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185-082
PLUGGING & · . . . LOCATION. 'CLEARANCE REPORT State of Alaska.· -..- . · ALASKA OIL & ~AS 'CONSERVATION COMMISSION · · . M~,or-nd,,m To ' File': API] No. Location · .- · ..' Abnd Date · Spud: 511a IS5' · "TD'~ '39J-'~." -, Completed . . Note casing size,, wt, depth, cmt vol, '&.procedure. sfc csg: )%~/~ ~' ~-*.~ ~'-~'!~o' ~/~oo s~. ~-~0 Long Csg:' ~Z/~ ~o3~.5,~./4~ e-,lo' ~"~o,7~5-'~ w/~_ooo S~ . . Liner: ~ ' "' ~ ~' -' - Review the well file, _~d" comment on plugging, well head status, and location clearance - provide loc. clear, code. Plugs: 3G~L~O ~),, ~o~6.0 -['Me.OO~4 Pe~s' To d-z>~T~O~- ~u~oOr ,-~ ,5" . Toc '~' ,5'"~ P. ~ I~'/z" ~P~ ~0~ = bo~, ~c ~ :~.P. ~-3'b© ' ' ' ' _ Well head Cut off: Marker post or plate: Location 'Clearance: Conclusions: code Signed STATE OF ALASKA ' (~~ ALAS-~A OIL AND GAS CONSERVATION'r-,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED]i~r] SERVICE [] 2. Name of Operator 7. Permit Number Union 0il Company of California 85-82 3. Address 8. APl Number P.O. Bo× 190247 5o- 733-20094-01 4. Location of well at surface Leg 4, Conductor ¢/22, 1829'N & 1483' W 9. Unit or Lease Name of SE Cor., Sec 29, T9N, R13W, S.M. Trading Bay Unit At Top Producing lnterval Plugged back total depth - 765'MD, 765'TVD 10. WelI Number 13.5'S and 4.84' W of surface location G-]O RD At Total Depth 11. Field and Pool 3949'MD, 3778'TVD, 886~/S and 332'~_ of surface location McArthur River Field 5. Elevation in feet (indicate KB, DF, et~.~" I 6. ~_ease Designation and Serial No. RT 99' MSLI ADI,-17594 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 5-19-&7 _'~ 5-22-85 7-8-8 5 1'25 feet MSL -0- 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 3949'MD 3778'TVD 765'MD 765'TVD YES]~ NO []I NA feetMD 22. Type Electric or Other Logs Run Temperature, Acoustic, Sonic/Denspac, spinner survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" 1" wall drive surf 362' Drive pipe 16" 75fi J-55 surf 643' 1250 sx C1 "G" G-1 0 ABANDONMENT 13-3/8" 61¥J J-55 surf 3120' 2700 sx C1 "G" 760' 9-5/8" 40,43.5,47¥/ N-80,P-110 surf 10,257' 3000 sx C1 "G" 760' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. Drill pi De i~~EcORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5" 2415' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED SEE ATTACHED FOI,I,OW gHEET 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PI6ODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ 1 , . · Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ . 28. CORE DAT'~ Brief description of lithology, porosity, fractures, apparent dips and presence of ~il, gas or water. Submit core chips. It:- ~!-,..,,. ~.... Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~,~ GEOLOGiCM/~R . : ' .: ::'_ ~ - : :' RM~,TIONTESTS ' . . ; . - · .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · 31. LIST OF ATTACHMENTS 32. I hereby certify th~ the foreg.oing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 G-10 RD WELL COMPLETION OR RECOMPLETION REPORT AND LOG FOLLOW SHEET: CEMENT SQUEEZES All squeezes through perforated 5" drill pipe into 5" x 12-1/4" open hole annulus. DEPTH INTERVAL ( MD ) 1941 ' 1766' - 1768' 4 hpf 1500' - 1502' 4 hpf 1290' - 1292' 4 hpf 1100' - 1102' 4 hpf 828' - 830' 4 hpf 810' - 812' 4 hpf 758' - 760' 4 hpf 688' - 690' 4 hpf AMO~,~ AND KIND OF ~'~ATERIAL USED 2500 sx Cl. "G" cement 2200 sx Cl. "G" cement 3250 sx Cl. "G" cement 4300 sx Cl. "G" cement 3800 sx Cl. "G" cement 3500 sx Cl. "G" cement 3000 sx Cl. "G" cement 5500 sx Cl. "G" cement 8220 sx Cl. "G" cement 1. Top of cement in 5" drill pipe at 765' MD. 2. Top of cement in 5" drill pipe - 12-1/4" open annulus at 608'. 0338N GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB.SURFACE DIRECTIONAL SURVEY Union Oil Company of California COMPANY G-lO ReDrill WELL NAME Gra,ylinq Platform Cook Inlet LOCATION AM585D9 JOB NUMBER Dane Clark Gyro & MWD Tool Readinqs 7/1/85 TYPE SURVEY DATE D i r ecti o nal S u per visor k~~_~. ~.~__~ NAME TITLE SIGNATURE 1QO 3929 DEPTH INTERVAL FROM TO 5/19/85 5/23/85 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any blueprint company. /lUG 1989 Alaska Oil & Gas Cons. Commissl Anchorage G R [:'. A T I.. A i',l D r) ]: R E C 1" I .r) N A I... D R .'1: I... I... ]: I'-I G 'i ~ '~ C 0 fq F' I... E 'i' .1:0 N [',, [:. F' 0 F,, T C [) f'l F' U T IF 13 0 N ? .... 1 "" fi! 5 t.J S I N O R A I..31 U S C) I::' C U F< V A "f' U R E:' F:' F;.' [) I:1 S LJ f;: V I!!: Y r) A'I" A T A I-(E iq 5 .... .1. 7 ..--8 5 I::INAI... CI...OSI..IF<Ii!i I)II?I!::C'1".IiON S 3::.!,,1'2 kl SURVEY TOOL. RF:AI:)].NGS R I-( [!, ,' 9 9,0 ( W E !.. I... '1- E C I.-I iq :1:. Q U I:;:E'C.r.)RI) 01::' ~:~LII:;tVEY A q,.. c,.,.: [ ........... I lg I':' J") t,) i? I:;~ T T C ~ I... '1" f'l UNION OIL. COI'IP('-,NY OF C~I....1:F=OF,.'NiI:A G -.- .1. 0 R E D f;.', ]' I... I.. .1. 00 ,, 0 ) Iq Iii: AS I..) 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I:)~TA ]:N'I-E:I:~I::'OI..ATI:::D I::'OR i::'VIEN 100 I::'1::'1::'"[' 01:." SLJE>,S!::'A DE:'F:'TH M E: A S 1' R U V I::: R '1" c, , . ::> U I:.:. S E'A I~1 [)-.- 1' U D V E: R 'l" ]: C A I... l) I.:':. e T H k') 1::: F' T H I:.) E e '1" J..I I:) :l: [:: e , (?.. 0 F( e E C 1" 99 '~ 9 0 0 0 .1. 99 1. 99 100 0 0 '2. 9> :2 :'299 200 0 0 ?;99 S99 SO0 0 0 499 499 400 0 0 599 .,.,:: c>, o, 500 0 0 6 ? ? 699 600 0 0 799 799 700 0 0 900 899 800 .1. 1. .1. 000 999 900 :1. 0 .I. 1. 0 .1. 1. 202 .1. ;.~ 04 1407 1511. :1.6:1.6 :1.722 1829 1. 9 S 5 2042 2:1.49 2256 ~...S6':> ~.. 2469 '2.575 ,.-..") 788 :?J 00 .1. S :1. 07 :1. 099 .1..1.99 .1. "~ 99 .,,.'., :1. S99 1499 1. 599 :1.699 1.799 .1. 899 1999 '2099 '2.1. 99 ':) "> 99 :.>"*'99 ;. 2499 '>599 ~% .. 2699 '~799 2899 ') 999 1000 ?. :1. .1..1.00 S .1. .1..~:.>. 00 ',5 2 1. S 00 8 S 1400 .1. :2 4 :1. 500 17 1600 2 S 6 1.700 SO 7 :1. 800 S 6 6 :1.900 4:.4 7 200 () '.'.:~ 0 7 2100 57 7 ~.'.. ~'. ~....- :.?. :~00 70 7 2400 76 6 2500 8 S 7 2600 89 6 27O0 96 7 2800 .1. 0 ~:,! 6 2900 108 6 R I:..' i... A 1' .1: V I:.:: C 00 R I:) ]: N A T I:...- S F'ROI'I 14 I:-- I... I._ --.. H Ii:'. A I.') 0.00 0 ,, 00 .1.,,15 S 0,,96 W ~') Z ~') · . .... ,::,,. o 1,,:?~?.W 4.¥>7 S 1,,40 W · ., ,, .:"~ 5 .1. ':: 4 44,,09 S .1.7,,79 W 58.69 S 24.4t".:; W 7 :/,, '.::j 2 S '29 ,, 76 14 99.94 S S5.:.~S W ")'"' S . .1. ,... ~::, 8 .1. 43 40 W 224,2:'.'l S 80 ,, 70 W · ") I::' .,... ,.: <:l ,, ,q.. 5 S 94 ,, 84 W 29 S ,, 78 ,S 108 ,, .1. '? W D A T A I N'1' E R F:' 0 I... A T E' D F:' 0 R E U E N 10 0 F E E T 0 F' S U E?,.'.'.'~ E A r.) E'.' P T H ¥741 S 846 :. I':' ,~,. 6 ,.~ 00 14 :~ S 600 .1. 47 5 R I!.: I... ~ T I V E.: C 00 R D I N A T E I::' R 0 I"~ l.,J E L. I...- H I.E' A 668,, 99 S 70.1., 42 S 73S,,;;~7 S 76-4,57 S 8 5 6.6 0 S G - :t 0 R E [) R I L.. L L'> A TA I N T E R F) 0 L. A T {!il D F 0 R E V {ii' N :L 0 0 0 F Ii.". E T {] F iq li![ A S U R {!il D D }ii' F' T F{ i'"lli.:, h S. T R I.J V I.:.' IR 1' S !J Ii!. S Ii:' A D E' F:' T I"l D r:i' F:' T H D E F:' 'T I..I 1 <)0 <) ? ':'/$; ? 0 C., "" (> 0 0 19 d: ,.'.> :L ~3 61 ...'... . ~,'.. (23, ? ,.2: ..'..: /V Notes; All value~ in feet. Depths shown are TVD. Closure: 940 ft at S 20 dog 3~ min W Bottom hole: TVD 3779 THD 3929 Hagnetic declination: 24 deg 30 min E HORIZONTAL VIEW UNION OIL COMPANY OF CALIFORNIA G-~OREDRILL RADIUS OF CURVATURE SURVEY TOOL READINGS SCALE: ! inch = 200 feet DRAWN: 7-1-85 [ ft x tooo } VERTICAL SECTION 0.25 0.50 0.75 l.O0 1.50 t.75 2.00 2.50 2.75 3.00 3.25 3.50 3.75 4.00 ,~.50 -0.25 J ,RADIUS OF CURVATURE -~-- , jSURVEY TOOL READINGS J I SCALE · t[nch = 500 feet [ .... .. ~ ....... i TVD 3778 T~ 3~29 . 0 0.25 0.50 0.75 t.O0 t.25 i.50 i.75 2.00 2.25 2.50 2.75 Departure ! ftx tooo I G. A. Graham District Operations Manager Alaska District Union Oil and Gas F sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, ,,n August 5, 1985 Alaska Oil & Gas ~2<¢nservation Commission 3001 Rorcupine/~ Anchorage ~/~ 99504 ATT~.V. Chatterton RE' EiVED SUMMARY G-lORD BLOWOUT ,*.\o;~"~ ~; .i. ~'~ '~;_.~ ~ GRAYLING PLATFORM COOK INLET, ALASKA Alaska 0il & ~.