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161-033
• STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMIFON JUL 19 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well U Plug Perforations U Perforate U Other Li AOGCC Performed: Alter Casing ❑ Pull Tubing PI Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 161-033 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic[] Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10153-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 Swanson River Unit(SRU)212-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock from Sterling Undefined Oil Pool 11.Present Well Condition Summary: 5,698; Total Depth measured 7,800 feet Plugs measured 5,789;5,820 feet true vertical 7,800 feet Junk measured 5,914(fish) feet Effective Depth measured 4,400 feet Packer measured 2,783 feet true vertical 4,400 feet true vertical 2,783 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 32' 32" 32' 32' Surface 3,455' 9-5/8" 3,455' 3,455' 3,950 psi 2,570 psi Intermediate Production Liner 7,800' 5-1/2" 7,800' 7,800' 7,740 psi 6,360 psi Perforation depth Measured depth See Attached Schematic 9 True Vertical depth See Attached Schematic SCANNED NOV 0 6 2013 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 2,858'MD 2,858'ND Packers and SSSV(type,measured and true vertical depth) Halliburton PHL 2,783'MD&TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 10 1500 Subsequent to operation: 16 447 1499 695 205 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development IN Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-280 Contact Stan Porhola Email sDorhola(C hilcorD.com Printed Name Stan Porhola Title Operations Engineer 1 Signatures Phone 907-777-8412 Date "7//cj4 3 RBDNIS 4 201i\ - 7.7-'•13 Form 10-404 Revised 10/2012 l'074' Submit Original Only 1 • • Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 212-27 50-133-10153-00 161-033 6/6/13 6/18/13 Daily Operations: 06/06/2013 -Thursday Pulled BPV, SITP: 1,500 psi. MIRU SL and tested. RIH w/1.85" GR and tag fill @ 5,776' wlm. POOH. RIH w/1.5" GS and 2- 3/8" AD2 stop set at 5,700' wlm. POOH. RIH w/1.5" GS and 2-3/8" PACKOFF, set at 5,698' wlm. POOH. RIH w/1.5" GS and G- stop, set at 5,696' wlm. POOH. Bleed down tbg. PU 1.75" bailer loaded w/cement, made 4 runs and dumped 6 gallons. RIH w/1.75" Blind Box and tag heavy fliud (cement) at 5,672' wlm. RDMO SL. 06/07/2013-Friday SITP: 0 psi. MIRU SL, P/T Lubricator to 2,000' psi. RIH w/ 1.75" dump bailer, made for runs and dumped 6 gals of cement on plug. PU a 1.80" Blind Box and RIH. Tag heavy fliud (cement) at 5,755' wlm. POOH. RDMO SL. 06/11/2013-Tuesday Set containment and WOR equi.. MIRU WOR. Hooked rig pump to well and pumped 30 bbls, broke circulation. Circulated clean. SI tbg and P/T csg to ',500psi for 30 mins and charte.. : , L 06/12/2013 -Wednesday Finished RU and contained equip. Tested BOPE,Values, Blind Rams, Pipe Rams 3,000psi-250psi,Annular 1,500psi-250psi for 10 mins. Test was witnessed waived by Jim Regg. Prepped WOR to pull tbg hanger. Backed out lockdown pins and pulled hanger. Sent hanger to Cameron shop to have the ID bored. Secured well and SDFN. 06/13/2013 -Thursday SOOH 68 stands, 1 cut jt of 2-3/8"4.6# IBT, 1 chemical injection mandrel and 2,500' of control line. PU a 5-1/2" csg scraper,4 DC. TIH w/BHA and 55 stands to 3,516'. Circulated 90 bbls of 6% KCL and TOOH L/D 136 jts of 2-3/8" 4.6# IBT. Secured well and SDFN. 06/14/2013 -Friday PU and RIH w/ 10' x 3-3/8" 6spf 25gm Millennium Gun, 180' 3-3/8" spacer gun, 10' x 3-3/8" 6spf 25gm Millennium Gun, 124' 3-3/8" spacer gun, 10' x 3-3/8" 6spf 25gm Millennium Gun, 118' 3-3/8" spacer gun, 10' x 3-3/8' 6spf 25gm Millennium Gun, 24.29' x 2-3/4" safety spacer, .71" DCI Sub, 1.81" x 3-3/8" TDF firing head, 32.02' x 2-7/8" 8rd EUE, 3" x 2.27" below packer vent,4.50" x 5-1/2" champ packer, 1.68" x 3" annular pressure XO, 2 jts of 2-7/8" 6.5# EUE,4.120" x 2-7/8" RA sub,87 jts of 2• 7/8" 6.5# EUE, Filled tbg w/6% KCL to 354'for 10% underbalance. MIRU EL, RIH w GR/CCL log from 2,795'to 2,100'. Correlated log and PU pipe 17'. Ran back down to 2,780' and log to 2,100'. POOH. RDMO EL. Lower pipe 1' and set packer at 2,808'. Pressured up on annular to 2,500psi and bleed off. Guns fired in 6 mins. Perfed 2,877'-2887', 3,005'-3,015', 3,139'- 3149', 3,329-3,339'. Well had a 10% blow and then went static. Secured well and SDFN. 06/15/2013 -Saturday SITP was 48 psi. Shot fluid level at 600'. Prepped rig to pull pipe. Released packer and SOOH L/D TCP guns. PU 2.875" WLRG, 2.875" XN-nipple (2.201") loaded w/RHCP, 5.50" PHL packer, 2.875" X-nipple (2.313") and 88 jts of 2-7/8" 6.5# E 8rd and TIH. Landed tbg hanger,dropped ball and pressured up on tbg to 4,000psi (charted for 30 mins)Set packer t 2,788'. EOT is at 2,860'. Pressured up on cssto 22500psi (charted for 30 mins). Set BPV, ND BOPE and NU PT. Tested PT to 5,000psi. Secured well and SDFN. 06/16/2013-Sunday • S Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 212-27 50-133-10153-00 161-033 6/6/13 6/18/13 Daily Operations: RDMO WOR and PU containment. RU Johnson tank and MIRU SL. NU lubricator and test to 1,500psi- 250psi, test OK. RIH w/2"JDC and tag at 2,821'wlm. POOH w/ball & rod. RIH w/2.5" GS to 2,826'wlm latched plug and POOH. RIH w/swab cups and tag at 320'wlm, pulled from 520', recovered 160' of fluid. Made a total of 28 swab runs and recovered 45 bbls. Last fluid tag was @ 170'. Secured well and SDFN. 06/17/2013- Monday RU SL. RIH w/swab cups. Made a total of 37 swab runs and recoved 157 bbls. Secured well and SDFN. 06/18/2013 -Tuesday RU SL. RIH w/swab cups. Made a total of 18 swab runs and recoved 77 bbls. Secured well and SDFN. Swanson River Unit Well SRU 212-27 n • • Completion Ran:6/15/13 ACTUAL SCHEMATIC PTD: 161-033 I uhoen kla,,l.a.l.l.1. API: 50-133-10153-00 RKB=14.32' CASING DETAIL 1,22"zz„ Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top A 22" Conductor Surf 32' Yes Surf. Q. 9-5/8" Surf Csg 40 1-55 8.835 Surf 3,455' 12.25 1620Sx Surf. c ° 1 5-1/2" Liner 17 N-80 4.892 Surf 7,800' 8.750 1100 Sx 2,280' TUBING a © 2 eK 2 2-7/8" I Prod Tbg 6.5 L-80 2.441 Surf 2,859' i_ I 1 3 Z?g$, �„ D _ JEWELRY DETAIL m: Item Top ID OD Description in 4 14.32' - - Tubing Hanger, 2-7/8"w/Cameron H BPV profile 5 r m 1 2,000' 2.441" 4.500" 2-7/8"GLM(Special Clearance)w/1"dummy valve 1.11.1 2 2,742' 2.313" 2.875" X-Profile _ 3 2,783' 2.441" 4.700" 5-1/2"Packer V FY1 4 2,825' 2.205" 2.875" XN-Profile 1° 611W 5 2,858' 2.441" 2.875" WLEG 2 ire p ,9-5/8 6 4,300' Tubing Cut • 7 5,749' 1.901" 4.25" Macco 2-3/8"D-S0 GLM w/1"dummy.Btm of GLM @ 5,756' 8 5,799' 1.978" 4.656" Packer,Retrievable,Baker Mod."FH"2-3/8"x 5-1/2",17# 9 5,844' 1.875" 2.9" Nipple,'X',1.875"I.D. e 10 5,878' EOT BOT Shear Sub 6 Toc@ 11 6,024 Plug set @ 6,050',TOC @ 6,024' v a, 12 6,056 Plug set @ 6,176',TOC @ 6,146',Fill @ 6,056' 0 - 13 6,800 Tubing Cut,10/27/96 7,544 Camco MM mandrel with CEV 7,577 Tubing cut,10/25/96 " 7,582 2-3/8"Baker bridge plug,10/25/96 7,589 Camco D nipple a, 56-9c ■°, i 7,601 Baker D packer c 7,612 EOT A 5,698' AD-2 Stop and Packoff(Capped with 43'of cement) 1/ O , B 5,789' Cement Retainer ✓ a 18 C 5,820' CIBP 1/ PERFORATIONS(OPEN HOLE) it Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date Sterling B2 2,877' 2,987' 2,877' 2,987' 10' 4 3-3/8"TCP Guns 6/14/13 roe_914 C_ 59'2 Sterling B3 3,005' 3,015' 3,005' 3,015' 30' 4 3-3/8"TCP Guns 6/14/13 'fi # Sterling B5 3,139' 3,149' 3,139' 3,149' 10' 4 3-3/8"TCP Guns 6/14/13 Sterling B6 3,329' 3,339' 3,329' 3,339' 10' 4 3-3/8"TCP Guns 6/14/13 r"1" „ ■ 61-3 56-9 5,741' 5,747' 5,741' 5,747' 6' 4 Squeezed 06/27/04 -;,�{"_ a 61-3a 56-9c 5,758' 5,767' 5,758' 5,767' 9' 6 Abandoned Jun 2013 r 12 56-9c 5,770' 5,774' 5,770' 5,774' 4' 4 Squeezed 06/27/04 ■62-5 5,787' 5,789' 5,787' 5,789' 2' 4 Tbg Punch to circ cmt 06/28/04 •65-7 5,794' 5,798' 5,794' 5,798' 4' 4 Tbg Punch to circ cmt 06/28/04 t.,T 13 59-2 5,914' 5,924' 5,914' 5,924' 10' 4 P&A'd Mar 2004 61-3 6,076' 6,090' 6,076' 6,090' 14' 4 P&A'd Feb 2004 ly -' � 61-3a 6,104' 6,108' 6,104' 6,108' 4' P&A'd Tyonek 62-5 6,237' 6,254' 6,237' 6,254' 17' P&A'd Tyonek 65-7 6,527' 6,537' 6,527' 6,537' 10' 4 P&A'd Feb 1997 7,620' 7,621' 7,620' 7,621' 1' 5 WSO Squeezed 1961 I Tyonek 77-3 7,625' 7,635' 7,625' 7,635' 10' 4 Abandonded 1961 ' 77-3 a. 5-1/2" TD=7,800 MD/7,800 TVD Max Deviation=Straight Hole PBTD=7,750'MD/7,750'TVD Downhole Revised:06-15-13 Updated by STP 07-15-13 • (,c _( r --,211_ • Swanson River Unit H Well SRU 212 -27 SCHEMATIC (` pTD : p�n.d: 0-7106/04 Hilton) Alaska. LLC API: 50- 133 - 10153 -00 RKB= 14.32' CASING DETAIL LI L22" Size Typ Wt Grade ID T op Btm Hole Cmt Cmt Top 22" Conductor Surf 32' Yes Surf. 9 -5/8" Surf Csg 40 J -55 8.835 Surf 3,455' 12.25 1620 Sx Surf. 5 -1/2" Liner 17 N -80 4.892 Surf 7,800' 8.750 1100 Sx 2,280' = TUBING • I 2 - 3/8" I 4.6 I N - 80 1.995 I Surf I 5,878' I I 120 Sx I 4,400' Ili m 9 JEWELRY DETAIL LA Item Top ID OD Description 14.32' - - Tubing Hanger, 2 -3/8" w/ Cameron H BPV profile 1 2,508' 1.901" 4.25" Macco 2 -3/8" SMO -1C1 Chemical Inj Mandrel (3/8" Line) 2 5,749' 1.901" 4.25" Macco 2 -3/8" D -SO GLM w/ 1" dummy. Btm of GLM @ 5,756' 3 5,799' 1.978" 4.656" Packer, Retrievable, Baker Mod. "FH" 2 - 3/8" x 5 - 1/2 ", 17# 4 5,844' 1.875" 2.9" Nipple, 'X', 1.875" I.D. 5 5,878' EOT BOT Shear Sub TO( ' = i,Jar 6 6,024 Plug set @ 6,050', TOC @ 6,024' 7 6,056 Plug set @ 6,176', TOC @ 6,146', Fill @ 6,056' t 1 i 8 6,800 Tubing Cut, 10/27/96 7,544 Camco MM mandrel with CEV 7,577 Tubing cut, 10/25/96 7,582 2 -3/8" Baker bridge plug, 10/25/96 . 7,589 Camco D nipple 7,601 Baker D packer O 7,612 EOT in I B 2 { 5,789' Cement Retainer 5 5,820' CIBP vi , I 56 - i ISSUES F � ° 3 S HHE° JUN 1 1 20 3 Depth Issue rvno��- 5,914' 1.8" Down Hole Choke @ TOF - B 7,544' 27' Strip Gun 5 PERFORATIONS (OPEN HOLE) ° • 59 -2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date Sterling B2 2,890' 2,900' 2,890' 2,900' 10' 4 Squeezed 1961 Sterling B3 3,018' 3,028' 3,018' 3,028' 10' 4 Squeezed 1961 6 Sterling B5 3,152' 3,162' 3,152' 3,162' 10' 4 Squeezed 1961 im 61 -3 Sterling B6 3,342' 3,352' 3,342' 3,352' 10' 4 Squeezed 1961 in 61 -3a 56 -9 5,741' 5,747' 5,741' 5,747' 6' 4 Squeezed 06/27/04 7 56 -9c 5,758' 5,767' 5,758' 5,767' 9' 6 Perf w/Power Spiral 06/29/04 • 62 - 56 -9c 5,770' 5,774' 5,770' 5,774' 4' 4 Squeezed 06/27/04 El - 65 - 5,787' 5,789' 5,787' 5,789' 2' 4 Tbg Punch to circ cmt 06/28/04 8 5,794' 5,798' 5,794' 5,798' 4' 4 Tbg Punch to circ cmt 06/28/04 _ _ 59 -2 5,914' 5,924' 5,914' 5,924' 10' 4 P &A'd Mar 2004 61 -3 6,076' 6,090' 6,076' 6,090' 14' 4 P &A'd Feb 2004 - 61 -3a 6,104' 6,108' 6,104' 6,108' 4' P &A'd Tyonek 62 -5 6,237' 6,254' 6,237' 6,254' 17' P &A'd , ,.. " w Tyonek 65 -7 6,527' 6,537' 6,527' 6,537' 10' 4 P &A'd Feb 1997 ' s d ' 7,620' 7,621' 7,620' 7,621' 1' 5 WSO Squeezed 1961 .•w,1 r k .. 77 -3 ♦. Tyonek 77 -3 7,625' 7,635' 7,625' 7,635' 10' 4 Abandonded 1961 w ' t . . F'..,M 5 -1/2 Max Deviation = Straight Hole TD = 7,800' MD / 7,800' TVD PBTD = 7,750' MD / 7,750' TVD Updated by DMA 06 -03 -13 .4. . `V9 (mil M SRU 212 -27 Shallow 011 Zone 14 1 , Hilcoep Alaska, 1.1,C Sum mary of Events • Summer 1959 — Drilled SRU 12 -27 as Hemlock oil development well. — Took gas kick in Tyonek 77 -3 sand. Future target of SRU 212 -27 III • Spring 1960, drill & complete SRU 14 -27 as Hemlock oil development well. • Fall 1960, casing failure & remediation in SRU 14 -27 — June 1960: Recognized abnormal temp gradient above 3500'. Determined that Hemlock oil migrating up tbg x csg annulus, entered 13 -3/8" x 7 -5/8" csg annulus and flowing into Sterling B sands at the 13 -3/8" shoe (2,883' MD). 7 -5/8" csg parted at 338'. — Estimated 90 MBO — 775 MBO migrated (based on ranges of daily production and time of leakage) — Nov. 1960. Cemented & tested 13 -3/8" x 7 -5/8" annulus. • SRU 212 -27 drilled Oct. 1961 and found oil 150' NW of 14 -27 — Oil was found 5' updip of 14 -27 in a structural location that should have been wet in all sands • B2, B3 and B5 have small gas pools farther updip; B6 is wet — 4 zones tested in 6 day production test • • Initial rates up to 910 BOPD, dropping to 160 BOPD w/ Wtr cut incr. to 50% by end of test • SRU 21 -33WD drilled in May '62 as a B zone gas well (Sterling structural high) — Compl'd as development fuel gas well, May -62 (SRU 221 -33) — Compl'd B5 in Dec -62. Added B2 and B3 in Feb -63 — Oct -64 converted to Gas producer and annular water disposal — Apr -65 S/I due to water & sand prod'n — Cum. 1.53 BCF from B2, B3, B5. Never produced oil. SRU 212 -27 — Hemlock Oil in the Sterling B Sands SPN [I441 Hilcorp Alaska, I.I.C. M UDLOG 150 11 P • RESD [ MJ PHI [cPS arc [us'F] I x _, Cuttings -__-_ 2o loo 261 oo I DRILLING RATE I- o Cl C2 C3 C4 C5 Description r —. a r e ■ ■ u u n ■■■ TM } �^`� �'�'`' - -z ■ _ I� �rr� } ... a �? It �F i ;$ ,� } {� aa8:: r a:aa ua�i I� N 4114 1 ' I C� - ! �I l)t■75 /01,• �� !� ha . -� l 1I l l IlliQ .i Mill "91 " : i ., .. z YE , . _ g •. - 1 11 ! e 1 I inn I t .,�; C .r Ei " .R :; iI :■r$ I •1 -f = I .KEo -� G J..Z. S . 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I t 11 !I ■■ ■■ ■ .a ■ ■.. 1 1 �. r:: Nil i i = i IO 1 1 ill ' i h 1JIiliiiiii 1II111 :1 � - ; r, rr • I a cc rr t ■rr n■ ■u ■ , ; ih; la EH :: •• fiia:lli i ■■■ l j il inn nii I ; , C L OiilIrn _ Nl l t!J1lommullro nm mill Illllll ' 1 : 6 : , - f 4 ■ n. � • u . . rat■ 1 II �� �:ay� C. iilBE� 151 D M x Rat - = i iithi l o ill! ° M I111111I1I1111113111hIIlla111811 111 P t I --.. __ B6 8! . :; o iEl i311 1 I iR ! i 1 !8 I i t i 5+ B rj I L4I11 P � :111 I:i :IIIIE.ha: Il11II1 �` 111 11 1 1:1 t!• ! ' — i • ° __� ._ !! ■, 11 .'..��' 111 I�lII C ! : ! 0!! !! - -- I : li1111111111; : ::.: Oil i(ai INIMI 8l 1 J . I Hii111 ! IHII:IIIli11 .III : ':- . - 7' m . _ . Point to which Hemlock oil 1 9 21 5 �{ 19 • 1-05 05 migrated to charge SRU - -28 �U�'- 4 6 1 ► -2 0 Hilcor ,1 ka,1.1.c B sands in SRU 314- 1981 -1z— 4 27 wellbore /S 01 -2637 r ' 1 " . Ea , :-; SU 1_ % et:17) 7 N 4 -28 6 S U z2 -2 41 1 K 5F2 01/ 19: +— 1 - 24 2 8 2112 -07 - + SF3 ' r 4 ' • SRU 43 -26 1961 -07 -22 4 . _2613► Itiff SRU 223 -28 I RU 23 1997 -09 -15 .� I+ 19 1-0 00 ..0 ` SR i 96 14 . 21 D • 33 -�- 3 ii RU 34 -25 ., " RLI 1$6 '_ i_1 i Point at which 1963 -05 -1• 2 SRI 31 -2 Hemlock oil escaped BI2OGWC -2 0 / G': C 19 ` -o; -14 in SRU 314-27 in N 1960 ACTIVE INJ. , 0% .RU 21 34 AS SRU 31 -33WD ` 19E -03 25 • I SRU 21 -33WD 4. - 255 8 1981 -05 -2a 5 ` :It-403- 33 •• 1 197— . -06 19 34 r∎ -27'1 6 SRU 41 -33WD 1 - 2.425 S'U 6 19 -0 0 • 1960 -08 -17 • GAS • AC VE INJ. / I • S' U 32 -3 D NDE SRU /A. l . N 1 -05 -29 .1. 1991 01-23 I 1+ -3' SRU 3 7-33 IN ,l Swanson River Unit 1960-0¢ 5 ■ B2 SAND STRUCTURE C.I. = 20' .. / Contoured on Well Tops onl MTL SC I • 3 -33 1 91113-0; 1 =NOMMEN OMMEMMEM S I 5RU a2 -33 I 5RU 21 I 5RU 3# -28 I SRU —28 I ( SRI) 212 I 5/81 5/62 5/63 7/61 10/61 —2400— 1 � — a „s �. 11 — BO kA —2500— _ S BOB 117 _ B2TL 9p • —2600— 80$ i an T1. $ ,,, .2 r� 90 Belo • - e3 h�7L 5GC _ ___ it — A38 Ira . BAB MTV Na —2800— __. . L.19111..,-.-- ea 125' Below • ' B3 GWC ef 9 Mil. 939 MTz , t i '� 80' Below � B5 GWC —300f —... P — • _ . 86 kd7L M° l4G —3100— . aimarat I 33O0 320 — � _ ... -____ __w. — 1800ft 2100ft 1760ft 2235ft — Hilcorp Alaska, 1JA: Observations • B zones that have oil in SRU 212 -27 are correlative with the same reservoirs that contain gas updip: — B2 gas pay in SRU 21 -33WD, SRU 41 -33WD, SRU 32 -33, SRU 34 -28 • No original hydrocarbons in Sterling B sands at SRU 212 -27. — All hydrocarbons recovered from Sterling B sands in SRU 212 -27 are Hemlock in origin. • Only known occurrence of oil was in SRU 212 -27 — No other wells drilled updip after 1961 encountered oil (but none close by) — Note: SRU 212 -27 wellbore is only 150' from SRU 314 -27 • Can gain roughly 100' of structure above SRU 212 -27 — Structure dips 2 -3 degrees to east, with high west of SRU 212 -27 • — Assume no trap for Hemlock oil in B sands — no faults, no pinchouts • Oil should disperse updip to west • KGSF #3 well drilled in 2003 on same pad. — No oil shows or staining reported in Sterling B Sands although drilled 20+ ft below Sterling B sands at 212 -27. • V ®F ripj, • e. w �� \ \I S A THE STATE Alaska i and aS ®f A s K A cciuservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue �F AL A 9* Anchorage, Alaska 99501 -3572 Main: 907.279.1433 `LOY3 Fax: 907.276.7542 spa NED SUN Stan Perhola Operations Engineer 0 33 Hilcorp Alaska, LLC (� 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Undefined Gas Pool, SRU 212 -27 Sundry Number: 313 -280 Dear Mr. Perhola: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ) 0 day of June, 2013. Encl. • fik, III ,� '5 RECEIVED b� .f,. STATE OF ALASKA 1 JUN 0 4 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC A4.41 20 AAC 25.280 1. Type of Request: Abandon { ' Plug for Redrill ❑ Perforate New Pod 0 ' Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations [}r,7r, 4 Perforate 151 Pull Tubing Ell Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development 0 161 -033 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: OG -`;C Anchorage, Alaska 99503 50-133-1015 /�"�cf l 7. If perforating: 8. Well Name and Number. t,' What Regulation or Conservation Order governs well spacing in this pool? CO '123A Swanson River Unit (SRU) 212 -27 Will planned perforations require a spacing exception? Yes' o // 5j7 No [r �l7 13 9. Property Designation (Lease Number): 10. Field /Poo1(s): 1,4' '-°' oL ° L FEDA028406 Swanson River / Tyonek Undef Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,800' 7,800' 1 4,400' 4,400' 5,820; 5,789' 6,024', 6,056'; 7,582' 5,914' (fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 32' 22" 32' 32' Surface 3,455' 9 -5/8" 3,455' 3,455' 3,950 psi 2,570 psi Intermediate Production Liner 7,800' 5 -1/2" 7,800' 7,800' 7,740 psi 6,360 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -3/8" 4.6# / N -80 5,878' Packers and SSSV Type: Baker "FH" Ret Pkr Packers and SSSV MD (ft) and TVD (ft): 5,799' MD - 5,799' TVD Baker D Pkr; N/A 7,601' MD - 7,601' TVD; N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 06/07/13 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907 - 777 -8412 Email sporhola @hilcorp.com Printed Name ,�/71 /�� � Stan �gr ola Title Operations Engineer Signature „.,,d' " i�Gr"'//"� Phone 907 - 777 -8412 Date 00,3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _ 5\2) a „, 6 t:, , Plug Integrity ❑ BOP Test [B-- Mechanical Integrity Test ❑ Location Clearance ❑ Other: 7 3 DO b i i 60/9 / �.__ RBQAAS JUN 11 201 g- / Soo p5,.- /4n 1, Je.4 - ;i;i -- . Spacing Exception Required? Yes ❑ No l Subsequent Form Required: / d — / 0-7 t APPROVED BY v / Approved by: COMMISSIONER THE COMMISSION Date Form 10 (Revised 10/2012) Approved application is valid for 12 months from the date O�'approval. a ii t L. 4 11 • Well Prognosis Well: SRU 212 -27 Hilcorp Alaska, LLC Date: 6/4/2013 Well Name: SRU 212 -27 API Number: 50- 133 - 10153 -00 Current Status: Shut -in Gas Well Leg: N/A Estimated Start Date: June 7th, 2013 Rig: Williams 405 Reg. Approval Req'd: 403 Date Reg. Approval Rec'd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 161 -033 First CaII Engineer: Stan Porhola (907) 777 -8412 (0) (907) 331 -8228 (M) Second Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) AFE Number: Current Bottom Hole Pressure: — 2,686 psi @ 5,752' TVD Shut -in tubing pressure @ 800 psi Maximum Expected BHP: — 2,686 psi @ 5,752' TVD BHP = 9.0 ppg ( Tyonek 56 -9c) Max. Allowable Surface Pressure: — 2,111 psi BHP — (0.1 psi /ft x 5,752' TVD) Brief Well Summary SRU 212 -27 was drilled in August 1961 to a depth of 7,800'. The well was tested for oil in the Sterling B -sands between 2,890' and 3,352' at rates up to 1,010 bopd and 150 mcf /d. This oil had migrated from the Hemlock into . the Sterling B -sands from well SRU 314 -27 (PTD 159 -016). The flow path was believed to be from the SRU 314- 27 production casing x tubing annulus to a hole in the production casing at 1,500' and down the surface casing x production casing annulus to the surface casing shoe. SRU 212 -27 was originally completed in the Tyonek 77 -3 , sand. The well was worked over in 1996 and recompleted in shallower Tyonek gas sands and a cement packer was put in place in 2004 to access the Tyonek 56 -9c sand. The casing scheme consists of a 9 -5/8" surface casing @ 3,455' and cemented to surface in 2- stages. A 8 -3/4" hole was drilled to 7,800' and a 5 -1/2" N -80 production casing was run and cemented in 2- stages. Notes Regarding Wellbore Condition Current well status is a shut -in gas well in the Tyonek 56 -9c with fill last tagged @ 5,761' on 7/06/2004. . OBJECTIVE OF WORKOVER Abandon the existing Tyonek 56 -9c gas sand and recomplete uphole in the Sterling B -sands to test the producibility of oil that migrated from the Hemlock into the Sterling B -sands (B2, B3, B5 and B6). The well test data will be used to evaluate the long -term production capabilities of this well before going on full -time production. Pre Work -Over Rig Procedure 1. MIRU slickline, PT lubricator to 2,500 psi Hi 250 Low. 2. RU gauge ring, RIH and tag fill at 5,761'. 3. Set tubing stop /plug at +/- 5,700'. Bleed off tubing pressure. 4. Dump bail 25' of cement on tubing plug. 5. Tag top of cement. 6. RD slickline. 7. MIRU a -line, PT lubricator to 2,500 psi Hi 250 Low. 8. RU gamma ray tool, RIH and log from +/- 5,600' to surface. 9. RU jet cutter, RIH and cut tubing at +/- 4,300' (10 ft above a collar). • • Well Prognosis Well: SRU 212 -27 Hilcorp Alaska, LLC Date: 6/4/2013 10. RU circulating manifold and bleed any pressure off tubing through same to working tank. 11. Circulate well with 6% KCI. 12. Test casing to 2,500 psi for 30 min. /G4 13. RD e-line. Work -Over Rig Procedure 14. MIRU Williams pulling unit. 15. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubing stop /plug and set at 500'. 16. Set BPV in tubing hanger, ND tree, NU 11" BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. c. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 17. Release test pressure, pull tubing stop or BPV and install handling sub in hanger. 18. Back out tbg hanger hold down pins and pick up on hanger. 19. With hanger free POH with tubing, chemical injection mandrel and control line. Rack back tubing. 20. PU 5 -1/2" 17# casing scraper, RIH on 2 -3/8" recovered tubing down to +/- 3,500'. 21. Circulate hole clean with 6% KCI. 22. POOH and LD casing scraper and LD 2 -3/8" tubing. 23. PU new 2 -7/8" tubing and rack back. 24. PU 3 -3/8" TCP guns and champ packer, RIH and set on depth. 25. RU e-line. Correlate TCP guns on depth and set champ packer. 26. RD a -line. 27. Perforate Sterling (B2, B3, B5, and B6) intervals with deep penetration charges with 3 -3/8" OD carrier 4 spf on 90 deg phase. a. Proposed perfs shown on the proposed schematic in red fort. b. Final Perfs tie -in sheet will be provided in the field for exact perf intervals. 28. RIH with 5 -1/2" packer and GLV per design with new 2 -7/8" 8rd EUE L -80 tubing. Set packer at +/- 2,790'. Land tubing hanger with 4 -8K pounds max tension on tubing. 29. Hydraulically set packer and test casing to 2,500 psi and tubing to 3,000 psi, chart for 30 min ea. 30. Set BPV, ND BOPs, NU Tree, test tree to 5,000 psi 31. RDMO workover rig and equipment. 32. MIRU slickline, PT lubricator to 1,500 psi Hi 250 Low. -pp_ _ ', ) 33. Swab test well to tank, collect oil samples and send in for analysis. ( ?Jai ie t(G 34. RD slickline. lases 35. Shut -in well and evaluate swab test and oil sample data for future development potential. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic • Swanson River Unit 1 • Well 21 - 27 SCHEMATIC Last Com plee 07/06/04 PTD: 161 -033 Hi ' corn Ala,,ka, LI,C API: 50- 133 - 10153 -00 y RKB= 14.32' CASING DETAIL - 2r, Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 22" Conductor Surf 32' Yes Surf. 9 -5/8" Surf Csg 40 J -55 8.835 Surf 3,455' 12.25 1620 Sx Surf. ca 5 -1/2" Liner 17 N -80 4.892 Surf 7,800' 8.750 1100 Sx 2,280' a TUBING c. � , F i �1 2 -3/8" 1 4.6 I N -80 1.995 I Surf 1 5,878' I I 1205x I 4,400 m m m I ,� U , 9 5/8 JEWELRY DETAIL I!J Item Top ID OD Description 14.32' - - Tubing Hanger, 2 -3/8" w/ Cameron H BPV profile 1 2,508' 1.901" 4.25" Macco 2 -3/8" SMO -1C1 Chemical Inj Mandrel (3/8" Line) 2 5,749' 1.901" 4.25" Macco 2 -3/8" D -SO GLM w/ 1" dummy. Btm of GLM @ 5,756' a../ 3 5,799' 1.978" 4.656" Packer, Retrievable, Baker Mod. "FH" 2 -3/8" x 5 -1/2 ", 17# +hs 4 5,844' 1.875" 2.9" Nipple, 'X', 1.875" I.D. TOC (a) 5 5,878' EOT BOT Shear Sub i - 4,400' 6 6,024 Plug set @ 6,050', TOC @ 6,024' J 7 6,056 Plug set @ 6,176', TOC @ 6,146', Fill @ 6,056' A 8 6,800 Tubing Cut, 10 /27/96 ' 7,544 Camco MM mandrel with CEV c 7,577 Tubing cut, 10/25/96 • 7,582 2 -3/8" Baker bridge plug, 10/25/96 7,589 Camco D nipple 7,601 Baker D packer O1 h � 7,612 EOT W 2 A. 5,789' Cement Retainer B. 5,820' CIBP o± 56 -9c _ 1 "t' lEtlia wr Q. _- - ISSUES r it 3E ° i Depth Issue 3 5,914' 1.8" Down Hole Choke @ TOF �� H 7,544' 27' Strip Gun I 4 5 1 --__3 PERFORATIONS (OPEN HOLE) 7 O H 5.914. (' 4* 1 59 - Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date Sterling B2 2,890' 2,900' 2,890' 2,900' 10' 4 Squeezed 1961 "._ Sterling B3 3,018' 3,028' 3,018' 3,028' 10' 4 Squeezed 1961 11 J 6 Sterling B5 3,152' 3,162' 3,152' 3,162' 10' 4 Squeezed 1961 t, 61 -3 Sterling B6 3,342' 3,352' 3,342' 3,352' 10' 4 Squeezed 1961 n ft }f£ ?k ?k ' • 61 -3a � .... .: ......:;.:: 56 -9 5,741' 5,747' 5,741' 5,747' 6' 4 Squeezed 06/27/04 �" 56 -9c 5,758' 5,767' 5,758' 5,767' 9' 6 Perf w /Power Spiral 06/29/04 ■ 62 -5 56 -9c 5,770' 5,774' 5,770' 5,774' 4' 4 Squeezed 06/27/04 E3 . 65 -7 5,787' 5,789' 5,787' 5,789' 2' 4 Tbg Punch to circ cmt 06/28/04 "' 8 - 5,794' 5,798' 5,794' 5,798' 4' 4 Tbg Punch to circ cmt 06/28/04 ill-1111 I 59 -2 5,914' 5,924' 5,914' 5,924' 10' 4 P &A'd Mar 2004 61 -3 6,076' 6,090' 6,076' 6,090' 14' 4 P &A'd Feb 2004 t o ki. - 61 -3a 6,104' 6,108' 6,104' 6,108' 4' P &A'd Tyonek 62 -5 6,237' 6,254' 6,237' 6,254' 17' P &A'd Tyonek 65 -7 6,527' 6,537' 6,527' 6,537' 10' 4 P &A'd Feb 1997 'r ,e i � 7,620' 7,621' 7,620' 7,621' 1' 5 WSO Squeezed 1961 . .e ' 77 -3 Tyonek 77 -3 7,625' 7,635' 7,625' 7,635' 10' 4 Abandonded 1961 s, ... • iR'•z. °°-- 5 -1/2 Max Deviation = Straight Hole TD = 7,800' MD / 7,800' TVD PBTD = 7,750' MD / 7,750' TVD Updated by DMA 06 -03 -13 • • Swanson River Unit Well SRU 212 -27 Proposed PROPOSED SCHEMATIC PTD: 161 -033 Ilikorn Alaska. I. API: 50- 133 - 10153 -00 RKB = 14.32' l CASING DETAIL Aa is i 1 L22" Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top `1, r 22" Conductor Surf 32' Yes Surf. v �; 2 9 -5/8" Surf Csg 40 J -55 8.835 Surf 3,455' 12.25 1620 Sx Surf. - o ^ J I 1 I 3 5 -1/2" Liner 17 N -80 4.892 Surf 7,800' 8.750 1100 Sx 2,280' = C' ..1,.. TUBING 5 © 4 2 -7/8" 6.5 1 -80 2.441 Surf 2,850' j c _ 5 ■ CO ,� 9 5/8 JEWELRY DETAIL I!J 31(5 -' Item Top ID OD Description 14.32' Tubing Hanger, 2 -7/8" w/ Cameron H BPV profile 1 2,000' 2.441" 4.500" 2 -7/8" GLM (Special Clearance) w/ 1" dummy valve 2 2,760' 2.313" 2.875" X- Profile 3 2,790' 2.441" 4.750" 5 -1/2" Packer 4 2,830' 2.313" 2.875" X- Profile 6 5 2,860' 2.441" 2.875" WLEG TOC 4.400' 6 4,300' - - Tubing Cut -8 7 5,749' 1.901" 4.25" Macco 2 -3/8" D -SO GLM w/ 1" dummy. Btm of GLM @ 5,756' 8 5,799' 1.978" 4.656" Packer, Retrievable, Baker Mod. "FH" 2 -3/8" x 5 -1/2 ", 17# 9 5,844' 1.875" 2.9" Nipple, 'X', 1.875" I.D. ' 10 5,878' EOT BOT Shear Sub 11 6,024 Plug set @ 6,050', TOC @ 6,024' 12 6,056 Plug set @ 6,176', TOC @ 6,146', Fill @ 6,056' 13 6,800 Tubing Cut, 10/27/96 0 7,544 Camco MM mandrel with CEV 5 f� 7,577 Tubing cut, 10/25/96 o '' - 56 I 7,582 2 -3/8" Baker bridge plug, 10/25/96 - - 7,589 Camco D nipple ts, n 7,601 Baker D packer 7,612 EOT o u A. 5,789' Cement Retainer r= I _ . g B. 5,820' CIBP B j I( 1 PERFORATIONS (OPEN HOLE) OF '''. '< 1 59 -2 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date `2" , .4 Sterling B2 2,890' 2,900' 2,890' 2,900' 10' 4 3 -3/8" HSD Guns Proposed n Sterling B3 3,018' 3,028' 3,018' 3,028' 10' 4 3 -3/8" HSD Guns Proposed , 11 Sterling B5 3,152' 3,162' 3,152' 3,162' 10' 4 3 -3/8" HSD Guns Proposed R 61 -3 Sterling B5 3,327' 3,335' 3,327' 3,335' 8' 4 3 -3/8" HSD Guns Proposed p ;- N 61 -3 ,;M Sterling B6 3,342' 3,352' 3,342' 3,352' 10' 4 3 -3/8" HSD Guns Proposed 12 56 -9 5,741' 5,747' 5,741' 5,747' 6' 4 Squeezed 06/27/04 ■ 62 - 56 -9c 5,758' 5,767' 5,758' 5,767' 9' 6 Abandoned Proposed C:t • 65 -7 56 -9c 5,770' 5,774' 5,770' 5,774' 4' 4 Squeezed 06/27/04 4. , - 13 5,787' 5,789' 5,787' 5,789' 2' 4 Tbg Punch to circ cmt 06/28/04 - 15M7.1. - 5,794' 5,798' 5,794' 5,798' 4' 4 Tbg Punch to circ cmt 06/28/04 59 -2 5,914' 5,924' 5,914' 5,924' 10' 4 P &A'd Mar 2004 61 -3 6,076' 6,090' 6,076' 6,090' 14' 4 P &A'd Feb 2004 61 -3a 6,104' 6,108' 6,104' 6,108' 4' P &A'd ', 1 Tyonek 62 -5 6,237' 6,254' 6,237' 6,254' 17' P &A'd let 4 ,,. ,tt ^ ; 'r 77 g Tyonek 65 -7 6,527' 6,537' 6,527' 6,537' 10' 4 P &A'd Feb 1997 �». 0,x ♦11, 7,620' 7,621' 7,620' 7,621' 1' 5 WSO Squeezed 1961 fir , ∎$. f , Tyonek77 -3 7,625' 7,635' 7,625' 7,635' 10' 4 Abandonded 1961 _ 5 - 1/2 „ Max Deviation = Straight Hole TD = 7,800' MD / 7,800' TVD PBTD = 7,750' MD / 7,750' TVD Updated by STP 06 -04 -13 • • la • Swanson River SRU 212 -27 06/04/2013 Swanson River SRU 212 -27 Williams BOP • • 111 Ii ` III IIII[ 11 III 111 3.46' Shaffer 11" 5M rill 111 111 IEI III Shaffer LWS - 1 kb= • 0 - : 2.75' maw _II1,1111111111� j Fil 1 A - 1,1 111111111 111'111 x 7 1/16 S 2.00' Ground Level - -- =111 1 'I ` liin Tubing head, Shaffer lei Mk. I!i 0 T59-AD, 11 3M X 111 7 1/16 5M w/ 2- 2 1/16 5M , ? Valve, WKM -M , 2 1/16 11 1 l secondary 5 1/2 yp head I 11, ; ,11 I 11 111-1 "' 5M FE, HWO, 1St !I Casing head, Shaffer KS, - 11 3M X 9 5/8 SOW, w/ 2- • 2" LPO, 5 1/2" KD slips III . 111 and packoff assy in head . a Valve, plug, Rockwell, 2" ICI � 0:0 1 lA-b:i LPO, • • Davies, Stephen F (DOA) From: Stan Porhola [sporhola @hilcorp.com] Sent: Thursday, June 06, 2013 3:40 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA); Kevin Eastham; Larry Greenstein Subject: RE: SRU 212 -27 Steve, No other wells are in the governmental section (Section 33) or within 3,000' of SRU 212 -27 (PTD 161 -033) that are perforated in the Sterling B2 to B6 sands. The closest well perforated in the Sterling B -sands is SRU 23 -33 (PTD 161 -019), a shut -in gas well due to high water production. This well is located approximately 8,540' to the southwest. Our geologist Kevin Eastham is planning on presenting information on this reservoir to the BLM. We would also like to include yourself and possibly Guy Schwartz. Would it be possible to setup a meeting at the AOGCC offices are do a single presentation on the reservoir /geology for the SRU 212 -27 recompletion? Regards, Stan Porhola 1 Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331 -8228 From: Davies, Stephen F (DOA) [ mailto :steve.daviesOalaska.gov] Sent: Thursday, June 06, 2013 10:28 AM To: Stan Porhola Cc: Schwartz, Guy L (DOA) Subject: SRU 212 -27 Stan, Reviewing the Application for Sundry Approvals for SRU 212 -27 perforating. Are any other wells perforated in the Sterling B2 to B6 sands in the same governmental section as, or within 3000' of, this well? If so, which wells and how far from SRU 212 -27 are the perforations? An exception may be needed. Please review regulations 20 AAC 25.055(a)(2) and (a)(4), which are available online at http: / /www.doa.alaska.gov /ogc /Regulations /Reglndex.html. Thanks, Steve Davies AOGCC 907 - 793 -1224 1 \ L -e- \o�>3c) Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 -" Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 AUG 0 b 2.009 Cathy Foerster Commissioner CANNA OC i 0 2 2014lqSII & Gs f'ac"o'�"g'r�r` Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 1842 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platforin life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage Ino flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage Ino flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct4 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 iCollapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life �F { AXA, SKA 01% AND GAS CONSERVATION COMUSSION June 22, 2009 \ (.*.A --c)`3 3 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 SCANNED 0 C T 0 22014 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.aubert(a),alaska.gov. Sincerely, 444"�� Cathy . Foerster Commissioner Enclosure 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 41B-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 Union Oil Company of California 172-020 173-014 _ Trading Bay St A-23DPN Trading Bay St A-30 ~ STATE OF ALASKA ~ ALASKJ. ,L AND GAS CONSERVATION COMMIS~ ,N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: OilO Gas0 Plugged 0 Abandoned 0 Suspended r WAGO 1b. Well Class: - 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJO WINJO WDSPLO No. of Completions 1 Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., °lflJ 12. Permit to Drill Number: :2- Union Oil Company of California /0/6/1-(.. 161-033 3O't'-:J I 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10153-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,850' FNL, 1,500 FWL, of Sec. 27, T8N, R9W, SBM. SRU 212-27 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 1,850' FNL, 1,500 FWL, of Sec. 27, T8N, R9W, SBM. 14.32' RKB Total Depth: 9. Plug Back Depth(MD+ TVD): Swanson RiverlTyonek 1,850' FNL, 1,500 FWL, of Sec. 27, T8N, R9W, SBM. 7,750'n,750' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 349,072 y- 2,469,854 7,800'n,800' Swanson River Firld TPI: x- 349,072 y- 2,469,854 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 349,072 y- 2,469,854 nla A-028406 18. Directional Survey: Yes 0 No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL nla 21. Logs Run: GammalCCL 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" 0 32' 0 32' nla 9-5/8" 40# J-55 0 3,455 0 3,455 nla 5-1/2" 17# N-80 0 7,800' 0' 7,800' nla 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE I DEPTH SET (MD) PACKER SET (MD) See schematic attached for full perf detail. 2-3/S" @5,S7S' cemented. TOC is 4,400' 5,799'; 7,601' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED see cementing record on Schematic. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): n/a Flow (see reverse for results) Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: [GaS-Oil Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ..... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none; state "none". ~ ~ RECEIVED ~'~~ non. ~:u /0- '{)~(J{bQW~/O-'fO3. SEP 2 2 2004 ORIGINAL Alaska Oil & Gas Cons. Commís~ i Anchorage t.;F on Form 10-407 Revised 12/2003 CONTINUED ON REVERSE R8DMS Bf L SEP 2 7 10°' 28. GEOLOGIC MARKERS 29. FORMATION TcSTS NAME' MD " - TVD Include and briefl~mmarize test results. List intervals 56-9 sand 5752'md 5752'TVD Perf. 5758' - 5767'md open well to production NFTS. no flow at 1000psi tubing Pr.; drop to 540psi, no flow; drop to Opsi, still no flow. SI well RECE'VED SEP 2 2 2004 A\aska Oi\ & Gas Coos. Commission L --"e 30. List of Attachments: Daily Operations Summary, Schematic. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. for Sundry 304-210 Contact: Steve Tyler 263-7649 Printed Name: Philip J. Krueaer Title: Drilling Manager Signature:~.ß~,. Phone: 907-276-7600 Date: 9/22/2004 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 UNOCAL8 API# 50-133-10153-00 ~ .'--"" RKB =14.32' !cURRENT COMPLETION as of 6/30/0~ Swanson River Field Soldotna Creek Unit Well SRU 212-27 Original Drill & Completed 10/61 Last WO 11/24/96 ~ @ g ¡ '" .. ; @ " ~ > Q .. ~ @ '" ¡: e TD= 7800' PBTD= 7750' Max Deviation = Straight Hole Size 22" Tub i n Btm 32' 3455' 7800' sx Cmt Yes Sx 9-5/8" 5-1/2" Tobin 2-3/8" J-55 N-80 J ewe ry Item Top ID OD Description 14.32' - - Tubin2 Han2er, 2-3/8" wi Cameron H BPY profile 1 2508' 1.901 4.25 Macco 2-3/8" SMO-ICI Chemicallnj Mandrel 2 5749' 1.901 4.25 Macco 2-3/8" D-SO GLM wi I" dummy. 8tm of GLM @ 5756 3 5799' 1.978 4.656 Packer, Retrievable, Baker Mod. "FH" 2-3/8" x 5-1/2", 17# 4 5844' 1.875 2.90 Nipple, 'X', 1.875" LD. 5 5878' EOT BOT Shear Sub 6 6024 Plug set@6O50', TOC @6O24' 7 6056 Plug set@6176', TOC@6146',FiII@6056' 8 6800 Tubing Cut, 10/27/96 7544 Cameo MM mandrel with CEY 7577 Tubing cut, 10/25/96 7582 2-3/8" Baker bridge plug, 10/25/96 7589 Cameo D ninnle 7601 Baker D nacker 7612 EOT A. 5789' Cement Retainer B. 5820' CIBP 5914' 7544' Issues 1.8" Down Hole Choke 27' Stri Gun TOF PERFORATION HISTORY DIU Interval ACCODL Date ZOne Top Btm Amt spf Comments 2,890' 2,891' l' 4 Sqz'd '61 3,018' 3,028' 10' 4 Sqz'd '61 3,152' 3,162' 10' 4 Sqz'd '61 3,342' 3,352' 10' 4 Sqz'd '61 06/27/04 Sqz Perls 5,741' 5,747' 6' 4 Sqz'd 6/27/04 06129/04 56-9c 5,758' 5,767' 9' 6 Perl wI PowerSpirai 06/27/04 Sqz Perls 5,770' 5,774' 4' 4 Sqz'd 6/27/04 06/28/04 Thg Punch 5,787' 5,789' 2' 4 Tbg Punch 10 cire aD 06/28/04 Thg Punch 5,794' 5,798' 4' 4 Thg Punch to circ emt Mar-04 59-2 5,914' 5,924' 10' 4 P&A'd 6/24/04 Feb-04 61-3 6,076' 6,090' 14' 4 P&A'd 6,104' 6,108' 4' P&A'd 6,237' 6,254' 17' P&A'd Feb-97 Tyonek 6,527' 6,537' 10' 4 P&A'd 1961 7,620' 7,621' l' 5 WSO sqid '61 1961 LTyonek 7,625' 7,635' 10' 4 Aband '96 SRU 212-27 Current Schematic 06-30-04 5/27/2004 SL T ~ .--..., 6/13/04 No operations PJSM. Csg @ 1500psi. Tbg @ 1200 psi. RU Blow-down tank and Pump to csg. Attempt to bleed csg off. In 2 min csg pressure @ 500 psi at a stable flow. Tbg pressure droped to 1100 psi. SI csg. Tbg pressure came back up to 1200 psi. csg pressure was climbing. Suspend Operations. RD equipment. 6/14/04 No Operations PJSM Spot pollard slickline equipment, Johnson flowback tank & choke skid. RU same. Tbg @ 1200 psi; Csg @ 800 psi. Bleed down csg to 0 psi. Gas & fluid returns. Monitor well. RU Schlumb Pump truck. Pressure test surface iron to 3000 psi. fix leaks repressure test same. OK. Pressure csg to 1000 psi fl 5 min. lost 10 psi. Pressure csg to 1500 psi fl 5 min. lost 11 psi. Pressure csg to 2000 psi fl 20 min. No loss of pressure. Used a total of 5 bbls for pressure test. Bleed off csg to 0 psi. RD equipment. 6/21/04 Coil operations still spotted at SRU 34-28 Hard iron broke down and moving unit to new loacation SRU 212-27 Make up hard iron & support equipment as it arrives on location. Change pack off on unit. Load water in tanks. Clean batch mixer. Finish all hardlines. Start BOP pressure test (Test Blind Rams) 6/22/04 Cut and make up new coil connector. Pull test same and makeup BHA Stab Injector Head and pressure test Pipe Rams. Rig up annulus hard lines pressure test same. Bull head well from surface and get higher than anticipated pressures (3500#). Decide to lubricate and bleed from surface. Bleed off gas and fluid. Bull head again and well breaks over at 1500#. Establish injection rates into formation 1.0 BPM 450#,0.75 BPM 430#, 0.25 BPM 215# Looks like formation bridge broke down. RIH checking pickup weights. Review Braiden Head Squeeze procedure with Schlumberger. Stop coil at tubing tail. Mix Cement Pump and Spot 5 Bbls of Cement as pulling coil out according to schedule. Pump 2 Bbls extra displacement fluid and end up with coil 600' off top of cement. Had a small show of annular returns which showed that cement gradient was not going to perfs when laying in. Squeeze cement into formation at 2400# and breaks 4 times during squeeze down in the 1800# range. Stopped squeeze at 4.8 Bbls away. Called town and discussed Cement time and clean out plan. Reciprocated coil during this time. Bleed pressure off annulus and started washing pipe going in hole to 5850'. Washed way out of hole seeing one small over pull and washed the pipe that had cement again. POOH circulating low rates. POOH CT AS Move injector head out of way rig up slickline. Already on location. Rig up pressure test and RIH with 1.865 gauge ring to 5865'. Did not set down & did not see any restrictions of cement stringers. Rig down slickline & rig up E-line. Held PJSM Tested to 2500#. Weatherford bridge plug was made up waiting on bank. (1.75" OD) RIH with bridge plug to 5839'. Log to 5820' Set plug at 5820' Schlumberger on surface Bridge plug was tested to 1500# Work on SRU 212-27 /"""' .--..., switches from AFE # 162565 P&A To AFE # 162566 Re-completion AFE at this point Switch from 212-27 P&A AFE to Completion AFE at 16:00 Hrs RIH on Schlumberger line with 4' perf gun (1.56" 4 spf HC) Spotted gun and shot 17 holes from 5794' to 5798'. After firing perf gun, ran GAMMA/CCL and logged from 5820' to 4900'. POOH RIH with Weatherford 1.75" OD FH cement retainer and set retainer at 5789'. Set at this depth due to tubing collar. Schlumberger E-Line POOH Rig down Schlumbeger to let coil on well Stab injector head, Pressure test. Put Weatherford polish Retainer Stinger Start running coil in hole. Mixing Cement Chemicals and lining up for cement job 6/23/04 Continue RIH for cement packer job and set down on retainer at 5789' Estabish flow rates above retainer. Set down on retainer. Could not establish circulation through retainer. Call Town Pulled out of hole to take seals off retainer and remove 5/16" plug out of bottom of the retainer stinger RIH and establish circulation above retainer and attempted to wash out retainer body. (No luck) Town called to rig down and move coil to 34-28 Town called to mobe Schlumberger e-line to perforate and cement PJSM, rehead cabe, rig up and pressure test lubricator to 2500 psi RIH with tubing punch gun to 5787' (2' high) Put 500 psi on tubing and fired gun (17 holes) Pressure dropped to 100 psi POOH Rigged down Schlumberger Circulated bottoms up with Schlumberger pump truck. (125 bbls) Established rate: 1.5 bbls - 670 psi, 2.5 - 1240,3 - 1640,3.5 - 2000 Mixed chemicals for cement and mixed cement for pumping 6/24/04 Pumped 25 bbls 15.8# cement down tubing from surface with Schlumberger Cement Truck. Had no problems keeping up with injection in 2 3/8" tubing. Slowed pump down at 20 BBls away to 500# discharge on surface. Cement turned comer at 22 BBls and built to 1000# on surface as cement was displaced around back side. Total displacement was 22 Bbls. Shut down pump tubing droped right to 500#. Tubing pressure slowly fell down to 385# Shut in all wellhead valves. Close both master and swab valves on wellhead to hold tubing pressure on cement packer. Rig down equipment and wait on cement PJSM with pollard, rig up, test lubricator RIH with 1.65 " GR and tagged top of cement at 5479' RKB. POOH RIH with temp survey down to 5448'. Logged in and out of well. Check data - good Rig down and secure well. (Well had 385 psi when shut in at 1 :00 AM and had 220 psi when Pollard rigged up) Suspended operations & wireline crew went to SCD 43B-8 for production 6/26/04 Move equipment onto pad and spot. Flange up BOP's and make up hard lines. Pick up injector head. Pressure test BOP's 300# low & 3500# high on blinds and rams. (OK) Move nitrogen unit and crew to SRD 42A-5 and bull head N2 into tubing while taking returns up annulus. Make up soft lines from shaker, batch mixer, filter skid and c-pump. Mix Gel. Baker hand and Schlumberger made up Coil Connector and pull test (15) & PT 3000#.. Make up BHA of 1.69" extreme motor with 3 Blade Cement Mill. Stab injector /"'" ~. head and shell test to 3500#.. RIH checking pick up weights, Dry tag made at 5465' Attempt to pump polymer gel straight from batch mixer. Having problems. Move gel to surface tank and dilute until able to break circulation on surface. Change filters in filter pots at C-pump. Mill ahead after getting gel system to circulate. Work our way up to 54 FPM by midnigth.Back reaming and checking weights on a regular bases. Milled a total of 265' by midnight. 6/27/04 Finish milling out cement to 5772' Keep stalling out motor. Baker rep says its metal. Depth is too high. POOH Coil POOH, Set injector head back. Help spot wireline PJSM, rig up wireline, pressure test to 2500 psi RIH with 1.75 OD bailer down to 5779' RKB. POOH RIH with 15' of 1 11/16" dummy gun down to 5779. POOH RIH with 1 3/4" bailer down to 5779'. Work tools and POOH. Very little cement. Rig down, standby and released. PJSM, rig up Schlumberger, pressure test RIH with 6', 1.56 perf gun down to 5774'. Talked town. POOH and reduced gun to 4'. RIH with 4',1.56 perf gun and punched 17 holes from 5770' to 5774' with 500 psi on tube (lost pressure) RIH with 6', 1.56 perf gun down and punched 25 holes from 5741' to 5747' with 500 psi on tube (lost pressure) Rig down wireline after POOH. Perform injection test on squeeze perfs 0.5 BPM - 2550#, 0.75 BPM - 2700# & 0.25 BPM - 2475# Stab injector head onto well with cement nozzle & shell test. RIH checking pick up rates. Dry tag bottom. 5 Bbls drill water followed by 10 Bbls Cement and 3 Bbls drill water pumped. Stage coil out of hole as laying cement in hole on pump schedule displacing rest of coil. Bull head 6 Bbls of cement away at 2573# well head. Shut down 10 minutes. Pump 1 Bbl at 2610# shut down and wait 15 minutes. Pump 1 Bbl at 2620# and shut down 15 minutes. Pump Bbl #9 at 2675# and shut down. Pressure stabilized at 2200#. WOC to clean out Waiting on cement before washing out. Holding 2200# while waiting. 6/28/04 WOC Bleed well off slowly. Replacing some pressure with ECD while pumping. Slowly start washing pipe from 2900' Circulate bottoms up from 5772'. Check returns (Clean) POOH WOC prior to injection test Attempt to get pressure test. At 2600# we had leak off. Talked to town. At 3000# we have 0.12 BPM rate leak off. At 3500# we have 0.4 BPM leak off. Call for cementers. Town talking to Schlumberger about job. Crew shows and rig equipment back up. RIH checking pick up weights Dry Tag 5772' Mix 10 Bbls of cement 15.8# Latex Gas block Pump 5 Bbls drill water 10 Bbls cement and 5 Bbls drill water. Displace cement to end of coil with lease water. Pumping at 1/4 Bbl per minute starting pulling coil out of the hole while laying in cement. Pulled above cement top to 2961'. Bull head cement at 1/4 BPM for 7 Bbls at 2928# max well head. Shut pump down and wait 30 minutes. Pressure fell back to 2523# Pump last two Bbls 8 & 9 in at 1/4 BPM. Shut down at 3384# well head. POOH pumping in pipe displacement volume to maintain well head pressure. CT AS Pull injector head back. Make up Baker BRA with 3 blade cement mill. (PIT & pull test same) PIT stack after stabbing injector header back onto wellhead. RIH while blowing well head pressure down Set down dry at 4925' on cement stringers Start pumping at 1/4 BPM and mill ahead on surface r- ..--.... stringers in pipe starting at 4925'. Milled ahead to 5600' by midnight and back reamed same. 6/29/04 Continuation of milling cement from yesterday 5600' to 5786' =hard and above retainer. Back reamed as needed, Circulate clean baclcreaming as needed from TD to 5680'. PIT squeeze (OK) for 10 minutes Launch 7/16" ball and open circulating sub Displace coil and tubing with nitrogen from 5680' to surface POOH and pressure well up to 2500# with nitrogen. Close well head valves Rig down nitrogen and coil. Call out Weaver Bros and start mobe PTS to location WBI on location moving equipment to Happy Valley & Moving PTS T=Pak to 212-27 Finished moving Coil Tubing equipment and spotting PTS equipment. Moved in and rigged up Schlumberger EL picked up 1.69" Power Spiral EJ strip gun 7-SPF (9') Pendulum 45-degree phasing, 1-3/16" Fishing Head, Swivel, 4' weight bar, 6' weight bar, 1-11/16" CCL, Magnetic positioning device, safe firing head (Total length 27.6') Pressure tested lubricator to 3,000-psi, opened well pressure 2,500- psi. RIH tagged fluid at 4,800' ELM finished GIH to 5,790' Pick up weight 730-lbs. Logged from 5,790' to 5,590' correlated on depth w/GR & CCL log 6/22/04. Bled Tubing pressure from 2,500-psi to 1,725-psi (268-psi underbalanced). Positioned guns 5,758'-5,767' CCL depth 5,751.2' fired gun monitoried pressure increased to 1,731-psi. Picked up tools roughly 3' stuck at depth 5,764' ELM. Worked EL several times unable to pull free. Bled Tubing pressure from 1, 731-psi to 1,600-psi worked EL would not pull free, picked up to 1,500 lbs. pull unable to free tools, bled off tubing to 1,500-psi worked EL picked up to 1,700-lbs. unable to pull free. Called Town discussed situation. Decision was made to pressure back up to 2,200-psi work EL free. Pressured up Tubing from 1,547-psi to 2,200-psi worked EL gradually increasing tension from 1,600-lbs, 1,800-lbs, 2,000-lbs, weak point broke at 2,160-lbs. Started POOH Pulled out of hole to 68' EL measurement, became stuck in injection head (flow tubes) with 40' +/- below bottom hanger. Pulled 1,800-lbs. unable to pull free, Closed wireline rams bled off lubricator. 