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Home My WebLink About169-004J Als&SKA ®IL AND GALS CONSERVATION COMUSSION June 22, 2009 SARAH PALIN, GOVERNOR id 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines SCAMED OCT 0 7 2014 UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Enclosure Sincerely, Cathy . Foerster Commissioner Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 _ Trading Bay Unit D-06RD Union Oil Company of California 169-004 _ Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ _ Union Oil Company of California 182-083 Trading Bay Unit D40RD Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 _ Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 _ Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN Union Oil Company of California 173-014 Trading Bay St A-30 ( t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of request Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disposal 0 Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change Approved Program D Pull Tubing 0 Perforate New Pool 0 Install CTNelocity String 0 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: . .' s i Union Oil Company of California ~Q_nnnA'Lß Il/\ q.-. IC)() '-1- ~'4...- 3. Address: Development 0 Exploratory D 6. API Number: I ,-.,'- PO Box 19-0247, Anchorage, AK 99519 Statigraphic D Service D 50-733-2016900 7. KB Elevation (ft): 9. Well Name and Number 106' D-18 8. Property Designation: Dolly Varden Platform 10. Field/Pool(s): Trading Ba~Ga~SandS 11. Present well condition summary ~£/IIJ Total depth: measured 8,175 Feet Plugs (measured) 8,129' fJ¡... i \ 1I:D true vertical 4,796 Feet '-l... 2 9 Effective depth: measured 8,129 Feet Junk (measured) ""'~&Ga 2003 true vertical 4,764 Feet A- ~Cons~ Casing Length Size MD TVD Burst v", ,~ëõ(f~ Structural Conductor Surface 2,514 13-3/8" 2,556 2,084 962 psi 1,540 psi Intermediate Production 8,175 9-5/8" 8,175 4,796 916 psi 3,090 psi Liner Perforation depth: measured 6,883-6,951',7,118-7,150' true vertical 3,957 -3,996', 4,096-4,115' Tubing (size, grade, and measured depth) 3-1/2" L-80 9.2# @ 6,816'; Velocity String: 2-3/8" 4.6# Packers and SSSV (type and measured depth) Otis RH Hydraulic packer, 3.5" GS FN WLRSSSV @ 6,798'1,875' 12. Stimulation or cement squeeze summary Intervals treated (measured) n/a Treatment description including volumes used and final pressure 13 Representative Dailv Averaae Production or Iniection Data Oil-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 430 620 Subsequent to operation 395 14. Attachments 15. Well Class after proposed work: Daily Report of Well Operations: (attached) 0 Exploratory 0 Development Oservice 16. Well Status after proposed work: D Oil 0 Gas D WAG D GINJ D WINJ 0 WDSLP 17. I hearby certify that the foregoing is true to the best of my knowledge. Sundry Number: -, ::;J () 3' ...... .., !O..~ï-" Contact Steve Tyler (263-7649) ~. '- . <::J...J "1- Printed Name: Phil Krueger Title: Drilling Manager . \ "1//' ',l,i/ 1.,/'" Signature: ~:.>I,'t..- .,,/... / n,,! -,,"'--.. ....-...,....-...-- Phone: 907-263-7628 Date: 12/26/03 Form 10-404 Revised 2/2003 11188FL E3:iIJ' . SÇt:~~NË¡t J#~N 2 tV) 2004 RKB to TBG Head = 40.8' 1 SIZE TOP 13-3/8" 61 BTC 12.515 42' 2556' 9-5/8" 40 BTC 8835 42' 8175' B 2 Tobin 0 3-1/2" 9.2 L-80 Armco 2.992 42 6816' (E.OT) 2-3/8" CT 4.60 HS-90 NA 1.995" -44' -6858' DETAIL 2556' m hem I. 41' 2.992 Cammn hanger 3 y," 8rd (to !bot) 2. 318' 2.75" Otis 3-1/2" Ball Valve Ni Ie 3. 6764' 2.75" Otis "XO" Circulatin" Sleeve 4. 6798' 3.0" Otis "RH" H draulic Ph 5. 6810' 2.75" Otis "Q" oi Ie 6. 6816' 2.90" Otis Catcher Sub E Deployment Sub wiGS 43' & BOT CTC to 313' 1.99. 2.375",0.190" 313' 1.93' BOT CTC & 4' 3 319' 4 6798' 5 6 Rim 6824' H Zone Top Btm Amount Condition C-1 6,883 6,950 67 Open C-1 6,931 6,951 20 Open C-1 C-3 7,118' 7,128' 10 Open C-3 7,130' 7,150' 20 Open C-3 PBTD = 8129' TO = 8175' MAX Angle 70° @ 5446' MAX Angle thru interval 54° Dolly D- 1 8 Actual Schematic 12- 15-03 Created: ] 2/11102 Dolly D-18 Operation Summary Date From To Hours Remarks 2-Dec 0:00 6:00 6.0 Shut down for crew sleep PJSM Joint with production simops meeting. Work on snow removal from rig floor & Pipe rack, Start EMD & work on getting 6:00 18:00 12.0 power to rig floor, Break loose brakes on draworks, Install pick up slings on blocks for injection head. Run blocks up out of way. Move out piping and other equipment from rig floor, start working on cleaning out pill pit. Mckinley crane operator check out crane. 18:00 0:00 6.0 Shut down for night; Walk about with Schlumberger coil tbg operator, Set down went over procedure & fill out coil tbg check list. 3-Dec 0:00 6:00 6.0 shut down for crew sleep 6:00 16:00 10.0 Hands clean out both pill pits & prep tree cap for nipple up coil, round up PPE & Scafolding for coil job. ( 16:00 18:00 2.0 suspend operations & wait on Heicopter. Drilling foreman & hands leave platform. 18:00 0:00 6.0 no activity, Schlumberger having probems getting coil drifted at their yard, DSM Working out plan with Schlumberger while waiting on nitrogen 11-Dec 0:00 4:30 4.5 Shut dn for crew rest 4:30 6:00 1.5 Travel to OSK (Schlumberger coil crew no show, Hauck & Ned hands to Dolly Varden Platform, Lucas chase dn Schlumberger crew) 6:00 7:30 1.5 Travel to Dolly Varden Platform Crane operator, two Ned hands & Hauck - Platform orientation & safety meeting 7:30 10:00 2.5 Chklout work area, Remove V-door pipe bumper post for injector head access- Set beaver slide - Rlup hyd Man rider hyd .' pump 10:00 11 :30 1.5 Lucas showed wI Schlumberger in tow - Platform orientation & safetylSimops meeting wI all hands & lunch 11 :30 17:00 5.5 Unload boat & spot equipment 17:00 22:00 5.0 Rlup 2-3/8" coil tbg unit - Remove tree cap on D-18 & stack up lubricator & bops - secure well & equipment 22:00 0:00 2.0 Shut dn for crew rest 12-Dec 0:00 6:00 6.0 Rest Crew 6:00 6:30 0.5 SIMOPS with production. Safety meeting on continuation of rig up 6:30 8:00 1.5 Strung out hard line and laid out hydraulics to BOP's, fired up power pack and function tested same ( 8:00 9:30 1.5 Spotted injector head laid out hydraulics lines function tested same. Function tested transducers & mechanical gauges 9:30 12:00 2.5 Stabbed coil in injector head 12:00 15:00 3.0 Spotted Injector head on rig floor and spaced out lubricator in relation ship to V-Door roller height to accommodate BHA hook ups 15:00 17:30 2;5 Tested BOP's (see BOP test sheet) 17:30 18:30 1.0 While crew ate dinner leads discussed BHA space out. Conversed with Steve Tyler 18:30 20:30 2.0 Picked up BHA #1 , Stabbed injector head on lubricator. Shell tested to 2500#. Repaired pipe counter. 20:30 21:00 0.5 Drain and blow down lines. Secure well head and equipment. 21:00 0:00 3.0 Shut down crew for rest. End of day paper work for leads. 13-Dec 0:00 6:00 6.0 Continue to rest crew 6:00 6:30 0.5 SimopslSafety meeting & go over days forward plan wI production & all hands involved 6:30 8:00 1.5 Permit, Chk & warm equipment & go over RIH & procedure wI Schlumberger - Test both mechanical & electronic counters by Rih & tag swab valve & Pooh t/ weld on conn. (ok) - equalized pressures & open well (594 psi on well head) 8:00 8:30 0.5 Pump 26 bbls of FIW wI 6% KCL & 1 gal of J-313 friction reducer dn tbg & reduce well head pressure t/192 psi . Date From To Hours Remarks 8:30 9:00 0.5 Rih wI 2-3/8" coil tbg & bha #1 at <50 fpm noticed that mech & elect counters were not tracking each other @ 1777' CTM stopped & chk & tightened chain on elect counter & adjusted to mech. Well head pressure trending up 800 psi 9:00 10:00 1.0 Continue rih (ok) tJ 3026' CTM & started notice 4-5k extra dn wt - well head pressure trending up (1100 psi) Continue rih tJ 3932' CTM with up tJ -17k multiple dn wt - POOH 30' wI pipe moving free @ 1 Ok up wt & start pumping FIW wI 10:00 11 :00 1.0 6% kcl On coil X tbg annulus To help wI heavy dn weights - hydrostatic of fluid dropped it some, then continued trending up (1400 psi) 11'00 12.30 1 5 On pump & continue RIH tJ 6504' wI smooth dn wI of -9-1 Ok - well head up tJ 1880 psi & monitor WH pressure 15 min 1880 - . . . 1771 psi - well is fluid packed have production bleed gas only Close pipe slip rams & lock in same - held PJSM on cutting pipe - bleed off lubricator above rams & pull test & chk slips (ok, 12:30 17:30 5.0 but slip chains) Brk lubricator & strip lubricator & injector head over coil - Cut coil & dress stump stub & cut off 52' & ch k coil wear chains had slipped on coil (ok) - dress stub & install external conn. & pull test same (ok) Shut dn for dinner ( Install Schlumberger internal slip conn.on stump & SSSV assy & mate same - pull test assy & seat internal conn slips (while 17:30 19:30 2.0 repeating torque up steps to take up slack from pull test both bearing washers came out of place 19:30 21 :00 1.5 Shut dn operation & contacted Petro tech tools & anch engineering & discussed options 21 :00 22:00 1.0 Removed both bearing washers & finished m/up of Internal E-Z conn. 0 Strip lubricator & injector head over coil & assy & m/up same - equalize pressure (1400 psi) & unlock & open slip Ipipe rams & 22:00 0:00 2. rih 6779' & while rih noticed slowing increasing (suspected leak in SSSV assy) Pooh " . . .. " . ,', . " ,',.''''', "'. ',.",," ':':,' ." . ',' '. .'" '" . ",',',','," .. ,". "" .....' .. 14-Dec 0:00 1 :00 1.0 Continue Pooh tJ 6503' & shut pipe slip rams & lock in same 1 :00 2:00 1.0 Bleed off lubricator above rams (411 psi) and coil tbg @ 290 psi & bleeding dn also 2:00 4:00 2.0 Brk lubricator @ SSSV (00 packing bad) Hyd Pump open SSSV & chk for trapped pressure had 290 psi below bleed dn coil & could hear leek above suspected External conn. - M/up lubricator & strip injector head over coil & secure well & equipment 4:00 12:00 8.0 Shut dn for crew rest 12:00 12:30 0.5 Simops/Safety meeting & go over days forward plan wI production & all hands involved 12.30 13.00 0 5 Permit, Chk & warm equipment, clear snow & spread ice melt around work area & hang additional personal anti-fall devices in . . . sub base - chk lubricator (zero) chk well (460 psi gas) Brk lubricator @ SSSV Hyd Pump open SSSV & chk for trapped pressure (Zero ok) - strip injector head over coil & SSSV & . 0 1 .00 10 M/up lubricator & brk lubricator @ top of BOP & found stub 15" high (unable to work assy) Chk & retighten Internal coil conn. - ( 13.0 4. . Strip lubricator & injector head over assy & m/up same & equalize lubricator above rams - unlock & open slip/pipe rams & rih 15" Shut slip pipe rams & lock in same - Bleed dn lubricator (appears SSSV flapper is leaking) - pull test (ok) - Brk lubricator @ 14:00 15:30 1.5 SSSV Hyd pump & chk for pressure (none) - Re strip M/up & brk/out lubricator @ top of bops - Brk 511 conn. @ btm of BOT ", swivel & chk same (ok) Brk out SSSV & redress same (found table spoon of fine sandI pipe rust in flapper) - Cut off external coil conn. & chk same 15:30 16:30 1.0 incorrectly seated on coil Gust short of o-rings) & dress stub - attempt to re-dress external coil conn. (alien head lock screw stripped on body) Drill & EZ out same 16.30 17:30 1.0 Schlumberger coil operator Attempt to re-build external connector & broke slips - swapped slip body from other external . " ", ,', connector & lunch 1 .30 19.00 15 M/up SSSV assy & install test sub on btm of swivel & run assy in to well head room for visual inspection of test & loaded coil wI 7. . ,,', .,.. 2 bottles N2 & test ed 200 psi for 15 min (ok) . 