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Facility No Flows • Page 1 of 1 Regg, James B (DOA) __ _ _ _ From: Johnson, Wayne E [johnsonw@chevron.com] ~ Sent: Friday, February 06, 2009 3:11 PM ~Q~ To: Regg, James B (DOA) Cc: Santiago, Johnny T; Greenstein, Larry P; Bartolowits, Paul D; Lovett, Juanita L Subject: Facility No Flows Attachments: G-33 8-95.doc; A-22dwg comp11-9-79.DOC; G-1Schm9-17-97.doc; G-31Schm9-10-89.doc; G-32 Schematic 5-13-08.DOC ./ ,, «G-33 8-95.doc» «A-22dwg comp11-9-79.DOC» «G-1Schm9-17-97.doc» «G-31Schm9-10-89.doc» «G-32 Schematic 5-13-08.DOC» ~ Jim, Here is your well schematics. ~.~ '~A-22s: Shut In ~rD 17 b -ti 3 l /A-22L: No flow on May 27, 2004 ~1s: Shut In ~y~ j`1 ~ (-~ 13 °( G-1 L: : No flow May 27, 2004 ~G-31s: No flow November 23, 2004 ~ i(,y _U72' ~31 L: „ 6 Shut In _- ' l 'c~-32: No flow April 21, 2003 --, P~ ~~~t- ~~ -33s: Shut In ~ ~?~, o!( -33L: No flow November 23, 2004 Wayne E. Johnson Operations Supervisor MidContinent/Alaska Business Unit Chevron North America Exploration and Production Grayling 907-776-6632 King Salmon 907-776-6692 Monopod 907-776-6672 Mobile 907-398-9942 2/6/2009 UNOCAL • • Trading Bay Unit Well # G-31 ~~`1~-®Z Z- Completed 9/10/89 RKB to TBG Hngr = 47.27' Tree connection: Dual 3-1 /2" Butt A ,..-. , 1 B 2 C 3 E D 10,315' 4 F 5 G G-2 G-3 5 G-4 G-5 ,,,,,,,,,,,,, 7 8 10,862' J 10 11 .•; FIII Tagged~11,210 ~:~ ~ ~ HB-1 ;~MilledB Reamed Csg f/10,900'to 9~ Fi6-2 11,sza' on allola9. . Failed isolation tests fl 11,000' to ~' ;11,065' on 8111189. ~ HB-$ .~ 20 days of cmt sqz woAC on HB-2 & HB-3. ~ ' PeAs will still break down ~ 5200 ~ HB-4 psi,'/. BPM. 1 t,5os• 13 11,5za' Junk 14 11, 576' 11,591' 15 11,595' West Forland 11,811' PeAs RKB to MLLW ELEV = 103' TD = 12,738' ETD = 11,509' MAX HOLE ANGLE = 42° ~ 4,383' G-31 Schm9-10-89.doc SILE W'T CASING AND TUBING DF,TAIL GRADE CONK ID D1D TOP MD BTM. 17-3/4" .312 wall Welded Surf. 520' 13-3/8" 61 J-55 Seal Lock 12..515 Surf. 5222' 9-5/8" 47 P-110 Butt 8.681 Surf 120' 9-5/8" 43.5 N-80 Butt 8.755 120' 5837' 9-5/8" 47 P-110 Butt 8.681 5837' 11,668' 7" 29 N-80 Butt 6.184 11,595' 12,729' Tubing: LS 2-7/8" 6.4 L-80 Butt 2.441 0' 10,936' S5 2-7/8" 6.4 L-80 Butt 2.441 0' 10,359' JEW F.LRY DETA[L NO. De th ID Item 47.27 Dual "DCB" 10" nominal, 3-1/2"Butt X Butt. A. 334' 2.313 Otis SSSV "XXO" Landing Nipple #1 2109' 2-7/8" GLM, Length 6.76' #2 3747' 2-7/8" GLM, Length 6.76' #3 5215' 2-7/8" GLM, Length 6.76' #4 6188' 2-7/8" GLM, Length 6.76' #5 6976' 2-7/8" GLM, Length 6.76' #6 7727' 2-7/8" GLM, Length 6.76' #7 5351.' 2-7/8" GLM, Length 6.76' #8 9000' 2-7/8" GLM, Length 6.76' #9 9603' 2-7/8" GLM, Length 6.76' #10 10,213 2-7/8" GLM, Length 6.76' C. 10,274' 2.313 2-7/8°' Otis "XA" Sliding Stecvc D. 10,308' 2.375 Safety Shear Sub, 40k E. 10,315' 2.44 Center of 9-5/8" Otis "RDH" Dual Packer, SS set, ,Top to center 6.29', Center to btm 9.9' F. 10,352' 2.35 Otis Collet Shear Sub G. U);358' 2?OS 2-7/8" Otis "XN" Nipple, 2.313 Btm 10,359' 1 Y 327' Otis SSSV "XXO" Landing Nipple #1 ~ 1 2166' ~ ~ . , 2-7/8" GLM, Length 6.76' #2 3802' 2-7/8" GLM, Length 6.76' #3 5277' 2-7/8" GLM, Length 6.76' #4 6247' 2-7/8" GLM, Length 6.76' #5 7032' 2-7/8" GLM, Length 6.76' #6 7785' 2-7/8" GLM, Length 6.76' #7 8442' 2-7/8" GLM, Length 6.76' #8 9061' 2-718" GLM, Length 6.76' #9 9663' 2-7/8" GLM, Length 6.76' #10 10,233' 2-7/8" GLM, Length 6.76' 3 1(1,371' 2.313 2-7(8" Otis "XA" Sliding Stecvc 4 10,315' 2.44 Center of 9-5/8" Otis "RDH" Dual Packer, SS set, ,Top to center 8.64', Center to btm 8.53' 5 10,353' 2.313 2-7/8" Otis "XA" Sliding Sleeve 6 10,441' 2.313 Baker Blast Joints, Length 321.20' 7 10,829' 2.313 2-7/8" Otis °XA" Sliding Sleeve 8 10,862' 2.44 Otis Straight Slot Locator, w/ 8' of seals 9 DPM 10,847' 4.00 Otis "BWD" Perm Pkr 10 10,852' 4.00 Otis Seal Bore Extension, Length 7.70' I l 111,9(14' 2.313 2-78" Otis "Y" Nipple, 2.31.3 12 10,935' 2.44 WLEG btm 10,936' 13 11,509' Howco EZSV Retainer 14 11,524' Howco EZSV Retainer 15 11,581' Baker Model "FH" Hydroset Paker w/ 5' tbg stub above STIn1ULATIONS Page 1 of 2 9/2/88 SOC Treatment Hemlock 1/16/91 Scale Inhibition Treatment Hemlock 8/15/91 X Iene /Scale Treatment Hemlock REVISED: 11 /4/97 DRAWN BY: SLT i ~~~ ~-3,1 ~~ 16t--o~~v p~ ~ o~ z PERFORATION DATA G-2 10,448' 10,484' 36' 20 9/14/1994 ReperF. Open f/.Production G-3 10,540' 10,570' 30' 20 9/14/1994 Rsperf. Open f/ Production G-4 10,610' 10,635' 25' 20 9/14/1994 Reperf. Open fi Production G-5 10,708' 10,728' 20' 8 9/6/1989 Open f/ Production H6-1 10,900' 10,990' 90' 4, 16, 32, 40 9/3/1989 Open f/ Production 10,910' _ 10,911' 1' _ _ 9/14/1969 Sqz perfs. 85 sx cmt __ ___ _ HB-2 11,008' 1_1,025' 17' _ ____ 8/20/1989 Cement Sqzd, w/ total 31 cult. Class G__ HB-2 11,042' _ 11,057' 1 5' 8/14/1989 Cement Sqzd, w/ total 24 cult. Class G HB -2 _ 11,068' _ 11,140' _ _ 72' _ 8/24/1989 Cement Sqzd, w/ total 106 cult. Class G __ _ HB-3 11,153' 11,200' 47' 8/18/1989 Cement Sqzd, w/ total 172 tuft. Class G HB-4 11,211' 11,315' 104' 6, 22 9!311989 Repert. Open f/ Production ~ 11,364' 11,366' ~ 2' ~ 8/30/1989 Sqz perts f/ isolation. 20 sx placed _ __ WF-2 WF-2 __11,678' 11,688' 11,696' 11,706' ~ 10' 10' 4 9/18/1969 Isolated w/ BP 11,524' 4 9/18/1969 Isolated w/ BP @ 11,524' _ WF 2 11,723' _1. 11,738' ~ 15' __ __ 4 ~-9118/1969 Isolated w/ BP @ 11,524' ~ 11,870 _x 11,871' 1 T 9/14/1969 Sqz perfs. 75 sx cmt _ _ _ WF-5 ~ j _ 12,021' --- 12 100' ~ __ 12,045' ~-- 12 101' 24 1' ~ ~ _ 4 _ ~ ~ 9/17/1969 9/11/1969 DST'd. Isolated w/ BP @ 11,811' - 55 sx cmt Sqz perts ~ _ , ~ ' , _ -, ' --- ' - ~ - -1 - ______ . 11 t _ 12,100 - + 12,101 ~ ---- 1 -- f - ~ 9/13/1969 t 5 sx cm __ ___ __ Sqz perts. SLICKLINE Ta ed Fill w/ 2-7/8" Scratcher 10/8/94 11,210' Bailed'/z anon of formation sand 10/8/94 11,210' Page 1 of 1 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, February 06, 2009 8:50 AM To: 'myersc@chevron.com' Cc: Fleckenstein, Robert J (DOA) Subject: No Flow Determinations '1e1~ Z~~(~~G`~ ~/ We've just completed an update/review of AOGCC "no flow wells" database and found a few dual completions that are not clear if the no flow determinations were on long string or short string. Wells in question are: > Trading Bay State (Monopod) A-22; PTD 170-031 > Trading Bay Unit (Grayling) G-01 RD; PTD 191-139 > Trading Bay Unit (Grayling) G-31; PTD 169-072 > Trading Bay Unit (Grayling) G-32; PTD 169-086 > Trading Bay Unit (Grayling) G-33; PTD 170-011 I would appreciate it if you could provide: 1) current well schematic for the listed wells; 2) current status of the LS and SS completions; 3) Union's understanding of which string the no flow determination applies to and why. Call if you have any questions about this request. Thank you in advance. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 2/6/2009 Unocal.s Grayling platform valve repairs ) Subject: Unocal's Grayling platfonn valve repairs From: "Waski, John" <waskij@unocal.com> Date: Thu, 20 Jan 2005 11 :00: 12 -0900 To.: Jim - regg@admin.state~ak. us . cC: lou_grimaldi@admin.state.ak.us ) Gentlemen, Re: AOGCC inspection on Grayling platform 1-17-05 l~DJ .~. Repairs were made to the SSV (Surface safety valve) on Unocal's Grayling platform well # G-3tS ( 1-17 -05) Wire line work for SSSV repairs on well # G-14L are being scheduled. Regards, J.C. Waski Production Foreman Grayling Platform (907) 776-6632 WK (907) 776-6632 Cell SCANNED FEB () 4 2005 1 of 1 1/24/20059:30 AM ) ~=:!Æ~E :} !Æ~!Æ~~«!Æ A.I,ASIiA. OIL Alfl).GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR December 10, 2004 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-.7...54.... 2.,'.','...'.""'.". .,.~ a- I ~''''' Ð, Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: Safety Valve System Inspections No Flow Tests Trading Bay Unit, Grayling Platform Dear Mr. Johnson: On November 23, 2004 the Alaska Oil and Gas Conservation Commission ("AOGCC") inspected Unocal's Grayling platform, Trading Bay Unit. The Commission's inspection included witnessing semi-annual safety valve system ("SVS") tests, no-flow tests on four wells, and general platform safety inspections. The platform was found to be clean, orderly, and in good condition. The SVS associated with thirteen of the platform's wells were tested. Eleven wells were not tested during the November 23 inspection - four wells were shut in for no-flow testing, two wells were not tested at the request of the platform supervisorl, and five wells were not tested due. to their "long term shut in" status. Unocal must provide a schedule for completing the semi-annual testing of the six wells2 that would normally be in operation, and provide the Commission with sufficient notice when SVS testing will be conducted so these tests can be witnessed. The Grayling platform production wells utilize artificial lift gas to produce hydrocarbons. It is unclear if a catastrophic failure of a well or flowline component will automatically shutdown artificial lift gas, or if the well will flow for several hours until it depressures. Unocal is requested to provide an explanation and relevant supporting flow schematics with sufficient detail to demonstrate the emergency shutdown system and its control over the artificial lift gas. 1 TBU G-14 (PTD 168-080) and TBU G-18DPN (pTD 183-135); reason for not testing was concern about disrupting the platform's fuel gas supply 2 TBU G-12 RD3, G-14, G-18DPN, G-21, G-31, and G-33 SCANNEr}, DEC 1 4 2004- ") ) Dwight Johnson December 9, 2004 Page 2 of2 We also note that safety valve system test results at Grayling are not routinely provided to the Commission. Unocal should begin reporting all safety valve system tests to the Commission, particularly those tests that are not witnessed by a Commission inspector. Please contact Mr. Bob Fleckenstein at 793-1242 to get the proper reporting format. No Flow Tests Wells G-12RD3, G-21, G-31, and G-33 were no-flow tested on November 23 to determine if they qualify for removal of the subsurface safety valve. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for 3 hours. Gas flow rates less than 180 SCF per hour, and total liquid recovery less than ~ gallon during the 3-hour monitoring period were determined for each well tested. Based on the results of no flow tests, the subsurface safety valve may be removed from service in Wells G-12RD3, G-21, G-31, and G-33. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in each well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, r-:-=' " ~~~~~ James B. Regg ( f Petroleum Inspection Supervisor cc: Bob Fleckenstein File: TBU G-12RD3 (pTD 202-055) TBU G-21RD (pTD 198-064) TBU G-31 (pTD 169-072) TBU G-33 (PTD 170-011) ) ') MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~'{ tz,(~I~ DATE: November 23, 2004 FROM: Jeff Jones Petroleum Inspector SUBJECT: No-Flow Test Unocall Grayling PL T G-31 S/L PTD 1690720 McArthur River Field I TBU November 23,2004: I traveled to the Grayling Platform in Cook Inlet to witness a No-Flow Test on Unocal's McArthur River Field well G-31 S/L. Unocal representative Darrel Bruce performed the test today in a safe and proficient manner. Well G-31 S/L was lined up from the production tubing through a 1" hose terminating in an open top drum. Gas flow from this well was such that it was below the amount measurable (180 SCFH) with the Armor-flow model 3461-03TO flow meter usually used for No-Flow Tests. This well utilizes artificial lift gas to produce hydrocarbons, which was shut in at least 12 hours previous to the test, and the well was allowed to depressure into the test separator. This artificial lift gas may not be automatically shut off in the event of a catastrophic failure of well head or flow line components, depending on the nature of the failure. In the event of such a failure, it may be necessary to block in the lift gas manually, and in any case the well may flow for several hours unassisted until it depressures. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the well during the test did not exceed the maximum permissible 900 SCF hourly flow rate and no significant amount of fluid was produced. Summary: I witnessed a successful No-Flow Test on Unocal's McArthur River Field weIlG-31S/L on the Grayling Platform in Cook Inlet. Attachments: none ÇÇ;. Dwight Johnson I J.C. Watski (Unocal) , . ¡ ,. :, '. .' . ..01' "."~',~ ' -., . " ,; . ~. . "Well'N~F/òw T èsf :Dätå::.::~~,~:::r:'::.:~~~~~k~::;;"i\~r'~i', Unocal Date 11/23/2004 Darrell Bruce Jeff Jones MRFffBU Gra lin PLT " .' .. 11:45 AM 12:15 PM 12:45 PM 1: 15 PM 1:45 PM 2:15 PM 2:45 PM Gas <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Lìquìd < 1 cup <1 cup < 1 cup <1 cup <1 cup < 1 cup <1 cup Start Test End Test Produced to open top container. Total liquid produced: < 1/2 gallon SCANNED DEC 1 4 2004. RJF 09/19/02 Page 1 of 1 NO-FLOW Grayling PLT G-31 S-L 11-23-04 JJ.xls ~.0. Box 196247 Anchorage, Alaska 99519-.6247 March 16, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 OR Dear Mr. Douglas: On September 14, 1994 the following intervals were perforated in well G-31S (AP150-73 3 -201944)0) in the McArthur River Field: ~ BENCH TOP ('MD) BOTTOM (MD) FEET G2 10,448 10,484 36 G3 10,550 10,570 20 G4 10,615 10,635 20 TOTAL 76 RECEIVED APR 20 1995 Ataska U~l & Gas Cons. Comnlission gnchora£.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION (~,MMISSION REPO ( .' OF SUNDRY WELL (3 ERATIONS 1. Operations performed: Operation ;hutd°Wn __ Stimulate __ Plugging __ Perforate X_ "-' Pull tubing __ Alter casing Repair well Pull tubing __ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal ~ X_ KB: 103' ~to~ _ feet 3. Address staagap~ 7. Unit or Property name" P.O. Box 196247 Anchorage, Alaska 99519-6247 Serv~ __ Trading Bay Unit 4. Location of well at surface 8. Well number 1878' N, 1389' W of SE Ocr., Sec. 29, T9N, R13W, SM ORiGiNii~L G-31 At top of productive interval 9. Permit numberjappro,~al number 1768' N, 3664' E of SW Cor., Sec. 28, T9N, R13W, SM 69-72/94-233 At effective depth 10. APl number 1585' N, 3831' E of SW Cor., Sec. 28, T9N, R13W, SM 50-733-20194-00 At total depth 11. Fielcl/Pool 1223' N, 4423' E of SW Cot., Sec. 28, T9N, R13W, SM McArthur River/G,Hemlock 12. P'~:esent well condition summary Total depth: measured 12729 feet Plugs (measured) true vertical 10768 feet Effective depth: measured 11509 feet Junk (measured) true vertical 9719 feet Casing Length Size Cemented Measured depth True vertical depth Structural 368' 26" Driven 368' 368' Conductor 520' 17-3/4' 790 sx 520' 520' Surface 5222' 13-3/8' 2500 sx 5222' 4596' Intermediate Production 11667' 9-5/8' 1600 sx 11667' 9854' Liner 1134' 7' 300 sx 11595' - 12729' 9796'- 10768' Perforation depth: measured 10448-10484, 10540-10570, 10592-10636, 10708-10728, 10960-10990,10976-11006, 11018-11025, 11211-11315 true vertical 8821-8852, 8900-8926, 8945-8983, 9045-9062, 9258-9283, 9272-9297, 9299-9313, 9469-9556 Tubing (size, grade, and measured depth) LS: 2-7/8', 6.4#, N-80 @ 10936' SS: 2-7/8', 6.4#, N-80 @ 10354' Packers and SSSV (type and measured depth) Otis BY @ 328'; Otis RDH dual pkr. @ 10306'; Otis BWD perm. pkr. @ 10847' '13. Stimulation'or cement squeeze summary i~ E C E iV ~ U Intervals treated (measured) ~ ~i-T{ 2 0 ~ Treatment description including volumes used and final pressure ,~ u,~ ~ Gas Cone, ~mmisslt "14. Representative Daily Avera,qe Production or Injection Data Ailch0ra~,{~ ~.:,' ..... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation' 312 351 416 1240 200 Subsequent to operation 354 108 451 1210 140 _ '15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations _ Oil X_ Gas, ~ Suspended Service -: .... 17. I hereby certify that the foregoing is true. al3d correct to the best of my knowledge, Form 1 d-40~ Rev 06/15/88 SUBMIT IN DUPLICATE Unocal North American Oil & Gas Division ( Unocal Corporation ~,~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region Ralph P, Holman En§ineer Technician Unocal P,O. Box 196247 Anchorage, Alaska 99519-6247 August 19, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-31S (API# 50-733-20194-00) on the Grayling platform. BENCH TOP, (MD~ BOTTOM OIDI FEET G5 10,748 10,774 26 (32 10,448 10,484 36 G3 10,540 10,570 30 G4 10,592 10,636 44 G5 10,708 10,728 2_0.0 TOTAL 156 RECEIVED AUG 2 4 1994 Alaska OJj & Gas Cons, Commission Anchor~.~e August 19, 1994 Grayling Platform, Well G-31 Perforating Procedure 1. Hold safety meeting. 2. Rig up electric line unit. e Pressure test lubricator to 2500 psi for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. e Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) . Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET G5 10,748-10,774 26 G2 10,448-10,484 36 G3 10,540-10,570 30 G4 10,592,10,636 44 G5 10,708-10,728 20 TOTAL: 156 Alaska 0~1 & Gas Cons. commission Anchor[.~e STATE OF ALASKA ALASK i., L AND GAS CONSERVATION CCi IISSION APPLICA, ION FOR SUNDRY AP, ROVALS /ps of reques, t: Abandon m Suspend __ Operations shutdown __ Re-enter suspended well__ Alter <~asing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program Pull tubing Valance Perforate X__ Other m 6. Datum elevation (DF or KB) Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1878' N, 1389' W of SE Cor., Sec. 29, T9N, R13W, SM At top of productive Interval 1768' N, 3664' E of SW Cor., Sec. 28, T9N, R13W, SM At effective depth 1585' N, 3831' E of SW Cor., Sec. 28, T9N, R13W, SM At total depth 1223' N, 4423' E of SW Con, Sec. 28, T9N, R13W, SM 5. Type of Well: Gas Cons. Commiss~¢ Anchor~,~e KB: 103' feet 7. Unit or Property name Trading Bay Unit 8. Well number G-31 9. Permit number 69 -72 10. APl number 50-733-2O194 11. Field/Pool McArthur River/G, Hemlock 12. Present well condition summary Total depth: measured true vertical 12729 feet Plugs (measured) 10768 feet Effective depth: measured 11509 feet Junk (measured) true vertical 9719 feet ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural 368' 26' Driven 368' 368' Conductor 520' 17-3/4" 790 sx 520' 520' Surface 5222' 13-3/8' 2500 sx 5222' 4596' Intermediate Production 11667' 9-5/8' 1600 sx 11667' 9854' Liner 1134' 7' 300 sx 11595'- 12729' 9796'- 10768' Perforation depth: measured 10448-10484,10540-10570, 10592-10636, 10708-10728, 10960-10990, 10976-11006, 11018-11025, 11211-11315 true vertical 8821-8852, 8900-8926, 8945-8983, 9045-9062, 9258-9283,9272-9297, 9299-9313, 9469-9556 Tubing (size, grade, and measured depth) LS: 2-7/8', 6.4#, N-80 @ 10936' SS: 2-7/8', 6.4#, N-80 @ 10354' Packers and SSSV (type and measured depth) Otis BV @ 328'; Otis RDH dual pkr. @ 10306'; Otis BWD perm. pkr. @ 10847' 13. 14. 16. Attachments Description summary of proposal X_ Detailed operations prograrr~__ Questions? Call Hal Martin @ 263-7675 or Ralph Holman (~)263-7838 Estimated date for commencing operation ~15. Status of well classification as: 1994 1 If proposal was verbally approved I Oil X_ Gas __ I Name of approver Date approved Service correct to the best of my knowledge. FOR COMMISSION USE ONLY 17.1 BOP sketch Suspended__ Conditions of approval: Nr~tlf,, r,~.,,.,- dssion so representative maY witness ]Approval ;)Test Location clearance_ $'-~bsequent[orm requked 10- /,/o [)riginal Signed By sion navid W. Johnston SUBMIT IN TRIPUCA'~ ~ ALASKA OIL AND GAS CONSERVATION CO~IMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 July 14, 1993 Mr. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, , In'conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. : To be in compliance with AS' 20 AAC 25.280(d) of the RegUlations, the Form 10-404 is required to be filed within 30 days following completion of work. In previous telephone conversat~ concerning the subject, it had beeq_.explained to me that either ARCO or Marathon had been the ~operator on the majodty of the work proposed; however, it is the feeling of the Commission that if the work was completed, .it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application. on file can-be marked accordinglY. ~ ~.. Sincerely, · · Statistical Technician ., ~ prinled on recyi:led paper b y Well Permit No, No. D-4 82-41 D-SRD 80-65 D-26 74-9 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Description Perforate 2-91 Perforate 5-91 Workove~ 4~91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush'.. G. Bush G. Bush G. Bush G. Bush · G. Bush G-5 67-71 3/15-91, 91-086' G-6 82-33 10-30-91, 91-325 4-21-92, 92-093 G-17 G-19 G-21 G-27 78-3 69-17 72-42 78-70 G-31 K-1 67-65 K-2RD 78-38 K-3 80-144 K-9 68-38 11-1-91, 912331 11-10-92, 92,238 · 4-21'92, .92-094 6-17-93, 93-154 · . . . 4-21'92, 92-95 1-6-93, 92-203 · 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this · Perf. 10-19-91 Perf 4-92 G. Bush G.'Bush G. Bush Perforate G. Bush Temp. log 10-15-92 .. Perf· 4-92 Coil. tubing' clean°ut TM :' ' -' ._ · . · Perforate Convert to inj. G. Bush· Production profile Perforate 2/90 G. Bush R.' Roberts Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 R. Roberts G. Bush G. Bush Perforate 2/90 R. Roberts Repair well, p. tubing, stimulate, perforate R. Roberts' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging ~ Time extension ~ Stimulate Change approved program ~ Pull tubing __ Variance __ Perforate __ O'~'~r 2. Name of Operator 5. Type of Well: 6. Union Oil Co of Calif. (UNOCAL) Development-x- · Exploratory __ 3. Address Stratigraphic_ 7. POB 190247, Anch, AK 99519-0247 Service~ 4. Location of well at sudace Leg #2, Conductor #38 8. 1878' N & 1389' W of SE Cot., Sec. 29, T9N, R13W, SM At top of productive interval 9. 1768' N & 3664' E of SW Cor., Sec. 28, TgN, R13W, SM At effective depth 10. 1585' N & 3831' E of SW Cor., Sec. 28, T9N, R13W, SM At total depth 1223' N & 4423' E of SW Cot., Sec. 28, T9N, R13W, SM Datum elevation (DF or KB) KB 103 Unit or Property name Trading Bay Unit feet Well number G-31 Permit number 69-72 APl number 50-- 733-20194 11. Field/Pool McArthur River/G, Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 368 ' Conductor 520 ' Surface 5,222 ' Intermediate Production ll, 667 ' Liner 1,134' Perforation depth: measured 12,729 feet 10,768 feet Plugs(measured) RECEIVED MAR 2 0 19'-3t 11,509 feet Junk (measured) 9,719 feet ~Ja$...~.._ 0ii & Gas Cons. G0mmissi0_ Size Cemented M e ~ s b ~re ~leOpht0nracJi~ 26" Driven 368' 17 3/4" 790 sx 520' 13 3/8" 2,500 sx 5,222' ~uevertiCaldepth 368' 520' 4,596' 9 5/8" 1,600 sx 11,667' 9,854' 7" 300 sx 11,595'-12,729' 9,793'-10,768' See Attached true vertical Tubing (size, grade, and measured depth) L.S' 2 7/8", 6.4#, N-80, Buttress @ 10,936' S.S: 2 7/8", 6.4#, N-80, Buttress @ 10,354' Packers and SSSV (type and measured depth) Otis BV @ 328', Otis RDH Dual Pkr. @ 10,306', Otis BWD Perm. Pkr. ~ 10;847' 13. Attachments Description summary of proposal __ Detailed operations program X_ BOP sketch __ 14. Estimated date for commencing operation Upon Approval 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~o...,..,,.A %. (~,..,..~¢,, Title ~--,,z_o,. ~k~ va'~ ~'~ ro t'~ otify Commission FOR COMMIS~ION USE OI~LY Conditions of so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- O'RIGIN~,: .... ,,~n 8V LONNI[-" ':'* Approved by order of the Commission Approved Copy Returned Date [Approval No. ¢/~, Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ATTACHMENT TO APPLICATION FOR SUNDRY ARROVAL, WELL G-31 PERFORATIONS TOP BO'I-i'OM TOP BO'I-i'OM ZONE MD MD TVD TVD G 10,448 10,484 8,821 8,852 G 10,540 10,570 8,900 8,926 G 10,592 10,636 8,945 8,983 G 10,708 10,728 9,045 9,062 HB-1 10,960 10,990 9,258 9,283 HB-1 10,976 11,006 9,272 9,297 HB-2 11,008 11,025 9,299 9,313 HB-4 11,211 11,315 9,469 9,556 March 18, 1991 RE: Grayling, Well G-31 Production Profile 1. RU electric line unit. 2. Pressure test lubricator to 2500 psi for five minutes. 3. Shut well in and run in with the following sensors: five inch fullbore flowmeter, petal basket flowmeter, gradiomenometer, temperature, and pressure. The holdup meter will not be used due to the high water cut. 4. Once the production tools are below the tubing tail, turn on the gas lift and produce the well for ten to twelve hours before production logging. 5. Make three logging passes up and down the well recording all PL sensors at once. The basket flowmeter should be kept closed during these logging passes. 6. After the up and down passes are completed, take stationary readings above,A24 between and below all perforations. The basket flowmeter should be opened at each of these stations. 7. After the stationary readings are completed, shut in the well and POOH. GRAYLING DISTANCE &~.DIRECTIONS FROM SE CORNER SEC. 29~ TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL FEL LEG #3: LAT = 60050' 22.569" LONG =151°36' 46.519" 2,502,352.30 212,272.70 1804 1409 1 2 3 4 5 6 7 8 9 l0 ll 12 2,502,346.65 212,269.32 G-22 1789 1413 2,502,350.14 212,266.48 G-21 1802 1415 2,502,354.64 212,266.55 G-26 1806 1415 2,502,358.05 212,269.49 G-25 1810 1412 2,502,358.77 212,273.94' G-24 1810 1408 2,502,356.46 212,277.80 G-20 1808 1404 2,502,352.20 212,279.28 1804 1402 2,502,347.99 212,277.68 G-36 1800 1'404 2,502,345.80 212,273.75 G-34 & RD 1798 1408 2,502,350.83 212,270.89 G-23 & RD 1803 1411 2,502,354.60 212,272.33 G-33 1806 1409 2,502,351.47 212,274.88 G-27 & 28 1803 1407 LEG #4: LAT = 60050' 22.832" LONG =151°36' 48.042" 2,502,380.80 212,197.90 1831 1486 , 13 14 15 16 17 18 19 20 21 22 23 24 LEG #1: 2 LAT = 60050' 23.575" LONG =151°36' 4Z. 505" ' 2,502,374.34 212,196.66 G-14A 1825 1487 2,502,376.65 ,. 212,192.79 G-19 1827 1491 2,502,380.90 212,191.32 G-13 1831 1493 2,502,385.11 212,192.92 G-15 1835 1491 2,502,387.30 212,196.85 G-5 1838 1487 2,502,386.45 212,201.28 1837 1483 2,502,382.96- 212,204.12 G-3 1833 1480 2,502,378.46 212,204.05 G-2 1829 1480 2,502,375.05 212,201.11 G-11 1825 1486 2,502,378.50 212,198.27 G-lO 1829 1483 2,502,381.63 212,195.72 G-17 & RD 1832 1488 2,502,382.27 212,199.71 G-7 1832 1484 ,502,455.60 212,226.40 1906 1458 (Reserved for C'ompressors) LEG #2: LAT = 60°50' 23. 313" LONG =151°36' 45.982" 2,502,427.10 212,301.20 1880 1383 37 38 39 40 41 42 43 44 45 46 47 48 2,502,421.45 2,502.,424.94 2.502,429.45 2,502,432.85 2,502,433.57 2,502,431.26 2.5D2,427.00 2,502,422.80 2,502,420 2,502,425.63 2,502,429.40 2,502,426.27 212,297.82 212,294.98 212,295.05 212,297.99 212,302.44 212,306.31 212,307.78 212,306.18 .60 ............ 2'12,'302. 25~ ................. G-8 & RD 212,.299.39 G-6 212,300.83 G-32 212,303.38 G-16 G-12, RD & 2 1874 " 1386 G-31 1878 1389 G-4 1882 1 389 G-1 1886 1386 G-9 1886 1 382 G-18 1884 1378 G-14 1880 1376 G.-30 ............ 1876 ........ 1378 ....... 1874 1382 1879 1385 1B82 1383 1879 1381 Ala~ca Re~an April 1~, I990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A~ckora~e, A~ 99504 A~tn: Ms. Elaine Johnson Dear Ms. JohnSon: I have attached surfac~ survey locations of tke "Les" _ . g and conductors for the four platforms in the Tradlng Bay Unit as we!~ as the Union Oil-operated Monopod and Granite Point Plat - unable to locate an forms. I was Y plats from a registered surveyor but I hope this will meet your needs. GSB/lew Yours very truly, Regional Drilling Manager STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well ~ 2. Name of Operator ! 5. Type of Well: / Development x__. fJnlc)n Oil cc)rnp~ny cH= c~1 '~ f:c~,'n~ ~ (f~C~-AL) Exploratory__ 3. Address ! Stratigraphic ---=T'. P.O. Box 190247~ Anch~ Ak., 99519-02l~7/ Service__ Grayling Platform, Leg 2, Conductor 38 W F/SE Corner, Sec. 29, T9N, R13W, S.M. 4. Location of well at surface 1878' N, 1389' At top of productive interval 1768' N, 3664' At effective depth 1585' N, 3831' Attot~:~t,h N, 4423' E F/SW Corner, Sec. 28, T9N, R13W, S.M. E F/SW Corner, Sec. 28, T9N, R13W, S.M. E F/SW Corner, Sec. 28, T9N, R13W, S.M. 12. Present well condition summary Total depth: measured true vertical 12,729' feet Plugs(measured) 10,768' feet Perforate __ Other 6, Datum elevation (DF or KB) 1OR' ~R ~h~ i 7. Unit or Property name Tradinq Bay Unit 8. Well numbe/ , 9. Permit dumber/approval number tV. 69-72 10. APl number · 50-- 133-20194 Field/Pool McArthur River Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured ~ngth 368' 520' 5222' 11667' 1134 true vertical Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) ll,509'feat Junk(measured) 9,719' ~at Ret @ 11509' Size Cemented Measureddepth ~ueverticalde~h 26" Driven 368' 368' 17-3/4" 790sxs 520' 520' 13-3/8" 2500sxs 5222' 4596' 9-5/8" 1600sxs 7"' 300sxs 11667' 9854' 11595'-12729' 9793'-10768' Uppermost 10,448' Lowermost 11,315' Uppermost 8,828' Lowermost 9,556' LS: 2-7/8", 6.4#, SS: 2-7/8", 6.4#, Otis ball valve @ Otis "BWD" N-80, Buttress @ 10,936' N-80, Buttress @ 10,354' 328'; Otis "RDH" dual pkr perm pkr @ 10,847' @ 10,306; 13. Stimulation or cement squeeze summary 14. Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ See Attached "Ceme~~l'V~rY Intervals treated (measured) Treatment description including volumes used and final pressure DEC Representative Daily Average Production or luj.UL,ur,~..raz. - , OiI-Bbl Gas-Mcf Water-Bbl Casing Pressu~~II ]]O~ing Pressure ss 46 1487 Prior to well operation LS 54 1026 SS 146 103 258 1310 psi (gas lift) L_~ 42 221 714 1310 ~:i ~ac lift; 16. Status of well classification as: Oil x_... Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / ~Roy D. Roberts -~,,'~ Title Environmental Engineer Form 10-404 Rev 06/15/88 ^ feet 90 SUBMIT IN DUPLICAIF Baroid Drilling Fluids, Inc. October 2, 1989 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re- Workover Fluids Recap G-31Workover (Grayling) Dear Mr. Chudanov' Attached is the workover fluids recap for the above referenced well. Please note the following comments as they apply to this workover. 1. Due to the extended fishing on the initial clean-out and numerous cement jobs-on the isolation work, 51 days of Technical Service were used on this workover. The technical service charge of $20,655 was 28% of the total $73,313 cost of our workover fluid services. 2. Two Baracarb Pills (sized CaC03) were used to keep the brine 1.osses to a minimum during the initial phase of the workover. A Litesal Pill (sized Ulexite salt)was used prior to the final completion. 3. 673 sacks of KC1 were used to maintain the specified 3% concentration. This amount of RECEIVED KC1 would have built approximately 5,600 barrels of 3% KC1/FIW brine. D[C2o1989 A) , .Oit & Gas Cons. Commissi 2000 West Int'l. Airport Rd., Suite A-10 (99502) · RO. Box 102492 · Anchorage, Alaska 99510 (907) 248-3511 .. Fax (907) 248-5390 Page 2 Mr. Don Chudanov Uncoal Oil & Gas Division Re: Workover Fluids Recap G-31 Workover (Grayling) October 2, 1989 4. A significant amount of polymers, both HEC and XC, were used to assist hole'cleaning efforts. Initially.high-vis sweeps were used, however, the entire system was treated for a time. Please refer to the recap for specific details concerning brine properties, material usage, billing data and operational notes. If additional information is required, please advise. Very truly yours, BAROID CORPORATION J. G. Rose District Engineer CC' Bush/Neve' Ri g Copy File Attachments RECEIVED DEC~ o1989 Alaska Oil & (~as Cons. Commissio.