~s Cons. Commission Anchorage A gas blowout occurred while redrilling G-lC from the Grayling platform on May 23, 1985. By 6:00 a.m. on May 26, 1985, bridging had occurred and the gas flow stopped. The first "on platform" inspection was performed on May 26th. By July 6, 1985, 36,270 sacks of cement had been pumped through nine intervals in the drill pipe in G-lORD between 1941' and 688' to prevent any subsequent gas flow. The Key Hawaii jack-up drilling rig was in position approximately 1250' south of the Grayling Platform from June 5 to June 11, to provide the capability of drilling a relief well if conditions had warranted. Inspection of the seabed around the platform indicated a depression resulting from the gas and water flow removing seabed material. By August 1, 1985, this depression had been essentially refilled with gravel from Anchorage and Seldovia. The equipment on the platform has been cleaned, inspected, repaired and reinstalled. The pipeline has been inspected and did not suffer any damage. Additional piles will be installed in Leg 1 of the Grayling platform to insure platform stability during the winter ice environment. The professional actions taken by the personnel on the platform during the blowout prevented personal injuries, fire and oil spills. Union received extreme cooperation from all the state and federal agencies involved, as well as oil industry representatives, during this emergency. Ail effected agencies were notified as soon as possible on May 23, 1985. G-lORD Blowout Leg 4 At approximately 11:00 p.m. on May 22, 1985, pulling the drill pipe from a depth of 3929' was begun to replace the drilling bit. At 11:30 p.m., after pulling the bit to 2415', gas bubbles were observed in the Bell Nipple. Flow Page 2 August 5, 1985 C.V. Chatterton through the diverter stopped at about 12:15 a.m. on Hay 23, 1985, indicating that bridging in the well had occurred. Nonessential personnel began leaving the platform by helicopter to the adjacent platforms at that time. Shortly thereafter gas bubbles were observed in the Inlet about 100' to 150' west of the platform. Gas was detected in Leg 1 and the total shutdown of the platform was completed by 1:30 am. The last personnel left the platform at 1:30 a.m. A plume of gas, water and mud from Leg 1 was observed at 2:20 a.m. reaching an estimated height of 600' above sea level. By 6:00 p.m., May 23, flow through Leg 1 had ceased but gas flow continued through the Inlet water column between Leg 1 and 4. By 6:00 a.m., May 24, gas flow had essentially stopped. Apparently, bridging in G-lORD had occurred by 6:00 p.m. on May 23, and gas flow depleted the gas which had entered shallow water sands by May 24. Relief Well cootingeocy If control of G-lORD could not have been obtained from the Grayling platform, an option would have been to drill a relief well to intersect the G-lORD open hole section from a self contained drilling rig, such as a jack-up drilling rig. Mobilization of a relief vessel was begun on May 23. The nearest vessel capable of drilling a relief well was Keydril's Key Hawaii jack-up, located at Seward, Alaska. Keydril immediately agreed to begin mobilizing the Key Hawaii to the Cook Inlet. Crowley tugs in Whittier and Valdez were dispatched to Seward to tow the Key Hawaii to Cook Inlet. Tugs were brought from Seattle to replace the tugs from Whittier and Valdez which had been performing work for Alyeska and Hydrotrain. The Key Hawaii was positioned near the Grayling platform and prepared to drill a relief well if needed. Control of G-lORD was affected by pumping cement into the open hole portion of the wellbore through the drillpipe in G-lORD directly. The need for a relief well did not exist and the Key Hawaii was demobilized from the Cook Inlet. Seafloor Restoration Profiles of the seafloor were run by Besse, Epps and Rotts to determine the degree of seafloor disturbance. It was concluded that the disturbance was sufficient to provide an unacceptable risk to platform stability if a significant earthquake or ice impacts should occur. Manson Construction was contracted to provide cranes, barges, tugs and rock from a location near Seldovia to fill the depression. Additional rock was obtained through the Port of Anchorage and transported to the location via barge. Recent profiles indicated the seafloor elevation has been restored around the Legs and the platform is stable relative to earthquake effects. Additional stability for ice and earthquake impacts will be provided by piling to be placed through Leg 1 G-lORD Control and Abandonment After checking the platform vicinity for explosive gases by boat, an inspection team arrived on the Grayling platform at lO:O0 a.m. on May 25. There was no structural damage to the platform, but seafloor silt covered t~e~ platform top deck up to six feet in thickness. The Susitna barge was contracted through Nortec and outfitted with equipment from local oil Page 3 August 5, 1985 C.V. Chatterton contractors' supplies to cleanup the platform sufficiently to perform control work in G-lORD. Specialty equipment was flown in by charter airplane from Houston, Texas. Representatives of Boots and Coots, Inc., a company specializing in control of blowouts, were contracted to provide consulting services and equipment. By June 7, 1985, the platform had been sufficiently cleaned and repairs had been made to all damaged surface equipment to safely resume work in the down hole portion of G-lORD. An Otis snubbing unit was installed to permit cleaning-out inside the drillpipe. Wireline logs were run in the drillpipe to identify bridges and potential gas accumulations outside the drillpipe. Cement was pumped through the drillpipe to assure complete sealing of the original and any subsequent sources of gas below the seafloor. A total of 36,270 sacks of cement were pumped through nine intervals into the wellbore. The gas blowout of the G-lORD, Grayling platform was a very unfortunate occurrence. However, it did demonstrate that the industry and governmental agencies are well organized to respond to an emergency. This emergency did not result in injuries, fire, or an oil spill, however, the organization was in place to respond had any of these occurred. The following is a brief review of the response with the key governmental agencies. It is not intended to be a complete or detailed review, but does illustrate the outstanding cooperation and response mechanisms now in effect. Alaska Oil and Gas Conservation Commission (AOGCC) C.V. Chatterton (AOGCC) was informed of the blowout at 3:00 a.m. on May 23, 1985, and further briefed at 8:30 a.m. as additional information was available. At least daily updates were provided to AOGCC during the blowout and control efforts. The relief well option, as well as control through G-lORD drillpipe, were reviewed with AOGCC such that any permits, which might have been required by the changing situation, could have been obtained almost immediately. United States Coast Guard (USCG) The USCG was informed at 3:03 a.m. on May 23, 1985, and at 3:15 a.m. Lieutenant Lautenberger, USCG, Anchorage, was further briefed. The USCG immediately imposed a restricted area for mariners in the vicinity of the Grayling platform for safety. Lieutenant Lautenberger was briefed daily on the ongoing status of the situation. He was very helpful in assuring that all Coast Guard regulations concerning the tug, barges, etc. were met or necessary inspections were expedited. Ooug Campbell, USCG Strike Team, informed Union that their equipment was on standby if needed to contain an oil spill from the Grayling platform. Union indicated that there had been no oil spill and no oil spill was anticipated since all wells had been shut-in prior to removing personnel from the platform. The confirmation that the Coast Guard equipment was readily available, if needed, was appreciated. Page 4 August 5, 1985 C.V. Chatterton Fe.d.e.r.a.! .A.y. iation A_dmioistratiqn _(FAA) The FAA set up a restricted flight zone around the Grayling platform by 9:00 a.m. May 23, to minimize the risk of gases being ignited by low flying airplanes. Alaska Department of Environmental Conservation (ADEC) Bob Cannone, Mike Lucky, Pat Syr and Bob Flint were briefed on the blowout at various times on May 23. They were assured that there was no oil spill. During the removal of the silt from the platform, after all flow had ceased, a small amount of oil did enter the Cook Inlet from a broken pipe on the platform. This was properly reported to the effected agencies. E~n. vir_o.nmen,~a~l' .Protection. Agency (EPA) Dwayne Carns and Don Dossett, EPA, Seattle, were contacted relative to emergency approval for mud discharge from the Key Hawaii if drilling a relief well had been necessary. Within an hour, a procedure had been resolved for obtaining this authorization by administrative order. Union developed the required information which would have been submitted by telex had the relief well been required. United States Army Corp.