19:00 20:00 t.O Bleed N2 out of coil & while attempting to M/up assy on to stump damaged 00 seal stack of SSSV on lubricator 20'00 21.00 1 0 Brk/out SSSV & redress 00 Seal stacks on SSSV - Re M/up SSSV assy - strip lubricator & injector head over assy & coil- . . . equalized above rams 460 psi - unlock & open Slip/pipe ram Date From To Hours Remarks 21:00 21:30 0.5 Fix e-counter on Schlumberger unit 21:30 22:00 0.5 RIH 263' of coil. Close slips & manually locked out. Bleed lubricator, locked down and shut down for night 22:00 0:00 2.0 Rest crew 15-Dec 0:00 10:00 10.0 Continue to rest crew / One SCS hand swapped out @ 0530 hrs & hand carried coil conn. In / Attend 0600 hrs Simops meeting wI production & go over plan forward / Chk coil pressure (zero ok) & well pressure 510 psi (gas) 10:00 10:30 0.5 Simops/Safety meeting & go over days forward plan wI production again & Coil crew after rest & new hand 10:30 11 :00 0.5 Permit, Chk & warm equipment, spread ice melt around work area - Wait On re-built external coil conn. From BOT & one new SCS hand 11 :00 12:00 1.0 SCS new hand on board w/ re-built external coil conn chk (ok) Platform orientation for new hand - lunch - PJSM w/ all hands & go over days plan & get the two new hands up to speed 12:00 13:00 1.0 Chk lubricator & bleed off pressure (appears pipe/slip rams have developed sm leek over night) - Equalize above rams - unlock & open same - Rih 6" & close slip/pipe rams & lock same & bleed dn lubricator (ok) ( Brk lubricator @ top of bops & strip lubricator & injector head off coil & cut coil - Dress both stub for external coil conn. - install same on top & pull test (ok) & M/up GS assy on same & swallow assy into top section of lubricator - Brk/out 5' & one 8' section 13:00 15:30 2.5 of lubricator & build deployment assy on stump - strip 5' & 8' section of lubricator over Deployment assy & space out & latch GS into deployment sub - strip injector head & lubricator over coil & assy. & pull test Btm external Conn. Brk lubricator & strip injector head & chk same (ok) 15:30 16:00 0.5 Strip injector head & lubricator back over assy & m/up same - equalize above rams - unlock sliplpipe rams & open same 16:00 16:45 0.75 Rih @ 2 FPM f/ 6786' tJ 6824' (-2.5' below tbg hanger) & land btm of SSSVLN in "AO" SVLN @ 322' 16:45 17:15 0.5 Tested control line & HES SSSV nipple by AO SSSV cavity tJ 3500 psi for 15 min (ok) 17:15 18:45 1.5 Fill coil wI FIW wI 6% KCL & Attempt to release "GS" having problems wI air induced cavitations of pump, Reprime pump twice & build KCL volume @ pill pit & finely released GS @ 40 bbls away (hole fluid packed & sheer out plug gone) 18:45 20:15 1.5 " Shut in well (all well head valves shut) Bleed lubricator to production - Drain fluids - PJSM on rig dn 20:15 0:00 3.75 Break lubricator at BOP's & cut off "GS" bha - Load nerf ball in coil & blow On coil w/ bottled N2 - Rig down injector head & lubricator. Break down hard lines, soft lines and bleed fluids from pump. Put night cap on BOP's for night. 16-Dec 0:00 6:00 6;0 " Continue to rest crew 6:00 6:30 0.5 Simops/Safety meeting & go over R/dn plan w/ production & All hands ( 6:30 10:00 3.5 Continue r/dn 2-3/8" Coil tbg equipment & prep for boat, Clean up work area & work on paper work Load boat (only equipment left on board was Maxi heater Do to space on boat, talk to production & will send in next boat) & 10:00 13:30 3;5 continue to clean up work area & work on paper work 13:30 15:30 2.0 Wait on chopper & send in hands except two Schlumberger do to weight & bags continue to work on paper work 15:30 17:30 2.0 Two Schlumberger continue wait on chopper & work on paper work 17:30 23:00 5.5 " Finish paper work & wait on chopper - travel to Steel head - Job complete Total Lost Time 0.0 hrs Jnplanned Time 0.0 hrs RU CT Unit 0.0 hrs ~Mobe CT Equip 0.0 hrs ~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O ACC 25.280 1. Type of request Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Annular Disposal [] Alter Casing [] Repair Well [] Plug Perforations r3 Stimulate [] Time Extension [] ~ Other X Change Approved Program [] Pull Tubing Q Perforate New Pool r~ Re-enter Suspended Well [] 2. Operator Name: 4. Current Well Class 5. Permit to Drill Numbe~A, Union Oil Company of California/Unocal 69~04-0 3. Address: Development X Exploratory [] 6. APl Number: PO Box 19-0247, Anchorage, AK 99519 Statigraphic [] Service [] 507332016900 ,, 7. KB Elevation (ft): 106' 9. Well Name/Number: D-18 8. Property Designation:~a~r,,Platform 10. Field/Pool(s): Trading Bay/Grayling Gas Sands 11 ~ '~3~,~,..~ ~ ~,..~c-., PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Eft Depth TVD (ft): Plugs (measured): Junk (measured): 8,175 4,796 8,129 4,764 8,129.00 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,514 13-3/8" 2,556 2,084 962 psi 1540 psi Intermediate Production 8,175 9-5~8" 8,175 4,796 916 psi 3090 psi Liner Perf Depth MD (ft): Perf Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6883-6951, 7118-7150' 5708-8931 ', 4096-4115' 3-1/2"/2" L-80, 9.2#/HS-80, 3.080# 6816'/~6858' Packers and SSSV Type: Packers and SSSV MD (ft): Otis RH Hydoraulic Packer, 3.5" GS FN WLRSSSV 6798'; 1875' " 12. Attachments: Detailed Operations Summary 13. Well Class after proposed work: Description Summary of Proposal X BOP Sketch [] Exploratory r~ Development X . Service [] 14. Estimated date for commencing operations: i15. Well Status after proposed work: 8/10/2003 16. Verbal Approval: Date: Oil r3 Gas X Plugged [] Abandoned [] Comission Representative: WAG [] GINJ Q WlNJ [] WDSLP [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Printed Name: Steve Tyler Title: Engineering Technician Signature: Phone: 907-263-7649 Date: ,~./..!7/03 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission ,o representative may witness,,,, Sundry Number:' Plug integrity BOP Test...~ Mechanical Integrity Test Location clearance ..... S ubseq ua nt fgrm--'~q uir-ed "~0'"'~' ~"~ ~'~~J~...~ JUL BY ORDER OF THE 7J2 ~'~" Submit in triplicate ;ANNE L Form 10-403 Revised 2/2003 DUPLICATE WORKOVER SUMMARY: ,_ 1. Prep-Work- Have wellhead technician qualify wellhead. 2. Prep-Work- Have production qualify SSSV integrity. (may have to mobe SL to pull, clean profile & reset SSSV) 3. Prep-Work- Conduct a pre-job assessment of facilities. Complete CT Checklist. 4. Unload boat. Spot Dowell's coiled tubing unit, N2 unit & tank, CT Tank and flow-back tank. I 5. CT- NU Pump-in Sub, BOP's,and Riser. Rig up coil tubing unit. RU Dowell pump, surface lines. RU return hard lines to flow-back tank. NU Micro Motion on return line. 6. CT - RU suction line and filter pod from CT tank to DS pump. Pre-mix 6% KCI in drill water. Add surfactant. 7. CT - Thread 2" CT into injector head, MU Roll-on CTC. Test CTC & BOPE. RU to take returns to flow-back tank. 8. CT- MU 2" nozzle. Stab injector Head. Shell test BOPE. 9. CT - RIH to 7000' while circulating at minimum rate. Top of fill @ 7019'. Clean-out fill to 7397' w/6% KCI/N2 w/light surfactant. Displace wellbore w/N2. trap 700 psi on tbg. POOH. Cut CTC off. 10. SL - RU Slickline. RIH w/brush. Work brush BV nipple @ 318'. POOH. RIH w/"AO" valve. Pressure test control line. Retrieve SSSV. RD slickline. 11. CT- MU lower completion: HES BHA (Shear-out sub (set shearplug f/5OOpsi shear-~.),--~O" "XN" nipple & 2-1/16" x 10' pup), BOT CTC. 12. CT- Rl~tq'/~6550'+.~Close BOPE. Cut CT. MU CTC, 2-1/16" x 6' pup,' HEs--" --" ~.75" x 1.87~5' insert profile nipple (w/preload isolation slve) W/6' tie- back sl~-e~:~GT stub. MU CTC and GS PT on surface CT. 13. CT - RIH land insert nipple onto BV profile w/end of coil tubing velocity string at ~6850'. Pressure test control line. Release from insert nipple. POOH. 14. N2 - Pressure tbg to 1000 psi to shear shear-out plug. 15. CT - RD & demobe CT equipment. Turn well over to production Dolly D-18 { CTCO & Velocity String Revision #0 Workover Summary: 1. Prep-Work- Have wellhead technician qualify wellhead. 2. Prep-Work- Have production qualify SSSV integrity. (may have to mobe SL to pull, clean profile & reset SSSV) 3. Prep-Work- Conduct a pre-job assessment of facilities. Complete CT Checklist. , 4. Prep-Work- Weld CTC onto 2' coil in Dowell's yard, prior to mobe// 5. Unload boat. Spot Dowell's coiled tubing unit, N2 unit & ta,!:rk,/CT Tank and flow-back tank. 6. CT- NU Pump-in Sub, BOP's,and Riser. Rig up coil tub~g unit. RU Dowell pump, surface lines. RU return hard lines/Xo flow-back tank. NU Micro Motion on return Line. 7. CT - RU suction line and filter pod from CT tank ~ DS pump. Pre-mix 6% KCI in drill water. Add surfactant. 8. CT - Thread 2" CT into injector head, MU te~ CTC & BOPE. RU to take returns to flow-back tank. / . 9. CT- MU 2" nozzle. Stab injector Head?hell test BOPE. · ' 10. CT- RIH to 7000' while ci[culating atpinimum rate. Top of fill @ 7019'. Clean-out fill to 7397 w/6% KC/f/N2 w/light surfactant. Displace wellbore w/N2. trap 700 psi ~' tbg. POOH. 11. SL- RU Slickline. RIH w/brush.~ork brush BV nipple @ 318'. POOH. RIH w/"AO" valve. Press~e test control line. Retrieve SSSV. RD slickline. _/ .,. 12. shear-out)~'~':'50"'~N"~pple & 2-1/16" x 10' pup). · CT - MU lower c.o__m~mpletion I~A (Shear~ shearplug f/lO00 13. CT- RIHtJ;~/-6854'~.MU' ' ' \ /OTC, 2-1/16"x" 10"pup, HES~-~t on s/ye) w) 6; tie- back ~,/(TI' stub. MU CTC and GS PT on surface CT. 14. CT - RIH land inse,~ nipple onto BV profile. Pressure test control line. Release fro]¢ insert nipple. POOH. 15. N2 - Pressure,/t6g to 1000 psi to shear shear-out plug. 16. CT - RD & d obe CT equipment. Turn well over to production Dolly D-18 CTCO Velo Strng Procedure Rev0 07-03 Page 5 of 9 7/17/2003 "UNOCALe PROPOSED Velocity, String Trading Bay Unit Well # D-18 Fuel Gas Well Completed 02/13/69 RKB to TBG Head = 42.0' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 BTC 12.515 42' 2556' 9-5/8" 40 N-80 BTC 8.835 42' 8175' Tubing: 3- l/2" 9.2 L-80 Armco 2.992 42 6816' (E.O.T.) 2" CT 3.080 RS-80 NA 1.688" -36' -6858' 2556' 6798' JEWELRY DETAIL .,N,O. Depth ID Item 1. 42' 2.992 Camron hanger 3 ½" 8rd (topfoot) 2. 318' 2.75" Otis 3-1/2" Ball Valve Nipple 3; 6764' 2.75" Otis "XO" Circulating Sleeve 4. 6798' 3.0" Otis "RH" Hydraulic Pkr 5. 6810' 2.75" Otis "Q" nipple · 6. 6816' 2.90" Otis Catcher Sub A. -318' 1.875" HES Insert "X" SSSV Nipple w/6' Tie-Back Slve w~ 3-1/2" GS FN. WLRSSSV "FXE" BV B. ~314' 1.751" 2-1/16", 3.25#, CS Hydrl Pup Joint(s) &CTC C. 314' to 6858' 1.688" 2.0", 0.156" wall HS-80 CT D. -6858' 1.751" CTC & 2-1/16", 3.25#, CS Hydrl Pup Joint(s) E. .. ~6868' 1.448" HES "XN' profile nipple~ w/1.50" profile , F. ~6870' Shear-out sub set for 1000 psi C-1 C-3 PERFORATION DATA Zone Top Btm Amount Condition C-1 6,883 6,950 67 Open C-1 6,931 6,951 20 Open C-3 7,118' 7,128' 10 Open C-3 7,130' 7,150' 20 Open PBTD = 8129' TD = 8175' MAX Angle 70° @ 5446' MAX Angle thru interval 54° Dolly D-18 Proposed Schematic 07-17-03 Created: 12/11/02 'Do~ly D- 18 { 2TCO & Velocity String Revision #0 1'1/2", ASL t:bSh 0t'lJ SJtl(' llyd. Pk.'. &7~8' "(3.0.a' ID) CIV' it)CBt TI)g, 119to ,1 112" ~.u£ txb otis *VI.A-AO' 0tls ~XO' Circ. sly. (2,7~' Inl &BIOt Okls 3-I12 q-nipple (2.?~' 10) &gl& ' Otli cJt~h~r Sub Zone C1 C1 C3 C3 C3 PE~,IrOI~ATI Offs (~lL) InterVal SPF Pha~i'ng' Date-i 6883- 6950 6 90 3/20/99I 6931 - 6951 6 90 11/11/95I 7118-7128 6 90 '11/11/95I 7118- 7128 6 0 7/6/92I 7130- 7150 4 , 2113169! 73~7' 7433' 7444* 812~' Top 3~' Tbg, Fish 7/17/2003 Dolly D-18 CTCO Velo Strng Procedure Rev0 07-03 Page 2 of 9 Re: D-18--169-004 Subject: Re: D-18--169-004 Date: Mon, 19 May 2003 09:47:06 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Santiago, Johnny T" <santiagoj@unocal.com> CC: Dwight Johnson <johnsond@unocal.com>, Lou Grimaldi <lou_grimaldi@admin.state.ak.us>, Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Hi Johnny, This note confirms our discussion with regard to D-18. You note in your message and call that the well makes only gas and has recently started making some sand. Your response to this situation was to SI the well and there are presently no plans to produce the well. If a decision is made to return the well to production, some work will be necessary to provide "sand control" and likely a velocity string will need to be deployed to prevent "loading up" at the 2 MM/day rate. Such work is presently speculative and has not been analyzed let alone approved. Any work is not likely for at least a year. For the interim, I believe that since setting a back pressure valve will remove the ability to monitor the tubing pressure without further intervention that a BPV should not be set. The wellbore does not presently have any integrity losses. The tubing, packer, production casing and wellhead are competent and the SSV was tested satisfactorily. The fluid produced by the well is methane with no H2S or CO2 that could give rise to corrosion concerns and the present SI tubing pressure is 630 psi. So long as the well is not produced, there is little risk that an integrity loss will be experienced. By copy of this email, your plan to keep the well SI using the wellhead valves is acceptable. The normal routine of monitoring the pressures on the tubing and all annuli should be continued. So long as the present integrity of the well is maintained, there is no need to install a BPV or other downhole flow control device. Should any pressure observation indicate that pressure communication has developed, you should notify the Commission and provide a plan to mitigate the identified communication. Please contact me with any questions. Tom Maunder, PE AOGCC "Santiago, Johnny T" wrote: Mr. Maunder, As you are aware of D-18 we talked about in the memo below had the leaking SSSV. Well Drilling completed work on the Dolly and left. We did get wireline out here to pull the SSSV on D-18 to repair or replace. D-18 is a gas well that we have been using about 2mmcf per day. This well is producing some water and has recently started producing a little sand. When we did pull the SSSV