6/30/04 Called Town, discussed situation decided to mix and pump kill weight fluid before attempting to retrieve EL. Lined up Weaver Brothers, Schlumberger, and Baroid. Had Peak personnel to deliver 8.5-ppg lease fluid to site. Spotted pumping unit and mixing tame Unloaded 65-bbls. lease fluid, mixed 45-bbls. patassium chloride to get 9-ppg kill weight fluid. R/U Pump Unit lines. Held JSA Finished mixing KCL fluid, primed up and pressure tested to 3,000-psi. Opened well Tubing 1,935-psi, zero casing, pumped 9-bbls. 9-ppg kill weight fluid at .5 bpm rate. Pressure went to 2,020-psi at 2-bbls. gradually increased to 3,000-psi at 9-bbls. pumped. Retested lines to 4,500-psi, Pumped 2.5-bbls. pressure went to 3,500-psi, waited 15-mins pressure fell to 3,200-psi. Pumped 1.5-bbl. Pressure 3,500-psi. Shutdown waited I-hour open well on low choke had water at surface. Unable to lubricate kill weight fluid in well successfully, very little gas at surface when bleeding down well slowly. Team decided to bleed down well and monitor for flow. Started bleeding pressure offwell with 3,1O0-psi bled down to to O-psi in 1.5- hours. Well appeared to be plugged off at formation. Monitoried well for flow, broke ,-. .--..., lubricator connection above wireline rams and pulled remaining EL out of well. Secured well. Rigged down EL, MIRU Pollard S/L Picked up 1.75" impression block pressure tested lubricator to 4,000-psi. Pressure up on well with gasllift gas to 2,200-psi. RIH wlImpression block to 5,710' slack off jarred down on TOF at 5,721' SLM (5,735' RKB). Pooh,found fluid level at 4,570' SLM. Finished Pooh had impression of EL rope socket. (No wire indication). Picked up 1-5/8" JDC Fishing tool, RIH to TOF 5,735' latched fish jarred several times with no success, slacked off reset oil jars picked up jarred on fish several times eventually came free, Pooh recovered EL BHA with perforating stem. Rigged down Pollard S/L. Turned well over to PTS to flow test. Tubing pressure 1,537- psi fluid level 4,451'. Open well to production at 1,000-psi Tbg. Pressure No Flow. Dropped Tubing pressure to 504-psi no flow. Dropped Tubing pressure to zero pressure, no flow Shut in well. 7/1/04 Well was secured for the night with zero psi on tubing, no feed in over night. Lined up Slick line, MIRU on well, pressure tested Lubricator to 2,000-psi. Held JSA, Picked up 1.75" bailer w/1.5" oil & spang jars RIH to 5734' SLM (5,748' RKB) set down beat down made 5' (5,753' RKB) 4' inside SPM. POOH recovered grey sand. Picked up 8' of 1.75" bailer w/l-1/2" oil & spang jars RIH to 5,753' RKB hit one good lick made 3' to 5,756' RKB picked up jarred down second time. Picked up stuck jarred couple times spang jars quit working. Picked up to 1,800 lbs. pull worked oil jars. Jarred 2-hours with no success. Picked up to 1,800-lbs. held pull. Called Town decision made to drop cutter, Picked up 1.25" Go devil w/l-3/16" fishing neck. Dropped cutter made cut wIno problems. POOH appeared to recovered all .125" slickline. Picked up 1-5/8" Global fishing tool wI 1. 8" Skirt RIH to 5,709' RKB latched cutter bar POOH recovered cutter. Secured well for the night, will need to swap out Boom trucks to cover both BHA's. 7/3/04 None Activity Time. Attended Sim-Ops meeting Held JSA w/crew. Rigged down Pollard SL off 42A-05 traveled to SRU 212-27 Rigged up same. Rigged up 3/16" Braided line PIU JDC pulling tool RIH latch TOF @ 5,736' RKB jarred on fish spang jars on fish started working. Continued to jar on fish with both oil jars going off for I-hour. POOH inspected pulling tools. RIH with JDC latched fish started jarring on fish picking up to 2,900-lbs. on indicator. Jarred I-hour fish came free. Pulled out of hole recovered 1-3/4" bailer full of formation sand. Laid down Braided line equipment, picked up 125" SL equipment, pressured up on well to 1,600-psi. Shutdown and secure well for the night. *Cameron inspected SRU 22-4 wellhead & Tubing Hanger (Cycled 4" 5-M Cameron Valves) valves seal on well test void to 5,000-psi for 15-minutes. Test Good *Inspected 42A-05 Hanger, Test void to 5,000-psi for 15-minutes tested good. 7/4/04 None Activity Time Checked pressure on the SRU 42 A-05 4,425-psi Tubing, 1,700-psi Casing. Sim-Ops Mtg. with Field Personnel, discuss remaining clean up on different well ."--'" ~ pads with Bruce. Picked up 1.5" Pump Bailer, Pressure tested lubricator to 2,500-psi Opened well with 1,600-psi. RIH tagged sand @ 5754' RKB. Made 6 trips with 1-1/2" Bailer recovering sand, water, and some pieces of gun debris total of3' (5,760'). Picked up 8' 1-3/4" Pump bailer RIH to 5,760' worked for 30-minutes pulled out of hole had recovered gun debris, no fluid are sand. RIH w/same to 5,760' worked 10 times POOH recovered sand and water bailer half full. RIH w/same to 5,761' drove down 6-times pumped 8-times POOH Tight spots between 4,800',5,100'. Bailer 1/2 water and some perf debris. Made 3-trips with 1-3/4" bailer. Secured well. SI tubing 1,440-psi. Note: SRU 42A-05 Tubing 4,475-psi, Casing 1,800-psi bled casing down to 500-psi took 45- minutes at a good rate. The Casing had pressured up from 760-psi to 1,800-psi in 38- hours, 27.36-psi per hour. Tubing holding same. 7/5/04 None Activity Time. Sim-Ops mtg. with Plant personnel, Held JSA with SL. Picked up 1-3/4" Pump Bailer RIH to 5,759' work 15-mintues POOH Bailer had no fluid and very little debris. Tagged 2' high than previous run. Picked up 1-3/4" Magnet w/sleeve to 5,759'. Pooh had I-ounce of debris. Ran in hole w/same to 5,759' POOH recovery about the same. RIH w/8' 1-3/4" pump bailer w/ball made I' worked 15-minutes POOH bailer had same as 1 st magnet run plus bailer 1/2 full fluid. RIH w/same to 5,761' worked for 15-minutes POOH Bailer had very little debris. RIH w/pump bailer with no flapper and muleshoe to try rearrange top of obstruction jarred down 15-minutes pulled out of hole had 3 large pieces of gun debris. RIH w/1-3/4" Magnet to 5,761' tagged POOH very little Debris. Picked up 1-3/4" Hydrostatic Bailer to 5,757' jarred down 8 times POOH bailer had little solids and fluid. Rigged down SL and Secured well with 1,640-psi recovered 2" of debris inside I-pint sample bottle. 7/6/04 None Activity Time. Sim-Ops mtg. with Plant personnel, Held JSA with SL. Slip and cut 75' .125" wire rigged up on well Opened well with 1,700-psi. RIH w/wire grab spear, to 5,760' worked for 15-minutes final hit had 300-lbs over pull oil jars went off came free. POOH (Bottom prong on spear bent down). RIH w/Hydrostatic bailer to 5,760', hit down 4 times, bailer went off and sucked down 1.5'. Had to jar free Released tool left Hydrostatic bailer in hole. RIH w/2" JD to 5,751' top of bailer latch fish POOH bailer empty. RIH w/8' X 1-1/2" Pump Bailer to 5,762' pumped several times POOH bailer had more debris than previous runs. RIH w/same to 5,761' 8-pumps POOH had about the same. RIH w/same to 5,761' Work 25 pumps POOH had same amount of debris but also clear water in sample. RIH w/junk basket instead of ball bottom. Run to 5,762' worked tapping down and pumping 25 times POOH bailer had some small pieces of metal, and a large Screw from strip gun. RIH w/same to 5,761' pumped 5 times POOH bailer empty. Layed down lubricator Secured well w/1 ,320-psi. ') Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand<Cv.unocal.com ) \ UNOCAL(i> "-Alaska Debra A Oudean G & G Technician August 23, 2004 To: Helen Warman . 333 W 7th Ave, Suite 100 Anchorage, AK 99501-3539 AOGCC From: Debra Oudean 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Alaska DATA TRANSMITTAL. SRU SCU Transmitting as follows: .:.WELL . I'rJ 1, SRU 212-27 .ICOMPLETION RECORD 1.56 TUBING PUNCHER ð SRU 212-27 COMPLETION RECORD 1.69 SPIRAL ENERJET ~.I POWERJET 7SPF ¡ SRU 212-27 GAMMA RAY / COLLAR LOG 2 3/8 CIBP / 2 3/8 CEMENT 5 INCH RETAINER 1.56 TUBING PUNCHER ~RA~Es~~~~t.,'~¿~~~~L, B.LIN,~ FILM CD 15 INCH 6/16/200417550-10065 I' 10 51NCH 6/13/20046400-10177 1 0 15 INCH I 6/20/200415832-5842 I ¡5INCH I 6/13/200416400-10177 I .15 INCH I 6/23/200414900-5820 I 5 INCH 6/29/2004 5770-5788 111f11 111[J] 11 1/11 1 1 1 6/22/2004 4900-5820 1 1 RECEIVED SCANNED NOV (] :3 2004 AUG 2 :~~ 2Ø04 ArdSka Oil & Gas Cons. Comrni88tor1 And10rage ei V?;Jt;;;: copy of Ih:a::nsmitt~;~ ;¡t1!28 .. =. Abandon ~ Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 14.32' RKB 1. Type of Request: 8. Property Designation: Swanson River Field 11. Total Depth MD (ft): 10,965' Total Depth TVD (ft): 10,965' Length Casing Structural Conductor 32' 3,455' Surface Intermediate Production Liner ~ STATE OF ALASKA ,~ ALAS, . Oil AND GAS CONSERVATION COMMk ~,ON APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class'/ Development 0 Stratigraphic 0 I - I Opr "/7/?-- Suspend U Repairwell 0 Pull Tubing 0 Perforate ~ Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Annular Dispos. U Other 0 V-i (7 ,f-- Exploratory 0 Service 0 0 .61-G65~ t -(Pi - 0 3 ) 6. API Numbe/ 50-133-10153-00 9. Well Name and Number: SRU 212-27 / 10. Field/Pools(s): Swanson River, Tyo~ PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 6,024' 6,024 Plugs (measured): 6,024' Junk (measured): 6,024' Size MD TVD 22" 32' 32' 9-5/8" 3,455' 3,455' Burst Collapse 3,950 psi 2,570 psi Perforation Depth MD (ft): 2,890 to 7,635' Packers and SSSV Type: 7,800' 5-1/2" Perforation Depth TVD (ft): 2,890 to 7,635' Baker D packer 7,800' 7,740 psi 6,260 psi Tubing Grade: Tubing MD (ft): N-80 10,611' 7,601' 7,800' Tubing Size: 2-3/8" Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal l:d Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager Signature / ¡:; Phc;>ne 907-276-7600 Date Y' . , COMMISSION USE ONLY 16. Verbal Approval: 13. Well Class after proposed work: 0 0 / 0 Exploratory Development Service / 15. Well Status after proposed work: 7/3/2004 Oil 0 Gas 0 / Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Date: Contact Steve Tyler 907-263-7649 6/1/2004 Conditions of approval: Notify Commission so that a representative may witness SUndryNUmber: 3O4.:Å }o V Plug Integrity 0 BOP Test 0 Other: - 4-°4- Form 10-403 Revised 12/2003 Mechanical Integrity Test 0 Location Clearance 0 RECEIVED JUN 022004 Alaska Oil & Gas Cons. Commission Anchorage - .' ~ 1".(,;' r>,r;:;\ \~~?;\ jw\,è'å \,y¡¡~,.- ~ G)t'~h )tJ~ 01 t) II\. ì\~. BY ORDER OF t. h- / COMMISSIONER THE COMMISSION Date:" r/ /)'1 INSTRUCTIONS ON REVERSE 0 R I r, I N A I Submit in Duplicate \. .~ ~ ~ Workover Summary SRU 212-27 . MIRU Slickline. RIH gauge/bush tbg. . MIT tbg and csg. . MIRU Eline. RIH set retainer @ 5820'. RD Eline. . MIRU CT unit and cementers. NU BOPE. Test same. PUMU polish stringer. . RIH stab into retainer @ 5820'. Establish injection rate & pressure. Mix/p~l~ of cement below retainer. PD. CBU. POOH. UU~L . RU Eline. RIH punch tbg @ 5794' w/ 4' x 1.56" gun. RIH set retainer @ 5790' .RD. / . RU CT. PUMU polish stringer. RIH stab into retainer @ 5790'. Establish circulation rate & pressure down~a d out tbg x csg annuli. . Mix/pump/circulate 5 Is of cement below retainer and up tbg x csg annuli (this / will bring TOe to 5 ' in csg x tbg annuli). PD. CBD. POOH. RD CT. . MIRU slickline. RIH w/ memory temp survey to 5750'. POOH. Review data to depict TOC. . WOC for 72 hrs. / . RU Eline. RIH perfsqz hole @ 5737' to 5747'. POOH. RD . RU CT. MU w/ cmt nozzle on CT. RIH to 5730'. Establish injection rate and pressure.~ . Mix/spot 00 ~ of cmt to end of CT. Sqz cmt into sqz perfs. While choking returns, RI to 579 -lfculate tbg clean. CBU. POOH. WOC. . Pressure test sqz perfs to 3000 psi. . RDCT. ~.- . RU Eline RIH w/ 1.56" PowerSpiral gun. Perforate 56-9c sand ~;~ to 761'. / POOH. RD. ~ w--f.ÀL \~C~~' . Turn well over to production. UNOCAL L ~ ~ :5 . ð :- Q 3 TD= 7,800' PBTD= 6,024' Straight Hole Size 22" 9-5/8" 5- ]f2" Tubing 2-3/8" Item SRU 212-27 Current Schematic 08-23-021 Swanson River Field Soldotna Creek Unit Wen SRU 212-27 Original Drill & Completed Last WO CURRENT COMPLETIONI 1 2 3 4 5 6 7 8 Type Conductor SurfCsg Liner Casing & Tubing Wt Grade ID Top Btm Hole Cmt Cmt Top Surf 32' Yes Surf. 40 J-55 Surf 3455' Sx 17 N-80 Surf 7800' sx I 4.6 I N-80 I 1.995 I 10,474' I 10,611' Top 14.32' 2508' 5749' 5799' 5844' 5878' 6024 6056 6800 7544 7577 7582 7589 7601 7612 ID 1.901 1.901 1.978 1.875 4.25 4.25 4.656 2.90 Jewelry OD Description Tubing Hanger, 2-3/8" wi Cameron H BPV pro tile Macco 2-3/8" SMO-ICI Chemical loj Mandrel Macco 2-3/8" O-SO GLM wi I" dummy Packer, Retrievable, Baker Mod. "FH" 2-3/8" x 5-1/2", 17# Nipple, 'X', 1.875" 1.0. EaT BOT Shear Sub Plug set @ 6050', TOC @ 6024' Plug set@ 6176', TOC @6146', Fill @6056' Tubing Cut, 10/27/96 Cameo MM mandrel with CEV Tubing cut, 10/25/96 2-3/8" Baker bridge plug, 10/25/96 Camco 0 nipple Baker 0 packer EaT FISH 15914' 11,8" Down Hole Choke @ TOF I 7544' 27' Strip Gun Mar-04 Feb-04 Feb-97 1961 1961 Date Tyonek LTyonek Zone 59-2 61-3 PERFORATION HISTORY (DIL) Interval Accum. Top Btm Amt spf 2,890' 2,891' l' 4 3,018' 3,028' 10' 4 3,152' 3,162' 10' 4 3,342' 3,352' 10' 4 5,914' 5,924' 10' 4 6,076' 6,090' 14' 4 6,104' 6,108' 4' 6,237' 6,254' 17' 6,527' 6,537' 10' 7,620' 7,621' I' 7,625' 7,635' 10' 4 5 4 Comments Sqz'd '61 Sqz'd '61 Sqz'd '61 Sqz'd '61 Produced Gas P&A'd P&A'd P&A'd P&A'd WSO sqz'd '61 Aband '96 5/2712004 SL T UNOCAL8 API# 50~133~lO153~OO RKB =14,32' L ~ ~ :5 . ð :- Q ~ §t u 0 ,.. ¡¡¡ u TD= 7,800' PBTD= 6,024' Straight Hole SRU 212-27 Proposed Schematic 05-041 Size T~pe 22" Conductor 9-5/8" SurfCsg 5- ]f2" Liner Tubing 2-3/8" Item 1 2 3 4 5 6 7 8 A. B. Swanson River Field Soldotna Creek Unit Wen SRU 212-27 Original Drill & Completed Last WO C<ising Wt Grade ID & Tubing Top Btm Hole Surf 32' Surf 3455' Surf 7800' Cmt Yes Sx Cmt Top Surf. 40 17 J-55 N-80 sx I 4.6 I N-80 I 1.995 I 10,474' I 10,611' Top 14.32' 2508' 5749' 5799' 5844' 5878' Jewelry Description Tubing Hanger, 2-3/8" wi Cameron H BPY profile Macco 2-3/8" SMO-IC1 Chemical1nj Mandrel Macco 2-3/8" D-SO GLM wi I" dummy. Packer, Retrievable, Baker Mod. "FH" 2-3/8" x 5-1/2", 17# Nipple, 'X', 1.875" I.D. EaT BOT Shear Sub ID OD 1.901 4.25 1.901 4.25 1.978 4.656 1.875 2.90 6024 6056 Plug set@ 6050', TOC @ 6024' Plug set@6176', TOC@6146', Fill@6056' 6800 7544 7577 7582 7589 760] 7612 Tubing Cut, 10/27/96 Camco MM mandrel with CEV Tubing cut, ] 0/25/96 2-318" Baker bridge plug, 10/25/96 Cameo D nipple Baker D packer EaT Retainer Cement Retainer FISH 15914' 11.8" Down Hole Choke @ TOF I 7544' 27' Strip Gun Date Marc04 Feb-04 Feb-97 1961 1961 Zone PERFORATION HISTORY (DIL) Interval Accum. Top Btm Amt spf 2,890' 2,891' l' 4 3,018' 3,028' 10' 4 3,152' 3,162' 10' 4 3,342' 3,352' 10' 4 5,914' 5,924' 10' 4 6,076' 6,Q90' 14' 4 6,104' 6,108' 4' 6,237' 6,254' 17' 6,527' 6,537' 10' 7,620' 7,621' l' 7,625' 7,635' 10' 5,794' 5,798' 4' 5,752' 5,761' 9' 5,747' 10' Comments Sqz'd '61 Sqz'd '61 Sqz'd '61 Sqz'd '61 Produced Gas P&A'd P&A'd P&A'd P&A'd WSO sqz'd '61 Aband '96 PROPOSED PROPOSED PROPOSED 59-2 61c3 Tyonek 4 5 4 4 6 4 LTyonek Tbg Punch 56-9c 5/27/2004 SL T Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL October 3, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Cammy Taylor, Commissioner Re: Swanson River Form 10-404 SRU 212-27 Dear Commissioner Taylor: Enclosed for your review is the Report of Sundry Well Operations for the coil tubing clean out performed on Well SRU 212-27. The operations performed for this well are outlined per the attached Well Daily Summary. If there are any questions, please contact Jim Mosley at 263-7679. ey Senior Advising Drilling Engineer RECEIVED OCT 0 7 2002 Alaska Oil & Gas Cons. Commission Anchorage STATE oF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: x Perforate: Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unoin Oil Company of California (UNOCAL) Development: x 14 feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519-6247 Service: Swanson River Unit 4. Location of well at.surface Conductor #21 8. Well number 1850' FNL & 1500' FWL of Sec. 27, T8N, R9W, SBM SRU 212-27 At top of productive interval 9. Permit number/approval number Same 161-033 At effective depth 10. APl number Same 50- 133-10153-00 At total depth 11. Field/Pool Same Swanson River/'l'yonek 12. Present well condition summary Total depth: measured 7800' feet Plugs (measured) true vertical 7800' feet Effective depth: measured 7750' feet Junk (measured) true vertical 7750' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 22" Surface 3455' 9-5/8" 1620 sx 32' 32' Intermediate 3455' 3455' Production 7800' 5-1/2" 1100 sx Liner 7800' 7800' Perforation depth: measured = true vertical 7625'-7635' (abandoned in 1997), 6527'-6537' (abandoned in 2001 ), 6237'-6254' (abandoned in 2001) 6104'-6108' Tyonek'61-3 (abandoned 2002), 6076'-6090' Tyonek 61-3 (abandoned 2002) , 5914'-5924' Tyonek 59-2 Tubing (size, grade, and measured depth) 2-3/8", 4.6~, N-80 at 7612' Packers and SSSV (tyPe and measured depth) POSlSET plug at 6176' with 30' cement on top POSISET plu~ at 6050' with 25' cement on top 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes Used and final pressure 14. Representative Daily Averaoe Production or Iniection Data - N/A OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: x R" Fr) Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: OCT 0 7 2002 Signe Jim Mosle¥ Title: Drilling Engineer Date: Form 10-404 Rev 15/88 SUBMIT IN DUPLICATE SRU 212-27 Well Daily Summary Unocal Alaska Drilling Daily Summary Report SRU 212-27 Well 8117102 to 8~22~02 8/17/02 PJU DS coil tubing unit. M/U connector and pulled test to 9500 lbs. Mixed 100 bbls 9% KCL water. Tested BOPS. Opened well with SITP=2400 psi. GIH circulating at 1/2 bpm, holding constant BHP. Tagged first bridge at 21'. Washed thru bridge, continued GIH to 87', had difficulty overcoming backpressure without buckling coil. POOH for motor. P/U Baker PDM motor and 1.77"OD mill. GIH, still had trouble getting down due to high well pressure. Began letting well flow and washed thru bridge at 93'. Continued GIH holding proper constant BHP. At 1200' began losing returns. Continued GIH to 1335', but became unable to control backpressure with choke due to losing returns. At times had no returns, at others had double amount pumped. Lost 35 bbl to well. 8/18/02 POOH to 656'. Observed well with SITP =450 psi. Bled 4 bbl, SITP rose to 925 psi. Finished POOH and L/D motor. Secured well. Let well fluids stabilize... P/u injector and wash nozzle. Pressure tested riser to 4000 psi. Opened well. SITP=1300 psi. GIH to 5800', circulated at 1/4 to 3/4 BPM, maintained constant BHP. Got returns at 25 to 75%. Continued circulating, letting gas out until well dead and returns 70-75%. GIH, tag at 6000' and begin washing sand at 1.5 BPM, 3200 psi. Full open choke. 75% returns. Washed to 6056' CTM. Stopped dead, could not wash further. P/U to EOT and waited 1 hour. GIH and retagged at same 6056'. With Coil at 6056', displaced well with Nitrogen, maintaining constant BHP. POOH with coil.maintaining 2300 psi. On well. Final SITP=2300 psi. Secured well. R/D coil unit and SDFN. 8/19/02 R/D Dowell CT unit and moved to P&S yard. Vacuumed tanks and properly dispose of fluids. Schlumberger unit and equipment on location. M/U lubricator and prepared forjob. SDFN. 8/20/02 R/U lubricator and grease tubes and teSted to 4000 psi. P/U posiSet plug, opened well with 2350 psi SITP, GIH and set same at 6050' WLM. GIH with Dump Bailer #1, tagged plug at 6050' and dumped 3.5 gal cement on top. GIH with Dump Bailer #2, tool fired but screw did not shear and no cement dumped. GIH with Dump Bailer #3, dumped additional 3.5 gal cement. GIH with Dump Bailer ~,~. 8/21/02 Continue to GIH with Dump Bailer #.4. Dumped 3.5 gal cement on top of plug for a total of 10.5 gal. ETOC 6039.2'. Made DB runs #5 and 6, placing additional 7 gal of cement on top of plug. Made DB runs #7 and 8; misruns no cement dumped. Actuator weight bar inside DB#8 had a broken stud, sent for repairs. ETOC 6032.1'.. 8~22~02 P/U lubricator and M/U Dump Bailer tool. Shortened to 30' holding 2.5 gallons. GIH and made DB runs #9, 10, and 11, dumping an additional 7.5 gallons of cement for a total of 25 gallons cement. ETOC 6024.4' L OCRL Swanson River Fidd Well # SRU 212-27 8/23/02 Actual RKB to TBG Head = 14.32' Tree connection: TC-3 Uni-bolt 532* TOC 5800' CBL 10/2/6l 14 13 Top of Tbg @ 680{t' TOC 7135" -annulus 7135' -tbg Top of FEll 7609' 10/1/88 7 Fish = 27' of perf gun 8 9 ti 12 PBTD = 7750' TD = 7800' MAX HOLE ANGLE - Straight CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 32' %5/8" 40 J-55 Surf 3455' 5-1/2" t7 N-80 Buttress Surf 7800' NO. 1 2 Tubing String: 2-3/8" 4.6 N-80 Buttress Surf 5878' with 3/8" SS methanol injection lineSurf 2508' JEWELRY DE'FAlL Depth Item 7 8 9 9a 10 11 12 13 14 14.32 2508 5748 5799 5844 5878 2-3/8" Tbg hgr w/Cameron H BPV profile Macco 2-3/8" SMO-1 C1 Chem lnj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO giro w/1" dummy Baker "FIt Retr. pkr, 2-3/8" x 5-1/2" 17# X nipple Tubing tail (shear out sub) 6800 Tubing Cut, 10/27/96 7544 Camco MM mandrel with CEV 7577 Tubing cut, 10/25/96 7582 2-3/8" Baker bridge plug, 10/25/96 7589 Camco D nipple 7601 Baker D packer 7612 Bottom of tubing tail 6056 Plug at 6176', TOC at 6146', Fill at 6056' 6024 Plug at 6050', TOC at 6024' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 5914 5924 6076 6090 6104 6108 6237 6254 6527 6537 7620 7620 7625 7635 59-2 Tyonek 4 3~02 Prod Gas 18 hfs 61-3 Tyonek 4 2-01 Abandoned Abandoned Abandoned Tyonek 4 2/12/97 Abandoned 5 1961 WSO sqzd '6t I, Tyonek 4 1961 Prop abdn '96 2890 2890 surf casing 4 Sqzd '61 3018 3028 surf casing 4 Sqzd '61 3152 3162 surf casing 4 Sqzd '6 I 3342 3352 surf casing 4 Sqzd '61 SRU 212-27 Schematic 082302 REVISED: 10/3/2002 JWS DRAWN BY: TAB August 15, 2002 UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501 Attn' Commissioner Cammy Taylor Subject: Swanson River Unit Well #212-27 APl #50-133-10153-00 Form 10-403, Proposal to Abandon U. Tyonek perforation below 6076'. Dear CommissiOner Taylor: Unocal proposes to abandon Upper Tyonek perforations in Swanson River Unit Well # 212-27 and isolate the 59-2 Upper Tyonek gas interval. This well is currently shut-in due to sand production from the 61-3 Tyonek interval The proposed work will require abandoning the existing perforations below 6076' by placing a Posiset packer at 6060', then dump bailing 25' of cement on top. Attached in triplicate are the 10-403 form with operations program and schematics of the existing wellbore, and the proposed abandonment. Estimated start date is August 17th, 2002 so your timely consideration of this proposal would be appreciated. Please direct any questions to Jim Mosley at 907-263-7679. Sincerely, Jim Mosley e 27AOGCOV.DOC ORiOI AL ! 