~_of~ Engineers (Corps) The Corps permit to refill the seabed depression was requested and received quicker than the equipment could be mobilized to begin the operation. Since this operation has not been completed, the final seabed status as required under the permit has not yet been submitted. Alaska Department of Fish and Game The Department of Fish and Game was briefed on the blowout status at 11:15 a.m. on Nay 23. They were assured that no oil spill had occurred and safety valves were in each oil well at approximately 300' below the Kelly Bushing. The only governmental problem of which I am aware that occurred in the entire blowout, containment and refurbishment of the Grayling platform was relative to rock movement from the quarry near Seldovia to the barges for transport to the Grayling area seabed. Union's contract with Manson Construction specified that Nanson was responsible for obtaining all permits and authorizations required. Allegedly Manson did not have approval to place the rock in the water enroute to the barges. In summmary, the response of government agencies, oil companies and oil industry contractors to the emergency was an outstanding example of a successful cooperative effort to minimize the risk to human health and life, as well as to the environment, in a safe and expeditious manner. Very truly yours, G.A. Graham GAG:lp/1463o cc: Bill Ross, Commissioner, ADEC Rodney Smith, MMS LEASE DATE 5-11-85 5-12-85 5-13-85 5-14-85 5-16-85 5-17-85 5-18-85 5-]_ 9-85 5-20-85 5-21-85 5-22-85 5-23-85 5/24-27 2/80 TBUS E.T.D. 3,150' 3,150' 3,150' 3,150' 3,150' 2,105' 2,105' 708'/65 1599 '/2 2524'/9 3949'/1. 3949'/0 Moved r i¢ UNION OIL CO. OF CALIFORNIA D R I/LLING RECORD ~,~// G-10 RD WELL NO McArthur River Field FIELD Cont. rig move. NU BOPE. RIH with bit to 2185'. Circ. from G-4 to G-10, rig ~54 to rig ~.55 respectively. Observing platform. Observing platform. POH. Ran GO CCL/CBL to cmt @ 3163'. Logged same. W/TSA csg cutters - cut 9-5/8" csg @ 1185', 60', & 50'. Changed out DCB spool. With TSA csg spear latched csg, jarred, recovered 18.18' 9-5/8" csg. Engaged csg @ 60' - jars failed. POH. Cut 9-5/8" csg @ 90'. Engaged csg w/spear. Jarred & recovered 30.4' csg. Cut csg @ 270'. Engaged & jarred w/o movement. Cut csg @ 150'. Engaged & recovered 59.45' csg. Cut csg @ 220'. RIH w/spear - bridge @ 135'. Tripped for 12-1/4" bit. CO cmt f/135'-150'. Movement noticed on 13-3/8" csg head. Est free to 650'. RIH w/8-1/2" bit to 2167' Circ. POH. RIH w/GO. Perfed 4 hpf with 4" guns from 2214'-2221'. Set Baker K-1 ret @ 2105' Dt~4. Sqzd w/115 sxs cmt. RIH w/multi-string cutter. CUt 9-5/8" & 13-3/8" csg @ 730'. ND BOPE. Jarred on fish w/o success. Recut csgs @ 665' . RIH w/9-5/8" spear. Engaged fish @ 160'. Recovered 625' of 13-3/8" csg with 9-5/8" csg inside. RIH w/9-5/8" spear. Engaged. & jarred fish w/o success @ 665'. CUt 9-5/8" & 13-3/8" csg @ 695'. RIH w/spear. Engaged fish @ 665' & recovered 31' of 9-5/8" csg. With 12-1/4" bit, CO inside of 13-3/8" csg f/665'-675'. RIH w/13-3/8" spear. Recovered 31' of 13-3/8" csg with 9-5/8" spear, engaged fish @ 695'. Jarred w/o success. Welded seal ring between 16" & 20" surf csgs. Welded 20" flange to 16" stub. NU 20" riser, Hydril, & diverter lines. Cut 13-3/8" & 9-5/8" csg @ 720'. RIH w/spear, engaged, & recovered 23.50' of 9-5/8" & 13-3/8" csg. Engaged fish again @ 719'. Recovered 9.56' of 9-5/8" csg only. With 12-1/4" bit, CO csg 13-3/8" f/719'-730'. Cut 9-5/8" & 13-3/8" @ 760'. With 13-3/8" spear, engaged fish @ 719'. Recovered 9.89' of 13-3/8" csg. RIH w/9-5/8" spear @ 730'. Recovered. 30.35' of 9-5/8" & 13-3/8" csg. Top of csg @ 760' (117' of open hole below 16" csg). RIH w/OEDP to 895'. Pumped 30 bbl "dirt magnet" flush followed by 20 bbls H~20, followed by 332 sx "G" cmt mixed with 0.5% CFR-2, & 2% CaC12 in FIW. Disp with 35 cf H20. POH to 514'. Rev out. Braden head sqzd to 550 psi. POH. RIH with 12-1/4" to TOC @ 577'. CO cmt to 640', POH. RIH with kick off BHA. Drld 12-1/4" hole to 708'. Dyna drill f/708'-832'. POH & install Teleco MP.TD tool. RIH & drill f/832'-1236'. POH & LD Dyna drill. PU building assy & RIH. Drld 12-1/4" hole f/1236'-1599'. 5' Drld 12-1/4" hole f/1599'-1664'. Tripped for BHA #4 (locked up). Drld 12-1/4" hole f/1664'-2105'. Twisted off. Jtur~ped pin f/box in 5" DP. RIH with 10-5/8" overshot, extension, cut-lip guide, dressed with 6-3/8" grapple on jars & BS. Engaged{ fish. Grapple slipped off at 300,000.~ pull. POH. RIH with same BHA dressed with 6-1/2" grapple. Engaged & worked fish free. Recovered same. RIH with BHA 934. Drld 12-1/4" hole f/2105 '-2524' . [25' Drld 12-1/4" hole f/2524'-3949'. Well kicked while POH. Unable to contain. Blowout. Abandoned platform. 1 of 8 PAGE NO. , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS UNION OIL CO. OF CALIFORNIA DRILLING RECORD 2of8 PAGE NO LEASE TBUS G-10 RD McArthur River Field WELL NO, FIELD DATE 5-28-85 5-29-85 5-30-85 5-31-85 6-1- 85 6-2-85 6-3-85 6-4-85 6-5-85 6-6-85 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS GRAYLING PLATFO~4 OPERATIONS: 1) Bled well G-16 13-3/8" x 9-5/8" annulus off to zero psi. 2)Checked out and started east side crane. Will change out line. BARGE OPERATIONS: Completed rig up of washdown barge at 2100 hfs, 5-28. Mob'd to location. (ETA Grayling 0700 HRS, 5-29). RELIEF WELL OPERATIONS: "Key Hawaii" presently jacked up off of Chinitna Bay (Homer area). WOW. Weather permitting should be able to move this PM. BARGE OPERATIONS: Mobilized washdown barge to Grayling platform. Rigged up and commenced washdown operations at 1400 hfs. RELIEF WELL OPERATIONS: "Key Hawaii" presently jacked up off of Chinitna Bay. WOW. Bled G-16 back down to 300 psi. Suspended due to weather. BARGE OPERATIONS: Both pipe racks 100% clean. Rig floor 90% clean. Sub base 90%+ clean. Ceased operations at 1600 hrs due t o weather. RELIEF WELL OPERATIONS: "Key Hawaii" presently jacked up off of Chinitna Bay. WOW. BARGE OPERATIONS: WOW till 0300 hrs. Rigged "Susitna" for tow to Nikiski Dock. Sustained minor damage to barge while rigging for tow because of weather. Recovered anchors. Left Grayling at 1130 hrs. Began refit of "Susitna" at 1830 hrs. RELIEF WELL: "Key Hawaii" is presently jacked up off of Chinitna Bay. WOW. BARGE OPERATIONS: 24 hr refit of "Susitna". RELIEF WELL: "Key Hawaii" is WOW in Chinitna Bay. G-10 RD CONTAINMENT: Began washing down derrick. Began replacing 4" diverter lines (one to south, one to west). G-10 RD - Installed 2-4" diverter lines. Installed air lines from barge to rig controls and air tugger. Installed hydraulic line from barge to Koomey. Koomey press brought up from 1600 psi - 2500 psi. Disconnected power leads to rotary. G-10 RD - Rigged up blow down line overboard f/standpipe. Bled press on DP slowly f/800 psi to 500 psi in 10 min. Shut in. Press built to 700 psi in 6 min. Bled DP to 0 psi in 17 min (1207 hr). Left open to atmosphere. Started %3 WAK engine on line at 2000 hrs. Set slips around DP. Broke Kelly @ 2113 hrs. Set back. Stabbed master valve. RU for wireline. %3 WAK down - out of fuel. G-10 RD - Tstd wireline RU & lubricator to 5000 psi. Tstd OK except inboard wing valve on pump-in side of mud cross which tstd to 3200 psi. RIH with GO temp/acoustic tool @ 0130 hrs. Logged temp down. Tools stopped @ 678' ~,~v[. Could not work thru obstruction. Logged acoustic tool out. Mobilized Otis snub unit to Grayling. Began RU of Otis @ 1300 hrs. Cont same thru 2400 hrs. NOTES: WAK #3 fueled and running. Koomey recharged as necessary from "Susitna". One centrifical pump running- powered from "Susitna". G-10 RD - Rigged up Otis snubbing unit. Made up 2.80" OD flat bottom mill with check valve & "N" nipple on 2-1/16" cs Hydrill tbg. Snubbed into DP to 628'. Filled DP thru tbg. Washed DP from 628' to 1242' (did not take any wt). Circulated out some coal in fill. Had some gas from 690'-721'. RIH to 1378'. Washed to 1400'. Pulled to 1370'. Circulated out large amounts of coal and some gas on bottoms up. RIH back to 1400'. Circulated. Snubbed out of hole. Rigging up GO at 2400 hours. 