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Home My WebLink About187-106 MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Telecopy No. (907) 276-7542 March 7, 1990 Marathon Oil Company P 0 Box 190168 Anchorage, AK 99519 Re: Trading Bay Unit M-26 Sec 33 TgN R13W SM Permit # 87-106 Dear Sir or Madam We wish to bring to your attention that the Commission .has not yet received the following required items on the subject well which our records indicate was approved for abandonment on April 19, 1988: Pre-blowout Operations History Well Completion Report Section 71(b) of Title 20, Chapter 25, Article I, Alaska Administrative Code, stipulates that operator shall file this material with the Commission within 30 days after completion, suspension, or abandonment of a drilling well. Please submit the missing material listed above to' Larry Grant of this office. Sincerely, C V Chatterton Chairman jo/L.LJG.06-07 STATE OF ALASKA ALAS; LAND GAS CONSERVATIOK ' ,MIS~N I G IN A WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED~ SERVICE [] 2. Name of Qperator 7. Permit Number IINCi('AI (Mnrnfhnn ~i 1 {'n - q~h ~n~nfn~ 87_1n~ 3. Add~ .... ' ..................... r ...... / 8. APl Num~e~~ p n Rnv 1Qfl9~7 &n¢hn~nnn ~ QQgl Q 50- 7qq 9nqQq , . v. ~v.. &~ ,. ,.,,~,,v, ~I '~ ~ I ~ ~ 4. Lo~t~o~ o~ w~, ~t,~_=/eh B-1 Cond l, Steel head P1 atfor$ a. un~ or%~,~ ~m~ 964' FNL, 525 FWL, Sec. 33 9N-13W-SN Trading n~,, '~ At Top Producing Interval 10. Well Number ~ ..... N-26 At Total Depth 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) ) 6. ~ease~esignatio~ and Serial No. , HcArthur Ri ver Fi el d 152' KB above MSL AgE 18730~-~{~8f8~c Grayling Gas Sand ~=. ~te S,.dd,d ~3. ~at. T.~..~a~,.~ ~. ~at~ Com,~s,. or *~n~.~. ~at.r ~.,th. if off,hor, 1~6. ,o. of Co~,,.tion, 12/16/87 ~/~ ~~~- 187' ,~tus~'~ 0 17. Total De~th {MD+TVD) 18.~lu~SackDe~th{M~WD) 1~ ~irectionalSurveg '20. ~e~th~hereSSSVset 21. Thickness of ~ermafrost 2265' 8 2~36' 188~ - 188' ~[s ~ ~D ~/~ ,~u~ ~/A ...... 22. T~e [lectric or Other ~o~s Bun 1~0~ SITTING ~[~TH MD CASING SIZ~ ~T.~[~ FT. G~ADfi TOP BOTTOM HO~SIZ[ CfiM~TI~G ~[CO~ AMOUNT .._ 20" 94 X-56 0' 776~ ~26" 1325 Class ~ 8 lk~ 13-3/8" 0' 2250' 17-1/2" ~one ..... 24. ~erforations open to ~roduction (MD+TVD of Top and Bottom and 25. TUBING ~fiCO~D interval, size and number) SlZfi ~fi~TH S~T {~D) ?ACKE~ SIT ~one 2~. AC~D, F~ACTU~[, CfiM[~T SOU~[Z[, ~TC. None DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (FlOwing, gas lift, etc.) None DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD ~ Flow Tubing casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE ~ ' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ivlAh 1 o lt!qp Form 10-407 Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE 29. NAME 30. GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Attachment #!, Summary of Operations; Attachment #2, Wellbore Diaeram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge [ Environmental S ig n ed__~',/z'~ ,~ ~-'/z-~z Title Engineer Date.. 3/9/90 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 9iven in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and 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 Daily Operations Report Steelhead Platform Well M-26 12/16/87 Skid rig from M-25 to M-26. NU 30" riser & 29-1,/2" preventer & 10" diverter lines. Function test preventer & diverter. RIH w/ 26" BHA tag bottom @ 460'. Drlg 460'-545'. Spud Well M-26 @ 0330 12/16/87. 12/17/87 Drl 547'-780' C&C hole. POH. RU & Run 18 jts 20", 94#, X~,56, w/ RL-4C connectors. ~IH w/ 5" stab-in string. Mix & pump 525 sx "G w/ additives, 425 sx Trinity lite weight w/ additives & 375 sx "G" w/ additives. POH. PU stack & presently installing 26" x 20" centering ring. 12/18/87 Cutoff 20" csg. NU diverter. MU BHA & RIH. Drl cmt & float equipment. Orient Dyna-drill. Drl & Dyna-drill 780'-1060'. 12/19/87 Dyna-drl 1060'-1463'. POH. LD motor & bent sub. MU BHA RIH. Drl 1463'-2075'. 12/20/87 Drlg to 2265'. CBU, RIH & CBU. POH. RIH w/ 13-3/8" csg to 2250' MD. MU hanger & landing jts. Circ to cmt. 12/21/87 Circ mud. Pump pre-flush, pump 300 BBL cmt. Increase in flow on returns. Went to divert mode; actuated platform ESD; well control pumping mud down 13-3/8". 12/22/87 Abandon platform. FINAL REPORT. 02/24/88 Wells M-25 & M-26 static. Cont RU mud system & checked rates to load deck tanks from rig pits below deck. Function tested Otis & Howco equipment. Function tested fire water monitors on north and west diverter lines. Transferred liquid mud and bulk barite from MV Ocean Fin to Steelhead. Anchom~ Daiqy Well Operatic. Steelhead Platform Well M-26 Page 2 02/25/88 Wells M-25 & M-26 static. Cont RU mud system, bulk barite system, & seawater supply system. Pump tested Howco frac skids (4) and cementing skids (2). Tested Otis BOP stack. Held meeting to review re-entry procedure & safety procedures. Fin taking on liquid mud this morning. 02/26/88 Fin RU & start Otis & Howco equip. MU BHA (pilot mill) & RIH to 354' on 5" DP. Could not circ w/ NW FW pump, air locked at low, slack tide. Fabricated 12" tie-in from seawater to firewater system in subdeck. Tested mud mixing equipment. Total 3775 BBL liquid mud + 2.0 MM # dry mud materials onboard. 02/27/88 RIH w/ pilot mill-tag Ca 370'. Wash w/ seawater returns to 479'-1ost returns. Pump in seawater Ca 66 BPM, bubble around leg decreased to about 10~o of original size. Pumped w/ some torque. POH w/ mill. RU to run caliper log in morning. From 1800 hours to 0600 hrs (2/27) pumped seawater in well at 20-25 BPM No gas out diverter. 02/28/88 Ran caliper/CCL log from 450' ~id not locate 13-3/8" cs~ 20" csg to 450' looked OK. RD WL. RIH w/ 7-i/2 pilot mill to 479'. Sh down pumps 30 lnin and observe well, no flow to surface. Washed from 479'-507' w/ seawater & no returns. Washed through 507'-511' several times, sticky. Worked pipe until no drag. Washed & reamed 511'-542' w/ no returns. Hard fill 526'-542'. Shut down for night w/ DP Ca 527' & pumped 5 BPM into well. 02/29/88 While RU, well headed Ca 0645 hrs (2/28). Increased pump in rate down annulus from 5 BPM to 30 BPM. Had full returns. POH from 525'-479' w/ tight hole. ¢irc Ca 479' w/ 30 BPM & pumped dye, got dye back in returns. ¢irc & POH from 479'-385'. Had 10-15,000# drag up to 400'. RIH, tag Ca 401'. Wash from 401'-473'. Wash & rmd 473'-479' w/ high torque. POH & had 1-1/2" to 2" rocks in blades of mill. Ran caliper/CCL log, sat down Ca 414'-tool malfunctioned. Re-ran w/ same results. SI for night. Pump-in annulus Ca 10 BPM all night. Hole stayed full. 03/01/88 RIH w/ 12-1/8" lead, impression block, set down Ca 420'. POH w/ impression block, looked like top of 13-3/8" csg, egg-shaped. RIH w/ RC, junk basket & set down Ca 420'. Wash 420'-426', no rotating. POH, well began to head & blow small amount of gas while pumping in annulus Ca 10 BPM. Recovered only small rock in RCJB. RIH w/ RCJB to 313'. Stabilized well w/ 20 BPM down DP. Well continued to head & blow small amount of gas throughout night. Dai'ly Well Operatio: Steel head P.latform Well M-26 Page 3 03/02/88 RIH from 313' w/ rev circ junk basket. Set down 0 426'. Washed down 426'-448' w/o rotating. Well began flowing gas, water, coal, & rocks. Pumping down DP 20-40 BPM. Diverted flow out west diverter line. POH to 417' w/ 100,000# (string-30,O00#). Stuck pipe. Well quit flowing, except steady stream of seawater. Pump in @ 20 BPM down DP. Pump 80 BBL hi-vis (13.9 ppg) mud. Lost returns. Cont pumping down DP @ 40 BPM. Worked pipe free & POH w/ RCJB. Pumped in annulus @ 20 BPM while POH, regained full circ. RIH w/ 7-7/8" bit, w/ nozzles cut out. Tag w/ bit @ 445', POH to 313' & SI for night. Closed diverter valves. Had 29 psi pressure on wellhead @ 0600 hrs. 03/03/88 Pumped SW down DP & bled press down to 0 psi thru overboard line. RIH w/ 7-7/8'I bit from 313' 475'. Had intermitten~ returns w/ diverter valve open. Washed & drld 475'-4~9' w/ torque. Lost al~ returns @ 479' Drld to 506', PU & hole would fill in. W&R back down to 506 several times ~/ 30 BPM down DP & 20 BPM down annulus. PU to 445' & shut off pumps, wait 15 min. RIH & tag ~ 487'. Repeat & tag O 487'. POH w/ bit RU WL & ran caliper/GeL ~ag ~ q79'. Log out. Still inside 20" csg, iooks OK. MU & RIH w/ 11-i/2 OD magnet to 313'. SI for night w/ diverter lines closed. Well had 10 psi ~ 0600 hrs. o3/oq/88 RIH w/ 11-1/2" OD magnet. Tag @ 487'. POH w/ 3 jts. Well tried to kick. Stripped out w/ 40 psi on well. Recovered only small metal shavings on magnet. Pump in @ 30 BPM & press dropped 40 psi to 0 psi. RIH w/ 12-1/4" bit to 479', did not tag. Pump @ 5 BPM @ 2200 psi. POH looking for plug in DP, found nothing. Changed BPV. RIH w/ 12-1/4" bit & tag @ 484'. Drld w/ high torque 484'-490', POH to 351' & SI for night. Had 10 psi on well ~ 0600 hrs. 03/05/88 RIH w/ 12-1/4" bit & boot basket. Tag @ 484'. Drld 484'-503' w/ high torque. Could not drl below 503'. POH & recovered about 2 cups of pebbles & rocks (1/4"-2") in boot basket RIH w/ RCJB. Tag ~ 484' Drld 484'-486' w/ varied torque. PU w/ 20,000# d~ag. Set down @ 484' coul~ not make hole. POH, recovered approx 3 gal cobbles (1 rock-("x5"x4"). RIH w/ RCJB to 313'. SI for night. No press buildup during night. 03/06/88 RIH f/ 313'-483' w/ RCJB. Drld w/ RCJB 483'-485' w/ high torque. Could not get deeper. Pump hi vis pill @ 8.7 ppg. POH, recovered 5-3" cobbles & 1 qt of gravel. RIH w/ open ended DP to 436'. Hole would not stand full w/ SW. Mix & pump 378 sx of cmt. Displace w/ 10 BBL SW. CIP @ 1645 hrs, 3/5/88. POH w/ OEDP. Hole standing full @ +88' elevation. Pumped 29 BBL SW into well & SI for night. Had 6 psi on well @ 0600 hrs 3/6/88. Daily Well Operatio,_ Steel head Platform Well M-26 Page 4 03/07/88 Opened NE diverter to bleed off gas. Had a flow of gas, rocks & water. Closed NE diverter. Pumped in 250 BBL SW @ 150 psi. Press increased to 1800 psi O 258 BBL. Opened NE diverter & had 8" flow of water. Noticed 2-30" flanges on riser stack leaking. SD pump. RIH w/ 7-7/8" bit & BPV & tag @ 479'. Isolated leaking butterfly valve. Well not flowing. Re-torqued 30" flange bolts & check diverter valves. Could not function either valve. Mix & pump 168 sx cmt & laid balanced plug from 479'. POH w/ 7-7/8" bit. CIP @ 1808 hrs, 3/6/88. Est top of cmt @ 380'. Repaired sheared key in actuator for NE diverter valve. Function valve OK. West valve actuator not functioning. SI & observed well. Had 0 psi @ 0600 hrs, 3/7/88. o3/o8/88 Removed actuator from west diverter valve. Repaired problem w/ hydraulic line quick-connect @ accumulator. Valve functioned OK. Tested BOP stack to 500 psi, pumping i BPM to maintain 500 psi due to leakage out of NE diverter valve. No leaks at BOP stack. MU & RIH w/ 12-1/4" bit & boot basket. Tag cmt @ 373'. Drld hard cmt fr 373'-403', hold down bar on snubbing unit rotary broke. Had full circ w/ SW. PU to 288'. SI for night. 03/09/88 RIH w/ 12-1/4" bit fr 2881-403'. Drld hard cmt 403'-4051 in 1-1/2 hrs. Pumped 50 BBL hi vis mud sweep, recovered lots of cmt cuttings. POH w/ 12-1/4" bit. RIH w/ 7-7/8" bit. Slip spider broke on traveling slips. Changed out spider. Drld w/ 7-7/8" bit from 405'-415' in 1-3/4 hrs. Pump 50 BBL hi vis mud sweep & got good cmt cutting returns. POH to 314' & SDFN w/ both diverter valves closed. 03/10/88 RIH fr 314'-405' w/ 7-7/8" bit. Drld cmt 405'-440' pumping hi vis mud sweeps to clean hole. Tight @ 440', work pipe w/ 6-10,000# drag. Made connection & drld to 470', hole OK. Made connection & drld to 479' lost returns Pumped ~w~:~"~ri~s rates & regained partial returns. Drld 4~9 -482'. PU ~o 476'. SD on fill ~ 478' (lost 4' of hole). Well began to unload gas, gas cut water & rocks up to softball size. Pumped SW followed by 250 BBL of 12.5 ppg mud, could not kill well. Pulled one jt of DP. BPV's not holding. SDFN w/ 70 psi on DP & 70 psi on annulus. Bit @ 470'. 03/11/88 Well had 70 psi ~ 0600 hrs, 3/10/88. RU & bled gas off well & pumped in @ 20 BPM. Well stable. Worked pipe & got BPV to hold press. POH. Changed BHA & RIH w/ 7-7/8" bi$_$~g.