8/15/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: x Time extension: Stimulatei Change approved program: Pull tubing: Variance: Perforate: Other: PlugBack 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 14 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Swanson River Unit Anchorage, AK 99519-6247~, Service: 4. Location of well at surface ~/' ~ v/' 8. Well number 1850' FNL & 1500' FWL of Sec. 27, T8N, R9W, SBM SRU 212-27 At top of productive interval 9. Permit number Same ~'~,//- ~:~ At effective depth 10. APl number Same 50- 133-10153-00 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary v,~ RECEIVED Total depth: measured 7800 feet Plugs (measured) 6176' with cement t true vertical 7800 ~ feet Effective depth: measured 7750' feet Junk (measured) AUG true vertical 7750' feet Casing Length Size Cemented Measured depth Tru~~pth Structural Conductor 32' 22" 32' 32' Su trace 3455' 9-5/8" 1620 sx 3455' 3455' Intermediate Production 7800' 5-1/2" 1100 sx 7800' 7800' Liner Perforation depth: MD = TVD 7625'-7635' (Abandoned in 1997), 6527'-6537' (Abandoned in 2001), 6237'-6254' (Abandoned in 2001) 6104'-6108' Tynonk 61-3 (To Be Abandoned), 6076'-6090' Tynonk 61-3 (To Be Abandoned), 5914'-5924' Tyonek 59-2 To Remain Tubing (size, grade, and measured depth) 2-3/8", 4.6#, N-80 at 7612" Packers and SSSV (type and measured depth) Posiset plug at 6176' with 30' cement on top. 13. Attachments Descripti°n summary of proposal: x Detailed operations program: x BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 8/17/2002 16. If proposal well v~.~lly approved: Oil: Gas: x Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: r~ /'~}~~,~F® Mosley Title: Drilling Engineer Date: 8-15-2002 ~J ~J FOR COMMISSION USE ONLY so represent 've may witness '~ Conditions of approval: Notify Commission ..... ~ t.~,~~:~,~,'~'~ -~-~ Approval No. Plug integrity, mu~' lest ~ Location clearance] Mechanical Integrity Test ~ Subsequent form required 10- Cammy C)8ch,qli Tayl0r .~.,~/~ Approved by order of the Commissioner Commissioner Date ~-' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL UDjec'uve: AFE # 156364-O-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 I Ill I I I I IIllll Clean Fill and Possible Hydrates From 2-3/8" Production Tubing Special Concerns: Ensure proper field communications - Telephone and radio History: SRU 212-27 gas well was originally perforated in the Lower Tyonek (7625-7635) and placed on production in 1/1/61. Well had hydrate problems so heater string was installed in '63. Well was shut in 6/66 due to high water production. Well was brought back on 5/89 - shut in 12/89 due to high water production. In 9/11/97, well was perforated in the Upper Tyonek (6237 - 6243). Over the next 4 yrs, the well was perforated twice more. On 2/24/01, a Posiset plug was set at 6210' followed by perfs 6108-6076. The well sanded up and bridges were bailed out with Slickline. Fill was found above the perfs and a decision to add perfs was made. On 03/09/02, the well was perforated 5914-5924. It flowed for 18 hrs and then froze off likely due to hydrates. Slickline was used to clean out hydrates to 400'. The next morning, sand/clay was found at the surface. Skickline was unable to get sufficient weight at the surface to cleanout the fill. Current Status: Well is currently shut in. Perforations are at 5914-5924, 6076-6090, and 6104-6108. RKB: 14' above ground level Estimated Pore Pressure: 2754 psi Top of cement 5800' based on 1961 Bond Log Proposal: Clean out fill and hydrates to approximately 6146'. Jet well out holding back pressure with Nitrogen. Set POSISET plug on e-line above the perforations at 6076 holding pressure on well to prevent flow. Set plug at approximately 6060' and dump bail cement for 25 feet holding pressure on well to prevent movement of fluids or gas. Bleed well off and establish flow. Return well to production. Wellhead Status: Steve Lawrence to inspect and test wellhead and grease valves prior to job SRU 212-27 CTU CLEANOUT AND BP SETYING REV2 Page 1 of 6 7/30/02 UNOCAL AFE # 156364-O-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 Equipment Requirements: Company Contact Equipment/Service Provided Contact Number Baker Oil Tools Bob Harris Bottom Hole Assembly 273-5100 Dowell/Schlumberger Tab Keys Coil Tubing unit and associated equipment. 776-8155 Paul Perius 7800 Slickline Work (coordinate w/Unocal WL Pollard Wireline Steve Barrow Foreman #6814) 283-7006 Steve Lawrence Wellhead service work and connections 6725 Unocal Jim Mosley Drilling Engineering and project support 7679 Gary Orr Reservoir engineer 7768 I Pre-Well Work 1. Wellhead technician on location to test and qualify tbg and csg hangers, void area, tree, tree valves 2. Test and qualify any other production equipment valves to be used during CT operation 3. Obtain CTU layout drawing from Schlumberger 4. Complete CT checklist 5. Contact downhole motor source and have available on location Note: Have extra ring gaskets and flange bolts on site. SEE ATTACHED WELLHEAD DIAGRAM FOR PARTICULARS ON WELLHEAD AND TREE. SRU 212-27 CTU CLEANOUT AND BP SETFING REV2 Page 2 of 6 7/30/02 UNOCAL AFE # 156364-0-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 SCU 212-27 Tree Cap 2 1/16" 5M B-15-A WI2 3/8" EUE Lift Swab 2 1/16" 5M Grey Valve HWO. Tee 2 1/16" 5M All LM, UM, Wing, WKM 2 1/16" 5M, M/M, HWO, T-21 Tubing Hanger, Schaffer AJ-O 7 1/16" x 2 3/8" BTC Top & Btm. & CL Complete with 2" Type "H" BPV Profile Tubing Spool, Schaffer 55-L1, 11" 3M X 7 1/16" 5M WI2-2 1/16" 5M SO Casing Head, Shaffer, 11" 3M X 9 5/8" SOW W/2-2" LPO Tubing Head Adapter, Schaffer 7 1/16" 5M x 2 1116" 5M W/CL Casing Hanger, Schaffer KS With Pack off 11" x 5 1/2" 5 1/2" 2 SRU 212-27 CTU CLEANOUT AND BP SETYING REV2 Page 3 of 6 7/30/02 UNOCAL AFE # 156364-0-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 II Rig Up and Testinq of CTU and Surface Equipment Hold safety meeting with all involved personnel. Specifically discuss risk associated with working under live well conditions including downhole trapped gas. Discuss crew member responsibilities particularly with respect to operating Xmas tree valves and communication guidelines. 1. MI and spot all required 1-1/2" CTU equipment and pump. Ensure that the coil and coil unit has been thoroughly checked out prior to delivery to SRU. Drift and pump through the coil prior to going in the hole with the coil. Ensure coil is circulated clean. 2. Spot Crane and all auxiliary equipment as per pad layout drawing. 3. RU choke manifold, Baker tank with surge vessel, filter and associated equipment. 4. Ensure master and swab valves closed, bleed pressure from above swab valve 5. ND wellhead equipment above swab valve. Nipple up Coiled Tubing Unit Connector to the Swab Valve. 6. NU CTU pump-in sub, Quad BOPs, crossover to CT injector head 7. Install & support BOPs to prevent excessive movement. Secure BOPE and Pick up Injector Head. III Coiled Tubinq Operations Note: 1. 2. Shear rams have been tested and do not require field shear; verified test has been done by Schlumberger. Run CT down to expose the end of CT MU coiled tbg connector, dual check valves and 1.60" OD bullnose downjet nozzle. Make 5000 # pull test or at least a 4000 psi pump rate above master valve prior to going in hole. NOTE: Utilize Slimhole BHA Assembly tools due to the OD of the connectors a roll on connector will be used. 3. Pull BHA up to bottom of injector head. 4. Set depth counter with bottom of CT at bottom of injector. Adjust for RKB of 14 feet and proceed. 5. Make up injector head and components onto BOPE. Fill coil with 9% KCL fluid and circulate coil clean above master valve taking returns to the tank. 6. Pressure test all components above the Swab Valve including the pump, choke, lines and valves to 4000 psi and to 250 psi. Fill out UNOCAL PREJOB CHECKLIST FOR COILED TUBING BOPE AND RIG UP. 7. Equalize pressure. 8. Open swab and master valves. 9. Start CT pump and commence circulating 9% KCI into CT, and out the CT/2-3/8" annulus 10. Slowly RIH w/CT washing fill and bridges out of tubing and well head. Wash to depth of 6146'. Monitor returns at surface for rate as well as solids. Have a hand on the choke as intermittent bridging with pressure traps below bridges are expected. Maintain pressure on choke during cleanup to ensure controlled surface pressure (Possible high pressure gas trapped below hydrates) 11. If unable to wash through bridges, circulate bottoms up, POOH to pick up motor assembly. Motor assembly is assumed to be needed to drill through hydrates if jetting through hydrates is unsucessful. Do not plan to run motor to TD due to the tight tolerances and cost of the motor if we were to lose it. 12. Close swab valve 13. Bleed pressure above swab valve through choke to surface tanks 14. Remove injector 15. Lower CT and remove slimhole BHA. 16. Install MHA (motor head assembly) CT connector Dual check valves Circulating sub Hydraulic disconnect SRU 212-27 CTU CLEANOUT AND BP SETTING REV2 Page 4 of 6 7/30/02 UNOCAL AFE # 156364-O-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 18. Pressure test same to 4000 psi 19. Bleed off pressure 20. Install 1-11/16" PDM (positive displacement motor) and 1-3/4" to 1.80" mill. Note there is a 1.875 .... X" Nipple in the hole. 21. Pull BHA into lubricator 22. Zero counter 23. Install injector on well 24. Perform shell pressure test to 4000 psi. 25. Bleed pressure from above test 26. Open swab valve 27. Repeat cleanout process using PDM (positive displacement motor). Wash and drill with motor to a depth that indicates hydrates are gone (assume that the hydrates are 9one when running in hole is possible with the pump runnin9 at minimum rate or when a depth of 3000 feet is reached. POOH with motor while continuin9 to run pump at a slow rate. IF the well is making gas, trap sufficient pressure to prevent additional 9as entry. LD Motor assembly and pick up previous jettin9 assembly and ~IH as before. 28. Wash to desired depth (6146') and circulate hole clean. POOH with Coil pumping nitrogen to jet the well empty. Ensure that the choke is used to trap at least 2000 psi nitrogen pressure on the well when the tubing is out of the hole. Consider making a tag with the Coil tubing after circulating out and pulling up hole to confirm the depth of fill is below the desired plug settin9 depth. 29. Close Master Valve and bleed off. 28. ~D Schlumberger CTU and Demob Barriers while runninq CT: · Tested shear rams · Tested CT BOPs · Wellhead valves Coiled Tubinq Data: Tensile Strength: 80,000 lbs Min Yield (36,000 lbs safe pull when new) OD: 1.5" ID: 1.232" with seam Wall 0.109 Wt/Ft 1.910 Ib/ft Internal Capacity: 2574 psi pore pressure is equivalent to) Coiled Tubing x 2-3/8" tubing annular capacity: 1.661 bbls/1000' Ensure proper drawings are recorded for all downhole equipment and are kept on file (lengths, OD and ID) Double check ball size for circ sub and disconnect Follow all Unocal fluid handling and transfer policies and procedures with particular emphasis on proper disposal Contact Jim Mosley for operational problems: 263-7679 or cell # 351-8639 Contact Nick Scales for safety and environmental issues: 263-7654 or cell # 223-6844 III E-LINE PROCEDURE SRU 212-27 CTU CLEANOUT AND BP SETI'ING REV2 Page 5 of 6 7/30/02 UNOCAL AFE # 156364-0-00 Swanson River Well # SRU 212-27 Coiled Tubing Cleanout Rev 2 1. MIRU Schlumberger while CTU is rigging down. 2. MU CCL, e-line jars, weight bars and MPBT BHA. Stab to the well. 3. RIH, tie in to Schlumberger GR/CCL run previously. 4. Position top of plug at - 6060'. Flag line for bailer operations. 5. Set MPBT at 6060' 6. POOH. 7. MU Dump Bail BHA and stab to the well. 8. RIH with bailer to Top of Plug. Dump cement above the plug. POOH. 9. Repeat runs, if necessary, for a total plug length of 25'. 10. Allow plug to cure for a minimum of 24 hours. 11. RD and release E-line. Note: Do not bleed the pressure off of the tubing at this time. It is important to allow the well to remain balanced so that differential pressure does not fail the plug. 12. Turn well over to production. Ensure that well is not flowed before establishing methanol injection. SRU 212-27 CTU CLEANOUT AND BP SETTING REV2 Page 6 of 6 7/30/02 UNOCAL ) DV @ 1532' RKB to TBG Head = 14.32' Tree connection: TC-3 Uni-bolt DV @ 4430' TOC @ 5800' CBL 10/2/61 ?erfs: ~914-5924 5076-6090 5104-6108 13 Top of Tbg @ 6800' TOC 7135' -annulus 7135' -tbg 7 Fish = 27' of perf gun 8 9 Top of Fill 7609' 10/1/88 11 12 PBTD = 7750' TD = 7800' MAX HOLE ANGLE = Straight SRU 212-27 112496Completion Schematic.DOC SIZE WT Swanson River Field Well # SRU 212-27 Actual Completion, 11/24/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" Surf 32' 9-5/8" 40 J-55 Surf 3455' 5-1/2" 17 N-80 Buttress Surf 7800' Tubing String: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injection lineSurf JEWELRY DETAIL NO. Depth Item 5878' 2508' 1 14.32 2 2508 3 5748 4 5799 5 5844 6 5878 2-3/8" Tbg hgr w/Cameron H BPV profile Macco 2-3/8" SMO- 1C 1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO glm w/l" dummy Baker "FH Retr. pkr, 2-3/8" x 5-1/2" 17# X nipple Tubing tail (shear out sub) 7 6800 8 7544 9 7577 9a 7582 10 7589 11 7601 12 7612 13 6146 Tubing Cut, 10/27/96 Camco MM mandrel with CEV Tubing cut, 10/25/96 2-3/8" Baker bridge plug, 10/25/96 Camco D nipple Baker D packer Bottom of tubing tail Plug at 6176', TOC at 6146' PERFORATION' DATA TOP BTM ZONE SPF DATE COMMENTS 5914 5924 59-2 Tyonek 6076 6090 61-3 Tyonek 6104 6108 61-3 Tyonek 6237 6254 62-5 Tyonek 6527 6537 Tyonek 7620 7620 7625 7635 L Tyonek 4 3-02 Prod gas 18 hrs 4 2-01 Low Perm 4 2-01 Low Perm 4 9-12-97 Abd 2-01 8 11-7-99 Abd 2-01 5 1961 WSO sqzd '61 4 1961 Prop abdn '96 2890 2890 surf casing 3018 3028 surf casing 3152 3162 surf casing 3342 3352 surf casing 4 Sqzd '61 4 Sqzd '61 4 Sqzd '61 4 Sqzd '61 REVISED: 8/15/2002 DRAWN BY: TAB UNOCAL ) DV @ 1532' RKB to TBG Head = 14.32' Tree connection: TC-3 Uni-bolt DV @ 4430' TOC @ 5800' CBL 10/2/61 SIZE WT Top of Tbg @ 6800' TOC 7135' -annulus 7135' -tbg Top of Fill 7609' 10/1/88 Swanson River Field Well # SRU 212-27 Proposed CT Cleanout PBTD = 7750' TD = 7800' MAX HOLE ANGLE = Straight SRU 212-27 Proposed 8-02 Schematic.DOC CASING AND TUBING DETAIL GRADE CONN TOP 22" Surf 9-5/8" 40 J-55 Surf 5-1/2" 17 N-80 Buttress Surf Tubing String: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injection lineSurf BOTTOM JEWELRY 'DETAIL NO. Depth Item 32' 3455' 7800' 1 14.32 2 2508 3 5748 4 5799 5 5844 6 5878 5878' 2508' 7 6800 Proposed 8 7544 Posiset Plug @6050' 9 7577 9a 7582 10 7589 11 7601 ......... 13 12 7612 13 6146 7 Fish = 27' of perf gun 8 9 11 12 2-3/8" Tbg hgr w/Cameron H BPV profile Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO glm w/l" dummy Baker "FH Rem pkr, 2-3/8" x 5-1/2" 17# X nipple Tubing tail (shear out sub) Tubing Cut, 10/27/96 Camco MM mandrel with CEV Tubing cut, 10/25/96 2-3/8" Baker bridge plug, 10/25/96 Camco D nipple Baker D packer Bottom of tubing tail Plug at 6176', TOC at 6146' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 5914 5924 6O76 6O90 6104 6108 59-2 Tyonek 4 3-02 Prod Gas 18 hrs 61-3 Tyonek 4 2-01 Low perm 6237 6254 6527 6537 Tyonek 4 2/12/97 7620 7620 5 1961 WSO sqzd '61 7625 7635 L Tyonek 4 1961 Prop abdn '96 2890 2890 surf casing 4 Sqzd '61 3018 3028 surf casing 4 Sqzd '61 3152 3162 surf casing 4 Sqzd '61 3342 3352 surf casing 4 Sqzd '61 REVISED: 8/15/2002 DRAWN BY: TAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL ) Alaska James R. Harrison Drilling Manager June 6,2002 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Attn: Mr. Tom Maunder Subject: Swanson River Unit Well SRU 212-27 APl No. 50-133-10153-01 10-404 Abandon bench 62-5 and perforate bench 61-3c Dear Mr. Maunder: Please find enclosed in duplicate Form 10-404 for the abandonment of bench 62-5 and perforation of bench 61-3c in well SRU 212-27. On 3/5/01 a Schlumberger PosiSet plug was set at 6176' with 30' of cement placed on top putting the top of cement at 6146'. The following intervals were then perforated: Bench Top Boffom Feet 61-3c 6,104 6,108 4 61-3c 6,076 6,090 14 Total: 18 If you have any questions, please contact Ralph Holman at 263-7838. Sincerel.~~/~__,~ eo eips //' Drilling Manager (acting) RECEIVED JUN 1 5 2002 ORIGINAL Alaska Oil & Gas Corm, Anchorage STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: X Perforate: X Pull tubing: Alter casing: Repair welt: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 14" KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Swanson River Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1850' FNL, 1500' FWL, Sec. 27, T8N, R9W, SM SRU 212-27 At top of productive interval 9'. Permit number/approval number Same 61-0033 At effective depth 10. APl number Same 50-133-10153-01 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary Total depth: measured 7800 feet Plugs (measured) 7135, 6146 true vertical 7800 feet Effective depth: measured 7750 feet Junk (measured) true vertical 7750 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 22" 32' 32' Surface 3455' 9-5/8" 1620 sx 3455' 3455' Intermediate Production 7800' 5-1/2" 1100 sx 7800' 7800' Liner Perforation depth: measured 6527-6537, 6237-6254, 6104-6108, 6076-6090 true vertical 6527-6537,6237-6254,6104-6108,6076-6090P E( EIVED Tubing (size, grade, and measured depth) 2-3/8", 4.6 Ib/ft, N-80 from surface to 5878' JUN 1 52002: Packers and SSSV (type and measured depth) Baker "FH" Retr. pkr. at 5799' Alaska 011 & 6as Cons. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 241 0 300 180 Subsequent to operation 0 130 0 80 600 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06¢¢15/88 ORIGINAL SUBMIT IN DUPLICATE S~ anso Yet Field Well # SRU 212-27 Actual Complefiom 1 1/24/96 RKB to TBG Head = 14.32' Tree connection: TC-3 Uni-bolt CASING AND TUBING DETA~IL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 32' 9-5/8" 40 J-55 Surf' 3455' 5-t/2" 17 N-80 Buttress Surf 7800' DY(fi24430* 3 4 6 TOC ((~ ~., 5800 CBL 10/2/61 ~ ~ ............. ] 6800' '1 '7 TOC 7135~ 7135' 'lop of Fill 7609' l(I/1/88 8 9 9a 10 1l 12 6076~6090 6104-6108 6237-6254 6527-6537 Fis]~ = 27~ of per£ gu~ PBTD= 7750' TD= 7800' MAX HOLE ANGLE = Straight 212-27 schematic 5-02.DOC Tubing String: 2-3/8" 4.6 N-80 Buttress Sm'f 5878' with 3/8" SS methanol injection lineSurf 2508' NO. 1 14.32 2 2508 7 8 9 9a 10 tl t2 13 JEWELRY DETAIL DeB~h Btem 5748 5799 5844 5878 2-3/8" Tbg hgr w/Cameron H BPV profile Macco 2-3/8" SMO-1C1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO ghn w/l" dummy Baker '~F~t Rem pkr, 2-3/8" x 5-I/2" t7# X nipple Tubing tail (shear out sub) 6800 Tubing Cut, 10/27/96 7544 Camco MM mandrel with CEV 7577 Tubing cut, 10/25/96 7582 2-3/8" Baker bridge plug, 10/25/96 7589 Camco D nipple 7601 Baker D packer 7612 Bottom of tubing tail 6146 Plug at 6176', TOC at 6146' PERFORA FION DATA TOP BTM ZONE SPF DATE COMMENTS 6076 6090 Tyonek 4 3/5/01 6t04 6108 Tyonek 4 3/5/01 6237 6254 Tyonek 4 9/12/97 6527 6537 Tyonek 4 1i/7/99 7620 7620 5 t961 WSO sqzd ~61 7625 7635 L Tyonek 4 1961 Prop abdn '96 2890 2890 surf casing 4 Sqzd '61 REVISED: 6/6/2002 DRAWN BY: TAB JUN-06-2002 THU 01:22 PM UNOORL NO, 90~283 7828 P, 02 Form 0t60-5 UNI' ,0 STATE8 (Juno 199o) DEPARTMENT OF THE INTER.IOR BUREAU OF LAND t~NAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budge[ Buret, No, 1004.0105 Expka~: March 31, 1~93 S, La~a Dea~n~llon ~d Ser~l No. Do not use this form for proposals to drill or to deepen or reentry to a different reservoir, Use "APPLICATION FOR PERMIT-" for such pmp. osals SUBMIT IN TRIPLICATE 1 .Type a! well _ Oil ~ Gas Other 2, Name of Operator Unocal ~, Address and Telephone Ne. P.O. Box 196247 Anchorage, Ala~a 99819-6247 4. Lo~atlon of Well (Footage, Se~,, T., R,, M., ar Survey Description) 12. G. If Indium, AIIoUeo or Tribe NAme 7, Ir Unil or GA, Agmomenl Designation b-"wansen River Unit 8, Wall N~rne and No, _ SRU 212-27 9, APl Well No. ~133-10t53-00 10, Reid ~nd Pool, ~ ~ploml~ Ar~ Swanson RNed m, ....... 11, coun~ m Pmbh, 8~[e ~?, ~ ......... CHECK APPROPRIATE BOX(S) TO INDICATE NATURE OF NOTICE, REPORT,, OR OT_HE_R_D_ _A_'r_A .... TYPE OF SUBMISSION TYPE OF ACTION I-'1 Nellie o! Inbanl r~ Aban~nment E] ReoomptetJon I~ Subsoqueni Report [] Plugging Back [~ casing Repair' [] Fired Abandonment Nolkm I--] AltarMg Caslng I'-! Other remove Iowqr packer r~ crumgo ol~ Plans r~ New Conslru~llon , r'l Non-Routine Fra~iurlng r~ Wale~ ~hut-OIT [~ Conversion lo InJe~l~ 1~ Dispose Water (Note: Report results of multiple eOmplelion on Well complo~n or FIo~ornpleUon Reperl and Log bra.) 13, Describe Proposed or complolod Operations (Clearly am, to all pmllnenl details, a~d give perfinonl dates, Including saline[ed dale ofetmling any proposoO work, 11 well is dlroello~slly drilled, give subsurface IDea[lore and measured and lrua Vol[cai deplhs [or all markers a~d L~nes perllnont lo Ihb work.) Abandon the 62.5 & 65-7 sands (turret reservoir pressure @ 931 psi) Set Schlumberger Through Tubing Poslse? Plug @ 6210' Dump ball 10' of cement on top of plug Wait 24 Hours, Pre.ute test plug to 1500 psi, ~,:,.-i'orate the 61-30 sand @ 6076-6090' & 6104'-61o8' with 1-11/16" Pivotgun RECEIVED JUN 0 6 ZOO[ 14. I her~dertl~y Ihs( ~ ~oragoii3~ls true an~ oorre~ (Tills sp~ao ~r Federal ~ State o~oe ~e) ~p roved by _~~/~~~ ~, O~ndlliana of approval, ff ~: _D~il!ine Manaaer Dale ~,~,//~. T~e 10 u.s.o. ,se=tlo~ 1001, makes It a crime Ior any pera~ I~l'lowl~gty and wlllful~ lo make ID any dep~rtmmrll or agon~/el the UnReal Stal~ nr~ la~e, ~--flfl=ue at Imudulertl e[alemer~la ar reprementstlona at~ ta any mattel' wilhlPI Itt lurlf~dl~lio~. JUN-06-2002 THU O1:22 PM ,U~O~L ~L~SK~ F~x ~0. 90~263 '7828 P, O1 Unocal Nasl<a 909 W. 9th Ave Anchorage, AK 99501 Mailing: P. O. Box 196247 Anchorage, Alaska 99519 Switchboard: (907) 276-7600 3~ Floor Fax: (907) 263-7828 Fax Message: UNOCd L Oompan~ Unocal Al~ka Fax: 907-263-7828 Phone: Pages including Cover Sheet Urgent [] For Review [] Please Comment [] Please Reply [] PIo~e Recyolo .Commnls: RECEIVED JUN 0 $ ZOOZ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager May 2, 2002 Alaska Oil Ex Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Tom Maunder Subject: Swanson River Unit Well SRU 212-27 APl No. 50-133-10153-01 10-404 Perforate Bench 62-5 Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the 62-5 bench in well SRU 212-27. The following intervals were perforated on 9/12/97: Bench Top Bottom 62-5 6,237 6,254 Feet 17 Total: 17 If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager · '--" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 14" KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Swanson River Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1850' FNL, 1500' FWL, Sec. 27, T8N, R9W, SM SRU 212-27 At top of productive interval 9. Permit number/approval number Same 61-0033 At effective depth 10. APl number Same 50-133-10153-01 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary Total depth: measured 7800 feet Plugs (measured) 7135 true vertical 7800 feet Effective depth: measured 7750 feet Junk (measured) true vertical 7750 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 22" 32' 32' Surface 3455' 9-5/8" 1620 sx 3455' 3455' Intermediate Production 7800' 5-1/2" 1100 sx 7800' 7800' Liner Perforation depth: measured 6237'-6254' true vertical 6237'-6254' Tubing (size, grade, and measured depth) 2-3/8", 4.6 Ib/ft, N-80 from surface to 5878' Packers and SSSV (type and measured depth) Baker "FH" Retr. pkr. at 5799' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 233 8 190 175 Subsequent to operation 0 993 0 550 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: . , ,. '.., i ~ / Daily Report of Well Operations: Oil: Gas: X Suspended: Servtce: -' 17. I hereby'certify that the foregoing is true and correct to the best of my knowledge: Signed:~ ~)~, } ~~/~~ j' Title: ~' ~. I, (~ ~.;! /~(] ?._ Date:'~-- hr~ Form 10-404 Rev 06/15/88 t SUBMIT IN DUPLICATE S~ an so'i~iver Fieid Well # SRU 212-27 Actual Completion, 11/24/96 RKB to TBG Head- 14.32~ Tree connection: TC-3 Ual-bolt DV ~d 4430' i 3 4 5 6 TOC 4z 5800' ~, ~-~ CBL 10/2/61 e ekn ~ ii 'Fop of Tbg [ 4' 6800' 7 TOC 7135' ~annuhls 8 9 9a 61)76-61)9t) 6104-6108 6237-6254 6527~6537 Fish 27* ofperfgnn PBTD 7750' TD 7800' MAX HOLE ANGLE Straight 212-27 schematic 5 02 DOC CASING AND TIt BING DETAIL SIZE WT GRADE CONN TOP BOTTOM 2? Surf 32' 9-5/8" 40 J-55 Surf 3455' 5-1/? 