~ Anchorage Barazan Baravi s CAC12 Caustic 'EZ Mud KCl Li tepl ug-Fi ne Liteplug-R Liteplug-X Litesal Polytex-S Sapp Salt SDI Defoam Baracarb-5 Baracarb-50 Baracarb-150 Baracarb-600 Baracarb-2300 PAC-L Unocal Oil & GAs Division G-31Workover Inventory Beginning Invent°r~z Received 10 80 25 30 35 0 3 0 20 0 71 730 42 0 66 0 80 0 40 0 5 0 1 0 214 144 4 0 0 120 0 109 0 80 0 80 0 20 0 40 Ending 40 50 25 30 0 35 3 0 0 20 673 128 20 22 20 46 15 65 25 15 2 3 0 1 175 183 2 2 28 92 49 60 28 52 40 40 0 20 10 30 RECEIVED DEC201989 Alaska Oil & Gas Cons. Com~tSsi(~s Anchorage (, Unocal Oil & Gas Division order Document Numbers: qp_7037 ~ Q27039 Q27o32 Q27046 Q27054 Q27o56 Q27O67 Q27o$1 QZTOB2 QZ7OB3 Qz7o96 Q27O45 Q27O45 Q27O55 qz7O71 qz7O97 qz7ogg · qZTlO1 $15,2B5'10 16,723.47 16 ;425.27 7,480. OB 9,256. BO 15,146.80 16,720.72 17,020.00 3,686' 6B 2,161.52 Total Charges 5B2.00 1,916.00 392.40 21,144.72 14,002.07 11,202.09 Total Credits Total Well Cost $127,638.84' $73,313.ZZ RECEIVED DEC OI989 Ai~slm Oil & Gas Cons. Commlssi(t~ Anchorage II OPERATIONS · Unocal Oil & Gas Division G-31 Workover Date Depth, Ft. Tour 7-21-89 7-22 7-23 7-24 7-25 7-27 Move rig to G-31, open L.S. XA sleeve @ 10,290', Pump 625 bbls down tubing, no returns, monitor well on vaccum, pump 142 bbls down S.S. tubing w/annulus open, no returns. Bullhead 521 bbls down annulus, monitor well on vaccum, mix and pump 40 bbls Baracarb pill, bullhead down S.S. 300 psi increase. RIH w/wireline gage cutter, get to 8840', RIH w/wireline scratcher, hole still taking fluid. Mix and pump 41 bbls Baracarb pill, bullhead into formation, 500 psi build up, run tubing cutter and cut short string @ 10,330', Run tubing cutter in long string, cut L.S. Nipple down tree and N/U BOP, test BO~, RIH on S.S. and cut @ 10,322', R/U and circulate down SS, w/returns up L.S., circ tubing 'volume R/U to pull dual string, pulling on dual string. RIH and free point both L.S. and S.S. @ 10,270'. RIH, S.S., w/tubing cutter, no go @ 7244', R/U myers wireline and RIH, S.S., w/2.6 gage cutter, no go @ 7252', RIH w/2.5 swedge to 10,300', RIH w/2.65 swedge, pull out of rope socket @ 8531'.:. Retrieve swedge and POH with wireline, RIH w/2.60 9auge, work tight spots 8535' - 10,300', rig down meyers, rig up APRS, RIH w/tubing cutter on wireline, cut short side @ 10,245', rig W.L. over to long side and RIH, cut.long side @ 10,205', circ down long side and up annulus (no loss of fluid observed), cirCulate down short side of tubing and up annular while working tubing free (15.5 bbls/hour losses observed) and pump bottoms up, POH with dual tubing strings and lay down same. E~Q~nish la~ing down tubin.q (13 hours)~ replace rubbers on ram blocks and test BOP's, RIH w/3½" DP to 10,189', circulate above fish and add'3% KC1 over 2 circulations (have 304' of BHA inc. 6¼" DC's, jars and ove'rshot). Latch fish with overshot and jar free, circ hole clean, POH, recovered 93.82' of 3½" tubing, re-dress overshot, TIH to 10,220', circ btms up, dress and latch fish @ 10,250', POH with fish (wet fish was plugged), recovered 75.5' of tubing, pick up 60' tubing string and RIH ~o 10,250', wash from 10,250' to packer at 10,325', circ btms uo, start POH. OPERATIONS · Page 2 Unocal Oil & Gas Division G-31Workover' Date Depth~ Ft. Tour 7-28 7-29 7-30 7-31 . RE¢£1VED DEC201 'Nast Oil & Gas Cons. Commas' Anchorage 8-1 8-2 8-3 8-4 Finish POH, PU overshot and BHA and TIH, latch fish @ 10,300' and jar packer loose, circ btms up, pull 4 stands, circ btms up .again (gas), POH with fish, recovered packer with one short and one long piece of tubing in it, 'lay down fish and grapple, slip drlg line, P.U. 60' tubing stringer on DP and RIH, wash from 10,850' - 10,885' (tag solid fill @ 10,885'), circulate. Wash and work stringer f/10,885' - 10,900', circ btms up, POH, P.U. fishing assembly, change out jars, TIH to 10,873', dress and latch fish @ 10,873' and seal assembly, circ btms up, POH, lay down fishing tools, recovered 58.62' of Tbg and seal assembly, P.U. TSA mill and PRT and BHA, RIH and tag packer @ 10,900', work on rotary table, attempt to mill packer, no go, release PRT, circ btms up, POH. POH wi th mill and PRT tool, L.D. PRT tool, TIH w/PKP mill, mill on packer @ 10,900' 4 hours, POH, LD mill and PU spear, RIH and spear packer, work packer 14' down, POH w/packer. Lay down fishing tools (retrieved packer), test BOP's, P.U. mill boot basket and csg scraper and RIH, W & R f/10,950' - 11,234',. it got tight-at 11,234' so we pumped 50 bbls of high vis HEC sweep (vis - 150 sec, YP - 79), it brought lots of sand up which ~ept coming after sweep passed, so sweep was allowed to circulate around twice more, W&R f/11,234' - 11,245', POH. POH w/casing scraper and mill, RIH w/mill #2, Ream to 11,247', POH w/mill, remove rotary drive motor, P/U and RIH w/overshot. Washover fish to 11,253', POH, no recovery, reduce grapple.to 1" and RIH, Wash over fish to 11,253', POH, no recovery, RIH to spot Baracarb pill. RIH to 11,228', circ and mix Baracarb pill, pull up hole to 10,757' spot Baracarb pill, squeeze 35 bbls of pill into perfs, return to btm to tag fish and circ out remaining 65 bbls of pill, POH and P/U impression block, RIH w/Imp, block to 11,223', POH, P/U wash pipe. ~. RIH w/washpipe t© 11,213', ream/wash to 11,292', Pull hi vis sweep and CBU, work w~sh pipe and POH to 10,926', pull hi vis sweep and continue to oumo/POH tioht hole, rai~m viq w/[ mnh ~m~:~=n e~u Page 3 Unocal Oil & Gas Division G-31 Workover OPERATIONS · Date Depth~ Ft. Tour 8-4 (Continued) 8-5 8-6 8-7 8-8 8-9 'RECEIVED DEC201 Oil & Gas Cons. 8-10 Anchorage 8-11 L/D 3~" DP, hole tight to 8950', Complete laying down 3½" DP, change rams to 5", test BOE, P/U .wash pipe and RIH picking up 5" DP. RIH to 11,292', wash over to 11,382', hole tight, raise vis/yp with ½ ppb Barazan, POH, hole tight, run pump to pull pipe, change S.S. screens to ',.84" Pipe pull free @ 7205', clean junk from boot basket, change shoe and RIH, condition mud w/½ ppb Barazan, washover, clean/ circ between connections, pump hi vis "Baravis" sweep, wash to 11,526' and ta9 retainer @ 11,529', pump hi vis "Barazan" sweep and POH, hole tight, run pump to pull pipe. L.D. wash pipe, clean best baskets, P.U. mill and RIH to bottom on 11,526', hole clean, circ and work on pumps, pump high vis sweep and pull 50 stands, hole, OK. Mix and pump high vis Barazan sweep around from 11,527', POH, clean out junk baskets, run Schlumberger CET, BBT, GR casing inspection and cement bond logs, RIH with 9 5/8" RTTS and bypass sub, break circ, set RTTS @ 10~385' and test casing to 2000 psi' for 30 min, OK, release packer, pump bottoms up, pump salt slug ~or trip. POH w/RTTS, set cement retainers at 11,205' and 11,148' with Schlumberger wireline, pick up stinger on DP and RIH, break circ rig up and test Halliburton lines to 5000 psi, establish injection rate, got communication back to annulus thru perfs above upper retainer, mix and pump 15 bbls of 15.6# cement, squeeze 12. bbls holding annulus pressure under 1800 psi, reverse out twice, (got back 6 bbls brine cut cement, POH with DP and stinger). Make up RTTS and RIH, break circ, set RTTS and establish injection rates at 11,065' 11,058' 11038' 11030' 11,000' and 10,942' (got communication back to annulus at all but 10,942'), circ btms up, POH and LD RTTS, RIH w/bit and 2 junk baskets, tag top retainer at 11,148' (12' of cmt stringers above it), drill ~ retainer and good firm cmt f/11,151' - 11,203' (tag btm retainer), circ btms up, PDH w/bit, clean out boot baskets. Dc~te Depth, Ft. Tour 8-12 8-13 8-14 RECEWED DEC2019B9 Alas Oit & G.as Cons. Anchorage 8-15 8-16 - 8-17 8-18 Page 4 Unocal Oil & Gas Division G-31Workover OPERATIONS · PU stinger and cmt retainer and RIH, set EZ SV @ 11,138', test DP to 3000 psi, test Halliburton lines to 5000 psi, Establish .injection'rate, got communication around packer, changed plans, didn't cement here, reverse circ DP, POH with stinger and lay down same, PU 8½" bit and 2 csg scrapers and RIH, tag cmt retaine~ at 11,137' and drill on it, push it down hole to 11,201', circ, POH. test lines, establish injection rate, cement with 100 sxs 15.6# cmt, pull up 15' and reverse out DP, POH,'test BOP's, RIH with stinger and EZSV, set EZSV @ 11,067', test lines, establish injection rate, mix and pump 127 sx of 15.6# cmt, reverse out DP (got about 19 bbls raw cement back), POH. PU stinger and EZSV and RIH, set EZSV @ 11,032', test lines, -- establish rate, mix and pump 32 bbls of 15.6# cmt, hold back )ressure on annulU~ and squeeze, pick uP 15' and reverse out DP ot 25 bbls raw cement back due to communication back thru ~fs above retainer), POH, lay down stinger and bottom joint.DP, PU new stinger and EZSV and RIH, set EZSV @ 10,993', test lines, establish rate, mix and pump 19 bbls of 15.6# cmt, squeeze, pick up 15' and reverse circ DP, got~back 10 bbls raw cement, POH with stinger. PU mill, boot baskets and jars and RIH, break circ @ 10,959', tag soft cmt @ 10,986', tag and drill out EZSV @ 10,994', wash and drill cement to next EZSV @ 11,032', drill on packe~ 5~ hours, didn't 9e~ through it, POH for new mill. Lay down mill, clean boot baskets, RIH w/bit #3, drill cement to 11,066', drill on EZSV to 11,072', POH and P/U Bit #4. RIH w/bit #4, drill EZ~V and clean cmt to 11,203', CBU twice and POH, P/U Howco RTTS and RIH, discard cmt flocculated polymer brine (247 bbls). Test lines to 5000 psi and test squeeze at 11,148', 11,148' to 11,067' to 11,032' and 11,032' to 10,993' all tests failed, CBU and POH, hole tight & swabbing, CBU again and POH, Add 50 bbl FIW, P/U Howco squeeze tools and RIH. OPERATIONS · Page 5 Unocal Oil & Gas Division G-31 Workover Date De~th, Ft. Tour 8-19 8-20 8-21 8-22 8-23 8-24 Set EZSV @ 11,147' and squeeze, release retainer and reverse circ, discard 30 bbls cmt/brine, POH, P/U EZSV and new stinger, .RIH, set EZSV @ 11,067'. and squeeze, release retainer, reverse circ, discard 36 bbls excess cmt/brine, POH, P/U EZSV and stinger, RIH. Set EZSV and prepare to squeeze formation work, not taking fluid, POH for EZSV, RIH and set EZSV @ 10,993' and squeeze, reverse circ, discard 35 bbls cmt/brine, POH, P/U bit #5 and RIH. Drill out retainer @ 10,993' and 11,031', CBU and POH, P/U RTTS and RIH, test squeeze from 11,031' to 11,067', OK. Pull up and test squeeze from 10,993' to 11,031', would not hold, POH for Bit #6 and RIH. Drill out retainer @ 11,067.', tag lower EZSV @ 1,1148', circ hole clean, POH w/drlg assembly, PU RTTS and RIH, break circ, set RTTS @ 11,067', test csg from 11,067' to 11,148', broke down at rate ,,, of I bbl/min, at 5400 psi, set RTTS @ 11,007', wouldn't hold pressure there either, POH w/RTTS, PU EZSV cmt retainer on drill pipe and RIH to 11,067', set EZSV, test lines, establish injection rate. Squeeze cement @ 11,067' with 22 bbls of 15.6# cmt, reverse circ DP clean (got back approx. 18 bbls cement), POH w/stinger, PU bit and drilling assembly and RIH, PU kelly and Circ and WOC for 3½ t(~ours, drill out retainer @ 11,067' and clean out to 11,147' (no cmt under retainer), circ hole clean, POH w/drl9 assembly, PU bypass sub and RTTS and RIH. Pressure test, squeeze didn't hold 4600 psi, establish 3/4 bbl/min. rate @ 5300 psi, POH w/R?TS, PU EZSV packer and TIH to 11,066', Set packer @ 11,066', pressure test lines and pumps to 7000 psi, sting into packer and ~stablish injection rate while holding 200 psi on the annular, un-sting from retainer, mix and pump 42 bbls of 15.5# cmt and displace while holding 1000 psi back pressure stab in and squeeze while holding 2000 psi on the annulus, pull out of retainer and reverse circ DP clean (got back 20-30 bbls raw cmt) POH and LD stinger, PU bit and RIH. Page 6 Unocal Oil & Gas Division G-31 Workover OPERATIONS · Date Depth, FI'. Tour 8-25 8-26 8-27 8-28 DE C 2 o 1989 8-29 8-30 8-31 Circ and WOC for 9½ hours, drill out cmt and EZ drill retainer at 11,071' and 11,147' clean out to 11~203' circ TOH for new bit .PU bit #9'and RIH, dril. 1 out cement retainer @ 11,203' to 11~208', clean out to 11,452' circ hole clean, clean out to 11,524' , , circ btms up, POH w/bit. Rig up Schlumberger, RIH with gage ring and junk basket on wireline, POH w/wireline. RIH with EZSV on wireline, set EZSV @ 11,403', POH w/wireline, RIH w/perf gun on wireline, perforate @ 11,364', POH w/perf gun. RIH with EZSV on wireline, EZSV set unintentionally @ 9780', POH w/wireline and rig down Schlumberger, PU bit #10 and RIH, drill out cement retainer @ 9780', RIH slowly to tag other EZSV @ 11,403' OK, circ bottoms up, POH with bit, RIH with new EZSV. Set new EZSV @ 11,350', test lines, establish injection rate, mix and pump 21 bbls of 15.6# cement, displace cmt, stab into retainer but could not pump any cmt thru tool (evidently some junk or fill came into the annulus from the perfs above the top EZSV while we were establishing our injection rate into the perfs below the top EZSV, as there is know to be communication, squeeze was designed to be a "circulating squeeze"). Pull out of retainer and reverse circ DP clean, get all 21 bbls of our raw cement back' POH w/stinger PU bit #11 and RIH, drill out retainer at 11,350', and clean out to 11,398', circ btms up, POH and LD bit and boot baskets, RIH w/new EZSV. Set retainer @ 11,345', establish injection rate, mix and pump 21 bbls cmt slurry w/lO bbls perflush and post flush, spot' slurry but no squeeze, reverse circ and discard 31 bbls, POH, P/U drlg assembly, RIH and dr'l'g/chase retainer to 11,390', mix and pump hi vis sweep, POH, P/U and RIH with retainer. Set retainer @ 11,347'~ duplicate, spot and squeeze cmt slurry, reverse circ and dump 31± bbls cement, cement contaminated FIW POH and lay down tools, P/U bit #12 and drillin9 assembly and RIH, circ until 2000 hours while WOC, drill on retainer. POH for NB @ 11,400', RIH w/bit #13 and drill on retainer to 11,404', push jdnk to 11,508' and drill on same to 11,522', POH, Pill F7 D~!! ~H Date Degth, Ft. Tour 9-1 9-2 9-3 9-4 D[C201 9 9-5 Maslm 0it & cons. 'Anchorage 9-6 9-7 9-8 9-9 OPERATIONS - Page 7 Unocal Oil & Gas Division G-31Workover .. Set EZ Drill @ 11,509', CBU and test for sheen and pH~ dischard 412 bbls excess W/O fluid. Discharge diluted 100% w/412 bbls FIW~.. .build 820'bbls FIW @ 3% KC1 and filter same. Finish cleaning pits, displace hole w/FIW and circ until clean, displace FIW w/3% KC1 brine, build additional 220 bbls 3% KC1 and refilter entire system to 30 NTU, POH and P/U guns and RIH. discharge 765 bbls workover fluid, diluted 100% w/FIW. RIH w/perf guns, wireline correlation log and set packer, fire guns and monitor well, mix 250 bbls 3% KC1/FIW, reverse circ, sending 200 bbls to production, continue reverse circ, additional 200 bbls thru pits, CBU long and POH, H2S present while laying tools. RIH w/RR #13 and clean out to 11,505', pull up to 11,300' and spot 50 bbls Litesal pill, squeeze pill w/400 psi, run in hole ,,. to circ hole clean, POH and P/U Otish perma drill packer,~RIH and set packer @ 11,847', build 50 bbls 3% KC1 for active and bbls 3% KC1/FIW for reserve filter, reserve brine to 15 NTU. Spot 10 bbls frac sand @ 10,829', pull 5 stds and circ hole clean, run in and tag sand @ 10,841', pull up to 10,767' and circ and filter active brine system to 23 NTU, POH and P/U guns and equipment RIH filling 67 stds w/brine. Position guns and fire same monitor fluid levels, reverse circ 250 bbls to production, continue reverse circ, another 280 bbls thru pits, unseat packer and monitor well, 3½± BPH loss, POH, · guns and equipment P/U retrieving tools, RIH to 11,820'~, monitor well, fluid loss @ 1± BPH, tag frac sand and reverse circ, cleaning holeto 11,847'. POH laying down 5" DP, P}U dual production assembly and start in hole picking up 2 - 2 ~/8 tubing Continue running dual 2 7/8" tubing, hydro test while running Land tubing, nipple down, discharge 1,652 bbls. RECEIVED DEC2.01~9 AlaSl~ Oil & Gas Cons. Commlssi(l:~ Anchorage ALASKA OIL AND GAS CONSERVATION COMM k ,)N D% I[ G N · APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Alter casing __ Repair well __ PlugQ~r)g __ Change approved program __ Pull tubing ~ Variance ~ 2. Name of Operator ~ 5. Type of Well: Union Oil Company of California (UNOCAL)! Development~[_ Exploratory __ 3. Address Stratigraphic_ P.O. Box 190247, Anch, Ak., 99519-0247 Service__ 4. Location of well at surface ~9~*i~,g {~*°~mF~~;orner2' Conductor, uec. ~,8'T9N, R13W, SM. At top of productive interval Operation shutdown __ Re-enter suspended well __ Time extension __ Stimulate __ Perforate Z.._ Other __ 1768' N & 3664' E F/SW Corner, Sec. 28, T9N, R13W, SM. ~effectivedepth 1585'N, 3831' E. F/SW Corner, Sec. 28, T9N, R.3W, SM ~totaldepth 1223' N, 4423' E. F/SW Corner, Sec. 28, T9N, R.3W, SM 6. Datumelevmion(DForKB) 99 KB above MSL 7~nitgr Prop~y nqm~ ~ a~ng nay un~= 8. Well nurr~_§ 11. 9. Permit number 69-72 10. APl number 50 133-20194 11 .Fie. Id/Pool Mcar~nur River/Hemlock feet ,,, , 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12,729' feet Plugs(measured) 10,768' feet 11,524' fe~ Junk(measured) 9,732' feet Ret @ 11524', TOF 11576' Casing Length Structural 368' Conductor 520 ' 5,222' Surface 11,667' Intermediate 1,134 · Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments Size Cemented 26" Driven 17-3/4" 790sxs 13-3/8" 2,500sxs 9-5/8" 1,600sxs 7" 300sxs MeasureddeCh ~ueverticaldepth 368' 368' 520' 520' 5,222' 4,596' 11,667' 9,854' 11,595'-12,729' 9,793'-10,768' Uppermost Lowermost Uppermost Lowermost 3-1/2", 9.2#, N-80 RECEIVED 10,966' JUN 07 t989 9,263' 9,5 5 6' Alaska Oil & Gas Cons. Commi~ 10,9 3 3' Anchorage Otis Ball valve @ 303'; Baker A-5 dual pkr @ 10,324'; Description summary of p-~o-I~-s~l ~ .... "-D-e~ail~d ~p~rations program ~ BOP sketch ~ 14. Estimated date for commencing operation I July 15, 1989 16. If proposal was verbally approved Oil __X Gas Name of approver Date approved Service 17. I hereby~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~..X..~~~~ ~// Title Environmental Enqineer ..... ~v~l~_., /2 FOR COMMISSION USE ONLY Conditions'(J~¢pp~o'val'."~'t~(~mmissio~o representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ 15. Status of well classification as: Suspended __ Date 6 / 2 / 89 j Approva, No. 9- o~,'~'~,':' J Mechanical Integrity Test_ Subsequent form required lO- ORIGINAL SIGNED BY J Ap_proved bv order of the Commissioner LONNIE C. SMITH ~,pOroved C.oP¥ RTrne~ Commissioner F(~m~l~)'-~,~):~ ~ev 06/15/88 SUBMIT IN TRIPLICATE le 2. 3. 4. Se e 7, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. GRAYLINE PLATFORM WELL G-31L WORKOVER PROCEDURE Move rig #54 over TBUS G-31, Leg #2, conductor #38. Kill Well. Install BPV's, remove tree, install and test BOPE. Pull and lay down 3-1/2" production string, Baker "A-5" dual packer set at 10,324' DIL. Burn over and recover Baker single permanent. Packer is set at 10,900' DIL. Clean out inside 9-5/8' casing below deepest interval (Hemlock bench 4 at 11,315' DIL) to 11,524' ETD with 8-1/2" bit and 9-5/8" casing scraper. Junk exists in the annulus and was last tagged at 11,277' CTM. Run a casing inspection log from 11,524 ETD to surface. Pressure test the 9-5/8" casing. Perform injectivity test into wet Hemlock benches in preparation to squeeze. Cement squeeze the following Hemlock benches: HB2 11,008'-11,140'; HB3 11,153-11,200'. Clean out to 11,524' DIL with 8-1/2" bit. Change over to clean completion fluid. Reperforate the following Hemlock zones underbalanced with 7" OD tubing conveyed guns at 4 SPF: HB1 10,960'-10,990 DIL (30'); HB4 11,211'-11,315' DIL (104'). Clean out inside 9-5/8" casing with 8-1/2" bit and 9-5/8" casing scraper to 11,524' ETD. Isolate the Hemlock benches from the "G" zone. Reperforate the "G" zone underbalanced with 7" OD tubing conveyed guns at 4 SPF. "G" Zone 10,450' - 10,480' DIL (30') 10,540' - 10,570' DIL (30') 10,610' - 10,635' DIL (25') 10,708' - 10,728' DIL (20') Clean out inside 9-5/8" casing with 8-1/2" bit and 9-5/8" casing scraper to 11,524' ETD. Run a dual completion assembly. (Long 3-1/2" and Short 2-7/8"). Remove BOPE and install dual tree. Return well to production. Well control fluid: 3% KCL with filtered inlet water SBHP: 4025 PSI 0019n/78 17-3/4" @ 520' 13-5/8" @ 5222' Z TOP JUNK ?? 7" TOL @ 11595' 9-5/8" @ 1 1 667' 7" L @ 12729' 7 TUBING DETAIL LS' 3-1/2", 9.3#, N-80 BUTT SS: 2-7/8", 6.4#, N-80, BUTT 1) SSSV 2) GLM's 3) XA SLV's 4) "X" NIPPLE 5) RE-ENTRY GUIDE 6) DUAL PER @ +/- 10;300' 7) PERM. PKR @ +/- 10850' "G" ZONE INTERVALS F/ 1 0450'- 10728' HEMLOCK BENCHES HB1 10960'-10990' HB2 11008'-11025' SQZ'D 11 04-2'- 11057' SQZ'D 11 090'-111 40' SQZ'D 111 55'-11200' SQZ'D 11211'-11218' 11255'-11315' ET. @ 11524.' ETD HB3 HB4 EZSV R TOF @ 11576' WELL TBUS 6;-31 PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE: NONE DATE: 3-20-89 .o G ZON · V HB-1 HB-2 HB-3 HB-4. vi VII VIII WELL TBUS G-31 GLMI' 1 3 CASING & ABANDONMENT DETAIL I.) Rotary Table Measurement at 0.00° II.) Cameron Split Dual Tubing Hanger at 38.60' III.) 17 3/4°, 0.312' Spiral Weld Casing at 520' IV.) 13 3/8', 61P, J-55 Casing at 5222' V.) Howco 'EZSV° Retainer at 11,524' VI.) Top 7', 29~, N-80 Liner at 11,595' VII.) 9 5/8°, 43.5~ & 47~', N-80 & P-110 Casing at 11,667' VIII.) Bottom 7', 29~, N-80 Liner at 12,729' TUBING DETAIL LONG STRING: 3 1/2", 9.2~, N-80 TUBING 1.) Otis Ball Valve at 302.97' 2-17.) Camco Gas Lift Mandrels at: 2) 1901.62' 3) 3010.91' 4) 4031.06' 5) 4953.05' 6) 5582.82' 7) 6054.45' 8) 6494.80' 9) 6932.36' 10) 7362.30' 11) 7742.27' 12) 8143.55' 13) 8575.36' 14) 8971.56' 15) 9372.60' 16) 9780.26' 17) 10,162.45' 18.) Otis 'XA' Sleeve at 10,289.82' 19.) Baker Model 'A-5' Dual Packer from '-' 10,323.90' to 10,337.60' 20.) Otis 'XA' Sleeve at 10,863.92' 21.) Buttress Locator Sub at 10,899.00' 22.) Baker Perm. Packer with Seal Assembly from 10,900.00' to 10,921.06'. Packer at 10,900' 23.) 'Q' Nipple at 10,931.22' 24.) Bottom of. Mule Shoe at 10,933.50' .SHORT STRING: 3 1/2", 9.2~ N-80 T, UBING A.) Otis Ball 'Valve at 299.57' B-H.) Camco Gas Lift Mandrels at: B) 1991.56' C) 3527.82' D) 5079.23' E) '6427 67' F) 7703.18' G) 8941.97' H) 10,059.54' __l~ I..) Otis 'XA° Sleeve at 10,290.05' J.) Baker Model 'A-5' Dual Packer .from 10,323.90' to 10337.60' K.) Bottom of 'Q' Nipple at 10,349.15' PERFORATION RECORD DA TE INTERVAL CONDITION 9/18169 10708'-10728' Open G Zone Production ~22 5/04174 10540'-10570' Reperf G Zone Production 5/04/74 10450'-10480' Reperf G Zone Production 5/04/74 10610'-10635' Reperf G Zone Production 5/13174 11255'-11315' HB-4 Production 5/15/74 11160'-11190'. HB-3 Production 5/16/74 10966'-10986' HB-1 Production 11(~15'-11025' HB-2 Production 11042'-11057' HB-2 Production . 11080'-11110' HB-2 Production NOTE: 8ottom of Long String w~s shot off ' in Aug, 1980, WELL TBUS G-31 WELL SCHEMATIC UNION OIL COMP&NY OF CALIFO~INIA BELL NIPPLE 1 FLOWLINE 12" 5000 PSI ANNULAR I' ' ~---I 13-5/8" 3M FLANGE ' ~ ADAPTER 5M x 5M l I I ,.. . , I 13-5/8" 5M FLANGE BLIND RAMS , DOUBLE GATE 5M I PIPE RAMS , I I I !15-5/8" 5M FLANGE 2" KILL LINE WITH I, I 4." CHOKE LINE WITH ONE REMOTE (2) I & 1 MANUAL 4-" 5M VALVE 2" 5M VALVES I, ' :;L:' , :LL:' I ::l:' ::l:" I KILL LINE FROM MUD PMP CONNECTED TO CHOKE MANIFOLD &: CEMENT UNIT I ' (SEE MANIFOLD DRAWING) I I.._...m , ] 15-5/8" 5M FLANGE PIPE RAMS SINGLE GATE 5M , I I I I 15-5/8" 5M FLANGE I,, 1 RISER I, ! 10" 5M x 13-5/8" 5M I1 ...... !I ADAPTER I CAMERON 5M DCB ~OOL .U 1 , 15-5/8" BOPE 5M STACK DRAWN: CLL APP'D: GSB ALL DRILLING OPERATIONS SCALE: NONE DATE: 5/12/89 UNION OIL COMPANY OF CALIFORNIA (db~ UNOCAL) , , STATE OF ALASKA AL , OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ Stimulate __ Plugging __ Perforate.,~' Repair well __ Pull tubing __ Other __ 2. Name of Operator ! 5. Type of Well: Union 0il Company of' Calif'ornia (UN0CA~)' Development Exploratory __ 3. Address ! Stratigraphic_ P.O. Box 190247: Anch~ Ak.~ 99519-0247!-- Service__ 4. Location of well at surface 1878'N, 1389' W F/SE corner, Sec. 29, T9N, R13W, SM At top of productive interval 1768' N, 3664'E f`/SW corner, Sec. 28, T9N, R13W, Slvl At effective depth 1585'N, 3931'E f/SW corner, Sec. 28, T9N, R13W, SM At total depth 1223'.N, 4423'E f/SW corner~ Sec. 28, T9N, R13W, SM 12. Present well condition summary Total depth: measured 10,729 ' feet Plugs (measured) true vertical 10,774 ' feet 6. Datum elevation (DF or KB) 99'KB above MSL 7. Unit or Property name TBU 8. Well number G-31L 9. Permit number/approval num her 8-332 69-72 lO. APl number 50-- 133-20194 11, Field/Pool Hemlock Effective depth: measured 11,524 ' feet Junk (measured) true vertical 9,732 feet feet Casing Length Size Cemented Structural 368 ' 26" Driven Conductor .520' 17 3;/4" 790 SXS Surface 5222' 13 3/8" 2500 sxs Intermediate ll, 667' 9 5/8" 1600 sxs Production 1134' 7" 300 SX Liner Perforation depth: measured uppermost 10,966' lowermost 11,315 ' true vertical uppermost 9,263 ' lowermost 9,556 ' Tubing (size, grade, and measured depth) 3 1/2", 9. N-80 $ 10,933' Measureddepth 368' 520' 5222' 11,667 11,595'-12,729' PackersandSSSV(typeandmeasureddepth) Otis ball valve $ 303' A-5 dual Baker perm pkr $10,900' Wueverticaldepth 368' 520' <ECEIVED Al~sim .Oil & Gas C0ni. C0mmiisi Rnch0rage pkr. ~ 10,324' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 6 71 58 1160 Tubing Pressure 100 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations 55 73 1223 1050 16. Status of well classification as: Oil .~ Gas_ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 100 Signed Roy rD. Roberts Title Environmental E-nqi neer Form 10-404 Rev 06/15/88 Dat~O/31/88 SUBMIT IN DUPLICATE STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ~,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate '~ Other [] 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of. wellatsurface 1878'N, 1389' W F/SE corner, Sec. 29, T9N, R13W, S~ Attop ofproductiveinterval 1768'N, 3664'E f/SW corner, Sec. 28, T9N, R13W, SH Atef~ective depth 1585'N, 3931'E f/SW corner, Sec. 28, T9N, R13W, SH At total deoth 1223'N, 4423'E f/SW corner, Sec. 28, TRN, R13W, SH 5. Datum elevation (DF or KB) 99' KB abof~t 6. Unit or Property name TBU 7. Well number G-31L 8. Permit number 69-72 9. APl number 50-- 133-20194 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 10,729' feet Plugs (measured) 10,774 ' feet Effective depth: measured 11,524' feet Junk (measured) 732 true vertical 9, feet Casing Length Size Cemented Structural 368' 26" Driven Conductor 520' 17 3/4" 790 sxs Surface 5222' 13 3/8" 2500 sxs 11,667' 9 5/8" 1600 SXS Intermediate Measured depth 368' 520' 5222' 11,667 True Vertical depth 368' 520' Production 1134' 7" 300 sx Liner 11,595'-12,729' Perforation depth: measured true vertical ppermos~ 10,966' owermos~ 11,315' uppermost 9,263' Tubing (size, grade and measured ~e~rmost 9,556' 3 1/2", 9.2~f N-80 $ 10,933' Packers and SSSV (type and measured depth) 12.Attachments Description summary of Otis ball valve $ 303' A-5 dual pkr. $ 10,324' Baker perm pkr $ 10,900' proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 5-01-88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~ '~~ Roberts Title Environmental Spec. Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Date n~/~7/88 Approved by~~ '2~/~~~'~/ Form 10-403 Rev~2-1-85 , [ / / ~pproved Copy Returned .~, "' by order of Commissioner tje commission Dat;ubmit/1n triplicate ISL G-31 L PERFORATION PROCEDURE 1. Rig up E-Line Unit. Pressure test lubricator to 2500 psi. 2. RIH with 2 1/8" perforating guns, 8 SPF, 0° phasing. Perforate underbalanced or flowing as follows: B-1 B-3 B-3 B-4 B-4 10,9~0'-10,990' DIL 11,153'-11,190' DIL 11,190'-11,200' DIL (new) 11,211'-11,255' DIL (new) 11,255'-11,315' DIL 3. Rig down E-Line Unit. 4. Flow well to test separator. ,? GLIb. I 13 14 15 16 17 18 ,HB-Z ~ ~ASING & ABANDONT;,~NT DETAIL I.! Rotary Table Measure~ "at 0.00' lI.~ Cameron Split Dust Tu~.. Hanger at 38.60" III.) 17 3/4', 0.312' Spira'l Weld Casing at 520" IV.) 13 3/8", 61~, J-55 Casing at 5222' V.) Howco 'EZSV° Retainer at 11,524' VI.) Top 7', 29+, N-80 Liner at 11,595' VII.) g 5/8', 43.5+ & 47+, N-80 & P-110 Casing at 11,667' VIIi.) Bottom 7°, 29,~, N-80 Liner at 12,729' TUBING DETAIL LONG STRING: 3 1/2", 9.2#, N-80 TUBING 1.) Otis Bali Valve at 302.97' 2-17.) Camco Gas Lift Mandrels at: 2) 1901.62' 3) 3010.91' 4) 4031.06' 5) 4953.05' 6) 5582.82' 7) 6054.45' 8) 6494.80' 9) 6932.36' 10) 7362.30' 11) 7742.27' 12) 8143.55' 13) 8575.36' 14) 8971.56' 15) 9372.60' 16) 9780.26' 17) 10,162.45' 18.) Otis 'XA' Sleeve at 10,289.82' 19.) Baker Model 'A-5' Dual Packer from "" 10,323.90' to 10,337.60' 20.) Otis 'XA' Sleeve at 10,863.92' 21.) Buttress Locator Sub at 10,899.00' 22.) Baker Perm. Packer with Seal Assembly from 10,900,00' to 10,921.06'. Packer at 10,900' 23.)'O' Nipple at 10,931.22' 24.)Bottom of Mule Shoe at 10,933.50' SHORT .STRING: 3 1/2', 9.2#. N-80 TUBING A.) Otis Ball 'Valve at 299.57" B-H.) Camco Gas Lift Mandrels at: B) 1991.56' C) 3527.82' D) 5079.23' E) 6427 67' F) 7703.18' a) 8941.97.' H) ,059.54' I.) Otis'XA" Sleeve at 10,290.0 ' J.) Baker Model 'A-5" Dual 'Packer from 10,323.90' to 10337.60' K.) Bottom of 'Q" Nipple at 10,349.15' PERFORATION RECORD DATE ' INTERVAL CONDITION 1 9/18/69 5/O4/74 5/04/74 5/04/74 5/13/74 5/'15/74 10708'-10728' Open G Zone Production 10540'-10570' Reperf G Zone Production 10450'-10480' Reperf G Zone Production 10610'-10635' Reperf G Zone Production 11255'-11315' HB-4 Production 11160'-11190' HB-3 Production HB'3 ~ 5/16/74 4.OJg-6-6-~-l'e~:J'~ MB-1 Produclion ' 11042'-11057, HB-2 Production Ht~-4, :~ '~_--~ ,,l- vii · in Aug. 1980. ' ' Viii J ' ' 1: , · WELL TBUS G-31 WELL SCHEMATIC ,,... ,.. , ;. --... · NONE ..'. ~/Za/e5 ". ~. - STATE OF ALASKA ~r ALASt( O , b AND GAS CONSERVATION COMf~ SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other F~ 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Comjpany of California dba UNOCAL 99' KB Above MSL Feet 3. Address 6. Unit or Property name P.O. BOX ~390247, Anchorage, Alaska, 99519-0247 Trading Bay Unit 4. Location of well at surface 7. Well number 1878' N, 1389' W f/SE Corner Section 29, R13W, S.M. G-31L At top of productive interval Top Hemlock: 1768' N, 3664' E 8. Approval number f/SW Corner, Section 28, T9N, R13W, S.M. 566 At effective depth 9. APl number 1585' N, 3931' E f/SW Corner Section 28, T9N, R13W.S.M. 50-- 133-20194 At total depth 10. Pool 1223' N, 4423' E f/SW Corner Section 28, T9N, Ri3W, S.M. McArthur River Field/Hemlock 11. Present well condition summary Total depth: measured 12,729 feet Plugs (measured) true vertical 10,7?4 feet Effective depth: measured 11,524 feet Junk.(measured) true vertical 9, ?32 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 368 ' 26" Driven 368 ' 368 ' Conductor 520 ' 17-3/4" 790 sx 520' 520 ' Surface 5222' 13-3/8" 2500 sx 5222' 4602' Intermediate 11,667' 9-5/8" 1600 sx 11,667' 9854' Production -- Liner 1134' 7" 300 sx 11,595'-12,'729' 9792'-10774' Perforation depth: measured Upper Most 10,966' LOwer Most 11,315' true vertical Uppe.r Most 9,263' Lower Most 9,556' 3AN 0 6 1987 , Tubing (size, grade and measured depth) 3-1/2", 9.29, N-80 @ 10,933 a~sSks. 0il & G3$ C0~ts. Commission Anchorage Packers and SSSV (type and measured depth) Otis Ball Valve @ 303' "A-5" Dual pkr. @ 10,324', B. aker Perm. pkr. @ 10,900' 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 30 0 160 1090 90 Subsequent to operation 55 26 1189 1 o~q0 1 14. Attachments Daily Report of Well Operations I~-i,, Copies of Logs and Surveys Ru..n [] 15. I'hereby certif~t the foregoing is tr~ a~rect to the best of my knowledge Form 10/04 Rev. 1L¢-1-8~ v- ;. ~ Submit in Duplicate DAILY REPORT OF WELL OPERATIONS 12-5-86 12-6-86 12-7-86 12-8-86 12-9-86 ll,524'ETD ll,279'ETD Commenced o.perations 2100 hours 12-4-86. Moved rig over G-31L. Attempted to pull ball valve at 303'. No go. Spotted acid for 1 hour. Pulled ball valve. Rigged up C.T.U. Tested surface equipment to 3000 psi. Ran in hole and tagged scale at 6470' with 2.6" O.D. wash tool on 1-1/4" coiled tubing. Cleaned out to 6885'. Unable to wash deeper. Pulled out of hole. Ran in hole with 1-3/4" Dyna-drill with 2.7" mill. Tagged scale at 5627'. Cleaned out scale to 6460'. Dyna-drill lost torque. Pulled out of hole at midnight. Finished pulling out of hole and discovered lost Dyna-drill in hole. Ran in hole with C.T. and overshot with 1.75" grapple. Tagged fish at 6464' Set down 900#, picked up with 1000# over pull. Pu~led out of hole with fish. Ran in hole with 2-3/8" Dyna-drill and 2.7" mill. Tagged scale at 6460'. Cleaned out to 6960'. Dyna-drill locked up. Pulled out of hole. Ran in hole with 2.7" hydrablast tool at midnight. Ran in hole with hydrablast tool. Unable to get below 2320'. Pulled out'of hole. Ran in hole with 1-3/4" Dyna-drill and 2.7" mill. Tagged scale at 6960' · Cleaned out to 7391' with slow progress. Pulled out of hole. Mill was 1/8" out. Ran in hole with 1-3/4" Dyna-drill and 2.7" diamond bit. Tagged scale at 6647'. Cleaned out to 9085' at midnight. Continued to clean out scale with 1-3/4" Dyna-drill and 2.7" diamond bit from 9085' to tubing tail at 10,926'. Pulled out of hole. Ran in hole with 1-3/4" wash tool with pump off and tagged fill in casing at 11,240'. Cleaned out casing fill using high vis sweeps with gas lift on. ~Tagged top o.f junk/fill at 11,279' (36' of HB-4 covered). Unable to clean out deeper. Circulated bottoms up. Pulled out of hole to 10,870' and circulated tubing capacity. Ran in hole with pump off and tagged hard fill at 11,279'. Pulled out of hole at midnight to move to G-21. Finished pulling out of hole. Rigged down coiled tubing unit. Released rig 0300 hours 12-9-86. ALAS . OIL AND GAS CONSERVATION COM APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) feet /,~ UNOCAL Corporation Address P. o. Bo× ].90247, Anch., Ak. 995].9 Attn' C. Lockwood Location of well at surface 1878' N, 1389' W f/SE Corner Section 29, R13W, S.M. At top of productive interval Top Hemlock: 1768' N, 3664' E f/SW Corner Section 28, At effective depth T9N, R13W, S.M. 1585' N, 3931' E f/SW Corner Section 28, T9N, R13W, S.M. At total depth 1223' N, 4423' E f/SW Corner Section 28, T9N, R13W, S.M. 11. Present well condition summary 99' KB Above MSL 6. Unit or Property name Trading Bay Unit 7. Well number G-31L 8. Permit number 69-72 9. APl number 50-- 133-20194 10. Pool McArthur River Field/Hemlock RECEiVF. D' Total depth: measured 12,729 feet true vertical 10,774 feet Effective depth: measured 11,524 feet true vertical 9,732 feet Casing Length Size Structural 368 ' 26" Conductor 520 ' Surface 5222 ' Intermediate 11,667 ' Production Liner 1134' Perforation depth: measured 17-3/4" 13-3/8" 9-5/8" Plugs (measured) Junk (measured) Cemented Driven 790 sx 2500 sx 1600. sx NOV 1 5 1986 0ii & Gas Cons. C0mmissi0n knct~orage Measured depth 368' 520' 5222' 11,667' 7" 300 SX 11,595'-12,729' ~ueVerticaldepth 368' 520' 4602' 9854' 9792'-10774' Upper Most Perf: 9263' true vertical Lower Most Perf: 9556' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) ) ) ) ) ) ). SEE ATTACHED SCHEMATIC 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation December 1, 1986 14. If proposal was verbally approved Name~ 15. ~--~er_eb.~¢'. tyt~y~go,ny~. ~~..~?rrect Signed v ~,- Title / '} Commission Use Only Co,gzfitions of apprdval N( tify ( 3mmissi ,,~ [] Plug integrity Date approved to the best of my knowledge Drilling Superintendent Date 11-10-86 Approval No. ~---~ G Approved by Notify commission so representative may witness [] BOP Test [] Location clearance Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate G-31L COILED TUBING CLEANOUT PROCEDURE 1. RU slickline and pull ball valve. 