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Home My WebLink About178-004 Page 1 of 2 Schwartz, Guy L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Monday, September 10, 2012 8:35 AM To: McMains, Stephen E (DOA) Cc: Schwartz, Guy L (DOA) ( ) , Subject: FW: G -29RD (PTD 192 -052) K -23 W0 (PTD 178 -004), K- 24RD2(PTD 201 -141) Steve, � - -_ After we talked this morning, I looked back through my emaiis and found the basis of why we submitted the 404 on K -23. 1 We can do it either way, just please advise what you would like to see. Be aware that we have two more wells with a similar situation that we will need to file 404's on if you decide that this is the correct path (K -24RD2 and G- 29RD). Thanks, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907- 777 -8420 SCANNED LIAR 0 4 2013 C 985 -867 -0665 From: Ferguson, Victoria L (DOA) Finailto: victoria.ferquson(aalaska.govl Sent: Friday, August 24, 2012 11:56 AM To: Mike Dunn; Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: RE: G -29RD (PTD 192 -052) , K -23 WO (PTD 178 -004), K- 24RD2(PTD 201 -141) Mike and Ted, For these wells, please submit an email note(like note from Mike on G -29RD below) on your plan of action(run kill string). A new sundry 10 -403 will not be necessary for the kill string. However, a 10 -404 for the work to date will need to be submitted as well as a new 10 -403 when you have a plan for further well work. Thanx, Victoria From: Mike Dunn Jmailto:mdunn(ahilcorp.coml Sent: Thursday, August 23, 2012 10:03 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Regg, James B (DOA); Wayne Biart - (C) Subject: G -29RD (PTD 192 -052) - suspend wellwork 9/10/2012 Page 2 of 2 Guy and Victoria, The fishing challenges on G -29RD have prompted us to suspend rig operations to give us time to rethink the plan forward. By tomorrow we will have run 2000' of 4 -1/2" tubing as a kill string and install the X -mas tree. While the rig is on the other side of the platform will run a video camera and put together a fishing plan. We expect to come back to this well in October. We have not changed the basic scope of the wellwork, only the duration. We will be moving over to well G -01RD and would expect a BOP test around Sunday or Monday if the rig moves goes well. Wayne Biart will notify Jim and the inspectors when he has a better handle on timing of the BOP test. Thanks, Mike Dunn i Senior Engineer Hilcorp Alaska, LLC Office: (907) 777 -8382 Mobile: (907) 351 -4191 9/10/2012 STATE OF ALASKA ALWA OIL AND GAS CONSERVATION COM1PSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ ,/, Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubin 4./ 0 4 LStimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Ej Exploratory ❑ 178 -004 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20313 -00 7. Property Designation (Lease Number): 8. Well Name and Number: Trading Bay Unit / ADL0018730 Trading Bay Unit / K -23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A McArthur River Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,700 feet Plugs measured 14,660 feet true vertical 9,831 feet Junk measured N/A feet Effective Depth measured 14,660 feet Packer measured 12,040 feet true vertical 9,813 feet true vertical 8,423 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 384' 24" 384' 384' Surface 5,005' 13 -3/8" 5,005' 3,959 3,450 psi 1,950 psi Intermediate Production 12,482' 9 -5/8" 12,482' 8,699 8,150 psi 7,100 psi Liner 2,534' 7" 14,700 9,831 8,1E I Y 020 si Perforation depth Measured depth See Schematic feet SEP True Vertical depth See Schematic feet +(/��(�'�+ AOGCC Tubing (size, grade, measured and true vertical depth) 4 -1/2" L -80 / 12.6# 12,189' (MD) 8,516' (TVD) 12, 040' (MD) Packers and SSSV (type, measured and true vertical depth) WD Packer 8,423' (TVD) SSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 0 Subsequent to operation: 0 0 0 0 8 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ■ Sundry Number or N/A if C.O. Exempt: 312 -237 Contact Ted Kramer Printed Name Ted Kramer Title Sr. Operations Engineer Signature ,."7-2--‘_____- Phone 907 - 777 -8420 Date 9/7/2012 Form 10-404 Revised 11/201 SEP 1 0 2012 iiiC v Ii2'' Submit Original Only H . • Trading Bay Unit Well # K -23 SCHEMATIC Actual Completion 2/28/88 Hileorp Alaska, LLC CASING AND TUBING DETAIL RKB to Hangar = 33.75' SIZE WT GRADE CONN ID TOP BTM Hangar Type:FMC 4 -1/2" BTC 24" Driven Surf. 384' J l 13 -3/8" 72 & 68 K -55 Butt 12.415" Surf 5,005' 9-5/8" 47 5 -95 Butt 8.681" Surf 12,482' 7" 29 L -80 BTC KC 6.184" 12,166' 14,700' 1 Tubing: 4 -1/2" 12.6 L -80 BTC 3.958" 10,198' 12,189' JEWELRY DETAIL NO. Depth ID Item 1 3,002" 4 -1/2" Kill String 2 12,038' Locater Seal Assembly (Seals- 18.27 +mule shoe - 0.98') Top of Cut/ Fish @ 10,198' 3 12,040' Ottis "WD" Perma -Drill Pkr. W/ 5" bore i I 4 12,042' Seal Bore extension (0.60 +19.51 +0.47= 20.58') D 5 12,156' 3.75 CAMCO "DB -6" No -Go Nipple 6 12,189' OTTIS 4 -1/2" WL re -entry guide I) 7 12,189' 4 -1/2" Tubing Tail Gas Lift Mandrels >< 2 NO Depth ID Item 4>< 3 7 10,404' 2.867" Camco MMG MA, JMR -2, RK Latch 4 8 11,162' 2.867" Camco MMG MA, JMR -2, RK Latch 9 11,981' 2.867" Camco MMG MA, JMR -2, RK Latch g PERFORATION DATA Zone Interval FT SPF Date Comments 14,100' - 14,110' 10 4 2/23/1988 Reperf 7/7/92 5 B-1 14,110' - 14,158' 48 SQZD 4/23/1978 SQZD 2/23/88 L � 14,179' - 14,209' 10 4 to 8 9/26/1980 Reperf 2/28/88 L ,6 B -2 14,263' - 14,288' 25 4 2/28/1988 7 14,295' - 14,330' 35 4 2/28/1988 14,350' - 14,360' 10 4 2/28/1988 Reperf 7/7/92 14,375' - 14,385' 10 4 2/28/1988 Reperf 7/7/92 I3 B - B-3 14,420' - 14,430' 10 4 2/28/1988 ' 14,442' - 14,450' 45 4 2/28/1988 B - B -4 14,450' - 14,487' 37 4 2/28/1988 B -3 B -4 PBTD = 14,660' TD = 14,700' MAX HOLE ANGLE = 70° @ 13,265' REVISED by TDF: 9/6/12 • • 11 Hilcor p Alaska, LLC (-73,_ c04- W ell Operations Summary Well Name API Number Well Permit Number Start Date End Date K -23 507332031300 178 -004 6/9/12 8/9/12 Daily Operations: 06/09/12 - Saturday R/U coil unit. 06/10/12 - Sunday Test bop's, low 250, high 4,000, hold & chart for 5 min each. AOGCC witness waived on 6 -6 -12 by Jim Regg. P/U injector m/u lubricator, install connector & pull test t/ 22k. P/U 2 -7/8 BHA w/ 3 -5/8 mill. Stab injector on well & fill coil & p /t. Open well check sssv open, set tool depth. RIH t/ 450' est circ. w/ FIW & N2, wash in hole t/ 6,700' @ 50 fpm adjusting as needed, pump gell pill every 3,000'. wt ck every 1,000'. 06/11/12 - Monday Cont. wash in hole w/ FIW & N2, t/ 12,043', wipe f/ 8,000' t/ 7,000'. Pump gell pill every 3,000', wt ck every 1,000', restrictions @ 8,408' & 11,938'. String movement restricted, hung at 12,019'. Cont. wk string until free. Wipe hole 300', wash down T/ EOT 12,190'. Start wiper trip, pooh t/ 11,650' pull tight, S/O 100'. Cont. wk pipe up t/ 11,670'. Lost down movement, stuck @ 11,670'. Cont. wk pipe & pump pill around. S/d fluid pump, cont. pump N2 t/ evacuate coil. Shut in N2 & well. Cont. wk pipe holding in static up, dn, & neut. positions. Line up & pump down the ann. attempt t/ wash down free, pump @ 2.5 bpm. S/d pumping, cont wk pipe. & monitor hole. 06/12/12 - Tuesday Continue attempting t/ free coil. Mix 30 bbl safe lube pill, pomp and spot at bha 11,670' & up hole. Let pill sit, r/u iron t/ bleed off N2 f/ coil and work pipe. 06/13/12- Wednesday RIH f/ 11,670' t/ 12,209' tag light. Line up pump 2x tubing vol f/ 11,670' down annulus. @ 2 bpm. Pull up t/ 11,675', tag w/ 2,500 over x2, tag w/ 4,500 got hung up. R/u pump 10% hcl acid pill, pump accross hang up point @ 1 bpm, shut down let soak 20 min. Pump down annulus. Attempt t/ pull through restriction @ 11,670' no go. Monitor well and stand by for e-line unit. 06/14/12 - Thursday Monitor well. Waiting f/ a -line unit. 06/15/12 - Friday R/U a -line tools. RIH through BOP stack tag inside BHA no go @ 11,651'. P/U 6" above top of BHA fire cutter and POOH. Cutter not fired. R/D and get new cutter. R/U tools & arm cutter and RIH. Tag inside BHA no go @ 11,651'. P/U 6" above top of BHA fire cutter. Signs that cutter fired. RIH t/ 11,659' no wt loss. POOH w/ a -line and verified cutter shot. R/D a -line. P/U injector, install coil coupler and stab injector on prep t/ POOH. POOH t/ 1,000'. R/U & blow down coil w/ n2 and finish POOH. R/D injector. 06/16/12 - Saturday RIH through BOP stack w/ 2.25 swedge, tag 11,332' and POOH. RIH on slick line w/ 2.0 drive down bailer t/ 11,334'. POOH w/ sample of thick mud substance. RIH on slick line w/ 2.0 drive down bailer t/ 11,337'. POOH w/ sample of thick mud substance. RIH on slickline w/ 2.75 gauge ring t/ 11,339'. POOH. R/D slick line unit. R/D BOP's f/ K -23 & secure well. Work will continue upon CUDD unit arrival. 07/12/12 - Thursday R/u choke manifold prep BOP's for install. Install BPV and set @ 16:00. R/D greylock clamp & pull tree. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K - 23 507332031300 178 -004 6/9/12 8/9/12 07/13/12 - Friday R/U test equipment & chart recorder. Fill stack & choke manifold. Test Blind Rams & choke manifold valves to 200 psi low / 3,000 psi high. Test witnessed by Lou Grimaldi of AOGCC. R/U tanks & hard line, shaker stand & shaker, gas buster & pit monitor system. R/U hard line to gasbuster f/ choke manifold. Hang Hawkjaw. M/U 4 -1/2" test jt. Fill stack & test w/ Annular Preventer and IBOP. Change out test jts f/ 4 -1/2 to 4 ". Test w/ 4" test jt. Annular Preventer, upper & lower rams & replacement TIW valve. Rig down test jt. 07/14/12 - Saturday Pull BPV. R/U Weatherford power pack. M/U landing jt t/ hanger 11 rounds. Back out L/D pins f/ hanger. Pull on hanger & tubing assy. Hanger came free little to no restriction. R/U a -line unit & equip. RIH w/ 2.75" guage ring t/ 10,380' sat down. Tagged out at 11,123' WLM. POOH. RIH w/ tubing punch, 13 shot, locate collar, space out top shot @ 11,102' ( middle ofjt). Coordinate w/ Knight fishing hand, fire punch and POOH. RIH w/ cutter. P/U string 20k over, cut @ 11,102' and POOH. Work string up t/ 180k cycle several times. R/U e-line 07/15/12 - Sunday R/D a -line and clear deck. M/U landing jt t/ POOH. POOH f/ 3,462' and L/D landing jt. Stage BHA on pipe rack. P/U BHA, make up overshot, jars, & 1 drill collar. 07/16/12 - Monday Run crane t/ cont. p/u BHA. RIH picking up 4" DP, drifted w/ 2 -3/8" t/ 3,313'. R/U rotary & test. RIH t/ 3,503' W/D f/ 3,503' t/ 3,545' set down. Pull 20K over, set off jars, pulling string free. R/D rotary and attempt t/ circ. unsuccessfully. POOH wet t/ 3,125'. POOH t/ 201' prep t/ lay down BHA. L/D overshot BHA. 07/17/12- Tuesday Cont. L/D BHA. POOH wet L/D 4 -1/2" tubing. Joint #138 plugged off w/ scale. Cont. POOH wet scale falling f/ jts t/ pulled jt # 182. Cont. POOH dry @ jt #215, scale falling f/ jts, corrosion holes through collars & pins looking worse jt #233 7,365' out. Cont. POOH dry t/ bank. 313 jts total pulled, pin parted f/ box, left 1,278' t/ cut @ 11,102' in hole. Prep BHA. P/U BHA, mill shoe, overshot, and jars. 07/18/12 - Wednesday P/U BHA with 4 -1/2" mill overshot. RIH w /4" D/P stands t/ 3,505'. RIH P/U singles t/ 9,795'. RIH t/ 9,902' and tag fish. P/U catch & release and mill over t/ 220' came free. R/D rotary and POOH f/ 9,902' t/ 8,725'. Continue to POOH t/ 7,392'. 07/19/12 - Thursday Continue POOH with Fish BHA and close blinds. MU 6 -3/4" overshot BHA and open blinds. RIH w /BHA on 4 HT -38 and 4 -1/2" BTC tbg. Engage fish at 9,914' and POOH to inspect for recovery. POOH. 1845 hrs - 7/18/12 notified Bob Noble, AOGCC Inspector, via email /phone of BOPE test on 7/20/12. 07/20/12 - Friday Continue POOH, LD BHA and close blind rams. No recovery and no markings on overshot or grapple. Confer with Anchorge Eng on next BHA. MU BHA with 3' extended overshot on deck. Open blind rams - PU / MU BHA #3 with 3' extended overshot and 1st std DP. RIH with BHA #3 and circ /rotate down on fish at 9,933'. Work jars with good licks at 55k -70k over cal tbg weight, gaining upward movement of fish. Continue POOH to inspect overshot for recovery. 07/21/12 - Saturday Continue POOH with Fish BHA. LD BHA on deck, no fish recovered, overshot shows signs of being on tbg - scale was above grapple. RU to test BOPE drain stack. Conduct weekly BOPE test as per AOGCC and Hilcorp procedures at 250 psi low / 3,000 psi high. Witness of test waived by AOGCC Jim Regg on 7/19/12. Pull BOPE test plug, install wear bushing, LD test jts and clean deck of test equip. Prep to PU 8- 1/8 wash pipe. RU to run 8 -1/8 WP. Change traveler slips to hand slips. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K -23 507332031300 178 -004 6/9/12 8/9/12 07/22/12 - Sunday Cont MU WP with crane to BHA - change tong dies. RIH with 8 -1/8" WP with DP from rack. Tag fish at 9,919' continue rotating to engage fish. 07/23/12 - Monday Continue rotating /washing over fish at 9,931' varing pump rate and pipe weight unable to make progress. Reverse circ tbg BU no debris on shaker. POOH. LD DP / BHA. RU break out tongs and LD 8 -1/8" WP. 07/24/12- Tuesday Continue LD WP with crane onto deck. Close blinds. No recovery - marks on outside of shoe - no marks inside shoe indicating not over fish. PU / MU 8 -1/8" rotary shoe to 8 -1/8" WP w/ crane for WP. MU / BHA - swap csg tongs with hawk jaws - change dies on hawk jaws. RIH with 8 -1/8" Rotary Shoe on WP. Tag at 9,905'. Continue washing w /reverse circ trying to plug off. Switch to circ do tbg, good returns w/ scale and slugs of heavy fluids. Continue washing at 9,990'. 