .: '~,\~¡#_~\ï\f, 18;:1:.: 29.69 23.47' 12.51' R-54 1"1 L...".'...·...:...:..,,1.....i.5....:œ......'..:.'....'.'.'....1..1...,. ~;,:",;; ,;,:",'1::J~"-,I,,, R 54 ',t____ rH11~!5M'!" k-n LJ-+T~~~P<iÞ'MJ I I Top of 11" 5 M Tbg Spool 59.76' If Steelhead UNOCALe Well No. M-28 Actual of 4/10/05 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. ~ ~ 26" 267/397 DriI-Quip Surf 990' ~ 16" 75 K-55 Buttress Surf 1,445 ' 3 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' L ~ 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193 ' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' 4 Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,167' 5 6. 7 ,. Casing Leak 10466' DIL Squeezed with 100 sx cement JEWELRY DETAIL 8 c = Squeeze Perfs -i: 10620-10623' rI: G Perfs 5 9 10 "Bad" casing at 11035' II L 11 lHem,ock. - Fish-at 11931' - W. Foreland Perf. 5-7/8" junk 11i11, 4-3/4" bit sub, 6-1!j6" s. mill, 4-3/4" XO, Total length 14.37' = - <C:e ~ g~12 14 - - - Jurassic Peri. - o STRESSFRAC Tool @12,880' ,/ ......... PBTD = 12,952' TD = 13,000' MAX HOLE ANGLE = 41.7 NO. I Depth 72.06' 2 3 2196' 4 5 10060' 10167' 6 7 10440.3 ' 8 9 10 11 12 13 14 10627.5' 10945.7' 11197.6' 12351 10537' 12369' Zone G-l G-2 G-2 G-3 G-4 G-4 G-5 G-5 G-l G-2 G-2 G-3 G-4 G-4 G-5 OD 13.625 4.500 7,031 5.130 5.62 8.460 7.00 8.437 8.25 7.00 7.00 5,875 5.156 5.093 Interval 10632-10658 10684-10710 10720-10774 10792-10822 10840-10850 10858-10888 10964-10994 11012-11037 10638-10658 10690-10705 10720-10740 10790-10820 10840-10850 10858-10888 10965-10990 ID 3.902 3,958 3.833 6.000 6.184 6.000 6.312 6.184 6.184 4.00 3.813 4.438 Item Cameron Tubing Hanger PIN 2161723-01-0 I 13-5/8" NOM 4-112" Butt Top x Bottom with Cameron Type H BPV profile wI two 3/8" injection lines. 4-1/2" 12.61b/ft L-80 AB Modified tbg 2,017',3,448',4,735' Gas Lift Mandrels 4-1/2" SFO-2 located at 5,811', 6,485', 7,071', 7,595',8,139',8,545' Centrilift ESP GC 4100 Assembly (304 hp) Anode, Motor Centralizer, Phoenix Motor Base Plug Motor Seals, Intake, Pump, See Tbg Setting for Details, Baker 9-5/8" SC-I L Isolation liner 4 jts and pup. 7" 29 Ib/ft L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) Baker Model FA permanent packer (190FA75) with 6' tieback Baker ZXP liner packer 7" x 9-5/8" Isolation Liner 5 jts and pup. 7" 29 Ib/ft Butt L-80 casing Baker Muleshoe Assy.into TIW TBE Baker FB-I Packer (Size 85-40) Otis X landing nipple TIW LG-6 Tie-back Seals with Y2 muleshoe N/A PERFORATION DATA Date Zone 12/5/97 HB-l 12/5/97 HB-2 12/5/97 HB-3 12/5/97 HB-4 11/9/93 HB-4 11/9/93 HB-4 11/7/93 HB-5 11/7 /93 HB-6 9/13/99 HB-7 9/13/99 WF-O 9/13/99 WF-O 9/13/99 WF-O 9/13/99 WF-O 9/13/99 WF-l 9/13/99 WF-l WF-2 Jur Jur Jur Jur Interval 11206-11246 11266-11276 11430-11470 11480-11500 11510-11530 11540-11550 11570-11590 11722-11742 11764-11788 11815-11831 11836-11841 11848-11858 11865-11875 11912-11922 11930-11950 11966-11976 12655-12675 12675-12748 12748-12808 12810-12900 Date 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 1/2/92 1/2/92 1/2/92 1/2/92 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAY 1 0 2005 1 , Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing [] Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3, Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 160' KB to MSL B, Property Designation: Trading Bay Unit, Steelhead Platform 11. Present Well Condition Summary: Total Depth measured 13,000' true vertical 10,801' Effective Depth measured 12,952' true vertical 10,751' Length Size Casing Structural Conductor 1,447' Surface 4,590' Intermediate 11,399' Production 1,255' Liner 632' 16" 13-3/8" 1 0-3/8"/9-5/8" 7" 5" Stimulate U AlonrQ!tß Gß¡!6JeMfc{¡JommissionJ Waiver D Time Extension D AnchofBWè Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 190-019 Service D 6. API Number: 50-733-20414 9. Well Name and Number: M-28 10, Field/Pool(s): McArthur River Field, G Zone, Hemlock, West Foreland Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development D Stratigraphic D feet feet Plugs (measured) none Junk (measured) 5-7/8" junk mill at 11,981 feet feet MD Burst Collapse TVD 1,447' 4,590' 11,399' 12,448' 13,000' 1 ,443' 4,030' 9,333' 10,265' 10,801' 3,090 psi 6,870 psi 8,160 psi 9,910 psi :sr;;{id~H:'6Lb"-:) LI¡¡ 'iI¡'V ". ~ Li"'U '\'I ð "d ¡ç; 11..· !tu.J..¡ ,j 1 1 1,540 psi 4,760 psi 7,020 psi 10,490 psi 2DU5 True Vertical depth: Measured depth: Too many intervals to list. See Schematic Attached Perforation depth: Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6#, L-80 @ 10,167' n/a 13. Treatment descriptions including volumes used and final pressure: RBDMs SFt MAY] 1 2005 Prior to well operation: 260 Subsequent to operation: 291 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 20 3131 75 290 2615 73 15. Well Class after proposed work: Exploratory n Development r:ïl 16. Well Status after proposed work: Oil[] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl x Contact Larry Buster Printed Name _Timo, thy C. Brandenb~ Q Signature é¿ c..-/) /" Form 1 0-404 Revised 04/2004 Tubing Pressure 76 75 Service n GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-052 Title Drilling Manager Phone 907-276-7600 Date 5/10/2005 (; \..... } ,: ,:\ L () ¡ ¡'J ¡-, Submit Original Only Steelhead UNOCALe Well No. M-28 Actual of 4/10/05 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. L¿ ~ 26" 267/397 Dril-Quip Surf 990' ~ 16" 75 K-55 Buttress Surf 1,445' 3 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' L ~ 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193 ' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' 4 Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,167' : : . . 1- D1=, '."..,..",. i.~" 11'=.: '~I .~: 5 6. 7 ,. Casing Leak 10466' DIL Squeezed with 100 sx cement JEWELRY DETAIL = Squeeze Perfs j 10620-10623' 8 ~ 5 G Perfs 9 "Bad" casing at 10 11035' a 11 lHem,OCk. L - Fish- at 11931' - W. Foreland Perf. 5-7/8" junk Tlill, 4-3/4" bit sub, 6-1!j6" s. mill, 4-3/4" XO, Total length 14.37' = - ~ If ·'¿3,·..::"M 12 ð't..., ~ 14. - - Jurassic Perf. - ,-,. ,.~ STRESSFRAC Tool @12,880' /' " PBTD = 12,952' TD = 13,000' MAX HOLE ANGLE = 41.7 NO. Depth OD ID Item 1 72.06' 13.625 3.902 Cameron Tubing Hanger PIN 2161723-01-01 13-5/8" NOM 4-1/2" Butt Top x Bottom with Cameron Type H BPV profile wi two 3/8" injection lines. 2 2196' 4.500 3.958 4-1/2" 12.6Ib/ft L-80 AB Modified tbg 2,017',3,448',4,735' 3 7.031 3.833 Gas Lift Mandrels 4-1/2" SFO-2 located at 5,811', 6,485', 7,071', 7,595',8,139',8,545' 4 10060 ' 5.130 Centrilift ESP GC 4100 Assembly (304 hp) 5 10167' 5.62 N/A Anode, Motor Centralizer, Phoenix Motor Base Plug Motor Seals, Intake, Pump. See Tbg Setting for Details. 6 10440.3' 8.460 6.000 Baker 9-5/8" SC-l L 7 7.00 6.184 Isolation liner 4 jts and pup. 7" 29 lb/ft L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) 8 10627.5' 8.437 6.000 Baker Model FA pennanent packer (190FA75) with 6' tieback 9 10945.7' 8.25 6.312 Baker ZXP liner packer 7" x 9-5/8" 10 7.00 6.184 Isolation Liner 5 jts and pup. 7" 29 lb/ft Butt L-80 casing 11 11197.6' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE 12 12351 5.875 4.00 Baker FB-l Packer (Size 85-40) 13 10537' 5.156 3.813 Otis X landing nipple 14 12369' 5.093 4.438 TIW LG-6 Tie-back Seals with Y2 muleshoe PERFORATION DATA Zone Interval Date Zone Interval Date G-1 10632-10658 12/5/97 HB-1 11206-11246 9/13/99 G-2 10684-10710 12/5/97 HB-2 11266-11276 9/13/99 G-2 10720-10774 12/5/97 HB-3 11430-11470 9/13/99 G-3 10792-10822 12/5/97 HB-4 11480-11500 9/13/99 G-4 10840-10850 11/9/93 HB-4 11510-11530 9/13/99 G-4 10858-10888 11/9/93 HB-4 11540-11550 9/13/99 G-5 10964-10994 11/7/93 HB-5 11570-11590 9/13/99 G-5 11012-11037 11/7/93 HB-6 11722-11742 9/13/99 G-1 10638-10658 9/13/99 HB-7 11764-11788 9/13/99 G-2 10690-10705 9/13/99 WF-O 11815-11831 8/14/92 G-2 10720-10740 9/13/99 WF-O 11836-11841 8/14/92 G-3 10790-10820 9/13/99 WF-O 11848-11858 8/14/92 G-4 10840-10850 9/13/99 WF-O 11865-11875 8/14/92 G-4 10858-10888 9/13/99 WF-1 11912-11922 8/14/92 G-5 10965-10990 9/13/99 WF-1 11930-11950 8/14/92 WF-2 11966-11976 8/14/92 Jur 12655-12675 1/2/92 Jur 12675-12748 1/2/92 Jur 12748-12808 1/2/92 Jur 12810-12900 1/2/92 4/4/05 NU BO P. Test BOP and related equipment to 250 psi low/3,OOO psi high. PJSM. Pump down tubing with returns from annulus. RD circulating hoses and back out lock down pins. Pull hangar to floor. LD hanger. POH with ESP completion. 4/5/05 Held cable cutting drill. POOH 4 1/2" completion standing back pipe. Break telescoping connection on bottom of Y-block, Lay down 2 3/8" bypass tubing. Lay down ESP top pump section. 4/6/05 Lay down ESP assembly including Y -block. Lay down ESP handling equipment. Make up 5" DP test joint, set test plug, test bottom pipe rams 250 psi low and 3000 psi high, pull plug set wear bushing, PJSM. Pickup BHA. RIH with tu bing. 4/7/05 Clean out 11,104' to 11,654'. Pump 20-25 BBL high-vise sweeps. Pump sweep, drop ball, circulate. Open circ sub. Circulate at 15-17 bpm. Pump 30 bbl high-vise sweep. Displace well with 3% KCLlFIW at 8 bpm. Pump dry job. POH. Stand back 5" DP. Change elevators and continue POH with 4-1/2" tubing. 4/8/05 POH w/4 1/2 tubing, stand back in derrick. Pick up ESP assembly. 4/10/05 RIH with ESP assembly to 3845'. Hook up cable to penetrator. Land hanger with BPV in place. Meg test, run in lock downs. PJSM. Nipple down BOP. Nipple up tree and flowlines, test void and hangar seals 5000 psi, pull BPV set two way check. Test tree. Rig crew cleaning up, had ESP start up meeting with production and prepared to start up ESP. 4/11/05 Release rig. M-28 (AFE 163743) morning report summary, CONFIDENTIAL: last revised 5/10/2005, Page 1. ) ~\ .1í~!ð\ v.Œ: I]J' fj': f rE fÆ/ß"'\" r-Li1 ffi/fi ~ (~ \~~I( /A;r~~~\ , !J": 1\ [ lit; , :1 ¡ "[lj'\)i!\' I,' '~ L! W \ I !: ~ ,':~. L: ,!, r \ i~1 )' )" 1 :' / '\ \ ) / 90 ~ 1)(1 FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL Al'VD GAS CONSERVATION COMMISSION / j 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: McArthur River M-28 Sundry Number: 305-052 Dear Mr. Brandenburg: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to supe.:0' or u unless rehearing has been requested. ~ nc ~ , / .~ . JO . . N an,- aIrman DATED this$ day of February, 2005 Encl. SÇANNED MAR 0 2 2.DD5 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 160' KB to MSL 1. Type of Request: 8. Property Designation: Trading Bay Unit, Steel head Platform 11. Total Depth MD (ft): 13000' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): See attached schematic Packers and SSSV Type: None 12. Attachments: Schematic 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Total Depth TVD (ft): 10801 ' Length 1447' 4590' 11399' 1255' STATE OF ALASKA ALA...,...A Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing 0 Perforate U Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ¿þ/ Exploratory D ~J-1'9 D 6. API Number: 50-733-20414 Other lJ Replace Failed ESP Development Stratigraphic 0 D Service 9. Well Name and Number: M-28 10. Field/Pools( s): McArthur River Field. G/Hemlock/West Foreland PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12952 10751 Plugs (measured): None Junk (measured): logging tool 12880' Collapse Size MD Burst TVD 16" 1447' 13-3/8" 4590' 10-3/8"/9-5/8" 11399' 7" 12448' 5" 13000' 1443' 4030' 3090 psi 1540 psi 6870 psi 4760 psi 8160 psi 7020 psi 9910 psi 10490 psi Tubing MD (ft): 10113' 9333' 10265' 10801 ' 632' Perforation Depth TVD (ft): Tubing Grade: See attached schematic L-80 Packers and SSSV MD (ft): N/A Description Summary of Proposal lJ 0 BOP Sketch 0 4/5/2005 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D WDSPL 0 Service D D D Abandoned D D Plugged WINJ Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Tim Brandenburg Title Drilling Manager Signature Contact Larry Buster Phone 907-276-7600 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test Form 10-403 Revised 11/2004 Mechanical Integrity Test D Location Clearance D COMMISSIONER APPROVED BY THE COMMISSION Date: Submit in Duplicate OBJECTIVE: Replace the failed ESP assembly currently in Well M-28. PROCEDURE SUMMARY: 1. Shut off gas-lift gas. Bleed down slowly to avoid damaging ESP cable. Turn off cathodic protection system. 2. Circulate oil out of annulus and load well wi 3% KCL. 3. Spot sized salt pill (if necessary) to manage losses and keep hole full while POH and while RIH wi tubing and ESP assembly. 4. Set BPV and N/D tree on Well M-28. N/U and test 16-3/4" BOPE (see attached diagram) to 250/3,000 Note: To streamline and optimize the rig up, we would like to use 2" 5K flanged rubber hoses for our choke and kill lines to the stack. We would like to run blind rams not blindlshear rams in the lower double gate (we do not have nor have any blindlshear rams been manufactured for the 16-314" stack) 5. Verify well dead. 6. POH wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POH. Send failed ESP equipment & unusable tubing to shore. 7. If clean-out is required. RIH with 5-7/8" clean-out string to clean out across existing perforations. Spot acid across perforations if required to clean-up. Circulate acid out and re- spot sized salt pill as required. POOH. 8. RIH wi replacement ESP assembly similar to the current failed completion (see attached diagram). 9. Install BPV. N/D BOPE. N/U & test tree. 10. Install flow line and surface facilities & turn well over to Production. Turn platfonn cathodic protection back on. 11. Startup ESP. AOGCC M-28 ESP Workover Summary 1 of 1 February 17, 2005 L¿: ¿: '~~ 4\ iJ 6 7 8 9 IlL ~ 1() 11 12 L ~ 26" 267/397 ~ 16" 75 K-55 3 13-3/8" 61/68 K-55 ~ 10-3/4" 51/55 N-80 9-5/8" 47 N-80 7" 29 N-80 5" 18 N-80 Tubing: 4-1/2" 12.6 L-80 Dril-Quip Surf 990' Buttress Surf 1,445' Buttress 12.415 Surf 4,590' Buttress 9.604 Surf 497' Buttress 8.681 497' 11,399' Buttress 6.184 11,193' 12,448' FL4S 4.276 12,368' 13,000' AB Mod 3.958 Surf 10,091' , Casing leak 10466' Dll Squeezed with 100 sx cement = Squeeze Perfs - 10620-10623' ~ G Perfs "Bad" casing at 11035' Œ>K\ :, -: Hemlock. 9-- "..,~.. ~ 1-' Fish- at 11931' ~ W. Foreland Perf. 5-7/8" junk llill, 4-3/4" bit sub, 6-1:J6" s. mill, 4-3/4" XO, Total length 14.37' = c:=:::8 L:J 14 () 0 - F~i 13 ..~ 15 - - ;;; Jurassic Perf. STRESSFRAC Tool @12,880' /" "'- PBTD = 12,952' TD = 13,000' MAX HOLE ANGLE = 41.7 72.06' 13.625 3.902 Cameron Tubing Hanger PIN 2161723-01-01 ] 3-5/8" NOM 4- 1/2" Butt Top x Bottom with Cameron Type H BPV profile wi two 3/8" injection lines. SN ] 13] 7538 2 2]96' 4.500 3.958 4- 1/2" 12.6 ]b/ft L-80 AB Modified tbg 3 7.03] 3.833 Gas Lift Mandrels 4- 1/2" SFO-2 located at 2] 96' ,3615' 4550', 5399',6130',6701',72]3', & 7759'. 4 ]0098 8.250 3.5 Phoenix "Y" Block 5 ]0] ]3' 5.]30 Centrilift ESP GC 4]00 Assemb]y (304 hp) 6 ]0]96 3 NIA Anode, Motor Centralizer, Phoenix Motor Base Plug Motor Seals, Intake, Pump. See Thg Setting for Details. 7 10440.3' 8.460 6.000 Baker 9-5/8" SC-]L 8 7.00 6.184 Isolation liner 4 jts and pup. 7" 29 Iblft L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) 9 10627.5' 8.437 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 10 10945.7' 8.25 6.312 Baker ZXP liner packer 7" x 9-5/8" 11 7.00 6.184 Isolation Liner 5 jts and pup. 7" 29 Ib/ft Butt L-80 casing 12 11197.6' 7.00 6.184 Baker Muleshoe Assy.into TIW TBE 13 12351 5.875 4.00 Baker FB-] Packer (Size 85-40) ]4 ]0537' 5. ]56 3.813 Otis X landing nipple 15 12369' 5.093 4.438 TIW LG-6 Tie-back Seals with Yz mu]eshoe Zone Interval Date Zone Interval Date G-l 10632-10658 12/5/97 HB-l 11206-11246 9/13/99 G-2 10684-10710 12/5/97 HB-2 11266-11276 9/13/99 G-2 10720-10774 12/5/97 HB-3 11430-11470 9/13/99 G-3 10792-10822 12/5/97 HB-4 11480-11500 9/13/99 G-4 10840-10850 11/9/93 HB-4 11510-11530 9/13/99 G-4 10858-10888 11/9/93 HB-4 11540-11550 9/13/99 G-5 10964-10994 11/7 /93 HB-5 11570-11590 9/13/99 G-5 11012-11037 11/7 /93 HB-6 11722-11742 9/13/99 G-l 10638-10658 9/13/99 HB-7 11 764- 11 788 9/13/99 G-2 10690-10705 9/13/99 WF-O 11815-11831 8/14/92 G-2 10720-10740 9/13/99 WF-O 11836-11841 8/14/92 G-3 10790-10820 9/13/99 WF-O 11848-11858 8/14/92 G-4 10840-10850 9/13/99 WF-O 11865-11875 8/14/92 G-4 10858-10888 9/13/99 WF-l 11912-11922 8/14/92 G-5 10965-10990 9/13/99 WF-l 11930-11950 8/14/92 \VF - 2 11966-11976 8/14/92 Jur 12655-12675 1/2/92 Jm 12675-12748 1/2/92 Jm 12748-12808 1/2/92 Jm 12810-12900 1/2/92 '. 71.81' ~......~~ Rig Sub Grating Upper well Bay Floor " .. Top of Rotarv Table KB= 71.81' " 'J.' 'J.!. . '--A----'-' Á Drip Pan 5.85 '" 6.75' (' 163/4" 5M " Hydril Annular 15.98 5.40' l .J BX 162 ""\ r .... 21.22 16314" 10M HydrilÐBLGiate r::::;;: nk',~lIijj,¡t¡¡¡'tinl'U\ÌIII"j:;'\¡¡U\'td'~""';¡:r,"M ::::.;:] ~1~~1I!1~!)j';i~~1!~¡t~~~~~~ 6.0.3' , .. .. ./j ~I r 23.45 I~;f~,!,:\~f, ;:if'\ì_.~~..ìi~;;;1":~Î,~1 !1II\I~~~11 ~ ~ r" [TI])= BX 162 163/4" 10M Mud Cross 2.45' ~ BX 162 I I ALL Wing valves 3" 5M ""\ 1~_1~:, r ,. EIi"~:"I"¡''''''I'!I""""",,''1..iItAI'....._~ '\~I';W;,~\:' ''¡''~",!\Ii,-'''''~ê",.,,,,,,,.Jjf'!!mr,,.,,,:......., ,\ . "". ...' ...., ::.:. ~ ~ V~ J BX 162 I I 29.69 Spool added for ESP Completion 1.50' i1"/iM X 11"5'" Top of 11" 5 M Tbg Spool 23.47' 12.51' BX 162 .60' J.. 36.25' 59.76' .. Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950 l Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant 6/I 7/2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - HAPPY VALLEY #1 ARRAY INDUCTION DIPOLE SHEAR ~ SONICTOOL TVD*PEX* 5 INCH 7/1/2003 4008-9680 1 1 1 ARRAY INDUCTION DIPOLE SHEAR SONIC TOOL *PEX* 2/5 INCH 7/1/2003 4314-10841 1 1 1 DIPOLE SHEAR SONIC TOOL P&S STONELEY BCR MODES 2/5 INCH 7/1/2003 4314-10841 1 1 1 --- ~ DIPOLE SHEAR SONIC TOOL P&S, STONELEY AND BCR MODES TVD 5 INCH 7/1/2003 4008-9680 1 1 1 DML-MWD COMBO LOG 2 INCH 6/16/2003 122-10871 1 1 DRILLING DYNAMICS LOG 2 INCH 6/16/2003 122-10871 1 1 EPOCH FINAL WELL REPORT 2 INCH 6/15/2003 1 1 FORMATION LOG 2 INCH 6/16/2003 122-10871 1 1 1 // INTEGRATED HOLE AND CEMENET / VOLUMELOG 2 INCH 7/1/2003 4314-10841 1 1 1 / STEELHEAD - M-28 %'-"::~".,~ a:~'fftfV:.,;C--'.,'..ff'~:i-' ~. . .. ':..:,:.:...,t:r¢:,,;,:.'..'-:~::t?,'"'.'~:LOu TYPE :." '" ' "'~; "1 SCALE ]'::',DATE.". ,[ INTERVAL"' COMPLETION RECORD ' 1'56" HSD I I POWERJET 5 INCH 6/21/2003 9600-11270 ' B-[INE"'I, FILM' ] .':'CD 'l PAPER"'] 2 1 1 i(~ }CC:-'[ RECEIVED JUL 1 4 200:5 Aia~ka Oi'; & Gas Cons. Commieeion. -. Rlease acknowl.e,(J.g,e,.receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. STATE OF ALASKA ALASKA. OIL AND GAS CONSERVATIONC -MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: X Repair ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 160' KB to M5L feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 19-0247 Anchorage, AK. 99519-0247 Stratigraphic: Trading Bay Unit Service: Steelhead Platform 4. Location of well at surface 8. Well number 970' FNL, 532' FWL, Sec 33-9N-13W-SM ~ M-28 9' Permit numl~eb At top of productive interval ~ '~- ;; ~,C I -J ~ "' 150' FNL, 2333' FEL Sec 28-9N13W-SM At effective depth 10. APl number 90' FNL, 2335' FEL, Sec 28-9N-13W-SM 50-733-20414 At total depth 11. Field/Pool 85' FNL, 2331' FEL, Sec 28-9N-13W-SM MRF G/Hemlock/West Foreland 12. Present well condition summary Total depth: measured 1,300 feet. Plugs (measured) None true vertical 10,801 feet Effective depth: measured 12,952 feet Junk (measured) Stresspac Logging Tool at 12,880' MD true vertical 10,751 feet Casing Length Size Cemeylted Measured depth True vertical depth Structural Conductor 1447 16" 1800 sx 1 447' 1443' Surface 4590 13-3/8" 2900 sx 4590' 4030' Production 11399 10-318"/9-518" 3360 sx 11399' 9333' Production 12448 7" 400 sx 12448' 10265' Liner " 13000 5" · 136 sx 13000' 0 Perforation depth: measured true vertical SEE ATTACHED Tubing (size, grade, and measured depth) 4-1/2" 12.6~, L-80, AB Mod {~10,091' Packers and SSSV (type and measured depth) See Attached We#bore Schematic 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used end final pressure 14. Representative Daily Averaee Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 337 30 2471 76 77 Subsequent to operation 336 100 2718 979 104 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Jim Mosley ~-~ ~ ~~ Title: Drilling Engineer Date: I -. Form 10-404 Rev 06/15/88 ORIGINAL RBBNS BFL /9 SUBMIT IN DUPLICATE Perforation Data, M-28 lone Interval TVD (~ top Date G-1 10632-10658 8,692 12/5/1997 G-2 10684-10710 8732 12/5/1997 G-2 10720-10774 8760 12/5/1997 G-3 10792-10822 8817 12/5/~1997 G-4 10840-10850 8855 11/9/1993 G-4 10858-10888 8869 11/9/1993 G-5 10964-10994 8954 11/7/1993 G-5 11012-11037 8993 11/7/1993 G-1 10638-10658 8696 9/13/1999 G-2 10690-10705 8737 9/13/1999 G-2 10720-10740 8760, 9/13/1999 G-3 10790-10820 8815 9fl 3/1999 G-4 10840-10850 8855 9/13/1999 G-4 10858-10888 8869 9/13/1999 G-5 10965-10990 8955 9/13/1999 HB-1 11206-11246 9149 9/13F1~999 HB-2 11266-11276 9199 9/13/1999 HB-3 11430-11470 9337 9/13/1999 HB-4 11480-11500 9380 9/13/1999 HB-4 - 11510-11530 9406 9/:~3/1999 HB-4 11540-11550 9432 9/13/1999 HB-5 11570-11590 9458 9/13/1999 HB-6 11722-11742 9592 9/13/1999 HB-7 11764-11788 9629 9/13/1999 WF-0 11815-11831 9675 8/14/1992 WF-0 11836-11841 9693 8/14/1992 WF-0 11848-11858 9704 8/14/1992 WF-0 11865-11875 9720 8/14/1992 WF-1 11912-11922 9763 8/14/1992 WF-1 11930-11950 9779 8/14/1992 WF-2 11966-11976 9812 8/14/1992 Jur 12655-12675 10461 1/2/1992 Jur 12675-12748 10480 1/2/1992 Jur 12748-12808 10551 1/2/1992 Jur 12810-12900 10611 1/2/1992 9 10 11931' 5-7~8" junk mill, 4-3/4" bit sub, 6- 1/16" s. UNOCALe Head = 7t.4' Casing Leak 10, Squeeze Perfs 10620-10623' G Perfs "Bad" casing at 11035' -- Hemlock. W. Foreland Per 11 Jurassic Perf. STRESSFRAC Tool ~12,880' PBTD = t2,952' TD = 13,000' MAX HOLE ANGLE = 41.7 Steelhead Well No. M-28 Actual Completion 11-25-02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,091' ~66' DIL Saueezed with 100 sx cement JEWELRY DETAIL NO. Depth OD ID 1 72.06' ~13.625 3.902 2 2196' 4.500 3 7.031 4 10098 8.250,' 5 10113' 5.130 6 10196 3 5 10440.3' 8.460 6 7.00 7 10627.5' ~437 8 10945.7' 8.25 9 7.00 10 11197.6' 7.00 11 12351 5.875 12 10537' 5.156 13 12369' 5.093 Item Cameron Tubing Hanger P/N 2161723-01-01 13-5/8" NOM 4-1/2" Butt Top x Bottom with Cameron Type H BPV profile w/ two 3/8" injection lines. SN 11317538 3.958 4-1/2" 12.6 lb/ft L-80 AB Modified tbg 3.833 Gas Lit~ Mandrels 4-1/2" SFO-2 located at 2196',3615' 4550', 5399', 6130', 6701', 7213', & 7759'. 3.5 Phoenix "Y" Block Centrilift ESP CrC 4100 Assembly (304 hp) N/A Anode, Motor Centralizer, Phoenix Motor Base Plug Motor Seals. Intake, Pump. See Tbg Setting for Details. 6.000 Baker 9-5/8" SC-1L 6.184 Isolation liner 4 its and pup. 7" 29 lb/ft L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) 6.000 Baker Model FA permanent packer (190FA75) With 6' tieback 6.312 Baker ZXP liner packer 7" x 9-5/8" 6.184 Isolation Liner 5 jts and pup. 7" 29 lb/ft Butt L-80 casing 6.184 Baker Muleshoe Assy.into TIW TBE 4.00 Baker FB-1 Packer (Size 85-40) 3.813 Otis X landing nipple 4.438 TIW LG-6 Tie-back Seals with ½ muleshoe Zone Interval G-1 10632-10658 G-2 10684-10710 G-2 10720-10774 G-3 10792-10822 G-4 10840-10850 G-4 10858-10888 G-5 10964-10994 G-5 11012-11037 G-1 10638-10658 G-2 10690-10705 G-2 10720-10740 G-3 10790-10820 G-4 10840-10850 G-4 10858-10888 G-5 10965-10990 PERFORATION DATA Date 12/5/97 12/5/97 12/5/97 12/5/97 11/9/93 11/9/93 11/7/93 11/7/93 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 9/13/99 Zone Interval Date HB-1 11206-11246 9/13/99 HB-2 11266-11276 9/13/99 HB-3 11430-11470 9/13/99 HB-4 11480-11500 9/13/99 HB-4 11510-11530 9/13/99 HB-4 11540-11550 9/13/99 HB-5 11570-11590 9/13/99 HB-6 11722-11742 9/13/99 HB-7 11764-11788 9/13/99 WF-0 11815-11831 8/14/92 WF-0 11836-11841 8/14/92 WF-0 11848-11858 8/14/92 WF-0 11865-11875 8/14/92 WF-1 11912-11922 8/14/92 WF-1 11930-11950 8/14/92 WF-2 11966-11976 8/14/92 Jur 12655-12675 1/2/92 Jur 12675-12748 1/2/92 Jur 12748-12808 1/2/92 Jur 12810-12900 1/2/92 11/14/02: Killed well before skidding. 11/15/02: Accepted rig at 03:00. Skidded from M-29 to M-28 and set BPV. Removed tree and NU BOPE. RU to test BOPE. 11/16/02: Tested BOPE. Made up landing jt. Installed TIW valve and pump in sub. Pulled tbg hanger loose and started POOH w/4.5" tbg. 11/17/02: Finished POOH w/tbg & failed ESP. PU csg scraper and SIH. 11 / 18/02: Continued RIH with casing scraper. Tagged bridge in c~sing ~ 10,228'. Pulled up hole to 8396' and RU wireline unit and lubricator. RIH to 10,228, POOH w/LIB, observed markings after inspection indicating sand and scale. RIH w/bailer to 10,228.' POOH. RD wireline unit. Started POOH w/tbg. 11/19/02: Cont. POOH w/tbg. Recovered lost SS bands. RIH w/6" bit to bridge ~ 10,253'. Washed bridges to 11382'. 11/20/02: RIH to 11,741'. Hit hard bridge. POOH w/4 5" tbg. RU to run ESP "Y" block assy w/8 jts 2-3/8" bypass tbg and W/L entry guide. Installed ESP & telescopic nipple. RIH w/4.5" tbg. 11/21/02: Ran ESP "Y" block gas lift assy on 4.5", 12.6# tbg checking conductivity e~very 1000'. Cont to RIH with ESP. 11/22/02: RIH w/4.5" ESP completion to 10,199' Anode depth w/bypass EOT ~ 10,299'. Landed hanger. Installed BPV. RD. ND BOP and rack same. NU tree and flow lines, Pressure test hangar, neck seals and AP1 ring .to 500 psi. Pulled BPV. 11/23/02: RD tbg equipment & turned well over to production. Removed DSA from drilling riser. Performed shut down on accumulator. 11/24/02: Rig deactivation. 11/25/02: Continued rig deactivation 11/26/02: RD/Final Report. Jim Mosley Sr Adv Drlg Eng Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) ~as ~ons. Commissi_o.n Anchorage Friday, August 23, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commissioner Cammy Taylor Re: SUNDRY NOTICE FOR ESP REPAIR ON STEELHEAD M-28 STEELHEAD M-28 Permit # 91-19 APl # 50-733-20414 Dear Commissioner Taylor, Enclosed is a Sundry Notice Form 10-403 asking permission to reperforate selected intervals and repair the ESP pump on the M-28 well. Please find attached the current wellbore schematic. The ESP equipment will be sized the same and the proposed completion will look very similar to the current actual. Our rig schedule indicates that we would anticipate moving onto this workover the 1st of October, 2002. Your timely approval is respectfully requested. If there are any questions, please contact Jim Mosley at 263-7679. JH/jm SK/File Enclosures Sincerely, Jim Mosley Sr Adv Drilling Engineer Unocal Alaska ORI Ik AL ("' 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: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: X Repair ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: X 160' KB to MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface ,~t~e~-l.~ldt, Steelhead Platform 8. Well number 970' FNL, 532' FWL, Sec 33-9N-13W-SM M-28 At top of productive interval 9. Permit number 150' FNL, 2333' FEL, Sec 28-9N-13W-SM J 9,.1,.1.e~V/'' At effective depth 10. APl number 90' FNL, 2335' FEL, Sec 28-9N-13W-SM 50-733-20414- At total depth 11. Field/Pool 85' FNL, 2331' FEL, Sec 28-9N-13W-SM McArthur River Field G/Hemlock/West Foreland 12. Present well condition summary ~' Total depth: measured 13,000' feet /' Plugs (measured) None true vertical 10,801' feet Effective depth: measured 12,952' feet Junk (measured) Stresspac Logging Tool at 12,880' MD true vertical 10,751' feet measured 11931 feet Junk (measured) 5-7/8" junk mill, bit sub, string mill, xo = 14.3 feet true vertical 9780 feet overall length Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,447' 16" 1800 sx 1,447' 1,443' Surface 4,590' 13-3/8" 2900 sx 4,590' 4,030' Intermediate 11,399' 10-3/8"/9-5/8" 3360 sx 11,399' 9,333' Production Liner 12,448' 7" 400 sx 12,448' 10,265' 10.802' Liner 13,000 5" 136 sx 13,000' p,,~ ~..,. Perforation depth: measured (See attachment) ii.~,~,~, ,. ~,,. '-L,.i!~' ~ 'i!~!'. '!,':;'"' true vertical I! ~' h~'' '""~ "" Tubing (size, grade, and measured depth) 4-1/2" 12.6 Ib/ft L-80, Imp Butt at 10,090' with Failed ESP pump and cable Alaska 0it' & ..... ', .~ .... Packers and SSSV (type and measured depth) (See Attachment) 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X Well bore Schematic showing perforations, and proposed ESP placement. 14. Estimated date for commencing operation 15. Status of well classification as: 10/1/2002 16. If pr~Ipg~al well verbally al~proved: Oil: X Gas: ~ Suspended: ---- N Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~,1~ ~ Title: Drilling I~11~!~ ~V~-- Date: ~,'~,/j; FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness '~~ ~:~ ~'~ .~--.~.~,~. IApproval No. Plug integrity BOP Test /'~ Location clearar~ceI ~'~-") Mechanical Integrity Test Subsequent form required 10- ,Approved by order of the Commissioner M L. Bill Commissioner Date Form 10-403 Rev 06/15/88 WORKOVER PROCEDURE SUMMARY: · 2. 3. 4. 5. 6. 7. 8. , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21.'" 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. 34. 35. Pre Rig Activation to include a Gauge Ring Run to near the ESP pump. Activate Rig (Activation included in cost estimate) Prepare rig for Operations (Locate Tree Cap Pulling Tool) Take on and mix kill fluids (1000 bbls of 8.65 Filtered KCL) Shut-off gas lift & bleed SICP to 0 psi (2 days prior to skidding) Be prepared to punch holes in tubing one joint above the pump. Rig up and Skid rig over M-32 (Circulate tubing after skidding over w~ Load tubing and annulus. Attempt to circulate. Spot pill and re-atte to obtain 50 psi on pill. Bleed off tubing & verify dead. Rig up Slickline and run Tubing stop to joint above the punched and set check valve. Make third run and set hold down for ch slickline. Be prepared to tubing punch above the check Install BPV. ND tree/flowline. Inspect hanger threads. NU BOPE USING SWEENEY TORQUE WRENCH Recover BPV, install TWC valve & test BOPE with Recover TWC valve & engage hanger with landing circulate the well with one full circulation taking ret~ Pull hanger loose and circulate one full circulatio~ RU to pull Buttress tubing. Limit pull to 80% of ~w rating. Pull Tbg Hgr to rotary table. Cut BIW LD Hanger and landing joint. RU to power drips. POOH LD Bad tubing. Stand back good Determine ESP Failure Mechanism. Pick up TCP guns with pressure Tbg as needed. Drift all tubing work. RU Eline and RIH to Correlate Position Guns and bar drop fire Monitor Well and if possible necessary. POOH. Fill with 2 times cah pt to circulate. Try Make second run valve. Rig down if necessary. to 3000 psi. ~t. If circulation is possible, to production via wellhead outlets. returns to pits. of guns. POOH & RD Eline guns to Re-Perforate "G" zones as directed. ~late with two circulations of the well spotting pills as displacement if the well will not stand full, otherwise keep the hole full. )ut seal rings on tubing again. RU to Run ESP. Chang )ut Spooler Reels Pickup ESP and RIH clamps and making splices as needed. MEG cable each 1000 feet going into hole. Install CMU sliding sleeve 2 joints above the ESP. Pick up Tbg hange nd splice as needed. Install Penetrator in tubing hanger. Land Tubing :ontrol line and Cable spliced through hanger. LD Landing joi~ RD Tbg Tools Install BPV ND bell ni ND BOPE/& RISER NU ada~er and tree. NU wing valves to tree. Pull BP/V, Install TWC & Shell test tree to 3000 psi.. Turn ~ell over to production Inst~l flowlines & Test Electrical Equipment'. Meg system for baseline. Skid to M-29 Secure and backload all unnecessary parts. ,$t;ANNED SHRT and RIH with Same. PU replacement up or not gauge ringed previously during wireline Use pipe wiper above Rotary. ', & start cable on spool. sh cable and tubing on TOOH to prevent UNOCAL RKB to TBG Head = 71.4' Steelhead Well No. M-28 Actual Completion 5-6-00 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" · 47 N-80 Buttress 8.681 497' 11,399' 7" 29 ~-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,090' 9 10 z :ish- at 11931' 5-7/8' junk mill, Total length 14.37' Casing Leak 10466' DIL Squeezed with 100 sx cement JEWELRY DETAIL : Squeeze Perfs 10620-10623' G Peffs "Bad" casing at 11035' Hemlock. NO. Depth OD ID Item I 72'.06' 13.625 2 455.0' 4.500 3 7.031 7.063 4 10179' 5 10440.3' 8.460 6 7.00 7 10627.5' 8.437 8 10945.7' 8.25 9 g.00 10 11197.6' 7.00 11 12351 5.875 12 10537' 5.156 3.902 Cameron Tubing Hanger P/N 2161723-01-01 13-5/8" NOM 4-1/2" Butt Top x Bottom with Cameron Type H BPV profile 3.958 4-1/2" t2.6 lb/fi L-80 AB Modified tbg 3.833 Camco MMG GLM's w/RK latch (5.625" x 7.031") No. 6-8 At 2457',4422',5582' 3.833 McMurry SFO-2 GLM's w/RK latch (6.141" x 7.063") No. 5-1 at 6374',6888',7404',7950',8470' Centrilifi ESP Assembly (304 hp) 6.000 Baker 9-5/8" SC- 1L 6.184 Isolation liner 4 jts and pup. 7" 29 lb/fi L-80 Butt casing with Baker Anchor Assy KBH-22 (75 x 60) 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 6.312 Baker ZXP liner packer 7" x 9-5/8" 6.184 Isolation Liner 5 jts and pup. 7" 29 lb/fi Butt L-80 casing 6.184 Baker Muleshoe Assy.into TIW TBE 4.00 Baker FB-1 Packer (Size 85-40) 3.813 Otis X landing nipple Jurassic Perf. STRESSFRAC Tool ~12,880' PBTD = 12,952' TD = 13,000' MAX HOLE ANGLE = 41.7 Zone Interval G-1 10632-10658 G-2 10684-10710 G-2 10720-10774 G-3 10792-10822 G-4 10840-10850 G4 10858-10888 G-5 10964-10994 G-5 11012-11037 G-1 10638-10658 G-2 10690-10705 G-2 10720-10740 G-3 10790-10820 G-4 10840-10850 G-4 10858-10888 G-5 10965-10990 PERFORATION DATA Date Zone Interval Date 12/5/97 HB-1 11206-11246 9/13/99 12/5/97 HB-2 11266-11276 9/13/99 12/5/97 HB-3 11430-11470 9/13/99 12/5/97 HB-4 11480-11500 9/13/99 11/9/93 HB-4 11510-11530 9/13/99 11/9/93 HB-4 11540-11550 9/13/99 11/7/93 HB-5 11570-11590 9/13/99 11/7/93 HB-6 11722-11742 9/13/99 9/13/99 HB-7 11764-11788 9/13/99 9/13/99 WF-0 11815-11831 8/14/92 9/13/99 WF-0 11836-11841 8/14/92 9/13/99 WF-0 11848-11858 8/14/92 9/13/99 WF-0 11865-11875 8/14/92 9/13/99 WF-1 11912-11922 8/14/92 9/13/99 WF-1 11930-11950 8/14/92 WF-2 11966-11976 8/14/92 Jur 12655-12675 1/2/92 Jur 12675-12748 1/2/92 Jur 12748-12808 1/2/92 Jur 12810-12900 1/2/92 ~VISION 5 154718-O-00 Steeihead Piat£orm Well # M-28 ESP WO2 Reperforate & Replace ESP Procedure STEELHEAD NIPPLE UP BOPE STACK SCHEMATIC M-28 BOP Stack Double Studded Adapter 16" 5M x 13-5/8" 5M M-28M-28 WO 04-11-02 REVISION 5DOC 2.05' 16-3/4"5M by16-3/4"10M ADAPTER SPOOL 16-3/4"5M by16-3/4"5M SPOOL Top of DCB Spool Page 4 of 47 08/23/02 MEMORANDUM State of Alaska Alaska Oil' and Gas Conservation Commission TO: Mike Bill THRU: Tom Maunder Petroleum Engineer DATE: November 12, 2002 SUBJECT: No-Flow Test Unocal I Steelhead PLT Well M-28 PTD:1900190 x~ Mc, Arthur River Field I TBU FROM: Jeff Jones Petroleum Inspector November 12, 2002: I traveled to Unocal's Steelhead Platform in the McArthur River Field to witness a No-Flow Test on well M-28. Unocal representative Mike Chivers performed the test today in a safe and proficient manner. Well M-28 was lined up from the tree top swab valve through a 1/2" hose to an Armor-Flow model # 3461-0310 flow meter (180 SCFH to 1800 SCFH span) and terminated in an open top drum. The flow. from the well was monitored for 3.5 hours with readings recorded every 30 minutes. Unassisted. gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and as the data below indicates, we!l.M-28 meets the AOGCC requirements for a No-Flow status determination.' Summary: ! witnessed a successful No-Flow Test on Unocal's McArthur River Field well M-28 on the Steelhead Platform in Cook Inlet. Attachments: Well completion schematic (1) CC-' Dwight Johnson I Gary Ross (Unocal) Operator: .............. ~noc~[~ ......... Date 11/12/2002 Op~,i=itor Rep: Mike Chivers AOGCC Rep: ' Jeff Jones Field/Unit/Pad MgF£1'BUIStee!head Well M-28 PTD: 1900190 ........... :.2 Gas Li~uM 3:30 PM 180 SCFH Ga., Cond~te droplets 4:00 PM 260 SCFH Gas Cona_~ate droplets 4:30 PM 340 SCFH Gas Cona_~sate droplets 5:00 PM 370 SCFH Gas Cond_~..~te droplets 5:30 PM 480 SCFH Gas Cona__~sate droplets 6:00 PM 480 SCFH c~.~ Condensate droplets 6:30 PM 500 SCFH Gas ,Condec_ate droplets 7:00 PM 500 SCFH Gas Con&,~n_sate droplets Produced to open top contsi~er throul~h Armor-Flow meter model #3461-0310. Flow meter calibrated by IISCO: 4/16/02 Total liquid p~-oduced: less thsn 1 quart. SCANNED DEC 0 2002 NO-FLOW TBU Steelhead M-28 11-12-02 IJ.xls RIF 09/19/02 Page 1, of 1 :.'..'...: '....::..~... ::.....: ...... ........ .'...:.'. ...::...:: .. ..... ..: .... ... .... ,.......:.... ....... ............,............................:.....,..'.:.......:........................'.'..:' , , . ....:...: :'...::. .. .;...:.:::. .. ' .. · ':'".:: ' ': ".'". '"" :"'.'~':: :.'i:.':::. :..::i.'.;:':.;' :;i '.::;..;.: · .......... !.470 ..,. :'!i!i'::/:!.':: MAX HOLE ANGLE '-" 41.7'i:'.'-.'.'.:: ::..i.}::!.:.:..':.':..:.:...!:::':.;::::.:.':.:..':). '.2: '.'.:" ':.'.'..:'.'. :':::.:.:.:'.. .. !!)-.'t)~,)- l ~):',;2.'..I .'q:.:.:.: :'::' 1!).'441,.1~!84,} :i 'i'::.'::i:!':.:f!:: ... ...-,-.:'::.:::. .... !,~,.,(;.~-~:),.~,)~ ::.:;: "i....Q. ...... ......5 : .:.'.i:'i')i'.. .... ' '-"""."' ;i. i 1912-1 ,o", M-28 Procedure Subject: M-28 Procedure Date: Fri, 8 Nov 2002 11:31:59 -0800 From: "Mosley, Jim I" <mosleyj@unocal.com> To: "q'om_Maunder@admin.state.ak.us"' <Tom_Maunder@admin.state.ak.us> Tom, Attached as promised is the latest ESP procedure for the M-28. I will forward to you a better picture of the Proposed Completion. I will call to see if this came through alright. Jim M. <<M-28 PGM for AOGCC.doc>> Jim Mosley Sr. Advising Drilling Engineer Unocal Alaska Union Oil Company of California 909 W. 9th Ave. P.O. Box 196247 Anchorage Alaska 99519-6247 Office 907-263-7679 Cell 907-351-8639 Home 907-694-4170 Fax 907-263-7884 EMAIL Mosleyj@Unocal.com I r-~M-28 PGM for AOGCC.doci Type: WINWORD File (applicationlmsword)! i Encoding. base64 . 1 of 1 11/8/2002 10:52 AM NOTICE OF PUBLIC MEETINGS ALASKA OIL & GAS CONSERVATION COMMISSION Under the Open Meetings Act (AS 44.62.310), notice is given that the Alaska Oil and Gas Conservation Commission will meet in public meetings on December 4, 11, 18, 2002, January 8, 15, 22, 29,. 2003 and February 5, 12, 19, 26, 2003 at 9:00 AM in the Commission's Conference Room in Anchorage, Alaska at the address below. The Agenda may include: general commission business including personnel; regulation matters; policy and budget matters; oil and gas conservation issues; legislative issues; and agenda items deferred, from prior meetings. 'The public is invited to attend the meetings, however, commission business meetings do not provide for public testimony. A finalized agenda will be prepared and posted at the Commission's office by noon of the workday before each of the scheduled meetings. Circumstances may cause items to be either added or deleted from an agenda. If you have any questions about the agenda, please contact Jody Colombie at the Alaska' Oil and Gas Conservation Commission, 333 W. 7th Avenue, Suite 100, Anchorage, Alaska 99501, (907) 793-1221. If you are a person with a disability who may need special accommodation in order to attend the public meeting, please contact Jody Colombie at the address or phone number indicated' above as soon as pOssible .but at least 72 hours before the accommodation is needed, to ensure that any necessary accommodations can be Sammy O)~chsli Taylo/} Chair Published November 12, 2002 ADN AO# 02314022 UNOCAL ) REVISION 6 TABLE OF CONTENTS [ AF~ ,~ 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure TABLE OF CONTENTS ............................................................................................................................................................. 1 VENDER CONTACT LIST: ....................................................................................................................................................... 2 IMPORTANT REFERENCES FOR ESP WORKOVER OPERATIONS.(copies attached) ................................................. 4 STEELHEAD NIPPLE UP BOPE STACK SCHEMATIC ...................................................................................................... 5 STEELHEAD M-28 CURRENT COMPLETION CONFIGURATION ................................................................................. 6 STEELHEAD WELLSLOTS AND LEG DIAGRAM .............................................................................................................. 7 DIRECTIONAL SURVEY .......................................................................................................................................................... 8 CONTINGENCY PLANS: ........................................................................................................................................................ 11 WELLHEAD STATUS .............................................................................................................................................................. ! 1 lo II_. IH. IV. V. VI. VII. VIII. IX. X._: XI. STEELHEAD ACTIVATION CHECKLIST ............................................................................................................ 15 PREPARE WELL FOR WORKOVER ..................................................................................................................... 17 MOBILIZE RIG ................................................................................................. ~ ........................................................ ! 8 PULL COMPLETION ............................................................................................................................................... 19 RUN ESP COMPLETION ......................................................................................................................................... 22 GAS LIFT CALCULATIONS .................................................................................................................................... 25 ND BOPE% NU TREE ............................................................................................................................................... 29 NOTES SPECIFIC TO RUNNING ESI' COMPLETIONS ..................................................................................... 30 WELL HISTORY ....................................................................................................................................................... 31 M-28 WELL WORK HISTORY ............................................................................................................................... 37 CAMERON WELLHEAD DRAWING ..................................................................................................................... 43 DEC 0 6 2002 M-28 PGM for AOGCCI.doc Page 1 of 43 11/08/02 UNOCALe REVISION 6 AF{ .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure WORKOVER OBJECTIVE: Retrieve the current 4-1/2" gaslift/ESP completion. Run a "Y" block with 2-318" By Pass Tubing and a 400 HP (562 series GC 4100) ESP on the same tubing string. Replace any damaged tubing as needed. Reposition and replace the GLM's as per attached GLM recommendation. Place btm of ESP between 10,380' and 10,420'. Place "X" nipple profile, in tubing string 2 joints above the pump. History: Well M-28 was originally spudded on Mar 23rd 1990. The well was squeezed on June 6th and completed on June 21st 1990 in the Jurassic formation as an oil well. The history of the well has included numerous workovers and recompletions. A complete summary of the well history is attached. VENDER CONTACT LIST: Company Contact Equipment/Service Provided Contact Number AOGCC Tom Maunder BOPE Test Notifications 793 - 1250 North Slope Insp After hours NS pager # 907-659-3607 APRS Billy Applewhite Jet Cutter 3.5625" OD 283-9576 Tbg Punch f/4-1/2" tbg Baker Oil Tools Todd Duwe Fishing BHA's 776-8131 Centralift Tim Lewis or Robert ESP Equipment 349-3731 de Long Cameron Dave Shaw Wellhead Materials 748-1981 cell Tim Griffith Wellhead Service 562-2332 Office GBR Chad Renner Tubing Tongs 283-7490 HES Dave Newton TCP Perforating Equipment 260-3246 Office 283-6708 Home 252-3463 Cell 262-3019 Pager MI Drilling Fluids Gus Wick KC1 & 776-8680 Calcium Carbonate (LCM) Pollard Wireline Johnny Butler GLM's Bucked on pups..GLV's 283-7006 installed Pollard Wireline Steve Barrow Slickline Work (coordinate w/ 283-7006 Unocal WL Foreman #6814) Winslow Resources, Inc. (303) 279-1629 Phoenix David Winslow Petroleum 2840 Berry Lane Fax (303) 279-8430 Services Golden, CO 80401 Cell (303) 919-8847 Home (303) 232-6525 dave_winslow~eompuserve.eom M-28 PGM for AOGCC1 .doc Page 2 0£43 11/08/02 AF( ,~ 154718-O-00 Steelhead Platform ~Jl~lO~kl~ Well # M-28 ESP WO2 REVISION 6 Replace ESP Procedure Schlumberger Ron Laesecke E/line equipment & crews 776-8155 Unocal Steve Lawrence Wellhead Service #2544 Weatherford JD Drill Pipe, DP misc. XO's, DC & 776-8148 Handling equip. Tbg Pup Jts. Weatherford Daily Chaz Kidd Daily Jars, Acc Jar and Bumper Jar 345-4497 M-28 PGM for AOGCC1 .doc Page 3 Of 43 11/08/02 UNOCAL ) REVISION 6 Alt{' .) 154718-0-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure IMPORTANT REFERENCES FOR ESP WORKOVER OPERATIONS (copies attached) · SOP # 1 PRE RIG ARRIVAL ACTIVITIES (dated 30 OCT 02) · SOP #2 ESP PILL SETTING (dated 30 OCT 02) · SOP # 3 NUBOPE (dated 30 OCT 02) · SOP # 4 RIG START UP (dated 30 OCT 02) · SOP # 5 NORMAL TRIPPING (dated 30 OCT 02) · SOP # 6 BARE PIPE SHUT IN (dated 30 OCT 02) · Standard Guideline For ESP Workover Operations · ESP MOC Checklist (dated 6 Nov 02) · SlMOPS Checklist and SIMOPS REQUIREMENTS (dated 25 Oct 02) · QAQC Checklist (dated 30 OCT 02) M-28 PGM for AOGCC1 .doc Page 4 of 43 11/08/02 UNOCAL ) REVISION 6 STEELHEAD NIPPLE UP BOPE STACK SCHEMATIC M-28 BOP Stack Table AF( ,~ 154718-0-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 16-314" 5M by 16-3/4" 10M ADAPTER SPOOL Double Studded Adapter 16" 5M x 13-518" 5M I I 16-3/4" 5M by 16-3/4" 5M SPOOL Top of DCB Spool M-28 PGM for AOGCCI.doc Page 5 of 43 11/08/02 AF{ 154718-O-00 Steelhead Platform Ul lO Well # M-28 ESP WO2 REVISION 6 Replace ESP Procedure STEELHEAD M-28 CURRENT COMPLETION CONFIGURATION RKB to 71.4' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 Surf 10,090' Casing Leak 10466' DIL Squeezed with 100 sx cement 10 Squeeze Perfs -10620-10623' ~'B~l'~g at ::11035' · ~ -= Hemlock. ~ish- at 11931' [5-718" junk mill, 4-314r ~it sub, 6-1116" s. milll 1~-3/4" xo, / []'otal length 14.37' / / ~ W. Foreland Perf. Jurassic Perf. PBTD = t2,952' TD = 13,000' MAX HOLE ANGLE = 41.7 No Depth OD 1 7206' 13.625 2 4550' 4.500 3 7.031 7.063 4 10179' 5 10440.3' 8.460 6 7.00 7 10627.5' 8.437 8 10945.7' 8.25 9 7.00 10 11197.6 7.00 11 12351 5.875 12 10537' 5.156 13 12369' 5.093 JEWELRY DETAIL ID Item 3.902 Cameron Tubing Hanger P/N 2161723-01-01 13-5/8" NOM 4-1/2" Butt Top x Bottom with Cameron Type H BPV profile 3.958 4-1/2" 12.6 lb/R L-80 AB Modified tbg 3.833 Camco MM(} GLM's w/RK latch (5.625" x 7.031") No. 6-8 At 2457',4422',5582' 3.833 McMurry SFO-2 GLM's w/RK latch (6.141" x 7.063") No. 5-1 at 6374',6888',7404',7950',8470' CentriliR ESP Assembly (304 hp) 6.000 Baker 9-5/8" $C-1L 6.184 Isolation liner 4 its and pup. 7" 29 lb/fi L-80 Butt casing with Baker Anchor Assy K.BH-22 (75 x 60) 6.000 Baker Model FA permanent packer (190FA75) with 6' tieback 6.312 Baker ZXP liner packer 7" x 9-5/8" 6.184 Isolation Liner 5 its and pup. 7" 29 lb/R Butt L-80 casing 6.184 Baker Muleshoe Assy.into TIW TBE 4.00 Baker FB-1 Packer (Size 85-40) 3.813 Otis X landing nipple 4.438 TIW LG-6 Tie-back Seals with ½ mulesho¢ PERFORATION DATA Zone Interval Date Date G-1 10632-10658 1470 9/13/99 G-2 10684-10710 1500 9/13/99 G-2 10720-10774 1530 9/13/99 G-3 10792-10822 1550 9/13/99 G-4 10840-10850 1590 9/13/99 G-4 10858-10888 1742 9/13/99 G-5 10964-10994 1788 9/13/99 G-5 11012-11037 1831 8/14/92 G-1 10638-10658 1841 8/14/92 Zone Interval 12/5/97 HB-3 11430- 12/5/97 HB-4 11480- 12/5/97 HB-4 11510- 12/5/97 HB-4 11540- 11/9/93 HB-5 11570- 11/9/93 HB-6 11722- 11/7/93 HB-7 11764- 11/7/93 WF-0 11815- 9/13/99 WF-0 11836- M-28 PGM for AOGCC l.doc Page 6 of 43 11/08/02 UNOCALe REVISION AF~ .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure STEELHEAD WELLSLOTS AND LEG DIAGRAM STEELHEAD WELLSLOT DIAGRAM 12/1/99 M-4 " / ~-2 Leg B-1 Leg B-2 NW Corner NE Corner Producer Duol Gas Well Injector 20"& 16" Csg Completion Preset ~M-19 Leg A-1 Leg A-2 SW Corner SE Corner SG~NED (~£C 0 6 2002 M-28 PGM for AOGCC 1.doc Page 7 of 43 11/08/02 UNOCAL ) REVISION 6 AF{ .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure DIRECTIONAL SURVEY Measured Ve~ical Subsea Drift Coordinates Depth Depth Depth Angle Azimuth X Y 0! 