2f e Se e MU KCl-polymer workover fluid RU skid pump unit to 1-1/4" coiled tubing unit. Pressure test surface equipment to 3000 psi. Function test coiled tubing unit BOP system. RIH with Otis Hydrablast tool on 1-1/4" coiled tubing to +--500' and break circulation with KCl-polymer fluid. Continue down hole and clean out scale to tubing tail. (Reciprocate and check pick up weight on coiled tubing after every 20' drilled to insure no bridging. If returns are lost during operation turn on gas lift and reestablish circulation. Use nigrogen to provide additional lift if needed.) 7. POH with coiled tubing and RD. Replace ball valve. 8. Return well to production and demob. 11-10-86 0173D C WELL TBUS G-31 CASING & ABANDONMENT DETAIL I.) Rotary Table Measurement at 0.00' II.) Cameron Split Dual Tubing Hanger at 38.60' III.) 17 3/4', 0.312' Spiral Weld Casing at 520' IV.) 13 3/8'. 61+, J-55 Casing at 5222' V.) Howco 'EZSV' Retainer at 11,524' VI.) Top 7', 29~,, N-80 Liner at 11,595' VII.) 9 5/8°, 43.5, & 47+, N-80 & P-110 Casing at 11,667' VIII.) Bottom 7°, 29~,. N-80 Liner at 12.729' TUBING DETAIL 18.) 19.) 20.) 21.) 22.) 9/18/69 10708'-10728' Open G Zone Production 5/04/74 10540'-10570' Reperf G Zone Production 5104/74 10450'-10480' Reperf G Zone Production 5/04/74 10610'-10635' Reperf G Zone Production 5113/74 1'11255'-11315' HB-4 Production 5/15/74 11160'-11190' HB-3 Production 5116/74 10966'-10986' HB-1 Production 11015'-11025' HB-2 Production 11042'-11057' HB-2 Production ,11080'-11110° HB-2 Production LONG STRING: 3 'I/2", 9.2#, N-80 TU. BING 1.) Otis Ball Valve at 302.97' 2-17.) Camco Gas Lift Mandrels at: 2) 1901,62' 3) 3010.91' 4) 4031.06' 5) 4953.05' 6) 5582.82' 7) 6054'.45' 8) 6494.80' 9) 6932.36' 10) 7362.30' 11) 7742.27' 12) 8143.55' 13) 8575:36' 14) 8971.56' 15) 9372.60' 16) 9780.26! 17) 10,162.45' Otis 'XA° Sleeve at 10,28-9.82' Baker Model 'A-5' Dual Packer from 10,323.90' to 10,337.6Q' Otis 'XA° Sleeve at 10,863.92' Buttress Locator Sub at 10,899.00' Baker Perm. Packer with Seal Assembly from 10,900.00' to 10,921.06'. Packer at 10,900' 23.) 'Q' Nipple at 10,931.22' 24.) Bottom of Mule Shoe at 10.933.50' SHORT STRING: 3 1/2", 9.2#. N-80 TUBING A.) Otis BallYalve at 299.57" B-H.) Camco Gas Lift Mandrels at: B) 1991.56'. , C) 3527.82' D)5079.23' E) '6427 67' F) 7703.18' G) 8941.97' H) 10,059.54' I.) Otis 'XA' Sleeve at 10,290.05' J.) Baker Model 'A-5° Dual Packer from 10,323.90' to 10337.60' K.) Bottom of 'Q' Ni0ple at 10.349.15' PERFORATION RECORD DA TE INTERVAL CONDITION · NOTE: Bottom of Long String was shot off in Aug. 1980. VIII WELL TBUS G-31 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA RECEIVED NOV 1 1986 Alaska Oil & Gas Cons. Uommissi0n Anchorage wellhead. It contains four pairs of rams which arc hvdraulically,,powered for opening and closing., Thc . preventers also contain a manual override to enable the rams to bt operated ~'ith loss of hydraulic power or to be locked closed, Thc four pairs flora thc bottom up are: l-inch OD tubing rams to packoff around the tubing, l-inch OD t~bing OTIS REELED TUBING UNIT BLOWOUT PREVENTER ASSEMBLY i i Ii - i , i /~ ' l,'Ja~;~ ~'us us malfunction, l-inch OD tubing cuti~r rams to cut the tubing ~hile it is in the wcilborc if ncccssaD', and a pair of blind rams to close when the tubing is out of the wellbore. This prexemer assembly has a side outl¢t or int¢t to produce or pump through if n~cessary. ~ assembly is designed for H2S 5e~'ice and has a 5000 psi working pressure ra~ing, ECEI E'9 ~c~ora~o OTIS ENGINEERING CORPORATION D[OWOUT PREVENTER ASSEAIBLY r Training BLIND RAM ~ CI~TTER I~AM StlP I~AM O.D. PIPE RAM October 3, 1980 Union 0il Company Box 7600. Kenai, Alaska 99611 Attn: Bob Culver Production Superintendent Res No Flow Tests on ~rayling Platform. Gentlemen: We have reviewed .the test data from the "no-flow" tests con- ducted on. September 23 & 24, 1980, which were partially wit- nessed by our Petroleum Inspector, Harold Hawkins. We concur that the "no-flow" tests demonstrated that wells G-iS, G-23S, G-27, and ~%~ are not capable of unassisted flow; therefore, you may remove the down hole safety valves from these, wells. However, the flow test on well G-2·0 disclosed that it is cap- able of unassisted flow; therefore, the down hole safety valve must be maintained in well G-20. Sincerely, Lonnie/C. Smith Commissioner cc Platform Supervisor Grayling Platform LCS: BEW: mm .. October 3,'i980 Union Oil Company Box 7600 · Kenai, .Alaska 99611 Attn: Bob Culver Production Superintendent Re.' No' Flow' Tests on qrayling. Platform. ..-. .o Gentlemen = · We have reviewed the test data from the "no-flow" tests con- ducted on. SePtember 23 & 24, 1980, which were partially wit- nessed by our Petroleum Inspector, Harold Hawkins. We concur that the "no-flow" tests demonstrated that wells G-iS, G-23S, G-27, and iG931Li~ are not capable of unassisted' flow; therefore, you may remove the down hole safety valves from these.wells. However, the flow test on well G-20 disclosed that it is cap- able of unassisted flow; therefore, the down hole safety Valve must be maintained in well G-20. Sincerely, Lonniet C. Smith Commissioner cc Platform Supervisor Grayling Platform LCS: BEW: mm Form 10-403 REV. 1-10-,73 Submit "1 ntentlons' in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to Orlll or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. V~/iELL L [~-] GAS D OTHER WELL 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P.O. Box 6247 Anchorage, AK 99502 4. LOCATION OF WELL At surface Conductor #38, Leg #2, 1878' N & 1389' W from SE corner, Sec. 29 T9N, R13W S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99 RT above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20194 6. LEASE DESIGNATION AND SERIAL NO. ADL # 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unii~ State 9. WELL NO. G-31L 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 28 T9N, R13W, S.M. 12. PERMIT NO. 69-72 )orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (other)Reperforate existinq interval~ SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well C{~lDletlon or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPER/~-TIONS (Clearly state all pertinent 0etlll~, and give pertinent dates, including estimated date of starting any proposed work. We propose to reperforate the ~,ollowing intervals' B-1 10,960 - 990 B-2 ll,O08 - 023 11,085 - 140 B-3 11,153 - 168 B-4 11,285 - 355 11,2ST'- It, 3 B~ "e. I hereby certi~Tt~;t~e foregoing is true and correct SIGNED C.~. COSe TITLE District Fnainpp~ . {~f[Thls space for State office use) CONDITIONS OF APPROVAL. IF AN~/.. BY ORDER Or-THE C0~MISSION / DATE See Instructions On Reverse Side Approved Copy Returned ~'0 0 ...too ............. .-3.' 0o: ' ".: .... · , .0 i: Tes .,o,... l~em.{~'. ) Locatlon.,General '::~.,~t;-.-~.,~,~'::~T. Yes .-No Ite~?; ( ~ 'BOPE .Tm~+¢ '-~.~::-~'~:':"~:;~:/":~;:~:~ ~ ~.....~.... ~.~?..~:m ' ' ' · ' . -'~ ~r'.~i~-~?~:m.,;~='' ': ~, ~ ~:;~::'~'~'-~' ,, ." ...... '?~ ~:;~i:~''.'~ ;~-. ~, ,' , :' ¥ .',~:'.,~:; :' ~ . g.-' . . ':,.-. -' ,.::~..,'x.~::-,', (-) ( ) .'.'...-. 15. :.,-. -Cas ~ ng set. ~ -.-...:?.~,.~, :~x,.~,-:.: -'~t,'~ ~ · ] · ~ '~).~::~i~":-~.-.bene~al Ho~se.Keeping '...~';~?'~:'Z;2<~;:~;), (.-~ ! ( ~."?.'1~.;~:~.· m'~',,~- ~ ~,..,~-'~;'~;~ .:/. ~:-(.-) . (.) :x?x;~:3.' Reserve. P~t-( )open( )filled:'~::'?' (~ ) ".'::: (") :-t;?:;:l 7:ftMas~e~. Hyd ' .COnt~o1- :~ s >-;; ~':; ; ;.',"~ '~' ;...-(~F sa~e'tv"Valve 'Tests..'?:u.: ,,'~-;-~:: ( ~; '~.-~ "~':~" 19'~/~'R~m~+~ ~;?;~'~ ~";"-;-';; ;~ t ~.,,,.'~).. ~;.,..o. ~u~su~t.ace-No. Wells'~.~?~,.;-..'?~'. ( ) - (~) ;'~:;.~ 21','"' K~11' .Lihe-( ),'Check-valve .. }",:",;. ,' ,'~ '"~'._ · (- )."'Nell' Test 'Da~a-~'- ~'. '.'( ) (") ~22' 'Choke-F1°wllne (') HCR' Wal~e ~ ) ~ ) 7 Well Nos ~ , ; ," 23' C ' ' ': /' ' ' ' 8' .~. ',:~.: ~.' ._~,~..:.( ) (-) .... · . hoke Man~fold No.. valvs fl~s ' ~'"')~ { ). ';'u'?: .'Hrs. obser :.? ',~, , ';. ( ) ( )'. 24~ Chokes-( .)Remote( )Pos (~dj' t")/( )' "."9 BS&W~, 'T ,~, ', , 2 ' ' ' ' ' ' ' .... / ,. ~ , .,~ · ,..,,.,,., ..>' -~' ' _ ( ) ( ) 5. Test Plug-( )Wellhd( )cso(. )none"'~?.,.=;==L....,<;~.,, . ~,'/ -~. ) ~u. br. ~D/S. , , , '( ) (). 26. A. nnular Preventer, :-psi~ . ( )Final Abandonment ( ) ( ) 27. Blind Rams, psiQ . '];(') (-). 11. P&A Marker '~ '. ( ) ( ) 28~' Pipe Rams - psiS. .:.:.~..) (') 12. Water well-( )capped( )plugged ( ) ( ) ~29. Kelly ~ Kelly-cock . ) (') 13. Clean-up';~~ .. ' ' , ( ) (.) 'q:30. Lower ,,ell.y valve .:]' p :'( )~( ) 14. Pad leveled'-.' -' .; ~:.', ...... ".~.(), (') ~; 31..Safety Floor valves,( ;)BV ( )Dart.~.,}, Total. inspection obser.vation time ~/.'~;7~r~l/dayS~.] Total-number leaks and/or, equip, fai ' ~m:- · · 1 ures- Remarks ,,-. ,,~ .,., ' ' ' ......... ,, ....... M,.,;,~.~.m- .i /~.~/ <-~ -~ ,.;, / ~ ~- :~-. '~ ,~/~ .... :.,,) ...... .., ~.. , :.. 'r~' ~;.~ '-. '~ ,-. ~ ...~ ..? ~' , . . . cc' ,./ x~ ~,.',,,.,: ,~..,x No~f~ ~n. ~da~s o~;.~hen' ready I~spec~ed. bz I~~~" ' ,~.D~te. ~/- ,) ~/ ........ 1~-~'. . . ..1,.' ,,-. :... .t. . . ~.~ . , .,. -. '.,.," . ' .... '-.' ,.t' :'. .... ~ '.:~.:".'.:~' -: · : -; .': :.','.~:'~:.~.~ .',~.":.:' ~.;:i'..%',?~:~ ' '."'..'" .~ .:r,:.-:' ,~: ..... ' . .· :. . - ... ' --, :.::~;~?, . . . . . . Union Oil COmpany alifornia unlsn Mr. Homer ~rrell Division of 0il ~ Gas State of ~as~ 5001 Porcupine Dr. Anchorage, Alaska 99504 RE: TBUS G-S1 P-4 TBUS G-8 P-4, 10-405 TBUS G-4 P-4, 10-405 TBUS K-19 P-4 TBUS D-26 P-4 Dear Mr. Burrell: ~nclosed for your files are the State required Monthly Report of Drilling Operations for May for Trading Bay Unit State Wells G-51, G-8, G-4, K-19 and D-26. Also enclosed are the Sundry Notices ~ Reports on Wells for Trading Bay Unit State Wells G-8 and. G-4. Very truly yours, fJim R. Callender District Drlg. Supt sk ~ncl. (14) cc: Marathon Arco Amoco .... Skelly Socal Phillips JUN 8 i'574 rom,, m,. ~,~ STATE OF ALASKA REV. 1- 1-70 OIL AND GAS CONSERVATION COMMITi'EE SUBMIT n~ DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. API NUMERICAL CODE 50-133-20194 2. NAME OF OPERATOR UNION 0IL C(~4PANY OF CALIFORNIA 3. ADDRESS OF OPERATOR LEASE DESIGNATION AND SEKIAL NO. ADL- 18730 8. L~.'IT FA-R~I OR LEASE NAME Trading Bay Unit 909 West 9th Avenue, Anchorage~ Ak. 99501 4.LOCATION OF WELL Conductor #38, Leg #2, 1878'N ~ 1389'W from the SE corner. Section 29: TgN, R13W, S. M. 9 W~:LL NO State G-31 10. ~',~nj~ A.'~D POOL. OR WILDCAT t*GVV ~ ~rthur River Field-~est Forel~ IL s~., T., R., M.. (~OM HO~ o~ Section 28: T9N, R15W, S. M. 12, PERMIT NO. 69.,72 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CE/VIENTING JOBS INCLUDING DEPTH SET A/ND VOLU1VIES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AIWD SIDE-TR~CKED HOLE AND A~IY OTI~ER SIGNIFICANT CI-I2%NGF. S IN HOI~ CONDITIONS. *To abandon the West Forelands i recomplete Well TBUS G-51 as a Dual "G" ~ Hemlock Producer. ~ Commenced operations on G-51 to abandon the West Forelands @ 12:01 am, 5/1/74. Rigged up t killed well. Removed x-mas tree 5 installed ~ tested BOPE's to UOCO specifications. Pulled ~ laid dwn. 3 1/2" tbg. f accessories. Left single hyd. pkr. in hole @ 11,540'. Ran Gamm-Ray CBL 5 Collar Log from 11,500' to 10,000'. 'Ran ~ set ? 5/8" Howco EZSV retainer @ 11,524' RIH w/ 5" DP. Broke circ. Stabbed into retainer. PreSsured below retainer to ~500 psi-held 10 rains, n° bleed back. POoh. Rigged up Go-Interna- tional t reperforated the "G" Zone from 10,610' to 10,655', 10,540' to 10,570' and from 10,450' to 10,480' w/ 4" csg. guns @ 4 hpf. Ran ~ set Baker 9 5/8" perm. pkr. @ 10,900'. Rig released from 6-31 abandonment of West forelands @ 12:00 Mi.Rite, 5/4/74. Commenced operations on G-31 to recomplete as a Dual "G" 5 Hemlock Producer @ 12:01, 5/5/74. Rigged up 6' ran dual 3 1/2" tbg. strings. Stabbed into perm. pkr. @ 10,900'. Spaced out ~ landed tbg. w/ hyd. pkr. @ .!0,324 '. Removed BOPE 5 installed x-mas tree i tested to SO00 psi-ok. Displaced tbg. ~ annulus w/ diesel ~ put well on production. Thru tbg. differentially perforated the Hemlock as follows: ZONE INTERVAL 'FOOTAGE, ~ 10, 966' - 10-, 986 ' -'~ H-2 11,042'-11,057' 15' H-2 11,080'-11,110' 30" H-3 11,160'-I1,190' 30' JuN H=4 11,285'-11,315' 30" $-4 11,255'-11,285' 'G Dt¥ SDN 0F Well returned to production. RIG RELEASED @ 12:00 MIDNITE, 5/16/74. ...... ... ~ ~ .: : __ i:~> ~: ,~ ~ . ~,,,, ~,. ..... ._-,: ~-,.. '14. I hereby e~ that the f.m'~l~o~ is ~-tLe and correct · "' sm--~ '~d~~=~ District Drl~. Smt, ~A~ 6/11/74 Union Oil and Gas on' Western Region Union Oil CompanY of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union May 17, 1974 Mr. Homer Burrell Division of Oil ~ Gas State of Alaska 5001 PorcUpine Drive Anchorage, Alaska 99504 P~: TBUS G-51 FORM I0-405 Dear Mr. Burrell: Enclosed for your files are two (2) copies of the Sundry Notice ~ Reports on WellS for Trading Bay Unit State Well #G-S1, Grayling Platfom. Very truly yours, David A. $ohnson Drilling Engineer sk Enclosures (2) CC: Marathon Arco Socal Skelly Amoco Phillips MAY 2 ! 1974 Form 10-403 REV. 1-10.73 Sub,nit "Intentions" in Triplicate "Subsequent Reports" in Duplicate 2. NAME OF OPERATOR UNION OIL COb~ANY OF CALIFORNIA Di¥i$i0N 3. ADDRESS OF OPERATOR _ 909 West .9th AVenue, Anchorage, Alaska 99501 4. LOCATION OF WELL ....... At surface Conductor #58, Leg #2, 1878'N ~ 1389'W from SE comer. Section 29: TgN, R13W, S. M. STATE OF ALASKA s. APl NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20194 AND o. (D°n°t~thisf°rmf°rpr°"°saist°drill°rt°deepeb~ ~ ~ ~~87~0 ' R Use "APPLICATION FOR PERMIT~' for such proposa!~~ MAY 2 '" o 8. UNIT, FARM OR LEASE N~ME 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99' RT above MSL. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT' SHOOT OR AcIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) 14. .~}J,[Yr~.~ng · Bay Unit WELL NO. State G'31 ~O. FIELD AND POOl, OR WILDCAT "~, ~ McArthUr River Field'West Forelan~ 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 28' T9N, R13W, S. M. 12. PERMIT NO. 69-72. )orr, or Other Data SUBSEQUENT REPORT OF.' WA!ERSHUT-OFF [~ - REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING sHOOTING OR ACIDIzING I I 'ABANDONMENT* (Other) Perf. Hemlo%~,.. (NOTE: Report results of multiple completion on Well Completion or Recompletion RePOrt and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. *To abandon the West Forelands ~ recomplete well TBUS G,31 as a Dual "G" & Hemlock Producer. PlAN OF PROCEDURE. 1. Rigged up 6 killed well .... 2. Removed-x-mas tree. Installed & tested BOPE. 3,.-Pulled ~ laid'dwn. 3 1/2" tbg, [ .accessories. 4. : Set9 5/8".cmt. retainer onWL@ ll,524'DIL'. - 5, .Stabbed into retainer w/ 5" DP; Pressured up. below retaine¥ to 3500 psi. NO bleed :'.baCk. (Received ~erbal approVal from HoyleHamitton, State Oil'& GaS Commission, on. West Foreland abandonment,.) '6'~ '.'."Pooh w/.. DP. t! tt 7. Reperforated G. Zone w/ 4" csg.'@ 4 hpf from '10,610' to 10,6o5', !0,540' to 10,570' and from 10,450' to 10,488' 8. Ran & set perm. pkr on~ ~ 10,900' 9. Ran 3 1/2" dual tbg~ strings w/ gas lift assemblies as programed. 10. Removed BOPE & installed_x-mas tree. 'Left single'hYd..pkr;-.:in' hole @ 11,540'.' Form 1 0-403 REV. 1-10-73 Submit "! nteptions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND' REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) :1' OiL F-I GAS r-~ WELL'' WELL OTHER 2. NAME Of OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface 'v' :13. ELEVAA~IONS(Show whether DF, RT,-GR, etc.) .. ; 14. 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND ~;ERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Check Appropriate Box .To Indicate Nature of Notice, Re ~). WELL NO. 10. FIELD AND POOL, OR WILDCAT SEC, T., R., M., (BOTTOM HOLE OBJECTIVE) . 12. PERMIT NO. _ ~.: .. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perf. Hemlock (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any 0roposed work. PLAN OF PROCEDURE: (cont..".) ' - ~ "' 11. Thru tbg. differentially perforated the Hemlock as follows: ZON~ IN~FERVAL FOOTAGE- H-1 10,966'-10,986' H-2 11,015'-11,025' H-2 11,042'-11,057' H-2 11,080'-11,110' H-3 11,160'-11,~190' H-4 11,285'-11,315', H-4 11, 20' 10' 15' 30' 30' 30' 30,; _ . 12: -Returned well to production. . I hereby cer fy hat the fore g i ~rue an orrect ~ Dist Drlg. S~t 5/17/74 SIGNE ' ' DATE (This space for State office use) CONDITIONS OF~PPI~VAL, IF ANY: / -- / Approved Cop~ ~,~ Returned See Instructions On Reverse Side .... i. -1878.'N, 13'89'W ff SE cor~ Sec. 29, TgN, RiSW, SM mi,?,:~ re-~entered 5/1/71.14 5/20/714 (oil we!.i) . Vertie~ P~p~ , , C. :,::,' ? 71 Pd,~ -'-:,'.'".~" Lt'.,::C,L'~ M~d L,o?.Li~ Comp,any .............................. ; ....... :~;t _~_ .__ -' 10, 6i2'-10, 635'i i 10, 5,0' -10, 510' i t 10, 1,50'-10, ....... - ............. ~,~4"" ~'_ ~:7 -:~.-;;Z,~~', .... - .... __~,.,:..~ ~_ . ...... 777" 7'? t ........... _ ¢~' 25~) - ~'~- 3k. 1° d~ xoc~,,c~o. 949 Mcf ~om gas l.,epen'.. Hemlock Bench ~. Well origina!ly drilled and completed in 1969 (see ticket ~i719). '",. . . . F. cfcm~l 0-403 REv. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L l'g"l GAS r"] WELLIZ)~I WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface Conductor #38, Leg #2, 1878'N & 1389'W from SE comer. Section 29: TgN, R13W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99 RT above MSL. 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20194 6. LEASE DESIGNATION AND SERIAL NO. ADL-18750 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-31 10. FIELD AND POOL, OR WILDCAT ~lGt, & ~ McArthur River Field-West Foreland 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 28: T9N, R13W, S. M. 12. PERMIT NO. 69-72 )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (other) Perf. Hemlock. PULL OR ALTER CASING g.a MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT H ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. *To abandon the 'West Forelands ~ recomplete well TBUS G-31 as a Dual "G" & Hemlock Producer. Plan of Procedure; 7. 8. 9. 10. 1. Rig up ~ kill well. 2. Remove. x-mas tree ~ nipple up BOPE. 3. PUll & lay dwn. dual 3 1/2" tbg. Strings. 4. RIH w/ 8 1/2" bit~ 9 S/8" csg. scraper to top of 7" liner @ ll,S9S'. 5. Set 9 S/8" cmt. ,retainer on WL a.t +II,S00'. 6. Stab into retainer w/ S" DP. DispTace l;00sx, of cmt. below retainer & 30 sx. on top of retainer. Pooh w/ 5" DP. RIH w/ 8 1/2" bit ~ 9 S/8" csg. scraper to top of cmt. plug @ 11,430'. Run dual 3 1/2" tbg. strings w/ gas lift assemblies. Remove BOPE ~ install x-mas tree. of cmt. ~i~orm,16:.403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to ~lrill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~' O,L I--! GAS I--I WELLL..--I WELL L-J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME 3, ADDRESS OF OPERATOR 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc.) CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEC~UENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 11. Thru tbg., differentially, perforate the Hemlock as follows: SAND INTERVAL FOOTAGE Bench .~4 I1,285-'%i1,'315' ~ Bench #3 11,155'.11,185' 30' Bench #2 11,015'-1'1,025' 10' 11,042'-11,052' 10' 11,084'-11,114' 30' Bench #1 10,966"-10,986' 20' 12; Return well to production. Estimated Time of Operations: Eight r(8) Z6. I hereby cgf~f'~ that the foregoing is true and correct ~.' caiie~der · 'T,TLE Drlg. Supt. District DATE ..... 4/30/74 (This space for State office use) CONDITIONS OF('~ppROVAL, IF ANY'= See Instructions On Reverse Side TRADING t[IY UNIT STATE G- 31 ~pRKOVER PROCE~ ~ 1. Pull Otis "CX" gas lift valves & ball valves in short string & long string. Close "CX" sleeves in long string & short string. Open "XO" sleeve in long string @ 11,546' & "XO" sleeve in short string @ 10,26S'. 2. Move rig over well. 3. Displace long string, 9 5/8" x 3 1/2" annulus between packers & 9 5/8" X 3 1/2" X 3 1/2" annulus above dual packer w/ 70#/ cu;-ft, invermu], by pumping down annulus'& taking returns out long string. Displace short string by pumping down annulus & taking returns out short string. Displacement Volumes: 1. Displacing down long string & out annulus: a) Long string capacity 11,546' of 3 1/2" 9.2# tbg. 100.5 bbls b) 9 $/8" annulus between packers 11,595'~- 10,388' = 1207' of 9 5/8" 47# csg. w/ single 3 1/2" 74.0 bbls c) Annulus above dual packer- 10,388' - 5837' = 4551' of 9 5/8" 47# w/ dual 3 1/2" 224.8 bbls 5837' - 120' -- 5717 of 9 5/8" 43.5# W/ dual 3 1/2" 289.9 bbls 120' - 35' = 85' of 9 5/8" 47# W/ dual 3 1/2" 4.2 bbls 518.9 bbls Total theoritical displacement d~m. long string & out annulus 693.4 bbls 2. Displacement dram annulus & out short string 10,265' of 3 1/2" 9.2# tbg. 90.0 bbls Total theoritical displacement (1 plus 2) 783.4 bbls 4. Install BPV's. Remove x;mas tree. Install 3000 psi BOPE as per attached sketch & test to UOCO specifications. The records show that the tubing head top flange is '10" 5000#. · TBUS ~orkover' Procedt~re t~ -2- April 2S, 1974 5, Pick up on 5 1/2" short string & release from d~ml packer @ 10,388'. The records indicate that the short string is landed in dual packer w/ a seal assy. It should take 4000# to 6000# over the weight of the short string to pull out of the dual packer. If the short string does not release, it is possible that the short string is latched w/ a right hand collet. This arrangement takes 4 to 6 turns right hand torque to release the short string. Pick up on the long string & release the Baker Dual A-S packer at 10,388' & the Baker Single "F"-"H" packer at 11~581'. The packers should release w/ 30,000# over'the weight of the 3 1/2" long string. The 3 1/2" long string weight to the dual packer is est/mated at 96,000#. The total weight of the long string is estimated at 107,000#. ]~e tubing is good in tension for 207,770#. Do not exceed 165,000# hook load on either string. If necessary, cut the tubing between packers to unseat the dual A-S packer or above the dual A-5 packer if the tubing is not capable of the pull reauired to unseat the packers. Retrieve the packer or packers w/fishing tools and 5" DP if required. 6. Pull and lay down tubing and accessories. Send all tubular goods and equipment immediately to Ihrold Piland, Nikiski Dock. The tubing is to be inspected, returned to the rig and rerun in this well. 7. Rill w/ 8 1/2" bit ~ 9 5/8" csg. scraper and clean out to top of 7" liner at 11,595'. Circ. out rat hole fluid. 8. Run GR, CBL-CL. Log from 11,500' to 10,000'. Tie in flat w/ DIL measurements. 9.. Run 9 5/8" cmt. retainer on ¥/L & set at +11,550'. Stab into retainer w/ 5" DP. Mix & displace 100 sx. of Class "G" cmt.-%v/ 1% friction reducer below retainer & if bond is good, leave 30 sx. of cmt. on top of retainer. If bond is poor, rev. out any excess cmt. on top of retainer. 10. If bonding is poor between 11,400' to ll,S00' perforate for zone isolation squeeze at 11,525' Run ~ set 9 $/8" cmt. retainer at + 11,500'_ Squeeze between retainers ~s determined from formation breakdm~ [ pump-in rates. Leave 20' of cmt. on top of retainer. 11. If bondin~ is poor between 10,.700' & 10,900' perforate for zone isolation soueeze at +10,920'. Set 9 5/8" cmt. retainer at 10,900'. Cmt. squeeze to be determined fro[ formation breakdown & pump-in rates. 12. CO 9 5/8" csg. to + 11,200'. 13. Dual complete well as per production department design. 14. Install BPV's. Remove BOPE. Install & test x-mas tree. 15. Displace long, short & annulus w/ diesel. · TBUS G-31 Workover Procedure April 25, 1974 16. Thru tubing, Perforate thb follOwing Hemlock Benches: Bench #4 Bench #3 Bench #2 Bench #1 11,285'-11,315' 11,155'-11,185 11,015'-11,025' 11,042'-11,052' 11,084'-11,114' 10,966'-10,986' FOOTAGE 30' 30' 10' 10' 30' 20' -- 17. Return well to production. 130' --T-: T-r- ~ l--i, i ~i, ; F'-[-*'-i-T t--~ ._~ ,., .... ,,,, ~ , : . ,. , .-'_-, ,-r ~, -- . , '-" --'7---'~. ' } ' - ~ ' ~ '~'~;----~ ..... ; -- ~--- -: .i : ' . -_ ' . ............. [ ' _ -,l. ; . · ' i : : i : I : : · ; ........ ; --- ' ...... ~ -: , i I ~ .: ! i i , .. ' - i i · , : i , i : l,.:.. : .... ] ,~L__z__;. l---~ ' ., . ,~ i I , , . · · [ ! ..... ; .... : : ' : , ' i .- , : : ' ' : i : I I ! I. . i t t 'J ': ' -- - - -- ' ' : ' ' ' : i J ' ~ ~'" i ~ -',)C~,'~'..'-..?,' : ' :''! '~-: ' ' ~ : ~ ' · - -! '-~r:~--'"-- _ : .: i , , , , ! t i : _._.~ _ ' , .: ~ ~ , ? .... - , "' i, : --..1.-... ~ ' ' .'. .~ ', ~ : - i ~ i .., -~ ;. .'. --- · ~:'. - I i i 'i '. I : ' , : : : ' ' : "'~ ....:-"'"~ .......... ~'-'i ~ - . . :~ · . , , , : f ~ · ~ ~ : .__/t ': . : "~", I : . . ~ , ' · , : : ~ i ' ........ ~ .-. , .... · ._ ,_ ; . ; _ · ; :-.i. . ,~ __z' ; : --- / . rl,D'~z /' .._: ...... ,_ " ' ' , , _L__; t 1 !. ,' ~' , _ ~ -- t . // - .' '.'~t .................. ~ T----T----: ( , · .,. __,, ;.:. :l , _ 1. _.. /~.__..::-._~aD..~,,:..f:r.,~4C, F. : .:_ 1 . ' : : ', ! --i ' '. '. ': ......... T ~,- - '~ : : L ,4 ' : : : i t · ' --m - -- ] G'..<; . _. '. : , ~.'-'----t .............. ~ ~ ~-- ~ ~ · - - ' ! ~' --I- ' :.. I, , ~' ~ :---t--- .... :- ~ · '.' -------- . , . _.. .: ...... j ..... :_ : : ,. : : ] , ! . . , : . ..... :-- . ....... :_z _ =. _-.L .._ ;~ _L .l_:_ ~!I[_1__ r_ i · i' -~ -"1 ..... I ..... , - ' - .- "" . .... ; -. -.k-..--+---~ _l : ! I: ....... ! ..... : ', ' ' ' , / ~ , ! : , . : UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT TO: STATE OF ALASKA TRANSMITTAL DATE: November 11, 1969 FROM' .... a_ H. Laughbaum, Jr. WELL NAME: TBU G-Si Transmitted herewith are the following' Run No. __Final__ Sepia Blue Scale Induction Electrical Log Dual Induction' Laterlog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) [:[0"/l~gg9 High Resolution Dipmeter (HDT)~iVi~iON OF OIL AHD.~_G_A~ CDM Safety Print CDM or Printout CDM or Polywog Plot CDM Polar Plots Proximity Microlog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. £ore Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut RECEIPT ACKNOWLEDGED' RETURN RECEIPT TO- Union Oil & Gas Division - Western Region Anchorage District P. O. Box 6247, Airport Annex Anchorage, Alaska 99503 Attn: Rochelle Carlton l. orra No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS WELL wELL OTHER 2. NAME OF OP~TOR Union 0il Company of California ~, ADDRESS Or OPm~TOR 507 W. Northern Lights Blvd,, A~¢horage: Aln.~kz ggsoq 4. ~CA~ON or w~u~ Conductor (/38, L~g #2, 1878'N & 1389'W from SE corner S~ction 29, T9N, R13W, SM. HLB TRM ~. A~'~ ~m¢~mC~L CODE OKG 50-133-20194 KLV REL ~L 18730 -- ?. IF INDIA]~, ALO-I l~E O]{ TRI~E~A[~F............~ 8. LrNIT F.~qA{ OR LEASE N.~ME Trad{ng Bay Unit g. %VELL NO. State G-31 10. Fi~ AND POOL OR WILDCAT .... McAt thur River-~.ldFor~ndG 11. SEC., T., R., M.. (BOTTOM HOI~ o~nrE) Section 28, TgN, R13W, SI'{. 12, PE/~VIIT NO. 169-72 ]3. REPOi~f~%~T,~~~_~OF MONTH, Ct-IA/~GES IN HOLE SIZE, CASING A_ND CEiVIENTING JOBS INCLUDING DEPTH SE~ ~~~~~O~o~s, ~.s~s A~ro ~SUL~S. ~Sm~G ~O~, ZU~K IN ~O~ )mD SIDE-r~CZ~D SOL~ AWO )mY O)~%~{(~AI~C~T C~U~S~ IN ~OU~ COWO~TIO~S. Drld out cmt, shoe @ 11667'. Circ clean. Drld 8-1/2" hole 11667'-12736'TD. Circ & condition hole for E logs. POH. Ran Schlum DIL log. Ran density log, tool s~opped @ 12,028' going in hole. Unable to move tool. Cut & stripped over line w/Schlum overshot on dp. Fnd fish @ 12,028', worked over & pulled loose. Recovered all Schlum wireline & density tool. RI with 8-1~2" da to 12,736'. Circ & cond hole. POH. Ran sonic log & GR density log. Shot sidewall samples. RI & circ & cond for lnr. Ran 26 jts 7" 29# '. N-80 csg on TIW lnr hngr. Hung w/shoe @ 12,~28' w/top hngr @ 11,595'. ~ Cmtd w/300 sx "G" cmt w/l% CFR-2 (100% excess slurry volume). Bumped plugs '~ w/3200#, floats held OK. CIP 11:00 AM 9/10/69. Set pack off on lnr hngr. i POH. RI with 8-1/2" bit on 9-5/8" csg scraper· Located top cmt above hngr @ 11,147'. CO ' 450 to top of lnr @ 11,595'. Circ & cond mud. POH. i RIH. CO 1' cmt in top 7" lnr. Ran to 12,637'ETD. Circ & cond mud. PO. Ran Schlum GR correlation log & cmt bond log. Sbu't% four 1/2" holes in 7" lnr @ 12,100'. RI w/Baker sqz tool. Set @ 11,840'. Circ thru perfs & out lnr lap @ 3 bpm w/1800#. Reset sqz tool below perfs @ 12,200'. Press tstd sqz tool OK. Reset above perBs @ 11,890'· Free circ around lnr lap. POH. w/sqz tool. RI w/Baker model "K" cmt retainer & set @ 12,070'. Stab into retainer· Broke circ thru perfs @ 12,100' & around lnr lap. Cmtd w/55 sx "G" w/l% CFR-2. POH. RI with 8-1/2" bit on 9-5/8" csg scraper to top of hngr @ 11,595'. No cmt above lnr lap. Circ clean. Close rams & test lap w/2700# OK. POH. RI w/6" bit & 7" scraper, fnd top soft cmt @ 11,846'. CO cmt stringers to retainer @ 12,070'. Drld out retainer & 30' hard cmt to 12,100'. RIH to float @ 12,637'. C~rc & condition mud @ 12,637'. POH. Schlum shot four 1/2" holes @ 12,100'. RI w/7" Baker sqz tool, set pkr @ 11,890'· .ii ,i . s~fi'kJ '~ . =?~ Dist, Drlg. Supt. mA~ 16/14/69 ~e · ~ NOTE IR~t on ~his form~ required for each calendar month, ~egardless of the status of operations, anO must ~ file, in duplicate with the Division of Mines & Mi~rals by the 15th of the succeeding month, unless othe~ise directed. Broke down w/3600#. Mixed 150 sx "G" w/l% CFR-2. Sqzd 115 sx to form- ation w/max press 4700#. Held OK. CI? 5:00 pm ~./1.3/69. PO. Shot four 1/2" holes @ 11,870'. RI w/7" Baker sqz tool, set pkr @ 11670'. Broke down w/4400#. Mixed 100 sx "G" cmt w/l% CFR-2. Sqzd 75 sx to formation w/max press 5000#. Held OK. CIP 6:0.0 am.9/14~69. Reversed clean. POH. w/sqz tool. Perfd four 1/2" holes @ top Hemloc~ section 10,910'. RI w/Baker full bore sqz tool. Attempt to set tool, pkr failed. ?OH. RI w/new pkr. Set @ 10,8o7'. Broke down w/4000#. Mixed 100 sx "G". Sqzd 85 sx cmt to formation. Mas press 4900#. OK. CIP 6:30 am 9/1~/69. Reversed clean. POH. RI w/ 8-1/2" bit & scraper. Drld firm cmt 10,840'-11270'. Ran to 11,595'. POH. RI w/6" bit & scraper. CO to 12,636'. Circ & chngd over to 74# filtered salt wtr. Schlum perfd four 1/2" hpf for W~st Foreland.DST......#1~ 12,024,~12,0~.5'. Ran Howco tstr on dry dp. Set pkr @ 11,903' w/tail @ 11,921'. Pressd dp 950# w/gas cushion. Opened tool for 15 min IF @ 11 pm 9/16/69. Surf press w/dp closed increased to 1225#. SI for 90 min ISI. Opened tool for flow. Surface press bled to 50#, fluid to surf in 2 hrs. Well flowed for 3 hrs @ stabilized rate 792 BPD (33 BPH), 1% oil, 1-1/2% solids, 97-1/2% wtr, salinity 18,000 ppm sodium chloride. Closed tool for FSI. Pulled pkr loose @ 11:00 am 9/17/69. POH. Charts indicated tst OK, no evidence of plugging or tool failure. IH 5112. IF~ 2881, FF~ 3322 (15 min), ISI 4562 (90min), IF~ 3322, FF2 4452 ( 5 h~s)',~FSI 4~66 ~5 hrs), FH 5085. Schlum set castiron BP @ 11,811~o RI w/oedp, circ clean. Spotted 175 bbls 75# Invermul pill 11,811'-9400'. POH. Schlum perfd four 1/2" hpf 11,738'-11,723', 11,706'-11,696' , 11,688'-11,678', 10,728'-10,708', 10,636'-10,592', 10,570'-10,540', 10,484'-10,448'. Ran & landed dual 3-1/2" 9.2# N-80 butt. tbg strings. LS 344 its w/tail @ 11,622', Baker FH Hydroset single pkr @ 11,580' & Baker dual A-5 Hydroset pkr @ 10,332'. SS 304 its stabbed into pkr @ 10,332'. Removed riser & BOE. Instld Cameron 10" 5000# dual tree. Set btm pkr @ 11,580' OK. Set top dual pkr @ 10,332' OK. Opened sleeves in both strings above dual pkrs. Chngd over fm hole fluid to diesel. Closed both sleeves. RIG RELEASED @ 12:00...?idnight ~2~0./~6~ FORM 369 4-63 PRINTED IN U.S.A. UNION OIL COMr 'Y OF CALIFORNIA 'locumem ( ~,~nsmittal FROM I=IT~_ ~_~'n O_~ '[ AT 280~ Den~li Stree~ TRANSMITTING THE FOLLOWING: ..... ~75 ' ~ ~ "' ':,,' C IVISION OF a ~ AN~ G/.S - PI.~ARE A~KN~.fi~ R~T~ A~ R~ll N Union 0~ Co. O~ ...... P.O. ~x 2647 _ _ . , , , ,, I .... ~'orm P--7 . LONG ,. SUBMIT IN DUPLI ~- STATE.,,OF ALASKA (See o,,,c: in- structions on OIL AND 'GAS, CONSERVATION: COMMITTEE ~er~ ~ia~) ~' ~ ~~ cooz ~0-133-20194 WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ~.~~ia~X~o~~~o. · ~L 18730 la. TYPE OF WELL: om ~ WELL WgLL DRY Other ~. IF ~I~, ~~ OR ~BE N~ b. TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLUG ~ DIFF. ~ ~VELL OVER EN BACK ~ESVR. Other 2. ~*Mz oF oPrRA~oa ...... ~rading Bay Unit Union Oil Company of CalifOrnia ,. W~L~O. S. A.~s~sS o. o~A~0~ ;tat~3~ 507 W. Northern Lights Blvd , Anchorage, Alaska 99503 ~0,~ ~~L'OB W~T ' '" ~ Mid K nam ~. LOCATION OF WELL (Report loca~ton clearly and m accordance with ~,~ Stdte requtreme, t,)* ~' lcArthur River-west Fore.fid a,.u~.~.~on~uctor_38.~Leg 2. 1878'N & 1389'W fm SE corner n.~c.,~.,m.,~.,(~~o~ ~ ~eccion 29, T9N, .R13W, SM. O~m~E) .... At top prod. interval reported ~elow '., 335'S & 5385'E of surface location ~ec. 28, ~;~13W, SM. · t total dep~ 'I~~ NO. 655'S & 5812~'E of surface location li. D*~ ~DD~ [14. D*~ T.D. ~C~D 115. D*~ CO~,~USP,~ ~. II~:.~V4~O~S (D'F, RKB, ~T, GR, ~)'11~. ~, 7/21/69 [ 9/6/69 I 9/20/69 , ['RT 99' above MSL t 59' above MSL 18, T~ D~H, ~ & TVD~9. PLUG ~,~CK M & ~D~. ~ ~LT~L~ CO~L., · [ ~1. INTERVALS DRILLRD x~,~o - ~~ 11263~"'- ~ 10660 ~" 2 : [ o - TO [ --- ~. E~~G'-~~(S). O~ ~s ~T~O~, BO~O~,, N~ (~ 'AND ~)* . ,., ~: ,/:.u-,~,, ~,[~.'W~ West Foreland ~1678' - 11738' ~ - ~ 9864 TVD - 9912 ~ / ...... m ,~ ~_4~ yes DIL, FDC-GR, BHC-SONIC, & H~ - ~lVli~'~rOll ~' . .' C~G R~, (Re~ all strinBs set ~ well) .' ~ ~~,~ . ' ' ~ , I' , . ~-~/~"[ .~ S~'=~. ila '.' !