07/25/12- Wednesday Finish LD 8 -1/8" WP. Close blinds. PU /MU 8 -1/8" BHA. MU WP x DC xo and 1 jt DC. When jacking in DC the winch holding the DC was not slacked off resulting in bending top section of gin pole. Develop plan for removing and replacing gin pole. PU / MU ox's and 3 jts DP onto WP BHA and RIH across BOPE. Install TIW valve and secure well. 07/26/12 - Thursday Notify AOGCC of upcoming BOPE test. Asked to defer test until CUDD back in service. Received a 2 day extension. 07/27/12 - Friday Continue monitoring well. Jim Regg, AOGCC, has granted request to waive BOPE test for 7/27/12 until 8/3/12. 07/28/12 - Saturday Continue to monitor well. 07/29/12 - Sunday Continue to monitor well. 07/30/12 - Monday Continue to monitor well. Notify Jim Regg, AOGCC, of BOPE test. 07/31/12 - Tuesday Continue to monitor well. Assemble gin pole top sheave, winch motor package, string winch cables and main winch cable. Pick gin pole up with crane and attach to CUDD unit. Notify Jim Regg, AOGCC at 0630 hrs via message and email. Spoke to Jeff Jones, AOGCC NS Insp, at 0645 hrs. Insp Jones informed me to wait until Anc office opened to contact Jim Regg. 0830 hrs left 2nd message for Jim Regg of upcoming BOPE test. Recieved call from Jim Regg, AOGCC at 0915 hrs waiving the witness of BOPE test. 08/01/12 - Wednesday PU /MU 9 -5/8' RTTS w /SSCV c/o dies as needed to lower. RIH to 120' & set b /o. POOH w/ d /p. M/U 4" test jt and set test plug. Conduct weekly BOPE test as per AOGCC and Hilcorp procedures at 250 psi low / 3,000 psi high. Witness of test waived by Jim Regg, AOGCC, on 7/31/12. Pull test plug, set wear bushing. R/D & L/D test jt's & equipment. RIH & retrieve RTTS & L /D. P/U remaining BHA. r ' • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K -23 507332031300 _ 178 -004 6/9/12 8/9/12 08/02/12 - Thursday P/U remaining BHA. RIH to 4,826'. Repair control air line on Hawkjaw. Cont. RIH to 9,859'. R/U rotary and RIH, tag TOF @ 9,933'. ROT & slide over fish to 10,201'. P/U 10' to first collar. Shut down pumps & rotary. Rig down Kelly. POOH. 08/03/12 - Friday POOH f/ 10,190' t/ 421' (BHA). L/D BHA t/ wash pipe. B/O 1st jt. wp found fish. P/U overshot BHA w /6' ext. & grapple. RIH on 4" dp w /overshot BHA. 08/04/12 - Saturday RIH w/ overshot BHA t/ 9,951'. RIH P/U singles to TOF, tag @ 10,201'. Engage fish, POOH t/ 8,315'. 08/05/12 - Sunday POOH to overshot BHA. L/D BHA and fish. P/U wash pipe w/ poor boy cutter & wave shoe. Swap handling equipment & continue P/U BHA. RIH t/ 10,240' and tag. P/U & R/U Kelly. 08/06/12 - Monday Wash & ream t/ 10,266' (11' above fish), and POOH. L/D Kelly. RIH t/ 10,260' and tag up. POOH. R/U Kelly attempt wash & ream pumping long w/ same results. Discuss options, decide C/O BHA run w/o cutter to wash over tubing. R/D Kelly and POOH. Decision made t/ move off well. Clear pipe deck & prep t/ L/D D /P, L/D 4" D/P and 22 jts. Secure well. 08/07/12 - Tuesday Continue L/D 4" dill pipe f/ 6,796' t/ 2,998'. L/D drill pipe t /BHA @ 421'. L/D BHA t/ wash pipe. L/D wash pipe & cutter. 08/08/12 - Wednesday TIH P/U 4 -1/2" L -80 IBT MOD Kill string t/ 3,002'. M/U & land hanger, TWC installed. N/D bell nipple & Hydril. Cont. N/D BOP's & prep for HWU rig down. N/U kill string tree & test t/ 5,000 psi for 15 min. Test void t/ 3,500 psi for 15 min. Pull TWC, start R/D hyd hoses on unit. R/D hoses, scope down gin pole, prep for removal. 08/09/12,- Thursday L/D gin pole. Break down HWU. 1 ' a �,� vim - fi n J� )--) pRinl • • 16--z3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, July 27, 2012 11:52 AM c'e 1 I 771 To: Joe McInnis - (C) t Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: CUDD Rig 136 Past BOPE test performance has been generally good; we appreciate the effort put forth to address the slow recharge time for the accumulator. I have discussed the situation with Commissioner Foerster; AOGCC is granting your request to delay the BOPE test due today (7/27/12) until 8/3/12. Should repairs to the Cudd 136 take longer to complete than 7 days, we can discuss late next week your status and a possible additional extension. Jim Regg AOGCC SCANNED MAY 0 2 2013 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Joe McInnis - (C) [mailto:jmcinnisOhilcorp.com] Sent: Friday, July 27, 2012 11:07 AM To: Regg, James B (DOA) Subject: RE: CUDD Rig 136 Jim, Here are the before and after pictures plus example layout of equipment. The first shows the gin pole fully extended with platform crane in back ground. The second shows the bent section of gin pole with crane tied on to it. The crane was not involved in the incident. The third is example of how the CUDD 136 is laid out the pumps, mud tank, shaker and pill tank may be on different levels of the platform. Hope this helps. Joe From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Friday, July 27, 2012 9 :51 AM To: Joe McInnis - (C) Subject: RE: CUDD Rig 136 Do you have a basic drawing of the Cudd unit that would identify the components, including the gin pole? I've search a little on Cudd's webpage without much success. Thanks in advance. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 1 • 1 From: Joe McInnis - (C) [mailto:jmcinnis@hilcorp.com] Sent: Thursday, July 26, 2012 5:32 PM To: Regg, James B (DOA) Cc: Ted Kramer Subject: RE: CUDD Rig 136 The drill pipe was placed across the BOPE to have the 8 1/8" wash pipe below the BOPE and it will be easier to pump into if needed. Joe McInnis From: Regg, James B (DOA) [mailto:jim.recg@alaska.gov] Sent: Thursday, July 26, 2012 5:08 PM To: Joe McInnis - (C) Cc: Schwartz, Guy L (DOA) Subject: RE: CUDD Rig 136 Commissioners are gone for the day; I will have an answer tomorrow. I am granting at this time a 2 day extension. I understood from our conversation that there is approx 500 ft of BHA and drillpipe in the well. Why do you prefer to have pipe across BOPE during this delay? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: Joe McInnis - (C) [mailto:jmcinnisCahilcorp.com] Sent: Thursday, July 26, 2012 3:34 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Ted Kramer Subject: CUDD Rig 136 Jim, Too clarify our telephone discussion earlier today about The CUDD 136 Gin Pole damage. On 7/25/12 the gin pole used for lifting down hole equipment to the work basket was damaged. This has prevented us from continuing forward with our well work in the usual manner. We have a weekly BOPE test scheduled for 7/27/12. We have an 81/8" BHA in the well with DP across the BOPE at the present time. The well is being converted to a water injector and is losing % bph fluid. We are monitoring and keeping well full. We could remove the BHA and wear bushing by using the crane to pull the BHA. We estimate this to take approximately 15 hrs due to the nature of a slow moving snubbing unit and size and fine threads of BHA . We could test the top rams, Hydril and choke valves by closing the bottom rams. We don't have confidence the bottom rams will hold pressure from the top without a plug in the hole. We would ask our BOPE test be deferred until repairs are made to the CUDD unit gin pole. We would prefer to have DP across the BOPE during this delay. CUDD estimates repairs be complete in 7 — 9 days at the earliest or up to 2 weeks. 2 • • Joe McInnis 907 - 776 -6698 3 Cudd 136 HWO — Damaged Gin Pole • Photos courtesy of Hilcorp (J. McInnis) 7/27/2012 y/ ..4 E k,vck . • • 0 9� i i y � S le e te k , .'', \ he I b if f i!li . ' k _ „ . ,til its i 1 'll — — e, .x z / / I/I 1y. P.m.. VII I ' / i t 3. 1562 leggy ' ' - - _ — - - -- Granite Paint Clrc�drawing � �� How. I Cudd Pressure Control Inc- Proposed Rigup Illustration - fr With Flanges & Clrc. Hoses I-I■ai! •_ I1 IM11111 20,Mar. 07 , I ?" . EKE-c<1 , 7 ' — '3; ;P:" I's' ' rev 0, no scale 3" Miriam Trull 1 7 A • s ^lsalwa0o _ III P4* °fr ."' 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R g. a-. rim.laln tM.en 2• Mrrmd MINIM 3.5in Choke Muff aki C1.'1:. 4M {1de Valves . 131 .€. If _. _. _ ._______.__ • • G[F zi titaA,A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Ted Kramer Drilling Manager , o` (� Hilcorp Alaska, LLC V 3800 Centerpoint Drive Anchorage, AK 99524 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit K -23 Sundry Number: 312 -237 Dear Mr. Kramer: 5LAMED J U E. c a n Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair, Commsisioner DATED this day of June, 2012. Encl. III STATE OF ALASKA ‘" 7-6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for RedriI El Perforate New Pod ❑ Repair WeN ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ PuN Tubing O Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Replace tubing(Convert to Int 0 2. Operator Name: 4. Current Well Class: 5. Permit to DrNI Number. Hilcorp Alaska, LLC Development El Exploratory ❑ 178-004 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20313 -0000 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. WeN Name and Number. ®' property line where ownership or landownership changes: C Spacing Exception Required? Yes ❑ No El Trading Bay Unit / K -23 • 9. Property Designation (Lease Number): 10. Field /Pool(s): JUN 26 2012 Trading Bay Unit ADL0018730 ° McArthur River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY AOGCe Total Depth MD (ft): , Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Jun feasured): 14,700 9,808 14,670 9,794 EZ drill plug @ 14,660' Casing Length Size MD TVD Burst Collapse Structural Conductor 350' 24" 384' 384' Surface 4,971' 13 -3/8" 5,005' 3,940' 3,450 psi 1,950 psi Intermediate Production 12,465' 9 -5/8" 12,495' 8,688' 8,150 psi 7,100 psi Liner 2,534' 7" 14,700' 9,808' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment #1 See Attachment #1 4 -1/2" L -80 12,155 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): WD packer / Camco SSV 12,040 / 303 12. Attachments: Description Summary of Proposal 12 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch M Exploratory ❑ Development ❑ Service M • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/3/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ M , GINJ ❑ WAG El Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature �'�' ~— Phone (907) 777 -8420 Date 6/25/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 9 )1 W , Plug Integrity ❑ BOP Test b Mechanical Integrity Test Location Clearance ❑ TTT Other: TCJ"f 5 36 P fU 3000 p3 t lue /- - /f -1 1�✓3pr -efCV as �he caa ied ;bf% L'Gt5io Ito 25`oopsi ahc', JiavF fvv 36iiih a inc/,cat >d Subsequent Form Required: /0 4 T _ APPROVED BY Approved by: / 464,24--- COMMISSIONER THE COMMISSION Date: la -- 2.8-12____ Z- VLF 0 R 1 `' A[ N 2 0 1G' - -, L i A lt/ Form 10-403 Revised 1/2010 6/77/IL Submit in Duplicate `i/ V • • ATTACHMENT #1 K -23 PERFORATION DATA Zone MD TVD 14,100' - 14,110' 9,512' - 9,518' B -1 14,110' - 14,158' 9,518' - 9,545 14,179' - 14,209' 9,558' - 9,575' B -2 14,263' - 14,288' 9,606' - 9,621' 14,295' - 14,330' 9,625' - 9,645' 14,350' - 14,360' 9,656' - 9,662' 14,375' - 14,385' 9,670' - 9,676 B -3 14,420' - 14,430' 9,696' - 9,700 14,442' - 14,450' 9,707' - 9,711' B -4 14,450' - 14,487' 9,711' - 9,730' • • Well Work Plan Well: K -23 Hilcorp Alaska, LLC Date: 06/25/2012 Well Name: K -23 API Number: 50- 733 - 20313 -01 Current Status: Gas Lifted Producer - SI Leg: Leg 1, NE Corner Slot #5 Estimated Start Date: July 3, 2012 Rig: Cudd Hydraulic Workover Unit Reg. Approval Req'd? June 30, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 178 -004 First Call Engineer: Ted Kramer (907) 777 =8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: 1221342 Current Bottom Hole Pressure: 3,861 psi @ 9,010 TVD (mid perf of 10,795 MD). Based on Offset . Well K -25 from the 2009 Redoubt Shut In Maximum Expected BHP: 3861 psi @ 9,531 TVD Max. Allowable Surface Pressure: 0 psi (Using 0.43 psi /ft to surface) Well Summary The K -23 is currently completed as a Hemlock gas lifted producer. Review of the bottom hole location found that this well is ideally positioned to be a Hemlock injector. Hilcorp plans to convert this well to injection service as a Hemlock Injector and will re- perforate Hemlock benches HB -1, HB -3, and HB -4 as part of this workover. � ��l U P '�°�� colic/ , his /lot cer0 fb►ce /><lior f aT 1-4tf Bottom Hole Review T,,•� Vac ( D/ 6 4a% — 2S`60td A y Ica we. Cony /, r44e wC , ;n,1 o Shove :0 rUvC- Pow) . o,w �+ foal Y z- A bottom hole review was conked to determ which wens if any would be impacted in the immediate area once this well was converted to a Hemlock injector service. A map showing a one quarter mile radius around this well bore (See Attached K -23 Base Map) shows that the only well who's bottom hole location falls into the quarter mile radius is the M -27 well. A review of the M -27 revealed that this wellbore has a 9 -5/8" production casing string set at 13,643 ft with a 7" liner from 13,451' – 15,379'. The 9 -5/8" was cemented with 1,230 sxs. of light weight cement followed by 1,900 sxs. of class "G ". The 7" liner was cemented with 500sxs. of class "G" cement. A Schlumberger USIT log was ran in M -27 on May 28, 2012 specefically looking at the cement bond in this well during a recent workover. The USIT log showed that there was very good cement (80 -100% bonded) from the base of the log at 12,600' up to the top of cement which was picked to be 4,180'. The K -23 Well has a 9 -5/8" production casing string from surface to 12,482' and a 7" liner from 12,166' to 14,700'. Cemented 9 -5/8" Production casing with 236 sxs. of Class "G" cement with additives. The 7" liner was cemented with 800 sxs. class "G" cement. Circ out 170 sxs. • • Well Work Plan Well: K -23 Hilcorp Alaska, LLC Date: 06/25/2012 A K -23 cement bond log ran 4 -13 -78 was reviewed by Ted Kramer of Hilcorp and Kerry Richards of Baker Atlas. The bond log shows 80 to 100% bond from the base of the 7" up to 11,800 feet where the log stopped. Procedure: 1. MIRU CUDD Hydraulic Workover Unit. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. RIH with tubing punch and punch tubing ( + / -) 40 feet above the Otis WD Perma -drill Packer. 4. Reverse circulate one tubing volume of FIW. 5. Shut down for 1 hour and monitor fluid loss. Kick in pumps and measure number of barrels to catch fluid. Calculate the fluid loss to formation. Adjust loss to acceptable level by pumping graded rock salt (or other acceptable fluid loss material) pill in FIW. Note: Well will not flow to surface. 6. RIH with tubing cutter on E- line to ( + / -) 12,137' and cut tubing. 7. RD E -line. 8. POOH laying down 4 -1/2" tubing string 9. PU overshot mill and down hole motor on 4" work string and RIH to Otis WD Perma -drill Packer at 12,040'. Mill up and remove same. 10. PU bit and scraper and RIH to Top of 7" liner at 12,166'. POOH with same. 11. PU smaller mill and scraper and clean out to PBTD at 14,660'. POOH with mill laying down workstring. 12. RU Schlumberger TCP Perforating and RIH W/ TCP perforating guns and re- perforate the Hemlock Zones as follows: Zone MD B1 14,100 — 14,158' B -3 Through B — 4 14,350 — 14,575' Total 283 feet 13. RD Schlumberger. 14. PU Hydraulic set injection packer and RIH on 4 -1/2" injection tubing. 15. Circulate packer fluid and Set Packer at 14,025' + / -. 16. ND BOP NU Well head. 17. Perform initial MIT test. 751W p 5L. , eh a. r 10 pin eel 18. Turn well over to production. kV/ r5.5 i /1 rParr iN jcc - ,., .5tc1,b 3 r$, Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics . H • • Trading Bay Unit Proposed Well # K -23 Hilcorp Alaska, LLC Actual Completion 2/28/88 CASING AND TUBING DETAIL RKB to Hangar = 33.75' SIZE WT GRADE CONN ID TOP BTM. Hangar Type:FMC 4 -1/2" BTC 24" Driven Surf. 384' r J U 1 13 -3/8" 72 & 68 K -55 Butt 12.415" Surf 5,005' 9 -5 /8" 47 5 -95 Butt 8.681" Surf 12,482' 7" 29 L -80 BTC -KC 6.184" 12,166' 14,700' Tubing: 4 -1/2" 12.6 L -80 BTC 3.958" Surf ± 14,010' JEWELRY DETAIL NO. Depth ID Item 1 ± 303' 3.81 CAMCO TRDP -1A SSSV nipple 2 ±13,995' CAMCO "DB -6" No -Go Nipple 3 ± 14,000' Baker Hydraulic set Permanent Pkr. 4 ± 14,005' 4 -1/2" tubing tail 5 ± 14,010' 3.75 4 -1/2" WL re -entry guide PERFORATION DATA Zone Interval FT SPF Date Comments 14,100' - 14,110' 10 4 2/23/1988 Reperf 7/7/92 B-1 14,110' - 14,158' 48 SQZD 4/23/1978 SQZD 2/23/88 14,179' - 14,209' 10 4 to 8 9/26/1980 Reperf 2/28/88 B -2 14,263' - 14,288' 25 4 2/28/1988 14,295' - 14,330' 35 4 2/28/1988 g 14,350' - 14,360' 10 4 2/28/1988 Reperf 7/7/92 14,375' - 14,385' 10 4 2/28/1988 Reperf 7/7/92 B -3 14,420' - 14,430' 10 4 2/28/1988 14,442' - 14,450' 45 4 2/28/1988 A B -4 14,450' - 14,487' 37 4 2/28/1988 2 3 -4 5 B -1 B -2 B -3 B -4 i PBTD = 14,660' TD = MAX HOLE ANGLE = 70° @ 13,265' REVISED by TDF: 6/25/12 • • Trading Bay Unit 'Blear!) Alaska, LLC ASBUILT Well # K -23 Actual Completion 2/28/88 CASING AND TUBING DETAIL RKB to Hangar = 33.75' SIZE WT GRADE CONN ID TOP BTM. Hangar Type:FMC 4 -1/2" BTC 24" Driven Surf. 384' J o 1 l 13 -3/8" 72 & 68 K -55 Butt 12.415" Surf 5,005' 9 -5/8" 47 S -95 Butt 8.681" Surf 12,482' 7" 29 L -80 BTC -KC 6.184" 12,166' 14,700' 1 f Tubing: 4 -1/2" 12.6 L -80 BTC 3.958" Surf 12,189' U JEWELRY DETAIL I NO. Depth ID Item D 1 303' 3.81 CAMCO TRDP -1A SSSV nipple 2 12,038' Locater Seal Assembly (Seals- 18.27+mule shoe - 0.98') U 3 12,040' Ottis "WD" Perma -Drill Pkr. WI 5" bore 4 12,042' Seal Bore extension (0.60 +19.51 +0.47= 20.58') I D D 5 12,156' 3.75 CAMCO "DB -6" No -Go Nipple I 6 12,189' OTTIS 4 -1/2" WL re -entry guide 7 12,189' 4 -1/2" Tubing Tail Gas Lift Mandrels 2 ( 1'1/01 l/hi NO. Depth ID Item 0:111q, 3 1 2,451' 3.833" Camco MMG CA, R -20, RK Latch 4 2 4,681' 3.833" Camco MMG CA, R -20, RK Latch - ∎ e , , 3 6,280' 3.833" Camco MMG MA, JMR -2, RK Latch Vi V7 � 4 7,783' 3.833" Camco MMG MA, JMR -2, RK Latch 5 8,912' 2.867" Camco MMG MA, JMR -2, RK Latch 6 9,704' 2.867" Camco MMG MA, JMR -2, RK Latch 5 7 10,404' 2.867" Camco MMG MA, JMR -2, RK Latch L .1 8 11,162' 2.867" Camco MMG MA, JMR -2, RK Latch 6 9 11,981' 2.867" Camco MMG MA, JMR -2, RK Latch 7 PERFORATION DATA Zone Interval FT SPF Date Comments 14,100' - 14,110' 10 4 2/23/1988 Reperf 7/7/92 _ B B -1 B-1 14,110' - 14,158' 48 SQZD 4/23/1978 SQZD 2/23/88 _ 14,179' - 14,209' 10 4 to 8 9/26/1980 Reperf 2/28/88 = B -2 B -2 14,263' - 14,288' 25 4 2/28/1988 B 3 14,295' - 14,330' 35 4 2/28/1988 14,350' - 14,360' 10 4 2/28/1988 Reperf 7/7/92 B - 4 B 3 14,375' - 14,385' 10 4 2/28/1988 Reperf 7/7/92 14,420' - 14,430' 10 4 2/28/1988 14,442' - 14,450' 45 4 2/28/1988 X1 4.-2 W B - 14,450' - 14,487' 37 4 2/28/1988 PBTD = 14,660' TD = 14,700' MAX HOLE ANGLE = 70° @ 13,265' REVISED by TDF: 6/11/12 • . King Salmon Platform 2012 BOP Stack 05/15/2012 Hilrnr : t1a, ka. 1,1.t King Salmon K -23 4.54' • Hydril ' GK 13 5/8 -5000 II 111 1 1111 4.67' CII-U — 2 7/8 -5 variables 800stelbo -tso= bon• — Blind Shear - 2.00' D.II: 01I' 11 11 1 K4110.1111: •i� i. ,,.i 1 r 2.83' - — 2 7/8 -5 variables 1.17' 1111 111111 111 1 14.. Drill deck Riser 13 5/8 5M FE 14.20' U9 X135/85MFE lil ,I11 ,:i:. 1 1 1. 1 1 1 , Spacer spool 2.16' 13 5/8 5M FE X 13 5/8 5M i, .Ii ,1, 1 1 , FE AIM 13 1 �, 1 1 Spacer spool 2.00' 13 5/8 5M FE X 13 5/8 5M P hi a, I I FE UOCD + 111 ► ! Crossover spool 1.41' 1227 I I 13 5/8 5M FE X 11 5M FE 1 A -30 gr K -02 i K -15RD 1 K -15 K -07 0 K -17 .,•AK -O7RD K- O2Rf3 ••• . M • • • • M -32RD �K -30 • • II • ■ M - K 09 _OK -3OPB M28 ' 05 Iv K -21 RD 2 • • , K -23 Q 1, , • ,JflM �% • =1111::; 1 w 1111R° .. K -24RD2 . . •. ii‘ • •: • • 1 L1 G25 S • M -32 "`K -21 ............... . •• 11 HILCORP ALASKA, LLC • MCARTHUR RIVER FIELD SG -32 t 0 500 FEET OM -25 G -01 o� ; K -24RD POSTED WELL DATA •1 - G, RD K -24 iv • Well Label 4117 WELL SYMBOLS • Oil Well _ _. - -- Gas Well \ je InjecOoc Well ..41 O Aba do d Well Abandoned Gil We Converted Water -Input Wel Shut -in Oil Well �G2O Shut -in Water Injector 4111411 June 19, 2012 — PFTRA R /boot, g.1,A PRA • • • RECEIVED • STATE OF ALASKA JUN 15 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Rednll ❑ Perforate New Pod ❑ Repair Well ❑ Change Approv -• 'rogram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 • T e Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing El Other Replace tubi w Convert to Ini O • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill umber. Hilcorp Alaska, LLC Development O . Exploratory ❑ 178 -004 3. Address: Stratigraphic ❑ Service ❑ 6. API Nu , • er. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50 -7 •20313 -0000 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership cianges: Spacing Exception Required? Yes ❑ No O Trading Bay Unit / K -23 • 9. Property Designation (Lease Number): 10. Field / Pool(s): Trading Bay Unit ADL0018730 ' McArthur River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,700 9,808 14,670 9 94 EZ drill plug @ 14,660' Casing Length Size MD TVD Burst Collapse Structural Conductor 350' 24" 384' 38 Surface 4,971' 13 -3/8" 5,005' 4,940' \ 3,450 psi 1,950 psi Intermediate Production 12,465' 9 -5/8" 12 , 95' 8 8 ' 8,150 psi 7,100 psi Liner 42,534' 14, r0' 08 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): `tub••g Si e: ( Tubing Grade: Tubing MD (ft): See Attachment #1 See Attachment #1 4-1/2" L -80 12,155 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): WD packer / Camco SSV 12,040 / 303 12. Attachments: Description Summary of Proposal Fri 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch O Exploratory ❑ Development ❑ Service O 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ O GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and c rect to the best of my knowledge. Contact Ted Kramer Printed Name Ted E. Kramer Title Sr. Operations Engineer Signature �J �1 ....... - [, G Phone (907) 777 -8420 Date 6/14/2012 COMMISSION USE ONLY f ,, Conditions of approval: Notify Com sion so that a representative may witness Sundry Number: 3 \ -2. 2-Lo Plug Integrity ❑ B P Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: D Jul ci- a ?o Subsequent Form - -quired: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ./ Form 10-403 Revised 1/2010 ORIG!NIAI Duplicate F, , P ty ATTACHMENT #1 K -23 PERFORATION DATA Zone MD TVD 14,100' - 14,110' 9,512' - 9,518' B -1 14,110' - 14,158' 9,518' -9,545 14,179' - 14,209' 9,558' - 9,575' B -2 14,263' - 14,288' 9,606' - 9,621' 14,295' - 14,330' 9,625' - 9,645' 14,350' - 14,360' 9,656' - 9,662' 14,375' - 14,385' 9,670' - 9,676 B -3 14,420' - 14,430' 9,696' - 9,700 14,442' - 14,450' 9,707' - 9,711' B -4 14,450' - 14,487' 9,711' - 9,730' • • Well Work Plan Well: K -23 Hilcorp Alaska, LLC Date: 06/11/2012 Well Name: K -23 API Number: 50- 733 - 20313 -01 Current Status: Gas Lifted Producer - SI Leg: Leg 1, NE Corner Slot #5 Estimated Start Date: Jul 1, 2012 Rig: Cudd Hydraulic July � g Y Workover Unit Reg. Approval Req'd? June 29, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 178 -004 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: 1221342 Current Bottom Hole Pressure: 3,861 psi @ 9,010 TVD (mid pert of 10,795 MD). Based on Offset • Well K -25 from the 2009 Redoubt Shut In Maximum Expected BHP: 3861 psi @ 9,531 TVD Max. Allowable Surface Pressure: 0 psi (Using 0.43 psi /ft to surface) Well Summary The K -23 is currently completed 9 com teed as a Hemlock gas lifted producer. Review of the bottom hole location • found that this well is ideally positioned to be a Hemlock injector. Hilcorp plans to convert this well to injection service. Procedure: 1. MIRU CUDD Hydraulic Workover Unit. 2. ND wellhead and NU BOP stack. Pressure test BOP to 250 psi. low / 3,000 psi high. Note: notify AOGCC 48 hours in advance of test for the opportunity to witness bop test. 3. RIH with tubing punch and punch tubing ( + / -) 40 feet above the Otis WD Perma -drill Packer. 4. Reverse circulate one tubing volume of FIW. 5. Shut down for 1 hour and monitor fluid loss. Kick in pumps and measure number of barrels to catch fluid. Calculate the fluid loss to formation. Adjust loss to acceptable level by pumping graded rock salt (or other acceptable fluid loss material) pill in FIW. Note: Well will not flow to surface. 6. RIH with tubing cutter on E- line to ( + / -) 12,137' and cut tubing. 7. RD E -line. 8. POOH laying down 4 -1/2" tubing string 9. PU overshot mill and down hole motor on 4" work string and RIH to Otis WD Perma -drill Packer at 12,040'. Mill up and remove same. 10. PU bit and scraper and RIH to Top of 7" liner at 12,166'. POOH with same. 11. PU smaller mill and scraper and clean out to PBTD at 14,660'. POOH with mill laying down workstring. lest 74 L // ror.®vt1`. , '4' Ante 70 / 1 ' 1 / 9 iq*, cvf Cyr ` I- Coll , � '8 pb fa- o re. Q lief,- � {� [ q 9 Z /'.fin �T 6 C �%1� ✓ /(/j i ,4 - f (/ l Vr •!/!r/*! 47 r 4 f —et To qn 1 ? ecf - CAiovlo/ /nrrvv' (rCove Tf i6o" 19 /a 4 S Well Work Plan Well: K -23 Hilcorp Alaska, LLC Date: 06/11/2012 12. PU Hydraulic set injection packer and RIH on 4 -1/2" injection tubing. 13. Circulate packer fluid and Set Packer at 14,000' * / -. 14. ND BOP NU Well head. 15. Perform initial MIT test. 16. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics � • • Trading Bay Unit Ilikorp Alaska, LL( ASBUILT Well # K -23 Actual Completion 2/28/88 CASING AND TUBING DETAIL RKB to Hangar = 33.75' SIZE WT GRADE CONN ID TOP BTM. Hangar Type:FMC 4 -1/2" BTC 24" Driven Surf. 384' J o r 1 13 72 & 68 K -55 Butt 12.415" Surf 5,005' 9 -5/8" 47 5 -95 Butt 8.681" Surf 12,482' 7" 29 L -80 BTC -KC 6.184" 12,166' 14,700' Tubing: D 4 -1/2" 12.6 L -80 BTC 3.958" Surf 12,189' JEWELRY DETAIL I D NO. Depth ID Item I) 1 303' 3.81 CAMCO TRDP -1A SSSV nipple I 2 12,038' Locater Seal Assembly (Seals- 18.27 +mule shoe - 0.98') D I 3 12,040' Ottis "WD" Perma -Drill Pkr. W/ 5" bore D 4 12,042' Seal Bore extension (0.60 +19.51 +0.47= 20.58') I III D 5 12,156' 3.75 CAMCO "DB -6" No -Go Nipple I 6 12,189' OTTIS 4 - 1/2" WL re -entry guide 7 12,189' 4 -1/2" Tubing Tail h Gas Lift Mandrels , �+ N fZoU P "'� 4 " , NO. Depth ID Item 2 / 1 2,451' 3.833" Camco MMG CA, R -20, RK Latch I 4 /2Oif. 1 . �/ _ /Z 3 d v � 2 4,681' 3.833" Camco MMG CA, R -20, RK Latch /Zr ` fvbi� 3 6,280' 3.833" Camco MMG MA, JMR -2, RK Latch 4 7,783' 3.833" Camco MMG MA, JMR -2, RK Latch k 5 8,912' 2.867" Camco MMG MA, JMR -2, RK Latch 6 9,704' 2.867" Camco MMG MA, JMR -2, RK Latch 5 7 10,404' 2.867" Camco MMG MA, JMR -2, RK Latch 4 8 11,162' 2.867" Camco MMG MA, JMR -2, RK Latch 06 9 11,981' 2.867" Camco MMG MA, JMR -2, RK Latch 7 PERFORATION DATA Zone Interval FT SPF Date Comments 14,100' - 14,110' 10 4 2/23/1988 Reperf 7/7/92 li B-1 B-1 14,110' - 14,158' 48 SQZD 4/23/1978 SQZD 2/23/88 _ 14,179' - 14,209' 10 4 to 8 9/26/1980 Reperf 2/28/88 B - 8-2 14,263' - 14,288' 25 4 2/28/1988 -- B 14,295' - 14,330' 35 4 2/28/1988 14,350' - 14,360' 10 4 2/28/1988 Reperf 7/7/92 B -4 B 3 14,375' - 14,385' 10 4 2/28/1988 Reperf 7/7/92 14,420' - 14,430' 10 4 2/28/1988 14,442' - 14,450' 45 4 2/28/1988 ,., 41 z B -4 14,450' - 14,487' 37 4 2/28/1988 PBTD = 14,660' TD = 14,700' MAX HOLE ANGLE = 70° @ 13,265' REVISED by TDF: 6/11/12 , • • Trading Bay Unit Proposed Well # K -23 Ilikorp Alaska, LL( Actual Completion 2/28/88 CASING AND TUBING DETAIL RKB to Hangar = 33.75' SIZE WT GRADE CONN ID TOP BTM. Hangar Type:FMC 4 -1/2" BTC 24" Driven Surf. 384' J o 1 Ll 13 -3/8" 72 & 68 K -55 Butt 12.415" Surf 5,005' 9 -5/8" 47 S -95 Butt 8.681" Surf 12,482' 7" 29 L -80 BTC -KC 6.184" 12,166' 14,700' Tubing: 2 4 - 1/2" 12.6 L - 80 BTC 3.958" Surf ± 9,999' A JEWELRY DETAIL Pr NO Depth ID Item 1 ± 303' 3.81 CAMCO TRDP - 1A SSSV nipple 4 '\ =G 2 ±9,879' CAMCO "DB -6" No -Go Nipple r* 2 3 ± 9,899' Ottis "WD" Perma -Drill Pkr. W/ 5" bore f _3 4 ± 9,998' OTTIS 4 -1/2" WL re -entry guide 5 ± 9,999' 3.75 4 -1/2" Tubing Tail -4 PERFORATION DATA G - Zone Interval FT SPF Date Comments 14,100' - 14,110' 10 4 2/23/1988 Reperf 7/7/92 6 B 1 14,110' - 14,158' 48 SQZD 4/23/1978 SQZD 2/23/88 -7 14,179' - 14,209' 10 4 to 8 . 9/26/1980 Reperf 2/28/88 B -2 14,263' - 14,288' 25 4 2/28/1988 14,295' - 14,330' 35 4 2/28/1988 121(6(1 1K 14,350' - 14,360' 10 4 2/28/1988 Reperf 7 /7/92 14,375' - 14,385' 10 4 2/28/1988 Reperf 7/7/92 B -3 14,420' - 14,430' 10 4 2/28/1988 14,442' - 14,450' 45 4 2/28/1988 A . B -4 14,450' - 14,487' 37 4 2/28/1988 P i=i - B -1 = B -2 - B -3 - B -4 :r! -. ?'I - PBTD = 14,660' TD = 14,700' MAX HOLE ANGLE = 70° @ 13,265' REVISED by TDF: 6/11/12 • • King Salmon Platform 2012 BOP Stack 05/15/2012 IIII.. rp ■44.1. 1.11. King Salmon K -23 4.54' • Hydril ' GK 13 518 -5000 Iii 'II III lil lit IC 111 III III 111 4.67' 2 7/8 -5 variables Blind Shear III lil lit 1i1 U1 islnlnt 2.00' 1.If II0II4f l �l I1/ 1/11/1111 111 Ii II®I�I, 1111 111 111 111 111 2.83' — 2 7/8 -5 variables lil Ii1 111111 Ii1 1.17' III 111 111 1 11 411 Drill deck Riser 13 5/8 5M FE 14.20' X135/85MFE III III Iii Iii Ul III iij 1a III Spacer spool 2.16' 135/85MFEX 13 5/8 5M IIt I I ri/1�l lit FE Ills tel tin tet 111 Spacer spool 2.00' 135/85MFEX 135/85M 111 1:1111 11 Iii FE UOCD .5i I' 1+1 1 'it, Crossover spool 1.41' 1227 ;; ;, ,;,,;, 111 13 5/8 5M FE X 11 5M FE • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Wednesday, June 27, 2012 8:57 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: TBU K -23 Sundry (312 -237) Victoria, Please withdraw sundry 312 -226. ()b Thanks -you, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto: victoria.ferguson©aalaska.gov] Sent: Wednesday, June 27, 2012 8:49 AM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: RE: TBU K -23 Sundry (312 -237) The new sundry for K -23 is 312 -237. Please withdraw sundry 312 -226 by responding to this email. From: Ted Kramer [mailto:tkramer@hilcorp.coml Sent: Wednesday, June 27, 2012 8:43 AM To: Ferguson, Victoria L (DOA) Cc: Tom Fouts - (C); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: TBU K -23 Sundry (312 -226) Victoria, The 10 -403 package for K -23 was resubmitted to AOGCC on Monday 6- 25 -12. I included a section called bottom hole review that discusses the wells in the 1 /4 mile radius. Since this will be the next well the workover rig will be going to, please move this application to the top of the Hilcorp pile. Thanks and sorry for the mix up, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 1 �� Hilcorp Alaska, U U �- n n�n��K� ��o��n^�� u-u-�� 11 �� U �� ^ � � �� n� "�� ~��~ ' ' ' Well Name API Number Well Permit Number Start Date End Date K-23 507332031300 178'004 6/9/12 Daily � Operations: "�*� 06/13/12 - Wednesday R|Hf/11 tag light. Line up pump Zx tubing vol f/l1'67U' down annulus. @2bpm. Pull upt/11'G7S', tag w/ 2,500 over x2, tag w/ 4,500 got hung up. R/u pump 10% hcl acid pill, pump accross hang up point @ 1 bpm, shut down let soak 20 min. Pump down annulus. Attempt t/ pull through restriction 11,670' no go. Moriitor well and stand by for e- line unit. 01' -7 06/14/12 - Thursday Monitor weV. Waiting f/ e-Iine unit. 06/15/12 - Friday R/U e-line tools. RIH through BOP stack tag inside BHA no go @ 11,651'. P/U 6" above top of BHA fire cutter and POOH. Cutter not fired. R/D and get new cutter. R/U tools & arm cutter and RIH. Tag inside BHA no go @ 11,651'. P/U6"above top of BHA fire cutter. Signs that cutter fired. R|Ht/1l POOH w/e'|ine and verified cutter shot. R/De- line. P/U injector, install coil coupler and stab injector on prep t/ POOH. POOH t/ 1,000'. R/U& blow down coil w/n2and finish POOH. R/D injector. 06/16/12 - Saturday R|H through BOP stack w/I.2SsvvedQe. tag 11,333' and POOH. 0Hon slick line w/%.0 drive down bailer t/11^334' POOH w/ sample of thick mud substance. RIH on slick line w/ 2.0 drive down bailer t/ 11,337'. POOH w/ sample of thick mud substance. RIH on slickline w/ 2.75 gauge ring t/ 11,339'. POOH. R/D slick line unit. R/D BOP's f/ K-23 & secure well. Work will continue upon CUDD unit arrival. 06/17/12 - Sunday No operations to report. 06/18/12 - Monday No operations to report. 06/19/12 - Tuesday No operations to report. V `1 'ZY -C344�_C-' ` Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 !AUG 0 h, 2.009 Cathy Foerster Commissioner Isle Oil & Cas C.Ons, GprnrrlisgirAn Alaska Oil & Gas Conservation Commission fanrl�oi•2[1, 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) "'e,1�cc&�_ Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platforrn life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug-9parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casing Producin Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life Y f AL&SHA 011L AND GALS CONSERVATION COMMSSION June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCANNED Anchorage AK 99503 \-IY-oC� 44, SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 _ Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 _ Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 _ Trading Bay Unit D-18 _ Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD _ Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 _ Union Oil Company of California 179-016 _ Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 _ MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 _ MGS St 17595 28 Union Oil Company of California 193-118 _ MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD _ Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 _ S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 _ Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 _ Trading Bay St A-30 MEMORANDUM TO: THRU: FROM: David John~, Chairmar~,~~ Blair Wondzell, P. I. Supervisor Chuck Scheve, ~ Petroleum Inspector Friday April 18:1997: State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 18, 1997 ,pr..'~''' FILE NO: I ujkdree. DOC SUBJECT: No Flow Test McArthur River Field King Salmon Platform Wells K-2, K-3 & K-23 ~.- ~'i~ 8~ -{~,~1 i travel~ to Uno, is King Salmon PlaEorm and a NO-FLOW test on Wells K-2, K-3 & K-23. The subject Wells had been bled down-prior to my arrival on the platform. The wells were lined up to open top drums via a 1/2" hose and observed for 1 h.....__9our with no fluid flow observed. Well K-2 had a minor amount of gas flowing from the hose, it was then shut in and slowly built 30 PSI over a 1 hour period. The pressure bleed off instantly when opened to atmosphere. I recommend approval of NO-FLOW status for these Three wells SUMMARY: I witnessed a successful NO-FLOW test on Unocals K-2, K-3 & K-23 Wells ( King Salmon Platform ) in the McArthur River Field. X Unclassified Classified Unclassified with Document Removed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator UNOCAL Corporation (ARCO Alaska. Inc. is sub-oDerator) 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 698' FSL, 81' FEL, Sec. 17, TgN, R13W. SM At top of productive interval 91' FSL, 1754' FWL, Sec. 22, TgN, R13W SM At effective depth 367' FNL, 1875' FWL, Sec. 27, TgN, R13W Slvl At total depth 394' FNL~ 1881' FWL~ Sec. 27~ TgN~ R13W SM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 100' 7. Unit or Property name Trading Bay Unit 8. Well number 9. Permit number/approval number 78-0004/92-171 10. APl number 50-733-20313 11. Field/Pool IvlcArthur River Hemlock feet 12. Present well condition summary Total Depth: measured true vertical 14700' feet Plugs (measured) 9808' feet 13. Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 14670' feet Junk (measured) EZ drill plug @ 14660' true vertical 9794' feet Length Size Cemented Measured depth True vertical depth 354' 24" Pile Driven 4975' 13-3/8" 2387 sx CIG 12465' 9-5/8" 1000 sx CIG 2534' 7" 800 sx CIG measured 384' 384' 5005' 3940' 12495' 8688' 12166'-14700' 8450'-9808' See attached well schematic Perfed: 14100'-14110' Reperfed: 14340'-14350'~ 14365'-14375' true vertical See Attached well schematic Perfed: 9493'-9498' Tubing (size, grade, and measured depth) 4-1/2"L-80 tubing w/tail 2 1 2189' MD Packers and SSSV (type and measured depth) WD packer @ 1 Z040' MD~ Camco SSSV @ 303' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Reperfed: 9632'-9639', 9646'-9651' RECEIV£0 N/A Alaska 0it & Gas Cons. C0mm'tss'~on Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 198 166 2246 1310 124 141 2096 1300 Tubing Pressure 100 100 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 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. SUBMIT IN DUPLICATE ARCO Alaska, Inc. Tr~....,ng Bay Unit - King Salmon P, /arm Well K-23 APl#: 50-733-20313-[]0 Spud Date: 1-19-78 Completion Date: 2-24-88 Original RKB: 100' MSL Hanger Type: FMC 4-1/2" BTC Top of Hemlock: 14102' Max Hole Angle: 70° @ 13265' Annulus Fluid: Sea water Last Revised: 9-92 All Depths are RKB MD to Top of Equipment. Well Type: Producer New I-1 Workover !~1 RKB to Hanger: 33.75' Angle at Perforations: 57° Reason: eR/GL Data Update' J Jewelry 1 303" 2 12038' 3 12040" 4 12042' 5 12156' 6 12189' 7 12189' Camco TRDP-1A SSSV nipple: ID = 3.812" Locator seal assembly (Seals - 18.27" + mule shoe - 0.98') Offs "WD" Perma-Drill pkr. w/5" bore Seal bore extension (0.60 + 19.51 + 0.47 = 20.58') Camco "DB-6" No-Go nipple: ID = 3.750" Offs 4-1/2" WL re'entry guide 4-1/2" tubing tail Casing and Tubing Size Wei_aht 13-3/8" 72# & 68~ 9-5/8" 47# 7" 29# 4-1/2" 12.6~ Grade Thread ToD Bottom Description K-55 34' 6005' Casing S-95 BTC 34" 12482' Casing N-80 BTC 12166' 147CX~ Uner L-80 ABM-BTC 34' 12189' IPC Tubing Gas Uft Information Depth Stn. TVD 2451' 1 2338" 4681' 2 3743' 6280' 3 4752' 7783' 4 5603' 8912' 5 6294' 9704' 6 6849' 10404' 7 7338' 11162' 8 7836' 11981' 9 8366' Mandrel Type Camco MMG Camco MMG Camco MMG Camco MMG Camco MMG Camco MMG Camco MMG Camco MMG Camco MMG Valve Latch PortSz. TRO Psc CA, R-20 R K 1/4" 1140 1220 CA, R-20 R K 1/4" 11,55 1208 MA, JMR-2 R K 5/16" 1215 1206 MA, JMR-2 R K 3/8" 1275 1185 MA, JMR-2 RK 7/16" 1345 1160 MA, JMR-2 R K 7/16" 1325 1135 MA, JMR-2 RK 7/16" orif orif MA, JMR-2 RK dura - - MA, JMR-2 RK dum - - Perforation Data- DIL depths 13 Zone ToD-MD/SS perf Interval 1 14100"/9391" 1410C~-14110' 14120'-14168' 2 14175'/9436' 14179-14209" 14263"-14288' 14295'-14330' 3 14340'/9631' 14340'-1~' 14366'-14375' 1442~-14430" 14442'-14450' 4 14450'/9591' 1445(~-14487' FT SPF 10 4 38 SQZD ~[] 4-8 25 4 35 4 10 8 10 8 10 4 8 4 37 4 Gauge Ring and Fill Level Data Date Size DeDth Comments 2-23-88 3.75" 8200' No fight spots Did not attempt to run GR deeper 9-7-88 3.75" 12134' No tight spots Did not attempt to run GR deeper 9-7-88 3.70" 13146" Would not go deeper. Hole angle = 65°. 12-18-88 PL 13275' No deeper 2-28-89 PL 1442~ No deeper 3-2-89 3.75" 777C~ GLV lost as fish 1-23-90 3.70" 143717 tagged fill 5/12/92 2.7" 1321~7 WLM high REEEIVED angle hole PBI'D = 14660' MD S EP '~ 1 1992 TD = 14700' MD Datum = 14025' MD (9350' SS, 9450' TVD ) Alaska Oil & Gas Cons. (;o~m'tss[oQ Anchorage JLB 9/2/92 ARCO Alaska, Inc. , Subsidia~ of Atlantic Richfield Company WELL C"'"~RA~TOR IPBDT WELL SERVICE REPORT IFIELD - DISTRICT- STATE iOF;ERATiON ~,T REPORT TIME DATE A.n_chora[lo r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report °F Chill Fact°r 1 VisibilitY°FI miles ]Wind Vel. JU'L 8 ,'S~= 5:5S FROM KINJ:t SALMON PLATFORM TO CI EN~_~GINEERING PAGE.00!,'00£ ARCO Alaska, Inc. % ~?,.