to repair, we found sand in the valve. We suspect this is why we are not able to get a good test on the valve. We did run and tested a couple of SSSV and could not get them to completely hold pressure. We started looking at a different type of SSSV. Possibly a flapper type or storm choke. Mean while what we did was rig wireline down and shut in the well and no longer producing it. We are still looking at our options. Currently we have no plans on flowing this well. Would like to keep our options open, as we may at a later date decide to go in and look at applying some sand controls and producing it. One option that may be a possibility that was mentioned was a back pressure plug at the tubing hanger?Is this a option?If I'm not going to produce this well do I still need to have a SSSV if the SSV test ok?Current shut in tubing pressure on this well is 630 psi. Thanks Johnny T. Santiago Production Foreman Dolly Varden Platform 907-776-6846 Cell 398-9913 santiagoj@unocal.com ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak, us] Sent: Monday, February 17, 2003 7:49 AM To: Santiago, Johnny T Cc: Bob Fleckenstein; John Crisp Subject: Re: D-18 ""~'""';Th~k's Johnny. According to the test report, the pilot and SSV were OK. As you note, please let us know when D-18 is repaired. Tom Maunder, PE 1 of 2 · SGANNED 0 20[ 3 5/19/2003 9:47 AM Re: D-18-169-004 .. .,~, AOGCC "Santiago, Johnny T" wrote: Mr. Tom Maunder, Dolly Varden has completed all repairs of the failed components from the last inspection. * SSSV on D-18 has not been repaired due to drilling being onboard. We do not have the deck space. I will get to it as soon as drilling makes room or finishes. Drilling should be completed in 5 weeks. If there are any questions, please give me a call. Thanks Johnny T. Santiago Production Foreman Dolly Varden Platform 907-776-6846 santiagoj@unocal.com ~Tom Maunder<tom maunderC, admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 SCANNED I~AY ~ 0 2003 5/19/2003 9:47 AM Re: D-18 Subject: Re: D.18 Date: Mon, 17 Feb 2003 07:49:04 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Santiago, Johnny T" <santiagoj@unocal.com> CC: Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us>, John Crisp <john_crisp@admin.state.ak.us> Thanks Johnny. According to the test report, the pilot and SSV were OK. As you note, please let us know when D-18 is repaired. Tom Mau~nder, PE AOGCC '" ' "Santiago, Johnny T" wrote: Mr. Tom Maunder, Dolly Varden has completed all repairs of the failed components from the last inspection. * SSSV on D-18 has not been repaired due to drilling being onboard. We do not have the deck space. I will get to it as soon as drilling makes room or finishes. Drilling should be completed in 5 weeks. If there are any questions, please give me a cell. Thanks Johnny T. Santiago Production Foreman Dolly Varden Platform 907-776-6846 santiagoj@unocal.com Tom Maunder <tom maunder~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission SCANNED FEB 3 1 2003 1 of 1 2/17/2003 7:49 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~,/,~:~ · Blair Wondzell, P. I. Supervisor FROM: John Crisp,'? ~ ~. SUBJECT: Petroleum In~ector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON,CONFIDENTIAL SVS Dolly Plt. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Cx,sp Date: Field/Unit/Pad: McArthur Rvl/',Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI. PSI Trip Code Code Code GAS or C¥C,,LW D-01 1670800 110 80 85i P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810l 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 ~)IL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P {3IL D- 11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 801 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 "' 0IL ~ 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P ~)IL D-25RD 1780870 110 80 100 P P OIL , , D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 1101 80 100 P P . OIL D-30RD2 1880980 D-31RD 1760740 110, '80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 ..... OIL D-48 1921540 110 80 80 p p I p OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 9o Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jc 1 Unocal North Americl~ Oil & Gas Division Unocal Corporation P,O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson ..Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, ~g~o Sn~~~l ~~1 ~ i~ 7n~ager GSB/lew DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG ~/A-1: LAT = 60°48' 28.272" LONG =151°37' 57.620" 2,490,836.22 208,461.20 757.5 2,490,836.95 208,454.55 2,490,840.99 208,456.66 2,490,842.79 208,460.79 2,490,841.51 208,465.11' · 2,490,837.76 208,467.60 2,490,833.28. 208,467.10 2,490,830.18 208,463.83 2,490,829.90 208,459.34 2,490,832.58 208,455.72 2,490,835.56 208,458.66 2,490,838.66 208,462.17 2,490,834.00 208,462.61 D-27 D-28 D-29 D-32 D-40 D-41 D-26 D-25 & RD D-24 & 34A D-31 & RD D-24A 758. l 762.1 764.0 762.9 759.2 754.7 751.5 751'.1 753.7 756.8 760.0 755.3 LEG ~A-2: 2,490,835.42 208,381.20 2,490,836.16 2,490,840.19 2,490,842.00~ 2,490,840.72 2,490,836.97 2,490,832.49 2,490,829.39 2,490,829.11 2,490,831.78 '2,490,834.77 2,490,837.86 2,490,833.21 208,374.66 208,376.67 208,380.80 208,385.11 208,387.60 208,387.10 208,383.84 208,379.34 208,375.72 208,378.66 208,382.17 208,382.61 D-1 D-17 D-11 D-7 & RD D-9 D-19 D-23 D-21 D-5 & RD D-15 & RD.& 2 D-3 & RD D-13 754.7 755.3 759.4 761.3 760.1 756.4 751.9 748.8 748.4 75O.9 754.0 757.2 752.5 LEG ~B-l' LAT = 60°48' 27. 485" LONG :151°37' 57.564" 2,490,756.22 208,462.00 677.5 1 2 3 4' 5 6 7 8 9 0 1 2 2,490,755.48 208,468.53 2,490,751.45 208,466.53 2,490,749.65 208,462.40 2,490,750.92 208,458.08 2,490,754.67 208,455.59 2,490,759.15 208,456.10 2,490,762.25 208,459.36 2,490,762.53 208,463.85 2,490,759.86 208,467.48 2,490,756.87 208,464.53 2,490,753.78 208,461.02 2,490,758.43 208,460.58 D-8 & RD D-6 D-14 & RD D-20 D-16 D-22 D-2 &A&RD D-4 D-lO D-12 & RD D-18 D-30 & RD 677.0 672.9 671.0 672.1 675.8 680.3 683.5 683.9 681.3 678.3 675.1 679.7 LEG #B-2: 2,490,755.43 208,382.00 (Reserved for Compressors) 674.8 FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 ll31.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 121'9.5 1215.4 1211.1 1208.5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Marathon Oil Company September 24, 1986 Alaskan (" 'ict Productio% Jnited States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 Bobby Foster Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska The SSSV on Well D-18 was tested on 9/10/86 during a platform shutin. D-18 is a fuel gas well for the platform. Hydraulic pressure was removed from the SSSV at 1325 hours, the turbines were allowed to run, thereby reducing pressure on the tubing. When tubing pressure reached 90 psi gauge, the turbines shutdown and the tubing was shutin. The well and valves remained in this condition for 15 minutes with no increase in gauge pressure. We then equalized with 1040 psi on the tubing above the SSSV and applied hydraulic pressure to the SSSV which opened.(see attached chart) Don R. Erwin Production Foreman Dolly Varden Platform DRE:er RECEIVED SEP 2 6:1986 Aladm 011 & Gas Cen,,, Cmmmledon VED Anchora.qe t x'-~-lo ! zooo'" k-lA' t o I 2oo'~'' /4oo 1 ! o~ I i 1980 Mr. C. H. Case Union Oil Company of California P. O' Box 6247- ~tnchorage, Alaska 99502 Dear ~. Case.= This 4s ~n response to claee:ification o£ the Monthly. Production ang I980 arding the ,on the Please refer :to g.tate-.o£. Alaska, Conservation Order ~o. 8:0, Rule I -'De£~ttion of PoOls, for de~~nat~on o~ t~ ~I ffr~ ~h~ch' ~e ~18 pr~ucea gas. You u~lI note t~t paragraph (b) sta~s '~e ~.~ur R~ver Middle ~.ena~ Oas ~oI .: as ~ ac~.lat~on of gas c~n to a~ which W~th ~e acc~u.Iation fo~d in 'the Union Trading Bay ~-I8 ~11 ~t~en t~ depths of 5360 feet and 6010 The records that' Union has sub~it~ 'to the Commission reflect that the gas production in the D-18 [s through per£orations from 71.30 feet to 715.0 feet. These are in a sand t~t corre- 'lares with the sand between 5360 feet and 53'87 feet at the top of the "Middle Kenai'~as Pool" .in the O-I.8 type well., on the J:~ usry and Subse~ent reports, the D-18 well s~.uld accordingly class~fied aa a gas produce~ from the ~cArt~ur RiVer. · Kenai ~as Pool and not be included .among the wells prod~c't~ve from. 2he ~dd. le Kenat ~undef~ned pool, Lonnie Sm i th Comm'£ssioner Union Oil and Gas ~": 'sion: Western Region · Union Oil Company ~.,,.;alifOrnia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union March ]9, 1980 Mr. Lonnie smith State Division of Oil and. GaS 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr, Smith' This is to inform you that we have diScovered an error on our monthly production and ·injection report. The error concerns the classification of D-18, a gas producer. It has been included in the group of wells listed under Middle Kenai "D" Pool and should be under Middle Kenai PoOl (Undefined). In addition, the summ~ry page of the report should read M-K (Undefined) Pool rather than M-K "B" Pool. These corrections are shown on the attached copies of the monthly report. Subsequent reports will reflect these changes. ADS/kel Very truly yours, C. H'. Case District Engineer FORM I0- 405 REV. II- 1-71 FILE IN DUPLICATE {INSTRUCTIONS ON REVERSE S !DE ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE . MONTHLY PRODUCTION AND INJECTION REPORT Trading Bay Unit, McArthur River' FIELD NAME Union Oil Company of California OPERATOR NAME January, 1980 MONTH AND YEAR OF PRODUCTION Page 7 POOL NAME 8 FIELD § DALLY AVG PROD OR INJECT DAYS TOTAL MONTHLY PROD OR INJECT LEASE NO OR WELL '"'~ ~ POOL ~ IN OiL O~ CO~D ~R m ~S UNIT NUMBERS NO APl NUMBER '- ~ CODE ~, OIL ORCOND WTR GAS OPER (BBL) (BOL) (MCF) MIDDLE KENAI POOL (UNDEFINED) 520552 UNIT 012070 D - 10 1,33-20132-00 G " 1 2,537 31 78,647 ,. 012070 G - 14 133-20146 O0 G " 1 5,171 31 160,312 ' [ TOTALS _ 238,959 MIDDLE KENAI "D" POOL 520550 ~l 2 mOl0 ' -- 9~ . D - ,18. 133-2016 G " l- 2,082 31 64,538 012070 K - 20~' 133-20192-00' G " 1 5,370 31 166,473 TOTALS 394,796 ._ ..... , ......... FiCILiTi INVENTORY- ...... L __ m' m 3mmm '.L~IAsE OR UNIT NUMBERS BEGIN IN',/'(BBLS) ENDINO INV (BBLS) ACTOR ALLOC PRODUCTION 633,755 ! INJECTION = , , PROPERTY TOTALS FORM I0 - 4 05 REV. II- 1-71 tILE IN DUPLICATE (INSTRUCTIONS ON REVERSE SIDE) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY PRODUCTION AND INdECTION REPORI POOL NAME 13 WELL LEASE NO OR NO UNIT NUMBERS FIELD APl NUMBER a POOL CODE HEadLOCK POOL K "B" P H.K "D" POOL H-K "G" POOL W-F POOL FACILITY INVENTORY LEASE OR UNIT NUMBERS 520120 520552 520550 520l 50 5201 90 BEGIN INV (BBLS) DALLY AVG PROD OR INJECT IL OR COND WTR OR ALLOC GAS PRODUCTION iNJ~'CTION Tradinq Bay Unit, r'.IcArthur River" FIELD NAME [IDioD Oil Co_m~anv of California OPERATOR -NAME ' January, 1980 MONTH AND YEAR OF PRODUCTION Pa ell TOTAL MONTHLY PROD OR INJECT OIL OR COND (BBL') 1,686,1 33 183,881 82,499 ~TR {BBL) 1,228,997 18,534 37,414 PROPERTY TOTALS GAS (~CF) 545,573 238,959 394,796 80,205 19,916 Conservation September 21, 1978 . . Mr. Eugene F. Griffin District Operations :,~anager Union Oil COmpany P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Griffin.: I would like~.tQ..know if you have made any progress in developing a. procedure for testing the downhole safety valves in the two gas source wells D-10 and~'D-IS~fon the Dolly Varden Platform since my letter of~July 13, 1978 to you. As I mentioned before, we would like to work with you in any way we can to get these valves tested and avoid an unscheduled Platform shut down. However, if something is not worked out in the next 30 days we will have to insist that we witness the testing of these even .if it entails a platform shut down. ~': Please contact me if you have any questions. Sincerely, Director HH, H: be Eugene F. Griffin District Operations Manager Alaska District Union Oil and Gas D~" 'ion. Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 · July 18, 1978 unl, n Mr. Hoyle H. Hamilton ................... Department of Natural Resources 3001 Porcupine Drive Anchorage, Ak. 99501 Dear Mr. Hamilton: By copy of this letter I am transmitting your July 13, 1978 lett~Mr. A. Mechler, Jr. requesting that the testing of wel~ down hole safety valve be reviewed. ' We concur with your concern and would hope a method of testing the ball valve can be achieved without a full platform shutdown. After MarathOn has revieWed the matter, we will be in touch. EFG:csw cc: Mr. A. Mechler, .Jr. - Marathon Oil cOmpany Mr. L.J. Anderson JUL 1 9 1978 Division ot 0il ~nd Gas Coriser'v~lon Anchorage Conservation July 13, 1978 Mr. Eugene F. ~ifftn/ District Operations ~anager Union Oil ~°mPany-~ P. O. Box 62.47 Anchorage, Alaska 9'9502 Dear Mr. Griffin: It has been brought to my attention that the downhole safety valves in the two gas source wells on the Dolly Varden Plat- form have not been checked in some time. Well~8!