0 160 0 0 214150 2499532, 130 130 30 0.28 178.53 214150 2499531 230 230 -70 0.3 160.52 214150 2499530 330 330 -170 0.32 122.83 214151 2499530 430 429.99 -269.99 0.62 133.62 214152 2499529 530 529.98 -369.98 0.77 98.15 214153 2499529 630 629.93 -469.93 1.88 101.98 214156 2499528 730 729.85 -569.85 2.2 86.25 214160 2499529 830 829.79 -669,79 2 80.82 214163 2499529 930 929.74 -769.74 1.78 74.75 214166 2499530 1030 1029.63 -869.63 2.67 65.9 214171 2499532 1080 1079.57 -919.57 2.95 58.53 214173 2499533 1130 1129.5 -969.5 2.93 42.75 214175 2499535 1230 1229.25 -1069.25 4.1 20.8 214177 2499541 1280 1279.06 -1119.06 4.97 11.98 214178 2499545 1330 1328.68 -1168.68 7.02 10.52 214180 2499551 1380 1378.14 -1218.14 8.48 9.9 214181 2499559 1430 1427.45 -1267.45 9.52 8.32 214183 2499567 1480 1476.67 -1316.67 10.1 12.53 214185 2499575 1530 1525.7 -1365.7 11.33 12.27 214187 2499585 1580 1574.35 -1414.35 13.35 13.48 214190 2499596 1630 1622.58 -1462.58 15.28 15.08~ 214194 2499609 1680 1670.34 -1510.34 17.2 15.88: 214198 2499623 1730 1717.82 -1557.82 18.28 17.52 214203 2499638 1780 1764.93 -1604.93 19.58i 19.45 214209 2499653 1830 1811.42 -1651.42 21.6; 20.82 214216 2499670 1880 1857.52 -1697.52 22.77 21.7 214224 2499688 1930 1903.2 -1743.2 23.98 21.42 214232 2499707 1980 1948.69 -1788.69 24.53 21.63 214240 2499726 2030 1993.95 -1833.95 25,15 21.88 214248 2499745 2080 2038.59 -1878.59 26.77 20.98 214257 2499766 2130 2082.36 -1922.36 28.9: 21.25 214266 2499789 2180 2125.25 -1965.25 30.93, 21.93 214276 2499812 2230 2167.4 -2007.4 32.55 22.3 214287 2499837 2280 2208.78 -2048.78 34.13 22.98 214299 2499862 2330 2249.41 -2089.41 35.67 23.35 214311 2499889 2380 2289.14 -2129.14 37.37' 23.78 214324 2499916 2430 2328.17 -2168.17 38.7, 24.35 214337 2499944 2480 2366.88 -2206.88 39.27' 24.92 214351 2499973 2530 2405.37 -2245.37 39.65i 24.95 214365 2500001 2630 2482.24 -2322.24 39.77 24.18 214393 2500059 2730 2559.7 -2399.7 39.23 24.73 214421 2500116 2830 2637.25 -2477.25 39.15 24.65 214449 2500173 3030 2794.06 -2634.06 38.37 24.78 214504 2500284 3130 2872.52 -2712.52 38,32 24.97 214531 2500340 M-28 PGM for AOGCCI.doc Page 8 of 43 11/08/02 AF( 154718-0-00 Steelhead Platform Well # M-28 ESP WO2 REVISION 6 Replace ESP Procedure 3230 2951.1 -2791.1 38.2 24.4 214558 2500395 3330 3030,06 -2870.06 37.85 24 214584 2500451 3430 3109,54 -2949,54 37,37 25,92 214612 2500505 3530 3189,12 -3029.12 37.27 25,4 214639 2500559 3630 3268.81 -3108.81 37,17 24,35 214666 2500613 3730 3348,71 -3188,71 36,97 24.9 214692 2500667 3830 3428.75 -3268,75 36,83 24,47 214719 2500721 3930 3509,1 -3349.1 36.53 25.72 214746 2500774 4030 3589,55 -3429,55 36,43 25,4 214772 2500827 4130 3669.1 -3509.1 37.3 23,28 214798 2500882 4230 3748.01 -3588.01 37,9 22,27 214822 2500938 4330 3826,01 -3666,01 38,73 22,58 214848 2500995 4430 3903,12 -3743,12 39,55 22,25 214873 2501054 4530 3979,71 -3819,71 40,02 21,85 214899 2501113 4630 4056.42 -3896,42 39.9 21,42 214924 2501172 4730 4132,73 -3972,73 40,27 22,58 214950 2501231 4830 4209.31 -4049,31 40.02 20,78 214974 2501290 4930 4286 -4126 39,92 21,37 214999 2501350 5030 4362,4 -4202,4 40,18 21,58 215024 2501409 5130 4439 -4279 40 21,67 215049 2501468 5230 4515,88 -4355,88 39,75 21,63 215074 2501527 5330 4593,76 -4433,76 38,85 21,75 215099 2501585 5430 4671,27 -4511,27 39,18 22,37 215125 2501642 5530 4749,68 -4589,68 38,37 21,92 215149 2501699 5630 4827,73 -4667,73 38,68 21,93 215174 2501757 5730 4906,28 -4746.28 38,23 21,32 215198 2501814 5830 4984,41 -4824,41 38,62 20,77 215221 2501872 5930 5062,02 -4902,02 39,1 21.23 215246 2501930 6030 5139,43 -4979,43 39,27 20,55 215269 2501989 6130 5216,54 -5056,54 39,55 21.5 215294 2502047 6230 5293,48 -5133,48 39,7 20,77 215318 2502106 6330 5369,42 '-5209,42 40,58 20,68 215343 2502167 6430 5445,82 -5285,82 40,18 21,88 215368 2502226 6530 5522.641 -5362,64 39,8 23,4 215395 2502284 6630 5599.381 -5439,38 39.88 22.58 215421 2502343 6730 5675,64. -5515,64 40,3 23,82 215449 2502401 6830 5751,87' -5591,87 40,33 24,15 215477 2502460 6930 5828,17 -5668,17 40,27 25,48 215506 2502517 7030 5903,98 -5743,98 40,7 24,1 215534 2502576 7130~ 5979,38 -5819,38 41,07 23,12 215561 2502636 7230' 6055.36 -5895,36 40,55 19,8 215585 2502696 7330' 6131.17 -5971.17 40,7 19,15 215608 2502758 7430 6206,11 -6046,11 41,47 20,08 215632 2502819 7530 6281 -6121 41,5 18,9 215655 2502881 7630 6356,34 -6196,34 41,12 18,03 215677 2502943 7730 6431,69 -6271,69 41,1 19.63 215700 2503005 7830 6506.84 -6346,84 41,28 20,35 215725 2503066 7930 6581,55 -6421,55 41,65 20,03 215749 2503128 8030 6656.49 -6496,49 41,47 21,47 215775 2503189 M-28 PGM for AOGCC1 .doc Page 9 of 43 11/08/02 AF{ 154718-0-00 Steelhead Platform Ul lO kl( Well # M-28 ESP WO2 REVISION 6 Replace ESP Procedure 8130 6730.98 -6570.98 41.85 21.38 215801 2503250 8230 6805.96 -6645.96 41.42 21.15 215826 2503311 8330 6881.81 -6721.81 40.67 20.75 215851 2503372 8530 7033.97 -6873.97 40.47 20.98 215900 2503492 8630 7110.23 -6950.23 40.3 22.23 215926 2503551 8730 7186.52 -7026.52 40.28 19.75 215949 2503611 8830 7263.07 -7103.07 40.05 20.23 215973 2503671 8930 7340.34 -7180.34 39.4 20.18 215996 2503730 9030 7417.44 -7257.44 39.55 20.13 216020 2503789 9130 7494.91 -7334.91 39.22 20.25 216043 2503848 9230 7573.03 -7413.03 38.63 21.45 216067 2503906 9330 7652.16 -7492.16 37.68 20.78 216090 2503962 9430 7731.89 -7571.89 37.13 22.28 216115 2504018 9530 7811.87 -7651.87 36.88 20.07 216137 2504073 9630 7891.94 -7731.94 36.8 20.58 216159 2504129 9730 7971.56 -7811.56 37.23 18.27 216179 2504186 9830 8051.18 -7891.18 37.23 19.47 216201 2504242 9930 8131.4 -7971.4 36.65 17.33 216220 2504299 10030 8211.27 -8051.27 37 16.28 216239 2504356 10130 8291.2 -8131.2 36.93 18.27 216259 2504413 10230 8370.79 -8210.79 37.25 17.32 216278 2504470 10330 8450,07 -8290.07 37.55 18.92 216299 2504527 10430 8528.98 -8368.98 37.9 20.47 216322 2504584 10530 8607.67 -8447.67 38.1 22.55 216347 2504641 10630 8685.86 -8525.86 38.57 22.13 216372 2504698 10730 8764.12 -8604.12 38.5 22.22 216397 2504755 10830 8843.2 -8683.2 37.73 22.18 216422 2504811 10930 8923.12 -8763.12 36.95 22.02 216445 2504866 11030 9003.14 -8843.14 36.85 22.58 216470 2504921 11130 9084.53 -8924.53 35.52 22.33 216493 2504974 11230 9167.2 -9007.2 34.23 21.47 216515 2505026 11330 9251.24 -9091.24 32.82 21.4 216536 2505076 11430 9336.05 -9176.05 32 20,77 216556 2505125 11530 9422,66 -9262.66 29.98 19 216574 2505172 11630 9510.66 -9350.66 28.35 19.07 216590 2505216 11730 9599.55 -9439.55 27.27 17.97 216605 2505260 11830 9689.57 -9529,57 25.82 17.98 216620 2505301 11930 9780.37 -9620.37 24.77 18.93 216634 2505340 12030 9872.07 -9712.07 23.5 18.88 216648 2505377 12130 9964,72 -9804.72 22.1 19.27 216661 2505413 12230 10058.25 -9898.25 20,73 19.13 216674 2505446 12330 10152.82 -9992.82 18.97 17.62 216684 2505476 12430 10248.65 -10088.65 16.6 14.12 216692 2505504 12530 10344.8 -10184.8 15.95 16.12 216700 2505530 12630 10441.24 -10281.24 15.32 12.08 216707 2505556 12730 10538.36 -10378.36 13.8 8.03 216710 2505579 12830 10635.95 -10475.95 12.6 6.37 216713 2505601 12930 10733.91 -10573.91 11.57 3.85 216715 2505621 13000 10802.49 -10642.49 11.57 3.85 216717 2505635 M-28 PGM for AOGCCI.doc Page 10 Ot:43 11/08/02 UNOCAL ) REVISION 6 AFl .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure CURRENT WELL STATUS: The current completion includes gas lift mandrels and an ESP pump. The ESP has failed and will be replaced. The current ESP ran for 22 months before failure. When the current ESP was installed, a drop in oil rate was apparent after the new pump was installed. It is believed that the "G' zone perforations may have been damaged during the workover. Re-Perforating the "G" zone is expected to reestablish the reduction in oil rate that occurred during the last workover. The re-perforating exercise can be done through the By Pass tubing after the well is back on stream. This will give us an opportunity to evaluate the effectiveness of the pills and the damages done to the completion during the workovers. CONTINGENCY PLANS: There is a NO SHEAR RAM contingency plan in effect for the work over that provides detailed requirements. WELLHEAD STATUS The present tubing spool on M-28 is a McEvoy model EP-4SP. This spool has a 13 5/8" 5M top. Notes: KB to MSL Original RKB to TH Max Deviation: Pore pressure: 160' 71.4' 41.85° @ 8130' MD, 6730' TVD' G Zone 2700 psi @ 8765' TVD G-2 Zone Estimated Hemlock 4000 psi @ 9170' TVD HB-1 Zone Estimated Workover Fluid: Produced Fluid: Filtered 6% KCI w/FIW (8.9 ppg) Oil: 33° APl Gravity Water: 1.02 spg Special Concerns: · Formation Damage during workover. · Well was NO_FLOW Tested in Sept, 99 work over operation and is not still valid. Conduct a new NO FLOW TEST. Note: Notify Torn Maunder wi AOGCC {793-1250) 24 hours in advance of NOFLOW and before BOP TESTS, Or North slope inspectors pager (907.659.3607). · Well has an H2S Concentration of 105 ppm Mar 2002. · Normally will need to pressure test blind rams after completion is retrieved. · Well may not stand full, and if so, a limited fill up scheme will be used only as a last resort. · Pill Placement will be conducted as per the SOP for ESP Pill Placement. M-28 PGM for AOGCC1 .doc Page 11 of 43 11/08/02 UNOCAL ) REVISION 6 AF{, . ) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Pump had been operating for 22 months and was run on used tubing during the last work over. Tubing condition is an issue. The AFE anticipates replacing % of it. A full string will be prepared in the event it is needed. Reconditioned GLM's will be moved to facilitate getting better gas lift next time the pump goes down. The Pump will be moved down the hole some 250 feet. WORKOVER PROCEDURE SUMMARY: NOT._._._~: Because the M-29 workover is being conducted immediately before the M-28 workover, some of the out of the critical path items that are preferred to be done as per the SOPs will need to be done after the rig has skidded. For instance the BOPE is on the M-29 well and cannot be installed on the M-28 until the M-29 is finished. Perhaps we can have both trees off at the same time and be nippling up BOPE on M-28 while we are nippling up the Tree on M-29. 0 Pre Rig Activation to include a Gauge Ring Run to near the ESP pump. 1 Activate Rig (Activation included in cost estimate) 0.0 2 Prepare rig for Operations (Locate Tree Cap Pulling Tool) 0.0 3 Take on and mix kill fluids (1000 bbls of 8.9 Filtered KCL) 0.0 4 Shut-off gas lift & bleed SICP to 0 psi (2 days prior to rig start) 0.0 5 Holes have been punched in the tubing one joint above the pump. 0.0 6 Mix Pill and kill well Spot pill across the G peris and establish loss rate. Circulate the well to3.0 the production facilities off the critical path. Rig up and Skid rig over M-28 7 Load tubing and annulus as needed to fill the hole. Circulate the well. Re-Spot pill and 3.0 circulate as needed. Try to obtain 50 psi on pill. Bleed off tubing & verify dead. 8 Conduct PreStart Up Spud meeting with all hands and go over "Y" block installation. 3.0 9 Install BPV 1.0 10 ND tree/flowline 4.0 11 Inspect hanger threads 1.0 12 NU BOPE USING SWEENEY TORQUE WRENCH 20.0 13 Recover BPV, install TWC valve & test BOPE with KCL Water to 3000 psi. 8.0 14 Recover TWC valve & engage hanger with landing joint. Circulate the well with one full 1.0 circulation taking returns to production via wellhead outlets. Pull hanger loose and circulate one full circulation with returns to pits. 15 RU to pull Buttress tubing. Limit pull to 80% of New rating. 2.0 16 Pull Tbg Hgr to rotary table. Cut BIW Penetrator, & start cable on spool. 3.0 17 LD Hanger and landing joint. RU to power wash cable and tubing on TOOH to prevent drips. 1.0 M-28 PGM for AOGCC1 .doc Page 12 of 43 11/08/02 UNOCAL ) REVISION 6 .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 18 POOH LD Bad tubing. Stand back good tubing. LD all Gas Lift Mandrels. Use pipe wiper 12.0 above Rotary. LD ESP and determine ESP Failure Mechanism if obvious. 19 Pick up "Y" Block assembly and ESP Assembly as per Centrilift and Phoenix. Keep the hole 14.0 full and monitor continuously. Change out seal rings on tubing prior to running in the hole. 24 RU to Run ESP. Change out Spooler Reels 4.0 25 Run ESP installing clamps and making splices as needed. MEG cable each 1000 feet going 28.0 into the hole. 26 Pick up Tbg hanger and splice as needed. Install Penetrator in tubing hanger. 6.0 27 Land Tubing with Control line and Cable spliced through hanger. 3.0 28 LD Landing joint & RD Tbg Tools 2.0 29 Install BPV 1.0 30 ND bell nipple 2.0 31 ND BOPE & RISER 8.0 32 NU adapter and tree. NU wing valves to tree. 6.0 33 Pull BPV, Install TWC & Shell test tree to 3000 psi.. 6.0 34 Turn well over to production 3.0 35 Install flowlines & Test Electrical Equipment'. Meg system for baseline. 0.0 36 Skid to M-29 8.0 37 Secure and backload all unnecessary parts. 8.0 CAMERON WELLHEAD SERVICE HANDS REPORT DURING LAST ESP WORKOVER Well # M-28 ESP 5-3-00 Checked tools and equipment, standby while killing the well. Tubing on a vacuum and tubing annulus at 0 psi. L/D landing joint and set a 4" bpv, n/d choke and spool from flow line. Removed the actuator from the second master valve and checked the voids for trapped pressure. Cut swagelock fittings on the I wire and chemical injection line. N/D the tree and adapter cut and plug the I wire and chemical injection lines. Inspected the 4 ½" buttress lift threads in the top of the tubing hanger. Nipple up BOPE and test, pull the BPV and set a TWC, tested the blind rams, pulled the TWC and MU the landing joint. Circulated the well, BOLDS, held a pre-job safety meeting and pulled the tubing hanger to the rig floor. Removed the penetrator and all of the swagelock fittings and inspected the hanger, everything looks good, will install new seals prior to completion. Tubing Head Adapter P/N 216172%01-01 Tubing Hanger P/N 2161723-01-01 type EP-4SD-SL is 4 ½" buttress box top and bottom and is prepped for lea. 3/8" injection line, lea. ¼" I wire and lea. electrical penetrator. This hanger has a 3.980 O.D. type "H" bpv profile. M-28 PGM for AOGCC1 .doc Page 13 Of 43 11/08/02 UNOCAL REVISION 6 AF{' .) 154718-0-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Well # M-28 ESP 5-6-00 Checked tools and equipment for completion, cleaned and redressed the McEvoy 13 5/8" O.D. x 4 ½" tubing hanger. Tubing hanger P/N 2161723-01-01 has one ½" npt port for continuous chemical injection line, and one 3/8" npt port for continuous instrument wire, and one port for electrical penetrator. This hanger has 4 ½" buttress threads top and bottom, minimum I.D. is 3.950, and type "H" bpv profile. M/U and orientated the tubing hanger, fed chemical injection line and I-wire through and m/u swagelock fittings, r/u and tested between fittings through the 1/8" ports on the O. D. of the hanger to 5000 psi, no leaks. M/U penetrator and set one 4" bpv m/u landing joint and landed the hanger, pulled one tie down pin to verify the hanger was in the profile. Ran in all of the tie down pins and n/d BOPE cleaned and inspected the hanger top installed new neck seals and ring gasket. N/U tree, actuator on 2nd master valve and flow line, r/u and tested between the hanger body/neck seals, and all penetrations to 5000 psi for 15 minutes, no leaks, bled the test pressure. Pulled the bpv and set a twc, shell tested the tree and flow line to 250/5000 psi, no leaks, pulled the twc and serviced the lower master and swab valves. Cleaned and prepared tools and equipment for shipment to the beach. M-28 PGM for AOGCCl.doc Page 14 of 43 11/08/02 UNOCAL ) REVISION 6 Alt{ 154718-O-00 Steelhead Platform Well tt M-28 ESP WO2 Replace ESP Procedure I. STEELHEAD ACTIVATION CHECKLIST Mud.. PumPs,.. centrifugals, ..Pits, .. and.. circulating system. 1. p~ps~.~.~e: ~dressed~' jU~t:'n..'e....e..'~?t0~!~:~!: :v~yes.~i.:~ng~. 2. Need to insure rod oilers are not plugged by salt deposits, inspect hose conditions. Clean out rod oiler tank and pump rod cavities, make sure all of this is flushed really well before filling rod oiler tank. ( This has been a problem in the past) 3. Check filters on mud pump gear oil system, check oil in pumps and chain case. Ensure extra gear oil is available on platform. 4. Check pre-charge in pulsation dampeners. 5. Install suction screens in screen pods 6. Function all valves on mud pumps 7. Wash up salt residue on pump room floor 8. Several lights burnt out in pits, fix same. 9. Make sure drain plugs are installed in centrifugals 10. Function valves on centrifugal manifolds 11. Identify fluid in pits 12. Dispose of to production drains if fluid is not compatible with M-28 W/O 13. Ensure mud pumps and centrifugal pumps are lined up on the appropriate leg. This task requires tracing down of lines, If personal has not been on Steelhead before even more scrutiny is needed. Several spills have occurred in the past due to improper line up 14. Ensure tilting mud ditch in cellar is lined up on the proper Drill deck ditch and that towline valve in upper well bay is open to the pits and towline drain valve is closed. 15. Make sure towline valves in other legs are dosed. Dry Sack Room 1. Reorganize welding equipment to allow room for mud product and keep egresss clear. 2. Check air ventilation system to make sure its operational 3. Make sure hopper valves are operational and containment still intact around hoppers Upper well bay 1. After utilities are hooked up ensure egresses are clear and housekeeping is good. 2. Make sure all hatch covers are secure by either safety chains or OD ext.. 3. Inspect upper well bay tugger and cable goods. 4. Inspect beam clamp and sheave before hanging on rig cellar beams. 5. Clean up all trash and wash floor. . t:;AH EI 13EC 0 6 2002. Accumlator 1. Check oil level in Koomey 2. Make sure isolation valves in Dry Sack room are closed. 3. Cheek pressure in bladders, make sure nitrogen is available to bring up to 1000 psi 4. Unlock electrical lock-outs in MCC room 5. Inspect dryloeks in upper well bay 6. Position personal in well bay rooms and pressure up accumulator to 3000 psi 7. Inspect Koomey and lines for leaks. M-28 PGM for AOGCC 1.doc Page 15 of 43 11/08/02 UNOCALe REVISION 6 AF[' 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Rig. 1. Ensure all utility hoses are in upper well bay along with top riser section, Graylock clamp, and 13 5/8 . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. x 16 ~A 5M DSA. This DSA will have to be rented it is not on the platform. Skid rig over oil leg and over M-28. Hook up utilities, including power. Need to drift riser sections. Set Beaver slide Remove tarps from traveling equipment. Check oil in Top drive and grease traveling equipment Install guard on Top Drive Hang rig tongs and rig up floor Check all traction motors and make sure brushes have not been pulled Ensure shakers and upper pits are lined up properly Perform Derrick inspection paying special attention to cable goods and ropes Install new air tugger sheaves. Install chain baskets on BOP hoists, do a complete visual inspection of hoists. Choke and Kill hoses are in place, target tees are on platform Measure out for bell nipple modification if needed No line on new cellar air tugger, order and install line Check oil in Drawworks and rotary Ensure all traction motor blowers are uncovered Install drain plugs in sub pits centrifugals and function same. Make sure air booster system in substructure is operational. Drain oil from choke manifold. Have Quadco on the hook to install rig instrumentation Function all valves on choke manifold and mud manifold Install inspection plate on gas buster Make sure all grating in cellar is secure Inspect deadman clamp and load cell. Test rig ventilation system in sub Check level in brake water tank and test nm system Turn on utilities. When turning on utilities close coordination with production is needed. Make sure Glycol booster pump in lower sub is hooked up. Open return valve and slowly open feed valve staying in contact with production. When taming on air and charging rig system, crack open feed valve and let rig system slowly fill. Until rig is pressured up, then full open valve. Thoroughly inspect low pressure mud hose before hooking up Ship fluid from mud pits to trip tank, have personal in well bay rooms and cellar when conducting this test. Pressure test mud lines to 4000 psi with test pump. Activate Drawworks and nm blocks up and down. Function test crown-a-matic and block height alarm system Run top drive through its functions Drill deck 1. Clear decks of trip hazards 2. Make sure all skid rail walking surfaces are of any slick spots. 3. Organize decks for ESP change out. ( Will be dealing with oily cable and tubing ) M-28 PGM for AOGCC 1 .doc Page 16 of 43 11/08/02 UNOCAL ) REVISION 6 AF{' ,$ 154718-O-00 Steeihead Platform Well # M-28 ESP WO2 Replace ESP Procedure II. . PREPARE WELL FOR WORKOVER Have Wellhead hand Steve Lawrence check all voids for pressure, check all hold downs for easy threading,, check all bolts for scale and corrosion buildup. Run and set BPV and confirm that the BPV will thread in properly. Pull BPV and prepare to rig up Pollary slickline. Conduct NOFLOW TEST Note: Notify Tom Maunder wi AOGCC (793-1250) 24 hours in advance of NO FLOW TEST: Or North slope inspectors pager ( 907-659- 3607). . Check all man Riders and air hoists for proper maintenance and good condition of lifting gear and cable. 4. Bleed off casing and tubing pressure to 0 psi. RU surface lines. . Fill rig pits with 1000 bbls of 6% KCL water using FIW and 22 #'s per bbl KCL. (6% KCl (8.65 ppg). The tubing will be completely displaced and the backside of the well will be circulated to a depth of 10200'. NOTE: DISCUSS WITH SUPT THE NEED TO PUMP A COMPLETE CIRCULATION PRIOR TO PUMPING A PILL INTO THE WELL TO ENSURE NO HYDROCARBONS ARE IN THE WELLBORE WHILE PULLING OUT OF THE HOLE. . Mix and displace Pill as per MI Recommendation. Circulate the pill to within 5 bbls of the holes just punched and then close in on the well. Bullhead pill into place noting if a pressure increase is seen. Attempt to get a 50 psi pressure increase when pill hits. Stop pumps and hold pressure on pill for a few seconds. Re Pressure up to 50 psi at least twice to ensure that the pill is seated on the perfs. 1 Circulate and load well bore with complete circulation attempt using 6% Filtered KCI water. Record volumes pumped. If well will not circulate, then re-spot a pill and attempt to circulate again. If circulation attempts fail after three pill settings then notify Supt and Engineer. Ensure well is dead. Bleed off as necessary. 8. Have ESP Checklists double checked in town and on the rig. Calculations Formation Pressure G.Zone 2700 psi 8765' 0.308 ppf 5.92 ppg TVD Hemlock 4000 psi 9350' 0.427 ppf 8.2 ppg TVD Wellbore Water Gradient 6% KCl FIW Gradient 0.4498 ppf M-28 PGM for AOGCCI .doc Page 17 of 43 11/08/02 UNOCALe REVISION 6 AF{ .) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Anticipated Hydraulic BHP G Zone Hemlock 4-1/2", 12.6# Tubing 10,090' 9-5/8", 47# x 4-112" 10,180' Total Annular Capacity Total Wellbore Capacity After tubing Is pulled 3942 psi 8765' TVD 4205 psi 9350' TVD 0.01522 bpf 0.05353 bpf 153 bbls 542 bbls to Pump Intake 550 bbls to Top of 7" liner. 557 bbls to Top Perf "G" @ 10632' 764 bbls t/top Perf "G" @ 10632 801 bbls t/Top of Fish at 11631'. (Top of fish is effective PBTD) III. MOBILIZE RIG Note: Notify AOGCC 24 hours in advance of BOP test. 9. Skid rig over M-28. Disconnect I-Wire, corrosion inhibitor line, and BIW pig tail. Plug.off with blind swages and BIW penetrator cap. NOTE: The reports should start up again as of rigging up to pump into the well. 10. Complete Unocal Alaska "Pre-Spud" & Substandard check lists and E-Mail to Drilling Superintendent. Obtain the new SIMOPS checklist and go over SIMOPS issues with all drilling, production, and construction personnel onboard. Install Type "H" BPV in the Cameron Tubing Hanger as described below. See notes above from Cameron service hand in 2000. NOTE: The present tubing spool on M-28 is a McEvoy model EP-4SP. This spool has a 13 5/8" 5M top. Tubing hanger data: MCEVOY Tubing Head Adapter P/N 2161727-01-01 Tubing Hanger P/N 2161723-01-01 type E?-4SD-SL is 4 ½" buttress box top and bottom and is threaded for 1 ea. 3/8" injection line, 1 ea. %" I wire and 1 ea. electrical penetrator. This hanger has a 3.980" O.D. type "H" bpv profile. 11. Verify that well is dead. Have Wellhead Service Rep. verify that all pressure has been bled from all lines and voids associated with the tree, seal flange and tubing spool M-28 PGM for AOGCC1 .doc Page 18 of 43 11/08/02 UNOCAL ) REVISION 6 AF , ) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure immediately prior to removal. Wellhead engineer should ensure hangar lock pins have been checked for free movement prior to the start of rig operations. 12. Cut the power to all of the offset ESP wells adjacent to the M-28 in the wellhead room. Make arrangements to protect the cables and provide security within the wellhead room. All of the offset adjacent wells that are capable of flowing are to be evaluated by the Unocal Drilling Foreman as to whether they need to have BPV's in place prior to the nipple down of the tree on M-28. 13. ND tree and seal flange. Verify that any ports on the tubing hanger have been properly plugged to prevent leakage during BOP testing. Verify the lift thread type on the tubing hanger and inspect its condition. NOTE: Install tree cap adapter, wi DP threads, on X-mas tree. PU tree wi DP. DO NOT USE SLINGS. USE SWEENEY TORQUE WRENCH ON BOPE. 14. N/U BOP's. Locate the 13-5/8" 5M by 16-3/4" 5M DSAF for use on this job and clean up same prior to needing it. See the BOP Arrangement: Annular Preventer One set of Fixed Pipe Rams (4-1/2") Blind Rams Mud Cross One set of Fixed Pipe Rams (4-1/2") 15. Test BOP per Unocal and AOGCC specifications. Test rams 250 psi Iow, 3000 psi high. Annular 250 psi Iow, 2000 psi high. Complete Unocal Alaska BOP Checklist and Contractors Checklist and fax to office. Note: Notify Tom Maunder wi AOGCC (793-1250) 24 hours in advance of BOP test Or North slope inspectors pager (907-659-3607). IV. Note: PULL COMPLETION If tubing hanger thread condition is bad: It will be necessary to utilize a spear to recover the tubing Note: Document fluid losses to the wellbore and report on the Daily Drilling Report. Note: Conduct Cable Cuffing and Close in on Bare Pipe Drills with all rig crews until the cable cuffing and shut in can occur to the satisfaction of the Unocal Drilling Foreman. Obtain this level of competency prior to pulling tubing hanger to the rig floor. Make sure that at each crew change a drill is conducted with the coming on tour crew prior to releasing the going off tour crew. M-28 PGM for AOGCCI.doc Page 19 of 43 11/08/02 UNOCALe REVISION 6 AF(' . t 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 16. Recover BPV w/Anti-Blow-up Tool. Make up 4-1/2" landing joint with Bow Springs installed to center the landing joint. Run landing joint into the hole and engage hanger. Monitor well for pressure. If well is stable, confirm that the hanger hold down screws are backed out. 17. Hold pre-job safety meeting and pull hanger to the floor. (The anticipated pick up weight is 170 K lbs.) Check standing fluid level in the well bore. DO NOT RUN PIPE WIPER BELOW ROTARY TABLE. Ensure that the hole is full and that the NO SHEAR RAM contingency plan has been communicated to all of the personnel. 18. Centrilift will disconnect Feed Through cable and recover corrosion inhibitor check valve. NOTE: TURN OFF CATHODIC PROTECTION PRIOR TO THE START OF CABLE RECOVERY. Power Wash tubing and cable on TOOH. MAXIMUM PULL = 201,000 lbs. This will provide for over pull of approx. 72,488 lbs. at the Pump intake based on air weight. Notes: String Weight for 10,200' of 4-1/2'', 12.6#,L-80, BTC tbg = 128,500 lbs. Yield for 4-%", 12.6#, L-80, BTC tbg = 288,000 lbs. (100%) Max. Pull 201,000 lbs. (70%) - 128,500 lbs. (Tbg wt) = 72,488 lbs. @ Pump (air weights) SEE ATTACHED TUBING SETTING REPORT FROM THE LAST TIME THIS PUMP WAS RUN. 19. Monitor well to ensure it is dead. 20. Start POOH with completion, install closed-end thread protectors on all bad joints and on pin ends of all pipe stood in the derrick. LD bad tubing and stand back the rest. Check any damaged tubing and completion jewelry for NORM's. Lay down all gas lift mandrels and send same to Kenai for refurbishment. Be aware that the pipe may pull wet if the hole is full because of the check valve installed in the tubing string. If the holes were punched below the check valve then there will be no trapped pressure in the string. If however, there are no holes and the string pulls wet, there may be some small amount of trapped pressure in the string below the check valve. Note: Tubing Connections should be checked and new seal rings installed before standing back. Have a Tuboscope hand onboard to assist with inspecting tubing and changing the seal rings. Note: Gas Lift Mandrels will require service by Pollard for new setting depths. It is planned to swap out mandrels and valves for a reconditioned set currently in stock with Pollard. Note: Note: Cable should be spooled down V-door until sufficient cable is pulled to run cable through sheave. This completion was run in 2000 and the plan is to reuse the tubing on this well. A replacement string is available but is not anticipated. M-28 PGM for AOGCC1 .doc Page 20 of 43 11/08/02 UNOCAL ) REVISION 6 AF(" ) 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Note: It is very important to get an accurate count of all Bands, Flat Guards, and Lasalle clamps that are removed from the 4-1/2" completion string. If clamps and or bolts are bad, then segregate bad parts and replace same. Lay down and clearly mark the punched joint of tubing as junk. Plan to install a Sliding Sleeve type CMU (JAR UP TO OPEN) two joints above the pump during rerunning the assembly. The purpose of the CMU is to allow spotting of pills in the future. The "X" Profile in the top of the sliding sleeve will be used to install the check valves that are to be part of the standard operating procedure for pulling ESP's in the future. Note: Carefully inspect the lower connector areas. Look for signs of heat, electrical arcing or mechanical damage Note: Disconnect the lower connector from the bottom of the wellhead power feed through penetrators. Look for signs of damage. Note: Conduct electrical testing of the power feed through penetrators and the lower connector. Note: Once the ESP system has been pulled to surface, close the blind rams and carefully inspect the motor-flat to main cable splice for signs of heat or damage. Note: As the cable is pulled from the well look for signs of damage. Power wash cable and ensure that the used cable spools are stored in containment baskets. Note: Note: Since the well has been in service for some time, the cable will be changed out to a used inspected cable. If damage is found on the cable that is in the hole, then spray paint the damaged areas and continue out of hole. The existing cable will be shipped in for a thorough inspection. If at any time during the pulling of the tubing from the well, gas is noted on the annulus or tubing, be prepared to cut the cable and close the preventer on bare pipe. Once the well is shut in, if the fluid will circulate to the surface, then the well can be circulated out safely to the production facilities. Do not circulate crude oil into the pits. Equipment Disposition Tree and tubing hanger Tubing Seals. Tubing Drift ring run. Power cable GLM's for reconditioning Inspect re-dress and re-run Re-run and replace any bad joints. Change Drift tubing 3.75" on TCP RIH if them was not a gauge Send to Centrilift for inspection/repair. Use new or reconditioned Replace with rebuilt GLM's. Send in used ones M-28 PGM for AOGCCl.doc Page 21 Of 43 11/08/02 UNOCAL ) REVISION 6 LaSalle clamps Flat guards Pumps inspection/repair Seal sections inspection/repair Motors inspection/repair Phoenix Gauge "Y" Block and Bypass Sentry Gauge Al _ # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Inspect and re-mn Re-mn if acceptable condition Replace and send used pumps to Centrilift for Replace and send used seals to Centrilift for Replace and send used motors to Centrilift for A New Phoenix gauge will be run. A "Y" Block and new 2-3/8" flush joint tubing will be run alongside the pump. Have Centrilift and BOT inspect and send the used gauge to Centrilift. Install new Phoenix gauge. 21. NOTE Condition of ESP as far as SCALE is concerned and determine if a casing scraper run is prudent. 22. If Scale is not an issue, then RU slickline and make a Gauge Ring run to 10250' with an 8.25" Gauge Ring. If Gauge Ring goes without a problem, then rig down slickline and run ESP as planned. 23. If Gauge Ring does not go to bottom, then Rig Down Slick line and make a casing Scraper run to 10250'. Pull out of hole and pick up "Y" Block and ESP as planned. 24. IF Casing scraper does not go to bottom, then pull out of hole and run ESP without "Y" Block. Ve RUN ESP COMPLETION NOTE: Take digital pictures of ESP components as they are RIH, i.e. motor/pump/bearing assembly, typical GLM hook-up and tubing hanger. · Use 1-¼" SS bands. · Ensure that the triple connection sub and by pass tubing is secured and handled carefully. There are no back up tools in Alaska. · Cathodic protection on the platform should be turned off priOr to running completion. Problems could be encountered with stray voltages giving readings on the pump cable that indicate a cable problem. · Check to ensure 4-1/2" tubing slips have enough open area to accommodate ESP cable. Check OD of hanger to ensure it will pass BOP's and all BOP spools. M-28 PGM for AOGCC 1.doc Page 22 of 43 11/08/02 UNOCAL ) REVISION 6 [ # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 25. Rig up cable handling equipment. Re-Hang cable sheave (54"dia.-Centrilift) from top of V-door. Position spooler so cable can be run from spooler, through Centrilift conex, to rig floor. Ideally spooler operator should have a view of the rig floor operations. Rig up a portable Gaitronics hand set next to spooler. Note The Centrilift spooler has approximately 4000' of cable spooled on each reel. Centrilift A-frame will be secured to deck. Two or three spools of cable will be needed. Safety Items Shut in on Bare Pipe is the primary method of stopping flow should it occur. The preferred method is to cut the cable with an intrinsically safe hydraulic cutting tool and secure the cable to the pipe. Run one joint into the hole and close the annular on the pipe prior to trying to circulate. Take returns through the choke to the gas buster. A hydraulic acting or hand pump actuated cable severing device should be used to cut the cable if it is necessary to do so. 26. Make up ESP assembly generically as follows: ESP PUMP SIDE OF "Y" BLOCK Aluminum Anode. 3' length x 3.0" OD. Phoenix multi sensor 7" OD Motor Centralizer (Cast carbon) S/N 40394 with Chemical Injection Port assembled on motor at rigsite Centrilift Motor Type 562, 304 HP Model KMH, 2290V 81 Amp (LT # and UT# ) Motor Flat Plug-In ~f4 AWG X/O 5.62" x 6.75" (Adapter SN 44727) Centrilift Tandem Seal Section Model GST3 4B IL H6 PFS (# 31H53141) Centrilift Tandem Pump 71 Stage, GC 4100, Series 513, Model GCARI:I (2 Sections) (LP #, TP # ) Pump has 3-1/2" EUE 8RD Box looking up 3-1/2" 8rd L-80 Pin x 4-1/2" 12.6 Ib/ft L-80 Mod Butt Box collar installed above. PHOENIX "Y" BLOCK with 3-1/2" Pup Joint at least 6 feet long above the "Y" Block XO to 4-1/2" Tubing. BYPASS SIDE OF ESP ASSEMBLY Pup Joint of 2-3/8" Flush Joint Tubing Triple Connection Sub By Pass Tubing Wireline Reentry Guide NOTE: SEE THE ATTACHED PHOENIX AND CENTRILIFT DRAWINGS FOR EXACT DIMENTSIONS AND RUNNING ORDER. M-28 PGM for AOGCCI.doc Page 23 of 43 11/08/02 UNOCAL ) REVISION 6 AF '( 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Notes: Phoenix to supervise picking up the "Y" Block and ESP Assembly. Use a Baker Liner Running Table and C Plate as needed to pick up the "Y" Assembly. Unocal Foreman shall witness the following checks: Free rotation of all ESP motor and pump components, proper oil filling of motor and seal sections, tightness of all fill, vent and drain plugs. Cover the hole at all times while installing any cable clamps, LaSalle Protectolizers shall be run on the ESP assembly to secure and protect the flat Motor lead cable. (Galvanized flat guard ~ (SE3932X02) will be used over the motor flat cable) Run one at each flange of the ESP equipment. Use of 1 ¼" SS Superbands will be determined by onsite Centrilift representative Strap and record the dimensions of each piece of equipment prior to running in the hole Tubing must not be allowed to turn while making up connections or TIH with ESP because of the control lines and electric cable. Use APl Lead Free Modified connection dope on completion assembly. Dope should be installed with a small paint brush on the pin and any excess wiped off. Centrilift will provide 200' of 3/8" stainless steel line for hook up of inhibitor line. Turn off Platform Cathodic protection. If possible have Centrilift splice the flat motor lead cable to the round cable prior to deliverin,cl reel to platform, Position of the chemical injection line. The chemical injection line will have two Baker CH series check valves (No Back Up) installed. One check valve will be installed directly below the tubing hangar and the second check will be installed above the discharge point at the centralizer. The line will be banded alongside the pump and motor down to the centralizer. An extension will be installed to place the chemical injection point below the motor. The Cable splice from the fiat motor lead cable to the round cable will be made so that the splice is above the pump by about 15 feet. This will put the change in cable diameter in the middle of a joint. We need 53' for pumps, seals, intake, discharge, crossover, Motor Offset. A premade up pup joint will be in the top of the "Y" Block. The Flat to OVAL Cable splice will be made onsite. Measure all components and prepare the splice off the critical path. 27. RIH picking up the additional footage as singles and then run the stood back stands of 4- 1Z~ 7:, 12.6# tubing w/Modified Buttress connections and Gas Lift Mandrels as per the latest Pollard recommendation. Strap and rabbit (3.83" OD rabbit) any new tbg as RIH. See Attached GLM Recommendation. 28. Install "X" Nipple two joints above the pump assembly. 29. Run the remaining 4-1/2" 12.6 Ib/ft L-80 AB Modified. Butt Tubing completion torquing connections to make up marks on improved buttress connections. (Actual torque observed previously 4000-4200 ft-lbs.) We will have 4 %" Cannon clamps available as backup for Lasalle Clamps. M-28 PGM for AOGCC 1 .doc Page 24 of 43 11/08/02 UNOCALe REVISION 6 VI. GAS LIFT CALCULATIONS AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Rev 3 POLLARD WlRELINE PRESSURE VALVE GAS LIFT DESIGN CALCULATIONS Unocal Steelhead M-28 23-Oct-02 Valve Depth Depth Tv( F) Port R D Pc Pt Psc Pd OP Pso Pd@ TRO PTRO No, TVD MD Size Pvc 60F 1 2150 2206 145,8 16 0,066 31.6 422,2 1055 1100 1148 1101 920,3 985,3 985 2 3250 3602 154.4 20 0,103 54.7 576,9 1040 1107 1168 1097 911,6 1016 1015 3 4000 4551 159,7 20 0,103 69,5 686,6 1030 1112 1161 1075 906,7 1011 1010 4 4650 5397 164 20 0,103 81,7 785,4 1020 1115 1153 1054 901,7 1005 1005 5 5200 6103 167,3 20 0,103 91,6 871,3 1010 1115 1143 1035 896,6 999,5 1000 6 5650 6690 169.8 32 orifice Orifice Valve 7 6050 7215 171,8 Dummy Valve 8 6450 7747 173,6 Dummy Valve 4 1/2" SFO-2 Mandrels. Max OD 7.063" Drift 3.833 M-28 PGM for AOGCCI.doc Page 25 0f43 11/08/02 UNOCAL ) REVISION 6 TV: Temperature of Valve TCF: Temperature Correction Factor R : Ap/Ab PT: Tubing Pressure @ Depth PSC: Closing Pressure at Surface PVC: Closing Pressure at Depth OP: Opening Pressure at Depth PSO: Surface Opening Pressure PD AT F: Bellows Pressure at Base Temperature PTRO: Test Rack Opening Pressure OP= (PVC - PTR)/(1-R) OP= PSO+DPC PVC = PSC + DPC PD AT F = TCF X PVC PTRO= (PDATF)/(1-R) AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure R-2 Pressure Valve RK Latch Double Checks M-28 PGM for AOGCCI.doc ?age 26 of 43 11/08/02 UNOCALe REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 100 :120 GaS:..'LiftValve Plot Steelhead. Temperature(degrees F) 140 160 180 1'000' T 2000. 'U 3000 V e. r 40.00: t i c HO00 I D 6000 ".t 7000: -h : .f t 8000 9000. 10000. ..... . 3601;548 ! 3260. -64.60 2~'0 .40O 6oo: ;.8oo :~.:0'oo: I-:' :.1200 ObJeMivo Tubing Pre~nJre: O Iiq = 4000.000 STBIday Tompera~m: O liq = ~ 5T~day M~mum C~no Prate, 11~ psig OperaUng C~ng Pr~fe. 1~7.~ ~ig Unloading ~quln~ ~ :.- ....... ~ ...... Unloading C~in0 P~u ': 1.:~00 ~ssUm! (P-~iq) !'6~o 1 ebo 2o'o0 ezbo 24'00 26'o0 2800 M-28 PGM for AOGCCl.doc Page 27 0f43 11/08/02 UNOCAL ) REVISION 6 # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Note: 4-1/2" x 4' and 4-1/2" x 6', 12.6 Ib/ft L-80, Butt Tubing Pup Joint will be bucked-on, at Pollard shop, on each GLM. (4' pup on bottom & 6' pup on top). Note: The Gas lift Mandrels are threaded Buttress. The Tubing is threaded Modified Buttress with seal rings. The Pup Joints will have Buttress Pins and Modified Buttress Boxes. Once they are screwed together the Gas Lift Mandrel Box ends will be the only connections in the hole without seal rings. Attach a 4-W' LaSalle Clamp on the connection of each pup joint, above and below each GLM. i. Place the refurbished 4-1/2" x 1-1/2" SFO-2 Gaslift Mandrels Major OD= 7.063" Minor OD= 6.141" Effective running OD w/Cable = 7.752" GLM#8 @ 7747'+ GLM#7 @ 7215'+ GLM#6 @ 6690'+ GLM#5 @ 6103'+ GLM#4 @ 5397'+ GLM#3 @ 4551'+ GLM#2 @ 3602'+ GLM#1 @ 2206'+ ii. 4-1/2" 12.6 Ib/ft L-80 Butt Mod. Tubing to surface iii.10' Double Pin 4-1/2" 12.6 Ib/ft L-80 Mod Butt (bucked onto tubing hanger in advance at BOT shop) iv. McEvoy Tubing Hanger with BIW penetrator for ESP cable and scale inhibitor line. (EFT feed through to be installed after hangar picked up to ensure no damage occurs. Thread protectors to be installed on feed through) Notes: · Have extra 4-1/2" modified seal rings available. · All GLM depths are to nearest joint. Place Mandrels on the deeper end of the joint where necessary. · Double checks are to be installed in all of the GLM valves. · Do not use space out pups in the completion assembly. The approximate setting depth of the completion should be 10,390' to 10,430'. (Bottom of ESP). · Install LaSalle cable protectors over every other coupling to surface. LaSalle recommends 30 fi-lbs of torque for the cap screw fasteners. Use speed wrenches. · Orient LaSalle cable protectors and the GLM's so the ESP cable will run along the same side as the minor diameter of the GLM. (4-1/2" GLM, 7.063" x 5.625") One LaSalle cable protector to be used above and below each GLM assembly on collars of pups. M-28 PGM for AOGCC 1 .doc Page 28 of 43 11/08/02 UNOCALe REVISION 6 AF~ ,~ 154718-0-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure · Install LaSalle cable protectors above and below all splices. SuperBand above and below all splices. · TIH slowly (+/- 1 joint/min) and exercise caution to avoid sudden starts and stops which may damage ESP cable, especially during setting slips. · Perform conductivity test on ESP cable every 1000' or while RIH. Report Megs on DDR. · A Hot Work Permit will be required during conductivity tests. (2500 Volt) · Record location and number of clamps and straps run in the well on the pipe tally. 30. Cut ESP cable and strip back wire and chemical injection line. Splice ESP cable to BIW hangar penetrator pig tail. Make up chemical injection upper check valve. Test conductivity of both ends of the BIW penetrator/ESP cable. We will change BIW Cable and FeedThru to new style. 31.Install BPV and make up 4-1/2" IBTC landing joint to hanger. Mark hanger with paint to observe proper landing at wellhead. Have well drained to tubing head and lock down screw removed so ClW can observe proper seating of hanger in tubing spool. Hook up 100' Centrilift "Pigtail" to ESP cable and spool out while lowering down the hanger to ensure electrical conductivity. Orient and lower hanger downward while scribing position of cable relative to annulus gas lift inlet. (See Note 2 below). Care should be taken while lowering hangar, as it tends to catch on the BOP's. Land tubing with extreme caution to avoid damage to ESP cable hanger. Engage lock down screws. VII. ND BOPE's~ NU TREE 32. Recover landing joint. ND BOP's. 33. Lower the adapter flange through the rotary table. N/U carefully to minimize risk of damage to the penetrator. Note: Tree connection is 4-1/2" Buff. 34. Make a final conductivity check of ESP cable. 35. Recover BPV and set two way check. Pressure test tree, hangar body and neck seals, ESP penetrations and ring gasket to 5000 psi. Recover two way check. 36. Install flowline and surface facilities. 37. Turn well over to Production. Consider getting a baseline Gas Lift rate prior to ESP rate. Note: Prior to turning on gas lift or the pump, record BHP from "Phoenix Gauge" and relay to Steve Martinez. M-28 PGM for AOOCCl.doc Page 29 of 43 11/08/02 UNOCAL ) REVISION 6 # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure VIII. NOTES SPECIFIC TO RUNNING ESP COMPLETIONS 1. Do not handle cable spool with forks or slings which are in contact with the cable. 2. Exercise caution when handling seal, motor and pump sections to minimize bending. Use at least two lift points when moving horizontally. Equipment will remain in boxes until ready to install. 3. All ESP and cable movement shall be witnessed by an ESP service company representative. 4. If the temperature is below 32 degrees F, bring the motor oil and pump equipment into a heated location at least 48 hours prior to running. 5. Motor, seal and pump boxes should be supported by three equally spaced rests or on a flat surface whenever in storage or shipment. 6. Exercise extreme care to avoid jarring or bending equipment (especially pump) when transporting to rig floor. 7. Test pneumatic bander on a junk piece of cable and tubing joint to ensure proper band tightness. Band stretcher shall be operated at manufacturers recommended pressure of 60 psi. 8. The hole shall be covered at all times when bands are being installed. 9. Designate one person on the rig floor to be responsible to ensure the slips do not set on the cable when running in. 10. The cable shall be double banded above and below each splice. "Super Bands" will be used at all times with the exception of flat cable. 11. Check and record ESP conductivity phase to phase and phase to ground for all three phases at the motor, Initial check with pump at surface and second when tubing hangar installed, Electrical conductivity checks shall be made at least every 1000' while TIH. · 12. Send one copy of the ESP Installation Report into the Anchorage office. ESP Assembly Preparation 1. All ESP equipment including pressure sensor shall be inspected and tested as appropriate and serial numbers confirmed as soon as the ESP representative arrives on board. 2. An ESP representative shall be on the rig floor at all times when the ESP cable or equipment is run in the hole. 3. The motor lead extension shall be spliced and tested prior to picking up. 4. All cable penetrators shall be high-potted prior to bringing to location. Attach copy of high-pot test to Daily Drilling Report and send copy to Anchorage Office. 5. Confirm oil on location Centrilift CL5. All components will come to the rigsite pre-filled. 6. Pothead/Motor Lead Extension Handling: Do not bend the motor lead near the base of the pothead. Never bend the motor lead along its major axis. This causes relative movement of the conductors. Never pull directly on a pothead., especially when unreeling or running over a sheave. Pull on cable at least 1' away. GANNED DEC 0 2130 M-28M-28 PGM for AOGCCl.doc Page 30 of 43 11/08/02 UNOCALe REVISION 6 Al(, # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Do not apply tension to the motor lead during installation. Have it and the cable above it completely banded prior to applying any cable tension. IX. WELL HISTORY LAST WORK: 4~7~99 Date 1990 3/23 6/6 9/21 - 10/19 10/27 -10/29 11/2 11/5 11/22 1991 3/15 STEELHEAD PLATFORM API# 50-733-20414-00 TBU M-28 Action Spud Well. Perforated and squeeze the interval 10620-10623'. 