2/8O UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO3 of 8 LEASE TBUS G-10 RD McArthur River Field WELL NO FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6-7-85 6-8-85 6-9-85 6-10-85 6-11-85 6-12-85 6-13-85 G-10 RD - RU GO, tstd lubricator. RIH with acoustic log. Tagged fill @ 1406' ~LM. POH for tool change. Switched to barge power. Logged from TD to surf. Denspac/acoustic/temp/ free pipe. Possible hole @ 852'. RU Dowell. Press up to 1800 psi - no drop. RIH with 2.475" bladed mill on 2-1/16" cs Hydril tbg. Circ @ 1305' @ 2400 hrs. G-10 RD - RIH in 5" DP with 2.475" mill on 2-1/16" cs Hydril tbg. Tagged bridges @ 1400'. Circ bottoms up. Washed thru bridges to 1827'. RU power swivel. Drilled out bridges to 1843'. TLC @ 1843'. DP & tbg on vacuum. POH tbg to 1772'. Pumped + 150 bbls mud, switched to inlet water. Pumped 120 bbls water @ 3 bpm, + 500 psi thru tbg. Switched to 2-1/16" x 5" annulus. Pumped @ 5 bpm, +_ 250 psi. POH tbg @ 1600 hrs. Pumped down 5" DP. RU Gearhart. Quit pumping (total of 2270 bbls pumped). RIH with acoustic/temp survey. Logged temp down, acoustic up. Reran temp - noted press on DP + 300 psi @ 2330 hfs. G-10 RD - Ran temp log. DP press to 350 psi. Ran spinner survey with DP @ 40 psi & pump rate of 5 bpm to 1941'. No indication of holes. Ran acoustic tool to 1941'. Detected fluid level @ 1220' MD. POH. RIH with radioactive tracer survey. Showed. upward movement to 1230' MD to major entry point. Also picked up minor entry pt (+_ 25%) @ 1035' MD. POH. DP press 610 psi @ 2200 hrs, 710 psi @ 2400 hrs. G-10 RD - Maintained DP press below 300 psi. Rigged up Howco unit on deck. Sqzd stage 1 as follows: test both Dowell & Howco to 3000 psi against snub unit wing valve. Pumped 40 bbls inlet water @ 3 bpm. At 1419 hrs, mixed 103 sxs "G" cmt with 2% CaC12 and 1% CFR-2, 16.2 ppg using Dowell. Mixed & pumped 500 sxs "G" cmt with 2% CaC12 & 1% CFR-2 @ 15 ppg. Problems getting to 16.2 ppg CIP @ 1540 hrs. WOC & monitored DP pressure to 2400 hrs. DP press maintained below 300 psi. WOC and monitor pressure to 1525 hrs. Rigged & ran GO temp log to 1941' WLM. Logged cmt @ 1858'. POH. Rigged up Howco & Dowell. Tstd to 3000 psi. Sqz #1, stage 2. Mixed & pumped 500 sxs "G" cmt with 2% CaC12 & 3/4% CFR-2 @ 3 bpm. Disp with 42 bbls inlet water. CIP @ 1755 hrs. Final pump pressure @ 500 psi. WOC. Monitored pressure. Zero press @ 2400 hrs. WOC. No DP pressure from stage #2, sqz 91. Mixed 1500 sxs "G" cmt, 16.1 ppg, stage 03, sqz ~1. Disp with 38 bbls inlet water. CIP @ 1402 hrs. 300 psi final pump press. Press bled to 220 psi in 3 rain to 0 psi in 30 min. No press on DP @ 2400 hfs. WOC. RU GO. Ran temp survey. Top of cmt in annulus at 1743' DP & ~34. Tagged bridge inside DP @ 1856' WL. POH. Ran 2.8" mill on mud motor & 2-1/16" tbg. Tagged bridge @ 1839'. Unable to CO DP below 1927' TM. (Some metal to surf. ) Tstd DP to 3600 psi - OK. POH. Mill indicated junk or reduced ID. RU GO. VDL computer failed. 2/8O UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO, 4 of 8 LEASE TBUS G-10 RD McArthur River Field ,WELL NO. FIELD DATE E.T.D. 6-14-85 6-15-85 6-16-85 6-17-85 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RU GO WL. Tstd tools to 1500 psi - OK against bottom master valve. Ran free pipe log to 1424'. Had poor results due to computer problems. RIH with GO 2" Gowinder tbg gun 2' long 0© phasing 4 hpf. Shot from 1766'-1768' with 500 psi on DP. Bled to zero. RU Howco & Dowell. Tstd all pumps & lines to 4000 psi against bottom master valve. Howco pumped sqz ,%2, stage ,%1 as follows: 1200 sxs "G" cmt mixed with 2% CaC12, 0.75% CFR-2 to a slurry wt of 16.1 ppg @ 3 bpm. Disp with 35 bbls inlet water 2 bpm @ 100 psi. Bled to 0 psi in 3 min. CIP @ 1204 hrs. WOC. Changed out guts in upper master valve. RU GO. Tst temp tool & lubricator to 1500 psi against bottom master valve. with temp tool to cmt in DP @ 1763'. TOC in annulus @ 1698'. POH @ 2400 hrs. RU Otis snubbing unit. Press tstd unit to bottom master valve to 4000 psi - OK. RIH with 2.80" mill, 2-3/8" Navidrill, on 2-1/16" cs Hydril tbg. Tagged cmt @ 1763'. CO cmt to 1785'. Broke thru cmt. RIH to 1833'. Circ to clean hole. Lost circ after 40 bbls. Dowell pumped in to formation 1-1/2 bpm @ 700 psi thru tbg & 3 bpm @ 500 psi down 5" x 2-1/16" annulus. POH. RU & tstd Howco to 4000 psi - OK. Howco pumped sqz ,%2, stage ,%2 as follows: 1000 sxs "G" cmt mixed with 2% CaC12 & 3/4% CFR-2 to a slurry wt of 16.2 ppg @ 2-1/2 bpm @ 100 psi. Displaced with 28 bbls inlet water, 3 bpm @ 300 psi. Press fell rapidly to 100 psi. Disp with additional 6 bbls inlet water, 3 bpm @ 200 psi final (4 bbl disp over theoretical) CIP @ 1210 hrs. Had zero psi 20 min after CIP. WOC. Repaired 2" choke. RU GO temp tool. Tstd same to 1500 psi - OK against bottom master valve. RIH with same to top of cmt in DP @ 1694'. No temp change observed outside of DP. Previous temp change @ 1698'. POH with ~. RIH with Otis snubbing unit 2.8" OD mill on 2-3/8" OD Navidrill & 2-1/16" cs Hydrill tbg. Tagged cmt @ 1644' CO to 1780' & broke thru cmt. RIH to 1833' & circd hole clean. POH 2-1/16" tbg. Press tstd perf @ 1766'-1768' with Dowell to 2500 psi. Tstd OK. RU GO WL. RIH with 2" OD Go winder tbg gun 2' long loaded 0© phasing 4 hpf. Shot 1500'-1502' with 500 psi on DP. Press bled off to 0 psi when gun fired. POH. Rigged on GO. RU Howco & Dowell. Tstd both to 4000 psi. Did sqz ~3 stage %1 as follows: pmpd 20 bbls inlet water with Howco @ 3 bpm @ 350 psi. Mixed & pumped 1000 sxs "G" cmt and 2% CaC12 & 3/4% CFR-2 to a slurry wt of 16.2 ppg @ 3 bpm @ 100 psi. Displaced with 25 bbls inlet water 260 psi final. Press bled rapidly to 100 psi with pumps off. Displaced additional 6 bbls inlet water (total 31 bbls) 4 bbls over displacement. CIP @ 1315 hrs. WOC. Final press after total displacement 260 psi. Bled to 0 after 10 rains. (While WOC, removed wing valves on choke side & chipped cmt out of same.) RU GO WL with temp survey. Tstd against lower master valve, choke & pack off to 1500 psi, OK. Run temp log. Log indicated top of cmt @ 1404' on outside of DP. Found cmt @ 1500' on inside of DP. POH. Rigged dn GO WL. Contd to WOC until 2359 hrs. WOC. RU Dowell & Howco. Broke down perfs @ 1500'-1502'. 10 bbls water used @ rate of 3 bpm @ 375 psi. Sqz ,%3, stage ,%2. Aborted 1st attempt due to plugged cmt hose. Howco mixed & pumped 500 sxs "G" cmt with 2% CaC12, 3/4% CFR-2 16.2 ppg slurry. Disp with 25 bbls inlet water. Final rate of 3 bpm @ 650 psi. CIP @ 0545 hrs. WOC. RU GO. Ran temp survey TOC inside @ 1500' (top of sqz ,%3 perfs) TOC outside @ 1379'. POH. WOC. RU Dowell & Howco. Pumped with no breakdown 27 bbls @ 3 bpm & 400 psi into sqz #3 perfs. Sqz 93, stage ,%3: Howco mixed & pumped 1000 sxs "G" with 2% CaC12, 3/4% CFR-2 16.2 ppg slurry. Disp with 24 bbls inlet water. Final pressure 350 psi @ 3 bpm. CIP @ 1951 hrs. WOC. 2/80 UNION OIL CO. OF CALIFORNIA DRILLING RECORD 5 of 8 PAGE NO~ LEASE TBUS G-10 RD McArthur River Field ,WELL NO FIELD DATE 6-18-85 6-19-85 6-20-85 6-21-85 6-22-85 6-23-85 2/80 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS WOC. Tstd Dowell to 4000 psi. Dowell pumped into well - 3 bpm @ 300 psi. Held 70 psi after pumps down 1 min. Pumped 20 bbls total. Tstd Howco to 4000 psi. Sqz ~3, stage ~4 (1500'-1502'). Howco mixed & pumped 750 sxs "G" cmt with 2% CaC12, 3/4%0 CFR-2, 16.2 ppg @ 4.2 bpm. Disp with 18 bbls inlet water @ 3 bpm, 600 psi final. Press bled to 230 psi slowly after 11 min. CIP @ 0937 hrs. Held 190 psi @ 1215 hrs. WOC. RU Otis. RIH with 3.375" mill on 2-3/8" Navidrill on 2-1/16" cs Hydril tubing. Tbg set down @ 364' RT. CO cmt to 391' RT. POOH for 2.80" mill. RIH with same to cmt @ 1278' RT. CO cmt to 1338' @ 2400 hrs. CO cmt f/1338'-1350' RT. Press tstd DP to 3000 psi - OK. POOH. RU & tstd GO to 1500 psi - OK. On second attempt perfd 5" DP f/1290'-1292' 2" tbg gun, 4 hpf, 0 phase. No breakdown. Pumped into formation 3 bpm @ 400 psi - 20 bbls total. Sqz ~4, stage ~1. Howco mixed & pumped 1800 sxs "G" cmt with 2% CaC12, 3/4% CFR-2, 16.0 ppg. Disp with 20 bbls water @ 3 bpm @ 475 psi - final. CIP @ 1050 hrs. RIH with 3.125" mill on 2-3/8" Navidrill, on 2-1/16" cs Hydril tbg. Tagged cmt scab @ 391'. CO same to 406'. POOH. RIH with 2.80" mill. CO cmt f/1294'-1350'. Circ. POOH. RU & tstd GO to 1500 psi. Ran GO temp log. TOC outside @ 1216'. RU Dowell. Pumped into formation - 3-1/2 bpm @ 600 psi, 25 bbls total. Press bled to zero in 20 min. Sqz #4, stage ~2 (1290'-1292') 2000 sxs "G" cmt with 2% CaC12, 3/4% CFR-2, 15.8 ppg. Disp with 17 bbls drill water. 