~: =::: WELL SERVICE REPOR~ · ' _+/. ? ,LOCK IF sUMMARY CONTINUED ON BACK JbL 8 , 'S2 5:59 FROM KING SALMON PLATFORM TO CI ENGINEERING PAGE.002×002 REMARKS CO_,NTINUED: DESORIFTION DAILY ACCUM. TOTAL C&MCO O-nS - ., _.,.... ,,.._,..._ .~-M;~==r:-== ............. ' '" DRESSER-ATLAS DOWELL , i · ! i! i I ! i iii HALLIBUR~'ON ' ' ARCTIC COIL T~'BING ........... FRACl~/~$TER ...... B. J. HUGHES Roustabouts Diesel ............ ~..... ~,, ~, ! %.i~ ~'~ ~ . 5ul3emsion ,.. _ ....... ,- r~ ,, ~ ~0(~9.. . Pre-,Job Safety Meeting ~_F i ..... , . . ~ AFE Alnet,a Ail & Gas C(~6s. ....... ~nnhora~O __ Slgnecl JUL ? '92 5:33 FROM KING 'ARCO Alaska, Inc. Suba~diaW Of Atlaf~tl¢ Ric~fteld ~omDeny WELL tPBDT C .1ACTOR SALMON PLATFORM TO CI ENGINEERING PAGE.001/001 WELL SERVICE REPORT tFIELD - Dl~i i MICT · STATE OPERATION -AT REPORT T'IM E ._ . REG. EiVED 1'"'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK S E P 2 1 1992 AJa~;{a.Oii .& uas t;ons. Commission Weather ..-. I"'"'- .,,~'"'"'"°' i,,,,,,,,.,, .,,. i ARCO Alaska, Inc. Sul~id~'t~y of Atlantic Richfield Company ~-2~ O, nI~'RACTOR ...... WELL. SERVICE REPORT OPE~ON AT REPORT TIME llOC~ ~o g4,~g' 1o1~;,s ~ ~ _/~~~' ~~~ ~,~ GLH, .P~,,~... ' .'..~, ~ , y, l _ ~ ~ ,1,I L CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARK~ (~ONTINUED: D ESCRI PTION DAILY ACCU M. TOTAL _ CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER · B. J. HUGHES Roustabouts Diesel Methanoi' SUpervision Pre-Job Safety Meeting D ~' J~ ~ I ~ J/~ r~ AFE ~,I,~,L~ ] V L ~ 'S E P 2 ! 1992 RnGhora9~ , , _ TOTAL FIELD ESTIMATE 11Signed JUL 02 ~2 08:B~ UMOCAL AMCH Uno=al North Amerid;an~ Oil & Gas Division Unocal Corporation P,O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 fer Fax Cor~lrmaflon Fa~sLmlle (907) 263-7884 P.1/lb UNOCALZ AlasKa Region PLEASE DELIVER THIS iNFORMATION TO: At the request of: If you do not receive ask for: [S~'Cer~ar%I, ................... /~.___ pages (including this cover sheet), please call (907) 276-7600 and [~ operator] ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X. Other 2. Name of Operator ~ 5. Type of Well: UNOCAL Corporation I Development CARCO Alaska. Inc. is sub-ooerator) Exploratory i3. Address I Stratigraphic P. O. Box 100360, Anchorage, AK 99510 I Service 4. Location of well at surface Leg I Conductor 5 698' FSL, 81' FEL, Sec. 17, T9N, R13W SM At top of productive interval 91' FSL, 1754' FWL, Sec. 22, TgN, R13W SM At effective depth 367' FNL, 1875' FWL, Sec° 27, T9N, R13W SM At total depth 394' FNL, 1881' FWL, Sec. 27, T9N, R13W SM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) 14700' 9808' feet Plugs (measured) feet Effective depth: measured 14670' feet Junk (measured) true vertical 9794' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 14375'-14385', Length Size Cemented RKB 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-23 feet 9. ,.jP~.rr~it number 10. APl number 50-133-20313 11. Field/Pool McArthur R[yer..(l-J.emlgc, k), ,., JUl_ - 21992 . . EZ drill plug @14660' Alaska 0il & Gas Cons. C0mmlssi0n Measured depth Trl~l~l~ depth 354' 24" 4975' 13-3/8" Pile Driven 384' 384' 2387 sx Cl G 5005' 3940' 13. 9-5/8" 7" 14179'-14209', 1000 sx CIG 12495' 8688' 800 sx Cl G 12166'-14700' 8450'-9808' 14263'-14288', 14295'-14330', 14350'-14360', proposed: 14110'-14120', 14350'-14360', 14375'-14385' 9605'-9620', 9624'-9645', 9656'-9662', 9496'-9506', 9630'-9640', 9655'-9665' BOP sketch 12465' 2534' measured 14420'-14430', 14442'-14487' true vertical 9557'-9575', 9670'-9676', 9695'-9700', 9706'-9731' proposed: Tubing (size, grade, and measured depth 4-1/2" L-80 tubing w/tail @ 12189' MD Packers and SSSV (type and measured depth) WD packer ~ 12040' MD, Camco SSSV ~ 303' MD Attachments Description summary of proposal _ Detailed operation program 14. Estimated date for commencing operation July. 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Suspended Service J17. I her~b.~, certify that the foregoing is true and correct to the best of my knowledge. Jsigned Title ~-~.~,"~...~ I ~ ~c~ FOR OOMMI8810N USE ONLY J Conditions of)approval: Notify Commission so representative may witness Plug integrity _ BOP Test Mechanical Integrity Test _ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Date IApprova[ No. __ Location clearance __ ,~pproved Copyl ,~'.~- / 7 / Subsequent form require 10-4JO-/ Returned ,,, '7, _~- c/~ Original Signed By l-3~irt W . h~hn~,-,,-, Commissioner Date 7/2/y SUBMIT IN TRIPLICATE KING SALMON PLATFORM PERFORATING PROCEDURE WELLS K-10RD, K-21RDL, K-23 June 9, 1992 OBJECTIVE The purpose of this work is to increase the oil production rate and decrease the rate decline in wells K-10RD, K-21RDL, and K-23 by selectively m-perforating Hemlock intervals. 2-1/8" strip guns with 4 SPF and zero-degree phasing are recommended. A list of equivalent perf guns from the various service companies is attached. WELL STATUS The current stares, perforating depths, tubing restrictions, and gauge ring data are presented for each well on the accompanying Well Data Sheets. Individual well schematics are also attached. PROCEDURE . 3~ Obtain a representative 12-hour well test prior to perforating. Conduct a safety meeting with ali appropriate personnel. Obtain a diagram of the tool string prior to commencing E-line operations. Rig-up E-line unk and lubricator. Make-up tool string of adequate weight bars, perforating guns, decen~i~ and CCL. Turn off platform radios, phones and electric welders and make thc proper announcements before arming guns. These may be returned to service after the tool string is 500 feet below the wellhead. 4. Pressure test lubricator to 2500 psi. e RIH with well shut-in, and tie into CBL or CET as referenced in the Well Data Sheet. Position gun below interval to be perforated. Route well to test and/or swab separator. Unload well and produce for at least thirty minutes to establish adequate drawdown. , Raise gun to proper depth and fire. Allow well to flow for 10 minutes to clean-up perforations. . Shut-off injection gas, close wing valve, and POOH. Turn off platform radios, phones and electric welders and make the proper announcements before reaching the SSSV. Check gun and record depths of any misfires. Repeat thc gun mn if necessary. 9. Repeat steps 5 through 8 for the gun runs listed on the Well Data Sheets. NOTE: Well K-21RDL will be perforated in stages, with an intermediate 12 hour well test following the perforation of Bench 7. Benches 5 and 6 should not be repefforated until an ARCO engineer has had time to review the well tests results. R E ~ [ [ V ~ D J U L - 1992 Alaska Oil & Gas Cons. Commission Anchorage 10. 11. 12. NOTE: Well K-23 will also be perforated in stages, with an intermediate 12 hour well test following the repeffomtion of Bench 3. Bench I should not be repefforated until an ARCO engineer has had time to review the well tests results. Rig-down electric line unit. Return well to production and obtain a stabilized 12-hour well test. Repeat steps 1 through 11 for all wells. Murray O. Hamilton Cook Inlet Engineering Endorsed By .~(~ ~ W~LL DATA SHEET Ob_iecriv~ The purpose of this work is to increase oil production rate and decrease production decline by re- perforating Hemlock Benches 1 and 3. Status Well K-23 is currently perforated in Benches 1-4 with Bench 1 cement squeezed, and lower Bench 3 and Bench 4 under fill. On 6/2/92 this well tested at 141 BOPD/2184 BFPD at 93.6% watercut and 2.2 MMSCFD lift gas. This well was worked over in February 1988 to remove a CTU motor/bit, cement squeeze Bench 1, and add new perforations in Benches 3 and 4. Bench 1 was squeezed in order to better evaluate the production from Benches 3 and 4. It was originally planned to reperf Bench 1 after preliminary tests on Benches 3 and 4, but this work was never completed. K-23 was started on the scale inhibition treatment program in 10/88. A production profile obtained on 2/28/89 showed the majority of fluid and oil production from Benches 3-4. In recent months K-23 has shown steeper than usual decline in total fluid rate and oil rate. Near wellbore damage due to scale buildup or fines migration is the likely cause. Perforation Data Tie-in Log: 4/13/78 Dresser Arias CBL (CBL is 10' off depth with DIL; CBL = DIL - 10') RunNo.. Bench Interval CMD-CBL~ Interval (MD-DILl ~ SPF 1 3 14365-14375 14375-14385 10' 4 2 3 14340-14350 14350-14360 10' 4 OBTAIN 24 HOUR WELL TEST BEFORE CONTINUING 3 1 14100-14110 14110-14120 10' 4 30' Gauge Ring Data: (5/12/92) 1.70" gauge ring tagged fill @ 14,434' WLM (14,468' MD) Minimum Tbg Restriction: Camco "DB-6" nipple (ID = 3.75") @ 12,156' MD ARCO Alaska, Inc. T~ading Bay Unit - King Salmon_platform Well ~ ,~Pi~: 50-73~20313-00 C;oua Date: 1-19-78 Completion Date: 2-24-88 ,iginal RKB: 100' MSL Hanger Type: FMC 4-1/2" BTC rap of Hemlock: 14102' Max Hole Angle: 70° @ 13265' Annulus Fluid: Sea water Last Revisecl: 02-27-90 All Depths are RKB MD to Top of Equipment. vCeli Type: Proclucer New ~ Workover RKB to Hanger: 33.75' Angle at Pefforc~ons: 57° Reason: Gauge Ring Data 11 12 13 Jewelry I 303' 2 12038' 3 12040' 4 12042' $ 12156' 6 12189' 7 12189' Camco TRDP-1A $$SV nipple: ID · 3.812' Locator seal assernt~l~ (Seals - t8.27' + mule shoe - 0.98~ Offs 'WD' Pe~ma-Drlll pkr. w/5' bore Seal bore extension (0.60 + 19.51 + 0.47 = 20.58~ Can~a "DB-6' No*C~o nLagle: tD - 3.750' Offs 4-1/2' WL rccntry guide 4-1/2" tubing tal Cming ami Tubing 8 13-318' 72iR & 68tR 9 9-5/8" 47~ 10 7 ' 29~ 11 4-1/2' 1~ K-55 34' ,5005' Casing S-95 BTC 34' 12482" Castng N-80 BTC 12166' 14700' Uner L-80 ABM-BTC 34' 12189' IPCTubtng Lilt Infomx~on 2451' 1 2338' 4681' 2 3743' 62B~ 3 4782~ 7783' 4 8912' 5 ~;~,' 9704' 6 6849' 10404' 7 7338' 1116~ 8 7835' 11981' 9 Camco MMG CA. ~20 R K 1/4' Camco MMG CA. R-20 RK 1/4' Camco MMG MA. JMR-2 RK 5/16' Camco MMG MA. JMR-2 RK 3/8* Camco MMG MA. JMR-2 RK 7/16' Camco MMG MA. JMR-2 RK 7/16' Camco MMG MA. JMR-2 RK 7/16' Camco MMG MA. JMR-2 RK dura Camco MMG MA. JMR-2 RK dum 1143 1220 11,.~ 12a8 1215 12a5 12:/5 1185 1345 11~) 13~ 1135 alit grit PeH~:m ~- DIL 13 1 14102/9394' 14110-14158' 2 14175/9436' 14179-142]~ 14963-14288' 14295-1~ 3 14356/9539' 14350-14360' 1442~1443(7 14442-14450' 4 14450/95~ 14450-14487' · . FT SPF 48 SQZD 33 4-8 25 4 33 4 10 4 10 4 10 4 8 4 37 4 G~uge Ring anct Fill Level Dab= 2-23-88 3.75" 82013' No tight spots Did not attempt to run GR deeper 9-7-88 3.75' 12134" No tight spots Did not attempt to run GR deeper 9-7-88 3.70' 13146' Would not go cleeper. Hole angle = 6,9'. 12-18-88 PL 13275' Nocleeper 2-28-89 PL 144~0' No deeper 3-2-89 3.75' 7770' GLV ~ as fish 1-23-90 3.70' 14370' taggea fill PB1D= 1466~ MD 10 = 147Q3' MD Dak111 = 14Q25'MD (9350'SSo 945171VD) RECEIVED J U L - 2 1992 Alaska Oil & Gas Cons. CommissiOn Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspend m Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Change approved program m Pull tubing ~ Variance _ Perforate ;~ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Corporation Development X (ARCO Alaska, Inc. is sub-ooerator) Exploratory _ 100' KB above MSL feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 service __ Trading Bay Unit 4. Location of well at surface 8. Well number 698' FSL, 81' FEL, Sec. 17, T9N, R13W, SM K-23 !21-27) _ At top of productive interval 9. Permit number 91' FSL, 1754' FWL, Sec. 22, T9N, R13W, SM At effective depth 10. APl number 367' FNL, 1875' FWL, Sec. 27, T9N, R13W, SM _50~133-20313__ _ At total depth 11. Field/Pool 394' FNL, 1881' FWL, Sec. 27, T9N, R13W, SM Hemlock R ~(~ ~IV ~- 12. Present well condition summary Total Depth: measured 14700' feet Plugs (measured) 14660' JUL - (J true vertical 9808' feet Effective depth: measured I 4 6 6 0' feet Junk (measured) 14370' Alaska. 0ii & Gas Cons. C true vertical 9 7 9 0' feet 'Anch0mge Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 4 9 71' I 3 - 3 / 8" yes 5005' 3 9 4 0' Intermediate I 2 4 4 8' 9-5/8" yes 1 2 4 8 2' 8 6 8 0' Production Liner 2 5 3 4' 7" yes 1 4 7 0 0' 9 8 0 9' Perforation depth: measured 14110-14158' ; 141 79-14209' ; 14263-14288' ; 14295-14330' ; 14350-14360' ; 14375-14385' ; 14420-14430' ; 14442-14487' true vertical 9498-9526'; 9538-9556'; 9587-9602'; 9606-9626'; 9637-9642'; 9651-9656'; 9675-9680'; 9686-9710' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 BTC @ 12189' MD Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 303' MD; Otis "WD" pkr @ 12040' MD 13. Attachments Description summary of proposal Detailed operation program _X__ BOP sketch Proposed perforations attached. , 14. Estimated date for commencing operation 15. Status of well classification as: June. 1 991 Oil _~. Gas ... Suspended 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~:::~ .