6/21COMPLETED AS A DEVELOPMENT OIL WELL. Perforated Middle Jurassic, 4HPF, 90° phase. Mid-Jur 12675-12748' 73' Perforated Middle Jurassic 4HPF with 3-3/8" Omnikone Guns, 90° Phase. Mid-Jur 12675-12748 73' Mid-$ur 12748-12808 60' Mid-Jur 12810-12900 90' 223' Fracture stimulate (Stressfrac) 12883-895'. Lost Stressfrac tool at 12880' Fracture Stimulate (Stressfrac) 12680-704' Production Test (24 hours) Oi__.! Gas Water FTP CP Gravity 224bbls 110mcr 0bbls 150psi 100psi 32.9° Fracture Stimulate (Stressfrac) 12692-704', Lost 16' Stressfrac Tool at 12862' and ran 76 hr PBU Survey. Fracture Stimulate - (Datafrac) 6/9-11 Coiled Tubing Cleanout - RIH with CT to 12,000'. Started pumping KCL ~ 2 1/2 bpm, 4,300 psi, washed sand and earbolite to 12,733'. PooH flowed well until Wcs return to 40% range. Shutin M-28M-28 PGM for AOC-CC1 .doc Page 31 of 43 11/08/02 UNOCALe REVISION 6 (' A X_ # 154718-O-00 Steelhead Platform Well it M-28 ESP WO2 Replace ESP Procedure well for 3 hours - max SIP was 1,975 psi. RIH with CT tagged fill at 12,733' CTM. Washed to 12,853'. POOH open well to flow RD CTU. 6/11 Coiled tubing cleanout to 12,733 7/10 - 14 72 hr. PBU Survey and Flowing Gradient 7/15 - 16 Perforated Middle Jurassic 6I-IPF with 3 3/8" Omnicone guns, 60° Phase: Mid-Jur. 12,650-670' Mid-Jur. 12,700-640' 7/22 Ran 4 1/2" 12.6# L-80 tbg to 10,568' with Baker db pkr. set ~ 10,254' and 11,175' and Baker FB- I pla' set ~ 12,351' Tagged fill ~ 12745'. 8/14 Static BlIP Survey 9/18 Fracture stimulate with CT cleanout. 9/18-20 Fracture Stimulate with CT Cleanout - Install tree sayer. Pressure test treating lines against tree saver valve to 10,000 psi. Perform injeetivity test. Establish 15 BPM ~ 5,200 psi. ISIP = 3,850 psi. Proceeded frac treatment but coul not stabilize PPA @ 12 PPG. Cut stage early when losing blender discharge. Rate and pressure stable until prop hit perfs and screen out occurred. Le/~ 47,000 lbs of 54,000 lbs propent in wellbore. Shutin allowed propent to settle and gels to break. RU CTU and cleaned out to 12,390'. 9/24 Tagged fill at 12855'. 10/3 Install Jet Pump - On 2/22 hung 4 1/2" 12.6# L-80 Butt AB Modified tba. with Otis XD production sleeve ~ 10,462'. In September 1991 a jet pump / SCSV Assembly was RIH and set in XD sleeve at 10,462'. On 10/3/91 conduct well test. 10/31 to 11/2 Stress Frae. 11/22 Stress Frae. 12/10 72 hr. PBU Survey 1992 1/1 - 2 PF - Perforated West Foreland 6 HPF with 2 1/8" Dyna-strip guns, O° phase: WF-0 11,815-831' 16' WF-0 11,836-841' 5' WF-0 11,848-858' 10' WF-0 11,865-875' 10' WF-1 11,912-922' 10' WF-1 11,930-950' 20' WF-2 ! 1,966-976' 10' M-28M-28 PGM for AOGCCI.doc Page 32 of 43 11/08/02 UNOCAL ) REVISION 6 / AI~,.~ # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure Total 81' 1/2 - 3 PF - Perforated G-Zone 4 HPF with 2 1/2 Hollow Carriers, O° Phase: G-1 10,632-658' 26' G-2 10,684-704' 20' G-3 10,798-822' 24' G-4 10,858-888' 30' G-5 10,964-994' 30' G-5 11,012-037' 25' Total 185' 7/12 TAG - Tagged fill 12,080' with Bailer 8/14 PF - Reperforated West Foreland 6HPF with 2 1/8" Enerjet IH, 0° Phase: WF-0 11,815-831' 16' WF-0 11,836-841' 5' WF-0 11,848-858' 10' WF-0 11,865-875' 10' WF-1 11,912-922' 10' WF-1 11,930-950' 20' WF-2 11,966-976' 10' Total 81' 8/14-15 PF - Reperforated G-Zone 6HPF with 2 7/8" Hollow Carrier, 0° Phase: G-1 10,632-658' 26' G-2 10,684-704' 20' G-2 10,720-744' 24' G-3 10,92-827' 30' G-4 10,858-888' 30' G-5 10,964-980' 16' G-5 11,014-028' 14' Total 160' 10/28 TAG - Tagged Fill ~ 12,348'. 1993 1/2 4/9 11/1 11/2 11/10 TAG - Tagged fill ~ 12,036' PS - Static BHP Survey WO - Pulled tubing - ran 4 1/2" 12.6# L-80 tbg. to 10,575' with Baker FHL Pkr set 10,435' and a Baker SB-3 pkr. set at 10,481' to straddle leak in 9 5/8" csg. ~ 10,446'. TAG - Tag fill ~ 12,351'. PF - Perforated G -Zone, 6HPF with 3-3/8" HSD Guns, 0 Phase: 11/10/93 G-1 10,634 - 654' 20' 11/10/93 G-2 10,685 - 705' 20' M-28M-28 PGM for AOGCC1 .doe Page 33 of 43 11/08/02 UNOCALe REVISION 6 AI . # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 11/10/93 11/9/93 11/9/93 11/9/93 11/7/93 11/7/93 TOTAL G-2 G-3 G-4 G-4 G-5 G-5 10,722-737' 10,798-818' 10,840- 850' 10,858- 888' 10,964-994' 11,012-037' 15' 20' 10' 30' 30' 25' 170' Production Tests: Date Oil(Bbls) Gas0VICF) Water(Bbls) TP(Psi) CP(Psi) 10/13/93 1,311 949 304 4,237 65 11/30/93 1,506 39 218 175 830 1994 1995 1996 8/26 GLS - Gas Lift Survey: BHFP = 775.4 psi ~ 8,584' TVD. BHT = 172.6 deg. F ~ 8,584' TVD. Well is lifting from GLV # 11. RATE = 1,632 BFPD, 1,350 BOPD, 17.3 WC PI = 0.8 BFPD/PSI. 1997 1/25GR - Rill w/3.70" GR set dwn ~ 10,340' cut scale to 10,392', set down unable to pass. Rill w/2.81" GR set dwn ~ 12,172' WLM. POOll. Rill w/3.30" broach to 11,000'. ?OOll. Rill W/3.60" broach to 10,454' worked dwn to 10,491'. Scale to EOT ~ 10,195'. 2/2 SR - Production Profile. Schlumberger Profile: Flow Rates At Surface Conditions. (Shut-in 5 hrs.) SIBI-IP = 2,054 psig and Temperature of 177.5 degs F ~ 10,850 MD. A downhole flowing pressure of 851 psi and temperature of 177.3 degs F ~ 10,850 MD. An average flowrate of 511 BOPD with 27.3 percent water cut was recorded at the surface during the flowing survey. Interval Bench Water Oil Gas %Water GOR Interval BPD STB/D Mscf/D Cut SCF/STB % 10632'-10658 G-1 10 10 15 44 1400 4 10684'-10705' G-2 10 155 60 6 384 28 10720-10744' G-2 35 310 110 10 363 56 10792-10822' G-3 5 15 5 33 357 3 10840'-10850' G-4 0 5 0 0 250 1 10858'-10888' G-4 0 0 0 0 0 0 10964'-10994' G-5 50 0 0 100 0 6 11012'-11037' G-5 20 0 0 100 0 2 Total 125 495 190 20 388 100 2/2 SR - Production Profile. Schlumberger Profile: Flow Rates At Surface Conditions. M-28M-28 PGM for AOGCCl.doc Page 34 of 43 11/08/02 # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 REVISION 6 Replace ESP Procedure (Shut-in 4 hrs.) SIBHP = 2,277 psig and Temperature of 185.5 degs F ~ 11,875 MD. A downhole flowing pressure of 1,220 psi and temperature of 186.3 degs F ~ 11,875 MD. An average flowrate of 511 BOPD with 27.3 percent water cut was recorded at the surface during the flowing survey. Bench Water Oil Gas % Water GOR Interval Interval BPD STB/D Mscf/D Cut SCF/STB % 11815'-11831 WF-2 5 0 0 100 0 2 11836'-11841 WF-2 0 0 0 100 0 1 11848'-11858 WF-2 5 20 5 12 190 21 11865'-11875 WF-2 0 10 0 0 200 9 11912'-11922 WF-3 0 0 0 0 0 0 11930'-11950 WF-3 25 20 5 53 181 38 11966'-11976 WF-3 25 10 0 71 181 30 Total Surf, 60 65 10 47 187 100 Production 12/5 12/5-8 1998 5/16 1999 2/23 TAG- Tagged fill ~ 12,120' with GR/CCL. PF - Perforated G -Zone, 6HPF with 3-3/8" H. Carrier Guns, 60 Phase: 12/8/97 G-1 10,638 - 658' 20' 12/5/97 G-2 10,685 - 710' 25' 12/5/97 G-2 10,725 - 745' 20' 12/5/97 G-3 10,805 - 825' 20' TOTAL 85' FL - Shoot Fluid level on M-28, Fluid ~ 10,395.' TAG - Tagged TD ~ 11,038' KB w/2.25" gauge ring, no problems. 2/24-25 WL - RIH w/2.0" gauge ring to 11,038' KB, beat down for 1 hour, couldn't get past, POOH, gauge ring was dented up pretty good. RIH w/8' X 2 ¼" DD bailer to 11,038' KB, work tools, POOH w/bailer full of sand & fine grain scale w/some small rocks. Continued bailing sand from 11,038' KB, couldn't get deeper. Could not complete production profile. 3/18-19 FL - 1. Shoot fluid level, found fluid level ~ 6,897' KB. NOTE: Tubing pressure 730#, Casing pressure 760#. 2. Shoot fluid level ~ 5,966' KB. NOTE: Tubing pressure 815#, Casing pressure 760#. 3. Shoot fluid level, fluid level @ 5630' KB. NOTE: Tubing pressure 865#, casing pressure 760#. 4. Shoot fluid level, fluid level ~ 5220' KB. NOTE: Tubing pressure 920#, easing pressure 760#. 5. Shoot fluid level, fluid level @ 5001' KB. NOTE: Tubing pressure 950#, casing pressure 760#. 6. Shoot fluid level, fluid level ~ 4820' KB. NOTE: Tubing pressure 980#, casing pressure 760#. 7. Shoot fluid level, fluid level ~ 1848' KB. NOTE: Tubing pressure 80#. 3/21-24 Tag - DG - RIH w/ 3.25" gauge ring & tagged obstruction in line ~ 11,006' KB, possibly damaged liner, gauge ring had metal to metal marks. RIH w/20' x 2 7/8" dummy gun & set down M-28M-28 PGM for AOGCC1 .doc of A}INEO DEC 0 6 200 11/08/02 UNOCALe REVISION 6 AI~.. # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure ~ 11,015' KB, worked tools, couldn't get any Tagged obstruction ~ 10,626' KB w/3.70" gauge ring. RIH w/2-¼" DD bailer & set down ~ 11,014' KB, couldn't get any deeper. Attempted to pass obstruction in casing ~ 11,038' KB w/N kick over tool, no luck. 4/4-7 DG - LIB - Tagged obstruction w/3.5" tapered LIB ~ 10,940' WLM, 11,022' KB. Tagged obstruction w/2.872" dummy gun ~ 11,022' KB, unable to pass, POOH.. Tagged obstruction w/ 2-7/8" dummy gun & bent stem. Tagged obstruction w/3.40" dummy gun, unable to get down & unable to get tools into tubing. Freed stuck tools & POOH. 2001 7/16 After 3 days of shut in to work on surface electrical equipment, the ESP pressure gauge read 2855 at 8254' TVD. Using 0.43 psi/ft gradient, datum pressure is 3369 psi at 9450' TVD. M-28M-28 PGM for AOGCC 1 .doc Page 36 of 43 11/08/02 UNOCALe REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure X. M-28 WELL WORK HISTORY Report Name [ Well I Well History (Database) M-28 Date Created I 4~4~02 I Date Type Tbg String Event Event April 2002 Failed ESP 4-1/2" A workover will be performed to replace the ESP that has failed. The well is currently producing via gas lift mandrels. The oil rate after the last ESP replacement was 250 BOPD short when compared to the previous ESP. It is believed that the "G" zone perforations are damaged. During the upcoming workover, it is proposed to reperforate the "G" Zone. 05/01/00 to 05/13/00 Replace failed ESP 4-1/2" Well M-28 was converted from a gas lift completion to an ESP completion in September 1999. The ESP system failed on 2/21/00. The well was immediately brought on line with gas lift while awaiting an opportune time to work over the well. The well work consisted of recovering the tubing string and defective ESP assembly. The well was then re-completed with used 4-1/2" completion string and new 400HP motor, pump and electric cable. (Eight GLM's were installed in the 4-1/2" completion string to enable lift should the pump fail.) The apparent mode of failure was a short in the fiat cable alongside the motor. 8/24/99 to 9/19/99 Conversion 4-1/2" The well work consisted of recovering the tubing string, fishing the top packer and milling up and retrieving the lower packer. Afterwards a cleanout trip to below the West Foreland was attempted in order to isolate the Jurassic below with a cement retainer. The cleanout trip ,was unsuccessful and eventually the lower 14' of the cleanout assembly was left as a fish on bottom. An isolation assembly consisting of 5 joints of 7" 29 Ib/ft casing was run on a ZXP packer and stabbed into the 7" liner top packer to isolate 9-5/8" casing damage above the liner top. Afterwards an upper isolation assembly consisting of a 9-5/8" Baker FA permanent aacker set on wireline was run in conjunction with 4 joints of 7" 29 Ib/ft casing run on a 9-5/8" SC-IL retrievable packer. The existing G and new Hemlock intervals were subsequently under- M-28M-28 PGM for AOGCCI.doc Page 37 of 43 11/08/02 UNOCALe REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure balance perforated with TCP guns. The well was allowed to flow back for one hour to obtain a "No Flow" and the TCP assembly was retrieved. The well was completed as a 4-1/2" single string completion with lift provided by a 600 hp Centrilift pump assembly. (Six GLM's were installed in the 4-1/2" completion string to enable lift should the pump fail.) The well was brought on production at the following production rate: Gross 3492 BPD, 906 BOPD, 103 psi FTP. 4/7/1999 Misc DG - LIB - Tagged obstruction w/3.5" tapered LIB @ 10,940' WLM, 11,022' KB. Tagged obstruction w/2.872" dummy gun @ 11,022' KB, unable to pass, POOH.. Tagged obstruction w/2-7~8" dummy gun & bent stem. !Tagged obstruction w/3.40" dummy gun, unable to 4/7/1999 Misc DG - LIB - Tagged obstruction w/3.5" tapered LIB @ 10,940' WLM, 11,022' KB. Tagged obstruction w/2.872" dummy gun @ 11,022' KB, unable to }ass, POOH.. Tagged obstruction w/2-7~8" dummy gun & bent stem. Tagged obstruction w/3.40" dummy gun, unable to 3/24/1999 Tag Tag - DG - RIH w/3.25" gauge ring & tagged obstruction in line @ 11,006' Tag 11015 KB, possibly damaged liner, gauge ring had metal to metal marks. RIH w/ 20' x 2 7/8" dummy gun & set down @ 11,01 5' KB, worked tools, couldn't get any Tagged obstruction @ 10,626' 3/24/1999 Tag Tag - DG - RIH w/3.25" gauge ring & tagged obstruction in line @ 11,006' Tag 11015 KB, possibly damaged liner, gauge ring had metal to metal marks. RIH w/ 20' x 2 7~8" dummy gun & set down @ 11,01 5' KB, worked tools, couldn't get any Tagged obstruction @ 10,626' 3/19/1999 Misc FL - 1. Shoot fluid level, found fluid level @ 6,897' KB. NOTE: Tubing pressure 730#, Casing pressure 760#. 2. Shoot fluid level @ 5,966' KB. NOTE: Tubing pressure 815#, Casing pressure 760#. 3. Shoot fluid level, fluid level @ 5630' KB. NOTE: Tu M-28M-28 PGM for AOGCCl.doc Page 38 of 43 11/08/02 UNOCALe REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 3/19/1999 Misc FL - 1. Shoot fluid level, found fluid level @ 6,897' KB. NOTE: Tubing pressure 730#, Casing pressure 760#. 2/25/1999 Misc WL - RIH w/2.0" gauge ring to 11,038' KB, beat down for 1 hour, couldn't get past, POOH, gauge ring was dented up pretty good. RIH w/8' X 2 ¼" DD bailer to 11,038' KB, work tools, POOH w/bailer full of sand & fine grain scale w/some small rocks. Cont 2/23/1999 Misc TAG - Tagged TD @ 11,038' KB w/2.25" gauge ring, no problems. 5/16/1998 Misc FL - Shoot Fluid level on M-28, Fluid @ 10,395.' 12/8/1997 Perforate/Re-Perforate PF - Perforated G -Zone, 6HPF with 3-3/8" H. Carrier Guns, 60 Phase: Perf 12/8/1997 Misc G-1 10,638 - 658' 20' 12/5/1997 Tag TAG - Tagged fill @ 12,120' with GR/CCL. Tag 12120 12/5/1997 Misc IG-2 10,685 - 710' 25' 12/5/1997 Misc :G-2 10,725 - 745' 20' 12/5/1997 Misc G-3 10,805 - 825' 20' TOTAL 85' 2/2/1997 Production/Injection Log SR - Production Profile. Schlumberger Profile: Flow Rates At Surface Prod Log Conditions. (Shut-in 4 hrs.) SIBHP = 2,277 psig and Temperature of 185.5 degs F @ 11,875 MD. A downhole flowing pressure of 1,220 psi and temperature of 186.3 degs F @ 11,875 2/2/1997 Production/Injection Log SR- Production Profile. Schlumberger Profile: Flow Rates At Surface Prod Log Conditions. (Shut-in 5 hrs.) SIBHP = 2,054 psig and Temperature of 177.5 degs F @ 10,850 MD. A downhole flowing pressure of 851 psi and temperature of 177.3 degs F @ 10,850 1/25/1997 Misc (3R - RIH w/3.70" GR set dwn @ 10,340' cut scale to 10,392', set down unable to pass. RIH w/2.81" (3R set dwn @ 12,172' WLM. POOH. RIH w/3.30" broach to 11,000'. POOH. RIH W/3.60" broach to 10,454' worked dwn to 10,491'. Scale to EOT @ 10,195'. 2/2 SR 8/26/1996 Gas Lift Survey GLS - Gas Lift Survey: BHFP = 775.4 psi @ 8,584' TVD. BHT = 172.6 deg. GLS F @ 8,584' TVD. Well is lifting from GLV # 11. RATE = 1,632 BFPD, 1,350 BOPD, 17.3 WC PI = 0.8 BFPD/PSI. M-28M-28 PGM for AOGCCI.doc Page 39 of 43 11/08/02 UNOCAL ) REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 11/10/1993 Perforate/Re-Perforate PF - Perforated G -Zone, 6HPF with 3-3/8" HSD Guns, 0 Phase: 11/10~93 Perf G-1 10,634 - 654' 20' 11/10/93 G-2 10,685 - 705' 20' 11/10/93 G-2 10,722 - 737' 15' 11/9/93 G-3 10,798- 818' 20' 11/9/93 G-4 10,840- 850' 10' 11/9/93 G-4 10,858 - 888' 3 11/2/1993 Misc TAG - Tag fill @ 12,351'. 11/1/1993 Rig Work Over WO - Pulled tubing - ran 4 1/2" 12.6# L-80 tbg. to 10,575' with Baker FHL Workover Pkr set 10,435' and a Baker SB-3 pkr. set at 10,481' to straddle leak in 9 5/8" csg. @ 10,446'. 4/9/1993 Misc PS - Static BHP Survey 1/2/1993 Misc TAG - Tagged fill @ 12,036' 10/28/1992 Misc TAG - Tagged Fill @ 12,348'. 8115/1992 Perforate/Re-Perforate PF - Reperforated G-Zone 6HPF with 2 7/8" Hollow Carrier, 0o Phase: G-1 Perf 10,632-658' 26' G-2 10,684-704' 20' G-2 10,720-744' 24' G-3 10,92-827' 30' G-4 10,858-888' 30' G-5 10,964-980' 16' G-5 11,014-028' 14' Total 160' 8114/1992 Perforate/Re-Perforate PF - Reperforated West Foreland 6HPF with 2 1/8" Enerjet III, 0o Phase: Perf WF-0 11,815-831' 16' WF-0 11,836-841' 5' WF-0 11,848-858' 10' WF-0 11,865-875' 10' WF-1 11,912-922' 10' WF-1 11,930-950' 20' WF-2 11,966- 976' 10' Total 81' 7/12/1992 Misc TAG - Tagged fill 12,080' with Bailer 1/3/1992 Perforate/Re-Perforate PF - Perforated G-Zone 4 HPF with 2 1/2 Hollow Carriers, Oo Phase: G-1 Peri 10,632-658' 26' G-2 10,684-704' 20' G-3 10,798-822' 24' G-4 10,858-888' 30' G-5 10,964-994' 30' G-5 11,012-037' 25' Total 185' 1/2/1992 Perforate/Re-Perforate PF - Perforated West Foreland 6 HPF with 2 1/8" Dyna-strip guns, Oo Perf phase: WF-0 11,815-831' 16' WF-0 11,836-841' 5' WF-0 11,848-858' 10' WF-0 11,865-875' 10' WF-1 11,912-922' 10' WF-1 11,930-950' 20' WF-2 11,966-976' 10' Total 81' 12/10/1991 Pressure Buildup/Falloff 72 hr. PBU Survey PBU Test 11/22/1991 Fracture Stimulation Stress Frac. Frac 111211991 Fracture Stimulation Stress Frac. Frac M-28M-28 PGM for AOGCCI.doc Page 40 0f43 11/08/02 UNOCAL REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 10/3/1991 Misc Install Jet Pump - On 2/22 hung 4 1/2" 12.6# L-80 Butt AB Modified tba. with Otis XD production sleeve @ 10,462'. In September 1991 a jet pump ! SCSV Assembly was RIH and set in XD sleeve at 10,462'. On 10/3/91 conduct well test. 9/24/1991 Misc Tagged fill at 12855'. 9/20/1991 Fracture Stimulation Fracture Stimulate with CT Cleanout - Install tree sayer. Pressure test Frac treating lines against tree saver valve to 10,000 psi. Perform injectivity test. Establish 15 BPM @ 5,200 psi. ISIP = 3,850 psi. Proceeded frac treatment but coul not stabilize 9/18/1991 Fracture Stimulation Fracture stimulate with CT cleanout. Frac 8/14/1991 Misc Static BHP Survey 7/22/1991 Misc Ran 4 1/2" 12.6# L-80 tbg to 10,568' with Baker db pkr. set @ 10,254' and 11,175' and Baker FB-1 pkr set @ 12,351' Tagged fill @ 12745'. 7/16/1991 Perforate/Re-Perforate Perforated Middle Jurassic 6HPF with 3 3/8" Omnicone guns, 600 Phase: Perf Mid-Jur. 12,650-670' Mid-Jur. 12,700-640' 7/14/1991 Pressure Buildup/Falloff 72 hr. PBU Survey and Flowing Gradient PBU Test 6/11/1991 Misc !Coiled Tubing Cleanout- RIH with CT to 12,000'. Started pumping KCL @ 2 1/2 bpm, 4,300 psi, washed sand and carbolite to 12,733'. PooH flowed well until Wcs return to 40% range. Shutin well for 3 hours - max SIP was 1,975 psi. RIH with CT tagged fil Date Type Tbg String Event Event 6/11/1991 Misc Coiled tubing cleanout to 12,733 3/15/1991 Fracture Stimulation Fracture Stimulate - (Datafrac) Frac 11/22/1990 Fracture Stimulation Fracture Stimulate (Stressfrac) 12692-704', Lost 16' Stressfrac Tool at Frac/PBU 12862' and ran 76 hr PBU Survey. 11/5/1990 Misc Production Test (24 hours) Oil Gas Water FTP CP Gravity 224bbls 110mcf 0bbls 150psi 100psi 32.90 11/2/1990 Fracture Stimulation Fracture Stimulate (Stressfrac) 12680-704' Frac 10/29/1990 Fracture Stimulation Fracture stimulate (Stressfrac) 12883-895'. Lost Stressfrac tool at 12880' Frac M-28M-28 PGM for AOGCCI.doc Page 41 of 43 11/08/02 UNOCALe REVISION 6 AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP WO2 Replace ESP Procedure 9/21/1990 Perforate/Re-Perforate finished 10/19 Perforated Middle Jurassic 4HPF with 3-3/8" Omnikone Perf Guns, 90o Phase. Mid-Jur 12675-12748 73' Mid-Jur 12748-12808 60' Mid- Jur 12810-12900 90' 223' 6/21/1990 Complete Well COMPLETED AS A DEVELOPMENT OIL WELL. Perforated Middle Completion Jurassic, 4HPF, 90o phase. Mid-Jur 12675-12748' 73' ran 6/6/1990 Perforate/Re-Perforate Perforated and squeeze the interval 10620-10623'. Perf 3/23/1990 Spud/Re-Drill Well Spud Well. Spud M-28M-28 PGM for AOGCCI.doc Page 42 of 43 11/08/02 UNOCAL ) WO2 REVISION 6 XI. CAMERON WELLHEAD DRAWING AFE # 154718-O-00 Steelhead Platform Well # M-28 ESP Replace ESP Procedure M-28M-28 PGM for AOOCCl.doc Page 43 of 43 11/08/02 Re: M-28 Sundry I'~,otice Subject: Re: M-28 Sundry Notice Date: Fri, 01 Nov 2002 13:36:57 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Mosley, Jim I" <mosleyj@unocal.com> Thanks Jim. "Mosley, Jim I" wrote: Tom, The Sundry notice sent in August 23, 02 requested permission to reperforate while we are out of the hole during the ESP repair. We have had a change of scope and will not reperforate while we are out of the hole. We will however, run a "Y" block assembly with bypass tubing. This will allow us to have several options after we run the pump. I will send you a copy of the program shortly so that you will have more of the details. Thanks, Jim Mosley Jim Mosley Sr. Advising Drilling Engineer Unocal Alaska Union Oil Company of California 909 W. 9th Ave. P.O. Box 196247 Anchorage Alaska 99519-6247 Office 907-263-7679 Cell 907-351-8639 Home 907-694-4170 Fax 907-263-7884 EMAIL Mosleyj(~Unocal.com Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 11/5/2002 2:37 PM TBU M-28 Subject: TBU M-28 Date: Sun, 01 Sep 2002 14:58:53 -0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Jim Mosley <mosleyj(~unocal.com> Jim, I have looked at the workover proposed for M-28. M-28 has a failed ESP and Unocal proposes to replace it and re-perforate the G zone. ! am requesting that you provide further information with regard to this proposed operation as specified in 20 AAC 25.280 (b) (1) through (5). You should also note 20 AAC 25.033 (e) (3) which specifies the wellbore must be kept full of drilling fluid at all times and (4) which specif'~s the filling frequency. The advice in step 12 of your procedure may not be suff'=ient to keep the hole full. I also request information regarding Unocal's contingency plan for shutting in the well with the ESP cable through the rotan/and what provisions Unocal has made for safely cutting the cable should it be necessary. Thanks for your attention to these questions. I will likely not be in on Tuesday since I have been summoned for jury duty and my group reports that day, but I will be checking my messages as I can. Tom Maunder,. PE AOGCC Tom Maunder <tom maunder~admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 911/2002 2:59 PM ' ~W: Schematic of Well M-28 After Completi,,' and Completion Detail s Subject: FW: Schematic of Well M-28 After Completion and Completion Detail s Date: Thu, 9 Sep 1999 11:06:51 -0700 From: "Magee, D. Nell -Contract" <dnmagee@unoeal.eom> To: "'Blair Wondzell"' <Blair Wondzell@admin.state.ak.us> CC: "Williamson, Dan R" <w~liamsond@Orion. Unocal.com> Blair, attached is the anticipated completion schematic of M-28. <<M-28 As Built Completion. doc>> > We will be performing a "No Flow,, test after TCP perforating this weekend. > The wellbore model indicates that the reservoir pressure of the newly > perforated Hemlock will be 7.7 ppg EMW and water cuts exceeding 90~. As > such we do not plan on installing a packer or safety valve in this > completion. A surface safety valve will however be incorporated in the · surface wellhead system. · In answer to your question regarding the reasoning for excluding a packer · in our completion, the following was the line of thought behind our · decision. It was felt that a packer would present a number of operational · uncertainties. As this is our first foray into large horsepower ESP's in · the Cook Inlet, we decided to exclude the packer for the following · operational considerations. > The free gas which is produced would make the efficient operation of the · pump difficult. There were concerns that gas slugging would shorten the · pump life due to motor amperage fluctuations and overspeed conditions. > Additionally, as the gas is produced, the expanding gas would have an > unknown effect on the pump operation and production rate. · We have estimated 4-6 weeks from the time the pump goes down to a · replacement pump being installed. Our primary objective during this period · of ESP downtime is to provide enough lift to prevent cross flow of the G · and Hemlock intervals and the gas lift design would enable this and still · provide some production benefit. > The final concern with placing a packer in the completion was the need for · two additional electrical penetrations. The electrical penetrators and > additional splices were identified as areas for special' concern in these · large horsepower pump applications. We were concerned that this would be · two additional areas for potential electrical failures. · > > · > · · We feel that given the well is anticipated to be in a no flow condition, and that the Hemlock reservoir pressure is expected to decline at a moderate rate once the pump is brought on line, (We anticipate 8000 BFPF lift rates) that we were best served with the completion shown. ~M-28 As Built Completion.doc Name: M-28 As Built Com~ Type: Winword File (application/msword)] Encoding: base64. . .......................................................................... I 1 ofl 9/9/99 2:26 PM UNOCAL Steelhead Well No. M-28 Proposed Completion RKB to TBG Head = 71.5' I 9 10 Casing Leak 10466' DIL Squeezed with 100 sx cement Squeeze Perfs 10620-10623' G Perfs "Bad" casing at 11035' Proposed W. Foreland Perf. 11 rassic Perf. RESSFRAC ------: L, oo] PBTD = 12,952' TD = 13,000' MAX HOLE ANGLE = 41.7 SIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415 Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604 Surf 497' 9-5/8" 47 N-80 Buttress 8.681 497' 11,399' 7" 29 N-80 Buttress 6.184 11,193' 12,448' 5" 18 N-80 FL4S 4.276 12,368' 13,000' Tubing: 4-1/2" 12.6 L-80 AB Mod 3.958 NO. Depth OD ID'~w~"ttxa"~sasLItem 1 Cameron Tubing Hanger EP-4SD-SL 13-5/8" NOM 4-1/2" Butt 72.50' 13.625 3.902 2 455.0' 4.500 3.958 3 7.031 3.833 4 10250' 5 10440.3' 8.460 6.000 6 7.00 6.184 7 10627.5' 8.437 6.000 8 10945.7' 8.25 6.312 9 7.00 6.184 10 11197.6' 7.00 6.184 11 12351 5.875 4.00 12 10537' 5.156 3.813 13 12369' 5.093 4.438 Top x Bottom 4-1/2" 12.6 lb/ti L-80 AB Modified tbg Otis GLM's with RK latch (5.625" x 7.031") 2459', 4426', 5595' 6371 ', 6894' 7422' (Valves Installed) Centriliii ESP Baker 9-5/8" SC-1L Isolation liner 4 its and pup. 7" 29 lb/ff L-80 Butt casing with Backer Anchor Assy KBH-22 (75 x 60) Baker Model FA permanent packer (190FA75) with 6' tieback Baker ZXP liner packer 7" x 9-5/8" Isolation Liner 5 jts and pup. 7" 29 Ib/ft Butt L-80 casing Baker Muleshoe Assy.into TIW TBE Baker FB-1 Packer (Size 85-40) Otis X landing nipple TIW LG-6 Tie-back Seals with ½ muleshoe PROPOSED PERFORATION DATA 10,705' 10,710' 5 10,684' 10,705' 21 10,720' 10,744' 24 10,792' 10,822' 30 10,840' 10,850' 10 10,85~ 10,888' 30 10,964' 10,994' 30 11,012' 11,037' 25 11,206' 11,246' 40 11,266' 11,276' 10 11,430' 11,470' 40 11,480' 11,500' 20 11,510' 11,530' 20 11,540' 11,550' 10 1157O 1159O 2O 11722 11742 20 11764 11778 14 12/5/97 12/5/97 12/5/97 12/5/97 11/9/93 11/9/93 11/7/93 11/7/93 G-1 G-2 G-2 0 G-3 11815 11831 16 8/14/92 WF-0 G-4 11836 11641 5 8/14/92 WF-0 G-4 11848 11858 10 8/14/92 WF-0 G-5 11865 11875 10 8/14/92 WF-0 G-5 11912 11922 10 8/14/92 WF-1 HB-1 11930 11950 20 8/14/92 WF-1 HB-2 11966 11976 10 8/14/92 WF-2 HB-3 12,655' 12,675' 20 1/2/92 Jur HB-4 12,675' 12,748' 73 1/2/92 Jur HB-4 12,748' 12,808' 60 1/2/92 Jur 12,810' 12,900' 90 1/2/92 Jur HB-5 HB-6 HB-7 DATE: 9/3/99 NM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~ Chairman DATE: August 23, 1999 THRU: Blair Wondzell, P. I. Supervisor Lou Grimaldi, ,~<.~ SUBJECT: FROM' Petroleum InslSector FILE NO: AUGJHXGF.DOC BOPE Test, Steelhead Unocal #M-28 McArthur River Field PTD #91-9 cio.- o~ Sunday, August 22, 1999: I witnessed the initial BOPE test on the Steelhead platform which was preparing to work over Unocal well #M-28 in the McArthur river field. The rig was almost ready to test when I arrived and we began shortly thereafter. All BOPE equipment was tested with three failures observed. These being a blind flange on the Kill line targeted "TEE" which was repaired by changing out the APl ring, the lower "Kelley" valve on the top drive which was cycled and retested "OK", and the Accumulator which during the function test bled below the 1200 psi minimum. This was tracked down to some of the accumulator bottles precharge being Iow or bled off. The bottles were recharged and retested "OK". There are still three bladders that are bad and need to be replaced but the extra capacity of the system should be able to carry it through. The rest of the BOP equipment tested out satisfactorily. The test time could have been much shorter if a small triplex pump were present instead of the Air pump used. SUMMARY: I witnessed the initial test of the BOPE on the Steelhead platform working over Unocal well # M-28 in the McArthur River Field. There were Three failures observed. Test time 10 hours. Attachments' AUGJHXGF.XLS CC: Dan Williamson (Unocal drilling supervisor) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: X Pool Rig No. Stlhd PTD # 91-19 UNOCAL Rep.: M-28 Rig Rep.: Set @ Location: Sec. Weekly Other TEST DATA ...~ DATE: 8/23/99 Rig Ph.# 776-6833 Larry McAIlister Donnie Fowler 33 T. 9N R. 13W Meridian Seward MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A FLOOR SAFETY VALVES: Quan. Well Sign P Upper Kelly/IBOP Drl. Rig P Lower Kelly/IBOP 1 Hazard Sec. P - Ball Type 2 '/ Inside BOP 1 Test Press. 250/3500 I 250/5, 000 I 250/5,000 1 250/5,000 1 250/5,000 I 250/5,000 3 250/5,000 250/5, 000 P/F P P P P P P P N/A MUD SYSTEM: Visual Alarm Trip Tank P p Pit Level Indicators P p Flow Indicator P p Meth Gas Detector P p . H2S Gas Detector P p - Test Pressure 250/5,000 250/5,000 250/5,000 250/5,000 P/F CHOKE MANIFOLD: No. Valves 12 No. Flanges 32 Manual Chokes 1 Hydraulic Chokes I Test Pressure 250/5, 000 250/5,000 Functioned Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 ] P 1,250 P minutes 56 sec. minutes 14 sec. P Remc~te: P Eight Bottles 2000 average Psig. ' ' ".'":. ,..:"'~ Y~$T: RESULTS ' Number of Failures: 3 ,Test Time: f0~.0 Hours. Number of valves tested 2'/ Repair or Replacement of Failed Equipment will be made within N/A ~ Notify the Inspector and follow with Wren or Faxed verification to the AOGCC Commission Office at: Fax No. 276.7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Blind flange on kill line tee leaked, replace APl ring and retest roOK: Lower kelley leaked. Accumulator drawdown below 1200 psi minimum, recharge Iow bottles and retest. Accumulator at minimums,'~'eplace bad bladders at first oppurtunity. Test time would be 2-3 hours shorter if good test pump was available. ,-- Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES' X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev.12/94) Augjhxgf. xls Unocal Corporation P.O. Box 196247 Anchorage, Alaska 995'19 907-263-7655 UNOCALe Dan Williamson Drilling Manager Subject: Steelhead M-28 Recompletion Dear Mr Wondzell, Unocal is proposing to workover the Steelhead Platform Well M-28 and re-complete the well as a 4-1/2" single string ESP completion. After the addition of the Hemlock interval, the additional drawdown provided by the ESP is expected to increase the well deliverability by 600 BOPD. The work program is expected to commence 1 June 1999. A "no flow" performance test will be performed on Well M-28 after perforation of the Hemlock interval. The current wellbore model indicates that the reservoir pressure of this interval will be 7.7 ppg EMW. The G Formation currently has a wellbore pressure of 2800 psi or an EMW of 7.3 ppg. If the results indicates a "no flow" condition, we do not plan on installing a sub surface safety valve or packer in the completion assembly. A surface safety valve system will be incorporated in the surface wellhead system. Attached is an Application for Sundry Approval and an overview of the planned workover. If you have any questions, please contact me at 263-7677 or Neil Magee at 263-7671. Dan Williamson Drilling Manager 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: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of Califonia (UNOCAL) Development: X 160' KB to MSL feet 3. Address Exploratory: 7. Unit or Property name Strafigraphic: Trading Bay Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface Leg B-1 Slot, Steelhead Platform 8. Well number 970' FNL, 532' FWL, Sec 33-9N-13W-SM M-28 At top of productive interval 9. Permit number 150' FNL, 2333' FEL, Sec 28-9N-13W-SM 91-19 At effective depth 10. APl number 90' FNL, 2335' FEL, Sec 28-9N-13W-SM 50-733-20414 At total depth 11. Field/Pool 85' FNL, 2331' FEL, Sec 28-9N-13W-SM McArthur River Field G/Hemlock/West Foreland 12. Present well condition summary Total depth: truemeasuredvertical 113'000' feeto,801, feet Plugs(measured) None Effective depth: measured 12,952' feet Junk (measured) Stresspac Logging Tool at 12,880' MD true vertical 10,751' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,447' 16" 1800 sx 1,447' 1,443' Surface 4,590' 13-3/8" 2900 sx 4,590' 4,030' Intermediate 11,399' 10-3/8"/9-5/8" 3360 sx 11,399' 9,333' Production Liner 12,448' 7" 400 sx 12,448' 10,265' Liner 13,000 5" 136 sx 13,000' 10.8Q2' · , Perforation depth: measured (See attachment) .., ,.~ .; .... . true vertical .. Tubing (size, grade, and measured depth) 4-1/2" 12.6 Ib/ff L-80, Imp Butt at 10,574' Packers and SSSV (type and measured depth) Baker Model FHL @ 10,435' Baker Model SB3 @ 10,481' Baker Model FB-1 ,..i,,~,..r ...... "' @12,351, ,,, Camco TRDP SSSV @ 455' 13. Attachi~ents Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estin~ated date for commencing operation 15. Status of well classification as: 6/1/1999 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby,~--~ify that t~e fop,~3j{ ~ is true _enid correct to the best of my knowledge. Signed: ~~~~~_ Title: Drilling Manager Date:W~f~~ " FOR COMMISSION USE ONLY ' Conditions of approval: Notify Commission so representative may witness JAppro.~ ~;~ (~)~, ,~_ Plug integrity BOP Test ~ Location clearance .-. Mechanical Integrity Test Subsequent form required 10- ~ ...... ,~e,.~ ) -17 ORiGiNAL SiGNED. BY Robert N. Chdstenson Approved by order of the Commissioner Commissioner Date ~'~'"-~.- Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Steelhead M-28 Perforations Zone FT TVD G-1 G-2 G-2 G-3 G-4 G-4 G-5 G-5 10632'-10658' 26 10684'-10705' 21 10720'-10744' 24 10792'-10822' 30 10840'-10850' 10 10858'-10888' 30 10964'-10994' 30 11012'-11037' 25 8687'-8707' 8728'-8744' 8756'-8775' 8813'-8837' 8851'-8859' 8865'-8889' 8950'-8974' 8989'-9008' WF-0 WF-0 WF-0 WF-0 WF-1 WF-1 WF-2 11815'-11831' 16 11836'-11841' 5 11848'-11858' 10 11865'-11875' 10 11912'-11922' 10 11930'-11950' 20 11966'-11976' 10 9676'-9690' 9694'-9699' 9705'-9714' 9720'-9729' 9764'-9773' 9780'-9798' 9812'-9821' 12655'-12675' 20 12675'-12748' 73 12748'-12808' 60 12810'- 12900 90 10465'-10484' 10484'-10555' 10555'-10614' 10616'-10705' Steelhead M-28 Summary of the Workover Proposal The well is completed in the G and West Foreland Formations and produces via a single string 4-1/2" gas lit~ completion. Currently the well produces 367 BOPD and 856 BWPD. Unocal plans to convert the well to an ESP completion as part of an initial program to evaluate the feasibility of converting a number of other potentially high volume Hemlock producers to ESP lif~ mechanisms on the Steelhead Platform. The proposed re-completion of M-28 is expected to increase well deliverability by 600 BOPD. The recompletion will entail circulating the well to 3% KCL/FIW, retrieving the existing gas lif~ completion, milling and retrieving the uppermost packer, isolating squeeze perforation and damaged casing intervals with an isolation assembly and re-rtmning a 4- 1/2" ESP completion. A draft workover program is provided as Attachment 1. UNOCALe Steelhead Well No. M-28 Proposed Completion RKB to TBG Head = 74.5' Tree SIZE 26" 16" 13-3/8" 10-3/4" 9-5/8" 7" Tubing: 4-1/2" WT CASING AND TUBING DETAII, GRADE CONN ID TOP 267/397 75 61/68 51/55 47 29 18 12.6 BTM. Dril-Quip Surf 990' K-55 Buttress Surf 1,445' K-55 Buttress 12.415 Surf 4,590' N-80 Buttress 9.604 Surf 497' N-80 Buttress 8.681 497' 11,399' N-80 Buttress 6.184 11,193' 12,448' N-80 FL4S 4.276 12,368' 13,000' L-80 AB Mod 3.958 Casing Leak 5 10466' DIL 6 Squeezed with 100 sx cement 7 Squeeze Perfs 10620-10623' 9 10 G Perfs "Bad" casing at 11035' __ Proposed Hemlock IW. Foreland Perf. ~ Bridge Plug 12 =~}~i!~_~}~ _-- Jurassic Perf. STRESSFRAC Tool ~12,880' PnTD = 12,952' TD = 13,000' MAX HOL£ ANHI. r: = 4t.? NO. Depth 72.50' 2 455.0' 3 4 10200' 5 10420' 6 7 10490' 8 11000' 9 10 11193' 11 10481' 12 12351 13 10537' 14 12369' OD 13.625 4.500 7.031 7.00 8.125 5.875 5.156 5.093 JEWELRY DETAIL ID Item 3.902 Cameron Tubing Hanger EP-4SD-SL 13-5/8" NOM 4-1/2" Butt Top x Bottom 3.958 4-1/2" 12.6 lb/ft L-80 AB Modified tbg 3.833 Offs GLM's with RI( latch (5.625" x 7.031") Centrilift ESP Baker ZXP liner packer 7" x 9-5/8" 6.184 Isolation liner 7-5/8" FJ Baker Model FA permanent packer (194FA75) Baker ZXP liner packer 7" x 9-5/8" Isolation liner 7-5/8" FJ TIW/Baker tieback seal assembly Halliburton EZSV 4.00 Baker FB-1 Packer (Size 85-40) 3.813 Otis X landing nipple 4.438 TIW LG-6 Tie-back Seals with ½ muleshoe Proposed Hemlock Perforations: 11206-11246', 11266-11276', 11430-11470', 11480- 11500', 11510-11530', 11570-11590',I 1596-11654', 11722-11742', 11764-11778' Wireline Record Obstruction tagged at 11035'. (9 bailer runs attempted without success) Last fill cleanout to 12024' with coil tubing (3/99) Top Btm Amt PERFORATION DATA Last Perf Date Zone Top Btm Amt Last Peri: Date Zone 10,632' 10,658' 26 10,705' 10,710' 5 10,684' 10,705' 21 10,720' 10,744' 24 10,792' 10,822' 30 10,840' 10,850' 10 10,858' 10,888' 30 10,964' 10,994' 30 11,01Z 11,037' 25 11/10/93 G-1 11815 11831 16 12/5/97 G-1 11836 11841 5 12/5/97 G-2 11848 11858 10 12/5/97 G-2 11865 11875 10 12/5/97 G-3 11912 11922 10 11/9/93 G-4 11930 11950 20 1119/93 G-4 11966 11976 10 11/7/93 G-5 12,655' 12,675' 20 11/7/93 G-5 12,675' 12,748' 73 12,748' 12,808' 60 12,810' 12,900' 90 8/14/92 8/14/92 8/14/92 8/14/92 8/14/92 8/14192 8/14/92 1/2/92 1/2/92 1/2/92 1/2/92 WF-0 WF-0 WF-0 WF-0 WF-1 WF-1 WF-2 Jur Jur Jur Jur DATE: 4/16/99 NM UNOCALe RKB to TBG Head = 74.5' Tree connection: Casing Leak 10466' DIL Squeezed with 100 sx cement 11 Squeeze Perfs 10620-10623' G Perfs W. Foreland Perf. Jurassic Perf. STRESSFRAC Logging,Tool @12,88o PBTD" 12,952' TD = '13,000' MAX HOLE ANGLE -- 41.7 ,. ( Steelhead Well No. M-28 Current Completion SIZE WT CASING AND TUBING DETAH, GRADE CONN ID TOP BTM. 26" 16" 13-3/8" 10-3/4" 9-5/8" 7" 5" Tubing: 4-1/2" 267/397 75 61/68 51/55 47 29 18 12.6 Dm-Quip Surf K-55 Buttress Surf K-55 Buttress 12.415 Surf N-80 Buttress 9.604 Surf N-80 Buttress 8.681 497' N-80 Bu~ess 6.184 11,193' N-80 FL4S 4.276 12,368' L-80 AB Mod 3.958 990' 1,445' 4,590' 497' 11,399' 12,448' 13,000' NO. 1 2 3 4 5 Depth 74.50' 75.25' 455.0' 455.0' OD 7.031 6 10435' 8.437 JEWELRY DETAIL ID Item FMC Tubing Hanger, TC-1A-HD CS Hydrill 3.958 Crossover, 4-1/2" CS Pin x 4-1/2" Buttress Pin 3.958 12 jts. 4-1./2" 12.6 lb/ft L-80 AB Modified thg 3.813 Camco TRDP-4A SCSSV with 5.17' Flow coupling 3.958 Camco MMG GLM at 1745', 3375', 4538', 5620' 6535' 7177, 7855', 8530', 9180', 9793', 10401' with 10' pups above and below 4.00 Baker FHL Retrievable Packer (781-20-xxxx) 7 10481' 8.125 4.750 8 10489' 7.00 6.00 9 10537' 5.156 3.813 10 10572' 5.62 3.865 11 10574' 5.25 12 12351' 5.875 4.00 13 12360' 5.015 3.725 14 12369' 5.093 4.438 Baker SB-3 Packer (409-06-1940) Tubing Meas. Millout Extension Otis X landing nipple Baker Hydro-Trip Sub ½ Mule Shoe Baker FB-1 Packer (Size 85-40) Drill Pipe Meas. Otis XN Nipple TIW LG-6 Tie-back Seals with ½ muleshoe Special Note: Unable to pass obstruction at 11035'. Fill cleaned out to 12024' with coil tubing Top 10,632' 10,684' 10,720. 10,792' 10,705' 10,840' 10,858' 10,964' 11,012' PERFORATION DATA Last Last ~ Ant PerfDal~ Zone Top ~ Ant PerfDate 10,658; 26 12/5/97 G-1 11815 11831 16 8/14/92 10,705' 21 12/5/97 G-2 11836 11841 5 8/14/92 10,744' 24 12/5/97 G-2 11848 11858 10 8/14/92 10,822' 30 12/5/97 G-3 11865 11875 10 8/14/92 10710' 5 12/5/97 G-1 11912 11922 10 8/14/92 10,850' 10 11/9/93 G-4 11930 11950 20 8/14/92 10,888' 30 11/9/93 ~ 11966 11976 10 8/14/92 10,994' 30 11/7/93 G-5 12,655' 12,675' 20 1/2/92 11,037' 25 11/7/93 G-5 12,675' 12,748' 73 1/2/92 12,748' 12,808' 60 1/2/92 12,810' 12,900' 90 1/2/92 Zone WF-0 WF-0 WF-0 WF-0 WF-1 WF-1 WF-2 Jur Jut Jur Jur DATE: 4/15/99 NM ( 1 2 3 4 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 STEELHEAD M-28 RECOMPLETION DRAFT PROCEDURE (Attachment 1) Prepare Rig for Operations Install BPV and ND tree. NU BOPE and riser. Recover BPV and install 2-way check Test BOPE Pull 2-way check. MU landing joint. Engage tubing hangar and pull tubing free from cut. CBU with filtered 3%KCL/FIW POOH and lay down 4-1/2" tubing. Make up overshot assembly and RIH picking up drill pipe. Engage tubing stub and and right hand release from SB3 packer Unseat FHL packer at 10435' and POOH Make up packer picker assy/BHA TIH to SB3 packer at 10481' Mill packer and circulate POOH with packer Lay down packer mill assy. Make up 9-5/8" x 7" clean out assy. P/U 3-1/2" drill pipe and TIH to 12,351' (FB-1 Packer) Circulate bottoms up and displace well to filtered 3%KCL/FIW POOH laying down excess 3-1/2" drill pipe. RU Sclumberger. RIH and set EZSV at 12300' PU TCP gun assembly and RIH Perforate Hemlock Benches 1-7 Make up isolation assembly and set packer at 11000' - sting into 7" liner top RU Schlumberger and set isolation packer at 10450' DIL Make up isolation assembly and top isolation packer RIH and stab isolation assembly into lower packer and set Pressure test isolation assembly POOH laying down drill pipe and running tool. Install storm packer N/D BOP's Install new tubing spool and test N/U BOP's and test Retrieve storm packer RU power cable handling equipment 38 39 40 41 42 42 43 44 45 46 47 48 49 50 RIH with ESP on new 4-1/2" Butt robing. Splice and land TBG HGR. Lay down landing joint. Install BPV. RD robing running equipment. ND BOPE and riser. NU adapter flange and install penetrator. NU tree. Pull BPV and set 2-way check. Test tree and wellhead. Pull 2-way check. Install flowlines. Test electrical equipment. Demobilize rig Unocal Corporal' P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNO AL G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 On October 3, 1991 a Jet Pump was installed on well M28 located on the Steelhead Platform. . Sincerely · . ,. G. Russell Schmidt Drilling Manager GRS/leg STATE OF ALASKA ALASI . OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate XX Plugging] .-.. Perforate Install Jet.._..Pmp ~ 2. Nar. e of Operator Pull tubin~l After casing UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE. AK 99519 - 6247 Repair well 5. Type of Well: Development Exploratory Stratigraphic Service 4. Loca~on of well at surface Leg B1, Slot #3, Steelhead Platform Pull t¥_b!ng Other XX 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Tm_ding Bay Unit 8. Well number 970' FNL, 532' FWL. Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL. Sec. 28, T9N, R13W, SM At effective del~ At total depth 85' FNL, 2,331' FEL. Sec. 28, T9N~ R13W, SM 12. Pre~ent well condition summary Total depth: measured 13,000 true vertical 10,801 Effective depth: measured 12,952 true vertical 10,751 M-28 9. Permit number 90-19/91-252 10. APl number 50-733-20414 11. Field/Pool G Zone/West Fore!=_nd feet feet feet feet Plugs (measured) None Stress frac Tool Junk (measured) 12,880' Casing Structural Length Size Cemented Measured depth True vertical depth Conductor 1,447' 16" Surface 4,590' 13-318" Intermediate 11,399' 9-518" Production 1,250' 7" Liner 632' 5" Perforation depth: measured 1,800 sx 1,447' 1,445' 2,900 sx 4,590' 4,031' 3,360 sx 11,399' 9,310' 400 sx 12,448' 10,261' 136 sx 13,000' 10,801' 12,650-12,808'; 12,810-12,900' 13. 14. true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) S~inula6oi-, or cerr~t ~=~tuesze summary Intervals treated (measured) 10,463'-10,609'; 10,611' - 10,699' 4-112" 12.6#, L-80 AB MOd. Butt tbg to 10,568' Baker FB-1 Pkr size 85-40 {~ 12,351'; Baker DB Pkr Size 194-47 w114' SBE ~ 10,524'; Baker pkr Size 194-47 ~ 11,175 -,. ,,,/- i.' I · I ~ I'~ I KI:L.I:I v [;ul APR 0 5 1996 Treatment description including volumes used and final pressure Representative Dali~ Average Production or Injection Oat~,.. ,.. ~~u~~ OiI-Bbl Ges-Mcf Water-Bbl Casing. l~j~a Pdor to well operation 9/24/91 374 77 180 -- 148 I --Subsequent to operation 10/3/91 499 88 251 -- 4020 15. Att~ch,~e,~L~ Copies of Logs and Surveys run Daily Report of Well Operations 16. igned G. Russell Schmidt ~1.1~ _.~vv~-l'~de Drilling Manager Fo~,~ 10-404 Rev 06/15/88 /- - Status of well classification as: Oil c.~,~ .~, ,~,~nd~,~ $ _.~rvi.'_,~e X SUBMIT IN DUPLICATE Summary of Well Operations for Well M-28 Steelhead Platform 10/3/91 INSTALL JET PUMP - On 2/22/91 hung 4-1/2", 12.6# L-80 Butt AB Modified tbg w/Otis XD production sleeve @ 10462'. In September 1991 a jet pump/SCSSV assembly was RIH and set in XD sleeve at 10,462'. On 10/3/91 conduct well test. . Unocal Corpora( P.O. Box 19624'/ Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 On September 18, 1991 a Fracture Stimulation w/CT cleanout was performed on well M28 located on the Steelhead Platform. G. Russell Schmidt Drilling Manager GRS/leg ,- STATE OF ALASKA (" .t ALASI~...)IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OpecaiJons performed: Opera~n shut___down Stimulate XX Plugging Perforate 2. Name of Operai~r Pull tubin~l After casing UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 4. Loca6on of well at surface Repair well 5. Type of Well: Development x Exploratory __ Stratigraphic ~ Service 12. Leg B1, Slot #3, Steelhead Platform Pull h;_h!ng Other 6. Datum elevalJon (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 970' FNL, 532' FVVL, Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28, T9N, R13W, SM At effective depth At t~tal depth 85' FNL~ 2~331' FEL~ Sec. 28~ T9N, R13W~ SM Present well condition summary Total depth: measured 13,000 true vertical 10,801 M-28 9. Permit number 90-19/91-285 10. APl number 50-733-20414 11. Field/Pool G Zone/West Foreland feet Plugs (measured) None feet Stress frac Tool Effective depth: measured 12,952 true vertical 10,751 feet Junk (measured) 12,880' feet Casing Structural Length Size Cemented Measured depth True vertical depth Conductor 1,447' Surface 4,590' Intermediate 11,399' Production 1,250' Liner 632' Perforation depth: measured 16" 1,800 sx 1,447' 1,445' 13-318" 2,900 sx 4,590' 4,031' 9-5~8" 3,360 sx 11,399' 9,310' 7" 400 sx 12,448' 10,261' 5" 136 sx 13,000' 10,801' 12,650-12,808'; 12,810-12,900' true vertical 10,463'-10,609'; 10,611' - 10,699' Tubing (size, grade, and measured depth) 4-112" 12.6#, L-80 AB MOd. Butt tbg to 10,568' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker FB-1 Pkr size 85-40 ~ 12,351'; Baker DB Pkr Size 194-47 w/14' SBE ~ 10,524'; Baker pkr Size 194-47 ~ 11,175 Intervals treated (measured) 14. 15. Treatment description includinl] volumes used and final pre~sure Representative Daiiy Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Pdor to well operation 9114/91 203 57 26 Tubing Pressure --Subsequent to operation 9/24/91 374 77 105 Attachmei~ts Copies of Logs and Surveys run Daily Report of Well Operations 180 148 16. 17. I hereby cer'~fy that the fo~gpi~ is tm~,~n~l c~rrect 1~t t~a best of my knowledge. Signed G. Russell Schmi tie Ddllin9 Man~_~er Form 10-404 Rev 06/15188 / ' - Status of well classification as: Oil X Gas Suspend~ APR 0 5 1996 (' ( Summary of Well Operations for Well M-28 Steelhead Platform 9/18-20/91 FRACTURE STIMULATE W/CT CLEANOUT - Install tree saver. Pressure test treating lines against tree saver valve to 10,000 psi. Perform injectivity test. Establish 15 BPM @ 5200 psi. ISIP=3800 psi. Proceeded frac treatment but could not stabilize PPA @ 12 PPG. Cut stage early when losing blender discharge. Rate & pressure stable until prop hit perfs & screen out occured. Left 47,000 lbs of 54,000 lbs propent in wellbore. Shutin allowed propent to settle & gels to break. RU CTU and cleaned out to 12,390'. i E 'EIVED ,APR 0 $1995 Alaa~ ~!1 & 81~ ap,.nf~. Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL( G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 On October 3, 1991 a Jet Pump was installed on well M28 located on the Steelhead Platform. G. Russell Schmidt Drilling Manager GRS/leg ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Opera§one performed: Operation shutdown S§mulate XX Plugging ---- Perforate Pull tubin9 After casing Repair well 2. Nan~e of Operator 5. Type of Well: Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stmfigraphic P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service 4. Location of well at surface Leg BI, Slot ~3, Steelhead Platform 970' FNL, 532' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28, T9N, R13W, SM At effective depth X At total depth 85' FNL, 2,331' FEL, Sec. 28, T9N, R13W, SM 12. Present well condition summary Total depth: measured 13,000 true var'dcal 10,801 ORIGINAL Pull tubing Other XX 6. Datum elevation (DF or KB) 152' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number M-28 feet 9. Permit number 90-19/91-252 10. APl number 50-733-20414 11. Field/Pool G Zone/West Fora!and feet Plugs (measured) None feet Stress fmc Tool Effective depth: measured 12,952 feet Junk (measured) 12,880' true vertical 10,751 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,447' 16" 1,800 sx 1,447' 1,445' Surface 4,590' 13-3/8" 2,900 sx 4,590' 4,031' Intermediate 11,399' 9-5~8" 3,360 sx 11,399' 9,310' Production 1,250' 7" 400 sx 12,448' 10,261' Liner 632' 5" 136 sx 13,000' 10,801' Perforation depth: measured 12,650-12,808'; 12,810-12,900' 13. true vertical 10,463'-10,609'; 10,611' - 10,699' Tubing (size, grade, and measured depth) 4-112" 12.6#, L-80 AB MOd. Butt tbg to 10,568' Packers and SSSV (type and measured depth) Baker FB-1 Pkr size 85-40 ~ 12,351 '; Baker DB Pkr Size 194-47 w/14' SBE ~ 10,524'; Baker pkr Size 194-47 ~ 11,175 St;.,ulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pre~_ure ..Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 9124/91 374 77 180 --- 148 Subsequent to operation 10/3/91 499 88 251 -- 4020 15. Attachrner,~ 16. Status of well classification as: __ Copies of Logs and Surveys run ~Daily Repo.~ of Well Operatio. ns. Oil 17'l"erebyce'"'Ythatthefor~g.olr){jlstru~Jllld~or~ctto//IJ:~l~bestofmy knowledge. Gas Suspended Service 71// IJU L~ Signed G. Russell Schmidt H.~_{:_.~~ ~ ~ T~tle Drilling Manager ... Date '~/~ ~- I~ E ~. E I V~I~F.:/' APR 0 5 1996 Alaska 011 & Gas Cons. Commission Anchorage (, ( Summary of Well Operations for Well M-28 Steelhead Platform 10/3/91 INSTALL JET PUMP - On 2/22/91 hung 4-1/2", 12.6# L-80 Butt AB Modified tbg w/Otis XD production sleeve @ 10462'. In September 1991 a jet pump/SCSSV assembly was RIH and set in XD sleeve at 10,462'. On 10/3/91 conduct well test. RECEIVED APR 0 5 1996 Oil I~ ~m[~ ~n~, 8ommit~m Unocal Corporation P.O. Box 196247 ' Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 On September 18, 1991 a Fracture Stimulation w/CT cleanout was performed on well M28 located on the Steelhead Platform. G. Russell Schmidt Drilling Manager GRS/leg STATE OF ALASKA ,-, ALASKA OI "AND GAS CONSERVATION COM,,,~SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate XX Pull tubing After casing Repair well 2. Name of Operator 5. Type of Well: Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stmtigraphic P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Service 4. Location of well at surface Leg B1, Slot I/3, Steelhead Platform Plugging X Perforate Pull tubing Other 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 970' FNL, 532' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28, T9N, R13W, SM At effective depth At total depth · 85' FNL~ 2t331' FELt Sec. 287 T9Nt R13W~ SM 12. Present well condition summary Total depth: measured 13,000 true vertical 10,801 M -28 9. Permit number 90-19/91-285 10. APl number 50-733-20414 11. Field/Pool G Zone/West FOm!r-_-nd feet Plugs (measured) None feet Stress frac Tool Effective depth: measured 12,952 feet Junk (measured) true vertical 10,751 feet 12,880' Casing Length Size Cemented Measured depth True vertical depth Structural Conduct. or 1,447' 16" 1,800 sx Surface 4,590' 13-318" 2,900 sx Intermediate 11,399' 9-5~8" 3,360 sx Production 1,250' 7" 400 sx Liner 632' 5" 136 sx Perforation depth: measured 12,650-12,808'; 12,810-12,900' 1,447' 4,590' 11,399' 12,448' 13,000' 4,031' 9,310' 10,261' 10,801' true vertical 10,463'-10,609'; 10,611' - 10,699' Tubing (size, grade, and measured depth) 4-112" 12.6#, L-80 AB MOd. Butt tbg to 10,568' Packers and SSSV (type and measured depth) 13.' Stimulation or cement squeeze summary Baker FB-1 Pkr size 85-40 ~ 12,351'; Baker DB Pkr Size 194-47 w114' SBE ~ 10~524'; Baker pkr Size 194-47 ~ 11 ~175 Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or InJection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 9114191 203 57 26 105 --Subsequent to operation 9124191 ~ 374 15. Attachment~ Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby ce, [;ry that the fo~i~ i~ ir~n~ c~..~best Signed G. Russell Schmidt/L"J-~~-~itle Form 10-404 Rev 06/15/88 ! 77 180 -- 148 16. Status of well classification as: Oil X Gas Suspended Service of my knowledge. Drilling Manager Date RECEIPt7 (' Summary of Well Operations for Well M-28 Steelhead Platform 9/18-20/91 FRACTURE STIMULATE W/CT CLEANOUT - Install tree saver. Pressure test treating lines against tree saver valve to 10,000 psi. Perform injectivity test. Establish 15 BPM @ 5200 psi. ISIP=3800 psi. Proceeded frac treatment but could not stabilize PPA @ 12 PPG. Cut stage early when losing blender discharge. Rate & pressure stable until prop hit perfs & screen out occured. Left 47,000 lbs of 54,000 lbs propent in wellbore. Shutin allowed propent to settle & gels to break. RU CTU and cleaned out to 12,390'. RECEIVED 0 5 1996 _(~' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Opera~ons perfo~od: Ope~ai~on shutdown Stimulate Plugging -.-- Perforate Pull tubing XX After casin~ Rep_=ir well 2. Name of Opera~,r 1 5. Type of Well: I Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stmtigraphic P.O. BOX 196247 ANCHORAGE~ AK 99519 - 6247 Sew!ce 4. Loca~on of well at su, t',ce Leg B1, Slot #3, Steelhead Platform Pull _h_Lhing Other 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 970' FNL, 532' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28, T9N, R13W, SM At effective depth At total depth 85' FNL~ 2~331' FEL~ Sec. 28~ T9N~ R13W~ SM 12. Pre~ent~,,,,--" cond~o~ summary Total depth: measured 13,000 true vertical 10,801 ORIGINAL M-28 9. Permit number 90-19/93- 253 10. APl number 50-733-20414 11. Field/Pool G Zone/VVe~t For-:--~d feet Plugs (measured) None feet Stress frac Tool Effective depth: measured 12,952 true vertical 10,751 ; , 'feet i Junk (measure?) 12,880' feet ' Casing ,.i Length, ,' I Structural : ' Size : Cemented 'Measured depth True vertical depth Conductor 1,447' Surface ' 4,590' Intermediate 11,399' Production 1,250' Liner 632' Perforation depth: measured 16" 1,800 sx 1,447' 13-318" 2,.900 sx 4,590' 9-518" 3,360 sx 11,399' 7" 400 sx 12,448' 5" t 36 sx 13,000' See Attached 1,445' 4,031' 9,310' 10,261' 10,801' true vertical See Attached 13. Tubing (size, grade, and measured depth) 4-112" 12.6~, L-80.AB Mod. Butt tbg to 10,575' Packers and SSSV (type and measured depth) Baker FB-1 Pkr size 85-40 ~ 12,351'; Baker FHL Pkr ~ 10~435'; Baker SB-3 pkr wlEBH-22 anchor {~ 10,481' Stimulation or c, ernent squeeze summary 14. Intervals treated (measured) ~ P i'~ 0 ~- '~ Q ~ "~ ! ~.~ ~/ Treatment description including volumes used and final pre=~ure Representative Daily Average Pmdu~on or Inje~on De~ ~.~r:.~'..':-~ I'.:~ ~' (~:"~:~ C~:[r~; C~; OiI-Bbl Gas-M~ Water-Bbl Casing Da~ ~umng'~mss~ Prior to well operation 10113193 1311 949 304 65 4237 Subsequent to operation 11130/93 1506 39 218 830 1- 15. Attachment~ I 16. Status of well classification as: I Copies of Logs and Surveys run I I Daily Report of Well Operations Oil X G~_~ Suspended 117' I hereby certify ~'hat the for~in~ tr.:: ~ ct~,rr~st of my knowledge. ISigned G. Russell Schmidt J~,~j~3~,~*~u~itle Drilling Manager 175 Service Form 10~404 Rev 06115188 ~ SUBMIT IN DUPLICATE D ATTACHMENT #1 WELL M-28 Perforations MD TVD G-ZONE 10,632 10,658 8,692 8,713 10,684 10,704 8,733 8,749 10,720 10,744 8,761 8,780 10,792 10,822 8,818 8,841 10,840 10,850 8,856 8,864 10,858 10,888 8,870 8,893 10,964 10,980 8,954 8,966 11,012 11,037 8,.991 9,011 WEST FORELAND 11,815 11,831 9,674 9,688 11,836 11,841 9,693 9,697 11,848 11,858 9~703 9,713 11,865 11,875 9,719 9,728 11,912 11,922 9,762 9,771 11,930 11,950 9,778 9,796 11,966 11,976 9,811 9,820 BASAL WEST FORELAND 12,650 12,808 10,463 10,609 12,810 12,900 10,611 10,699 RE-.CEIVi:D Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Ddlling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 On November 1, 1993, Unocal pulled tubing and re-ran 4-1/2" 12.6# L-80 tubing to 10,575' w/Baker FNL packer set @ 10,435' and a Baker SB-3 packer set at 10,481' to straddle leak in 9-5/8" casing @ 10,446'. G. Russell Schmidt Drilling Manager GRS/leg O(i STATE OF ALASKA {. ALASKA LAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Ope~,[;ons performed: Operation shutdown Stimulate Plug igigigig~ ~ Perforate Pull tubing After casing Repeir well 2. Nar~e of Opera[or 5. Type of Well: Development UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory 3. Address Stratigraphic P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service 4. Loca~on of well at surface Leg B1, Slot f/3, Steelhead Platform X __ Coil Tb~ Clean Pull tubin~ Other xx out 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 970' FNL, 532' FWL, Sec. 33, T9N, R13W, SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28, T9N, R13W, SM At effective depth At total depth 85' FNL~ 2~331' FEL~ Sec. 28, TgN~ R13W~ SM 12. Present well condition summary Total depth: measured 13,000 t~ue vertical 10,801 ORIGINAL M -28 9. Permit number 90-19/91-183 10. APl number 50- 733-20414 11. Field/Pool G Zone/West Foml=nd feet Plugs (measured) None feet Stress frac Tool Effective depth: measured 12,952 true vertical 10,751 feet Junk (measured) 12,880' feet Casing Structural Length Size Cemented Measured depth True vertical depth Conductor 1,447' Surface 4,590' Intermediate 11,399' Production 1,250' Liner 632' Perforation depth: measured 16" 1,800 sx 1,447' 1,445' 13-318" 2,900 sx 4,590' 4,031' 9-518" 3,360 sx 11,399' 9,310' 7" 400 sx 12,448' 10,261' 5" 136 sx 13,000' 10,801' 12,675-12,808'; 12,81 0-12,900' 13. true vertical 10,480'-10,609'; 10,611' - 10,699' Tubing (size, grade, and measured depth) 4-112" 12.6#, L-80 AB MOd. Butt tbg to 10,568' Packers and SSSV (type and measured depth) Baker FB-1 Pkr size 85-40 ~ 12,351'; Baker DB Pkr Size 194-47 w114' SBE ~ 10,524'; Baker DB pkr Size 194-47 {~ 11,175 Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure .Representative Daily Average Production or InJection Data_ OiI-Bbl Gas-Mcr Water-Bbl Casing Data Tubing Pressure Prior to well operation 619/91 686 72 260 Subsequent to operation 611/91 723 354 428 -- 1- 15. Attachmen~ 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended 17. I hereby cer~fY ~at the for~oi~ i.s, t:~)~lco/l~~best of my knowledge. ISigned G. Russell Schmidt .~J,,,~/~itle Drilling Manager Form 10-404 Rev 06115/88 ~ ' ' 111 Service RECEIVED SUBMIT IN DUPLICATE A~'""R 0 '2 195g Unocal Corporation P.O. Box 19624? Anchorage, Alaska 99519 907-263-7676 UNOCALe G. Russell $chmidt Drilling Manager Thursday, March 21, 1996 Mr. David Johnston, Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: STEELHEAD PLATFORM WELL M28 APl NUMBER 50-733-20414 This is to inform you that the coil tubing cleanout Sundry Request (Approval No. 91-183) was completed on 6/11/91. Sand & carbolite was washed from wellbore to a depth of 12853' and the well returned to production. (~inc~erely, ~^ ~ .. ^_ G. Russell Schmidt Drilling Manager GRS/leg I ' STATE OF ALASKA ~,"~ ALA$1~A OIL AND GAS CONSERVATION COMI~,,~$1ON REPORT OF SUNDRY WELL OPERATIONS Operations Shutdown Stimulate Plugging Perforate X Pull Tubing m A~'er Casing m ~epair Well__ m -- Other m · Operations Performed: Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 970' FNL, 532' FWL, Sec. 33-9N-13W-SM At top of productive Interval 150' FNL, 2,333' FEL, Sec. 28-gN-13W At effective depth Leg B-l, Slot 3 Steelhead Platform At total depth 85' FNL, 2,331' FEL, Sec. 28-gN-13W-SM 2. Present well condition summary RECEIVED .... -,~.~ ~.,.::; & G.~s Cons. Commission 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number M-28 9. Permit number/approval number 90-19 / 91-224 10. APl number 50- 733-20414 11. Field/Pool G-Zone / West Foreland Total Depth: measured 1 3,000' feet Plugs (measured) None true vertical 1 O, 801' feet Effective depth: measured 1 2,9 5 2' true vertical 10,751' Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Junk (measured) feet Size Cemented Jet Pump Stressfrac tool @ 12,880' Measured depth 1,447' 16" 1,800 sx 1,447' 4,590' 13-3/8" 2,900 sx 4,590' 11,399' 9-5~8" 3,360 sx 11,399' 1,250' 7" 400 sx 12,448' 632' 5" 136 sx 13,000' measured BWF 12,675'- 12,808' MD 10,480'- true vertical 12,810'- 12,900' MD 10,611'- True vertical depth 10,609' 10,699' 1,445' 4,031' 9,310' I 0,261' 10,801' TVD TVD feet 13. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 AB Mod Butt Tbg to 10,568' Packers and SSSV (type and measured depth) Baker FB-1 Pkr (~ 12,351'; Baker DB Pkr w/14' SBE @ 10,.524'; Baker DB Pkr @ 11,175' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure Prior to well operation 7/14/91 201 94 48 0 Subsequent to operation 7/18/91 161/// 35 9 0 Tubing Pressure 100 109 15. Attachments Copies of Log and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service Date Form 10-404 Rev 06115/88 SUBMIT IN DUPLICATE DAILY NELL OPERATIONS H-28 7/14/91 Held safety meeting. PT lub to 3500 psi. OK. RIH w/ logging string (CR, CCL, temp & weights). Tagged fill ~ 12,750' DIL. POOH. Log indicated production from 12,710' - 12,740'. RIH w/ 3-3/8", 4 SPF, 90° phased guns and perforated the following intervals: RUN INTERVAL DIL RESULT #1 12,720' - 12,740' Misfired #2 12,720' - 12,740' Misfired RD E-Line. 7/16/91 PT lub to 3500 psi. OK. Continued perforating w/ the same guns. RUN INTERVAL DIL RESULT #3 12,720' - 12,740' Fired #4 12,700' - 12,720' Fired #5 12,650' - 12,670' Misfired #6 12,650' - 12,670' Fired RIH. Tagged fill ~ 12,725' DIL. RD E-Line. Returned well to production. RECEIVED 1994 Armhorage H:\WELLOPS\H28 1. Type of Request: ALAG~ OILAND GAS CONSERVATION CO ,,&SION APPLICATION FOR SUNDRY APPROVALS Abandon w Suspend w Operation shutdown ~ Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulat'-~' Change approv'~ program ~ Pull Tubing X -- Variance P~rforate Othe'~" 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: 4. Location of well at surface Leg B-l, Slot 3 Steelhead Platform 970' FNL, 532' FWL, Sec. 33-9N-13W-SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28-9N-13W At effective depth At total depth 85' FNL, 2,331' FEL, Sec. 28-9N-13W-SM Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number M-28 9. Permit number/approval number 90-19 0. APl number 50- 733-20414 1. Field/Pool G-Zone / West Foreland 12. Present well condition summary Total Depth: measured true vertical 13,000' feet Plugs (measured) None 10, 801' feet Effective depth: measured 12,952' feet Junk (measured) true vertical 1 0, 751' feet Casing Length Size Cemented Structural Conductor 1,447' 16" 1,800 sx 1,447' Surface 4,590' 13-3/8" 2,900 sx 4,590' Intermediate 11,399' 9-5/8" 3,360 sx 11,399' Production 1,250' 7" 400 sx 12,44.8' Liner 632' 5" 136 sx 13~000'. Perforation depth: measured P'E'([IE vED true vertical See Attachment #1 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 AB Mod Butt Tbg to 10,568' Packers and SSSV (type and measured depth) Baker FB-1 Pkr@ 12,351'; Baker DB Pkrw/14' SBE @ 10,524'; Baker DB Pkr@ 11,175' Jet Pump Stressfrac tool @ 12,880' Measured depth True vertical depth 1,445' 4,031' 9,310' 10,261' 10,801' SEP 2 0 199 Alaska 0il & Gas Cons. C0mm'tssi0~ ~nchorage 13. Attachments Description summary of proposal X_~ Detailed operations program BOP sketch X Estimated date of commencing operation October 17, 1993 If proposal was verbally approved Name of approver Date approved 15. Staffs of well classification as: Oil X Gas Service Suspended 17. I hereby (~rtify ' Signed ~ the forgiving ~tru~an~he best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission s9 representative may witness Plug integrity BOP Test ~ Location clearance Mechanical In~e'egrity Test _ ' Subsequent form required 1-~- Original Signed By Approved by order of the Commision David W. Johnston Commissioner Date ~./. ?../~"~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 M-28 WORKOVER PROCEDURE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmemmmm OBJECTIVE: Pull tubing, mill-up and retrieve packers, retrieve parted jet pump assembly on top of fill, run new completion for gas lift assisted production. 10. ll. 12. 13. 14. 1. SI FIW power fluid to well. Pressure-up on tubing and casing to 3500 psi to shear equalizing feature in jet pump safety valve. 2. RU slickline. Pressure test lubricator to 2500 psi. RIH and pull jet pump and jet pump safety valve at 10,462'. 3. Kill well by circulating drill water + 3% KCl through sliding sleeve at 10,462'. 4. RIH with slickline and set plug in SCSSV profile at 461'. Set BPV. 5. Skid rig over M-28. ND tree. NU BOPE and riser. Test to 250/2500 psi. Pull BPV. RU slickline and pull plug at 461'. 6. POOH and lay down 4-1/2" tubing and packer seal assembly. 7. Mill-up/retrieve packer assembly at 10,524' and 4-1/2" tubing between packers. 8. Mill-up/retrieve packer assembly at 11,175' and 4-1/2" tail pipe. 9. RIH with fishing tools and retrieve parted jet pump assembly at 12,036'. RIH with bit and casing scrapers. Clean-out fill to packer top at 12,351'. RIH with isolation packer. Set packer in 7" casing at 11,600'. RIH with production packer, 4-1/2" tubing, gas lift mandrels, and SCSSV. Set packer at 10,500' with tubing hanger landed. RU slickline. Set plug in SCSSV profile. POOH. Set BPV. ND BOPE and riser. NU and test tree to 5000 psi. Pull BPV. RU slickline and pull plug from SCSSV profile. Release rig. RECEIVED $ E P 0 Alas~ Oil & Gas Cons. Commissio~ Anchorage ATTACHMENT G-ZONE M-28 Perforations MD TVD 10,632 10,684 10,720 10,792 10,858 10,964 - 10,658 - 10,704 - 10,744 - 10,822 - 10,888 - 10,980 11,014 - 11,028 8,692 8,733 8,761 8,818 8,870 8,954 - 8,713 - 8,749 - 8,780 - 8,841 - 8,893 - 8,966 8,993 - 9,004 WEST FORELAND MD 11,815 11,836 11,848 11,865 11,912 11,930 - 11,831 - 11,841 - 11,858 - 11,875 - 11,922 - 11,950 11,966 - 11,976 TVD 9,674 9,693 9,703 9,719 9,762 9,778 - 9,688 - 9,697 - 9,713 - 9,728 - 9,771 - 9,796 9,811 - g,820 BASAL WEST FORELAND MD 12,655' - 12,808' 12,810' - 12,900' TVD 10,468' - 10,60,9' 10,611'- 10,699' \docs\SHP\M28.doc SEP 0 199;) & Gas Cons. Commissio,'~ Anchorage Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP . t0 _ ? SEP 2 0 1993 Alaska Oil & Gas Cons, Comrnissio,", Anchorage X-:~018-K-REV. 2 MARATHON OIL COHPANY TO GAS BUSTER STEELHEAD PLATFORM CHOKE MANIFOLD TO DERRICK VENT A-.mE-- TO SHALE SHAKERS CHOKE LINE ALL VALVES IN FLOW PATH ~RE 3-1/16' 5000 PS1CAMEROH GATE TYPE SECTION AA I Flow Line Hydrll 18-3/4' 5000 Del Type GK Annular Pipe Rams Blind Rams Gate Velve Gate Valve HCR Valve Choke Line PIDe Ram8 16-3/4° 10,000 Singlegate 16-3/4° 5000 psi Riser RECEIVED e.,I V.iv. S EP ~ 0 199~ ,AJaska OJJ & Gas Cons. Co~missiop Anchorage Well#ead ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 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 conversations concerning the subject, it had been explained to me that either ARCO or Marathon had been the'.~b-operator on the majority of the wb~k proposed; however, it is 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, ~. , ,I,i Statistical Technician ~ p~inled on recyclo, d paper b y .. -2- Well Permit No. No. K-17 73-1 K-25 85-78 M-25 87-86 M-28 ~.':'90-19 Approval Date & No. 7-9-91, 91-198 2-9-90, 90-079 7-9-91, 91-201 11-1-91, 91-326 7-30-91, 91-224 8-27-91, 91-252 9-20-91, 91-285 Des cription Perforate. 6/91 Perforate 2/90 Perforate 6/91 Perf. G/WF intervals & rerun jet pump 10-22-91 Perf. & evaluate BWF potential 7-14-91 Install jet pump, pump-in test 8-15-91. Ba~al W/F Refrac 9/91 10-403 Signed By G. Bush R. Robe=ts G. Bush G. Bush G. Bush G. Bush G. Bush · ,! .! Unocal North Arum ) Oil & Ga~ Division . . Unocal Corporation 909 West 0th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCALe RECEIVED APP, 2 0 ~99~ Alaska 0ii & G~s Cons. Commission Anchorage DOCUMENT TRANSMITTAL April 16, 1993 TO' Larry Grant FROM: Kirk Kiloh LOCATION: 3OOl PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COM1VL - ,,,l t31l, i__ i Ill I I - J[ , i, , LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSM1/q/NG AS FOLLOWS ' TRADING,BAY UNIT 1 blucline and 1 sepia Logs from specified wells listed below .. ~1)--(~ .- D-SRD Perforating Record 7 7-~7-* - D-7RD Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record &'~-.-qS' -- D-20 Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 D-28 D-43RD D-47 G-1RD M-3 M-7 M-28 M-29 Completion Record Perforating Record Perforating Record Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool Perforating Depth Control Tubing Patch Record 6-20-92 11-21-92 11-25-92 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 8-12-92 11-13-92 PLEASE ACIG'gOWi.,EDGE RECEIPT BY SIGNING AND RE~G ONE COPY OF ms Doc~~ m~. smut. pr. nm,ar ro~J DATED: REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: OperatIon snutclown __ 2. Name of Operator Stimulate __ Plugging ~ Perforate ~__ Pull tubIng m Alter casing __ Rep~,,r well ._... Other J 5. Type of Well: Development r) Exploratory Stratigrapn,c AK 9951 Ser~ce Leg B-l, Slot 3 Steelhead Platfon~ Att~p79' FNL. 532' FWL, Sec. 33-9N-Z3W-SM proOuctNe ~ntervai 150' FNL, 2 333' FEL Sec. 28-gN-13W-SM At effecbve depth ' ' : 3. Address 4. LocatIon of well at sudace At total depth 85' FNL, 2,331' FELI 12. Present welt condition summary Total depth: measured true vertical Effective depth: measured true vertical Length Sec. 28-9N- 13W-SM 13,000' feet 10,801' feet 12,952' feet Junk(measured) 10,751' feet Size Cemented Plugs (measured) 1,447' 16" 1,800 sx 4,590' 13 3/8" 2,900 sx 11,399' 9-5/8" 3,360 sx 1,250' 7" 400 sx 632' 5" 136 sx measured Measured depth 1,447' 4,590' 11,399' 12,448' 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number M-28 9. Permit number/approval number 90-19/92-209 10. APl number 50- 733-20414 11. Field/Pool PlcArT. nur Kiver G-Zone/Nest Foreland Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: None Stressfrac tool 12,880' True vertical depth 1,445' 4,031' 9,310' 10,261' 10,801 ' truevertical SEE ATTACHMENT Tubing (raze. grade, and measUred depth) 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' Packers and SSSV (type and measured depth) Pkr Size 194-47 14' 5BE e 10,524'; 13. Stimulation or cement squ~,:-_.z~ summary NOV 2 7 199[ Aiasl~ 0ii, & Gas C0~s. G0mm~ss'to~ Anch0rag~ Baker 'FB-1 Pkr Size 85-40 @ 12,351' Baker DB pkr Size 194-47 (a 11,175' Intervals treated (measured) .. Treatment description including ~otumes used and final pressure 14. Represer~ia~ive Daily Average Preduction or Injection OiI-Bbl Gas-Mcr Wator-Bbi Casing Pressure Prior to wail operation 567 /'" 139 6 100 Subsequent to operation 898 ,'"" 299 113 15. Attachmer, L~ 16. Siaius of well classification as: Copies of Logs and Sun~ys run ..~_. __ Daily Report of Well Operations _._ Oil X ~_~__ Su~._ne_nded 17. I hereby ce[[~ly that the forc--.~ng is true and correct to the best of my knowledge. 96 Service 'r~e Tubing Pressure 4002 3985 · SUBMIT IN DUPUCATE. ATTACHMENT G-ZONE M-28 Perforations MD TVD 10,632 10,684 10,720 10,792 10,858 10,964 - 10,658 - 10,704 - 10,744 - 10,822 - 10,888 - 10,980 11,014 - 11,028 8,692 8,733 8,761 8,818 8,870 8,954 - 8,713 - 8,749 - 8,780 - 8,841 - 8,893 - 8,966 8,993 - 9,004 WEST FORELAND MD 11,815 11,836 11,848 11,865 11,912 11,930 - 11,831 - 11,841 - 11,858 - 11,875 - 11,922 - 11,950 11,966 - 11,976 TVD 9,674 9,693 9,703 9,719 9,762 9,778 - 9,688 - 9,697 - 9,713 - 9,728 - 9,771 - 9,796 9,811 - 9,820 BASAL WEST FORELAND MD 12,655' - 12,808' 12,810' - 12,900' TVD 10,468' - 10,609' 10,611' - 10,699' \docs\SHP\M28.doc NOV 2 ? 1992, Alaska Oil & Gas Cons. Commission Anchorage ( (r DATLY NELL OPERATIONS H-28 8~5~92 PT lines & lub to 5000 psigo O.K. Open swab valve and establish Diesel pump rate ~ 1-1/2 bpm. Platform ESD. SD pump. Wait on platform to return to normal operation. 8~7~92 Bled off pressure in discharge line. Displ discharge line w~ 2 bbls water and bled to 0 psig. SI lines/valves/etc. Waiting on platform to return to production. 8/11/92 Held safety meeting. Test lines to 5000 psi. Started pumping diesel at 1-1~2 BPH. Having to change diesel filter continuously. 8/12/92 Shut down waiting for diesel filters. 8/13/92 Finish circulating 824 bbls of diesel. RU Otis. Pt. lub to 2000 psi. RIH w/ RS stem KJ, OJ, SJ, GS. Latch JP ~ 10,470' WLM. Jar free. POOH. RIH w/ 2.70" swedge. Tag fill ~ 12,098' WLM. POOH. RD Otis. RU SWS. PT lub to 8000 psi. RIH w/ CC1, WTS, and 30'of unloaded. 2-7/8" carrier (3-3/4" OD). TO BOT. No tight spots. POOH. 8/14/92 Est comm BO. Perforated the fol lowing: RUN ZONE FOOTAGE DIL GUNS RESULTS #1 WF-2 11,966 WF-1 11,930 #2 WF-1 11,912 WF-O 11,865 #3 WF-O 11,848 WF-O 11,836 #4 WF-O 11,815 #5 G-5 11,014 #6 G-5 10,964 #7 G-4 8/15/92 #8 G-3 G-4 #9 G-2 #10 G-2 #11 G-1 - 11,976 - 11,g50 - 11,922 - 11,875 - 110858 - 11,841 - 11,831 - 11,028 - 10,980 10,858 - 10,888 10,792' - 10,822' 10,868' - 10,888' 10,720' - 10,744' 10,684' - 10,704' 10,632' - 10,658' 2-1/8" EJ3, 14 gr, 6 SPF, 0° phased Fired " Fired " Fired " Fired " Fired " Fired " Fired 2-7/8" HJII, 15 gr, 6SPF, 60° phased Fired " Fired " Top 10' Fired " F i red " F i red " F i red " F i red " F i red H: \WE L LOPS\M28 Daily Well Operations M-28 Page 2 8/15/92 (continued): RD SWS. RU Otis. PT lub and Howco lines to 200 psi. RIH w/ JP & JPSV. Set JP e 10,470' WLM. POOH. RD. Return well to production. H:\~ELLOPS\H28 (" STATEOFALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abanclon __ Suspend __ Operation shutdown __ Re-enter suspended well m Alter casing m Repair well m Plugging __ Time extens,on ~ 2timulat Change approved program __ Pull tubmg __ Variance __ Perforatem eo~'~'~r ~ 2. Name of Operator . ! 5. Type of Well: UNOCAL (Marathon 0i 1 Co - Sub 0peratlr) Development X Exploratory ~ 3'Addr~s, s0. Box 190247 Anchorage, AK 99517 StratigraphiC__service__ 4. Location of well at surface Leg B-l, Slot 3 Steelhead Platform 8.~el~mber 970' FNL, 532' FWL, Sec, 33-DN-13W-SN At top of productive interval 9. Permit number 150' FNL, 2,333' FEL, Sec. 28-DN-13W-SN 90-19 At effective depth Att°~eP~NL, 2,331' FEL, Sec. 28-9N-13W-SM 6. Datum elevation (DF or KB) 152' KB above MSL rU nit,or Pro_oerty ,nan3e. ao~ng ~ay un~: feet 10. APl number 50- 733-20414 · t:_ elO/H ~-:~one~est Fore] and 12. Present well condition summary Total depth: measured true vertical 13,000' feet Plugs (measured) 10,801' feet Effective depth: measured 12,952 ' feet Junk(measured) true vertical 10,7 51 ' feet None _ Stressfrac tool 1 , 8o' Casing Length Size Cemented Structural Conductor 1,447' 16" 1,800 sx 4,590' 13 3/8" 2,900 sx Sudace 11,399' 9-5/8" 3,360 sx Intermediate 1,250' 7" 400 sx Production 632' 5" 136 sx Liner Perforation depth: measured true vertical SEE ATTACHMENT Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' Packers and SSSV (type and measured depth) Baker DB Pkr Size 194-47 w/ 14' SBE 0.10.524': 13. Attachments Description summa~'y of proposal ~ Measured depth True vertical depth Baker FB-1 Baker DB Okr Size Detailed operations proc~ram .~_ 1,447' 1,445 ' 4,590' 4,031' 11,399' 9,310' 12,448' 10,261' 13,000' 10,801' Alaska 0il & Gas Cons. G Pkr Size 85-40 e 12,351' 194-47 e 11.]7~' BOP sketch L 14. Estimated date for commencing operation 115. Status of well classification as: 8/5/92 I 16. If proposal was verbally approved Oil _~X Gas 8/5/92 Name of approver Mi ke Mi nder' Date approvedI Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,o..,.~ ~. {~ ,.,.~ Title ~ .~ FOR COMM~ION USE ONLY Conditions of~l::tprov~lt'. Notify Commission so representative may witness . ' ! Approval No. d-~. ,,.2 -,=~'~,/~ Plu~integrity __ BOP Test __ Location clearance __ L~ ,.,, Approved ~"_py ,.' Mechanical Integrity Test __ Subsequent form required 10- '"1 ~ '1 ' Returned ~- ~l. el;;)..._ Original Signed By David W. Johnston Commissioner Date Approved by order of the Commission / Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE ~:~. ATTACHMENT G-ZONE M-28 Perforations MD TVD 10,632 10,684 10,720 10,792 10,858 10,964 - 10,658' - 10,704' - 10,744' - 10,822' - 10,888' - 10,980' 11,014 - 11,028' 8,692' - 8,713' 8,733' - 8,749' 8,761' - 8,780' 8,818' - 8,841' 8,870' - 8,893' 8,954' - 8,966' 8,993' - 9,004' WEST FORELAND MD 11,815 11,836 11,848 11,865 11,912 11,930 - 1!,831' - 11,841 - 11,858 - 11,875 - 11,922 - 11,950 11,966 - 11,976 TVD 9,674' - 9,688' g,693' - 9,697' 9,703' - 9,713' 9,719' - 9,728' 9,762' - 9,771' 9,778' - 9,796' 9,811' - 9,820' BASAL WEST FORELAND MD 12,655' - 12,808' 12,810' - 12,900' TVD 10,468' - 10,609' 10,611' - 10,699' \docs\SHP\M28.doc RECEIVED AUG 1 lgg 41a~ka Oi~ 8, ~a,; Con~. Commission ~chor4g~ Procedure: . . Hold pre-job operational meeting with all pertinent parties. Review all relevant environmental and safety issues. Any service company personnel who have not viewed the Alaska Region Safety Video should do so prior to commencing work. HIRU tank(s) capable of holding 750 bbls (31,500 gals) of diesel. Utilizing on-board equipment, fill the tank(s) with diesel. SI H-28. NU the on-board HOWCO HT-400 pump discharge to H-28 PF line/tbg head and suction to water injection supply. PT the discharge line to 5000 psig. RD the suction line to water injection and NU to the diesel tank. gas detection along both the suction and discharge lines. PUMP the DIESEL at 2-3 BPH, 4000 psig maximum WHP. Run At 700 bbls of diesel displacement, reduce PFP to 3500 psig. Close in flowline at production header and allow flowline pressure to build to 2000 psig. Close in flowline at casing valve. Continue to pump diesel until pressure breaks ba6k, indicating the equalizing feature of the safety valve has sheared. SD diesel pump. RD the tank, pump, and lines. o . . Note: The JPSV is pinned with 11 pins and will take 2750 psig differential across the tool to shear. SI well at wing valve, swab, and master. RU Otis on pipe rack level. Take SCSSV off platform system and put on hand puako (4500 psig) located near well room door. Install lock open fusible cap on master manumatic. MU tool string with GS pulling tool. PT lubricator to 3500 psig. Nptq: Zero tool string at pipe rack level, which is 41' lower than KB. Report all depth on a KB basis. Open master and note SITP. Open swab. RIH and retrieve jet pump/SCSSV from XO sleeve at 10,473' WLN RT. RT a 30' spent 2-7/8" Schlumberger hollow carrier gun. (Note: A 10' unspent (2-3/8" O0 with 2-7/8' bullnose) hollow carrier gun was run to 11,341' KB on 12/31/91). Results from this pilot run will determine whether 2-1/8" or 2-7/8' hollow carrier guns will be used to perforate the 'G' zone. RIH with 1-1/2" sinker bars and tag for fill. Fill g 12,080' WL KB (7/12/92). RU E-line unit. PT lubricator to 3500 psig. PERFORATE the G-ZONE and. YEST FORELANO intervals with the well open to production. For each perf run, establish communications blackout prior to arming guns and until the guns are below 1000'. Re-establish blackout when POH above_ 1000'. Guns to used are: WF - 2-1/8' EJ3 ROX, 14 gr chgs, 5 SPF, 0° phasingostrip guns; G-ZONE -- 2-7/8' HSO-N 34B H~II ROX, 15 gr chgs, 6 SPF, ~ phasing carrier guns OR 2-1/8" OS 25A UJ RI)X, 6.5 gr chgs, 4 SPF, u pnasing carrier guns (only if pilot run in Step (6) fails). ~ne WF - 2 WF - 1 WF - 0 Run la Run lb Run 2a Run 2b Run 3a Run 3b Run 4 Depth Footaqe 11,966' to 11,976' DIL 10' 11,930' to 11,950' DIL 20' 11,912' to 11,922' DIL 10' 11,865' to 11,875' DIL 10' 11,848' to 11,858' DIL 10' 11,836' to 11,841' DIL 5' 11,815' to 11,831' DIL 16' RECEIVED AUG 18 lggP. Alaska Oil & Gas Cons. Commission Anchorage 7. PERFORATE the G-ZONE and YEST FORELANO (cont.) Zone Run Depth Footaqe G - 5 Run 5 11,014' to 11,028' DIL 14' Run 6 10,964' to 10,980' OIL 16' G - 4 Run 7 10,858' to 10,888' DIL 30' G - 3 Run 8 10,792' to i0,822' DIL 30' G - 2 Run 9 10,720' to 10,744' DIL 24' Run 10 10,684' to 10,704' DIL 20' G - I Run 11 10,632' to 10,658' DIL 26' DO NOT EXCEED 500 BFPD RATE WHILE GUNS ARE IN THE TUBING BELOW THE OTIS 'XD' PRODUCTION SLEEVE AT 10,462' KB. 8. RD E-line. . RU Otis on pipe rack level. SI well. PT lubricator to 3500 psig. HU production tool string with running tool and jet pump/safety valve assembly (w/12B nozzle/throat combination). RIH with assembly and set in XO sleeve at 10,462' KB. POH. Rig aside Otis. 10. Test integrity of safety valve below jet pump by bleeding flowline pressure to separator pressure. Close in flowline at header and monitor for pressure buildup to verify safety valve is closed and holding. Slowly apply power fluid increasing pressure to 1500 psig. Monitor production for net returns. Increase PFP in 500 psig increments every 15 minutes until operating pressure of 4000 psig is reached. If okay, complete RD of Otis. 11. After stabilization, obtain a production well test. A: H:~SPERF. BRP/brp (3085-999) RECEIVED A U6 18 lggP. Alaska Oil & Gas Cons. Commission Anchoraee -"Completed 22-MAR-91 MARATHnN FilL j~" .ANY TRADING .BAY ii. .T STEELHEAD PLATFORM WELL M-88 All measurements are RKB to top oF equipment, Comoletlon String: (KB = 74.5' From Tubing Head Tom FIonge) 4.5' FMC TC-1A-EN Tbg Hngr, Butt ToD & Btm. 461' 0'-10.568' 990' 1445' 4590' 0-497' 497'-11,399' 11193'-18,448' 18,368'-13,000' CAMCO TRDP-4A SCSXV (3.Rl3' D ProFile). ~5', 18.6~, L-BO AB Mod Butt Tbg, 26', 267-397#, Dril-Ouio 16% 75#, K-55 BTC 13-3/8°, 61/68#, K-55, BTC i0-3/4°, 51/55.5~, N-80 Butt 9-5/8°, 47#, N-80 Butt 7', 89#, N-80 Butt liner =~°, 18#, FL4S, N-80 liner Att r. LM's are Danlei GL$1]. 4.5' x 1.5' slcleDocket ~an~lrel$ (1~ total) ~3;~0' ! Dungy 4034' ;~ I 5440' 3 6651' 4 7445' 5 7911' 6 8370' 7 ~80~' 8 9~9' 9 9619' 10 '- 10010' 11 I04~' 1~ Dum~y Latch Port Size RK Squeeze PerFs IO,6EO'-SE3' 10,468' O~is 'XD' Production Sleeve (3.813' X ProFile). Production P~cker Assembly: 10,51~4' Bnker DB Pkr size 194-47 w/ 14' SBE 10,543' Millout 10,590' Otls 'X' Landing Nipple (3.813' Pkg Bore). 11,173' B~ker Loc~tor Semi Assembly G-ZONE PERFORATION~ Interval F~ ~PF Ph~sino -- 10,63~' - 10,658' ~6' 4 10,684' - 10,704' ~0' 10,7~0' - 10,744' 24' 10,79~' - 10,8~e' 30' 10,858' - 10,888' 30' 10,964' - 10,980' 16' 11,014' - 11,028' 14' 4 O' ~solo~;on P~ckep AssembIy: 11,175' B:kep Model DB P:cker s~ze 194-47. w/ 4' 11,183' Miilou~ 11,~30' O~s 'x' Lcndmg Nipple (3.813' ProFile). 11,~68' W/L Re-en~emy Guide WEST FORELAND PERFORATIONS Interval F~ SPF Ph:slnq ,815' - 11,831' 16' 6 ~ 11,836'- 11,841' 5' ] 11,848'- 11,858' 10' ~ 11,865'- il875' lO' ~ 11,912'- 119~2' 10' i 11,930' - 11,950' 20' ~1,966' - 11,976' 10' 6 Isoi:~ion P:cker AsSembly: 1~,351' B:ker Model FB-1 Pkr, Size 85-40 12,360' O~s 'XN' Nspple (3.813' Bore, 3.7~5' NoGo). 12,369' 113192 1/3/92 1/2192 I 1/2/92 TIV 5' LG-6 Tie-B=ck Se:ls with 1/2 Muleshoe, D~te 1/8/92 1 1/1/9~ 1/1/9~ RECEIVED A U G 1 I] 1992 Alaska u~j ~ ~ uons. Anchora§Q Intervol 18,655'-1~,675' 18,675'-18,748' 1P, 748'-18,808' 18,810'-18,900' BASAL WESTFORELAND PERFORATIONS F_~.~ SPF Phasing 80 6 60 73 8 90' 60 4 90' 90 4 90' Average Deviotlon = 13.0' Fill 8 1P,080' WLKB (7/18/98) TOF (STRESSFRAC Tool) 8 12,880' (10/31/90). PBT]) 8 12,952' TD i~ 13,000' Dote 7/16/91 6/90 & 10/90 10/90 10/90 Revision Date: 7/13/92 Revised By. EVO Reason: Update Previous Revision: 12/17/91 ALASKA OIL AND GAS CONSERVATION COMMISSION n APPLICATION FOFI SUNDRY APPROVALS 1. Type of Request: Alter casing ~ Repair well __ Plugging m Change approved program m Pull tub, ng__ Var,ance ~ 2. Name of Operator ~ 5. Type of Well: Development ~ IINd~AI (MRv,;¥1'hnn al'il ~n - ~,mh d,n~v,a'l- r) Exploratory__ &Address- ' A ;r iAK-09511 Stratigraphic __ P,0, Box 190247 nch age Serv,cem 4. Locabon of well at sudace Leg B-l, Slot 3 Stee]head Platform ' F . 970 NL 532' FWL Sec 33-9N-13W-SH At top of productive interval ' 150' FNL, 2,333' FEL, Sec, 28-gN-13W-SH At effective depth Abanaon__ Suspend__ Operatlonshutdownm Re-enter suspended well ~ Basal W/F Refrac At total depth 85' FNL~ 2~331' FEL~ Sec. 28-9N-13W-SH 12. Present well condibon summary Total depth: measured 13,000 ' feet true vertical 10,801 ' feet Plugs (measured) Effective depth: measured 12,952 ' feet Junk (measured) true vertical 10,7 51 ' feet Casing Length Size Cemented Structural Conductor 1,447' 16" 1,800 sx Surface 4,590' 13 3/8" 2,900 sx Intermediate 11,399' 9-5/8" 3,360 sx Production 1',250' 7" 400 sx Liner 632' 5" 136 sx Pe. doration _measured. uasam ~ee~: rorelano 12,655' - 12,808' MD true vertical Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' P k rs an S t p andm re ept) ~er ~)~ ~Y §~ze ~4¢~[¥d w~ 14' SBE g 10,524'; Time extension __ Stimulate Z.._ Pedorate __ Other Measured depth 1,447' 4,590' 11,399' 12,448' 13,000' 10,468' - 10,609'TVD 12,810' - 12,900'ND 10,611' - 10,699'TVD 6. Datum elevation (DF or KB) 1R2' KB above Hgl feet 7. Unit or Property name Tradinq Bay Unit 8. Well number H-28 9. Permit number _ed-lq 10. APl number 50- 733-20414 11. Field/Pool McArthur River G-Zone/West Forel and None Stressfrac tool 12,880' ~ue ve~ical depth 1,445' 4,031' 9,310' 10,261' 10,801' Baker FB-1 Pkr Size 85-40 e 12,351' Baker DB pkr Size 194-47 e 11,175' 13. Attachments #1, 2, 3, 4 Description summary of proposal Detailed operations prograr~..E C ~l~l~h[~,. 14. Estimated date for commencing operation September 13, 1991 16. If proposal was verbally approved Russ Douqlas Name of appriSver 9 / ~egalpproved 15. Status of well classification as: sSuS~ ePnd~e)1~9(~ Oil ~ Gas ~ p ~ Alaska 0il & Gas Cons, Comm. iss~n Service ~,nnhnmn~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~-~. ~ ,..,..~,, Title {2.,e._%, ~ ~-~.~, ~ O FOR COMMISSION USE ONLY Conditions of a'l~droval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required Approved by order of the Commission Form 10-403 Rev 06115/88 Date J Approval No. ¢/_.~ OP~r~!,~,tA!. ,g)GNED BY LONNIE C, SMITH Commissioner Date ¢.~.--, ~'/ SUBMIT IN TRIPLICATE ( .... Attach~nent #1 ( PROCEDURE Basal West Foreland Refrac Procedure 1. Shut in well. 2. RU Otis on pipe rack level. RIH and record 30 minute static reservoir pressure at 12,696'. Tag fill depth. POI4. 3. Desired depth of fill is 12,720' KB wireline (12,700' DIL). If fill is too high, bail it out to approximate depth. If fill is too deep, proceed to next step. 4. Pick up Camco frac sleeve assembly. RIH and set across SCSSV. POI4 and RD slickline. 5. Install tree saver. RU fracture pumping equipment capable of pumping 15 BPM at 8000 psi. 6. If additional fill is required, pump sand slurry for required amount of fill up into tubing and displace to 12,000' with filtered 2~ KC1 brine. Shut down and allow sand to settle. RU slickline and confirm depth of fill. RI) slickline. 7. Perform fracture treatment as follows: a. Pressure test surface lines against tree saver valve to 10,000 psi. b. Perform injectivity test by pumping 100 barrels 2~ KC1 brine at 15 BPM or 8000 psi maximum tubing pressure. C. Proceed with fracture treatment by pumping 6,200 gallons YF140 and 54,000 lbs of Acme SB resin-coated 20/40 Carbo-lite. 8. RD D-S tree saver. RU wireline. PT lubricator to 3500 psi. Pump up SCSSV control line w/ hand pump to 5000 psi. RIH & retrieve frac sleeve. RD wi rel i ne. g. RU CTU. Cleanout to 12,850'. RD CTU. 10. RU E-line. PT lubricator to 3500 psi. Run spectrum gamma ray tracer profile from PBTD to 12,300'. RD E-line. 11. Flow test well. 12. RU slickline. PT lubricator to 3500 psi. RIH w/ rounded guide and tag fill. POI4. 13. Flow test well. \docs\shp\m28.doc RECEIVED S EP 1 9 1991 Alas.~ Oil :& Gas Cons. Gomm'tss~o~ Rnchorage Completed 22-MAR-gl ,t-,ttaci~nlerl'~ MARATHDN OIL CDM(~ANY TRADING BAY UNIT STEELHEAD PLATFORM WELL M-2@ ALI measurements rare RKB to top oF equipment. Comoket~on String: (KI~ : 74.5' ?rom Tubing Head Top Flange) 4.5' FMC TC-1A-EN Tbg Hngr, Butt Top &iBtm. 461' 0'-10,568' 990' 1445' 4590' 0-497' 497'-11,399' 11193'-12,448' 12,368'-13,000' CAMCO TRDP-4A SCSSV (3.813' D ProFKe). 4.5', 12.6#, L-80 AB Mod Butt Tbg. 26', 267-397#, ]ifil-Quip 16', 75#, K-55 ]~TC 13-3/8', 61/68#, K-55, OTC 10-3/4°, 51/55.5#, N-80 9-5/8t ~7~, N-80 7', ~9~, N-BO ~utt Unep 5', 18~, FL4~, N-80 liner Oeo.th 2320' 4034' 5440' 6651' 7445' 7911' 8370' 8802' 9229' 9619' 10010' 10401' GLM's ore Dansel GLSO, 4.5' x 1.5' sldepocket mondreis (12 .totol) Valve Tyoe Lo.tch Bor.t Size 1 Dummy RK - 2 - 3 - 4 - 5 - 6 - 7 - 8 - 9 - 10 - It - 12 Dummy RK - 10,46~' Otis 'XD' Production Sleeve (3.813' X ProFile). Squeeze Per?s 10,6~0'-6~3' Produc't~on Packer Assembly, 10,524' 9oker DB Pkr, s;ze 194-47 w/ 14' SBE 10,543' M~ilou.t Ext. 10,590' Dt)s 'X' L0.nding Nipple (3.813' Pkg Bore). 11,173' ~ker Loc~tor Seol Assembly G-ZONE Top oF G-1 ~ 10,632' Bo.t aP G-6 t~ 11,126' Isolo'l:lon Pocker Assembly, 11,175' 11,183' 11,230' 11,268' t~aker Model DB Packer s~ze 194-47. w/ 4' SBE Mlllout Ext. Otis 'X' L0,ndlng Nipple (3.813' Pro?lle~,,~, ~/EST FORELAND SEP 1 9 !99t Top VF-O ~ 11,790''~l~.-~ .OJ] .& Gas Cons. C0mmissl0n Bo~ ~/F-6 e 1P,310' .Anchorage Isolation Packer Assembly. 12,351' 12,360' 12,369' :Baker Model FIB-1 Pkr, S~ze 85-40 Otis 'XN' Nipple (3,813' Bore, 3,7~5' No[ia), TIW 5' LG-G Tie-]~ock Seals wi'th 1/2 Muleshoe. BASAL WESTFORELAND PERFDRATIDN~ In'terval Ft SPF Phas;ng 12,675'-12,7~8' 73 8 90' 12,748'-12,808' 60 4 90' 12,810'-12,900' 90 4 90' Averoge I)evlotlon = 13.0' Top o~ ~and Plug ~ 12,767' E-Line (3/15/91) TDF #1 (STRE~$FRAC Tool) ~ 12,880' (10/31/90). 6/90 & 10/90 . 10/90 10/90 PBTD ~ 12,952' TD @ 13,000' Revision Date. 5/6/91 Revised By, PMO/evo Re~son. Workover Previous Revision. Tagged TDF JUL 30 '91 89:16 DOWELL SCHLUMBERGER S07~835~59 ' ' ~ . Attachment #3 ('5 RECEIVED "" SEP 1 9 t991 ' Alaska OJJ & Gas Cons. CommissiOn Anchorage JUL ~0 '91 09:17 DOWELL SCHLUMBERGER 907~935259 · Whh Dowell% TTee Saver tool, you have th~ capability to stirnulat~ your well and protect tAe Christmas Tree f~orn damage by bi§h pressures, corrosive fluids end abrasive wear. Current stbnulntion t~hniques usually require high pressures nn~t large volum~ of il~;.d for succe.,~sful trea:rnents. Since some wells arc equipped wilh Christmas Tr~s rated be]ow the minimum r~cluireraeats for & stirnulat/on treannent, the tree has to be replaced with an expen~i~,,e high-pressure tree. Removing the on~nnl tt~ often means kilting th~ well and fisldn§ damage to the format/on, With Doweil's Tree Saver, the iow-pre~sure Christmas Tree cnn' remain on the well dut/ng sthnula'Jon and be protected from high pressures and abrasive flu/ds. · Adv~ .,The Dowell Tree Savm :.' 1. ls pressm'e rated at 15,000 psi workinf~ pressure, 2. Contains high press~L-es within the tree saver tool for a safer ope. ration. 3. lsola~,s abrasive and corrosive fluids from conuct with expensive v~ves ~d fittings. 4.Allows high. pzcssure u'~aunents t~ be pedorrn.ed on welh low-pressure Christmas 5.Can be installed with the well dead or un~r pressure, 6.Can be installed wilA~r the &id of n worko3;er rig, 7.]s adaptable to most Christmas"fl'ees with a standfud flange connection. S.Minimizes vibration during treating operations due to lov/-pt'ofile design. ~). Gives'trouble-free performance ~tue to simple dssi~ and operation. Operation To insull the Tre~ Saver tool: l.. Close thc master valve on the Christmas Tree. 2, Remove top per'lion of Christmas Tree at flan~e connc,~tion. 3. Wi~ th~ aid ora Doweli hydraulic hoist, place the Tree Saver on top of the Chrhtrnas Tree and attach at the f]anf~e conn~tion, 4.Open thc master valve. 5. Extend the'l~ee Saver tool nundml either hydraulically (wells with pres- sure) or meehanlcally (wells without pressure), Th~ Tre~ Saver tool mandrel pusses through thc Christmas Tree.nnc~ seels off in the upper portion o~ the tubing, thus isolating th~ Chrisunas Tree all pressune and abrasive fluid. To re. move the Tree Saver tool: t, Rctntct the Tree Saver tool mandrel hy~,eaiie, all¥ into the Tree S~ver tool, 2. Close th~ master valve on the Christmas Tree. 3, Attach the Dowell hydraulic hoist to the top of the Tre~ Saver t0ol. 4. Remove Tree S~vcr tool from Christmas Tree flnnge. 5. Rcphce top et'Christmas Tree to flange nnd open master valve to complete the Operation. RECEIVED S E P 1' 9 ,t99 Alaska Oil & Gas Cons. Oommissio Anchorage ,) Christmas Tree P.3 Hook Up Position JUL BO ~91 09:18 DOWELL SCHLUMBERGER 907F_8~5259 P,4 RECEIVED Alasl(a Oil & Gas Oons. Anchorage Extending ManOrel In Treating Position Retracting Mandrel Attachment #4 ('" ~TEELHEAD PLATFORM (" Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP RECEIVED SEP 1 9 ~99t ^laska 0il & 6a, s Cons. Oommissio~ Anchorage . ... ---i0 ....... MARATHON ( STATE OF ALASKA ~ 0 ~ ! ~ !~;.,["?;,~':' "~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abanclot~ __ Suspend __ Alter cas, rig __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon 0il Co - Sub 0peratlr) Development_Z_ Exploratory __ 3. Address Stratigraphi~_ P.O. Box 190247 Anchorage, AK 9951~1 ' Service__ 4. Location of well at sudace Leg B-l, Slot 3 Steelhead Platfom Operation shutdown __ Re-enter suspended well __ Install Jet Pump Plugging __ Timeex, lens,on__ Sbmulate__ X Pump-in Test - Pull tubing __ Vanance __ Pedorate __ Other __ 6. Datum elevation (DF or KB) 152' KB above NSL feet 7. Unit or Property name Trading Bay Unit 8. Well number H-28 970' FNL, 532' FWL, Sec. 33-9N-13W-SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28-gN-13W-$N At effective depth At total depth 85' FNL. 2.331' FEL. Sec. 28-9N-13W-gM 12. Present well condition summary Total depth: measured 13,000 ' feet true vertical 10,801 ' feet Effective depth: measured 12 952 ' feet true vertical ' feet 10,751' Casing Length Size Cemented Structural Plugs (measured) 9. Permit number 90-19 10. APl number 5o- 733-20414 11. Field/Poo~lcArthur Ri ver G-Zone/West Foreland None Junk (measured) Stressfrac tool 12,880' Measured depth True vertical depth 13. Conductor 1,447' 16" 1,800 sx Sudace 4,590' 13 3/8:; 2,900 sx Intermediate 11,399' 9-5/8 3,360 sx Production 1,250' 7" 400 sx Liner 632' 5" 136 sx P~foratLon.(;lept.h: measured ~asal west Forelan[! true vertical 12,655' - 12,808' MD Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 AB Mod Butt tbg 1:o 10,568' Description summary of proposal X_._ Procedure, NBD, & BOP 1,447' 4,590' 11,399' 12,448 ' 13,000' 10,468' - 10,609'TVD 12,810' - 12,900'MD 10,611' - 10,699'TVD 1,445' 4,031' 9,310' 10,261' 10,801' Pa..ck,ers and....SSS..¥ (type and measured depth) Baker FB-1 Pkr Size 85-40 e 12,351' uaKer uP ~'Kr Size 194-47 w/14' SBE e 10,524'; Baker DB pkr Size 194-47 e 11,175' Attachments Detailed operations program ~ BOP sketch _X. 1,2&3 15. Status of well classification as: K 14. Estimated date for commencing operation 8/15/91 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Q~u_u~,,~ f~ ~---~. {~-~-~ Title ~_..,~_.~, . ~:~ ~.,~,,~, FOR COMMISSI~ USE ONLY Conditions of ~prova-'r.' Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 1'~'- Approved by order of the Commission Gas__ Suspend.~(~. 2 6 1991 A,..~. ^,, o_ ..~ Oons. O0mmlssion Anch0mgm ORIGINAL SIGNED BY ~_nNNI; q, SMITH Form 10-403 Rev 06115/88 SUBMIT IN TRIPLICATE Attachment #1 Steelhead Well M-28 Install Jet Pump for BWF Drawdown Procedure 1. Hold pre-job meeting. 2. Shutin well at wing valve and master. RU Otis on pipe rack level. Take SCSSV off platform system and put on hand pump (4500 psi) located near well room door. Install lock open fusible cap on master manumatic. MU tool string w/ 3.80" OD gauge ring. Pressure test lubricator to 3500 psi. Open master and note SITP. Note: Zero tool string at pipe rack level, which is 41' lower than KB. Report all depths on a KB basis. 3. Open swab. RIH w/ 3.80" GR to XO sleeve at 10,463'. POH. 4. RIH w/ shifting tool and jar down on XD sleeve to open equalizing ports.. Wait for casing pressure to stabilize, then continue jarring down through sleeve to open it fully. POH. NOTE: Pressure in casing at XD sleeve depth is 3800 psi. Expected shut in pressure in tubing at XD sleeve depth is 5500 psi. Run a jumper from water injection header and pressure casing to 1000 psi prior to RIH w/ shifting tool. 5. Inject FIW down tubing while taking returns to production to ensure the sleeve is open and not restricting flow. 6. RIH w/ National jet pump assemble and Otis SSV w/ tandem Petrodat electronic memory strain gauges attached to bottom of SSV. Set gauges' sampling rates to collect data up to the life of the batteries. Set assembly in XD sleeve at 10,463'. POH. Rig aside Otis. 7. To test jet pump and perform step rate test: a) Bleed casing pressure to separator pressure over 30 minute period. b) Bring power fluid pressure up to 1500 psi over 30 minute period. c) Monitor well for net returns. If OK, finish RD Otis. d) Increase PFP in 500 psi increments every 15 minutes until operating pressure of 3000 psi is reached. .e) Test well at 3000 psi PFP for 48 hours. f) Increase PFP to 3500 psi and test well for 48 hours. g) Increase PFP to 4000 psi and test well for 48 hours. h) Shut in well and record 72-hour PBU. i) Returned well to production at 4000 psi PFP. 8. Analyze BHP data for PI dependency on drawdown. \docs\ce58\30. doc RECEIVED AUG 2 $1991 Alas~ Oil & ~las Cons. Commission Anchorage Attachment #2 .o ALL MARATHON OIL COMPANY TRADING BAY UNIT ST££LH£AD PLATFORM VELL M-28 ALL measur'emen~s are RK~ to ~op o? equipment. Comolet~on S~pmg: (Kg = 74.5' Fearn Tubing He~d Top Flange) 4.5' FHC TC-IA-EN Tbg Hnge, gut~ Top 461' CAMCO ~DP-4A SCSSV (3.813' D 0'-t0,568' 4.5~ 1~.6~, L-80 AB Mod But~ Tbg. 990' ~6~ ~67-397~, ~rl[-Qulp 1445' 16~ 75e, K-55 gTC .4590~ .... 13~3/8', 61/68~, K-55, gTC 0-497' 10-3/4~ 51/55.5~, N-80 497'-1L399' 9-5/8% 47~, N-80 11193'-1~448' 7~ ~9~, N-BO ~u~: tines 1~368'-13,000' 55 1Sa, FL4S, N-80 hnee G~'s =re ~=nle[ GLSO, 4.5' x t.3' sidepocket Oeo'l:h V~lve 2320' 40:34' 5440' 3 665L' 4 744.5' 5 7911' 6 8370' ? 880~' 8 9;?~9' 9 9619' 10 tOOtO' 11 10401' 1~. Tyoe ~ DumMy RK Poe~ Size m '10,46~.' aris 'XD' Production SLeeve <3.81'3' X ProFile). G-ZBNr' Top o? G-I ~ 10,'63E' Boi: oF G-6 e ILLE6' ~O[~c~on Pec;kqr' I1,~75' ~ker' Model Dg Packer size ~cj4-47, II, LB3' Hltlout Ex1:. I]~P30' Otis 'X' L~ndlng Nlpp{e (3.813° Pr'aCRe). 1L268' V/L Re-entery Guide lr;i Ica VEST FDRELANO Top VF-O a 11,790' Bo1:VF-6 e 17,310' .[~olo~lon P~cker- Assembly! ". 1Po351' ]~e~ker Node[ F9-1 Pku, S~ze 85-40 1~,360' aris 'XN' Nzppie (3.813' Bore, 3.7~5' NoGo). 1~369' TI~ 3' LG-6 T;e-g~ck Se~ts wi~h'l/2 Muteshoe. ~A~AL WE~TFDRELAND PERFDRATION~ ~n~eevol. ~ ~PF ~hns;no IE,G75'-IE,748' 73 8 90' 12,74B'-LE,BQB' 60 4 90' 12,810'-1~,900' 90 4 Average Devlatmon = 13.0® Top oF S~nd Plug l~ 1;?,767' E-Line (3/15/91:) TOF lit (STRESSFRAC Tool) E l~,8BO' (10/31/90). RECEIVED AUG 2 6 1991 '" alaska Oil & Gas Cons. C0mmlssi~n Anchorage. 6/90 & 10/90 10/90 10/90 PDTD e Tn m 13.000' Rev;sion D~te~ 5/6/91 Rev;sed By. PHO/evo Re.son, ~toekover (' · -- -' ':;:i - .. '(' · ... " DOLLY VARDEN PLATFORM ,. . Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR ~ 4'~1X.-~.'6~. '5000 'ps1 CHISTMAS TREE -- POSITIVE CHOKE RECEIVED AUG 2. ~.la~ka.Oll.& Gas Con~. Comn]bsien ~chorage' ~ 2' 5000 psi 2' 3000 psi · 13 3/8' CASING · Attachment # 1. Hold pre-job meeting. PROCEDURE Steelhead Well M-28 Pump In Test 2. Shut in well at wing valve and master. RU Otis on pipe rack level Take SCSSV off platform system and put on hand pump (4500 psi) located ~ear well room door. Install lock open fusible cap on master manumatic. MU tool string w/ 3.50" OD swedge {rounded bottom for entering isolation packer}. Pressure test lubricator to 3500 psi. Open master and note SITP. Note: Zero tool string at pipe rack level, which is 41' lower than KB. Report all depths on a KB basis. Slickline measurements have consistently run 20' deeper than DIL. 3. Open swab. RIH and tag fill depth. POH. 4. Desired depth of fill is 12,720' wireline (12,700' OIL). A +/-10' variance is acceptable. If fill is too deep, use D-S to pump sand slurry into tubing for required amount of fill up, then shut down and allow sand to settle. Well should be flowed just prior to pumping to lower pump pressure. If fill is too high, bail it out to appropriate depth. Once fill is at acceptable depth, proceed to next step. 5. Pick up Camco frac sleeve assembly. RIH on GS running tool and set across SCSSV. Well should be shut in with maximum tubing pressure built up at the time the frac sleeve is set. POH and RD slickline. Bleed control line pressure to zero. 6. Install tree saver per D-S procedure. Technical data for the tree saver is attached. 7. RU D-S CPS-361 pump unit (dual pumps) to casing and to pump down tubing. Pressure test line to casing to 4000 psi and line to tubing to 8000 psi. Hold safety meeting and ensure all personnel are clear of testing area prior to pressurizing lines. 8. Mix 100 bbls of 3~ KC1 water in D-S 250 bbl tank. Use D-S jet blender and filter pod units to mix and filter fluid. g. Apply 3000 psi to casing annulus. Monitor casing pressure at all times during the next pumping step. Pumper to have constant casing pressure readout on unit so that he can shutdown at first indication of tubing to casing communication. RECEIVED AUG G lgg! 41aska Oil & Gas Oons. Commisslen Rnchorage Procedure Pump-in Test Page 2 10. Open tree saver valve. Establish injection rates per following schedule: Rate Barrels Pumped Maximum Injection Pressure 1/2 BPM 5 Bbls 7000 psi I BPM 10 Bbls 7000 psi 2 BPM 20 Bbls 7000 psi 3 BPM 65 Bbls 7000 psi (Remainder) 11. Record both injection pressure and rate as well as casing pressure. 12. RD D-S equipment and tree saver. 13. RU Otis on pipe rack level. MU tool string w/ GS pulling tool. Pressure test lubricator to 3500 psi. Apply 4500 psi to SCSSV control line. Open master and note SITP. RIH and retrieve Camco frac sleeve. RD Otis. 14. Return well to production. \docs\oe58\34. doc AUG ~ 6 1991 4/a,~ka 08 & ~aa Cons. AnChOrage C°~mis;ien Attachment ~.2~ ~ CompLeted 2~-MAR-gt MARATHON DIL COMPANY TRADING ])AY UNIT STEELHEAD PLATFORM WELL M-28 Att measurements ape RKO to lop o? equipment. ComoEetlon -~rlnc~: (K]~ : 74.5' ~om Tubing Hood Top Ftonge) 4.~' FHC TC-1A-EN Tbg Hng~, But~ Top & ~tm. 46V CAMCO TRDP-4A SC~SV (3.813' D ProFRe). 0'-10,568' 4.5'~ IE.6~, L-80 AB Hod But* Tbg. 990' ~65 E67-397ff, ~pit-Quip 1445' 1~5 75~, K-55 BTC '4590~ .... 13~3/8~ 61/68~, K-55, BTC 0-497' 10-3/4', 51/55.5~, N-80 Bu~ 497'-11,399' 9-5/8', 47~, N-80 ~u~ 11193'-I~448' 75 EBb, N-80 ~u~ t~nep 1~368'-13,000' 55 18ff, FL4S, N-80 hne~ Att GLM's are ])an:et Gl. SD, 4.5' x 1.5' s:depocket nandrets (12 Dec)ih Valve Tvc)e Latch Por'i Size 2320' I Ounmy RK - 4.034' E .. - 5440' 3 - 6651' 4 - 7445' 5 - 7911' 6 · - 8370' 7 - 8802' 8 - 9~;!9' 9 - 9619' 10 - 10010' 11 - 10401' 1E Ounmy RK - '10,46;~' I]tls 'XD' Product:Ion Steeve (3.813' X Prof'lte). Squeeze Per?s 1~6~0'-623' Pr'oducFl:lon Poql<er Assembly, 10,5247 BAker. nB Pkr' size 194-47 w/ 14' SBE 10,543' Mlttout Ext. 10,590' otis 'X' Land;n9 Nipple (3.813' Pk9 Bore). 11,173' Baker~ Loca't:or. Seat Assemloty G-ZONE Top o? G-I e 10,~,32' Bo~ oR G-6 e I11~6' Isolation Poqker- Assqmbly, I1175' ~kee Hode[ ~g P~ckeP s~ze 194-47. ILIB3' Mlttout Ext. 1[~30' Btls 'X' L~ndlng Nipple (3.813' IL~68' V/L Re-entery Guide VEST FBRELAN]) Top VF-O 8 11,790' Bo't ~/F-6 Q 12,310' Isolation Pack~r- Assembly. 12,351' Baker Model FB-I Pkr, Size 85-40 1P, 360' ntis 'XN' N~ppte (3.813' Bore, 3.7~5° NoGo). 1~369' TI~ 5' LC-6 Tie-Back Seats ~i~h't/~ Huleshoe. '. m~ASAL ~ESTFDR~LAND P~RFDRATIDN~ ~n~e~vat ~ ~PF" ~ 1~,67S'-1~,748' 73 8 90' 1~,74~'-t~,8~8' 60 4 90' 1~,810'-1a,900' 90 4 90' Average ])evian:Ion = 13.0' Top oF SGnd Plug ~ 12,767' E-Line (3/15/91) TDF fit (STRESSFRAC Tool) e 12,880' (10/31/90). RECEIVED AUG 2 6 1991 Naska OiJ & Gas Cons. Commission Anchorage · · 6/90 & 10/90 10/90 10/90 · PBTD e 18.952' TD ~ 13,000' Rev;sion ]]ate, 5/6/91 Revmsed By. PMD/evo Reason, ~/orkover P~v'mn,,< D~,,~.~m Tn~noW Ttqtr JUL SID '91 09:17, DONELL~CCH~BEAGER 907~335259 Pmm Clx6stmas. tag, h pressures and abrasive fluid · With Dowell% Tree Saver tool, you have tt~ capability to stimulate your well and protect the Christmas Tree from damage by high pressures, c°rro~ive fluids and abrasive wear. · Current -~timulation t~¢hniques usually require high pressttres and large volumes o~f fl~;.d for suc. cessfal treatments. Since some wells are equipped with Christm~ Tre~s rated below the minimum requirements for a stimulation tw~tment, the tree has t,o be replaced with an expensi~,e high-pressure tree. Removing the orig. inal tree. often means kUliag the WeU and tiskin§ damage to the formation. · Wi~ Dowelrs Tree Saver, the iow-pressure Christmas Tree cnn remain on the well during sthnula~ion and be protected from high presst~es nod abrasive fluids. : Advantages · ,The Dowcil Tree Saver:. :.' 1. Is pzessure ratexi at 15,000 psi workiv, g pressure. 2. Contains high pressures within the tree saver tool for a safer Old.' ration. 3. Isolates abrasive and corrosive fluids from conts~ with eXl~nSibe valves and fittings. 4. Allows high.pressure treaunents ~o be performed on wells with/ low-pressure Christmas Trees. 5. Can b~ installed with the well dead or under pressure. 6. Can be installed ~iihou~ the aid of a worko'~er rig. 7. Is adaptable lo most Christmas' Trees with a standaui flani~ connection. lt. Minimizes vilxa~ion during treacinE operations due to low-profile design. 9. Oives'r. rouble.free performance due ~o simple design and operaxion. Operation To install the Tre~ Saver tool: : t. Close the mas~er valve on the Chris,mas Tree. 2. Remove top poaion of C.kristmas Tree at flanEe conac,~cion. ~. Wi~ lhe aid ora Dowell hydraulio hoisL pla~e the Tree Saver on top offll~ Chrismlas Tree and attach at the flange connection. . 4. Open the masvzr valve. 5, Fottead the ~ee Saver tool mandrel ekher hydraulically [wells with pres. sum) or mechanically (wells withouz pressure). T]~ Tree Saver tool mandrel passes through the Christmas Tree.and seals off in ~he upper portion of the mbig§, thus isolating ~he Chrisunas Tree lmm all pressure and abrasive fluid. To remo,~e the Tr~ Saver tool: I. Retract the Tree Saver tool mandrel hydraulically into the Tree Saver tool. 2. Close the master valve on the Christmas Tree. 3, Attach the Dowell hydraulic hoist to the top of the Tree Saver tbol. 4. Remove Tree Saver mol from Chris,mas Tree flange. $, Replace ~op of Christmas Tree to flange and open master valve to comple~ ~he operation. P.3 Tree Saver Tool · ! · Christma~ Tree .o Hook Up Position RECEIVED AUG 2 6 1991 Alas~.Oil'.& Gas Cons. Commiss~en 'Rnchorage ., Wireline Lubricator w/Associated BOPE · GREASE HEAD (Hydraulically Activated) - LUBRICATOR MANUALLY OPERATED BOP POSITIVE CHOKE · 4'~.1/~1.6-'..5000 psi CHISTMAS TREE RECEI.VED UG 2 6 1991 Gas Cons· Commission '~nchorage ---- 2' 5000 pal' -.- 2' 3000 psi · 13 3/8' CASING · .... STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ Alter casing m Repair well __ 2. Name of Operator ! 5. Type of Well: Development ~ UNOCAL (Marathon Oil Co- Sub Operat r) Exploratory__ 3. Address Stratigraphic ~ P.O. Box 190247 Anchorage, AK 9951~1 Service__ 4. Location of well at surface Leg B-l, Slot 3 Steelhead Platform 970' FNL, 532' FWL, Sec. 33-9N-13W-SM At top of productive interval 150' FNL, 2,333' FEL, Sec. 28-9N-13W-SM At effective depth At total depth 85' FNL, 2,331' FEL, Sec. 28-9N-13W-$N Stimulate __ Plugging m Pedorate m Other X CT Cleanout 6. Datum elevation (DF or KB) 152' KB above NSL feet 7. Unit or Property name Trading Bay Unit 8. Well number N-28 9. Permit number/approval number 91-183y/~:~ ~-~°/I 10. APl numlSer 5o- 733-20414 llm Field/Poo)MCArti~ur Ri ver G-Zone/West Foreland 12. Present well condition summary Total depth: measured true vertical 13,000 ' feet Plugs (measured) 10,801 ' feet 12,952 ' feet Junk (measured) 10,751' feet Effec.tive depth: measured true vertical Casing Length Size Cemented Structural Conductor 1,447' 16" 1,800 sx Surface 4,590' 13 3/8" 2,900 sx Intermediate 11,399' 9-5/8" 3,360 sx Production 1,250' 7" 400 sx Liner 632' 5" 136 sx Perforation depth: me~adl West Foreland 12,675' - 10,480' - true vertical 12,810 ' - 10,611' - Tubing (s. ize, grade, and measured depth) 4-1/2" 12.6~ L-80 AB Mod Butt tbg to 10,568' Pa san S dm re e t ) ~a~er dD~ ~tYrP~e el~)~-~ ~ 14' Measured depth 13. Stimulation or cement squeeze summary 1,447' 4,590' 11,399' 12,448' 13,000' 12,808' MD 10,609' TVD 12,900' MD 10,699' TVD Baker FB-1 Pkr Size SBE e 10,524'; Baker DB pkr Size None Stressfrac tool 12,880' 14. Intervals treated (measured) True vertical depth 1,445' 4,031' 9,310' 10,261' 10,801' 85-40 e 12,351' J U L 2 § 1991 Treatment description including volumes used and final pressure .~la$~a .0JJ :& Gas .Cons. Commission Anch0ra,qe Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6 / 7 / 91 797 224 525 0 117 Subsequent to operation 6/12/91 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations 663 324 392 0 102 16. Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed l~,(:~.,,.,..~, ~. {~;~,~,.,.4,~,, Title ~, Date "-{ -- 2..?. -ct ~ SUBMIT IN DUPLICATE Attachment # 1 Daily Summary of Well Operations Wel 1 M-28 CT Cleanout 6/8/91 Otis, pressure test lubricator to 3500 psi for 10 min. SI wing valve. RIH w/ 3.80" GR to 10,430'. POOH. RIH w/ 3.50" GR to 11,235'. 6/9/91 RIH, tag fill g 12,636'. RD Otis. RU Arctic Recoil w/ 1.g" wash nozzle, 6' x 2.25" OD by-pass tool, and two check valves. SI swab and pressure test surface lines, CT & lubricator to 5000 psi. Open well to production w/ +/- 1000 psi. RIH w/ CT to 12,000' CTM. Pumped KC1 g 4300 psi. RIH & SD ~ 12,28g'. No progress. 6/10/91 POH w/ CT. PT lines, CT & lub to 5000 psi - OK. RIH w/ 2.50" nozzle to 12,235'. Pump ~ 2.5 BPM, 3500 psi. Set down at 12,2g0'. Pump 5 Bbl "XC" pill. Sweep and displace with 220 Bbl KC1. POH w/ CT, replace stripper bushings. PT surface lines, CT & lubricator to 5000 psi. RIH. Pump ~ 2.25 BPM, 3900 psi. Choke FTP back to 1000 psi. Returns rate ' 2.5 BPM. Pump 5 Bbl "XC" pill, 50 Bbl KC1 ~ 2.25 BPM. Wash easy to 12,700'. Pump 10 Bbl "XC" pill and wash to 12,770'. Displace w/ 225 Bbl KC1. Pump 10 Bbl "XC" pill and wash 12,770 - 12,820' CTM. Pump 50 Bbl KC1. Pump 10 Bbl "XC", wash 12,820' - 12,858'. Pump 10 Bbl "XC", 10 Bbl KC1, 10 Bbls "XC", 10 Bbls KC1, 6 Bbl "XC". Displace w/ 370 Bbl KC1. Returns .1 to 1.04 BS. Last go Bbls free of sand and carbolite. SD pumps. 6/11/91 Flow well w/ CT g 12,000'. Rate stable g 816 BFPD, 394 WC. FTP = 110 psi. SI 3 hrs. Pressure buildup to 110 psi. RIH w/ CT. Tagged fill e 12,733' CTM. Calc. static BHP = 6085 psi after 7 hrs, 20 min. Shut in. Open to production, pump KC1 e 3 BPM, 4500 psi. Pump 5 Bbl pill, wash from 12,730' to 12,7g0', displace ~ 50 Bbl KC1 Pump 5 Bbl "XC" pill, wash 12,7g0' to 12, 853'. Displace./ 40 Bbls KCi. Keep CT e 12,850'. Pump 40 Bbl "XC", sweep and displace w/ 350 Bbl KC1. POOH while continuing to pump KC1. SD pumping w/ CT 5700'. POOH w/ CT. SI swab. Open well to production. RD CTU. \docs\shp\m28.doc J U L 2 5 tggt fl, "~ F:' "~ Alaska 0ii ¢~ 1;~ (J01'lS, L;0mmlssion Anchorage Attachment # 2 .,. Como[ e~cecl MARATHFlN DIL C[]MPANY TRADING BAY UNIT 'STEELHEAD PLATFFIRM ~/ELL M-28 ALI measuremen't~ 0.re RKB 'to 'top of' equ;pmen't:. Como[etlon S~trmcF (KB = 74.S' ~eron Tub;n9 Heod Top Ft,,nge) 4,5° FHC TC-tA-EN Tbg Hngr0 But~ Top 8, Ill:m, 461' CAMCO TRDP-4A SCSSV (3.813' O ProFIte). 0'-t0,568' 4.5', 12.611 L-gO AB Nod Butt Tbg. 990' ~6: ;~67-397#, Drlt-Oulp 1445' l&; 75tt, K-55 gTC 4590' 13-3/8'. 61/$8#. K-55, gTC 0-497' 10-3/4°, 51/55,5#. N-a0 Bu,t 497'-11.399' 9-5/8: 47#, N-80 Butt 11193'=1E. 448' 7; 291~. N-80 3ut[ t~ner IP.,368'-13.000' 5: 18#. FL4S. N-80 truer Squeeze 10.6RO'-GR3' Att Oeo~h 2320' 4034' 5440' 665t' 7445' 7911' 8370' 880~' 9E~9' 9619' 1oolo' 10401' 10.46R' GLN's Gte Dan;el GLSO, 4.5' x 1.5' $;depocket mandrels (lP ~otaL) Valve._ Tvoe ~ Port S~ze I Dummy RK - E - 3 . 4 - ~i _ 6 - 7 _ 8 _ 9 _ ~0 - 11 _ IE Dummy RK - Otis 'XD' Produc't:son SLeeve (3.813' X ProFIte). Produc~clon Pocket Ass~mbty~ 100524' g~ker DB Pkr size 194-47 w/ ~4" Sg~ 10,543' Mt[tout Ext. 10,590' otis 'X' L~nd;ng N~ppte (3.813' Pkg Bore). 11,173' g~ke~ Loc~o~ Se~t Assembly G-ZONE Top o1~ G-I ~ 10,632' Boi: of' G-6 e 11,t26' Isoln~lon Pocke~- Assembly, 11,175' g~ke~- Node[ ])g Packer s;ze 194-47. 11,183' Mlllout Ext. IL;330' rl~cls 'X' Lnndlng Nipple (3.813' I126g' V/L Re-efltery Gu;cie VEST FORELAND Top VF-O ~ 11,790' Bo-t ~/F-6 e t~,3100 REEEIVED JUL 2 5 t99 ~solo~c~on Pocl<~-r As:sembly, 1~,351' getke~' Node[ rg-t Pke, S;ze 85-40 A~aska OJJ & Gas Cons. Commission ' 11360' Ot~s 'XN' N~pple (3,813' Bore. 3,7~5' NoGo), Anchorage 1~369' TI~ 5' LG-6 Tie-gGck SeGIs w;~h I/E Muteshoe. BASAL I,JESTF'OR£LAND PERF'QRATION~: ]niervo! F't ~PF ~ 1E,675'-12.748' 73 8 -.. 90' "6/90 & 10/90 ':;:"'": ' ]E,748'-IE,808' 60 4 90' 10/90 "'' ~E, StO'-lE,900' '90 4 ~0' 10/90 · ' "' " · ..., . .... ,... . Averoge ~ev~G~mn - 13.0' . ' ' .... :~.: ' ' ' · .?:. · :.-.'..'.' ....;.,: . ::; ,::';~.' ,. · .... ... -~;.:.~ .,.;,.~.,...,,........,.,,...:~;:~.,:,,,,.,....,.,.,~ ... -..,~ ..... ;: . . ::~..' .... Re~ Date, 5/~/9~ ',. ~,...~' ' '"':'"';'""""~';':" ........ " 'PST° e t~95a' ',~ :'. ' %"" "..' ."' Revised ay. PHO/evo :.~~¥~ ,-... . · .~ ..... .... ~' .~.--. ,-~ ~. TD ~ t~ nnn, .. ... .... :.'......;,.. - '..........: .... : Reas~ V~kover ......... ~.., REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown m StimulateL Plugging m Pedorate __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Narathon 0il Co - Sub 0peratlr) Development~X Exploratory m 3. Address Stratigraphic ~ P.0. Box 190247 Anchorage, AK 9951~ Service__ 4. Location of well at surface Leg B-l, Slot 3 Steelhead Platform 970' FNL, 532' FWL, Sec. 33-gN-13W-SM Other __ 6. Datum elevation (DF or KB) 152' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number N-28 At top of productive interval 150' FNL, 2,333' At effective depth FEL, Sec. 28-gN-13W-SM At total depth 85' FNL. 2.331' FEL. 12. Present well condition summary Total depth: measured true vertical Sec. 28-gN-13W-SM 13,000' feet 10,801' feet Effective depth: measured feet · true vertical! 2,952 ' feet 10,751' Casing Length Size Structural 9. Permit number/approval number 10. APl num~3er 5o- 733-20414 11. Field/PO~cArthur River R-7nn~./W~.~t Fn~_l and · Plugs (measured) None Junk (measured) Stressfrac tool 12,880' Cemented Measured depth True vertical depth Conductor 1,447' 16" Surface 4,590' 13 3/8" Intermediate 11,399' 9-5/8" Production 1,250 ' 7" Liner 632 ' 5" 1,800 sx 1,447' 2,900 sx 4,590' 3,360 sx 11,399' 400 sx 12,448' 136 sx 13,000' Perforation depth: measured Basal Nest Forel and true vertical 1,445' 4,031' 9,310' 10,261' RECEI 'b 12,675'- 12,808' MD 10,480' - 10,609' TVD 12,810' - 12,900' MD JUL 2 5 199l .10,611' - 10,699' T~aska Oil & Gas Cons. Commission Tubing (size, grade, and measured depth) 4-1/2" 12.6// L-80 AB Mod Butt tbg to 10,568' Anchorage. Pack_ers and SSSV (tyRe and measured depth) Baker FB-1 Pkr Size 85-40 ~ 12,351' Baker DB Pkr Size 194-47 w/ 14' SBE e 10,524'; Baker DB pkr Size 194-47 e 11,175' 13. Stimulation or cement squeeze summary Basal West Foreland Hydraulic Fracture Stimulated' Intervalstreated(measured) 12,675' - 12,808', 12,810' - 12,900' MD 14. Treatment description including volumes used and final pressure 46400 Ga 1., Y F 140 Gel. 122':;0001 bs ?N/4N £av, hnlii-.~ Max ln.nnn p.-i TSTP 32fiO nsi Representative Daily Average J:'roduction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/5/91 172 '" 80 0 0 100 Subsequent t° °perati°n 4./1E / q 1 1 .':iF R / ~? 61n 73r1 16rl.~ 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .~X Oil .~X Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Signed Form 10-404 Rev~/15/8~ Date ri'- ZZ - ~ ~ .~ SUBMIT IN DUPLICATE. Attachment #1 Summary of Daily Well Operations Well M-28 Workover/Frac Stimulation 02/28/91 Accepted rig from Well M-2g. Skidded rig and rigged up. Rigged up coiled tubing unit. Tested lubricator and lines. Started testing coiled tubing. 03/01/91 Finished testing coiled tubing. RIH with same to 12,880' Displaced 5" casing, 7" casing and tubing with 3~ KCL. Oisplaced 3~ KCL with [0 ppg NACL weighted with CAC03 to 13.2 ppg to kill well. POOH with coiled tubing and rig down same. 03/02/91 R/U Schlumberger lubricator. Weight up 10 ppg NACL with CAC03 to 13.2 ppg. RIH and perforated tubing 10,508' to 10,510'. POOH and R/D Schlumberger. Displaced annulus with 13.2 ppg fluid. Observed well. Had slight flow. Shut in well, monitor pressure while building volume. 03/03/91 Monitored pressures while building volume. Pumped 185 bbls 13.2 ppg fluid. S/O to weight up surface volume. Circulated 13.2 ppg fluid around holding 300 psi backpressure. Set pump through plug in SCSSV. R/D lubricator. Set two way valve. N/O tree. Started N/U BOP's.. 03/04/91 Nippled up BOP's and tested same. Pulled backpressure valve. R/U slickline. Retrieved SCSSV pump through plug. Set SCSSV X. lock with flow tube. R/D slickline. Pulled tubing hanger to rig floor. Circ and conditioned completion. fluid. POOH L/D tubing. 03/05/91 POOH, laying down tubing. Changed top set of pipe rams to 5". Tested upper and lower pipe rams. M/U mill and packer retrieving tool. RIH picking up drillpipe. 03/06/91 RIH, picking up DP. Milled packer at 10,510' CBU. RIH and latched onto packer. POOH. L/D packer assembly. M/U fishing assembly for second packer. REEEiVED J U L 5 t991 Alaska Oil & Gas Cons. Anchorage SHP Well H-28 Daily Summary of Well Operations Frac/St imu 1 at i on Page 2 03/07/91 RIH mill packer #2 from 11,154'-11,157'. POOH with 100>, recovery. L/D fish. 03/08/91 L/O Fish. R/U slickline. Made two attempts to retrieve stress frac tool at 12,880' but could not get past 12,334' WL R/D wireline. P/U tapered drill string with overshot. RIH and washing at 12,700'. 03/09/91 Wash to 12,870m. CBU. Washover fish to 12,g04'. POOH with no recovery. Testing BOP's. 03/10/91 Change piston mud seal in top rams. Finish testing BOPE. RIH w~th.2-7/8" PAC X new 3-1/2" S-135 frac string. Reverse out at top of 7" liner, cont. P/U frac string. 03/11/91 RIH with 3-1/2" drill pipe and 2-7/8" stinger - wash and reverse clean to 12,890' - plugged drill pipe - POOH wet P/U frac BHA and RIH. 03/12/91 RIH with frac string - R/U and test string to 7000 psi and frac head to 12,000 psi. Set packer at 12,241'. R/U coiled tubing unit and test to 6000 psi. RIH with CT. Open multi service valve. Test casing to 1500 psi. RIH with CT to fill at 12,g07'. P/U to 12,g02' Displace DP with 3% KCL. Spot sand slurry for plug back. Wait on sand to ~ettle. 03/13/91 Wait for sand plug to settle. RIH with coiled tubing. Unable to work through packer at 12,365' CTM. POOH with CT and change nozzle. RIH with CT to packer. CT partially parted above injector head checks held. Removed damaged section and weld coil together. POOH with CT and R/D same. 03/14/91 Spooled off coiled tubing. Made slick line run to tag sand fill at 12,775' WLM. Surged perf's. Established inj. rates. R/U surface lines for frac equip. Gelled 1000 bbls of data frac fluid. 03/15/91 Wait on daylight. Held platform safety meeting. Tested lines to 13,500 psi. Performed data frac. R/U W/L. Attempted to obtain down~]~e.p~:i ~.temp. Kl:Li:iV : U J U L 2,5 1991 Ala'sl(a Oil & Gas ,Cons. Commission Anchorao. e SHP ~ell "-28 Daily Sugary of ~ell Operations Frac/Stimulation Page 3 Gauges did not start up after proc rammed delay. Reset gauge POOH. RIH with GR/CCL/PTS for temperature profile. 03/16/91 Finished temp survey. R/U D S. Gel fluid. Dump sand in silo. Held safety meeting. Primed pumps and pumped through all lines. Put 1000 psi on backside. Tested lines in stages to 12,500 psi. Bled lines to 3000 psi. Opened well SIDPP 2380 psi. Pumped frac job as follows: 120 bbls YF140 pre-pad at 8300 psi, 162 bbls YF140 w/ .8 ppg 100 mesh sand g go00 psi, 168 bbls YF140 pad at 8300 psi, lgl bbls YF140 2 ppg stage at 8250 psi, 215 bbls YF140 3 ppg stage g go00 psi, 237 bbls YF140 4 ppg stage ~ g700 psi, 218 bbls YF140 5 ppg stage ~ 10000 psi, 3g bbls YF140 6 ppg stage ~ 10000 psi. Lost proppant feed to blender. Flushed w/ go bbls WF140. Shut down and monitored pressures. ISIP 3150 psi. All 20/40 carbolite proppant tagged w/ gold lg8 isotope. SIDPP stabilized at 2580 psi one hour after S/D close well in. RD D S. Wait on gels in wellbore to break. Treatment volume into the perfs approx. 46400 gal YF140 6000 lbs 100 mesh sand {in pad), and 122,000 lbs 20/40 carbolite, and 3800 gal WF 140 flush. 03/17/91 R/Uslickline and RIH with 1.g" swedge to 7750'. POOH. RIH with 1.75 chisel bailer to 7800'. POOH. R/D slickline. R/U coiled tubing;' RIH with coiled tubing in stages, with trace of sand in returns, to 12,241 (packer depth) 03/18/91 RIH with coiled tubing. Tagged sand at 12,415'. Pulled coiled tubing into DP at 12,241'. Displaced KCL with 13.2 ppg completion fluid. POOH with CTU and R/D same. Unseated packer and circ and cond fluid. POOH L/D frac string. Circ to balance fl uid. 03/19/91 Circulated. POOH laying down frac string and BHA. Set RTTS at 660'. Test BOP' s. 03/20/91 Finished testing BOP's. Retrieved RTTS. R/U and run packer assembly. Set at 11,170'. Circulated and conditioned mud. POOH. 03/21/91 RIH w/seal assy, tubing tail and packer #2 Set packer at 10,520'. CBU. POOH. Change top rams to 4-1/2". Test to 1500 p~i. JUL 2 5 199l Alaska 0il & Gas Cons. Commission Anchorage SHP Well H-28 Daily Summary of Well Operations Frac/Stimulation Page 4 03/22/g1 ,, R/U run 4-1/2" AB modified buttress tubing. Rabbit each joint and test each connection to 5000 psi. Run SCSSV and test control line to 6000 psi. Fluid U-Tubing up tbg. Shut-in and monitor pressures. 03/23/91 Monitor casing tubing/casing pressures and repair super choke. C & C mud. Finish running and landing 4-1/2" AB MOD buttruss tubing. Test annulus to 1500 psi. RIH w/3.70" gauge to 12,340' WLM with slickline. N/D BOPE. N/U tree. 03/24/91 N/U tree. Test to 5000 psi. R/U slickline. Attempt to shift XD sleeve at 10,467' w/o success due to 13.4 ppg fluid. POOH. R/U coiled tubing. Test lines to 5000 psi. RIH with CT to 14,600'. Displace 13.4 ppg w/8.4 ppg 2~ KCL from 4-1/2" tubing. 03/25/91 Displaced 13.4 ppg mud w/8.4 ppg KCL water from TBG. Shift sleeve open at 10,467'. Displaced 13.4 ppg mud from annulus w/8.4 ppg kcl maintaining a constant bottom hole pressure. Closed sleeve and test. RIH with coiled TBG and developed lubricator leak. POOH. Repairing leak. 03/26/91 Circ and wash 12,349'-12,475' with coiled tubing. Shut in and monitor well. Pressure increased to 2400 psi. R/U to take returns to production. RIH and wash to 12,630'. Pump sweep followed by 2~ KCL. 03/27/91 POOH with coiled tubing due to shipping pumps and test separator problems. Shut in and monitor well while waiting on repairs. Flow test well for 7 hours. Recovered 595 bbl of fluid. Rate at report time 1939 BFPD; FTP 2150 psi, 14/64" choke, 40~ WC. 03/28/91 Flowed Well M-28 to test separator for 24 hours. FTP-2400 psi. Fluid rate 1400-1600 BPD. 12/64" choke. R/D coiled tubing and skidded rig to Well M-2g while flowing well. 03/29/91 SI M-28 at 0820 hrs 3/28/91 for PBU and rig skid. Returned well to production at 2130 hrs. Trying to stabilize rate. Last rate 982 BOPD, 0 BWPD, 2392 psi FTP. Release rig to Well M-29, at 1430 hrs. 3/28/91. RECEIVED JUL 2 5 1991 Alaska 0/I & Gas Cons. Commission Anchorage Attachment #2 Comoteteci E;~-MAR-Bt Squeeze Per~s I~6EO'-6E3' MARATHON DIL COMPANY TRADING BAY UNIT 'STEELHEAD PLATFORM WELL M-88 COmOl. et:ton ~'~rtng: (KB = 74.5' ~'r'om Tub;rig He(id Top Flange) 4.5' FMC TC-IA-EN Tbg Hngr', Butt Top & 461' CAHCr] TRDP-4A SCS-~V (3.813' 0'-10,568' 4.5', t8.61f, L-BO AB Mod Butt Tbg. 990' 86; E67-397#, Drl[-Ou~p 1443' 16', 7Sit, K-SS gTC 4590' 13-3/8', 61/681f, K-SS, BTC 0-497' t0-3/4°, 51/55.5#, N-BO gu~:'c 497'-11,399' 9-5/8', 47#, N-80 Butt 11193'-18,448' 7; 8911, N-80 3ut~ t;ner- IP,368'-13,000' 5', 18#, FL4S, N-80 ALt GLM's ~r'e :Dc~nie[ GLSO, 4.5' x 1.5° s;depocket: M~ndr-eis (18 '];ot~LL) Deo'~h Vnlve 8380' 1 4034' 5440' 3 6651' 4 7445' S 7911' 6 8370' 7 88°;=' 8 9889' 9 9619' 10 lOOtO' 11 10401' 10,468' .Type Latch Dummy RK Otis 'XD' Pr'ociucl:lon SLeeve (3.813° X Pr'oFf[e). Port -- -- -- Pnoduc'bon Poc;~r' Assq. mb[y, 10,584' B~kep DB Pkn size 194-47 w/ 14' SBE 10,543' H~[[ou~ Ex~. 10,590' Otis 'X' L~nd;ng NippLe (3.813' Pkg Bore). 11,173' B~ken Loc~op Se~[ Assembly G-ZONE Top oF G-I ~ 10,G38' Bo-I: oF' G-6 e I1,1~6' lsolatlon Packer As~q~mioly, 11,175' B~kep Node[ :DB P~cker' size 194-47. w/ 4' 11,183' Nil[out Ext. 11,E30' ri'els 'X' L~ndlng Nipple (3.813' Pro{ire). 11,868' V/L Re-entery Guicle VEST FORELAND TOPBot WF-6VF-O e 11,790'e 18,310'Dt.L.E jVE , 18,360' Ot~; 'XN' N~pp[e (3.813' , i'Noa 11369' TIV 3' LG-6 Tie-B~ck h E Hui~sh mJssJ0n BASAL ~/I:'~TFOR£LAND P~RFORATION~ Inter'vat F~ ~;PF Phas;ng 12,675'-12,748' 73 8 '. 90' 18,748'-18,808' 60 4 90' IP,810'-18,900' 90 4 90' Average ~ev~t;on = 13.0' Top oF S~nd Plug 8 1~767' r-Line (3/15/91) T~ fit (~TRE~SFRAC Tool) E 1~880' (10/31/90). J~ '" . · .. . ~. .. . ..........'; ,./: ,,., . ~.'.; ~'. .... . . ..... , .;..~. '.~. .~,~.',., ' .., ~ ~ ...... ,*.. PBTD 8 1~958' TD e ~3,000' '""" ,.....'...*.( '":'* ' D~ t~ 6/90 & 10/90 10/90 10190 ' ' (" STATE OF ALASKA ( M0C 91-0 ~3/" ALASKA OIL AND GAS CONSERVATION COMMISSION '~ APPLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Operation shutdown __ Re-enter suspended well __ Evaluate Alter casing __ Repair well __ Plugging __ Time extensIon __ Stimulate__ PO ten Change approved program __ Pull tubing __ Variance __ Perforate Z.._ Other _Z_ 2. Name of Operator . 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon 0il Co - Sub 0peratt)r) Development__X 152' KB above MSL feet Exploratory __ Stratigraphic __ 2. U nit,or PrqDerty 3'Addrm~S.~). BOX 190247 Anchorage, AK 9951!) Service__ )rao~ng uay ~n~c 4. Location of well at surface Leg B-l, Slot 3 Steelhead Platform 8.~el~r~mber 970' FNL, 532' FWL, Sec. 33-gN-13W-SM ,. At top of productive interval 9. Permit number 150' FNL, 2,333' FEL, Sec. 28-9N-13W-SM 90-19 REEE VED 10' APl number At effective depth 50- 733-20414 At total depth 11. Field/PoolMcArthur P,i var 85' FNL~ 2~331' FEL~ Sec. 28-9N-i3W-SM JUL ~ § 1~9) G.-_Z. one/West Foreland , 12. Present well condition summary Total depth: measured 13,000' feet Al~knugslmeaj~i~r8.geoi[ & Gas ,C, ons, C0mmtS~,,~" None true vertical 10,801 ' feet Stressfrac tool Effective depth: measured 12,952 ' feet Junk (measured) 12,880 ' true vertical 10,7 51 m feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1,447' 16" 1,800 sx 1,447' 1,445' Surface 4,590' 13 3/8" 2,900 sx 4,590' 4,031' Intermediate 11,399' 9-5/8" 3,360 sx 11,399' 9,310' Production 1,250' 7" 400 sx 12,448' 10,261' Liner 632' 5" 136 sx 13,000' 10,801 ' Perforation depth', me~%~%dm West Foreland 12,675'.-12,808' MD ' 10,480' - 10,609' TVD ~d?_~, true vertical 12,810' - 12,900' MD ~(-tr~ 10,611' - 10,699' TVD Tubing {size, grade, and measured depth) 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' P k rsan S t p andre r ap.t) Baker FB-1 Pkr Size 85-40 e 12,351' ~er ~ ~1~ §~ze ~j~d./d~ 14' SBE e 10,524'; Baker DB pkr Size 194-47 e 11,175' 13. Attachments I & 2 Description summary of proposal x Detailed operations program ~ BOP sketch'.X_ &3 14. Estimated date for commencing operation 15. Status of well classification as: 7/14/91 16. If proposal was verbally approved Oil 7, Gas ~ Suspended ~ I 91 Lonnie Smith 7/uat-7/'eapproved Name of approver Service , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~a.x.o, S (~,..,..~ Title ge..c~,, ~¢'\o~0 ~,, Date "~-~_ ' FOR COMMISSION USE ONLY ?-5{' ' - Conditions of al~vah(~tify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10~ ~'1~ ~ Original Signed By David W. Johnston Approved Copy, , Returned / Approved bY order .of the Commission ~//~/~ _ Commissioner Date'"'J Form 10-403 Rev06/15188 I '~ ~. SUBMIT IN TRIp [..ICATE Attachment # 1 STEELHEAD WELL M-28 Evaluate BWF Potential Procedure 1. Hold pre-job meeting. RU Otis on pipe rack level. Take SCSSV off platform system and put on hand pump {4500 psi) located near well room door. Install lock open fusible cap on master manumatic. MU tool string w! 3.70" OD swedge {w/fluid by-pass}. PT lubricator to 3500 psi. NOTE: Zero tool string at top of tubing head flange (75' from KB) 2. Continue to flow well to test. Open swab. RIH w/ 3.70" OD swedge to a) tag depth of fill, and b) ensure minimum of 3.70" ID through 5" x 7" liner isolation assembly. POH. 3. LD swedge and PU two electronic memory quartz crystal gauges. Program gauges for flowing gradient survey, followed by 72-hour PBU, followed by a static gradient on way out of hole. Increase sampling rate during initial buildup. RIH with the well flowing and make 15-minute stops as follows: STOP WIRELINE DEPTH TVD I "0" ~ tbg hanger 75' 2 g25' 1000' 3 1959' 2000' 4 4474' 4000' 5 7074' 6000' 6 g686' 8000' 7 10,g48' go00' 8 11,544' gso0' g 12,097' 10,000' 10 12,30g' 10,200' 11 12,518' 10,400' 12 12,621' 10,500' . 0 . Continue. to flow well with gauges at 12,621' WLM for two hours to obtain data on stability of BHFP. Shut well in at wing valve to begin 72-hour PBU. Monitor tubing and casing pressures throughout the buildup. POH, making 15 minute stops at same depths as Step 3. Pressure data to be analyzed prior to proceeding to next step. Hold pre-job meeting. RU E-line unit. Pressure test lubricator to 3500 psi. Ensure that SCSSV is off platform system and on hand pump_(4_5~, psi). Install lock open fusible cap on master manumatic. ~'(j~JV~D J U L 5 tggt Alaska Oil & Gas Cons. Corem[ss'ton Anchorage Procedure ( Evaluate BWF Potential Page 2 go PU & RIH w/ CCL/gamma ray/temperature tool. Log over 5" liner from liner top to PBTD. Repeat log in up pass. Compare gamma ray with prior gamma ray logs for indication of scale deposition in 5" liner. Use temperature log to confirm proposed reperf intervals in Steps 10 and 11. 10. PU & RIH w/ CCL depth control And 3-3/8" hollow carriers loaded w/4 SPF deep penetrating charges w/ gov phasing. Reperforate the Basal West Foreland from 12,720' - 12,740' with the well flowing. Production choke should be open just enough so as not to restrict flowrate. POH. Do not exceed 500 BFPD while guns are in tubing. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN HOLE, NOTIFY LOGISTIC SUPPORT AND ESTABLISH BLACKOUT. RE-ESTABLISH WHEN PULLING GUNS ABOVE 1000'. 11. Repeat Step 12 'for the following BWF intervals: Run #2 (reperf) 12,700' - 12,720' Test well for 12 hours Run #3 {new zone) 12,650' - 12,670' Run #4 (new zone) 12,630' - 12,650' 12. RD E-line and flow test well. 13. Evaluate need to perform drawdown test {via jet pump} on Basal West Foreland. \docs\shp\M28.doc RECEIVED J U L 2 5 199t Alaska 0il & Gas Cons. Comm'~ss'ton Anchorage Wireline Attachment # 2 STEELHEAD PLATFORM Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP ~ ---10 I---I I ," .:": '" MARATHON ----12 RECEIVED JUL 2 Alaska Oil & Gas Cor~s. Ancl~orage OIL' CO...vlrAlXTY "' Attachment # 3 ... Carnal e~ceel 2:~-MAR-gt MARATHON OIL CF1MPANY TRADING BAY UNIT STEELHEAD PLATFORM WELL M-88 ALI me~suremenl:s are RKB 1:o 'top oF equ;pmen"t. Como{qtlon S~celnc]; (Kg = 74.5' ~r'om Tubing HeQct Top FtQnge) 4.5' FHC TC-IA-EN Tbg Hngr, gut~ Top & ]~tm. 461' CAM(l[ TRDP-4A SCSSV (3.813' o ProFile). 0'-L0,568' 4.5; LP.61L L-80 AB Mod But¢ Tb9. 990' ~6; ~67-397#, Dr~-Ou~p 1445' t6; 75#, K-SS OTC 4590' t3-3/8', 6t/681L K-SS, BTC 0-497' 10-3/4°, 51/55.5#, N-BO Bu~t 497'-1L399' 9-5/8'. 47#, N-80 ~u~ 11193'-12.448' 7'~ 291t, N-80 ]~u~l: I;ner' IP,368'-13.000' 5', 18#, FL4S, N-80 liner Squeeze Per~s 10,6~0'-&23' Att Deo~ch 2320' 4034' 5440' 6651' 7445' 7911' 8370' 8802' 9E29' 9619' lOOtO' 1040t' x~46a' GLN's are iOan;e[ GLSD, 4.5' x 15° s;depocket m~ndreis M~lv~ Tyoe L~qh Po?* Size I Dummy RK - 3 - 4 _ 5 _ 6 - 7 _ 8 - 9 _ 10 _ 11 _ IE Dummy RK ntis 'XD' Production SLeeve (3.8L3' 'X ProFile). ~eoduc'lrlon 10,5~,' Baker 10,543' H~[tout Ext. 10,590' 11,173' B~kee Loc~oe Se~[ Asse~eiy G-ZONE Top oF G-I ~ 10,6:32' Bo'l: of' G-6 e 11,t~.6' Isolet-~on Pack~.r- A~embly. 11175' B~kee Node[ ~ Packee size 194-47. IL183' Mil[out Ext. IL~30' Otis 'X' L~ndlng Nipple (3.8t3' ILE68' V/L Re-entery Guide VEST FORELAND Top VF-O ~ 11,790' Bo1: VF-6 ~ 12o310' RECEIVED 1~,33[' ~ker Hode[ FO-! PEr, ~;ze 83-40 ~,360' Offs 'XN' Nipple (3.813' Bore, 3.72~' NoGo). Alaska OJ! & G25 [~0D$, G0mmissi0~ IE, 369' TIW 5' LG-6 Tie-Back Seals w.'~h 1/~. Muteshoe.Ap. cll0rage BASAL VESTFDRELAND PERFDRATION.~- In~erv~l Irt SPit 1:=,675"-t~°748~ 73 8 ". ~0° 6/90 l. 10/90 1E,748'-18,808' 60 4 90' 10/90 lE,810'-lE,900' 90 4 90' 10/90 Average Deviation = 13.0' "- ' . , Top oF S~nd Plug @ 1P~767' £-Lme (3/15/91) · .:,. ". .~.; '.~ · :' ' ' "" '"" · "; '~: ' ':" ',:':iF' "' ' ..... ,".'"';' ~'- · TO . . ....... . ..... : easoo . V~kover .... , ..... · .. 13.000 .. ~, ........ ..... .......,..~._,..-., ..... : ..... ..,., ....,..':'..',.','.¢~..:;.'." '.','"",~..',...~.,.':;,:...':.~;',~"~,.~'.::'~'::~"~' ALASKA OIL AND GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casmg __ Repair well __ Change approved program __ Pull tubmg __ Variance __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Operate)r) o~:j,o~ x 3. Address I Stratigraphic __ P,0, Box 190247 Anchorage, AK 9951~ Service__ 4. b ocationofwellatsudace Leg B-l, Slot 3 Steelhead Platfom 970' FNL, 532' FWL, Sec, 33-9N-13W-SM At top of productive interval 150' FNL, 2,333' FEL, Sec, 28-9N-13W-SM At effective depth At total depth 85' FNL, 2,331' FEL, Sec, 12. Present well condition summary Total depth: measured 13,000 ' true vertical 10,801 m Effective depth: measured 12 952 true vertical 10,751' Casing Length Structural Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension m Stimulate __ Perforate __ Other 6. Datum elevation (DF or KB) 152' KB above MSL 28-gN- 13W-SM feet 7. Unit or Property name Trading Bay Unit 8. Well number M-28 9, Permit number 90-19 10. APl number 5o- 733-20414 11. Field/PoOIMcArthur Ri ver G-Zone/West Forel and feet Plugs (measured) None feet Stressfrac tool feet Junk (measured) feet 12,880' Size Cemented Measured depth True vertical depth Conductor 1,447' 16" 1,800 sx 1,447' 1,445' Surface 4,590' 13 3/8" 2,900 sx 4,590' 4,031' Intermediate 11,399' 9-5/8" 3,360 sx 11,399' 9,310' Production 1,250' 7" 400 sx 12,448' 10,261' Liner 632' 5" 136 sx 13,000' 10,801' Perforation depth: me~ured. uasal West Foreland 12,675' - 12,808' MD .~'.'-,':,.,.-.~.-.....,,.,. .;'~ (~ ' ,i ";" '¢ '"' "' ;'~ true vertical 10,480' - 10,609' TVD 12,810' - 12,900' MD 10,611' - 10,699' TVD Tubing (size, grade, and measured depth) ~,.~. ~ .. ~. . 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' m P~kQrs ancL,~.SSV (tyD~and..r0easur_e..d.degt..h) . ..] ' "~4.[/BJ~l]0)raoa' ' uaKer.uu... .Er ~ze 1~-~/ w/ z~' SBE g 10,524'; Baker DB pkr Size 194-47"~ 11,175' 13, Attachments #1, 2, & 3 Description summary of proposal X__ 14. Estimated date for commencing operation , 6/10/9[ 16. If proposal was verbally approved Lonn~e Smith Name of approver 6/10/91 Date approved Detailed operations program __ BOP sketch X__ 15. Status of well classification as: Oil~X Gas~ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ..~'~ .....~./.¢~.~..4 ,¢,- /.-~-~ Title (...,--. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date ~,,.//'~/ I Approval No.~/--/~,..~ Plug integrity __ BOP Test __ Location clearance __ ~ ~., Mechanical Integrity Test __ Subsequent form required 10-....,z/ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH GemT-n'~Oner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ¢ Attachment #1 (' STEELHEAD WELL M-28 COILED TUBING CLEANOUT PROCEDURE 1. RU CTU. Pressure test surface lines, lubricator and coil to 5000 psi. Bleed coiled tubing pressure to 1000 psi. Take SCSSV off platform system and put on hand pump {5000 psi). Install fusible cap on master on manumatic valve. 2. Choke well back to 1000 psi FTP using tree's adjustable choke. Open swab valve and RIH w/ CT to 12,000'. Begin pumping 2% KC1 w/ friction reducer at highest rate possible with 5000 psi. Rill to 12,600'. 3. Pump sweeps and wash fill. The amount of packpressure to be held will be adjusted as conditions dictate. 4. Stop pumping KC1. Allow well to flow until WC's return to 40% range. 5. Shut well in for 3 hours. Pump on CT to keep pressure differential less than 500 psi. After 3 hours, RIH and tag depth of fill. 6. POH. Flow test well to determine results. (Expected duration of test is 4 to 6 hours.) If OK, RD CTU. \docs\shp\M28.doc I" Atta'chmeni~ #2 ~' Compte'ted 2~-MAR-91 MARATHDN DIL CDMPANY TRADING BAY UNIT STEELHEAD PLATFDRM ~ELL M-2B All measuremen.ts are RKI~ .to .top o? equipmen.t. I;:gmole.t~on S.trin§: (KI~ : 74.5' ~rom Tubing Head Top Flange) 4.5' FMC TC-IA-EN Tbg Hngr, But~c Top & ;Btm. 461' CAMCO TRI)P-4A SCSSV (3.813' D ProfRe). 0'-100568' 4.5', 1E.6#, L-80 AB Mod But* Tb9. 990' ::'6; 267-397ff, Drmt-Qulp 1445' IG~ 75~, K-55 OTC 4590' 13-3/B', 61/6B~, K-550 OTC 0-497~ 10-3/4', 51/55.54S, N-BO Bu.t.t 497'-11,399' 9-5/85 47#, N-80 l~u.tt 11193'-1;3,448' 7'~ :~9#, N-80 ]~u.tt I:nep 1E,368'-13,000' 55 18#, FL4S, N-BO liner ALL 2320' 4034' 5440' 6651' 7445' 7911' 8370' 880P' 98P9' 9619' I0010' 10401' OLM's are Danle[ GLSrl, 4.5' x 1.5' sldepocke.t mandrels (12 .to*aD Valve Tyoe La,ch. Port Size 1 Dummy RK - 8 - 3 - 4 - 5 - 6 - 7 - 8 - 9 - 10 - 11 - 1~ Dummy RK - 100469' ntis 'XD' Produc.t~on Sleeve (3.813' X Profile). Squeeze Per?s 10,620'-623' Produci:lon Pc~cker Assembly. 10,524' Baker DB Pkr slze 194-47 w/ 14' SBE 10,543' Nmilou'l: Ex.t. 10,590' O.tls 'X' Land:rig Nipple (3.813' Pkg Bore). 11,173' Baker Loca.tor Seal Assembly G-ZONE Top of G-1 e 10,632' Bo't o? G-6 e IL186' IsOt~.tlon Packer AssembLy, 11,175' It,lB3' 11230' 11,~6B' B0~ker Mode[ D:B Packer size 194-47. w/ 4' SBE Millout Ext. O-tls 'X' Landing Nipple (3.813' Pro,lie). V/L Re-en.tepy Gu:de VEST FORELAND Top VF-O @ 11,790' Bo't VF-6 ~ 1~310' [sol~lon P~cker Assembly, 1:~,351' Baker Mode[ FB-1 PEp, Size 85-40 IP~360' ntis 'XN' N~pp[e (3.813· Bore, 3.7~5' MOOD). 12,369' TIW 5' LG-6 Tie-Back Seals wi'th 1/2 Muleshoe. DASAL ~ESTFDRELAND PERFORATIONS ~ Ft iPF phasing 1:~,675'-18,748' '73 B 90° 12,74B'-IP.,BOB' 60 4 90' 1~,810'-1~,900' 90 4 90' '~vep~ge 9~v;ot~on = 13.0' Top o; ~nd Plug ~ 18,767' E-Line (3/15/91) TDF ~1 (;TRE;~FR~C Toot) ~ 18,880' (10/31/90), 6/90 & 10/90. · 10/90 10/90 .. PBTD e 1~95~' TO e 1~000' Revision Oote~ 5/6/91 Revised By, PMO/evo Reason, -Vopkover Previous Revision, Tagged TOt Attachment #3 STIC_.ZLHEAD 'P LATF RM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Ram8 5000 psi WP 0 --- HYDRAULIC RAMS .:4'1Z16". 5000 psi CHISTMAS TREE POSITIVE CHOKE · . /,"""/': ~,, . ~' '""~' .;'.'...i," 'C, ~,"'~ ,.":. !; ~:' ,""./. ' ':% ~" r,.; ,r,. I ,k' ,(. /, ~"" ~,'~r.,'~" ",.: .,.. ,. ~'" "',,¢.'¢ ..,',' ~ ..,.,. ~ ¢, %".:.;,.:'.';'~,.';',, ,n.,, ". 4 ¢.::~' .~' ,.~'o ~ ,, 2' 5000 psi lj ' '2' 3000 ps1 · · · 3 3/8'-c~s,.~ , · TO: THRU: FROM: MEMORAN'OUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~' DATE: March 28, 1991 Commissioner ' v FILE NO: LG328-1 Louis R. Grimaldi.~g~ Petroleum Inspector TELEPHONE NO: SUBJECT: RIG/BOPE Inspection ~~ ~'~ .arathon N-~8 'q/.)'l q Steelheafl Platform Cook Inlet/ Trading Bay Workover Sunday 3/17191: I travelled from the Dolly Varden platform to the Steelhead platform to witness a blowout preventer test but due to a coil tubing job that was taking longer than anticipated, Lance Lamens asked if they could do the test on the 18th as their last BOP test was on the 11the. The coil tubing unit was presently cleaning frac sand and would not be finished for approximately eight hours. I agreed. Lance Lamens, Marathon drilling foreman, accompanied me on a RIG/BOPE inspection. I found the rig and associated equipment to be of impressive design and having much evidence of frequent and regular maintenance. There was one area that I found in non-compliance. This was the kill line. There were a minimum of three 90 degree turns not targeted and one 45 degree turn that I observed. The line also exited the substructure and ran up the outside to...the rig floor where it reentered and was connected to the standpipe. 'This outer portion of kill line was heavily insulated and therefore; I could not tell if all turns were 90 degrees and targeted. I discussed this with the drilling foreman .who will, when the weather warms up,..remove the insulation and inspect the hidden line. The other turns have had a work request turned in and Marathon will contact the Commission laying out repairs and approximate time to finish. It should be noted that although the kill line outside of the rig was hidden by view, the configuration of the insulation indicated targeted turns. The rest of the equipment I observed, was operating satisfactorily. In summary: The Steelhead's. drilling rig, with the exception of the kill line, was found to be in a good operating condition. Attachment. 02-00lA (Rev. 6/89) 20/11AMEMO1.PM3 ALASKA 01L AND GAS CONSERVAT I ON COMM i SS I 0,~ BOPE Walk-Thru Inspection Report OPERATION: Drlg. ~.~vr /~ UlC Operator/~}/'~ J~ h-/"~f O Permit # Locat J on: Sec T R M Drlg contr /~0~ L_ Rig# Location (gen'l) b/~/~-/ ~~ Well sign I N COMPL I ANC~ yes n_~o n/a A. DIVERTER 1. () () ( 2.() () ( 3. () () ( q.() () ( S.() () ( 6.() () ( 7.() () ( ) line sz & length ) line conn& anchored ) bifurcated & dwn wind ) 90° targeted turns ) vlvs= auto & simultaneous ) annular pack-off ) condition B. BOP STACK 1. (LL~ ( ) ( ) wellhead flg wkg press 2. (~ ( ) ( ) stack wkg press 3. ,~ ( ) ( ) annular preventer .~.~.~::~. ( ) ( ) pipe rams 5. {P~ ( ) ( ) blind rams 6. ~ ( ) ( ) stack anchored 7. C/~) ( ) ( ) chke/kt11 line sz 8. ( ) ~(~ ( ) 90° turns~ (chke &~ 9...~) ( ) ( ) HC'-R vlvs (chke 10. j~ ( ) ( ) manual v1vs (chke & kill) 11.'[;~) ( ) ( ) connections (flgd, whd, clmpd) 12. (~ ( ) ( ) dr1 spool 13. ~:~ ( ) ( ) flow nipple 1~. ~1~), ( ) ( ) flow monitor 15.{t/~ ( ) ( ) control lines fire protected C. CLOSING UNITS 1. (~ ( ) .( ) wkg press 2.(~/~ ( ) ( ) fluid level Representative Wel 1 name ~ Representative IN COMPLIANCE yes n_~o n/a 11. (~ ( ) ( ) firewall 12.~) ( ) ( ) nitrogen power source (back-up) 13. ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM 1. 0~) ( ) ( ) pit level floats installed 2. ~) ( ) ( ) flow rate sensors $. ~ ( ) ( ) mud gas separator ~. (X~ ( ) ( ) degasser 5. {~/ ( ) ( ) separator bypass 6.(~ ( ) ( ) gas sensor 7. (~,~ ( ) ( ) chke In corm 8.~ ( ) ( ) trip tank .bO () 2. ('~ () 3.~O () ~.~x/) () 5. j () 6.() () 7.~ () 8. (') 3. {)C) ( ) (), oprtg press 1. (~,) ( ) q. (:X/) ( ) ( ) press gauges 2. 5. (~ ( ) ( ) sufficient vlvs 3. 6.F! ( ) ( ) regulator bypass. ~. (~) 7. ~/~ ( ) ( ) Q-way vlvs (actuators) 5. (~) 8.(.~ ( ) ( ) blind handle cover 6. 9. ('~ ( ) ( ) driller control panel 7. 10. (~) ( ) ( ) remote control panel RECORDS E. RIG FLOOR kelly cocks (upper,lower, IBOP) floor vlvs (dart vlvs ball vlv) kelly & floor vlv wrenches driller's console (flow monttor~ flow rate indicator, pJ~ level indicatorss gauges) kill sheet up-to-date gas ~etection monitors (HS & methane) hydr chke panel chke manifold 8.() 9.{~ F. MISC EQUIPMENT ( ) flare line ( ) ( ) vent line ( ) ( ) 90° turns targeted ( ) ( ) (dwn strm choke lns) ( ) ( ) reserve pit tankage ( ) ( ) personnel protective equip avail ( ) ( ) all drl site suprvs trained _for procedures ( ) (/~ HZs probes ( ) ( ) rig housekeeping Date of last BOP test:. Date of last BOP inspection: ~ Resulting failures: /A~ 0 ~J ~ Failures not corrected & why: Date corrections will be completed: BOP test & results properly entered on daily record?.~ Kill sheet current? ..~..~.~ Inspector _~/~~/'~~~, ~' '~ C.0013 (rev 02/25/91) , r f ~ / APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandof~ __ Suspend __ Operation shutdown ___ Re-enter suspended well __, ---' Alter casmg ~ Repair well __ Plugging __ Time extension ~ Stimulate .~L Change approved program __ Pull tubing __ Variance __ Perforate 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL ~Marathon Oi 1 Co - Sub Ooerat~r) Development .~X Exploratory__ 152' KB above MSL feet 3. Address Stratigraphic __ 7. Unit or Property name P.O. Box 190247 Anchorage, AK 9951!) Service__ Trading Bay Unit 4. Location of well at surface Leg B-I, Slot 3 Steelhead Platform 8. Wellnumber M-28 970' FNL, 532' FWL Sec. 33-gN-13W-SM .. . At top of productive interval ' 9. Permit number 150' FNL, 2,333' FEL, Sec. 28-9N-13W-SM qo-lq At effective depth 10. APl number 50- 733-20414 Attotal depth 11. Field/PoolMcArthur Ri ver 85' FNL, 2,331' FEL, Sec. 28-9N-13W-SM G-Zone/~st Foreland 12. Present well conditionsummary. Total depth: measured 13,000 ' feet Plugs (measured) i~,..} '"""~'~i"' 'x~{.,i~,'*',,.~' .'m~,"' ~mmm'~ true vertical feet "~'~" ~ .... . ~ None 10,801' ~.x.~"' .,,.:~ .>-~' Effective depth: measured feet Junk(measured) Stressfrac tool true vertical 12,952' feet 12,880' 10,751' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,447' 16" 1,800 sx 1,447' 1,445' 4,590' 13 3/8" 2,900 sx 4,590' 4,031' Intermediate 11,399' 9-5/8" 3,360 sx 11,399' 9,310' Production 1,250' 7" 400 sx 12,448' 10,261' Liner 632' 5" 136 sX 13,000' 10,801 ' Perforation depth: measured Basal We'st Foreland 12,675'- 12,808' MD true vertical 10,480' - 10,609' TVD 12,810' - 12,900' MD Tubing (size. grade, and measured depth) 10,611' - 10,699' TVD · 4-1/2" 12.6# L-80 AB Mod Butt tbg to 10,568' ~,daskaOll&l~.asl~ous'~s~' Packers and SSSV (type and measured depth) ' ,'i~ ~_'O~Of~[~. ' Baker SB-3A Pkr w/ 12' SBE & [nteqral.S/A ~ 10,521': Baker DB Dkr Size 194-47 ~ 1].,].70 .......... 13. Attachments # 1 ~ 2 ~ Description summary of proposal ~ Detailed operations program 3, 4, and 5 14. Estimated date for commencing operation 15. Status of well classification as: 2/].9/9]. 16. If proposal was verbally approved Oil _~ Gas Name of approver Date approved Service "17'Signedl hereby c0fy(~the f°reg°ing istrue and c°rrect t°the ~est °f mY kn°wledge'~, ("'~ \,- Title ~-, ' ~)~.Z~'", e.~, ~,~. ~'"~.~c.. Date FOR COMMISSION USE'ONLY Conditions of al~ ;rova~otify Commission so representative may witness I Approval No. Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~vo~ _. Approve~ Origlnal Slgned By ReturneO W. Johnston David ,,Appr°ved by order of the Commission'-~'""-'-'-- Commissioner Date Form 10-403 Rev 06115188 SUBMIT IN TRIPLICATE Attachment ~1 M-28 FRACTURE STIMULATION PROCEDURE 1. Skid rig over M-28. RU slickline. Fish STRESSFRAC tool at 12,860' RU CT. RIH To PBTD. Circulate kill weight brine. Monitor well. POH and ~D CT. RD slickline. RU E-line and shoot circulating holes in tubing above packer. RD E-line. Circulate kill weight brine to backside. 2. ND tree. NU BOPE. 3. Pull seal assembly free. Circulate and monitor. POH and LD tubing. 4. Retrieve production packer from 10,521'. 5. Retrieve isolation packer assembly from 110142'. 6. Fish STRESSFRAC tool at 12,881'. 7. RIH w/ frac string {5" x 3-1/2" DP}. Spot sand to 12,765'. POH. 8. RIH w/ 7" treating packer. g. RU fracture pumping equipment for 20 BPM at 12000 psi. I0. Perform step rate and data frac. 11. Perform fracture stimulation. 12. POH. RIH and clean out to PBTD. POH. 13. Run tracer log. 14. Run completion. ND BOPE and NU tree. RU CTU. RIH to PBTO and displace kill weight brine. RD CTU. Release rig. 15. Unload and test well. \docs\shp\m28.doc Fillup Line _ Attachment #2 F Flow Line Hydril 18-3/4° 5000 psi Type GK Annular I~111 Line 16-3/4' 10,000 psi Doublegate Check Valve Gate Valve Gate Valve Pipe Rams Blind Rams Gate Valve HGR Valve Choke Line Pipe Rams 16-8/4° 10,000 Psi Singlegate 16-314° 5000 psi Riser 8TEELHEAD PLATFORM Preventer Schematic Ball Valve Wellhead . STEELHEAD PLATFORM CHOKE MANIFOLD TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS ! CHOKE LINE -' SWACO ALL VALVES IN FLOW PATH ~RE ;3-1/16' 5000 PSI CAMERON GATE TYPE SECTION AA Attachment #4 (' Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP I---! I ---12 Attachment #5 11/90 MARATHDN OIL CDMPANY TRADING BAY UNIT ST£ELHEAD PLATFDRM ~/ELL M-2E) ALI ~easur-e~en"ts: o,r`e RKR to 'top oF equ;p~en"t. Comote t:lon ~:~mng: 4.5' FHC TC-IA-E:N Tbg Hngr, gutt Top & ]~te. 445° CAHCQ TRDP-4A SCSSV C3.813· O ProFile). O'-IO, SSB' 4.5; 1~.S#0 L-BO AB Hod But't Tbg. 990' ES; ~67=397#, ]}rfl-QuJp 1445' Ia; 75#, K-55 gTC 4590' J3-3/81 &1/S8#, K-55, BTC 0-497' 10-3/41 51/55.5#, N-80 Butt 497'-11399' 9-5/8; 47#, N-80 Suit 11193'-12,448' 7; :=9#, N-80 3utt Liner` IA3S8'-13,000' 5; 18#, FL4So N-80 hner. Att GLH's ar`e Darnel GLSD, 4.5° x 1.5' sidepocket mandrels Deoth :=309' 4013' 5494' 3 6687' 4 75:=0' 5 7956' 8386' 7 8812' 8 9:=41' 9 96;'3' 10 10,013' 10,404' 10,463' Type L~ch Du~y RK Dummy RK a.l:lS 'xo' Pr`odu¢.~lon SLeeve (3.813' X ProFile). Production Packer. Assembt¥~ . 10,521' Baker' SB-3A Pkr. w/l~=' 'SBE & 'ln*begr.al, S/A. 10,535' M~ttout Ext. 10,554' ntis 'X' Landing Nipple ¢3.813° Pkg Bor.e). 10,566' Baker Hydrotmp Sub. 10,568' VL Re-entr`y g~de. G-ZONE Top oF G-I ~ 10,632' BDt o~ 6-6 Isolation Packer. 11,[49' g=kee Hodek Dg Packer ssze 194-47. 11~53' HILLout Ext. IC~70' O~ls 'X' Landing Nipple (3.813' Profile). IL~88' TIV 7' L~-6 Se=k Nipple. NOTE. Hlnl~uA ID caliper Log run Nov 3, 1990 indicates 3.70' restrictions ~ 11~60' and 1~170' ~ublno ne=su~e~en~. VEST FnRELAI~D Top VF-O @ 11,790' Bo*t VF-6 @ 1~310' Packer' Assembly~ Bakee Hodet IrR-t 'Pke, S;ze 8:5-40 ........... ; ntis 'XN' N3pple (:3.813' ~ore, 3.7:=5' NoGo). TIV 5' LG-& Tie-Back Seals wlth 1/;= Hu[eshoe. BASAL VESTIrDRELAND PERFORATIONS Interval Irt Spit ~ 12,675'-12,74B' 73 B 90' lE,74B'-t2,808' 60 4 90' 1E,810'-12,900' 90 4 90' Average Deviation = 13~' Tar #2 (STRESSIrRAC Toot) e 12,862' (11/22/90). Tnt #! (STRlrSSFRAC Tool,) @ lP,880' (I0/3~/90). Do 'be 6/90 & 10/90 · 10/90 !0/90 FIU tagged e 17.,900' ¢10/28/90). TD 8 13,000' ,' ' Rev;s;on Date, 11/26/90 Revised Bye' PMD/neF Reason, Tagged TaF Peer=us Revis=n..Tagged TIllr' .,."',~..:.:' :~.';.~!:i'~,~,:.. ,;..~'"~" .......... , ...... .,~,:.j..:.: ...... '..,. lO,&~o'-6e3' Proposed Completion SCSSC @ ± 500' Production Packer Assembly Ca -+ 10,50 Isolation Packer Assembly, Ca _+ 11,10( , , Isolation Packer ,Assembly Ca _+ 12,351 Perforations Same as Previous Completion , ./~_ STATE Of ALASKA ~ "" .. ALASK .,L AND GAS CONSERVATION '.,,,iMISSlON ' ' ' '" WELL COMPLETION OR RECOMPLETION REPORT AND LOG' 1. Status of Well Classification of Service Well OIL ~[] GAS [] SUSPENDED [] ABANDONED I-I SERVICE [] 2. Name of Operator LOC. AT1ONSi- 7. Permit Number UNOCAL (Marathon Oil Co. Sub-operator) W~F:~. ! 90-19 . 3. Address ,~ur~ ~ { 8. APl Number P. O. Box 190247 Anchorage, AK 99519 :~'~L~-~.' 50- 733-20414 4. Locat~o, ofwe, atsurface Leg 81, slot 3 Steelhead Platfo~- .~ 9. Unit or Lease Name 970' FNL, 532' FWL, Sec. 33 9N-13W-SM ~:~.-.,,'~ Trading Bay Unit At Top Producing Interval )'~'. 1'0. Well Number 150' FNL, 2,333' FEL, Sec. 28 9N-13W-SM - M-28 At Total Depth ~ 11. Field and Pool 85' FNL, 2,331' FEL, Sec. 28 9N-13W-SM J i McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G 0i 1 Zone/West 152' KB above MSL ADL 18730/ADL 17594 Foreland 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/23/90 5/26/90 6/18/90I 187' feetMSLI 1 17. Total Depth {MD+TVD)13,000,&10,801' 18. Plug Back Depth(MD+TVD)12,952,&10,751' YES I~m( 19. Directional SurveYNoD I20' Depth where sssV set445mfeet MDI21' Thickness Of PermafrOstN/A 22. Type Electric or Other Logs Run DIFL/BHC/SP/GR/PCM/CHT; CHT/PCM/DEN/NEU/GR; CHT/PCM/GR/DEN; CBL; CAL/CDL/CNL/CHT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 75# K-55 "0' 1,447' 20" 1800 sx Class .3-3/8" 61/68# K-55 0' 4.590' 17.5" 2900 sx Class G cmt NA 9-5/8" 47# N-ED/S-g5 0' 11.399' 12.25" 3360 sx Class G cmt 650.000# ...7" 29# N-80 ]1,193' 12,448' 8.5" ~00 sx Class G cmt 'N/A 5" 18# N-80 ]2,368' 13,000' 6" [36 sx C]a$$ G cmt N'/A · 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) Basal WF 4.5 10.532' 10_ ~71 ' · · 12,675' - 12,808' MD 10,480' - 10,609' TV[ 12,810' - 12;900' MD 10,611'_- 10,699' TV£26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. All perforations were 4 SPF 0° phasing DEPTH INTERVAL{MD)AMOUNT & KIND OF MATERIAL USED . . , , · 27., PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/22/90 IFlowing 0il Well ' Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 11/05/90 24 TESTPERIOD ~ 224 110 0 _NAI 491 Flow Tubing CaSing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 150 100 24-HOUR RATE ~ 224 110 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. ,. . RE,([EIVED None O~_C ~ 0 Alask & cons. DEC 1 0 1990 Anchorage Alaska Oil & Gas Cons. Comm[Ss[o~t' ;Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ~ i GEOLOGIC MARKERS FORMATION TESTS t' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G- 1 10,632' 8,692 ' HR-! 11,203' 9,147' I.IF- 0 11,790' 9,752' 31. LIST OF ATTACHMENTS Attach #1, Summary of Operations; Attach.#2, Current t'!ellbore Diagram; Attach_.~_3~_ Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing 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 ., Attachment #1 Summary of Daily Well Operations Steelhead Platform Well M-28 03./22/90 Mobilizing rig to )fell M-28. Skid rig to slot #3 of Leg B-1. Hookup service lines and power. Tighten rig clamps. Level derrick. NU diverter risers. Begin mixing spud mud. 0)12319o Fin NU diverter and test to 500 psi. RIH w/ bit and UR and drill cmt 437'-450'. 03/24/90 CO csg from 450'-613' w/ bit and 22" UR. POOH. LD UR and RIH w/ bit. CO csg 'to 974'. Displace hole w/ mud. POOH. RIH w/ motor and kickoff assembly. 03/25/9o Drld c~, float shoe and 8' of new formati°n. Oriented. Directionally drld and surveyed 998'-.1465'. CBU. ST. CBU and POOH. RIH w/ 20" UR. UR 626'-630'. 03/26/90 UI~ 830'-1461' w/ bit ~ 1465'. Pumped sweep. ST to shoe. Pumped sweep and circ out. IN)OH to run 16" csg. 03/27/90 Fin POOH. RU and run 30 its 16", K-55, 75# BTC csg. Circ and cond mud prior to cementing. Cementing unit starter shaft twisted off. Waiting on replacement starter. 03/28/90 Cemented 16' csg w/ 1800' sx. Flush riser. POOH w/ stab-in tool. Wait 'on cmt. "LO landing jts and ND diverter. ' ' 16" Casing Detail KB to top of casing 61' FIqC Mandrel Hanger 29 its 16', 75# BTC K-55 Float collar, BTC I Jt 16', 75~ BTC K-55 Float shoe, BTC FROM TO 0.00' 80.18' 80.18' 83.01' 83.01' 1398.44' 1398.44' 1400.57' 1400.57' 1444.69' 1444.6g' 1446.6g' 03/29/90 NU and test casinghead. NU BOPE. Test to 250/3000 psi. RIH w/ bit. SHP Well M-28/ t' (' ' Daily Summary of Well Operations .. Page 2 03/30/90 RIH w/ 14-3/4' bit. Test csg to 1850 psi. Drill cmt and f]oat equip, plus 7' new hole. lest shoe to 14.0 ppg EMW. POOH. RIH w/ 12-1/4" bit on steerable systea. Bri]] 1472'-1886'. 03/31/90 Drld w/motor 11~t36'-2592'. POOH. BHA. LD motor. Service rig. RIH. Dril] to 2618'. Drld 2618'-3392". CBU. Drld to 3736'. o4/o /m CBU. ST to 2.573'. Hole swabbing. RIH. CBU. ST to 2397'. Drlg 3735'-4018'. CBU. IN)OH.. BHA. PU mud motor. RIH. Drill to 4290'. o4,/o / o Drld 4290'-4610'. CBU. ST to 3630' No fill. CBU. POOH. RU E-line and run DXFL/GR 4610'-1446' and GR 1446'-surface. RD E-line. RIH w/ 17-1/2" UR and UR 13~6 '-1485"'. 04/04/90 UR 12-1[4" hole to 17-1/2" from 1485'-2564'. o, /os/ o UR 12-1/4' hole to 17-1/2" from 2564'-2750'. CBU. POOH. Change cutter arms. Rllt. #as# 230;0'-2750'. UR 12-1/4" hole to 17-!/.2" from 2750'-3344'. o /o6/9o UR to 17-1/2' 3344'-3850' CBU POOH. Test BOPE to 250/3000 psi. Change top -drive oil. PU new 17-1/2;' UR a~d RIH. , RIH to 3280'. Wash and ream 3280'-3850'. Run check survey. UR to 17-1/2" 3850'-4395'. CBU. POOH. Changed cutter ams. RIH to 4395'. o4/oe/ o POOH to 4195". Wash/ream to 4395'. UR not making hole. CBU. POOH. }{IH w/ 12-1/4" bit to 4010'. (No problems, no fill.) CBU and POOH. RIH w/ new UR. {JR 12-1/4' hole to 17-1/2" 4395'-4527'. RECEIVEO DEC 1 0 1990 Alaska Oil & Gas Cons. Gommiss'~o~ Anchorage SHP Nell M-28 ( .... Daily Summary of Well Operations Page 3 04/09/90 UR bole to 17-1/2" 4527'-4610'. CBU. ST to shoe. CBU. POOH. Pull wear ring and set test plug. Change top rams to 13-3/8" and test doors to 2000 psi. Run 28 its of 68~/ft , K-55, 13-3/8" csg filling each it. Jt #28 would not fill. Begin mixing LCM pill. Shoe ~ 1126'. o4/: o/9o P~mped LOI pill out of csg w! no returns. Ran 13-3/8" csg to 16" shoe and monitor well. Taking g BPH on annulus. RIH w/ csg. Circ w/ mud w/ 40~ down to O~ returns. Build surface volume. RU to cmt csg. Cemented surface csg w/ 2900 sx w/ partial returns. Displaced w/ mud and bumped plug w/ 1500 psi. LD landing its and set and test packoff in casinghead. Test BOPE 250/3000 psi. Ran temp log. Est TOC ~ 1940'. PU BHA. 13-3/8" Casing Detail I~B El.evation i~MC Hanger 58 Jts 13-3/8", 61#, BTC, K-55 I Pup 13-3/8", 68#, BTC, K-55 ~J8 Jts 13-3/8"0 68#, K-55 F1 oat col 1 ar 2 Jts 13-3/8", 68#, K-55 F1 oat shoe FROM TO 0.00' 78.63' 78.63' 81.43' 81.43' 2562.67' 2562.67' 2580.58' 2580.58' 4507.06' 4507.06' 4508.67' 4508.67' 4588.25' 4588.25' 4590.00' oq'mZ/9o PI) drlg B:HA. RIH to 4487'. Test csg to 2150 psi. Drill FC0 FS and 10' new formation. Test shoe to 14.0 ppg. Drill 4610'-5277'. Drill 5277'-5510'. Trip for bit and BHA. Drill 5510'-5948'. Drill 5948'-6614'. Circ BU. ST to 5400'. Drill 6614'-6822'. 04115190 Drill ~822'-6868'. POOH. PU steerable motor. RIH. MWD failed. POOH. o4/16/9o POOH., CO HWD. RIH. Drill 6874'-7307'. SHP 14el) M-28 ( Daily Summary of Wel 10perati ons Page 4 04/17/90 Attempt MWD survey. Drop S.S. POOH. Test BOPE. RIH. Drlg 7307'-7496'. 04/18/90 Drlg 7496'-7815'. ST to 6843'. Drlg 7815'-7870'. 04/19/90 Drlg 7870'-8305'. ST to 7300'. Drlg 8305'-8338'. 04/20/90 Drld from 8338'-8445'. CBU. Dropped survey. POOH. Change BHA. Cut and slip drlg line. Service top drive. RIH to 5960'. Lost electric power to dra~orks. Troubleshooting problem. 04/21/90 POOH to shoe. Troubleshoot and repair drawworks electrical. RIH. Drlg from 8445'-8788'. Top drive gooseneck leaking. CBU prior to pulling to shoe. 04/22/90 Fin CBU. POOH inside shoe. Repair leaks in top drive mud line. RIH. Drlg 8788'-9078'. 04/23/90 Drld 9078'-9187'. ST to 8156'. Drld 9187'-9341' Worked tight spot ~ 9330'. Stuck pipe. Pipe came free by jarring down. DrlJ 9341'-9434'. CBU prior to POOH. 04/'24/90 CBU. Drop survey and POOH. BHA. Test BOPE 250/3000 psi. Change leaking annular.element. Fin testing BOPE. BHA. RIH. Drlg 9434'-9457'. 04/25/90 Drld 9457'-9840'. CBU for ST.' 04/26/90 CBU. ST to 9350'. Drill 9840'-10,247'. 04/27/90 Drill 10,247'-10,269' POOH. Change BHA and PU steerable motor. C/$ drill line. RIH to shoe. ~djust $CRs and replace drawworks blower fan. RIH, Orient and drill 10,269'-10,390'. Daily Su~m~ary of Well Operations .. Page 5 04/28/90 Drill 10,390'-10,550'. Lost platform power. Wait on same. ST 10 stands. Drill 10,550'-10,660'. o4/ / o Drill 10,6§0'-10,840'. ST 10 stands. Drill 10,840'-10,940'. o413019o Dri]! 10,940'-11,005'. C~rc and drop survey. POOH. Test BOPE. PU Hit tight spot ~ 10,759'. Work free. Wash/ream 10,759'-10,790'. os/o.Vso 1Jash[ream 10,790'-11,005' Dr]d 11,005'-11,102'. Wash/ream tight spot 11,0~6'. Dr]d 11,102'-111253'. os/o / o Drld 11,253'-11,450'. CBU. ST. POOH tight 0 11,016'. Wash/ream 11,075'-10,982'. RIH 11,450'. CBU. POOH. LD BHA. o /oa/ o Log run //1 D[L-GR-^coustic 11,450'-4,590'; log run I/2 GR-Density-Neutron 11,450'-8,450'; log run //3 acoustical array 11,450'-8,450'. FlU BH^. RiH. Cut and slip drlg line. os/o /9o RII4 to 11,450' for wiper trip. CBU. POOH. RIH w/ coring tool on E-l~ne. ^ttemp't 10 cores w/o success. POOH. Identify problem and change out tool. RIH. ~ttempt 4 cores w/o success. POOH. Rewire cable head. os/os/9o ,.Troubleshot wireline unit's electrical problems w/o success. RD E-line. RItl to 4400'. Restring blocks to 12 lines. Fin RIH 11,450'. Circ and cond mud. POOH. Pull WR and set test plug. Change top rams to g-5/8". os/o6/ o RU and run g-5/8" csg. os/o7/9o Fin running 9-5/8" and 10-3/4" csg. Circ and cond mud while reciprocating csg. Pumped 75 bbls 10 PPg brine followed by 245 sxs scavenger slurry 0 1! PPg- Followed by 2212 sxs TLN 0 13.2 PPg w/ additives. Followed by 903 sxs Class "G" SHP We11 M-28/'~,~ Daily Summary of Well Operations Page 6 w/ additives. Displaced w/ 756 bbls mud. Recip csg. Had cmt to surface. Inflated CTC pkr w/ mud 0 2700 psi. Set packoff. 10-3/4" & 9-5/8" Casing Detail KB Elevation ~ Hanger 7 &ts 10-3/4", 51#, Butt, N-80 long 3 &ts 10-3/4", 51#, Butt, N-80 long 10-3/4" x g-5/8" X-over 36 Jts 9-5/8", 47#, Butt, N-80 long CTC Packer 77 Jts g-5/8", 47#, Butt, N-80 long 145 Jts g-5/8", 47#, Butt, s-g5 long Float col 1 ar 2 Jts g-5/8", 47#, Butt, N-80 long Float shoe FROM TO 0.00' 77.04' 77.04' 7g.71' 7g.71' 367.85' 367.85' 494.gs' 494.gs' 497.13' 497.13' 2002.6g' 2002.69' 2022.50' 2022.50' 528g.12' 528g.12' 11,315.g6' 11,315.g6' 11,317.5&' 11,317.56' 11,397.63' 11,397.63' 11,3gg.4s' Test pack-off. Test BOPE. LD 12-1/4" BHA. Restring block. RIH TOC 0 10,010'. Test csg to 3000 psi. Drill cmt 10,010'-11,125'. os/o9/9o Orld cmt 11,125'-11,310'. Tested csg to 3000 psi. Drld FC, FS and formation to 11,465' Tested shoe to 14.0 ppg. Displaced cmt contaminated mud. POOH. PU BIIA. RiH. Drld 11,465'-11,655'. os/to/9o Drld 11,655-11,7g0'. ST to 11,378'. Drld 11,7g0'-11,813'. POOH. FiD POOH. Left one cone in hole. RIH w! mill and junk basket. Reamed 11,.732'-11,813'. Milled on junk ~ 11,813'. POOH. Recovered 2 lbs bit debris. PIJ EllA. RIH. Fin RIH. Orld from 11,813' to 11,896'. Surveyed w/ MWD. Tripped for bit. i)rld from 11.,896' to 11,g26'. os/ a/ Drld from 11,926' 'to 12,281'. Surveyed w/ MWD. 05/14/90 Dropped survey. POOH SLM. Tested BOPs. RIH. Drld from 12,281' to 12,333'. SHP Wel 1 M-28 Daily Summary of Well Operations Page 7 Drill 12,333'-12,450'. ST to shoe. POOH. RU loggers. Run ,(1 w/ DIFL-BHC-SP-GR-PCM-CHT. Run #2 w/ CHT-PCM-DEN-NEU-GR. Density failed 0 12,250'. Run #3 w/ CHT-PCM-GR-DEN Stuck tools ~ 11,838' and work free. RIH for wiper trip. Ream 11,658'-12,035;. POOH to shoe. Tight ~ 12,237'-12,229'. Reaming to bottom. os/ 7/ o Bash/ream 11,399'-12,450'. Raise MW 9.7-10.0 ppg. Spot resinex pill in open hole. IN)OIl. RIH w/ digital array acoustilog/GR. Could not pass 11,830' DIL. Lmj 11,830'-8,800'. RIH w/ FMT-CHT-GR. Could not pass 11,787'. Recovered one pressure e 11,730' and tool failed. POOH. RIH cut drlg line. RIH. Regulator on I~y unit leaking. Secured well. Repai'r hydraulic pressure regulator on koomey unit.' RIH for wiper trip. POOH. RI) E-li~ne. RIH w/ FMT-GR. Could not get past 11,770'. POOH'. RD E-line. RIH for wiper trip prior to running 7" liner. Wash/ream to 12,450'. C&C hole. Raise mud wt from 10.1-10.4 ppg. CBU. POOH. RU run 7"' liner and hgr. RIH w/ 7" liner on 5" d.p. RIH w/ 7", 29#, N-80, TKC liner on d.p. to 12,448'. C&C hole w/ rotating and recip. Cmt w/ 400 sxs Class "G" cmt w/ additives while rotating and recip liner. Bump plug and set hgr w/ 3200 psi. CIP e 1630 hrs on 05/lg/g0. Release setting tool. POOH. LD tools. RIH w/ bit and scraper to top of liner e 111!~m . C~U, 7" Liner Detail TI# Rotating Hanger w/ Tieback Sleeve, 7" x 9-5/8" 27 Jts 7", 29#, Butt, N-80, TKC TI# Landing collar ! Jt 7", 29#, Butt, N-80, TKC TI# Float col 1ar I Jt 7", 29#, Butt, N-80, TKC TX# Float shoe FROM TO 11,193.00' 11,212.68' 11,212.68' 12,357.68' 12,357.68' 12,358.66' 12,358.66' 12,400.44' 12,400.44' 12,402.27' 12,402.27' 12,445.08' 12,445.08' 12,447.97' SHP Wel 1 M-28t' Daily Summary of Wel 10perati ons Page 8 Fin CBU, no c~ in returns. POOH 2 stds. WOC. POOH to HWT and test liner lap to 3000 psi, ok. LD HWT and jars. Test BOPE to 250 and 3000 psi. MU liner dry test t,ools on RTTS. RIH. Fin RIH w/ DST tools. Differentially tested liner lap to 3.5 ppg EMW. RO one d.p. volume. POOH. LD test tools. RIH w/ 6" bit. Tagged cmt g 12,067'. Tested liner to 3000 psi. Drld cmt 12,067'-12,208'. os/2 /9o Orld cm~ to 12,353'. Tested liner to 3000 psi. Orld floats cmt, shoe, and 10' new formation to 12,465'. Tested shoe to 14 ppg EMW. Cond mud. Tripped for dr1§ assembly. 05/24/90 Orld 12,465'-12,774'. Gas increased to 3000 units. Shut-in well. No d.p. pressure. Opened annular and CBU. o5/25/9o Circ and ra(sed MW in stages from 10.7 ppg to 11.5 ppg, BGG increased from 2500 to 4000 units, mud cut to 7.g ppg. SI well and monitored pressures. Circ 11.7 ppg mud on choke. SD pump. No flow. Circ and raised MW to 12.2 ppg. POOH to shoe. C)rc and cond mud, BGG increased to 4000. SI well-O SIDPP. Circ 12.5 ppg on open choke. 05/26/g0 Orld to 13,000' CBU w/ 5000 Units Conn Gas. MW cut 12.5-11.4 ppg. BGG increase to 10,~00 U. Circ and raised MW to 12.8 ppg. BGG while circ 12.8 areund ~-10,000 U. Mud cut 12.5-11.0 w/ 12.8 around BGG 7500 U. Decrease to 4~00 on second BU. Circ and raised MW to 13.0 ppg. BGG dropped to 500 U. Mud cut 12.8-12.7 ppg. 05/27/90 Circ and raised MW to 13.0 ppg. BGG decrease to 400-500 units. ST to shoe. Monitor well. RIH to bottom. Circ BU. POOH. RU to log. Run #1 - GR/SP/OIFL/BIIC/CHT. Run #2 - Spectral/CAL/CDL/CNL/CHT. RIH for wiper trip. o5/28/9o I~ade conditioning trip. Max gas 2000 U w/ mud cut to 11.7 ppg. Attempt 30 rotary sidewall cores. Recovered 23. Started testing BOP's. · SHP Wel 1 M-28 ( Daily Summary of Wel 10perati ohs Page 9 05/29/90 Tested BOP's. Made conditioning trip. Max gas 2500 U w/ mud cut to 11.6 ppg. Ran CBIL log. Pti 5" liner and hanger. RIH. os/3o/9o RIH w/ 5' liner on d.p. Circ g 12,400'. Fin RIH w/ liner to 13,000' Circ and .rm~ip pipe. Mixed and pumped 136 sxs cmt. Displaced cmt and bumped ~lug w/ 3000 psi. Set #§r g 12,368'. POOH 10 stands. Circ. POOH. RIH w/ bit. S' Liner Detail TI¥ Liner Hanger 13 its 5', 18#, FL4S, N-BO TI# Landing col 1 ar I Jt §', 18#, FL4S, N-80 TI¥ Float col 1 ar I Jt S" :, 18#, FL4S, N-80 TI# 'Float shoe os/3 / o FROM TO 12,368.02' 12,383.56' 12,383.56' 12,g14.g8' 12,914.98' 12,915.82' 12,915.82' 12,955.15' 12,955.15' 12,956.83' 12,956.83' 12,997.72' 12,997.72' 13,000.00' Fin Rill w/ bi't to 11,500'. Washed to 11,g51'. Circ. Washed and reamed cmt to 12,320'. Waited on cmt. Washed and reamed to 12,368'. Circ. Tested liner lap to 1780 psi for 30 min. POOH. PU retrievable pkr and tester valve. RIH 'w! retrievable pkr and tester tool to 12,330'.. Filled d.p. for an equivalent 7.0 ppg. Set retrievable pkr ~ 12,318' Opened tester valve. Had no flow at surface. Closed valve for build-up. R~ air from d.p. POOH. RIH w/ 4-1/8' mill. Fin Rill w/ 4-1/8" mill to 12,368' POOH. RIH w/ retrievable pkr. Set pkr ~ 12,131'. Tested 5" liner lap to ~000 psi. Displaced d.p. w/ 8.34 ppg water. Closed by-pass. Bled d.p. to zero. Monitored for flow. RO water from d.p. o6/o)/9o Fin POOH ~/ retrievable pkr. RIH w/ cmt mill. Reamed through liner hgr ~ 12,368'. Rill tagged landing collar g 12,g11'. Drld cmt to 12,g55'. Tagged float co)lar. CBU. Tested liner to 1800 psi. POOH. o6/o4/9o Fin POOH w/mill. RIH w/ 5" and 7" csg scrapers. CBU. POOH. RU WL. RIH w/ 5" c~ bond log. Logged 5" csg 12,g32'-12,368' ~ O, 500, 1000 and 1500 psi. POOl(.i RII( w/ 7' cmt bond log. Logged 7" csg 12,368'-11,191' ~ 0 and 500 psi. RECEIVED DEC 1 0 1990 Alask~ 0il & Gas Cons, Anchorage o, SHP Well M-28 Daily Summary of Well Operations Page 10 o /os/9o Fin running omt bond log across 7" liner. Ran cmt bond log over 9-5/8" csg from 11,193' to 7300'. Ran digital array acoustic from 12,g32'-11,010'. Ran gyro survey 12,900'-2200'. 06/O6/9O Fin running gyro survey. Perf for squeeze 10,620'-10,623'. RIH w/ retainer to 10,590'. Attempted to establish inj w/o success. Set retainer 0 10,6g0'. POOil. RIH and set retainer at 10,596'. RU to squeeze. o6/o7/9o Squeezed perfs w/ 100 sx. POOH. Tested BOP's. RIH. Started drlg retainer. 061o819o Drld retainer and cmt. Tested squeeze perfs to 2,500 psi. Bled to 2100 psi in 30 min. POOH. RIH w/ retainer. Test perfs to 2500 psi. Bled to 1840 psi in 30 min. Set retai'ner 0 10,580'. Attempted to establish inj w/o success. POOH. Rill w/ bit. os/o /9o R'IH. Drld retainer 0 10,580'. POOH RIH to 10,687'. Spot 100 sx balanced cmt plug. PIJ out of cmt. RO. Closed h~dril and pressured up on cmt. WOC. POOH. o6I o/9o Fin POOH. RIH w/ bit. Drld cmt to 10,680'. Tested squeeze to 2500 psi. Drld cmt and retainer to 10,6g0'. CO to 11,193'. RIH w/ csg scrapers. 06/ll/gO RIH w! 4-1/8" mill and csg scrapers. Unable to work into liner. POOH. RIH w/ 6' bit., York into 7" liner top. RIH to top of 5" liner. Displaced mud w/ water. .. Fin displacing mud w/ water. POOH. PU new mill. RIH to 12,36g'. Worked mill into liner to 12,40g'. RIH to 12,g52'. Attempted to reverse circ. POOH to 12,369'. Established circ. Washed to 12,g47'. Circ. Circ caustic sweep followed by inlet water. Displace inlet water w/ drill water. Circ drill water while mixing in 3~0 KC1. Filtered the 3~0 KC1 to <50 NTU's. POOH. RIH w/ 5.25" polishing mill. Polished 5" seal bore lreceptacle. Daily Summ~ary of Well Operations Page 1! 06/14/g0 POOH w/5" polishing mill. Run & set 5" liner lap isolation assy. Backside tested to 1507 PSI. POOH. L/D 3-1/2" DP, HWT & DC's from derrick. Change top RAMS to 4-1/2 test BOPE 250/3000 PSI. RIH w/7" polishing mill. 06/15/g0 RIH w/7" polishing mill Dress PBR 11,190'-11,196'. POOH. RIH w/g-5/8" by 7" isolation assy. Sting into polished bore and test backside to 1500 PSI. Set packer. Rotate out of packer. POOH L/D 5" DP. 06/16/g0 LD 5" d.p. Pulled wear bushing. RIN w/ 4-1/2" completion. 06/17/90 MU tbg hgr. Land tbg and set pkr g 10,520'. Test to 2000 psi RIH w/ 3.70" gauge on slickline to 12,914'. Set BPV. ND BOPE. NU tree. ~isconnect service lines. Preparing to skid rig. 06/18/90 D~sconnect r~ service lines. RU rig jacks, RELEASED RIG to We~l ~-4 csg preset AFE 8356-0 ~ 0700 hrs. on 06/17/90. 06/19/90 RU E-line to per~orate. 06/20/90 06/21/90 Finish R/U E-line Run #1: Perf Basal W/F 12,735' - 12,745' DIL. TP inc. from 0 PSI to 80 PSI. Run #2: Perf Basal W/F 12,705' - 12,735'. Run #3: Perf Basal W/F 12,675'-12,705'. S/I well. TP built up to 2200 PSI in 30 min. R/D E-line. Put .well on test. Well unloading ~ 7 8PH. Had oil to surface ~ 06:00 hrs 6/21/90 FTP: 120 PSI.. ' , · 06/22/90 Continue flow testing: Production for last 2.4 hrs. 159 BO OBW, TR BS&W, 58 MCFD, 120 psi FTP. Gravity = 32.9° API. ' 06/23/90 Production last 24 hrs, 131 80, 0 BW, TR SS&W, 60 MCFPD (est.), 125 psi FTP. SHP Well M-28 ( .... ('" Daily Summary of Wel 10perati OhS .. Page 12 06/24/90 RU #L. PT lubricator to 4000 psi. RIH w/ tandem pressure gauges. Obtained FBIIP survey. POOH. FBHP at 12,696' was 3928 psi. On 23 hou~ test, we]] produced 135 ~PD, 0 BN, TE BS&N, 90 NCFPD, 90 psi FTP. o /25/ P~u¢.t~on last 24 h~s, Z32 BO, 0 BN, TR BS&N, 90 NCFPD, 90 ps~ FTP. C~t testin~ we]] w/ 24 h~s tes~ as fo]lows: 125 BFPD, ~ace of BS&~, 125 BOPB, ~ ~FPO, TP = 90 psi and CP = 100 psi. ~t testing p~o~ ~o obtaining p~essu~e buildup. P~oduct~on fo~ past 24 hours ~s ]25 ~PD, no wa~e~, 90 NCFPD on natural flow. TP = 90 ps~. CP = ZOO ps~. ~t ~es~ng. P~oduct~on fo~ pas~ 24 h~s was Z27 BOPD, no wa~e~, 90 NCFPD w/ 90 psi FTP and 80 ps~ CP. 06/29/m ~t testing. P~oduc~on fo~ pas~ 24 h~s was Z22 BOPD, no wa~e~, 90 NCFPD w/ 90 ps~ ETP and 80 ps~ CP. Coat testing. P~oduc~ion fo~ pas~ 24 h~s was 121 BOPD, no water, 90 NCFPD w/ 90 psi ~P ~d 80 psi CP. OT/OZ/~ Pmduction fo~ pas~ 24 h~s was 123 BOPD, no water, 90 NCFPD w/ 90 psi FTP and 80 .... psi o7/o2/ P~uction fo~ pas~ 24 h~s was 118 BOPD, no water, 90 NCFPD w/ 90 psi FTP and 80 ps~ CP. o7/o3/~ Con~ testing. P~oduction fo~ pas~ 24 h~s was 121 BOPD, no water, 90 NCFPB w/ 90 psi ~P and 95 psi CP. SHP Well M-28 ('" Daily Summary of Well Operations · Page 13 07/04/g0 24 hr test: 121 BOPD, 0 BWPD, go MCFPD w/ go psi FTP and 35 psi CP. o7/os/9o 24 hr test: 120 BOPD, 0 BWPD, go MCFPD w/ go psi FTP and 45 psi CP. o7/o6/9o 24 hr test: 121 BOPD, 0 BWPD, gO MCFPD w/ gO psi FTP and 40 psi CP. 07/07/90 ¥ell produced approximately 60 BOPD, no water in 12 hours. SI well for 8-1/2 hfs for shipping pump maintenance. Opened well up and unloaded 27 bbls fluid, then wel! died. 07/08/90 No flme after 12 hrs open to separator. Pressured above SCSSV to 2720 psi. SCSS1/ had closed during unloading. Opened well and unloaded 2g bbls fluid in 10 minates, then no flow for 3 hrs. SI and TP increased to 2200 psi in 5 hrs. Open well .and unload 34 bbls fluid in 5 min~ then no flow for 2 hrs. o71o919o $! well and TP increased to 2725 after 7-1/2 hrs, then stabilized. Opened well and unloaded 34 bbls fluid. After 5 hfs, well started flowing. Current rate is 135 BOPD, no water. 07/]0/90 24 hr test: 129 BOPD, 0 BWPD, 56 MCFPD w/ 135 psi FTP and 25 psi CP. 07/11/90 24 hr test: 124 BOPD, 0 BWPD, 50 MCFPD w/ 50 psi FTP and 30 psi CP. 07/12/90 24 hr test: 124 BOPD, 0 BWPD, 50 MCFPD w/ 50 psi FTP and 40 psi CP. 07/13/90 24 hr test: 122 BOPD, 0 BWPD, 50 MCFPD w/ 85 psi FTP and 30 psi CP. 07/14./90 24 hr' test: 124 BOPD, 0 BWPD, 50 MCFPD w/ 85 psi FTP and 30 psi CP. SHP Well M-28 (" (" Daily Summary of Wel 10perati ons .. Page 14 07/15/g0 24 hr test: 11g BOPD, 0 BWPD, 50 MCFPD w/ 88 psi FTP and 30 psi CP. 24 hr test: 120 BOPD, 0 BWPD, 50 MCFPD w/ 85 psi FTP and 30 psi CP. 07/ll7/90 Cent testing well. 24 hr. test: 119 BOPD, 0 BWPD, 50 MCFPD, 85 psi FTP and 30 psi CP. Rtl slickline. RIH w/ 3.70" O.D. gauge ring. Tag bottom ~ 12,g33'. No drag. PO011. RIH w/ tandem pressure gauges. 07/]8/90 Attempt to RIH w/ gauges. Unable to get past 368'. Run gauge rings to 452'. Unable to get past 452' due to asphaltenes and wax. Dump 25 gals dispersant in tbg. Open SCSSV. Well not flowing. 07,/xg/go Well started flowing. RIH w/ gauges to 12,696'. Flow well prior to PBU. SI well O 2Z30 hrs. for PBU' TP increased to 2650 psi and stabilized. SI for PBU. o7/2o/9o Continued pressure buildup. Surface TP = 2700 psi, CP = 60 psi. o7/2V9o Cent PBIJ. 07/22/90 RECEIVED DEC 1 0 1990 Fin PBU. POOH w/ gauges Alas~ Oil & Gas Cons. Comm~Sitoa · Anchorage o7/ /9o ,r. Produced well production for past 24 hrs: 94 BOPD, 0 BWPD, 39 MCFPD w/ 100 psi TP and 20 psi CP. Well is producing 20-35 barrels in heads every 5 to 7 hrs. 07/24/90 Produced welt production for past 24 hrs: 97 BOPD, 0 BWPD, 40 MCFPD w/ 85 psi TP and 10 psi CP. Alaska Region Drilling Report o7/ 5/9o Produced well production for past 24 hrs: g5 BOPD, 0 BWPD, 3g MCFPD w/ 100 psi TP and 10 psi CP. Alaska Region Drilling Report SHP Well M-28 ( (' Dai 1¥ Summary of Wel 1 Operations .. Page 15 07/26/90 Produced we)l. Production for past 24 hfs: 90 BOPD, 0 BWPD, 40 MCFPD w/ 100 psi TP and 10 psi CP. Analyzing pressure buildup. Will drop from report. 07/27 - 9/17/90 Honitoring and testing Basal West Foreland production & evaluating well for further perforating. o9/]8-]9/ o Rtl CTU. PT coil, lubricator and injection line to 3500 psi, OK. RIH with CT to 12,892' KB. Reverse circ 110 bbls diesel w/ paraffin solvent added e I BPM, 2700 psi. RIH and tag bottom e 12,g15' KB. PU to 12,g00' KB. Reverse circ 250 bbls diesel for total of 360 bbls. Recovered 180 BW, go BO, 120 bbls diesel. Well flowed approx 30 BO while displacing hole w/ diesel. POOH w/ CT. Return well to production. Well flowing steady e 5 BPH, go psi FTP. m/ o-z]/9o Rtl E-line and PT lubricator to 3500 psi, OK. MU and RIH w/ 3-3/8" OMNIKONE perf guns, 4 SPF, 22 gm, gov phase. Made three runs perforating Basal West Foreland 12,735' - 12,748'; 12,705' - 12,735'; and 12,675' - 12,705' DIL..Flow well to praducti on. 9./27/96 Rtl wireline and PT lubricator to 3500 psi OK. RIH w/ pressure and temperature survey tools and obtain FBHP e 12,710' DII' at 3,030 psi. POOH. RIH w/ controlled displacement samples and obtain oil samples. Run bubble point tests fram sample collected at 12,404' DIL. POOH. Test showed consistent results. m/4- /9o RU E-line and PT lubricator to 3000 psi MU and RIH w/ 3-3/8" OMNIKONE perf guns, 4 SPF, 22 gm, go~ phase. Tag filie 12,gog' DIL. PU and perforate the ~Basal Best Foreland 12,870' - 12,g00' DIL. POOH. RD & flowtest well. 09/12-13/90 RU E-line and PT lubricator to 3000 psi, OK. MU and RIH w/ 3-3/8" OMNIKONE perf guns, 4 SPF, 22 gm, go phase. Made two runs perforating the Basal West Foreland 12,840' - 12,870' and 12,810' - 12,840' DIL. POOH, place well on production. 10/18-19/90 RU E-line and PT_lubricator to 3000 psi. MU and RIH w/ 3-3/8" JUMBO JET guns, 4 SPF, 22 gm, go° phasing. Made two runs perforating the Basal West Foreland SHPWe11H-28' il Daily Summary of Well Operations Page 16 12,778' - 12,808' and 12,748' - 12,778' OIL. POOH and return well to production. 10/27/90 i~U E-line and PT lubricator to 3500 psi. With well flowing RIH w/ STRESSFRAC tools and tag fill g 12,g00' DIL. PU to position tool from 12,883' - 12,895'. Ignite 2" STRESSFRAC tool. POOH to 11,300' and monitor well for 30 minutes. Z0/28/90 C~ntinue POOH. Maximum pressure recorded was 9200 psi., 0.85 psi/ft, gradient. Flow well to test. RU E-line and RIH w/ 2-1/2" x 12' STRESSFRAC tool. (Correlate and tag fill g 12,g00' DIL. POOH e 30 FPM. Ignite STRESSFRAC w/ tool across 12,704' - 12, 716'. POOH, wire parted at rope socket, left lg.25' of tools in hole. RD E-line. 10/29- 10/31/90 RU wireline with fishing tools and PT lubricator to 3000 psi. Made several unsuccessful attempts to fish tools from hole. Last tagged TOF ~ 12,880'. POOH. RD. 11/2/90 RU E-line and PT lubricator to 3500 psi. With well flowing, RIH w/ 2" x 12' STRESSFRAC tool, correlate and ignite tool across 12,692' - 12,704' while POOH e steady 30 FPM.' Maximum.pressure generated was 8600 psi. MU and RIH w/ 2" x 12' STRESSFRAC tool. Ignite tool as before across 12,680' - 12,692', POOH. Maximum pressure generated was 8600 psi., 0.81 psi/ft gradient. Flow test well. 11/22/90 RU E-line and PT lubricator to 3500 psi. RIH w/ pressure/temperature tools and log from TOF e 12,880' to 12,600'. BHFP g 12,694' MD = 3ggo psi. Avg gradient over logged interval - 0.40 psi/ft. POOH. RD logging tools. MU and RIH w/ 2-1/2" STRESSFRAC tool, corrleate and. ignite tool across 12,692' - 12,704' while POOH e 30 FPM. Continued POOH e 30 FPM through 5" x 7" isolation packer. Lost 180 lbs tension immediately. Flow well for 30 min. POOH. End of cable showed clean break at head. Estimated TOF e 12,862' MD. docs\shp\M28 ; Sque~.ze Per;s Attachment #2 ( MARATHDN DIL CDMPANY TRADIN6 BAY UNIT STEELHEAD PLATFDRM WELL M-28 Ali e~e(~Sure~en~s oJ-e RKO t:o lop oF eqtJl~en~. Co~DLe'b~n 4~' FHC TC-IA-i~H Tb9 Hngr, ]kart Top & 445' CAHCD TR])P-4A $CS~V ¢3.813' 0'-10,~i68' 4,5; 1~.,61~, L-BO AB Hod Bu~'~ Tbg. 990' 26; 267-397#, 1445' tgi 75t, K-55 ~TC 4590' L3-3/8; 61/68ft., K-55, BTC 0-497' ].0-3/4; 5t/~5.St~, H-B0 ]~t, rtt 497'-11,399' 9-5/8', 47#, N-80 l~u%t t]I93'-lP_,448" 7', 29#, N-BO ]lu'tt liner LP.,368'-13,000' 5; 18#, FL4.% H-BO ttner 2309' 4013' 5484' 6687' 7520' 7956' 831~' 8812' 9241' 96E:3' 10,013' 10,404' 10,463' GIN's om :DGn~l GLSO, 4.5' x 1.~' sldep~ket p~xndrets ¢12 to,Gl) V~lve Tvoe ].9~LG~ Po~t_ Size I ])u~y RK - E - :3 - 4 - $ - 7 - 8 - g - 10 - l~ ])ur~y RK - n~s 'XD' Production ~eeve (3J~t3' X Profile), G-ZnNr' Top oF G-I · 10,632' Bo* or G-6 e IL~&' [SOIn~!.on Pocket A;seflbl~. ~1~].49' ]~ker Hodet ])]! Packer size 194-47. ]].153' Hlllout £xt ~].170' O~ls 'X' L~ndlng NIl~le (3~13' ProFIte), 11188' T[V 7' LG-6 Se~l Nipple. REEEIVED DEC 1 0 1990 Alaska Oil & Gas Cons. Comm~Ss'to~ Anchorage HilTS, HImnun ID c=tq~er loG) r~ Nov 3, 1990 Ind~:~ 3.70' restrictions e 1],160' ~d 11,170' *ubln9 n~surenen%, VEST FORELAND Top VF-O sm 11,790' ]Sot VF-6 e 1E.,310' Is~=~clon Pecke~ Assenbl_~ IP_.,351' l~ker Node[ FB-I Pkr, SIze 85-40 1,%360' Otis ~ ~le (3~13' B~, ~7~ No~). 1~36~ TXv 5' LG-G Tme-~ Se¢~ with I/2 H~e~. BA~AL VE~ITBRELAND PERF_DR_ATIDN~S ]nterv=~ F~ SPiC Phe;ln_~ D~e 12,675'-1P.,748' 73 8 O* 6/90 & 10/90 1P_,748'-lP_,808' 60 4 O* 10/90 12,810'-1P-.900' 90 4 O' 10/90 Avenge ])ev=t~m = t3J)* TI2r (STRESSFRAC Toot) tc~gged e IP.880' VLH 10/31/90. FiLl ~ao(~d 8~ 1~900' C1~28~0~ Re~si~ ~em PBTD e ~ Reused ~ Re==~ N~ C~pte~i~ T~ ~ ]3,000' Prevlo~ Rev~lofl, N/A ~'$= " '~. ' ~.~"';' ~. ' ~ ., ~,~,.-"'~"'~ ".~, ' .r, ~ .. '. · :,~',":'<~., $: ';v~.~. ' ... 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' .... ~..~, .~ .... . ,. ,.. . - · - ~,,r~ ~ . ~.'~ ~' ~ . ~_ ,.,'., ~,' .'~*.- ~ .~.~. '.,~' .~' ~ ' ~,. .~. '. ~ ~..~ ..~. '..' .~'~-,.. ~'., '.,.'... .'. ?': ~. - ~.. · %~ .~:~, ~.. ~.~ ;' ,~,'~,.. ~,'.,~. ~.~' '~ ~'~*,,-'~*~;'~';~,,~'~, ~,~.'.-:~:~r.,~-- ~.~",~;~:'.':.-'~... '. ~.~z'~',.:~.'..~,,~~,~, ..~-.' .-- ~. ~*~ ~,~ ;%~.. ~..',-,- .... ,~ ,~.., .~,,-,,'~' ~.t.'~.~ ~ ,, .~.f' .. , ,~ . .~,.-:~ ,.,., ~;,~ .~. ;.. ~ .... ~ '.. ~ ' "~'-'.~ .... '~T (.'-.~ ,',-~-,: ,;- "~'~ ~- ~.,~;~ ' ' ,~ .~ ,,,~*~'~,.~ ..' , · -' .... , ........'% .' - -,~, ' .'. , ~' , ,, :~,.- ..... ' -, ~,. · . ,/ AUG 30 '91 20:,':'-4 STEELH,~?'-DR!LLIHG · . I ,. : :~:.:~' :'.? ... Company Represantati ye:. .. ' ':..: AOGCC Representative,, - ' ........ :::: ' Rig No.:. _'~-~,,,,,,./.~?~,.~ ": . ',:Permit No.: ........... Shoe Test: _ __ __ __ __ppg : · .;'~ . :,~ .,: . . , Annular Preventer ~ ~~ ~" Full Cha~e Pressure__ ~o~ __~pstg_ '. ____ ,' ,P~pe Rams, Upper ..~.-.~o '~- ' Pressure After C1'osu~e .... . Pipe ~ams, Lo. er~-~-.~¢~. ~ Nitr~en Pressure_ ~~ 81tnd Ram .. ' ,',,~:*~:~-.~~ ~' 'T~me Required to ~ncr~ase- .. Choke Ltne Valves ' :.,f,.'.~..~o.,., ,,, _ _~.~-' Closing Pressure 200 t~CR Valve '~c~::~=~ ~'" Ttme '.~o Attain Full ' ' .. Ktl1 Line.Valves· ~ ~:~~",~ '~ ' ~ha'rge Pressure ' .. ~,_. rain'sec Check Valves, ,. ~-'~~ ,~ ~.. ...... ,. . ,Ke11,L.'and..F1oo~ Safet~ Valves ;"~ Controls= ~aste~_" · ---, ......... ."/ Re~te -.-~ Lower K~lly,:,.Safety --~.' ~a~ ~ Detection De:~tces Full_Opent~ ' - "~ .... ---' "- - - Valve ~, Trip Tank ~'.: '"'~ "" '~. Flow Nonttor ~ ,' ;~:k'e. NaA~fo]'d'. ... , Gas Detectors " ';":" ' ~" . .'. '"'"' ?'"' I~ , Stroke Counters _. ,~" -~' .' ~o;~ .... , ,,Va'lyes ._ .:.,, ....... "" ,.-. No'._.~ ~ ..... ' Flanges._ . .. ~.. .... 'House~eeoJ na ' Re.re Ad3ustable Chokes ', -.. .... Rigt /' ' . · · ,.~.. .~-, i i iii i1,11_ i ...... ,, Locat ~on: . ~ m *. - .... I I I I i i mi m m ~ j . "'""" * Hell Sign:_ ~ . " - " Reserve ~Jt= _._~_ .._. . ....... . ~ ' . ... .'. ~ . .,' ~ ~ · . . . . , · , . . T~s.t,Resu'~ts~. Fa~guye~'~'· ~" Test T~ "~ hrs, ~eP~r'or.'rep~ace~e~t of' fagged equipment to be eade ~h~n ~_ ~ days and Representative/ Commission off'ice' not~fied:,.,~ Remarks: ...... ' ~: ,'v. .: ..... _ . ,.-. , __ -- 1.1 ii l illl_- i . .---- :_ - ..... ..... '' i ' · i iii ..... ~ ~ i i ., -" --- ' .... : -: .......... _.:__ ....... -( ~ . :: . '" ..---~- .---;:~---,, . ~/ :' ~. ~ ...... , ........... Toolp~~ ~~'~~.. ~ . ' .~ ' . P. 2/2 Company Representative, /~_.~v/~oy Rta No. t. ~e~ M ~ . -- ' ....... ~Ca~lng Set P ~~e~' -,--~t. ...... ~--- Shoe Test L:._=_ , / ~. o'..-=. __ppg _BOP Stack. Tes,t__p~mssure Accumul&tor..Svstem ': ,, Annular Preventer Pipe Rams, Upper Pipe Rams, Lower .. Blind Rams Choke Line Valves HCA Valve Kill Line Valves ' Check Valves ~e'll~and'..,F!~qr SAfAtv.,Va]v~. ' , Upper Kelly .. " ~o Fbll Opening Safety In~id~ BO~ ',... ~-;m~_~',-' .... Pit ,, ~e ~antfold'" " Flow Monitor ..... ' .. Gas. Detectors Stroke Counters Full Charge Pressure__?~_Q_L__' pslg .... Pressure After Closure~_~_~.~_ ps!g Nitrogen Pressure, ..~_3~>~ ...... ps.~g ~.i.i_~_.: ~i:-.-._. Ttme' ~equlred to increase Clostng Pressu~ 200 psig~mln.. ~ sec Time to Attain Full. ' Charge Pressure', ~}n~sec , Controls ~ Naster~_. RemuteL;-'-~~ ~', ,,-'~ ......... " ....... gltnd Switc~ Cove~;_ ~.~. ,, , , ..... , .... ~ ._~L~' ........ Test Results~ F~tlures ~..~y,~. '' Test Time' _. 'hrs." _ min.' .Repair .or,rep. l_.acement of 'faiT~d~ulpment to be made w{thl"d'-:._ day~' a'~! Representat)vej/ ~ommiss{on orr'Ice notified. . _ Remarks: ~u/~l '~/~- ~d~ ~ ~' .'~.Z~ ' . _ .... ~ ...... .~, _~'~ ~ -=~,,:... \DRLG\BOPE. ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 05/08/98 PERMIT API I WELL NUMBER NUMBER I NAME 90-0019-0 7332041400 TRADING BAY UNIT CODE NAME ...... 145000 UNION OIL CO OF CALIFORNIA M-28 838 ADL0018730 33894 ON-OFF I NUM 820 COOK INLET BASIN OFF FLDPOL FIELD AND POOL CODE ] NAME 520150 MCARTHUR RIVER, MIDDLE KENAI G + MULTIPLE POOLS 520190 520195 000000 000000 000000 IUNIT . UNIT ,CODE I NAME + KB 152 13000 10801 + I .o~o~.o~,. ~,oc~o. .... I~:-~ 0970 N 0532 W 33 09N 013W S 0085 N 2331 E 28 09N 013W S I IPERM Isssv ~'~1~:~1 ........ ,~c I~1~:~1-~-~1~-I~1~-I~1~''~ 445 + + DEV 1-OIL DEV 1-OIL RCV NO RCV NO 50004 PERMIT ] PERMIT DATE DATE I STATUS I RECORD APPROVED ISSUED SPUDDED COMP, ETC DATE LAST UPD. 02/28/90 03/22/90 03/23/90 06/21/90 10/04195 ICROFILMED ALASKA INDIVIDUAL WELL PRODUCTION AS OF os/o8/~8 WELL-NAME: TRADING BAY UNIT M-28 FIELD/POOL: MCARTHUR RIVER, MIDDLE KENAI G SALES CD - 50 ACCT GRP - 004 ** OIL PRODUCTION ** API: 733-20414-00 LEASE: ADL0018730 OPERATOR: UNION OIL CO OF CALIFORNIA FINAL STATUS: DEV 1-OIL CURRENT STATUS: 1992 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 27 29 31 26 30 30 30 24 30 31 30 OIL 16,810 16,474 17,279 12,855 12,557 12,806 6,936 9,984 20,132 21,200 20,550 WTR 30 168 85 132 51 39 GAS 4,436 5,226 4,929 3,115 3,065 3,503 1,519 2,431 5,753 5,362 5,803 1992 TOTALS OIL 190,398 WATER 505 GAS 51,187 CUM OIL 190,398 CUM WATER 505 CUM GAS 1993 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT. GAS LIFT GAS LIFT DAYS 30 28 31 20 31 30 31 28 30 13 29 OIL 15,649 14,128 18,615 9,496 17,005 14,672 17,119 13,795 18,244 9,194 21,805 WTR 1,896 1,517 2,800 1,294 2,502 6,874 2,305 656 2,109 C~AS 5,196 4,645 5,985 3,270 5,074 3,965 5,004 3,610 663 494 9,052 1993 TOTia~LS OIL 204,060 WATER 24,759 GAS 65,449 CUM OIL 394,458 CUM WATER 25,264 CUM GAS . , 1994 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LiFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 .28 31 30 31 30 31 31 30 31 29 OIL 39,923 38,363 40,720 39,715 40,371 41,172 37,833 40,563 37,895 36,430 36,652 WTR 3,981 4,731 4,676 4,830 4,661 4,713 4,971 4,221 3,861 3,773 4,087 GAS 11,345 13,739 15,199 16,978 20,622 21,368 17,777 19,954 18,641 20,165 18,336 1994 TOTALS OIL 466,455 WATER 53,115 GAS 212,556 CUM OIL 860,913 CUM WATER 78,379 CUM GAS 1995 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 31 30 31 31 30 31 OIL 33,823 30,644 38,336 35,149 35,650 38,306 37,342 36,764 34,337 38,774 WTR 3,154 6,911 3,530 4,483 4,930 4,619 4,612 3,187 4,335 5,002 GAS 15,338 18,390 21,172 21,008 18,589 13,338 22,229 33,364 37,694 13,476 1995 TOTALS OIL 437,976 WATER 54,289 GAS 247,030 CUM OIL 1,298,889 .CUM WATER 132,668 1996 JAN FEB MAR APR MAY JUN JUL AUG SEP METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 29 31 30 31 30 31 31 30 OIL 40,055 37,873 38,099 36,241 36,510 35,809 34,490 29,595 34,303 WTR 4,636 4,514 4,950 3,770 5,154 6,093 4,278 5,019 5,930 GAS 21,106 23,295 24,819 25,724 23,602 21,723 24,460 17,539 30,108 1996 TOTALS OIL 405,315 WATER 62,403 GAS 281,871 CUM OIL 1,704,204 CUM WATER 1997 JAN FEB MAR APR MAY JUN JUL AUG SEP METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 30 30 31 31 27 OIL 24,558 23,057 26,306 32,575 33,160 27,409 22,199 21,878 15,468 WTR 6,267 6,958 7,994 6,213 7,288 8,923 9,398 11,837 12,082 GAS 36,171 39,082 16,685 15,760 16,460 27,888 21,307 22,792 9,264 1997 TOTALS OIL 276,494 WATER 122,703 GAS 255,467 CUM OIL 1,980,698 CUM WATER OCT GAS LIFT 31 2'9,910 5,679 22,554 195,071 OCT GAS LIFT 30 16,276 15,439 14,951 317,774 NOV. GAS LIFT 30 38,042 4,778 11,225 CUM GAS NOV GAS LIFT 30 26,067 5,879 21,056 CUM GAS NOV GAS LIFT 30 17,105 13,276 22,709 CUM GAS DEC GAS LIFT 31 22,815 6,045 51,187 DEC GAS LIFT 31 34,338 2,806 18,491 116,636 DEC GAS LIFT 31 36,818 4,610 18,432 329,192 DEC GAS LIFT 31 40,809 4,748 21,207 576,222 DEC GAS LIFT 31 26,363 6,501 25,885 858,093 DEC GAS LIFT 31 16,503 17,028 12,398 1,113,560 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1998 JAN FEB ~k%R METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 16,201 13,677 13,845 WTR 15,554 13,569 15,434 GAS 13,637 11,580 13,162 1998 TOTALS OIL 43,723 WATER APR 44,557 FIELD/POOL: MCARTHUR RIVER, WEST FORELAND MAY JUN JUL GAS 38,379 CUM OIL SALES CD - 50 ACCT GRP - 004 ** OIL PRODUCTION ** 1992 JAN FEB MAR APR METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 27 29 31 26 OIL 8,669 8,491 8,897 6,474 WTR 17 86 1,661 GAS 2,281 2,688 2,530 4,517 1992'TOTALS OIL 95,748 WATER 7,792 1993 JAN FEB MAR APR METH GAS LIFT 'GAS LIFT GAS LIFT GAS LIFT DAYS 30 28 31 20 OIL 8,061 7,278 9,590 5,044 WTR 977 794 GAS 2,677 2,395 3,083 1,733 1993 TOTALS OIL 89,044 WATER 12,950 1994 JAN FEB MAR APR METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 OIL 8,983 8,632 9,162 8,936 WTR 1,251 1,487 1,470 1,518 GAS 2,553 3,091 3,420 3,820 1994 TOTALS OIL 104,922 WATER 17,601 1995 JAN FEB MAR APR METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 OIL 9,661 6,895 8,626 7,909 WTR 1,324 2,172 1,109 1,409 GAS 4,250 4,138 4,764 4,727 1995 TOTALS OIL 101,917 WATER 15,976 1996 JAN FEB MAR APR METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 29 31 30 OIL 9,012 8,522 8,572 8,154 WTR 1,457 1,419 1,556 1,185 GAS 4,749 5,241 5,584 5,788 1996 TOTALS OIL 93,424 WATER 17,685 MAY JUN JUL GAS LIFT GAS LIFT GA~ LIFT 30 30 30 6,472 6,600 3,575 44 1,579 ' 1,806 785 GAS 30,918 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 30 31 8,422 -7,558 8,819 2,843 666 1,289 2,634 2,043 '2,578 GAS 25,824 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 30 31 9,084 9,264 8,512 1,465 1,481 1,562 4,640 4,808 4,000 GAS 47,713 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 30 31 8,021 9,940 8,402 1,550 33 1,449 4,182 3,814 5,002 GAS 62,075 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 30 31 8,215 8,057 7,760 1,620 1,915 1,345 5,311 4,888 5,503 GAS 63,155 CUM OIL AUG SEP OCT NOV DEC 2,024,421 CUM WATER 362,331 CUM GAS FINAL STATUS: DEV 1-OIL CURRENT STATUS: AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT 24 30 31 30 5,144 10,370 10,237 9,451 69 2,628 2,291 1,252 2,964 3,076 4,002 95,748 CUM WATER 7,792 CUM GAS AUG SEP OCT NOV GAS LIFT GAS LIFT GAS LIFT GAS LIFT 28 30 13 29 7,107 9,399 4,736 5,304 3,541 1,188 338 522 1,860 342 254 2,065 184,792 CUM WATER 20,742 CUM ~ 1,151,939 DEC GAS LIFT 31 11,368 996 3,438 30,918 DEC GAS LIFT 31 7,726 792 4,160 56,742 AUG SEP OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 31 30 31 6,659 9,951 6,730 5,865 5,927 1,577 1,785 1,848 1,978 3,828 6,612 5,075 4,738 5,838 485,055 CUM WATER 72,004 CUM GAS 229,685 AUG SEP OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 31 30 31 8,272 7,726 8,724 8,559 9,182 1,002 1,362 1,572 1,502 1,492 7,507 13,321 3,072 2,526 4,772, 391,631 CUM WATER 54,319 CUM GAS 166,530 AUG SEP OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 30 31 29 31 9,127 8,526 8,197 8,215 8,284 1,326 1,213 1,186 2,193 1,449 4,490 4,194 4,537 4,013 4,147 289,714 CUM WATER 38,343 CUM GAS 104,455 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1997 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 5,529 5,173 6,410 WTR 1,928 2,232 2,656 GAS 8,186 7,248 5,306 1997 TOTALS OIL 67,038 WATER 1998 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 3,645 3,077 3,115 WTR 4,888 4,264 4,851 GAS 3,068 2,605 2,961 1998 TOTALS OIL 9,837 WATER FIELD/POOL: MCARTHUR RIVER, UNDEFINED APR MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT GAS LIFT 30 30 30 31 7,304 7,461 10,541 4,994 1,977 2,290 2,954 3,546 3,703 6,275 4,794 35,930 GAS 57,533 CUM OIL APR 14,003 1990 JAN METH DAYS OIL WTR GAS ' 1990' TOTALS MAY JUN JUL GAS 8,634 CUM OIL SALES CD - 50 ACCT GRP - 004 ** OIL PRODUCTION ** FEB MAR APR MAY OIL 25,922 WATER 455 GAS FEB MAR APR GAS LIFT GAS.LIFT GAS LIFT 26 4 30 4,385 6,912 37,967 769 13,875 1,965 2,744 10,424 155,464 WATER 64,587 FEB MAR APR GAS LIFT GAS LIFT GAS LIFT 29 31 26 5,053 5,223 4,738 718 790 741 3,605 3,776 2,985 60,110 WATER 14,798 FEB MAR APR GAS LIFT GAS LIFT GAS LIFT 28 31 20 4,531 5,325 2,546 3,289 4,285 2,017 3,579 3,834 2,291 46,070 WATER 31,038 1991 JAN METH GAS LIFT DAYS 31 OIL 5,257 WTR GAS 2,288 1991 TOTALS OIL 1992 JAN METH GAS LIFT DAYS 27 OIL 4,431' WTR 1,603 GAS 3,010 1992 TOTALS OIL 1993 JAN METH GAS LIFT DAYS 30 OIL 4,679 WTR 2,588 GAS 4,060 1993 TOTALS OIL AUG SEP OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 31 27 30 30 31 4,922 3,480 3,662 3,849 3,713 3,720 3,797 4,852 4,172 5,352 5,128 2,084 3,364 5,110 2,789 552,093 CUM WATER 107,934 CUM GAS 287,218 AUG SEP OCT NOV DEC 561,930 CUM WATER 121,937 CUM GAS FINAL STATUS: DEV 1-OIL CURRENT STATUS: JUN JUL AUG SEP. GAS LIFT GAS LIFT GAS LIFT GAS LIFT 15 27 30 30 1,019 3,106 2,879 2,839 881 822 10,971 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 29 28 45,479 17,832 5,167 25,775 10,639 1,332 13,987 7,318 3,055 GAS 56,990 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 30 30 30 5,252 5,110 4,994 1,387 459 478 3,811 3,604 3,I53 GAS 42,691 CUM OIL MAY JUN JUL GAS LIFT GAS LIFT GAS LIFT 31 30 31 5,267 5,124 5,324 2,987 3,367 4,153 3,805 3,741 3,982 GAS 30,108 CUM OIL .1,227 1,208 25,922 CUM WATER OCT NOV GAS LIFT GAS LIFT 30 28 4,213 6,073 128 327 1,470 2,694 455 CUM GAS AUG SEP GAS LIFT GAS LIFT 31 17 4,693 3,382 701 1,256 816 890 181,386 CUM WATER OCT NOV GAS LIFT GAS LIFT 31 30 12,747 5,784 6,301 1,637 2,445 7,819 65,042 CUM GAS AUG SEP GAS LIFT GAS LIFT 24 30 4,114 5,122 1,246 926 3,072 3,933 241,496 CUM WATER 295,852 AUG SEP GAS LIFT GAS LIFT 28 30 4,050 5,175 4,096 2,966 2,990 824 287,566 CUM WATER DEC GAS LIFT 27 5,793 2,669 10,971 DEC GAS LIFT 26 5,859 2,302 3,239 67,961 OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT 13 29 31 2,293 898 858 806 253 231 267 273 462 110,878 CUM GAS 140,760 OCT NOV DEC GAS LIFT GAS LIFT GAS LIFT 31 30 31 5,513 4,990 5,570 2,797 2,094 1,559 3,741 4,035 3,966 79,840 CUM GAS 110,652 DJ~ASKA INDIVIDUAL WELL PRODUCTION AS OF 05/08/98 1994 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 31 30 31 31 30 31 29 31 OIL 998 959 1,018 993 1,009 1,029 946 1,014 947 911 916 920 WTR 455 541 534 552 533 539 568 482 441 431 468 527 GAS 284 343 380 424 516 534 413 499 466 504 457 461 1994 TOTALS OIL 11,660 WATER 6,071 GAS 5,281 CUM OIL 299,226 CUM WATER 116,949 CUM GAS 146,041 1995 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAB LIFT DAYS 31 28 31 30 31 30 31 31 30 31 30 31 OIL 1,073 766 958 879 891 958 934 919 858 969 951 1,020 WTR 481 790 403 512 563 528 527 364 495 572 546 543 GAS 487 460 529 525 465 333 556 834 942 337 280 530 1995 TOTALS OIL 11,176 WATER 6,324 GAS 6,278 CUM OIL 310,402 CUM WATER 123,273 CUM GAS 152,319 1996 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 29 31 30 31 30 31 31 30 31 30 31 OIL 1,001 947 952 906 913 895 862 740 858 748 652 659 .WTR 530 516 566 431 589 696 489 574 678 649 672 719 GAS 528 582 620 643 590 543 611 438 753 564 526 649 1996 TOTALS OIL 10,133 WATER 7,109 GAS 7,047 CUM OIL 320,535 CUM WATER. 130,382 CUM GAS 159,366 1997 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV' DEC 'METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 30 30 30 31 31 27 30 30 31 OIL 614 575 712 812 829 685 555 547 387 407 428 413 WTR 701 812 966 719 833 1,020 1,074 1,353 1,381 1,764 1,517 1,946 GAS 910 805 590 394 411 697 533 570 232 374 568 310 1997 TOTALS OIL 6,964 WATER 14,086 GAS 6,394 CUM OIL 327,499 CUM WATER 144,468 CUM GAS 165,760 1998 JAN FEB MAR METH GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 OIL 405 342 346 WTR 1,778 1,551 1,764 GAS 341 289 329 1998 TOTALS OIL 1,093 WATER APR MAY JUN JUL AUG SEP OCT NOV DEC 5,093 GAS 959 CUM OIL 328,592 CUM WATER 149,561 CUM GAS 166,719 ORIGINAL REC;EIVED ,/UN 1 9 1990 .Alaska.Oil.