17 N-80 Buttress Surf 7800' Tubing String: 2-3/8" 4.6 N-80 Buttress Surf 5878' with 3/8" SS methanol injection lineSurf 2508' NO. I I4.32 2 2508 7 8 9 9a 10 1I 12 13 JEWELRY DETAIL __ Depth Item 5748 5799 5844 5878 2-3/8" Tbg hgr w/Calneron H BPV profile Macco 2-3/8" SMO-iCI Chem 1nj Mdrl w/1000 psi them ini valve Macco 2-3/8" D-SC) giro w/t" dummy Baker '~FH Retr. pkr, 2-3/8" x 5-~/2" 17# X hippie T'abing tail (M'~ear out sub) 6800 Tubing Cut, 10/27/96 7544 Camco MM mandrel with CEV 7577 Tubing cut, 10/25/96 7582 2-3/8" Baker bridge plug, 10/25/96 7589 Camco D nipple 760 ] Baker D packer 7612 Bottom of tubing tail 6146 Plug at 6176', TOC at 6146' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6076 6090 Tycmek 4 3/5/01 6104 6108 I'yonek 4 3/5/01 6237 6254 1 yonek 4 9/12/97 6527 6537 Tycmek 4 I l/7/99 7620 7620 5 1961 WSO sqzd 7625 76~5 · Tyonek 4 1961 Prop abdn ~96 2890 2890 surf casing 4 Sqzd :6I REVISED: 5/2/2002 DRAWN BY: gAB Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager Wednesday, March 22, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Swanson River Unit Well SRU 212-27 APl No. 50-133-10153-01 10-404 Perforate Bench 62-5 Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the 62-5 bench in well SRU 212-27. The following intervals were perforated on 11/7/99: Bench Top Bottom Feet ~.~.~, 6,527 6,537 10 C ¢' '~ /~> Total: 10 If you have any questions, please contact Ralph Holman at 263-7838. erely, Dan Williamson Drilling Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Otheri 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 14" KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Swanson River Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1850' FNL, 1500' FWL, Sec. 27, TSN, R9W, SM SRU 212-27 At top of productive interval 9. Permit number/approval number Same 61-0033 At effective depth 10. APl number Same 50-133-10153-01 At total depth 11. Field/Pool Same Swanson River/Tyonek 12. Present well condition summary Total depth: measured 7800 feet Plugs (measured) 7135 true vertical 7800 feet Effective depth: measured 7750 feet Junk (measured) true vertical 7750 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 32' 22" 32' 32' Surface 3455' 9-5/8" 1620 sx 3455' 3455' Intermediate Production 7800' 5-1/2" 1100 sx 7800' 7800' Liner Perforation depth: measured 6527'-6537' true vertical 6527'-6537'ORIGINAL Tubing (size, grade, and measured depth) 2-3/8", 4.6 lb/fi, N-80 from surface to 5878' Packers and SSSV (type and measured depth) Baker "FH" Retr. pkr. at 5799' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1601 0 720 1020 Prior to well operation 0 Subsequent to operation 0 1605 0 700 880 ... 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 March 7, 1997 907-276-7600 907-263-7884 fax Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Swanson River Unit Well #212-27, Approval # 396-205 Recompletion Report Form 10-407 j -iLE Commissioner Johnston: Attached is the Form 10-407 for the recompletion of Swanson River Unit Well #212-27. In October 1996, the Lower Tyonek perforations in Swanson River Unit Well # 212-27 were abandoned by placing a balanced cement plug in the tubing and in the casing annulus above the existing production packer. In November 1996, a workover rig pulled the old tubing and run a new 2-3/8" completion. The Upper Tyonek gas zone was perforated on 2/12/97 with through-tubing guns at 6527'-6537'. Attached in duplicate are the 10-407 Well Recompletion form with wellbore schematic and Summary of Rig Workover Operations. If them are any questions about this report, please call me at 263-7659. Sincerely, Drilling Engineer 0 7 997 ,~aska 0il & Gas Cons. ~mmissi0~ U AOCJCOV. DOC 1 3/5/97 · ~"~ STATE OF ALASKA ~-, ALASKA OIL AND GAS CONSERVATION ~OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: , 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 61-0033/396-205 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-10153-00 4. Location of well at surface 9. Unit or Lease Name a7 1850' FNL, 1500' FWL, Sec. 27, TBN, R9W, SBM ! Swanson River Unit At Top Producing Intervali 10. Well Number SAME ~ , ' ' . SRU #~,45-- '-' ~ At Total Depth ~ 11. Field and Pool SAME 5. Elevation in feet (indicate KB, DF, etc.) ' J 6. Lease Designation and Serial No. Swanson River Field/Tyonek 14' KBI A-028406 12. Date Spudded8/61 13' Date T'D' Reached I 14' Date C°mp" sUsp' °r Aband' I 15' Water Depth' if °fish°re I 16' N°' °f C°mpleti°nsl 0/61 2/12/1997 NA feet MSL 1 17. Total Depth (MO+TVD)7800/7800,18. Plug Back Depth (MO+TVO)6800,16800, I19' Directi°nal SurveyYes: No: X I20' Depth where SSSV ,etNA feet MD I21' Thickness °, Permatr°stNA 22. Type Electric or Other Logs Run GR/CCL and Perf Record-2/12/97 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , 22" 0 32' To surf 0 9-5/8" 40~ J-55 0 3455' 12-114" 1620 sx 0 , 5-1/2" 17# N-80 0 7800' 8-3/4" 1100 sx 0 , 24. Perforations open to Production (MD+TvD of ToP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 5878' 5799' 6527.-6537' MD 4 spf, 0.34" dia hole 6527'-6537' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/14/97 I flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3/5//97 24 TEST PERIOD => 0 500~CF ~. 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF W,~TER-BBL OIL GRAVITY-APl (corr) Press. 2100 0 24-HOUR RATE => 0 500MCF ¢ 0 NA 28. CORE DATA "~, Brief descdption of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~'~AR 0 7 ~997 AJaska 0il & Gas Cons, Cc,~';~t-~l~ssio~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. L. Tyonek 6527'-6537' 6527'-6537' Flowed dry gas. Alaska Oil & Gas Cons, Commission 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Rig Workover Operations 32. I hereby certify that the fore~ Ioing is true and Rorrect to the best of my knowledge Signed _~~_~~~U~ T~Ie.....D.rillin.qManager Date Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ii Summary of Rig Workover Operations Swanson River Unit Well No. 212-27 10121196- RU SLICKLINE. RIH WITH 1.75" BAILER, TAG AT 7605' wlm. RIH WITH 1.85" GAUGE RING, TAG "D" NIPPLE (~ 7562' wlm (DEPTH CORRECTION BETWEEN wlm AND dpm ON WELLBORE SCHEMATIC IS +27'). 10123196- RU PUMP TRUCK AND LOAD TUBING WITH 35 BBL LEASE WATER, TBG PRESSURE --' 620 PSi. 10125/96- RU E-LINE UNIT, SET 2-318" TUBING BRIDGE PLUG AT 7582' ~b (7' ABOVE "D" NIPPLE). PRESSSURE TEST TUBING/BRIDGE PLUG TO 2000 PSI. RIH WITH JET CUTTER, CUT TUBING AT 7577' rkb. POOH AND RD E-LINE. 10126196- RU DOWELL CEMENT UNIT. ClRC WELL THRU TUBING CUT AT 7577'. PUMP 2 BBL FRESH WATER SPACER AND 10 BBL CLASS G CEMENT WITH ADDITIVES AT 15.8 PPG. DISPLACED WITH 2 BBL FRESH WATER SPACER AND 25.5 BBL LEASE WATER. 10127196- PRESSURE TEST TUBING TO 1000 PSI, NO COMMUNICATION TO ANNULUS. RU E-LINE, RIH WITH 1.813" GAUGE RING. TAG TOC (~ 7010', (PRESSURE TEST AND TOC TAG WITNESSED BY LOU GRIMALDI-AOGCC). POOH WITH GAUGE RING. RIH WITH JET CUTTER, CUT TUBING @ 6800'. POOH, RD E-LINE. 11/22/96- ACCEPT RIG (~ 00:00 11122/96. NU BOPE. TEST BOPE (WITNESSED BY LOU GRIMALDI-AOGCC). MU DUAL ELEVATORS AND DUAL LANDING JOINTS FOR 2-318" AND 1-114". PULL DUAL TBG STRINGS TO RIG FLOOR, LEFT BOTTOM PLATE OF TBG HANGER IN TUBING SPOOL. RELAND 2-318" LONG STRING AND PULL 1-114" HEATER STRING, LAY DOWN 46 JOINTS OF 1-1/4" TUBING. PULL 2- 318" LONG STRING HANGER OUT OF TUBING SPOOL, ClRC BU. POOH LAYING DOWN 2-318" TUBING. 11123/96- MU SPEAR, RETRIEVED LOWER PLATE OF TUBING HANGER FROM TUBING SPOOL WITH 5K PULL. RIH WITH MILL AND CASING SCRAPER ON NEW 2-3/8" TUBING TO 6300'. CIRC BU. TEST CASING TO 1500 PSI, OK. DISPLACE WELL TO 6% KCL AND 1% CORROSION INHIBITOR. POOH WITH MILL/SCRAPER. MAR 0 7 Oil & Gag Cons 11124196- RUN 2-3/8" COMPLETION WITH METHANOL INJECTION LINE TO 2500'. LAND HANGER, PRESSURE TEST INJECTION LINE, DISPLACE TUBING WITH DIESEL PLUS 5 BBLS TO FREEZE PROTECT ANNULUS. DROP BALL, SET PACKER (~ 5799' WITH 3000 PSI, SHEAR OUT BALL WITH 3200 PSI. TEST ANNULUS TO 1500 PSI. ND BOPE, NU AND TEST TREE TO 5000 PSI. RELEASE RIG AT 24:00 HRS. 11126196- RU SLICKLINE. RIH WITH 1.75" BLIND BOX TO 5925'. NO PROBLEM AT SHEAR OUT SUB @ 5878'. 2/12/97- RU SCHLUMBERGER, RAN GR-CCL CORRELATION LOG AND TIE IN TO TDT LOG 8114196. RIH WITH 10' PIVOT GUN AND PERF 6527'- 6537' 4SPF, 180 DEGREE WITH WELL OPEN TO FLOW. UNLOAD WELLBORE FLUIDS AND FLOWED DRY GAS. SHUT-IN WELL AND PULL E-LINE, STUCK AT 288'. PULL WIRE BUT LEFT TOOL STRING IN HOLE. 2/13197- RU SLICKLINE, ATTEMPT TO FISH TOOL STRING, TAG AT 265' AND PUSH DOWN TO 324'. POOH WITH SLICKLINE AND PUMP METHANOL DOWN TUBING WHILE RIH WITH SLICKLINE FISHING TOOLS. DID NOT TAG FISH, TAGGED TOP OF TUBING STUB AT 6801'. POOH AND TURN OVER WELL TO PRODUCTION. Anchorage UNOCAL 1532' RKB to TBG Head -- 14.32' Tree connection: TC-3 Uni-boit Swal~oon River Field Well # SRU 212-27 Actual Completion, 11/24/96 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 32' 9-5/8" 40 J-55 Surf 3455' 5-1/2" 17 N-80 Buttress Surf 7800' Tubing String: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injection line Surf 5878' 2508' DV ~ 4430' TOC ~ 5800' CBL 10/2/61 Top of Tbg ~ 6800' TOC 7135' -annulus 7135' -tbg Top of Fill 7609' 10/1/88 Prop Perfs 7 6527-6537 Fish = 27' 8 of perf gun 9a 10 11 12 JEWELRY DETAIL NO. Depth Item 1 14.32 2 2508 3 5748 4 5799 5 5844 6 5878 2-3/8" Tbg hgr w/Cameron H BPV profile Macco 2-3/8" SMO- 1C 1 Chem Inj Mdrl w/1000 psi chem inj valve Macco 2-3/8" D-SO glm w/l" dummy Baker "FH Retr. pkr, 2-3/8" x 5-1/2" 17# X nipple Tubing tail (shear out sub) 7 6800 8 7544 9 7577 9a 7582 10 7589 11 7601 12 7612 TOP BTM Tubing Cut, 10/27/96 Camco MM mandrel with CEV Tubing cut, 10/25/96 2-3/8" Baker bridge plug, 10/25/96 Camco D nipple Baker D packer Bottom of tubing tail PERFORATION DATA ZONE SPF DATE COMMENTS 6527 6537 4 Proposed 7620 7620 7625 7635 L Tyonek 5 1961 WSO sqzd '61 4 1961 Prop abdn '96 ~.~...~.,.~x~:.: :~,:.:~.:...:.:-..~.:.... ~5i.-. ~ ,,::.,..'..~.~ ::~ .'.~.'.:: ~ ::~i:74:~:.+. PBTI) = 7750' TI) = 7800' MAX HOLE ANGLE = Straight 2890 2890 surf casing 3018 3028 surf casing 3152 3162 surf casing 3342 3352 surf casing 4 Sqzd '61 4 Sqzd '61 4 Sqzd '61 4 Sqzd '61 REVISED: 2/28/97 SC27AC.DOC DRAWN BY: TAB MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 22, 1996 THRU: Blair Wondzell, ~'d~ FILE NO: P. I. Supervisor ~/2~' A99JKVDD.DOC FROM: Lou Grimaldi,'r~ SUBJECT: Petroleum Inspector BOP Test UNOCAL well #SRU 212-~7,, Swanson River Field PTD #61-0033 Friday, November 22, 1996: I witnessed the initial BOP test on Alaska Well Service's rig #5 which was preparing to work over UNOCAL's well #SRU 212-47 in the Swanson river field I arrived late on Thursday night to find the crew still rigging up the choke and kill lines on the stack. The side outlets on the double gate were going to be used, but when the blind flanges were pulled the outlets were found to be packed with cement. This necessitated opening the ram doors to clean these and slowed down the progress. The test once started went quite nicely. There were two valves on the choke manifold that leaked through the stem packing, these being the inside valve on the manual choke line and the inside valve on the Blooey line. Both valves were greased and cycled. The inside manual choke valve held fine but the Blooey line valve gave us trouble throughout the test with a small but persistent leak. This necessitated the repair of this valve. All other equipment functioned properly and held its respective pressure tests. This rig has one more well after this one and I discussed its preparedness for extreme-cold weather with Doug Nienhaus (UNOCAL drilling foreman). SUMMARY: I witnessed the initial BOP test on AWS rig #5. Working over UNOCAL's well #SRU 212-47 in the Swanson river field. Two failures observed. Test Time; Four hours. Attachments:. A99JKVDD.XLS cc: Dale Haines (UNOCAL Drilling, Anchorage) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: _____ Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Alaska Well Services "Rig No. 5 _ PTD # UNOCAL Rep.: 212-47 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 11/22/96 61-0033 Rig Ph.# 283-5535 Doug Nienhaus Ron Holmes 27 T. 8N R. 9W Meridian Seward .... aiSC. INSPECTIONS: FLOOR SAFETY VALVES: Quan.I Location Gen.: P Well Sign P Upper Kelly / IBOP N/A Housekeeping: P (Gen) Drl. Rig P Lower Kelly / IBOP N/A PTD On Location P Hazard Sec. N/A Ball Type - Inside BOP 1 Standing Order Posted P Test Press. 250/3000 250/5,000 250/5,000 250/5,000 25O/5,0O0 250/5,000 250/5, O00 ~IF P __ P ,, P P P __ P __ N/A __ BOP STACK: Quan. Annular Preventer 1 Pipe Rams _ 1 Lower Pipe Rams _ Blind Rams 1 Choke Ln. Valves 1 _ HCR Valves '/ Kill Line Valves 2 Check Valve N/A 250/5,000 MUD SYSTEM: Visual Alarm Trip Tank P P 3it Level Indicators P P .. Flow Indicator P P Meth Gas Detector P P - H2S Gas Detector P P 2 ,Test Time: ~urs. Test Pressure P/F 250/5,000 I ._ 250/5,000 I 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves 14 No. Flanges 30 Manual Chokes 1 Hydraulic Chokes Test Pressure 250/5,000 250/5,000 Functioned Functioned P/F F - P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3 Bottles 1900 average psi 3,000 I P 2,200 P minutes 32 sec. minutes 56 sec. p Remote: P Psig. Number of valves tested · /9 Repair or Replacen~ent of Failed Number of Failures: · ' I be made within N/A Notify the Inspector and follow with Written or Faxed verification to Equipment wll .... _.__ ')'~ ?542 Insnector North Slope Pager No. 659-3607 or 3687 the A GCC Commission Office at: Fax mu .... '- REMARKS: Inside valve on Blooey line and inside valve on manual choke leaked from stem packing. Greased both and choke valve held but blooey valve did not."Repair valve and retest.~Kelly was not assembled or tested, if picked up test and send results to AOGCC. ~' Distribution: STATE WITNESS REQUIRED? orig-Well File YES X NO c- Oper./Rig c- Database 24 HOUR NOTICE GIVEN c - Trip Rpt File YES X NO c- Inspector Waived By: Witnessed By: Louis R Grimaldi FI-021L (Rev. 12/94) A99JKVDD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnstoj~--'~ DATE: Chairma h'-'a[~z-~ THRU: FILE NO' Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, ~-,~- SUBJECT: Petroleum Inspector October 27, 1996 B99JJ1DD.DOC Casing Cement plug UNOCAL SRU 212-27 Swanson River Field PTD #~ Sunday, October 27, 1996: I witnessed the pressure test and tag of the cement plug used to abandon the lower zone on UNOCAL's well # 212-27 in the Swanson river field. The plug had been laid the previous day. A bridge plug was set in the tubing which was pressure tested to 1000 psi. The tubing was then cut 5 feet above the plug. The tubing/annulus was circulated with lease water to '., balance. A 10 barrel balanced plug was to the cut and the tubing annulus were connected at surface to allow the plug to find balance. I arrived this morning to witness the following. A 1000 psi pressure test was applied separately to the tubing then the annulus, both tests were held for fifteen minutes each with no decline in pressure noted. A E-line unit was rigged up and ' the plug in the tubing was tagged to verify depth. The unit tagged up 125' high from expected depth. This equated to approximately .5 barrel's of cement which if higher then the casing cement, still left more then enough to satisfy State requirements. SUMMARY: I witnessed the verification of cement plug placement on UNOCAL's well #212-27 in the Swanson river field.. Attachments: B99JJIDD.XLS CC.' Confidential with attachments STATE OF ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION Plug And Abandonment Report Operator: Unocal Operator Rep.: Larry McAIlister Lease No.: SRU Well No.: Total Depth: Date: 10/27/96 Well Name: SRU 212-27 PTD No.: 61-0033 Sec. T-R S-27, T-8N, R-9W Meridian: Seward 7800 Elevation: 14.3 Mud Wt.: 8.4 ppg. CASING DATA: Drive Pipe: O.D." Set @: ft. With Penetration Conductor: O.D." Set @: ft. Surface: O.D." Set @: Intermediate: O.D." Set @: ft. Pmdctn: 5 1/2 O.D." Set @: 7980 ff. PLUGGING DATA: 1. Open Hole Plugs: 2. Open Hole Isolation Plugs: 3. Perforation Plugs: 4. Annulus Plugs: Bridge plug set in 2 3/8 tubing @ 7582' RKB, Cut 2 3/8 @ 7577 RKB and circulate and lay a 10 bbl balanced plug of class "G" cement at cut. (Not witnessed by A.O.G.C.C.) 5. Casing Stub Plugs: 6. Surface Plug: Casing Removal: " Casing Cut@ Feet " Casing Cut@ Feet " Casing Cut@ Feet " Casing Cut @ Feet REMARKS: Witnessed Pressure tests of above plug to 1000 psi (tubing then annulus). Tagged plug with E-line at 7010 RKB (approx. 125' high). This well is due to be recompleted at upper interval. Distribution: orig - Well File c - Operator c- DNPJDOG c- Database c - Rpt File c - Inspector Inspector (s): Louis R. Grimaldi FI-000 (Rev. 3/93) B99JJ1DD.XLS UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 October 7, 1996 907-276-7600 907-263-7884 fax Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501 Attn: Commissioner David Johnston Subject: Swanson River Unit Well #212-27 APl #50-133-10153-00 Form 10-403, Proposal to Abandon L. Tyonek and Recomplete to U. Tyonek Dear Commissioner Johnston: Unocal proposes to abandon Lower Tyonek perforations in Swanson River Unit Well # 212-27 and recomplete in an Upper Tyonek gas interval. This well is currently shut-in due to high water production in the Lower Tyonek. The proposed work will require abandoning the existing perforations by placing a balanced cement plug in the tubing and in the casing annulus above the existing production packer. After the abandonment, a workover rig will pull the old tubing and run a new 2-3/8" completion. The Upper Tyonek gas zone will be perforated with through- tubing guns. Attached in triplicate are the 10-403 form with BOP schematic, detailed operations program and three schematics of the existing weilbore, the proposed abandonment and the proposed recompletion. Estimated start date is October 31, 1996 so your timely consideration of this proposal would be appreciated. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, Tim Billingsley '-~ U 27AOCsCOV.DOC I 10/7/96 "-' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. :l'ype of Request: Abandon: Suspend: Operation shutdown: Re. enter suspended well: Alter casing: Repair '~vell: Plugging: x "Time extension: Stimulatelu Change approved prOgram: Puli tubing: x VarianCe: Perforate: x Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 14 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Swanson River Unit Anchorage, AK 99519-6247 Service: 4. Location of well at surface 8. Well number 1850' FNL & 1500' FVVL of Sec. 27, T8N, R9W, SBM SRU 212-27 At top of productive interval Same 9' Permit number ~ I '~' {~ 3..~ -- At effective depth 10. APl number Same 50- 133-10153-00 At total depth 1 i' Field/Pool Same Swanson River/Tyonek ~ 2. P'r~sent well condition summary Total depth: measured 7800 feet Plugs (measured) 7750' true vertical 7800 feetnR true vertical 7750' feet Casing Length Size Cemented Measured depth True vertical de~h Structural Conductor 32' 22" 32' 32' Surface 3455' 9-5/8" 1620 sx 3455' 3455' Intermediate Production 7800' 5-1/2" 1100 sx 7800' 7800' Liner Perforation depth: measured 7625'-7635' RECEIVED true vertical 7625'-7635' Tubing (size, grade, and measured depth) 2-3/8", 4.C:~t, N-80 at 7612" Packers and SSSV (type and measured depth) Baker Model D 2-3/8" x 5-1/2'' ~) 7601' 13. Attachments Description summary of proposal: Detailed operations program: x BOP sketch: x ,. 14. Estimated date for commencing operation 15. Status of well classification as: 10/31/96 16. If proposal well verbally approved: Oil: Gas: x Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~_~ ,u~) ~ cc,~,-, Dale Haines Title: Drilling Manager Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. ~i~0~ ~ Plug integrity ~ BOP Test ,~' Location clearance Mechanical Integrity Test Subsequent form required 10- ~ O ~ Original Signed By David W. Johnston Approved by order of the Commissioner Commis,sio_ner - Form 10-403 Rev 06/15/88 Approved Copy Returned " SUBMIT IN ~JATE UNOCAL ) Swanson River Field SRU 212-27 Workover Program 10/6/96 Obiective: Recomplete SRU 212-27 from a Lower Tyonek Gas Producer to an Upper Tyonek Gas Producer. Status: Shut-in Lower Tyonek gas producer due t° high water production. Well design: Based on recompleting the well to an Upper Tyonek gas producer. Table II: Tubular Capacity Tubular Size 2-3/8" 4.6#" .00387 2-3/8" x 5-1/2" 17# .0178 5-1/2" 17# .0232 1-1/4" buttress heater strin[~ .00185 Capacity (BBL/FT) Pre-riu prep work: Kill tubinR, ...Sli.c..klin.e. tau fill, set plu~, cut tubing, Pump balanced cement plug to abandon perfs? Pressure test cement, E-line ta~ TOC and cut tubin~ above TOC. Note: Notify AOGCC for possible witness of step #9 and #10. 1 Pump kill weight brine down tubing. Note: Last BI-IP info was 4/21/93 with BI-[P=3577 psi ~ 7570' (9.1 ppg EMW) from a slickline static BHP survey. 2 RU slickline unit. RIH with 1.8" gauge ring and tag fill in long string. (Last tag was 10/1/88 (~ 20' below D nipple) 3 RIH with 1.81" Camco CA-2 bla~fldng plug with prong on slickline and set in "D" nipple at 7589'. Ensure plug is holding by pressuring tubing to 2000 psi. 4 RU E-line, RIH ~vith 1.813" full jet cutter for 2-3/8" tubing and cut tubing above blanking plug as deep as possible (at =-7580'). POOH and RD E-line. RU cement and pumping equipment. Pump 150 bbl kill weight brine down tubing taking returns out annular valve and heater string. Hole should now be loaded with kill weight fluid above plug in D nipple. Batch mix 10 bbls (50 sx) Class G cement with additives. Cement volume of 10 bbls displaced as a balanced plug will result in: 0.4 bbl in the annulus rat hole from tubing cut at 7580' to packer at 7601 '. 7.9 bbl in the annulus from tubing cut at 7580 to TOC at 7135' 1.7 bbl let~ inside tubing on top of plug from 7589' to TOC at 7135'. RECEIVED OCT 'l 0 199(; Pump down 2-3/8" tubing while taking returns out annulus as follows: 2 bbl fresh water spacer followed by 10 bbl cement, drop 2-3/8" tubing wiper plug, displace cement with 2 bbl fresh water spacer followed by 25.6 bbl kill weight brine so that TOC on balanced plug is at 7135'. Install and open jump-over line from annulus to tubing to ensure plug balances. U AOOCPRO2.DOC I 10~6 UNOCAL Swanson River Field SRU 212-27 Workover Program 10/6/96 8 WOC overnight. 9 Pressure test cement plug by applying 2000 psi on tubing. (AOGCC may want to witness) I0 RU E-line. Tag TOC in 2-3/8" tubing with 1.813" gauge ring. (AOGCC may want to witness this step as well as step #9). POOH w/gauge ring. 11 RIH with 1.813" full jet cutter for 2-3/8" tubing. Cut tubing approximately 200' above TOC to ensure cut is above cement in annulus. RD E-line and wait for rig move. Note: This ends the "Abandonment" portion of the procedure. II. Rig Mobilization and Prepare Well for New Completion Note: Notify BLM and AOGCC 24 hours in advance of BOP tests. I MIRU Alaska Well Service RIG 5. 2 ND tree, NU BOPE, choke line, kill line and choke manifold. 3 Pressure test BOPE. 4 Pull 1-1/4" heater string. Pull 2-3/8" tubing. 5 RIH with bit and casing scraper to 6300'. 6 Pressure test casing to 1500 psi. Circulate hole to 6% KCL water plus corrosion inhibitor. 7 POOH and LD bit/scraper. Run 2-3/8' Completion: 1 RIH with new 2-3/8" completion including: 1) X nipple in tubing tail 2) 2-3/8" x 5-1/2' 17# Retrievable packer set at 5800'. 3) 2-3/8" buttress gas lift mandrel with dummy. 4) Chemical injection mandrel with 1000 psi chemical injection valve at 2500' appx. 5) 2-3/8" buttress tubing to surface with 3/8" ss control line strapped to tubing. 2 Land tubing hanger. 3 Cite diesel down tubing for underbalance perforating. 4 Drop packer setting ball and set packer with 3000 psi tubing pressure. Shear out ball. mi 5 Pressure test annulus to 1500 psi. 6 ND BOPE, NU tree and test tree. 7 RD rig and move to next workover. u AOGCPRO2.DOC UNOCALe Swanson River Field SRU 212-27 Workover Program 10/6/96 IV. Perforate Tyonek: ! MIRU E-line unit. Tie-in Lo~:_ Schlumberger's TDT date 8/14/96. 2 P,/H with 1-11/16" GR/CCI for correlation log. Log from 6300' to packer jewelry at 5800'. 