~ ~.. ~... ~2o.,. ~ ! ~" I ~o ,x ~"~" ~ / [ ~# '~ :' /J"~ l/ ':'::~z~'~' I ~"' I~°°° '~ ~ ~,x + ~oo sx.q Z6~ LINER ~CO~ ~ _ "'~ , , ~ ~. T. UB~G ~O~ [11595'' I 12729' ~l' 300 SA' I "1-1/2~" I 11622'. "' ~. PErdiTIONS OPeN TO PRODU~ON :l.' (In%erval, size ~d numar)~ 29. ACID, S}!O:T, F~C'T:U~, C~NT SQUEEZE. 11678-11688 -. ,. ~ D~-: ~v~ .(~) / A~o~T ~m zmm o,~ ~m~ u~ 11696--11706 12100--12101 ~ cml sqz~205 sx G w/l% CFIR-2 11723-11738 I " ~11870-11871 I~ ,cml sqz w/75 sx "G" w/l% CFR-2 ,10910-10911 ] lcmt sqz w/100 sx "G" w/l% CFR-2 four 1/2" hp~,f . ' ' Ill I ......... I I 1 ~. ~ODU~ON DATE FIR,ST P~ODUC~ON I ~ODUCTION ME'i'I{O~ (.FloWh3l~, g~ lif, t, pump~g~size and type of p~p) l~-ELL STA~S (~oduc~ or ' I silut-in) . ' 9/24/69 Gag Li~t ...., ] producI~ FLOW ~BING' [~S~G P~SS~ [CAL~~ .."OILBBL - ~ G~CY. W~B~. [OIL GRAVITY-~I (CA.) t ]TETWITNeSSeD BY ' ] T.K. Muir ~3. I herSb :matlon is-6omple~e and correct as determined from allravatlable records SIGNED '.~ '!TiTLE.i. DiS'trict Drilling DATE. 9/29/69 I super i,ntenaent' [ I I .... tructions and Spaces [or Additional Data on ReVerse Side) INSTRUCTIONS General: This form is'designed for submitting a complete and correct well'icompletion report egd log on all types of lands and Peases irt Albska. : :' Item: l&: Indicate which elevation is used as' reference (where not otherwise shown).for depth';measure- ments given in other spaces on th'is form and in any attachments. " Items 20, t~nJ 2'~::.lf this well is completed fOr separa!ie p,r,0duction from more than -one interval zone. ' Z (multiple completion), so state in item 20, and in item 22:;:show the prc. Jucing inte~:val, or inte~:vals 'top(s), bottom(s) and name (s) (if-any) for only. the i~'i~val reported in item 30. Submit a separate report (page) on this form, ';adequately identified,'for each :ii~!clitional inte, val to be sePeratelY produced, .show--. ing the additional', data pertinent to such interval. '?~' ;;!? ' " · ' .,.:2. ........ Item26: "Sacks Cement": Attached supplementaI recoils for this well' shoul,d show the details of any' mul- tiple stage cementing and the location of the.cementing tool. . Item ]8: Submit a separate completion report on' this form for each interval to be separately produced. (See instruction for items 20 and'22 above).. i;. ~ ~4. SUMMAJ:lV OF ~O~¢AT'bN ~',~:SWS INCLUDIN(]"'iNTERVAL T~ES~ P~U~E'DATA ~ ~0V~' OF OIL. G~. ' ..... WAT~ AND MUD . BST ~fl. ~e_st r~r_~land (12024' - 12945') ......... ~'~' . Set pkr 0 11903' w/ta~l pipe 0 11921~. Pressd dp ro 950~J W/gas a opened H~ddle Kenai "E- 7180~ too~ for 15 mSn. Initial flow ~ 11:00 PH 9/16/69~~.Press ~ncreased to 1225t//15 min. Shut in for 90 m~n. SI opened tool 0 12~:~5 ~ 9/17/69 "F" 8265~ through 1/2" ~hoke. Press bled to 50f1 in 45 min. Fluid to surface in . 2 hrs. Flowed well thru 1/2" choke 3 hrs 0 55(J-60~t, total 75 bbls. :"G" 10021' Fluid/3 hrs. lX o~1, 1-1/2~ solids, 97-1/2~ wtr. Last two hrs flowed ' ' 0 33 bbls/hr rate. - HemloCk '.. 10~57~ I~P 5112 FFP1 3322 IFP2 2752 FClP ~568 · ~P12881 IClP ~562 FFP2 3304 FHP 5075 ~est Foreland' .' 1160~' , ~ ~ , ,, , , ~-T, _. ~.,CORE DATA. Aq~ACII BRIEF ~CRIPI~O~S O~ LITHOLOGY. POROSITY. FRA~R~.' APP~NT DIPS .. .... . ..... AND DE'FECq'EI) SIIOWS OF OIL. G~ OR, WA~: ..... -' I II , . . . . . .,. BOB~ .. .. ... Form P--7 · SHORT STRI: SUBMIT IN DUPLiL~ STATE OF ALASKA {See other:ln- structions on WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYI~E OF WELL: WELL WELL DRY Other b. TYPE OF COMPLETION: NEW WORK '"ELL[] [] DEEP- OVER [] PLUG BACK [] DIFF. [] Other EN nESVR. 2. NAME OF OPERATOR Union Oil Company of California ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 LOCATION OF WELL (Re~ort location clearl~ and in accordance with any StYe requirements)* At.u~.ce Conductor BB._Leg 2. 1878'N & 1389'~ fm SE corner Section 29, T9N, R1BW, SM. At top prod. interval reported below 20'S & 4806'E of surface location At total dep~ 655'S & 5812'E of surface location .~_.-' 13' DATE SPUDDED 114' DATE T'D' RF-'ACI-IF'o [ 1§. DATE CO'MP, SUSP, ~OR~ABA/vD. [ 16'.'- ELEVATIONS ( DF, RKI3 7/21/69 9/6/69 9/20/69 [RT 99' above MI 18. T~ D~a. ~ & TVD,9. PLUG ~CK MD ~ 'i'VO~. ~ ~LW~L~ CO~.. [21. 12~.6, .,~..,. I [ DEP~ HOW ~Y* ROTARY TOOLS .~ - xu,,~ [12637' -~10660' two ~. PRODUCIN~I~~), OF ~IS ~P~TIO~, BOSOM, N~E (D AND ~)* Middle Kenai "G" I 48' - 10728' ~ 8821' - 9061' TVD 2;. ~FE ET.~.c'rmC ~D.-OT~ ~GS ~UN ............ ~L~--~""FU~Z~R, BHC-~0NIC, & H~ , u CAS~G RECO~ (Re~ all strings'set in well) SIZE WE~G~, LB/FT. D~ ~T (MD) S~E spir, 9-5 TRM OKG ~<~l..' ~. &PI NUMEaXC.~L COBOLV 50-133-20194 HWK 6. ~E D~IGNA~ON FILE 8. U~T,F~ OR ~SE Trading Bay Unit 9. w~L NO. t0. ~'13~.~) AZ~D POOL, OR WILDCAT · "id K hal- "~"/U ~cArthur R~ver-~est ~orelan~ il. SEC;~ T., R., M.. (BOTTOM HOLE .... -OBJECTIVE) '~ -. Section 28, T9N, R13W, SM. '12. PER1VIIT 1~O. 69-72 · RT, GR, .E'PC)*ll7. EI.,EV. CASIN'GHEAD ;L J 59' above MSL INTERVALS '~)RILLED BY CABLE TOOLS 0 - T,B .... :~-% . --- SURVEY 1VfADE PlVI$10N OF 0IL AND GAlS A.1VIOUlkrTPULT,~ none none none PACKER SET(~D) RECOi{D sx BJ 26. LINER 1TEC Oi%D SIZE TOP (MD) BOTTOM (MD) SACI~S CE1VIEi~T* SC'REEN (MD) 11595' 12729' 300 sx 27. TUBING 1;LI~OOP, D. SIZE DEPTH SET (MD) 1035 PERFORATIONS OPEN TO 10448-10484 10540-10570 10592-10636 10708-10728 (Interval, size and number) four 1/2" hpf 29. DIiX-~FI'I II~T]ERVAL (1VLD) 10910-10911 ACID, SP!O:T, FZL~CI'URE, CENiEArT SQUEEZE, ETC. AMOLrNT ;=ND KIND O,F 1VL~T~R/.:.I.L USED 1 cmt sqz 100 sx "G'" w/l% CFR-2 30. PRODUCTION DATEg/24/69FIRST PI~ODUCTION. I PRODUCTIONFiowingMETHOD (Flowing,~ gasgas li~t,liftPumping--size and type of pump) DATE OF T~ST, [I-iOU'RS TE~'r~iu. '[CHOKE SIZE [PROD'N FOR OIL~--BBL. GAS--1ViCF. __9/25/69, ~ .,, 24 13a/64 [ 1877 I 683 [ 1877 31 110 . -- - '~ I 683 · DISPOSITION OF OAS (Sold, used for '~uel, vented, etc.) ...... - 32. LIST 0~' ATT"ACHMENTS [WELL STATUS (Producing or ~,~t-~) producing WATER--BBL. [ GAS-OIL R~kTIO ! 19 1364 WA.~BBI.,. ! OIL GRAVITY-APl (~Oi:LR.) 1, 19 I 33'20 ,, . .K. Muir - 33. I hereb, certify th~/~e for~-IJnd a/tached ,nf ' ' .... i ormation m complete and correct as determined r from allVavailable records ~/, · TITLE istrict Drilling DATE 9/29/69 -{ INSTRUCTIONS '~ .... . C~neral: This form is designed for subm ttlng, a"'complete and correct well completiOn report and log on " all typps of lands and leases in A.l,aske. "· ':· Item: 1-16: Indicate wF;i.f:.,h ieli~vation is used as reference (where not otherwise shown') for depth measure- " m'ents i,given in other spaces on lhis form and in any attachments. Items 20, and 22:: If this Well is completed for separato production from more tha~ one interval .zone ..... (multiple completion), so state in item 20, arid in item 22 .rS,hOw the prc. Jucing intcrval, or. intervals, · 'top(s), bottom(s) and name (s) (if-any) for only the interval r~?orted in item 30. Submit a separate report· (15age) on this form, ;adequately identified, ~for each adcl, ii~tional,inte~ vel to be separately prodc~.c..ed, ;showL" -- --' ing. the additional data pertinent to such interval. . .... . ,. ... It®m26: "Sacks Cement": Attached supplementaiii' record.~for this well shoUld show the details of any mul- tiple stage cementing and the location of lhe..cementing:~'tool. : ..... ' ..... Item 2~: Submit a separate completion reP0rt on': this form for each"- interval to be separately produc~l. .; ?..-~ ~": (See instruction for items 20 and 22 above). : }L4 '' · 7: · . 35. G IiX)LOG IC' ":' ':"' WATgR AND MUD ;.%. La. ' -'" ' ' ' ' ".. . ' · , ~ ' "' ' '" .Z) ; '" :- '~'" ' : - NANI'~ ;- 'J : } ,,, , 'i . · ,' N.OHE. Middl:e Kenai ?'E" 7180' 6167' .... "F" 8265' 7036' .... . · j .~ " ' .... Hemlock 10957 - . . . .' ~. 7,.. .... ~qe'st .Foreland 11604 ' 9799' "'J , · . "~ ~::~""~a'0? Cor~g D^;r^. ^a~r^C~ Cm~ ~mcmP~o~s'-o~ ~**to~o~, Ponos~. ~a~'~a~, app~. -~.2 · .. . . . .. . . II ~ -' . ~ .. ~. %. ~ .~ . . ~.. .. : .... . ~ , : .... . , , , UNOCAL WELL RECORD PAGE NO. LEASE TRADING BAY FIELD WELL NO. TBUS G-31 LOCATION: CONDUCTOR 38, LEG ~2, t878' N 1389' W F/SE CORNER, SEC. 29, T9N, R13W, SM PERMIT NO. 69-72 SERIAL NO. TD 12729' TVD 10768' DEVIATION (BHL) 1223'N, 4423' E F/SW Corner Sec. 28, T9N, R13W S.M. COMPANY ENGINEER ..CHUDANOV, HARNESS, GRAHAM SPUD DATE COMP. DATE CONTRACTOR POOL ARCTIC RIG NO. TYPE UNIT National 1320 54¸ DRILL PIPE DESCRIPTION 5", 19.5~ E&S ELEVATIONS: WATER DEPTH 125' RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK 228' 103' 23.3' 46.6' RT TO PRODUCTION DECK APPROVED SIZE WEIGHT THREAD CASING & TUBING RECORD GRADE DEPTH BMMARKS 17-3/4" 13-3/8" .312 Wall SPIBJtL WELD 61~ BUTTRESS - 520 ' J-55 5222' CMT'D W/790 SXS .... 2500 SXS 9-5/8" 43.5 & 47~ " 7" 29~ " N-80., P-110 11667' N-80 11595'-12729' .... 1700 SXS .... 300 SXS DATE INTERVAL E.T.D. PERFORATING RECORD REASON PRESENT CONDITION 4-11-69 12100'-12101' 12637' 9-13-69 11870'-11871' 12637' 9-14-69 10910'-10911' 12637' 9-16-69 12021'-12045' 12637' 9-18-69 11678'-11688' 11811' SQZ ,, DST ~1 PRODUCTION SOZ ~1 55 SX, SQZ ~2 150 sx SQZD W/100 SX SOZD W/100 SX PLUGGED OFF W/CIpB 9 11811' "WF" ADANDON W/RET 9 11524' 9-18-69 11696'-11706" 11811' " 9-18r69 11723'-11738' 11811' " 9-18-69 10448'-10484' 11811' " 9-18-69 10540'-10570' 11811 ..... G" ZONE OPEN 9-18-69 10592'-10636' 11811 ..... G" ZONE OPEN 9-18-69 10708'-10728' 11811 ..... G" ZONE OPEN 5-04-74 10450'-10480' 11524 ..... G" ZONE OPEN 5-04-74 10540'-10570' 11524 ..... G" ZONE OPEN 5-04-74 10610'-10635' 11524 .... G" ZONE OPEN INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS "WF" ABANDON W/RET 9 11524' "WF" ABANDON W/RET 9 11524' "G" ZONE OPEN WELL HEAD ASSEMBLY TYPE: Shaffer-Cameron CASING HEP~: Shaffer 12" 900 v 13-3/8" SOW ~ KD Mead W/2" threaded side outlets CASING HANGER: SHaffer 12" Nominal 9-5/8" Model KDKS TUBING HEAD: Cameron 12" 3000~ x 10" 5000~ DCB W/2" Flanqed side outlets TUBING HANGER: Dual DCB, 10" nominal, w/ 3-1/2" buttress x 3-1/2" buttress TUBING HEAD TOP: 10" 5000~ MASTER VALVES: Cameron dual string solid block tree w/2 ea. 3-1/8" bore master valves ..... w/2 ea 3-1/2" bore winq valves. CHRISTMAS TREE TOP CONN: 3-1/2" EUE 8RD UNOCAL WELL RECORD PAGE NO. LEASE TRADING BAY WELL NO. TBUS G-31 FIELD LOCATION: CONDUCTOR 38, LEG ~2, 1878' N 1389' W F/SE CORNER, SEC. 29, T9N, R13W, SM PERMIT NO. 69-72 sERIAL NO. TD 12729' TVD 10768' DEVIATION (BHL) 1223'N, 4423' E F/SW Corner Sec. 28, T9N, R13W S.M. COMPANY ENGINEER CHUDANOV,..HARNESSr GRAHAM SPUD DATE CONTRACTOR TYPE UNIT COMP. DATE pOOL ARCTIC RIG NO. National 1320 54 DRILL PIPE DESCRIPTION 57,. %9.5~ E&S . ELEVATIONS: WATER DEPTH 125' RT TO OCEAN FLOOR RT TO MLLW RT TO DRILL DECK 228' 103' 23.3' 46.6' RT TO PRODUCTION DECK APPROVED PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5-11-74 11285'-11315' 11524' PRODUCTION HB-4 OPEN 11285'-11315' 11524' 5-13-74 PRODUCTION HB-4 OPEN 5-13-74 1~255'-11285' 11524' PRODUCTION HB-4 OPEN 5-15-74 11160'-11190' 11524' PRODUCTION HB-3 SQZD 8-18-89 5-16-74 10966'-10986' 11524' PRODUCTION HB-1 OPEN 5-16-74 11015'-11025' 11524' PRODUCTION HB-2 OPEN (attempt sqz 8-20-89) 5-16-74 11042'-11057' 11524' PRODUCTION HB-2 SOZD 8-18-89 5-16-74 11080'-11110' 11524' PRODUCTION HB-2 SQZD 8-24-89 12-20-75 10966'-10986' 11524' PRODUCTION HB-1 OPEN .12-20-75 11010'-1102~' 11524' PRODUCTION HB-2.. OPEN (~ttemp~. sqz 8-20-89) 12-20-75 11042'-11057' 11524' PRODUCTION HB-2 SQZD 8-14-89 12-21-75 11068'-11128' 11524' PRODUCTION HB-2 SQZD 8-24-89 12-21-75 11160'-11180' 11524' PRODUCTION HB-3 ~QZD 8-18-89 12-21-75 11260'-11300' 11524' PRODUCTION HB-4 OPEN 08-20-80 10960'-10990' 11524' PRODUCTION HB-1 OPEN 08-20-80 11008'-11023' 11524' PRODUCTION HB-2 ...OPEN (att~mp% ~qz 8-20-89) 08-20-80 11085'-11140' 11524' PRODUCTION HB-2 .$QZ. 8-24-89 08-20-80 11153'-11168' 11524' PRODUCTION HB-3 08-30-88 11227'-11234' 11524' PRODUCTION HB-4 08-31-88 11169'-11216' 11524' PRODUCTION HB-3 SQZ 8-18-89,, OPEN SQZ 8-18-89 09-01-88 10976'-11006' 11524' PRODUCTION HB-1 OPEN 09-05-89 10960'-10990' 11509' PRODUCTION HB-1 OPEN 09-05-89 11211'-11315' 11509' PRODUCTION HB-4 OPEN 09-07-89 10450'-10480' 11509' PRODUCTION "G" ZONE OPEN 09-07-89 10540'-10570' 11509' PRODUCTION "G" ZONE OPEN 09-07-89 10610'-10635' 11509' PRODUCTION "G" ZONE OPEN 09-07-89 10708'-10728' 11509' PRODUCTION "G" ZONE OPEN 08-27-89 11364'-11366' 11509' ISOLATION SQUEEZE sQZ 8-30-89 LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 7/20/89 11524' COMMENCED OPERATIONS ON WELL G-31 AT 0400 HOURS, 7./20/89. Skidded rig over slot #38, Legroom #2. Rigged up miscellaneous equipment. Rigged up wireline on G-31S. Tested lubricator-OK. Ran 2.75" gauge cutter to ball valve. Pulled ball valve in short string. Rigged up lubricator on G-31L and tested same-OK. Made gauge run to ball Valve. Pulled ball valve in long string. Made wireline scratcher run to "X-A" sleeve in long string at 10864'. Ran in hole with "X-A" shifting tool - stopped at 4490'. Made up 2.73" gauge cutter and ran in hole. 7/21/89 11524' Continued running in the long string with 2.73" gauge cutter to 10,884'. Trip for "X-A" shifting tool. Engauged long string "X-A" sleeve at 10290' and jarred same open. Rigged up to take returns to the well clean tank. Pumped one casing volume down long string - no returns. Pumped one annular volume into formation. Mixed and pumped calcium carbonate pill down short string. Squeezed pill into formation - pressure built from 400 psi to 1400 psi. Ran in short string with 2.735 gauge cutter - stopped at 8774'. Trip for scratcher. Scratcher stopped at 5517'. Ran in with 2.5" gauge cutter to 10320' - no problems. Trip for 2.7" scratcher and worked same from 5040' - 8200'. Ran 2.5" gauge cutter to 10323' - no problem. Worked 2.7" scratcher from 8206' - 8950'. 7/22/89 11524' Ran in short string with 2.7" scratcher and worked same from 5040' to 8200'. Ran 2.5" gauge cutter to 10323' - no problem. Ran 2.7" scratcher and worked same from 8206' to 8950'. Mix and pump calcium carbonate LCM pill. Squeezed pill into formation - pressure built from 800 psi to 1600 psi. Ran in short ~~~~~~0~.~~%$$%~w~i!i~i~!!~i~~i~~~i!~~!~!i~~t°9ol9''Changed out in sho~t string with 2.59" recovery. Ran ~et cutter and cut tubing at 10320'. Rigged up APRS wireline on long string. Ran in with 2.7" jet cutter and cut tubing at 10873'. Tripped for new cutter. Cut tubing at 10300'. Circulated down short string taking returns up the annulus at same pressure as before the cut . 7/23/89 11524' Set back pressure valves in each string. Removed production tree. Installed and tested ~ ~ TT~~ ~'~c~ications Rigged up landing jOints and APRS wireline. Ran in short string with 2.59" jet tubing cutter and cut tubing at 10321'. Circulated one tubing volume down short string taking returns up long string at 4 BPM at 1000 psi - with good returns. Rigged up to pull both strings. Bucked out hanger pins and pulled hanger LEASE GRAYLING UNOCAL DRILLING RECORD' ALASKA REGION PAGE NO. 2 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 7/23/89 CONT. free. Attempted to pull tubing free with 320 K overpull - no success. Rigged up APRS to run free point survey in short string. 7/24/89 11524' Ran in short string with free point. Tubing was free to top of "X-A" sleeve at 10290'. Attempted to move long string with 130K overpull - no movement. Ran freepoint on long string. Tubing was free to top of "X-A" sleeve at 10290'. Ran in short string with 2.59" jet cutter - set down at 7244'. Changed out wireline units. Change out damaged landing joint. Ran in short string with a 2.5" swage and worked through tight spots from 7244' to 7485'. Fell free to 10300'. Trip for 2 65" swage Ran swage in to 8500' · · f worked down to 8530' and swage hung up. Wire pulled out of rope socket while working to free swage. Trip for fishing tools. Ran in and engaged fish with overshot. Working swage while circulating down long string. 7/25/89 11524' Continued working to free wireline fish. Circulated down long string taking returns on short string at 6 BPM at 1000 psi. Fish came free· Ran in hole with 2·6" gauge cutter to 10300' (tight spot at 8530'). Rigged APRS up on short string and ran in with 2·59" jet cutter. Pulled 95K overpull on short string and cut tubing at 10245'. Rigged up APRS on long string and ran in hole with 2·7" jet cutter· Cut long string at 10205'. Circulated down long string with full returns up the annulus for 30 minutes· Circulated · %~"-"~'°wn short string with partial' returns up the 'annulus· Gradually worked overpull on short string to ll0K over string weight - tubing' came free· Circulated one casing volume down short string taking return up annulus. Checked well for flow - no flow· Pulled out of hole laying down dual 3-1/2" production string· 7/26/89 11524' Continued laying down dual 3-1/2" gas lift completion string. Changed bottom pipe rams to 3-1/2" single. Set test plug and tested lower pipe rams - OK. Pulled test plug and set wear bushing. Made up fishing assembly #1 and ran in hole to 10189'. Circulated and added 3% KCL to workover fluid. 7/27/89 10300' Engaged long string fish @ 10212'. Jarred fish loose with 60K overpull. Picked up 3' and circulated well clean from 10297' until fish was completely free. Pulled out of hole recovering entire fish (93.82', including X-A sleeve). New top of long string fish at 10305'. Redressed overshot and ran in hole to 10220'. Circulated one casing volume and engauged short string fish at 10250' - fish plugged. Jarred fish free with 60K overpull - fish plugged. Pulled 2 stands and dropped LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 3 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. 7/27/89 CONT. 7/28/89 10873' 7/29/89 10900' RECEtV 7/30/89 10933' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS ball for pump open sub. Pulled 18 stands while letting ball fall to seat. Kelly up and shear pump open sub with 1200 psi. Pulled out of hole recovering entire fish (75 5 ' · , including "X-A" sleeve). Make up clean out assembly #2 and ran in hole to 10250'. Washed down from 10250' to 10324' (top of dual packer). Circulate well clean at 10 BPM rate. Redressed overshot and ran in hole with fishing assembly #1 to 10300'. Engauged fish and jarred free with 150K overpull. Circulated bottoms up from 10870'-some gas to surface. Pulled 4 stands - had trouble with swabbing. Dropped bar and sheared pump open sub. Circulated bottoms up from 10687'. Pulled out of hole with fish - no swabbing. Recovered dual packer, 18 joints tubing, and "X-A" sleeve (572.26' total). Made up clean out assembly #2 and ran in hole to 2800'. Cut drilling line 104'. Continued running in hole to 10850' (worked by top of fish at 10873'). Cleaned out hard fill from 10855' to 10900'. Pulled out of hole and layed down washover assembly. Ran in hole with overshot assembly and engaged long string fish at 10873'. Pulled seal assembly out of permanent packer at 10900', circulated bottoms up, and pulled out of hole. Recovered 25.77' tbg above seals; 22.38' of seals and locator sub; and 10.47' tbg below seals - 58.62' total. Ran in hole with burn over assembly with packer retrieving tool to permanent packer at 10900'. Attempted to mill on packer, but could not rotate - pipe stuck below bumper sub. Worked pipe loose and made two more attempts to mill on packer with the same results. Released packer retrieving tool, circulated bottoms up, and pulled out of hole. Continued to pull out of hole with burn over shoe. Found junk inside burn over shoe (2-1/2" W X 20" L piece steel, similar to 7" csg). Found a piece of wire on PRT grapple. Layed down packer retrieving tool. Ran in hole with barefoot burnover shoe. Burnover permanent packer at 10900'. Pulled out of hole and layed down burnover shoe. Rigged up for BOPE test - could not get test plug to seal. Delayed test to next trip. Made up spear to catch packer body. Held rig floor H2S drill. Ran in hole and engaged packer bodv at 10650'. Chased packer down hole to 109~3'. Pulled out of h~le and layed down fishing assembly and packer. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 4 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. 7/31/89 11246' 8/1/89 11247' 8/2/89 11247' RECEiYED DEC201 9 Gas Cons. chorage 8/3/89 11247' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Performed weekly BOPE test to Unocal specifications. Made up 8-1/2" mill with junk boot and scraper. Ran in hole to 10900'. Washed and reamed down to 11234'. Hole very tight at 11234'. Pumped high viscosity sweep - recovered large amounts of sand. Continued to ream from 11234' to 11246' - stopped making hole. Trip for new mill. First nine stands out were tight through the perforations. Continued tripping for new 8-1/2" mill. Mill had 50-60% wear on side edge. Layed down casing scraper. Cleaned packer junk out of junk boot. Ran in hole with new 8-1/2" mill to 11246'. Washed and reamed from 11246' to 11247' in 5-1/2 hours. Pulled out of hole with mill Mill indicated running on a wireline fish (1-11/16 ID marks on bottom). Cleaned wireline tool pieces out of junk basket. Traction motor on rotary table went to ground. Spent 3-1/2 hours pulling motor. Slip and cut drilling line. Made up rolling dog grapple to catch 1-1/2" to 2". Ran in hole to 10400' while waiting on replacement parts for rotary table. Completed repairs to rotary table. Ran in hole from 10400' to 11247' with rolling dog overshot with drag tooth leading edge. Washed over top of fish to 11253' (fish too light to tell if engaged). Pulled out of hole to check for recovery-no success. Changed to a 1" cage in overshot bowl. Ran in hole and attempted to engage fish. Pulled out of hole-no recovery. Ran in hole with open end drill pipe to spot CaCO3 LCM pill while waiting for impression block to be machined. Continued running in hole to 10750' and spotted a 100 bbl CaCO3 pill (57# CaCO~/bbl). Squeezed away 35 bbl of pill into the formation. Circulated out balance of the pill. Made up and ran in hole with 8" impression block. Set down with 12000# at 11216'. Pull out of hole to check block-no useable impression. Made up washover assembly and ran in hole. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 5 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/4/89 11292' Completed trip for new washover assembly. Cleaned out fill from 11253' to 11264'. Rotary torque increased. Mixed and pumped high viscosity HEC pill-torque decreased. Continued to clean out from 11264'-11286'. Pumped second pill. Continued to clean out from 11286'-11292'. Stuck wash pipe. Worked loose in 30 minutes. Started to pull out of hole and found damaged connection between 10th and llth joints due to excessive torque. Continued pulling out of hole laying down 3-1/2" drillpipe. Had to pump the first 80 joints out of the hole. First 60 joints had very tight breaks. 8/5/89 112'92' Completed pulling out of hole laying down 3-1/2" drillpipe. Washover shoe 100% worn. Top of drive sub had been polished by junk riding on top. Ran in hole with 4-3/4" drill collars and excess 3-1/2" drill pipe from derrick. Pulled out laying down 3-1/2" drill pipe. Replace 3-1/2" rams with 5" rams. Changed handling tools. Tested BOPE to Unocal specifications. Unloaded 266 joints 5"-19.5#-S-135 and 140 joints 5"-19.5#- Grade E drillpipe. Made up washover assembly. Ran in hole picking up 5" drillpipe. 8/6/89 11381' Continued running in hole with washover RE~V~D assembly on 5" drill pipe to 11292'. Cleaned out fill from 11292' to 11381'. Normal rotary torque running ± 450 Amps. Circulated until D~C~01~ shakers were clean. Trip for new washover ~~&Ga$C0~ __~shoe. Had to pump out the first 44 stands. U0~ Added XC polymer to active system to improve ~~g0 hole cleaning. 8/7/89 11524' Continued trip for new washover shoe. Washover shoe was 90% used. Junk boots full of various types of debris. Made up new washover shoe. Ran in hole and raised mud properties to 36 VIS, 6 PV, and 14 YP. Cleaned out fill and junk from 11381' to 11524' ETD (cmt retainer). Pumped high viscosity sweep. Pulled out of hole with washover shoe. 8/8/89 11527' Continued to pull out of hole with washover assembly. Pumped out the first 9 stands. Layed down washover assembly. Ran in hole with 8-1./2" mill and tagged fill at 11527'. Worked on mud pumps 7 hours. Pumped a high viscosity sweep at 12.25 BPM. Pulled 50 stands with slight drag. Ran back to bottom and prepared to pump a second high viscosity sweep. 8/9/89 11527' Mixed and pumped around a second high viscosity sweep at 11527'. Trip for CET/CBT/GR. Cleaned out junk subs, which were full. Rigged up Schlumberger and ran CET/CBT/GR from 11500' DIL to 8500' DIL. Ran in hole with RTTS with bypass to 10400'. Broke circulation and set packer at 11385'. Pressure tested casing to 2000 psi for 30 minutes-OK. Pulled out of hole with RTTS packer. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 6 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/10/89 11148, Continued to pull out of hole with RTTS packer. Rigged up Schlumberger with lubricator. Ran in hole with HOWCO cement retainer on wireline. CCL not working-trip wireline for repair. Ran in and set cement retainer at 11205' DIL. Trip wireline for another cement retainer. Set second retainer at 11148' DIL. Ran in hole with HOWCO stab-in tool on 5" drill pipe to 11140' and broke circulation. Rig uP and tested surface lines to 5000 psi. Stabbed into retainer at 11148' DIL (11150' DPM). Pumped away at .75 BPM at 2000 psi. Increased rate to 3 BPM at 3800 psi-started getting returns to surface. Pulled up to blanking port and pressure tested drill pipe to 2100 psi-OK. Pumped cement as follows: 56 ft3 FIW; 95 ft3 Class G cement with .5% Halad 344, .14% LWL, .2% CFR-3, and .71 ft3/SX FIW; 56 ft~ FIW,; and 909 ft~ mud. Closed tool and squeezed away cement. Pressure built to 3000 psi at 3 BPM and held while displacing cement. 51 ft3 cement squeezed outside casing with a final pressure of 3000 psi. Drill pipe pressure and casing pressure equalized as soon as pumping stopped. Cement in place at 1930 hours. Pulled up 11138' and reversed drill pipe clean (20 ft3 cement cut mud to surface). Trip for RTTS packer. 8/11/89 11203' Ran in hole with RTTS packer with bypass to 11065'. Rigged up surface lines and broke circulation. Searched for isolation as follows: Set at 11065', pumped at 1 BPM at RECEIVED 2950 psi, started circulating to surface and pressure dropped to 2700 psi; Reset at 11059', circulated to surface at 1 BPM at 1100 psi; D~C~01~ Reset at 11038', circulated to surface at 1 A il&Gss C0n G mm% BPM at 2250 psi, pressure fell to 2000 psi after 7 BBLS pumped; Reset at 11000', ~0~g9 circulated to surface at 1 BPM at 2450 psi, pressure fell to 1200 psi after 7 BBLS pumped; Reset at 10942', pumped 1 BPM at 3000 psi with no communication to surface. Established a breakdown of 3000 psi at 1.5 BPM, 3400 psi at 5 BPM. Trip for clean out assembly #11. Ran in hole to 11136' and tagged soft cement. Drilled retainer at 11148' and cleaned out to 11203' (cmt retainer). Had good cement across performations. Trip for cement retainer. 8/12/89 11201' Made up and ran in hole with HOWCO cement retainer to 11138'. Broke circulation and set retainer at 11138' (set higher to move away from last set). Rigged up and tested surface lines to 5000 psi. Attempted to establish a breakdown rate. Surface returns at 1100 psi at 1.5 BPM-set in perforations. Trip for clean Out assembly #11. Ran in hole and tagged retainer at 11138'. Drilled retainer and pushed to 11201' (cmt retainer). Trip for cement retainer. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 7 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE 8/13/89 E.T.D. 11067' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Ran in hole and set HOWCO retainer at 11148'. Pressure tested drill pipe to 3000 psi-OK. Rigged up and pressure tested surface lines to 5000 psi. Stabbed into retainer. Pumped 1.5 BPM at 1650 psi with returns to surface. Pressure dropped to 1200 psi after pumping 4 BBLS. Mixed and pumped cement as follows: 56 cf FIW; 119 cf Class "G" mixed with 0.5% Halad 344, 0.14% LWL, 0.2% CFR-3, and 0.71 CF/sx FIW; and 893 CF drill mud. Closed tool with cement 25 CF short of tool. Squeezed cement at 2 BPM with final drill pipe pressure of 2600 psi (1800 psi annulus). Pulled up to 11118' and reversed out 44 CF cement. Performed weekly BOPE test. Ran in hole and set HOWCO retainer at 11067'. Rigged up and tested surface lines to 5000 psi. Stabbed into retainer and pumped 1.5 BPM at 2100 psi. Increased rate to 4 BPM at 3400 psi. Pressure dropped to 3200 psi after pumping 15 BBLS. Mixed and pumped cement as follows: 56 CF FIW; 151 cf Class "G" (same as above slurry); 56 cf FIW; and 859 CF drill mud. Stabbed into retainer-pressure immediately built to 4500 psi. Unstabbed from and stabbed back into retainer-no good. Unstabbed from retainer at 2000 psi. Cement U-tubing in to annulus. Stabbed back in and displaced 33 cf cement outside perforations while taking returns up the annulus. Shut in annulus for last 33 cf of displacement. Final squeeze was 2 BPM at 2600 psi (1800 psi annulus). Pulled up to 11050' and reversed out 56 CF cement. Trip for cement retainer. RECEIVED DEC20|9 A asl,m Oil a Gas Con Anchorage LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 8 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. 8/14/89 10993' RECEIVED DEC201989 Gas Cons. Gomm sS' Anchorage 8/15/89 11036' 8/16/89 11071' 8/17/89 11203' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Cont trip for cement retainer. Ran in hole with cement retainer. Set retainer at 11031' DPM. Rigged up and tested surface lines to 5000 psi. Stabbed into retainer and established a breakdown of HB-2 perforations from 11042'-11057' DIL with 1.5 BPM at 2900 psi, Pumped away 15 BBLS at 4 BPM at 3500 psi with intermittent flow to surface. Mix and pump cement job as follows: 178 cf (150 SXS) Class "G" cement mixed to 116 pcf with 0.5% Halad 344, 0.14% LWL, 0.2% CFR-3, and 0.7 cf/sx FIW; 56 cf FIW; and 824 cf drill mud. Stabbed into retainer and displaced with additional 240 cf drill mud. Final squeeze at 2 BPM at 3200 psi. Cement in place at 1045 hrs. Pulled up to 11018' DPM and reversed drill pipe clean recovering 130 cf good cement (24 cf outside perforations). Trip for cement retainer. Found blast spots on drill pipe from 111' to 36' above retainer (10999'-11024' DIL). Ran in with cement retainer. Set retainer at 10993' DPM. Rigged up and tested surface lines to 5000 psi. Stabbed into retainer and established a breakdown at HB-2 perforations from 11008'-11025' DIL with 2 BPM at 3000 psi with returns to surface. Pumped 17 BBLS a 4 BPM at 3175 psi with returns to surface. Mix and pump cement job as follows: 107 cf (90 sxs) with same additives as above; 56 CF FIW; and 898 CF drill mud. Stabbed into retainer and displaced with additional 263 cf drill mud. Final squeeze at 2 BPM at 2600 psi. Cement in place at 2200 hrs. Pulled up to 10978' DPM and reversed drill pipe clean recovering 10 cf good cement (19 cf outside perforations). Trip for drilling assembly. Continued trip for Drilling assembly. Ran in hole and tagged soft cement at 10986' DPM. Drilled out retainer. Down two hours with electrical problems on rotary table. Cleaned out firm cement from 10997' DPM to 11033' DPM. Drilled on retainer from 11033' DPM to 11036' DPM. Trip for new bit. Continued trip for bit. Cleaned junk subs-large pieces approx 1-1/2" x 1-1/2". Mill worn 50% with some gauge wear. Made up Smith "DGJ" bit and ran in to 11036' DPM. Cleaned out cement and junk to 11066' DPM. Drilled on retainer and junk to 11071' DPM. Trip for new bit. Cleaned junk subs. Made up Smith "SDGH" bit and ran in to 11071' DPM. Continued cleaning out from 11071' DPM to retainer at 11148' DPM. Drilled retainer and hard cement from 11148' to 11179' DPM. Cleaned out from 11179' DPM to 11203' DPM-very little cement. Circulated well clean. Trip for RTTS packer and retrievable bridge plug. Made up and ran in hole to 11148' DPM with test assembly. Set packer and rigged up surface lines. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 9 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/18/89 11147' Tested surface lines to 5000 psi. Pressure tested HB-3 squeeze from 11148' DPM to 11203' DPM-broke down with 4000 psi. Pumped into formation at 3 BPM at 4100 psi-good isolation from above zone. Pressure tested HB-2 squeeze from 11067' DPM to 11148' DPM-broke down with 3200 psi. Pumped into formation at 3 BPM at 3900 psi-good isolation from above zone. Pressure tested HB-2 squeeze from 11032' DPM to 11067' DPM-broke down with 3600 psi. Pumped into formation at 3 BPM at 4100 psi. Pressure tested HB-2 squeeze from 10993' DPM to 11030, DPM-broke down with 4000 psi. Pumped into formation at 3800 psi with returns around RTTS to surface. Made two resets with RTTS to obtain a seal to surface-no success. Released packer. Packer dragging and would not rejay. Pulled to 11000' DPM and circulated. Worked packer-rejayed OK. Ran in and picked up retrievable bridge plug at 11030' DPM. Started swabbing when pulling pipe-circulated bottoms up. Trip for cement retainer. Made up retainer and ran in to 2000' DPM. Cut drilling line. Continued in to 11147' DPM. Rigged up surface lines and set retainer at 11147' DPM. Test drill pipe to 3000 psi and surface lines to 5000 psi. Established break down at 3800 psi. Pumped into formation at 2.5 BPM with 4500 psi. Mixed and pump cement as follows: 56 cf FIW; 178 cf (150 ex) Class "G" cement mixed to 116 pcf with .5% Halad 344, .14% LWL, .2% CFR-3 and .70 cf/ex FIW; 56 cf FIW; and 830 cf drill mud. Stabbed into retainer and displaced with an additional 186 cf drill mud. Final squeeze pressure was 4700 psi. 8/19/89 11032' Pulled out of retainer. Cement in place at 0020 hours. Pulled to 11132' DPM and reversed out 99 cf cement, leaving 55 cf (46 ex) RECEiVeD outside perforations. Trip for cement retainer. Made Up cement retainer on running tool, ran in to 11067' DPM, and set retainer. D~C~01~ Test drill pipe to 3000 psi and surface lines ~i_.