5 bpm @ 630 psi final. Bled to 300 psi in 5 min. CIP @ 0600 hrs. RU Otis. RIH with 3.125" clutch mill. Tagged cmt seals @ 406'. Milled to 414' @ 4-1/2 hr avg. POH. RIH with 2.80" mill on 2-3/8" Navidrill on 2-1/16" cs Hydril tbg. Tagged cmt @ 1244'. CO cmt to 1350'. Circ. POH. RU tstd & ran GO temp survey. TOC in annulus still @ 1216'. POH. RU Howco. Pumped 3-1/2 bpm @ 700 psi. Sqz #4, stage ~.3 500 sxs "G" cmt with 2% CaC12, 3/4% CFR-2, 15.8 ppg disp with 16 bbls, 5 bpm @ 950 psi. Bled to 320 psi in 5 min. CIP @ 2400 hrs. WOC. Tested sqz @ 1250 psi. RU GO & ran 2" Gowinder 2' long gun, 0 phase, 4 hpf. Tagged cmt in 5" @ 1137'. Tested cmt plug @ 3000 psi. Held 500 psi on 5" DP & perfed @ 1100'-02'. Estab inj rate of 3 bpm @ 1500 psi. Ran 2nd 2" Gowinder 2' long gun, 0 phase, 4 hpf & perfed @ 1100'-02'. Estab inj rate of 3 bpm @ 1000 psi sqz #5, stage #1 - thru perfs @ 1100'-02' with 1500 sxs "G" with 2% CaCl2 & 3/4% CFR-2 @ 15.8 ppg. Displaced with 22 bbls drill water @ final sqz press of 250 psi @ 3 bpm. Press dropped to 100 psi in 5 min. CIP @ 1445 hrs. RU Otis. RIH with 3" junk mill & tagged up @ 409'. Milled cmt to 416'. POOH & PU 2.80 mill. Tagged cmt @ 1102'. Milled out cmt to 1115'. POOH with 2.80" mill. Ran GO temp surv. Loc TOC in 5" annulus @ 1052'. Estab inj rate 3 bpm @ 450 psi. Sqz 95, stage ~2 thru perfs @ 1100'-02' with 1800 sxs "G" & 2% CaCl2, 3/4% CFR-2 @ 15.8 ppg. Displaced with 13-1/2 bbls inlet water. Final sqz press of 325 psi @ 3 bpm. Dropped to 205 psi in 5 min. CIP @ 0900 hrs. RU Otis. RIH with 2.80" mill. Tagged cmt @ 954'. CO cmt from 954' to 1000'. Milled cmt from 1000' to 1080'. Milled cmt from 1070' to 1108'. POOH. Ran-GO temp surv & loc TOC in 5" ann @ 1016'. Broke down form @ 1300 psi. Pumped 3-1/2 bpm @ 2500 psi. Sqz ~5, stage #3 - thru perfs @ 1100'02' with 500 sxs "G" with 2% CaC12 & 3/4% CFR-2 @ 15.8 ppg. Displaced with 13-1/2 bbls inlet water. Final sqz press of 430 psi @ 3 bpm. Press dropped to 280 in 5 min. CIP @ 1430 hrs. RU Otis. RIH with 2.80" mill to 900'. POOH. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO 6 of 8 LEASE TBUS G-10 RD McArthur River Field WELL NO, FIELD, 2/80 DATE 5-24-85 6-25-85 6-26-85 6-27-85 6-28-85 6-29-85 E.T.D. DETAILS OF OPERATIONS, DESCRIPTION5 & RESULT5 Tstd sqz #5, stage #3 to 3000 psi - OK. RU Otis. RIH with 3.00" mill with Navidrill on 2-1/16" cs Hydril tbg. CO cmt scab f/416'-451' Dt~4. POOH. RU GO. Perfed 5" DP f/828'-830' with 2 attempts with 2" - 2' Gowinder, 0 phase, 4 hpf. POOH. Inj rate of 3 bpm @ 1250 psi, sqz 96, stage .~1. 1500 sxs "G" cmt, with 2% CaCl2, 3/4% CFR-2 - 15.8 ppg. Disp with 18 bbls water (5 bbls over disp). Final rate of 3 bpm @ 0 psi. CIP @ 1530 hrs. WOC. RU Otis. RIH with 3" mill. CO cmt scab f/451'-455' DPM. Broke thru. RIH to TOC @ 834' DPM. CO cmt f/834'-860'. Circ. Ran GO temp log. Found TOC of sqz #6, stage ~1 in annulus @ 834'. POOH. Inj rate thru sqz ~6 perfs - no breakdo%~, 3-1/2 bpm @ 350 psi - bled to zero. Sqz #6, stage ~2 1500 sxs "G" cmt mixed with 2% CaC12, 3/4%o CFR-2, 15.8 ppg. Disp with 15 bbls drill water. Final squeeze of 150 psi @ 3 bpm. Bled to zero in 1 min. CIP @ 0930 hrs. WOC. RU Otis. RIH with 3.125" mill, 2-3/8" Navidrill, on 2-1/16" cs Hydril tbg. Tagged cmt scab @ 410'. No circ. POOH. WOC. RIH with 3.00" mill on same BHA to 831' CO cmt to 832'. Lost circ. POOH. WOC. Injected into sqz #6 3-1/2 bpm @ 200 psi - bled to zero in 5 sec. Sqz #6, stage #3 - 500 sxs "G" cmt, 2% CaCl2, 3/4% CFR-2 - 15.8 ppg. Disp with 8 bbls drill water. Final of 3 bpm on vacuum. CIP @ 0330 hrs. WOC. RIH with 3" mill on 2-3/8" Navidrill. CO cmt f/750'-796'. WOC. CO cmt f/796'-860'. RIH with GO temp log. Found TOC in annulus @ 807' & TOC inside @ 855'. Ran GO free pipe log f/855'-surf. Pressured sqz #6 perfs (828'-830') to 3000 psi - held OK. Ran GO 2" 2' Gowinder gun. Perfed 4 hpf, 0 phase f/810'-812'. Zone broke down @ 1600 psi. Injected 3-1/2 bpm @ 1500 psi. Sqz #7, stage ~1 - 1000 sxs "G" cmt with 2% CaCl2, 3/4% CFR-2 - 15.8 ppg. Disp with 13 bbls drill water. Final sqz of 260 psi @ 3 bpm. Dropped to 0 psi instantly. CIP @ 0100 hrs. RU Otis. RIH with 3-1/8" mill on 2-3/8" Navidrill. CO scale f/410'-455'. POOH. RIH with GO temp log. TOC inside DP @ 818'. TOC in annulus @ 804' Injection rate: no breakdown - 3-1/2 bpm @ 250 psi - bled t~ 0 psi instantly. Sqz ~7, stage ~2 1000 sxs "G" cmt with 2% CaCl2, 3/4% CFR-2 - 15.8 ppg. Disp with 11 bbls drill water. Final sqz of 110 psi @ 3 bpm. Bled to zero instantly. CIP @ 2000 hrs. RIH with 3-1/8" mill on 2-3/8" N~vidrill. Tagged cmt @ 804' & milled to 818'. RU GO & ran temp surv. TCC in 5" annulus @ 789'. Inside 5" DP @ 818'. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt scale @ 410'. Milled to 436'. POH. Estab inj rate - no breakdown. Pumped in 3-1/2 bpm @ 150 psi - bled to "0", sqz ~7, stage #3 - 500 sxs "G" & 2% CaCl2 & 3/4% CFR-2 @ 15.8 ppg. Displaced with 8 bbls drill water. Final sqz press 110 psi @ 3 bpm. CIP @ 1500 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tag cmt scale @ 436'. Milled to 479'. POH & changed to 3-1/8" mill. Tagged cmt @ 719' & milled to 818'. RU GO & ran temp surv. TOC in 5" annulus @ 797' inside 5" DP @ 818'. POH. Perfs broke down @ 1300 psi. Inj rate 3-1/2 bpm @ 360 psi - bled to "0", sqz ~7, stage ~4 - 500 sxs "G" & 2% CaC12 & 3/4%o CFR-2 @ 15.8 ppg. Displaced with 9 bbls drill water. Final sqz press 100 psi @ 3 bpm - "0" shut-in. CIP @ 1400 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt scale @ 479' & milled to 547'. POH & changed to 3-1/8" mill. Tagged cmt @ 732' & milled to 818'. UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. 7of8 LEASE TBUS G-10 RD McArthur River Field WELL NO FIELD 2/8O DATE 6-30-85 7-1-85 7-2-85 7-3-85 7-4-85 7-5-85 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RU GO & ran temp surv. TOC in 5" annulus @ 797' inside 5" DP @ 818'. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt scale @ 547'. Milled to 565'. POH. Perfs @ 810'-812', held 3000 psi. RU GO. Ran 2" Gowinder, 2' long run, 0 phase, 4 hpf. Perf from 758'-860'. Estab inj rate. Broke down @ 1200 psi. Pumped in with 2 bpm @ 2700 psi. Ran 2nd 2" Gowinder, 2' long gun, 0 phase, 4 hpf. Reperfed @ 758'-760'. Estab inj rate of 3-1/2 bpm @ 1300 psi. Sqz #8, stage #1 2000 sxs "G" cmt & 3% CaC12 & 3/4% CFR-2 @ 15.8 ppg. Displaced with 12 bbls drill water. Final sqz press of 100 psi @ 3 bpm- "0" shut-in. CIP @ 1300 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged scale @ 360'. Milled to 570'. POH & changed to 3-1/8" mill. Tagged cmt @ 758'. Milled out cmt to 780'. POH. Ran temp surv. TOC in 5" annulus @ 759'. Cmt inside 5" DP @ 780'. WOC. Estab inj rate. No breakdown. Pumped in 3-1/2 bpm @ 280 psi, sqz ~8, stage ~2 - with 1500 sxs "G" & 3% CaCl2 & 3/4% CFR-2 @ 15.8 ppg. Displ with 12 bbls drill water. Final sqz press of 220 psi @ 3 bpm "0" shut-in. CIP @ 0630 hrs. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt scale @ 5' & milled to 145'. Broke thru to 570'. Milled to 645'. POH. RIH with 3-1/8" mill. Tagged cmt @ 686'. Milled to 758'. Milled to 780' with + 75% returns. POH. Temp surv. TOC in 5" annulus @ 692'. Inj rate. No breakdown. Pumped in 3-1/2 bpm @ 140 psi. Sqz #8, stage ~3 - 1000 sxs "G" & 3% CaC12 & 3/4% CFR-2 @ 15.8 ppg. Displ with 8 bbls drill water. Final sqz press of 150 psi @ 3 bpm. "0" shut-in. CIP @ 2300 hrs. WOC. WOC 5 hrs. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt scale @ 390'. Reamed to 645'. Milled from 645'-660' & lost full returns. Milled f/660'-780' with APR 75% returns. POH. Temp survey. TOC in 5" annulus @ 692'. Est inj rate without breakdown - 3-1/2 bpm @ 150 psi. Sqz with 1000 sxs "G" & 3% CaCl2 & 3/4% CFR-2 @ 15.8 ppg @ 4-6 bpm. Displ with 8 bbls drill water. Final sqz press of 180 psi @ 3 bpm & 0 psi & shut-in, sqz #8, stage ~4 in place @ 2100 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill on 2-1/16" cs Hydril tbg. CO cmt f/645'-725'. Ran GO temp survey. TOC in annulus @ 692'. Tstd cmt inside DP @ 725' to 3000 psi - OK. Perfd DP twice f/688'-690' with 2" Gowinder, 0 phase 4 hpf gun. (lst attempt not complete.) Est injection rate of 3 bpm @ 900 psi. Sqz ~9, stage #1 1550 sxs "G" cmt mixed with 2% CaC12, 3/4% CFR-2 - 15.8 ppg. Disp with 11-1/2 bbls water. Final sqz press of 250 psi @ 5 bpm. Press bled to zero @ shut-in. CIP @ 1910 hrs. WOC. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. CO cmt f/692'-725' with 70% returns. Ran Gearhart temp survey. Est TOC in annulus @ 616'. WOC. Reran temp log. Verifying TOC @ 616'. Establish injection rate of 3 bpm @ 200 psi. Sqz #9, stage #2 1200 sxs "G" cmt with 2% CaC12 & 3/4% CFR-2. Displ with 11-1/2 bbls water. Final sqz press 75 psi @ 3 bpm. Final shut-in press was 60 psi. CIP @ 1550 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt @ 695'. CO to 696' & lost returns. Ran Gearhart temp survey. TOC @ 614'. Est inj rate of 3 bpm @ 100 psi. Sqz ~9, stage ~3 1640 sxs "G" cmt with 2% CaCl2 & 3/4% CFR-2. Displ with 11-1/2 bbls water. Final rate of 3 bpm @ 130 psi. Final shut-in press was 80 psi. CIP @ 0900 hrs. RIH with 3-3/8" mill on 2-3/8" Navidrill. Tagged cmt on inside of 5" @ 695'. CO to 725' with no returns. Ran temp survey. TOC @ 600'. WOC. UNION OIL CO. OF CALIFORNIA DRILLING RECORD 8of8 PAGE NO LEASE TBUS G-10 RD McArthur River Field WELL NO FIELD DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7-6-85 7-7-85 7-8-85 7-9-85 7-10-85 0338N/tjp WOC. Sqz %9, stage %4. Est inj rate of 3 bpm @ 100 psi 1450 sxs "G" cmt with 2% CaC12 & 3/4% CFR-2. Displ with 11 bbls inlet water. Final shut-in press 100 psi. CIP @ 0403 hrs. WOC. RIH with 3-3/8" OD mill on Navidrill. Tag cmt on inside of 5' DP @ 696'. CO bridge to 700'. RIH to 725'. POH. Ran Gearhart temp survey log. Log showed TOC in 5" x 16" annulus to be 592'. Estab inj rate of 3 bpm @ 200 psi. Sqz %9, stage %5, 780 sxs "G" cmt with 2% CaCl2 & 3/4% D-31. Displ with 11 bbls inlet water. Final sqz press of 175 psi @ 3 bpm. Final shut-in press 75 psi. CIP @ 2150 hrs. WOC. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. CO cmt f/696'-700'. RIH to 725'. POH. Ran Gearhart temp log & found TOC @ 608'. (Contributed TOC dropping f/592'-608' as being contaminated cmt in 5" x 16" annulus.) Estab inj rate of 1/4 bpm @ 100 psi & 3 bpm @ 175 psi. Sqz %9, stage %6, 1600 sxs "G" cmt with 2% CaC12 & 3/4%0 CFR-2. Displ with 11 bbls inlet water @ rate of 3 bpm @ 350 psi. Final shut-in press 275 psi after 5 min. CIP @ 2230 hrs. WOC. RIH with 3-3/8" mill on 2-3/8" Navidrill. CO cmt stringers f/30'-675'. CO hard cmt f/675'-720'. RIH to 725'. POH. Ran GO temp log. TOC in annulus @ 608'. Tstd perfs f/688'-690' to 2000 psi for 30 min - OK. RIH with 3-3/8" mill on 2-3/8" Navidrill. CO cmt f/725'-765'. Tested perfs @ 688'-690' & 758'-760' to 1900 psi. Rig down snubbing unit and cementing equipment, lay down drill pipe. Offload mud system and pipe racks. Backed off 5" drill pipe @ 58' and lay down same. Install 20", 2000 psi blind flange on starting head. 2/80 Union Oil and Gas Division: Western Region Union Oil Company o' lifornia P.O. Box 6247, Anch°~:age, Alaska 99502 Telephone: (907) 276-7600 union August 2, 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE & MONTHLY REPORT Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of Intention for WD #1, and Monthly Report for G-lORD. Please return the approved Sundry to the undersigned. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST STATE OF ALASKA ALASKA O-,c AND GAS CONSERVATION COke. MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS '1. Drilling well '~ Workover operation [] 2. Name of operator 7. Permit No. UNTON 0TL COMPANY OF CALIFORNIA 85-82 3. Address PO B_OX~7_ ANCHORAGE AK 99502 4. Location of Well at surface 1829'N & 1483'W of SE Cor., Sec. 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 99' RT above MSL ADL-17954 8. APl Number 50- 733-?n09~-0! 9. Unit or Lease Name Trading Bay Unit 10. Well No. G-10RD 11. Field and Pool McArthur River Field For the Month of. 3u!y ,19 ... 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEOM = 58' Retrived drill pipe to 58'. 13. Casing or liner' ru. n ar~c~ quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run Ran Temp Survey f/Surface to 780' Ran Temp Survey f/Surface to 780' Ran Temp Survey f/Surface to 695' Ran Temp Survey f/Surface to 725' Ran Temp Survey f/Surface to 780' Ran Temp Survey f/Surface to 725' Ran Temp Survey f/Surface to 725' 1 6. DST data,-perforating data, shows of H2S, miscellaneous data Sqz'd #8 Stage #2 w/1500 sxs cl "G" #8 Stage #3 w/lO00 sxs el "G" #8 Stage #4 w/lO00 sxs ol "G" Perf'd f/688-690' w/BHPF & Sqz'd #9 Stage #1 w/1500 sxs ol "G" #9 Stage #2 w/1200 sxs el "G" #9 Staqe #3 w/1640 sxs ol "G" 17., here~y cer~~re~ and correct to the best of my knowledge. SIGNED Lawrence 0. Cutting TITLE ENVIRONMENTAL SPECIALISTDATE 07/29/85 NOTE- -Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Union Oil and Gas Division: Western Region Union Oil Company c~_ ~ ~lif(?nia P.O. Box 6247, Ancho~'age, 'Alaska 99502 Telephone: (907) 276-7600 union July 26, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORT & SUNDRY NOTICE Attached is the Monthly Report for G-lORD, and Sundry Notice of Intention for D-29RD, Trading Bay Unit. Please return the approved Sundry Notice of Intention to the undersigned. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SRECIALIST RECEIVED JUL 2 91 5 Alaska Oil &,Gas Cons. Commission '~nchorage STATE OF ALASKA ALASKA Oi~ AND GAS CONSERVATION COM.~,~ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS '1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. UNION 0TL COMPANY OF CALIFORNIA 8.5-82 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20094-01 4. Location of Well at surface 1829'N & 1483'W of SE Cot., Sec. 29, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 99' RT above MSL I ADL-17954 9. Unit or Lease Name Tradinq Bay Unit 10. Well No. G-lORd 11. Field and Pool McArthur River Field For the Month of. June ,19 8_5 12 Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DOEM = 780' MD 13 Casing or liner ru.~%d quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run SEE ATTACHED ADDENDUM RECEIVED 1 6. DST data, perforating data, shows of H2S, miscellaneous data SEE ATTACHED ADDENDUM Alaska 0i! & 6as 00ns. 00mmissi0fi Anchorage , 17. I here~y'cDrtify~~in~d correct to the best of my knowledge. l SIGNED Lawrence 0. Cutting TITLE ENVIRONMENTAL SPECIALIS~ATE 07/2.5/8.5 NOTE-..Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 (15) LOGS RUN AND DEPTH WHERE RUN: Ran Temp/Sonic Log f/Surface - 678'. Ran Temp/Acoustic Log f/678' - Surface. Ran Denspac/Acoustic/Temp/Free pipe Log f/1406' - Surface. Ran Acoustic/Temp Survey f/1843' - Surface. Ran Spinner Survey f/Surface - 1941' Ran Radioactive Tracer Survey f/1941; - Surface. Ran Temp Survey f/Surface - 1941'. Ran Temp Survey f/1743' - Surface. Ran Free Pipe Log f/Surface - 1424' Ran Temp Survey f/Surface - 1694'. Ran Temp Survey f/Surface - 1404'. Ran Temp Survey f/Surface to - 1350'. Ran Temp Survey f/Surface - 1338'. Ran Temp Survey f/Surface - 1108'. Ran Temp Survey f/Surface - 860'. Ran Temp Survey f/Surface - 860'. Ran Free Pipe f/855' - Surface. Ran Temp Survey f/Surface - 818'. Ran Temp Survey f/Surface - 818'. Alaska Oi! & Gas Cons. commissiou Anchorage DST DATA, PERFORATING DATA, MISCELLANEOUS DATA: Sqz'd thru hole in drill pipe at 1035' Sqz'd #1, Stage #1 w/500 sxs cl "G" . Rerf'd f/1766-1768' w/4HRF Perf'd f/1500-1502' w/4HRF Perf'd f/1290-1292' w/4HRF Perf'd f/ilO0-1102' w/4HPF Perf'd f/828-830' w/4HPF Perf'd f/810-812' w/4HPF Perf'd f/758-860' w/8HPF Sqz'd #1, Stage #2 w/500 sxs ¢1 "G". Sqz'd #1, Stage #~ w/1500 sxs ¢1 "G". Sqz'd #2, Stage #1 w/1200 sxs ol "G". Sqz'd #2, Stage #2 w/lO00 sxs el "G". Sqz'd #~, Stage #1 w/lO00 sxs el "G". Sqz'd #3, Stage #2 w/500 sxs ¢1 "G". Sqz'd #3, Stage #3 w/lO00 sxs ¢1 "G". Sqz'd #3, Stage #4 w/790 sxs ol "G". ~Sqz'd #4, Stage #1 w/1800 sxs el "G". Sqz'd #4, Stage #2 w/2000 sxs ¢1 "G". Sqz'd #4, Stage #2 w/2000 sxs ol "G". Sqz'd #4, Stage #~ w/500 sxs ¢1 "G". Sqz'd #5, Stage #1 w/lgO0 sxs ¢1 "G". Sqz'd #5, Stage #2 w/1800 sxs el "G". Sqz'd #~, Stage #~ w/900 sxs ol "G". Sqz'd #6, Stage #1 w/lgO0 sxs ¢1 "G". Sqz'd #6, Stage #2 w/lgO0 sxs el "G". Sqz'd #6, Stage #~ w/500 sxs cl "G". Sqz'd #7, Stage #1 w/lO00 sxs ¢1 "G". /S~z'd #7, Stage #2 w/lO00 sxs ¢1 "G". Sqz'd #7, Stage #3 w/900 sxs cl "G". Sqz'd #7, Stage #4 w/500 sxs ¢1 "G". Sqz'd #8, Stage #1 w/2000 sxs el "G". RECEIVED J U L 2 9 Jg j5 Alaska Oil & Gas Cons. Commission Anchorage Union Oil and Gas Division: Western Region Union Oil Company oi~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union June 18 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE'S Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of Intention for G-lORD, and Subsequent's for G-4RD & A-22. Please return the approved G-lORD Sundry Notice of Intention to the undersigned. LOC/ti Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED JUN2,* ~laska Oil & 8as Oons. Commission Anchora(j¢ STATE OF ALASKA ALASKA...,LANDGASCONSERVATIONC~ .... iMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL[] 7 Permit No 8.5-82 8. APl Number 9. Unit or Lease Name '-~ "' T=adzng Bay Unit G-10RD 11. Field