~," .,~.~,~ .~. .Title /"~..-¢. ~../Z',.~,F ..'.~....- Date c~ ~ FOR COIV~llSSION USL~ONL~ Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity ,.. BOP Test ~ Location clearance ~ I ~::;~"',~-~ Mechanical Integrity Test ~ Subsequent form require 10- /~c~C~ Approved Copy Ret/Jrned ~. 0RIGINAI~ SIGNED B~' Approved bY the O~de' Of tl~e Comm'ssion~ Commissioner Date 7 Form 10-403 Rev 5/03/89 SUBMIT I CATE SUMMARY OF PROPOSED WELL OPERATIONS WELL TBU K-23 (June, 1991) 1. RU E-line unit. 2. Perforate the following intervals under draw-down conditions: ~ Bench Interval (MD-CBL~ Interval (MD-DIL) 1 3 14340-14350 14350-14360 2 2 14168-14184 14178-14194 Note: Lubricator will be pressure tested to 2500 psig prior to each mn. 3. RD E-line unit and lubricator. Lcn~h SPF 10' 4 16' 4 26' RECEIVED d U L - 9 ~99~ Alaska OJJ 8,.. Gas Cons. CommisSim~ Anchorage E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve ,A~a Oii & Gas Co~s~ Commi~z~o~ A~chom~o Double ~aster Wellhead MOH 6/1/91 Unocal North Amer' Qil & Gas Division Unoca~ Car~oraz]on P.O. Box 190247 Anchorage. Alaska 99519-024.7 TeieDnone tg0~ 276-7600 Alasxa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regional Drilling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG #l: LEG #2' 9 l0 ll 12 13 14 15 16 LEG #3: 17 18 20 21 22 23 24 Leg #4' 25 26 27 28 29 30 31 32 "Y" COOR. "X" COOR. WELL #' FNL 2,511,762 213,819 K-21 & RD 688 2,511,761 213,815 K-30 687 2,511,764 213,811 K-18 690 2,511,768 21 3,810 K-17 694 2,511,772 213,812 K-23 (23-19) 698 2,511,773 213,817 K-19 699 2,511,770 213,821 K-22 & RD 696 2,511,766 213,822 K-20 692 2,511,690 213,768 2,511,686 213,772 K-15 & RD 611 2,511,684 213,768 K-9 610 2,511,687 213,763 K-4 & RD 613 2,511,691 21 3,762 K-11 617 2,511,695 213,765 K-13 & RD 621 2,511,696 21 3,769 K-2 & RD 622 2,511,694 213,776 K-7 & RD 619 2,511,689 21 3,774 K-5 615 2,511,723 213,712 2,511,721 213,708 2,511,724 213,703 2,511,728 213,702 2,511,732 213,705 2,511,733 213,709 2,511,731 213,713 2,511,726 213,714 2,511,799 213,760 2,511,798 213,756 2,511,801 213,752 2,511,805 21 3,751 2,511,809 213,753 2,511,810 213,758 2,511,807 21 3,762 2,511,803 213,763 K-8 K-1 &RD K-10 &'RD K-16 K-12 & RD K-6 & 24 K-3 & RD 725 724 727 731 735 736 729 FWL 74 78 82 83 81 76 72 71 121 126 130 131. 128 124 120 ll9 133 135 141 142 140 135 130 STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNOCAL (ARCO Alaska, Inc. is sub-operator) 78-4 3. Address 8. APl Number P. 0. Box 190247, Anchorage, AK 99519 50- 133-20313 4. Location of well at surface Leg #], L. onO. ~.~ 9. Unit or Lease Name 698' FSL, 81' FEL, Sec.17, TgN, R13W, SM Trading Bay Unit At Top Producing Interval 10. Well Number 91' FSL, 1754' FWL, Sec.22, T9N, R13W, SM K-23 (21-27) At Total Depth 11. Field and Pool 394' FNL, 1881' FWL, Sec.27, TgN, R13W, SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Hemlock Pool RKB 100' MLLWI ADL 18730 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 01 / 19/78 04/09/78 04/24/78 * N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) i9. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 14700'MD, 9808'TVD 14670'MD, 9794'TVD YES~] NO [] 303 feet MDI N/A 22. Type Electric or Other Logs Run DIL, Sonic/GR, CBL/CCL/GR, FDC/CNL, CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Z~,'' -- ' -- Surf 384 ' -- Pi 1 e dri ven 13-3/8" 72#/68# N-80/K-55 Surf 5005' 17-1/2" 1887 sx Class G & 50¢ sx neat cmt 9-5/8" 47# S-95/N-80 Surf 12495, 12-1/4" 1000 sx Class G 7" 29# N-80 12166' 14700' 8-1/2" 800 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf 4-1/2" 12189' 12040' . .. 14179'-14209'MD 9557 '-9575 'TVD ,, , 14263'-14288 'MD 9605 '-9620 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14295'-14330'MD 9624'-9645'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14350'-14360'MD 9656 '-9662 'TVD Perfs f/13581'-1417¢' 275 sX Cla~s ~ 14375'-14385'MD 9670'-9676'TVD 14420'-14430'MD 9695 '-9700'TVD 14442'-14487'MD 9706'-9731'TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 4/23/78 Gas lift , Date of Test Hours Tested PRODUCTION FOR OI L-BBI_ GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/23/78 12 TEST PERIOD I~ 3268 Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAs-McF wATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · NOTE: Workover performed & perforations added 2/24/88. ?!ii?,~ ..... Submit in d~e~9 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Hemlock B-#2 B-#3 B-#4 GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 9493' 9533' 9635' 9691' FORMATION TESTS 14100' 14170' 14347' 14450' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ."' ~xoy O~-~berts Title Environmental ErlgDAte 4/28/88 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 STATE OF ALASKA .... ALA,, A OIL AND GAS CONSERVATION CON., .~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other ~ WORKOVER 2. Name of Operator UNOCAL (ARCO Alaska~ Inc. is sub-operator) 3. Address P.O. Box 190247, Anchorage, AK 99519 4. Location of well at surface Leg 1, Conductor 5 698' FSL, 81' FEL, Sec.17, TgN, R13W, SM At top of productive interval 91' FSL, 1754' FWL, 5ec.22, T9N, R13W, SM At effective depth 367' FNL, 1875' FWL, 5ec.27, TgN, R13W, SM At total depth 394' FNL, 1881' FWL~ Sec.27~ TgN~ R13W~ SM 11. Present well condition summary Total depth: measured 14700 true vertical 9808 'TVD feet feet 5. Datum elevation (DF or KB) RKB 100' 6. Unit or Property name Tradincp Ba~, Unit 7. Well number K-23 (21-27) 8. Approval number 7-BB1 g. APl number 50-- 1~,-?~'~1'~ 10. Pool Hemlock Plugs (measured) None Feet Effective depth: measured 14670'MD true vertical 9794 'TVD feet feet Junk(measured) Junk (EZ drill plug) ~ 14660' Casing Length Size Conductor 354 ' 24" Surface 4975 ' 13-3/8" Producti on 12465 ' 9-5/8" Liner 2534' 7" Cemented Measured depth True Vertical depth Pi le driven 384'MD 384'TVD 2387 sx C1 ass G 5005 'MD 3940'TVD 1000 sx Class G 12495'MD 8688'TVD 800 sx Class G 12166'-14700'MD 8450'-9808'TVD Perforation depth: measured true vertical 9557 ' -9575 ' 9656 ' -9662 ' Tubing (size, grade and measured depth) 4-1/2", L-80 tbg w/tail ~ 12189' Packers and SSSV (type and measured depth) WD pkr @ 12040' & SSSV @ 303' 14179'-14209', 14263'-14288', 14295'-14330', 14350'-14360', 14375'-14385', 14420'-14430', 14442'-14487' , 9605'-9620', 9624'-9645', , 9670'-9676', 9695'-9700', 9706'-9731' 12. Stimulation or cement squeeze summary Intervals treated (measured) Perforations f/13581'-14170' Treatment description including volumes used and final pressure 275 sx Class G 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover W~_l History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) SW03/56 Submit in Duplicate ARCO Oil and Gas Company,v,"~ Well History- Initial Report- Dally Instructions: Pre0are and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field I ~ounty. parish or borough KENAI BOROUGH Lease or Unit [(--23 TRADING BAY UNIT ITM I WORKOVER I Sta~( IWell no. Auth, or W.O. no. AD6081 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/27/88 ( TD:14700 PB:14670 SUPV:ML 01/28/88 ( TD:14700 PB:14670 SUPV:HP 01/29/88 ( TD:14700 PB:14670 SUPV:HP 01/30/88 ( TD:14700 PB:14670 SUPV:HP 01/31/88 ( TD:14700 PB:14670 SUPV:HP 02/01/88 ( TD:14700 PB:14670 SUPV:HP 02/02/88 ( TD:14700 PB:14670 SUPV:HP API: 50-133-20313 I ARCO W.I. IDate IHOur IJ 18' 0000W.O.status if a 01/26/88 1300 ['[~S iPri°r Complete record for each day reported KING SALMON ) · ND TREE MW: 0.0 SKID RIG OVER WELL. ACCEPT RIG ~ 1300 HRS 1/26/88. KILL WELL. ND TREE. DAILY:S8,400 CUM:$8,400 ETD:S8,400 EFC:$900,000 PREP TO PULL LDT MW: 8.5 FIW ND TREE. NU BOPE AND TEST TO 1800 PSI. UNSEAT TUBING. REVERSE CIRCULATE. MONITOR WELL. PREPARE TO POOH LD TUBING. DAILY:S12,400 CUM:$20,800 ETD:S20,800 EFC:$900,000 VENTING GAS MW: 8.5 FIW POOH LD 276 JTS OF TUBING. RECOVER BLIND BOX CUTTER AND BLIND BOX FISHING STRING. ATTEMPT TO CIRCULATE DOWN TUBING. THAW OUT DEGASSER AND CHANGE LINE. PRESSURE BACK SIDE TO 1000 PSI. ATTEMPTING TO RELIEVE TRAPPED PRESSURE BELOW TUBING BRIDGE. DAILY:S14,256 CUM:$35,056 ETD:S35,056 EFC:$900,000 WO OTIS HOT TAP EQUIP CONTINUE TO VENT GAS. HOT TAP EQUIPMENT. MW: 8.5 FIW SECURE VENTING OPERATION. WO OTIS DAILY:S12,800 CUM:$47,856 ETD:S47,856 EFC:$900,000 WO OTIS HOT TAP EQUIP WO OTIS HOT TAP EQUIPMENT. DAILY:S12,400 CUM:$60,256 ' MW: 8.5 FIW ETD:S60,256 EFC: 8900, 000 ..... LAY DOWN TUBING MW: 8.5 FIW WO OTIS HOT TAP EQUIPMENT. RU SAME. TEST AND DRILL HOLE TBG. REVERSE CIRCULATE OIL AND GAS FROM TBG. RD OTIS. POOH LAYING DOWN TBG. DAILY: $12,400 C~: $72,656 ETD: $72,656 EFC:$900,000 CBU MW: 8.5 FIW FINISHED POH, LDT. CHANGED PIPE RAMS TO 5" & TESTED TO 3000 PSI-OK. INSTALL WEAR RING. MU MILLING BHA & TIH. CIRC. & WASHED TO TOP OF PACKER. MILLED ON PACKER. CIRCULATE BOTTOMS UP. DAILY:S39,626 CUM:$112,282 ETD:S112,282 EFC:$900,000 The above is correct For form preperation/~Tnd distribution, see Procedures MerCI, Section 10, IDate Title ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptl~ as of 8:00 I County or Parish ARCO Alaska. Inc, I KENA[ Lease or Unit BOROUGH · UNTT I K-23 Complete record for each day while drilling or workover in progress 02/03/88 ( TD:14700 PB:14670 SUPV:HP 02/04/88 ( TD:14700 PB:14670 SUPV:HP 02/05/88 ( TD:14700 PB:14670 SUPV:MAL 02/06/88 ( TD:14700 PB:14670 SUPV:MAL 02/07/88 ( TD:14700 PB:14670 SUPV:MAL 02/08/88 ( TD:14700 PB:14670 SUPV:MAL 02/09/88 ( TD:14700 PB:14670 SUPV:MAL KING SALMON 8) 9) .0) .1) .2) .3) 14) I StateAK PU 3-1/2" DP MW: 8.5 FIW FINISHED CIRC. BOTTOMS UP. POH SLOWLY. LD PACKER FISH & W.O. FISHING TOOLS. RIH WITH 8-1/2" CO BHA. CIRC. POH. LD 8-1/2" BHA. MU 6" BHA & PU 3-1/2" DP. DAILY:S38,296 CUM:$150,578 ETD:S150,578 EFC:$900,000 PREPARE TO POH MW: 8.5 FIW PU 3-1/2" DP. RIH. TAGGED UP @ 14095'. CLEANED OUT LINER TO 14670' PBTD. CIRC. HIGH-VIS SWEEP. CIRC. HOLE CLEAN. DAILY:S14,727 CUM:$165,305 ETD:S165,305 EFC:$900,000 TIH W/7" RTTS MW: 8.5 FIW ATTEMPTED TO TOH. TIGHT. RU & REVERSE CIRC. FINE SOLIDS/SAND OUT OF HOLE UNTIL RETURNS CLEANED UP. TOH. LD BIT/SCRAPER/JB. PU 7" RTTS & TIH. DAILY:S13,400 CUM:$178,705 ETD:S178,705 EFC:$900,000 TIH W/7" BRIDGE PLUG MW: 8.5 FIW TIH W/7" RTTS. SET @ 14060'MD. TESTED CASING & LINER LAP TO 2500 PSI FOR 30 MINUTES-OK. REVERSE CIRC. HOLE CLEAN. TOH. RU SOS & RUN CNL/GR/CCL FROM 14645'-11900'. RD WIRELINE UNIT. MU 7" DRILLABLE BP. RIH W/3-1/2" & 5" DP. DAILY:S13,400 CUM:$192,105 ETD:S192,105 EFC:$900,000 TIH W/BIT TO CLEAN OUT CE MW: 8.5 FIW TIH WITH 7" DRILLABLE BP. RU SOS WIRELINE UNIT. RIH. CORRELATE & POSITION BP @ 14172' POOH. RD SOS. SET BP @ 14172'. RU BJ. SPOTTED 100 SX CLASS G CEMENT ON TOP OF THE BP. PULLED 12 STDS. SQUEEZED AWAY 4 BBLS CMT. HOLD 2000 PSI FOR 4 HOURS. TOH. PU CLEAN-OUT ASSY. TIH. DAILY:S42,744 CUM:$234,849 ETD:S234,849 EFC:$900,000 TOH MW: 8.5 FIW TIH. TAGGED UP @ 13581'. SERVICED RIG. DRILLED FIRM CEMENT F/13581'-13685'. CIRC. BOTTOMS UP. ATTEMPTED TO PRESSURE TEST THE SQUEEZE. CHECKED FOR SURFACE LEAKS. PRESSURE BLED F/2500 PSI TO 0 PSI IN 22 MIN. REV. CIRC. BU. TOH TO LD BIT. DAILY:S21,815 CUM:$256,664 ETD:S256,664 EFC:$900,000 TOH MW: 8.5 FIW TOH. LD BIT. RIH W/ OPEN ENDED DP. RU BJ. TEST LINES TO 3000 PSI. SPOT 75 SXS OF "G" CEMENT ON TOP OF BP AT 14170' PULL 9 STANDS OF DP. REV CIRC DP. SQZ AWAY 2 BBLS CEMENT. HOLD 2000 PSI FOR 4 HRS. TOH. DAILY:S13,400 CUM:$270,064 ETD:S270,064 EFC:$900,000 IWell no. The above is correct Signature ~ ~./,~ For form preparation/][nd distribution see Procedures Mar~l Section 10, Drilling, Pages 86 al~d 87 Date ITitle ASSOCIATE EN~ilNEEH ARCO Oil and Gas Company,,,"~' Daily Well History--Interim Instructions: This form's u ' gAttach ...... aua~.,i"[ion~, or a~i corus, vvu,,~ t~=,,ur uu y y P t Im" sheets until final Number a dril stem tests sequentiallY.sentative tes[' ' u-n "Final" form. 1) Subm t "Interim'" sheets when filled' out but not less frequently than every 30 days, or (2) comp et on Report official or repre --, c,,bmit weekly for workovers and fo ow ng setting of oil string until completion. on Wednesday of the week in which oil string ~s District I Stat~K County or Parish I KENAI BOROUGH ARCO Alaska, Inc. ILease or Unit IWell no. Field I TRADING BAY UNIT I K-23 Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. KING SALMON 02/10/88 ( 1 TD:14700 PB:14670 SUPV:MAL i) REPAIRING BOPE MW: 8.5 FIW TOH. MU 6" BIT. TIH. TAG CMT AT 13751' DRLD CMT TO BP AT 14170'. REPAIRING BOPE. DAILY:S39,446 CUM:$309,510 ETD:S309,510 EFC:$900,000 PREP TO POOH MW: 8.5 FIW REPAIR BOPE. TEST SQUEEZE # 2 TO 2000 PSI. PRESS BLED TO 0 PSI IN 30 MIN. POOH. RIH W/ RTTS. SPOT 100 SX BALANCE PLUG OF CLASS "G" CEMENT ON TOP OF RET AT 14170'. DAILY:S13,400 CUM:$322,910 ETD:S322,910 EFC:$900,000 PREP TO TEST CSG MW: 8.5 FIW PULL 8 STANDS DP. REVERSE CIRC. SET RTTS. PRESS TEST CMT PLUG TO 4000 PSI. OK. RELEASE RTTS AND POOH. TEST BOPE TO 3000 PSI. OK. RIH W/ 6" CLEAN OUT ASSEMBLY. DAILY:S29,538 CUM:$352,448 ETD:S352,448 EFC:$900,000 MU & STRAP PERF ASSY MW: 8.5 FIW TESTED CASING TO 2000 PSI-OK. TAGGED CMT @ 13834' DRILLED F/13834'-14165'. REV. cIRC. HOLE CLEAN. TESTED SQUEEZED PERF ZONE TO 2000 PSI-OK. DRILLED EZ DRILL PLUG & PUSHED PLUG TO BOTTOM. (NEW PBTD=14660') REV. CIRC. HOLE CLEAN. POH & LD BHA. PU & MU TUBING CONVEYED PERF ASSEMBLY. DAILY:S13,600 CUM:$366,048 ETD:S366,048 EFC:$900,000 POH W/PERF ASSEMBLY MW: 8.5 FIW RIH WITH PERF GUNS ON DP. CORRELATE DEPTH. PERFORATED THE FOLLOWING WITH 4 SPF, 20.0 GM CHARGES: 14179'-14209', 14263'-14288', 14295'-14330', 14350'- 14360', 14375'-14385' 14420'-14430', 14442'-14487'. FLOWED WELL. REV OUT & KILLED WELL. POH WITH PERF ASSEMBLY. DAILY:S13,600 CUM:$379,648 ETD:S379,648 EFC:$900,000 PREPARE TO MU TAILPIPE FINISHED POH WITH PERF ASSEMBLY. ASSEMBLY. CIRCULATE HOLE CLEAN. MW: 8.5 FIW LD. RIH WITH CLEAN OUT POH, LD 75 JTS 3-1/2" DP. DAILY:S66,828 CUM:$446,476 ETD:S446,476 EFC:$900,000 POH MW: 8.5 FIW MU OTIS WD PACKER & TAILPIPE ON DP. RIH. PACKER PREMATURELY SET @ 6460'. POH. PU MILL OVER FISHING TOOLS. RIH. MILLED OVER PACKER. POH. DAILY:S28,218 CUM:$474,694 ETD:S474,694 EFC:$900,000 02/11/88 (1i) TD:14700 PB:14670 SUPV:HP 02/12/88 ( 1 ) TD:14700 PB:14670 SUPV:HP 02/13/88 ( TD:14700 PB:14670 SUPV:HP 02/14/88 ( 1!) TD:14700 PB:14670 SUPV:HP 02/15/88 (2(~) TD:14700 PB:14670 SUPV:HP 02/16/88 ( 2~.) TD:14700 PB:14670 SUPV:HP The above is correct For form preparation,4nd distribution see Procedures Man~l Section Drilling, Pages 86 a/~ 87 IDate ITitle ~- 1~-~ ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instructions' This form is used durinn dr iling or workover operations. If. te.sting,.coring.,,or..per!orating~, show formation name in describing work performed. ..... '- = ....... , ~- of all cores WOrK performs(3 oy ~rooucing ~ection will be reported on "Interim" sheets until f hal ~_u_m?,er..ail ~.[rHi stem .t. ests sequentially: ~ttac. n_~..~",?~}~;i,, form 1) Subm t "Interim" sheets when filled out but not less frequently than every 30 days or (2i (.u,.pls[ion. Hepor! ofticial or represen[auve les[ u,, - ' ' on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ARCO Alaska. In¢ ICountyorParish JState K~NAI ROROUGR Field TpAnT~. Date and deptl'l as of 8:00 a.m. 02/17/88 ( TD:14700 PB:14670 SUPV:HP 02/18/88 ( TD:14700 PB:14670 SUPV:ML 02/19/88 ( TD:14700 PB:14670 SUPV:ML 02/20/88 ( TD:14700 PB:14670 SUPV:ML 02/21/88 ( TD:14700 PB:14670 SUPV:ML 02/22/88 ( TD:14700 PB:14670 SUPV:ML 02/23/88 ( TD:14700 PB:14670 SUPV:ML ILease or Unit ' [INTT Complete record for each day while drilling or workover in progress ~2) ~3) :5) KTNG SAL~ON !6) ~7) .~8) RIH WITH DP MW: 8.5 FIW LD MILL OVER SHOE. PU SPEAR ASSEMBLY. RIH. SPEAR FISH @ 6138'. POOH. LD FISH AND SPEAR ASSEMBLY. RIH WITH BIT, ' SCRAPER, AND JARS TO TOL @ 12166'. CIRC 75 BBL HI-VIS SWEEP. POOH. LD 8-1/2" BHA. PU 6" BIT AND 7" SCRAPER AND RIH. DAILY:S23,296 CUM:$497,990 ETD:S497,990 EFC:$900,000 TIH W/ PKR ASSY MW: 8.5 FIW TIH TO 14660', PBTD. CIRC HOLE CLEAN. TOH. LD BHA. MU 9-5/8" PKR/TAILPIPE ASSY. RIH ON 5" DP. DAILY:S13,946 CUM:$511,936 ETD:S511,936 EFC:$900,000 RUNNING 4-1/2" COMPL. MW: 8.5 FIW TIH WITH 9-5/8" PACKER. SET @ 12040' TOH. CHANGED AND TESTED PIPE RAMS. RU AND STARTED RUNNING THE 4-1/2" COMPLETION STRING. DAILY:S13,600 CUM:$525,536 ETD:S525,536 EFC:$900,000 LD 4-1/2" TUBING MW: 8.3 FIW FINISHED RUNNING 4-1/2" TUBING. SPACED OUT. ATTEMPTED TO LAND AND CHECK SPACE OUT. CIRCULATING WHILE LANDED ON PACKER. RU SOS. CONFIRMED CIRC. AROUND SEAL ASSY. RD SOS. RU AND LD 4-1/2" TUBING STRING. DAILY:S28,136 CUM:$553,672 ETD:S553,672 EFC:$900,000 POOH TO RUN COMPL. MW: 8.5 FIW POOH AND LD 4-1/2" TUBING. CHANGED TO 5" PIPE RAMS AND TESTED TO 3000 PSI. RIH WITH SEAL ASSY ON 5" DP. STING INTO PACKER. TESTED CASING AND PKR TO 2000 PSI. UNSTING. CIRCULATE BOTTOMS UP. POOH. DAILY:S15,400 CUM:$569,072 ETD:S569,072 EFC:$900,000 RUNNING 4-1/2" COMPL. MW: 8.5 FIW TOH. CHANGED TO 4-1/2" PIPE RAMS AND TESTED TO 3000 PSI. REPLACED SEALS ON SEAL ASSY. RUNNING 4-1/2" COMPLETION STRING. DAILY:$2tS,400 CUM:$787,472 ETD:S787,472 EFC:$900,000 JARRING ON STANDING VALVE MW: 8.5 FIW RAN 382 JTS 4-1/2", 12.6~, L-80, ABM BTC TBG W/PI<D. @ 12040', TAIL @ 12189'. STING INTO PKR. UNSTING & DISPLACE HOLE W/FIW TREATED WITH CORR. INHIBITOR. SPACED OUT & LAND TUBING. SET STANDING VALVE @ 12160' WLM. ATTEMPTED TO TEST TUBING TO 2500 PSI - UNSUCCESSFUL. RIH TO RETRIEVE STANDING VALVE. LATCHED PLUG & JARRED. POOH. RIH AND LATCHED IWell no. The above is correct VALVE. JARRING ON STANDING VALVE. (SSSV @ 303' ) For form preparation .alj[d distribution see Procedures Man~'~l Section 10, Drilling, Pages 86 ant187 ARCO Oil and Gas Company Daily Well History--Interim Instruction~: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workevers and following setting of oil string until completion. District Field I County or Parish _ IState I KENAI BOROUGH AK A~CO Alaska, Inc.JLease or Unit I K-23 TRADING BAY UNIT Date and depth as of 8:00 a,m. 02/24/88 ( TD:14700 ~B:14670 SUPV:M~ Complete record for each day while drilling or workover in progress KING SALMON ~9) POH W/STANDING VALVE MW: 8.5 FIW RETRIEVED STANDING VALVE. RD WL UNIT. RU SOS. RAN SPINNER SURVEY. CONFIRM GLM VALVE LEAK @ GLM #8 (11160'). PRESSURE TESTED SSSV TO 1500 PSI - OK. RIH & LATCHED SSSV. POOH WITH SAME. DAILY:S19,767 CUM:$873,717 ETD:S873,717 EFC:$900,000 IWell no. The above is correct Signature For form preparation anJydistribution see Procedures Manual/~ection 10, Drilling, Pages 86 and ~7 Date ITitle ,..~-/~-~ ASSOCIATE ENGINEER . ! ARCO Oil and Gas Company Daily Well History-Final Report Instructions: t,P, repare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Repor should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon comp etion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operat on if space is available. I Accounting cost center code District ] Stat ARCO Alaska, Inc. - - Field TRADING BAY UNIT Auth. or W.O. no. Operator ARCO ICounty or Parish KENAI BOROUGH Lease or Unit Title WORKOVER K-23 IWell no. Spudded or W.O. begun ACC~.PT Date and depth as of 8:00 a.m. 02/25/88 ( TD:14700 PB:14670 SUPV:ML API: 50-133-20313 IA.R.Co. W.I. ~otal number of wells (active or inactive) on thisI ~ost center prior to plugging and 18. 0000 ~bandonment of this well IDate01/26/88 / ~our 1300 IPriOr status if a W'O' Complete record for each day reposed KING SALMON RIG RELEASED MW: 8.5 FIW RETRIEVE STANDING VALVE. CLOSE SSSV. SET BPV. ND BOPE. NU PRODUCTION TREE AND TEST TO 5000 PSI OK. RELEASE RIG @ 2400 HRS 2/24/88. DAILY:S26,283 CUM:S900,000 ETD:S900,000 EFC:$900,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data INew TD J PB Depth Date IKind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day .... Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation ;(l{d distribution, see Procedures Mam/'e~, Section 10, Drilling, Pages 86 anU' 87. ASSOCIATE ENGINEER STATE OF ALASKA AL, .<A OIL AND GAS CONSERVATION CO,. .AISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well:~ Alter casing C Time extension © Change approved program [] Plugging [] Stimulate © Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) RKB 100' feet 6. Unit or Property name Trading Bay Unit 7. Well number K-23 (21-27) 8. Permit number 78-4 9. APl number 50-- 133-20313 10. Pool Hemlock UNOCAL (ARCO Alaska~ Inc. is sub-operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg 1, Conductor 5 698' FSL, 81' FEL, Sec.17, T9N, R13W, SM At top of productive interval 91' FSL, 1754' FWL, Sec.22, T9N, R13W, SM At eftective depth 367' FNL, 1875' FWL, Sec.27, T9N, R13W, SM At total depth 394' FNL, 1881' FWL, Sec.27, T9N, R13W~ SM 11. Present well condition summary Total depth: measured 1 4700 ' ND feet true vertical 9808'TVD feet Plugs (measured) None Effective depth: measured 14670'MD feet Junk(measured) 8750' (Dyna Drill) true vertical feet 9794 ' TVD 61 00 ' Casing Length Size Cemented Measured depth True Vertical depth Conductor 354' 24" Pile driven 384'MD 384'TVD Surface 4975' 13-3/8" 2387 sx Class G 5005'MD 3940'TVD Production 12465' 9-5/8" 1000 sx Class G 12495'MD 8688'TVD Liner 2534 7" 800 sx Class G 12166'-14700'MD 8450'-9808'TVD Perforation depth: measured 14110'-14158', 14180'-14194' truevertical 9498'-9576' 9538'-9546' Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80, BTC ~ 12144' Packers and SSSV (type and measured depth) 1 Baker FB-1 pkr @ 12064' & Camco TRB-6 SCSSV @ 296' Gas r, ........... ohs. Commiss!o~ Description summary of proposal [] Detailed operations program [] BOP sketch 12.Attachments 13. Estimated date for commencing operation November~ 24, 1987 14. If proposal was verbally approved Name of approver Date approved Date 15. I hereby~certify.that the fo,.re~going //,4./ '~; ~ '" S~gned (~, N, Lockwood Conditions of approval Approved by Form 10-403 Rev 12-1-85 is true and correct to the best of my knowledge j~c Title Environme~tal Sp~c~list Commission Use Only (T.IR) .qA'~/1 F, Notify commission so representative may witness I' Approval No. [] Plug integrity [] BOP T~Jpr~e[~l~ D~ clearancel - Returne~ /:~ . missioner by order of the commission Date J,'/I ~JJ ~'~ Submit in triplicato(~ KING SALMON PLATFORI~- WORKOVER PROGNOSi~ WELL TBU K-23 Remove exlatl~ 4-112' completion assembly, perforate production zones, run a new 4-1/2" X 3-1/2" tapered completion assembly, and put on production. K-23 has been shut-in since November, 1985 because of a stuck Navi-drill, fishing tools and wireline left inside the tubing. Heavy barium sulfate scale deposits are expected inside the tubing and the 7" liner. PROCEDURE 1. MIRU over well TBU K-23, leg #1, slot #5. Kill well with NaCI brine (expect 4120 psi bottom hole pressure ~ 9450' TVD). ND tree. NU and test BOPE. Pull and lay down 4-1/2" tubing string. /Vote: Expect a 2-3/8" Navi-drill with a 3-1/2" diamond bit at 8968' MD. Also expect assorted fishing tools and wireline above the Navi-drill and barium sulfate scale inside the tubing. Mill over and"recover Baker Model "FB-I" permanent packer set at 12064' MD inside 9-5/8" casing. Pressure test casing, and cement squeeze any casing leaks found above the perforated interval. 7. Clean out to PBTD @ 14670' MD. Expect barium sulfate scale inside the 7" liner. 8. Perforate Hemlock Benches 1-4 with 500-1000 psi under-balance using 5" tubing conveyed guns (approximately 180' of guns with 4 SPF and 220' of blanks will be required). Under-balance may be achieved with a partial fluid column in the drill pipe. Retrieve guns after perforating. 9. Run new 4-1/2" X 3-1/2" tapered completion assembly (see attached completion diagram). 1 0. ND BOPE; NU tree. RD and prepare rig for next well. 1 e 0 , . A. L. Moritz Cook Inlet Engineering October 14, 1987 Workover fluid: 8.6 ppg NaC1 brine K-23 PROPOSED COMPLETION SCHEMATIC O A. SSSV, TUBING RETRIEVABLE @ 380'-+ MD 13-3/8", 72#/FT, N-80 & 68#/FT, K-55 CASING @ 5005' MD GLM 6 NO. ~IZE 5 I 4-1/2" 2 4-1/2" 3 4-1/2" 4 4 4-1/2" 5 4-1/2" 3 6 4-1/2" 7 4-1/2" 2 8 4-1/2" 9 4-1/2" 4-1/2" X 9-5/8" PACKER @ 12,000'_+ TOP OF 7" LINER @ 12,166' MD 9-5/8", 47#/FT, S-95, BTC CASING @~.:~,495' MD ~TUBING TAIL W/WL RE-ENTRY @ 12,060' MD -' PERFORATIONS 14,110'-14 510' MD I - HOLE ANGLE AT PERFS IS 57° _- PBTD @ 14,670'MD · TD @ 14,700'MD NOT TO SCALE JG 10/23/87 13-5/8" 3000 PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 1. FMC TYPE III UNIHEAD 2.13-5/8" 5000 PSI HUB X 3000 PSI FLANGE ADAPTER 3.13-5/8" - 3000 PSI DRILLING SPOOL 4.13-5/8"- 3000 PSI BLIND RAMS 5.13-5/8"- 3000 PSI PIPE RAMS 6.13-5/8" - 3000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOp STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLDq3OWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURETO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 9, 1987 (FOR TBU WELLS) Union Oil and Gr" 'Wision: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union September 11, 1984 Hr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99502 Dear Hr. Chatterton: Sundry Notice - K-23 Attached for your approval is a request to perforate Hemlock Bench 3, Well K-23, King Salmon Platform, Cook Inlet, Alaska. Please return the approved Sundry Notice to the undersigned. Very truly yours, Lawrence O. Cutting Environmental Technician LOC:cwl Attachment RECEIVED SEP ! 19C4 'Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER[~ 2. Name of Operator 7. Permit No. Union Oil Company of California " 3. Address P. O. Box 6247, Anchorage, Alaska 99502 4. Location of Well 697' N & 81' W of SE Sec 17, TWP 9N, Range King Platform (Leg 1, 5. Elevation in feet (indicate KB, DF, etc.) 100 K.B. 12. cor. 13W, S.M. Cond. 23) 6. Lease Designation and Serial No. 8, APl Number 50- 133-20313 9. Unit or Lease Name Trading Bay Un i~ 10. Well Number K-23 11. Field and Pool McArthur River Hemlock Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: {Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Stimulate [] Abandon [] Stimulation [] Repair Well [] Change Plans [] Repairs Made [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Altering Casing [] Abandonment [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following Hemlock intervals will be perforated: Bench 3 14343-14363 ft. CBL Bench 3 14398-14418 ft. CBL NOTE: CBL reference is 4/13/78 *ARCO Alaska, Inc. is sub-operator RECEIVED SEP ! ,q I9~,4 Alaska 0tl & ~s Cons. Commission Anchorage 14. I hereby certify that the foreggJ~g is trjJ.e and correct to the best of my knowledge. , ned -,,,,,,-,,~- u. ~,u, , z,~u v ' ' S'g I nI.IDL.