~_~&~a$C0~$.~$~_~~ to 5000 psi. Established break down at 2800 psi. Pumped into formation at 3 BPM with 3400 ~-' ~Q~ psi. Mixed and pumped cement as follows: 56 cf FIW; 188 cf (158 ex) Class "G" cement mixed to 116 pcf with .5 Halad 344, .14% LWL, .2% CFR-3, and .70 cf/ex FIW; 56 cf FIW; and 824 cf drill mud. Stabbed into retainer and displaced with an additional 255 cf of drill mud. Squeezing at .5 BPM with 4300 psi and broke around to annulus. Final squeeze pressure was 3900 psi-drill pipe and annulus equalized after 5 minutes. Cement in place at 1340 hours. Pulled to 11052' DPM and reversed out 109 cf clean cement, leaving 46 cf outside perforations. Trip for cement retainer. Made up cement retainer on running tool, ran in to 11032' DPM, and set retainer for squeeze of HB-2 from 11032' to 11067' DPM. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 10 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/20/89 10993' Pressure tested drill pipe to 3000 psi and surface lines to 6000 psi. Stabbed into retainer and attempted to break down with 4000 psi - no good. Unstabbed from retainer and circulated. Stabbed back in and pressured drill pipe to 5300 psi with 1500 psi on annulus-no bleed off. Stabbed and unstabbed several more times-no success. Trip for cement retainer. Made up cement retainer on running tool, ran into 10993' DPM, and set retainer for squeeze of HB-2 from 10993' to 11032' DPM. Rigged up and pressure tested surface lines to 5000 psi. Established breakdown at 4600 psi. Pumped into formation at 1 BPM with 4600 psi a total of 6 BBLS with no decrease in pressure. Mixed and pumped cement as follows: 56 cf FIW; 113 cf (95 ex) Class "G" cement mixed to 116 pcf with .5% Haled 344, .14% LWL, .2% CFR-3, and .70 cf/ex FIW; 56 cf FIW; and 894 cf drill mud. Stabbed into retainer and displaced with an additional 179 cf drill mud. Squeezing at .25 DPM with 4800 psi and broke around to annulus. Final squeeze pressure was 4800 psi-drill pipe and annulus equalized at 1800 psi after 5 minutes. Cement in place at 1200 hours. Pulled to 10978' DPM and reversed out 15 bbl clean cement, leaving 12 cf outside perforations. Pulled out of hole and performed weekly BOPE test. Slow leak in lower Kelly cock-will replace 8/21/89. Set wear bushing and ran in hole with drilling assembly. Tagged cement at 10985' DPM and cleaned out firm cement to 10993' DPM. Drill on retainer at 10993' DPM. 8/21/89 Continued drilling on retainer at 10993' DPM. Cleaned out firm cement from 10994' DPM to 11020' DPM. Cleaned out cement stringers from 11020' DP, to 11031' DPM. Drilled on retainer RE~E~V~D at 11031' DPM and pushed to bottom at 11066' DPM. Circulated bottoms up and tripped for RTTS packer to test squeezed perforations in D~C~01~9 HB-2. RIH with RTTS and retrievable bridge plug to 11031' DPM. Set packer and pressure ~~~&Ga$C0~$~G0m~$$iQ-Rtested squeezed HB-2 perforations from 11042' ~' ~Ch0~g0 to 11057' DIL to 4600 psi for 30 minutes-ok. Pulled up and set packer a 10993' DPM to test squeezed HB-2 perforations from 11008' to 11025' DIL. Attempted to pressure test-had intermittent communication to surface at 3800 psi. Tried sets at 10990' , 10993' , and 10996' DPM with same results, pulled up and set bridge plug at 10945' DPM. Set RTTS at 10880' DPM ~nd pressure tested packer against blank pipe-ok. 'Ran in hole and set packer at 10993' DPM and 11000' DPM-no test with intermittent communication to surface. Trip for clean out assembly. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 11 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. 8/21/89 11067' 8/23/89 11147' RECEIVED DE0 O198,9 0il & Gas Cons. commissio Anchorage 8/24/89 11066' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Ran in hole with clean out assembly to 11067' DPM. Drilled up retainer and cleaned out cement to 11148' DPM. Circulated bottoms up and tripped for RTTS packer to test squeezed HB-2 perforations from 11080' to 11140' DIL. Set RTTS at 11067' DPM and pressure tested to 4600 psi-slow bleed to 2900 psi in 5 minutes. Established a breakdown at 1/2 BPM with 5500 psi, holding 1500 psi on annulus. Pumped away 7 BBL total with 5500 psi. Shutdown pump and pressure bled to 3700 psi in 5 minutes. Pulled to 11006' DPM and reset RTTS. Pressured to 4600 psi-bled to 2900 psi in 2 minutes. Repressured to 4350 psi and had a sharp pressure decrease and circulation to surface. Circulated to surface at 3 BPM with 1700 psi. Trip for cement retainer. Made up retainer, ran in hole to 11067' DPM, and set retainer. Pressure tested drill pipe to 3000 psi and surface lines to 6000 psi. Stabbed into retainer, pressured annulus to 2000 psi, and establish a breakdown at 5500 psi. Established 1/2 BPM rate with 6400 psi. Pumped away 6 BBL total at 1/2 BPM with 6250 psi-bled to'3900 psi in 5 minutes. Mixed and pumped cement as follows: 56 cf FIW; 122 cf (100 sx) Class "G" cement mixed to 116 pcf with .5% Halad 344, .14% LWL, .2% CFR-3, and .70 cf/sx FIW; 56 cf FIW; and 1080 cf drill mud. Stabbed in with cement 15 cf short of tool. Maximum squeeze pressure 6300 psi with 2000 psi back pressure on annulus. Cement in place at 0245 hours. Pulled out of retainer with 3400 psi and reversed out 74 cf cement, leaving 15 cf outside perforations. Trip for clean out assembly. Ran in hole and waited on cement 3-1/2 hours. Tagged firm cement at 11059' (8' above retainer). Cleaned out cement to 11067' DPM. Drilled retainer at 11067' DPM. Found no cement under retainer. Cleaned out to 11147' DPM and circulated bottoms up. Trip for RTTS to test squeezed perforations in lower HB-2. Continued trip for RTTS packer. Made up packer with bypass. Ran in hole and set at 11066' DPM. Rigged up and tested surface lines to 7000 psi. Pressure tested squeezed HB-2 perforations (11080'-11140' DIL) to 4600 psi, holding 20001psi on annulus-no good. Pressure dropped from 4600 psi to 3200 psi in 10 minutes. Established breakdown at 5200 psi. Znjected ~./2 BPM with 5200 psi and 3/4 BPM with 5300 psi. Shutdown Pumps and pressure dropped to 2800 psi in 6.25 minutes with no indication of communication to surface. Released RTTS and tripped for cement retainer. Made up cement retainer on running tool, ran in to 11066' DPM, and set retainer for squeeze of HB-2 perforations from 11080' to 11140' DIL. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 12 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/24/89(cont. ) Rigged up and pressure tested surface lines to 7000 psi. Attempted to establish breakdown - no good. Pulled out of retainer and rotated pipe to extend stinger. Stabbed into retainer and established breakdown at 5800 psi. Pumped into formation at .75 BPM with 5700 psi and .86 BPM with 6100 psi. Mixed and pumped cement as follows: 10 BBL FIW; 200 sx Class "G" cement mixed to 116 pcf with .5% Halad 344, .2% CFR-3, and .14% LWL; 10 BBL FIW; and 135 BBL brine. Stabbed into retainer, put 2000 psi on annulus, and pumped 25 BBL of slurry below retainer with a final rate of 3/4 BPM with 5650 psi. Casing pressure climbed to 2300 psi during last few bbls of displacement. Cement in place at 1515 hours. Pulled up and reversed out 188 sx cement. Trip for clean out assembly. Ran in hole with cleanout assembly to 11000' DPM and wait on cement. 8/25/89 11062' Continued waiting on cement until 0930 hours (cmt 18 hrs. old). Tagged good cement at 11062' DPM and cleaned out to retainer at 11066' DPM. Drilled retainer and hard cement to 11~00' DPM. Cleaned out to retainer at 11147' DPM. Drilled retainer and cleaned out to 11203' DPM. Circulated well clean, pulled 32 stands and set pipe on slips. Hung off blocks and changed out brake blocks. Continued pulling out of hole for new bit. 8/26/89 11525' RECEIVED Continued pulling out of hole for new bit. Ran in hole with clean out assembly to 11205' DPM. Drilled retainer and cleaned out to 11525' DPM ETD. Circulated bottoms up and pulled out of hole.. Rigged up electric line DEC 01 9 and lubricator. Ran in with 8-1/2" gauge ring Al 0 &G $C0ns, C0mmlssi and junk basket to 10750' WLM. Tripped wireline for drillable bridge plug. Ran in AI'I~J'II~I'~§~ hole and set bridge plug at 11400' CBT. 8/27/89 11403' Tripped wireline for perforating gun. Made up 2' squeeze gun loaded with 4 HPF. Ran in hole and fired gun at 11364'-11366' CBT (shale between HB-4 and HB-5). Tripped wireline for cement retainer. Made up retainer and ran in hole. Retainer set down at 9760' WLM. Could not work retainer loose. Set retainer, pulled out of hole, and rigged down wireline. Ran in with clean out assembly and drilled out retainer at 9780' DPM (wireline off depth). Pushed retainer junk to 11403' DPM. Pulled out of hole and performed BOPE test. Made up cement retainer on drill pipe and ran in bola. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 13 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 8/28/89 11400' Continued running in with retainer and set at 11350' DPM. Tested drill pipe to 4000 psi and surface lines to 7000 psi. Stabbed in and established a breakdown at 3200 psi. Injected 2 BPM at 2100 psi with full returns to surface. Mixed and pumped 100 sx cement. Displaced cement to 10 BBL above retainer. Stabbed in and pressure immediately increased to 4300 psi. Shutdown pump pressure did not bleed down. Put 2000 psi on annulus and increased squeeze pressure to 6300 psi-could not put fluid away. Unstabbed from retainer and reversed out cement. Trip for drilling assembly. Drilled out'retainer at 11350' DPM and pushed junk to 11400' DPM (cmt ret). Trip for cement retainer. 8/29/89 11392' Continued running in with retainer and set at 11350' DPM. Tested drill pipe to 4000 psi and surface lines to 7000 psi. Stabbed in and established a breakdown at 2100 psi. Injected 2-1/2 BPM at 2300 psi with full returns to surface. Mixed and pumped 100 sx cement. Displaced cement to 10 BBL above retainer. Stabbed in and pressure immediately increased to 4000 psi-retainer plugged again. Backed up annulus with 2000 psi and increased squeeze pressure to 6000 psi-no fluid movement. Reversed out cement and tripped for drilling assembly. Ran in with drilling assembly to 11345' DPM, drilled retainer and pushed junk to 11392' DPM. Pumped 50 BBL high viscosity sweep. Made up retainer on drill pipe and trip in hole. 8/30/89 11385' Continued in with cement retainer and set at 11347' DPM. Mixed and pumped 100 sx Class "G" cement with 0.5% Haled 344, 0.2% CFR-3, and 0.14% LWL (slurry weight: 15.5 PPG). Displaced 75 sx slurry through retainer. RE~E~V~D Cement in place at 0158 hours. Final squeeze at 2-1/2 BPM with 1300 psi. Had full circulation while cementing. Cement in place at 0158 hours. 'Attempted to pull out of ~~~.~&Ga$C0~$.C0~$$!~-~ retainer with 195 K overpull-no good. Worked ~¢h0~§~ pipe free and reversed out 80 sx cement. Trip for drilling assembly. Made up cleanout assembly and ran in hole to 11000' DPM. Wait on cement until 2000 hours. Drilled retainer at 11347' DPM and hard cement to 11385' DPM. 8/31/89 11522' Cleaned out junk from 11385' DPM to retainer at 11400' DPM. Trip for new bit. Ran in and drilled out retainer at 11400' DPM. Chased Tm ~ f~ retainer. junk to 1152.2' DpM ~D .... Made up cement retainer on drill pipe and ran in hole. 9/1/89 11509' (CMT RET) Continued running in hole and set retainer at 11509' DPM. Circulated well clean. Dumped active system. Large quantity of sand in bottom of pits with high oil content. Cleaning pits. LEASE GRAYLING UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 14 of WELL NO. G-31 FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 9/2/89 11509' (CMT ContinUed cleaning pits. Circulated well with RET) filtered inlet water while cleaning pits. Changed well over to 3% KCL completion fluid. circulated and filtered until turbidity of fluid was 80 NTU's. Trip for perforating assembly. Made up 5", 4 HPF, 32 gram, 90° phasing tubing conveyed perforating guns as follows: 9.70' blank, 104.00' guns for HB-4, 221.00' blank, and 30.00" guns for HB-1. Top shot to RA source = 259.23'. Ran in hole with perforating assembly. 9/3/89 11509' (CMT Continuing running in hole with perforating RET) assembly. Ran last 1800' of drill pipe for 700 psi drawdown at the top of the guns. Tested surface equipment to 2500 psi. Rigged up electric line and ran in with gamma ray correlation log. Positioned guns across HB-4 from 11211' to 11315' DIL and across HB-1 from 10960' to 10990' DIL. Set packer and reran gamma ray log-ok. Pull out of hole with wireline and rigged down same. Dropped firing bar at 0947 hrs. Recorded fluid levels during 60 minute flow period. Closed hydrospring. Filled drillpipe and pressured to open IPO circulating sub. Reversed 200 bbls to production and one drill pipe volume to the pits. Released packer and Circulated one hole volUme the long way. Pulled out of hole and layed down guns-all shots fired. Perform weekly BOPE test. 9/4/89 11509' (CMT Completed BOPE test. Made up bit and scraper RET) and ran in hole. Tagged retainer at 11509' DPM and circulated bottoms up. Hole taking fluid at ± 2 BPM. Mixed and pumped sized salt pill with bit at 11300' DPM. Pulled 10 stands ~ ~ ~ '~V~D and braden head squeeze pill-fluid loss E~E-------~ stopped and pressure held at 400 psi. Ran in to 10900' DPM and circulated out excess pill. D~C~01~ Trip for permanent packer. Made up hydraulic A _--~,S~0~et 9-5/8" Otis "BWD" permanent packer on ~a~Oil&Ga$C0~om%m""~rill pipe and ran in hole. Set packer at ~0~ 10844' DIL. Tested baCkside of packer to.400 psi-ok. Trip for isolation plug. Made up Otis "JP" plug on drill pipe and ran in hole. 9/5/89 11509' (CMT Continued running in with JP plug. RET) in Otis "BWD" packer at 10844' DIL. Set plug Spotted 6. sxs sand on top of plug. Waited 2 hours and tagged sand plug at 10841' DPM. Pulled to 10767' DPM to circulate and filter completion brine. Made up tUbing conveyed perforating assembly for "G" zone. Ran in hole leaving top 4000' dry to obtain a 700 psi drawdown at the ~top of the "G" Zone. Tested surface lines to 2500 psi. Rigged up electric line to run correlation log. LEASE UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. GRAYLING WELL NO. G-31 15 of FIELD MCARTHUR RIVER DATE E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS 9/6/89 11509' (CMT Ran gamma ray correlation log. RET) Set packer and reran correlation log. Pulled out and rigged down electric line. Cycled Omni valve open and dropped firing bar at 0506 hours. Guns fired at 0509 hours. Perforated "G" zone as follows: 10450'-10480' DIL; 10540'-10570' DIL; 10610'-10635' DIL; 10708'-10728' DIL. Allowed well to flow until 0600 hours. Reversed out and sent 250 BBLS to onshore facility. Release packer and pulled out laying down.perforating assembly. All guns had fired. Made up otis "JP" plug retrieving tool and trip in hole. Reversed out sand plug. Pumped down over and latched "JP" plug. Pulled plug out of permanent packer and pulled out laying down drill pipe. 9/7/89 11509' (CMT Continued pulling out with "JP" plug laying RET) down 5" drill pipe. Layed down "JP" plug. Pulled wear bushing. Rigged up tubing tongs and hydrotest. Made up landing joints and landed hangers. Changed bottom rams to 2-7/8" dual and tested same. Rig up to run production equipment. Made up stab in assembly. Ran in hole with dual 2-7/8" gas lift production equipment. Blast joints were run on long string from 10426' to 10747'. 9/8/89 11509' (CMT Continued running 2-7/8" dual G/L production RET) equipment. Hydro test same to 4000 psi. 9/9/89 RECEIVED DEC O198,9 : .... --, norage 11509' (CMT Continued hydrotesting in with 2-7/8" dual G/L RET) production equipment to safety valve nipples. Dropped setting ball on short string side. Installed subsurface safety valve nipples and control lines. Continued in hole and tagged permanent packer at 10862' (15.45' Deeper than DPM). Rigged up circulating line on long string and pressure test seal assembly to 350 psi-ok. Pulled up and spaced out tubing for landing. Had a 4' difference in tubing measurements between long and short strings that could not be found on measurement record. Checked several times on the way in to see that tubing strings were balanced. Landed tubing with approximately 6000# on slot locator. Rigged up circulating line on long string and pressure test seal assembly to 350 psi-ok. Rigged up on short string and set dual hydraulic packer. Tested dual hydraulic packer to 450 psi-OK. Locked down tubing hanger and removed landing joints. Installed 2-way check valves and nippled down BOPE. Install and test dual solid body tree to 5000 psi. Pressure test. hanger and pull 2-way check valves. LEASE DATE GRAYLIN...G UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 16 of WELL NO. G-31 FIELD MCARTHUR RIVER E. T · D____z_. DETAILS OF OPERATION DESCRIPTIONS & RESULTS 9/10/89 11509' (CMT Rigged down BPV lubricator. RET) Install flow lines on tree. Begun moving rig ~54 from Leg ~2 to Leg #3. Load out to beach one pipe rack section, reserve tank, and wireline trippod. Turned rotary table around. Moved stabbing board. Off loaded piperack, suction tank, shaker tank, shakers and stabbing board to boat. Jacked rig from Leg ~2 to Leg ~3, slot ~2, well G-21. Spotted shaker tank, suction tank, and piperack back on drill deck. ~eleaSed rig at 2.400 hOUrS, 9/10/89. RECEIVED c20] 9 AI I .OjJ & ! as Con . Qmmis$1 /l cliorage @ 520' @ 5222' Z RET @ 11509' RET @ 11524' BB AA CC PKR @ 11581' 7" TOL @ 11595' 9-5/8" @ 11667' 7"L @ 12729' Z 18-- -- 1 190_-- O__ 2 20~ 0 3 21~ O 4 22'~ 23'~' 0 6 o 7 24.~_ o 8 25~__ 26.~_. o 9 27.~_. ~ 10 28U--' ~ 11 29~ ~ 12 30~ ~ 131 31~ 14 : ~ 15 ~ 16 ~ ~7 dUNK C A) KELLY BUSNI~. ~T 9.00' CAMERON D~ SPLIT TUBING HANGER AT 42.64' c) 17-314", o.312" SPIRAL WELD AT 520' D) 13-318', 61~, J-55 CASING AT 5222' E! NOWCO EZSV RETAINER AT 11509' F) NOWCO EZSV RETAINER AT 115~4' Gl BAKER BYDROSET PKR AT 11581' ( TO£ @ 11576' ) N) 9-5/8', 43.$%, 47%, N-80, P-IlO CASING AT I) 7', 29~, N-HO LINER TOP AT 11595' m:)'r~ AT 22729' TUBING DETAIL 2-7/8", G.41, N-80, BUTT WITH SPECIAL CLEARANCE ~OUPLINGS 2) 2~65.89'~ 3) 2802.27'~ i) 527~.~8'~ S) 6) ~o32.~2'~ ~) 7785.46'; 8) 844:.47'; 9) 9062.49'r lo) 9662.~6'; ll) ~) ~XS RDH DU~ ~ULIC PACK~ TOP OF P~ (~G ~XNG) AT ~C~ OF P~ AT ~ OF P~ (~G STRING) AT 103~3.X8' 13) 2-~18" ~IS 0~' SLIDING S~E AT 10352.63' ~4) BALER 2.~5 x 2.313 ~ST JO2~S FR~ 1044~.36' ~2S ~P~-~PACK~AT 10862* STADoT~U S~ ASSY ~ 10662.46' ~ 10872.78' OTiS RElY GCX~ ~ ~ AT Z0936.40' SHORT STRING 28) 2-7/8' OTIS BAL~ VALVE AT 333.92' 29-28) 2-7/8" ~CCO G~'S AT: 19) 2108.71'; 20) 3746.53'; 21) 5215.33'; 22) 6288.35'; ~3) 6976.37'; 24) 7726.72'; 25) 835~.72'; 26) 8999.8~'; 27) 9602.52'; 28) 1~206.34' ~9) 2-7/8" mIA" SLIDING SLEEVE AT BB) OTIS RDH DUAL HYDRAULIC PACKER 40K SAFETY SHEAR SUB AT 20307.56' TOP OF PKR (SHORT STRING) AT 10308.38' CENTER OF PKR AT 103~4,65' BOT~M OF PKR (LONG STRING) AT 30) OTIS S~ING SLEEVE AT 10352.09' 31) OTIS "IN" NIPPLE AT 10358.00' WITH REENTRY GUIDE ~OM AT 10358.90' PERFORATXOK RECORD 4111/69 12100'-12101' 9113169 11870,'-11871' 9114/69 10910'-10911' 9;16189 12021'-12045' 9/18169 11678'-11588' 11696'-11706' 11723'-11738' 20448'-10484' 20540'-10570' 10592'-10636' 20708'-10728' 5/4/74 10450'-10480' 10540'-10570' 10610'-10635' 5111/74 11285'-11315' 5/13/74 11255'-11315' 5115/74 11160'-11190' 5/16/74 10966'-10986' 11015'-11025' 11042'-1105~' 11080'-11110' 12/20/75 10966'-10986' 12020'-21025' 11042'-i105~' 12/21/75 11066'-11128' 11160'-11180' 11260'-11300' 8/20/80 10960'-10990~ 11008'-11023' 11085'-11140' 11153'-11168' 8/30/88 11227'-11234' 8/31/88 11169'-11216' 911188 109~$'-11006' 8/27/89 11364'-11366' 9/$189 10960'-10990' 11211'-11315' 9/?/89 10450'-10480' 105~0'-10570' 10610'-10635' 10708'-10728' SQUEEZED SQUEEZED DST #1 SQUEEZED BELOW RET AT 11524' BELOW RET AT 11524' BELOW RET AT 11524' OPEN G-ZONE OPEN G-ZONE OPEN G-ZONE OPEN G-ZONE WELL TBUS G-31 COMPLETION ( 9-9-89 ) UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 10- 17-89 OPEN G-ZONE OPEN G-ZONE OPEN G-ZONE OPEN HE-4 OPEN SgZD OPEN HE-1 OPEN HB-2 (SQZ ?) SQZD S~ZD OPEN HE-1 OPEN BB-2 (SOZ ?) SQZD OPEN HE-4 OPEN OPENOPENOPENS~ZDSQZDSQZD o,E, .E-1 DEC'~ OPEN oPE. G-ZONE . Ol1 o,EN o-~sKa & Ga~ A., borage CEMENT SQUEEZE SUMMARY TBUS G-31 WORKOVER 7/20 THRU 9/10/89 PERFORATIONS HB-1 UPPER ~B-2 MIDDLE HB-2 LOWER HB-2 HB-3 HB-4 8/10/89 8/10/89 SET BP @ 11205' SET RET @ 11148' 8/12/89 SET RET @ 11148' 8/13/89 SET RET @ 11067' 8/14/89 SET RET @ 11032' 8/14/89 SET RET @ 10993' 8/18/89 SET RET @ 11147' 8/19/89 SET RET @ 11067' 8/20/89 SET RET @ 11031' 8/20/89 SET RET @ 10993' 8/23/89 SET RET @ 11067' 8/24/89 SET RET @ 11066' 8/27/89 8/30/89 SET BP @ 11400' SET RET @ 11347' 10960' - 11006' 11008' - 11025' R VED - ECEI 11068' - 11140' - DEC OI 9 11227' - 11234' 11255' - 11315 'Al~kB OJJ & GaB Oon~ Anchomge ISOLATION OF HB-3 FROM HB-4 SQZ W/ 80 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET SQZ HB-3 W/ 100 SX CMT. BROKE AROUND TO SURFACE SQZ W/ 151 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET SQZ w/ 150 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET SQZ w/ 90 SX CMT TO ISOLATE BLANK CSG, HAD CIRC AROUND RET RESQZ HB-3 W/ 150 SX CMT. POSSIBLE BREAK TO SURFACE. RESQZ LOWER HB-2 W/ 158 SX CMT. BREAK TO SURFACE. ATTEMPT RESQZ MIDDLE HB-2. NO BREAKDOWN. RESQZ UPPER HB-2 W/ 95 S× CMT. BREAK TO SURFACE. RESQZ LOWER HB-2 W/ 100 SX CMT. BREAK TO SURFACE. RESQZ LOWER HB-2 W/ 200 SX CMT. BREAK TO SURFACE. BOTTOM TO SQZ AGAINST. SQZ PERFS F/ 11364'-11366' W/100 SX CMT TO ISOLATE HB-4 FROM HB-5. TUBING DETAIL - LONG STRING JTS 1 1 1 2 PUP 18 19 20 21 24 25 31 48 54 60 9 PUP PUP X-OVER DESCRIPTION LENGTH 1.02 29.78 1.30 31.52 10.32 30.25 3.40 63.13 3.12 REENTRY GUIDE SHOE 2-7/8",6.4#,N-80,BUTT OTIS X LANDING NIPPLE 2-7/8",6.4#,N-80,BUTT OTIS SEAL ASSY 2-7/8",6.4#,N-80,BUTT OTIS XA SLIDING SLEEVE 2-7/8",6.4#,N-80,BUTT 2-7/8",6.4#,N-80,BUTT BAKER 3.75 x 2.313 BLAST JOINTS 321.20 2-7/8",6.4#,N-80,BUTT 85.33 OTIS XA SLIDING SLEEVE 3.40 2-7/8",6.4#,N-80,BUTT 29.45 BTM DUAL PKR TO CENTER 8.53 CENTER DUAL PKR TO TOP 8.64 2-7/8",6.4~,N-80,BUTT 32.02 OTIS XA SLIDING SLEEVE 3.40 2-7/8",6.4#,N-80,BUTT 30.64 MACCO GLM 6.76 2-7/8",6.4~,N-80,BUTT 563.67 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 594.51 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 612.26 MACCO GLM 6.76 2-7/8",6.4~,N-80,BUTT 650.25 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 746.58 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 778.79 MACCO GLM 6.76 2-7/8",6.4~,N-80,BUTT 962.63 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1468.15 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1629.62 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1835.88 OTIS SSSV X-PROFILE 2.52 2-7/8",6.4#,N-80,BUTT 264.34 2-7/8",6.4#,N-80,BUTT 15.33 2-7/8",6.4~,N-80,BUTT 3.96 2-7/8" x 3-1/2" BUTT 0.42 DUAL SPLIT TBG HANGER 0.80 LANDED BELOW ZERO 42.64 BOTTOM 10936.40 10935.38 10905.60 10904.30 10872.78 10862.46 10832.21 10828.81 10765.68 10762.56 10441.36 10356.03 10352.63 10323.18 10314.65 10306.01 10273.99 10270.59 10239.95 10233.19 9669.52 9662.76 9068.25 9061.49 8449.23 8442.47 7792.22 7785.46 7038.88 7032.12 6253.33 6246.57 5283.94 5277.18 3809'03 3802.27 2172.65 2165.89 330.01 327.49 63.15 47.82 43.86 43.44 42.64 TOP 10935.38 10905.60 10904.30 10872.78 10862.46 10832.21 10828.81 10765.68 10762.56 10441.36 10356.03 10352.63 10323.18 10314.65 10306.01 10273.99 10270.59 10239.95 10233.19 9669.52 9662.76 9068.25 9061.49 8449.23 8442.47 7792.22 7785.46 7038.88 7032.12 6253.33 6246.57 5283.94 5277.18 3809.03 3802.27 2172.65 2165.89 330.01 327.49 63.15 47.82 43.86 43.44 42.64 0.00 RECEIVED DEC20I 9 Alaska Oil & Gas'Cons, AnchOra TUBING DETAIL - SHORT STRING R ¢EIYED DEC201 9 DiI .& Gas Cons, JTS PUP 3 PUP 16 19 21 4 PUP 16 24 25 31 48 54 58 9 PUP PUP X-OVER DESCRIPTION LENGTH REENTRY GUIDE SHOE 0.90 2-7/8",6.4#,N-80,BUTT 4.60 SETTING SLEEVE 1.31 2-7/8",6.4~,N-80,BUTT 27.52 BTM DUAL PKR TO CENTER 9.90 CENTER DUAL PKR TO TOP 6.29 40K SAFETY SHEAR SUB 0.82 2-7/8" 6 4# N-80 BUTT 30 01 · · · · · OTIS "XA" SLEEVE 3.40 2-7/8",6.4#,N-80,BUTT 61.05 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 93.71 2-7/8",6.4#,N-80,BUTT 2.68 2-7/8",6.4#,N-80,BUTT 500.67 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 595.95 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 642.34 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 121.34 2-7/8",6.4#,N-80,BUTT 4.00 2-7/8",6.4#,N-80,BUTT 491.89 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 743.59 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 781.26 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 966.26 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1462.04 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1631.06 MACCO GLM 6.76 2-7/8",6.4#,N-80,BUTT 1772.27 OTIS SSSV X-PROFILE 2.52 2-7/8",6.4#,N-80,BUTT 268.93 2-7/8",6.4#,N-80,BUTT 8.08 2-7/8",6.4#,N-80,BUTT 8.42 2-7/8" x 3-1/2" BUTT 0.42 DUAL SPLIT TBG HANGER 0.80 LANDED BELOW ZERO 42.64 BOTTOM TOP 10358.90 10358.00 10358.00 10353.40 10353.40 10352.09 10352.09 10324.57 10324.57 10314.67 10314.67 10308.38 10308.38 10307.56 10307.56 10277.55 10277.55 10274.15 10274.15 10213.10 10213.10 10206.34 10206.34 10112.63 10112.63 10109.95 10109.95 9609.28 9609.28 9602.52 9602.52 9006.57 9006.57 8999.81 8999.81 8357.47 8357.47 8350.71 8350.71 8229.37 8229.37 8225.37 8225.37 7733.48 7733.48 7726.72 7726.72 6983.13 6983.13 6976.37 6976.37 6195.11 6195.11 6188.35 6188.35 5222.09 5222.09 5215.33 5215.33 3753.29 3753.29 3746.53 3746.53 2115.47 2115.47 2108.71 2108.71 336.44 336~.44 333.92 333.92 64.99 64.99 56.91 56.91 48.49 48.49 48.07 48.07 47.27 47.27 4.63 * 4.63 SHOULD HAVE BEEN 0, COULD NOT FIND MISTAKE IN TALLY 1) DID NOT USE ANY PUPS ON GLM'S, 7' PUP REQ TO PULL STRING 2) TAGGED PERM PKR AT 10867' TM (15' LOW). PERM PKR SET AT 10847' DPM (10844' DIL) 3) STRING WEIGHT BEFORE LANDING: PICKUP=150K SLACKOFF=100K 4) HANGER TOP IS 3-1/2" EUE 8RD PACKER DETAIL DESCRIPTION LENGTH BOTTOM TOP OTIS "BWD" PERMA-DRILL OTIS RDH DUAL HYD PKR LONG STRING SHORT STRING 12.58 17.17 16.19 10859.58 DPM 10323.18 TM 10324.57 TM 10847.00 DPM 10306.01 TM 10308.38 TM RECEIVED DEC20], 9 .Alas~ Oil & Gas Cons, ~o. mmtssl~ ~chorage O~s "J~DI{" Gua~ Rydrau~l.i.c iter. r~evab:te Pecker 16. Lg' .gl' 8.53' ~.38' ~7.17' &O,O00 LIS S~raigh~ Shear Release o£ Packer - Long S~rin$ &O.OOO LIS Release Valve of Sa~tet! Shear .3oink . ' ~ "' BIT RECORD COUNTY FIELD STATE SECTION TOWNSHIP RANGE LOCATION WELL NO. Cook Inlet McArthur River AK G-31 CONTRACTOR RIG NO. OPERATOR TOOLPUSHER Pool Arctic Alaska ~54 Unocal SPUD REACHED T.D. PUMP NO. 1 LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE Size Type O.D. NUMBER O.D. TOOL DRILL JOINTS COLLARS I.D. LENGTH DRAWWOPd~S POWER NO. SIZE MAKE TYPE JET 32nd DEPTH IN SERIAL OUT FEET HOUR FT/HR ACCUM WT. P~P SPM DRLG 1000 ~PUMP OPER- HRS LBS R P M PRESS PUMP ~ ~ MUD DULL. COND. FORMATIONS WT VIS WL ~ ~ G OTHER REMARKS 1 8 1/2" TSA MILL 2 8 1/2" TSA MILL 2RR 8 1/2" TSA MILL ~8 1/2" TSA BLADE MILLS, 1167 1167 5454 MILL PKR SCRAPER RUN CLEAN OUT CLEAN OUT 4 4 I C/0 RETAINER BIT RECORD COUNTY Cook Inlet FIELD McArthur River STATE AK SECTION TOWNSHIP RANGE LOCATION WELL NO. G-31 CONTRACTOR Pool Arctic Alaska SPUD REACHED T.D. RIG NO. #54 PUMP NO. 1 OPERATOR Unocal TOOLPUSHER LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL PIPE TOOL JOINTS .Size Type O.D. NUMBER DRILL COLLARS O.D. I.D. LENGTH DRAWWORKS POWER NO. SIZE MAKE TYPE JET 32nd DEPTH IN SERIAL OUT FEET HOUR FT/HR ACCUM WT. PUMP SPM MUD DULL..COND. DRLG 1000 PUMP OPER- HRS LBS R P M PRESS PUMP ~ ~ WT VIS WL ~ ~ G OTHER BITS 9 8 1/2" SEC. H77SG 16 404340 11524' 6.3 10 8 1/2" SEC. M44N 16 401193 11403' 2.5 11 8 1/2" SEC. M44N 16 401232 1.5 1/2" SEC. M44N .16 401232 1.5 4 4.5 12 8 1/2" HTC J-3 824JG 13 8 1/2" HTC J-2 16 812577 ~ 2 I 4 2 I 3 2 I 3 2 I 6 2 I 4 2 I FORMATIONS REMARKS C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER 13RR8 1/2" HTC J-2 16 812577 4 2 I SCRAPER RUN BIT RECORD COUNTY FIELD STATE SECTION TOWNSHIP RANGE LOCATION WELL NO. Cook Inlet McArthur River AK G-31 CONTRACTOR RIG NO. OPERATOR TOOLPUSHER Pool Arctic Alaska ~54 Unocal SPUD REACHED T.D. PUMP NO. 1 LINER PUMP NO. 2 LINER PUMP POWER TYPE MUD DRILL'PIPE Size Type O.D. NUMBER O.D. TOOL DRILL JOINTS COLLARS I.D. LENGTH DRAWWORKS POWER NO. SIZE MAKE TYPE JET,' 32nd DEPTH IN SERIAL OUT FEET HOUR FT/HR ACCUM WT. PUMP SPM DRLG 1000 PUMP OPER- HRS LBS R P M PRESS PUMP. 1 2 BITS MUD DULL. COND. FORMATIONS WT VIS WL T B G OTHER REMARKS 1 8 1/2" REED HP13G 18 BT4683 11203' 67 5.5 2 8 1/2" REED HP13G 18 BT4696 11201' 2RR 8 1/2" REED HP13G 18 BT4696 11201' 1/2" SMITH DGJ 24 MEl135 11071' 37 12 4 8 1/2" SMITH SDGH 24 LZ2697 1.5 5 8 1/2" SEC. M44NG 24 381831 11067' 81 3 8 2 I 1 1 I 1 1 I 8 8 I 8 4 I 8 2 I 6 8 1/2" SEC. M44NG 16/ 381835 11148' 81 3.5 8 2 I 24/24 7 8 1/2" SEC. H77SG 16 404337 11147' 4 2 I C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER C/O RETAINER 8 8 1/2" SEC. M44NG 16 378462 11203' 7.5 7 3 I C/O RETAINER 47 ~[~ Z 51 ~1~ --6 ~n ~: ~yl~ Platfo~ 52~--7 ~L~: ~31 53 ~ ~ ~ ~ ~ ~--8 ~: 9-5/8" 43.5/47 ~ N-80 54~~~--9 ~: 2-7/8" 6.4 ~ ~ (~) x 2-7/8" 6.4 ~ ~ (~) ~ ~: 431/1030/01/89 ~: ~ 22, 1989 55 10 ~~~: ~~_~, ~ 56 ~~ 11 (907) 283-7531 ~~ I.D. 0.D- 57 12 KoBo 59 ~14 2. C.I.W. Split Tubing Hanger 3. Swage - 3-1/2" ~J x 2-7/8" 60 15 BTC (PxP) 61 16 4. Pup Joint 5. Pup Joint 62 17 6. Nine (9) Joints of Tubin~ 63 18 7. 1/4" Stainless Steel Control Line 0.049" Wall ~hickness 64 19 (P/N 22 SXX 31050) 65 20 8. Otis "XXO" Safety Valve Landing Nipple (P/N 11 X~D 23110) 66 21 10. Macco 1" Gaslift Mandrel 9. Sixty (60) Joints of 67 22 Tubing 68 23 , 11. Fifty-Four (54) Joints of 24 12. Macco 1" Gaslift Mandrel 70 , 13. Fourth-Eight (48) Joints of 77 14. Macco 1" Gaslift Mandrel 15. 16. ~hirty-One (31) Joints of Macco 1" Gaslift Mandrel 17. Twenty-Five (25) Joints of 18. Maoco 1" Gaslift Mandrel 19. TWenty-F~ (24) Joints of T~ 20. Macco 1" Gaslift Mandrel 21. Twenty~ (21) Joints of T~ 22. Ma__~co_ 1" Gaslift Marzlr~l 2.99" 2.44" 3.5" 42.64' -0- .80' 42.64' .42' 43.44' 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" .25" 3.96' 43.86' 15.33' 47.82' 264.34' 63.15' 2.313" 2.44" 3.25" Ecc. 3.85" 2.52' 327.49' 3.5" 1835.88' 330.01' 2.44" 2.44" 2.44" 6.76' 2,165.89' 3.5" 1,629.62' 2,172.65' 6.76' 3,802.27' 3.5"- 1,468.15' 3,809.03' 6.76' 5,277.18' 3.5" 962.63' 5,283.94' 2.44" 2.44" 2.44" 3.5Il 3 · 5II 3 · 5'1 6.76' 6,246.57' 778.79' 6,253.33' 6.76' 7,032.12' 746.58' 7,038.88' 6.76' 7,785.46' 650.25' 7,792.22' 6.76' 5,442.47' 32 --33 34 35 ~X): 431/1030/01/89 September 22, 1989 PAGE2 23. Twenty (20) Joints of 24. Ma~o_ 1" Gaslift Mandrel 25. Ninet~n (19) Joints of 26. Macco 1" Gaslift Mandrel 27. Eighteen (18) Joints of 28. MaoTo__ 1" Gaslift Marzlrel 29. 30. 36 31. 32. One (Z) Joint of Tubing Otis "~A" Slid/ng Side Door O~ns-~/~o~s-D~n (P/N ~1 ~ 17) One (1) Joint of Tubing Packer 9-5/8" 40-47 LB (P/N 12 RE~ 9027) 3-1/2" ~J BxP c~ 'q~[X~' to 2-7/8" BTC BxP (Top of Packer to Center of Element is 8 · 64'/Center of Element to Bottom of Packer is 8.53') 40,000 Lbs Straight Pull 33. 34. --37 35. --38 36. 37. --39 38. --40 39. --41 40. 41. --A 2 --44 --45 one (1) Joint of Tu~in~ Otis "XA" Sliding Side Door (P/N 121 XA 17) ~lree (3) Joints of Tubing Baker Blast Joints - QTY 17 Pup Joint Two (2) Joints of Tubing Otis "XA" Slidin~ Side Door One (1) Joint of Tubing otis Straight Slot Seal a~mbly A. Straight Slot Locator (P/N 212 $ 40000-A) B. Seal Assembly (P/N 212 ~N 40000-A) C. Extensic~ (P/~ 212 x 40000-A) D. (P/N 212 ~N 40~0-A) E. Extensic~ (P/N 212 X 40000-a) · F. Seal Assembly (P/N 212 MSN 40000-A) G. Seal Assembly (P/~ 212 ~N 4~-a) H. ~aptor- 3-1/2" ~J x 2-7/8# BTC BxP I.D. O.D.. ~ EEPTH 2.44" 3.5" 612.26' 8,449.23' 2.44" 3.5" 2.44" 3.5" 6.76' 9,061.49' 594.51' 9,068.25' 6.76' 9,662.76' 563.66' 9,669.52' 6.76' 10,233.18' 2.44" 3.5" 30.64' 10,293.94' 2.313" 3.75" 3.40' 10,270.58' 2.44" 3.5" 32.02' 10,273.98' 2.44" 8.44" 17.17' 10,306.00' 2.44" RECEIVED DEC201 9 Gas.Con G_o.m ls,si chomge!. 2.44" 3.50" 29.45' 10,323.17' 2.313" 3.75" 3.40' 10,352.62' 2.44" 3.50" 85.33' 2.438" 3.75" 321.20' 2.44" 3.50" 3.12' 2 · 44" 3 · 50" 63 · 13 ' 2.313" 3.75" 3.40' 2.44" 3.50" 30.25' 10.32' 2.44" 4.97" (1.32') 2.97" 4.04" (1.0') 2.97" 3.96" (2.0') 2.97" 4.04" (1.0') 2.97" 3.96" (2.0') 2.97" 4.04" (1.0') 2,97" 4.04" (1.0') 2.44" 3.96" (1.0') 10,356.02' 10,441.35' 10,762.55' 10,765.67' 10,828.80' 10,832.20' 10,862.45' 431/lO~O/Ol/89 22, 1989 E~SCRIprTC~ I.D. O.D. 42. Ol%e (1) Joint of Tubil~g 2.44" 3.5" 43. Otis "~' Selective ~ 2.313" 3.25" Nipple (P/N 11 X 23100-A) 44. One (1) Joint of Tubing 2.44" 3.5" 45. Otis Wirel~ P~-E~ 2.44" 3.5" ~i~ (P/N 212 M 3) END OF LONG STRING TUBING TAIL 31.52' 1.30' 29.78' 1.02' PAGE3 10,872.77' 10,904.29' 10,905.59' 10,935.37' ~Q.936.39' ~i$~,:. Reference :!,~ii:,i,i.i:i~ Drawing on ; :.:~::i:i!'ii : Pages 1 & 2 '"~. %;,,:(! ¥,,i:?i 47. :::: ..... .