~.Z3', did not tag fill Circ w/ full returns SI diverter valve--s-~$ establish injection rate ~f 15 bPM @ 500 psi. ~OH to 421'. Pumped 10 BBL SW w/ tracer dye, followed by 200 sx cmt. Displ cmt @ fin rate of 1/4 to 1/2 BPM @ 275 psi. Did not see dye in inlet. ¢IP @ 1730 hrs, 3/10/88. SI for night. Had 8 psi on well @ 0600 hrs, 3/11/88. Dai'ly Well Operatio~ Steel head Platform Well M-26 Page 5 03/12/88 RIH w/ 7-7/8" bit. Tag cmt @ 306'. 'Drl cmt 306'-359'. Pump sweeps to clean hole. POH. MU mud motor, bit, & 8 its HWDP. RIH to 271' SI for night. 03/13/88 RIH w/ 7-7/8" bit & mud motor from 271'-479' w/ full returns. Bottom of cmt 0 479'. Lost partial returns. Drld & washed to 511', lost returns. Drld & washed to 514' PU to 485' Well flowed gas & water shut well in Pipe ............... ~ · ! · StUck. Bled off press (80 psi), pipe free. Pulled out of hole 5 jts. SI for night. 03/14/88 Wait on weather. Well press 110 psi. Snub out of hole w/ mud motor. LD motor, PU 7-7/8" bit & HWDP. RIH to 278' KB. 03/15/88 Weathered out all day. Helicopters could not transport personnel due to fog & snow. 03/16/88 Snubbed in hole fr 276'-304' w/ 75 psi on well. Washed 304'-479' w/ full returns. Drld 479'-521' w/ only occasional returns. Well heading occasional- ly. Hole~ti-'g~h{ @'"'52"I'~~ freed pipe by increasing pump rate. POH to 461'. Mixed 100 sx "G" cmt w/ 2% CaCl2_ Est TOC @ 260'. POH to 189'. SI for night. Wellhead press = 65 psi@ 0600. 03/17/88 RIH 189'-473I. Wash 473'-481', lost returns. Dr! 481'-492' SD to repair swivel. Well kicked while SD. SI, had 120 psi on well. Pu~ped into well ~ 20 BPM t°'~E'i'i'i~weli'' POH t°~390', hole tight. RIH to 419'. Wash 419'-460'. Pumped 3 hi vis sweeps. Mud contaminated on BU. POH to 370'. SI for night. Well press 0 psi ~ 0600. 03/18/88 RIH, 370'-460'. Wash to 479'. Circ hi vis sweeps to clean hole, wash to 492'. Lost circ below 479'. SD to repair swivel. POH t°r460"e Well kicked. SI well, press : 30 psi. Filled hole w/ 90 BBL inlet wat . Coui'd~n'-"-{"~ into well w/ 90 psi. Washed 460'-479', lo~t circ. Hole stayed open w/ no returns· POH to 399'.-M~"~'~:'~'iO0 sx G" cmt w/ 2~ CaC12. tDisplace w/ 5 BBL water· POH. LD BHA. SI well. CIP @ 1300 hrs. MU new bi . SI for night. Well press ~ 1800 hrs = 0 psi. Dai'ly Well Operation. Steelhead Platform Well M-26 Page 6 03/19/88 RIH. Tagged cmt @ 394'. Drld soft cmt 3941-402'. CBU. WOC 2 hrs. Drld firm.cmt..402'-465'. Average ROP = 30 fph w/ 4-6 K. Circ hi vis sweep. "R'e~°vered laf~i~'~'F~Uttings on bottoms up. POH to37 2'. SI for night. Monitored wellhead press = 0 psi all night. 03/20/88 RIH 372'-450' tagged fill. Washed & drld through fill to 465'. Drld to 480' w/ full returns. Pumped hi vis sweep. Drld 480'-496'. Lost returns @ 494'. Worked pipe to 476' w/ 35,000# drag. POH ~6 434'~"w/ no drag. Well kicked. SI. Press increased to 160 psi. Pumped @ 13 BPM until press : 0 psi. RIH, tagged @ 483' Drld & washed to 496'. POH to 465'. SI well. Press increased to i50 psi. Pumped into well until press bled to 0 psi. POH to 402' while pumping 20 BPM into kill lines. Mixed & pumped 1000 sx "G" w/ 24 CaCl~ (204 BBL). After 90 BBL, pump press increased to 30 psi. Displaced w/ 5 BB~ inlet water. POH. Csg press increased to 95 psi while POH. Wellhead press 135 psi. Both diverter valves leaking. 03/21/88 Wellhead press varied from 75-115 psi during night. Pumped into well @ 20 BPM & bled press to 0 psi. RIH, tagged @ 485',514' while pumping down kill lines @ 25 BPM w/ diverter valv6§"-~E'16'g:6~': H°i"e S:tated sloughing below 505'. POH to 402'. SD pumps. Press increased to 95 psi after 5 min @ 0 psi. Resumed pumping ~ 20 BPM & bled press to O. Slowed rate to 6 BPM & press increased to 60 psi. Increased rate to 20 BPM & bled press to 0 psi. Mixed & pumped 20 BBL Flo-chek, 10 BBL fresh water & 100 sx "G" w/ 2% CaCl . ¢IP @ 1745 hrs, POH. Press varied fr 0-90 psi then dropped to 0 @ 0400 ~rs. 03/22/88 Wellhead press varied fr 0-75 psi through night. Filled hole w/ 120 BBL inlet water. Pumped into kill lines w/ 15 BPM, had 1-2 BPM returns, RIH, ~agged ~ 485'. POH to 372' Pumped 20 BBL 10~ CaCl~, 10 BBL drl water, 20 BBL "~i'6-chek & 10 BBL ~rl water while pumping 5ZBPM in kill lines. Mixed & pumped 1000. sx cmt w/ drl water. Displaced w/ 6-1/2 BBL drl water. POH. Had 0 psi all night. 03/23/88 Fill annulus w/ 80 BBL. RIH & tag fill @ 399'. Drl soft cmt 399'-464'. POH to 400'. SI well for night. WOC. Wellhead press during night -- 0 psi. 03/24/88 Break circ, tag fill @ 449'. Circ to 464'. Drl cmt 464'-495'. Drl on rocks to 518', lost returns @ 518'. Attempt to POH. Had to pull 160,000# & rotate Lo~get out of hole. POH to 495'. Had no more drag. RIH, circ @ 20 BPM to 526'. Well began to unload dirty water, w/ sand & gravel & small amount of Daily Well Operation,_ Steel head Platform Well M-26 Page 7 gas. Pumped 240 BBL 9.3 ppg hi vis mud Ia 20 BPM & 1000 psi after 60 BBL lost returns. POH to 401'. Change swivel, B~I._~.;_.~.t..~g~..@ _45.4'. POH to 401. SI well, press this morning = 145 psi. 03/25/88 Bled 145 psi off well while pumping 5 BPM .... B~..~r~ZO' w/o washing, tagged fill. POH. RU w/reline run CCL/caliper to 570'. Opened caliper & POH. size from 570'-480' = 26+". Hole size from 480' 300' = 8"-10". Hole size '~OOi~L~'~~""~'~'~'. R~h DIL fr 550' into 20"@ 480' no indication of iron , below 480'. RD w/reline. RIH w/ DP to 411'. SI for night. 03/26/88 .~,H_.~_.~ag.~._~,~6,,. POH to 443'. Pump 150 BBL of 9.3 ppg mud w/ 20# LCM/BBL, 10 BBL water, 20 BBL CaCI~ brine, 5 BBL water 20 BBL Flo-chek, 10 BBL water, 773 sx "G" cmt. Hopper p~ugged. Displaced D~ w/ water. POH. Drained mud pits 5 & 6, back loaded bulk bar & bar tanks to MV Ocean Fin. Wellhead press this morning = 80 psi. 03/27/88 .._.R._IH & ~ag @ 458'. POH to 443'. Test ~nnulus to 400 psi. Pump 10 BBL ~'e"~'~'~'{E~;~ ~b~'::~'~ 15.5 ppg "G" cmt w/ 2~0 CaCl~, 7 BBL water. POH, LD DP. Backloaded 4 mud pits, 5 frac skids & assorted equip. 03/28/88 RIH & tag @ 247'. PU to 223'. Mixed & pump 100 sx cmt w/ 2% CaCl . CIP '0'92'6~] ......... .~_$1~']i'%._6]P..ii~2.f.~.~..sm.L.¢.].,68_.'. PON. Back load Halliburton, Otis, ~ Atlas equipment on MV Ocean Fin & MV Monarch. 03/29/88 Fin RD snubbing unit & BOPE. Back loaded remaining cmt, mud pits 3 & 4, Halliburton tanks, Otis equip, Oilfield's rental equip, Parker generator, & m/sc equipment. Cleaned "C" deck. 03/30/88 Backloaded boat w/ pits, 35 pallets of bar, transverse skid truss, pipe rack, gas buster, 20" single gate, 20" FSS. 03/31/88 Backloaded boat w/ mud material. Press up Steelhead accumulator. Locked blind rams & diverter valves closed. Bled press off control lines. Left 3000 psi in accumulator. Began to cut rotary beams out to remove the 13-5/8" BOP stack. Substructure shifted. Left BOP stack for reconstruction to remove. FINAL REPORT. Daily Well Operatiol,.. Steel head Platform Well M-26 Page 8 NOTE: As part of Well M-26 aband~nm_ent__Q~Z~$ During the M-25 re-entry program, the upper portion of M-25 between F~;~J~Fl~D--and 1295' was perforated at selected intervals, and approximately 136,600 sx of cement were squeezed into the void at the M-26 20" csg level, created by the blowout. Refer to the following summary operations report. M-25 RE-ENTRY o8/25/88 Begin mobilizing and RU Pool Rig #422, load MV Rig Engineer @ Anchorage & offload (a Steelhead, offload MV Monarch Ia Steelhead. 08/26/88 Fin RU all equip on Pool #422. Released rig from mobilization to M-25 re-entry @ 0600 hrs on 8/27/88. 08/27/88 RIH w/ 2" gauge ring on slick line to 6800'. Unable to work deeper due to heavy mud in tbg. Set BPV. Removed tree. Started NU BOP stack. 08/28/88 Fin NU BOPE. Function tested BOPE. Preparing to test BOPE. Tested 9-5/8" x 13-3/8" annulus to 1000 psi, 45 min, OK. Filled 9-5/8" x 4-1/2" annulus w/ 59 BBL water. 08/29/88 Test blind rams, pipe rams, HCR & choke/kill lines to 500 psi & 3000 psi. Unable to test to 5000 psi because of leaks around the tbg hanger. 3000 psi test pressure approved by Mike Minder w/ AOGCC. Presently NU flow line & bell nipple. o8/3o/88 NU flowline, tested upper kelly cock & choke manifold to 250/3000 psi. Function tested BOPE from remote panel. Modified pitcher nipple. NU pitcher nipple. 08/31/88 Fin NU pitcher nipple. Wait on start-up of turbine. Ran mud pumps. Replaced lube oil breaker in MP #2. Pulled tbg seals out of PBR. Closed annular. Had 1" stream of oil out of annulus. Circ. Got hi gas alarm at shaker. SI. Dai'ly Well Operation. Steel head Platform Well M-26 Page 9 Sting back into PBR. Attempt to bullhead oil back into formation. Pressured up to 2000 psi @ 0 BPM. Presently RU line from choke mainfold to pipeline. 09/01/88 Fin laying line choke mainfold to oil pipeline. Pumped oil f/ M-25 into pipeline, launched pig, displece pipeline w/ Cook Inlet water. Clean mud pits. RU to pull tbg. 09/02/88 Fin displacing pig to Trading Bay. RU to pull tbg. Held crew safety meeting. POH. LD tbg, GLM's, Otis SCSSV. RU slickline. RIH w/ 3.8" gauge ring & 220# sinker bars. Couldn't get past 9821'. PU weight dropped from 680# to 460# [~ +9150' indicating top of 12.5 ppg mud. RD slickline. Stringing blocks from 10 lines to 8 lines. 09/03/88 Fin restringing blocks to 8 lines. RU wirelineo Turbines down 2 hrs. Run CBL 3000' to surface. TOC est @ 2,150' Ran 64 arm caliper 4061' to 514'KB. Had 354 wall loss @ 4,027'; 4,012'; 3,4~7'. Had original wall thickness 3507' to 10/34" csg. Changed top PR's to 3-12/" RU floor to run 3-1/2" DP. Test 3-1/2" PR's to 1500 psi. PU & RIH w/ 3-1/2" DP. 09/04/88 PU 3-1/2" DP & RIH. Break circ @ 9000'. RIH to 10,927'. Break circ. RO 315 BBL seawater until returns are clean. POH. RU wireline. Run guauge ring & JB to 10,800'. POH w/ wireline. 09/05/88 Fin running GR & JB to 10,700'. POH. Set 7" EZSV's (a 10,600' CBL & 9690' CBL. Tested csg, liner lap & EZSV to 2500 psi. Lost 90 psi immediately, then leveled off & held. RIH w/ 3-1/2" DP to TOL. POH. LD DP. 09/06/88 LD 3-1/2" DP. MU Baker RBP attempt to set @ 550'. Wouldn't set. POH. Redress RBP. Attempt to set @ 550', wouldn't set. RIH to 610' set RBP. POH. LD 3-1/2" DP & setting tool. Change top PR to 5". ND BO~. ND tbg spool. Tack weld slips to 10-3/4" csg. Test BR riser & spools to 1000 psi. Csg hanger packoff leaking. Close csg valve & press up on 13-3/8" x 9-5/8" annulus. All breaks tested. MU retrieving tool. RIH & retrieve RBP @ 610'. MU internal csg cutter & RIH. 09/07/88 RIH w/ mechanical cutter, cut 9-5/8" csg (a 1451'. POH, RIH & spear 10-3/4" csg & LD 32 jts of 10-3/q" & 9-5/8" csg. Test BOPE. RU electric line, run csg inspection log 1162' to surface. RU to run pulsed neutron log. Dai'ly Well Operatior,~ Steelhead Platform Well M-26 Page 10 09/08/88 Attempted to set up PDK-IO0. Called out tech, ran noise log 1450'-200'. Ran temp log 1450'-25'. RD Atlas. MU 12-1/4" bit & 13-3/8" csg scraper. RIH. Tight @ 489' (5-10# drag up & down). Tight @ 1169'. Set 20,000# down. Slipped thru after numerous attempts. Pulled up thru w/ 30,000# drag. Set down numerous times. Worked thru tight spot. RIH to 1451' & tag 9-5/8" stub. POH. Pulled 40,000# over @ 1169'. POH. LD scraper. PU DCs & jars. RIH 5,000 drag @ 489' & 1169'. POH. RU wireline. Attempt to set up Dia-log 16 arm caliper. Caliper bad Running PDK-iO0 now. 09/09/88 RD Atlas wireline. Displace pig in pipeline w/ corrosion inhibitor & fresh water. Off-load Schlumberger unit. Run GR-CET 1435' to surface for csg inspection. Found ID restrictions @ 478'-483', 573'-576', 814'-818' & 1155'-1161'. Length of restrictions too short to evaluate w/ CET caliper. Test csg to 1000 psi for 20 min, no bleed-off. MU & RIH w/ 12-1/4" csg swedge. Note: PDK-IO0 indicated gas saturated sands: 410'-572', 671'-794', 1005'-1154', 1296'-1301' 1346'-1351', 1428'-1432'. Noise log indicates gas flow @ 480'. Slight gas'flow at 600', possible gas flow 870'-920', possible slight gas flow 1160'-1290'. 