3 RIH with gun run # 1 and tie in to GR/CCI correlation log. 4 Perforate 6238'-6252' (14 feet) with Schlumberger 1-11/16" pivot guns at 4 spf. 5 RD E-line unit and turn well over to production. U AOGCPRO2.DOC 3 10/6/96 UNOCALe Top of Fill 7609' 10/1/88 PBTD -- 7750' TI} = 7800' MAX HOLE ANGLE = Straight SC27BLMA.DOC SIZE WT Swanson River Field Well # SRU 212-27 Actual Completion 5/63 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" 9-5/8" 40 5-1/2" 17 Surf 32' J-55 Surf 3455' N-80 Buttress Surf 7800' Long Tubing String: 2-3/8" 4.6 N-80 2-3/8" 4.6 N-80 Short Heater String: 1-1/4" Buttress Surf 1593 (50 jts) EUE 8rd 1593 7612' Buttress 27' 1529' NO. Depth I 14 2 39 3 1593 4 7544 5 7589 6 7601 7 7612 JEWELRY DETAIL Item Tubing hanger with Cassasco BPV profile Otis S nipple in position #1 Crossover 2-3/8" buttress x 2-3/8" 8rd Camco MM mandrel with CEV Camco D nipple Baker D packer Bottom of robing tail PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 7620 7620 5 WSO sqzd 7625 7635 L Tyonek 4 Existing RECEIVED REVISED: 10/6/96 DRAV~N BY: TAB UNOCAL SIZE WT Swanson River Field Well ti SRU 212-27 Proposed Abandonment, 10/96 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 22" Surf 32' 9-5/8" 40 J-55 Surf 3455' 5-1/2" 17 N-80 Buttress Surf 7800' Long Tubing String: 2-3/8" 4.6 N-80 Buttress Surf 1593 (50jts) 2-3/8" 4.6 N-80 EUE 8rd 1593 7612' Short Heater String: 1-1/4" Buttress 27' 1529' Top of Fill 7609' 10/1/88 TOC ~ 7135' Tbg & Annulus 4a 5 6 7 JEWELRY DETAIL NO. Depth Item I 14 2 39 3 1593 4 7544 4a 7580 5 7589 6 7601 7 7612 Tubing hanger with Cassasco BPV profile Otis S nipple in position #1 Crossover 2-3/8" buttress x 2-3/8" 8rd Camco MM mandrel with CEV Tubing Cut Camco D nipple with plug Baker D packer Bottom of tubing tail PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 7620 7620 5 WSO sqzd, 1961 7625 7635 L Tyonek 4 Proposed P&A j ~E~l · ~ PBTD = 7750' TI} -- 7800' MAX HOLE ANGLE = Straight S27BLMA2.DOC REVISED: 10/6/96 DRAWN BY: TAB UNOCAL ) Swanson River Field Well # SRU 212-27 Proposed Recompletion 10/96 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 22" Surf 32' 9-5/8" 40 J-55 Surf 3455' 5-1/2" 17 N-80 Buttress Surf 7800' Tubing String: 2-3/8" 4.6 N-80 Buttress Surf with 3/8" SS methanol injection line Surf 5910' 2500' Top of Tbg ~ ~6935' TOC 7135' -annulus 7135' -tbg Top of Fill 7609' 10/1/88 8 9 10 11 12 Prop Perfs 6238-6252 JEWELRY DETAIL NO. Depth Item I 14 2 2500 3 5770 4 5800 5 5830 6 5860 Tbg hgr with Cameron H BPV profile Chem Inj Mdrl w/1000 psi chem mj valve GLM w/dummy Baker "FH Retr. pkr, 2-3/8" x 5-1/2" 17# X nipple Tubing tail (shear out sub) 7 6935 Tubing Cut 8 7544 Camco MM mandrel with CEV 9 7580 Tubing cut 10 7589 Camco D nipple 11 7601 Baker D packer 12 7612 Bottom of tubing tail PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6238 6252 62-5 4 Proposed 10/96 7620 7620 5 1961 WSO sqzd '61 7625 7635 L Tyonek 4 1961 Prop abdn 10/96 PBTD --- 7750' TD --- 7800' MAX HOLE ANGLE -- Straight S27BLMP2.DOC REVISED: 10/6/96 DRAWN BY: TAB FILL-UP -----i> ~'-" 5000 KiLL LINE ~.'. 5OOO psi - '--' ~,,I FLOW i i I CHOKE LINE 3" 5000 psi RECEIVED 0CT 1 0 ~99~ Alask~ Oil & C~as Con;. T BOP STACK 10" EO00 Fsi Form ~160-5 (JUNE 1990) UNITED. iTES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WEllS Do not use this form for proposals to drill or to deepen or reenlry to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such Proposals SUBMIT IN TRIFLICA TE 1. Type of Well Oil Gas [~ Well [~ Well E] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Design~on and SeriaJ No. 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Solclotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent [-1 Subsequent Report Final Abandonment E] Abandonment E] Change of Plans r-'] Recompletion [-] New Construction r'-I Plugging Back E] Non-Routine Fracturing E] casing Repair r'-I Water Shut-Off E~ Altering Casing E] conversion to Injec~on [~ Other Temporarily Abandon E] Dispose Water (Note: Report results of multiple conmpletion on Well Completion or Recom~ Rep<xt and Log fon~.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pe~nent dates, including estimated date of staJ1Jng any p~oposed work. If well is direcfionally drilled, give subsudace locations and measured and true vertical depths for all markers and zone pertinent to ~is w3rk.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit (~, j¢j SCU 21-8 ~ll SCU 34-9 ~") ~SRU 212-10 {O I" ~,~ SCU 34-8 ~' -~SCU 41B-9 ¢.eO 'o~RU 12-15 f~- I SCU 243-81 ~U 14-34 OO-J ~SRU 14-15 ~ j_~,SCU 13-9 ~..~.~.~. ~-_~O SRU41A-15 (~ SBU 14-22 '$8' ,--/ * High GOR well that may be produced intermittently Swanson River Unit ./,I SRU ~3-27 SRU 34-28 6~- 7_ SRU 43- 28 (e I" ~_ SRU 21-33W9 ~ ~",~, ~,PR 0 ~ SRU 24-33 ~ ~- "~ 14. I hereby cerlJfyth~the foregoing is trueand correct. / ...... //// - ['l'his space for Federal ana~ffme use) Dennis L. Gmboske 'r~ Petroleum Engineer Date 3/29/96 Approved by Cond'~Jons of approval, if any: Date T~fe 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United Slates any false, f~ous or fm_~_,__k~_ s_~,,f,=,~ents or rel:~___,=~,,~e=_ '_t~_ as to an~f n.~___-_~ within its iuris¢ic~. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period' April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Rate Potential P & A Shallow Gas Potential and 'Hemlock Only' P&A Shut-in Wells during Field Blowdown Hemlock Producers Future Shallow Gas Pr~oducer with the Hemlock Abandoned SCU 34-8 SRU 212-10 SCU 243-8 SRU 212-27 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 7 Wells 2 Wells 5 Wells ~.$ ~.~h GOR well that may be produced intermittently SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 Recompleted in Tyonek G1 and G2 zones · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. APR 01 1~6 Une~al North Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas -.- Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 · 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells Coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Atask~ Oil & Gas Cons. Commission Anchorage Form 3160- 5 (JUNE 1990) UNITL ATES DEPARTMENT ~F THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPUCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas [~ Well [] Well r-I Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage~ AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No, 1004-0135 Expkee: Maroh 31r 1993 5. Le, ue Deelgn~on and Serial No. 6. If Indian, Allottee or Tribe Name · . · o, 7. If Unit or CA, Agreement De~ignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or P~rbh, State Kenal, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent Subsequent Repo~ E] Final Abandonment r-'! Abandonment E] Recompletion E] Plugging Back r"] casing Repair E] Altering Casing [~ Other Temporarily Abandon r-i Change of Pjans E] New Construc~n E] Non-Routine Fracturing E] water Shut-Off 0 Conversion to Injection r-I Dispose water (Note: Repm't reault~ oi' multiple oonmpldion on Well 13. Descn13e Proposed or Completed Opemltons (Clearly state ali pe~tinent details, and giva perlinent datas, Including estlmat~l data d starling any proposed wodc As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ,~ I' * SCU 23B-a SCU 243-8 ..~ <~ I SCU 13-4 SCU 341-8 -':: <J t * SCU 21A-4 SCU 13-9 " 51 SCU 34-4 * SCU 34-9 5' 1 * SCU 43A-4 SCU 14-34 / .'0//-..* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit ~' ! SRU 212-10/'"SRU 14-22 $ I SRU 43-28 ~ os~ SRU 14-15//-0/<SRU 12-15 ~ I GRU 14A-33 5 SRU 23-15 ~1 SRU 23-22~u.~pSRU 24-33 ~5usl:,SRU 34-15 ;51 SRU 23-27 ": SRU 32-33WD %i. SRU 41A-15i ~SRU 212-27 SRU 21-33WD 5t~5~ SRU 43A-15G~ SRU 331-27 ~ u.f~o SRU 432-15 ~ SRU 34-28 14. (This space for Federal and t~ate~ use) Apr~oved by Conc~tions of appro~l, if any: RECEIVED APR - 1 1994 Title 18 U.S.C. Section 1001. makes it a crime for any person knowingly and willfully to nrmke to any deparl]Tx~ or agency e4 Itm United ~/~~'~ns. C0mmissi0r fraudulert statements or repmsenta6or= as to am/matter wilhin ils jurbdiclion. *See Instruction on Reverse Side A, Gh0rage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma ~~...Dennis L.' ~~,r~ske Petroleum Engineer Attachment cc: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Attachment No, I Swanson River Fiel~l Rate Potential Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Shallow Gas Potential P & A and 'Hemlock Only' P & A -/~t5 SCU 13-4 ~x~--I~ SRU 212-10 (~-~oSCU 34-4 L~[-c~ SRU 23-15 ~-'~.~SCU 341-8 (~.-~o SRU 41A-15 ~;~--~ SRU 34-28 ez~5~ SRU 14-22 e ~-~ SRU 43-28 ~-t'~ SRU 23-22 ~0--tt~ SRU 32-33WD ~I-~SRU 212-27 (~-b~ SCU 243-8 ~o-~ SRU 331-27 (0~--Z SRU 21-33WDa0-ZZ-SRU 12-15 Ioo--~&SCU 1 4-34 ~o-qq SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' ~O-I~t~ SRU 14-15 SCU 13-9 (~o-~t SRU 34-15 SCU 34-9' SRU 43A- 15 SCU 23B-3' %5-bb SRU 432-15 SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3: · SRU 33-5' Returned to full time production after workover, Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. tO RECEIVED aPR - 1 1994 Oil & Gas Cons. Commission Anchorage Alaska Region UNOCAL Oil & Gas Division Unocal Corporation ~ _. ~,,, P.O. Box 190247 CO Anchorage,-Alaska 99519-0247 Telephone (907) 276-7600 ?OMM_ ,,'.,,/. a. March 24, 1993 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S~wanson,RiverFielc[ Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIVED MAR 2 5 199;5 Alaska 0il & 6as Cons. 60rnrniss~oo Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED /Uaska 0il & Gas CoDs. Commission Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE 1. Type of Well I'X Oil Gas Well r'~ O Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchoraoe, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) (907) 276-7600 Swanson River Unit S°ldotna Creek unit 17 wells 14 wells 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 12. TYPE OF SUBMISSION TYPE OF ACTION 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field I!. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA r=x] Notice of Intent =-]Subsequent Report r-]Final Abandonment Notice O Abandonment n==] Recompletion O Plugging Back -=]Casing Repair [~] Other Temporari 1 y Abandon r--]Change of Plans O New Construction r--]Non-Routine Fracturing -=]Water Shut-Off r=-] Conversion to Injection '--1 Dispose Water (Note: Report resultsof multipl¢completionon Well Completion or Recompletiofl Report and Log form.) ! 3. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' SCU 21-3 SCU 23B-3*,~ SCU 13-4 SCU 21A-4 SCU 34-4 ~ SCU 43A-4- SCU 33-5 '~ Swanson River Unit / SCU 21-8*/ SCU 243-8" SCU 341-8~ SCU 13-9/ SCU 24A-9~ SCU 34-9'~' SCU 14-34 ~x Swanson River Unit SRU 212-10 SRU 14-15' SRU 23-15~ SRU 34-15 SRU 41A-15 SRU 43A-15 SRU 432-15 SRU 14-22~ * High GOR wells that maY be produced intermittently. 14.1 hereby certify thal~foreg,oing~e~:o~rrect. ~ Petroleum En 9i ne er Sig~ ~ ~~/ff~~ Title . - .,,/,/ .! ~b ~ for F~ m S~ o~) SRU 23-22' SRU 23-27 ~ SRU 331-27 SRU 34-28v SRU 43-28 ~ s,u RECEIVED SRU 24-33~ SRU 32-33WD~ NAR § 199) Alaska 0il& Gas O0ns. O0m~s~°r Anchorag~ Apl~o~nd by Title. Date Conditions of approval, if any: Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements 'See Instruction on Rmmme Side Attachment No. 1 'Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Rate Potential P & A(11 Shallow Gas Potential and 'Hemlock Only' P & A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3" SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24,33(:'1 5 Wells Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 Scheduled 'Hemlock Only' P & A in March-April, 1993. High GOR wells that may be produced intermittently. RECEIVED Alaska Oil & Gas Cons. Commission ~lch0rage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27', 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: · SCU 21-3: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: Returned t° production after flowline repair. SRU 12A-4: · SRU 211-15 Returned to full time production in 1992. Scheduled for fullP & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR Alaska 0il & Gas Cons. Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 'ENG ASST I i G-'~'~SR GE'~-~''=~ ~% ~ILE Mr. J. A. Dy gas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject;. 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC 3, 1 199t Alaska Oil & Gas Cons. Comm'tss'ton Anchorage ORIGINAl Form 3160-5 (November 1983) (Formerly 9.--331) UNITED STATES ( Of J~or D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON ~LLS ~ t~ll form for p~ls to drill or to d~n or plug back ~ a ~e~at rmrvolr. U~ -~P~CAT~ON ~R PERMIT~" for ~u~ 2. NAMI Of OPIIA~OI' ARCO Alaska, Inc. 3. a~nr. BI Of Opllm~Ol P.O.Box 100360 Anchorage, AK 99510 · I-. L~C&?tOl( Of ~'gL~. (Re~t lOCltlou clearly and in ac~Grdan(-~' with lay SCaf~ ~c-qulrementl.· See aim) spncP 17 below.) Form approved. Budget Bureau No. 1004-0135 .... Expires August 31. 1985 5. L~&ll DIIIiQX&I~Qll &lO lEAL&L, lO. ~. ~ IIOl&l. &LI, O~Tll PI TIIII flaYS ?. UIIIT inlllMll! Il&MI Soldotna Creek/Swanson Rv 8, farm OB LJAIB IAMB 10. lille ifil) l~Ob, OI WILDCAT At SUl'~aee Swanson River Unit 19wells Soldotna Creek Unit------13 wells I Swanson River Field IUIVBT OB &AB& J Kenai Alaska 16. Check Appfolx, ate Box To IndicaJe Nature el Notice, Relx)d, or Other Data IOBIB~UII~ ~ (If: 8BOOTIMO OI AC~iNO ~ I iliW~lMlffe I~ Completion or a~ompie~ ~ ~ I (O,h.,) Temporary Abandon "l"~. DS;SOling l. IOPOStD OR CO.%IPLETED 0PglATIO.~g (Clearly state all pPrtine,t details, and =lye pertinent dates, including IgtJmated dsm of itmrt~ug prolmoed work. If wall ia di~ct~onmfly driUed, give sulmurr-ee iocsLiuns and meal, red'and true vertical depUId fei MI m&~kerl lad IOINI nan~ to ~ w°rL) * As d~ i~ the attached me~o, ARCO Alaska, h~c. requests that the following weUs have a ~mporarfly abandoned status: Sol~l~tna Creek Urdt SC/3 23B-3 SCU 21-8 * Swpn~on River Unit SRU 212-10 SRU SCU 12.4-4 SCU 341-8 SRU 14-15 SRU SCU 13-4 SCU 13-9 SRU 23-15 SRU SCU 21A-4 SCL/ 24A-9 SRU 34-15 SRU SCU 34-4 SCI3 34-9 SRU 211-15 SRU SCU 43A-4 SCU 14-34 SRU 41A-15 SRU SCU 33-5 SRU 43A-~5 SRU SRU 432-15 SRU SRU 14-22 SRU SRU * -High GOR wells that may be produced intermittently. 21-22 23-22 23-27 212-27 331-27 34-28 43-28 14A-33 24-33 32-33WD 18. I hereby cej~Af~t ~tho fo, raising Il tree and correct RECEIVED DEC I 1991 Alaska 0il & Gas Cons. CommJ~ · n~ .... ...... · /, a~u TZTLE Acting Reqional En_gineer D,i. TB (Thtl ii)ace for Federal or ,qtat~ o~ce uN) APPROVED BY CONDITIONS OF APPROVAl, I~ ~: TITLE ee-Jd~ Ind,~-fians on Reve,N Side Attachment 1 Swanson, River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A :i:~:i:~:i:i:i:~:i:~:!:i:i:i:~:i:~:i:i:i:i:i:i:i:i:i:!:!:~:~:!:!:!:i:!:~:~:~:~:i:!:i:~:i:~:i:i:i:i:~:~:i:i:!:i:~:i:~:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:~:i:!:i:i:~:i:i:!:i:i:i:!:i:i:i:!:i:i:i:!:!~:i:i:i:i:!:!:i:i:i:i:!:!:i:i:i:i:!:i:!:i:i:i:i:i:i:i:i:i:i.i:i:i:!:~:i..~:i:i:i:i..i.~:i:.::~:i..!:i:i:::::::::::::::::::::::::::::::::::i:i:i:i:i.i:i.i:i:~:i:i:i:i:i:~:~. SCU 12A-4 SRU 212-10 SCU 14-34 SCU 13-4 SRU 211-15 SRU 23-27 SCU 21A-4 SRU 23-15 SRU 14A-33 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 43-28 SRU 32-33WD SRU 24-33 11 Wells 9 Well~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i:i:i:i:i:i:i~:i:i:i:i:i:i:i:~:~::.:i:i:i:i:~:i:~:i:i:i:i:i:i:i:i:!:i:i:i:i:~:i:i:!:~:i:i:i~:i:i:i:i:!:i:i:i:i:~:i:~:!:i:i:i:i:i:i:!:!:i:~:!:i:!:i:i:!:!~:!:~:!:!:i:i:!:i~:!:i:!:i:i:i:i:i:i:i:i:i:!::;i:~:i:i:i:i:i:i:~:~:i:i:i:~:!:~:i:i:i:i:!:i:!:!:i:~:i:~:::::::::::::::::::::::::~ SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For:. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) Alaska Oil & (~as Cons. Commiss. Anchorage Added to 1992 Temporam.'.!y Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, maybe produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, $RU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 5 1 1991 Alaska 0il & (~as Cons. ~,umrnissio~, Anchoraoe Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye.ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter' of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21,22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J. C. W inn Acting Regional Engineer JTZ:jlg:0025 Attachment L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation Alaska Oil & Gas Cons. Comm'tss'tO~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures April 7, 1988 Mr. J. Dygas Branch Lease Operations Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507' RE: Sundry Notice fo~~Zl:2~ Dear Mr. Dygas: Attached is a Sundry Notice to return SRU 212-27 to gas production. We wish to test thiS well and dete~ne its potential to supply fuel gas to the Swanson River Field. SRU 212-27 was completed with a packer above the "E" zone of the Tyonek formation in October 1961. The well was used to supply gas for fuel and for re- injection into the Hemlock reservoir between 1962 and 1966. The well was f'mally shut-in in September 1966 because of high water production. SRU 212-27 was returned to production on April 4, 1988 with an initial gas rate of 1.75 MMcf/d. If you have any questions, please contact Tom Wellman at 263-4304. Sincerely, D. S. Joiner DSJ:~ cc.C c. v.t..natterron, R£C£ ¥£D Form 3160--5 (November 1983) (Formerly 9--331) UNITED STATES sum,,ZT m ~Lze&rs- (Other tnstruettoue ou re* DEPARTMENT OF THE INTERIOR ,er. md,) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or pla, back to a diftetent reservoir. Use "APPLICATION FOR PERMIT--" for such propc~alL) Form approved. Budget Bureau No. 1004-0135 Expires. August 31, 198S 5. LB&SB DBSIONATION AND SBIIAL MO. A-028406 ~. IF INDIAI. ALLOT, lB OB TRill NAMI 1. ?. UNIT &OIBIBMaHT NAIl oil [-] ~Aa ~ ~,, Swanson River Unit WEbL W~LL 2. NaMB 0r OPBIA~R 8. ~M OB ~ASB NAMB aRCO AJaska, Sac. 0. ~o. Post Office Box 100360. Anchorage, AK 99510 4. LOCATION Or WELL (Report location clearly and tn aeeordance with any State requlrements,* See also space 17 below.) SRU 212-27 10, Fm~ ANO PO0~ OB W~AT Swanson River Field, At su~a~ 1850' from N line, 1500' from W line of Sec. 27 14. PBRAIIT NO. j 15. BI~V&TMNB (Show whether I~r, rr. QB. em,) I KB Elev. = 190' Ia. Check Apl~Ol~iate Box To Indicate Nature oS Notice, Repod, or Olbe~ Dale ,IL'tl ~7one q_~c; n~nl 11. 8~., 2., L, If.,~}l aLIL Sec. 27, T8N, R9W, R~rrl RiM Kenai J Alaska NO, ICl OF INTSNTION ~: SH~T OB ACID.S ABANDON* (Other) Return to Production NO'rB: Report results of mul_tilde eompl_etlon on Well ompletton or Reeompletton Report and Lo~ form.) 17. D~;.~CRtlIE I'ROI'OSEO OR COMPLETED OPERATION.~- (Clearly state all pertine,t details, and give pertinent dates, lneludln~ ~stlmated date of.stir'illS al}} pcopo=~d work. If well is directionally drilled, ~ive sub, ur, nee loe~tions and measured and true vertical depths for all markers neat to this work.) * PROCEDURE: · Flow well into the test separator of TS 1-27 on a 6/64" choke. The flow rate should be less than 1MMcf/d; if not, reduce this initial rate by reducing the choke setting. · Record gauge information every four hours for the first 3 to 4 days of pro- duction. Notify Anchorage office if the choke setting needs to be increased due to hydrate formation. 3. After 3 to 4 days, reduce gauge frequency to 4-6 hours. Gauge every 48 hours. SRU 212-27 returned to production on 4/4/88 Initial flow rate: 1.75 MMcf/d ~s G0~s- l~. I hereby certify that the foregoing ts tr~le and correct (Thts apace for Federal or State office utm) APPROVED DY CONDITIONS OF APPROVAL, L~ AN~: TITLE DATa '*See Instructions on Reverse Side ........ ,- .. , ,-~r~ ---,--- : .... ;--~ c ............ b.~,e,i..,.I,, ~,~d u~illf, llv tn f~:~k'~ t~ any det~artment or aeencv of the "1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories' 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Eegional Engineer Cook Inlet/New Ventures HFB'jWR:ch'O006 Attachment CC: C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Form 3160--5 (November 1983) (Formerly 9--331) uNITED STATES (Other lustructious on re* DEPARTMENT OF THE INTERIOR verseMde) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ this form for proposals to drill or to deepen or plug beck to I different re~,rvolr. Usm "APPLICATION FOR PERMIT--" for ouch propomJL) orr, ~ GAf ~ 2. NAMe Or OPERATOR ARCO Alaska, Inc. ADDUCe Or oPeaATOa Soldotn~ P. O. Box 100.360 Anchora~a. AK qgs10-O3RO LOCATION or WELL (Report location clearly and 1~ a~cordanee with any 8tats requirementLe See also space 17 below.) At Sql*face Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. PERMIT NO. iIS. m, EVAT~ONS (Show whether DF. wP, mt, ets.) Form approved. Budget Bureau No. 1004--0135 Expires, August 31, 1985 §. LB&aB DEIIONATIOR AND gEnIAL BO. 0. IF IMDIAM, ALr, O'I~BB OB TRIBE NA3dm CreekTSwanson River Unit 8. il*ABM OR LmAII NAME O. WELL MO. 10, B'IBLD AND POOL; 01 WILDCAT Swanson River Field 11. 8B~., T., It., M** OB ELK. AMD 8UUVBY OR imm& I Kenai I Alaska 18. Check Appropriate Box To Indicate Nature of Notice, Report, or Olher Data N(YTICB O1' INTENTION TO: TEST WATER eliOT-GrIP FRACTURE TREAT RFIOOT OB ACIDIZB REPAIR WELL (Other) PCLL oR ALTER CASINO M ULTIPLW COM PI,RTE ABANDONe CHANGE PLANS Temporarily abandon 17. DEsf'R~Ur. raoeosEo oR CO.~IPLETED OPSRATION~ (Clearly state all pertinent details, and give pertinent date~, including ewtimated date of starting any proposed work. If well ia dit~ctionMly drilled, wive subsurface Ioe~tluu9 and measured and true vertical deptlm for all markers and lease perti- nent to this wotb-) · As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-IO · SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU 2 lA-4 SRU 43A- 15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. [ hereby cert~z..Ul.at the foregoing l~/~'ae and correct TITLE (This space for Federal or Smte o~ee use) APPROVED B! COHDITION8 OF APPROVAL, I~ ANY: TITLE DATa *See Indnmflons on Reverse Side Title 18 U.S.C. Section 100l, makes it a crime for any person knowingly and willfully to make to any department or agency of the ........................ · .... .a..,~_, ~,-* ~--,*-*~ ,,--~*~-.= ~,~*m*, ~n~' aR to nnv matter within its ,,,,o,.,,.,,,,,, TABLE I Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i tS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 COMPLETION REPORT~- RE~EDIAL ¥JORK S, TA .RD~' ,.OIL ,,,,COMPANy oF CALIFORNIA -.~ESTERN._ OPERATIONS_ INC. -Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No. A-028406 PROPERTY: Swanson River Unit WELL NO.: sRu 212-27 Section 27, T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 1920' South and 1315' East from Northwest corner of Section 27. ELEVATION: 190' K.B. K.B. is 15' above ground DATE: July 17, 1963 f~-~//~ .... '~... ~., . . C. ~. CHKTTERTON,- DistriCt 'SuPerintendent CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED REMEDIAL WORK': February 27, 1963 DATE COMPLETED REMEDIAL WORK: May 1, 1963 SUmmArY TOTAL DEPTH: 7800' PLUGS: 7750' - 7800' JUNK: One 2 3/8" tubing broach lost in hole and assumed to be near bottom. CASING: 22" cemented at 9 5/8 cemented at 5 ~' cemented at 28' 3455' 7800' 'REC£1VED AUG 13 I963 Petroleum Branch Division of Mines and Minerals Alaska Dept. of Natural Resource~ C0~PLETION REPORT - R~EDIAL WORK SWANSON RIVER ,UNIT Section 2.~ T..8 N., R._.9 W,, .Seward B & M STANDARD OIL COMPANY- OF CA~RNIA, WESTEBN OPERATIONS, Commenced rigging up at 7:00 A.M. Conditioned clay base mud. pump mud down tubing due to ice inside tubing. February_ 28, ..196B Page INC. - OPERATOR Unable to Removed x-mas tree and installed BOPE. Ran 3/4" pipe inside 2 3/8" tubing and thawed out ice down to 600' using steam. Attempted to pull tubing without success. March 1.,r_.