~was last checked in February 22, 1977 and D-10 in November 10, 1'977. The problem as related to my man who was on the Dolly Varden July 5th, is that D-10 is presently not capable of producing and therefore it would require a platform shut down to check D-18. As you are probably aware, we want to witness a satisfactory test of these valves at least each six months or more fre- quently if a high incidence of failures are reported on our inspection trips. We would like to work with you in any way we can to get the valves tested in these wells, for example it could be done if there is a scheduled platform shut down for some reason. I would like to hear from you on what can be done in the near future to resolve this matter. Sincerely yours, Hoyle It. Hamilton Director ~HH:be July 16, 1973 Re: Inspection of downhole safety shut-~.in valves in fuel f!as supply District Operatl:~s Manager Union ~t ! ~o. of eat t.fornia ~0~ W. ~th Avenue D~ar S t r During the last two years, operating checks of fha dc~nhote safety shut-.,~ in valves on the M, arath~ operated ~11¥ Verdun platfonT,, and fha Atlantic Ric'hfietd operated King Salton plaffom~ have been wmived hy our engineer on Wells ? D-18 and ~ K--20 ~ the respe¢ive stm-~erafor's request, since in each case fha welt ts ¢t llzed for a fuel gas sup:ply w.l. fh no attemate syst~ of fuel s~ppty available, l.n each in~tance our engineer requested to be notified at the next planned ptatfo¢~ shut~-d~n so that fn. soe¢ion of the gas well valve ~)uld be observed without interrupting production operations.. These no~l~s and ~nspecttons were r~ot carried though la.st summer so no tests on va I yes I n these two we I t s has been w i tnessed s i ncc ~rch and 3erie of t970, a period of over three ,/ears. "Je were duly contacted last month by ~-~arathon concerning fha Dotty Verdun platfo~ shut.~down and ,on June 28 ~¢:, engineer witnessed the pJatfom shut~-~ down, The d~n hole safety shut-in valve tn welt ? D~,f8 failed to close or leaked severely and ¢ the sa~ time the ba,ck,~up safety valve, the surf~e Manumaffc valve also leaked, These two valves on welt ¢ D~-~8 were ~pla~d and on. June 30, our engineer w. tfnessed a positive test of both valves, The fai lure of the original valve in this we!I dictates that tests be conducted at more fr~t.mnf intervals un~tt te~tino ~rov¢~ h~ Ion(l a vatve can susfa, in operating and sealing cmdtfim~ I~ this well, For the forseeable future we plan to require a text of the shut---in valve's in wel ts ~ D-18 and ;? K--20 at least once each six ~mths even if it requ, i res a olatfor~ shut*-~n. We have been advised by AR~ +hat the King Salmon p latfom w'i It be shut.¢~down in September and we plan fo witness the safety va lv~ +~4- on ~,~,all ~"~ !<-?~ at tha+ +into,, on... .... u,<,.. initlafe plans fo tes-~ the ~ g..t~ ~,.~e! I t~for~ tho Homer l.~ ~urrel I FI i r~cfor !.!L%: LC$: ~1 h Harathon 0It Company f4r, Ken Stepr, Bistrict ?roduction Supervisor ,~t I an:~ i c R i ch'f i e I d Company 02-001B STATE of ALASKA TO: ? Fb,me, r L. B~rrel t D ! rector DATE : FROM: Lonnie C. >m~th Petroleum Engl neet SUBJECT: inspection of [?.'ownhoje oa~¢ty Shut--in Valvr-,¢, Well ~-r, ~ iln~on ~4ara?hon Opera,ed F~l ~y Verdun Pla?fom~ .~ Cook ~nief ,~a_tu__rda~ J___une~_3_O~..]g7~3 ,-~ departed Anchorage by comaerci8l ai rcr~,ft arr~v-- trig in Kenat where t p~cked up a renfml car and proceeded fo the ~ Tenders het tpor~r and caught the 4:00 PN chopper to fha Po~ ty Varden plat~'fom'~ arriving at 4:t3 Production superviso.r, ~rold Lee ~d Ptatfon~. forema;~ Dean ~ *ha* the d~nhole safety shu,-~n vaive had been t~p~aced as had fha surf~e M~¢tc safety vaive. Crews were *hen in pro~ss of pressure testing the fqanu~tlc and choke valves on the wei ~head prior to attempting the test on downhole safety shut-in valve. By 7:00 PN the head Man~t~c safety valve and choke had been tesl~d ~th hydraulic pres~ sure fo 2~0 psi and a tempora~ gas b~eed off ~me h~ked up on fha head. The shut-,,,in tubing pressure was observed to be t.580 psi. The downhole safe~ sht~.-ln valve was then actuated, and gas was bled off the tubing string to lower the pressure t60 psi to t,420 psi~ h'o t~crease ~n pressure was observed which assured that no leaka.ge of the valve was occuring~ The valve was then .actuated and upon opening, the pressure immediately cl ~mbed back ~ the original 1,580 psi, i~d:icaf~ng a ~s~tive actuation and, w~th ~o teaka~ when it was closed. J felled ~t a Field tnsp~t[o~ Report, (,copy attached) ~ndicating the s¢isfactory t~t of 'the downh:ote safety shut-in va[:ve the n~t morning alt p~fabrl~ted fltfi~gs had been i~stat J~g and cutting was c~pJet~ ~ the platfo~ and purgi~na~, of J in,..,~.,~ and .... ~'- had ~ ,~,:,,~ ~o, mme~6 for the resta¢~ng of ..... * .... p, ~,,,,,uu~ ~on on the platform. The work ~rogr~s ~em ~'nni ng approx ~mfe I y twa I ye h(~rs bah ~ nd the original 72 h¢~r shut-d~n schedule. -- ! departed the O~)lt¥ Yarden platform at 7:~ AH, arriving at the Rig Tenders heJipo~ at 7:45 AM, After ret'urn~ng to the Kenai at~o~ by rental aut~)t~e t caught the iO:O0 AH f.~ght back to A~chorage~ ar-r~v~ng at app~xi~teiy t ~:00 AM. On this field trip ~ returned to the DoI ty Verdun oIaffo~ to witness the test of the newly ~nstatted replacm~ent do~nhote safety sh,uf-in valve ,¢ ~ ¢.~¢¢,~ schedule n~to ex.ed six ~nths intervals, ever, ~f ~t rec, u~res 8 shut Attachment FORM NO. 02-1B ME ORANDUN T0: F- Homer Burre~'~ D i rector THRU: O. K. Gtlb~eth uhief'~ Petroleum Engineer Petro!eum Eng! neet - DEP^P~tENT OF NATURAL RESOURCES DIVISION OF OIL ^HD GAS DATE : Aprl~ 19, 1971 Fle!d Trip Report- ~nspect~on of Downhole Safety Shut-in valve in ~elJ D-18, and Bradenhead pressures on Marathon's Dol~y Varden P~atform, Cook Inter. A_p~EL!.. 1_4 ,=]_9_7]_ . I departed Anchorage by commercla~ alr~.~raft at 7:00 A. M. and arrtved at KenaJ at 7:30 A. M. Doyle Jones, ~arathon Platform Superin- tendent, met Raiph Math~s, Marathon Safety Engineer, Leo Fraske, Marathon Waterftood Engineer', and me at the a~rport and drove us to their office at NlklSkto The ~eJlcopters were 9~ounded due to bad weather so we ~atted for departure of the ~arathon boat, the 'RI9 Engineer'. Some time ago we had advised Marathon that we wished to witness an operat~ona~ test of the downhole safety shut-}n valve tn ~hetr D-18 dry gas wei~ on the Doily Varden Platform, This Is convenient onJ. y during scheduled p~atform shut downs, and t~e were advised by Mr. ~'~1t Barber that this was planned for the Dolly ¥~rden on April t4, 197~. The mai~n purpose of my F~eld Trip was to wi~tness operation of the D-18 dc~mho}e safe~ shut-in va~Ive. Doyle Jones, Ralph Math~s~ Leo Fraske and ~ d~parted on the "Rig Engineer", along with many other off-shore personnel, at 9:40 A, I~ We arr~ved at the ~t~y Varden Platfon~ at ~0:40 A. N., about two minutes ahead of the helicopter. ~ met the P(atform Foreman, Harold Lee and No. 1 Production Operator~ Dick Musgrove on arrival. ! was Impressed by the personal safety indoctrination given me by the Safety Engl'ne~i.. The Otis personnel went to work ~mmedlate~y making preparations to pull the ex~st~ng do~nhole safety valve from ~elt No. D-18. Wh~le this was being done Dick Musgrove and t recorded Bradenhead p~essures of a~l the we l ts. Due to the shut down status of the pla~orm and the equipment modification work in p-~ogress, ~t was not possible to bleed do~n casing pressures .and observe casing pressure build up. Observed pressures are sho~n I n the attached tab ~e, White Ot~'s was r~gg~ng up, ~ d~scussed p~atfo~t activities w~th Doyle Jones. He explained that the ptatform shut down ~as not to do routine maintenance on thel. r equipment, but was to perform const'ruct~on ~ork or modifications to equipment that required welding, cutttng~ or taking out of service. Shut do~ ~as called at th~s patl. cujar time because the Dr~ft River Terminal had cut platform production back f~om the full 45,000 barrels ot~ per day to approximately 25% o~ 10,000 barre~s per day. This was to a~low the CIPL Co. to reinstal ~ the fenders on their Drift River Tanker dock. These fenders operate ~n a ve.-rtJc~l track which does not have a stop at the bottom. The fenders ran off the track and no~ have to be re~nsta~ led~. t understand th:Is ~s the t~t.~rd t~me th~s has happened and that CIPL wi II instal~ a stop at the' bottom of the track fh~s t~me, The ~a~n equipment m:~dlfJcatlons being done on the p~atform ~ere ~nstallat~on of a second, or parr:el~e~, reJ,~f H~mer Burre!i I -2- Apr! ~ ~9, 197l valve on each separator wlth iock type ~so!at~on valves~ Normai~y both ~elief va!vas will be in operation. Hc~..,ever, at any time ~tther re!ief va!ye can be Isolated from the separator and tested to determine ~f the valve ~s relieving and at what pressure. Th~s type ~nst4I~tation ~s !n compliance ~!th OCS regutattons~ Another modification was being made to the high and .~ow !!qu~d shut-off and a~ar~ systems on both the vertical and hor~zona~ separators~ A boot is being ~nstal~ed connect!ng the h~gh and iow ieve~ outlets on each separator° The boot .;s valved so ~t can be Isolated from the separator¢ and has mu!tip~e threaded outlets aiong ;Cs vert~ca~ length so that a hTgh levei probe and a iow i'.~ve~ probe can each be positioned at any veft~ca~ height. The boot can be ~tsoiated from the separator w~thout affecting production by closlng the va.~ves, and operation of the probes, atarms and shut-in devices can be tested, modtf~ed or change~l. On the main deck, a new crane had been unloaded from the boat and was being ~nsta~ ~ed~ Th~.s crane rept~aces the one lost overboard several montl~s ago, and appears to be identical' to the other ex~st~ng crane on the p~atform. At th~s time ! returned to the welt teg ~oom where Otis was preparing to pui l the downhole safety valve from D-18 dry gas we~!. Some difficulty was expected due to sand, but the valve pu~ ted free easi ty and showed no sign of sand whe~ ~nspected at the surface. An Ident~ca~ ne~ Ya~ive ~Otis Type AO was run in the Wet~ and s~, ~n the 3½'~ tubing at 344'. As run, the va'~ve ~s ~n the open position. Since separator modfficaftons were ~n pr~]ress the Wee! could not be produced. An e~ght hour shut-in tubl~ pPessure was observed to be '~550 pstg. Pressure was b~ed off the hydraulic system that ho~ds the vafve open, and the valve was ~ssumed to be closed. Th~s was checked by insta~l~ng a hose from the ~ub~cator off the p~.a?form~ and b~eedtng pressure from the tubing above the safety valve down to 650 ps~g~ After 25 mi'nutes the surface tub~'ng pressure was stl~ 650 ps~g~ ~ndicatlng ~o ~eakage past the downho~e safety v~lve. The valve was then opened by pressuring up the hydrau!ic system and the surface tubing pressure .indicated t550 ps~. Otis then prepared to ru~ a bottomhote pressure bu~tdup test ~n Wetl~ D-I8. Doyte Jones, Ralph Math~s, and I ~ught the tast he'~ icopter from the p~atform for N~kisk~ at 5:t5 P. M. t departed Kena! by commercial a~rcraft at 6~00 P. M. and arr,'red :~n Anchorage at 6:30 P. H. Attach~nt OLLY VARDEN WELL HEAD PRESSURE~~- April 14, 1971 Wel I No. D-I D-2 D-3 D-4 D-5 D-6 D-7 D-8 D-9 D-lO D-II D-12 D-13 D-14 D-15 D-16 D-17 D-18 D-19 D-20 D-21 D-22 D-23 D-24 D-30 D-31 D-32 Type Wel I Oil - Gl Oil - GL Oil - GL Oi I - GL Oil - GL 0il - GL Oil - GL Oil P&A Oil - GL Wtr. Inj. Oil - GL Wtr. Inj. Oil - GE Oil - GL Dry Gas Wtr. Inj. Oil - GL Wtr. Inj. Wtr. inj. Oil - Gl Wtr. Inj. Oil - GL Oil - GL Oil - GL Producing Zone ,, Hem Ioc k Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Hemlock Shut.in Surface~Pre$$~re - P$i~i I n?er/l~roa ~'roa/,Dg 35 1170 1190 50 I000 1260 250 1105 840 130 980 440 290 1045 720 230 450 300 170 1165 1230 I10 1140 22~0 210 1260 900 50 1120 880 160 1200 1200 Hem Ioc k 0 0 0 Hemlock Hem lock Hem Ioc k Hemlock HemloCk Hemlock Hemlock Hemlock Hemlock Hem Ioc k G G 5O 15 320 180 0 20 190 220 0 555 0 8O 0 365 1060~ 760 500 0 !150 I000 1160 1080 ~75 I~00 30 200 1060 770 250 I00 875 700 !190 840 1450 0 1040 1420 1140 1310 1020 1050 GL = Gas Lift TO: FROxT. ,JNION Oil, & ,...,kS DIX.?*SION WESTERN P,.EG ION A N C II O R ;\ C F, D I S T R I C T STATE OF_A. LASKA ~ :__ DATE' June 17, 1969 G. H. Laughbaum WELL ,',;~'V.!E' TBU D-18 'rrans:~itted herewith are the fol.!m,,ing' ¢,m No. Final 1)'..131 Ip:J:.:<.'; ion ....... ~-, . Compensated Formation Density l':or~:~tion Nm~tron [,og (Fn) ,.D;': c~,~,,tv Print Cml or .... nt,. T~,~ V~.q~ C13~.I or ,..l Plot Ct,,, Po'-" Pl Prox!mS. ty ~!