and Pool 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX ~247 ANCHOBAGE AK 99502 4. Location of Well eg 4, Cond. #22, 1829'N & 1483'W of SE Cdr. cc. 29~ T~N~ RiT~ SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT ~9' MSL I ADL- 17~54 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data McArthur River Field NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon J~, Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposedwork, forAbandonmentsee20AAC25,105-170). G-10RD CONTAINMENT OPERATIONS LOGGING HISTORY: 1,) 06/05/85 - Temp/acustic log f/surf - 678', Inconclusive, 2,)06/07/85 - Denspac/acoustic/temp/free pipe logs f/surf - 1406', Showed some bridging and no fluid movement, Inconclusive, 3,)06/08/85 - Temp/acoustic log f/surf - 1843', No detectable fluid movement, 4,)06/0~/85 - Ran spinner/free pipe/acoustic/temp/radioactive tracer f/surf, 1941'. Tracer showed major fluid entry point ® 1230' MD and minor entry ~ 1035' MD. PROPOSED CEMENT PROCEDURE: 1.) Pump + 3000 sxs cl "G" cmt thru D.P. and displace. Resqueeze as necessary. Verify emt. in place thru press, buildup and/o~ CBL. 2.) The following zones, picked f/free pipe log of 06/09/85~ are to be individually shot, 4HPF~ and squeezed as necessary w cl "G" emt plus additives. CBL's wiii be run as necessary for progress evaluation. The zones are: 1880-1882' 1500-1502' 1290-1292' 1100-1102' 828-830' 688-690' ~.) Log analysis will be used for final cement evaluation. 4.) D.P. will be recovered to + 800' so that G-lC can be redrilled at a later date. VFRRAI APPROVAL RECEIVED FROM CHAT CHATTERTON ON 06-10-85. Signed lawrence 0. CuttTng Tide ENVIRONMENTAL SPECIALIST Date The space below for Commission use 06/13/85 Conditions of Approval, if any: BY ION~:E C. ~tfiiTII ByOrderof Approved by COMMISSIONER the Commission Approved C oI~/' R~turn~,c~ Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas Division: Western Region Union Oil Company or-.~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 June 10, 1985 Mr. Chat Chatterton Ak Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: MONTHLY REPORTS Attached are Monthly Reports ¢or G-lORD, 6-4RD, and D-29RD ¢or you in¢ormation and ¢ile. If you have any questions, please feel free to contact me at the telephone number llsted above. LOC/ti Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST AlasKa O~t & Gas Cons. commission Anchomgo ~ STATE OF ALASKA ALASKA C,~ AND GAS CONSERVATION CO .... .¢IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator UNION 0TL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99.502 4. Location of Well at surface 1829'N & 1483' W of SE Cot., Se0.29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 99' RT above MSL ADL-17954 7. Permit No. 85-82 8. APl Number 50- 733-20Q94-01 9. Unit or Lease Name Trading Bay Unit 10. Well No. G-10RD 11. Field and Pool McArthur River Field For the Month of. May ,19 ~5 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations 05-13-85 DEOM=3949' Blowout - 05-22-85 13. Casing or liner rgn and quantities of cement, results of pressure tests Cut & recovered 9 5/8" & 13 3/8" Csg. to 750' Abandoned w/332 sxs cl "G" cmt. ! 14. Coring resume and brief description NONE 15. Logs run and depth where run Ran CCL/CBL from Surface to 3163' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perf'd & Sqz'd f/2214-2221' ~ 4/HPF w/l15 sxs el "G' JUN :if, Alaska Oi! & Gas Cons, Commisslori Anchorage 17. I hereby~f, oregoing~ is true and correct to the best of my knowledge. Lawrence 0 ~NVIRONMENTAL SPECIALIST SIGNED. TITL DATE 06-06-85 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate May 7, 1985 Lawrence O. Cutting Environmental Technician Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502-0247 Re: Trading Bay Unit G-10RD Union Oil Company of California Permit No. 85-82 Sur. Loc. !829'N, 1483'W of SE cr Sec. 29, T9N, R!3W, SM. Btmhole Loc. 795'S, 3117'~ of NE cr Sec. 32, T9N, R13W, SM. Dear Mr. Cutting: Enclosed is the approved application for pe_rmit to drill the above referenced well. If coring is conducted, a brle._ description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except e×perimental logs, velocity surveys and dipmeter g urv ~.v ~q. }-fany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16 05 870 and the regulations promulgated thereunder (wit~ 5 Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as ~ended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. ~--~r. Lawrence O. Lunting Trading Bay Unit G-10RD ~a¥ 7 1. o 5 To aid us in scheduling field work, please notify this office 24 hours prior to commenc~.ng installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, p!esse also notify this office 24 hours prior to co~encing equipment installation so that the Commission may ~itness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yo_o3~s, ~ C. V. ChattertOn-" Chairman o f Alaska Oil and Gas Conservation Co~ission be Enclosure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. Mr. Bill It. Lamoreaux STATE OF ALASKA ALASKA ~,IL AND GAS CONSERVATION Ct. JMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 ____ 4. Location of well at surface Leg 4, Conductor #22, 1829'N & 1483 of SE Cor, Sec 29, T9N, R13W, SM At top of proposed producing interval +_461'S & +_2907'W of NE Cor, Sec 32, TgN, R13W, SM At total depth +795'S & +3117'W of NE Cor, Sec 32, T9N, R13W, SM 9. Unit or lease name Trading Bay Unit 10. Well number G-lORD 11. Field and pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RT 99'MSL ADL - 17594 12. Bond information (see 20 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number HartFord (55534278) Amount McArthur River Field $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line NW 22 miles + 3 ~ 100 ! feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease _+12,000'MD & +__ll,005TVD feet 5116 Acres 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1200' feet. MAXIMUM HOLE ANGLE 2d I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program SIZE SETTING DEPTH Hole I Casing MD .TOP TVD 15. Distance to nearest drilling or completed we~ G-2 +1700 ! feet 18. Approximate spud date 05-15-85 2000 psig@~ Surface A c;r'ln psig@ onnn~t. TD (TVD) i2 i/4'i9 8 1/2'[ 22. Describe Weight >/8" 47# N- 7" 29# proposed program: CASING AND LINER Grade Coupling Length BO&S-95 Butt. [+9900' N-80 Butt +1450 ' Surf I Surf + ~9650' ~9215'+ · i I MD BOTTOM TVD 9900' +9460' 11000' !+lNgOO' QUANTITY OF CEMENT (include stage data) +2000 sxs cl "G" + 192 sxs e! "g" SEE ATTACHED ADDENDUM 23. I hereby certify that the foregoing is true and correct to the best of my knowledge /;>. , SIGNED La-w~hce 0.--Cuttihq z~'~'--,'d T~TL~NVIRONMENTAL SPFC!AI !ST The space below for Commission use DATE 05-03-85 CONDITIONS OF APPROVAL Samples required Mud log required OYES ~ OYES Permit number Approval date 85-~9~ ~,~ /'B~v/~ Rev. 7-1-80 Directional Survey required I APl number i~kYES []NO 50- 733-2009/:-0Z SEE COVER LETTER FOR OTHER REQUIREMENTS *,COMM ISSI ON ER DATE by order of the Commission Hay 7, 1985 Submit in triplicate 22.) PROPOSED PROGRAM G-lORD 1.) 2.) 3.) 5.) 6.) 7.) 8.) Rig up over Leg #4, Conductor #22, TBUS G-lC. ND tree, NU and test Diverter bo =n~ Washover and recover 9 5/8" casing to 1200' or as deep as possible (at least 800'). Perform isolation squeeze above top of 9 5/8" casing. Perform isolation squeeze 100' above squeeze in step #3. WOC. CO to top of squeeze in Step #3. Condition mud and mill ± 60 window in 13 3/8" casing. Spot kickoff plug across window. WOC. Kickoff and drill 12 1/4" hole to + 9900'. 9.) Run and cement 9 5/8" casing. 0.) Drill 8 1/2" hole to +11,000. Cut three 30' cores as directed. - 11 ) Run logs. 12 ) Run and cement 7" liner from +9650'-+11,000'. 13 ) Perforate +800' as directed. - - ) Run dual 3-1/2" completion assembly. ) Rig down. /V u R~?£ ,~vD T£~ T -T ~ 2 ~ 'P~ / .... ::"~ AUXILIARY "~'~ CHOKE L.P. CHOKE MANIFOLD VALVE 2~ POSITIVE_~ CHOKE L.P. VALVES TARGETED TURN A DJUS TABL~E CHOKE TARGETED TURN ~~'"-GAUGE 'TARGETED TURN NOTE' Entire assembly is 3,000psi W.P. mini~mum: upstream of chokes. ' ....... ; ........... CHOKE MANIFOLD GRAYLING PLATFORM , .... --r ....... ~_~,:- UNION OIL COMPANY OF CALIFORNIA · ''.. ,, ALASKA DISTRICT ' ~:~;?-~'-";--~:";~'~;~-~-:~'.)::'; , 12'~ 30OOpsi BOPE ST/' ;K · . _ Flow Line Angled Fill Up Line · Blind Rams 12' 3000psi Shaffer Double Gate ,~-Pipe Rams Hydraulic Operated Valve Check Valve Kill Line Gate or Lo-Torque-,/ ._~ Gate Valve Y"~ G a t e Valve . . . Gate or Lo-Torque ~Choke Lin 5000psi HYDRIL Single Gate with Pipe Rams FOR 12 1/4" HOLE and 9 20" 2000psi X 12" 3000psi Casing Spool ~ ." 