09/10/88 RIH w/ 12-1/4" csg swedge, work thru tight spots @ 487I (6' length w/ 10,000# down & 20,000# up), 499' (8" length w/ 5,000# up & down), 578' (2,000#-5,000# up & down). RIH to 1187' unable to get through tight spot w/ 20,000. POH. LD swedge. RU E-line & Dia-log. Min ID caliper. RIH, found tight spots @ 1187'=12-1/16", 819'-822'=12-1/4''. POH. RD E-line. MU Baker RBP & RIH. Set RBP @ 1423' POH i std. Pump 21 sx sand on RBP . Let sand fall. Tag top of sand @ 1408[. POH. MU 7" TCP assembly. 09/11/88 MU & RIH w/ Baker model "C" pkr & annulus press firing head TCP guns. Orient guns w/ single shot gyro & GR-CCL. Set pkr @ 1055'. Fire guns w/ 1400 psi. Perf 1295'-1300' PDK w/ 120 psi under balance. Guns loaded 0° phasing oriented @ N19°W. Had good blow then liquid returns. Release pkr & RO. Circ. POH. LD TCP guns, i shot not fired. MU model "C" pkr w/ 2-7/8" tail pipe. RIH, set pkr @ 1060'. RU BJ test lines to 3000 psi. Establish inj rate of 1BPM @ 650 psi, 3 BPM @ 750 psi, 8 BPM @ 1050 psi. Mix & pump 3000 sx Class "A" w/ additives @ 15.8 ppg 7-7.5 BPM. Displace w/ 23.5 BBL water, CIP @ 1955 hrs. Final displacement press=650 psi. Unable to bleed to zero. Wait 4 hrs. Bleed off tbg to zero. Release pkr reset @ 1055' over displace 20 BBL. Establish inj rates i BPM @ 850 psi, 3 BPM @ 1150 psi, 5 BPM @ 1600 psi. Mix & pump 1000 sx Class "A" w/ additives. Final rate=l BPM @ 800 psi. CIP @ 0330 hrs. SIDPP= 700 psi WOC held 500 psi on squeeze. Bleed pressure. Release pkr. Circ. POH. Daily Well Operatior... Steelhead Platform Well M-26 Page 11 09/12/88 POH w/ pkr & tail. MU 12-1/4" bit & RIH to 846', WOC. RIH, tag TOL @ 1251'. Drill cmt 1251'-1314'. CBU. RU cementers. Attempt to test perfs. Pumped into perfs 1/2 BPM @ 550 psi, 2 BPM @ 850 psi press dropped to 750 psi. POH. Run temp log. Cmt indicated 1230'-~3~4'. PU squeeze assembly & RIH. Set pkr @ 1050'. Mix & pump 1000 sx Class A w/ additives @ 15.8 ppg 3 BPM @ 850 psi, press increased to 1000 psi. Mix & pump 450 sx Class "A" w/ additives ~ 15.8 ppg @ 2 BPM @ 6000 psi to 700 psi. Mixing cmt. 09/13/88 Fin mixing & pumping 550 sx Class "A" w/ additives. Displace w/ 25-1/2 BBL inlet water. Displacement press increased f/ 550 psi to 825 psi. Final rate i BPM @ 825 psi. Total sx pumped on job 2000. WOC for 4 hrs. Holding press, press dropped f/ 450 psi to 75 psi. Bled off press, unseated pkr, CBU. POH. LD pkr, MU 12-1/4" bit & RIH to 762'. WOC 4-1/2 hrs, RIH. Tag cmt @ 1262'. Drl cmt f/ 1262'-1290'. CBU. POH. RU E-line, run temp log. Top of cmt ~ 1256. RD E-line. Test cmt to 1000 psi for 20 min, OK. RU tbg conveyed perforating gun assembly w/ Flo-petrol pressure bombs. RIH. Fill 865' DP w/ water. RU E-line. Correlate depth for perf #2 and orient direction w/ gyro. 09/14/88 Set pkr @ 1070'. Perf zone #2w/ 2 SPF 1236'-1241'. Correlated off of PDK 100 log; no blow, no flow. CBU. Release pkr. POH. String backed off at cross-over on top of Flo-petrol mandrel. MU skirted screw in sub. RIH. Work over & screw into fish @ 1094'. Work pkr free. POH. LD fishing assembly & fish. Recovered all fish. MU cmt assembly & RIH. Set pkr ~ 1049' w/ tailpipe @ 1169. RU cementers, test lines to 2000 psi. Mix & pump 2000 sx Class "A" cmt w/ additives & pump @ 3 BPM @ 250 psi w/ press increasing to 500 psi. Mix & pump 1000 sx Class "A" w/ additives pump @ 2 BPM @ 350 psi increasing to 425 psi. Displace w/ inlet water @ 2 BPM. Final rate 2 BPM @ 675 psi. Cmt in place @ 0038 hrs 9/14/88. SI pressure 550 psi dropped to 375 psi in 5 min. SI & hold press. WOC. Initial breakdown prior to cmting 1BPM ~ 300 psi; 2 BPM @ 400 psi; 3 BPM @ 450 psi & 4 BPM @ 450 psi. Flo-petrol gauges indicated bottom hole press from 372-379 psi. 09/15/88 Unseat pkr circ hole clean. POH. Test BOPE & choke manifold to 250 & 5000 psi. Test annular to 2500 psi. Function test accumulator. PU 12-1/4" bit, RIH tag TOC @ 1174'. Drl cmt @ 1174' to 1250' CO to 1290'. CBU, POH. Run temp log Tog @ approx 1200' . Test perfs. Injected @ 1/4 BPM @ 425 psi. Establish injection rate 1BPM @ 600 psi, 2 BPM ~ 750 psi. MU tailpipe & Baker cmt pkr, RIH. Set pkr 1047'. Presently mixing & pumping Class "A" cmt @ 3 BPM @ 600 p~i. Total mixed 400 sx. Daiqy Well Operation. Steelhead Platform Well M-26 Page 12 09/16/88 Fin mixing & pumping 3000 sx Class "A" w/ additives. Displaced w/ 28 BBL inlet water. Displacement pressure increased f/ 550 psi to 800 psi. Cmt in place @ 1132 hrs on 9/16/88. Held pressure on squeeze for 3-1/2 hrs. Release pressure, release pkr, POH. Made up 12-1/4" bit. RIH to 761'. WOC for 5 hrs. RIH tag TOC @ 1167'. Drl cmt 1167'-1226'. POH. Ran temp log TOC @ 1180'. RU cementers & PU perf assy. 09/17/88 Test squeeze on zone #2 w/ rig pumps to 1000 psi. PU perf assy, RIH. Orient & correlate perf guns. Perf 1184'-1189'. Unseat pkr, circ hole clean, no gas during perf. POH. RIH w/ squeeze assy. Set pkr @ 1033'. Mix & pump 3000 sx Class "A" w/ additives. Over displace perf w/ 30 BBL water. Final displacement press 600 psi. RD cementers, WOC. 09/18/88 WOC. Run temp log TOC Ia 1104'. RU cementers. Mix & pump 3000 sx Class "AI' w/ additives, displace w/ 25 BBL inlet water. Final displacement press 850 psi. Cement in place at 1731 hrs 9/18/88. Hold press on squeeze job for 5 hrs, bled press. CBU. POH. MU drlg BHA. RIH. WOC. Tag TOG @ 1107'. 09/19/88 Drl cmt f/ 1107'-1174'. CBU. POH. Test csg to 1000 psi for 15 min, OK. Ran temp log f/ 1177'-40'. TOC ~ 1090' PDK. Also noted cooling trend @ 20" csg shoe. MU & RIH w/ 7" TCP guns. Orient guns w/ gamma ray & gyro single shot. Set pkr. Pkr safety released, POH. Reset safety release on Baker pkr, RIH w/ perf assy. Set pkr @ 1002'. Perf f/ 1117'-1122' PDK w/ 930' of water column, had a slight blow. RO DP, some gas. Release pkr & CBU. POH. PU & RIH w/ cmting pkr. Set pkr @ 975'. Establish inj rate @ 2 BPM @ 300 psi, 5 BPM @ 450 psi. Mix & pump 2200 sx Class "A" w/ additives. Waiting on boat to off-load more cmt. 09/20/88 Fin pumping 2530 sx Class "A" w/ additives. Displace w/ 57 BBL inlet water. Final displacement press 550 psi. Cmt in place (a 0700 hrs. WOC. Run temp log, set down @ 1089'. Questionable results from log, due to cmt inside csg. WOC. Offload cmt from Monarch. RU cementers, pumping cmt. 09/21/88 Mix & pump a total of 24q0 sx Class "A" w/ additives, displace w/ 22 BBL inlet water. Max press 350 psi. Press dropped to 100 psi. WOC 4 hrs. Release pkr & circ. POH. RIH w/ bit to 853'. Tag TOC @ 1044'. Drl cmt 1044'-1107' · ¢irc hole clean, test csg to 1000 psi. Stand back kelly. POH. Run temp log. TOC @ 998'. MU 7" TCP guns, RIH. Daily Well Operation. Steelhead Platform Well M-26 Page 13 09/22/88 Oriented perf guns w/ single shot gyro & gamma ray. Perf'd 13-3/8" csg f/ 10,043'-10,048 PDK. Had no blow at surface. RO. Initially lost 80 BBL fluid. Slowly regained returns. Circ. POH. MU & RIH w/ squeeze assy. Set pkr @ 911'. Establish inj rate, i BPM @ 100 psi, 3 BPM @ 350 psi, 5 BPM @ 475 psi. Mix & pump 2400 sx Class "A" w/ additives. Displace w/ 23 BBL water. Initial rate with cmt @ perfs, 3 BPM @ 300 psi. Final rate 3 BPM @ 900 psi. Displacement press 2 BPM @ 450 psi, increased to 1BPM @ 550 psi. CIP @ 1730 hrs. Held 350 psi for 5 min, then bled off. WOC. Bled off press, release pkr & circ. POH. Test BOP equip. Test annular 250 to 2500 psi. Pipe rams, choke & kill lines, choke & standpipe manifolds, TIW valve, upper & lower kelly cocks 250-5000 psi. MU bit. RIH. Tag TOC @ 981'. Drlg cmt. 09/23/88 Drld cmt f/ 981'-1033'. CBU. Test csg to 1000 psi. POH. Run temp survey TOC @ 898'. MU TCP perf guns. RIH. Perf f/ 950'-953' Release pkr. Hole taking 10 BPM initially, leveled off @ 4-1/2 BPM. Pumped a total of 450 BBL thru kill line & fill up line. Reset pkr. Open DP. Observe well, stable. Fin offloading cmt. Release pkr. Hole taking 1-1/2 BPM. POH. All shots fired. RIH w/ squeeze assy. Establish inj rate @ 3 BPM @ 50 psi & 5 BPM O 180 psi. Mix & pump 3300 sx Class "A" w/ additives. Special note: Release operation from AFE #8329-8 to AFE #8323-7 @ 1200 hrs on 9/23/88. 09/24/88 Fin pumping total of 5000 sx Class "A" w/ additives. Final press 5 BPM @ 250 psi. Displace w/ 56 BBL inlet water @ 3 BPM. Final press 130 psi. Cmt in place @ 0725. WOC . Run temp log from 901'-40'. Cmt in pipe causing erroneous readings below 715'. WOC. RU cementers. Mix & pump total of 4000 sx Class "A" w/ additives. Displace w/ 56 BBL inlet water @ 3 BPM @ 125 psi. Cmt in place @ 0400 hrs. RD BJ. WOC. Taking on cmt. 09/25/88 WOC. Run temp log. Saw gross heating trend beginning @ 600' thru log TD with cooling @ 20" shoe. WOC. Mix & pump 3500 sx Class "A" w/ additives. Displace w/ 21 BBL inlet water. Cmt in place Ia 2250 hrs. WOC. Attempt to release Baker pkr. Release safety. Working pipe. Have rotation into pkr w/ no pkr movement. 09/26/88 Attempt to release pkr. RU E-line. Ran temp log. Indicated cmt @ bottom of pkr. RU surface jars & jar on fish. LD fishing tools. RU wireline, ran CCL. Confirm cmt @ bottom of pkr. Ran 2 jar shots w/ 100,000 & 140,000 overpull. Rotating to right freely, work torque to left, backed off DP Ia 848'. POH. RIH w/ fishing assy, 8" DCs & screw in sub. Dai'iy Well Operatiol. Steelhead Platform Well M-26 Page 14 09/27/88 RIH w/ fishing assy. Screw into fish. Pulled loose from fish. POH. Screw in sub. Pulled out of DP box. MU new screw in sub. RIH. Circ. Engage fish & work free. POH. Full recovery. LD fishing tools & DCs. Test blind rams 500-3000 psi. RIH w/ bit. Drlg hard cmt 886'-940'. 09/28/88 Drlg hard cmt 940'-975'. Circ hole clean. Est inj rate 38 BPM ca 250 psi. POH. LD DP. RIH w/ squeeze assy. PU DP. Set pkr ca 755' tailpipe @ 818'. Mix & pump 6100 sx Class "A" w/ additives. Displace w/ 54 BBL inlet water. CIP (a 2112 hrs. WOC. Release pkr & pull 2 stds. CBU. WOC. 09/29/88 WOC. RU & run temp log, found TOC ca 670'. Hit obstruction ca 820'. POH. POH w/ pkr. RIH w/ bit. Drld cmt 820'-828' Test csg to 1000 psi. pOH 1 std. Secure well. Shut down Pool SCR to wireiine on Well M-2. Moving SCR house to uncover Well M-1.. 09/30/88 Fin relocating rig SCR house. Hook up electrical wires. Mix 450 BBL LCM in mud pits. POH w/ bit. Test BOP equip. 10/01/88 Complete testing BOP equip. RIH, drl cmt f/ 828'-975'. CBU. Est inj rate 2 BPM @ 100 psi, 4 BPM ca 150 psi, 5 BPM ca 200 psi. Pump LCM down backside. Watch hole - static. POH. MU squeeze assy, RIH. Set pkr ca 755', tailpipe ca 818' Mix & pump 50 BBL of 20% CaCl~, 30 BBL drl water, 80 BBL Flo-guard", 30 BBL ~rl water. Mix & pump 5000 sx C~ass "A" w/ additives. Pump ca 3 BPM ca 150 psi. 10/02/88 Fin mixing & pumping 5300 Class "A" w/ additives. Displace w/ 64 BBL inlet water 2 BPM. Press increased f/ 125 psi to 200 psi. Cmt in place ca 0702 hrs 10/2/88. Initial shut in DP press 100 psi. Release pkr, POH 2 stds. Set pkr ca 566'. Pump 2 BBL every 1/2 hr press increase f/ 100 to 250 psi. POH w/ pkr. RIH w/ bit & BHA. Drl firm to hard cmt f/ 819'-950'. Circ hole clean f/ 950'-975'. CBU. POH. Run temp log, TOC ca 670' Est inj rate 2 BPM ca 175 psi, 4 BPM ca 225 psi. Presently loading cmt on board. Have 3300 sx on board. 10/03/88 WOC. Set pkr ca 786'. Mix & pump 3200 sx Class "A" w/ additives. Displace w/ 23 BBL water. Cmt in place ca 1200 hrs 10/3/88. Final displacement press 1 BPM @ 270 psi. WOC. Release pkr. POH. RIH w/ bit. Drl firm cmt 849'-940'. CBU. Test csg to 1000 psi. POH. MU perf pkr assy. RIH. Dai'iy Well Operatior.. Steelhead Platform Well M-26 Page 15 10/04/88 ",:L, ..,-.,:.; ..~ . RIH w/ perf pkr. Perf thru DP f/ 870'-875' w/ 4 SPF. Establish inj ra~;'ct~°ra~e BPM ~ 50 psi, 3 BPM ~ 125 psi, 5 BPM ~ 220 psi. Mix & pump 6100 sx of Class "A" w/ additives. Final displacement press 180 psi ~ 3 BPM. Cmt in place 1750 hrs 10/4/88. WOC. Taking on cmt from MV Monarch. 0/05/88 WOC. POH w/ pkr. MU pkr w/ unloader. RIH. Set pkr @ 627'. Press up to 950 psi to clear perfs. Inj @ 2 BPM @ 200 psi. Est inj rate i BPM @ 120 psi; 3 BPM @ 240 psi; 5 BPM @ 475 psi. Mix & pump 4400 sx Class "A" w/ additives, displace w/ 50 BBL water @ 3 BPM. Maximum press 350 psi. Cmt in place @ 0600 hrs 10/6/88. 