$~ 1963 Attempte~ to thaw out ice. March 6, 1963 Set tubing plugs at 200' an~ 30'. While attempting to bleed off gas pressure above plugs~ ~s broke through ice plug, driving tubing plugs up into t[amer valve add wireline rams. Unable to close valve or rams and well blew ~s for ~ minutes before freezing itself off. March 7, 1963 Froze tubing above BOP with dry ice, removed top set up and recovered plugs. Reinstalled full opening valve and shut well in. March 8~ .1963 Replaced leaking nipple union on top of 2 3/8" tubing. Chipped ice out of tubing to 677' · ,.,l~aroh 9 -: 12, 1963 Attempted to pu~D oil down tubing at ~00 psi ~ressure. No success. Ran feeler to 67~' and ran thel~nometrie survey to 672'. Ran Otis "BW" equalizing plugs. -Set tubing plugs at 600', 53~' and ~0'. ~ad ~ psi surface pressure on tubing before setting plugs. Tubing bled to 0 psi after setting ~lugs. March 13,_ 1963 Froze tubing head with dry ice to replace series 900 BOP with series 1500 BOP. Made up series 1500 BOP on the ground. March l~,~ 196~ Removed tubing gate, 8" series 900 BOPE and 8" X 6" crossover spool to top of tubin~ head. Installed 6" series 1~00 mud cross, 6" series 1~00 Shaffer LWF preventer, Cameron QRO preventer, 0tis snubbing equipment and tubing landing ~oint. Removed dry ice and tested BOPE with %900 psi - OK. COnnEXION SWANSON RIVER UNIT 212-27 Page 3. Secti~ 27,~ T, 8 N..:~ R. ~ ..W., Seward B & STA~ oil com~A~ 'o~' CALr~RmA, ~ES~EaN OP~mTi0~S, ~. - Attempted to pull tubing loose but would not come. Apparently frozen in annulus. Pulled tubing plugs and ran inside cutter on i 3/4" pipe. Snubbed pipe in with Otis snubbing equipment. March: 16~ 1963 Ran to 67~'. Displaced mud with hot water and circulated to thaw out ice between 5~" casing and 2 3/8" tubing, Finally broke circulation through hole in 2 3/8" tubing near 677'. Marqh, 1L 1963 Out 2 3/8" tubing at 67o' with inside cutter. rams in QRC preventer and pulled donut, Pu~led i 3/4" pipe. C~n~d ~Mar~ch 18,, 1963 Pulled 2 3/8" tubing out of hole. Recovered 664' of 2 3/8" tubing. Changed rams in QRC preventer and ran 42' wash pipe. Located top of fish at 683' and washed over 42' while circulating with hot water. Pressure built up to 3700 psi. Changed over to 92 pcf mud. ..March 19~. 1963 Pulled wash pipe. Ran outside cutter and cut 2 3/8" tubing at 700' overshot and engaged fish. Conditioned hole. March 20, 1963 Pulled out with overshot and recovered one Joint 2 3/8" tubing. Tubing split and collapsed. Reran overshot and en~ged 2 3/8" tubing fish. March 21,__19_6_3 Pulled and recovered 2 3/8" tubing and packer assembly. Last 3 stands packed with dry weight material. Ran 4 5/8" bit and broke circulation with 1200~. March, 22~ 1963 Cleaned out to top of Baker packer.at 7600' at 7572 ' · Circulated and conditioned mud ~Ma~ rch 23~, 1963 Ran and.' set Baker model C retrievable bridge plug at 7271'. Laid down tubing and shut well in. Rig released to Union Oil Company at 9:00 P.M. COMPLETION REPORT SWANSON RIVER UNIT 212-27 Section 27, T.. 8~ N.., R. 9.W.~ Seward B & M ~TANDARD OIL COMPANY OF CALIFORNIA, WES'fERN OPERATIONS, Page INC. - OPERATOR Rig back on location at 6:00 P.M. March 28~ 196~ Rigged up and removed 6" - 1500 BOPE and installed new dual tubing head. 29,, 196 Reinstalled BOPE and picked up 2 3/8" tubing. Retrieved Baker packer at 7271'. Mar, 3o,_ 196 Ran a total of 142 joints 2 3/8", 4.7~, N-80, EUE 8R and buttress tubing. T~bing equipped with latch-in device. Tubing latched in Baker model "D" packer at 7600' with tail at 7609.09'. Ran and landed 1529' of 1~" heater string. Removed BOPE and installed dual x-mas tree. Tested tree with 5000 psi and displaced mud with oil. Rig released at 12:00 midnight. NOTE: Well was left shut-in to await the installation of heater facilities. ~---~000 psi on tubing and 0 psi on casing when shut-in. On April 18, 1963, while still shut-in, the casing pressure was noted to be 1500 psi and subsequent wireline check indicated tubing was parted at 5043'. Commenced rigging up for second remedial Job at 4:00 A.M. Attempted to kill well with 98 - 106 pcf mud. Conditioned mud. Pumped 30 bbls. of 12~ mud at 2000 psi down tubing. Well dead. Cosasco plug in tubing, removed x-mas tree and installed BOPE. Installed April 28, 196~ Pulled 1A~" heater string and laid down same. Pulled 2 3/8" tubing and recovered 159 Joints. Found tubing parted in split collar. Reran 2 3/8" tubing with collar on bottom and screwed into tubing fish. Pulled out of Baker model "D" packer. Apri_.l..~ .29, & 30, 1963_ Recovered all of tubing~ Ran 2 3/8" tubing open ended and conditioned mud to 96 - 98 pcf. Tagged bottom and pulled out. Reran a total of 142 Joints 2 3/8" tubing. Lost a 2 ~/8" tubing broach down hole. co~~:o~ ~E~o~ SWANSON RIVER UNIT 212-27 ' Page Section 27,_T. 8 N.._, R: 9. W., Seward B & M sm~ o~. C0~A~ OF Cin~O~mi, ~S~ ~mio~s, i~C~. ....O~A~0~ TUBING DETAIL K.B. to landing collar Landing collar Four 2 3/8" pup Joints Otis "S" nipple in position ~1 50 Joints 2 3/8", 2o~, N-80, BT R2 2 3/8" BT to EUE x-over 191 Joints 2 3/8", 4.6~, N-80, EUE 8R R2 Camco MM mandrel with CEV I joint 2 3/8" 4.6#, ~-8o, ~.u~ 8R ~ Camco D nipple One 2 3/8" pup Joint Locator sub Top of Model D packer Seating assembly with latch-in device Production tube Tubing landed in Model D packer with tail at 2%.20' 1.gO' 1.2~' 5950.~2' 13.51' 31-~5' · 90' 10.12' -5~' 5.02' 39.37' ~1.27' 1592.74' 1593.99' 754~. 41' 7557- 92' 7~89. R' 7~9o. 27 ' 7600.39' 7600.91' 7606.77' 7611.79' and landed l~" heater string at 1528.51'. NEATER STRING ,, ,, ~ . K.B. to landing collar Landing collar 1" nominal slick Joint 1" nominal X 1~" buttress 46 Joints 1~" buttress 1 Joint 1~" butress tapered on bottom Neater string hung at 1~. 32' -75' 11.75 ' .61' 1469.72 ' 31.36' 15.o7' 26.82' 27.43' 1~97.1~' 15~8. ~1 ' Removed BOPE, reinstalled dual x-mas tree and tested with 5000 psi - OK. Displaced mud with oil. Rig released at 7:00 P.M. S. R. NANSEN sPa:pb SW UNITED STATES DEPARTMENT' OF THE INTERIOR ~ GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Th, e, /ottow. in.~ ~s ~ correct repdr~ o/'-opcra~o'~s ~ prod~c~o~ (~r~ct~dO~ dritHn~ and ~) /o~ t~ ,,.o,.~ o; ............. _~~ .................. ~.~-~-, .............. ~~._m~r...~ .......................... ...................................... ~cbo~+._A~s~ ................. s~,~a . , : ;' c.'-~? ~~~: " Pho~,e ........................ ~R 7~01 ............. ~ .......................... J~ent's tine _._~Strt~ 8~e~~ ..... =-' , ' '~'% ..... o~,~o.~ o. ~.,~ o~ ...... ~'~-k-i~s .......... s,~. t '~.. I~.~.t ~.,. ' ........ , ~ ~'"'=~°' °~ °=~'" [ (~,,,o-=~)[ ~~°u~' w~"~V, ,, ..... AND ; ~VE~ DAYn ' . CU. ~T. OP OAS . , · (If drilll , degth; if shut down, a7 ~o~ ~a ~!T ~, . (a~) . Wi1 a~ ~*ed x-ms ~e. I~lled ~E a~ ~ joints Of the~E 3/8" tu~l~. F~ tubi~ ~~ t~ eo2r. kS~';, '~id ~ 1~ Jdin~s of reed 2 3/8" tubing, b~ , ~~-(~PE ~d ~lns~ x-md t~e. ~p~ee~ ~ cc: i MarShall e Service - J. B, We .Perry R. R. Rl tter [. M. Lian ~ ~4AY 14 1980 'Petroleum Branch Division of Mines and Minerals Alaska Dept. of Natural Resou.rce~ NoTr.--There were ....................................... ruus or sales of oil; ............................................... M ou. ft. of gas sold; ............................................. runs or sales ofgasoline during the mouth. (Write "no" where applieablo.) NOT~..--Report on this form is required for each calendar month, regardless of tho status of operations, and must be filed in duplicate with the supervisor by the 6th of the suoooc, ding month, unlo~s otherwise directed by the superxqsor. (;anuary 1950) UNITED STATES D~ARTMENT OF' THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval ~xpim. s LESSEE'S MONTHLY REPORT OF OPERATIONS 77~e followin~ is a correct 'repor~ of operations a~d prod~c~;o~s (includi'm$ driHin~ and produeitee' ,~,~.~) fo~ ~:~,.~ ,~o,,tn o/. ........................ ~h ............ m 63 ................... .Sy.a~O~..~.?~._U~.~ ................. ,~.~':, ~a~.~., .... P.. O, ._~..7~9 ......................... co,~,,,.~ S~.9~ ~,:.0~ c~.,. _WOZ P~on, e ~ ~-6~ .... ~ ' ........ -?=: .-. ..... I ........ ' ] a~ 7a~' a~ ~td ~ a 3/8" ~u~i~. ~g ~ lease~ to U~ 0il Co~ ~i~lled! ~PE, ~t~eve~ t ~ac~at 76~' with ~' of ~ll at 76C InsUring ~urface fa{~ilities I cc: [ U.S.O. ~ [. H. ~7st er (2) R. R. ~tter U~on t. Lisa ' Fi~s - Pr tueing ......... Norm.---There were ...................................... runs or sales of oil; .................................................. M au. ft. of ~ sold; .............................................. runs or sales of gasoline during the month. (Write "no' where applicable.) Norm. Report on this form duplicate with the supervisor by the 6th of the $ucce~ing mon~, uMe~ otherwise ~recied by the supervisor. ~ 9-329 16-~57~ O~uary (if d~ii!ing, depth; if shut dOWa, o~; dnte ~d r~ult of ~t for m in with g 5/8" top of ~r ~ab~ bri~ ~ ~m ~:~ P.M. ~r~ 2~. .~. ~rc~ 27. ~~ t~e ~xu~ a~d ma ~ 3/8" ~n~ ~ ~1 "D" '. a 3/8" e~- ~d x-~ ~e and ~rch ~, ~. 'RECEIVEff Petroleum Branch Alaska D~pt. of Naiural Re~our~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Th.e /b~lotciit~ ,:.~ a. correct report of ,'4r~.re~tion. s a~d prod'~eeLion. (inch~din~ driHin,J and produciz~ u,.~t~s) lyf t.t~, ,,~;~ o/ ...... ~~ ..... ~)6~.., Sw~son River Unit .4f~,~t'.~ a. ddr,'~s P.O. BOX 7-83_9 ............. Comp,u~.:~ STA~.D OIL .CO. OF C~IF. WOI ....................... Anchorage, Alaska ...... ~'i~nc,l C.' V; C~~T~-" ''~:'' PAo,,.c .............. BR __~20! ............................... t~ent's titl,' District .~pe~.nteg~. I ~ (3*ntO~'q t,V i I;*~Ugr~q o~ REMARKS 27. 8N No. Remedial work' commenced Febru. ~emo~ed x-~as ~ee arm install pull ~ubing. ~ry 27, 1963. Killed well, Led BOPE. Attempting to cc; U.~.G.S. - M.I H. Soys~er (2) State - T. R~Marshal! U:ISo Fish a~ Wildlife - 19hfield - q. W. Per~:y ~. R. Ri t';er M~athon - G~orge Sow~rds Union - H. Mo,J Lian Fi!e~ ' Produing , Hakala NoTm.--There were ...................................... nm~ or sales of oil; .......................................... M ou. ft. of gas sold; .............................................. runs or sales of gasoline during the month. (Write "no" where appli~tflm) NoTz.~Report on this form is required for each calendar month, regarrHess of the status of operations, and must be filed in duplicate with thc supervL;or by thu Gth of the aucce~ing month, unless otherwise directed by the supervisor. Forz~ 9-g29 PRODUCING DEPARTMENT TELEPHONE BR. 7--6;~01 C. V. CHA'I-rERTON DISTRICT SUPERINTENDENT P. O. BOX 7-839 * ANCHORAGE * ALASKA January 23, 1962 CONFIDENTIAL Mr. D. D. Bruce State Department of Natural Resources Division of Mines & Minerals P. O. Box 148 Anchorage, Alaska Dear Sir: Enclosed~ herewith, is the Completion Report for Swanson River Unit Well No. 212-27 for your informa- tion and-files. Very truly yours, C. V ~TTERTON Enclosure t-'.,':u P.- 7 '~ ~' :ATE* · :: - SUBMIT IN DUi STATE OF ALASKA <Se.<,thor m- st ructions off reverse side; OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* i ~1 ill la. TYPE OF'WELL: ' 01I:'" ~' ~S '~ ~ W ELL w g LL DR Y Other b. TYPE 0F COMPLE~ON: W ELI, OV ER E N BACK RESVR. Other ~ 2. NiSlE OF OPERATOR 4. LOC^TION O¥ WELD (Report location clearly and in accordance with any state requirements)* At surface At top prod. interval reported below At total depth DATE .~OMP SU.SP OR ABAND. ]16. MD & TVD[20. IF iVI'ULTIPLV. COM~L., HOW 1W.A~ Y* EII~EVATIONS (DF, RKB, 13. DA.T.E SPUDDED [14. DATE T.D. I~E~CHED 18, TOTAL DEPTH, ~LD & TVD~9. PLUG, B~CK ~. PRODUCING IN~VAL(S), OF ~IS CO~TIO~--~P, BO~OM, NAME (MD AND ~)* 24. TYPE ELECTRIC AND OTHER LOGS RUN t 2 1'ROTARY TOOLS APl NUM. J?A{ICAL CODE 6. LEASE DESIGNATION A.ND SERLA. L NO. 7. IF INDIAN, AJ-~OTTEE OR TRIBE HA_ME 8. UNIT,FA/I/Vi OR LF-~kSE NAME 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. pI~R1ViIT NO, RT, GR, ETC)*Jl7. ELEV. CASINGtIEAD INTER'PALS DRtI, LED BY CABI,E TOOLS [23. WAS DIRECTIONAL SURVEY MADE case~c~ s~zE ] w~,m~z; Lp?T.t 26. LINE~ I~CO~ CASING RECORD (Report all strings set in well) I'(~RADE 'i DEPTH SET (MI)) HOLE SIZE '~EIRFO1RATIONS OP¢-/N TO PRODUC~ON' ~intcrval, s~%e and nurn'~er) CEMLNTING RECOH.D A2~IOUNT PULLED Illll I II I 27. TUBING RE~OI~D :ACID, SHOT, Fi~CI'URE, C~,IENT SQUEXZE, ETC. D~IIi 1NT~V.~ (MD) ~5iOUNF Z~D I'2iND OF A,IAI~3~AL US~ 30. : PRODUCTION DATE FIRST P£~ODUCT[ON I :FRoD;ucT1ON MEIHO'D (Flov.4'ng, gas lif~, pumping--size and type of pump) HOURS TESTED .' ']CttOKE SIZE [PROD'N FO.t~ oIL--EDL. GAS~--iV~CF. FLOW, TUBING CA~t2qG PRESSURE [CALCULATED OIL--BBL. GAS--r4fCF. 31. DISPOSITION O~ GAS (Sold, used for '~uel, vented, etc.) [ 2}2. LIST OF ATTACHMENTS [ V/ELL STATUS (Producing or ~nu[-in) ]W£,TEI-i~BBI~. [ GAS-OIL IL%TIC WA:--BBL. ~OIL GRAVITY-~I (CORR.) 1 , , TEST WITNESSED BY 33.'I hereby certify that the foregoing and attached information is complete and correct as determined from all--available records *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJuci~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing. the acklitional data pertinent to such interval. Itom26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced, (See instruction for items. 20 and 22 above). 34. SUMMAH. Y OF FORMATION TF2~'I'S INCLUDIN(; INTERVAL TF_~TEI'), I~'I:~E.~k'~IJRE DATA. ,~l~,k.z~T~r ~OVL~I~-~S OF OIL~ GAS, WATEr( AND MUD 36. COIl. E: DATA, A.~I'I'~(CI[ l~'RIE~r' I~ES~P,~'~'-~D:~'S (~I~:-L~I..TtIOL;OG¥;. PO~OS.I~,Y.. F[IA:C~R~. ~N~-~R~, AND~' D~PEC~'~ SHOW, S, OF" OIL. GAS:,' O11'- IVA~I~ NAME GEOLOGIC COMPLETION REPORT - NEW ~J24 STANDARD OIL COMPANY OF CALIFORNIA, WESTERN GPEPA.TIONB INc, OPERATOR A/~EA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Swanson River Unit IAND OFFICE: A~chorage Lease No.: A-028~06 WELL NO.: SRU 212-27 SECTION 27, T. 8 N., R. 9 W., SEWARD B &M. . _.~ LOCATION: Surface: 1920' south and 1315' east from northwest corner of Section 27. ELEVATION: 190' K.B. DATE: January 12, 1962 BY: K. B. is 157 above ground. C. V. CHATTERTON, District Su~t. - ' Il ' I ........ I I Lr I I ' I ....... Illil I I I S~ TOTAL DEPTH: 7800' PLUGS: 7750 - 7800' CASING: 22" conductor pipe cemented at 28'. 5/8" casing cemented at S455', with 1620 sacks cement. First Stage around shoe with BSO sacks, second ~ through-'-'~ at 15S2' with 1240 sacks. ~" casing cemented at 7800' with 1100 sacks cement. _Fir~st_ stage around shoe with 600, and second .stage_ through DV at ~30' With 500 sacks. COMPLETION ~ORT SE. CTION 27~. T. 8 N,, R. 9. W:,oz.~a~xu ..... B & M S~~ 'o~L c0J 'oF- CAL~OaN~A, W.O.~. - O~.m~0~ Page 2. PERFORATION ~EECORDS: (Holes in 9 ~/8.~ cast~, c~t~,~e, off behind ~" casin~) .~ ~,, hoies/fOo~ 2~0 i 2~0,, 30i8 - 3528~, 3152 - 3162') $ }" holes/f0bt 7625 - 7635~'. 33k2- 3352' WELL SURVEYS: le 3. 5. 6. 7. 8. 9. 10. Schlumberger Neutron Collar log, interval 2~09 - 3~09'. Schlumberger Induction Electrical log, interval 100 - 3700'. Schlumberger Sonic log, interval 100 - 3694'. Schlumberger Micro log, interval 2400 - 3698'. Schlumberger Induction Electrical log, interval 3698 - 7799' Schlumberger Sonic log, interval 3450 - 7797'- Schlumberger Micro log, interval 6798 - 7798'. Neutron Collar log, interval 7200 - 7752'. Schlumberger Cement Bond log, interval 2200 - 7752'. Baroid Daily Mud log, interval 2000 - 3700'. DRILL STEM TESTS: " holes/foot 2890 - 2900'~ "holes/,foot 3018 3028' holes/.foot 3152 3162' i!! o es,,oot : holes at 7620'. W. S. O. Page 3. August,, ,~0~, ,1961,, Spudded at 8:30 P.M. Drilled 12~" hole 0 - 318' August. 21~, ,196% 1~,~,'' Drilled ~ hole 318 - 2, 126' AugRst ..22, 196~ Drilled 12~" hole 2, 126 - 3, 000' Drilled 8 3/4" hole 3, ooo - 3, 575' Augq,st, 23~ 1961 ~ Drilled 8 3/4" hole 3, 575 - 3, 700' 318' drilled 1, 808' drilled 874' drilled 575' drilled 125 ' drilled 86 pcf mud 92 pcf mud 95' opened 86 pcf mud August 24~ 196% Reamed 12~" hole 1, 600 - 3, 000' O~ened 8 3/4" hole to 12~" hole 3, 000 - 3, 095' 1, 400' reamed Opened 12~" hole to 15~TM hole O - l, 600' l, 600' opened Ran in with open end drill pipe and circulated. Ran Schlumberger I-ES log over interval 3700 - 100'; Sonic log 3694 - 100'; and Micro log 3698 - 2400' 88 pcf mud COMPLETION REPORT SWANSON RIVER UNIT 212-27 SECTION 27, T. 8 N., R.. 9 W., SEWARD B & M STANDARD OIL C0. 'OF ~LIFORNIA, '"W.6',I'[' ~-~OPE~ATOR Page 4. Au~st 25, 1961 Opened 8 3/4" hole to 12~" 3, 095 - 3, ~65' 370' opened Ran 87 joints 9 5/8" casing. Cemented 9 5/8" casing at 3455' in 2 stages with 1620 sacks of cement using Halliburton power.equipment. Used I top plug. First Stage around shoe with 380 sacks of cement. Pumped 25 bbls. of water ahead, mixed 380 sacks of cement in-17 mins. using Halliburton truck, displaced in 25 rains, using rig pumps. Average slurrY weight llS~. Bumped plug with 2000 psi. Full circulation. Secgnd Sta~.e through DV at 1532'. Dropped DV bomb, opened DV ports in 15 rains. Pumped 50 bbls. of water ahead, mixed 1240 sacks of cement in ~8 rains, using Halliburton truck, displaced in 13 rains, using rig pumps. Average slurry weight i18~. Closed DV ports with 2000 psi. Full circulation. Cement in place at 8:30 P.M. Hookload weight of casing before cementing 120,000~, and after cementing before landing casing 80,000~. CASING DETAIL: K. B. to landing head 38 joints 9 5/8" 40~ 8 R- J-55 Top DV Collar DV Collar 49 Joints 9 5/8" ~0~ 8 R- J-55 including shoe and float collar Casing cemented at 15.35' 1922,58' 345~.6~' August,,,26, 1961 Installed and tested BOPE w/2000~ psi, held OK. Ran in with 8 3/4"' bit and drilled out DV and tested with 1650~ psi, held OK. Tested Hydril with 1500~ psi, held OK. Drilled out baffle plate at 3372' and cleaned out cement to 3400'. Ran Neutron Collar log over interval 3409 - 2409'. Shot ~ ½" Jet holes per foot 2890 - 2900' for HCT ~l. COMPLETION REPORT SWANSON RIVER UNIT 212~27 .. S~CT~O~ 27, ..T. 8...~,,. R. 9 ~-~ .... S~WA~. ~ ~ ~ ~ STANDARD OIL CO. OF CALIFORNIA, W. 0.I. - OPERATOa Page 5- August, 27, 1961 Ran HCT ,~,~ 2,8,90 -,2900'. Tool assembly: 2 outside BT recorders, 8 feet of perf'd tail pipe, 9 5/8" Type C, hookwall packer, VR safety Joint, hydraulic Jars, 1 inside BT recorder, hydrospring tester, 95' of dry 4½" dril.l..p, ipe and TC, adjustable valve. Used no Water Cushion. Ran on 2720 feet of~ drill pipe. Set packer at 2839', with 22' of tail to 2861'. Opened tester at 11:04 A.M. for 30 min. ISI pressure. Opened tool to surface at 11:34 A.M. for 4 hr. 8 min. flow test. 11:34 A.M. - 12:46 P.M., medium blow, decreasing to dead. 12:46 P.M. - 3:42 P.M., strong blow, fluid to surface 1:04 P.M., allowed to clean up and adjusted bean while flowing to sUmp, fluid to trap 1:30 P.M., flow test 2:15 P.M. to 3:15 P.M., 1010 B/D rate oil, 150 MCF/D gas, surface pressure at head 250 psi, trap pressure 78 psi. Shut in tool at 3:42 P.M. for 74 min. FSI pressure. Pulled packer loose at 4:56 P.M. Ail oil circulated out, except bottom 95' oil. Pres ,s,ure D~t_~a~: IH ISI IF FF FSI FH Depth Gauge Top inside (2829) 1696 1177 912 1065 1200 1644 Top outside (2850) 1694 1164 1000 1055 1175 1629 Bottom outside (2855) 1678 1153 1012 1039 1155 1611 Cuts & Gravities: , Corrected Time o API Wet OF °API Total - ___1_ :: ~ ~ ~: ...:_ , . : : .- 2:10 34.5 74 33- 5 6.6 2:30 35,6 83 34,0 5,0 2:45 5,8 3:00 9.,0 3:15 34,1 89 3~,1 14,o 3:30 34.,0 83 32,4 ll,O Cut ~ Water Emulsion 4.4 -- 2.2 3.6 -- 1.4 3.4 -- 2.4 4.0 2.6 2.4 7.0 6.0 1.0 7.8 2.0 1.2 sample from bottom 95' of drill pipe. Perforated 4 ½" holes/foot, the interval 3018 - 3028'. COMPLETION REPORT SWANSON RIVER UNIT 212-27 sEc o 27. Sm. _9, ,, STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 6. August _28, 1961 Tool assembly: 2 outside BT recorders, 8' of perf'd, tail pipe, 9 5/8" Type C, hookwall packer, VR safety joint, hydraulic Jars, 1 inside BT recorder, hydro- spring tester, 95' of dry ~" drill pipe and TC adjustable vmlv~. Used no Water CuShion. Ran on 2836 feet of ~" drill pipe. Set packer at 2960', with 22' of tail to 2982'. Opened tester at 1:54 A.M. for 36 min. ISI. pressure. Opened tool to surface at 2:30 A.M. 2: 30 A .M. to 3:12 A.M., medium blow decreasing to dead. 3:12 A.M. to 9:06 A.M., strong blow, fluid to surface at 5:15 A.M., turned to trap 5:30 A.M. Gauged 612 B/D rate, 34.2°, 90 - 128 MCF/D, 10~ cut, (7.8~ water, 1.0% emulsion, 1.2~ S & M. ). Shut in tool at 9:06 A.M. for 53 min. FSI pressure. Pulled packer loose at 9:59 A.M. Recovered 90 feet net rise, air chamber backscuttled oil from drill pipe. Pressure Data: IH ISI IF FF FSI FH Depth Gauge Top inside (2950) 1728 1237 425 1060 1250 1728 Top outside (2975) 1737 12~2 475 105'5 1247 1737 Bottom outside (2980) 1720 1220 ~77 10S2 1231 1720 Cuts & Gravities: Wet Time Gravity 6:00 6:15 6:3o 6:45 36.3 7:00 7:30 8:00 Corrected Cut % °___E__F Gravity Tota~ Water Emulsion S_~& M 89° 34.2 16.o o.o 6.0 lO.O 13.0 3.6 3.4 6.0 8.0 4.0 2.4 1.6 3.0 1.o 1.4 0.6 4.4 3.0 1.o o.~ 6.0 3.4 2.4 0.2 16.0 12.0 1.4 2.6 10.0 7.8 1.0 1.2 Perforated 4 ~" holes/foot, the interval 3152 - 3162'. COMPLETION EEPORT SWANSON RIVER UNIT 212-27 STA/IDAED OIL CO. OF C2LI~FORNiA, W.O.I. - OPERATOR Page 7' ~ ~CT.,..-~3 3152- 3162'. : Tool AssemblY: 2 outside BT recorders 8' of perf'd. ~tatl pipe, 9 5/8" T~e C hookwall packer, VR safety Joint, hydraulic jars, i inside BT recorder, hydro- spring tester, 95' dry ~z drill pipe, and TC adjustable valve. Used no Water Cushion. Ban on 2989' of.4~" drill pipe.. Set packer at 3113', with 22' of tail to 3135'. Opened tester at 8:45 P.M. for 30 min. ISI pressure. Opened tool to surface at 9:15 P.M. for 174 min. flow test. Surface Bean -~" ~", Subsurface Bean- strong blow of air. Fluid to surface in 40 min. at 9:55 P.M. Shut in,. turned to traps at l0:05 P.M. Gauged at 12:00 P.M. 9lO B/D rate, 32.9°, 138 MCF/D. Cut 9.2~, 7.9~ water, 1.2~ emulsion, 0.7~ S & M. Shut in tool at ]2:09 P.M. for 42 min. FSI pressure. Pulled packer loose at 12: 51 P.M. Recovered 90" net rise, oil - backscuttled rise. Pressure Data: IH ISI IF FF FSI FH Depth Gauge Top inside (3103) 1799 1304 1019 1131 1315 1795 Top outside (3130) 1793 1286 1028 1115 ]286 1783 Bottom outside (3134) 1769 ]269 1000 1100 ]273 1769 Cuts & Gravities: Wet Corrected Time Gravity oF .... ..Gravity Ga__~s B/D Total.._ lO: 15 168 1060 9.0 lO: 30 165 lO6O .8.0 lO:45 150 880 6.0 ll: O0 36.6 85° 34.8 130 720 4.0 ll:15 147 930 9.0 11:30 149 893 9.0 1l:45 14~ 807 8.0 ]2:00 34.2 79° 32.9 138 910 9.2 Cut % water Emulsion S & M 2.0 6.0 1.O 3.6 4.0 0.4 3.2 2.6 0.2 1.9 2.0 0.1 7.9 1.0 O.1 7.9 1.O O.1 6.7 1.2 0.1 7.9 1.2 O.1 Page 8. Augu_.s.t 29, .196.1.. Made re-run with 8 5/8" bit to 3400'. Circulated and conditioned mud. out. Perforated 4 ~" holes/foot, the interval 3~42 - 3352'. Pulled l~,n,~CT, -~,,4 $342 ..- 33~2'. Tool assembly: 2 outside BT recorders, 8' of perf'd, tail pipe, 9 5/8" type C hookwall Packer, VR safety, joint, hydraulic Jars, i inside BT recorder, hydro- spring tester, 95 '- dry 4~ drmll pipe, and TO adjustable valve. Used no Water Cushion. Set packer at 3300', with 22' of tail to 3322'. Opened t~ster at 10:49 A.M. for 30 min. ISI pressure. Opened tool to surface at 11:23 A.M. for 167 min. flow test. ~" subsurface bean and ½" surface bean, strong blow of air. Fluid to surface at 12:00 A.M. (32 mine. ) Slightly oily drilling mud. Oil and g~s to surface at 12:05 P.M. Gauge at 2:15 P.M., 780 B/D rate, 130 MCF/D Gas, 10.2~ total (9.4% water, 0.8~ emulsion, trace S & Shut in tool at 2:17 P.M. for 53 min. FSI pressure. Pulled packer loose at 3:10 P.M. Recovered ~0' net rise, below TC valve backscuttled oil. p~r.es, sure~ Data: IH ISI IF FF FSI FN Depth Gauge Top inside (3290) 1933 1384 lo80 1185 139o 1933 Top outside (3318) 1887 1373 1097 1168 1364 1887 Bottom outside (3322) 1863 1329 1051 1139 1333 1863 Cuts & Gravities: ........ Corrected Time, ~ MCF/D .Gra .v.i. tY .T0ta.~ P.M. 12:30 970 154 34.8° 3.0 12:45 855 154 4.1 1: O0 6 31 148 4.0 l:15 930 142 4.2 1: 30 842 14Z 4.8 1:45 790 138 33.4° 7.4 2:00 798 135 9.2 2:15 78o 13o 32.7° 10.2 Water Emulsion S & M ,, ......... ,! _ 1.6 0.5 0.9 1.o 1.6 0.4 2.4 1.2 0.4 3.6 0.8 T 4.4 0.4 0.0 6.6 0.8 0.0 8.4 0.8 T 9.4 0.8 T Ran in with open end drill pipe to 2500' and displaced 30 sacks cement with 31 bbls. mud. Removed BOPE. 82 pcf mud COMPLETION REPORT SWANSON RIVER UNIT 212-27 STA~ OiL CO'OF' '~L~~~ "W:"6'i :' -'-OPERA~OR Page 9- August 30~. ,196,1 Installed tubing head and re-installed BOPE. Tested with 1500 psi, held OK. Ran in ? 