~ ere! og./Ca liper Ga~ma Ray Collar Log Cement Bond Sidewall Neutron Porosity Log Later!os 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analy~i Forma ~i on Tests Directional Surveys Core Chips Samole Cut RECEI PT au,,~ut, .,:L RETURN RECEIPT TO' Union Oil & ,qas Division - Western Region Anchorage ~strict 2805 Denali Street Anchorage, Alaska 99503 Attn: Rochelle Carlton Union Oil Company( Jalifornia 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 Telephone (907) 277-1401 union May 28, 1969 OKGTRM~KLvHLB HWK EEL ,...,.--... .._..... FILE Mr. Homer Burrell, Director Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Attached please find chronological well history on D-18 per your request. Please noteper attached Ma~ letter that no multi-point flow test conducted o~ Also enclosed is ~="~o~b~c--~-~ell history on D-i~7. BETIdp Very t~uly yours, B. ley ~ District ling Superintendent Enclosures FORM 401-ANC-W (8/67) MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA F~, O. [BOX [a3S0 ANCHORAGE,ALASKA 99501 May 27, i969 Union Oil Company of California '507 West Northern Lights Blvd. Anchorage, Alaska Attention: Mr. B. E. Ta]]ey Re: Trading Bay Unit D-J7 (4~-6) D-t8 (41-6) Gentlemen: We are forwardin~rewith in duplicate, history of oil and gas we]is D-17 an~D~for your submission to the Division of Oil and Gas, State of Alaska. For your information, a multi-point flow test was not made on the D-t8 well at the time of its completion. This was not done because of the necessity of shutting in production in order for this to be accomplished, it is programmed that such a test may be conducted in the very near future and we wi~ at that time furnish you with the test data. Very truly yours, MARATHON OIL COMPANY ., ">:~ "..¥?'" .. · ' ":""' "'"" ' ..... :">' /'}/-" '" ;i Morris L. Lowman District Landman MLL :.1 j Enclosures cc: George Susich ~ ~.-,~ ~,.~ ~ DIVISION OF OI~ AND GAS Union Oil Company,, ' ,~ qal~fornia 507 W. Northern Lights Blvd,, Anchorage, Alaska 99503 Telephone (907) 277-1401 May 21, 1969 Mr. i{omar L. Burrell Director State of Alaska Department of Nanura! Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, A!as'ka 99504 ,fILE _ Dear Sir: In reviewing our records, per your request, for missing Trading Bay Unit reports and required information, we find that sepia and blue line electric logs for wells TBU G-17~ D-15,~ D-i3, K-12, K-!3, and K-10 were forwarded for your files at an earlier date. If you are unable to locate the above information, please advise and we shall forward additional copies. The sepia logs for TBU G-iS. have been forwarded to your attention under separate cover this date. The final prints of sepia and blue line logs covering TBU K-15 have not yet been received from Schlumberger, and will be forwarded as soon as they are available. Very ~ruly yours, B.E.' Tailey/~/ District D=~lling Superintendent ~ET/dp FORM 401-ANC-W (8/67) Union Oil Compaq-if California '~' 507 W. Northern Lights Blvd., Anchorage, Alaska 99505 Telephone (907) 277-1401 MaX 16, 1969 Mr. Karl VonderAhe Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. VonderAhe': Attached please find directional surveys for ~e! ..... ~'" :"-~2 - ' and~ Every effort wil} [~e made uo get this-~in~or;:~at?~-°' {~,..,:on asD 1~ pro~iy as possible. Addiuional information as requested will be forwarded as soon as available. Yours ~ery trulY, '~ f / ,,.7 B. E. Talley /// District Dri:~ing Superintendent BET:mgl Enclosures A NC tI0 R AG E D I STR I CT TO: STATE OF ALASKA' G. H,' Laughbaum, Jr. I),\TE' . ~iay 1_.6_,_--1969 TBU K-10 ,] a: :.,:':t ~ t.:~.d hercw' *" · .... ~,, th follow Run .,.'.40. Sepia Blue Scale Induction Electrical Log 1 ea. --!_e.~ ~ Dual Induction t.,aterlos '"'-, ! ' T BHC Sonic/a~...;.per ,,o~., BIle Sonic/Gamma Ray B}tC Sonic/Cai' ., ~.pe~ ~ t,,:~,==.na Ray !,og Formation Sonic t,og (Fs) Compensated Formation Density Formation Density !.og (Fd) Neutron I,og Fornati. on Neu,.~.o~, Log. (Fn) High Resolution Dipmeter CDH Safety Print CUM Dy Printout CDH or Po~3,,oo P~ot ~.4 Polar Pi Prox~.m~ty Ga'~ta Ray-Neutron I,og " Cantata Ray Collar Log Cement Bond Log Sidewall Neutron Porositf Log La ~,.,rlog 5 Hud log Core Descripti. ons, Convent~ Core DescrSptions, Sidewall COTe ~'"' .. For~mtion Tests croons] Surveys Core Ch ips Sample Cut C'.q..'-un,qm Carina) MAY 19 1969 DIVISION OF OIL AND'GAS RECEIPT AC~:.kO, LEDucD' kh,U,,N RECEIPT TO ttnion O5.1 .ri. "~-,.,:,.~ Di'¢i¢ion-. ' Weste?n"Re~,.inn ~ict Anchorage Pis, .. ~.,.,05 , ..... ~a.~i. Street - , ..... .goOa- Attn: Rochelle Carlton Anchorage Alaska q = ' OIL AND GA C / ~ ~ S ONSERYATION COMMITTEE ......... l~ 50,,133-20169 -WELL C0MPLETIO,N, OR R~COMPLE~IoN~ REPORT ,'~~TRM ~" J,,.,.~.~,~'D~oN.,,.~o:~ ~DSER~,~NO.~. ADL: 18729 la. Typ~, OF WELL: 0 , r-"] 'As [-~ F'"] WELL ~ WSLL L_~ "DI~¥ L__J Other ~-,~'/I/-~; I'. IF I1N-DIAN. ALLOTTEE OR TRIBE NAME OKG I b. 'e~ o~ CO~L~.~o~: . ~ I NZW ~ovmlW°n][{ [-'-']I~Nr~E'EP' r--] PLUt~I~ACK [--'] PI~'F.nv. SV~. [7"] Other ~LV ~ 18. UNIT, F.a2~-Vl OR I.,F~SE ~...~E o~ o~=.~o~ .-,. .*'--'~-' -Jraa~ng Bay Uni t Union 0il Company of California* ~Et ~ a. ,,~,E~ o~ o~,,o~ -- '- D-18 (41X-6) 2805;.~Denal i Street,,. AnchOrage, Alaska 99503 ----- ~. ~0. rrm, ~r, r~o~., oa ;J. LOCATION OF WELL ',(RePort ~ocatiOn c~early and'.'it~ accordan~e with any State requireJlJJ~) ...... McArthur Ri vet ~~ 675.]' ~ 'and 1:>]3.9' £ from:$~ Corner, $ec.6-18~-R13~-S}I~x.~c..~..a..'~.. OBJECTIVE) tt to~ ~,a. late~,~l ,~o~tea below 497' ~N~ and 942' Fi:I., $ec.6-18N-R13~-$1~ SOc, 6, 18~, RI3~, At totaldeptla 3:>¢' [:St. and 1609' FI'L, Sec. 32-19N-R13W-S~ , 1~.. PI~Ia'ViIT 1~O. . 69-4 1-8-t59 i 1':27-69 ?'-14-69 DF 106' MS[ '.,;. 22. PRODUCING IZNTT3~RVAL(S), O,F ~[~IS eOMPL~TION--TO2, BO~I~OM, NAiVIE (1VID Alq'g ~wq'g)* 93. WA~q DI[RECTYIO,NAL C Zone (Lower Chuit River Fm,) Top: ,:6835 MD, 3924 TVD ! - Btm- 7740 MD, 4297 TVD : Yes 24..TYPE ELECTRIC AND OTHER LOGS RUN DIL, IES, Ga'ma RaY Neugron, Cement Bond C~SI2q'~- I~ECOR.D (Report all s~rings set in well) 26, LIATEI'{ I~ECO~ J 2"/. TUBIINT& SIZE 'j. TOP(MD). . BOTTOM (MD)J S.~CKS CE!VIEiNTT*1, ~' ! (' i' ,I SCREEN (~WID)',JJ SIZE3_1/2,,Jill' DEPTI-I SET (1V~D).~. :"J~ ~/i/~j ::" ~' ~ .... t '. iP~'clcER SET (1VID)'6803' 28. PERFO]RJkTIONS OPF/N TO PROI)UC --='-r.:~ ~ I~"~ Four Ho]es Per Foot' b~AR 1 7 ' 969 7452-745.3' 150 sacks Cema 7130' to 7150' ~, DI¥I$1ON OF OIL ~ND OAS_ ~'~ ': ' ANCHOI~OE i i i ,i,,i. DATE FIIqST PI~ODUCTION ,[ PRODUCTION I%~IETI{O~) (Flowh~g, gas lif'~, pumping--size and tYpe °f PumP)~_14_69Flowi n,. JWELL .S?ATUS (Producing orsnut_m)Producing DATE OF TEST, JI-iOLrRS TE~TED 'JCHOI{F~iZE JPi%OD'N FOR OIL--BEL. G.%S--1V~CF. WATER-~BBL. J GAS-OIL J J -~ JTEST PERIOD 2-24-69 /]-5 hrs. I " I ~ J i,2.33 mmcfl t I 'l 31. DISPOSITION Or ~AS (Sold, used f~r fuel, vented, etc.) ...... : '. Fuel t ~arathon Personnel 32. LIST OF ATTACHMENTS 33. I hereby certify]%l~/t the %ore~otng and attached information is complete a:~l~ correct as determined from all-available records -/M./~jjT~.,"L !1/.81/~_ eX'eLS D' ' ':' 3/12/69 ~t. ~Brlg. Supt. I (S~le Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS .~General: This form is desig0~d~ifbr, submittin~':a complete, and correct well completion report end log on !':ali types of lands and leases, in Alaska... ' ,' j,] ..,L ... '.-:.Item:: 16: Indicate which elevaf[6n' is used as..' reference (where not otherwise shown): for depth measure- ments given in clher spaces on this form and i~ any attachments. ." Items :20,-and 22:i If this well is completed '''":' . .... fo-r separato production from more' than one interval zone "i'(multiple completion), so state in item 20, a~d in item 2'2 show the io~c.zlucing inferval, or intervals, "'top(.s}, boj.,.tom(s)'and name (S) (if any) [..or onl.y.,i the inierval reported in item 30. Submit a separate report '.(page') on this foi:'m, adequately identif:ed, for' each ad6itional interval to be Se.'perately produced, show- .lng the .afJ~dition~'l' data pertine~,,t to s.uch infe,rval. . . '" "ZJtem26: ;'Sacks Cement": Attached SUl:)plemental records for this well should show the details of/any mul- :!i:-'tiple:'i. stag6 cementing and the Iocation:'°f the:'i'cementing tool. .' !!.'.Item 28: Submit 'a separate~ompletion,repo[t~on this form for each interval to b'e s~p~rately P~'oduc~. .~ (See instr.uction for items 20.1'and 22 above). . ~:'; , .:. · . WATEH AND MUD ...... ,~ :) ~ ..... NAME ':~ -: : C Zone 6835' 392'4' ~'" 7440 . DATA, Aq~I'ACIt BR1E~ D~CRIPI~ONS ,'0F LITHOLOGY, POROSITY. FRAC~RES, APP~NT DI~ ~:'.~ . .... ._DATE~. 5/27/69' · · (4].-6) WELL NO. D- ].8 LEASE STATE Alaska M~ATHON OIL COIV]P~Y HISI'ORY. OF OIL OR GAS W~LL Trading Bay Unit SEC. (~%~y Kenai Peninsula Borough FIELD McArthur River TWP. 8N i i R, mEASUREMENTS TAKEN FrOM KB ELEV. 106 ' toP OF OIL STRING I:'LEV. _ _ iToP OF ROTARY TABLE__ ELEV, {GRD. OR MAT. ELEV.__ HISTORY PREPARED BY Owen Aki ns T,TLE Drilling Superintendent All Measurements from KB It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1969 ]_/8 1/9 1/10 1/11 1/12 1/13 1/14 1/15 1/16 CONTRACTOR - SANTA FE DRILLING COMPANY, RIG 76 TD 250' - Started moving rig from D-14 to D-18 at 9:00 A.M. 7./8/69. Rigged up and ran in hole to 250' with 17~".bit. Mud lines froze. Thawed out lines. TD 632' - Continued mixing mud and rigged up over D-18 slot f~l~., leg B-1. Cleaned out with 17½" bit to 400'. Pulled out and ran Sperry Sun gyro. Surveyed 33" c~g. Drilled 12~4" hole from 400' to 535'. Pulled out and ran turbodrill #1 with 2° kick sub. Turned hole from S 25 E to N 387. Pulled out ho}e and ran. in with drilling set up. Drilled 12~" hole. Spudded at 4:00 P.M. 1 9/69. TD 812' - Ran in hole with turbodrill and 3° kick sub. Welded "T" in 4" dis- charge mud line cut out in generator room. Down 6 hrs. to cut .out and replace. Drilled with turbodrill from 632' to 734'. Pulled out of hole and ran in hole with drilling set up. Drilled from 734' to 812'. CoUld not build angle fast enough. Pulled out of hole to pick up turbodrill. TD 1,667' - Ran in hole with turbodrill with' 3° kick sub. Drilled with turbo- drill 12~" hole from 812' to 907'. Made trip. Drilled & surveyed 12~4" hole from 907' to 1,667' with drilling hookup. TD 2,323' - Drilled & surveyed 12~4" hole from 1,667' to 1,720'. Made trip. Ran in hole with turbodrill with 2~° kick sub. Drilled with turbodrill from 1,720' to 1,794'. Made trip. Ran in hole with drilling set up and drilled 12~" hole from 1.,794' to 2,323'. TD 2,323' - Ran in hole with 17½" hole opener and opened 12~" hole to 17~" from 350' to 2,285'. ' TD 2,323' - Opened 12~4" hole to 17~" from 2,285' to 2,306'. Made trip. Circul- ated and conditioned hole for 13-3/8" casing. Pulled out of hole. Rigged up and ran 37 jts 61f~ 13-3/8" and 18 jts 61f~ seal lock with I centralizer on bottom 3 jts. Landed at 2,255'. Cemented with 2,200 sacks class "G" with 6% gel 14fi/gal. slurry. Displaced with rig pump. Bumped plug with 1,500~ cement circulated. Job completed at 3:45 A.M. 1/].5/69. 13-3/8" Casing Detail Description RI to Top of Casing 1 - 13-3/8" 61f~ J-55 Change Nipple S.L. x Butt, Cond. 18 Jts. 13-3/8" 61~ J-55 Rge. 3, Cond. I S.L. Csg. 1 -13-3/8'' 61~ J-55 ~ange Nipple S.L. x Butt. Cond. 1 36 Jts. 13-3/8" 6]# J-55 Rge. 3 Cond. 1 Butt. Csg. 1 -13-3/8" 61# Baker Diff. Fill Collar Cond. 1 1 Jt~ 13-3/8" 61f~ J-55 Rge. 3 Cond. 1 Butt. Csg. 1 - 13-3/8" 61~ Baker Shoe Eff. From 0 3.10 '43.80 705.19 46.90 3.15 752.09 1,464.97 755.24 1.90' 2,220.21 30.76 2,222. ].1 2.71 2,252.87 To 43.. 80 46.90 752.09 ~55.24 2,220.2]. 2,222.11 2,252.87 - 2,255.58 TD 2,323' · Landed 13-3/8" casing. Made up casing head. Installed ].3-5/8'' riser. and B.O.P.E. Tested to 3,000#. Tested casing to 2~000#, OK. Ran in hole to 2,223' with drilling set up. TD 3,122' - Pulled out of hole. Ran Sperry Sun. Ran back in hole pressured Up with pipe rams closed to 2',000fi. Then tested hydrill with 2,000~'test OK. Drilled float collar and shoe at 6:00 P.M. 1/16/69. Drilled & surveyed 12~" hole from .DATE_~ M C IATHON OIL I:::O /IP NY HiS. orY. Of Oil OR GAS V, ,LL , BLOCK WE-LL NO D-18 LEASE Trading Bay Unit SEC. PARISH STATE COUNTY ., EIEV ..... I ToP of Oil STRING __ ELEV.,-- HISTORY PREParEd BY MEASUREMENTS ToP Of Rotary Table EIEV.... Title TAKEN FROM [GRD. OR Mat ELEV. FIELD McArthur River TWP. R. It is of the greatest importance to have a complete history of the welt. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1969 1/17-18 1/19 1/2o 1/21 1/22 1/23 1/24 1/25 1/26 1/27 1/28 1/29 TD 4,.188t - Drilled & surveyed. 