10/06/88 WOC. Release pkr. Unable to set pkr. Close annular. WOC. Pump 2 BBL every hr. POH. Found pkr backed off @ 4-1/2" 8-round connection on top of pkr. Left pkr & tailpipe in hole. RIH. Screw back into pkr, work pkr free. POH slow. LD pkr. RIH w/ bit. Drl cmt 781'-900' Circ hole clean. POH Run temp log. Found TOC @ 596'. RIH w/ pkr & 2-7~8" tailpipe. Set down ~ 477'. Work past, set down @ 602'. Dragging to RIH. POH. MU bit & scraper. Trip to 750'. POH. Found orginal tight spot @ 489'. RIH w/ pkr & 2-7/8" tailpipe. 10/07/88 RIH w/ pkr. Set pkr (a 721'. Mix & pump 5000 sx Class "A" w/ additives. Initial inj rate i BPM @ 150 psi, 3 BPM (a 240 psi, 5 BPM Ia 410 psi. Max displacement press 310 psi. Cmt in place @ 1810 hrs 10/7/88. Release pkr. POH 1 std. Set pkr, WOC. Taking on cmt f/ MV Rig Engineer & Monarch as weather al lows. 10/08/88 WOC. POH w/ Baker pkr. LD same. Run test plug, test BOPs and manifold 250/5000 psi. Annular 250/2500 psi. PU & RIH w/ RTTS. Set pkr @ 722'. WOC. Est inj rate 1BPM @ 180 psi, 3 BPM @ 380 psi. Mix & pump 2800 sx Class "A" w/ additives. Displace w/ 18 BBL water @ i BPM. Max press 275 psi. Cmt in place @ 2035 hrs 10/8/88. WOC. POH 2 jts, reset pkr @ 662. WOC. Taking on cmt. 10/09/88 POH w/ RTTS. RIH w/ bit. Drl cmt f/ 782'-860'. CBU. POH Run temp log. TOC @ 598'. Test csg to 1000 psi. OK. RIH w/ perf string $ RTTS pkr. Set pkr @ 662'. Perf f/ 790'-795'. POH. PU bypass. RIH w/ RTTS & tbg tail. Set pkr @ 655'. Est inj @ 1BPM @ 140 psi, 3 BPM @ 200 psi, 5 BPM @ 330 psi. Mix & pump 4500 sx Class "A" w/ additives. Displace @ 5 BPM @ 350 psi. Displace w/ 50 BBL water. WOC. POH I std, set pkr. WOC. Daily Wel 1 Operation, Steelhead Platform Well M-26 Page 16 10/10/88 WOC. Unload cmt from MV Monarch. Est inj rate 2 BPM ca 375 psi, 4 BPM ca 475 psi, 5 BPM ca 675 psi. Press dropped to 550 psi. Mix & pump 3300 sx of Class "A" w/ additives. Displace w/ 50 BBL inlet water, 4 BPM ca 350 psi. Cmt in place ca 1746 hrs 10/10/88. WOC. 10/11/88 WOC. POH w/ pkr. MU bit, RIH. Drl hard cmt 724'-820'. CBU. POH. RIH w/ pkr, set pkr ca 659'. Offloading cmt from MV Monarch, have 3100 sx on board. 10/12/88 Offload cmt. Set pkr ca 659'. Est inj rate i BPM Ca 125 psi, 3 BPM ca 300 psi, 5 BPM ca 500 psi. Mix & pump 3650 Class "A" w/ additives. Displaced ca 3 BPM ca 500 psi. Displaced w/ 18 BBL. WOc. POH w/ pkr. RIH w/ bit. Drl firm cmt f/ 722'-830'. 10/13/88 CBU. POH. Run temp log; TOC ca 610'. RD WL. RIH set pkr ca 659'. Offload cmt from boats. Presently have 3600 sx on board. 10/14/88 WOe. Est inj rate 1 BPM ~ 350 psi, 3 BPM @ 525 psi, 5 BPM ~ 800 psi. Mix & pump 4000 sx Class "A" w/ additives. Displace w/ 50 BBL water (a 4 BPM [a 525 psi. Cmt in place ca 1152 hrs 10/14/88. Release pkr, POH i std. Reset pkr, WOC. 10/15/88 WOC. Release pkr. Set pkr ca 659'. Had abandon platform drill. Secured well, all personnel to lifeboats. Est inj rate i BPM ca 250 psi, 3 BPM ~ 400 psi, 5 BPM ca 750 psi. Mix & pump 5000 sx Class "A" w/ additives. Fin rate 4 BPM ca 500 psi. Cmt in place @ 1210 hrs 10/15/88. WOC. POH. Test BOP equip to 2500 psi. PU bit & drlg assy. RIH. WOC. Drl hard cmt 722'-775'. CBU. POH. Run temp log. TOC @ 600'. Test csg & cmt to 1000 psi for 10 min, OK. PU pkr. RIH. Set pkr ca 457'. RU W-line. 10/16/88 RIH. Perf w/ 4 spf f/ 625'-630'. RD W-line. Est inj rate 2 BPM ca 100 psi, 3 BPM ca 300 psi. Pump 6 BBL total. Well on slight vaccum. POH. RIH w/ sqz pkr. Set @ 475'. Re-establish inj rate i BPM ca 125 psi, 3 BPM ca 475 psi, 4 BPM ca 650' psi. Mix & pump 4200 sx of Class "A" w/ additives. Displace 3 BPM ca 525 psi. Cmt in place ca 1503 hrs 10/16/88. WOC. Release pkr. POH. RIH w/ drlg assy. Drl firm cmt 538'-630'. CBU. POH. Daily Well Operatior, Steelhead Platform Well M-26 Page 17 10/17/88 Run temp log. TOC Ca 530'. RD W-line. RIH w/ cmt & assy. Set pkr Ca 475'. Est inj rate Ca 5 BPM Ca 650 psi. Mix & pump 5000 sx Class "A°' w/ additives. Displace w/ 50 BBL inlet water. WOC. POH. MU bit. RIH. Tag cmt Ca 538'. Drl cmt 538'-660'. CBU. Run temp log. TOC @ 480'. RD W-line. RIH w/ cmt assy. Set RTTS Ca 475'. Presently taking on cmt. 10/18/88 WOC. Take on cmt. Est inj rate 1BPM Ca 125 pis, 2 BPM Ca 200 psi, 3 BPM Ca 325 psi, 4 BPM Ca 370 psi, 5 BPM Ca 500 psi. Mix & pump 5200 sx Class "A' w/ additives. Displace w/ 50 BBL inlet water. Final sqz 350 psi Ca 4 BPM. WOC. Taking on cmt. 10/19/88 WOC. Take on cmt. Reset pkr Ca 471'. Est inj rate 1 BPM Ca 150 psi, 2 BPM Ca 250 psi, 3 BPM Ca 325 psi, 4 BPm @ 475 psi, 5 BPM ca 675 psi. Mix & pump 5000 sx Class "A" w/ additives. Pumping rate 4 BPM ca 400 psi. Final rate 2 BPM ca 200 psi. Displace w/ 15 BBL inlet water. Cmt in place Ca 2100 hrs 10/19/88. WOC. Reset pkr Ca 382'. o/2o/88 WOC. Drl cmt 535'-615'. CBU. Test csg to 1000 psi, OK. Run temp log to TOC Ca 497'. WOC. Take on cmt. RIH w/ pkr. Set Ca 378'. RU to perf. 10/21/88 Perf 490'-495'. POH w/ perf string. RIH w/ cmt string. Est inj rate of 1 BPM Ca 500 psi, 2 BPM Ca 900 psi, 3 BPM Ca 1200 psi. M&P 86 sx cmt Ca 3 BPM Ca 1200 psi. SD to increase press on backside. DP/annulus press equalized. Reset pkr above & below original setting depth, OK. RIH w/ bit, CO to 610'. Perf 500'-505'. Est inj rate of 1BPM Ca 275 psi, 3 BPM Ca 475 psi, 4 BPM Ca 475 psi. M&P 5000 sx Ca 4 BPM Ca 400 psi. 10/22/88 WOC. Est inj rate of 1 BPM Ca 225 psi, 3 BPM Ca 450 psi, 4 BPM Ca 600 psi. M&P 5000 sx Class "A" w/ additives Ca 4 BPM @ 600 psi. Displace w/ 50 BBL inlet water. WOC. Take on cmt. 10/23/88 WOe. Est inj rates of i BPM ca 225 psi, 2 BPM Ca 275 psi, 4 BPM ca 625 psi. M&P 5000 sx Class "A" w/ additives ca 4 BPM ca 500 psi. Reset pkr @ 255'. POH. Dai~y Well Operation. Steelhead Platform Well M-26 Page 18 ~?,~ 10/24/88 Test BOPE. MU pkr & RIH. Set prk (a 352'. Est inj rate of 1 BPM Ia 0 psi, 3 BPM @ 375 psi. M&P 5000 sx Class "A" w/ additives. Final press 1 BPM (a 140 psi. CIP @ 0042 hrs 10/25/88. WOC. POH w/ 40 stds DP. 10/25/88 POH. LD DP. WOC. Close BR. Attempt to test csg. Inj i BPM [a 600 psi. PU DP & RIH. OE. Spot 40 sx bal plug 349'-405'. POH. WOC. Test csg 1000 psi, OK. ND flowline & BOP stack. NU PSA on flange. Preparing to skid rig. docs~shp~m26, doc ATTACHMENT #2 STEELHEAD PLATFORM WELL M-26 Weilbore After Temporary Abandonment (3-27-88) (closed) Northeast -- Blind Rems (closed) ~ ~ west Divert 20' Diverter System 152' MSL 163' MLLW~ 300' 346' 188'-T~;~.of cement 100 sx cmt. 247'-Top of cement 150 ex cmt. 34' Conductor Mud Line 34' Conductor et 481' Cemenl Sheelh wilh 8'-10' I.D. 458'-To1~ of cement 773 tx cmt. (break in cement) 486'-Top of fill Open Hole ~ 570' - Top of 20' casing ? ~ Top 13-3/8' casing ? 20' Casing et 766' 2-13 3/8' Casing Fish ? TD I! 2265' STATE OF ALASKA ALASKa-, OIL AND GAS CONSERVATION COMM,o~,iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ ?emporary Abandon 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg B-1 Cond. ~fl Steelhead Platiorm 964.5' FNL, 524.6 FWL, Sec. 33 - 9N - 13W- SM At top of productive interval Ateffective depth 964.5' FNL, 524.6' FWL, Sec. 33 - 9N - 13W - SM Attotaldepth 721' FNL, 580' FWL, Sec. 33 - 9N - 13W - SM 5. Datum elevation (DF or KB) 152 ' KB 6. Unit or Property name Trading Bay Unit 7. Well number M-26 8. Approval number 87-106 9. APl number 50-- 733-20393 10. Pool N/A 11. Present welt condition summary Total depth: measured true vertical 2,265 ' feet Plugs (measured) 2,235 ' feet 188' - 486' cement Effective depth: measured true vertical 480 ' feet Junk (measured) 480 ' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 395' 703' 2,187' Size Cemented 34"Driven & Grouted 20" 1325 sx 13-3/8" not cemented Feet true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ... 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water.'Bbl Casing Pressure Measured depth ~ue Verticaldepth 468' 468' 776'parted @ 480' 776' 255'casing not 2,222' found 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Environmental Enqineer Tubing Pressure Date 4/19/88 Submit in Duplicate~ DQte:- ~February 26,-1988 Approved: ___ , , I. Well Status: , M-26'. Finish rigging up and started Otis and HOWCO equipment. Made-up BHA (pilot MIU) and RIH to 354' on 5" DP. Could not circulate with Northwest deisel firewater pump. Gas locked at low, slack tide. Fabricated 12" tie-in from seawater to firewater system in subdeck. Tested mud mixing equipment. Total 3775 bbl liquid mud plus dry mud materials on board. Date: February 27, 1988 Time: 9:00 A.M. Approved: I. Well Status: M-26: RIH with Pilot Mill-Tag at 370'. Washed with seawater returns to 479'. Lost returns. Pumped in seawater at 66 BPM - bubble around leg decreased to about 10% of original size. Pumped 420 BBL mud. Washed 479' - 507' without returns. Tagged at 507'. Rotated with some torque. POH with mill. Rig up to run caliper log in morning. From 1800 hr to 0600 b_rs (2/27) pumped seawater in well at 20 - 25 BPM. No M-26: gas out diverter. Date': February 28, 1988 7~ ¢~ ~ · ~ ~ ' Time: 9: O0 A.M. Ran ca!iper/CCL log fr~m 450'. Did not locate 13 3/8" casing - 20' casing to 450' looked okay. RIH with 7 1/2" pilot mill to 479'. Shut down pumps 30 minutes and observed well - no flow to surface. Washed fr~m 479' - 507' %%th seawater and no returns. Washed through 507' - 511' several times - sticky. 'Worked pipe until no drag. Washed and reamed51!' - 542' with no returns. Hard fill 526' - 542'. Shut down =~- ~?c%t ~,~_tb DP st 527' s_nd ~~ 5 BPM into well. I. #eli Status: Time: 9:00 A.M. Approved: i~~ M-26: While rigging-up, well headed at 0645 hrs. (2/28). Increased pump-in rate down annulus from 5BPM to 30 BPM. Had full returns. POH from 525' to 479' with tight hole. Circ. at 479' W/30 BPM and pumped dye- got dye back in returns to 385'. Circ. and POH from 479' to 385'. Had 10-15,000# drag up to 400'. RIH - tag at 401'. Wash from 401'-473'. Wash and reamed 473'-479' with high torque. POH and had 1 1/2" to 2" rocks in blades of mill. Ran-caliper/CCL log. Sat down at 414' - tool malfunctioned. Reran with same results. SI for night. · ..- .......... __~___,in annulus at 10. BPM all night- hole stayed full. Date:. MarCh 1, 1988 I. Well Status: Approve d: M-26: RIH with 12 1/8" lead impression block - set down at 420'. POH with impression block - looked 'like top of 13 3/8" casing, egg-shaped. RIH with reverse circulating junk basket and set down at 420'. Wash 420' - 426', no rotating. POH-well began to head and blow small amount of gas while pumping in annulus at 10 BPM. Recovered only small rock in RC-JB. RIH with RC-JB to 313'. Stabilized well with 20 BPM down DP. Well continued to head and blow small amount of gas -. _through-out the ·.night. ..:~ :. '...~.-~.~:.~%T...~-.~ ...... r.- ¥:.. ~.~- ~ .,~.... ~......~._ ~' %..~ ~ ...~.~,..~.~:~m?~..: ..- .~ --~ ~ -r. 