5/8" bit and drilled out cement 2536 - 2561'. Cleaned out to 3400', conditioned mud. Pulled out. Installed 2 7/8" tubing rams. Ran 107 Joints 2 7/8" tubing with pup joint and one beveled collar on bottom. Landed tubing at 3376'. Removed BC~E and installed and tested X-mas tree with 3500~ psi. 82 pcf mud Changed over from mud to oil and flowed well. Started running production test at 7:20 A.M. Oil/~Water Casing Tubing Total Date :Time .... _B/D .... Pressur__e Pressure ,Cu~, ~ ,M0~F Cas Beaq Siz~ 8-31-61 9-1-61 9-2-61 9-3-61 9-4-61 9-5-61 9-6-61 7:20 AM-I:O0 PM 668/262 1:OO PM-8:00 PM 667/~258 8:00 PM-3:00 AM 490/385 3:00 AM'8:OO AM 456/,4O6 8:00 AM-4:00 PM 303/259 4:00 PM-12:00 AM 225/198 12:00 AM-8:00 AN 205 199 8: O0 AM-4: O0 PM 209/178 4:oo PM-12:oo AM 18~/183 12:00 AM-8:00 AM 184/170 8:OO AM-4:00 PM 187/173 4:00 PM-~2:00 AM 169/169 12:00 AM-8:00 AM 160/155 8:OO AM-4:00 PM 175,/160 4:00 PM-12:00 AM 144~152 12:00 AM-5:00 AM 130/147 5:0o AM-9:oo AM 134/129 9:oo AM-l:OO PM 14~ ~135 1:0o PM-5:00 PM 156/.150 5:00 PM-9:00 PM 197/,187 9:00 PM-i:O0 AM 159/171 l:OO AM-5:oo AM 153/171 50 250 28 73 32/64" 80 225 ~/~ 32/~64' 80 225 47 44 32/64" llO 225 ~6 20/64" 125 225 47 20/64" ~5 225 ~ 43 20~6~" 130 220 ~ 20~64" 130 220 50 20~64" ~5 200 ~ 36 20~64'.' ~5 ~oo ~ 2oZ64" ~5 2oo 5o 2o~64" ~5 200 ~5 ~oo ~ ~o/6~" ~3o ~95 52 2o~6~'~ 1~ 220 53 36 20~64" 130 200 49 ~5 200 49 20~64'; ~5 2O0 130 200 49 20~6~'~ 135 190 52 20~65" ~35 190 53 32 20/64" Septemb.,e,r 7,~,,, 1,9,61 Finished flowing well at 8:00 P .M. Killed well with mud. Page 10. September 8. 196,1 Circulated. Removed Christmas tree and installed BOPE. Pulled out tubing to 1948' and pumped in low pH mud pill. Pulled tubing to 1765' and pumped in 40 sacks of cement for safety plug. Pulled out and laid down tubing. Removed BOPE and took off tubing head. Re- installed BOPE and tested plug and BOPE to 750~ psi for 30 min. - OK. 85 - 87 pcf mud ~ePte.mbe.,r 9~ 1.96.1 Picked up ~" drill pipe. Cleaned out cement to 1760'. Pushed plug from 1760 - 2600'. Drilled out cement and float collar at 3412'. Cleaned out to 3700 ' · Drilled 8 3/4" hole 3,700 - 4,045' Septembe,r 10 &....ll,~, 19,6,1 Drilled 8 3/4" hole 4,045 - 4,986' Se~ptember .127. 1,96! Drilled 8 3/4" hole 4,986 - 5,113' Increased mud weight to 90~ per. Drilled 8 3/4" hole 5,113 - 5,435' Septembe.r. !3. ..- 1.7~.. 1961 Drilled 8 3/4" hole 3,435 - 6,868' 345' drilled 941' drilled 127' drilled S22' drilled 1, 433' drilled 83 pcf mud 83 - 84 pcf mud 84 pcf mud 90 pcf mud 91.5 - 94 pcf mud COMPLETION BEPORT SWANSON RIVER UNIT 212-27 SECTION 27, T. 8 N., R.~gw~, SEWARD B & M STA OIL CO" OF' CAL FOaN , W. O,I. '- September 18, 1961 _ Drilled 8 3/4" hole 6,868 - 7,000' Lost circulation on trip at 7, 000'. Mixed lost circulation material and pulled to 5,000'. lation. 132' drilled Pumped in 120 bbls. of mud. 95 pcf mud No returns. Drillea 8 3/4" hole 7,000 - 7,046' Lost approximately 20 bbls/hr. terial. Drilled 8 3/4" hole 7,046 - 7,064' Lost approximately 60 bhls. mud/hr. 46' drilled Circulated ½ hour, mixed lost circulation ma- 18' drilled Pulled out and ran in with ~" open ended drill pipe and pumped in 50 bbls. low pH mud at 3384', displaced with 38 bbls. mud. Pulled up to 2706' and pumped in 100 cu. ft. water, followed by 200 sacks of cement, displaced with l0 cu. ft. of water and 206 cu. ft. of mud. Plug in place at 10:45 PM. Pulled up to 2520' and circulated. Septe.~.mbe.,,r 20¢ !~.6.1 Stood cemented ll hrs. Located top of cement at 3175'. Drilled out medium hard to soft cement 3175 - 3555'. Pulled to 3100', conditioned mud. Hung drill pipe at 3385'. Pumped in 50 bbls. of low pH mud. Pumped in 100 sacks of cement. Closed Hydril and pumped in 200 sacks cement, displaced with l0 cu. ft, of water and 217 cu. ft. of mud. Cement in place at 8:30 PM. 95-5 - 97 pcf mud ~Septe.m. ber. 21,,, 19.61 Stood cemented till 5 A.M. Ran in and located top of cement at 2681'. Drilled out hard cement 2681 - 3481'. 92.5 - 95 p cf mud September 19, 1961 Pulled up to 3, 300', regained circulation. Ran in to 4,656', circulated ½ hour, ran in to 7,000'. Hole taking mud at 60 bbls/hr. Did not regain circu- C~LETi0N REPORT STA/IDARD OIL CO, OF'C~FOPdIiA, W'0.i, OPERATOR Page 12. Septemb~rj~22~ 1962 Drilled out cementi 34~1 - mud. Cleaned out ~ 7664 Drilled 8 3/4" hole 7,064 - 7,199 ' No mud loss. September 23~ l~61 Drilled 8 3/4" hole 7,199 - 7,430' Septemb .e...r... 24, 1961 Drilled 8 3/4" hole 7,430 - 7,550' Cored 7 5/8" hole 7,550 - 7,562' Sep~tember 25, ~1961 Cored 7 5/8" hole 7, 562 - 7,606' Core ~1: 7550 - 7574' Core ~2: 7574 - 7598' September 26, 1961 Cored 7 5/8" hole 7,606 -. 7,616' Core ~3: 7598 - 7609' Core J4: 7609 - 7615' Core. ~5: 7615 - 7616' 3510' ~ ~n to 506~') circulated and conditioned 135' drilled 96 - 97 pcf mud 231' drilled 97 pcf mud 120' drilled 12' cored 97 p cf mud 44' cored 24' cut & recovered 24' cut & 20' recovered 97 pcf mud 10' cored. 11' cut 9' recovered 6' cut & recovered 1' cut & recovered 97 pcf mud COMPLETION REPORT SWANSON RIVER UNIT 212-27 1 ssc~o~ ~7,. ~. s ~., ~. 9 w., ssWA~o ~ ~ ~ . s~mmao o~ 'co. o~cA~O~; '~:o'.~, - o~Sm~o~ Page 13. September 27, 1961 Cored 7 5/8" hole 7,616 - 7,619' Core ~6: 7616 - 7619'' Core ~4, ~5, and ~6 were jammed. Opened 7 5/8" hole to 8 3/4" 7,550 - 7,619' Drilled 8 3/4" hole 7,619 - 7,621' Cored 7 5/8" hole 7,621 - 7,642' September 28, 1961 Cored 7 5/8" hole 7,642 - 7,701' Core ~7: Core ~-8: Core ~9: 7621 - 7645' 7645 - 7669' 7669 - 7693' 3' cored 3' cut & recovered 69' opened 2' drilled 21' cored 59' cored 24' cut & recovered 24' cut & recovered 24' cut & recovered .S..eptember 29, 1961 Core ~lO: 7693 - 7701' Opened 7 5/8" hole to 8 3/4" 7,621 - 7,701' Drilled 8 3/4" hole 8' cut & recovered 80' opened 97 pcf mud 97½ per mud 7,701 - 7,800' T.D. 99' drilled. Circulated and conditioned mud to log. Attempted to run I-ES log. Tool stopped at 7462'. PUlled out. Reran bit and cleaned out to bottom. 98 pcf mud COMPLETION REPORT SWANSON RIVER UNIT 212-27 STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 14. .Sept.ember. $0, 19~ Ran Schlumberger. Induction-Electrical log, the interval 7799 - 3698', Sonic log 7797 - 3450' and Micro log 7798 - 6798'. Circulated and conditioned mud for 5~2" casing. Laid down 4½" drill pipe. Started running ~" casing. 98 pcf mud 00t~,~, ~' l~ ~ i~ 1961 ~!,, casing. Ran 183 Jnts. of ~2 Cemented 5~2" casing'at 7800' in two stages with llO0 sacks of cement treated with O. ~ ~R-4 using Halliburton power equipment. Used i top and i bottom rubber plug. 1st Stage around shoe with 600 sacks of cement. Pumped 30 bbls. of water '~head, mixed 600 sacks of cement in 20 mins. using Halliburton truck, dis- placed in 16 mins. using rig pumps. Average slurry weight ll6~. Bumped plug with 2000 psi. Full circulation. 2nd Stage through DV at 4430'. Dropped DV bomb, opened DV ports in 17 mins. Pumped '30 bbls. of water ahead, mixed 500 sacks of cement in 16 mins. using Halliburton truck, displaced in 9 mins. using rig pumps. Average slurry weight ll6~. Closed DV ports with 200 psi. Full circulation. Cement in place at 3: 25 A.M. Hookload weight of casing before cementing 103,000~, and after cementing before landing casing 104,000~. CASING DETAIL: Top 104 joints or DV Collar at 4, 430' Next 71 joints Marker Joint 7 joints 3, 048.46' ~2~!'" 17~ 8 R 12.95' 308.61' ~" 17~ 8 R 7,817.07 ' Above K.B. ~ 17.. 97.' Casing cemented at 7,800. ' Removed BOPE. Landed 5~2" casing. Installed tubing head. Reinstalled BOPE. Tested secondary pack-offs with 3500~ Psi and BOPE with 1800~ psi. Drilled out DV at 4430'. COMPLETION REPORT SWANSON RIVER U~T 212-27 SECTION 27, T. 8 N. ,~ R._ 9 W:,.... S.E..WARD B & M STANDARD 0IL CO.' OF '~I~~'"~,O.I. - OPERATOR Page 15. October 2 and~3, 1961 Tested DV with 2000~ psi, OK. Tested pipe rams and ~Kelly Cock with 2000~ psi for 30 mins., OK. Drilled out Baffle Plate at 7709' and cleaned out cement to 7750'. Circulated and conditioned m~d. Ran Schlumberger Neutron Collar log the interval 7752 - 7200' and Cement Bond log 7752 - 2200'. Perforated 5 ~ holes at 7620' for EC~l. ~,. !1 · Halliburton casing~ test. ~.on 5 ~ holes at 7620' Tool Assembly: 2 outside BT Recorders, 3' of 2 7/8" perf'd, tail pipe~ ~" Hookwall packer, VR safety joint, hydraulic Oars, 2 inside BT Recorders, hydrospring tester, and dual closed-in valves. Used no water cushion. Run on 7556' of 2 7/8" EUE tubing. Set packer at 7580' with 16' of tail to 7596' Opened tester for~4 rains. Initial Flow at 10:53 P.M., dead. Closed tester for 30 min. Initial Shut-in Pressure at 10:57 P.M. Opened tester for 35 rains. Flow Test at 11:27 P.M., dead for 23 rains. (till ll:50 P.M.) then immediate strong blow with tubing pressure increasing to 2800 psi by 11:53 P.M. (approxi- mately 3 mins- ). Tubing pin and Chicksan joints began leaking. Closed wing valves and pulled packer loose at 12:02 A.M. to kill well. Annulus mud began bubbling gas slightly. Started to bleed down tubing at 12:20 A.M. and pulled tubing (started pulling a't l:O0 A.M. ). Recovered 140' net rise, all ' drilling fluid testing 0.95 ohm at 50° F. or 75 G/G. Ditch tested 0.91 ohms at 65° F. or 100 G/G. PRESSURE RECORDER DATA: (Final Pressures) Depth ' G~uge IH ISI IF FF FSI FH Top Inside 7566 5076 29 29 29 - 5062 Bottom Inside ' 7570 - 37 37 40 - - Top Outside 7590 - 49 49 50 - - Bottom Outside 759~ - 46 46 50 -. - Circulated and conditioned mud. Built up mud weight from 97~ to lO0~ pcf. Laid down 2 7/8" drill pipe. Started picking up 2 3/8" tubing. octo ,e, Picked up 2 3/8" tubing. Circulated. Perforated 4 ½" holes/foot the interval 7625 - 7635'. Set Model "D" Packer, ran on Schlumberger line at 7600'. Ran in with 2 3/8" tubing as follows: COMPLETION REPORT SWANSON RIVER UNIT' 212-27 _s~oN 27, ~W, 8~.~N~,R. 9_ ~.~_ SEWA~ B & M~ STA~RD OIL CO ~ OF CALIFORNIA, W.O. I. - OPERATOR Page 16. ojgtgbe,r' _4~ 1~,61 C_o_n_t_i_n_u.e_d_ 79 1/3 stands or 7,550-25' Pup Joint 1.90' Pup Joint 14.92' Brown Model "D" Packer 17.12 Cellar to K.B. 15~45' Cellar to donut 2. -- ' 2 3/8" tubing 7600 ' Tubing landed at 7,601.62' 0ctgb~er 5, 1961 Removed BOPE. Installed Christmas tree. Tested Christmas tree to 5000~ psi, Ok. Attempted to open sleeve valve, would not open. Removed Christmas tree and reinstalled BOPE. Pulled tubing above .packer and displaced mud in tubing with 28 bbls. of water. Relanded tubing. Removed BOPE and reinstalled Christmas tree. ooto~r~ .6, ~96~ Flow tested well. Installed Cosasco plug. Well shut in pending testing facilities. Rig released 8:.39 P :M~,~ iOctOber 6. 1961. COMPLETION REPORT SWANSON RIVER UNIT 212-27 SECTION 2% T. 8 N., R. ~ W., SEWARD B & M s~A~ O~L CO, Page 17. oe~t~ ~:LSi 2,; 12i5' 3, o0o i 6~o23~ 6,93?' DEVIATION DATA Degrees o° oo ~5,~ 0° 30 ' 0° 30' ~o ~, ~o WELL RECORD [NVEhlTORY Field: Swanson River Unit Location _ _. ~8.?.~9..W., Sec;. 27,. S._M... Name 1. Drilling Permit: Standard Oil Co. .... Unit .#212-27. I Il [ No. Pages 2. Survey Plat: 3. Month ly Reports (P-3): Completion RePOrt (P-7): 5. Well History: 6. 0ther: _ 7. Mi s ce 11 aneous: 8. Deviation Survey(s): 9. Well Logs: (1) . CB~ (2) SL Total Pages: (3) ~L (4) IEL (5) . NEUT _.. (7) i i i il il U l J:. i (8) (9) .... ' ii im ii i I - i i iii · i il UNITED STATES DEPARTMENT Of THE INTERIOR. GEOLOGICAL SURVEY Hudgct. B:'."eu:! .x,%.-/:J-t~33rllL LESSEE'S NIONTHLY REPORT O? OPERATIONS 6'tare ......... _~A.~_as.k_& ............... C'o~r, ty _K.~nai._Peninsula ..... kTeld Swanson River ..... Tl~c foHo'win.~ is a corrcc~ report; of ~pera~ion. s ~u~d p;'oduc!io;~ ~'t'~t,/'~,L,.::; ,,','i!lin~j an.,'t prvdu, ch~ wells) lot tt~e ~on. lh, o1' . ~tober ........... '$, 6~, Swam:on River Unit '-~ ............. St~~ Oi~ C©. ~"~t~- ..... i i , GALLONS o~' ~ B, t~.t.~ ,,v ];EMA ~ OF ~ . RANGX NO. [ P..;uuc~:~ ~ BAgR~!~ OF OiL I ~::~x';TY (tn tLousands) REt (~VEI;~:I) j YV)~It', k., S[alv, da.. a:. I :,,,.uft ....... , __ - .... ~ ................. ...... , .':'~!""':' [ I 8. wt Drilled out D.V. ahd te~ted w/20~, OK. Cl~mned ~t cement to 77~O'. ~ r~ CBL :~d NCL 7792~-2~OO"~ ~ HCT ~1 o~ ~ - 1/2" holes ~ T~St inconclustve.~ Perforated ~ ~ 1/'" h01:~s/root the interv~ ~ 76~,.7~~. Set packe~ $ 7600~ 'Ran ~d la, ed 2-3/8" tubing 7698'o Inst~led ~s Sree. TestBd. w/~OO0/~,~. ~ ~t~e~ted. to open · BO~E~ ~lled tubing above Oacker, disOl~ed mud i~ ~blng with 28 ~bbls ~ater. ' ~]anded tubing ~- 7608~, 'removed B~nE~ reinst~l~ Fl~ed ~11 bo clean up, no rates o~ ~ell shut-in pending installation of ~test~g f~cilit~s~ ' ~ : , released CC U.S~.G.S M.H. Soyster - 2 Alaska ~ CC- D. eD. B~ce ~ · C. ~. Per~ , , , R..R. Ritter ' Geurge Sow~rdS ~ ..~ - C. ~E. Smith ~ PrOducing Dept. i ................................ No:rE.--There were ......................................... runs or sales of oil; ........................................... M cu. f~. of gas sold; .................................................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE. B, epor~ on this form is required for e~ch calendar month, regardless of the ~tatus of ,operations, ~rtd tnust' be fi]ed dupheate with thc supervisor by the 6th of the succeeding month, unless otherwise direece,! by the supervisor. (lan~ry lg~) , i /// UNITED STATES DEPARTMENT OF THE-iNTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R356.5. Approval expires 12-31-60. ]LAND OFFIC£ .... .Anchorage ........... '~AS, N,M,,~,__A-020~. ............. UNIT ...... ..~.l~-~J~l, ~..(~.]J,. _ .~1,._'~'_e,~. .......... LESSEE'S MONTHLY REPORT OF OPERATIONS Tl*e follOwi:~.~ is a correct report of operatioT,$ and prod~ctio~, ('in. cludin~ drillin~ and prodt6ein~ wells) for the month of ........ ~P~r ................ 19..~, Sw~son River Unit ~.~ent' s address: ..... P. O. B~__7~8~9 ................................. - .................. ~dard-'0~'-~-~-~-f"~'f; ....... ompar~y _ ~~~_ ~ .......... ......................... : ......... .................... . .... . Phoebe BReathy 7~ 201 .................................................................................... i?~.,Fs title __ 3ist~_..fi~}~_ Ai~~ I ~ GALLONS ~;~ ]L~ m~rLs o~. I<E~IAH KS ....................................... --I ......... i ~,,.to,,~ of ~ ~ ~ECOVE;[~D ~(,!,e, SO st~I,[~) date ~,d r~:~I[ of t~[ for .......................... i ............ i 27 ~ ~ S 212-27 (2h) ~ , ~o[e~ gR~ 2~2-27 [ch~g~d ~o SR~ 2~2-270 F1 t~$ted ~eli hrough ~o/6h' B0~ at fe[l~Sng Da~e ll!D - Oil!~ater T.P. C.Po ~ut .~CF/D Gae 9-[ 328/288 225 105 47% 9-~ 200/1~ 222 127 47% 43 9-~ 180/17~ 200 125 49% 36 9-~ 160/15~ 197 127 50% 36 .~ 9~- 15t/16~ 188 132 51% 32 -~ ~-?~ ~32~5~ ~5 ~4o 54% 3o lliled Well wfth mudo ~led Cut 2 7/8"~tubi~. ~inst~lled an~ ~sted ~0~o Drilled ~mt float shoe an~ clewed out cement to ~700'. C~ndition~d ~. to 32~ regained$circ~atlon. R~ back ~o 7~0'.~ Lost appr~i- still l~sing ~ui~. R~ in wi~ ~pen end ~ill pt~e to 338~'. .~ed Sn 300 sac~s of~ement. 'P~ug ~d rot hold. Recemen~d ~,~ ~00 sacks cement ~rough tubing h~g $ 338~~. Drilled out h~d cement 2681~ ~- ~'. Cleaned out t~ 706~'. I D~illed!8 3/h" hole 7,..064' - 7,5~0'. C~red '7 5/8" hole~ Cut &irecovere~d' C~e ~l~ 7,550' '.7,57h'. ' C~re ~2t 7,574' + 7,5¢8'. Cut 2~' recovered C~el ~3~ 7,598' ~ 7,6Q9~.~ ~t lq', recovered NoTE.~There '~r w~ e ....................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................. , ............... runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.--Report on this form is required for each calendar month, regardless of the st, atus of opera[ions, and must be filed in duplicate with the supervisor bY the 6th of the Succeeding month, unless otherwise directed by the supervisor. Form 9-32.9 (January 1950) 16--25700-8 U. $. GOVERNMENT PRINTING OFFICE UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Bud~t Bureau No. 42-R356.& Approval expires 12-31-60. u.,~ __~_~ ~g_._~$.~O~ .............. LESSEE'S MONTHLY REPORT OF OPERATIONS The ]~ollowin, g is a correct report of operatio-t~,s an, d productio~ (i~chedin~ drillir~' and producin~ wells) for the mon~-l~ of ............... ~p.t~_~_e_r ........... 1,9_~_, Sw~son River Unit -~--~ .............. g ~h~3-' ~ ~-'-~-IT~; .... ~e~,t's address ........ R,__ 9,._~__7~9 ............................... compai,y---~~~~n~ ....... ................................... ...... - - -~~ ...... r~/._ .... Phone ........................ BRo~_~_~___7_.6aO1 ............................. ~z~er~t;'s t~t~c .... D~st,.- ~Up~.~L".A.!a~ ........... gEC. &ND W~VP. ~ANGE ' ~ARRELS OF OH~ (]*~AV~V'2 [ ~U. ?'T. OF OAS ~ OF ~ NO. Pno~uc~y~ ....... (~ ~lio~s~Bt[s) OASOLINE XVATE[~ (Il'(H drilling, d, pth: it qhl~t dt~wn, ,~altSO; i i I ' 27 8~ !~¢ S .. 212~27.(2h), don~Snaod Co~e ~h, 7,609' ~ ~,61~'. Cut & recovered Core ~5~ 7,615~ 2.,616,o Cut & reeovere~ 1'. Corn ff6~ 7,616' - 7,619'. Cut &~vecovere~ 3'0 ~nod ~ 5/8" hol~ ~o 8' 3/h", 7,5~0' - 7,6~9'. [ Co~e ~7~ 7,621' 4 7,6[~'. Cat &Ireeovere~ I Core ~8~ 7,6h5' q 7,66?'o Cut & recovere~ 2h'. ' Co~e ~9~ 7,669' ~ 7,69)'. CUt &lrecovere~ I Co~e ~10. 7,693' q 7,70~'. Cut & recovere~ 8'0 hole 7,701~ - 7,~qo' ~.V. ~n I-~ Log, 7i, 799~ - 3,698~,' Sohio Lo~ 7,7~7~ - 3,h5~' ~d[~cro Log~7,7?8' -I 6,798'. Ran ? ng? 7, S00' arb~d ~hoe and ~O0 sacks through D.V. ~ h .h71 . ~~eh¢~o~at- cf u. ~.r~, ~. '~. ~ .r 0hie/- GeprgeiSowa~ds ~lo,~tion NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................ runs or sales of gasoline during the month. (Write "no" where :~pplie,~ble.) No~.~l~epor~ on ~his form is required for each eaiendar men[h, regardless of ~he sr~arus of opera[ions, and mu,[ be filed in duplicate wi~h ~he supervisor by the §~h of the succeeding month, unless ot, herwise directed by ~he supervisor. l*ovm (Janllary 1~60) 16---2.5700-8 u.s. OOW:Itn~I~Nr ~alNvl~ta · rd). ITS1) (SUBMIT IN TRIPLICA1'~') UNITED STATES DEPARTMENT OF THE INTERIOR G£OLOG ICAL SURVEY lludf~ Bureau No. Apl2rovaJ expires ,--~ o~,, ~...o~.._ag~ ...... ,.-.....0~~ ............. u--,, .... ..S~__~_..~.. _n_._~$...v~..r _. SUNDRY NOTICES AND REPORTS ON WELLS (INDICATE ABOVE BY CHECK MARK NATUIqr Ofr R~T, NOTICe. O~ OTH~ DATA) Well No~_R.I]____2%_2._27 is located !~0__._ ft: from__ line and _13_15__ ft. from line of sec..27 ....... l~e..z4 l;~e. No.) 0~ (Twp.) (R~n~e) (M~'tdlaa) _s__wan.__s_~__~v.~ .......... [~__~r~~_, ........................ ~._aak~_ ................... (ltield) (Oounty or Bubdi?lMon) (Stad~ or The elevation of the a~~lllgabove sea level is _ .!$2 __ ft. DETAILS OF WORK ~nts, ~ ~! ~b [m~taflt p~ Well deaignation ~o be changed fron SRU 222-27 to 212-27, ~o~eo~ SeeZion 27. ~o a~ere ~o ~, p~ecr2b~ ~ell~er~{ the ~ n~er ~ to ~ ch~g~ f~m 5RU ~2-27 to SRO 212-27. Ad&~ ....... P_ ,__ _0_ _, _ _ ~..x__ 7_-__839 .................... ...... ' .............. Ao~_h_o_r_~,Ze ,~_ A~.~k~ ................. i UNITED STATES DEPARTMENT Of '['HE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLy REPORT OF OPERATIONS Tt~e followD,~ is a corrcc~ report of operutiot~,s and prod~ection (Dtchcdin~ drillin~ and producin~ wells) for the mo~¢h of ................. AuR~st . :~9 6_%, Swanson River Unit .................... S ~.O,.~ OIL ~c;*L s address F, .~. B_ x 7-.39 Company .... Western ~e2~!o~ .~a ........ Original Signed Anchorage ~ Alaska ........ Si~n. cd ................... ~ .... W Phoebe BRoadway ' 7-6201 ..l ~'cnt' s tit:lc _~_&O~_ .... ~_~S ' ,.. ...................................................... ~:~-~:::': ~W ::7: 27 GALLONS Or |)^ itREI,S ~)I~ t< E.MA R K S Ct,'. FT. 0~' (IAS (~RAYlfY ([11 thousands~ (]ASI}I. INE ~'ATER (If (If drilling, del)th: if si,ut ,.lown. Ca,lSe; ~ 222-27 (24) I 8~ 9W s~a~ed 8-20~. ~D~LZea 12 1/~" hole o~ - 3000~. 8 ]/h" hole 30DO, ~ -'3700~. ~ened I~ 1/h" hole ~o ~.~]" O" - 1600' ~00~ 1,gh~ ~tc~o Log 3700~ - ~oned ~oZe. ?~:Z-~ ~nd So~c Log . - ~- , 2~00~. ~Re~.ed !?:I/2" hole 1~0~ - 30~0~. RerAn I-ES Log 3700 9 ~,/~ 8" casin~ ~: 3457~ in two stag&s with lt~20 ~acks of ce~nt. I~talled BOPE. 3ril!ed out D.V. and tested with 1650~ osi. H~d OK. D~illed~out cement to ~400'. R~ NCL 3409' - 2409'. Per- forated; 4- 1/2" holes/foot ~. tested approx ~water. R~ 2 ~'~ tubi~, h~g ~' 3376'. GJ~, ~$~- ~7~ Tot~ Cut~, ~:5 - ~;'~ T.o. ~O - 80~ Csg. ~. S2/6a" Besn Si~e. [ cc! U,~.G.S. - M. ~. S~yster , ~O~l & C.~: Ohio - Geo. ow~ I Union - C. E~ S~ Files: ProdUcing ~ ~=~ti~ Land l NoT~:.--There were ....................................... runs or s3!cs of oil; ...............................................M cu. ft. of Las sold; ................................................. runs or ames oi g:ts~[[n:~ ,[t;.l'[;~ ~he month. (Write "m," w~cre npi>lieable.) Noru.~liep(..'t on this for.m is r.:,quired for ca~'h duplicate with tho supervi;-:vr by t, bc 5th of the >uccccd:.ng ' , (January 1950) FoFxn 9...8~1 ~ (Feb. 1~1) (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY Bud,~ Bur~u No. lpprov~ expir~ 1~-31-~0. 'SUNDRY NOTICES AND REPORTS ON WELLS o Division .6jaska NOTICE OF INTENTION TO DRILL .................. [_ X SUBSEQUENT REPO~T OF WATER Si~OT-OfF . NOTICE OF INTENTION TO CHANGE I~q_AHS .... NOTICE OF INTENTION TO TEST WATER SHUT-OFF . - - i SUBSEQUENT REPORT OF ALTERING CASING _ NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL ! SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR NOTICE OF INTENTION TO SHOOT OR ACIDIZE NOTICE OF INTENTION TO PULL OR ALTER CASING NOTICE OF INTENTION TO ABANDON WELL __ ?;~ls (INDICATE AIOVE IY CHECK MARK NATURE OF REPORT, NOTICi:, OR OTHER DATA) 1 Well No. ~ 222,~1s located ~0: ft. from__ 'i'~ line and ~ ft. from'[WJ" 'l~e of ~. ..... ~, ~_~_~_~,~o~ ~ ..... :.. a.~, ,. ~.a. ~a~.,~., .......... ~~_ ~ (~ ~. and ~. No.) (Twp;) (M~ldl~) (Fief) (( ;ounty or ~ubdJvision~ (8~M ~ Tertiary) The elevation of the derrick floor above sea level is ~ ft. DETAILS OF WORK (State names of and espoct~d depths to objective sands; show aim, woiwhts, and lenwth$ et peoposed ea*4nWsI lrsdlemto rnuddlrtw job0, arrant- inf points, &nd &J! other important prol~ w~'~,) lo 3. 5. 6. o ! undoestanKI that this plan o/ work must receive apl)reval in writinI by tb Cdoiowtcai Eurvey betore op~ratJor~e may be co~meneod. Company _~_ OIL CGI~AI~..~'__CA~ ~._~TIOI~ ................ A~_~_~a..._-~!~___ ~ .......... By .......................................... Title _Dlst~rict APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DI{ILL~ DEEPEN [-] PLUG BACK [] NAME OF COMPANY OR OPERATOR DATE Address City /i' ..... ' ' State DESCRIPTION OF IVELL AND LEASE Name of lease Well location (g'ive footage from section lines) 18~' f~ ~. ,~ ~ ~, ~ w. ~ ~~ ~,. ~. 8 1.~ a. 9 w. Field ~ reservolr (If wHdc~t, so stale) { County Distance, in miles, and d~rec~km from nearest town or post off~ce Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: Well number I Elevation (ground) Section--township--rang'e or 1)lock & survey feet Proposed depth ]Rotary or cable tools Approx. date work will starl Number of acres in lease: Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present. producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, state that (company), and that I am authorized by said corn an ~[0 p y ma e pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Or{g{nal s~gne~ Permit Number: 3,3-61 Approval Date' AUi~IIS~ 2, 1961 ,/q ~n/ f Division Notice: Before sending in this form be sure that you have gi~yen [ / eal~leienf~[l~thiu°sn ~eeqaUveSo~aeh.mueh unnecessary e°rresp~d' V See Instruction on Reverse Side of Form C. V. CHATTE~T()N Signature O,, Y, ~~ Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 Fob. I~LI) (SUBMIT IN TRIPLICATK) UNITED STATES DEPARTMENT OF THE INTERIOR G£OLCX~ ICAL SURVLry B~df~ Bm Ne,. ApJ~ovM ozpmu SUNDRY NOTICES AND REPORTS ON WELLS NOTIC[ Of' INTENTION TO DRILL NOTICE OF INTENTION TO ~ NOTICE OF INTENTION TO TEST WATER SHUT-43,FF I~K)TIC[ OF INTENTION TO UlU. NOTICE OF INTENTION TO SI4OOT NOTICE OF INTENTION TO PULL OR ALTER NOTICE OF INTENTION TO A~ANtX)N (INI:NCAT[ A~OVs' BY CI~'CK blAIWK ~ATL~WI[ C~r S~ll~qT, N(}TICE. Oft OTHIEIIW ~TA) line and ..3. _5C~...__ ft. from }W line of sec...~ ...... ()~ See. sn,t 5~e. No.) ._. ~n_B:tver (P'teid) (Twp.) ( P. ea~e ) (M~diam) (C4)unty or Subdivision.) (~ w Te~ritee'y) The elevation of the derrick floor above .sea level is 190_. ft. DETAII~ OF WORK for