12~" hole to 4,150'. Pulled out of hole for turbo- drill #5. Ran in hole with turbo and attempted to orient tool. Surveying instrument would not fall to bottom. Pulled drill pipe into 13-3/8" casing and built a circulating head. Ran turbo back to 4,150' and oriented tool. Drilled 12~" hole with turbodrill from 4,].50' to 4,177'. Pulled out of hole to pick up drilling assembly. Drilled 12%" hole from 4,177' to 4,188'. TD 5,167' - Drilled & surveyed 12%" hole to 5,167'. TD 5,509' - Drilled & surveyed 12~4" hole from 5,167' to 5,240'. Pulled out of hole. Picked up core barrel. Ran in, cut core #1 from 5,240' to 5,270'. Cut 30'. Recovered 20'. Went in hole and reamed core hole. Drilled & surveyed 12%"..hole from 5,270!. to 5,509'. TD 5,895' - Drilled & surveyed 12~" hole to 5,803' Trip for new bit. Drilled , . ' ' o ~ orienting tool. surveyed 12~4" hole to. 5 895' Trzp for turb # TD 6,277' - Set turbo #6. Drilled from 5,895' to 5,929'. Trip for drilling assembly. Drilled & surveyed 12~." hole from 5,929' to 6,277'. TD 6,702' - Drilled & surveyed 12~" hole to 6,702'. Circulated up samples. TD 7,155' - Circulated at 6,910'. Pulled out of hole. Picked up Christensen 5-3/4" core barrel, with 7-5/8" head. Cut #2 core from 6,9].0-6,940'-30'. Recovered 20'. Serviced core barrel. Picked up drilling set up. Ran in hole. Opened 7-5/8" hole to 12~4" and ran. survey. Drilled to 7,~55'. TD 7,505' - Drilled & surveyed 12~" hole from 7,155' to 7,195'. Mud started gas cutting. Circulated and built mud weight to 10.9/gal. Drilled & surveyed 12%" hole to 7,505'. Circulated for samples. Pulled out of hole for core Bbl. TD 7,755' - Ran in hole with 5-3/4" Christensen core barrel with 7-5/8" diamond head. Cored from 7,505' to 7,535' - 30', and pulled out and serviced core barrel. Rec. 30' sand. Ran in with drilling'set up. Opened 7-5/8" hole froTM 7,505' to 7,535'. Drilled 12~" hole from 7,535-7,755'. TD 8,175' - Drilled & surveyed 12~" hole to 8,175'. Circulated for logs. Made wiper trip for logs. TD 8,175' - Circulated 2 hrs. Pulled out of hole to log. Rigged up Schlumberger. Ran in hole with 3~5/8" DIL tool. Tool stopped at 2,980'. Pulled out of hole and rigged down Schlumberger. Ran in hole with drilling assembly and circul- ated 2 hrs. Did not hit any bridges going in the hole. Pulled out of hole. Rigged up Schlumberger and ran in hole with 3-5/8" DIL tool. Tool stopped at 2,980'. Pulled out of hole. Ran open ended drill pipe to 6,182'. Pumped 2-5/8" 1ES tool down thru drill pipe. Logging. TD 8,175' - Continued logging with IES pump down ~)g through 5" drill pipe. Logged intervals DIL 2,268-2,960' open hole. 5~'~-~ 3,930'-5,115'; 5,115 '-5,301' ; 5,316'-5,445'; 5,543'-5,760'; 5,755'-5,900'; 5 ~9~0'-8,175' Circulated to ~un 9-5/8" casing. HIS~T~ORY OF OIL OR gas W~LL WELL NO. D-18 LEASE Trading Bay Unit PARISH STATE COUNTY · __ ElEV. , BLOCK SEC. MEASUREMENTS ITOp Of OIL STRING ELEV.. TOP Of Rotary TABLE EIEV. TAKEN FROM LGRd. OR MAt ELEV. HISTORY PREPARED BY TITLE TWP R.~ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1969 1/2 1'/31 2/! 2/2 2/4 2/5 2/6 : 2/7 TD 8,175' - Conditioned mud. Spotted 40 sacks nut plu~. Pulled out of hole to run casing. Ran 9-5/8" casing. TD 8,175' - Ran and cemented 8,132.53' of 9-5/8" casing. Set 42.80' below.rotary table at 8,175.33. Ran 1 centralizer on shoe joint and 35 centralizers between 6,200' and 7,500'. Cemented with 1,250 sacks, 6% gel, 1% D-19, 1,400 sacks neat, 500 gal. mud sweep ahead. Cement mixing time 2 hrs. 10 min. Plug pumped 'down in 58 min. Plug down at 4:15 P.M. 1/31/69. Final pressure 2,000#. No cement returns. Cement slurry 14.2#. Nippled up. 9-5/8" Casing Detail Description RT to Top of Casing 196 Jts. 9-5/8" 40# N-80 Butt. Baker Float Collar 1 Jt. 9-5/8" 40# N-80 Butt. Baker Float Shoe Eff. From To 0 42.80 8,085.72 42.80 8,128.52 1.85 8,128.52 8,130.37 42.41 8,130.37 8,172.78 2.55 8,172.78 8,175.33 TD 8,175' - Finished nippling up. Tested B.O.P. with 3,000#. Tested casing 1,000#. Ran in hole with bit & scrape~. Circulated. Pulled out. Ran Lane well% Gamma Ray Neutron now running cement bond log. Cement bond log stopped at 5,191'. TD 8,175' - Cement bond log would not go. Ran gau~ge ring. Would not go below 5,190'. Perforated with Lane'wells casing gun 4 holes/ft, from 7,542' to 7,543'. Ran Halliburton EZ drill set, 1ES measurement at 7,528'. Ran in hole with Halli- burton stinger set into retainer. Broke formation down with 1,500#. Injection rate 1.5 B.P.M. at 2,000# squeeze cement with 150 sacks class "G", 1% D-31. Pumped 75 sacks into formation 3/4 B.P.M. St'arted s~aging cement obtained squeeze with 125 sacks. Squeeze pressure 2,000#. Reversed out 25 sacks. Job complete I:00A.M. 2/3/69. Circulated out and pulled out of hole. Went in hole ~ith 8~" bit and 9-5/8" casing scraper. TD 8,175' - Circulated mud around. Cleaned out mud tanks. Mixed up .inhibited sea water and displaced mud with water Pulled out of hole. Laid down drill pipe. Rigged up to run cement bond'log. TD 8,175' - Ran 6~ement bond log. Sonde stopped at 2,551'. Pulled out of hole. Ran Otis W.B. packer and set on wire line at 7,444'. Ran 240 jts. 3~'~ seal tubing (effective lens 7,364.34). Set into packer and pressure teSted to 1,000# - held OK. Pulled out to 340'. Installed ball valve landing nipple and spaced out for 15,000# weight on packer. Started to nipple down B.O.P.'s. TD 8,175' - Finished nippling down BOP equipment; set tree on and tested same with 5,000# test, fl<. Tested packer with 1,000# pumping down tubing. Tested -~" control line with 5,000#. Pulled dummy and pumped thru ~" line. Tested lubri- cator with 4,000#. Ran in hole with perforating gun. Would not go. Pulled out. Laid down 10' of gun, tried again, would not go. Released rig at ]2 midnight to .move over on D-8 to shift gas lift sleeves. Will move back to D-1.8 and rig up to circulate- perforating gun down, after shifting gas lift sleeves on well D-8. Static - wai.ting on rig from D-8. Will then Berforate. TD.8,175' - Started moving rig from well D-8 to well D-!8 at 1:00 A.M. 2/8/69. Ri~ed up lubricator and tested to 4,000#. Went im hole with 15' bear cat gun. DATE ,:,.._ hiL. ORY OF Oil or GAS LL WELL NO. STATE MEASUREMENTS TAKEN FROm D- 18 LEASE Trading Bay Unit PARISH COUNTY ELEV. __ IToP OF OIL STRINg ELEV. __ ToP OF ROTarY Table__ ELEV. __ GRD. OR MAt__ ELEV. BLOCK SEC. TWP HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing,, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. 2/8 ;.2/9 2/10 2/11 2/12 DATE 1969 PBTD 7,528' - Bear cat gun would not fall below 3,100'. Pulled out of hole. Ran Otis shifting tool. Unable to get tool bel~ 5,160'. Pulled out of hole. Shifting tool had backed off of tool string, Ran 1-7/8" Bowen grapple. Unable to catch fish. Removed Xmas tree and pulled a strain on 3½" tubing. Reran fishing tools with knuckle joints in tool string. Unable to catch fish at 5,]_60'. Rigged up BOP's and'pressure tested to 2,000#. .Pulled 3~" tubing. Recovered fish in "XO" circulating sleeve. Opened sleeve. Started in hole with tubing. PBTD 7,5'28' - Completed going in hole with 3~" tubing. Landed tubing with 6,000# weight on Otis "WB" packer. Nippled down BOP's. Installed tree and tested to 5,000#. Rigged up Dresser Atlas. Ran 2" slim hone gun. Gun became stuck at 7,485'. Worked gun free. Worked gun to 7,500'. Unable to get gun any deeper. Pulled out of hole. Ran tapered swedge jars and sinker bars on electric line. Worked swedge to 7,506'/1ES log measurement/. Pulled ~out-of hole. Ran Otis shifting tool to 7,430'. Displaced tubing with diesel and closed X-O circu- lating sleeve at 7,408'. Ran 2" slim Cone gun. Could not get gun below 7,503'. Perforated 7" casing from 7,502.5' to 7,497.5'. No increase in tubing pressure. Now going in hole with swedge and jars. TD 8,175' -Worked swedge and Otis tools to 7,508'. Pulled out of hole. Ran 2" slim cone gun to 7,501'. Worked gun to 7,506'. Perforated 9-5/8" casing 4 shots per foot from 7,500.5' to 7,505.5'with no increase in tubing pressure. Rigged up B.J. unit and-pressure casing to 1,500#. Broke down perforations with 2,200#. Pumped into formation at rate 1.5 bbls. per min at 3,500#. Well would not flow back. Ran Otis shifting tool. Opened "XO" sleeve at 7,408'. Mixed and conditioned mud. Displaced hole with mud. Removed Xmas tree. Installed B.O.P. Planned to pull 3!j" tubing, pick up 80' of~ 2-.1/16" tubing. Went in ~ole. Stabbed into packer and washed out from 7,506' to 7,520'. Then perforated from 7,505' to 7,515'. TD 8,175' - Installed riser and nippled up B.O.P. Picked up tubing landing head. Could not pull seal assembly from W.B. Otis paCker at 7,444' with 190,000#. Stretch in tubing indicates that tubing is stuck at packer. Circulated through circulating sleeve at 7,408' for I hr. Closed circulating sleeve and pressured tubing to 3,750# while pulling 195,000#. Unable to pull out of packer. Ran Dresser Atlas jet tubing cutter (2-5/8" O.D.) to 5,260'. Cutter would not fall. Rigged up circulating head in wire line lubricator. Ran Otis shifting tool to close circulating sleeve. Tool stopped at 5,260'. pumped shifting tool to 5,800' by pumping through 9-5/8" casing perforations from 7,497' to 7,505'. .. Tool fell freely to circOlating sleeve. Jarred on sleeve. Unable to open. Ran jet tubing;cut~er would not fall below 5,260'. Pumped cutter to 5,800'. Estimate a total of 30 bbls. of mud pumped into formation at 1,200#. Pulled tension on tubing of 190,000#. Cut tubing off'at 7,434'. Pulled 3~" tubing. TD 8,%75' - Finished pulling 3~" tubing. Cut off portion of tubing. Flared .to 3-3/4" 'O.D. for a length of 1". Recovered 2_1.65 of joint below circulating sleeve Ie~.'~ing 8.05' of 3~" tubing above packer. Length~ .of fish 16.55'. Top of fish ~,~3.05'. P~cked up 7.-5/8" wash pipe 3 jts. heavy wall drill pipe. Laid down sa~> to abandon "D" zone. Ran gauge ring and junk basket on wire line to 2,960'. Unable to work deeper. Ran Halliburton permanent bridge plug on wire line to 2,320'. Unable to work deeper. Rigged down wire line and ran Halliburton 9-5/8" bridge plug cast iron bridge plug on tubing. Set bridge plug at 7,397'. Rip,zed UD B.J. cement unit. Mixed 25 sacks class. "G" cement. Spotted on top of WELL NO. D-18 LEASE Trading Bay Unit PARISH STATE COUNTY ~. ELEV. BLO{ SEC. .IToP OF OIL STRiNg -- ELEV.-- HISTORY PREParED BY MEASUREMENTS 1TM Of ROTarY TABLE__ ELEV._ TITLE TAKEN FROM ~GRD. OR MAT ' ELEV. TWP r It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE ~.969 2/12 (Con1 2/13 'd) bkidge plug. Cement in place at 11:15 P.M' 2/12/69. Pulled tubing to 7,347' and reversed out. Pulled tubing to 7,170'. Circulated and conditioned mud. Now pulling out of hole with 3~" tubing. TD 8,175' - Rigged Lane %.,Tells lubricator up. Tested same with 3,000#. Ran in and ~erforated with casing gun from 7,130' to 7,150' with 4 holes per foot. Picked up Otis 9-5/8 R.H. hydraulic packer and ran in hole and landed 3~" tubing. Nippled down B.O.P. Tested ~" control lines to 5,000#, then pumped through. Pulled Otis dummy ball valve. Nippled up Xmas tree. Displaced mud with diesel, 500 bbls. Set packer at 6,803'. Tail pipe at 6,811'. Tested with 1,000#. ' Test OI4. Flowed 20 bbls. back to B.J. tanks. Had 700# on tubing. Turned into well clean tank at 6:00 A.M. Now flowing at 400#. Moved rig to well D-4 for workover. 3~" Tubing Detail Otis Catcher Sub Otis 3~" Q-nipple 3~" Buttress PUP Jt. Otis 9-5/8" RH ~acker 3~" EUE Pen X 3~" Armco Box 1 Jt. 3~" Armco Tubing Otis 3~" "XO" Sleeve 210 Jts. 3½" Armco Tubing Otis 3~" Ball Valve Nipple 9 Jts. 3~" Armco Tubing 3~"Armco X 3~" EUE Cameron Hanger Elevation Bottom of Tail Pipe 3½~ B~ttress Guide 3~" Buttress PUP 3~." Otis Q-nipple 3%" Buttress PUP 3~" Otis X-nipple 3½" Buttress PUP 3%" EU~ 3~" Buttress X-over 9-t/8" Otis W.B. packen~_. Otis Locator Seal Unit 4%" EUX 4½" Buttress Nipple 4½" Buttress Collar 4%" Buttress X 3½" EU Swedge 3~" EUX 3%" Armco Collar 1 Jt. 3~" Armco Tubing 3~" Oti "XO" Sleeve 230 3ts. 3½" Armco Tubing Otis 3½" Ball Valve Nipple 9 Jts. 3½" A~nnco Tubing 3%" Armco Box × 4~" Armco Pin 4 - 4~" Armco PUP 3ts. 4½" Armco Box X 3%" Armco Pin 3%" Armco Collar 3%" Armco pin X 3%" EU Pin . Cameron Hanger T~[F to Rotary .94 1.47 6 o00 4.95 .80 30.05 3.31 6,441o22 4.40 274.36 .98 .85 42.00 .70 10.10 1.60 8.0O ]..40 8.05 .60 5.60 .70 .40 .80 .45 .55 29.70 3.35 7,059.59 4.40 275.05 .70 24.34 .77 .61 '.58 .80 41.16 Depth 6,816.33 6,810.38 6,808.92 6,802.92 6,797°97 6,797.17 6,767.12 6,763.81 322.59 318.19 43.83 42.85 42.00 - 0 - 7,480.00 7,479.90 7,469.20 7,467.60 7,459.60 7,458.20 7,450.15 7,449.55 '7,444.00 7,443.30 7,442.90 7,442.10 7,441.65 7,441.10 7,411.40 7,405.05 348.46 344. O6 69.01 68.3]. 