5/8" CASiNG":TO~ T. Do REV. DATE B.O.P.E. STACK GRAYLING PLATFORM · UNION OIL COMPANY OF CALIFORNIA _. ALASKA D~STRICT ._~ ~':~:.~': D~Aw. BAW APP'O. SCALE 17 FLOW 2(' LOW PRESSURE '-"SER & 20" 2000psi HYDRIL ASSEMBLY 1/2" HOLE'and 13 3/8" CASING TO LINE 20" FLOWLINE RISER +_7200' 20" 2000psi HYDRIL 20" LOW PRESSURE RISER 20', 2000psi 20 , 2000psi 20" CASING X 20" S.O.W. _.-:-:i _,.:. 20" RISER ASSEMBLY ~'~. -_____j . GRAYLING PLATFORM _~. ~". ..... ' ........... t .:.:,.'"--'ii:- UNION OIL COMPANY OF CALIFORNIA , ' '- ALASKA DISTRICT l, x tO00 ) 0 VERTICAL SECTION · I U.~ON Oi~ORN,A j IjTBU G--IOREDRILL ~ j RADIUS OF CURVATURE ~ J 'WELL PROPOSAL J SCALE: 1 inch = 1250 feet - iL DRAWN: 4-9-B5 G-i. ORd Pi)sses ~nder ~-28 Co 2315 g.~. ~ ~ G-;'~8'~ 2,)50' V.D. 26~' of ~ertic~l Sep~ratio~ .... 0.63 t'.25 -t. BB 2.50 3. t3 3.75 4.38 5.00 5.63 5.25 6.BB 7.50 B. t3 8.75 9.3B iO.O0 ii.25 -0.63 ' i 0 0.63 t.25 i. BB 2.50 3.i3 3.75 4.36 5.00 5.6,3 6.28 6.BB // Notes: All values in feet. Depths shown are TVD. Closure: 3095 ft at S 33 deg 10 min W Bottom hole: TyD 10802 TMD 11124 Magnetic decl[natton: 24 deg 30 min E HORIZONTAL VIEW UNION OIL COMPANY OF CALIFORNIA TBU G-IOREDRILL RADIUS OF CURVATURE WELL PROPOSAL SCALE: ! inch : t250 feet DRAWN: 4-B-B5 WELL· . (~-/~/q~ FIELD CASING STRING BOROUGH CASING AND TUBING DESIGN STATE DATE DESIGN BY MUD WT. I ~ #/q. HYD GR. I .~0 psi/ft. MUD WT. II #/§. HYD. GR. II psi/ft. M.S.P. p,st. CASING SIZE INTERVAL Bottom Top LENGTH DESCRIPTION Wt. Grade Thread w7~ ,,v'.~ lsd, t/. · 77 ~ ~,:?~ ,, ,/J,, 2. ? 3. WEIGHT TENSION MINIMUM W/ BF, , -top of STRENGTH . W/O BF ~ section TENSION lbs lbs 1000 ., TDF //& / 2.';"0 COLLAPSE COLLAPSE PRESS. ® RESIST. bottom tension psi psi CDF '¢//(,-') . ,-,,,.-;/:~'- /./.z ~t770 ?/oO Z5-O INTERNAL BURST MINIMUM PRESSURE YIELD _ psi psi BDF , i _.Il - I J I II ~1 J I i2.140 I0,153 4. 4 6 I TD ' lC) ~ 7 I0 9?04 TO 11,072 / / \ .,. vD ,o,,4, IT/HEMLOCK: # /s / ,o.3,o "x."k N... ,, 22~ I 9876' MD (-9~o) ~'~ ~ .... / ~,~o~' T~ ,~ / / ~ ~ ,~.oo '..~ '. ~ 7' ~o,~' TV~ / / I ~~ ~"'~ ~, ,,~ ' ./ (-~o,5~) / ~ ~ ~ .~-, G-30 3RD-2 vo 1D II ~33 2 ' -- ' D-40 D-4ORD ' v~,o'~o~ D-4 'J 'G-3 RD ~m= / ,zY vD II II ~,o / /vo o.o~, 'Y .,~ I ~:~ ~-~' = =m=~~ . '~'' mm~ ' I : ' m::' '~~TRADI N G BAY U N It/ '/ - L-:- I./.Te N.' / y o-2Z-:.,", i-:' ':' ~McARTHUR RIVER FIELD >~> ~' / ." ,/ ,~, ,o,"~.-~' /'" I PROPOSED =E= ~/~ ,////'/ . I - -- G-lO RD - - u-I~ ~uT I .... . ~..,.:' ,z /' / ~' ~ '1 i =1000 -..:: ". .';:::.:.?:>',:~:.,,~:{~'~ .: FEB. 14,85 PRESENT PROPOSED CASING DETAIL 16',75~',J-55 CASING AT 643' - 13 3/8',61~,J-55 CASING AT 3,120' TOP OF CEMENT 3150' CEMENT RETAINER AT 3250' 4 HOLES 3300' COLLAPSED CASING AT 4500' · TOP 7' LINER AT 10,018' _ 9 5/8",40-~,43.5~ & 47~,N-80 & P-110 CASING AT 10,257' 2 7/8", 6.4-~, N-80 TUBING E.T.D. 11,009' 7',29~,N-80 LINER AT 11,050' T.D. 11,072 G-10 RE[)RILL 7.:, ,,;.?.' :-~ '""~..~ · ,-" ,'.. ~ --.,.. ~...- .," ...,:' :;~ :::;..'~ 13 3/8' WINDOW FROM 1,190~ TO 1.250' DUAL 3 1/2", 9.2~, N-80 TUBING · .. TOP 7" LINER AT 9650' 9 5/8",47-~,N-80 CASING AT 9900' PERMANENT PACKER AT_+ 9850' EST. TOP HEMLOCK AT 9900' -I- 450' of Perforations at intervals Packer at ~ 10,400' · · _+ 250' of Perforations at intervals EST, TOP WEST FORELAND AT 10,500' 7",29~,N-80 LINER AT 11,100' , ii ii i ii ii ii i ii i i! ii ,) Union Oil and Gas Division: Western Region Union Oil Company ol- alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 April 24, 1985 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 PERMIT TO DRILL G-lORD Dear Mr. Chatterton' Attached for your approval is a Permit to Drill for G-lORD, Trading Bay Unit. Please return the approved Permit to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/tj Attachment STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CON, ,IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE ~ ' 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247~ ANCHORAGEs._ ALASKA 99502 4. Location of well at surface Leg 4, ~_onductor #22, 1829' N & 1483' of SE Cor, Sec 29, TgN R~3W, SM At top of proposed producing ~nterval ~ +461'S & +2907'W of NE Cor,~Sec 32, TgN, R13W, SM ~"~ total depth -- -- +795'S & +3117'W o¢ NE Cot, S%c 32, T9N, R13W, SM /I 5~~e-e~"(i~ndic~3~e-KB~-~F et~.)-- X6. Lease designation and serial no. RT 99'MSL I% ADL - 17594 12~7~-on~TnT~or~%tEoo~s~e 2O AAC 25.0251 Natit~nal Fire Insurance Cor~rpany i Type S~ca~cewide Suretyand/ornun~ber Hartf'ord (B5534~,18) - i 13. Distance and direction from nearest town 14. Distance to nearest property or Ieee line NW 22 miles ~ + 3 ~ 100I / feet ! l~.Pr~p~;'~cl~depth (MD& TVD) 17. Num~er of acres in lease / +12,000'MD & +ll,O05TVD feet I ~ 5116 Acre¢ 159. If deviated (see 20~AAC 25.050) ~ 20. AnticiCated pressures o C KICK OFF POINT~ feet. MAXIMUM HOLE ANGLE2i~ I(see 20 A/AC 25.035 ( ) (2) Proposed Casing, g g SIZE CASING AND LINER SETTING DEPTH Hole Casing Weight Grade Length TOP TVD MD BOTTOM TVD I ? Unitorleasename II Tradlng Bay /10. Wellnumber . Uni~ · G-lORD 11. Field and pool McArthur River Field of Amount $200,000.00 15, Distance to nearest drilling or completed well G-2 feet 18. Approximate spud date 05-15-85 2000 psig@ Surface 4500 . psige__~.l~t. TD (TVD) QUANTITY OF CEMENT (include stage data) 22. Describe proposed program: SEE A to the best of my knowledge T~TLCNVZRONHENTAE SPECIALIST DATE 04-24-85 23. I hereby ertif t th, oregcaCn;g '~..9~4~d corl SIGNED Lawrence . u g __ . The space below for Commission use Samples required []YES ~XIO Permit number Mud log required []YES Approval date CONDITIONS OF APPROVAL Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY ,COMMISSIONER DATE by order of the Commission Form 10-401 Rev. 7-1 Submit in triplicate 22.) PROPOSED PROGRAM G-lORD 1.) 2.) 3.) 5.) 6.) Y.) 8.) 9.) i0') 1.) 2.) 3.) 4.) 5.) Rig up over Leg #4, Conductor #22, TBUS G-lC. ND tree, NU OIVg~?~ .,~--~-t~L BOF~ bu 3000 psl. Washover and recover 9 5/8" casing to 1200' or as deep as possible (at least 800'). Perform isolation squeeze above top of 9 5/8" casiig. Perform isolation squeeze 100' above squeeze in step #3. WOC. CO to top of squeeze in Step #3. Condition mud and m111 + 60 window in 13 3/8" caslng. Spot kickoff plug across window. WOC. Kickoff and dr111 12 1/4" hole to + 9900'. Run and cement 9 5/8" casing. Drill 8 1/2" hole to +11,000. Cut three 30' cores as directed. Run logs. Run and cement 7" liner from +9650'-+11,000'. Perforate +800' as directed. Run dual 3 1/2" completion assembly. Rig down. DATE Lease & Well'No, YES NO (1) Fee (2) Loc ~thru '87 (3) Admin ~-~-- Y- ~-~ 4 f' 9. (9~ thru 12) ]0. .dCm- (10 and12) ].2. (13 thru 219 2. 3. 4. 5. 6. 7. 8. Is well to be located in a defined pool .... Is well located proper distance from. property line .................. ~ ~ Is well located proper distance from Other wells ................ ,...{ 4__ Is sufficient undedicated acreage available in this pool ............ / ~_ Is well to be deviated 'and is wellbore plat included ................ Is operator the only affected party ................................. ~. Can permit be approved before ten-day wait ........................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed .................................... Is the lease number appropriate ..................................... ~ ] '3. ]4. ~5. 56. :,7. f'.9. 21. Is conductor string provided ........................................ Is. enough cement used to circulate on conductor and surface· ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ...................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, .tensicm and burst.. Is this well to be kicked off from an existing weilbore ; ............ Is old wellbore abandonment procedure included on 10-403 ...... . ....... Is adequate wellbore separation proposed ............................ REMARKS (5) B'OPE ~-~ q-30-SS' (22 thru 26) / / 22. 23. 3;14. :!5. 26. 2 7. Is a diverter system required ............... ' ....................... ~J/./. Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~ooo psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) '~ Is the presence of H2S gas probable .................. ............... Additional requirements Additional Remarks: ~t .,,/Jif 0 Geology: Engir~eering: HW~ ~ LCS ~BEW / WVA MTM, HJH JAL rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE