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Well Status: M-26: RIH from 313' with reverse circulating junk basket. Set down at 426'. Washed down 426'-448' without rotating. Well began flowing gas, water, coal, and rocks. Pumping down DP 20-40 bpm. Diverted flow out West diverter 'line. POH to 417' with 100,000 lbs (string - 30,000 lbs). Stuck pipe. Well quit flowing except steady, stream of seawater. Pump-in at 20 bpm down DP. Pump 80 bbl high visc. (13.9 ppg) mud. Lost returns. Continue pumping down DP at 40 bpm. Worked pipe free and POH with reverse circuiting junk basket. Pumped in annulus at 20 bpm while POH - Regained circulation - full. RIH with 7 7/8" bit', with nozzles cut out. Tag with bit at 445' POH to 313' and shut in for the night. Closed diverter valves. Had 29 psi pressure on wellhead at 0600 hrs. Date: ~ March 3, 1988 I. Well Status: Time: 9:00 A~~ Approved: M-26: Had 30 psi on well. Pumped SW down DP and bled pressure down to 0 psi through overboard line. RIH with 7 7/8" bit from 313' to 475'. Had intermittent returns with diverter valve open. Washed and drilled 475'-479' With torque. Lost all returns at 479'. Drilled to 506' - · pickup and hole woUld fill in. Washed and reamed back down to 506' several times with 30 BPM down DP and 20 BPM down annulus. PU to 445' and shut off pumps - waited 15 minutes. RIH and tag at 487'. Repeat and tag at 487'. POH with bit. RU WL and ran caliper/CCL. Tagged at 479'. Log out. Still inside 20" casing - looks OK. MU and RIH with 11 1/2" OD magnet to 313'. Shut-in for night with diverter lines closed. Well had 10 psi at 0500 hrs. · Approved: I. Well Status: M-26:_ _ RIH with 11 1/2" OD magnet. Tag at 487'. POH with 3 joints. Well tried to kick. Stripped °~t with 40 psi on well. Recovered only small metal shavings on magnet. Pump in at 30 BPM and pressure dropped 40 psi to 0 psi. RIH with 12 1/4" bit to 479' - did not tag. Pumped at 5 BPM at 2200 psi. POH looking for plug in DP - found nothing. Changed BPV. RIH with 12 1/4" bit and tag at 484'. Drilled with high torque 484' to 490'. PU. Hole fell in. Drilled back 484'-490' POH to 351' and SI for night. Had 10 psi on well at 0600 hours (3/4/88). Date: - March 5, 1988 Time: 9:00 A.M. I. Well Status: RIH wi~ 12 1/4" bit and ~t'basket. Tag at 484'. Drilled 484' to 503' with high torte. Could not ~ill below 503'. POH and recovered ~ut 2-cups of pebbles ~d rocks (1/4" to 2") in ~t basket. RIH wi~ Rev. C~c. ju~ basket. TAG at '484'. Drilled 484' to 486' wi~ varied torte. Regain circ. approx~atety 2 ~nutes. PU wi~ 20,000~ ~ag. Set down at 4~'- could not m~e hole. ~H. Recovered approx- ~atel7 3 gallons of cobbles (1 rock - 9" x 5" x 4"). RIH wi~ R~ to 313'. SI for night. No pressure buildup during night. Date: March~ 6;~11988 ~ - . I. Well Status: M-26: _ T/me: 9: 00' A.M. Approved: · RIH from 313' to 483' with reverse circulating junk basket. Drilled with'-RCJB"4'83' to 485' with high torque. Could not get deeper. Pump high risc. pill at 8.7 ppg. POH - recovered 5-3" cobbles and 1-qtl of · . gravel. RIH with open-ended DP to 436'. Hole would not stand full with SW. Mixed and pumped 378 sx of cement - displace with 10 bbl sw. CIP at 1645 hrs., 3/5/88. POH with OEDP. Hole standing full at +88' elev. Pumped 29 bbl sw into well and SI for night. Had 6 psi on well at 0600 hrs. - 3/6/88. Date: March 7, 1988, Time: 9:00 A.M. Approved: I. Well Status: M-26: Had 6 psi on well at 0600 hrs. - 3/6/88. Opened Northeast diverter to bleed off gas.- Hah a flow of gas, rocks, and water (rocks laying in diverter line)· Closed Northeast diverter. Pumped in 250 bbl SW at 150 psi. Pressure increased to 1800 psi at 258 bbl. Opened Northeast diverter and had 8" flow of water. Noticed 2 - 30" flanges on riser stack leaking. Shut down pump. RIH with 7 7/8" bit + BPV and tagged at 479'. Isolated leaking butterfly valve. Well not flowing. Retorqued 30" flange bolts and checked diverter valves. Could not function either valve. Mixed and pumped 168 sacks cement and laid balanced plug from 479'. POH with 7 7/8" bit. CIP at 1808 hrs., 3/6/88. Estimate top of cement at 380'. Repaired sheared key in ,. actuator for NE diverter valve. Function valve OK. West valve actuator not functioning. SI & observed well. Had 0 psi at 0600 hrs. -'3/7/88. I. Well Status: M-26: APProved: ' Removed actuator from West diverter valve. Repaired problem with hydraulic line quick-connect at accumulator. Valve functioned OK. Tested BOP stack to 500 psi - pumping 1 BPM to maintain 500 psi due to leakage out of Northeast diverter valve. No leaks at BOP stack. MU & RIH with 12 1/4" bit and boot basket. Tagged cement at 373'. Drilled hard cement from 373' - 403'. Hold-down bar on snubbing unit rotary broke. Had full circulation with SW. PU to 288'. SI for night. Date: March 9, 1988 Time: 9:00 A.M. Approved: I. Well Status: M-26: RIH with 12 1/4" bit from 288' to 403'. Drilled hard cement 403' - 405' in 1 1/2 hours. Pumped 50 bbl high visc. mud sweep - recovered lots of cement cuttings. POH with 12 1/4" bit. RIH with 7 7/8" bit. Slip spider broke on traveling slips. Changed out spider. Drilled with 7 7/8" bit from 405' to 415' in 1 3/4 hours. Pumped 50 bbl high visc. mud sweep and got good cement cutting returns. POH to 314"and SDFN with both diverter valves closed. ~ Approve~: . . I. Well Status:' M-26: RIH from 314' to 405' with 7 7/8" bit. Drilled cement 405'- 440' pumping high risc. mud sweeps to clean hole. Tight at 440' - work pipe with 6 - 10,000 ~ drag. Made connection and drilled to 470' - hole OK. Made connection and drilled to 479' - lost returns. Pumped SW at various rates and regained partial returns. Drilled 479' - 482'. PU to 476'. Set down on fill at 478' (lost 4' of hole). Well began to unload gas, gas cut water and rocks up to softball size. Pumped SW followed by 250 bbl of 12.5 ppg mud - could not kill well. Pulled one joint of DP. BPV's not holdin._.~g. SDFN with 70 psi on DP and 70 psi on Annulus bit at 470'. Date: March 11, 1988 Time: 9:00 A.M. Approved: I. Well Status: M-26: Well had 70 psi at 0600 hours, 3/10/88. Bit at 470'. RU and bled gas off well and pumped in at 20 bpm. Well stable. Worked pipe and got BPV to hold pressure. POH. Changed BHA and RIH with 7 7/8" bit to 473' - did not tag fill. Circulated with full returns. SI diverter valves and established injection rate of 15 bpm at 500 psi. POH to 421'.--Pumped 10 bbl SW with tracer dye, followed by 200 sacks of cement. Disp1. cement at final rate of 1/4 to 1/2 bpm at 275 psi. did not see dye in inlet. CIP at 1730 hours, 3/10/88. SIFN. Had 8 psi on well at 0600 hours, 3/11/88. ................................................................... _ ~I.':.:~'~''~. -, .'e~..'., .'..U?'.i. J .:'.,L",~.~ ~'~" Date: ~March: 12 ;~'~ 1988 ~ · . ~<~; .. Time: 9: 00~_A.M. Approved: I. Well Status: M-26: RIH with 7 7/8" bit. Tagged cement at 306'. Drilled cement 306' - 359'. Pumped sweeps to clean hole. POOH. M/U mud motor, bit and 8 jts HWDP. RIH to 271' SIFN. Date: ~March 13, 1988 I. Well Status: Time: 9:00 A.M. Approved: M-26: RIH with 7 7/8" bit and mud motor from 271' to 359'. Drill 359' to 479' with complete returns. Bottom cement at 479'. Lost partial returns. Drilled and washed to 511'. Lost returns. Drilled and washed to 514'. Picked up to 485'. Well flowed gas and water. Shut well in. Pipe stuck. Bled off pressure (80 psi). Pipe free. Pulled out of hole 5 joints. SIFN. .. Date: March 14, 1988 Time: 9:00 A.M. Approved: ~~ I. Well Status: ~ M-26: Down time (4 hrs. ) due to fog and snow. Well pressure at 110 psi. Snub out of hole with NAVI-drill for BHA change. Flush NAVI-drill · mach 1 With fresh water. Pumped down annulus at 3 bpm at various time intervals while snubbing out. P/U 7 7/8" bit and TIM with MWDP snub in hole and after 4 joints. Had enough weight on drill pipe to turn traveling slips over. Continue in hole for total 10 joints. Bit at 278' KB. Date: ~iMarch I. well Status: Approved: M-26: Waiting on weather, could not transport personnel to Steelhead Platform due to fog and heavy snow storm. Helicoptors could not fly. Well pressure 72 psi. Monitored well. Removed snow off the top decks. Date: - March 16, 1988 I. Well Status: Time: 9:00 A.M. Approved: M-26: , Snubbing.in hole from 276' to 304' with 75 psi, washed 304' to 479' with full returns. Drilled 479' to 521' with only occasional returns. Well heading occasionally. Hole tight at 521', freed pipe by increasing pump rate. POOH to 461'. Mixed and pumped 100 sacks Class "G" with 2% cacl/2. POOH to 189. SIFN. Wellhead pressur= 65 psi. Date: March 17, 1988 Time: 9:00 A.M. Approved: I. Well Status: M-26: Had 65 psi on well. RIH from 179' to 473'. Washed 473' to 481', lost returns. Drilled 481' to 492'. Shut down to repair swivel. Well kicked while shut down. 120 psi on well. Pumped into well at 20 bpm to kill well. Pulled out of hole to 390', hole tight. RIH to 419'. Washed 419' to 460'. Pumped 3 high visc. sweeps. Mud contaminated on BU. Pulled out of hole to 370'. Shut in for night. Well pressure at 0 psi at 0600, 3-17-88. Date: [March 18,..1988. I. Well Status: M-26: Wellhead pressure 0 psi. RIH 370' to 460'. Washed to 479'. Circulate at High risc. sweeps to clean hole. Washed to 492' and lost circulation below 479'. Shut down to repair swivel. Pulled out of hole to 460'. Well kicked. SI well pressure at 30 psi. Filled hole with 90 bbl. Could not pump into well with 90 psi. Washed 460' to 479'. Lost circulation. Washed to 487'. Hole stayed open with no returns. Pulled out of hole to 399'. Mixed and pumped 1000 sacks "G" with 2% calcium chloride. Displaced with 5 bbl water. Pulled out of hole L/D BHA. SI well. CIP at 1300 hours. MU new bit. SIFN. Well pressure at 1800 hours at 0 psi. Date: March 19, 1988 I. Well Status: Time: 9:00~ APproved: M-26: Wellhead pressure at 0 psi. RIH. Tagged cement at 394'. Drilled soft cement 394' to 402'. Circulate bottoms up. WOC 2 hours. Drilled firm cement 402' to 465'. Average ROP at 30 fph with 4-6K. Circulated high risc. sweep. Recovered layer cuttings on bottoms up. Pulled o~t~'of hole to 372'. Shut in for the night. Monitored wellhead pressure - 0 psi all night. I. Well Status: M-26: Date: March 21, 1988 Approved: _ Wellhead pressure at 0 psi. Ran in hole 372' to 450', tagged fill. Washed and drilled through fill to 465'. Drilled to 480' with full returns. Pumped high risc. sweep. Drilled 480' to 496'. Lost returns at 494'. Worked pipe to 476' with 35 M~ drag. Pulled out of hole to 434' with no drag. Well kicked. SI. Pressure increased to 160 psi. Pumped at 13 bpm until pressure returned to 0. Ran in hole, tagged at 483'. Drilled and washed to 496'. Pulled out of hole to 465'. SI. Well pressure increased to.150 psi. Pumped into well until pressure bled to 0 psi. Pulled out of hole to 402' while pumping 20 bpm into kill line. Mixed and pumped 1000 sacks "G" with 2% calcium chloride (204 bbl). After 90 bbl pumped, pressure increased to 30 psi. Displaced with 5 bbl inlet water. Pulled out of hole. Casing pressure increased to 95 psi while pulled out of hole. Well head pressure at 135 psi. Both diverter valves leaking. · Time: 9:00 A.M. Approved: I. Well Status:' M-26: Wellhead pressure varied from 75 to 115 psi during the night. Pumped into well at 20 bpm and bled pressure to 0. Ran in hole, tagged at 485'. Washed to 514' while pumping down kill lines at 25 bpm with diverter valves closed. Hole started sloughing below 505'. Pulled out of hole to 402'. Shut down pumps. Pressure increased to 95 psi after 5 minutes at 0 psi. Resumed pumping at 20 bpm and bled pressure to 0. Showed rate to 6 bpm and pressure increased to 60 psi' Increased rate to 20 bpm and bled pressure to 0. Mixed and pumped 20 bbl. Flow check, 10 bbl fresh water, and 1000 sacks "G" with 2% calcium chloride. Cement in place at 1745 hours. Pulled out of hole. Date: ~March 22'-1988':~ ~-. , Time: 9: 00 M. Approved: I. Well Status: M-26: Wellhead pressure varied from 0 to 75 psi back to 0 through the night. Filled hole with 120 bbl inlet water. Pumped into kill lines with 15 bpm and had 1 to 2 bpm returns. Ran in hole, tagged at 485'. Pulled out of hole to 372'. Pumped 20 bbl 10% calcium chloride, 10 bbl. · drill water, 20 bbl flo-check and 10 bbl drill water while pumping 5 bpm in kill lines. Mixed and pumped 1000 sacks of cement with drill water. Displaced with 6 i/2 bbl drill water. Pulled out of hole. Had 0 psi all night. Date:' March 23, 1988 I. Well Status:. Time: 9:00 A.M. Approved: <~ M-26: Filled annulus with 80 bbl. Ran in hole and tagged fill at 399'. Drilled soft cement 399' to 464'. Pulled out of hole to 400'. Shut · · in well for the night. Waiting on cement. Wellhead pressure durng night at 0 psi. Date: ';~ March ~ 24. i. 1988 I. Well Stat~s: Time: 9:00 A.M. Approved: -"X/ M-26: Break circulation, tagged fill at 449'. Circulate to 464'. Drilled cement 464' - 495'. Drilled on rocks to 518' and lost returns at ~518'. Attempted to pull out of hole. Had to pull 160 M and rotate to get out of hole. Pulled out of hole to 495'. Had no more drag. Ran in hole circulating at 20 bpm to 526'. Well began to unload dirty water, with sand and gravel and small amount of gas. Pumped 240 bbl 9.3 ppg. High visc. mud at 20 bpm and 1000 psi after 60 bbl lost returns. Pulled out of hole to 401. Changed swivel. Ran in hole. Tagged at 454'. Pulled out of hole to 401. Shut in well, pressure this morning at 145 psi. Date: March 25, 1988 I. Well Stat~s: M-26: Time: 9:00 A.M. Approved: . Bled 145 psi off well while pumping 5 bpm. Ran in hole to 570' without washing, tagged fill. Pulled out of hole. R/U wireline run casing coiar locater caliper to 570. Opened Caliper and pulled out of hole. Hoiesize from 570' to 480' = 26+". Holesize from 480' - 300' = . 