~:-,:. %,::.::.', o " )!?:': ~!:?,:2 40. .... :ill.. 'h,..:: .. :! ' /;" 51. .... ' i '" ::: ~:iii: :'": '!: '¥ :, ....... .?:h.. ' ' DEC2 0 . _ A. Otis "t~IP' Perma-Drill 4.0" 8.12" W/Hydraulic ~ Tool (P/N 212 BWD 95400-A) (P/N 212 C 7060) BO1TC~OFPERMANENTPACKER~~ 55. 56. 4.0" 5.0" * Drill Pipe Measurement. K. B. C.T.W. Split Tubing Pa=er Swage - 3-1/2" P~p Joirfc Pup Joint Nine (9) Joints of Tubing 1/4" Stair~less Steel Control Lil%e 0.049" Wall (WN 22 SXX 31050) Otis "X~0" Safety Valve Landing Nipple (P/N 11 X~D 23110) Fifty-Eight (58) Joints of Maoco '1" Gaslift Mandrel Fifty-Four (54) Joints of Ma~_oeo 1" Gaslift Marzk%l Fourth-Eight (48) Joints of Macco__ 1" Gaslift Mandrel ~:y-One (31) Joints of 2.99" 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" .25" 2.313" 3.25" EcC. 3.85" 2.44" 3 · 5" 2 · 44" 3 · 5" 2.44" 3.5" 2.44" 3 · 5" 4.89' Top of Packer 10,847.0'* 7.70' 10,851.89' 10.859.59' 42.64' -0- .80' 42,64' .42' 43.44' 8.42' 43.86' 8.08' 52.28' 268.93' 60.36' 2.52' 329.29' ' 1772.27' 331.81' 6.76' 2,104.08' 1,631.06' 2,110.84' 6.76' 3,741.90' 1,462.04' 3,748.66' 6.76' 5,210.70' 96~.26' 5,217.46' 61. Mao~o__ 1" GasliftMandrel 6.76' 6,183.72' NO: 431/1030/01/89 September 22, 1989 62. Twenty-Five (25) Joints of 63. Maoco~ 1" Ga,lift Mandrel I.D. O.D. ~ 2.44" 3.5" 781.26' 6.76' 2.44" 3.5" 743.59' 64. Twenty-Four (24) Joints of 65. Maoco~ 1" Gaslift Mandrel 6.76' 491.89 ' 66. 67. 68. 69. Sixteen (16) Joints of ~ Joint Four (4). Joints of Tubing Macco 1" Gaslift Mandrel 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" 4.0' 121.34' 6.76' 642.34' 70. TWenty-One (21) Joints of 71. Ma~co 1" Gaslift ~ 2.44" 3.5" 6.76' 595.95' Reference Drawings on Pages 1 & 2 72. Nineteen (19) Joints of 73. Maoco 1" Gaslift Mandrel 74. Sixteen (16) Joints of 75. Pup Joint 76. ~hree (3) Joints of Tubing 77. Macco~ 1" Ga, lift Mandrel 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" 2.44" 3.5" 6.76' 500.64 ' 2.68' 93.71' 6.76' 78. Two (2) Joint of Tubing 2.44" 3.5" 61.05' 79. otis "XA" Sliding Side Door 2.313" 3.75" 3.40' o~~/~-~ (P/N 21 ~ 17) 80. One (1) Joint of Tubing 2.44" 3.5" 30.01' 81. Otis "SO" Safety Shear Joirfc-Pir~ed for 40000 LB Shear Release (P/N 12 SO 2500) Otis '~EH" CX~l Hydraulic Retrievable (Ref. Item 32 Lo~ Stri~) ~ptors f~ 3-1/2" ~J BxP to 2-7/8" BTC ~xP (~ of T~ of Pack~ to C~-fcer of Elemerfc is 6.29' Center of Element to Bottom of Packer is 9.90') 2. 375" 3 · 62" · 82 ' 2.44" 8 · 44" 16 · 19 ' 83. One (1) Joint of Tubing 2.44" 3.5" 27.52' 84. otis Collet Shear Sub (P/N ~ =m 2500) 2.35" 3.75" 1.31' 85. Pup Joint 86. Otis .me, m~Go Land/rig Nipple W/Wireline m~Emxy ~ide ~ (P/N 11 ~N 23160-A) 2.44" 3.5" 4.60' 2.205" 3.5" .90' PAGE4 6,190.48' 6,971.74' 6,978.50' 7,722.09' 7,728.85' 8,220.74' 8,227.74' 8,346.08' 8,352.84' 8,995.18' 9,001.94' .9,597.89' 9,604.65' 10,105.29' 10,107.97' 10,201.68' 10,208.44' 10,269.49' 10,272.89' 10,302.90' 10,303.72' 10,319.91' 10,347.43' 10,348.74' 10,353.34' ,. .... END OFS~K~g/RINGTJBING~L 10.354.24' Otis "RDH" Dual Hydraulic Retrievable Packer Item #32 Long String - Item #82 Short String 16.19' 3i27 I 1.34' , , t 1.30' .74' .91' j 1.19' - ! 1.38' 8.64' 8.53' 17.17' Center of Packer Set at 10,299' 40,000 LB Straight Shear Release of Packer - Long String 40,000 LB Release Valve of Safety Shear Joint Item #81 Short String of Otis Completion Drawing. RECEIVED DEC201~9 Alaska Oil & Gas Cons. ~mmtssl~q Anchorage UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.T lof2 LEASE Trading Bay Unit State WE LL No.G-31 LS F~E LD MC Arthur River DATE 8/16/88 8/17/88 8/18/88 8/19/88 .. 8/20/88 8/21/88 8/22/88 8/25/88 8/26/88 8/27/88 0064C E.T.D. 11,278 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skid rig to TBUS G-31 LS and rigged up Otis 1-1/4" coiled tubing. Ran in hole with 2.7" mill on 1.75" mud motor and tag scale at 7500'. Cleaned out hard scale from 7500' to tubing tail at 10,926'. Ran in hole and cleaned out 9-5/8" casing to 11,277'. Mud motor stalled out, could not clean out deeper. Circulate clean. Pulled out of hole with coiled tubing. Laid down mud motor and 2.7" flat bottom mill. Make up Otis Hydro-Blast indexing tool and ran in hole cleaning tubing to 4960'. Pulled out of hole and work on. HOWCO pump (fluid end). Ran in hole with same tool and clean tubing to 6200'. Pulled out of hole and repair HOWCO pump. Ran in hole with same and clean to tubing tail at Indexed tool and washed tubing from 10,950'-4,390'. Discovered pin hole leak in coiled tubing. Pulled out of hole. Rigged down Otis and sent coiled tubing unit to Kenai for repairs. Rigged up Myers and ran 2.735" gauge ring - stopped at 5420'. Pulled out of hole. Released rig to G-8S at 1200 hours 8/18/88. Skid~ig to G-31 LS. Rigged up Otis l-l/4" coiled tubing unit and pressure te§.~nit and BORE to 3000 PSI, ok. Ran in hole with Hydro-Blast tool that )i~ded nine jets (.04" each) cleaning the tubing from surface to tubing ~il at 10,926'. Stop pumping to index tool. Pulled out of hole cleaning ;~j~bing, developed pin hole leak at 8530'- ~kig down Otis CTU and offload }o boat or repairs in Kenai. Estimate 24 hours for repair and change out. Rig up Myers wireline. Make up 2.735" gauge ring and pressure test lubricator to 2500 PSI, ok. Ran in hole with gauge ring to 5565'. Unable to pass deeper. Pulled out of hole and rig down Myers wireline. Rig up Otis l-l/4" CTU and make up Hydro-Blast tool with nine jets (.04" each). Ran in hole cleaning tubing to tail at 10,926'. Pulled out of hole. Completed two of three passes. Completed third pass cleaning tubing. Rig up Myers wireline and make up 2.735" gauge ring. Ran in hole to 5592', unable to go deeper, pulled out of hole. Make up 2.625" blind box and ran in hole, slight restriction at 8400'. Continued to tail, no problems. Pulled out of hole and rig down Myers and Otis. Released rig at 1200 hours 8/23/88. Rigged wireline unit and ran in hole with 3" X 2' scratcher. Worked through restrictions at 5450' to 5650' and continued to the tubing tail at 10,926'. Pulled out of hole. Ran in hole with 2.735" swedge to 5588', unable to pass. Pulled out of hole. Rig down wireline unit. Rigged up Otis, tested same to 2000 PSI - ok. Ran in hole with 2.735" flat bottom mill on 2-3/8" mud motor. Had restrictions at 5735' and 6862'. Ran in hole to XA sleeve at 10,864'. Pulled out of hole. Rigged down Otis. Rigged up Myers wireline. Ran in hole with 2.735" swedge. Restrictions at 5857'-5920', 6100', 6200', 6623', 6750'-6810', 6900', 7420' and 8300'. Ran in hole to XA sleeve at 10,864'. Pulled out of hole. Rig down. Rig up Schlumberger wireline unit. Tested lubricator to 2500 PSI - ok. Ran in hole with 2-1/8" flo-jet perf gun (4SPF) to 11,225'. Pulled gun into tubing tail at 10,926' to check depth. (Drillers depth = 11,277' TD). Gun stuck. Pumped 730 bbls water past fish to dislodge - no success. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO.. 2of2 LEASE Trading Bay Unit State G-31 LS Mc Arthur River WELL NO .... FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8/28/88 8/29/88 8/30/88 8131/88 9/1/88 9/2/88 11,278' 11,235' Rigged up clamp on Schlumberger's cable. Pulled 5000#, cable parted. Estimate 9600'-9800' of cable in tubing. Rigged down Schlumberger. Rigged up Myers wireline. Ran in hole with 3/16" line with 1-3/4" spank jars, oil jars, and rope spear to 1250'. Could not locate wire. Pulled out of hole. Ran in hole with a blocked gauge cutter to 1485'. Pulled out of hole. Ran in hole with rope spear. Engaged cable. Pulled in two with 2800# pull. Recovered 3.5' of wire. Reran rope spear twice to lB10'. Pulled cable to surface. Myers unable to pull cable. RD Meyers and RU air tugger. Worked cable. Spotted 4 gal HCL down 3-1/2" tbg. Worked cable. Cable parted. Recovered 1000' of Schlumberger cable. RU Myers. Ran in hole with rope spear-and jars. Engaged cable at 2900'. Pumped FIW thru tubing. Pulled out of hole with entire fish. Disarmed gun and laid down same. Ran in hole with rope spear. Tagged fill at 11,235'. Pulled out of hole. RD Myers. Returned well to production to stabilize prior to perforating. Rigged up Schlumberger. Tested lubricator to 3000 psi - ok. Ran in hole with 2-1/8" flo jet perf gun (4 SRF). Note all zones to be shot twice for required 8 SPF. Perforated the top of the B-4 (ll,211'-ll,218') in two passes. Perforated the bottom B-3 (ll,190'-ll,200') with 1st pass. Perforated the bottom B-3, 2nd pass (11,190'-1%,200') - total 8 SPF. Perforated the top B-3, 2 passes, (ll,153'-ll,190') 8 SRF. Perforated the B-l, 1st pass (10,900'-10,975') 4 SRF. All guns 2-1/8" flo jet 4 SPF 20' in length. Continued perforating using 2-1/8" flo jet, 4 SPF, guns. Completed the B-1 zone (10,975'-10,990') second pass and (10,960'-10,975') 2 passes. Rigged down Schlumberger. Returned well to production for 12 hour flow test prior to SOC job. Shut in well following flow test. Bull headed Solubility Optimization Control (SOC) treatment: 330 gallons S-256 (scale inhibitor), 275 gallons Chem Link (30% by weight CaC12), 220 gallons 15% HCL with no additives, followed by 72 bbls FIW. The treatment was displaced with 300 bbls FIW with 3% KCL. Treatment in place at 0330 hours 9/2/88. Rigged down HOWCO. Shut in well for 24 hour soak. /'-N ~ ["AGE. Ilo, 3 UNION OIL CC iIW' Y 01: CALII:OI<NIA I'ELL I LCOIC) I.~E TRADING BAY UNIT STATE AFE #341420 l~Lk [~[0, G- 31 F IEID McAR.THUR RIVER FIELD DATE 5/1/74 5/2/74 5/3/74 5/4/74 ElD 12,736'TD ll,811'PBTD 12,736'TD 11,811'PBTD 12,736'TD ll,811'PBTD 12,736'TD 11,524'ETD DETAILS OF OPERATIONS, DESCRIpTIOHS g RESUI'TS (Footage 0') Commenced operations on TBUS G-31 @ 12:01 am, 5/1/74. Tested BOPE to UOCO spec. Released SS 3 1/2" tbg. from pkr. @ 10,388'. Pooh'. Laid dwn. 334 jts. of 3 1/2" SS tbg. Unable' to pull LS tbg. & pkrs. RU Gp-Int'l. Ran Free Pt. & tbg. cutter. Top hyd. pkr. @ 10,388'-free. Tbg. free to top of btm. hyd. pkr. @ · 11,581'. Attempted cut 15' above pkr. @ 11,566' w/o success. (Footage 0') Ran Free Pt. & 2 1/2" tbg. cutter. Attempted to cut @ 11,571' w/o success. Repeated cut w/ 2 5/8" cutter @ 1].,576' w/o success. RIH w/ 2 5/8" tbg. cutter and cut tbg. @ 10,312' above dual hyd. pkr. @ 10,333" (corrected tbg. meas.) Pooh & Laid dwn. LS. TIH w/ OS & fishing tools to jar dual pkr. free. (Footage 0') TIH w/ OS & latched onto fish @ 10,306'DPM. Circ. btms. up. Jarred on pkr. & Pooh. Laid dwn. 9 5/8" X 3 1/2" X 3 1/2" Baker Model A-5 dual pkr. & 38 jts. of 3 ]./2" 9.2# N-80 Buttress tbg. Estimated top of LS @ 11,576'. Rigged up Go-Int'l & ran 9 5/8" guage ring & junk basket to 11,524'. Ran Gamma-Ray CBL & Collar 'Log from 11,500' to 10,000'. (Footage 0') Completed running Camm-Ray Log. Ran & set 9 5/8" Howco EZSV ret. @ 11,524'. RIH w/ 5" DP. Broke circ. Stabbed into ret. Press. below ret. to 3500 psi-held 10 rains. No bleed back. Pooh. Rigged up Go-Int'l & reperforated the "G" Zone from 10,610' to 10,635', 10,540' to 10,570' and from ].0,450' to 10,480' w/ 4", 4 hpf DML Densi-Jet XXIII csg. guns. Ran 9 5/8" gauge ring & junk basket to 11,000'. Ran & set Baker 9 5/8" perm. pkr. @ 10,900'DIL. RIG RELEASED FROM AFE #341420 TO AFE #341419 @ 12:01 am, 5/5/74 *Note: Fish still in hole below retainer @ 11,524'. I'A{7, E riO. UNIO[I OIL COHIW'fY OF CALIFOI [ilA I'LLL I LCOI LEASE TRADING BAY UNIT STATE AFE #341419 I' LL NO, 6- 3 FIELD McARTHUR RIVER FIELD DATE 5/5/74 5/6/74 5/7/74 5/8/74 5/9/74 5/10/74 5/11/74 5/]2/74 5/13/7'4 ETD 12,736'TD 11,524'ETD 12,736'TD 11,524'ETD 12,736'TD 11,524'ETD 12,736 'TD 11,524'ETD 12,736'TD 11,524'ETD 12,736'TD 11,524'ETD 12,736'TD 11,524'ETD 12,736"I'D 11,524'ETD 12,736'TD 11,524'ETD DETAILS OF OPERATIONS, DESCRIPTIOHS & RESUI_TS (Footage 0') Commenced operations on TBUS G-31, AFE #341419 @ 12:01 am, 5/5/74. Rigged up & ran dual 3 1/2" tbg. strings. (Footage 0') Completed running dual 3 1/2" strings. Stabbed into perm. pkr. @ 10,900' Spaced out & landed tbg. w/ hyd. pkr. @ 10,324'. Removed BOPE. Installed x-mas tree & tested to 5000 psi-ok. Opened "XA" sleeve @ 10,860' in LS. (Footage 0') Displ. dwn. LS & out annulus w/ diesel @ 2 bbls/min. Opened short string & disp. a total of 730 bbls of diesel. Set "Q" plug in "Q" nipple @ 10,349' in SS. Circ. around annulus. , Attempted to reset plug-unsuccessful. Pooh w/ "Q" plug while pump- ing w/ Howco. Plug coming up w/ 700# line pull @_+ 9900' line pull increase to 900#. Suspect hole in SS tbg. @_+ 9900' (6 its. above btm. GL valve) Cond. invermul to 68#. Displ. diesel w/ invermul. Removed x-mas tree. Installed BOPE & tested to 2000 psi- Ok. (Footage 0') Pulled dual 3 1/2" tbg. strings. Found tbg. collar backed off @ 9900' in short string. Laid dwn. gas lift mandrels & tested to 3000 psi. Checked dual hyd. pkr-ok. Reran dual 3 1/2" tbg. strings. (Footage 0') Reran 3 1/2" dual tbg. w/ Baker 3 1/2" seal assy. & Baker dual 9 5/8" X 3 1/2" X 3 1/2" pkr. mule shoe LS @ 10,933'. Perm. pkr. @ 10,900'DIL meas. Dual pkr. top @ 10,323'. Landed on dual 3 1/2" Buttress btm. X 3 1/2" EUE top tbg. hanger. Rigged up North Star. .Ran "Q" plug & landed in "Q" nipple @ 10,349' SS. Set Baker dual pkr. @ 10,323' w/ 2100 psi. Pulled "Q" plug up-test between pkr. for annulus leak. Ail test ok. Pulled "Q" plug. Rigged dwn. North Star. Set pkr. w/ invermul still in hole. Removed BOPE. (Footage 0') Completed installing x-mas tree. RU WL unit. Opened "XA" sleeve in SS @ 10,290'. Displ. annulus between pkrs., annulus above pkrs. & tbg. w/ diesel. RU WL unit & closed "XA" sleeve in SS @ 10,290'. Press. LS to 1000 psi to test SS sleeve. Pulled dummy valve in LS. (Footage 0') Closed "XA" sleeve in LS @ 10,683'. Press. LS to 1000 psi. RU Go-Int'l & perf. Hemlock Bench #4 w/ Bi-Wire Densi Jet @ 2 hpf from 11,285' to 11,315'. ([,'ootage 0') P, igged up to rel)(~.f. I~,~'ncl, Il4. (Footage 0') RIH w,/ 2 1/8" Tornado Jet Bi-Wire Gun, 4 hpf & reperforated Hemlock Bench #4 from 11,285' to 1].,315'DII,. Ilad immediate 500 psi increase on tbg. press. Reran 2 1/8" Bi-Wire gun to below Bench #4 perfs. Flowed well for 1 ]/2 hrs. & perf. Bench #4 from 11,255' to 11,285' w/ 4 hpf. Started gas lifting well. RD WL unit. Skidded rig over G-8 while gas lifting G-31. ,.,., - 8 9F5 UNION OIL. C[ItPANY OI: CALIFORNIA t' LLL I LCOI LEASE TRADING BAY UNIT STATE AFE #341419 B~TE ETD I'£LL NO, FIELD McARTt-IUR RIVER FIEIJ) 5/14/74 5/15/74 5/16/74 12,736'TD 11,524'ETD 12,736 'TD 11,524'ETD 12,736'TD 11,524'ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESUI_T$ (Footage 0') Continued production test of Hemlock Bench #4. GROSS NET CUT FM. GAS GOR GLR TBG. CSG. GRAVIT'~ 925 924 0.1% 85 63 843 200 1000 34.20 904 903 0.1% 124 137 906 180 1000 34.20 966 965 0.1% 163 168 888 200 1000 34.20 1057 1056 0.1% 267 253 910 200 1000 34.20 966 965 0.1% 242 251 970 200 1000- 34.20 PerfOrmed WL work on TBus G-1 & TBUS G-8 while gas lifting G-31. (Footage 0') Ran flowing gradient survey & 10 hr. static btm. hole build-up. Rigged dwn. North Star. Skidded rig from G-1 to G-31. RU Go-Int'l. RIH w/ 2 1/8" Tornado Bi-Wire Jet & perf. Bench #3 from 11,160' to 11,190' @ 4 hpf. while gas lifting well. (Footage 0') Perforated w/ 2 1/8" Tornado Bi-Wire gun w/ 4 hpf as follows: Hemlock Bench #1 from 10,966' to 10,986', Hemlock Bench #2 from 11,015' to 11,025', 11,042' to 11,057' & from 11,080' to 11,110'. Put well on production test. RELEASED RIG FROM TBUS G-31 TO TBUS G-4 12:00 MIDNITE,5/16/74 PAGE UNICq OIL COHP OF CALIFOPd"IIA IfCOt{D LEASE TRADII~G BAY UNIT STATE WELL NO, G-B FIELD McARTHUR RIVER .FIELD BATE ETD JTS. 4 9 13 14 15 4 10 11 30 . .17 33 24 31 331 Jts DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS TUBING DETAIL SHORT STRING DESCRIPTION LENGTH 3 1/2" Q Nipple .. 1.35 3 1/2" 9.60# Buttress Pup Sub' .10.'20 Baker 9 5/8" X 3-1/2" X 3 1/2" Dual Pkr ........... 13_.70- BOTTOM 10,349.15 10,347.80 10,337.60 TOP 10,347.~0 10,337 60. 10,323.90 3 1/2" 9.60# Buttress. Tbg. 29.31 .......... 10,3-2%:98''- Otis "XA" Sleeve ........ 4.54_- -. ...... 1.0,;"29'4.59 3 1/2" 9.60# Buttress Tbg:. ~ _ 124.4-3- 10,290.05 3 1/2" 9.60# Buttress Pup Sub ......... 8.-13 - 10~ t-65v6-2-- 3 1/2" 9.60# Buttress Tbg.--c~': .- -' 91.35 10,157.49 3 1/2" Camco Mandrel'#7 .... 6.60 ....... 10,066.14 3 1/2" 9.60# Buttress -T-bg.~_- 273.92 10,059.54 3 1/2" 9.60# Buttress.Pup Sub. ..... 8.'12' 9,785.62 31/2" 9.60# Buttress Tbg. 396.22 9,777.50 3 1/2" 9.60# Buttress"Pup Sub'; 9.13 9,381.28 3 1/2" 9.60#. Buttress Tbg. _r3~ 'c -'~423,58-'- --9,372.15 3 .1/2" Camco Mandrel #6 6.60 8,948.57 3 1/2" 9.60# Buttress.Tbg, 450.64 8,941.97 3 1/2" 9.60# Buttress Pup Sub. 8.12 8,491.33 3 1/2" 9.60# But'tress~Tbg%-~'-- ' 336.90 8,48,3.21 10,294.59-." 10,290.05. 10,'165.6~ 10,157.49 1'0,066.14 10,059.54 9,785.62 ' 9,777.50 9,381.28 9,372.15 .8,948.57 8,941.97 8,491.33- 8,483.21 8,146.31 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" 9.60# Buttress Tbg. - 119.54 8,138.20: 3 1/2" 9..60# Buttress Pup Sub. 2.12 8,01'8;66- 3 1/2" 9.60#~"Buttress Tbg .......... 306._76 ........ 8~016.'54 3 1/2" Camco Mandrel #5 6.60 7,709'.78 3 1/2" 9.60# Buttress Tbg. - .... 337.1Z ..... ~ ...... :.-.71,~7D~3_.I8 8.11 8,-I-46 . 31 ......... 8,138.20 -;:~8;, 018.66 .- 8,016.54 7,709.78 7,703-;:I8. 7,366.06 3_1/2" 9.60# Buttress Pup Sub 8.12 3 1/2" 9.60# Buttress Tbg. 923.67 3 1/2" Camco Mandrel #4 6.60 3 1/2" 9.60# Buttress Tbg. 313.22 3 1/-2" 9.60# Buttress Pup%ub, ~ 10.20 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #3 3 1/2" 9.60# Bfittress Tbg. 3 1/2" Camco Mandrel #2 3 1/2,' 9.60# Buttress Tbg. 3 1/2" 9.60'# Buttress Pup Sub. 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #1 3 1/2" 9.60# Buttress Tbg. 3 1/2" 9.60# Buttress Pup Sub . 3 1/2" 9.60# Buttress Tbg. 3 1/2" Otis Ball Valve 3 1/2" .9.60# Buttress Tbg.. 3 1/2" 9.60# Buttress Pup Sub 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" 9.60# Buttress Pup Sub. 7,366.06 ' 7,35~7;94 7,357.9R 6',-4F~.2-7 '6,434.27 6~..427_,67 6',427.67 6,114.45 --6,114.45 6,104%25 1018.42 6,104.25 5,085}83 6.60 -5,085~83 5.,079;23 1544.81 5,079.23 3,534..42 6.60 '3,534.42 3,.527.82 515.36 3,527.82 3,012.46 3.12 3,012.46 3,009.34 1011.18 3,009.34 1,998.16 6.60 1,998.16 1,991.56 736.28 1,991.~6 1,255.28 4.13 1,255.28 1,251.15- 947.10 1,251.15 304.05 4.48 304.05 299.57 239.56 299'.57 60.01 8.00 60.OJ 52.01 8.51 52.01 43.50 3.90 43,50 39.60 Cameron 3 1/2" Buttress split tbg. hgr ........ _1~.00, 39160 Landed 38.60' below 0 Total of Buttress N-80 Tbg. . 38.60 -0- I'AGE Ih, ? UNION OIL C(ItPANY OF CALIFORNIA I, tLL IILCOI D LEASE TRADING BAY UNIT STATE I[LL NO, G-3 FIELD McARTHUR RIVER FIELD DATE ElD DETAILS OF OPERATIONS, DESCRIPTIOItS & RESUI.TS JTS. 17 13 13 13 13 13 12 14 14 14 15 2O 3O 33 36 52 TUBING DETAIL LONG STRING DESCRIPTION Mule Shoe 3 1/2" Q Nipple 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" Baker #47 Seal Assy. 3 1/2" Buttress Locator Sub #47 3 1,/2" 9.60# Buttress Tbg. Otis "XA" Sleeve 3 1/2" 9.60# Buttress Tbg. Baker 9 5/8" X 3 1/2" X 3 1/2" Dual Pkr. 3 1/2, 9.60# Buttress Tbg. Otis "XA" Sleeve 3 1.2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #16 3 1/2" 9.60# Buttress Tbg. 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" Buttress Tbg. 3 1/2" Camco Mandrel #15 3 1/2" 9.60# Buttress Tbg. 3 ]/2" Camco Mandrel #14 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #13 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #12 3 1/2" 9.60# Buttress Tbg. 3 1/2" 9.60# Buttress Pup Sub. 3 1'/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #11 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandfel #10 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #9 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #8 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #7 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #6 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" 9.60# Buttress Tbg. 3 ].,/2"Camco Mandrel #5 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #4 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #3 3 1/2" 9.60# Buttresg Tbg. 3 1/2" Camco Mandrel #2 3 1/2" 9.60# Buttress Tbg. 3 1/2" Camco Mandrel #1 3 1/2" 9.60# Buttress Tbg. LENGTH BOTTOM 93 1 35 10 1.6 21 06 1 00 30 54 4 54 526 32 13 70 29 54 4 54 120 92 6 45 89 95 10 20 275 31 6.73 401.06 6.60 394.44 6.60 389.60 6.60 29.80 4.23 391.18 6.60 394.68 6.60 373.37 6.60 423.34 6.60 430.96 6.60 433.75 6 60 4 25 460 78 6 60 623 17 6 60 915 39 6 60 1013 55 6.60 1102.69 6.60 1594.17 10,933.'50 ].0,932.57 10,931.22 10,921.06 10,900;00 10,899.00 10,868.46 10,863.92 10,337 60 ] 0,323 90 10,294 36 10,289 82 10,168 90 10,162 45 10,072 50 10,062 30 9,786 99 9,780 26 9,379 20 · 9,372 60 8,978 ].6 8,97i 56 8,581.96 8,575.36 8,545.56 8,541.33 8,150.15 8,143.55 7,748.87 7,742.27 7,368.90 7,362.30 6,938.96 6,932.36 6,501~40 6,494.80 6,061.05 6,054 45 6, O5O 2O 5,589 42 5,582 82 4,959 65 4,953 05 '4,037 66 4,031 06 3,017 51 3,010 91 1,908.22 1,901.62 TOP 10,932 57 10,931 22 10,921 06 10,900 00 10,899 00 10,868 46 10,863 92 10,337.60 10,323.90 ] 0,294.36 ]0,289.82 10,1.68.90 10,162.45 10,072.50 10,062 30 9,786 99 9,780 26 9,379 20 9,372 60 8,978 16 8,971.56 8,581.96 8,575.36 8,545.56 8,541.33 8,150.15 8,143.55 7,748.87 7,742.27 7,368.90 · 7,362.30 6,938.96 6,932.36 6,501..40 6,494 80 6,061 05 6,054 45 6, O5O 2O 5,589 42 5,582 82 4,959 65 4,953 05 4,037 66 4,031 06 3,017 51 3,010 91 1,908.22 1,901.62 307.45 LEASE UNIOI1 OIL C(]','PAI'~ OF CALIFORNIA lfLL t~LCOI~ TRADING BAY UNIT STATE ~_LL NO, G-31 FIELD McARTHUR RIVER FIELD DATE ETD JTS. 349 Jts. DETAILS OF OPERATIONS, DESCRIPTIOHS g RESULTS TUBING DETAIL LONG STRING CONT... DESCRIPTION LENGTH BOTTOM Otis Ball Valve 3 1/2" 9.60# Buttress Tbg. 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" 9.60# Buttress PVP Sub. 3 1/2" 9.60# Buttress Pup Sub. 3 1/2" Cameron split dual tbg. hgt. Landed 38.60' below 0 TOP ].00 39.60 38.60 38.60 38.60 -0- Total of Buttress N-80 Tbg. (used). 4.48 307.45 302.97 244.70 302.97 58.27 8.18 58.27 50.09 2.00 50.09 48.09 8.49 48.09 39.60 above ixlSL) 1.iT Tbg. I im~,,cr ~IJBING I)^TA SS - 5 1/2" 9.24' N-80 Buttre:;s tl)g to 10,549'. LS - 5 1/2" 9.2tt N-80 guttress tbg to 10,934'. 21.JBI;JG ACCI.iSSORIES' (Short Stringl A. Otis 3 1/2" Ball Valve-300' qq2 ' B. 3 1/2" Crone@ Handrel Itl-i, C. 5 1/2" Crone@ ~lm~drel #2--3,52a'. D. 3 1/2" Camco .~landrel #3-5,079'. E. 5 1/2" Crone@ Handrel #4-6,428'. F. 3 1/2" Cml'tee Mandrel tt5-7,703'. G. 3 1/2" Camco ?,landrel #6-8,942' II. 3 1/2" Crone@ Handrel #7-10,060[. I. Otis "XA" sleeve 3 1/2"-10,291'. J. Baker 9 5/8" X 3 1/2't I~al pkr. @ 10,324'. K. 3 1/2" "Q" Nipple @ 10,348!'. TUBING ACCliSSORI1;S' (l,ong S'tring) 19 13 ~/8" csg. @ 5222'. ~IJBI?~G AC(,I:Sc, O,.IJ:S' (I,on.p S!:rJng) COTll;.. 22. 3' 1/2" P, aker /147 sen]. assy ;,,O, 900" . 23. Baker 9 5/8" peru. pkr. @ 10,9g0' . 24. 3 1/2" "O" Nipple-10,931'. 25. ~.!u. le shoe ~ 10,933'. 26. I~owco ]!ZSV ret. @ 11,52~'. 1. ()tis ball w~lve - 305' 2. 3 1/2" Gr,.con' Mandrel #1-1,902'. 5. 5 1/2" Crone@ );Iandrel #2-5,011'. 4. 3 1/2" C~m~co blandrel #3-4,051'. S. 3 1/2" Cmnco Han.drel #4-4,953'. 6. 3 1/2" C~.unco }..Iandrel ~t5-5,583'. 7. 3 1./2" (.:a~0co ~,Iandrel #6- 6,054'. 8. 3 1/2" Camac@ t, hndrel ~t7-6,75' J 9. 3 1/2" Cmnco Handre1 10. 3 1/2" Crone@ ~,Im~drel t19-71362, . 11. 3 1/2" Car,~co Hm~drel #10-7,792' . 12. 3 1/2" Camco bkmdrel'l,~ll- 8,144'. 13. 5 1/2" Cmnco ~..I~d.rel '#12-8,575'. 14. 3 1/2" Cmaco '~..'Iandrel #1.3-8,971'. 15. 3.1/2" Cmnco t. landrel #14-9',372'. 16. 3' 1/2" C~co ~,.bndrel tt~.~-u,~o (~ '"0' · 17. 3 1/2" C~co ~.'Im~dre! ~t16-10,162': 18. Otis "XA" sleeve - 19. Baker 9 5/8" X 3 1/2"-Dual pkr. @ 10,324 '. 20. Otis "XA" sleeve - 10,864'. 21. Locator sub Baker tl47 3 1/2" Buttress --'10,899'. I I'~I~LL SU-IDIATIC 23 l" liner-top @ 11,595'. 9 5/8" csg. @ 11,667'. 7" liner @ 12,72a' Trading Bay Unit State G-31 Work@vet AFI'i tt'3,11420 & #341419 UNION OIL COM?AN¥ OF CALI[-ORNIA l SCALE D&TE UNION OIL CO. (DF CALIFORNIA DRILLING RECORD .. _ LEAS~. Trading Bay ..Unit State SHEET D 5 PAGE NO ' ~ V~LL NO.. G-31 FIELD McArthur River' Field DATE E.T. ~. - . DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ' 7~20~69 21. 22 23 24 25 26 27- 28' 29 30 31 811169 _ 530.' 867' 1936' 2511' 3475' 3887' _ 4878' 5219' 5219' 5219' 5235' corrected 5235' Moved rig over Conductor //38. //38. PU drlg assem. RIH CO 10' of' fill in Rigged Up' over Conductro · conductor (358'-368.'), Drld 15" hole to 530'. Opened 15" hole to 22" hole to 525',, Ran & cmtd 13 j ts 17-3/4" csg. Stabbed into duplex shoe' @ 520'. Cmtd w/650 sx Class "G" mixed w/Inlet wtr followed w/140 sx "G" w/4/~ NaCI? added~' Cmt returns to surface. Dumped 18 ft3 on top of shoe. CIP @ 11~.00 PM 7/21/69.-WOC. WOC 3 hrs. Released & cut off csg. Welded on 20" flange. Instld 20" ttydril. PU DA. Tagg6d top cmt @ 513'. Tested csg & Hydril w/800 psi 10 mins OK. Drld out shoe & cmt. D & S 12-1/4" hole to 867'.. All surveys taken w/Sperry Sun Gyro. .. Drid & gyro from 867' to 1572'. Oriented DDrl w/Gyro. DDrld from 1572' ~o 1936' . Cont' DDrlg to 2062'. Laid down DDrl. RIH w/building assem. Drld & surveyed 12-1/4". hole from 2062' :o 2284'. DDrld 12-1/4" hole from-2284' ~o 2411'. PO~i, to pick up building assem. Rill, Drld 2411 to 2511'. D & S 12-1/4" hole 2511 to 2956'. Prep to run DDrl @ 2956' ~o counteract left turn tendency. D & S to 3475'. DOrld & surveyed 12-1/4" hole from 3475 to 3483'. DDrl failed @ 3483'. DDr!d w/new tool from 3483' to 3562'. Drld 12-1/4" hole (locked in) from 3562' to 3887'. POH for bit chng. , , Drld & surveyed 12-1/4" hole from 3887' to 4878'. · Drld & surveyed 12-1/4" hole from 4878 to 5219'. Opened 12-1/4" hole to 17" hole from 496! to 1830'. Opened hole to 17" from 1830' ~o 3062'.. Opened hole to 17" from 3062' to 4410'. Opened 12-1/4" hole to' 17" from 4410 to 5235' (corrected depth). While Rigging to run 13-3/8" csg, a sledge hammer was dropped into ,hole. RIH w/17" tiO, chased hammer to btm. RU & commenced rng' 13-3'/8" csg. Ran & cmtd 136 j tS.l~-3/8" 61// csg. (See Casing Detail). Cemented thru shoe @ 5222' w/20~0 sx "B-J" mix followed by 500 sx Class "G" Neat cmt. Preceded gmt w/100 ft wtr. DisPlaced w/4455 ftJ mud. Good cmt returns to surface. Bumped plug w/2000 psi. Floats held OK.--C.IP 10:15 ara 8/1/69. WOC 6 hrs. Cut off 13~3/~'' csg. Welded on' 13-3/8" "KD". head. · . .... ' ~' '~ 13'3/8" Casing Detail · ' Descrip~ip~ Len~ ° 13-3/8" Baker FleXiflow shoe 1.77 1 j t 13-3/8" 61# j255 seal lock csg 38.48 13-3/8" Baker fle~iflow collar 1.8,8 135 j ts 13-3/8" 61# J-55 seal 10ck casing' 5141.37 Landed Below Zero 39.00 Tpp 5220.73 5182.25 5180.37 39.OO Bottom. 5222.50 UNION OIL CO..OF CALIFORNIA - . · DRILLING RECORD LEASE Trading Boy Unit State SHEET D PAge NO. 6 , "' ~ ' %tZELL NO, G-31 FIELD, McArthur River' Field DATE 8/2/69 4 7 .10: 11 12 13 14 15 .16 17 18 19 · 20 21 2'2". · 23 - . 24 25 26 27 E. T. D. 5238 5489' 6493' 7115 7393 7804' 7980' 8477 8654' 9028' 9418' 9784' 9831' 10007' 10153' 10204' 10356' 10512' i0685" I0942' · . 11232' !1386' 11536' 11659' 11667' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Completeff welding on lower csg head. Tstd head w/3000 psi'OK. NU riser & BOP's. Tested blind rams w/2100 psi Ok. PU da. RIH. Drld FC @ 5180'. Tagged shoe @ 5220'. Tstd pipe rants w/2000 psi. OK. Tstd Hydril w/1500 psi OK. Drld shoe. CO to 5235'. Found sledge hammer on bottom. POH. Rill with 11-1/8" Globe junk basket. Cored'5235' to 5237'. No 'recovery. Reran baSket. Slipped over. core. Cored one more foot to 5238'. · POil'.w/junk basket'. Rec 2' of core.(No Hammer). ,RIH w/da. No indications of junk on btm. D & S 12-1/4" hole from 5238 to 5941. PU DDrl to attempt to correct direction deviation. DDrld to 6171. D & S 12-1/4" hole to 6493'/ D & S to 7115'. PU DDrl to turn direction. D & S 12-1/4" hole to 7393'. D & S 12-1/4" hole to 7804'. D & S 12-1/4" hole to 7980'. D & S 12-1/4" hole to 8477'. D & S 12-1/4" hole to 8654'. Ran Globe basket for slip pin. D & S 12-1/4" hole to 9028'. D & S 12-1/4" hole to 9418'. · D & S 12-1/4" hole to 9784'. PU ODrl to turn ~irection. POH w/DDrl washout. Dov~ 8 hrs for electric rpr. RIH w/DDrl. POH w/DDrl. D& S 12-1/4" hole to 10007'. D & S 12-1/4" hole to 10153'. Down for rprs to rotary 4-1/2 hrs. Dbrld & surveyed 12-1/4" hole from 10,153' to 10,204' to counteract excessive right turn. D & S to 10356'. D & S to.10512'. D & S to 10685'. D &'S to 10947~ D & S to 1107 D & S to-11232 D & S.to 11386'. D &S To 1t536'. D & S to 11659'. Schlum ran DIL 11660' - 522.6'. UNION OIL CO. OF: CALIFORNIA - DRILLING RECORD : LEASE .Trading Bay unit State V~ELL NO. G-31 SHEET D PA~E NO., , 7 , FIELD. mcArthur River-Field DATE E.T.D. . '8/28/69 . 29 3O 31 9/1/69 3 4 11667' 11667' 11667' 11779' 11908' 12055' 12265' 12362' 12562' 12736' 12736' 12736' .'t2'736' · 1273'6 DETAILS OF OPERATIONS, DESCRIPTIONS 8: RESULTS Schlum ran CF Density.ti669' ' 5226', & sonic caliper 1t612" - 5226'. J.C. 1i:00 pm 8/28/69. · . . . ConditiOned hole for casing. Ran & cmtd 282 its (11628') 9-5/8". 43.5# & 47# N~80 & P-il0 buttress new .csg @ 11667" w/1600 sx Class "G" W/l% CFR-2 mixed @ 117# / ft3 with Inlet wtr. CIp 11:30 am. ~/.30/~.9. 'Instid Cameron DCB 12" 3000# x 10~' 5000# tbg -spooi. NU riser & BOP. 9-5/8" Casing Detail DeS. criPtion Howco Float Shoe 1 jt 9-5/8" 47# P-110 butt.csg. Howco Side Fill Diff. Collar 141 jts 9-5/8" 47# p-110 csg. 138 jts 9-5/8" 43.5# N-80 csg. Len~ Top Bottom 2.00 11665.53 11667.53 42.50 11623.03 11665.53 2.10 11620.93 11623.03 5783.52 5837.41 11620.93 5717.17 120.24 5837.41 35.00 120.24 -0- 34.47 2 its 9-5/8" 47# P-il0 butt. csg. 85.24 Landing wt. below RT. 34.47 28.2 jts 9-5/8" 43.5# & 47# P-il0 & N-80 buttress csg. 11667.00 N~ & tstd BOP's & csg w/2000#. RIii to float collar. Drld collar, cmt & shoe. Trpd for new bit. . D & S 8-1/2" hole to 11908'. Rig down 7 hfs for rprs. 8 hrs rig rprs. D & S 8-1/2!' hole to 12055'. D & S 8-1/2" hole to' 12265'. O &'S 8-1/2" hole to 123~2'. D & S 8~1/2'! hole to' 12562'. Drld to 1~736. Schlum ran DIL 12739' - 11661'. Rill w/GR Density & stuck tool @ 12028'. · .. Cut & stripped in over Schlum wireline w/Bowen-Schlumberger overshot. Found tool @ 12~28,,' worked over & rec all of tool. Rib w/Da, & conditioned for logs. POH. · Schlum ran GE sonic, GR Density & sidewall samples. Rec 24 of 29 shots, cpn~itioned h'OlgfOr lnri PO. Ran 26 ~ts 7" 29# N-80 csg on TIW lnr hngr. · . .Hung. w/shoe @ 12,728; w/top'hngr-@.ll,595'. Cmtd w/300 sx "G" w/l% CFR-2 (100% excess slurry). Bumped plugs w/3200#, floats held OK. CIP 11:00 am 9/10/69. Set pack off on lnr hngr.-POll. ._ ' -... ~ ~_ ' _ .,: ~ . - UNION OIL CO. DF'"CALIFORNIA · '~" .... ' ' DRILLING RECORD · -. . - ~LEASE~ Trading 'Bay unit State" ' ' WELL NO.G-31 DATE E.T.D. 9/10/69 11 12637' 12637' 13 '12637' 14 12637' 1263~' SHEET D PAGE NO. 8 FIELDMcArthur River Field · -- DETAILS OF OPERA~:IONS. DESCRIPTIONS & RESULTS "- 7"' Liner Detail De s c~r_ip t ion Baker Model "G" Shoe 1 jt 7" 29# N80 8 rd lt&c Baker Model""G" Float Collar 1.jr 7" 29~/ ~80 8 rd LT&C · TIW Landing Collar 5 j ts 7" 29i/ NS.p" 8rd LT&C 1 j t 7" 29i/ NS0 8rdl>l"butt. XO 18 its 7" 297/ NS0- buttress TIW iiydro'Hanger w/53 pkr Total 26 its -' - Le,n~th Top Bo t tom 2.40 12726.17' 12728.57' 41.27 '12684.90 12726.17 1.80 12683,10 12684.90 44;70 12638.40 12683.10 .90 12637.50 12638.40 · 218.80 12418.70 12637.50 41.95 12376.75 12418.70 757.40 lf619,35 12376.75 24.35 11595.00 11619.35 1133.57 RIH w/ 8-1/2" bit & 9-5/8" csg scraper. Tagged soft cmt @ 11,147';· drld 450' soft c~t to liner top @ .11,597'. Circ & cond mud. Trpd for 6" bit & 7" csg scraper. CO to E/D @ 12637'. POH. RU Schlum & ran GR & CBL from 12616' - 9000'. Perfd 12100' - 12101' with 4 jets / ft for squeeze #1. Made up Baker 7"-Retreivamatic squeeze tool. RIH & set @ 11890'. Pumped into perfs w/1200# &circ thru lnr lap @ 3 bbls/min. P0t{ w/sqz tool. KI~ w/Baker Hodel "K" retainer & set @ 12,070'. Sqzd 55 sx Class "G" w/l% CFR-2 into perfs. Final press 100#. POH. PU 8-1/2" bit & 9-5/8" csg scrpr & RIH to top of lnr @ 11597'. No cmt above lnr. Tested lap w/2700#. POi{ & PU 6" bit & 7" scraper. KIH to soft cmt @ 11,846'. Drld streaky cmt to top of retainer @ 12,072'. Drld retainer & 30' hard cmt. RIti to float @ 12,637'. Ci3c .& conditioned. POt[. RU Schlum & reperfd 12100' - 12101' for squeeze #2 w/4 jets. POH & PU 7" Baker retrivamatic squeeze tool. RIli'& set @ 11890'. Broke do~,m perfs w/3600#, t£eld 1800~? w/pumps off. Mixed 150 sx Class-"G" w/l% CFR-2. Sqzd 115 sx into perfs, left 3~) sx in csg, reversed .5 sx. Max & final press 4700#. Job completed 5:00 pm 9/13/69. Backed off dp @ 7200' while attempting to release squeeze tool. Screwed back into pipe & pulled tool free. POH. Perfd 118~0' - 11871' w/4 jets for squeeze ~/3~ RIH w/sqz tool & set. @ 11670'. B.D. formation w/4400J~, held 3000# w/pumps off. biixed 100 sx Class "G" w/l% CFR-2. Sqzd 75 sx into f-ormation & left 25 sx in csg. Reversed no sx, max & final press 5000f/. POll, perfd 10910'-10911' w/4' jets for squeeze #4 Made UP Baker 'full bore squeeze tool & RIH to 10,800'. Unable tO set seal segment and unable to release top slips. Worked free & POH. . i~[ade up .Baker retrivamatic squeeze tool & RIH to 10807'.. B.D. formation w/4000#. Held 3200#. w/pumps off. Mixed 100 sx Class "G" w/l% CFR-2. Sqzd 85 sx into perfs. Left .15 sx in. cs~. Had 4900# standing press for 15 minutes, bled to 0~/ w/no flow back,attempted to test w/4900#. Press began increasing on annulus from 1000# to 2100#. Reversed dp clean. Job- complete @ 6.:30 am 9/15/69.. Apparent tool failure.