& Gas Cons. Commission Anchorage- 'SURVEY REPORT MARATHON OIL coMPANY 'TRADING BAY UNIT WELL NUMBER M-2B MCARTHUR RIVER Fl"ELD KEN~ BOROUGH, ALAS~ -ICROFILHED Gyrodata Directional for Survey HARATHON OIL COMPANY TR/~DING BAY UNIT WELL NUMBER M-28 McARTHUR RIVER FIELD KENAI BOROUGH, ALASKA Date Run: 04-JUN~90 23 Job Number: AS0690G229 surveyor: BOBBY BIRSS CalculatiOn Method: ~DIUS OF CL~VATURE 'ffurvey Latitude: .60deg 49min 30sec N Bearings are Relative to TRUE NORTH "Proposed Veil Direction: N 20deg 51min Osec E · , Vertical Section Calculated from ~ell Head Location '.Closure Calculated from ~ell Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata L4THON OIL COMPANY kDING BAY UNIT WELL NUMBER M-28 kRTHUR RIVER FIELD KENAI BOROUGH, ALASKA Number: ASO690G229 Directional · Survey Page MEAS INCL BORE HOLE DEPTH BEARING f t deg min dee min .0 0 0 N 0 0 E 130.0, 0 17 S 1'28 E 230.0 0 18 S 19 29 E 330.0 0 19 S 57 10 E 430.0 0'37 S 46 23 E 530.0 0 46' S 81 51 g 630.O 1 53 S 78 1E 730.O 2 12 N 86 15 ~ 830.0 20 N 80 49 E 930.0 { 47 N 74 45 E 1030.0 2 40 N 65 5g E 1080.0 2 57 N 58 32 E 1130.0 2 56 N 42 45 E 1230.0 4 6 N 20 48 E '1280.0 4,58 N ]1 59 g . 1580.0 13 21 N 13 29 E 1630.0 15. 17 N 15 5 E 1680.0 17 12 N 15 53 E 1730.0 18 17 N 17 31 E t780.0 19 35 N 19 27 E · DOG-LEG VERT VERT SEVERITY DEPTH SECTION deE/100' ft ft C L O S U R E DISTANCE BEARING ft dee min .00 .0 ,0 .0 N 0 0 E GYRODATA SURVEY RUN IN 9 5/8", 7" & 5" LINER MEASURED DEPTHS REFERENCED TO POOL 422 RKB ELEVbTION .22 130.0 -,3 .3 S 1 28 E .09 .20 .31 .44 1.12 .64 .28 .30 .95 .91 1.62 1.76 2.23 230.0 -.7 .8 S 659.E 330.0 -1.0 1.3 $ 19 9 E 430.0 ""-1.2 2.0 5,31 31 E 530.0 -1.4 3,1 S 43 22 E 630.0 -.9 5.1 S 58 51 E 729.9 .1 8.5 S 69 50 E 829.8 1.8 11.9 S 77 48 E 929.8 3.6 14.9 S 83 3 E 1029.7. 6.1 1079.6 7.9 1129.6 10.2 1229.4 16.2 1279.2 20.1 4.12 1328,9 25.2 2.92 1378.5 31.9 2.12 1427.9 39.5 1.87 1477.1 "47.9 2.45 1526.3 57.1 4.09 3,94 3,85 2.38 2.88 1575.1 6'7.7 1623.6 80.0 1671.6 ,,,93.9 1719.2 109.1 1766;5 125.3 18.5 S 88 27 E 20.6 N 88 13 E 22.7 N 84 17 E 26,9 N 73 54 E 29.2 N 67 21 E 32.4 N 59 40 E 37.1 N 51 44 E 43.2 N 44 42 E 50.5 N 39 15 E 58.9 N 35 10 E 68.9 N 31 47 E 80.8 N 29 9 E 94.5 N 27 ,9 E 109.5 N 25 42 E 125.6 N 24 46 E HORIZONTAL" COORDINATES feet .00 N .00 ~mmmm m mmmmm. .32 S' .01 E .82 S .10 E 1.24 S .43 E 1.74 S 1.07 E 2.26 S 2.13 E 2,66 S 4.40 E 2.92 S 7.94 E 2.51S 11.59 E 1.81S 14.81E .50 S 18.46 E .64 N 20.63 E' 2.27 N 22.61 E 7.45 N 25.83 E 1.24 N 26,94 E 16.36 N 27.96 23.00 N 29 15 ~"" 30.71 39.09 N 31.93 E 48.17 N 33.93 58.59 N 36.31 70.58 N ,' 39.36 84.06 N 43.10 98.65 N 47.47 , 114.03 N 52.62 A Gyrodata .~ATHON OIL COMPANY ,~DING BAY UNIT WELL NUMBER M-28 .~RTHUR RIVER FIELD KENAI BOROUGH, ALASKA Number: ASO690G239 Directional . Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft dee min dee min deE/lO0' ]830.0 21 36 N 20 49 E 1880.0 22 46 N 21 42 E 1930.0 23 59 N 21. 25 E 1980.0. 24 32 N 21 38 E 2030,0 25 9 N 21 53 E 2080.0 2130,0 2180,O 2230.0. 2280.0 2330,0. 2380.0 2430,O 2480,0 2530,0 '~2630.0 273O,0 2830,0 ..2930,O 3030,0' 3130,O "3230.0 3330.O '3430,0 3530,0 26 46 N 20 59 E 28 54 N 21 15 E 30 56 N 21 56 E 32 33 N 22 18 E 34 8 N 22 59 E 35 40 N 23 21E 37 22 N 23 47 E 38 42 N 24 21E ~ 39 16 N 24 55 E 39 39 N ~4'57 E 39 46 N 24 11E 39 14 N 24 44 E 39 9 N 24 39 E 38 44 'N 24 33 E 38 22 N 24 47 E 38 19 N 24 58 E 38 12 N 24 24 E 37 51 N 24 0 E 37 22 N 25 55 E 37 16 N.25 24 E 4,17 2,43 2.43 1,12 1,24 3.35 4.28 4.12 3,25 3.25 3,09 3.45 2.77 1.32 .78 ,50 ,63 .10 ,43 ,39 ,12 ,37 ,42 1,27 ,33 VERT DEPTH ft 1813.3 1859.6 1905.5 1951.0 1996,4 2041.4 2085.6 2128,9 2171,4 2213.2 2254,2 2294.4 2333.8 2372.7 2411,3 2488.2 2565.3 2642.8 2720.6 2798.8 2877.3 2955.8 3034.6 3113.8 3193.3 VERT SECTION ft 142.9 161.8 181.6 202.1 223.1 '*~45.0 268.4 293.3 319.6 347,1 375.7 405.4 436.1 467.5 499.2 563.0 626.4 689.5 752.2 814.4 876.3 938.0 999.5 1060.4 1120.8 C L O S U R E DISTANCE BEARING ft dee min 143,1 N 24 12 E 162,0 N 23 51 E 181.8 N 23 36 E 202.3 N 23 24 E 223.3 N 23 14 E 245.2 N 23 5 B 268,5 N 22 55 E 293.5 N 22 48 E 319.8 N 22 45 E 347.3 N 22 44 E 375,9 N 22 46 E '405,6 N 22 50 E 436,4 N 22 55 E 467,8 N 23 2 E 499.6 N 23 9 E 563,5 N 23 19 E 627,1 N 23 26 E 690,3 N 23 33 g 753,1 N 23 38 E 815,4 N 23 43 E 877.4 N 23 48 E 939,3 N 23 51 E 1000.9 N 23 52 E 1061,9 N 23 56 E 1122,5 N 24 2 E HORIZONTAL COORDINATES feet 130.54 N 58.67 148.14 N 65.52 166.59 N 72.80 185.70 N 80.34 205.21 N' 88.13 225,58 N 247.36 N 270,55 N 294,92 N 320,28 N 346.58 N 373.85 N 401.97 N 430.56 N 459.37 N 517,47 N 575,38 N 632,80 N 689.95 N 746,57 N 802.84 N 859.10 N 915.28 N 970.61 N 1025.25 N 96.13 E 104.54 E 113.72 E 123.62 E 134.20 E 145.45 E 157.34 E 169,91 E 183.02 E' 196,42 g 222,99 249,33 275,72 301.89 327.90 354.00 E 379.85 E 405.10 E 430.85 E 457.09 E A Gyrodata k%THON OIL COMPANY ,DING BAY UNIT WELL NUMBER M-28 ,RTHUR RIVER FIELD KENAI BOROUGH, ALASKA ~ Number: ASO690G229 Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft dee min dee min deE/lO0' 3630.0 37 10 N 24 21 E 3730.0 36 58 N 24 54 E 3830.0 36 50 N 24 28 E 3930.O. 36 32 N 25' 43 E 4030.0 36 26 N 25 24 E 4130.0 37 18 N 23 17 E 4230.0 37 54. N 22 16 E 4330.0 38 44 N 22 35 E 4430.0 39 33 N 22 15 E 4530.0 40 1 N 21 51 E 4630.0 39 54 N 21 25 E '' 4730.0 40 16 N 22 35 E 4830.0 40 1 N 20 47 E 4930.0 39 55 N 21 22 E 5030.0 40 11 N 21 35 E "~130.0 40 0 N 21 40 E · 5230.0 39 45 N 21 38 E 5330.0 38 51 ,, N 21 45 E 5430.0 39 11 N 22 22 E "5530.O 38 22 N 21 55 E ,. 5630.0 5730.0 5830.0 '5930.0 .6030.0 38 41 N 21 56 E 38 14 N 21 19 E' 38 37 N 20 46 E 39 6 N 21 14'E 39 16 N 20 33 E .64 .40 .29 .81 .21 1.53 .87 .85 .84 .54 .30 .83 1.18 .39 .30 .19 .25 .90' .50 .86 .32 .61 .52 .57 .47 VERT DEPTH ft 3273.0 3352.8 3432.7 3512.9 3593.3 3673.3 3752.6 3831.0 3908.6 3985.4 4062 .'1 4138.6 4215.0 4291.7 4368.2 4444.7 4521.5 4598.8 4676.5 4754.'5 4832.7 4911.0 4989.4 5067.3 5144.8 VERT SECTION ft 1181.1 1241.3 1301.2 1360.8 1,420.0 1%79.9 1540.9 1602.8 1665.9 1729.9 1794.1 1858.5 1923.0 1987.2 2051.5 2115.9 2180.0 2243.4 2306.3 2368.9 2431~2 " 2493.4 2555.5 2618.3 2.681.5 CLOSURE DISTANCE BEARING ft dee min 1183.0 N 24 4 E 1243.3 N 24' 6 E 1303.3 N 24 8 E 1363.0 N 24 10 E 1422.5 N 24 14 E 1482.5' N 24 14 E 1543.5 N 24 10 E 1605.4 N 24 6 E 1668.5 N 24 3 E 1732.5 N 23 58 E 1796.6 N 23 53 E 1861.0 N 23 49 E 1925.4 N 23 45 E 1989.6 N 23 40 E 2053.9 N 23 36 E 2118.3 N 23 32 2182.3 N 23 29 E 2245.7 N 23 26 E 2308.6 N 23 23 E 2371.2 N 23 21 E 2433.5 N 23 19 E 2495.6 N 23 17 E 2557.7 N 23 13 E 2620.4 N 23 10 E 2683.6 N 23 7 E HORIZONTAL COORDINATES feet 1080.12 N 482.53 1134.91 N 507.65 1189,46 N 532.73 1243.56 N 558.06 1297.20 N 583.72 1351.85 N 608.45 g 1408.11 N 632.07 E 1465.42 N 655.72 E 1523.77 N 679.79 E 1583,07 N 703.81 E 1642.77 N 727.49 E 1702.47 N 751.61 E 1762.37 N 775.42 E 1822.31 N 798.52 E, 1882.19 N 822.08 E 1942.07 N 845.81 E 2001.66 N 869.47 E 20'60.52 N 892.89 E 2118.87 N 916 53 F./' 21 ?6.87 N 940~13 ~[. 2234.66 N 963.39 E 2292.48 N 986.31 E 2350.47 N' 1008.62 E 2409.04 N 1031.10 E 2468.08 N 1053.63 E A Gyrodata ,RATHON OIL COHPANY ~DING BAY UNIT WELL NUMBER M-28 . :ARTHUR RIVER FIELD KENAI BOROUGH, ALASKA ~b Number: ASO690G229 Directional Survey Page NEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft dee min dee min deE/lO0' 6130.0 39 33 N 21 30 E 6230.0 39 42 N 20 46 E 63,30.0 40 35 N 20 41 E 6430.0. 40 11 ' N 21 53 E 6530.0 39 48 N 23 24 E 6630.0 39 53 N 22 35 E 6730.0 40 18 N 23 49 E 6830.0 40 20 N 24 9 E 6930.0 40 16 N 25 29 E 7030.0 40 42 N 24 6 E 7130.0 41 4 N 23 7 E 7230.0 40 33 N 19 48 E 7330.0 40 42 N 19 9 E 7430.0 41 28 N 20 5 E 7530.0 41 30 N ~18 54 E " 7630.0 41 7 N 18 2 E .. 7730.0 41 6 N 19 38 E 7830.0 41 17 N 20 21 E ...7930.0 41 39 N 20 2 E 8030.0 ' 41 28 N 21 28 E 8.130.0 41 51 N 21 23 E 8230.0 41 25 N 21 9 E 8330.0. ,.4040 N 20 45 E 8430.0 40 40 N 22 13 E 8530.0 40 28 N 20 59 E .66 .49 .88 .87 1.05 .53 .90 .22 .86 1.00 .74 2.23 .45 .99 .79 .68 1.05 .50 .43 .98 .39 .46 . .78 .96 .83 VERT DEPTH ft 5222.0 5299.1 5375.5 5451.7 5528.3 5605.1 5681.6 5757.8 5834.1 5910.'1 5985.7 6061.4 6137.3 6212.7 6287.6 6362.7 6438.1 6513.3 6588.3 6663.1 6737.8 6812.6 6888.0 6963.8 7039.8 VERT C L O S U R E SECTION DISTANCE BEARING ft ft dee min 2744.9 2808.7 2873.2 2938.0 3002.2 3066.2 3130.6 3195.2 3259.7 3324.5 3389.9 3455.2 3520.3 3586.0 3652.2 3718.2 3783.9 3849.7 3915.9 3982.3 4048.7 4115.2 4180.8 4246.0 4311.0 2747.0 N 23 4 E 2810.7 N 23 2 E 2875.2 N 22 58 E 2939.9 N 22 56 E 3004.2 N 22 56 E 3068.3 N 22 56 E 3132.7 N 22 56 E 3197.4 N 22 58 E 3262.0 N 23 0 E 3326.9 N 23 2 E 3392.4 N 23 2 E 3457.7 N 23 1 E' 3522.7 N 22 57 g 3588.3 N '22 53 E 3654.4 N 22 49 E 3720.2 N 22 45 E 3785.8 N 22 41 E 3851.6 N 22 38 E 3917.7 N 22 36 E 3984.0 N 22 34 E 4050,5 N 22 33 E 4116.9 N 22 31 E 4182.5 N 22 30 g 4247.7 N 22 29 E 4312.7 N 22 28 E HORIZONTAL COORDINATES feet 2527.33 N 1076.40 2586.82 N 1099.39 2647.12.N 1122.20 2707.49 N 1145.72 2766.80 N 1170.46 2825.78 N 1195.49 E 2884.98 N 1220.87 E 2944.09 N 1247.17 E 3002.79 N 1274.32 E 3061.73 N 1301.54 E 3121.71 N 1327.76 E 3i82.53 N 1351.67 E 3243.90 N 1373.38 E 3305.80 N 1395.44 E. 3368.24 N 1417.55 E 3430.85 N 1438.46 3493.08 N 1459.69 3554.97 N 1482.21 3617.12 N 1505.06 3679.15 N IS28.56 3741.02 N 1552.84 3802.93 N 1576.92 3864.25 N 1,600.39 3924.89 N 1624.26 '3985.36 N 1648.20 A Gyrodata .RATHON OIL COMPANY ~DING BAY UNIT WELL NUMBER M-28 ~RTHUR RIVER FIELD KENAI BOROOGH, ALASKA b Number: ASO690G229 Directional Survey Page · MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING' SEVERITY ft dee min dee min deE/lO0' 8630.0 40 18 N 22 14 E 8730.0 40 17 ' N 19 45 E 8830.0 40 3 N 20 14 E 8930.0. 39 24 N 20 11 E 9030.0 39 33 N 20 8 E 9130.0 39 13 N 20 15 E 9230,0 38 38 N 21 27 E. 9330.0 37 41 N 20 47 E 9430.0 37 8 N 22 17 E 9530.0 36 53 N 20 4 E 9630.0 36 48 N 20 35 E 9730..0 37 14 N 18 16 E 9830.0 '37 14 N 19 28 E 9930.0 36 39 N 17 20 E ]0030,0 37 0 N.16 17 E *10130.0 10230,0 10330.0 10430,0 10530,0 10630,0 10730.0 10830.0 10930.0 11030,0 36 56 N 18 16 g 37 15 N 17 19 E 37 33 N 18 55 E 37 54 'N 20' 28 E 38 6 N 22 33 E 38 34 N 22 8 E 38 30 N 22 13 E 37 44 N 22 11 E 37 57 N 22 I E 36 51 N 22 35 E .83 1,60 ,39 .65 ,15 .35 .95 ! .O3 1 ,O7 1.36 ,32 1,46 ,72 1,41 .72 1,19 ,66 1.02 1.02 1.29 .52, .08 .76 .24 1.15 VERT DEPTH ft 7116.0 7192.3 7268,7 7345.6 7a22.8 7500.1 7577,9 7656,5 7735.9 7815,8 7895.8 7975.7 8055.3 8135.2 8215.2 8295,1 8374.9 8454,3 8533,4 8612,2 8690.7 8768,9 8847,6 8926,6 9006,0 VERT C L O $ U R E SECTION DISTANCE BEARING ft ft dee min 4375.8 4440,4 4504,9 4568,8 4632,4 4B95.9 4758,7 4820.5 4881,2 4941,4 5001,4 5061.5 5122.0 5182.0 5241.8 5301.8 5362,1 5422,7 5483,9 5545.5 5607.5 ' 5669.8 5731.5 5792.8 5.,853.5 4377.5 N 22 27 E 4442.1 N 22 26 E 4506.6 N 22 24 E 4570.4 N 22 22 E 4634.0 N 22 20 E 4697,4 N 22 19 E 4760.2 N 22 17 E 4822.0 N 22 17 E 4882.7 N 22 16 E 4942.9 N 22 15 E 5002.8 N 22 14 E 5062.9 N 22 12 E 5123.3 N 22 9 E 5183.3 N 22 7 E 5243.0 N 22 3 E 5302.9 N 22 0 E 5363.1 N 21 57 E 5423.7 N 21 55 E 5484,8 N 21 53 E 5546.4 N 21 53 E 5608.4 N 21 53 E 5670.7 N 21 53 E 5732.4 N 21 53 E 5793.8 N'21 54 E 5854.5 N 21 54 E HORIZONTAL ' COORDINATES fee~ 4045.59 N 1672.05 4105.95 N 1695,21 4166,56 N 1717.27 4226.54 N 1739.35 4286.22 N 1761,26 4345.77 N 1783.15 4404.48 N 1805.52 4462.11 N 1827.78 4518.63 N 1850.07 4574.76 N 1871.81 4630.98 N 1892.64 4687.75 N 1912.66 4745.00 N 1932.23 4802.03 N 1951.20 4859.41 N 1968.53 4916.82 N 1986,38 4974,25 N 2004,80 5031,98 N 2023,68 5089.59 N 2044,30 5146.87 N 2066.87 5204.24 N 2090.44 E 5261,93 N 2113,95 E 5319.08 N 2137.27 E 5375.92 N 2160.35 E' 5432.12 N 2183.40 E !i i iii ;.':, ;'!'i'!~! 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F , I~, ~4-~,.-- - '~"- ,_'2~;. : ;.' , I.-..:. · . ...... ,, ~ ~ . ~=. .::!~::~!::" ..:.. :., :.l'-r':-,,.':. ~ '.,-~.. , -,,~ ..,_..:. . .; .-.- ..~-, , --- PERMIT~ /~;~ - /~' WELL NAME ..o COMPL,-'-TION DATE 6' j ..3./ t :~o CO. COmACT I AOGCC GEOLOGICAL MATERIALS INVENTORY UST ( check off or list data as it is received ~ "407 t/.-~/,.,/~o drilling history ~ suwey I / I ~l, t.~t. ~ I ~"'" d~drirtion d~ ditch intervals ,,, dioital data c, d in'terv~lls core,,,,,analysis~i ~ _~"/'~', i l lll I i , i i i i i i i i ii i LOG TYPE RUN INTERVALS SCALE NO. ii i ii i ...... ~X'eo/ - /,..aeoo ' c:~ '/ .. 4] 8} . . , , , , 11] , , , ,,,, , , , ~,, 13] 14] , , ,, ,, ,, , , ,, ,,, 16] ,, , , ,, .1~ I' Memorandum UNOCAL~) DOCUMENT TRANSMI'I-rAL June 26, 1990 HAND DELIVERED TO: John Boyle FROM: R. C. Warthen K. D. Kiloh LOCATION: Anchorage LOCATION: Alaska Region ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Trading Bay Unit - Steelhead M-28 Three (3) boxes - washed and dried well cuttings ~ ~ 6 .- 13°°° PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TR~NSMI'I-I'AL THANK YOU. RECEIVED BY: ~~.~_, ~"~,,~,,.-~'~ DATED: 'i~2-.~-~//?~/ ' DRM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. Memorandum UNOCAL ) ,i TO: John Boyle ALASKA OIL & GAS CONSERVATION COMMISSION DOCUMENT TRANSMITTAL June 19, 1990 HAND DELIVERED FROM: R.C. Warthen K. D. Kiloh Anchorage Alaska Alaska Region '. Transmitting as Follows: Trading Bay Unit - Steelhead M-25 1 blueline and 1 sepia: Dual Induction Focused Log/Gamma Ray Spectralog Formation Multi-Tester Log Acoustic Cement Bond Log-VDL/Signature/Gamma Ray Compensated Densilog/Compensated Neutron/Gamma Ray BHC Acoustilog/Gamma Ray Mud log 1 magnetic tape w/listing ~ CONFIDENTIAL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL.__.THANK YOU. RECEIVED BY: /~~~/ . V- DATED' RECEIVED dUN t 9 1990 Al;taka Oil & Gms Cons. uomm'tss'ton Anchorage FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. , UM State' of Alaska ALASKA OIL AMD GAS CONSERVATION CO~.~ISSION Lonnie C. Smith ~z/..... Commissioner DATE: April 4, 1990 FILE NO: JT. ~{. 439 0 TELEPHONE NO: THRU: SUBJEC'~ FROM: Mike Minder '~"~'~' Sr Petr Engineer BOP Test Union TBU M-28 Permit No. 90-19 ¥~ Rv Oil Pool Wednes,,day M. arch 28,~, 199,,0.' Testing of the BOP on Steelhead platform wa-l/ M'28 Commen~e~'~at~'10i0o~'p.m. (after a pretest in which the annular bag pressure was increas~ from 1200# to 1300~ and several connections were tightened) and-d~-ncluded at around 3:00 a.m. Thursday. There were no failures as shown on attached BOP test report. In summary, I witnessed the BOP Test on Steelhead Platform M-28 and encounted no failures. The SSSV in three wells were also tested, subject of another' report. Attachment ( STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT ION COMM I SS ION BOPE Inspection Report Location: Sec .~ T ~ R I~ ~ M ~ /~/' Cmsin, set Loae~ion (general) ., Well sign ~ ACCUHULATOR SYSTEH: General housekeeping ~ Rig / Full charge pressure ft Pump incr clos press 200 psig min ~ sec MUD SYSTEMS: V~la 1 A~o Full. ~_~oDc~h"a' rge m'' . p~.~S~ attained,.~. ~ $~ . ~ -,min .7~_ sec Pit g,.g, / J co.t.o ,: Master Flo. monitor ~ J ~ R~ote V~ Blind ,.itch cover ~.x. Gas detectors ~ J KELLY AND FLOOR SAFETY VALVES: BOPE STACK: . ;~Z.',~.,...,,,.~'..,~,.:,~.:,:.,. Annul ar preventer Pi pe rams HCR valve K~11 l~ne.'valves Check va1 ve Upper Kelly I Test pressure · ' Lower Kelly !~ Test pressure. '." .. ,.'., Tes~ Pressu..~e .... :.. ,:.,.:..:.,,,,,,,,-. ':., .........,'.,...,:,...,.. ..... :.-.,,..,,::.,,,,,::..,: ...... ~,.,,..~-LF,-~' . ' ..,,,.,,',,.~:~.,..,, ............. : ........ :.,,..,,.. ,...,. Ball type I Test pressure ,~--~'~/~,~ Inside BOP I Test Choke manifold VN~ Test / Number valves Number fl anges Adjustable chokes Hydraulically operated choke TEST RESULTS: Failures ~;~ Test time ~ hrs Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. Remarks: ~ ~/' ~~'~' days Distribution: orig - AOGCC c - Operator c - Supervisor C.O0~ (rev 03/17/89) ( ! March 22, 1990 Telecopy: (907)276-75~2 Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Re: Trading Bay Unit M-28 Revised Union Oil Company of California Permit No. 90-19 Sur. Loc. 970'FNL, 532'FW-L, Sec. 33, TgN, R13W, SM Btmhole Loc. 134'FNL, 2862'FWL, Sec. 28, TgN, RI3W, SM Dear Mr. Roberts.. Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated. February 28, 1990, accompanying the original approved pemit, are in effect for this revision. ' ' ' Ve~r~ truly yours, ' ~,,'"'? ..... 'i ./'~ .... . . Chat~aa of ',' Alaska Oil and Gas Conservation BY ,ORDER OF THE COMMISSION dlf , Enclosure ce, Department of Fish '& Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux Unocal North Ameri~' Oil & Gas Division Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL Environmental Affairs Alaska Region March 19, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REVISED - PERMIT TO DRILL WELL~-28 STEELHEAD PLATFORM Dear Mr. Chatterton-. Attached is the revised permit to drill for Well M-28 Steelhead Platform, in triplicate. This reflects a change in the Basal West Foreland target. If there are any questions, please call me at 276-7600. Sincerely, Donna M Secretary da Attachments PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill i-I~ well. Exploratory [] Stratigraphic Test [] ~ Re-Entry [] Deepen I-]I Service [] Developement Gas I--I Single Zone [] 2. Name of Operator '"""-"--- 5. Datum Elevation (DF or KB) R_EVISED UNOCAL (Marathon 0il Company, Sub-Operator) 3. Address P. O. Box 190247, Anchorage, AK 99519-0247 4. Location of well at surface 970' FNL, 532' FWL, Sec 33, T9N, R13W, S.M.' At top of productive interval 1100' FNL, 2500' FWL, Sec 28, T9N,. R13W, S.M. At total depth 134' FNL, 2862' FWL, Sec.28, T9N, R13W, S.M. 12. Distance to nearest 13. Distance to nearest well property line ADL-18730 unit boundar feet 21.5 feet 16. To be completed for deviated wells Kickoff depth 979feet Maximum hole angle38 {~ 18. Casing size Specifications - Hole Casing 26 20 16 17-1/2 13-3/8 73 12-1/4 9-5/8 500 152' KB above MSL 6. Property Designation ADL-18730/ADL-17594 7. Unit or property Name TradinK Bay 8. Well nurpber " .-28 feet Development Oil Multiple Zone 10. Field and Pool McArthur River Field "G" Oil Zone West Foreland 11. Type Bond<..2eAAC 35.0~S) Number 5194234 Equitable 9. Approxim_ate spud date IAmount $200,000 U.S. 14. Number of acres in~ depth(u~;~-~o) .... I 13,092' MD 3,840 acres 10,652' TVD feet 17. Anticipated pressure (s. a~ A~c 25.035 ---..-- Maximum surface 2,98 0 psig At total depth (TVD) 4,02 5 pslg Setting Depth Top Bottom Quantity of cement TVD (include stage data) 979 6108 sx 1450 '2100 sx 2439 sx 4000 5OO 9239 10652 *Pilot hole size - 17-1/2". **Pilot hole size - 12-1/4". Highest known gas bearing zone at 1460' TVD (AC-1 sand).' Cement volume on 16" casing base on 100% excess. Cement volume for 13-3/8" casing based on 50% excess. All other casing string cement volumes based on 30% excess, with the top of cement on production casing 500 inside surface casing· ' The lowest interval targeted for production testing, in Well M-28 is the Basal West Forel sand which is expected to correlate to the lowest sand in Well G-7 included in the West Foreland oil pool. Marathon plans to drill below the currently defined West Foreland oil pool to allow for sufficient rat hole. Any intervals showing productive oil saturations deeper than the currently defined WeSt Foreland oil pool may also be tested'. 20. Attachments Filingfee [] Pmperty plat ~ BOP Sketch ~ DiverterSketch ~ Drilling prog~m ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report E] 20 AAC 25.050 requirements [] 21. I hereby ~~a~"~h-~-~re'~'oin~ ~ ~nd correct t_o the best-~f m---"~-~wl'~'dge- --'--"--'--'-- ~___ ~Engineer -.__ Date 3/] 9/9~( Permit Number I AP~ ~ette~. -_ 90-19 m'02/'28/9Q ,! for othe~ requirements Conditions of approval Samples requir.ed t~Yes [] No Mud log r~q~Jir d- [] Yes l~No - ' Hydrogen sulfide measures [] Yes E~No Directional survey required ~,Yes [] No Required working pj, ees~re for~OPE ~1~211;}; i,~ 3M; E:[ 5M; [] 10M; ID 15M ' " ' Sub'nit in ~iplicate Form 10-401 Rev. 12-1.85 DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: M-28 FIELD: LEG: B-1 AFE No: SLOT: 3 TYPE: Trading Bay Unit, Steelhead Platform 8340-0 G/WF PRODUCER REVISION NO.: I DATE: 11101189 SURFACE LOCATION 970'FNL & 532'FWL SEC. 33, T9N,R13W FIRST OBJECTIVE: 1100'FNL & 2500'FWL SEC.28, T9N,R13W S.M. @ 8652'TVD SECOND OBJECTIVE 549'FNL & 2706'FEL SEC.28, T9N,R13W S.M. @9552'TVD BOTTOM LOCATION: 134'FSL & 2862'FEL SEC.21, T9N,R13W S.M. @10652'TYD KB ELEVATION: 160 ft. GL ELEVATION: 0 ft. MSL FORMATION ESTIMATED FORMATION TOPS POTENTIAL DEPTH{MD) DEPTH(TVD) CONTENT G-ZONE 10518' 8652' oil/water H EM LOCK 11081' 9082' oil/water WEST FORELAND 11595' 9552' oil/water BASAL W. FORE. 12599' 10477' oil/water CASING PROGRAM SET TYPE SIZE WT. GRADE THREAD FROM CONDUCTOR: 26" 267-397 DRL-QUIP Surf (preset) AUXILIARY: 16" 75 K-55 BTC Surf SURFACE: 13-318" 61 K-55 BTC Surf 68 K-55 BTC 2583' INTERMEDIATE: SET TO 975? DRLG. LINER: 1456' 2583' 4583' 10-3/4'' 55.5 ' N-80 BTC Surf 500' 9-518'' 47.0 N-80 BTC 500' 6500' 9-5~8" 53.5 N-80 BTC 6500' 11234' 7'' 29 N-80 ' BTC 11081' 12337' HOLE SIZE 26" 17-112" U/R to 20" 12-1/4" U/R to 17-112" 12-114" 8-112" PROD. LINER: 5" 18 N-80 FL-4S 12287' 12783' 6" SIZE ~;ASING DESIGN SETTING FRAC GR FORM PRSS WEIGHT GRADE pEPTH,TV @SHOE @SHOE MASP 16' 75.0# K-55 1456' 12.1 704 746 DESIGN FACTORS TENS COLL BURST 5.64 1.47 2.96 13.375' 61.0# K-55 2439' 3.28 2.02 1.26 68.0# K-55 4000' >14.0 1450 2456 7.86 1.29 1.40 10.75' 55.5# N-80 500' 9.625' 47.0# N-80 5496' 9.625' 53.50# N-80 9239' >14.0 4025 2962 7' 29.0# N-80 10,230' >14.0 2900 2962 1.21 6.78 1.29 2.02 8.01 1.30 3.49 11.16 1.59 4.74 11.4 2.09 3.78 17.70 2.83 18.0# N-80 10,652' >14.0 2800 2962 DIVERTER SYSTEM The diverter system will consist of a 29-112' x 500 psi annular preventer two 16' diverter lines each equipped with a 16' hydraulically actuated full opening ball valve and a 30' x 500 psi riser. A preselected diverter valve will open when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3~4' x 5000 psi Hydril type GK annular preventer,a 16-314' x 10000 psi Hydril double gate ram type preventer outfitted with pipe rams in the bottom and blind rams in the top, a 16-314' x 10000 psi drilling spool (mud Cross) equipped with a 4-1116' x 10000 psi outlet and a 3-1116' x 10000 psi outlet. The riser will be rated for 16-314' x 5000 psi. The choke manifold will be rated 3-1116' x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster ,and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. The blowout' preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2000 psi. MUD EQUIPMENT The solids control equipment consists of a Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. STARTING FLANGE: CASING HEAD: CSG. HEAD CLAMP: TUBING HEAD: WELLHEAD EQUIPMENT 30' MSS series 300 FMC Unihead Type II, 2 step, 16' pack-off bottom wi 21-114' 2000 psi clamp hub x 16-314' 5000 psi flanged top wi 2-1116' 5000 psi outlets 21-114' 2000 psi FMC segmented clamp FMC TC-60-ET. SPCL 16-314' 5000 psi STD BTM x 16-3/4' 5000 psi FLNGD top wi 2-1116' 5000 psi outlets and four 1/4" SCSSV control line ports CEMENTING PROGRAM AUXILIARY: 16'' @1456' MD LEAD SLURRY TYPE: Trinity lite wate cement w1.75% Halad 344 and 1% Calcium Chloride WEIGHT: 13.1 ppg. YIELD: 1.35 cu.ft/sk WATER REQ.: 6.89 gallsk PUMPING TIME: 4:00+ hrs:min EXCESS(O/o): 100 % SLURRY TOP: surface EST. QUANTITY: 1400 sx TAIL SLURRY TYPE: Premium cement w!.75% Halad 344 & 1% CaCI2 WEIGHT: 15.6 ppg, YIELD: 1.15 cu.ft/sk WATER REQ.:. 5.2 gallsk PUMPING TIME: 2:55 hrs:min EXCESS(O/o): 100 % SLURRYTOP: 950 ft.. EST. QUANTITY: 700 sx RUNNING AND CEMENTING DETAILS: I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint (float already welded onto shoe joint). 3 MIU float collar.(Baker-lok top and bottom of float collar) 4 Rig up to circulate and check float. 5 Run remaining 16" casing,(filling every joint) and land in 30" MSS flange. (install centralizers on jts. 1,2,4,6,8,1 0,12,14) 6 Circulate bottoms up with casing swedge. 7 Rig up and run 5" stab-in cementing string. 8 circulate drillpipe volume before stabbing into float shoe. 9 Stab into float shoe. 10 Circulate and condition mud. 11 Pump 10 bbls. fres~-...~ter spacer. 12 Mix and pump 35 bbls. of 11.0 ppg scavenger slurry. 13 Mix and pump 337 bbls. of lead slurry (1400 sx). 14 Mix and pump 143 bbls. of tail slurry'(700 sx). 15 Displace drillpipe. 16 Check float. 17 Pull seals out of float shoe. 18 Pull out of hole wld.p.' 19 WOC 12 hours. 20 NID diverter. 21 NIU 16~ thru-bore split-unil~ead. 22 N/U BOP stack. SURFACE: 13-318' @4583' LEAD SLURRY TYPE: Trinity Lite wate wi 1.5% Gas Ban WEIGHT: 13.2 ppg. YIELD: 1.33 cu.ft/sk WATER REQ.: 6.7 gallsk PUMPING TIME: 4:00+ hrs:min EXCESS(O/o): 50 % SLURRY TOP: Surface EST. QUANTITY: 2800 sx TAIL SLURRY TYPE: Premium cement wi .75% Gas Ban WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gallsk PUMPING TIME: 3:00+ hrs:min EXCESS(%): 50 % SLURRYTOP: 4050' ft., EST. QUANTITY: 500 sx RUNNING AND CEMENTING DETAILS: (ENSURE THAT BOWL PROTECTOR IS REMOVED!!) I Remove thread protectors and visually inspect connections. 2 Pickup'shoe joint. 3 MIU float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining casing. 6 Circulate and condition mud. 7 Pump 10 bbls. fresh water spacer. 8 Mix and pump 30 bbls. of 11.0 PI~ scavenger slurry. 9 Mix and pump 663 bbls. lead slurry (2800sx). 10 Mix and pump 105 bbls. of tail slurry (500sx) 11 Displace cement. 12 Check floats. 13 Install 16" X 13-3/8' packoff. 14 15 16 WOC 12 hours. Test BOPE. Run intermediate wear bushing. INTERMEDIATE: 9-5~8' and 10-314' @ 11234' LEAD SLURRY TYPE: Trinity Lite wate wi1.5% Gas Ban,.15%0 LWL WEIGHT: 13.2 ppg. YIELD: 1.33 cu.ft/sk WATER REQ.: 6.7 gal/sk PUMPING TIME: 4:45 hrs:min EXCESS(%o): 30 %0 SLURRY TOP: 8600' ft. EST. QUANTITY: 1700 sx TAIL SLURRY TYPE: Premium Cement w1.75% Gas Ban,.12% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gallsk PUMPING TIME: 4:00 hrs:min EXCESS(%): .30 SLURRY TOP: 10750' ft. EST. QUANTITY: 500 sx RUNNING AND CEMENTING DETAILS: (ENSURE THAT BOWL PROTECTOR IS REMOVED!I) I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint. 3 MIU float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining casing. 6 Circulate and condition mud. (Reciprocate casing throughout job). 7 Pump 10 bbls. fresh water spacer. 8 Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. 9 Mix and pump 403 bbls. lead slurry (1700sx). 10 Mix and pump 105 bbls. of tail slurry (500sx). 11 Displace cement. 12 Check floats. 13 Install 16' X 10-314' packoff. 14 WOC 12 hours. 15 NID BOP stack. 16 NIU tubing spool and BOPE. 17 Test BOPE. LINER: 7" @ 11081'-12337' Slurry Type: Premium Cement wl.2% CFR-3, .5% Halad 344, & .2% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gallsk PUMPING TIME: 4:00 hrs:min EXCESS(%): 30 % SLURRYTOP: 10990' ft. EST. QUANTITY: 250 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. MIU float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) Rig up to circulate and check floats. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. MIU swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 53 bbls. slurry. (250sx) Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. I. LINER: 5" @ 12287'-12783' SLURRY TYPE Premium Cement w1.2% CFR-3, .5% Halad 344, & .2% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gallsk PUMPING TIME: 4:00 hrs:min EXCESS(%): 30 SLURRYTOP: 12320' ft. EST. QUANTITY: 70 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. MIU float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) Rig up to circulate and check floats. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. MIU swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 15 bbls. slurry. (70sx) Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. · MUD PROGRAM DEPTH DEPTH WEIGHT VISC. WATER MUD TYPE FROM TO ppg sec/qt LOSS Surf 1456' 8.8-9.2 60-80 <30cc's Spud 1456' 11234' 9.4-9.6 40-50 <12cc's PHPA 11234' 12337' 9.6-9.8 40-50 <5cc's Ligno-Sulfonate 12337' 12783' 11.5-12.0 40-50 <5cc's Ligno-Sulfonate SPECIAL CONSIDERATIONS: Mud discharges will be monitored and reported per EPA requirements. DIRECTIONAL PLAN NORTH EAST VERTICAL DESC MD TVD INCL AZIM COORD COORD SECTION BUILD & TURN "'" '"' '";::":: ;~:~:~i:~`~::::~:;~;~::~:~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~:~;~;~:~::~::~:~:::~:: :':': .' :': ':': ::': : ' ' : : ::: : :::: : :: ::::::::::::::::::: HOLD TARG~E~z~r~e~:~=;1~8~:8~6~52~3~s3~~ ' "::'"'"==:'"":~'"'"'"'"':~:~::'""=:~:~=~='"'"'==::= :==:=~::::= ~ ::~: :~= :~: :::='~=:'"=::':':'=::' :='"::'~'::::::==::= :.:.:, :::: :::;: :.::::::::;::::: :.::::::::: :.::::: :.::::: ::::::::::: :.:.:::.:,: :::: :::.:::.:.: =========================== :::::::::::::::::::::::::::::::::::::::::::::: .'::.; :[:.::: :.:;:::.:;::::; ::::; ::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:: :: ::.:.:': ::;:::::::.; :::::.:::;':;. DROP ...... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: ·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nterference exists between the planned wellpath of M-28 and the following wells: Depth of DEPTH OF WELL DISTANCE & DIRECTION WELL M-28 INTERFERENCE WELL M-3 86.8' @ S40 20E 1050' TVD 1050' TVD M-14 114.1' @ S47 54W 950' TVD 950' TVD M-13 145.9' @ S53 23W 950' TVD 934' TVD M-25 21.5' @ N89 25W 950' TVD 950' TVD M-2 102.5' @ S33 3E 950' TVD 940' TVD M-ls/t 55.7' @ S89 52E 1290' TVD 1314' MD G-31 182.9' @ S55 39E 6310' TVD 7455' MD G-1 85.2' @ S57 35W 6770' TVD 7843' MD K-21 21.1' @ 557 35E 9140' TVD 12121' MD K-21RD 36.6' @ N87 45E '9390' TVD 12228' MD RLF-1 30.0' @ S31 35E 1550' TVD 1861' MD ,. LOGGING CONDUCTOR: No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: GRISPICalIDILI from 4583' to 1456'. GR from 4583' to Surface. INTERMEDIATE: GRISPICalIDILILDTICNLISONIC from 11234' to 4583'. PRODUCTION: GRISPICalIDILILDTICNLISONIC from 12783' to 11234'. COMPLETION: A Cement Bond log (CBIJGR) and a directional gyro- survey will be run prior to perforating. cORING PROGRAM RFT's and SWC's are planned for the G-Zone and West Foreland with 60 feet of full barrel core planned in the Basal West Foreland. TESTING PROGRAM ,Jet-pump testin.q of the Basal West Foreland Zone is planned. DRILLING PROGRAM SUMMARY FOR WELL M-28 CONDUCTOR: 26' insert pile with DriI-Quip connections is set at 979'~ AUXILIARY: Nipple up diverter and pressure test to 500 psi. Drill a 17-112' hole to 1456'KB per the directional program. Underream the 17-112' hole to 20' from 979' to 1456'. Run and cement 16' auxiliary casing with 2100 sx of cement. WOC. NID diverter. NIU 16" thru-bore split-unihead and BOPE. Test BOPE, choke manifold, and casing to 2100 psi. Run long bowl protector. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 14-314" hole from 1456' to 4583' per the directional program. Underream the 14-314' hole to 17-112' from 1456' to 4583'. Run and cement 13-518" casing with 3300 sx. Install 16' X 13-318' packoff. WOC. Test BOPE,choke manifold,and casing to 2500 psi. Run intermediate bowl protector. INTERMEDIATE: Drill float equipment and 10' of new formation. Run leakoff test. Do not exceed 14.0 ppg EMW. Drill 12-114" hole from 4583' to 11234' per the directional program. Run E-logs. Run and cement 9-5~8" and 10-314' casing with 3200 sx. Install 16" X 10-314' packoff. WOC. Test BOPE, choke manifold, and casing to 3000psi. Run short bowl protector. DRILLING LINER: Drill float equipment and 10' of new. formation. Run leakoff test. DO not exceed 14 ppg. EMW. Drill 8-112" hole from 11234' tO 12337' per directional program. Run E-logs. Run and cement 7' liner with 250sx. Set hanger and POOH with drill pipe. PRODUCTION LINER: Cleanout liner lap and test to 3000 psi. Drill float equipment and 10' of new formation.' Run leakoff test. Do not exceed 14 ppg. EMW. Drill 6" hole from 12337' to 12783' per directional program. Cut full barrel cores of the Basal West Foreland as per coring program. Run E-logs. Run and cement 5" liner with 70sx. Set hanger and POOH with drill pipe. .. COMPLETION: Cleanout 'casing to PBTD. Run gyro survey and CBL(under pressure). Perforate the Basal West Foreland and test with jet pump. If successful complete well in this zone. If unsuccessful squeeze the Basal West Foreland perforations. Perforate the West Foreland and G-zone sands with TCP guns. Run the completion equipment, gator-hawking each connection to 5000 psi. Space out and land tubing, set packer. Nipple down BOPE. Nipple up tree. 'Put well on production. The lowest interval targeted for production testing in well M-28 is the Basal West Foreland Sand which is expected to correlate to the lowest sand in Well G-7 included in the West Foreland Oil Pool. Marathon intends to drill below the currently defined West Foreland Oil Pool to allow for sufficient rat hole. Any intervals showing productive oil saturations deeper than the currently defined West Foreland Oil Pool may also be tested. HORI zr'NTAL PROJEOTION IN. - 1000 FEET · . . MARATHON OZL Compmny_- Lege B-I, Slotl ;5. Well Noe H-28 Revlaed Pr'opomml STEELHEAD Pletf'or... Cook Inlet. Aleek. ?000 6000 _ 5000 _ 4000 _ :3000 . 2000 _ 1 000 _ 1 000 i WEST-EAST 1000 0 1000 2000 3000 I I I I 'rD LOOAT !ON ~ 134' FILL, ~' FI4. BEC. gS. TgN. RI31~ TARGET TVD-1041q' THD-I EGG~ NORTH ~OS4, EAST ~110 TARGET el TflD-10518 I)EP,=SSI3 NORTH S150 EAST Im TARGET el LOCATION. 1100' FILL. g~O0' Fill ~EO. ~. TgN. RI31/ TARGET e3 LOCATION, 1~8' FILL. 2~42' Fill lEO, ~8. TgN. R131/ TARGET 'rvl)=9552 DEP-~IOI NORTH ~6701 EAST 2174 TARGET e2 LOCATIONs 54~' FILL', 9.7'0~' FIdL ~EC. 28. TON. R131~ SURFACE LOOAT!ON ~ 97'0' FSL. 532' Iq/L ~ "'~ TgN. RI31/ . . N 20 DEO 51 MIN E 6545' (TO TD) 1 O0 5O 0 50 100 1 50 200 300 250 2OO 150 1 O0 5O '0 50 100 56 58 6O 18 10 22 4O ~0 I I 64 16 ,'14 10 I I I I I I I 16 I I I I I 2 66 6 18 500 25(] 20C 15C 1 O( 5O 50 10 1 O0 50 0 50 1 O0 1 50 200 1 O0 20O 3OO ~oo Soo .~oo 100 I000 )00 ~00 ?00 6OO 50,0 400 300 7700 ;500 7800 ~000 O0 3,00O 2900 2800 2700 260O 2500 / I 24O0 I ? 2600 000 / / 2500 . / I I f 3100 I / / f 3000 I / I 2900 / / I ? 2800 I / / !700 ;8O0 4800 5000 7100 7200 5200 i0 540O 5300 '500 ;200 5500 7900 I I I I I .I I I _1 110C 100C 90O 800 700 600 500 400 300 I 100 I 200 300 I 400 I 500 I 600 SO0 400 500 SOO ?00 800 900 1 900 1 901 I I 4200 ! 1 80O 1700 4100 4000 3900 3800 ~00 3400 3300 3200 3600 3500 I I I / I / / / / ~ 3600 / / / ~.3500.. I / I ! =~oo I I t 4200 I I / t 4100 I / / /4000 I I / 3900 3800 1600 I 1500 I' I 1 400 I I 1300 I I 1200 I 1100 000 180~ 170~ 160 150 1 O0 20O 6000 s~oq 6400 6300 )0 6200 61 O0 140 130 120 110 300 400 500 600 700 800 900 600 ZOO 800 900 1000' ] 1 O0 ! 200 2700 I 270~ 2600. 2500 _ 2400 _ 2300 _ 22OO _ 2100 _ 2000 1900. 1 O0 4800 4700 5200 51 O0 5000 5300 / 5400 i I ! 5300 ! ~2oo ! $~oo ! ! / 5000 / / I ! / ,,.900 I / ! / ,moo I / I ~' 47'00 I" / 600 , 700 800 900 1 000 11 O0 1200 .2601 .250~ .240~ .230~ .220, .210~ 200~ 1 901 900 1000 1 1 O0 1 200 .1 300 ~1400 1.500 3500 3501 900 1 000 11 O0 1 200 1 300 1 400 1 500 ! I 3400. t / 340~ / 6~oo I - I ' / I I ' 3300. 3;30~ I / 6~oo ~ I 3200 _ I )o / 320~ / , I I ! 6ooo ~ I I O0 I :3100_ I' 310~ .I 6000 lO0 i ,00 I I ;00 I , I 5eoo ! ~oo 3ooo_I / I 3oo, I / I I / 2900 _ ~ / ... I 290, ~15600 I I ~ I I 27'00 270, 1 200 1 300: 1 400. 1 500 1 600 1700 ! 800 4~00 4.200 _ 4100_ 4000 _ $900 ..... i~ 7~500 ! r4oo i1 il?~0o ' ! Y OO11 'i'200 ! O0 I I FO0 9200 I / 430C .420C . 410C _ 400C 390C )80O )700 )600 )500 I // I . ?ooo ~0 '1l ~', ) i 6600 I I / / )0 9400 9500 3800 3600 3500 1200 1:300 1 400 1 500 1600 1700 1800 ; : 800 1900 2000 2100 2200 2300 2400 ..- ._..._ 5901 s~oo I ~ I [ 9000 'f 9900 I I ! 9800 .580~ 5800.', 1880o ol /., 9700 , oo ~?oo.I ~ I ~oo.I , ~ ~,oo~[ ~oo _ I ] ~ i/t 9*00 9500 5500. ~ ] _550( I ~ I [ f91 / I 5400 [ / 9200 . . 540( /~ooo I / I / '1 t s~oo9~oo 5300 530( I I /~,oo / 9400 5200 ] / 520~ ~ 8700 I ~ I / 9500 I ~ I ~oo _ - -4 .............. 800 1900 2000 21 O0 2200 2300 2400 HARATHON OIL Coml!. " Leg, B-l, Slot, 3,r~.~ll N , H-28 Revleed Pr.~=~oeal STEELHEAD Platrorm, Cook ;nlet. Alaeke 0 . RKB EL£VAI'~O#~ 152' 1 000 . 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000 _ KOP / 26" CSG PT TVD-9?9 THD-979 OEP-4 16" CSG PT TVD-1450 THD-1455 DEP-62 2.5 DOGLEG / I oo FT EOC TVD-2361 TMD-2476 DEP-503 13 3/8" CSG PT TVD-4000 TMDm4570 DEP-1808 PlAX I HUM AN GLE 38 DEG 32 HI N T~,,,,~., # 1 / G z.u,,~r.. :~. I ¥ U--OU,,,./~-.., /I IU--' I VN,~ i U i./t.,.i --,,./q,.~ I N.~ \ 9000 9 5/8" CSG PT TVD=9239 TMD=11234 DEP=5923 ~ TAROET #2 / I/EST FORELAND X_ ~oP~ ~o T~RGET ~NGLE TVD=9552 TMD=I 1 595 DEP=6101 --~PER 100 FT 11 ooool ...... D EG, 4 M I N . = - = = 7 CSO Pl' TVD 10230 T~D 123BZ DEP 6403 TARGET #3 / BASAL W FORELAND -~- .TVD= 1047Z TMD= 12599 DEP=6489 TD / 5 LINER TVD=10652 TMD=12Z8$ DEP'6545 uuu, m [ [ m [ [ 0 1000 2000 3000 4000 5000 6000 7000 February 28, 1990 Telecopy, (907)276-7542 Candaee Lockwood Environmental Analyst Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Res Trading Bay Unit M-28 Union 0tl Company of California Permit No. 90-19 Sur. Loc. 970'FNL, 532'FWL, Sec. 33, T9N, R13W, SM Btmhole Loc. 500'FSL, 2780'FEL, Sec. 21, T9N, R13W, SM Dear Ms. Lockwood Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipmmt so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ruly~your~s, c. v. Ch~terton Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMJ~ISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o eric!. Mr. Bill H. Lamoresux Unocal North Americanl," Oil & Gas Division J Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL ) Environmental Affairs Alaska Region February 16, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REVISED DRILLING AND COMPLETION PROGRAM - WELL M-28 Dear Mr. Chatterton: Please replace the enclosed drilling and completion programs for well M-28 with the ones that were originally.submitted to you on January 15, 1990 in the permit to drill. If you have any questions concerning the above, please call me at 276-7600. Sincerely, Secretary da Enclosures RECEIVED ..... '~'"~'~ .~Jit & Gas Cons. ',, ~cl~Or~..C~:~'~i,~,..~ ,. ' ~.,..;... DRILLING AND COMPLETION PROGRAM MARATHON OIL COMPANY ALASKA REGION WELL: M-28 FIELD: LEG: B-1 AFE No: SLOT: 3 TYPE: Trading Bay Unit, Steelhead Platform 8340-0 G/WF PRODUCER REVISION NO.: 0 DATE: 11101189 SURFACE LOCATION 970'FNL & 532'FWL SEC. 33, T9N,R13W FIRST OBJECTIVE: 1100'FNL & 2500'FWL SEC.28, T9N,R13W S.M. @ 8652'TVD SECOND OBJECTIVE 300'FNL & 2800'FEL SEC.28, T9N,R13W S.M. @9652'TVD BOTTOM LOCATION: 500'FSL & 2780'FEL SEC.21, T9N,R13W S.M. @10652'TVD KB ELEVATION: 152 ft. GL ELEVATION: 0 ft. MSL ESTIMATED FORMATION TOPS POTENTIAL FORMATION DEPTH(MD) DEPTH(TVD) CONTENT G-ZONE 10531' 8652' oil/water H EM LOCK 11081' 9082' oil/water WEST FORELAND 11812' 9652' oil/water BASAL W. FORE. 12900' 10502' oil/water CASING PROGRAM SET TYPE SIZE WT. GRADE THREAD FROM CONDUCTOR: 26" 267-397 SET TO Ailchor~ ,.. ~ :. , ..~., . HOLE SIZE DRL-QUIP Surf 975' 26" {greset) AUXILIARY: 16" 75 K-55 BTC Surf SU R FAC E: 13-3~8" 61 K-55 BTC Surf 68 K-55 BTC 2583' 1456' 2583' 4583' INTERMEDIATE: DRLG, LINER: 10-3/4" 55.5 N-80 BTC Surf 500' 9-5/8'' 47.0 N-80 BTC 500' 6500' 9-5/8'' 53.5 N-80 BTC 6500' 11282' 17-1/2'' U/R to 20" 7'' 29 N-80 BTC 11081' 12-114'' U/R to 17-1/2'' 12-1/4" 12552' 8-1/2" PROD. LINER: 5'' 18 N-80 FL-4S 12452' 13092' 6'' bASING DESIGN SIZE SETTING FRAC GR FORM PRSS DESIGN FACTORS WEIGHT GRADE DEPTH,TV @SHOE @SHOE MASP TENS COLL BURST 16" 75.0# K-55 1456' 12.1 704 746 5.64 1.47 2.96 13.375" 61.0# K-55 2439' 3.28 2.02 1.26 68.0# K-55 4000' >14.0 1450 2456 7.86 1.29 1.40 10.75" 55.5# N-80 500' 1.21 6.78 1.29 9.625" 47.0# N-80 5496' 2.02 8.01 1.30 9.625'~ 53.50# N-80 9239' >14.0 4025 2962 3.49 11.1 6 1.59 29.0# N-80 10,230' >14.0 2900 2962 4.74 11.4 2.09 18.0# N-80 10,652' >14.0 2800 2962 3.78 17.70 2.83 DIVERTER SYSTEM The diverter system will consist of a 29-112" x 500 psi annular preventer two 16" diverter lines each equipped with a 16" hydraulically actuated full opening ball valve and a 30" x 500 psi riser. A preselected diverter valve will open when the annular is closed. The direction of flow can be changed without opening the annular. BLOWOUT PREVENTERS The blowout preventer stack will consist of a 16-3/4" x 5000 psi Hydril type GK annular preventer,a 16-314" x 10000 psi Hydril double gate ram type preventer outfitted with pipe rams in the bottom and blind rams in the top, a 16-3/4" x 10000 psi drilling spool (mud cross) equipped with a 4-1116" x 10000 psi outlet and a 3-1116" x 10000 psi outlet. The riser will be rated for 16-3/4" x 5000 psi. The choke manifold will be rated 3-1/16" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor- boy gas buster ,and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. The blowout preventers, choke manifold and associated equipment will be pressure tested to 250 psi and to 3000 psi with the exception of the annular which will be tested to 250 psi and to 2000 psi. MUD EQUIPMENT The solids control equipment consists of a Brandt dual tandem shale shaker, a Brandt 2-cone desander, a Brandt mudcleaner, and a Brandt centrifuge. STARTING FLANGE: CASING HEAD: CSG. HEAD CLAMP: TUBING HEAD: WELLHEAD EQUIPMENT 30" MSS series 300 FMC Unihead Type II, 2 step, 16" pack-off bottom w/21-1/4" 2000 psi clamp hub x 16-314" 5000 psi flanged top w/2-1/16" 3000 psi outlets 21-114" 2000 psi FMC segmented clamp FMC TC-60-ET. SPCL 16-3~4" 5000 psi STD BTM x 16-3/4" 5000 psi FLNGD top wi 2-1116" 5000 psi outlets and four 1/4" SCSSV control line ports CEMENTING PROGRAM AUXILIARY: 16" @1456' MD LEAD SLURRY TYPE: Trinity lite wate cement w/.75% Halad 344 and 1% Calcium Chloride WEIGHT: 13.1 ppg. YIELD: 1.35 cu.ft/sk WATER REQ.: 6.89 gal/sk PUMPING TIME: 4:00+ hrs:min EXCESS(O/o): 100 % SLURRY TOP: surface EST. QUANTITY: 1400 sx TAIL SLURRY TYPE: Premium cement w/.75% Halad 344 & 1% CaCI2 WEIGHT: 15.6 ppg. YIELD: 1.15 cu.ft/sk WATER REQ.: 5.2 gal/sk PUMPING TIME: 2:55 hrs:min EXCESS(O/o): 100 % SLURRY TOP: 950 ft. EST. QUANTITY: 700 sx RUNNING AND CEMENTING DETAILS: I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint (float already welded onto shoe joint). 3 MIU float collar.(Baker-lok top and bottom of float collar) 4 Rig up to circulate and check float. 5 Run remaining 16" casing,(filling every joint) and land in 30" MSS flange. (install centralizers on jts. 1,2,4,6,8,1 0,12,14) 6 Circulate bottoms up with casing swedge. 7 Rig up and run 5" stab-in cementing string. 8 circulate drillpipe volume before stabbing into float shoe. 9 Stab into float shoe. 10 Circulate and condition mud. 11 Pump 10 bbls. fresh water spacer. 12 Mix and pump 35 bbls. of 11.0 ppg scavenger slurry. 13 Mix and pump 337 bbls. of lead slurry (1400 sx). 14 Mix and pump 143 bbls. of tail slurry (700 sx). 15 Displace drillpipe. 16 Check float. 17 Pull seals out of float shoe. 18 Pull out of hole w/d.p. 19 WOC 12 hours. 20 N/D diverter. 21 NIU 16" thru-bore split-unihead. 22 NIU BOP stack. SURFACE: 13-3/8" @4583' LEAD SLURRY TYPE: Trinity Lite wate wi 1.5% Gas Ban WEIGHT: 13.2 ppg. YIELD: 1.33 cu.ft/sk WATER REQ.: 6.7 gal/sk PUMPING TIME: 4:00+ hrs:min EXCESS(O/o): 50 % SLURRY TOP: Surface EST. QUANTITY: 2800 sx TAIL SLURRY TYPE: Premium cement w/.75% Gas Ban WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gal/sk PUMPING TIME: 3:00+ hrs:min EXCESS(O/o): 50 % SLURRY TOP: 4050' ft. EST. QUANTITY: 500 sx RUNNING AND CEMENTING DETAILS: (ENSURE THAT BOWL PROTECTOR IS REMOVED!I) I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint. 3 M/U float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining casing. 6 Circulate and condition mud. 7 Pump 10 bbls. fresh water spacer. 8 Mix and pump 30 bbls. of 11.0 ppg scavenger slurry. 9 Mix and pump 663 bbls. lead slurry (2800sx). 10 Mix and pump 105 bbls. of tail slurry (500sx) 11 Displace cement. 12 Check floats. 13 Install 16" X 13-3/8" packoff. 14 WOC 12 hours. 15 Test BOPE. 16 Run intermediate wear bushing. INTERMEDIATE: 9-518" and 10-3/4" @ '11282' LEAD SLURRY TYPE: Trinity Lite wate w/1.5% Gas Ban,.15% LWL WEIGHT: 13.2 ppg. YIELD: 1.33 cu.ft/sk WATER REQ.: 6.7 gal/sk PUMPING TIME: 4:45 hrs:min EXCESS(O/o): 30 % SLURRY TOP: 8600' ft. EST. QUANTITY: 1700 sx TAIL SLURRY TYPE: Premium Cement w/.75% Gas Ban,.12% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gal/sk PUMPING TIME: 4:00 hrs:min EXCESS(%): 30 % SLURRYTOP: 10750' ft. EST. QUANTITY: 500 sx RUNNING AND CEMENTING DETAILS: (ENSURE THAT BOWL PROTECTOR IS REMOVED!!) I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint. 3 M/U float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining casing. 6 Circulate and condition mud. (Reciprocate casing throughout job). 7 Pump 10 bbls. fresh water spacer. 8 Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. 9 Mix and pump 403 bbls. lead slurry (1700sx). 10 Mix and pump 105 bbls. of tail slurry (500sx). 11 Displace cement. 12 Check floats. 13 Install 16" X 10-3/4" packoff. 14 WOC 12 hours. 15 NID BOP stack. 16 N/U tubing spool and BOPE. 17 Test BOPE. LINER: 7" @ 11081'-12552' Slurry Type: Premium Cement w/.2% CFR-3, .5% Halad 344, & .2% LWL WEIGHT: 15.6 ppg. YIELD: 1.18 cu.ft/sk WATER REQ.: 5.2 gallsk PUMPING TIME: 4:00 hrs:min EXCESS(O/o): 30 % SLURRY TOP: 10990' ft. EST. QUANTITY: 250 sx RUNNING 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 22 AND CEMENTING DETAILS: Remove thread protectors and visually inspect connections. Pickup shoe joint. MIU float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) Rig up to circulate and check floats. Run remaining liner. Make up liner hanger and running tools. Run liner in hole on 5" drillpipe. When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. Continue in hole until 30' from desired depth. MIU swivel, manifold, flag sub and single on top of drill string. Continue to depth, circulate and condition mud. Reciprocate and rotate liner throughout job. Pump 10 bbls. fresh water spacer. Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. Mix and pump 53 bbls. slurry. (250sx) Displace cement. Set liner hanger. Release liner setting tool. Pull 10 stands. Reverse out drillpipe volume. POOH. WOC 12 hours. LINER: 5" @ 12452'-13092' SLURRY TYPE Premium Cement wl.2% CFR-3, .5% Halad 344, & .2% LWL WEIGHT: YIELD: WATER REQ.: PUMPING TIME: EXCESS(%): SLURRY TOP: EST. QUANTITY: 15.6 ppg. 1.18 cu.ft/sk 5.2 gal/sk 4:00 hrs:min 30 % 12320' ft. 70 sx RUNNING AND CEMENTING DETAILS: I Remove thread protectors and visually inspect connections. 2 Pickup shoe joint. 3 M/U float shoe and float collar. (Baker-lok float shoe and top and bottom of float collar) 4 Rig up to circulate and check floats. 5 Run remaining liner. 6 Make up liner hanger and running tools. 7 Run liner in hole on 5" drillpipe. 8 When shoe of liner is 250' above csg shoe perform rotate and recip, torque test. 9 Continue in hole until 30' from desired depth. 10 MIU swivel, manifold, flag sub and single on top of drill string. 11 Continue to depth, circulate and condition mud. 12 Reciprocate and rotate liner throughout job. 13 Pump 10 bbls. fresh water spacer. 14 Mix and pump 20 bbls. of 11.0 ppg scavenger slurry. 15 Mix and pump 15 bbls. slurry. (70sx) 16 Displace cement. 17 Set liner hanger. 18 Release liner setting tool. 19 Pull 10 stands. 20 Reverse out drillpipe volume. 21 POOH. 22 WOC 12 hours. MUD PROGRAM DEPTH DEPTH WEIGHT rISC, WATER MUD TYPE FROM TO ppg sec/qt LOSS Surf 1456' 8.8-9.2 60-80 <30cc's Spud 1456' 11282' 9.2-9.4 40-50 <12cc's Gel/Benex 11282' 13092' 9.2-9.4 40-50 <5cc's Ligno-Sulfonate SPECIAL CONSIDERATIONS: Mud discharges will be monitored and reported per EPA requirements. DIRECTIONAL PLAN NORTH EAST , VERTICAL DESC MD TVD INCL AZlM COORD COORD SECTION BUILD & TURN ::,?,'::::: ::::::::::::::::::::::::::::::::: ,~.',:: '.::::::::::::::::::::::::::: :.',:,: :,:: :.: :..,: ~ :':':':':':':':':':':':':':':"':' ..,. ,.,,., ,. ................. ... ,.. ,.,., ................. ,.,.....,.,,.,,,,..,,..., ..,,.., .. En~=,'.0.f.:::Ba.". ~1'~:= .................... 2.".4.".".4,"'.9.' ............... ~A".".4.'; ............. ~=.~"'~ .............. N2~:=~:~E ....... ."'.4!'.5"~'.'~ .~':.~'.~ ~ '~:~,.:-' ....... ~::?==~= ............. ?=~:=.::~:~?===~===~=.~:=~=:==~.==?~~ i i~=~i~ :~ ~=:~:=~=.= :::::::::::::::::::::::::::: i~. =~==~.~.~, ~.-..~!. =:~ili::====i:===~==i=: ...... ~ ~. ?=.. ~. HOLD ....... ;:;;: ":::::: ;:;:::::::: :'::::::":::::::::: ~ :; ::;:: ::::' ':;: :'::":;:" : ; ::::::::::::::::::::::: ':::;::::":::::::: ........ ;':':':':: :':':: ',;;:;:: :':';':':':':':':';';';': :':':': DROP & TURN ?:i:'::!'"'":::'"": .......... iiiiiii!iii[iiii!!i!!ii~i[ii!!!!! :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.'.:.:.:.: '.: .'::. ,:.,:.'.:.': .... :.:.=:;. :.::...: .:.:.: .......... .... ............ ,,,...,.....,...,,.,,.,..,,..,,.,..,,..,,..,,,.,..., ...... · ................ :,:.:.:,:.:.,.:.:.,.:.:.,,:.:,:.:.:,:.:,:,:,:.:,:.:,:,:.:,:.:,. .............. :.:.:,::::::::;: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :,::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::.::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::: HOLD ........ : ............ i:'"":': ......... '::~:: ......... ::::: ............................. ~ ............ :'":'~ : ....................... ' .................................. ,,...,.,.,,:,,,:,:.:.:,:.:::::::: :,.:::: ................ :,:.:,:.:.:,:.:,:.:,,.:.:.:.:.:,,,:.:::: .......... ,,, ..., .:. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: : :,:::::::::: :.::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::: ::: :::,: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Interference exists between the planned wellpath of M-28 and the following wells: Depth of WELL DISTANCE & DIRECTION WELL M-28 M-3 86.8' @ S40 20E 1050' TVD M-14 114.1' @ S47 54W 950' TVD M-13 145.9' @ S53 23W 950' TVD M-25 21.5' @ N89 25W 950' TVD M-2 102.5' @ S33 3E 950' TVD M-ls/t 53.2' @ N82 50E 1350' TVD DEPTH OF INTERFERENCE WELL 1050' TVD 950' TVD 934' TVD 950' TVD 940' TVD 1343' TVD LOGGING CONDUCTOR: No logging is planned for this interval. AUXILIARY: No logging is planned for this interval. SURFACE: GR/SP/Cal/DIL/from 4583' to 1456', GR from 4583' to Surface. INTERMEDIATE: GR/SP/Cal/DIL/LDT/CNL/SONIC from 11282' to 4583', PRODUCTION: GRISPICalIDILILDTICNLISONIC from 13092' to 11282'. COMPLETION: A Cement Bond log (CBL/GR) and a directional gyro- survey will be run prior to perforating. CORING PROGRAM RFT's and SWC's are planned for the G-Zone and West Foreland with 60 feet of full barrel core planned in the Basal West Foreland. TESTING PROGRAM Jet-pump testin.q of the Basal West Foreland Zone is planned. DRILLING PROGRAM SUMMARY FOR WELL M-28 CONDUCTOR: 26' insert pile with DriI-Quip connections is set at 979'. AUXILIARY: Nipple up diverter and pressure test to 500 psi. Drill a 17-112' hole to 1456'KB per the directional program. Underream the 17-112' hole to 20' from 979' to 1456'. Run and cement 16' auxiliary casing with 2100 sx of cement. WOC. NID diverter. N/U 16' thru-bore split-unihead and BOPE. Test BOPE, choke manifold, and casing to 2100 psi. Run long bowl protector. SURFACE: Drill float equipment and 10' of new formation. Run leak off test. Do not exceed 14.0 ppg. equivalent test pressure. Drill 14-3/4' hole from 1456' to 4583' per the directional program. Underream the 14-314' hole to 17-112" from 1456' to 4583'. Run and cement 13-518' casing with 3300 sx. Install 16' X 13-3/8' packoff. WOC. Test BOPE,choke manifold,and casing to 2500 psi. Run intermediate bowl protector. INTERMEDIATE: Drill float equipment and 10' of new formation. Run leakoff test. Do not exceed 14.0 ppg EMW. Drill 12-114" hole from 4583' to 11282' per the directional program. Run E-logs. Run and cement 9-5/8" and 10-3/4" casing with 3200 sx. Install 16" X 10-3/4" packoff. WOC. Test BOPE, choke manifold, and casing to 3000psi. Run short bowl protector. DRILLING LINER: Drill float equipment and 10' of new formation. Run leakoff test. Do not exceed 14 ppg. EMW. Drill 8-1/2" hole from 11282' tO 12552' per directional program. Run E-logs. Run and cement 7" liner with 250sx. Set hanger and POOH with drill pipe. PRODUCTION LINER: Cleanout liner lap and test to 3000 psi. Drill float equipment and 10' of new formation. Run leakoff test. Do not exceed 14 ppg. EMW. Drill 6" hole from 12552' to 13092' per directional program. Cut full barrel cores of the Basal West Foreland as per coring program. Run E-logs. Run and cement 5" liner with 70sx. Set hanger and POOH with drill pipe. COMPLETION: Cleanout casing to PBTD. Run gyro survey and CBL(under pressure). Perforate the Basal West Foreland and test with jet pump. If successful complete well in this zone. If unsuccessful squeeze the Basal West Foreland perforations. Perforate the West Foreland and G-zone sands with TCP guns. Run the completion equipment, gator-hawking each connection to 5000 psi. Space out and land tubing, set packer. Nipple down BOPE. Nipple up tree. Put well on production. The lowest interval targeted for production testing in well M-28 is the Basal West Foreland Sand which is expected to correlate to the lowest sand in Well G-7 included in the West Foreland Oil Pool. Marathon intends to drill below the currently defined West Foreland oil Pool to allow for sufficient rat hole. Any intervals showing productive oil saturations deeper than the currently defined West Foreland Oil Pool may also be tested. Fillup Line Flow Line Hydril 16-8/4' 5000 psi Type GK Annular I~ill Line ,. 16-3/4' 10,000 psi Doubiegate Check Valve Gate Valve Gate Valve Pips Rams Blind Rams ~~~-.~ C.~.hoke Line Gate Valve HCR Valve · Pipe Rams 16-8/4' lO,O00.psi 81nglegate 16-3/4' 5000 psi Riser 8TEELHEAD PLATFORM Preventer Schematic Ball Valve Wellhead STEELHEAD .PLATFORM CHOKE MANIFOLD. TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS A -~--, I I I I f CHOKE LINE I I I I A---_I I I I I I I I I I I I I o · "" SWACO .SECTION AA ALL VALVES IN FLOW PATH .~RE 3-1/16' 5000 PSI CAMERON GATE TYPE Plan View STEELHEAD PLATFORM . . DiVERTER SYSTEM Rig Substructure N Substructure I 1 29-112° 500 Rig ! ~ MSP Annular 16~ 'DIy~rter Line ' ~ 16' Remote Operated Ball Valve Section View Ceramite filled 81eaves 16' 'Diverter Line Riser Conductor 29-1/2' 500 psi Flange .. . u,~.. . "~ 4 O + 4. 4. .e, · · ~, J -' =, .. ~. ~.~.- I' I 1~ 1~_ ___lJ7 16 15 ,' 14 ', T9N-R 13NI -- I I a,.4~_ 19 20 2 1 22 2~ flRCO I~OZ flRCO IO0~ RRCQ IOOZ I HBUI HBU UN]ON 50~ HBU ROL-;tp68 . ROL-~8??? HRRRTHON 50Z RDL-J877~ I ' ' ' HBU ' · RDL- ]7594 0'''~', ~-~ I , I . 30 29 28 27 I i - , UNION 5 · ~RCO. tn --- 3 1 32 33 ajar-ts? o 35 HBU .' RDL_I87SB . 2 i 6 5 4 J 3 I :, r--j I IRRCO'mOIHBU I 7 8 ~ ~gL-17579"BU flDL-1760a ,I ! hDL-~87~9 14 13 18 17 ,_~ 15 ITeN-R13. I ' 26 ~S 30RRCO ]OOZ 29 28 27 HBU _ _ RbL-tS~S .~ i ii i i i STATE OIL & GAS IFASES ADL-17579 TRACT 2 2,2~0.00 Acres ADC-17594 1RACT 3 4,956.00 Acres ADC-17602 TRACT 6 640.00 Aores Ai:X.-18716 TRACT .9 ~62.50 Acres AJ:X.-18729 TRACT 10 :),085.00 Acres ADL-187:~O TRACT 11 2,880.00 Ac=es ADL-18758 TRACT 13 480.00 Acres ADC-18772 TRACT 1~ 1,600.00 Acres ADL-18777 TRACT 17 796.00 Acres N:X.-21068 TRACT 18 160.00 Acres llITAL STATE: AI~EAr~' 17,2~9..~:) Acres TOTAL UNIT ACREAGE 17~2c)9.50 Acres EXHIBIT 'A" TRADING BI~Y UNIT SCALE: 1'.'6000 REVISED 8/3/6 Teleeopy ~1o. (907) 276-7542 January 29, 1990 A D M I N I S T R A T I V E A P P R O V A L M O. 80.56 Re: The application of Union Oil Company Oil Company of. "' California, operator of the Trading Bay Unit (TBU), to drill and complete the TBU M-25 well as part of the pressure maintenance project approved by Conservation Order No. 80. Ma Kevin A Tablet Landman UNOCAL Corp P 0 Box 190247 Anchorage, AK 99502-0247 Dear Mr Tablet.. Your application of January 12, 1990 stated that the drilling and completion of the TBU M-28 well will"prOvide additional oil recovery from the Middle Kenai "G" and West Foreland oil pools. The Alaska Oil and Gas Conservation Commission hereby 'authorizes the drilling and completion of the TBU M-28 well pursuant to mule 5 of Conservation Order No. 80.' ....... : ..... , . Sincerely, Commissioner BY ORDER OF TBE CO.~9{ISSION' dlf/3.AA80 ' ' Unocal Oil & Gas Divi~ Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Robert T. Anderson Manager, Lands Alaska Region January 12, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 TRADING BAY UNIT State of Alaska Application to Drill and Complete H-28 McArthur River Field Gentlemen: Union Oil Company of California, as Operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State ~ell M-28 ~cArthur River Field "G & West Forelands oil zones" pursuant to Rule 5, Conservation Order No. 80, The proposed completions will result in additional recovery from these zones. Your approval of this request will be appreciated. KAT/clh ~, ....:,..." (45001) "'.,.. , , ,, cc: B. Penn - Marathon R. Warthen - Unocal V~y truly yours, "~vin A. Tab:let, , · 'Landman ' STATE OF ALASKA ALASKA f~ AND GAS CONSERVATION CC~"' .MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill. ~_~ Redr, ll ~. Type of well. Exploratory [] Stratigraphic Test [] Development O,1 Re-Entry DeepenI-]I Service [] Developement Gas [] Single Zone [] Multiple 7one __ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL (Marathon Oil Company~ Sub-Operator) 152' KB above MSt feet McArthur River Field 3. Address 6. Pxoperty Designation ) _ "G" Oil Zone P. O. Box 190247, Anchorage, AK 99519-0247 .~u"-~°~ui~L /7.~ West Foreland 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see2OAAC 2§.025) 1970' FNL, 532' FWL, Sec 33, T9N, R13W, S.M. Tradin~ Bay At top of productive interval 8. Well nurpber Number 5194234 1100' FNL, 2500' FWL, Sec 28, T9N, R13W, S.M M-28 Equitable At total depth 9. Approximate spud date Amount $200,000 U.S. 500' FSL, 2780' FEL, Sec.21, T9N, R13W, S.M. February 15, ~O 12. Distance to nearest . 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthCMDa.d'rVD) property line ADL-18730 13,092' MD unit boundary feet 21.5 feet 3~840 acres 10~652' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 2S,035 (eX2)) ,Kickoff depth 979 feet Maximum hole angle 38.~( ~aximum surface 2,980 psig At total depth ('I'VD)4,025psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26 267.'391 Dril-Ou:.n 906 73 73 979 979 '6108 sx (~n place) ~20 16 75.0 K-55 BTC 1383 73 73 1456 1450 2100 sx ~17-1/2 13-3/8 61.0 K-55 BTC~, 4510 7~ 73 4503 4000 3300 sx 12-1/4 10-3/4 55.5 N-80 BTC 427 73 73 500 500 2200 sx 12-1/4 9-5/8 47.0 N-80 BTC 6000 500 500 6500 5496 12-1/4 9-5/8 53.5 N-80 BTC 4782 6500 5496 11282 9239 J~)l~'f~,,~.~J%/~.' 8-1/2 7 29 N-80 BTC 1471 11081 9239 12552 10230 250 sx 6 5 18 N-80 ?L-4S 640 12452 10152 13092 10652 70 sx J A,N. "*Pilot hole size 17-1/2" :'.:.,~',',.,,;~,-:, -- . .......... ~ .v'~ .W, .ura~ .I~UilU. bO[ii **Pilot hole size 12-1/4" ~ R~i~ ~- ~?Y~J~m/~ xf4(,~',~¢' '-'" . Highest known gas bearing zone at 1460' TVD (AC-1 sand). Cement volume on '16" casing based on 100% excess. Cement volume for 13-3/8" casing based on 50% excess. All other casing string cement volumes based on 30% excess, with the top of cement on production casing 500' inside surface casing. the lowest interval targeted for production testing in Well M-28 is the Basal West Foreland sand which is expected to correlate, to the lowest sand in Well G-7 included in the West Foreland oil pool. Marathon plans to drill below the currently defined West Foreland oil ~ool to allow for sufficient rat hole. Any intervals showing productive oil saturations ~eeper than the currently defined West Foreland oil pool may also be tested. .~..~ . - 20. Attachments Filing fee Lg Property plat r~ BOP Sketch [~ Diverter Sketch 1~ Drilling program [] Drilling fluid program ~] Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and_corr.~ct to the best of my knowledge Signed '. Title Environmental Analyst Date 1/15/90 ,J Commission Use Only Permit Number I APl number I Approval date J See cover letter ~'".//~ I 50-- ~,¢',..,~-.2.0,~'/,~/ I 02/2R/90! for other requirements Con~litions o) approval Samples required ~ Yes [] No Mud Ion ~e:nu'ire'd [] H . .... Yes No ydrogen sulfide measures [] Yes ,,~'oNo Directional survey required _~Yes ID N Required working pr~m~ure for~BOPE/,"~2Mj. ~ 3M; [] 5M; [] 10M; [] 15M Other: f/~.~ //,.~,~_.,~_,._~,, .. _Approved by L ' ~' - ~/~' /~/'~~~ Commissioner by order of the commission Date ~,,i,,r,~,,~ '~S~ AAA I'~--.. .~'~-.~ n~' ~ //' / · n 01 Rev. 5 ~ Sul: cate HORIZON' .L PROJECT I ON SCALE ¥'-IN. = 1000 FEET HARATHON OIL Slot' :3. Le.,CB,);nr4,11o,,,, No, M-28 STEELEHEAD ~latf'orm. Cook Inlet. Pr'o~eed Alae ZOO0 6000 $000 4000 3000 2000 ! 000 2000 WEST-EAST 1 000 0 I TARGET ~2 TYD-~52 THD-11812 DEP-6256 #ORTH $50 EAST 1948 TARGET #2 LOCAT[O#~ 300' FNL, 2~#N)' FEL SEC. 28. Tg#, RI3W TARGET #1 TVD-8652 TI'E)-105,31 DEP-$492 NORTH 5150 EAST I ~ TARGET #1 - LOCAT ! lin, l I00' FNL, 2500' FWt. ~#~0. 28. TgN. RI3W 9URFAOE ( LOOATIO#' 9TO' FNL, 532' FWL SEC. 33, TgN. RI3~ 1 000 I 2000 I () () TD LOOATiON~ gO' FSL, 2820' FEL SEC. 2t. T9N, Rt3W N. 15 DEC, 57 MI NE 7020' (TO TD) 1 000 HARATHON OIL C6_a~,.~ Slot~ ~, Leg~ , ell No~ H-28 Propoeed STEELEHEADPlatform, Cook Inlet, Alaska RKB ELEVAT[ON, 152.3 1000 KOP / 26" CSG PT TVD-gZ9 TMD-979 DEP-2 2000 16" CSG PT TVD-14$O THD-1456 DEP=66 2. $ ° DOOLEG/I OOFT EOC TVD-2334 THD-2449 DEP-498 RATHOI~ 3000 4000 13 3/8" CSO PT TVD=4000 THD=4583 DEP=1820 5000 6000 AVERAOE ANOLE :38 DEO 40 7'OOO ~IEGIN TURN TVD-715;:3 THD-8622 DEP=4324 8000 · 8' DOOLEO/I OOFT 9000 TARGET #1 / O ZONE TVD=8652 TMD=10531 DEP=5492 9 5/8' CSO PT TVD-9239 TflD-11282 DEP=Sg40 TAROET #2 / VEST FORELAND TVD=9652 THD--11812 DEP=6256 Z" CSG PT TVD=10230 THD-12552 DEP-669Z 11000 1000 20O0 TD / $" LINER TVD.,I0652 THD=13092 DEP=Z020 3000 4000 5000 6000 VERTICAL SECTION 7000 8000 -.~. s !""i A R A W H 0 h.i 01 L Iii: CI M F:' (.'-.", N Y .~:'-,*-.- · .,x- .K- ,.,i..~. ~' '.~ S'F E E L. I--1 E: A ',"] F' ! ,..--~ t .F o r'. rr, ~-~- · ~...~(- .~,~. e..~- ~'.~. h~,_ A r'- .I.- h u r. ~''' ': ~" . .. ,-~ .~. z ~.., r'. i': _'i..~ 1 d.., l:": ,:-, ,:, ~.:: 'r ?.~ 1 e t,A K *-.~ · .'.~.-i:~- ..,~ .~.~. · ~..~. ..~ ,~..~:~. ~-'~'~ ~" · "' '"'~:'" ~"~ ~ 4~" ~ '~'" "'~" '~ ~" "~- ' ~ '" "~ ' '" l~ "-X-.~-.~--~.' .~.~,~..K--~-.~.-~..~.-.~,~.~,~. ...... .~ ~ ~ ,, .~ ~., ~.,.,..~ .~-.~, K- .~.;~--~-~ .~--.~-.~-.,~ ~...,-.;¢..~.~-.p,. ~.%~¢,.,..:~ ORIGINAL D i r- e c t: ± o r, ~i 1 F' 1 ,?~. I', :.~.~ u I::, m i t t e d I'.:, '-,.- : - E A S'T' M A N C:: I-..l R I :iii:'l" E N S E N., A n ,:: h o r e..'.:~ e., A 1 ,'a. '.:.-'. k ,~ Re-I::er. ence Fi 1 e txl¢~me : -- E300., 003]F"00467.5MA S 1 ,::, t n ;.t. me: -- B .t -3 We 1 1 n,.'zme : .... I't-2:F: R e .q u e s t e d b '-," : - L. I_. A M 0 N'.:.--.; Ac ce,,=-t e d b'.,, : .... Revision no : ..... 6 C: h e ,:: k e d b'.,' : -. ICItO, FILMED ERSTMRN ' CHRISTENSEN 1ERSTMRN CHRISTENSEN Me.asur-e,",' Tr. ue Ver-t £i e F, t h D e ,'-' t h I r, c 1 in. A z i m ~.; t !": B e a. r- i n '-': q- ' De De M ' S e C t i ,.] i"~ Tie ,:,r', P,:,irlt 1< I CK OFF F"O I !qT BIJ 'I L. D 8,: '[' LJ RI',I .- D L'.!'_-'; = 2.50 D I:= G / 100 F'l', B U I L D &. ]" U Flt',l .... DI_S = 2.50DEG / iOOF'T,. BUIL. D &. FLJRII - "" 5 0 D E G / 1 ()0 F'I" DL:'3 :"': ..': ..... HOLD HOL. O 9.=;-, C) C-' (:) 9 ..&':.) --z q .... . . ~ . u ." · · ,", I:-- ,.' '?. '1'. ) (') ("")'"--$ 4' 9 7 "I 1 "='=' '='~" ,, _ 4..: ......... 8() 14.... 0 () 0 ~ :3 5 4 2 7, '7 2 i I-.--. / 4 3 IE 2:3.1 '::.: N :.2:3 7 E i. ,:':,4 1. Il ...t ..._! _ ii ..... J.. Ii 4 r'=;_ ('}. ,, 81 Ix!,--. '"' '-' ..:, .':, '"', 10 . E 4.'P'7 ,, 5o 16 '7 7. 14. iq '"'/._,,-::,=' ,, '7 0 E 1 8 ':.'..: O. 4' '-',::, CHRISTENSEN W e 1 ! F:' r-,:, .F i 1 e S'-,.' n ,':, P s ± s ( ,'- ,:, n t i r, u e d ) I*h",a ~-. ul--ed._ .:. Tr-ue V~:,r.t_ D e P t h D e P t h I n c I in, A z im,: t h Be '.-~ r- i !", ~ D e :~ M i n D,.-. ~ r'- e e s J ,= :.~ I'I i r, R e ,:: ",.- ~ n ~ u ] ~ :". V e r. 'l' i c al 1 F: ,::: c, F- d i n a. t e s ~-'-'; e c t i o n .OROP & 'i'UFd'4- .DLS = O. :E:(':)]EIE~} / ! OOFT. 11:282 ,, 31 HOL. D TARGET ,_, :L 1.66 HOI_D ..P.,.~ I NG 12551..=i7 !? 2 3'F..'. 00 9 6 5 2.3 0 10 2 3 0.0 0 38 40 38 40 ,:,.., ....... / N 2 6,W. '-'--i/' ':-,'":' 31 HRISTENSEN EASTMAN CHR I STENSEN., Ar:,-; h ,:, !"-~.~,;e., A ] e. s l.::a. ]. 9.:' - D E C .-:'-:: 'F: W e 1 I F' r' ,':, f :L 1 e F;..,.. F, ,:, P S i S ( ,- ,:, r, t i r, u e :-I ) MemsUF-ed TF-Ue VeF't D e P t h D e I.~ t h IFic'l iFi. De ~ td i D Azimuth Bear'in~. De ~4 r. ees De-~ Min Re c e_ .~ n .~ '.J ] ~r'. Ver' 'L' i ,-_ a.'] r': ,:, ,:, F' d i n,~ t e s :_-'; e c t i ,:, n HOLD ""'-' 40 ............. 7 Ix! I .:-'-,'=,W 674.'.--.¢, 71N ~. '.'.?'.'.2 E: ,, .34E': 701 ?. 7,::,f ERSTMRN CHRISTENSEN P eL S~ e 5 · Wel 1 Pr.,:,File E A F.; T M A N C H R I S'I' E N'.=; E N.: Measured True Ver. t Ti e m t I-, f-I e P t h I n ,- 1 i n ,, I]e_~ Min A n ,: h c, r e. ¢. e, A 1 ,=: s k ~'-z A z i F,, u t h ~ e a. r. i r': ~ q" M De..:~ r. ees .,.,¢ g ir, R.::'.' c t a. n ~ u 1 a. r'. V e r. 't i c ,'.z 1 C ,:, ,:, r. d i r: a i- e s S e c t i o n (), O0 O. 00 · .. .... 0 o .._._'":' '-"':, 00 50. C.', 0 !5 c; ,, O0 7'9 ,, () 0 75.00 1 ('). ':'_'> . ¢''~.... ("}. ]. (".,,.. '''~ . f'). Q_ :I. :,:'5., O0 _t 25 ,, O0 15,'.'.) ... 00 i 5 (). 0 () 'i 75... C; 0 1. 75 ,, ()'3 :20 ('), 00 2 () ':]. (") ('.~ '":'"'-' =i O.q ":'":' ='i ,:90 .:]) C., 2:2 0 0 .I. 3 0 '::'5 0 5 ('> 't. 0 0 7 '.'::) .1. 6 0 I. 0 0. C.'.O N (') OE 1='''' /'-5 o ./. $2':.'.' 2 .~. E i '.:.:' 2, 12 F; 12 '7 W 78.23 N78 i.:.i.E 2/_", 8. <'.....,':' E; :-:.~ E: 2/.I. 3 ":.:.'5 ,:::./.--., 26N, :35 E;8 c) 21 W :[ 74, I. 5 ::_'-; 5 5 :t Ii...: 1 :=:_/-,_ ,, 8:3 '='..... 6 .i. 88.1:3 S :B :!ii',W ("). OON O, O(")E 0.0() 0., C) 7 S 0, O:--:E -. C). 0 6 0 ,, 18'.:::; 0, C) 4 E -' 0 ,, 1,2, 0.23 S 0. (".,..-'--' F_ -- 0 . 1 '--'... O. 1:3S 0 ,, ¢.")7 E - 0. I 1 # (".~,, 1 o'" '-'.-.., 0 ,, 0 :'-':_ W. - C.) . i 0. 1 F':'."":; 0 ,, 08 W - 0.19 ('} ,, ':2"2.'.!:; C?. ,, 1 '::"' W .... ("}. 24 () ::ii: C:' S 0.1' ..:~.!'-" I - C; . '--"? i! , · '..' ,i.. :250.00 Si'. 50 ,, 00 0 .... ' -' ::i -'-.,'7 =' C) 0 .,::. / ,.. O0 i") ~ ~:,. I ._1, . .. :3 0 0.0 0 :3 0 0.0 0 () · -.:, -~:, r'; ':*)0 .":::25 00 0 ....I ,i.'...,,. ii . Ii . 3 F-i 0,00 :'-': 50 ,, 00 0 14. 14 5 ,,:% ....I 1,_,.'::' 7 . ::ii: 7 :E; '7 2:2['4 t '71 i :2 S 8 :'i'=r-' · is -... ,,,,~ 1:'34,6:3 S 4- ::-::81/,I 161, .7:0 '.iii; 1 °''-',.., 4. 2 E 1 i (),/-I. 0 S69 36 [ir 0.49S (). 14W .- O. 5 i C'.. :::; 9 :=; 0.14 W - 0.60 0.66 S 0 ,, .i. 4 W --. (). 6,'7 C) ,, 76 S 0.12 W -- 0 ,, '7'7 O. 8'.-Ta.~; 0. OOW --0.86 :3 '75.00 .-,'27/.-,5.00 0 400 ,, 00 :39'P. 99 425 ,, O0 424,99 0 450. O0 .4.49.9'2 0 4'70,00 4 69.98 0 500. O0 499, 98 0 550.00 549 ,, 97 I 600.00 599 ,, 95 1 650.00 64 9. 'P :3 2 700 ,, 00 699 ,, 89 48 4 I~~ o_! ..9.'17 r ,',,; C;" .." .) .,S..,g. :3,5 72 ¢'''9 lq 7 ;l." ':5 ~ Ir u m~,'m .. ....... 72 .... :,7 N72 2:2E 90, i3 :F89 52E · '-'~. 8 1 .o.::, ..... S5:3 7E 152,, 23 S27 46E 1:35,, 1'7 S4.4 50E :1.1° 0° =.y-.., -. S 6 :I ..... ,.'::, E'-- 114...?,2. ::i;65 47 E 98.00 882 OE 88 ,, 8:3 N 8,':-'~, 50 E ]" ! !F PCtS ! "!" ]: ON '75 (), () 0 74':?, 85 2 8 () ....... 0 () 0 '799. ::,' .... ,..' 1 ':::' =:'"~ 0,;') 84.'.r'-~ 79 2 i.,., ..,.. ,.% :1 .... n 900 0 (') '::'<, 9 '77 1 u , . 1--* .- . 11 ':;, !:9 .:") r~. (') 'i~) 4 9 7 4 .... ' ...... ~! ..... n . 14 :36 0 37 0 88.85 N88 51E 8'?,,18 N89 llE 08,, 55 N88:33E ':":::' 4-:s: N 8 :.:3 ;2'.'? E ,..i i...z ~ '75.65 N75 :.39E ERSTMRN CHRISTENSEN i, 14 e ~ 'i F' r. ,:, i: i 'i e ( ,.': ,:, n -i- i r: .! e d ) Me :-',. s u r. e d T r- u e V c=. r. t q." D-:.? '? ,.. ,= p 'i: h P h Z n c i i r',. D e s~ M i r: r-, .'.Z 'i Fh I.; +.' h ~ e :..'~ I" I I"J ~ ll)e:~rees Ele :.~ P1in R,a c t ,an si u I a.r. V e r- 't' -i ,-: a Ii: o ,:, r'. ,:.I :i. n,-:.l i: e sS e c 't i o n iii: A S i: I"-! G F:' 0 i I',I"I" '25.0 Zl. N 25 :3 Er 24.6 t";.~ N 24 ::ii:61iE' 2'-.!, "~' '=' N 2,.'-!-!t. 4. r- ~ .% ...i . ,.#. :2:3.92: N2:3 .55E :2:3 ,, 65 N 23:39E .1. 49.82 I',1 I 00 .0 ',,-.: E 1 '71 . ....:: ...,":' .I. '::' z. 32 N t 16 '!;,' () E- ""'" :L 2-'!:'7 I.,i l...l II I, ,j%'..j. :2:26, F'~ 4 N 13 ri; ,, 15 E 25 4,95 :;?70, 35:'N .1. 54,7:3E :.?,02.../.I. 9 .~ ...,.,, [..... -o . :31 '7. '79 N .t / ....,, 6 ::.:' E:: ~,!'-': 3, 81 C:A S I t".1(3 PO I N T 4000.00 '"' '= ,s ,, . ..:: ..... !.4 60 4500,, ()0 ::.':~'!i:':::.'~4 ,, 97 z'-'""'"" 4 A ("~ C) ,, C; 0 · J- ;::~,:2, .=, ,, ":' ,2., 5()00. O0 ,'-1.3:;'=".5. 34 :.34 5'7 37 26 38 4.0 :38 4("~ 3:8 40 :3:F: 40 ::..i: :.'B 40 38 40 '::"::' .'1- C) · .., ~..~ . ....~ ¢.. .=,,:: 40 ,, .,::. %., E 23 42 N2:iii: .... "=' '- ":'.,:.....,':' ,, 21 lq 2:3 :t 3 E ":":' 1 c, ~x'"':":' 7 E:' ,, ~ .'-,.=. 7[=- 2:3 1:11!'. ti,: ..... "::'::' 12. ""'~'-' 7' E 2 3.12. N 2:3 7 L= 2:3.12 N 2:1.'] '7 E "::'"~ 1 '-" N 2:3 7 E 2:3 1 '-" N 9::: -- . .... . ~ ...../ 2 :':::. :t. 2N 2:3 7 E 3,'.'..:,::!: ,, 65N 197. '77E 40:::::. 8,0 422.87 N .,=.'-' ..o I . 14 E 46 7 . ..:,'-' '=..., =' '" "':"'~"':' 1 ~ ~ Zl. ...,, (.: c:, 1N ...... 497 MO .1:.. %.1 ._1 ii ... II i..l ~ ¢', ,-~ ',, ... "", '-, ' ,'.". '--, 0 ,.-.~ { 7 ,'.% 7,, ,.' ,.':, 1 I :q 68 .... -'- .,..: E. ,:,._- ......... 10!=;4. & 1N 490.90E 1148, 8'P .1. 341,94 N ,./:, 13.59E 1458.87 I ,.629,, 27N 736.27[':" 1768.85 1677, 14 N '756 ,, 70 E 1820 ,, 48 19 I. 6,61 N 858.95 E 20'78,83 5500. O0 4.715.72 38 40 6000,, O0 5106.09 38 40 6500,, c}0 5496, 46 38 40 7,:"~,:") 0 0 C) ':'-i':-".::' z. ,:,-:, - .... .......... . ...... ,.. ..... ,._, :::l~: 4- 750 () .., 00 627'7.20 38 40 5:'20:3.94N 981.6:3E.' 238::_",'. 81 .';:-:491.2'7N 1104 ,, 32E 26?8.79 .- ....... .- z. C) I,. I .Z / ,,' :::: ......... -., 1227. C, () E :3 00 8 ,, '7'7 3065 ,, 9:3 N :!. 349,68 E 3318 ,, 75 :i:353.27N 14.72, 37E 3628, 7:3 ERSTMRN CHRISTENSEN r';AE; I NG PF) I N T 8,300, ("),.'} 6 6, 67, 57 85,:]) 0. C, 0 7057, S..: 4 :F: 6 :;_:: 1 ,, 'P 9 7 ]. F-i :}.", ,: ! :::: :.7. 700= ,:::, 0 '7'-7-:' 14,. 13 E',E:O(), 00 '72'ii>:..--: ,, :'::8 c.:,,:-- (-'~ C') 00 7:77 (-) .... ' ,..., .., ... ........ /.D 9 OC) C). ,.'].~ 0 7 q. 49.22 '::"..- :1. 0 ,.'"), 00 '7. R ...... '2 '7 ,, 78 92,:') f') ,, C) c) '760/_-,. 4.1 '!;' 2,':') () ,, 0 C) -.? ,'- '::":9, _ · : ,_-_,._ ]. 'ii:' 4 () 0 ,, C, 0'776:3,8:3 9' 500 ,, () (') 784. 2,60 9/_:, 00, 00 '79:2 :t., :3'7 .'::~ 7 ':"~ (") 00 8 C) ()0. 'I '1 980 C),. 0 C) 8078. ::3'!~-' 9 ..... 9 ,:') (') ,, (). (7.,,,,. ,...,'::' 1 ..., =' '""/ ,, 61 :1. ,:") () () () ,, 00 82:36,, 2 '7 ";') .1. C)C) () 0 c,.:, '14 c., o .I. '. K ,..' .-; ... u I~.1 1 (:)200 ,, 00) 83'P::'::, 4() 10:300, n,.":....... 8471, ::.,'"'"".,..:. :3:--: 4.0 3E': q.,:") :_--::8 4 0 :--:8 :-_-:4 :38 :;;."'7 · ]) ::', .-., ,-.' '.," 4" :'3:!.-'.: 2 :3E: 4 10400 ,, 00 8550. 14 3 :.-'.i: :30 10500, O0 862.8, 33 38:3:E: i. 05:3. 0 ,, 88 ,...,c:' ,..,,,..._'"-i ,..9. :3. () :3:3 4 ,:") 1 i 00 O). (])0 9018.58 ::ii::E: 40 ','. 1:28:2 .-. ::ii: :t.. 923 S,'. 00 :38 40 A .:.-: :i. rh U !_': i J{:.',.:-3 ,'.-3. F' .,. r'~ S n D e M i .-.~ ~ r'.e.e S .2 2:'-.:.- 1:2 :L..'::3, 12 2:3, I. 2 ':?2 ,, ! 3 20, :i:::,S N:.:.':37E N2:Z.[ 7E N2:3 7E N2"..:: :::i:E N2C) 52E · '"", ~:2~ "- N 'i.. ':"... ..: .... E. I',.I ]. E: 18E f',i .1. / k. r::. N 1 ':" 44F: N 14:2 6E 1.9.5S: ! :iii:. 30 17, (')2 1I;"" ...... 7:'.:': 1 4 ,, 4:':": i :3, 14 N 1:3 8E 11.84 N ]. 1 50E I ~") ,, 54 N 10:32E .,::.-'.~. N 9 .~. 4E: '7 ,, 9 .zi.i. ix) "7 57E 4'758 ,, 9 ()N .i. 9 50 ,, 64 E 511 1 ,, 66 48:;;:0 ,, 30r'.,I 1957. o'Pl'.'c 5 .1. 72, ,'.1.'7 4 '-"-' ] ':':" ~'::i'--."-'::".':' ..... :,,: ....... 1 N i c...:, 6 2',, :I. 7 EE ._ .,=.._,...,, I 1 4 '.;' 4:3 7:2 N .1. '!..', 6 5:3 7 E = '-"-" "" ':::' ' . ~ ...I.::_'. ::, ._'.', ,, ...l r.::'.--, t"'"'-' =:: ,2, .r.~,..-., ~.-:.~ ff 1 :,, :.:,c,, 18E .................. .... ,'..., .., ..., ,, 71 N ' '-'' \ .. I:.'." ,,"'" ·" -- ..... ),'--, ?. 89 N 1969. 'l 2."-'E F;/I. 1:3 :E:4 · ..., :1. :30. 2:3 N'1 '::"..' ~.., ,_,c:'. 67 E [~ ...... 47:3./-, 6 514S.:' ,, '7 :! N :1_ 968. :v.:4. E 54'::.:'2 ,, :.":: 1 F:; ...... 44 '2 ,, 7 ::ii: N 19. ,S 1 . C.) .1. E ':9._ -'/'":'/.,...'-'. () .,'.1. 5619.0TN 1956.6.1. E' r-"~940 ,, 39 ERSTMRN CHRISTENSEN (' ,:*. 0 r'! '1-_- :j. ih U <'.' CI ) C: o c, r' d i r', a t ~, s :E;,._~ ,: 't i o n 1ERSTMRN CHRISTENSEN ~,-,! E L. ~ .... ....,r" ::_-,_ F' L E C T i C N S U R V E Y MARATHON OIL COMPANY S i,:,'b ,~ BI.. .... Well : M..-2:E: STEELHEAD P1 ~t~orm Sur-ve'.,- Re.Ferenc<:; : I 0046'? ,, '¥ 0 JlERSTMRN CHRISTENSEN I:Jel 'i ~ ¥l-<:'° F:'iqHL.. : Ix! 1 5 5/-" 0 :..~ r' R e 'F : '-T 0 0 4 6,9 , T, C;.. Me;.'-';.sur-ed :,3r-i-Ft Dr.i.~t C,:..ur. se ,~r. ti,::al Ver. ti,-,~l FR E F: i A )\i !3 I_l 1_ ~ R ,rjc,~le~ ]]-:;..':F:"i."h f'-.]r'l,..-.-i'Je D:!.r'ect±c,r~ L._en~'izh D....:...p'l:h Ei:~s,,"'t±on lei F'i F--i R Zi i N A 'T' iF.:: S '.T:;ev.::_,r. it'.,-' '.:.59 4.0 ,, :3 9 4 6 4 9.3 6 r,.i ii:4 8:3 ,, :27 F: C',., C:,O ,:':,:,==:56 ,, 0:3 4'.=::'8C). O0 t",i :2,q. 8(}. C..'-O E 0.0() 4._, c")= ()0 ,.../-,,...L, ,:~.. 7' ,, 2 4 ':'l ........ 4 4 '=' 1 .x-, ...... N ....::.'-~. ...... ,t, ,:,'. ' =' E:'. .. 7 019 ,, 7 6 5 7 8,:::,. 0(} I",.I 2..:1.,'.'i:. C,, 0 0 I.-'..-'0. C,O CA!_CUL..AT!C'I'-..I METHOB : R~.',,d:Lus o.F: (" ,..i r'. 'v a. tL:r'.e ......... Nh !U..:, : ........ 'i :!ii; 1 /-,/-, E ~ ,. ....i ,..":1 II .... B 0 T "F CI !'"1 H 0 L. E L ,.':.:I C A"i" T 0 N : R e i:: e r- ....:.': n c e d .1:: c, C E N'T' R }!ii: D :' ""'"' ~' )" F" :- /- '2 8 '7' :2 .L .:, ~ [...L\~ ..-[:. ~ ... ].. D '! R E: C"F i ON : i"-.i 2:3 :3 E I::;".r.i.:.F:'r:lF:;:T L.llq :[ 'T'S : Fee t kI· · a C C 6.' P t' 6; '::J L ',' ',', E: h e c k e ,:ii ii:, '-,- '..' ERSTMRN CHRISTENSEN ~HECK LIST FOR NEW WELL PERMITS ITEM AP~P_ROVE D~kTE, / (2 thru 8) ' "- (3) Admin ~ %~~D 9. / (10 and 1~) 12. 13. (4) Casg (14 thru 22) (5) BOPE ~.~,~, (23 thru 28) (6) OTHER ~_~~~_~ (29 thrd 31) rev: 01/30/89 ,011 14. 15. Company ~o~_.~/ NO REMARKS Y - -- Is the permit fee attached .......................................... 2. Is well td be located in a define~ pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ?. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Does operator have a bond in force .................................. L Is a conservation order needed ...................................... Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~' Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cower all known productive horizons ..................... ,~ Will all casing give adequate safety in collapse, tension and burst.. ~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... 7c Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams.and descriptions of diverter and BQPE attached. Does BOPE have sufficient pressure rating - Test to ~~mmm psig".. Does the choke manifold comply w/API RP-53 (May 84).. ~ .............. Is the presence of H2S gas probable ' eleell.leee.e.e..lllel.lee®.eee.® exploratory and Strati§raphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ' ~eell.eee.lll.l....ll......i ....mell.le.eee INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , S~o 15o ,. / ,f 32. (1) Fee (2) Loc LEST FOR NEW WELL PERMITS Ai~oPROVE AT _ '(9 ~hru .t~)~' '- 10. (10 and 13) 12. 13. (14 thru 22) (.5) BOPE ~/4f~.~. /-.2m- ?o' (23 thru 28) 14. 15. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is we.l] located proper distance from property line .................. 4. Is we~[ located proper distance from other wells .................... 5. Is suzficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day waiC ...................... 16. 17. 18. 19.' 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... //z/ For (6) OTHER 29. (29 thrh 31Y 30. 31. (6) .Add: ~'.~. t-2D-?~ 32. GeOlogy:_., Engineering: .. YES NO -- · Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production.strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. ,,~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ................ ; ...................... Is.the'drilling fluid program schematic and list of equipment adequate,4-~ Are necessary diagrams and descriptions of diverter and BOPEoattached. Does BOPE have sufficient pressure rating - Test to ,>~oOsoo psig .. Does the choke manifold .comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on pOtential overpressure zones? ..i..'..' .......... Are seismic analysis data presented' on shallow gas zones ...... ' ...... If'an offshore loc,, are survey results of seabed conditions presented Additional requirements .............. . ................................. IN ITIAL GEO. UN IT ON / OFF POOL CLASS STATUS AREA NO. SHORE ' ,, ,,, / ~o , Additional Remarks: rev: 01/30/89 011. 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. PPPPPP? P~ PP PP P~ PPPP?F~P PPPPPP~ po PP pp PP HICROFILMED AAAAAA AAAAAAAA AA AA AA AA AAAAAAAA AAAAAAAA AA AA AA AA AA ~A AA AA CCCCCC CCCCCCCC CC CC CC CC CC CC CC CC CC CC CCCCCC ~ ~C CCCCCC O0 O0 000'30000,0 000000000 O0000OO00 O00000OO0 000000000 O000000OO O0 000 O0 000 O0 000 O0 O00OO O0 00000 O0 00000 00000 O0 00000 O0 00000 0,3 CO00 O0 0000 O0 0000 O0 000 O0 000 O0 000 O0 000000000 000000000 000000000 000000000 000000000 000000000 O0 O0 O0 222222 22222222 222 22 222 222 222 222 222 22222222 22222222 3333333 ~3333z3 333 333, 33333 33 33 33 33 33333333 333333 333333'3 222222 :::: 3333333 22222222 :::::: 333 222 22 :::::: 33,3 222 :::: 33333 222 33 222 33 222 :::: 33 33 222 :::::: 33333333 22222222 :::::: 333333 22222222 :::: 0000000 00000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 lO0000000 )0 O0 O0 O 66666 666666 66 66 666666 666666 56 66 665666 66566 6 66 66 66 66 66 66 6 I! III I!1 II! !11 Iil !11 !11 Iil I!1 I!1 !I O0 // O000OO000 111 III 000000000 1111 III O0 3OO 11 /// O0 OOOO 11 III O0 00000 11 /// 00000 O0 11 /// 0000 O0 11 /// 000 O0 11 /// 000000000 11111111 /// 000000000 11111111 /// Ou I/ PROGR&M: LISC~K ~:V'S!ON: ~.1 PART NUMBER: WS790-PE32 Start of ex,cu, : . r ...a ~ +~on ~ ~ I JUN ***~ REEL HEADER ***~ LIS ATLAS 01 'LIS CUSTOMER FORMAT TAPE' **** TAPE HEADER **** LIS 82/05/15 4267 01 "OPEN HOLE-DIFL,OEN,CN-GR,AC,AND .SL: RANGE 1301.0-1350 mT' FILE ..~ 1 MAIN .001 **** FILE hEADER **** 1024 CN : MAR.~THON OIL CO. WN : M-2.8 FN : MC ARTHUR RIVER COUN : KENAI STAT : ALASKA COMMENT RECORD * COMPOSITE DiFL-AC-GR . FORMAT RECORD (T'YP~# ONE DEPTH PER FRAME TAPE DE~TH UNIT : FT 11 CURVES : NAM~ CODE S,~MPI. 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'2500 -999. 25110 -999.25C0 9910.000 134.7643 -9'~9.2S00 -999.25'30 9860. 137.21~,6 -999. 253 -999.P_500 ~810.000 143.4C98 -999.2500 -999.2500 9760.000 137.5924 -999.2500 -999.2500 9710.000 130.9454 -999.2500 -999.2500 9660.000 125.3248 -999.2500 -999.2500 9610.000 133.3675 -999.2500 -999.2500 9560.000 137.6288 -999.2500 -999.2500 9510.000 124.0495 -999.2500 -999.2500 9460.000 131.3793 -999.2500 -999.2500 9410.000 119.7219 0.67200~6E-01 -~99.2500 15.54&Q1 5~,.01~11 '2.1472921 -999..250,3 12.61379 53.37350 0.~963015E-01 -999.2500 12.35768 94.~6049 0.9154701~-01 -999.250~ 15.55606 87.0~870 0.759,8686E-01 -999.2500 12.18~73 79.36391 O....~477047E-01 -999.2500 15.?~09~,~ _ 59.65800 0.1141872 -999.2500 12.18229 78.07420 0.8217144E-01 -999.2500 12.22295 90.78841 0.6027031E-01 -999.2500 15.11867 64.43372 0.7276058E-01 -999.2500 14.07'399 70. 57069 0.1038036 -999.2500 16.39317 54.1~13.,,r) 2.350352 -999.2500 9~.1~597 176.785~ 2.55z. 1 4C - 999.2 ,'7., ~,2 4~.~5246 24~.3452 2.402269 -999.25CC 2E2.56~9 2.340993 -'~99.2500 97.51~,89 1 88. 4494 2.3255,89 -999.250,0 63.C136~ 230.4996 2.411678 -999.2500 97.94875 165.1452 2.57'702& -999.2500 55.11203 236.8586 2.400054 -999.2500 45.27156 214.9000 2.341735 -999.2500 72.08633 166.9358 2.491191 -999.~500 90.97~45 19~.6413 2 .~79182 -999.2,500 106.2222 ~,.....~1 , 5712.422 -999.2500 34.63589 4~.13712 5563.4~9 -999.25C0 21 .3171~ 86.z~1229 5692.,357 -999.2500 20./~21 55~5.363 -999.2500 42.40125 42.70230 5711.113 -999.2500 22.71216 78.23970 5586.918 -999.2500 29 · 6.5874 47.77690 5703.551 -999.2500 23.18640 79.31850 5562.289 -999.2500 26.30385 66.18460 5529.871 -999.2500 50.16330 34.5442~ 5477.875 -999.2500 3~.04291 53.60570 -999.2500 3,,1 .90179 6(]. 05340 30.34200 -999.2500 31. 129'41 -999. ~.500 30.99690 -999.2500 21.74403 -999.2500 30.99~Q0 -999.2500 21.03087 -999.25C0 31.99680 -999.2500 40.46823 -999.2500 30.99690 -999.2500 23.21870 -999.2500 31.23270 -999.2500 28.31689 -999.2500 31.99650 -999.2500 23.65524 -999.2500 31.99650 -999.2500 26.513/+4 -999.2500 32.34180 -999.25(]0 48.31340 -999 .,~500 32.8~750 -999.2500 30.95,~72 -999. 2500 32.10600 -999.2.500 30.2;>.36,9 -'99~.2500 -99'.9.2500 2~,1.6'z15 -9~c -999.2~0~ 9260.0~0 117.6381 -999.2500 -999.2500 9210.000 11~,2648 -999.2500 -999,2500 9160.000 173.1649 -999..2500 -999.2500 9110.000 127.6559 -999.2500 -999,2500 9060.000 125.4375 -999,2500 -999.2500 9010.000 123.2282 -999.2500 -999.2500 8960.000 122.2124 -999.2500 -999.2500 8910.000 131.5702 -999.2500 -999.2500 8860,000 164,3.332 0.9~63663(-'31 1~.8~27~. 59. ~ 609'9 . ~.. 19.4737~ -9g9.,]503 13.~62~3 50.76941 0.1034737 -999.2500 15,915Z6 51.36530 0.1050968 -999.2500 15.76990 153.9595 0.1089211 -999,2500 12.25971 75.74110 O. 434'7420E-01 -999.2500 12.58843 58.25760 0.63365'~4E-01 -999.2500 15.24403 5'7.49400 0.1090021 -999,2500 16.6520~ 5~.21710 0.9466362E-01 -'999,2503 14.09715 63.~3490 0.14591~ -999.2500 13,55264 215.2340 ;~. 577613 ~37.357~ -990.Z5S0 ~n 15~4~ 111,0226 1.3284~ -999.2500 91.65466 202.7353 2.594887 -99~.2500 91.73363 21'9.9945 2,602526 -999.2500 89.64079 142.2404 ~.1679,21 -999.2500 42.17911 26 4. 3889 2.3~4340 - 9',:,' 9,25 O0 2R2 72~8 2,440,277 -999.2500 102.18~4 1~4.6~.24 2..5~1456 -9'9'~'. ?,500 97.03253 213.Z790' 2.560366 -99~.2500 81.92447 17~.1593 2.593632 -99'~.2500 ~8,35405 334.7~83 5377..~16 -9~c'.'~00 22.67357 ~0.65691 5167.89~ -~99.2500 9~.69920 17.~6330 5147.520 -999.2500 27.66554 60,35930 5124.699 -999.2500 28.~3153 63.70612 5198.070 -999.2500 64.08325 26.30740 5319,824 -999,2500 16.8,6383 10S,0455 5136.953 -999.2500 14.95348 123.8429 5090.582 -999.2500 ~0.70354 5~.05130 5036.066 -999,2500 30.36356 59.6565'1 5024.941 -999.2500 31.651 5.~ 47,92970 50',35 71 c ,.,, . ~' -999.2500 20.99393 119,5605 . . 32.76091 -o99.2S00 22.18109 -999.25!]0 32.99670 -~a~.2500 96.09616 -~g.2500 32.99670 -Q99.2500 26,97762 -999.2500 31,979~0 -999.2500 27.51030 -999.2500 33.99661 -999.2500 62.63654 -999.2500 27.3~230 -999.2500 17.85910 -999.~500 27.99721 -999,2500 16.03311 -999.2500 27.99721 -999.2500 29.407'10 -999,2500 27.99721 -999.2500 2~.73338 -999.2500 27,99721 -999.2500 30.5~539 -999,2500 27.34230 -999.2500 21.05090 -999.2500 -999.2.500 -999. 250,3 -0.3578513E-01 -99',2. 2500 1,941069 -999.2500 5109.875 -9'~9.2530 -999.2500 8813.000 124.9c02 -999.2500 -'399.2500 15.23063 60.13502 3.13803~9 -99~.250~ ~9.~1453 207.1123 2.55026~ -999.~50C 31.30167 ~.76881 4911.155 29.96617 -Q99.2500 28.76131 -~99.250.0 8760.000 125.6781 -999.2500 -999.2500 12.56294 68.~7840 -999.2500 4~.93~35 259.7856 2.450732 16,87845 110,1944 4951.863 -999,2500 17.75841 -999.2500 ~7,99721 -999.2500 8710.000 124.0360 -9~9.2500 -999.2500 12.27520 6§.,2~410 0,5780315=-31 -99:?,2500 43,=301~ 2~1.332~ 2,453611 -999.2500 17.96275 102.83.80 4916.594 -999.2500 18.8426C~ -999.2500 27.997~_1 -999.2500 3660.000 124.2261 -999,2500 -999.2500 12.22217 65,26781 0.6944656E-01 -999,2500 44.31886 297.2158 2.479034 -99'9.2500 14.58675 132.0148 4863.195 -999,2500 15.83841 -999,2500 27.9~721 -999,2500 &610,000 162,5470 -999.2503 -999.2500 12,929~4 143.0373 0,7674217E-01 -999.2500 56,26036 212.3061 2.182708 -999.2500 30.99194 58.57861 4916.656 -999,2500 30.54282 '-999.2500 27.7,.5140 -999,2500 85,50,000 142..3167 -999.2500 -999.2500 15.35986 81.58350 0,1399870 -999,2500 57.71289 173.2003 2.429129 -999.2500 41.57474 39.69679 4852.3,05 -999,2500 39,70822 -9~9,2500 27.99721 -999.2500 8510,000 128.4702 -999.2500 -9~9,2500 16.42548 69.28349 0,8512592E-01 -999,2500 ~9.01855 194.6772 2.480455 -999.2500 38.87071 46.44450 4955.004 -999.2500 36,80'21 '7 -999.2500 27,761/+0 -999.2500 8460,000 233,1306 -999.2500 -9'99,2530 16.97527 579.6211 -0.22~2619E-01 -'999.25~0 50.68491 113,8372 1,463460 -999.~500 114.2622 17.22070 4714.914 -999.2500 122,2078 -999,2500 28.65210 -999.,2500 TOTAL D~TA RECORDS STARTING TAPE DEOTH FILE TRAILER **** : 764 = 1 301 O. O0 ENO'Z. NG TAPE 'DEPTH = 8430.00 FIL= # 3 RE'EAT ,003 **** FILE 'H=ADER **** 1024 * COMHENT RECORD . "--.'OTTOhl RF-PEAT RUN NO.1 FORMAT R:CORD (TYPE.~ 54) ONE CEPTH P:R FRA!,I-- TAPE _EDTH JNIT : ,=T 6 CUDVES : NAME CODE 1 ,.qR 2 RFOC 6,5 3 RILD 6.8.. 4 RILM 68. .5 CILD 6 SP 6~' SAMPLE# 1 I 1 1 1 1 UNIT BYTES APZ 4 OHMM 4 OHMM 4 OMMM 4 OHM~ 4 MV 4 * DATA RECORD DEPTH C!LD 464O.OO0 0.0000000 4590.000 132.9445 4540.000 69.4.2676 4490.000 68,56975 4440.000 123,9089 4390.000 16.04909 4340,000 39.16411 4290.000 110.9660 4240.0C, 0 O.O00000O (TYPE~ GR SP 0.0000000 0.0000000 71,,54575 126.0994 39,87401 97. 72577 72,47656 1 2.6. 3741 9'5.1 6200 120.3381 53,12791 66,37071 66.03368 ;~6.16337 3q.73521 139.376'.1 0.0000000 0.0000000 O) 1014 BYTES , RFOC 0.2000000 7.712756 11.93z, 20 13,76888 8,275146 60.91069 22. 38965 ~ ,417419 0.2000000 RILC 0.2000000 7.521933 14.40367 14.58369 8.070444 62.30884 25.53358 9.011770 0.2000000 RILM 0.2000000 8,715904 16.29884 18.38982 8.659637 66.34,6 98 25,59523 9. ! 4561 5 O. 20'00000 TOTAL DATA RECORDS : STARTING TAOE OEDTH = FILE TRAiL[R ***~ 25' 46~0.00 ENDING TApE .DEPTH : 4200.00 **** .='rLE HEADER **** 1,32/~ * COMqENT RECOR9 * SP REPEAT RUN NO.1 FORMAT R~CORD (TYPE~ 04) ONE DEPTH PER FRAM¢ TAPE D:PTH UNIT : FT CURVES : NAME CODE 1 GR 68 2 RFOC 68 3 RILD 68 4 RILM 68 5 CILD 68 6 SP ~8 1 UNIT ,::':, Y T E S AP1 4 OHMM 4 OHMM 4 OHMM ~. 3MMM 4 MV 4 DATA RECO~D D~PTH CILD 3120.000 -999,72'530 3070.000 84..~ 7876 3020.000 29'?0.0O8 446.3196 2920.000 4~5,0'959 2,370.000 449.0857 2520.000 448,9285 2770,000 451.5137 2720.000 452.2322 2670.000 451.6724 (TYP,.E # O) SP · 999.2500 999.2500 66,470.55 267,1092 61.14525 261.9312 28.5~$66 266.6721 47.3~932 18.65341 ~1.79~64 36.062~5 72.24338 63.63614 70.96407 56.91209 56.73160 55.49866 49.90/,75 .,59.8.4911 1014 !SYT=~S * -9'99.2500 9.'93753~ 2.251598 2.~13530 2.207524 2.209234 2.223330 2.226856 2.26'6856 2.219872 -999.2500 11 · 7676,5 '2.23,3445 2.2/+0547 2.2'98344 2.~26747 2.227527 2.21/+772 2.211253 ~.,?.13994 RILM -999.2500 11.49032 2.21362$ 2.218629 2.408651 2.?.02768 2.205106 2.195204 2.193973 2. 1947.,¢7 2620,003 449.1 7.30 2570,000 432.6123 2~20,000 422.~65~ 2470,0C0 414.6734 2~20,000 442.3~59 237,3.000 442.2524 2320.000 443.9189 2270.000 447.6597 2220.000 447.1855 2170.000 44'7. 991 2 2120,000 448,.o. 6.51 2070.000 451,0371 2020,000 450,5281 1970,000 4..,50.9734 1920.000 450,58;5O 1870.000 450.8306 1820.000 454.7449 1770.000 454. 732'9 1720.000 454.2307 1670.000 45'3.8...,¢... 60 1620.003 452.:5540 1570.000 453 65.16.528 69.84911 53.33305 64.207~2 4'.a.. 10170 6c?, ~_4~11 59,21199 69.84ell 61 ,41650 50,00345 59.84911 56,36249 59,84911 ~6,~1074 69.84~11 51,42929 69,84911 ~,.,,' .. , 69.8~911 46.26363 69.8,4911 45.37059 69. ,~4911 53.90430 59. ,84911 5~.19395 69.84911 c7 08943 69.84911 5,8,. 65154 ~9.84911 49.0340& 59.84911 50.58630 69. ~.4911 51 · ~71~, 6~. ,'~4911 2.222788 2.346473 2.357571 2.3~?,5~9 2.257778 2_.2.°,6795 2.24?909 2.274604 2.247668 2.240708 2. ,21,81 I 9 2.238483 2.244796 2.235351 2.228311 2.223023 2..P.C,'4402 2.22158,7 2.~15384 2.2~9567 2. 230373 2,.21913~ 2.22628~ 2.483779 2.367055 2.411553 2.2*0474 2.261152 2.252664 2.233840 2.236208 2.232186 :Z. 227345 .2.21 7113 2. 219617~ 2.217425 2.. 21 933'7 2.21 81 28 2.19903~, 2.199093 2.201525 2.203197 2. ~08217,, ?. 20411 '7 2.20733.3 2.351661 2.32~9d4 ~.~501S9 ~.237051 2.236490 2.219354 2.212584 2.214247 2.209982 2.204964 ,2.196365 2.196214 2.1 9370,5 2.197019 2.187887 2.176~20 2.1830/42 ~.182162 2.181922 2.189133 2.'1 83528 1 5 20.00~ ~5.5 :: '~ C. 4 454. 346o 59. :~1 I .. "~'3 =,'~ 5~o~7 16'~0. G:_ _,. a77.715 5 cc~..a ~5.Z.¢ 1 =70.u~.' ~ ~ 3 0.,.n33,3003 0.00000 £ 0 O. S '3 'j '0:30 ? 0. ~ 0 0 0 ' r, ~, ~ . 2 O'.', 961 2,1E0274 2,170152 > 0745c~ = ,,~. 2000000 TOTAL OATA RECORDS : STARTING TA~5 DE~TH = ;ILE TRA!LE~ **** 312C.00 ENCiNG TAPE DEPTH = 1340.00 FIL~ ~ 5 REP=AT,O05 **** FILl HEAD=R~ **** 1024 * COMMENT RECORD * GR LOG U'PTO SURFACE FORMAT RECORD ONE DEPTH PER TAPE DEPTH I CURVES : NAME 1 GR (TYPE# FRAME UNIT : ~T CODE ,58 64) SAMPL E# 1 UNIT APl BYTES 4 * DATA RECORD DEPTH 1520.000 1470,000 1420.000 1370.000 1320.000 1270.000 12Z0.000 (TYPE~ GR -9o9.25u0 55.71054 31,56426 3.~, 74495 33.02934 30.83660 3.5.88860 O) 10~2~ 5YTES 11 7'0,000 1120.000 1070,0C.'3 10-~0.000 970.0C0 920.000 8"zO. OC,3 8_~0.000 7'70,000 7.~0 · OOO 670.000 620.00G 570,000 520.000 470,000 420.000 370,000 320.000 270.000 220.000 170,000 1~0.000 70,000 20.000 31.3~3~P_ 27.42534 30.17216 15.~5~7~ 20.'~57C2 22.89~92 17.76572 16.034~5 19. ~0C, 99 16.45953 17.82534 14.25080 17.15051 16.16824 17.20923 12.15348 14.55107 12.41516 12.89651 14.77088 15.43218 14.59381 4.451830 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** : 24 = 1520.00 :ENDING TAPE DEPTH 0.00 FILE # 6 REPEAT.O06 FILE HEAD[R **** 1024 COMMENT R:CORD * DIFL-aC-SP-GR REPEAT SECTION RUN NO.2 FORMAT RECORD (Typ=~ ONE DEP-H P=R =RAM= T~m5. g=mTH. UN~T= : =T, 11 CURVES : NAME COD ! C~L 2 GR 6at 3 TTEN 68 4 RFOC 68 5 RZLD 65 ~ R!LM 68 7 CILD ~ ~C 68 9 SPC 68 10 SP 68 11 CHT 68 SAM UNIT 5YT"S INCH 4 APi 4 LB ~ OHMM 4 3HMM 4 OHMM 4 OWMM g US/F 4 F/MM 4 MV 4 LB 4 * DATA RECORD DEPTH RILD SP 11450,000 -999,2500 -999,2.500 (TYPE.e O) 1014 BYTES * CAL RILM CHT -999.250 -99~.250 -999.250 11~00,000 6100000 25,42780 24,9745 71,$5510 1943',79 11350,000 0,302600 2.8,06482 '29.3.$93 89,8991 2 1 95~, 3.8 11300.000 0,6'781000 13,98061 1~,50058 63,58575 1~59..963 11250,000 1,957501 17.15388 16,51660 111,0926 1971,193 11200.000 1,348700 0,2000000 0.2000000 0.0000000 1000,000 GR CILD 0 -999,2500 0 -999,2500 0 42,02815 39,32704 O 44,806§Z, 1 35.631 81 5 46,83502 71,5276.5 99.16646 5~,29584 89.3~198 0.0000000 TTEN AC -999.2500 -999.2500 6515.703 69.89777 ~453,434 71,339'72 6360.965 76.4988& 6263.590 84,1397& 4000.000 50.00000 RFOC SPD -999.2500 -999.2500 30,10529 .29,65201 27,06055 29,99701 24,77428 29,99701 16.94376 30,34200 0,2000000 0,0000000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILl TRAILER **** 26 1145.0.00 ENDING T~P= DEPTH = 1118.0.00 FiLE # ? **** FILE HEADER **** REPE&T.O37 1024 * CONMENT RECORD *' O!FL-AC-,.SR-SP ReD_=AT S=CT!ON e, UN NO.3 FORMAT RECORD (TYPE~ 6/-+) ONE DEPTH ~ER FR..~HE TAPE D'~PTH UNIT : F-T 11 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CAL 68 I INCH 4 2 GR 58 1 API 4 '3 TTEN 6,5 1 L5 4 4 R~OC 68 I OHMM 4 5 RiLD 68 1 OHMM 4 6 RILM 58 I OMMM 4 7 CILD 68 1 OHMM 4 8 dC 6~ I US/F 4 9 SPD 6.8 1 F/MM 4 10 SP 63 1 NV 4 11 CHT 68 1 L~ 4 * DATA RECORD (TYPE~ O) 101,~ BYTES * DEPTH CAL GR TTEN RILD RILM CILD AC SP CMT 11520,000 -999,2500 -999,2500 -999,2500 -999,2500 '-999,2500 -999,2500 -999,2500 -999,2500 -999,2500 I 1 470,000 6,000000 O, 0000000 561 2,453 26,,~6638 28,45531 37,05321 68,22725 41,11722 1297.676 11 420. 000 3,4030000 40,20920 561 6,727 32,1 2906 29,59624 31 , 1 2447 65 · 32761 23.61412 1300,506 11370,000 1 ,661000 53,07626 5523,762 O, 941811 0 10000, O0 I 061 , 784 96,92978 64,56503 1259,015 11320.000 1.071700 3!.93221 2000.000 0.2000000 0.2000000 0,0000000 50,00000 O.O000000 750.0000 RPOC SPD -99.Q, 2500 -999,2500 43,65097 35,36700 38,83049 35,06792 1,182241 32,99670 0.2000000 0.0000000 TOTAL DATA RECORD.S : 23 STARTING TAPE DEPTH : 11520.00 ENDING TAPE DEPTH : 11280.00 FILE TRAILER FiL~ ~ 3 **** $iLE M~ADER REP~AT.CS~ 1024 * COMMENT RECORD * DIFL-AC-SP-GR REPEAT SECTZON RUN NO,4 FORMAT RECORD (TYmE~ 6~) ON: DEPTH PER ~RAMm '-- _ TAPE DEOTH UNiT 11 CURVES : NAME COD: SAMPLE# UNIT BYTES 1 CAL 6B 1 INCH 4 2 GR 68 I ,&PI 4 3 TTEN 6~ 1 LB ~ 4 RFOC 68 I OHMM 4 ..5 RILD 68 1 OHMM 4 6 ~ILM 68 1 OHMM ~ 7 CILO 58 1 OHMM 4 8 &C 68 1 US/F 4 9 SPD 68 1 F/MM 4 10 SP 68 1 MV' 4 11 CHT 68 1 LB 4 * DAT~ RECORD (TYPE# O) 1014 BYTES * DEPTH C~L GR RILD RILM CILD SP CHT 12680.000 '999.2500 -999.2500 -999.25,00 -999.2503 '999.2500 '999.2500 -999.2500 I 2630. 000 3. 000000 O, 0000000 22. 65596 20. 56743 44,1 3849 99.56073 -7671.855 1 25,'30,000 9,05 71 (20 4'2,99783 3. 75571 7 4. 676907 ~66,2607 109.6354 -7692.176 1 25 30. 000 5. 535700 51.8.7029 2 3~,2200 2 ,'~35577 41~ 0~.51 · ..... m .,~ , ~,.. ~ 104.0775 -7710.461 1 24 80. 000 5. 433900 49. 99060 1. 303.665 1. 431 919 767. ,,3684 I 05.1 566 -7747.3,,,53 TT=N ~C -999.2500 -99~.2500 4957.36'7 61.79295 4942.750 75.15,617 49~.5.414 9.'5.40007 48 '~ ,~,1.020 11 3.3293 RFOC SPO -999.2500 -999.2500 24.32672 26.99730 4.374439 2'7.99721 ].9066'98 27.997'21 2.553150 28.39160 1. ~431,37 >Z. 1 4711 $ 514. :531 ,S 94. z. 289 ? 7 ~. 34 'c 2 ,?. - 777,5. :; ~ 6 12380.007, 9.546701 35.94272 ;g ~7 ooo~ .~c~ I~, 7o2~2 17~ · ~ ' ' · · ' · '.., I _ .. . _ · . -- 54.99210 28.95551 C,.4279583 28.39751 O.20G0300 O.O00000O TOTAL DATA ~ECORDS : STARTING T~OE ~=PTH = FILE TRAILER **** 3~ 12680.00 ENDING T'~PE Dr-PTH 12310.00 PiLE ~ 9 **** FILE HEADER **** REPEAT.OC9 1024 * COMMENT R=CORO , CN-DEN-C~L-GR R;P~AT SECTION RUN NO.2 (LOG D&TE: 5-2-90') FORMAT RECORD (TYPE~ 64) ON= DEPTH PER FRAME TAPE DEPTH UNIT : :T 13 .CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CAL 68 1 INCH 4 2 GR 68 1 ~PI 4 3 CN 68 1 PCT 4 4 CNC 68 1 PCT 4 5 SSD o8 1 CTS 4 6 LSD 58 1 CTS 4 7 SSN 68 1 CTS 4 8 LSN 68 1 CTS 4 9 CORR ,5~ 1 GMCC 4 10 DEN 68 1 SMCC 4 11 TT,EN 68 1 LB 4 12 CHT 58 1 LB 4 13 SPD b8 1 F/MM 4 DATA RECORD (TYPE~ O) 1014 BYTES * DEPTH CAL GR CN SSD LSD SSN LSN D$N TTEN CHT .SPD CNC CORR 11460.000 -°99.2500 -999.2500 -99'9.2500 -9'79..2500 -909. . .2~nOu -~9:~. . .,..7500 -o09.2500... -999.2500 -999.25C0 -999.2500 -999.2500 11 41C. OOO 1 2.1 071 5 175.01 32 1 2. 59645 1 ~3.4~'3C 60.93~61 28'.~. 5355 1 '¢8.79 20 2.524'075 ~776.54~ 1145.95~ ~C.99690 11 360. COO 1 2.3'~1E5 4a .1 41 56 1 I. 51 21 2 1 28. 943~ 65. 78671 2, '50. 4651 1 41.2526 2.4 94159 -~ 477. ,.".~ ~ 111 9. 476 ~ O. 651 9~ 11310.C03 12.23110 43.66403 13.19534 1 26 . 371 ? 5~ . 71141 279 . 503_2 131 . 1 35 S 2.477380 6522_ . 056 11 66. 537 ~C, .99693 11260.0C~ 13.30341 124.1~2~ ~C.5a991 2.555230 ~447.~64 11210.000 1ri ,,;O~ 0.0000030 O.O000OO0 2.000000 5OO0.OC3 97961 S5.~5 '7.78 ~ · .,.., 00.,.) 00 ~ 1000.003 5C.01176 ,52.25021 996913 -15.30000 O.C, On ~ ,uOOuO O.c,n~ ~:,uO0'~ -999.2500 -999.2500 14.124,'72 O. 88/.,.1705 E-01 13.07231 0.1093054 14.59646 .~;,-,. 'qO72472E--01 29.4330~ 0.9765339E--01 0.0000000 -0.5000000 TOTAL D,~,TA RECO~''''F,~S : ,_,'a"'. STAPTING TAPE DEPTH = 11463.00 FILE TRAILER **** 2NDiNG TAPE DEPTH = 11200.00 FiLE fi 10 **** FiLE HEADER **** REPEAT.010 1024 * COMMENT R:CORD * CN-DEN-SL-GR-CAL REPEAT SECTION RUN NO.3 FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE D~PTH UNiT : ~T 18 CURV=S : NAME CODE SAMPLE# UNIT BYTES I CAL 68 I INCH 4 2 GR 63 1 ~I . , 3 CN 63 1 PCT 4 4 CNC ,~8 1 PCT 4 5 SSD 6g 1 CTS 4 6 L'~B 6~ 1 CTS 4 7 cSN ~"::~ 1 CTS ~ LSN ,~'~ .,~ 1 CTS 4 9 CSSN 58 I CT$ 4 10 CLSN -5~ '1 CTS 1 I CORR 55 I 'SMCC 1 m ~' = 6 © " ., N 1 * D~TA R"-CORD (Ty.~;~. _ ,',),., 9e'z, ~YT:-S * D=PTH C.aL GQ CN CNC SSD LSD SSN LSN CSSN CLSN CORR DSN TTEN KTH TH K U CHT 12~30.0C0 -999.2500 -9'~9.2c00 -999.2500 -999.2503 -999.2503 -999.2500 -999.2500 12380.000 11.85605 219.4559 361.5725 0.0000000 0,7366467E-01 6.$74574 1.1.54217 -9~9.250C -9g9.2500 -~99.2500 -999,2500 72,86755 0.0000000 1,760505 1.109225 -999.2500 -999,2500 -999.2500 -999.2500 200,DO00 0,0000000 8472,063 1167.746 -999.2~00 -999.25~0 -999.2~00 235.4474 0.0000000 72.93367 I 2330,000 9,504368 11 4.5211 200.0000 21 9,7905 I 29,8004 72,7451 2 O, 0000000 O, 0000000 O. 0000000 O, 0000000 O, 8098221 E-01 '2 · 454724 5271 , 5'7'4 1 0.5,5329 4. 4408~ 6 1.1 3.5902 1'. 295008 1073. 522 98,09715 0,0000000 2,459234 0,80'78157 66.66788 0.0000000 2,499063 0.2904~23 12280.000 9.513254 122.4449 69.04721 0,0000000 0.3816128E-01 5.326742 1.21¢827 12230.000 9,23515g 117.3916 60,38461 0 . 0000000 O. 4060936E-01 7.871768 0,9151406 200.0000 0.0000000 60'96.902 1088.503 200.0000 0.0000000 6215,65,6 1078.028 200,0000 0.0000000 3000.000 0.0000000 12180,000 6.000000 0,0000000 0,0000000 O.OOOO000 -1,500000 2,757524 1.325559 97,16843 0,0000000 2.O00000 4.258369 219.8766 0,0000000 93.52980 217.1815 0,0000000 66.66?88 0.0000000 0,0000000 77.50456 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 44 12430.00 ENDING TAPE D~PTH : 12150.00 FILE # 11 REPEAT.011 **** ~ILE HEADER **** 1024 * COMMENT RECORD , CN-DEN-SL-GR-CAL R;PEAT SECTION RUN * '~CR~.~AT RFCORD (TYPE~ 54) ON; C:DTM PER F~ME TAPE DEDTm UNIT : =T 15 CURVES NA"=,,, COSE I C~L 6~ I INCH ~ CN ~ CNC S SSC 6 LSD ? SSN 8 LSN 9, CSSN .~.~.5 1 ~"TS 10 CLSN 11 ,.~ORR 6.~. 1 GMCC 12 D:N 65 1 GMCC 13 TTEN 6,8, I L~ 14 KTH 68 1 PCT 15 TH 68 1 ~CT 16 K 17 g 68 1 CTS 18 CHT 58 I LB * DATA RECORD (TYPE~ O) 994. ,,.~YTr-S. . DEPTH CAL GR CN CNC SSD LSD SSN LSN CSSN- CLSN CORR DEN TT,EN KTH TH K U CHT 12570.000 -999.2500 -9'99.2500 -999.2500 -999,2500 -999.2500 -999,2500 '-999,2500 12520.000 9.031481 1 20. 691 3 9.4..59850 27.00C20 -0.5721188 5,476493 0.1010126 1 2470. 000 7.1 5011 $ 100.1055 45.89020 152.4835 -0.1602173 I .398730 0.6:::375,598 =-01 -999.2500 -999,2500 -999.2500 -999.2500 50,96268 96.24550 2,200652 3.006167 37.84090 295.6768 2.555302 1,268286 -999.2500 -999,2500 -99'9,2500 -999.2500 31.16641 27.00020 5143.871 1209,935 11,43501 152.4835 5031.871 1191.209 -99'9.2500 -999.2500 -999.2500 33.B0539 96.24850 20. 501 2'7 15.24661 295.6768 30.48044 1 2420,000 5. 457,38C 38. 14542 39 . 2451 2 49.457'24 44.96780 40.02042 1 22. 8477 29.73520 1 22. 8477 29 . 73520 -O. 5926547 2. 039487 4977. 945 25 . 21 936 I · 611 654 O, 456.6456 I · 870,.8,?7 11 87,347 TOTAL DAT& RECORDS : STAR'T!NG TAPE DEPTH : FILE TRAILER **** 30 1 25'70. O0 ENDING TAPE DEPTH 1'2380.00 **** TAP; TRAILER LIS 8.2/05/15 4267 01 TOTAL R:CORDS TN TP. ZS LOGICAL TAmE : 2261 **** R=EL LIS 8Z/05/15 ATLAS 01 TRAILER **** TOTAL RECORSS IN Tn!$ TOTAL AE,:~CR'.,,.$ ?N T:-iiS Eno of ex, ecut, ion: Er'.'. 1 Ei:~!~secl ex, ecution SYSTEM RETURN CODE = lc L','.:6.~,2,~.L R =''''L : 226~: PHYSICAL REi}L: 226.2 JON 90 7:1~,~ re:inures, 34.0 s~conds.