8 to 10". Holesize 300' to surface = 19". Run DIL from 550' into 20" at 480', no indication of iron blow 480'. R/D wireline. Run in hole with drillpipe to 411'. Shut in for the night. Date: <M~ch 26,'.1988~ ~'<~ ~. . I. Well Status: Time: 9:00~~ Approved: M-26: _ RIH and tag at 486'. POOH to 443'. Pump 150 bbl of 9.3 ppg mud w/20# LCM/bbl, 10 bbl water, 20 bbl CaCl2 brine, 5 bbl H20, 20 bbl rio-check, 10 bbl water, 773 sx class "G" cement. Hopper plugged. Displaced drillpipe w/water. POOH. Drained mud pits 5 & 6, back loaded bulk bar and bar tanks to M/¥ Ocean Fin. Wel% head pressure this A.M. = 80 psi. Date: March 27, 1988 Time: 9:00 A.M. Approved: I. Well Status: M-26: Run in hole, tagged solid at 458'. Pulled out of hole to 443'. Pumped 10 bbl sea water followed by 150 sacks 15.8 ppg class "G" with 2% calcium chloride, followed by 7 bbl water. Checked drill pipe floats - OK. Pulled out of hole L/D drill pipe. Backload M/V Monarch with pits ~5 & #6; 3-U mixer; cement skid and mixer and various Halliburton equipment. Backload M/V Ocean Fin with mud from pits f3 & #4 (5) V-16 frac. skids, Halliburton equipment and Otis equipment. Date: March 2B,. 1988 I. Well Status: Time: 9:00 A~ Approved: M-26: Ran in hole and tagged at 247'. Pulled up to 223'. Mixed and pumped 100 sacks cement with 2% calcium chloride. Cement in hole at 0920. Estimate top of cement at 188'. Pulled out'of hole. Backload Halliburton, Otis and Atlas equipment on M/V Ocean Fin and M/V Monarch. ST=ELHEAD PLATFORM WELL 1~-26 Wellbore After Temporary Abandonment (3-27-88) RKB at -163' (closed) Northeast Divert .88' · ' (~ Blind Rams (closed) ~ West (closed) Divert -= 20' Diverter System 152' MSL 163' MLLW 188'-Told.of cement 100 sx cmt. 300' 346' 247'-Top of cement 150 sx cmt. 34' Conductor Mud Line Cement Sheath with 8'-10' I.D. 468'-To1~ o( cement 773 ex omt. (brook In cement) 486*-Top of fill ~26+" Open Hole 570' Top of 20" casing ? Top 13-3/8" casing ? 20" Casing at 766' 2-13 3/8' Casing Fish TD at 2265' STE,r~,,HEAD PLATFORM WELt'~-~I-26 Wellbore prior to Temporary Abandonment (3-24-88) RKB at .163' Northeast *88' Snubbing Unit West 20" Diverter System 152' MSL 163' MLLW 300' 346' 34" Conductor Mud Line 34' Conductor at 481' Cement Sheath with 8'-10" I.D. 26+' Open Hole ~570' Top of 20" casing ? Top 13-3/8" casing ? 20" Casing at 766' 2-13 3/8" Casing Fish ? --TD at 2265' Unocal Oil & Gas Divis~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL April 7, 1988 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Uni~~, Steelhead~well One sepia and one blueline each of: 4-Arm Caliper Log Dual Induction Focused Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE~PY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. DAT~: .... ,.. ~ A ~'}q ~'~ :;' ~' '' Unocal Oil & Gas Divisi~ ~" Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL March 25, 1988 HAND DELIVERED TO: 3ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska Dlstrlct ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: ~~McArthur River Field, Steelhea,~.~well One sepia and blueline of 4-Arm Caliper Log One sepia and blueline of 4-Am Caliper Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. ~, -' -- ' STATE OF ALASKA ' ' ALASPq, OIL AND GAS CONSERVATION COM,.'%SION ' APPLICA. iON FOR SUNDRY Ai . ROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~3 Alter casing [] Time extension [] Change approved program [] Plugging F'I Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Ope~rator Union Oil Company of California* 3. Address P. O. Box 190247 Anchorage, AK 99519-0247 4. Location of well at surface 964.5' FNL. 524.6' FWL, Sec. 33, T9N, R13W, SM Steelhead Platform, Leg B-l, Conductor At top_ of productive interval 8662' TVD: 1304' FNL, 2282' FWL, Sec. 28 . 9632' TVD: 550' FNL, 2550' FWL, Sec. 28 At effective depth 264' FSL, 2840' FWL, Sec. 21 5. DatuEn elevation (DF or KB) 152-- KB 6. Unit or Property name Trading Bay 7. Well number M-26 8. Permit number 87-106 9. APl number 50_733-20393 10. Pool "G" Oil Zone 'West Foreland feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner · Perforation depth: measured Length Size 395' 34" 703' 20" 2187 ' 13-3/8" true vertical Tubing (size, grade and measured depth) 2265 feet 2232 feet Plugs (measured) feet feet Junk(measured) D Qemented .Measured depth r:Lven & Grouted to Leg 468 ' 1325 sx 776' Not Cemented 2255' True Vertical depth 4.68 ' 776' 2222' RECEiVEJ) Alaska Oil &, Gas Cons. Commissio[~ Anchorage Packers and SSSV (type and measured depth) *Marathon Oil Company - Sub-operator 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing Operation February 15 , 1988 14. If proposal was verbally approved Name of approver Date approved 15.. I here~l/~c.e~_'fY,~~ foregoing is true and correct to the best of my knowledge Signed ~ O. ~ODerts ~, Title Environmental Enqineer Commission Use Only Date 2/9/88 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test F3.. Location clearance, ~ -- Approved Copy Return? by order of Approved by LONNIE C. SMITH Commissioner the commission Date¢,~-''//'''' Form 10-403 Rev 12-1.85 Submit in triplicate M-26 CLEAN OUT PROCEDURE m · No bridges on top of 13-3/8" casing inside 20" conductor. 1. Nipple up 30" riser and 20" diverter lines. · Nipple up 20-3/4" double gate BOP. Insert blind rams on top, 13-3/8" pipe rams on bottom. ~ Rig up 90 ton crane with sheave to run subsea camera. If visibility is good, inspect top of 13-3/8" casing and general inside condition as deep as possible, but not below ~800'. POH. Run CCL/GR/Cal sonde in hole as deep as possible. Run Magnelog, Acoustic/Temperature/ GR and PDK. Run CBL/CCL/GR. After log analysis and visual observation of the casing string indicates that the casing is in good condition, proceed to tie back 13-3/8" casing. Should top of 13-3/8" casing indicate any damage, casing will be cut with a power swivel and inside casing cutter suspended from the 90 ton crane. The cut will be fished out with the casing spear. The 13-3/8" casing top will be dressed off with a dressing mill to minimize damage to the seals of the Tri-State casing patch from any rough edges. · 'Pick up required 13-3/8" casing with casing patch, run in well, swallow 13-3/8" fish, land 13-3/8" on top 20" ram, space out and make cut, weld nubbin or slip on collar. Close bottom rams, change blind ram to 13-3/8" pipe ram. (Top ram to be installed upside down). 5. Nipple up mud cross with 2 - 4" outlets for kill lines. 6. Nipple up 20-3/4" single blind ram. · Nipple up 13-3/8" diverter lines and 10" mud return flow line. Nipple up snubbing unit. Pressure test -- casing patch and casing string. · · Clean out 13-3/8" casing string to bottom with water while diverting gas through the 13-3/8" diverte_r~i~~ kill well with 11.3# mud.~.~~ Displace water and well, and pump mud as required. If well is static, Run logs as required, perforate 13-3/8" casina~t0 selected intervals to fill bottom of welg~~~0~f hole doesn't take mud, it may require pumping through the perforations, caution should be exercised not to break down formation. Observe circulation. 10. If logs indicate casing damage, run string of 8-5/8" casing to bottom. M-26 Clean Out Procedure Page 2 B · Bridge on top of 13-3/8" casing in 20" conductor. i · If camera indicates any iron in hole, run magnet and retrieve junk. 2. Nipple up double mud cross. 3o Nipple up 20-3/4" single BOP. 4. Nipple up 13-3/8" diverter spool and lines. 5. Nipple up 13-3/8" mud return spool with flow line. 6. Rig up Otis snubbing unit. · Wash out bridges inside i3-3/8" with water, and 7-1/4" mill, divert gas flow through 20" diverter. Wash to ±800', should well be static and little or no gas be encountered. POH and run logs as outlined in "A" above. It is recommended that the snubbing unit be rigged down and the 13-3/8" casing tied back as set out in "A" above. See note below. Should well commence to ~unload and a large volume of gas is being diverted through the 20" diverter lines, continue snubbing into well and clean out to bottom of casing string or as deep as possible. Displace hole with 11.3# mu'd and kill well. Observe well. Run logs as required. If log analysis indicate damaged casing string, we are prepared to run 8-5/8" casing to bottom. NOTE: Under condition "A" & "B", the 13-3/8" casing string may have pressure integrity with no communication to 17-1/2" annulus. Casing and drill pipe can_be perforated while on bottom, above ball check valve in the drill pipe. When pumping mud into annulus, an unbalanced condition will exist due to heavy mud in the casing and water in annulus. The U tube effect may take place. Fill annulus with 11.3# kill mud, observe well. It will be mandatory to pump down float valve for check valve before POH. It is doubtful that a perforating gun can be run into the 13-3/8" casing to shoot circulation holes if the well is flowing through the 20" diverter. Under condition "A", you will be able to M-26 Clean Out Procedure Page 3 pump through the perforations, under condition "B" we will have to'depend on U tube effect to displace fluid in annulus or until another casing string is run into well for final squeezing operations. Every effort should be made to tie back the 13-3/8" string for better well and pumping control in killing the well. We are pumping blind during the kill operation if the 13-3/8" casing is not tied back. In the event the clean out string enters open hole, and the well is static, a string of 8-5/8" casing may be run to allow drilling beside the 13-3/8" casing to 2265'. 5" drill pipe will then be cemented into place as a kill/squeeze string. If the clean out string enters open hole and the well is on the diverter, drilling will continue to 2265' and the well will be killed with 11.3 ppg mud. The 5" drill pipe will not be pulled out so that it is used as a kill and squeeze string. GMS/GRW/rs/DD7/54 SQUEEZE PROCEDURE Squeezing off the sand intervals will begin after the well is static and filled with kill mud. Upon log analysis and pending movement of gas or water, zones of priority will be selected. However shooting at the bottom of the well is highly recommended. Log analysis should indicate bridging in the annulus. It is intended to utilize these bridges as cement baskets to assist in sand interval isolation. Should logs indicate damaged casing, an 8-5/8" casing string will be run or snubbed into the well to perform the squeeze work contemplated. The primary reason for running a new string of casing is eliminating the liability of cementing in our cement string or filling the well bore with cement that would subsequently have to be drilled out if satisfactory results were not obtained in the previous squeeze. During the squeeze process, in the event that a final squeeze pressure is attained and the cement string is still full of cement, it will be impossible to reverse out the cement with holes in the casing above any retainer in the well bore. Approximately 40 BBL of cement (200 sx) would have to be circulated out the long way or dumped on the bottom. It is estimated that 25,000 sx cement may be pumped through retainers opposite the sand intervals. Ail retainers set in the casing will be check slip engagement. Ail cement lines will be tested to 3000 psi prior to each squeeze operation. Ail cementing units will be equipped with recorders. Twenty-five (25) BBL of water will be pumped ahead of any cement slurry and spotted on bottom before engaging the retainer run on drill pipe. A formation break down will be attempted and an injection rate established. A lead slurry of 13.5 ppg will follow the above water lead. A 13.5 ppg pilot slurry will be used initially and cement placement analized before cement densities are increased. Depending on experience 16.2 ppg may be used as a tail in slurry. The amount of cement to be squeezed into the annulus will be determined pending final squeeze pressure. The cement to be utilized will be Class "G" with 2% CaC12 plus 3/4% CFR2. The slurry will be pumped into-the~ formation at 2 to 4 BPM until a final low pressure squeeze is achieved (50/100 psi). In the event that a final squeeze of 50/100 psi is experienced and the cement string is still full of cement, mixing will cease; pumping will continue with 15 BBL of water behind the slurry up to maximum squeeze pressure of 500 psi. At that point, the cement string will be picked up out of the retainer to reverse circulate the cement string clean. Pipe rams will be opened and closed accordingly to monitor the annulus during squeeze operations and to reverse out the surplus cement. Circulate the hole clean after each squeeze operation. M-26 Squeeze Procedure Page 2 In those instances where no final pressure build-up is experienced, after pumping 1000 sx of cement, the perforations will be cleared with water. WOC and re-squeeze the perforations. Logs will be run after each squeeze to determine cement height. If necessary,.each retainer may be drilled out to allow cement placement determination. GMS/GRW/rs/DD7/53 STEELHEAD M-2 ~ SNUBBING STACK WINCH 44' 3400~ Work Ba,ket 168' 10,000~ Jecy 7 1/16' Bore 4000* Meet Pole 701 3000* Stationary Slips 'I~~ 100' 5000* 13 5/8' Window ,~.