·.. POH w/sqz tool. · ; LEASE Trading Bay Unit State DATE E.T.D. 9/i6/69~ t-~ i7 12637' 18 11811 19 11811 20 11811 UNION OIL CO. (DF'CALIFORNia DRILLING RECORD SHEET D PAGE NO. 9 IYELL NO. G-31. .FIELD. McArthur River Field o DETAILS OF OPERATIONS. DESCRIPTIONS 8: RESULTS 'Drld hard Cmt 10840'~ to 11274'-, 11662' to 11875' & 1188'2~ to 12130' Circ & WOC. _ perfd 12021' - lJ045' & run DST #1 w/pkr @ 11903' & tail pipe @ 11921'. Ran dp dry & pressd to 950# w/gas'before'opening tool. Press inc 1225~ during IF 15 min w/dp shut in @ surface. Closed ih 90 min, 5 hr. FF had fluid to surface in2 hrs, headed & surged 1 hr & flowed at stabilized rate of 33 B~H for 2 hrs. Stabilized. rate 792 5PD, 1% oil, 1-1/2% solids, 97-1/2% wtr, salinity 18,000 .ppm sodium chloride. Closed tool for 5 hrs FSI. Outside Iii 5112 IF1 ~881 FF1 3322 ICIP 4562 IF2 3322 FF2 4452 FCIP 4562 FH 5085 Inside IH 5103 330~ ICCP 4548 IF2 330~ FF2 4438 FCIP 4548 FtL 5075 Schlumberger set CIPB @ 11,811'.. Ran in w/oedp. Spotted 175 bbls 75# Invermul 11811'-9400', Schlum perfd 11738'-11723'; 11706'-11696'; 11688'-11678'; 10728'-10708'; 10636'-10592'; 10570'-10540'; 10484'-10448'. Layed do~ Old string of Grade "G" dp. RU to run tbg. Ran & landed 344 jts 3-1/2" buttress N-80 tbg @ 11522' w/Baker "F-H" ~iydro set pkr @ 11,580' & Baker "A-5" dual pkr @ 10,332'. R.& L 304 jts 3-1/2" buttress N-80 tbg @ 10,332'. Rnvd riser &' BOP. NU tree & tstd 5000#. Otis tested ball valves & fittings 5000#. Pull ball valves & drop setting balls. Chased long String ball do~ W/Otis wireline, set ~ottom pkr. Set top pkr. Open btm two circ sleeves on long string. Displaced diesel do~ annulus and out'long string. Shut in long string and displaced do~ annulus and out short string. RIH w/Otis wireline and closed circ sleeves. RIG RELEASED @ 12:00 Midnight 9/20/69. .- (See Long String Tubing Detail and Short String Tubing Detail Attached). UNION OIL CO. OF' CALIFOrNiA SHEET D DRILLING RECORD PAGE NO. 10 · . LEASE Trading .Bay Unit State DATE E.T.D. . . IYELL NO. G-31 FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS 8: RESULTS .. ..-. - . .-.. .L. ong Stri.ng i%Uib,i~n Description ' ~ Baker Hydro T~ip Sub 1 jt 3-1/2'"'~buttress tbg. 9.2# N-80 Otis "X" Landing Nipple ' ' Baker 9-5/8" Single tiydro set pkr 1 jt 3-i/2" buttress tbg 9.2# N'80 Otis "XO" SLeeve 39 its 3-1/2" buttress tbg 9.2#'N-80 Baker 9-5/8" dual hydro-set pkr 1 jt 3-1/2" bhttress tbg 9.2# N-80 Otis type "XO" sleeve 78 jts 3-1/2" buttress tbg 9.2# N-80 Otis Type CX g~l. mandrel 15 its 3-1/2" buttress tbg. 9.2# N-80 Otis· Type CX g.i. mandrel 16 its 3-1/2" buttress tbg. 9.2# N-80 Otis Type CX g.i-. mandrel 20 jts 3-1/2" buttress tbg. 9.2# N-80 Otis Type CX g.i. ~andrel 21 jts 3-1/2" buttress tbg. 9.2# N-80 Otis Type CX g.i. mandrel 23 its 3-1/2". buttress tbg 9.2# N-80 1,15 31.30 1.20 8.15 31.73 3.00 1201.22 12.75 31.40 3.00 2411.22 5.70 448.91 5.70 479.16 5.70 602.89 5.7O 636.30 5.70 702.07 Otis Type CX g.1. mandrel 5.70 33 its 3-1/2" buttress tbg 9.2# ~-80 1029.58 Otis Type CX g.i. mandrel 5.70 29 jts 3-1/2" buttress tbg 9.2# N-80 895.26 Otis Type CX g.I. mandrel 5.70 25 jts 3-1/2" buttress tbg 9.2# N-80 770.40 Otis Type CX g.1. mandrel 5.70 63 jts 3-1/2" buttress tbg. 9.2# N-80 1950.41 Otis ball valve nipple 3.35 9 jts 3-1/2" buttress tbg 9.2# N-80 278.02 Tubing Hanger 1.00 Elevation 38.00 Top 11622.50 11589.12 11580.97 11546.24 10332.2.7 10297.87 7880.95 7426.34 6941.48 6332.'89 5690.89 4983.12 3947,84 3046.88 2270.78 317.02 Bottom 11623.65 LEASE Tradin$ Bay Unit State r. UNION OIL CO. OF CALIFORNIA DRILLING RECORD . SHEET D PAGE NO. 11 V~ELL NO. G- 31 FiELDMcArthur River Field DATE E.T.D. DETAILS OF :OPERATIONS. DESCRIPTIONS & RESULTS · . Short String_ Tubing Detail Description . . - L~ingth' To~ Baker tlydro-Trip sub 1.15 _ ' Otis Type Q'%anding Nipple 1.70 Baker dual Hydro-Set pkr 9-5/8"(on long st)8.82 · Baker Collett Latch seal assert. 8.67 2 j ts 3-1/2" 9.2# N-80 butt. tbg. Otis Type XO' sleeve 78 j ts 3-I/2" 9.2# N-SO butt. tbg. Otis Type CX g.1. mandrel 15 jts 3-1/2": 9.2# :~-80 butt. tbg. Otis Type "CX" g.1. mandrel 16 jgs 3-1/2" 9.2# N-SO butt. tbg. Otis Type CX g.1. mandrel 20 its 3'1/2" butt. tbg. Otis Type CX g.1. mandrel 21 jts 3-I/2" 9.2~~ N-SO butt. tbg. Otis Type CX g.1. mandrel 23 jts 3-1/2" 9.2# i<-$0 butt. tbg. Otis Type CX g.1. mandrel 33 jts 3-1/2" 9.~,~ N-SO butt. tbg. Otis Type CX g.1. mandrel 29 jts 3-1/2" 9.2# !~-80 butt. tbg. Otis Type CX g.1. mandrel ~5 jts 3-1/2" 9.2# N-80 butt. tbg. Otis Type CX g.i. mandrel 63 jts 3-1/2" 9.2# N-SO butt. tb g. 2 3-1/2" butt pup its 2 3-1/2" butt pup its 1 jt 3-1/2" 9.2# N-80 butt. tbg. Otis ball valve landing nipple 8 jts 3-1/2" 9.2# N-80 butt. tbg. Tubing Hanger KB elevation Less slack~off for. weight on tbg. 60.98 3.00- 2372.18 5.70 445.91 5.70 476.16 5.70 600.90 5.7O 635.30 5.70 689.95' 5.7O 1012.59 5.7O 893.25 5.7O 772.40 -5.70 1960.41 20.20 4.20 30.88 3.35 247.14 1.00 38.00 -4.10 10348.22 10337.~70 10265.12 7887.24 7435.63 645~.77 6347.17 5706.17 5000.52 3982.23 3083.28 2305.18 286.14 Bottom 10349.37 VVELL RECORD PAGE NO 4 LEASE Trading Bay Unit State WELL NO. G-3i ,- FIELD HcArthur River Field . · CASING & TUBING RECORD ' ..... s~ZE 1 WE_IG..HT -1 , THREJ~D , ' GRADE -- "DEPTH, ' .... REMARKS .... 17-3/4" ..312 wa]l...'spir.~l .w~id ' 520' Cmtd ~650 ',G'"' fo. Il.owed w/140.sx "C" .w/4% NAC12 _1..3-3/8" 61t/...' se, al lock .-, j255 .'152.22' Cmtd w/2000 sx. BJ mix & 500 sx "G" neat. 9-5/8" 43 5&47~~ But,.tress N-80 &iPill¢ 11667... Cmtd w/t700 SX Class "G". .. w/CFR-2 .... 7" 291} .... Buttress. . ..-. ~ 12729' See Drlg RR_cord .f. or Detail~ -. · 3-I/2';' 9.2t/ Buttress N-80 . · D.ual Tubin~.'Strings - /. , . , PERFORATING RECORD -;9/.11/6..9 12100-12101. ' 12.637 .qqz . sqz off w/150 sx-S_.~z //2 & 55 sx-Sqz ~1 · }.13 .... 11_870-11871 12637 ,qqz , sqz off w/lO0 s× . .., . ' , , 5_ _14 10910-10911 - 1263'7 .qnz_ sqz off w/100 sx __ 16 12021-12045 12637 DST '.- plugged off w/CIPB 0 11811' : 17, 1173,~ ~kt723 i1811 '"' nrod onen ~h ,., -,. ~ - 11706.11696 11811 prod open west Forela.d .... .... 11_688-11678 11811 prod open ..... .... _ 10728-10708' 11811 prod open ~' , ..... · . 106~6-10592 ~ 11811 orod oven ..... Middl,e Ken¢i "G;i'.. Zone ._ 10570-1{)540 11811' prod open J '.- ,,. o , INITIAL PRODUCTION . . , , ..... . TYPE' CASING HEAD: Sh'affer 12" 900x 13-3/8" SOW, lid Head w/2" 1i-1/2 THD side outlets CASING HANGER' Shaffer 12" nominal 9-5/8" Hodel K.D.K.S. CASING spOoL: · . TUBING HEAD: Cameron 12" 3000(~ x 10" 5000'/~ DC3 w/2-2" flan~ed outlets TUBING HANGER:. Dual DCB10" nominal w/ 3-1/2" , 3-1/2 buttress on 5-3/64" centers TUBING HEAD ~OP' !0" 50001~ 1V[ASTER VALVES: ca.~: an Tyne F C~a dual strin~ solid black leg .tree ;;/2-3-1/.8" bore master vai~es with 2 3-1/8" bore wing valves UNIC'"' OIL CO. OF CALIFO"' NIA DRILLING RECORD · . LEASE Trading Bay Un. St State WELL NO..G.31 FIELD McArthur River LOCATION- Leg 2, Conductor 38,-N1878' 9t : W138 ,. of SE corner Section 29 :.i T9N, R!3W," SM. PERMIT NO. 69-72 T.D.~i 12,736' ~ DEVIATION (B.H.L.) ' SERIAL NO. T.V.D. 10,774' .. 655'S, 5812.';E of sur. loc. SHEET a PAGE NO.,.1 sptID'~ATE 7/21/69 COMP. DATE 9/?0/69 .. CONTRACTOR WODEC0 RIG NO. 5~ ~ TYPE UNIT_ ;;ational 1320 UE Ro'tary DRILL PIPE DESCRIPTION 5" T.F. · ELEVATIOB~S: WATER DEPTH R, T. TO OCEAN FLOOR R.'T. TO MLL.%V R.T. TO ml R.T. TO 125,00 235.60 110.60 '19.30 ~" ' 42.60 COMPANY ENGINEER DA Ash, . Al?PROVED: (B.E. Talley) ~ ''" BIT RECORD "'~ ~' lv~JD VF~._ DEPTH & D:SVIiTIOr: ' . . '" BIT jET DEPTH! VERTICAL · 1"1 DATE. DEPTH Z~O. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. DIRECTIONAL ~ __ .. 7/21/69 '0 , 1RR 15" HTC . '~OSC3A · 5-30 162 3 ___- --_ ,,21 22 ;sg vco -I 5251574-1/2 23 1572 3 " hTC OSC3A 3-5/8. 2062 490 8-1/2 92 DDrld 24 12062 2RR. " G10be SS3A 3-14 2284 220 1-1/2 92 426 25 228~ 4 ' " '"' HTC HTC 3-5/8 2411 127 3 I 92 DDrld . 25 2411 4RR ,, ,, ,, ,, 2811 400 4 ,, 426 25 2811 I5 ".' smit'h'~ DThJi'' 3-14 2956 145 2 " " , ~! '! 26 2956 6 ' '" Globe SS3A " 3475 519 4 26 2475 7 "' Reed ytlAG 3-20 3483 8 1-i/2 110 400 DDrl failed ' 26 3483 '~RR " " " 3-12 3526 79 2 110 ". -" 26 3526 7RR "+ ' ' .... ' ' 3~14 3887 '325 6 " " T-8 5-3 .. "28' 3887 8 "- ~TC OSC3A " 4783 896 10. " " T-8 B-30G .1/8" ' 28 4783 9 " Globe SS3A " 5219 436 9 . " " T-8 B-60G !".' · 29 496 1~02 17" . Smith REG open 28~3 2317 21 60 T-3 5-5 29 '2317 HO3 ' " " REG-GP " 4112 1299 2,1-.1/2 60 T-6 B-4 30 41i'2' ti04 ',' " .. " " 5235 1123 1'4 60 T-5 B-3 .. "'8/2/69 5235 JB "11-1/8" Globe ~' 5238 3 Cut core, fish hammer., '3 ' ' 10 12-1/4" !Smith DG}L ~'3-15 5941 706 11-1/2 112 352 T-5 B-4 ' '3 5941' L1 " Smith DGH 3-20 ~ 48 1 ~98 175 DDrld. ' 4 I 1i " " DGHJ " 6171 230 6 98 "' DDrld ' _ 4 6493 12' " " DTnJ 3-15 322 6 102 323 d.rlg 5 12 ,, " " " 6493 " 6 102 323 , , , 5 13 " Globe ST3G " 6938 445 8 ~ " ". T-6 B-4 1'/4 · '5 7115 14. " " " " 7115 177 5 " " T-4 B-2 6 7115 15 " Reed ST~AG· ,, 7206 91 4-"1/2 ,, ,, T_3 B-4 ' 7 I~206 16 , I ' ' Globe ST3G 3-14 7470 264 9-1/2 108 340 T'6 B-2 7 7~70'' 17~ " Smith" DGH3 " .7804 ~4. ~,9-1/2 ,, " T-6 B-4 8 ~ 7804 ].8 " Cl0be tST3O " 79~q0 17b 9-1/2 ,, " T-6 B-3 .... I! I ' 8 '7980 19 " Smith DGHJ " 821.1 231 8-1/2 " T-2 5-4~.f ......... '_ 9 8211 12..0 " " " " 847,4 263 7 " " T-~ B-4 .... ' 9 - 8474 21 I ' ' Globe ST3G " 8654 180 0-1/2 ,, " Ti5 B-4. 10 8654' ~j " "' " " 8948 294 g-1/2 " ",, T-5 B-5 "i2''9193 23 " ,,,, ,,. 9193 245 I10-1/2 1,02 T-5 B-7 , , 13 9432 24 " Smith DGHJ " 9432 239 ~-1/2 ,, 372 T-4 B-6 ...13 . 1 9'7'84 25 " "' ~ " " 9784 352 11 ' ,, " T-6 B-4 14 9~00 26 . " Reed ST1AG' 3-24 9800 .16 4 _ - T-2 B-4 DDrld , ln5 9865' 27 I - '" t' "' " " 9865' '65 9 ~ ..... __ -- T--7 B--7 · 16 10027 '28 " smith DGHJ 3-14' 10027 162 7'i/2 t~2 372 T-5 BJ4 .i6 10027 29 "' Slobe ST3G " 10153 126 6-1'/2 ,, " T-2 B-1 pulled for r.p'~ 17 10153 30 ". Reed ' ST1A~ ~ 3-2'4 ~ 10204 51 8 ,, " T-7' B-4 DDrld ~. 18' 10204 31 . " ,, YT1AG 3-14 . 10323 119 10-1/2 ,, .,, T-6 B-4' . 19' Lb658'- 32 " Smith K2HJ " 10512 189 8 ,, " T-6 B-6 .... 20 'I1077]~ 33 I ' ' ' ' ' ' '' 10671 159 [~ I I ' ' ' ' T-6 B-7' 20 L07~i 34 " · Globe ~11'3' ,, 10771 100 5-1/2 J. ,, ,, T_7 B-3 ' ' 21' 10942 35 " Smith' K2HJ '" 10942' 171 '8-1/2 ,, " T-5 B-4 OK 21 11006 36. . "' "' " 11006 64 8 " " T-7 B-6 1/4" 11 I ' " 22' L1076 37 " :iTC XDR ' " 11076 74 11 ,, T-5 B-3 OK I , 24' .1272 38 " ,, .K55R., " 11272 196 24-i/2 ,, ,' T_5 B-50~i' 2~ ' j1153'6 39 " ,, ,, ,, 11536 264 31' ,, T-5 B-5 OK , ' 2'6 ~1'1659 40 " leed SCM " " ' '27_. 11667 40 " j " . l ." 11667 131 22-1/.2 ,, ,, T_5 B-5 _ ....... ~ Ran 9-5 ~8'"' casing ~,] '1 [667' I - 31 11762' 41 8-1/2" ~TC ~DDV 3-12 11762 95 3 . 1~ 332 T-5 B-3 -- 9/1/69 11908 42 " " !X55R " 11908 -146 12-]/° ,' " T-4 B-6 .. ~ .. ~ ............. it DRiLLiNG RECORD UNIC' I OIL CO. OF CAI_tF IA LE~E. Trading, Day Unit Stat.e VFELL NO. G-31 FIELD LOCATION ~ERMIT NO. SERIAL NO. TI). T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER SPUD-DATE. CONTRACTOR TYPE UNIT DRILL PIPE DESCRIPTION ELEVATIONS: WATER DEPTH IL T. TO OCEAN FLOOR ' - IL:T. TO MLLW · :~ ' ' '- ILT. TODRILL DECK ': tL T. TO PRODUCTION DECK APPROVED: SHEET A PAGE NO. COMP. DATE RIG NO .... i . · -' ' 'BIT RECORD blUD VEL. DEPTH & DEVIATION' DATE, , ,.DEPT ,.H NO. SIZE MAKE TYPE SIZZ- OUT FEET HOURS ~'9/3/69 12265 44 8-1/2 HTC '~55R 3-12 12265 I II2~ ~5' ~60 332 Ti5 B--8 !5 ,, '! .12,637 RRi 8~1/2" Gtobe ST3¢ open Dr~d .15, ,126-37] 50 6'' =' iliTC', , , O~'Copen Drld ....................... ........... , ,, , ...... [ · ....... . . . ~ . .... . ........ ............. · UNiO~ Oil CO. Of CalifO~Nia MUD RECORD SHEET B PAGE NO LEASE Tradinj'Bay'Un.il,/t 'Stla[e ' WELL'NO] D-~I "~' FIELD McArthur River Field TI/PE ~ DISTRIBUTOR . D~~ I V!SCo, I, , WoLo PH SALT 'OIL SAND SOLIDS I~EMAI~KS ,. 21 , 530 74 .. ...65 .... 10,8, 10.2 12000 0 2 16 Set 1,7-3/4",csg @ i20' , .ii..23 11.90 7!,. 38 14.3 12,,, 1%000 0 2 . , ,, , , , 24 .205.~ 76' 37 , 9.6 ,].0.! ,!2,000'0 ,.2.. t ., --. , -.. 2.5 - ~_811 ..7s 42 10.4. 10.112000 0 2.: . ........ . ........ - .... t ,, ' '26 ' ~ ~ 75 i ..80 4'3 9 ' 8 ~ 0 ' 3 ~ 2000 0 2 .27 t 4226 79 ,, 52 11..: 2, 1.0..1 12000' ,0 2 · , ,. . ..28i.' 5154 79 -40.i 9.6. J..o.,] z200.0 0 3 , ~..'29 . 23'65' '78, 39 16,`4 9.8 [2000 0 .4 " Opened ~o:].e- , , , . ,. , . , , . , · . , ............. 30 3~90 7.s..._ 43 . 8.4 9.5.12000 o. ,..3,~L/2 '].'6 Opened hole ,, 31. 4900 78.5 44 8.6 9.0 '11500 ' 0 3 ].7 " " , . :8/,]-/69'. 52:~5'' '?'s-. ~ .......... ". 4,... 8.85.,,.9,.5 i2'ooo o .. ~-:]./:t _:]-6 .... ,.,',3, ..... .594.! 7t .44. ,. 6.4 10.5 120QO,. ,0.~, 1-!./~ 12 ..... . ............ .... 4 L' 64,93 ,,,,,~74 56 ,, 5..2 9,6 ,.t20o0 ,3, .l-]./; ].4 ,. :.'5. f.' 71:].5 73 ..... .52..... 5.0 .9.5- !,2000 4 , I 12 ~ ....... 7.. [. 7,650 . .7.3 . ....50 ,4.89.6 z. ZO00. - ..5!-I/:l '12 ,, , "8 .. 786,5 .73.5 53 4. 6.. 9.5 ]..2,500. `4..1. .]..4 ............ .... ~'9 8187 75 51 ,, z~.,~l. 9;,4,. 12000 5 '!-!/: ,,15 ,, · ' _tO ,,8622' ' 74-5 54 ,4.6 9.5 120,0.0,' .5, ,. . " .14 , . , '. 11-t.. '872.:z 7',~ .... 52. `4 8 ~,6 1200,0 i ...." :].~ ...... ,t ...... ,., 12' [. 94:18 t 76 ,.54,. 4..6,,. 9'.4 12000 4 ,2 .15 , . , , .... ' 13- i'" 9184 75 5(::, 4.8 9,;8 lr2OQO, .4 2 15 .... ' :L,:,, ' ~'~:~1 t' 75 ' '.~0 5.0 ~.4 120O0 4' .1-.1/: ]_4 15" i "~0007 75 50 4.8 9.4 12000 4 1 14 ....... --''- ~6'II 10.160' ~ 6 ' 5 6 2 .... 4 6 9 7 12000' 6I 'i'1/2 I I13 ~ 18 10222 76.5 5.7 5.1. 9.7 12000 5 1-1/l'.:. 14 -- i9" ' 10495 76 ' 54 4.~ 9.8 ' 12'000" 4 1 14 . .......... " 20 10671 76 50 '4.8 93. '1'~0'~0 7 1 13 ----]t 10942' ' 76 " 50. "4.87 9.3 12000 6 ' 1-'1/2 14 .22 .... ,11076 ~ 76 ' 50 5.2' 9.1' '12000' ' 6 I 14 .... .... 2~ ..... ~1232 ~"76 5.o -4.8 10:0120o0 '~ 1-1/2 'i"4 .... - 24 113~5o 7~ 51 5.1. ~).'? '120~0 5 1-1/2 '.i:'4 " ~ 11~,~.I,,7~ ~ 4 s ~.6 12060. 7 1-z/~ ].4 .... .,i .... "' 26 11~59 76 48 4 8' 9.8 12000 7 1 '13' " 27 i1667 75.5 53 4.6 9.6 12000' ~ 6 t 12 Conditione~ for 9-5/8" csg,: .......... Ran c.'"5/6'' ca, sing. @ ]"1',667'": ' ' ' . ........ 28 ' 11667 -- 75 53 , ,4:6 9.6' 12000 ~ :1 1 '1'2. ' ..... "24' ' '11667 ' 75 53 4.6 9.6 120(}0 6 1 " 12 - - 31 - 11774 ..... 74 47 4.6 10';6, 12000 7 "1 3/4 12' ~'xcess sloU~hin~ _9/1/69 '11908 73'I I 4 8 4.4 '10.5 !12000 7 1/2 12 2 .... 120'5~ 7a 53 '4'2 ~ 0 ' 0 ~ ~ 000 6 ~ t'2 ~ 3 __.' ~ I ' ~22'55' r'' f~ ' 56 l' I4:'0 , 9.8 "i2500 5 '3/4 'i4 .... 4-' 'i')'362 73 55! 4.0 9.9 112500 5I 3/4 14 I .5 12562' ,77/73' 50 4.0 9.2 12000 4 1/2 -14-:' ' II i-6 1'~'"~36'' III ~7'6/73 "52 ' II~'~'2 !9.'4.112000' 5 1/2 ' I II 14 ......... I ' ' '- '' 7 ' 12736 77/73 ...50 4..0 9..2 12000 .4 '1/2, 14 ,, " _8 : ,ii2736 79/74 56 4.2 9.0 1'3000 ..6 3/4 1 5 9 .,1273.6 79/,75 · 54 .4.0 1,9.0 1250(> .6 '. 1/2 - 16, .- . . 10 . 12,736 . 72 43 28~.6 !!2+ -' 12000 4 1 ' 12 Drld cm't , ,, _ 11I ' 12736, 70......44 3(~,,i2 12+ ]_2000 - 4 1 11 · ~ i"' ,,: ,.'', _ 12 12736 71i~5 36 22.6 12+ 12000 4 I 1.1, .[.~ 15 ' ,1.2736 67 W~i~!ting. u!~ Fill' d ' ' -'. .... ere I~let W-~ter to 7~/~i ' " 16 12736 73 Filth-tied InLet W~ter- , , 17 1181.1 73 I Filt ~red .InLet Wite. r . · . - .... ~g,; _: - ] 7 11 11 ~ 75 Inve :mu1 oi I 1 tp perf thrtl [ ........ i , , ,, .... [ ' · . . ..- . ~ · _ · . __ - . Form D-tO01-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD SHEET A PAGE NO. ¢.--' Jim R. (Jatlen¢~er SIZE DEPTH t7 3/4" 520' 13 3/8" 5,222' 9 5/8" 111,667' 7"Liner 112,729' 3 t/2" Dual IhT LEASE TRA~,NG BAY UNIT STATEWELL NO G-3]. CONTRACTOR Parker Drilling Company FIELD j/j_cArth.ur .Biver~Field TYPE UNIT. l~0_.ME_Nation~ BEGAN:~ !/7~_ COMPLETED: _5/16/7{ ..... ELEVATIONS: GROUND See .t~u.__~_vma~ _.. o~,~ ,~O. ~ ,~, ~ ~v~n CASING HEAD N · . TUBING HEAD Hq COMPANY E,?GINEER;o ~'~4 ~ ~ ~_ ~ _Wea~.,. _ A. ppROVED~5~f2~;~~:2~f_~v~M~D g34!420 & g341419 .... R~TARY DRIVE BUSHING CASING & TUBING BECOB. D REMARKS WEIGHT GRADE -Weld J-55 N80,Pil0 N-80 N-SO -- - · 312 Spiral 61# 43.5 & 47g 29# 9.2# 4/1~/6V~12,101' 9/13/69 !11,870'-11,871' 9/14/69 110,910'-10,911: 9/16/69 12,021'-12,045' 9/18/69 11,678'-11,688' 9/18/69 11,696'-11,706 9/18/69 11,723'-11,738 9/18/69 10,448'-10,484 9/18/69 10,540'-10,570! 9/18/69 t10,592'-10,636 9/18/69 110,708'-10,728 Conti~.u~[d' on Page #2 1 12,637' 12,637' 12,637' 12,637' 11,811' 11,811' 11.,811' 11,811' 11,811' 11,811' 11,811' beet B. /18/74I 5/19/74 I Hemlock Hemlock ttemlock 5/17/74 5/18/74 5/19/74 755 774 3038 2654 2644 Cmt'd w/ 650 sx. "G" followed w/ 140 sx. "G" w/ 4% NaC1-2 Cmt'd w/ 2000 sx. BJ mix & 500 sx. "G" Neat. Cmt'd w/ 1700 sx. BJ w/ CFR-2. Liner top @ 11,595'. Cmt'd w/ 300 sx. "G" w/ 1% CFR-2. Dual tbg. strings. See attached detail. . .. PERFORATING RECORD Sqz. Sqz. Sqz. DST #1 Production Production Production Production Production Production Production INITIAL PRC CUT GRAY. 1.8 35.2 .1 34.1 .1 34.7 .1 3~4.0 .1 33.7 PRES~ITTQON~)ITION Sqz. #1 55 sx. Sqz. #2 150 sx. % Sqz'd w/ 100 sx. Sqz'd w/ 100 sx. Plugged off w/ CIPB @ 11,811'. WF Zone abandoned 5/4/74 w/ cmt. ret. @ 11,524'. WF Zone abandoned 5/4/74 w/ cmt. ret. @ 11,524'. WF Zone abandoned 5/4/74 w/ cmt. ret. @ ].1,524'. "G" Zone (reperf'd 10,450'-10,480' 5/4/74.) "G" Zone (reperf'd 10,540'-10,570' 5/4/74.) "G" Zone (reperf'd 10,610'-10,635' 5/4/74.) "G" Zone - Open for Production. DUCTI¢ 900 905 880 900 905 N AFTER RE' AIR "' T. ,i 95 [ ] 125 I 175 ].86 [ ] 124 180 238 Short S' 64 182 235. Short S' 107 881 280 ~ong St 107 770 290 bong St 107 767 -...,~0 String String String String WELL HISTORY PRIOR TO REP.AIR LAST COMPLETION NO. 1 (Original Completion) COMPLETION DATE: PRODUCING iNTERVAL: Middle Kenai ~'G Zone & West Foreland Zone · ~ '~ ', :' '" "' ~ ]531 BOP?, Av~. rate S~'}t 19E,~ INITIAL PROD UC J.'~ON: ~D~ '~-: .................. ~WF "Zone 326 BOPD . ~vg. rate Sept 1969 LAST REGULAR PROD. & DATE: "O" Zona 1592 BC)PD Avg. rate April ]974 CUMULATIVE PRODUCTION :__ '_" G " Zone 1,255,780 bbls oil thru April ].974 9. 72: ~ .... ' I-,,- ' ' O Form ... UNION OiL CO. OF CALIFORNIA REPAIR RECORD SHEET PAGE NO LEASE TRADING BAY UNIT STATE 5/11/74 5/13/74 5/13/74 5/15/74 5/16/74 5/16/74 5/16/74 5/16/74 COMPLETION DATE:_ I DATE INTERVAL 5/4/74 0,450'-!0,48 ' 5/4/74 LO, 540'-10,57 5/4/74 L0,610'-10,63}!' [1,285'-11,3 L1,285'-11,3 !.1,255:-11,28 [1,160'-11,19( [0,966'-10,9g ' L1,015'-11,02 I, 042'-11,05 1,080'-11,11 WEL'~, N(D. G-31 FIELD_ McARTHUR RIVER FIELD APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ETD REASON 11,524' 11,524' 11,524' PERFORATING RECORD CONT... 11,524' 11,524' 11,524' 11,524' 11,524' 11,524' 11,524' PRESENT CONDITION Perf-Prod. "G" Zone - reperf as noted on Sheet A Page #1. Perf-Prod. "G" Zone- " " " " " " " "'. Perf-Prod. "G" Zone- " " " " " " " ". Production Hemlock Zone Bench #4. Production Reperf. Bench #4. Production Hemlock Zone Bench #4. Production Hemlock Zone Bench #3. Production Hemlock Zone Bench #1. Production Hemlock Zone Bench #2. Production Hemlock Zone Bench #2. 11,524', Production Hemlock Zone Bench #2. TYPE: -~-.-- Shaffer 12" 900 X 13 3/8" SOW KD Head w/ 2" 11 1/2 THD side outlets. CASING J~.uA_u: .... CASING ttANGER: Shaffer 12" Nominal 9 5/8" Model KDKS. CASING SPOOL: TUBING HEAD: Cameron 12" 3000# X 10" 5000~ DC3 w/ 2-2" Flanged outlets. TUBIN~ HANGER:_Dual_D/~L.L~LoluJ~rLaL_~~, 3 ]:f2 Buttress on 5 3__/64" centers. TUBING HEAD TOP:___L~~ }xA~E~t VALVES: '-. r~ sc, l~d t~l~c¥ 1%,' tr~e ~v/ 2-3 ]/8" )~(')re met{":, valves w/ 2-3 1/2" bore wing valves. CHRISTMAS TREE TOP CONN.: DATE ZONE PERF©II':'FEO VCest Foreland 9/11/69 West Foreland 9/13/69 Middle Kenai G 3/14/69 Wes t Foreland 9/17/6c~ Ini[ial Perforations Middle Kenai "G" · 9/18/69 West Foreland 9/18/69 TRADING BAY U.NI'i' WELL G-31 p ERFrnp ',?T©,X~ .'.-:-,0 .:,.'. TO FEET Com~leti6n Date- Workover No. Wor/:over Date 9/20/, REM. ARKS WATER SHUT OFF PERFO.%%T!ONS 12,100 11,870 10,910 12,101 '11,871 10,911 Sqzd 150 sx sqzd 55 sx Sqzd 100 sx - Sqzd 100 sx DRILL STEM TEST PERFORATIONS ! i , 12,021 12,045 24 4 spf w/Sch, csg gun in ~0~. filtered inlet water. Recvd 97 1/2% water Plugged off by CIBP @11,.811' 10,448 10,540 10,592 10,?08 11,678 11,696- 11,723- COMPLETION PERFORAT iONS 10,484 36 10,570 30 10,636 44 10,728 20 130 11,688 10 11,706 10 - 11,738 15 3.5 4 spf w/Sch, csg gun Perf'. in invermul 4 spf w/Sch. Perf. in invermul - 0 SAF~ EQUIPMENT 0 GAS Ul~ EQUIPMENT O PACKErs AND ACCESSORI~ OC0MPL~ION EQUIPMENT O ~ST COMPLETION E~UIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES ~, /t II |I II II I~ //_/~, ! J k II II Il .. / 7, " f' d . p ESTIMATE 93.s? ?7¢ 2o/~ /~ )~ / ~ ~/~ /~// ~ It Il tt It Il II 4 II l/ Il ff y /~Q~ ;EASE T,rading· __ . .... Bay Unit State,~tr ____WELL NO.,G-31 _FIELD_~'~?thur River Field -- ii i II ~ ...... I I ! II I I ~ ~....=~_ -- I I ~ i I C_~_'_SI_=N_G__& TUBI~,~G RECORD , SIZE I V/EIGHT [ THREAD t GRADE D~pTH _i-3/.i"; [ .3i5 wa~l spiral .'w~!d 520' {. J,ss 5222 1~5/S"{43.5347,i ]3uttress }2;-80 S P-!IC -'9:r iButtress I 1~ 637 1/637 T 1072LL-1070S 10636-10592 10570-10540 10Ag4-1044'a .TYPE:., 12637 12637 llgll 11811 ---~r'~cd '~,/650.".G" fqllowed w/140 sx "G" w14% NACl2 - Cmtd W/2000 sx BJ mix & 500 sx "G" neat 11667 tC;:atd w/1700 sx Class "G" w/CFR-2 [See i.r_l.g Record for Details 7-OPo,') //,5~L~-/, 12729 __ . ! , Dual Tub±rig S trin_gs PERFORATING RECORD · ~ ~o2{ ~ sqz ~ sqz I s~z off W/100 sx ~nz ~..~.' ,off w/100 sx DST ! plugged off w/CIPB D 11E]1' prod ,l_onen % - prod I ogen ~ West Foreland 1i~11 prod t oben J !_~tz of~_0__azz.S.ctz ~/2 & 55 sx-S~az. #1 11811 ° 11811 11811 prod prod .prod open open open Middl~..Kenai "G" Zone WEL_T~t!>~: ,MP_A S SZ. ~,~T ~T, Y CASING HEAD' Shaffer 12" 900x 13-3/8" SOW, KD }lead w/2" 11-1/2 TIiD side outlets ,. CASING HANGER'Shaffer 12" nominal 9-5/8" Model K.D..K.S. CASING SPOOL: TUBING }lEAD' Cameron 12" 3000# x 10" 5000# DC3 w/2-2" flanged outlets TUBING HANGER:...Duq~...D.Ci';'10'; norainal w/ 3'i/2" ~ 3-1/2 buttress on 5-3/64" centers TUBING tIEAD TOP: '!0" 5000# MASTER \AL\,Eo:_C~nnn Ty. pe "I'". ,:,marc, dual strinz_ [21id~c~.~rcc w/2-3-1/8 bore master w~ivcs witl~ 2 3-i/U" bore wing valves Ct{RIST?.iAS TItEE TOP CQN~ .' ~ 3-1/2" i,lUr Grd . · (, . WELL G-31 '.. ' Oom~leti6n Dat~ 9/20/~ ~ ' Workover No. Wor~ov~r Date .......... ZONE ~ .... ' West Foreland 9/11/69 West Foreland 9,/13/69 Middle Kenai G 3/14/69 WATER SHUT OFF PERFO.~-%T!ONS 12,t00 12,101 11,870 '11,871 10,910 10,911 L im Sqzd 150 sx sqzd 55 sx Sqzd 100 sx Sqzd 100 sx Wes t Foreland 9/17/6c~ DRILL STE?.4 'rEST OERr O~,.ATIONS 1'2,045 24¸ 12,021 4 spf w/Sch, csg gun in ~0~ filterec inlet water. Recvd 97 1/2% water Plugged off by GIBP @11,811' , , i Il 11 Initial Perforations COMPLETION i · · ""-- ...... '' ' Middle Kenai "G" · 9/18/69 West Foreland 9/18/69 10,4~8 10,540 10,592 10,708 11,678' 11,696' 11,723- 10,484 10,570 10,636 10,728 11,688 11,706 11,738 P {RFORATIONS 36 30 44 20 '. 130 4 spf w/Sch, csg gun Perf'. in invermul t0 10 15 35 · 4 spf .w/Sch. Perf. in invermul · (99' Above M.S.L.)R.T( . ....... Tubing Hanger 39' TUBING DATA Short Strin9 3-1/2" Buttress Tubing To 10,349 Lon9 St.ri ng. 3-1/2" Buttress Tubing To 11,624 13-3/8" Casing @ 5222' GAS LIFT EOUIPMENT Short Strinq l) 3-1/2" Otis CX Mandrel @ 2305' 2) 3-1/2" Otis CX Mandrel @ 3083' 3)'3-1/2" Otis CX F!andrel @ 3982' 4) 3-1/2" Otis CX Mandrel-@ 5001' 5) 3-1/2" Otis CX Mandrel @ 5706' 6) 3-1/2" Otis CX Mandrel @ 6347' 7) 3-1/2" Otis CX Mandrel @ 6~54' 8) 3-1/2" Otis CX Mandrel @ 7436' 9) 3-1/2" Otis CX Mandrel @ 7887' 9-5/8" Baker Hydro Packer @ 10,388' .on9 String l) 3-1/2" Otis CX Mandrel @ 2271' 2) 3-1/2" Otis CX Mandrel @ 3047' 3) 3-1/2" Otis CX Mandrel e 3948' · 4) 3-1/2" Otis CX Mandrel @ 4983 5) 3-1/2" Otis' CX Mandrel @ 5691 6) 3-1/2" Otis CX Mandrel @ 6333 7) 3-1/2" Otis CX Mandrel @ 6941 8) 3-1/2" Otis CX Mandrel @ 7426 9) 3-1/2" Otis CX Mandrel @ 7881 9-5/8" Baker Hydro Packer @ 11,581' 7" Liner Top @ 11,5'95' 9-5/8" Casing @ 11,667' Liner @ 12,729' WELL SCHEMATIC TRADING BAY UNIT G-31 ! Original Completion 9-20-69 UHION OIL CO~/,?A,H¥ OF CA.,r(D,dqlA LEASE Tradinz Bay Unit State DATE E. T. D. __%VELL NO.. G-31 }' -thur River Field ,, DETAILS OF OPERATIONS. DES TIONS & RESULTS o. .L. on,& Strin~ TubinR Detail Descrip~ioR Length Baker Hydro Trip Sub i jt 3-1/2" buttress tbg. 9.2# N-80 Otis "X" Landing Nipple Baker 9-5/8" Single Hydro set pkr 1.jr 3-1/2" buttress tbg 9.2# N-80 Otis "XO" Sleeve 39 jts 3-i/2" buttress tbg 9.2# N-SO Baker 9-5/8" dual hydro-set pkr 1 jt 3-1/2" buttress tbg 9.2~ N-80 Otis type "XO" sleeve 78 jts 3-1/2" buttress tbg 9.2# N-80 Otis Type CX g.1. mandrel 15 its 3-1/2" buttress tbg. 9.2# N-80 Otis Type CX g.i. mandrel 16 jts 3-1/2" buttress tbg. 9.2# N-80 Otis Type CX g.1.. mandrel 20 jts 3-1/'2" buttress tbg. 9.2# N-80 Otis Type CX g.I. mandrel 21 jts 3-1/2" buttress tbg. 9.2# I¢-80 Otis Type CX g.1. mandrel 23 its 3'1/2" buttress tbg 9.2# N-80 1.15 31.30 1.20 8.15 31.73 3.00 1201.22 12.75 31.40 3.00 2411.22 5.70 448.91 5.70 479.16 5.70 602.89 5.70 636.30 5.7O 702.07 Otis Type CX g.i. mandrel 5.70 33 jts 3-1/2" buttre~;s tbg 9.2# ~-80 1029.58 Otis Type CX g.1. mandrel 5.70 29 jts 3-1/2" buttress tbg 9.2# N-80 895.26 Otis Type CX g.1. mandrel 5.70 25 jts 3-1/2" buttress tbg 9.2# N-80 770.40 Otis Type CX g.1. mandrel 5.70 '63 jts 3-1/2" buttress tbg. 9.2# N-80 1950.41 Otis ball valve nipple 3.35 9 jts 3-1/2" buttress tbg 9.2# N-80 278.02 Tubing l{anger 1.00 Elevation 38.00 .. Top Bottom 11622.50 11623.65 11589.12 11580.97 11546.24 10332.27 10297.87 7880.95 7426.34 6'941.48 6332.89 5690.89 4983.12 3947,84 3046.88 22 'o.7s 317.02 LEASE Tradi:iz Bay Unit State , , DATE E.T.D. WELL NO._G-31 Fir ~M__c' thur River Field DETAILS OF OPERATIONS. DES =TIONS & RESULTS -. ,Short Str. in~ Tu.bing D?:.tail Descrip t~on LenKth · . Baker tlydro-Trip sub 1.15 Otis Type Q Landing Nipple 1.70 Baker dual tiydro-Set pkr 9-5/8"(on long st)8.82. Baker Collett Latch seal assem. 2 its 3-1/2" 9.2# 2-S0 butt. t~og. Otis Type.XO'sleeve 3 1/~'' .2~" 80 butt. tbg. 78 its - ~ 9 ,, Otis Type CX g.1. mandrel 15 its 3-1/2". 9.2# N-SO butt. tbg. Otis Type "CX" g.i. mandrel 16 ~ts 3-1/2" 9.2# N-SO butt. tbg. Otis Type CX g.1. mandrel 20 jts 3-1/2" butt. tbg. Otis Type CX g.1. mandrel 21 its 3-1/2" 9.2# N-80 butt. tbg. Otis Type CX g.1. mandrel 23 jts 3-1/2" 9.2# N-SO butt. tbg. Otis Type CX g.1. mandrel 33 its 3-1/2" 9.2# N-SO butt. tbg. Otis Type CX g.1. m~ndrel 29 jts 3-1/2" 9.2# N-80 butt. tbg. Otis Type CX g.1. mandrel ~5 its 3-1/2" 9.2# N-80 butt. tbg. Otis Type CX g.1. mandrel 63 jts 3-1/2" 9.2# ~-$0 butt. tb g. 2 3-1/2" butt pup its 2 3-1/2" butt pup its ~-o0 butt. tbg. 1 jt 3-1/2" 9.2# '~ o Otis ball valve landing nipple 8 its 3-1/2" 9.2# N-80 butt. tbg. Tubing Hanger KB elevation Less slack off for weight on tbg. 8.67 60,98 3.00- 2372.18 5.70 445.91 5.70 476.16 5;70 600,90 5.70 635.30 5.70 689.95' 5.70 1012.59 5.70 893.25 5.7O 772.40 5.7O 1960.41 20.20 4.20 30.88 3.35 247.14 1.00' 38.OO -4.10· 10348.22 10337.70 10265.12 7887.24 7435.63 6~53.77 6347,17 5706.17 5OO0.52 3982.23 -3083.28 2305.18 286.14 Bottem 10349.37 (99' Above M.S.L.)R.T. Tubing Hanger O' 39' TUBING DATA Short String 3-1/2" Buttress Tubing To 10,349 Lon9 Stri n9 3-1/2" Buttress Tubing To 11,624 13-3/8" Casing ~..3 5222' GAS LIFT EQUIPMENT Short String l) 3-1/2" Otis CX Mandrel @ 2305' 2) 3-1/2" Otis CX Mandrel @ 3083' 3)'3-1/2" Otis CX I~tandrel @ 3982' 4) 3-1/2" Otis CX Mandrel. @ 5001 5) 3-1/2" Otis CX Mandrel @ 5706 6) 3-1/2" Otis CX Mandrel @ 6347 7) 3-1/2" Otis CX Mandrel @ 6454 8) 3-1/2" Otis CX Mandrel @ 7436 9) 3-1/2" Otis CX Mandrel @ 7887 9-5/8" Baker Hydro Packer @ 10,388' ,ong Stri l) 3-1/2" Otis CX Mandrel @ 2271' 2) 3-1/2" Otis CX Mandrel @ 3047' 3) 3-1/2" Otis CX Mandrel ~ 3948' 4) 3-1/-2" Otis CX Mandrel @ 4983 5) 3-1/2" Otis' C× Mandrel @ 5691 6) 3-1/2" Otis CX b~andrel @ 6333 7) 3-1/2" Otis CX ~qandrel @ 6941 8) 3-1/2" Otis CX Mandrel @ 7426 9) 3-1/2" Otis C× Mandrel @ 7881 9-5/8" Baker Hydro Packer @ 11,581' : 7" Liner Top @ 11,595' 9-5/8" Casing @ 11,667' ~mm 7" Liner @ 12,729' WELL SCHE~!ATI C TRADING BAY UNIT · G-31 ! : Original Completion 9-20-69 UtitO}'~t OIL CO,V.?A, HT OF C?,LIFORNIA ^ff'O. F L U I D S A M P L E R D A T A ' Ticket , , Date 9-17 -69 Number 033168 Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas .,,Of' Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester MR, JONES Witness IV[R, JONES cc. Mud Drilling Tot. Liquid cc ..... ContractorW~STE~N OFFSHORE DRILLING. COMPANY DR Gravity. ° APl @, °F. E Q U I P M E N T & H O L E D A T A Gas/Oil Ratio.,, cu. ft./bbl. Formation Tested - Elevation [CB 99 Ft. RESISTIVITY CHLORIDE Net Productive Interval 12 s 024 t - 12,045 ' Ft. CONTENT All Depths Measured From Kelly Bushin§ Recovery Water __ @ __ °F. .ppm Total Depth 12 = 636 PPD Ft. Recovery Mud __ @ __ °F. /Main Hole/Casing Size - Recovery Mud Filtrate __ @ __ °F .... ppm Drill Collar Length 1143_ 65 I.D 2~ 764 Mud Pit Sample c~ ~ °F. Drill Pipe Length 5"- ]0; 7/~1 ._ 9R.D. /~_ 276 Mud Pit Sample Filtrate ~ @ ~ °F. , ppm Packer Depth(s) 11_; _gO_°· Ft. ..... Mud Weight ~~vis cp Depth Tester Valve 1 I i J~J~7 Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Gas 950# , Ft. Pres. Valve 11~881 Choke ¥'-¥' Choke 5/8" Recovered Feetof well surfaced and flowed salt water Recovered Feet of Recovered Feet of < Recovered Feet of Recovered Feet of ..... Remarks Production test: Filled drill pipe with 950# gas pressure, set packer and opened tool for 13 minute first' flow, pressure release, pressure build to 1250~. ..... ClOsed tool for 300 minute second flow., fluid surfaced @ 2:45 AM, flowed @ rate 33 barrels per hour, Closed tool for 309 minute second closed in .pressure, Reversed drill pipe clean while taking shu~ ~n, Gauge No. /Z.~/J Gauge No. 1252 Gauge No. TEMPERATURE 11~893 11 917 Ft. Depth: Ft. TIME .... Depth: Ft. Depth: /-+J5 Hour Clock 48 Hour Clock Hour Clock Tool 9-16-6~;. _Est. °F. Blanked Off .NO Blanked OffYes Blanked Off 'Opened 11:00 P.M. 11920~ Tool 9-17-6~.M. _Actual 183°F. Pressures Pressures Pressures Closed 11:00 _ Field Office Field Office , Field Office Reported Computed ln__j,.tial Hydrostatic,, 5103 5127 5112 5137 Minutes Minutes ~.~3 Initial, 2752 1962 2E71 ... 2138 .~.~' FlowFinal "3304 2871 3322 2998 15 13 _ Closed in 4548 4562 4562 4573 , , 90 93 ~3 Initial 3304 2763 3322 2881 c o Flow 8'r- Final 4438 4449 4452 4463 315. 300 ~ Closed i. 4548 4565 4562 4563 300 30'3 Initial ~o Flow ~ m Final Closed in --.._, _._Final Hydrostatic 5075 5199 5085 5220 PRINTED IN FORMATION TEST DATA LITTLE'~ t11;1421t II~M 4/~9---~$, 14-ll Gauge No. First Flow Period Time Dell. .000' .000 ·020 PLUGGI! PSI(; Temp. Corr. 1962 2871 1253 Time Deft. .000' · 000 .0185 .0370 .0555 ',0740 ,0925 .1110 .1295 ,1480 .1560 J Depth First Closed In Pressure PSIG Temp. Corr. 2871 4526 4546 4551 4557 4562 4562 4562 4562 4562* 11,893' Second Flow Period Time Deft. .000" .000 · 0823 · 1646 · 2469 .3292 ·4115 PSIG Temp. Corr. 2763 3876 4474 4463 4457 4452 4449 Clock No. 10,0541 Second Closed in Pressure Time Deft. .000" · 000 ·0506 · 1012 .1518 .2024 .2530 .3036 .3542 · 4048 · 4554 Loo PSIG Temp. Corr. 4449 4557 4560 4565 4565 4565 4565 4565 4565 4565 4565** J Ticket 48 hour No. Third Flow Period PSIG Temp. Corr. 033168 · 4940 .5210 Time Deft. .000" Third Closed In Pressure Time Deft. .000" L t-l-O og--~-- 0 1 1105 11 12 13 14 J e No. · 000 .022 PLUGG ]'NG Reodin~l Interval 1252 .000 2998 .0186 .0372 .0558 .0744 .0930 .1116 .1302 .1488 .1570 IL Depth 2998 4521 4548 4559 4563 4565 11,917' · 000 .0852 · 1704 · 2556 · 3408 .4260 2881 3906 Clock No. 92934 · 000 .0512 4488 .1024 4474 .1536 4468 4463 .2048 .2560 4463 4551 4556 4562 4562 4562 hour 48 PSIG Temp. Corr. 4567 .5110 4463 .3072 4562 4570 .3584 4562 4573 .4096 4562 4573* .460E 4562 .527G 4562~ ~0 REMARKS: 50 . * Last interval equal to 5 minutes ** Last interval equal to 39 minutes. Minutes PRINTED IN U.E-~A, SPECIAL PRESSURE DATA I. ITTL. E'I Il,lie 1014 4/l~---lJ, 14-JJ Reversing Sub ..................... Water Cushion Valve ............... 033168 O.D. I. D. 4 3/4" 5" 3¥' 3 7/8" 3 7/8" 3 7/8" 4. 276" 2. 764" 5/8" Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar 3 7/8" VR Safety Joint ................... Pressure Equalizing Crossover ......... 3 7/8" Packer Assembly . . . RT.TS-Hook .Wa.ll ...... 7" LENGTH DEPTH 1.00' 10741.98 ' 1143.65' 11~787' 6.95' 5.10' 11,887' 4.58' 2.65' 2.47' 3.95" 11,893' 11,903' Distributor ........................ · , Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ 2 7/8" .. 3, 7/8" 9,66' 1.05' 11,917' Pa~[~Le~~..Hr-.500 .......... Temp. Recorder Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Case ....... PRINTED IN, ,U./~.A. EQUIPMENT DATA LITTLE'$ 154~1 15M 4/69--15, .... U_N..!_O. N_.._D_ I..L_C_O M.P_A k.': ¥ ,,.G.,.~..!_.___~ E L L_CC. H:.P..L ET !ON. R EPOB T P REP ~ R E D._.B JL~_AS_UR__ED P. ..... EY_._I A ..-T-----~ 0 N TCTAL CeORDINATES ..... C .L _0_.._ _S__U_.R____E_~ )-EP_!H_ _gi~.!G.L..E .... .D_IBE.C.T_I.O~N TVD . SUB ScA LATITU .~E DEPARTURE ....... D_ _I_S.