43.92 43.15 42.54 41.96 41.16 - 0 15,000# :set on packer. ~AT.E '"'"' PAGE MA.tATHON OIL COMP'. Ny HISTORY, OF OIL OR GAS WELL FIELD · WELL NO. ~-18 LEASE STATE MEASUREMENTS TAKEN From ~ToP of OIL STRING, .TOP Of ROTARY TABLE Grd. OR Mat. BLOCK Tradin8 Bay Unit SEC.. PARISH COUNTY ELEV. ELEV __ HISTORY PREPARED BY. ELEV. __ TITLE ELEV. __ ., TWP. R It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1969 Bit # 1 2 3 4 RR4 5 6 7 8 9 10 Core f~l 11 12 13 13RR 14 Core #2 15 16 Core #3 RR16 ].7 Size Make 12-~ 12~ 12% 12t 17~ 12t 12~4 12~4 12% 12t 7-5/8 12t 12i 12t 121 12t 7-5/8 12t 7-5/8 z2~ 12k Reed HTC HTC Reed Reed HTC Smith HTC Reed Reed Reed Reed Christ Reed HTC HTC HTC HTC Christ HTC Reed Christ Reed Reed Type YT3A OSC OSC3 YT3 YT3 OSC 6P X3 YT3A YT ].AG YT3J YT3 Dimond YTIAG X3 X3 X3 X3 Y2020 OSC3 YTIAG Diamond YTIAG YTIAG Bit Record Depth On De'p~h Off 400 632 813 907 1,720 1,720 350 2,313 3,2].9 4,150 4,177 4,817 5,2~0 5,270 5,803 5,895 5,929 6,371 6,910 6,940 7,344 7,505 7,535 7,755 Ftg. Hrs. Cond. 632 232 3-3/4 - 734 102 2 T4-B4 907 94 2 T4-B3 1,720 8 ].3 4! 2,3!.3 521 5t T5 1,794 72 2 T5 2,306 1,956 2]. -' 3,219 906 ].l~j T4-B2 4,150 931 ].3~ T6~B3 4,177 27 2~ T4-B2 4,817 640 10-3/4 T5 5,240 423 7 T3-B2 5,270 30 1½ - 5,803 533 13~ T4 5,895 92 2t T1 5,929 34 3~ T5-B3 6,871 466 8 T6-B3 6,910 539 - - 6,940 30 4~ Good 7,344 404 9 TT-B2 7,505 161 5 Ti 7,535 30 6 Good 7,755 220 ? T7-B3 8,175 420 9~ T4-B2 ~ IDo~O~ I~, UTHO BY EASTCO IN U. S. A. SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY MARATHON , ,, , COMPANY TRADING B~ WELL NAME COOK INLET, ALASKA LOCATI~)~I JOB NUMBER AMI-169 TYPE OF SURVEY SINGLE SHOT DATE JAN. 196 9 SURVEY BY ANCHORAGE MEASUW, ED UEPTI~ 440 41I 5(]) 1 533 563 6O2 634 734 813 9O7 962 1024 1086 1210 1336 1471 1720 1792 1847 2053 2188 2539 27~1 2938 30 ? 3 MAR A THL)N O I L D L V I A T I I..] ANULE u I RL,..T 0 .30 ' S 1 10' S -~3E 0 bS' S 25E 0 35 ' S 32E 1 30 ' N 38W 1 15' N 31W 1 lO' N 31W 6 O' N 35E 6 30' N 57E 11 45' N 51E 14 0 ' N 44E 17 0 ' N 48E 19 30' N 43E 24 30' N 44E 29 0 ' N 44E 34 30 ' N 45E 41 30 ' N 44E 48 0 ' N 45E 46 0 ' N 39E 46 0 ' N q-OE 48 30 ' N 3 7E 52 15 ' N 35E 55 0 ' N 35E 60 O' N 36E .50 O' N 61 30' N 35E 62 30 ' N 36E 03 45 ' N 35E 65 0 ' f'4 34E 66 0 ' N 36E 67 0 ' N 36E WELL C COMPANY D-18 0 M P L E T I 0 N R E PREPARED FOR EASTMAN BY TVg TOTAL COURDINA SUB SEA LATITUDE DEPAR 439.97 470.97 500.96 532.96 562.95 601.94 633..94 733.39 811.88 903.91 957.28 1016.57 1075.01 1187.85 1298.05 1409.31 1502.92 1585.90 1635.91 1674.12 1756.40 1811.10 1882.79 1945.29 1976.29 2035.94 2093.66 2162,65 2229,00 2292,05 2341,28 333.77 364.77 394.76 426.76 456.75 495.74 527.74 627.19 705.68 797.71 851.08 910.37 968.81 1081.65 1191.85 1303.11 1396.72 1479.70 1529.71 1567.92 1630.20 1704.90 1776.59 1839.09 1870.09 1929.74 1987.46 2056.45 2122.80 2185.85 2235.08 2.97S O. 3.50S O. 3.94S O. 4.21S O. 3.59S 0. 2.87S 0. 2.31S 0. 6.25N 5. ll'12N 12. 23.16N 27. 32.73N 36. 44,86N 50. 60,OON 64. 96.99N 100. 140,9]N 142. 195.00N 196. 254.58N 254. 319.74N 319. 359.99N 351. 390.30N 377. 446.52N 419. 525.54N ~ 474. 609.42N 533. 697.00N 597. 743.02N 624. 833.01N 687. 922.71N 753. 1037.32N 833. 1155.28N 912. 1269.84N 996. 1363.67N 1064. PORT SCS 02/03/69 TANGE TES C L 0 S U R E S TURE DISTANCE ANGLE 38W OBW 16E 33E 14W 58W 92W 07E 57E 45E 69E 16E 27E OOE 43E 50E 04E 79E 22E 59E 92E 65E 28E 93E 94E llE 36E 93E 16E 33E 3.00 S 7.32W 3.50 S 0.64W 3.94 S 2.37E 4.23 S 4.55E 3.60 S 2,34W 2.92 S 11.52W 2.48 S 21.71W 8.05 N 39.07E 16.78 N 48.51E 35.92 N 49.83E 49.I7 N 48.26E 67.30 N 48.19E 87.93 N 46.97E 139.31 N 45.87E 200.37 N '45.30E 276.84 N 45.21E 359.65 N 44.93E 451.80 N 44.95E 503.34 N 44.33E 542.80 N 44.02E 612.73 N 43.21E 708.34 N 42.10E 810.05 N 41.20E 917.91 N 40.59E 970.89 N 40.06E 1080.36 N 39.55E 1191.04 N 39.22E 1330.61 N 38.77E 1472.46 N 38.31E 1613.95 N 38.11E 1729.86 N 37.97E . NTIAL MEIHOD DOG LEG SECTION EVER I IY D I STANCE 0.000 -2.68 2.860 -2.92 0.962 -3.17 1.078 -3.30 6.936 -3,06 0.771 -2.70 0.260 ,2.43 5.626 8.~.~ 3.076 16. 5.668 34.56 4.970 47.67 5.133 65.27 4.754 85.71 4.043 136.3~- 3.571 196.53 4.092 271.61 5.621 353.2~ 5.272 443.68 6.695 495.28 1.307 534.63 3.544 604.94 3.322 701.39 2.200 803.77 4.056 91I.°6 6.983 3.038 1075.42 1.067 118~.23 0.984 1326.12 0.981 1468.41 0.793 1725.85 MARATHON OIL tEASURED D E V I A T I 0 ~E'PTH ANGLE DIRECTION W E L L C 0 M P L E T I ON R E P OR T . COMPANY D-18 PREPARED FOR EASTMAN BY SCS 02/03/69 TOTAL COORDINATES C L 0 S U R E S TVD SUB SEA- LATITUDE DEPARTURE DISTANCE ANGLE P~G~ 2~ TANGENTIAL METHOD DOG LEG SECTION SEYERITY DISIANCE 328O 67 O' N 35E 3403 66 45' N 35E 3592 66, 15' N 34E 3781 65 45' N 33E 4001 65 45' N 33E 4150 65 30' N 35E 425I 64 O' N 30E 4470 63 30' N 30E 4722 62 30' N 3IE 4817 62 O' N 32E 5004 65 O' N 30E 5240 65 O' N 30E 5446 70 O' N 30E 5508 6g 30' N 30E 5697 68 45' N 31E 580~ 68 O' N 31E 58~7 68 O' N 31E 592~ 66 ~0' lq 32E 5994 65 O' N 33E 6119 62 30' N 34E 6277 59 45' N 32E 6371 57 45' N 35E 6514 57 30' N 34E 66'71 56 15' N 33E 6953 54 O' N 34E 7175 52 O' N 33E 7 344 52 O' N 33E 505 50 O' N 33E 7756 48 O' N 33E 8175 42 O' N 35E 2367.11 2258.91 2413.67 2307.47 2489.79 2383.59 2567.41 2461.21 2657.77 2551.5~ 2719.56 2613.36 2763.84 ,2657,64 2861.55 2755.35 2977.9i 2871.71. 3022.5I 2916.3I 3101.54.. 2995.34 3201.28 3095.08 3271.74 3165.54 3293.45 3187.25 3361.9.5 3255.75 3401.66 3295.46 3433.13 3326.93 3449.87 3343.67 3477.34 3371.'14 3535.06 3428.86 3614.66 3508.46 3664.82 3558.62 3741.65 3635.45 3828.88 3722.68 3994.63 3888.43 4131.31 4025.11 4235.36 4129.16~ 4338.84 4232.64 4506.13 4399.93 4818.25 4712.05 1409.67N 1096.54E 1502.24N i161.36E 1645.66N 1258.10E 1790.18N 1351.95E 1958.41N ~1461.20E 2069.47N 1538.97E 2148.09N 1584.36E 2317.82N 1682.35E 2509.42N I797.48E 2580.56N I841.93E 2727.33N 1926.67E 2912.56N 2033,61E 3080.20N 2130.40E 3130.50N 2159.44E 3281.49N 2250.i6E 3365.73N 2300.78E 3432.49N 2340.89E 3465.15N 2361.30E 3514.56Nv~2393.39E 3606.48N 2455.39E 3722.23N 2527.72E 3787.35N 2573.31E 3887.33N 2640.76E 3996.82N 2711.85E 4185.95N 2839.43E 4332.67N 2934.71E 4444.36N 3007.24E 4547.79N 3074.41E 4703.61N 3175.60E 4933.82N 3336.79E 1785.94 N 37.87E 1.509 1782.00 1898.81N 37.70E 0.203 1894.99 CLUSURE 5~56.24 34- 4' E MEASURED uEPTH 505 606 707 .~ 807 909 1013 1120 1231 1346 1467 1601 ..1749 1895 2050 2235 2438 2653 2884 3129 3384 3632 3875 4118 4346 4567 4782 5015 625~+ 5543 5815 WELL COMPLETION REPORT PAGE INTERPOLATED VALUES FOR EVEN 10.0. FEET ~OF.SUB SEA DEPIH MARATHON OIL COMPANY D-18 PREPARED FOR EASTMAN BY SCS 02/03/69 TANGENTIAL METHOD TOTAL COORDINATES MD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 506.20 606.20 706.20 806.20 906.20 1006.20 1106.20 1206.20 I306.20 I406.20 1505.20 I606.20 1706.20 1806.20 1906.20 2006.20 2106.20 2205.20 2306.20 '/2406.20 250~.20 2606.20 2706.20 2806.20 2906.20 3000.20 3106.20 3206.20 3306.20 3406.20 400.00 -3.98S 500.00 -2.79S 600.00 3.90N .?00..00 10.76N 800.00 23.57N 900.00 42.T~.N i000.00 70.22N 1100.00 . 104.31N_ 1200.00 144.89N 1300.00 193...49N 1400.00 257.15N 1500.00 336.08N 1600.00 419.25N 1700.00 520.36N 1800.00 642.21N 1900.00 788.14N 2000.00 943.54N 2100.00 1114.73N 2200.00 1296.80N 2300.00 1487.99N 2400.00 1676.21N 2500.00 1862.38N 2600.00 2045.45N 2700.00 2221.67N 2800.00 2391.33N 2900.00 2554.53N 3000.00 2735.97N 3100.00 2924.25N 3200.00 3158.59N 3300.00 3375.35N O.lgE 0 -0.62W 0 3.43E 1 12..03E I 27.84E 3 47.80E ......... 7 74.15E 14 107.06E .... 25 i46.39E 40 194.99E .... 61 256.60E 95 332.42E ..... 1.4.3, _ 399.04E 471.29E 557.47E 656.52E 767.70E 885.58E 1015.75E 1151.395 1277.94E 1398.845 1522.155 1626.845 1726.525 1825.66- 1931.655 2040.36 2176.32: 2306.56E 189 249 ....... 60 329 80 432 103' 547 115 678 131 823 145 978 155 1126 148 1269 143 1412 143 1540 128 1661 121 1776 115 1909 133 2048 139 2237 189 2409 172 0 0 1 2 .... 11 .................................................. 15 34 W E L L C O M P L E T I O N R E P O R T PAGE 2 INTERPOLATED VALUES-. FOR .EVEN 100- FEET.-OF SUB SEA DEPIH MAKATHUN OIL COMPANY D-18 PREPARED FOR EASTMAN BY SCS 02/03/69 . TANGENTIAL METHOD MEAS~JRED UEPTH TOTAL COORDINATES MD-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 605b 6260 6448 6630 6803 6972 7134 7297 7454 7606 7755 7890 8024 8159 3506 3606 3706 3806 3906 4006 4106 4206 4306 4406 4506 4606 4706 4806 .20 .20 .20 .20 .20 .20 .20 .20 .20 .20 .20 .20 .20 .20 3400.00 3560.51N 2424.38E 2550 141 3bO0.O0 3709.92N 2520.02E 2654 104 3600.00 3841.19N 2609.63E 2742 88 3700.00 3968.35N 2693.36E 2824 82 3800.00 4085.04N 2771.36E 2897 73 3900.00 .419,8.37N 2847..49E ...... 2966 ...... 69 4000.00 4305.71N 2917.20E 3028 62 4100.00 . 4413.06N . 2986.91E 3091 .............. 63 4200.00 4515.16N 3053.22E 3148 57 4300.00 . 4610.53N 4400.00 4703.66N 4500.00 4777.41N 4600.00 485I.iTN 4700.00 4924.93N 3115.15E .... 3200 .................. 52 3175.63E 3249 49 3227.28E 3284 35 3278.92E 3318 34 3330.57E 3353 ...... 35 i'iE ASLJR E D [)EPTH 1000 2000 3000 4000 5000 6000 7000 8000 MARATHON 993 1772 2254 2657 3099 3479 4023 4688 W E L L C 0 M P L E T I 0 N R E P 0 R T PAGE 1 INTERPOLATED VALUES FOR_EVEN 1000 FEET OF MEASURED DEPTH OIL COMPANY D-18 PREPARED FOR EASTMAN BY SCS 02/03/69 TANGENTIAL METHOD TVD TOTAL COORDINATES MD-TVD VERTICAL. SUB SEA LATITUDE DEPARTURE DIFFERENCE CORRECTION 20 20 20 20 20 20 2O 20 887.00 40.17N 44.gSE 1666.00 484.74N 446.35E 2148.00 1201.10N 946.22E 2551o. D0. 1957.b4N 1460.70E 2993.00 2724.19N 1924.85E 33~3.00 _ 3518.97N .,2396.36E 3917.00 4217.02N 2859.60E 45_82.00 ._ 4837...90N ..... 3269.63E 6 6 227 221 745 518 1342 597 1900 558 2520 ...... 620 2976 456 3311 ._ 335 STATE OF ALASKA OILMoNTHLyAND GAS CONSERVATIONREPORT OF DRILLINGCONVv%ITTEE TRMHLB' ~"l 'LL-,,. ! 50-133'20169~. LE3, SE DEsiGN'ATION A.'ND SE'fiIAL N'O. AND WORKOVER OPERATIONS O1(O ~ ! ADL 1872g KLV ~ 7. IF INDIA]~T, ALOTTEE O1~ TRIBE NAME 8. U~N'IT,F.~ OR LEASE Trading Bay Unit 9. %VELL NO. D-J8 (4] X-6) 10. FLI~.,I) AND POOL, OR WILDCAT Surface' 675 ]' N and ]2]3.9' E from SW Corner, Sec 6 McArthur River (Middle Kenai Gas · · , T8N, R13W, SM ,. sec., T.. R., ~.. (~o~oM Sec. 6, T8N, R13W, SM Prop. Prod. Zone- 300' S and 700' W From NE Corner, Sec. 6, T8N, R13W, SM ~,.. ~,,~-,~i.~ No. 69-4 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING A_N-D CEA/IENTING JOBS INCLUDING DEPTH SET ~ VOL~ USEI), PF./:LFO~TIONS, ~TS ~ B.ESULTS, FISHING JO~, JLrlNTK ~ HOI2~ AND SIDE-Ti~LACI4iF.~D HOLE AN/) A/NTY O~HER SIGNIFIC/%LNT C~i-I~INTG~ IN HOI~I~ COiN-DITIONS. WELL WELL ~t ~ ~.N~E OF OP~TOR ' ' Union 0il Company of California* ~- ~ 3,ADDR~S OF OPhiR -- 2805 Denali Street, Anchorage, Alaska 9950~- -- 4.~CA~ON OF W~ 1 ? 1969 DIVISION OF OIL AND GAS ANCHOi~.GE Cement bond log stopped at 5190'. Perforated with Lane Wells casing gun, 4 holes per foot from 7542' to 7543'~ brOke formation down with 1500 psi, injection rate ].5 BPM at 2000 psi, squeezed cement with 150 sacks at 2000 psi. Trading Bay. Unit D-18.,.. February 1969 Conditioned hole for logging, ran logs· 2/1 2/2 2/3- 2/5 Conditioned hOle to run cement bond log, ran log. Ran 3~112" seal lock tubing, tested to lO00 'psi. !nstal led BOPE and xmas tree, tested to 5000 psi; tested packer to 1000 psi; tested 1/4" control line to 5000 psi; tested lubricator to 4000 psi: Moved rig at 12-00 midnight to D-8 to shift gas sleeves. 2/6 - 2/7 Waiting on rig from D-8 to perforate. 2/8 Started moving rig from D-8 to D-18 at 1-O0 a.m. Perforating gun would not fall below 3100', rigged up shifting tool, would nOtgo below 5160'. Shifting tool backed off of tool string. Removed xmas tree and pulled strain on 3-1/2" tubing. Rigged up BOP and pressure tested to 2000 psi. Pulled 3-1/2" tubing. Recovered fish in circulating sleeve; opened sleeve. 2/9 2/10 Ran 3-1/2" tubing, landed with 6000 psi on Otis packer; installed xmas t~ee and tested to 5000 psi. Perforated~casing from 7502.5' to 7497,5'. Worked swedge and Otis tools to 7508'; ran 2, Slim Cone gun to 750~';'', perforated 9-5/8" casing, 4 shotsper foOt, from 7500..5' to.7505~5,: wi.th no increase in tubing pressure. Broke down perforations with.2200:'psi;~. pumped into formation at rate of 1.5 BPM at 3500 psi. Well would not flow {Continued next page) ~rm' No. P---4 REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP1 NUAIERICAL CODE 50-]33-20]69 LEASE DESIGNATION AXD SERIAL NO. ADL 18729 WELL WELL OTHER 2. NAME OF OPIgRATOR 8. L~.'IT,FA-RAi OR LEASE N.~ME Union Oil Company of California* Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 2805 Denali Street, Anchorage, Alaska 99503 D-18 (41X-6) 4. LOCATION OF WF-J~ Surface- 675.]' N and ]2]3.9' £ From SW Corner, Sec. 6, T8N, R]3W, SM Prop. Prod. Zone: 300' S and 700' W from NE Corner, Sec. 6, T8N, R13W, SM McArthUr River le Kenai Gas, ~anas ) 11. SEC., T., R., M.. (BO/'TOM HOLE OB.r~Tn~ Sec. 6, T8N, RI3W, SM 12. PERMIT NO. 69-4 13. REJ~ORT TOTAL DEPTH AT END OF MON"I'i-I, CH.A.~GES IN HOLE SIZE, CASING ~ CEi~IE, NTING JOBS INC'L'U"DI~'N~ ~H SET ~ VOL~ USED, P~O.