=A:;;~J? ~ 45' 13950* Shaffer [' ILE~D OFF EQUALIZING LOOP AND EQUALIZE 2.00.~= 48' 1600~ Spool / ~c ' '~'" .o~. ~ '::::.:' I ~3 ~/~- I , 3 1/1l' ADJ. ~ ~ ~ v,~v,, (2)2000. ~~~~~ ~~~ ~~~ ~~~~~~ To CHOKE MANIFOLD ~ ~l' 12ooe SPOOL ~ / ~ClW U-2 ~ ~ ~ ~ m ~ ~ ClW J-2 / .. . ~ ~ w GATE VALVE 4 i4OO~ ~ ~ TO CHOKE MANIFOLD ~ ~ I .~,.o I 33 3/4' 8300* ' ~ ~ Single 33 3/4' 9300~ ,,,,,- c,. ~..~ 33 3/4' 8300* lUPlR CHOKI _...,.~ln-le DSA 20' ~000 z 13-5/8' 5000--. R-74 BX-'t60 DSA 20' 2000 X 20' 3000 R-?3 R-74 20' 2000 R-73 Hy~ril FSS 20' 3000~ R-74 ol3en close 20' Single Blind Ram 20' 3000 R-74 4' Kill Line 20' 3000 R-74 3'-11'i 20' Pipe Ram Double Gate R-74 Spool 20' 2000z 20' 3000 DSA 30' 500~ X20' 2000~--I [ R-95 R-73 with 8' 3000 Valve x-over to 10' Mu~ Return 13-3/8' Tie Back String .. 20' Dtverter 30' 500 R-g5 lm~.._~, I 3-3/8' Dtverter , 3'-7 1/4'[ 3'-4 1/2' ~Q' 500 R-95 88' Level t 4' Kill Line 20' Dlverter 14'-0' 4'-2 6'-3/8' M-26 DIVERT PIPING STEELHEAD PLATFORM WELL December 30, 1987 Marathon Oil Company Alaska District P O. Box !02380 Anchorage, Alaska 99510 Attn: Thomas R. Brooks Environmental & Safety Supervisor Subject: Trading Bay Unit Steelhead Platform Relief Well STEVE COWPER, GOVERNOR RO. BOX 7034 ANCHORAGE, ALASKA 99510-7034 Dear Mr. Brooks· I hereby approve your request to amend the Twenty-Third Plan of Development and Operations for the Trading Bay Unit in order to drill a relief well to well M-26, Steelhead Platform. Please provide the Division with the timing and the appropriate drilling information for this well when it becomes available. Sincerely, s E. Eason [7irector Robert T. Anderson, Unocal 3484A RECEIVED JAN 0 4 Oil & Gas Com~ CemmL,,~lon Anchorage Marathon Oil'Company A/ask '~'" ~istrict Produ..,n United States P.O. Box 102380 Anchorage, Alaska 995 Telephone 907/561-531 ~0 December 24, 1987 Mr. B~ll Van Dyke State of Alaska Department °fNatural Resources D~vision of Land & Water Management P. o. Box 107005 Anchorage, AK 99510-7005 Re: Steelhead Platform Relief Well Dear Mr. Van Dyke: Pursuant to our telephone COnversation, Marathon 0il Company hereby requests an emergency amendment to the Steelhead Plan of Operations to drill a relief well. Such a well may be necessary to bring Well M-26 under control. The precise location and general procedure Will be provided at a later date. Environmental & Safety SUpervisor cas:ESlO:73 November 4, 1987 Roy D Roberts Environmental Engineer Union Oil Company of California P 0 Box 190247 ~chorage, AK 99519-0247 Telecopy No. (907) 276-7542 Re: Trading Bay Unit M-26 Union Oil Company of California Permit No. 87-106 Sur. Loc. 964..5'FNL, 524.6'FWL, Sec. 33, T9N, R13W, SM Btmhole Loc. 264'FSL, 2840'FWL, Sec. 21, T9N, R13W, SM Dear Mr Roberts: Enclosed is the approved application for permit to drill the -above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment 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 diverter 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. Very truly yours, W W Barnwell Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE COPIMISSION jo Enclosure CC: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl Douglas L Lowery ALASKA OIL AND GAS CONSERVATION COMMISSION Telecopy No. (907) 276-7542 November 4, 1987 Re: ADMINISTRATIVE APPROVAL NO. 80.53 The application of Union Oil Company Oil Company of California, operator of the Trading Bay Unit, to drill, complete, and produce the Trading Bay Unit No. M-26 well as part of the pressure maintenance project approved by Conservation Order No. 80. Kevin A Tabler Landman Union Oil Company of California P 0 Box 190247 Anchorage, AK 99502-0247 Dear Mr Tabler.. Your application letter of October 19, 1987 stated that the drilling, completion, and production of the Trading Bay Unit No. M-26 well will provide for additional oil recovery. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion, and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, W W Barnwell Comm± s s ioner BY ORDER OF THE COMMISSION jo/3 .AA80 STATE OF ALASKA ~ ' ALASKA.?IL AND GAS CONSERVATION CO_,MMISSION PERMIT TO DRILL 20 AAC 25.005 ,,, Re-Entry [] Deepen~ Service .~, Developement Gas ~ Single Zone :23 Multiple Zone r-i ' , , 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Un.ion Oil CompanY of California* 152' KB feet McArthur River Field 3. Address 6. Property Designation "G" Oil Zone P.O. Box 1902'47. Anchorage, AK 99519-0247 ADL 18730 West Foreland 4. Location of well at surface 7. Uqit. or prope'rty Name 11. Type BOnd Isee 20 ~,Ac 25.025) 964.5' FNL, 524.6' FWL, ...S~e6.,,-.3~, TgN, R13W, Trading Bay SM ~.t. eelhead .Platform. ~eg B-.~, Conductor #1 ,,, ~j,~op of proouc~we imervaf,- ............ "' 8. Well number Number ~Z TVD: 1304.'., FNL, 2282'-FWL Sec. 28 9632' TVD: 550' FNL, 2550' FWL, Sec. 28 M-26 B-2-165-724-1 At total depth 9. Approximate spud date Amount 10,679' TVD: 264' FSL, 2840' FW-L, Sec. 21 November 1~, 1987 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15~l_Proposed depthcMOa.dTVD) property line Well M-25 10'S5~E : 3,063' TMD 3050 feet at 240' TVD feet 3840 10,679' TVD feet 16. To be completed for d'eviated wells 17. Anticipated pressure ~see 20 Kickoff depth 800 feet Maximum hole angle39.5o Maximum surface 3380 ,s~ ^~ ~o~a, e.,~h rrvD) 4800 psi~ 18. Casing program Settinp Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26 20 91.5 X-56 1~-4C 675 75 75 750 750.. 1'300 sx _17-1/2 13-3/8 61.0 K-55 Butt. 1833 75 75 l~O ' t~_3~ ~I~00 sx 12-1/4 }0-3/4 55.5 N-80 Butt. 501 69 69 570 : 570 / 3000 sx' 12-1/4 9-5/8 43.5 N-80 Butt. 4000 570 570 4570 4122 /I . ." 12-1/4 9-5/8 47.0 N-80 Butt 5671 4570 4122 10241 8500/] ' - 8-1/2 ,7 2¢'.0 !~=80,~utt. 3263 ,9800 ,8160 113063,10679, 550sx Present well condition summary ...../ ~ ' Total depth: measured feet Plugs (measured) _tru_e ver_t_ical_ feet . z--,,;2.2~"~ D ~,~" 71/8 Effective depth: true measured vertical feet feet J u nk (measu red)~/~o/, Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical *Marathon 0il Company - Sub-operator ' , 20. Attachments Filing fee ~ Property plat ~ BOP Sketch '~ Diverter Sketch ,~ Drilling program Drilling fluid program X.~ Time vs depth plot f-] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and corliect to the best of my knowledge "' Signed _~..¢¢~.~¢~~- '~¢' Title EIlviro~fr~m_l EnqJ_~ee.r Date 10/16/~:'7 Rd~ D. Roberts Con,mission Use Only ' 7-/r 6 50- ..... ,, Conditions of approval Samples required [] Yes _~.'--N0 Mud Icg required E~ Yes Hydrogen sulfide measures [] Yes [:~--No Directional survey required ~'~Yes C No Required working pressure for BOPE m~2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: [//I'/ ~~~~./~~'"~~C by order of : '~ '::l-- Approved by · ~¢/. ommissioner the commission Date ~/~,~ Form 10-401 Rev. 12-1-85 Submit in triplicate ~ KING SALMON ~ -t ,~ + ADL 18777 ~ ~/ AD~17594 ..~"' ~"~.~ / + ADL 18772 2 30 2g ~ ' STEEL~EAD + + -' ADL 18730 ' + VA~EN ,*~" ~ ADL 17579 ~e +-,, ADL 18729 --'~ aska Od ~ Gas Cons. .... ~ nchora~o + + + + .... ~ + ~l + I + . T ~ ~9 20 ............~ ~ARATHON OIL COMPANY ~ TRADING BAY UNIT 35 STEELHEAD PLATFORM BOP Schematic WELL: M- 2~ FROM MUD PUMPS HYD. , CHOKE I_L ADJUSTABLE CHOKE CHOKE ~ANIFOLD -- DRILLFLOOR TO MUD SEPARATOR 3' TO DERRICK VENT TO SHALE SHAKER 3' 3' KILL LINE Co FLEXlP HOSE W LINE ' ' HYDRIL TYPE GK r~ ~._._~3 5/B' x 5ooo PSi At~st~ Oil & ~, ,IND RAM, ArI~ £EIVED Cons. Comrnissior~ CHOKE LINE Co FLEXlP HOSE RAM PR'EVENTORS ARE HYDRIL TYPE V 13 5/8' X 5000 PS! ~ 13 5/8' -5000 PSI RISER 3/8'- 5000 PSI 5000 CASING HEAD 30' DRIVE PIPE 20' CONDUCTOR 13 3/8' SURFACE CASING STEELHEAD PLATFORM DIVERTER SYSTEM SPECIFICATIONS 1. Riser = 30" OD, rated to 500 psi. 2. BOP = 30" Hydril Annular, rated to 500 psi. 3. Block valve = 10", 300 psi, full opening ball valve w/hydraulic actuator.* Diverter line = 250 mm nominal schedule 40. ID = 9.80", OD = 10.53". Direction ~lves = 10", 300 psi, full opening ball valves w/hydraulic actuators. , * Block valve is hydraulically manifolded to annular BOP such that block valve will automatically open when annular BOP is closed. ++Direction valves hydraulically manifolded together such that one valve is always open. NOTE: Ail turns in line are targeted. CRW/RLH/rs/DP5 / 3 STEELHEAD PLATFORM DIVERTER SYSTEM OPERATIONAL PROCEDURE TO CLOSE ANNULAR BOP Push "close" button on diverter system BOP control panel. Diverter block valve will automatically open. TO CHANGE DIRECTION OF VENT Push appropriate button on diverter system control panel. If west venting is desired, push "west". If east vent is desired, push "east". The hydrualically actuated valves are connected such that opening of one valve closes the other valve. Therefore, it is not possible to close both direction valves. ACTUATION OF BOP EQUIPMENT The BOP equipment on the Steelhead can be actuated form the main control panel on the rig floor or from two remote panels which are located on the bottom level at the southwest and northwest corners where the k~nittaker Emergency Escape craft are located. Also, a monitoring panel is located in the drilling foreman's office. GRW/RLH/rs/DD5/3 ?'~V:RT:R SYST:M SCHE"~"ATI''' ANNULAR BOP \ DIVERT='R SPOOL 10' DIVERT'ER BLOCK VALVE DIR=CTION VALVES 30" ANNULAR SCHEMATI(..; ,, 153' 9' BOTTOM OF FLOW NIPPLE 136' 6-3/8'~,~ ,. ~ S DIVERTER LINE 59-5/8' 132' 9' TOP OF PIPE RACK FLOW NIPPLE SLIP JOINT 29 1/2' HYDRIL 500 PSI BOP ~ DIVERTER SPOOL N DIVERTER LINE RISER SPOOL 110' 9' PIPE RACK FLOOR 10' OUTLET ~ " ~ WELLROOM FLOOR 67' JACKET TOP RISER SPOOL STARTING HUB CONDUCTOR EXTENSION STEELHEAD PLATFORM OPERATIONAL PROCEDURE FOR LOST CIRCULATION Should lost circulation occur during the drilling of the 26" hole from 0 to ± 800' TVD returns will be taken at the 88' level above ~LW rather than at the rig floor at 162' level above MLLW. There is a 10" outlet on the 30" riser at the platform's 88' level for returns to go overboard if lost circulation does occur. The valve on this outlet will be manned continuously during drilling and circulating operations. Personnel at this location will be responsible for opening and closing the valve and monitoring drilling fluid returns. a~W/R~,H/rs/DP3/3 oB ~ ~ · 4 i'. (.)' _'. '_...,. __ ~,-~,' · ! :~': 0~__.__.. !:):~ . I~'~ , i.i.o' . ~j-c) ! / ~,,~,,~,~.~ . ~ . .~/..,, · ~'~'~ I'/ ..... ---, / I'- ? · / | ; ..... " ~/--~- ' . '~lr/:~'/l::= -=- ":-,1 -----x---:--.--1 I'-:~- II - i, --~--. :~_~.. .- ........ . ..,x ?~ ,I_-r~_q~_IsT~_IY-F%/I/~ -- i I~ ~" f'--'; ':'" '" , ~" '<" '~ ~"' - ' '"--:- '1 ~/'"' '''''~' '"':- '" ' ' ~:~ ... .. ,.,,.,,.:.,, , -? ":l, ,.I I LI-'.:II,'-I-;-I-:IJlJj-I- II.:Ul:iI I .......... -: I _ _~1!:!::: _J -~ /I - l'l ': .-ll-lp. I:' ---'~. ,- ' :'l~!,n ' ' ' ~.i -- :'::'"--'- :.'~' . r ' ~ ~:. ' ' r I': I rr-~'?'.:!'T !i.!'i%:i :1' ::%,,.,,~.,,,"' I,..-, I I,,-, I / ~.~i _,, ~ t, ,.: , '.:, ','.'...,,.'~,,~: ,..~ :"-,,',.,-,,,,. / .:~._,,,, ,. ,,, ,.,,, ..... i I'J I,_,!,_L~J_,:?": L.;bl'. . /-,-/' :- . \ ..... I'- ' .Ir:'"" -I : t~--'. _1"-. . J I' ;' .... ,--- -- I. ,..I. (~ , ! ' _ .... '__l"--_r[. -- l..l-.~~l:. I . /'=~:.(,¥-~=i':\~.~',ll__~,&:,,,,:r. mn, r: ,,:,:,.,o,:: . t '""-" 1' '! '"""- /:: '-::1'.! , -- ....... ~ '?."ii -' :,,:: i I I ,iii: x ' ' i~, , · J . ,:::'. ' ,'o,,,. ' '. 'J . / I / II H ,:'\, / i_-::::::::l I 'i I/I-~-I I x~,.:(%- x- //I ,,,-, .,,..,/..: :~ I~d//I I ! ' ,-.,_.= ,f ":,' ' :' ' -- -- I ".? ' 1,'~!:-xJ`,,I l~::il .:,/..:,,.r "'..///:-~ i/'. ,,,, 1'." =:/_,::---17'1~-~'-::-:-7~_/:11. ~.:,,::=1/1: '_'--_1:1 · :.:il / ........ ' "':'-I ' %: ~£L:r,~z:~ll:: I,,IIID I.,l(')l]lil,l"_-IJ~PI:R PI.A!I ' . C, , ® A A I_ '""ii(-}. l £[ ii i fl l lin.! ';~ I ' '1"! I'lil I1: ':~. IIC), ll.i i ill II. "~'"~)'1]'ia'il 'l' ~i'i[Ll,l:l'') PtJJIP Ill,I I '""' [~ : ' "_~__1/ ''" ).,I , i , .,,, i,I I-tu I) PIT ~ el i,:, il~. [: / ~'1;I '.': ! lil,l l IJ .il~L_~' ".:' I ' '- -~- .... .I- ,ll-i ,,o o ~:!' · [I Y'- ': ~/' X,,. : ~lrl. l i, I_1, ;/ .'. 'x ' i..S"ll'x '1"· ....1~'-i__ ,:: . I'lll. II . ' ' ' ' ' . ;. : . . / -I~n ~,- :,. : · . ,. 'X..l , ..... ,, . ..... , ;In:~:~:'-"_M_ l"-'ll"<' .~ "?/I ,,:,:s,.,,.::,d l!i:.. I ...... : :- il.! jl(~fS~iIDF, fl PIT IIX: //I · I,uiu:...._ · . .-, : · l~,-"-l~l~ 'r ,l-"i~x) liiit."--,.. Il \ · /II (.:. '-t f ..... rrO~:( ' .... ~-I :, ..... .=~.~. .........,,,- '} I ~-' J '" "" ,: :I / llLJ.~ ., ll]lll l'IT "- l. · . · , , >l "" "'.[:.' J' ":" Il Y\" II i,u::r [Allll~ ..... .. I Jl ~l-':n],' '::,71.--... Il., :?\ Il. 'b~l-'l'! II:.:~l II : I I :. ' I, IlJl') I,IODIJI.I--_-I.O\YI--_F).: Pl.'AH I:-' I_. 70'- O' ( '~ ~. I.-3 ?) G 'l'llll S .~ I i ~e'll Program Page 2 DRILLING PROGRAM Conductor Drill 26" hole to 750' MD. Run & Cement 20" casing. · Surface Drill 17-1/2" hole to 1908' MD. Run & Cement 13-3/8" casing. Intermediate Drill 12-1/4" hole to 10,241' MD. or Production Run & Cement 9-5/8" casing with 500' 10-3/4" casing on top. Liner Drill 8-1/2" hole to 13,063' MD. Run & Cement 7" liner. DIRECTIONAL PROGRAM Drill vertical hole to 800'. Build angle at 3° per 100' to 7.0° at 1033' TVD. Hold to 1992' TVD. Build angle at 3° per 100' to 39.5° at 2973' TVD. Hold to TD at 10,679' TVD on a course of N19° 35'E. CASING PROGRAM Hole WOC Size Set At W~. Footage Grade Thrd -Size Time Cement , Conductor 20" 750' 91.5 675' X-56 RL-4C 26" 12 hrs. 1300 sx Surface 13-3/8" 1908' 61.0 1833' K-55 Butt 17-1/2" 12 hrs. 1500 sx Intermediate 10-3/4" 570' 55.5 501' N-80 Butt 12-1/4" 12 hrs. 3000 sx 9-5/8" 4570' 43.5 4000' N-80 Butt 12-1/4" 9-5/8" 10,241' 47.0 5671' N-80 Butt 12-1/4" Liner 7 13,063' 29.0 3263' N-80 Butt 8-1/2" 12 hrs. 550 sx From 0' 750' 1,900' MUD PROGRAM To(TVD) Wt. ViS. 750' 8.6-8.8 60-100 1,900' 8.6-9.0 40-80 10,679' 9.0-9.5 40-60 W.L. pH TMpe Mud' Treatment N.C. -- Fresh Water Low solids non-dispersed 30-12 8.0-8.5 Fresh Water Low solids non-dispersed 12-8 8.0-8.5 Fresh Water Poly-Plus K System Remarks: COMPLETION PROGRAM Run 7" liner to TD.- Cement with 550 sx of Class "G" cement. Clean out 9-5/8" casing to top of liner. Test liner top and casing to 2500 psi. POH. RIH and clean out 7" liner. Test 7" liner to 2500 psi. Make scraper runs. Displace hole with completion fluid. Run CBL and Gyro. Tubing convey perforate the West Foreland formation intervals. Set permanent production packer. LD DP. Run 3-1/2" tubing w/ 1-1/2" gas lift valves. ND BOPE. NU & test tree. Release rig. Production test well. DD6/71 ~SCALE 1 IN. = 1DO0 FEET MARATHON OIL COMP ANY Le~ B1. Slot 1. W~II STEELEHEAD PItf~. McA,"thur' M-26 P~opo,ed Rlver Field. Cook Inlet. Ak z lOOO 7OOO _~ WEST-EAST 0 lOOO 2000 5000 4000 I t I I 6000_ 5000_ 4000_ 5000_ 2000 i 1000 TD LOOATION, 264' FSL, 2840' FWL SEC. 21. TBN. RI3W TARGET (W FORELAND) ~ TVD=9632 / TMD=llT14 / DER-SO44 / NORTH 5894 ~ EAST 2025 / w FORELAND LDCAT!DN~ /' 550' FNL, 2550' FWL SEC. 28, TgN, R13W / N 19,DE¢ 35 MI N E ' (TO TARGET) / 9~54' FNL. 525' FWL · / SEC. 33. TgN. R13W ~ ..... .. ~ , . . / Comm~ss~u~ ' - ~ ' ' A~ ~-u~hOf' ,~ MARATHON OIL COMPANY Leg B1, SIo~ 1, Well No' M-26 Proposed STC'-"EHEAD Pltrm, HcArthur River FI~~"''' Cook Inlet, AK RKB ELEVATION, 152' VERTICAL PROJECTION SCALE 1 Itl. = 1000 FT. 1000 2000 3000 28" CONDUCTOR TVD=475 20' CSG PT TVD=750 KOP TVD=800 THD=800 DEP=O BUILD 3 DEO P~ 100 FT EOB TVD:1033 TMD=1033 DEP:14 AVERAGE ANGLE 7 DEG 13 3/8" CSG PT TVD=1900 TMD:1907 DEP=121 2ha KOP TVD=2000 TMD=2008 DEP=133 9 21 BUILD 3 DEQ PER I O0 FT 27 33 " 39 EOB TVD=2983 TMD=3092 DEP=5S6 . .. 4000 5000 6000 .... 7000 MAXIMUM ANGLE 39 DEG 32 MI N 8OOO 9OO0 lO000 11000 9 5/8' CSG PT TVD:8500 TMD=10246 DEP=5110 ~ ' G-1 TVD=8662 TMD=10456 DEP=5243 ~ HEMLOCK TVD=9082 TMD=llO01DEP=5590 ~ TARGET (W FORELAND) TVD=9632 TMD:IlTI4 DEP=6044 ~ TD / 7' LINER TVD=10679 TMD=13071 DIP=6908 ~ x 8/ W FORELAND TVD=lO27T TMD=12550 DEP=6576 ~ I I I I I I 0 1000 2000 3000 4000 5000 6000 VERTICAL SECT[ON I 7000 25O 2OO 150 100 5O 5O 100 150 100 t 6:300 100 0 50 I / / / / / i/ 2:3oo I / I 121oo / / t 1900 / 1700 / / ~' ~soo 1:300 5900 :3700 41 O0 ~0 1 500 1 500 1100 I I I 50 0 5O 9OO 5OO I1 5°° oo lOO i~-2 I 100 150 4500 700 200 1 ! , I I 150 I 2OO 25O 2OO 150 100 5O 5O lO0 150 1300 1200 1100 1000 9OO 300 700 SO0 500 7631 100 ! 7700 2OO I 3OO ! ,~,500 ooo ~200 / / / / / / 2900 / / / ~35oo / / / / / /- / 260O / 3200 4O0'"" 5OO I / ! / / / / 3800 ;000 53OO 0111 ;9 O0 6OO i 1300 1200 1100 1000 900 8OO 7OO 6OO 500 t lO0 I 200 3OO l 400 500 I 600 3800 3700 3600 3500 3400 3300 't200 ~100 000 9OO 1000~- I 1 O0 1 200 1 Z-'O 1 400 1 500 iii 6900 430O / / / / 6700 380C 3700 3600 3500 3400 / / '~ 6500 ~ ~111! I oo I ~ oo ~., I 3000 900 1000 1 1 O0 1 200 1 300 1 400 1500 Well M-26 Planned Well Course Interference Check An interference program was run to determine if any Steelhead, Grayling, or King Salmon wells come within a proximity radius of 300 feet to Steelhead's Well M-26 planned course. The seven wells that fall into this category are as follows: CLOSEST M-26 WELL DISTANCE DIRECTION MEASURED DEPTH M-25 9.88' S05 39E 240' M-1 ST1 85.21' S79 32E 1343' M-2 113.01' S43 02E 800' G-12RD2 189.62' S73 33W 3737' G-31 98.28' N60 14E 7679' G-1 189.19' N58 22E 8275' K-21RD 219.36' S85 19E 11543' -/ ° o · + 15 3O · 22 · mm 13 D&TUat: AI~e4(A ITAT'[ P~I~ COORDINATE tYlTEkt, M 4 . i--tm 18 __'. 2O ., r ............ 'J' I I ! |.% 10 .............. 16 15 · MARATHON OIL COMPANY ,.,k 6.t & n ,,IIIIC t TRADING nAY UNIT McARTHUR RIVER FIELD AUTMO·: NO.:__ PRESSURE DETERMINATION "G" AND WEST FORELAND OIL RESERVES The maximum pressure to be encountered while drilling WEll M-26 is expected to occur in the Hemlock reservoir. A pressure of 4041 psi at 9350' SS is predicted based upon a static reservoir pressure measured in Well G-IL on July 22, 1985. In the secondary production target, the G-zone reservoir, a maximum pressure of 3400 psi at 8510' SS is predicted based upon reservoir modeling studies. No pressure data from offset producing wells is available due to mechanical restrictions in their completions. In the West Foreland reservoir, targeted for production, the maximum anticipated pressure is 2900 psi at 9480' SS. This is based on a pressure buildup test run December 29, 1986 in Well K-30L. The maximum surface pressure calculated for the Hemlock reservoir is 3,380 psi. This pressure was calculated using the following formula: Ratio = 1 - (.018 x TVD) 1,000 Ratio = 1 - (.018 x 9082') = 0.8365 1,000 Maximum Surface Pressure = Ratio x Formation Pressure = 0.8365 x 4041 = 3380 psi LIST OF SOLIDS CONTROL EQUIPMENT 2 each - Brandt Dual Tandem Shale Shakers 1 each - Brandt Desander 1 each - Brandt Mud Cleaner 1 each - Swaco Centrifuge 1 each - Swaco Degasser A Totco E-mud system has been designed into the ~driller's console. Each of the six active pits are equipped with probes which actuate both visual and audio alarms at the driller's console. A monitored trip tank is located in the substructure of the rig to accurately gauge fluid volumes required to fill the hole on trips. GRW/RHL/rs/DD5/3 Unocal Oil & Gas f ion Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Robert T. Anderson District Land Manager Alaska District October 19, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Drill and Complete TBUS Well N-26, Lease Number ADL-18730 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 well N-26 in the NcArthur River Field "G" Zone and West Forelands pursuant to Rule 5, Conservation Order No. 80. The proposed completion of this well will re- sult in additional recovery of "G" and West Forelands Production. Your approval of this request will be appreciated. ~ery truly yours, / ~'~?~ev~ ~. Tab~e~ Landman bdb cc: S. Lambert R. Warthen Well: Steelhead Platform Well M-26 Field: McArthur River Coordinates: Surface: Top of Objective: AFE: 8315-7 964.5' FNL 524.6' FWL Sec. 33, T9N, R13W, SM Leg B-i, Conductor No. 1 "G" Oil Zone @ 8662' TVD: 1304' FNL, 2282' FWL, Sec. 28 West Foreland @ 9632' TVD: 550' FNL, 2550' FWL, Sec. 28 KB Elevation: 152' Total Depth: None Estimated Fm Tops G-1 Sand (G Oil Zone) Hemlock West Foreland Basal West Foreland Sand Estimated Total Depth Coring Program: None DST Program: None Logging Program: Conductor None Surface: None Ground Elevation: MSL 10,679' TVD: 13,063' Avg. Angle: 39.5° Course: N19°35'E GEOLOGICAL PROGRAM Potentially MD TVD Sub-Sea Productive 10,450' 8662' -8510' Yes 10,995' 9082' -8930' Yes 11,707' 9632' -9480' Yes 12,542' 10,277' -10,125' Yes 13,063' 10,679' -10,527' Intermediate: DIL/SP (DLL)/LSS on Production: FDC/CNL (Log to surface) Specrtal GR Liner: DIL/SP (DLL)/LSS FDC/CNL Spectral GR RFT (25-50 sets) & SW Cores (25-50 shots) DD6/70 Alaska,. ,.)istrict Production United States Marathon Oil Company October 12, 1987 Mr. Mike Minder Alaska Oil & Gas Conservation Commission 3001 PorcuPine Drive Anchorage, AK 99501 RO. Box 102380 Anchorage, Alaska 99510 Telephone p~'l'~ ~[ 907/561-5~11 Dear Mr. Minder: Attached with this letter is the application for the Permit to Drill Well M-26 from the Steelhead Platform and the filing fee. Should you have any questions concerning the application, please contact Bob Hosfield at 564-6338. Regards, Guy R. Whitlock Drilling Superintendent OCT ]...~- 1987 Attachment GRW/RLH / rs/DD6 / 72 (2 rmru 8) (4) Cas~ ..,~,;.~%~ .,?-~'o-,~Z (14 r2nru 22) - (5) BO~E z/~,~.~zK ........ '(2~ ~ 28) (29 r. br~ 1. Is fha p~u fee au-~ucZuad ........................................... 2. Is ~ ~o be located in a ~d pool ............................. ~E$ .3. Is well located prop. ar dis~-~nce fromm property lir~ .................. ~,, ' 4. Is ~ locar, adp .~ d~_~,-_~ca frc~ or.h~ ~ . .' ................. 5. Is ~~: undadicatad a~~ available i~ this pool ............ 6. Is ~ r.o be daviatad and is -w~_l]~ore p la~: ina!udad ................ ~ ,,, 7. Is operator ~ only m~eaT:ed part7 ................................. ~... . 8. Can l~-~i~ be .apprcr, zed before ff. fueen-daq w'ai~ ~ 9. Does ooerauor. ~ a bond im force .................................. 10. Is a conservation or'e? ~~d ...................................... 1! ~ a~~~ ~~-~~d 13 ~ ~ ~ ~ ~~ ~d · a ~ eec .e · eeeeeeeeeeeeeeeeeee . 14. ~ ~~~ s~ p~~d ........................................ 16. ~ ~ c~~ ~ed ~ ~v~ua 17. ~ c~u ~e ~ ~ca ~d ~u~~ue or pro~~ s~ ... 18. W~ c~u ~ ~ ~ ~~~ ~~ ..................... 19. ~ ~ ~~ ~ a~ue s~e~ ~ ~~se, u~i~ ~ ~u.. 20. ~ ~~~be~~o~ ~ ~. ~ old ~ore ~~u ~ce~e ~~d ~ 10-403 ............ ~. ~ a~a ~~o~ s~a~. p~sed ............................ For explorar, or~ and S~-'a~~c 29. Ar~ data presented c~ poum"~.~ overpressure zonas? ................. /J"' :31. If an.. off_s~ loc., rev: 01/28/87 6.011 ,~ ).zOo'..' /oo' ~ 7q2'~' iW - Z 6