~T fi N_ C E_ 6 '"RIGI_~_L_O.C.A_T.._ED AT ND : __~_7_~ ...... 0 45 '__.S. 34W __ 525 1 __!.5_!_ __S_ .!.2 W __._6__07 0 55 ' S 37 ._ 7.6_0. ¢_5__._0._! S_. 17 W i045 C 40 ' S 8N _1954 lO 0 '__ N _21Z9 ........16 ...... 0 ~_ ....... N..,65 E ............ 216 ..2271 ............. 19 .... O' .......... N 6~E ................ 2255 ~03 19 30' .N 6~ . ... 22~5 _2366 !~_30.~ ....... N__71E ........... 2345 o.00, ..... _!VD_=_ ........... _L_A_T..!TUDE_= ........ .... ............... g;O._.O 3?4.96 275.96 4.06S 2.74W ~.90 S 34.00W 0.000 -2~27 524.93 425.93 7.27S 3.42W 8.OB S 25.22W 0.q14 -2.58 606..~__ ..~_~_7_.?_9_2_ ..... 8_~. 58.5_ ...... _3.~.3..5_W ........ 932.1 _~ ...... ~_1.36W__ _0_- 530 759..9_..Q .......66g.90 10.7QS .... 4-oow._ _ 11~-43_S.__20-51W 0.205 .-2.78 1~44,_8_~__ 945.88 13.99S 4.46W__14.68 S 17.71W 0,071 -2,87 -J,_~_7- . .... _0._.}5__~. __S_ .... 9._.E ....... _!.3!0..8Z ..... 1211.87 16.66S q. O4w 17,~1_5 .... S__ !_3..6_4W ........ ~.076 .............. ,2.15__ _15.~ .g._._~D_~.~ ._S___I_'Z_E ......... !.5_7.1.85 lZ~72.85 19..57S ......... 3.15w 19.82 S 9.16w 0.046 -0 '4 _z _09_ .......N ................... 608. . .......... 2. ........... ]6_.71 2 45' N 53E 1670.78 1571./~8___ ...... 1..7_.57S_ ........ 0.3~.W ........... 1_7.5!,~ ......!.,11~_ 3.261 .............. 1,52 . ]__~ 3.~ ..... 4 __1..5_.E __N_._.57 E ........1733.60 ....... !63.4,60 15~03S .............. 3.577 ............. 15 · 4 ~_._~_S__ !.~,BTE .....2.410 ................ 5.23 ~860 . 7 O' N 60F 1858.66 1759.66 7.~5S~16.877 18.q0 S 66.447 2.19~ 17.5.~_ ~9.2_~ 9 ~5_.~_..~__577 1920.8(, .... !8~_1._.8_~ .... ~,.83S_ ........ 25,367_ ...... 25,~_S_.~5..857 ..... 3.633 ................. 25.41 1.~7 1852.37 O.08N 30.3~E 30.39 N 89.837 6.894 30.18 3.00 ....... !915,00 3.91~ ........... ~2,_~17 ....... ~_.3 ~. 09__._N__85 .?_78 E_ 3.396 42.20 8.72 ........... 2069.72 ................. 22.79N .............. 83.367 ...........86.~ N_ 74.717 ........... 2.737 ............. .ll 2156.71 36.38N llO.07E 115.93 N 71.70E 3.325 105.30 .87 21~6.87 q0.56N 119.9CE 126.58 N 71.B1E 4.406 114,60 .26 .......... 2246.26 ............... 47.40N .... 139.795 ..... 147.61 N. 71.26E ............ 2.119 .... 133,60 .16 ......... 2365.16 60,25~ ............ 187.72E ..... 197.15__~__72.20E ............... 2.981 ........... 179. ~649 2~ 30' N 755 2599.26_ .... ~50Q._,2.~. ...... 7_?.,5.~.N ....~9,_62E~_~ 27!_~5~.2__~___~.,.9~E ......... 3-525 ....... ~_8.Q.~ 3.%_~Q.~_ ....... ~...._767 2726..84 ..... 262.7..~ ...... 99..9.4~-~_.~4.1.567.__~_ ...... 355...8.~__._N ...... ~3.687._.~_ .......... 3.285 .........B28~21.. .292~ 36 3Q' N 757. 27'25..72 ......... 2726,72_ .......... !18..88~ ...... ~12.237 ....... ~29.0~._N_._.7.3,.917 ........... 2,483 ........... 396.32 30'~ , 3.e 15' N 7~ ' 2961.58 2862.58 150.19N 514.657 536.12 N 73.737 1.231 3319 .........38 ..... 15' .......... ~N_~677 ............... 3135.1~ ............ 3036.13 ................ 203.65N .... 6~0.5gE ....... 672.1~.N 72.367 .............. 1.680 ....... _3_6!3 .......~8__15J ..... ~.__677 3208.95 3].09.95 226.39N 694.167 730.15 N 71.9BE 0.000 664.44 ..................................................... . B517 38 O' U 79E 3 2 .9 _0.._ 9_1]'] ]j]~l~:']9~- .... 2~'0.85~'~ .... '756.477 ~---~93,8g--~-~2;3~E .... 5.045 ....... 724]74'-' 3724 B8 15' N 797 3453.47 3354.47 265.31N 882.277 921.30 N 73.267 0.120 847.01 }887 37 ~5~ N 807 3583.21 3484.21 282.44N__979.447 1019.35 N 73.917 0.719 941.64 4!28 40 O' N 81E __3767.83 3668.83 43_83 . 4_~. O' N 835 3957.33 3858.33 306.67N iI32,447 1173.23 N 7z~.847 1.i70 1090.97 327.47N v/13'O-i~--~-b-E-~--~-~-~-~'-~-5--~-f-~-~-~-~E- - ~';'9~ 7 ........ 1256.9]_~..] .~!..._.E L_L____~. 0 N P L E T I 0 N R E P 0 R T PAGE 2 .,EA.SURED__D.._E .... V_ ..... I ..... A.__! .... I .0_~_ ......................................................................... TC, TAL COORDINAT~ES ..... C. L O__S_._U_R E..S ....... DOG LEG SECTI'2N ~P_I.H.~~GLE_ D~R_EC_T.I..ON _T_Y_O ......... _SUB_..SEA__ ~fi~.!__~UDE ..... DE~AR_T.URE_ .... .~IS__Ig~IQE_ ...... 6.N_GLE ........ S~VERITY___D_I.S.TAr','C~._~ 6 ~_,5_ 4._0 _91 .... .0.' N 85.E 4.075.82 3976.82 336.~4N ..... I _404. _4..1E ....... !44~.. 14___N _~6_. 52E ......... !.057 .......... i357 47.5_3.__ _59 .... !.57. ........ N .... 86E ........ _424.0.77 ............. 4141.77 ....... 345.84N _. 1538.84E ..... 1577.23. N _77.33E ................ 0.875 ..... 1490 _5___2_19 37 45' N 89E 4609_.,23 45_!Q,23__.. 3.5_.0.82N .... !824..0_9E .... !_857_,53._.._N 79._!1E ......... 0_,513 ..... 1773 5606 36 o' s 90E 4922.32_ ~823:._32:____3_5.0,82N ..... 2051.57E,,-'/ 20e~'.35 N 80.29E 0.478 i999 _5_9_~_L_ _3_.3 [.5' S 86E__5202,_4~7 ..... 5103._..47_ ._3_.3.8.:0IN_..2234.80E ......... 2260,22___N____S!:..39E ...... !..064 ..... 2182 _6010 . 33 .... O' S 89E 52~.Q..:_'~,~ZL . 5.],_6._1~__~_.4 337.35N 2272.~'7E__2297.28 N 81.55E 2.403 222 r ~_.3 ~ ................................... · ..................... · .................... ....... -6J4 ..... _4...5__ _N__85__E .._5_3_.3_7,67 5238.67 341.86N 2323 84E 2348 85 N 81.63E 3 638 227 .__~_b~ __~_ .... 0_.. N 79E 5499.04 5400.04 363.42~ 2434.76E ~2461.74 N 8i. SIE 1.832 237 -6_6_! 1 40.__zt5' N ZgE 573.4.6-~i-~--~'~-_51635_._i'~i~L _?Oj';_ISN'---_i~263/, _6_9_3._8._: .... <-,0_~.5' N__'_7_9_E ..... 59,~2.37__ _5983.37 442.88N ...... 2843.57E ...... 2877._8.~_._N .8.!-i4E___O,.O00 ....... 277 _7.115 .... _z-tO__1.5' N 80E 6.117._46 ..... 60I;3._~.6_ . __~62,7~N_ 2956.20E ..... 2992.20_~N~_....SI...iOE ..... 9.4.63 .......288 7308 39 30' . N 90E ._6_~_~..~__~_3._~ ..... 6_l~7_,._~,.~ 462o74N 3078.96E 3II3.54 N 81.45E 3.34I 300 7490_ __~.6___.0' S_89..E.__ 6413.63 ...... 63!5-63_. ~60,87N.~-_3185.92E_..__/'_.._32Ig?.os_.._N___.8. I,_76E 1.952 ........ 3II 7804 34 O' S 83E 6673.94 6574.9-~ 439.48N 3360.20E 3368.82 N 82.54E 1.267 328 7980 35 O' S 85E 6818.1I 6719.II 430.68N 3460.76E 3487.46 N 82.90E 0.858 339 ._~L654 39 30'. S 79F 7~.~_~._,..~_~ _.7.2._~_5_.__9_.~ 364..39N 3889.35E__3906.38 N 84.64E 1,206 382 8_9~_8_.____~'~ ...... _0_' _~__.75E 756~.7_~____7..~6..9.7.~._ ___3!8.60~ ....... _4060.25E ...... _4.072,.7..4_____N.__85..51E .... 1. I96 ........... 399 9%9_3__.~_~_ ..... _0__._ _$__72E 7771.85 . 7672.85 276.26N 4190.55E _4199.65 N 86'.22E 1.415 413 9.7__84___ ~ 5_~.0·~ .....S_60E .... ~257,I_4 .... 8.I.~.8,. I4 12_0.05N__ ......... 4488.86E ....... _4 Z,.90_...4._8.._._N_..8.. 8~:._~6... E .... !,088 ....... 99TM' 32~_]~5_~ .... S_6_6_.E ........ _8___4.!~9...5_2_ .... 83~__0.~,__52 78o38.N_ ........ .4__.582..~.TE..__4583,.~.._~_N 89.02E .... 2.427._.4_54 0284 _~.!__0_' S 69E 8679.41 8580,41 6.84N 4730,90E 4730.91 N 89.91E 3.772 470 '0771 30 4§' S 64E 9C98o59 8999.59 93.20S 4957.57E 4958.45 S 88.92E 0.570 493 09~2 32 15' S 63E 9243.21 9144.21 134.63S 5038.88E 5040.68 S 88.46E 0.928 502 o~ °88 _ 0.29 . __ 5,77 . __ 7,,76 4°26 9,.83 0~,'75 7,90 ...... :~24 9.83 7~.18 4.86 5.07 C ~7 2.25 -1076 ~2 30' $ 61.E 9356.23 925.7,.23 169.53S 5101.85E 5104.66 S 88.09E 0.820 127~ 33 30' S 61E 9519.67 9420.67 221.98S 5196.46E 5201.20 S 87.55E 0.510 5088.74 5188.63 DIYI$10H OF OIt AND OAS ANCHORAGE PAGE 3 LEP_T~ _ANGLL_DI~EC]T_I.ON ............. _T.~D ................. _SUB ..... SEA__ LA!!!UDE .... _DEPARTURE_~IS.T_ANCE __~NGL[ ....... S_EVERITY Di.STA ..15.3_8 32_303. _S_6D F__ ._L66__7 31 45' S _5..9_E 1_7_62 ..3_1_1~ S 5_8F .1_9_0B__~_3_0 0 ' S 5_.6_E _ZZ65 _.31._ 0 ' _5____5_5.E___ .24P, 9 30 31' S ~..~ ,..3_0_ 0_' S 48E 97.44.01 __96__4_5.01__ 9.8.,53,7 I_ __97_5__4 _- 71 __q9__3 ~ . _.9_2 9839 -_9_..2 _ 1_0_0_ 6._l~._~_6_ .... 10367 . 37 10.2_~_8_._ 10560,36 10461,~4 107J 4 .._?~5 10675.25 655.02S 5811.53E v 5848.33 S 83.56E 0.646 5848 293.44S 5320.24E/~ 5328.32 S 86.84E 0.428 5319.63 o~ 328.40S 5378.42E 5388.44 S 86.50E 0.712 5381.36 ~ 354.52S 5420.22E 5431.80 S 86.25E 0.761 5425.92 ~ 3~.5,_3_~ .... 5~077_~___~4_~.~.98 ~ 85.__t_~.TE .~_. 104 ....5490. 53 .... D72.~8_~. 5719.75E 5748.32 S 84.28E 0.938 5747.87 .33 .5Z_._83_- 3__z+_' ' E_ ___ ~!V!$!O~ O.~ O!t ~_L~_ ~A$ AN_CHHORAGE ___' ___I_~Z. EJ3J~__C L AT__E_D_~AL U.ES ..... E.D ~... E VE~N_.._!0~_0__._F_~.E_T__ _0_F_ S_U B ..... SEA_ D E P 'T H .... Z _HEASUREQ DEPTH TOI' A L___.C_OOR_D I N_./~. TES M D.=__T VD VER T I CAL TVD SUB SEA LA_T_I_T_UDE _Q_PE.P_~J]&_]~_U_RE . DIFFERENCE CORRECTI. ON 399 _ z~99_ __ ___599_ _ 69.9_ 799 1399 __1599. 1_699 399.00 .............. 300.00 -4.58S ...........~2.85W ~.9.9_o.Q. 0__ 400..00 -6,7!S -37.30W 599_,00 _~00.C0 -8,45S -3 36W ..699_,_00 ........600,00 -9.86S -3,74W 799,~0 _.7_QD,~D -11..~5S~-___~_,_~7~ _8.R9._0_0 ...... 800,C0 ~12,3_.1S -4.23W 999°00 900,00 -1B,46S 109.9,0.~ 1.0.00 O0 -14,53S -4.38w 1~99,00 ........ 1100,00 ............... ,15.54S ........... r4.22W 129.9.,00 .... 1200.00 -16,54S 1..~99o.00___1~00.00 -1.~.._~.6S -3.40W 1599.00 1500.00 ....... ~19.42S ............=2.83W 169.9.,0~ 1600.00 -16.~..3S ..... 1..51E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1800 ................ 1799.00 ..... 1700.00 -ll.OlS ......... 10.52E ................................ 1 ................................. 1 ................................................... ___.1901 ................... 1899.00 2106 ..... ___2211 __Z~.2.~_ 2~ _2 769 .2892. ~Q18 3_1 ~.6. 32._7_3 1800.00 -3.77S 22.38E _. 2 _. 19_9_9_.,..0_0. 1900. · .0_0 .3_.,. O.._Zt.N . _zt..O~ ,=Q..ZF._ 4 2099, O0 ...... 2000,00 ___2199. O0 ..... 2100.00 ......... 27.52N ....... 92.67E .......... 12 ..... 229_9 ,..O_.Q__ 2_200.00 42.07N 124.29E 18 2399,00 ........ 2300,00 ............ 53,31N ............. 161.82E 25 __2.~.9.9 o.00 ....... 2400,00 65.52N 207...C3E 36 · 2599_,._0..0 .2_5.0_0.,._0. 0 . 29_,~_~_ .1~ 259.,_..Z±8 E 50 _2699,00 ........... 2600.00 ............. 95,48N .... 323.67E .......................... 70 _2799°00 ...... 2700,00 ............... 113,76N ........ 393,13E 93 . 2.8.99,00 2800.00 ...... 13.5,_77N 467.47E 119 _~9~9..00 ....... 2900.00 ......... 161..72.~ .... 5.~1,8.0E 147 3~9_,00__~000.00 192.52N 614.37E 174 7 3 5 11 14 2O 26 28 27 3400 3199.00 3527 3299.00 310_.0~00 223~3~N 686.94E 201 3200.00 242.07N 762.73E 228 27 27 ' L'- L/)I¥1~ION OF O!!. AND GAS ........................................................ INI_ERP_OLATEO VALUES. FOR. EVEN..IO0 FEET OF SUB SEA DEPTH MEASURED nFPTH TOT A.L__600RD I NATES MD-TVD .......... VERTICAL ~ .TVD SUB SEA L A.~T_L[UJ2_E___Z)f_~g_~ T U R E QiFFERENCE ..... CORRECTION Ot 3_6.55 .. - _37_81 39O8 _~0.38 __&l_70 4a__9i ........ 4953 _5_Q.8_0 .. 52_0_6 ........ ~77 5698... ~5.9.~.Z ...... ~~_6 ...... 6_56~ .6~6¢.. , 33 99,_ OQ . 3.300 ._0 Q 3_~ 9.9.o O0 . .3(+ 00_'.00_ 3.5~_9 .._OO_ 350.Q._0_0 ~3._6.99..00 ...... 3600..00 3799.00 37_00.00 3899,00 .... 3800,00 257 .... ! IN 271_.32N 916._37E , __28.4. 5..1N ....... 9 92 ._5 ! E 297..6~N ....... 10_7~5 ;_39 E 31D..,~QgN _ , 3 21 ,_06N_ _1249._66E 256 28 ~t 282 26 ;t 309 27 339 30 3_!1 32 406 35 3999_,0Q __390.0,00_ ~.30._6.2N ....... 1337.88E 4099...00 .~000.,.0~ .... 3~7_.76N__ 1423.29E ..&1.9.9_,_.0~__ 8.10_O....QO 42~9.00 ..... h. 200,0.0 ..... 4499..00 ....... ~400.00 .&59.9..00 450.0.00 '4699._00 ..... ~600..Q0____ 4.~99..00 ....... ~.~_00...00 4899.._00 4800.00 3~3_.46~ ....... 1504.80E _346o.63N ....... 1583,..92E 349,3~N ...... 17_38.75E 35.0,.6_~_. _!816.17E _.350.8_2~_ _1889.31E 350...82.~ .... ~961~.97E 350.82N 2034.62E ~2_,~2N__2101.72E 509.9,00 ..519.9,.00 5100.,00 . 52.9~.,.00 5200_.00 ~_39.9.,.09 ...... ~300.00 _5~99_,_.0.~' 5.~00.00 5599~ _ 5699..00 __~.600.,00 ~.99,.00 ....... ~YO0_.O0 5000.00 .......... 342..7.4.N__ .2167,12E 33.8.1Z~ ._2232.52E 339,61.~ ..... 2298.10E 350.05N_ _236~,'00E 363..~1.~_ _.2~34.73E 396o29_.N__ 2603o89E 412,73N .... 2688.47E 439 33 q71 32 ¢ 500 29 528 28 554 26 581 27 607 26 631 24 655 24 678 23 699 21 718 19 738 20 757 19 779 22 8O 83 86 89 .~800.00 ........... ~29..!8N 2773.05E .............. 92 5900.00 445.33N 2857.43E 96 1 22 3 32 5 32 7 32 9 32 1 32 7'0_9.J ,.,722;[ 6__099_,D. 0_ 6000..00 6199.00 6100.00. J~._9_i_,_EE_ 62_00:9_0 _ 460 ,_0 _:3.~___ ._2 950 · 80 E 462.,74N 3023.41E 462.33N 3102..65E 992 B1 ._ 1022 30 1049 27 _~t_LL,,L._ 6_D__~. ? ,L__E__I__I 0 N R E P 0 R T PAGE 3 I.~IERBCLA_TZ_DVALUES_ FOR EVEN 100 FEET OF SUB SEA DEPTH 6-31 WELL ..... 6.OMPL_E~_!O~.gEPORI PREPARED BY SCS 09/26/69 TANGENTIAL METHOD / DEPTH ND-TVD VERTICAL T O.T A L_COOR g !NA T_E_S _ _ TVD SUB SEA J~ITUD_E EEE~R__T_LLRE D._IEE, R~,'-CE . CORB_ECTION _Z&72 · .. 75_93___ 771& '78_3_5 _ 7957 8_6 6399.0.0_ _6300.00 461,06N ..... 31.75,29E 1073 24 6~99,0.0 .... ~4.00.00 453.86N _.3243.07E 1094 21 6.5.99..00 .6500,00 .... ~.45.64N .......3310.02E 1115 21 6699.00 ~600,.0_0__ 437,95N_ _33%7.67E 1136 21 .6899,00 _ __680D.,00 ~21,23N_ .... ~52.7_.,9.7F 1187 29 __.6.999,.0~ .... 690.0°00 .... q.09..54.N ......36t.1.15..E 1217 ~0 84_7_9___ 8609 8735 88:6.0 ___8_9.8_4_ . __9_109__ 2099,00. 7000...QO_ _~97.66_N .... 36~._72E 1249 7.199...00 ........7100.00 385.62N ....... 3780._15E .............. 1280 ZZg_9,.O~ ...... 7200.00 . __ 369o89~ ..... 386!,07E .... 1310 0 · . __ · ?_~ ..... 9. O0 Z.~O0.O0 ~2 2.0~ _4009.49E 1361 7599°00 7500.00 ~12o29N ....... 4079o66E 1385 7699.o0~ .... Y600.O0 291..45N ...... ~1~3_.81E 1406 32 31 3O 26 25 24 21 __92.26 _93~6_ 946.7 .__959_.0_ _9713 · 983% 995_2 _ lO .10.307. ._1.0~2 ~ 106~ . _10¥71 7799.00 ............ 7700.00 .......... 268.89N ........... 4207.12E ........................ 1427 789.9.00 7800.00 .............. 241.71N ....... 4268.16E 1447 .7~_.9~....Q0__ 7.90.Q...OO __Zl_2,...12_~~..3.2~_,_4LE , 1468 ....... 8099.00 ........ 8000.00 ...... 176.45N ....... 4391.18E ..................1491 8199°0Q_ .8100.00 .......... 1~0,79N__ ~452.96E 1514 ~.29~.o.D.D_ .~2.00o.00 ...... 109_,.B1N 4513o00E 1534 .8~99,00 ...... 8~00o00 ............... ~3.65N ........ ~570..64E 1553 8~99o0, Q~ .......8400.00 ~2.88~ ........ 4628o48E 1572 5 859R,.~0 - 8.99.,_~ li,.lJN &¢85.80E 1591 8699°00 ........ 8600.00 ................ 2.56N ......... 4741.50E ...................... 1608 .... 8799.00 ........ 8700.00 ........ -19.28S .........~795.57E 1624 89.9~...,.00 8900..00 . . _,6Z,_~.2S 4904 . 18E 1656 909&,gO 9000.00 -93o32S 4957o80E 1672 21 2O 21 23 23 20 19 19 19 17 16 17 16 J[ ....... z (: 10890 11o98 9199.00 9100.00 -L2__1_,96S 50'1 ,~.E 1691 9299,~ 9200.00 -151.86S 5069.'96E 1709__ 19 18 L~I~VI~iI.1N OP OIL AND ¢DA~ MEASUREQ TO!AL_.COORE INflTES ............... MD-TVD ...... VERTICAL DFPTH 'TVD SUB SEA L~L~_I_Y_UD E _O_EEA~I_U R E D_IFFERENCE CORRECTION ].11.27~ _9399 · O0 11.24.7 ..... _9~ 9 9.00 _113_66__ ......... _9599.00_.___ .11~.85 .......... 9699. OO 11603 9799.00 ___9300,00 ..... r183,26S ........ 5126,61E ............... 9400,00 ...... 7.215.34S .__5184,5.0E ._9500,,..0.0___ _.-_. 247 o25S 524-0.23E _9600,00.__ .=279, lOS ....... 5295.40E 1786 97_0_0.00 - 310._,_9_6S_ 5~_A.,_,..fi.~E 1__804 .9800,_00 . -3.0-2,96S_ 5401.73E 1821 9.900.,00_ ..-37.5,20S__ _5450.o89E 1837 10000° OQ _~_Z~08,31S___ 5499.26E 1853 1728 19 1748 20 1767 19 19 1¸7 16 16 ]2Q69 ~1.Z185 12302 J.2__6A9 1.o. 199, oo .... lOlO0.CO ......... ~442.77S ......... 5548.48E 10£99o00 ..........10200,00 .... m~77.2~S ..........5597.70E 10399.00 103_0_0.00 -5}2.53S 5645~8~E 10_~99.,00 .......1.0400,..00.--5~9,_~3S__5691,65E ..105_~DQ 1~.5Q._0_,9.0_ ~5~_,31S 5736,33E 1935 16 10_6__9_9..,D_0____ I_~6QQ,D0 -625.95S 5779,24E 1950 15 1870 17 1886 16 1903 17 1919 16 io1¥1510N OF OR ANn ~.,,. o _ ' .;~_E_ L_i C_D_JVL_E_L_E_I_!__Q_~___J~_E_P__O_R I --~G~ 1 i~_IERP.~L.A!EDV_.AL.U_E$ _E~R EVE]5.__IO00 FEET OF MEASURED DEPTH UNI_OS_~.II_C_D.~i~_g.~_Y _G~LJ~.~LL COHPLETIO~ REPORT PREPARED ~Y SCS 09/26/69 TANGENTIAL _MEASURED_ TOT A L CO.O_ gD I N/~ T ES N. B-T VD V ERTI CA L DEPTH, IVD gUB_ SEA · LAI_I_T_UD_E___ -J~P_AB_~_LL~E Q_~FFEREN_~E CORRECTION 8 6 --1000 _30.0 G_ 5000 1 1 4 3 116 112 331 215 564 233 749 185 _80.0 Q _9000___ ADDD O_ . llO00 _b 0'2 9. O.O .......... 5.930. O0 449.84N ....... _2883.02E Z6 11. O0 ........75_12.00_ _309.61~ .... ~408.7__.91E 8439. O0 ...... 8340. O0 _.71_~96~ __fi59fi.._06 E 971 222 1167 196 1389 222 1561 172 1708 147 1860 152 [( DIVISION OF OIL AND GAS Drilling Mud Record Baroid Petroleum Services COMPANY Unocal Oil & Gas Division STATE Alaska CASING PROGRAM 13 3/8 ~nch at 5222 ft. WELl G-31 Workover ' COUNTY Kenai 9 5/8 inch at 11595 ft. CONTRACTOR Monopod Platform LOCATION Cook Inlet SEC ~ 'I'INP RNG ~ Inch at fi, STOCKPOINT Rig Tenders Dock DATE 9/9/89 BAROID ENGINEER Kerr/Redford TOTALDEPTH 11,526 ft. DATE DEPTH A/EIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CDC pH FILTRATION ANALYSIS 1989 feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water % ~o Strip ~ Pm Pfl p,ip, CI CA REMARKS AND TREATMENT __ °F _°F 10 min APl __"F 32nds % % % KC 1 Meter F1 Mf I~pm ppm {See Operations Sheet) 7'-22 11524 63.5 ~ FIW 7.5 [4500 Kill well 7-23 10330 63.5 ~ FIW 7.5 14500 Pump Baracarb P' 7-24 10324 63.5 ~ ~ FIW 7.5 14500 Cut tubing 7-25 10322 63.5 ~ ~-~ -- FIW 7 5 14500 Work tbg swed§c 7-26 10245 63.5 I~ ~ m m__, FIW 7.5 14000 Lay down tubing 7-27 10189 64.5 ;;~ 0 [~_~ FIW plus ~% K]I 3 7.5 _)7000 Circ & add KC1 7-28 10325 64.5 ~,~ ~ i mm FIW p us I% K'l 3 7.5 .)5500 Fish out 2 ~ ~_" C) ~ sections of tb( 7-29 10873 64.5 {-~ ,~ ~-m ~ FIW 3 l us ~% K~]l 3 7.5 .~3000 Fish out A-5 pac 7-30 10900 64.5i ~ ~ t-mm FIW 3lus )% K;l 3 7.5 .~4000 Mill on permpac 7-31 10914 64.5 ~ ~ FIW p us )% K;1 3 7.5 25000 Fish out packeF _8-1 11245 64 ~,~' FIW p us )% KJl 3 7.5 25000 Clean out fill '8-2 11247 64 E, m FIW p us ~% KC1 3 7.5 25000 Mill on junk 8-3 11247 64 ~ FIW pilus )% K~I 3 7.5 24500 Wash over 8-4 11223 64+ FIW p~us ~% K]I 3 7 5 24500 Baracarb Pill 8-5 11292 64+ 33 7 5 0/1 FIW p us )% K'I 3 7.5 _)4500 L/D 31~" DP 8-6 11292 64+ 31 4 2 0/1 FIW p us I% Ki'l 3 7.5 .)5000 P/U 5" DP 8-7 11382 64.5' 34 6 8 2/6 FIW plus )% K~'I 3 7.5 _)6000 Wash over 8-8 11526 64.5 36 6 14 :5/12 FIW plus )%'K]l 3 7.5 26000 Add Barazan 8-9 !'1526 64.5 34 5 13 4/10 FIW plus 3% <C1 TR .3 7.5 26000 Hole-~leand oul, to bottom 8-10 11526 65 33 5 13 3/5 FIW plJs 3% CC1 TR 3 7.5 24000 Run cs.q~ log 8.-11 11526 65 30 4 5 1/1 FIW pljs 3% (C1 TR 3 9.0 .10/.80 30000 Squeeze cmt, per 8-12 11526 65+ 29 4 3 0/0 17 I TR 3 11.0 [.1 .2/.9 32000 1440 Drilling cemenl 8-13 11526 65 29 4 4 0/1 14 I TR 3 8.5 .05/.60 32000 1680 Drl out retainer 8-14 11526 65 29 3 4 0/0 14 I TR 3 9.0 .05/.50 )1000 1680 Squeeze cmt twic 8-15 11526 65 29 3 3 0/0 18 I "R 3 9.0 .05/.45 30000 1880 Squeeze cmt twic 8-16 11032 65 28 3 I 0/0 20 I TR 3 11.0 .8 25/.65 32000 154~ Drill out cemeFt .8-17 11072 65 28 FIW witl~KCl TR 3 12.0 31500 Drill out EZSV 8-18 11203 64+ 28 FIW wit) KC1 TR 3 11.0 24000 Drill out EZSV 8-19 11205 64 28 FIW wit~ KCl TR 3 11.0 23500 Test .squeezes 8-20 11067 64 28 FIW wit KC1 TR 3 11.5 23000 Re-squeeze 8-21 11993 64 28 FIW wit ~KC1 TR 3 11.5 ,24000 Re-squeeze 8-22 11067 64 27 FIW wit KC1 TR 2 1!.5 24000 Tes. t squeezes 8-23 11067 64 27 FIW wit KC1 "R 2 12.0 24500 RIH w/RTTS ll :r ',er i Page2 Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM 13 3/8inch at 5222 ft. WELL G-31 Workover COUNTY Kenai 9 5/8mc" at 11595 CONTRACTOR Monopod Platform LOCATION Cook Inlet SEC ~ 13/VP RNG ~ )rich at ft. STOCKPOmT Rig Tenders Dock DATE 9/9/89 BARO~DENOINEER Kerr/Redf°rd TOTAL DEPT, 11,526 DATE DEPTH ~/EIGHT VISCOSITY Yp GELS FILTRATION RETORT ' SAND CEC pH FILTRATION ANALYSIS ~wri e ~' strip Fl Pfl Cl CA REMARKS AND TREATMENT feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Solids Oil ater % Pm P,IPz 1989 __oF _°F 10 min APl °F 32nde % % % KC1 Meter E] Mf ppm ppm (See Operations Sheel) 8-24 11147 64 27 FI~ wi~h KC1 TR 2 12.0 22500 Circ and WOC 8-25 ~11066 64 27 FI~ wiih KCl TR 1~ 12.0 22000 Drlg cmt & reta 8-26 11203 64 27 FI~ wiih KC1 TR 1~ 12.0 22000 Drlg cmt & reta 8-27 11524 64 27 FI~ wiih KC1 TR 1.5. 12.0 22000 Run gage ring O) 8-28 11403 64 27 FI~ w~ih KC1 TR 1.5 12.0 21500 RIH w/EZSV on DI 8-29 11350 64 27 FI~ wiih KC1 TR I 5 12.0 20000 RIH w/EZSV on DI 8-30 11390 64 27 FI~ wii h KC1 ,~_:. TR I 12 20000 RIH w/EZSV on DI 8-31 11347 64 27 FI~ wilh KC1 [g_ TR I 11.5 19500 Drlg on retaine~ 9-1 11508 64 27 FI~ wilh KC1 ~ _T]~ I 11.5 18500 RIH w/EZ Drill 9-2 11509 '64.~. 27 3% KCl/FIW Br ne ¢3,.. -~ ~ 3 17.5 25000 Disolace w/3% Kt 9-3 11509 64¼ 27 3% KC1/FIW Br ne I~ ~ F~_m 3 7.5 23000 Perf 9-4 10847 64¼ 27 3% KC1/FIW Br ne ~ ~ ] {~:] 3 7.5 24000i Set Packer 9-5 10196 64¼ 27 3% KCl/FIW Br ne ~?_ ~ I'I'I 3 7.5 24500) Filter Brine 9-6 10847 64'¼ 27 3% KCl!FIW Br ne ~[ ~ 0 '=", 3 7.5 24000 Perf em ~ ~ ~ 3 7.5 250001 Lay down 9-7 10847 64.4 27 3% KCI!FIW Brine ~ , . . 9-8 10847 64¼ 27 3% KCl/ FIW Bri ne ~ ~ ~! 3 7.5 25000 R~n du~t]__~_ZZ~ 9-9 10847 64{ 27 3% KCl/..FI.W__Brine ~ ~ t"3 3 7.5 24500 Land tubing ~ ~' Nipple down. ~ discharge W/O f ~ 682 bbl s. COmD1 Workover COST COST COST MATERIAL AMOUNT $ MATERIAL AMOUNT ~ MATERIAL AMOUNT $ Barazan 40 15,136.80 Baracarb-5 28 457.80 Workover Additives 51.906.48 Baravis 25 3,389.50 Baracarb-50 49 801.15 Tech. Service 51 20~655.00 ,m Petroleum Services Caustic 3 93.12 Baracarb-15£ 28 915.60 Days @ $405 tDay/Man KC1 673 19,638.14 Baracarb-60C 40 1,308.00 Rework Char.qes 377.74 .iteplug-F 20 1,301.00 PAC-L 10 1,938.70 Kenai BorOu]h Tax 90.00 Liteplug-R 20 1,301.00 9 @ $10.00 each Li teplug-X 15 975'75 Delivery Ch~rqes 284.00 MUD MATERIALS Litesal 25 2,165.75 , .. Used (TOtal) Po 1 ytex-S 2 382.68 Salt 175 1,912.75 DRILLING MUD RECORD SDI Defoam 2 '188.74 ...... TOTALCOST 73~31,3.22 PRINTED IN U.$,A. I ney neF WL tbc. uic ~te TIME Each Horizontal Line Equal to 1000 p.s.i. REPORT and PLAN of OCT ~ 019~9 SUB-SURFACE SURVEY UNION OIL COMPANY T.B.U. 0-31 COOK INLET, ALASKA JOB NO.. AUGUST 1969 DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA ,, DRILLING CONTROL CORP. SNEET No- 1 SURVEY DATA SHEET COMPANY Union Oil Cc~any DATE Auc~ust 1969 JOB NO ..... WELL. T.B.U. G-31 FIELD CoCk Inlet COUNTY STATE, Alaska · TRUE DEVIA~ON DRIFT RECTANGULAB COOBD~ATES ~ASURED DRIFT VER~CAL COUBSZ DIREC~ffON RENLq~ DEPT~ ANGLE DEPTH , NORTH SOUT~ EAST WEST ~ 225 0° 00' 22500 VERTICAL 375 0© 45' 374 99 1 96 S 34° W 1 63 1 10 525 1© 15' 524 96 3 27 S 12° W 4 82 1 72 607 0° 55' 606 95 1 31 S 03° E 6 13 1 71 760 0° 50' 759 93 2 22 S 17° W 8 25 2 35 , 1045 0° 40' 1044 91 3 32 S 08© W 11 54 2 81 1311 0© 35' 1310 90 2 71 S 09° E 14 22 2 39 1572 0© 40' 1571 88 3 04 S 17° E 17 13 1 50 1609 0° 45' 1608 88 48 N 65° E 16 93 1 06 1671 2° 45' 1670 81 2 97 N 53° E 15 15 ] 31 1734 4© 15' 1733 64 4 67 N 57° E 12 61 5 22 1860 7° 00' 1858 70 15 36 N 60° E 4 93 ].8 52 1923 9° 15' 1920 88 !0 13 N 57° E 59 27 02 1954 10° 00, 1951 41 5 38 N 69© E 2 52 32 05 ,.~ 2017 12° 00' 2013 03 13 10 N 73° E 6 35 44 58 2179 16° 00' 2168 75 44 65 N 65° E 25 22 85 05 2271 19° 00' 2255 74 29 95 N 63° E 38 82 111 74 2303 19© 30' 2285 30 10 68 N 67° E 42 99 121 57 2366 ]_9° 30' 2345 29 21 03 N 71° E 49 84 141 45 2493 23° 00' 2462 19 49 62 N 75° E 62 68 189 38 2649 28° 30' 2599 29 74 44 N 75° E 81 95 261 28 2802 33° 30~ 2726 88 84 45 N 76° E 102 38 343 22 2925 36° 30' 2825 75 73 16 N 75° E 121 32 413 89 3098 38° 15' 2961 61 107 10 N 73° E 152 63 516 31 3319 38° 15' 3135 17 136 82 N 67° E 206 09 642 25 _ FOR UNION O ...., C,o,:~H.-,A~i,! ~..;? CAL!FON~TA _Fr. TO ...... 157,2 ...... FT. .---WELL NO. ~ UNION OIL COMPANY OF CALIFORNIA PAGE ALASKA SPERRY-SUN WELL SURVEYING COMPANY SU0-16487 RECORD OF SURVEY TRUE INCLINATION DIRECTION DOG-LEG RECTANGULAR COORDINATES MEASURED VERTICAL SEVERITY VERTICAL · 225. 225.00 ORIGIN AT THE SURFACE 0.00 0,00 37~. 376.98 0 65 S 3~ W 0.00 1.71 -1.62 -1.09 ......... ~g~- ....... g'~'~"~5 1 15 S 12 W 0'~'41 ........................ 4~96 -4.82 607. 606.9/+ 0 55 S 3 E 0.53 6.26 -6.13 1045. 1044.90 0 40 S 8 W 0.07 11.75 -11.55 -2.82 1572. 1571.8~ 0 ~0 S 17 E 0.0/+ 17.i9 -17.12 -1.51 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THE TANGENTIAL OR CHORD METHOD STATE OF ALA3KA AND GAS cONSERYATIC)N CO/VV~AITTEE MONTtU.¥ REPORT OF DRILLING AND WORKOVER OPERATIONS 50-133-20194 ADL 187 30 REL oIL ~ GAB ~ OTHE~ HELL ~-~ ~ELL ~~TOm NA.M~ u~ U~iou Oil of Ca 507 W. Northern Ligh Blvd., Conductor #38, Leg I~2, 1578'N & 1389'W from SE corner Section 29, T9N, R13W, SM. Trading Bay Unit NO, State G-31 (43-28) ~thur IIGII Sect. 28, T9N, R13W, SM. SET 69-72 JOBS iNCLUDING DEPTH ~I~IO~, -28)AUGUST 196~ ' ~ ' . Cmtd ,, h 1 2 cu.ft, perlite per sack, Ran 136 its 13-3/8" 61~ J-55 buttress casing. Hung w/shoe 8 5222' "G mixed wit / cmt returns ~sg head & 12 - · 'on hole for electric log~. - - .~ ~ 667'. Circ& condzt~ .. ~nn, a790'. Hole stickY. directional hoAe ~-**~'-5526', density log_~z,u~ 7~--~--er density Schlumberger DIL_ll, ~_~4~nn hole. PO. Reran ~cnAumu~m · ~I w/drlg assemuz~ .... ,, cfrculated for 9-5/8" casfn~. 1°~ & so~ lo~- ~ID to 11,667N_80 & ~-110 buttress 282 its 9-5/8" ~3.5# & ~7# slips an P · S 1500 tbg head. Reinstalled riser & B0E Tstd 0K. out cmt, shoe 8 11,667'. Circ clea~. Drld 8-1/2" directional hole 11,667' to 11,88~' · Now drilling- here TIT~ ~ ations and must be filed in duplicat lOorra No, P--.4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT liN' DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NA/~E OF OP]~R. ATOR Union Oil Company of Califorlaia 507 W. Northern Lights Blvd., Anchorage, A~aska 4. ~c,mo~ OF 99503 Conductor #38, Leg #2, 1878'N & 1389'W from SE corner Section 29, T9N, R13W, SM. 5. APl HI39,IERICAL ~ODE 50-133-20194 6. LEASE DESiGNA~--ION AND SEEIAL NC). ADL 18730 ?. IF INDIA]4', ALOTTEE OR TRIBE HAME 8. U/%'IT,FA-RAi OR LEASE Trading Bay Unit 9. WELL .NO. State G-31 (43-28) 10. FIF~NDPOOL. ORWILDCAT Mid Kenai "G" McArthur River - West Foreland ii. SEC., T., R., M.. ~O'I~FOM HOLE OBJECT~ Section 28, T9N, R13W, SM. 12. PERMIT NO. 69-72 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CE1VIENTING JOBS INCLUDING DEPTH SET ANT) VOLLrlVIES USED, PE1R/~ORATIONS, TESTS A/ND iR.ESULTS. FISHING JOBS, JLrN'K IN HOLE AND SIDE-/q:L~CKED HOLE AND ;~NY OTHER SIGNIFICANT ~GF.S rN HOL~ CONT)ITIONS. TRADING BAY UNIT STATE G-31 (43-28), J~Ly....1969 SPUDDED @ 6:00 a.m. 7/21/69. Drld 15" hole to 530'. Opened 15" hole to 22" hole to 525'. Ran 13 its spiral weld .312 wall csg. Landed w/shoe @ 520'. Stabbed into duplex shoe w/dp. Cmtd w/650 sx "G" cmt followed by 140 sx "G" w/4% CaCl2. Good cmt retu=ns to surface. CIP 11:00 p.m. 7/21/69. W0C 4 hrs. Released csg. Installed 20" Hydrill. Located top cmt tin 17-3/4""::~@ 513'. Tstd BOE & csg. Drld out firm cmt & shoe. CO to'530'. Drld 12-1/4" hole from 530' - 5219'. Opened 12-1/4" hole to 17" hole from 0' - 5235'. Circ & conditioned hole for casing. Now running 13-3/8" casing. 14. I hereby certify that the foregoing i~tl~le arui correct. . 8/nI69 NOTE--Repo~t on this form ~s required for each calendar month, regardless of the status of operations, a~ must ~ flied in dupikate with the Division of Mines & Minerals by the 15th of the succeedi~9 mo,th, unless othe~ise directed. ' ~, ~ ,, ': Re: 2 coozes.of..."$ !a,.iShOt , ~ ' ' ',! · ~ - :;~'-T.: i -': i.'~ ~::: . I · .'. , · ' :, .';':,' ' .?..:'...'.:.. ...' ,, · . . //. · . , .. :...,¥ ;: ...f:~ ?. ~ ~:X~::?:/::;: · . ,,.,.,, ' , ., ~, , ,/ ..... / - :~ . . . , . . / '' / .' , ~ . ~ . ' ' r . , , ....... ,., ........... . . .... ...... .~-. ........ . , , , ,: ,, , , ''. , , . . . . . ,, , · . . . . ...... . ....~.,~ ~-'7-r~ ~ ~ .~ . . .... - , ............. ..... ,, ,/dp 7/31/59, , , .... ~ .... ,, ,, , , , - . . ... · . u ! / / A~CHO,gAGE 99502 July 25, 1969 Mr. Wade S. McA!ister Union Oil COmpany of California 2805 Denali Street Anchorage., Alaska 99503 Re- Trading Bay Unit - State G-3i (43-28) Union Oil Company of California Dear Mr. McAlister' In reference to 'the subject offshore drill-site the following stipulations are required to protect fish and game resources' 1. No material foreign to the environment will be discharged from IChis platform. This includes garbage~ trash, refuse, petroleum. and/or its products, drilling mud and debris. 2. Drilling operations are not to interfere with commercial fishing. 3. The Habitat Biologist's Office~ 1018 West International Airport Road, Anchorage, Alaska 99502 will be notified prior to the abandonment of this l~'ra~an.~,.....~,.. _ r: =' ~ ~' ~ and/ State.~enu The foregoing provisions do not reliew the !:sse. or his contract:ors or assignees of any responsibilities or provisions required by law or regulation of the State of Alaska or the Federal Government. Si RJW- bb cco B. Hiiliker~ H Burrel P, Denton Robert J enhol d Habitat iologist FORM SA- I B MEMORANDUM State of Alaska FROM: DA T E : ~ 'J~-I~- Jj~jjljj SUBJECT: Form P--1 REV. '50-133- 20194 SUBMIT IN TRIP (Other instructions on reverse side) . STATE OF ALASKA OIL AND GAS CONSERVAIION ,COMMIIIEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1/[. TYPE OF WOIK DRILL ICI DEEPEN [~ PLUG BACK [] b. TYPI OF WELL OIL [~ O&81 F'~ 8INOLE [----] MULTIPI,J ~ WELL WELL OTHER ZONE ZONE 2.NAME OF OPEP~TOR Union 0il Company of California 3. ADDRE~ (~ OPEI:t~TOR 2805 Denali Street, Anchorage, Alaska 99503 LOCATION OF WELL ' Ars.trace CondUctor #38, Leg #2, 1878'N & 1389'W from SE corner ~g~qr~ro~Sz,.y9N, R13W, SM Top "G": 1675'N & 1975'W from SB corner D"fS'~[i~'~'~ I~I'~]~S ,~I~)']~IH~C~'I~.~)'I~ F.'~/~I~I NEABEST TOWN OR POST OFFICE* 23 air mi les NW of Kenai, Alaska 6. I.,EA~E DI~SIGNATION AND SEIIlAL NO. ADL 18730 :::'~:':' ": ~ "'~': .... ..... : L IF INDIAN, AJ_J~'i-rlfil~ OR 'I'I~j~E NAM. R 8. UNIT, FARM OR LEASE NAMI~ Trading Bay Unit ~. W~LL z4o. State G-51 (45-28) 10. FIELD AND POOL, OR wIL~Mi~idle McArthur River - Kenai "G"& 11. SEC., T., R., M.. (BOTTOM West ~ O ~ ~ ~a~ HOLE OBJECTIVE) Sec 28, T9N, R13W, SM 14. BOND INFORMATION: TYPE Statewide Surety and/or No United Pacific Insurance Co. B-55372 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST FROPERTY OR LEASE LINE, FT. (AlsO to nearest dr(g, unit, if any) 5650 ! 18. DISTANCE FROM PROPOSED LOCA~iON* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. . Approx 1400 ' 21. ELEVATIONS (Show whether DF, RT, ~R, etc.) 99' RT above MSL i16. NO~ OF ACRES IN LEASE 38'40 19. PROPOSE'DD~TI~ ' 13~000'MD & ll~100'VD A~O"'? $100,000. O0 ',17. NO. ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL ST/%RT* July 15, 1969 23. P~OPOSED CASING AND CEMENTING PROGRAM ,, , SIZE OF HOLE SIZE OF cASINO WEIGHT PER FOOT GRAD~E SETTING DEPTH ' QUANTIT! OF CE.'WZN'I .... 22!,': 17-3/4" .312 Wall-SpLral WeLd 500' 1000 sacks - cement to surface l~'i 13-3/8". 61#' . J-SS. 5100' 3S00 ." " " '" Circ~ i2-.1/4" .9-5'/8,' 45.5 ~ '~7# N & P 11550' 1500" " " " "$~.~o 8=1/2" 7" Liner 29#, '" N-80 15000-1140'0 400 " " " "~t?z Cement 17-3/4" csg in 22" hole at 500'. Install 20" Hydrill. Drill 12-1/4" directional hole to 5100'. 'Open to 17" and cement 13-3/8" cSg at 5100'. Install BOE. Drill 12-1/4" directional hole to 11,550' (Top of W. Forland). Run electric logs. .Cement 9-5/8" csg at 11,550'. Drill 8-1/2" directional hole to 13,000'TD.-Run electric logs. Cement '7" liner 11,400'-13,000'.. Block sqz above and below Hemlock for zone segregation. Perforate "G" and West Forland. sands. Complete for production through dual 3-1-/2" tbg strings. Bottom Hole Location: 1650'N & 625'W from SE corner Section 28, T9N, R13W, SM IH ABOVE SPACE DII'~C"RIBE i~ROPOSED Pl::~),GRA..M~: If ~1 is W dee~n or plug ~, give ~ on present p~u~ive zo~ ~d pro~ ~produ~ive ~. If propel ~ W drill or d~n d~e~lonally,, give pe~ent ~ on subsu~a~ ~t~ ~d meas~d ~d ~ue ~al ~ep~. Give bl~ut prevente~p~gram. . ~ / r~ . ~ ~4. I ~by ce~at the~mg is (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: ISAMPLES AND CORE CHIPS ar~mxv From the top o~[ cn~xa ~~: _i~Y~ ~ NO the "O" sand to T.D. J See Transmittal Letter DIRECTIONAL SURVEY RE(~ A.P.I. ~CAL CODE , APPROVED ~Y~ _ e,- - TI~. D~rector *See tnmuetio., On Reve~ Side 1969 DA~ July 14, 1969 ?J'// ~ G-19 \ G-5 K _ K-9 ~ G-4 ~K-5 D-I D-7 D-II UNION- MARATHON ,/~ .....~..../e ^~c-- ~TS~ I9N- RI3W -3 D-2 UNION -.MARATI-tC~'I ADL UN ION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION MAP UNION OIL CO. OPERATOR UNION TRADING BAY STATE UNIT 6-31 ( 43-28 ) DATE JUNE 15,1969 SCALE I"= ~.000' 0 ' ' IOOC' ' 2000"' ~,ompany Unl on U1 I bO. Ot ba i 1 ?. ADL 18730 Lease & Well No. TBU G-31' CHECK LIST FOR NEW WELL' PERMITS 2. Do statewide rules apply ........................ 3. Is ac~rvey plat attached .................. 4. Is well located proper distance from property line ........... 5,~ '~Is ~.~ell located proper distance from other wells . . .' ......... 6. Is sufficient undedicated acreage available in this pool Yes No Remarks Is well to be located in a defined pool 7. Is well to be deviated ......................... CKm Se Is operator the only affected party ................... 9. Can pe)"mit be approved before ten-day wait ............... ~ ~ 10. Does operator have a bond in force ................... Jy~a l l. Is conductor string provided ...................... 12. Is enough cement used to circulate on conductor and surface ...... l~, :.Will cement tie in surface and intermediate or production strings . . . 14?'~Will cement cover all possible productive horizons ,. .......... 15. Will surface casing cover all fresh water zones ............ 16. Will surface csg. internal burst equal .5 psi/ft· to next string. 17. Will all casing give adequate safety in collapse and tenSion ...... ~ 18. Does BOPE have sufficient pressure rating ............... Additional Requirements: SCALE t' · 5oo' I 7490' DEPTH- 12, SOUTH- 652.$7' EAST - 5815.10'