~TIONS, ~TS ~ ~SULTS, FISHING JO~, J~K ~ HO~ ~D SIDE-~C~D HOLE ~ ~Y O~ SIGNIFIO~T ~G~ ~ HO~ ~ITIONS. 1 7 969 Trading Bay .Unit D-18, February ..1969, Page_ 2_ DIVISION OF 01[ AND GAS ANCNO~/~GE 2/]] Installed riser and nipp]ed up BOP[; could not puli sea] assembly from packer at 7444' with ]90,000 psi; stretch in tubing indicated tubing stuck at packer. Circulated through.circulating sleeve at 7408' and pressured tubing to 3750 psi while pulling ]95,000 psi; unable to puli out of packer. Ran Dresser At]as jet tubing cutter to 5260', cutter would not fa]]. Ran Otis shifting too] to close circulating sleeve, too] stopped at 5260'; pumped shifting too] to 5800' by pumping through 9-5/8" casing perforations from 7497' to 7505'; too] fei] freely to circulating sleeve; unable to open; ran jet tubing cutter to 5260', pumped cutter to 5800'. Pulled tension on tubing of ]90,000 psi; cut tubing off at 7434'; pulled 3-]/2" tubing. 2/12 Cut off portion of tubing; flared to 3-3/4" OD for l"; recovered 21.65 joint below circulating sleeve, leaving 8.05' of 3-1/2" tubing above packer. Laid down 7-5/8" wash pipe and 3 joints heavy wall drill pipe to abandon "D" Zone.· Ran gauge ring and ~unk basket on wire line to 2960', unable to work deeper. Ran permanent bridge plug on wire line to 2320', unable to work deeper. Ran Halliburton 9-5/81' bridge plug on tubing, set at 739~.',, cemented with 25 sacks cement. Pulled 3-1/2" tubing out of hole. ,. 2/13 - 2/14 Perforated with casing gun from 7130' to'7150' with 4 holes per foot. Nippled down BOPE; tested 1/4" control lines to 5000 psi; nippled up xmas tree; set packer at 6803" tail pipe at 6811' tested with 1000 psi Turned into well clean tank at 6-00 a.m. 2-14-69. Released rig at $:00 a.m. 2-14-69, *Mar~athon Oil Company, Suboperator, Dolly .Varden Platform. ~ ,~] ~//]~ , Dist' Drl[. Supt. 3/11/69 duplicate No. P--4 9-2,0.-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN I~UPLICATE ,OKG _ . MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHI~-R 2. NAME OF OPE~,.A. TOR Union Oil Company of California* KLV ~- HWK ~ 3. ADDRESS OF OPEH. ATOR 2805 Denali Street, Anchorage, Alaska 99505 ~lp .. - 4. LOCATION &F WE~ Surface: 675.1' N and 1213.9' E from SW Corner, Sec. 6, T8N, R13W, SM Prop. Prod. Zone- 300' S and 700' W from NE Corner, Section 6, T8N, R13W, SM "5. AP1 NI.T~ERICA.L ~ODE 50-133-20169 6. LEASE DESiGNA~--ION AND SEHIAL NO. ADL 18729 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. U'NIT,F.~::~I OR LEASE NAME Tradinq Bay Unit 9. WELL *'0. D-18 (41X-6) 10. FIELD A-ND POOL. OR '~[~%~CTle ~egai McArthur River uas ~anas; 11. SEC., T., R., M.. (BO'FTOM HOLE OB,rgc-rrvF_J Sec. 6, T8N, R13W, SM ~"69--4P~IT 13. REPORT TOTAL DEPTH AT END oF MONTH, CH_A3qGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN]) VOLU/VIES USED' PERi~OB-&TIONS' TESTS A/~-D RESULTS' FISHING JOBS' JU/~K ~ HOLV' A/~D SIDE'TYL~C~ ~OI~E ANT) A~IY OTI{ER SIGNIFICA2qT CH2dq~ES IN HOL~ CONT)ITIONS. Tradi.ng _Bay. Unit D-18, January 1969 DIVISION OF OIL AND GAS ANCEOL,<::3' 5 1/8- 1/13 Moved rig to slot 11, leg B-1. Cleaned out piling, drilled 12-1/4" hole and reamed to 17-1/2" to 2285'. 1/14 Drilled 12-1/4" hole and reamed to 17-1/2" from 2285' to 2306'. Ran 13-3/8" casing set at 2255', cemented with 2200 sacks cement, tested to 1500 psi. 1/15 - 1/19 Installed casing head, riser and BOPE, tested to 3000 psi; tested casing to 2000 psi. Drilled and surveyed 12-1/4" hole from 2255' to 5167'. 1/20 Drilled and surveyed 12-1/4" hole from 5167' to 5240'. Cut core #1 from 5240' to 5270'; cut 30', recovered 20'. Drilled and surveyed 12-1/4" hole from 5270' to 5509'. 1/21 - 1/23 Drilled and surveyed 12-1/4" hole from 5509' to 6~02'. 1/24 Drilled and surveyed 12-1/4" hole from 6702' to 6910'. Cut core #2 from 6910' to 6940'; cut 30', recovered 20'. Drilled and surveyed 12-1/4" hole from 6940' to 7155'. 1/25 - lj26 Drilled and surveyed 12-1/4" hole from 7155' to 7505'. Cut core #3 from 7505' to 7535'; cut 30' core, recovered 30'. Drilled and surveyed 12-1/4" hole from 7535' to 7755'. 1/27 1/29 Drilled and surveyed 12-1/4" hole from 7755' to 8175'. Conditioned hole for logging, ran logs. (Continued next page) P~'V. 9-3O-6? STATE OF ALASKA S~B~rr m ~'PL~C~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUS{ERICAL ~ODE 50-]33-20]69 6. LEASE DESiGIN~ATION A.~-D SEEIAL NO. ADL 18729 1. T. IF INDIA~, ALOTIEE O1~ TRIBE N~%NIE 2. NA/~E OF Union Oil Company of California* 3. ADDRESS OF OPEi:~TOR 2805 Denali Street, Anchorage~ Alaska 99503 4. LOCATION OF WTM Surface: 675.l' N and 1213.9' E from SW Corner of Sec. 6, T8N, R13W, SM , Prop. Prod. Zone: 300' S and 700' W from NE Corner Sec. 6, T8N, R13W, SM 8. U/N'IT,F.~{ OR LEASE Tradinq Bay Unit 9. WELT~ -~0. D-18 (41X-6) McArthur River~'"~le Kenai 11. SEC., T., R., A{., (BO~FOM'I~I~f,E ...... I 0~~ Sec. 6, T8N, R13W, SM 1~.. PEKIVIIT 1~'0. 69-4 12. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~TGF_~ IN HOLE SIZE, CASING A.ND CEIViE1NTTING JOBS INCLUDING DEPTH SET AIN1) VOL~ USED, PF~':~FO'I:~TIONS, TESTS A/NI-D lq~ESULTS, FISHING JOB~, JUINTK IN HOLE A/NTD SIDE-TI:~CKED HOLE ANT) A.NY OTHER SIGNIFICANT CI-I.A/NTGF, S IN HOL]~ CONDITIONS. Trading Bay Unit D-18, January 1969, Page 2 -- 1/30- 1/31 Conditioned hole to run casing. Ran 9-5/8" casing, set at 8175', cemented with 2650 sacks cement, tested to 2000 psi. Installed casing head and tested to 5000 psi. Dj~jSJOJq O1: OIt AND GAS ,~ Jflllliil _. D±st, DrlE. SupS, 2/13/69 SIGlXq~:D " ...... lift i~// ;; /,! · ,,,~,,~,,, - ,t~.,~., .... DAT~ , lllltl/ ~ v~,..J 'ra~v~ ------- ---- NOTE---~ep~rt o~n this forrr/is required-for each calendar month, regardless of the status of operations, and must be filed in duplicate ' with the Division of Mines & ~inerals by the 15th of the succeeding month, unless otherwise directed. *Marathon Oil Company, Suboperator, Dolly Varden Platform. UNION OIL CO. OF CALIFORNIA ALASKA DISTRICT Transmittal TO: State of Alaska FROM' , ~nion 0il Company Transmitted herewith are the following: DATE' WELL NAbtE: Run No. Sepia Blue Scale Induction Electrical Log Dual Induction Laterolog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/ Caliper/Gamma Ray Log Formation Sonic Log (Fs) Density-Gamma Log Formation Density Log (Fd) Neutron Log FOrmation Neutron Log (Fn) CDM or l. ligh Resolution Dipmeter CDM Safety Print .CDM or Printout CDM or Polywog Plot CDM Polar', Plots Proximity-b!i cro log/Cal iper Log Gamma Ray-Neutron Log Gamma Ray Collar t, og Cement Bond Log bltid 1 o g Core DtmcFriir~lions, Conventional, No. Core Descriptions, Sidewall' Core Analysis Core Chips Sample Cut Drill Stem Test Direct i.,3nal Surveys Trading Oay Unit D-18 Receipt ackno:,'ledged: _~//c~_ Date' ~--/'3-~f .,t ...... ,~ rec. e~p~ to Union Oil Co. of California, 2805 De~al~ St Anchc)rage Al.a~a Rochelle Carlton 99503 MARATHON OIL COMPANY PRODUCTION - UNITED STATICS ANE) 0ANADA P. O. BOX 2380 ANCHORAGE, ALASKA 99501 February 7, 1969 Mr. Thomas Marshall State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Enclosed herewith is a copy of the Eastman Report of Sub-surface Directional Survey of Marathon Oil Company's Trading Bay Unit Well D-18, Cook Inlet Alaska. Very truly yours, MARATHON OIL COMPANY Calvin S. Smith Geologist lj Enclosure ! o ~II~I~ION OF OIL AND ANcHo~GE iii~MARATHoN OIL COMPANY i:=FIODU(DTION - UNITED STATES ,~,NED (DANA[DA January 13,' '196~ ': BOX 2~11~O Stat of Alaska Depa .ment of Natural Resources Divi on of Lands 344 h'Avenue Anch(. age, Alaska Re:. )L-I8729 - Oil and Gas Lease Dowllng ............. Pomeroy Secretary .... ..v(.... Assigned i, Route ~n Bz'anch MZNERAL8 B~ANON Date .!m,NOted by Branch Chief In ac ordance with Paragraph 21 o'f the sUbjeCt"oil and. gas lease, Mara~ on Oil Company, as sub-operator, hereby advises you that well o. D-18 was spudded January 9,'~1969 from the Dolly Varden Platf tm, Trading Bay Unit. The .~ rface location is 675.1'N and?12'13.9'E from the southwest corm Section 6, T. 8 N., R. 13..W., S.M., and the proposed boric hole location is approximately I'S, 4Ol",W from the nortl asr corner, Section 6, T. 8 N,, R.-i 13 W., S.M. Very trutyyours, MARATHON OIL cq mA Y Morris L. Lowm~ District Landman /,'iLL: 1 cc: -!'. T. Anderson - Union Oil Company ~perator - Trading Bay Unit JAN 1,5 1969 A~C~GE ~IV!SIO~; OF OIL /~:tS GAS January lO, t9L;9 Trading i!~ay unit L~-13 b~'~ion Oil Co~:~pany of California, operator ~4r. ~,]ad e S. ~cA l i s te r La~d~a~ Union Oil C~o~-~pa:r~y of California .2~05 Denal i Street Anchorage, Alaska 99503 Dear E.closed please fi~d ti~e approved app}icatimi for pem~t to ~rlll referm)ced well. i~all sm~p!es a~)u core chips are ~)ot required. Very tru, ly yours ~")ot~er L. Curret 1 i]irector E~l¢.'J os~re FORM SA- I B MEMORANDUM TO: I--Dale Walltmjt~ i;,eputy ~tssi~r FROM: J~J~ L. J~ll~l 1 Dtrecter State of Alaska DEPARTI~NT OF NATURAL i~ESOU~S DIVISION OF OIL ANi) GAS DATE : Ja~r~ 10. lg6g SUBJECT.' Trading. Bay Unit D-18 Union Oil Company of Cai t fornt a. operator £~¢l~ed are ~ ~:rov~l ap~ll:¢atten for pe~tt to d~ll. l~tto~ plat, a~ a ~k ia t~ .~nt of ~ for ftlimj fee,. FORM SA- I B MEMORANDUM TO: F i~trlal Safety II~l~:'N~r Department of Labor FROM: J~mr L. ~r~ell Dt~ect~r State of Alaska C~E.P~T~NT OF ~L RE~RCES DIVISION OF OIL ~ GAS DATE : ,,-' SUBJECT:, Jar~e~ 10, lg6g Trading ~y Unit Union 0tl Company of California, Operator E~I~ is a c~ e~ ~ appreved a~lic~tion for ~r~tt to drill f~r ~ ~e ~tte~ ~ell. Poi'rd P--1 REV. 9-30-67 SUBMIT IN ~rRit ~TE (OZher instructions on reverse side) STATE OF ALASKA API 50-133-20169 OIL AND, GAS CONSERVATIO'N ,C:O,MMITTE'E' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DEEPEN l--I PLUG BACK l-] MULTIPLE ~_~ ZONE LOCATION OF WELLAt surface 675.1'N and 1213.9'E from SW corner, Sec. 6, TSN, RiSW, SM At pro.posed prod. zone 300'S and 700'W from NE corner, Sec';';~,:6;': ~8N',,:'R'~,3W, SM 1R. TYPE OP WORK DRILL [] b. TYPE OF WELL SINGLE [] 2. ~E O~ OP~TO~ ~ ~nion 0il Company of California 3. ADDRESS ~ OPhiR 2805 Dena11 Street, Anchorage, Alaska 99503 13. DISTANCE IN MILES AND DIRECTION F.%OM NEAREST TOWN OR.POST OFFICE'* 21 miles northwest of.,Kenai, Alaska .... ~ ...... ,,~m , 14. BOND INFOI~ATION: TYPE Statewidesu~ety and/or No. ~nited Pacific Insurance ]iS./N0. OF ACRES IN]'LEkSE J 4,400,.'VDf':" 7'~ 600."~! MD 15. DISTANCE FROM PROPOSED* : LOCATION TO NEAREST (Also to nearest drig, unit, if any) 1, 00. ! 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED~ ORAPPLIE~D FOR, FT, 9 '200'''fr°m G-18 (MKG) 850 from D-1 (Hemlock, .we.ll:) - 21. ELEVATIONS (Show whether DF, RT. GR, etc,) 116.00 RT 6. LF~SE DESIGNATION ~ SERIAL NO. ?. IF IDI~, ~~ Oa ~ 8. ~I~FA~ OR LEASE N~ Trading Bay Unit 0. m~ NO. ~-~8 (4~x-~),~ 10. ~I~D AND POO~, O~ WILDCAT McArthur River ( ~iddle Kena~ Ga: n. s~c.-. ~., ~., ~., (~o~oa Sands) HOL~ O~ECTIV~) Sec. 6, T8N, R15W, SM lO. .. ,. :~[ ~ ~o~ $100,000.00 t~.. ~o.;,:~c~s ~ssia~ TO ~iS ~L 20. ROT~R¢' OR 'CABLE TOOLS ~.,A~O~; BATE WORK WILL START* January 20, 1969 23. PROPOSED CASING` A/XTD CEM]gNTING PROG1Wa%_M · SIZE OF HOLE SIZE OF cX~INd :'!WEIGHT 15~ER '~'": ' G~Ai~E [' sE~mG':;DE;PT~I' ' .... ' ~ ...... "QU'~NTITY 0P CEMEN[ ,, 17%" ' 15-5/8" 61 J-SS 2,600' 2':,40~'::'~a~k~~ ':' "~'~c., '- 12~" 9-5/.8" 43.5 N-80 7,600' 8n~~~., k ·' ~~ Install 20" Hydri! and riser. Drfll 17½" hole to,apProximately 2',6~5:0' Run 1~-3/8" casing. Install 13-3/8" BOPE' and risker. Test t0'"3,000#'. Drill 12¼" hole to approximately 7,600'. Run and cement 9-5/8" casing. Complete as a gag well. * Marathon 0il Company - suboperator - Dolly Yarden platform Bottom Hole Location - approximately 1.00'S and 401.00'W from NE corner, Sec. 6, T8N, R13W,Sk IN ABOVE SPAC"E DESCRIBE PROPOSED PROGRA/VI: If proposal is to deepen or plug back, give data on present productive zone and ' proposed new productive zofle. If proposal is to drill or deepen directLonally, give pertinent data on s~bsurface locations and measu~d and true vertical depths. Give blowout p_~venter progra~-n. 24. I he~-~erti~~ that the F~ing is .Tru~a,J~d ~orrect ' ..' c January 8, 1969 Landman (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAlViPLI~S AND CORE CHIPS RF_~ ~ REQU~: El'n~ li~o DIRECTIONAL SURVEY REQUIRED A.P.I. ~CAL CODI~. / ~2 ~Y~ ~NO ,~ ,-- ~33 -- 2_0 ~ P~T~O_~ ~?-Q~-'~ ~rPaOV~.Am Oanu~ry 8, 1969 , *See Infusions On Revere Side .t I I D-It D- I (14.-37.) $4-32) p.! i TOP D TMD 708O T V,D 4,180 G-:J D-7 (~4-33) TgN ~G-I2 J ' i , , i I UNtO N :M TH( D-i'7 =D-5- -._ _ -__ ~-o (44-6) · ) (22-7) ]8 (a2-5) ,5 (22-8) 8 D-14 x (44-7) 0 I' U-M PPSS ADL 18729 j ADL 17579k D-8 (24-8) DIVISION OF OIL AND OAS ANCHOI~GE UN ION D-6 (43 -8) WELL LOCATION MAP MARATHON SUB-OPERATOR TRADIN~ ,BAY STATE UNIT D-,18 (41X-6) 0 2000 SCALE:I": 2000' J~ · , ,L