-lUr'E' n r'IITTI~Hp /-/l,.~---ii.l~-~ritle ENVIRONMENTAL TECH. The space below for Commission use Date 9/10/84 Conditions of Approval, if any: Approved by ....... 'tJJlIJlIIA[ Jltlli[O By Order of COMMISSIONER the Commission Approved Copy .~Returned ,_~ Form 10-403 Submit "Intentions" in Triplicate and "SubseQuent Reports" in Duplicate Form !0-403 REV. 1-10-73 Suhmtt"lntentlons" in Triplicate *'Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 50-133-20313 AD% ~8730 SUNDRY NOTICES AND REPORTS ON WELLS (Do not usa this form for proposals :o drill or to deepen Use "APPLICATION FOR PERMIT-'-~' for SUCh proposals.) "' o,~. r'g-I G~s ~ WELL L,.%J WELL OTHER 2. NAME O.F OPERATOR ~ 8. UNIT, FARM OFR LEASE Union Oil Company of California Trading Bay Unit AOOR¢SOFO~ERATOR 909 West Ninth Ave., Anchorage, "~ ~x 99501 LOCATION OF WELL At surface 698' N 7 81' W of SE cr Sec 17, %9N-R13W, S.M. ELEVATIONS (Snow whether DF, RT, GR, etc.,) 100 ' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 9. WE~..-¢44;~.' - - ~ ~3 (21-27)~ ~LD ANO POOL, OR WtLIOCAT McArthur River (Hemlock) ii. sEC., T., R., M., (BOTTOM HOLE OSJEC]°IVE) Sec 27, TgN-:B_T3W, S.M. 12. PERMIT NO. . 78-4 )orr, or Other Data NOTICE OF INTENTION TO: 1' TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTU.~E TREAT L-- MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON~ REPAIR WELL CHANGE PLANS (Ortner) Increase Measured Depth Permitted SUBSEQUENT REPORT OF: FRACTURE TREATMENT AI~TER lNG, ,CAS lNG SHOOTING OR ACIDIZING ABANDONMENT~' (Other) (NOTE: Report results of multiple completion pti Well Comotetion or Recomoletion ReOor~ and Log form,) DE3CRIBE PROPOSED .OR ~oI~PLETED OPERATIONS (clearly state ail pertinent details, and give pertinent dates, including estimated date of ~artlng any prol3osed work. .As pe~r verbal agreement from H/oyle Hamilton. to Richard Knowles 4-6-78, on we propose the following changes. ._ 9-5/8" set @ 12,495' 7" liner .set 12,200' to 14,850' Proposed depth of 14,850' MD, 9908' TVD _ These changes only increased the measured depth permitted and not the true vertical depth. Atlantic Richfield Company - Sub-operator RECEIVED APR 1 4 'i078 Division ci 0;I .~nd u¢.~ Consep;adon Aachorage 16o I herel3y c~TT¥ that tl3e foregoing i$ true anct correct SIGNED TITLE (This s~:~ce for State office use) APPROVED -_ Oist. Drlg. Supt. _. PATE- 41.17/7R ! age O°lPlnlSSion AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field McArthur River Auth. or W.O. no. County or Parish Lease or Unit Title Cook Inlet - Kenai ADL #18730 Drill and Complete JState Alaska IWell no. K-23 Operator ARCO Alaska, Inc. IDate 1/19/78 Hour 0100 Hrs. A,R.Co's W.I. Pr or status if a W.O. Spudded or W.O. begun Soudded .. Date and depth as of 8:00 a.m. 01/;18/78 01/19/78 01/20/78 01/21/78 01/22/78 01/23/78 01/24/78 Complete record for each day reported Skid rig to K-23 & RU. 409' (25'), POH w/bit Wt. ~.9, Vis 50, PV 15, YP 14, PH 7, Sol 4, Oil 0 Instl 20" Hydrl. Spud well @ 0100 hrs, 1/19/78. Displ wtr in hole w/mud. Tst 20" Hydrl & csg to 500 psi. DO solid cmt f/365'-384', no jnk. Drl f/384'-409'. Circ hole cln. Rn gyro, 50' stations to 'btm. 547', (138'), POOH w/impression block Wt. 9.0, Vis 63, PV 21, YP 22, PH 7, Sol 5, Oil 0 POH, MU BHA & RIH. Surv & jet drl f/409'-547', bit stopped on metal, POH, ck surv. Rn 11-1/2" OD rev circ bskt, circ on btm, drop ball, wrk pipe, rotate, POH, no recovery, lB indicates being on pipe. 547' (0'), WOC Wt. ;.0, Vis 56, PV 18, YP 14~_ PH 8.5, Oil 0 DA rn colr locater to 540', unable to interpret log. Rn #2 IB, POH~ indicates being on metal. PU 5" DP to 547', circ & RU cmt'rs. Plug 12-1/4" hole f/547'. CIP @ 9:30 p.m., 1/20/78. Rev out 2 bbls contaminated cmt @ 332' POH & WOC 542', (89'), Surv'g Wt. 9.0, Vis 52, PV 17, YP 14, PH 9, Sol 5, Oil 0 WOC. RIH to 399', no cmt. Locate 12-1/4" x 17-1/2" shoulder, POH, breakdn tls. Rn 12-1/4" bit, locate cmt @ 433', circ@ 423', pulled in shoe, WOC. Locate cmt @ 433', dressed off soft-to-hard cmt cut mud, POH. MU BHA, RIH, surv & orient DD. DD & surv, rn gyro f/453'-. 542'. 843', (301'), Prep to DD & DOT Wt. 9.0, Vis 67, PV 21, YP 15, PH 8, Sol 5, Oil 0 Drl & surv f/552'-843' POH. MU BHA, RIH RU rotating head, pack-off & DOT on DA. 1700', (857'), Drlg Wt. 9.2, Vis 65, PV 21, YP 17, PH 8, Sol 6, Oil 0 Repair pack-off & re-rn DOT. DD & surv f/843'-1700'o Surveys: 915', 5-3/4°, N68E 1139', 7-1/2°, S71E 1414', 13°, S64E 1597', 16-3/4°, S62E 976 ' 6° S89E ' ' 1231', 9°, S69E !506 ' 14-1/4 The above is correct For form preparatmn and dmtnbut~on see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate I Title 11/29/82 Drilling Superintendent AR3B-459-1--B INumber all daily well history forms consecutively as they ~re prepared for each well. iPage no, ARCO Oil and Gas Company '~',~, ~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish IState Alaska Cook Inlet - Kenai I Alaska Field Lease or Unit Iwell no. McArthur River ADL #18730 I K-23 Date and depth Complete record for each day while drilling or workover in progress as of 8:0.0 a.m. 01/25/78 01/26/78 01/27/78 01/28/78 01/29/78 01/30/78 2353', (653'), Circ'g Wt. 9.5, Vis 63, PV 21, YP 13, PH 8, Sol 8, Oil 0 Drl & surv f/1700'-2353'. Surveys: 1690', 18-3/4°, S64E 1783', 21°, S64E 1876', 23-1/4°, S64E 1969', 25°, S64E 2062', 28°, S62E 2155', 30°, S61E 2248', 33°, S61E 2315', 35°, S61E 2283', (0'), On btm @ 2283' Wt. 9.6, Vis 62, PV 20, YP 14, PH 8, Sol 9, Oil 0 Circ @ 2353', mx pill & slug pipe, POOH. Rn & orient impression block; impression block stopped @ 2349' POOH MU BHA RIH , · , , rm 2222'-2252' to sidetract old hole & surv. Surveys: 2235', 32-1/2° 2205', 31-1/2° 3076', (793'), Drlg Wt. 9.6, Vis 68, PV 21, YP 14, PH 8.5, Sol 9, Oil 0 Drl & surv sidetrack hole 2283'-3076'. Surveys: 2300', 30°, S62E 2394', 31-3/4°, S63E 2549-', 36-3/4°, S62E 2623', 40°, S63E 2716', 43-1/4°, S63E 2810', 46°, S63E 2872', 47-1/2°, S62E 4122', (1046'), RIH w/bit #8 Wt. 9.7, Vis 71, PV 22, YP 16, PH 9.5, Sol 9, Oil 0 Drl & surv 12-1/4" hole f/3076'-4122'. Surveys: 3005', 50°, S62E 3215', 51°, S62E 3523' 51-3/4° S62E , , S63E 3832' 53° 4052' 54-1/2° , , S63E 4725', (603'), Drlg Wt. 9.7, Vis 68, PV 22, YP 13, PH 9.5, Sol 9, Oil 0 Drl 12-1/4" hole f/4122'-4695', surv, in broke 300' above surv. POOH, ' 5'. restring surv in, rec'd surv. Chg BHA, RIH, drl 4695 -472 Surveys: 4178'-54-1/2°, S62E 4131', 53°, S63E 4638' 54-1/2° S62E , , 5060', (335'), MU 17-1/2" BHA Wt. 9.8, Vis 64, PV 22, YP 16, PH 9.5, Sol 10, Oil 0 Drl & surv 12-1/4" hole to 5060'· POOH, MU 17-1/2" BHA. The above is correct Signature ~~ For form preparation a-~ dis~ri-~'-~ti~n see Procedures Manual Section 10, Drilling, Pages 86 and 87 JOate JTiUe 11/29/82 Drilling Superintendent AR3B-459o2-B INumber all daily well history forms consecutively as they are prepared for each well. JPa~e no. ARco Oil and Gas Company "~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish Field Alaska McArthur River 01/31-/78 02/01/78 02/02/78 02/03/78 02/04/78 02/05/78 02/06/78 Date and depth as of 8:00 a.m. Lease or Unit Cook Inlet - Kenai ADL # 18730 State Alaska IWell no. K-,23 Complete record for each day while drilling or workover in progress 5060', (Opened 1893'), MU 12-1/4" BHA Wt.10, Vis 72, PV 26, YP 20, PH 9.6, Sol 10, Oil 0 Fin MU BHA, RIH, opened 12-1/4" hole to 17-1/2" f/463'-2356'. HO bit stopped when @ btm of old hole, surv & POOH. Survey: 2335', 35° 2430', (Opened 187') Wt. t0.1, Vis 63, PV 22, YP 17, PH 9, Sol 11, Oil_ 0 MU & rn 12-1/4" bit, circ, rm 2198'-2435', POH & LD BHA. MU BHA w/12-1/4" bit w/cones off & 17-1/2" hole opener. RIH, opened 12-1/4" hole f/2243'-2383', circ, POH. MU & rn BHA to 2383'. Open 12-1/4" hole f/2383'-2430'. 3262', (Open hole 832') Wt. 10, Vis 65, PV 22, YP 20, PH 9.5, Sol 11, Oil 0 Open 12-1/4" hole to 17-1/2" hole f/2430'-2587'. No. 1 pmp dn, welder relocated oiler. Open 12-1/4" hole to 17-1/2" f/2587' to 3262'. 4440', (Open hole 1178') Wt.10, Vis 69, PV'20, YP 22,_PH 8.5, Sol i1, Oil 0 Opened 12-1/4" hole to 17-1/2" f/3262'-4440'. 4975', (Open hole 535') Wt. 10, Vis 70, PV 21, YP 18, PH 9, Sol 10, Oil 0 Open 12-1/4" hole to 17-1/2" f/4440'-4555', circ hole cln & measured out of hole. Chg out hole opener, RIH, rm 3455', slide to 4275'. Precautionary ream f/4275'-4505' (required rm'g f/4505'-4555'). Open 12-1/4" hole to 17-1/2" f/4555'-4975'. 5060', (Open hole 85'), MU uni-head & lndg jt Wt. 10.0, Vis 62, PV 19, YP 14, PH 9.0, Sol 10, Oil 0 Open 12-1/4" hole to-17-1/2" f/4975'-5060', C&C mud to rn 13-3/8" csgo RU & rn 18 jts, 72#, N-80 & 106 jts, 68# K, 13-3/8" csg. FS @ 5005' FC @ 4919' , 5060', (0'), Prep to RD BOPE Wt. 9.9' Vis 50, PV 14, YP 7, PH 11, Sol 9, Oil 0 Rn stab-in on HWDP to 4919', C&C. Cmt 13-3/8" csg w/500 sx Neat cmt. CIP @ 1600 hrs, 02/05/78. Good cmt to surf. Wsh out riser. Instl pack-off & set dn riser° Circ cmt f/DP. The above is correct Signature ~ .~~~~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 11/29/82 Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska McArthur River ICounty or Parish Lease or Unit Cook Inlet - Kenai ADL # 18730 IState Alaska Well no. K-23 Date and depth as of 8:00 a.m. 02/07/78 02/08/78 02/09/78 02110/78 02/11/78 02/12/78 02/13/78 Complete record for each day while drilling or workover in progress 5005' (0'), Prep to tst BOPE Wt. 9.5, Vis 37, PV 10, YP 4, PH 10.5, Sol 8, Oil 0 ND 20" BOP stack & flow In. Instl vlvs & flanges on OCT III Uni-head. Tst 20" x 13-3/8" pack-off to 200 psi. NU 13-3/8" riser & BOPE stack. Chg out electric mtr on 2nd pmp. Notified DOG, waived inspection (DOG request notification of nxt tst.) 4919' PBTD, (0'), RIH w/bit 8-B Wt. 9.5, Vis 37, PV 10, YP 4, PH 10.5, Sol 8, Oil 0 Csg shoe @ 5005'. Tst Hydrl w/1800 psi, tst blind pipe rams to 3000 psi. RIH. 5070', (10'), Chg brake band Wt. 9.5' Vis 43, PV 12, YP.6, PH 12, Sol 8, Oil 0 Fin TIH, found 13-3/8" FC @ 1919'. Tst upper & lower Kelly cock, safety vlv & inside BOP w/3000 psi. Electrician wrk'd on generator & repaired post on gen. Tst csg w/1500 psi, OK. CO baffle @ 4919' & med hard cmt to 4990'. Re-tst csg to 1500 psi. DO hard cmt f/ 4990'-5010' & FS @ 5005', soft cmt & stringers f/5010'-5060'. Drl f/5060'-5070'. Conduct formation tst to 9.5 ppg EMW. Rn gyro f/ 500'-5000'. 5358', (288'), POOH to retry surv Wt. 9.5, Vis 44, PV 12, YP 6, PH 12, Sol 8, Oil 0 Removed brake bands & relined new bands. PU BHA, RIH, drl & surv to 5358'. 6183', (821'), POOH f/new bit Wt. 9.8' Vis 46, PV 16, YP 8, PH 10, Sol 10, Oil 0 POOH, revtv'd surv. RIH w/bit #11, drl & surv to 6183'. Surveys: 5280', 51°, S62E 5789', 50-1/2°, S62E 6105' 50° S62E 6615', (432'), Drlg Wt. 9.8, Vis 42, PV 15, YP 5, PH 9.5, Sol 10, Oil 0 POOH &retrv surv MU BHA, RIH rm 6123'-6183' drl 6183'-66].5' 6924', (309'~¢ Drlg Wt. 10, Vis , PV 18, YP 7, PH 10, Sol 10, Oil 0 Drl & surv f/6615'-6924'. Survey: 6595', 51-3/4°, S62E The above is correct Signature ~ For form preparation an~- distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate [Title 11/29/82 Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. Pa= no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska I Cook Inlet - Kenai I Field Lease or Unit McArthur River ADL ¢/18730 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 02/14/78 02/15/78 02/16/78 02/17/78 02/18/78 02/19/78 02/20/78 02/21/78 Alaska JWell no. K-23 7296', (372'), Drlg Wt. 10, Vis 47, PV 19, YP 8, PH 10, Sol 10, Oil 0 Drl & surv 12-1/4" hole to 7296'. Surveys: 7103', 58°, S62E 7871', (575'), Drlg Wt. 10.1, Vis 45, PV 18, YP 7, PH 10.5, Sol 13, Oil 0 Drl & surv 12-1/4" hole to 7871'. 8040', (169'), Wait'g on tls Wt. 10.1, Vis 43, PV 17, YP 6, PH 10, Sol 13, Oil 0 Drl 12-1/4" hole f/7871'-8040', retry surv. Att to retrv wear bushing; failed to pull wear bushing. Called Tri-State f/spear. Tst BOPE while drlg (tst witnessed by DOG). 8293'1(~ (253'), Drlg Wt. .1, Vis 50, PV 21, YP 9, PH 10, Sol 13, Oil 0 Wait on spear. Tst BOP stack to 3000 psi (witnessed & approved by Hawkin of DOG). MU BHA, precautionary rm f/7978'-8040'. Drl 12-1/4" hole f/8040'-8293'. 8647' (354'), , Drlg Wt. 10, Vis 46, PV 17, YP 8, PH 10, Sol 13, Oil 0 Drl 12-1/4" hole f/8293'-8647'. 8983', (339'), Drlg Wt. 10.1, Vis 45, PV 18, YP 7, PH 10, Sol 13, Oil 0 Drl & surv 12-1/4" hole f/8647'-8983'. Coal section & rapid drlg 8717'-8877', stuck @ 8800', wrk'd loose immediately. Survey: 8588' 51-3/4° S56E , , 9110]~ (124'~{ Prep to rm 9048'-9110' Wt. v, Vis , PV 15, YP 5, PR 10, Sol 13, Oil 0 Drl & surv 12-1/4" hole f/8986'-9110'. Surveys: 8912' 49° , , S56E 9008' 48° S56E , , 9400' (290'), , Drlg Wt. 10.2, Vis 47, PV 18, YP 7, PH 10, Sol 14, Oil 0 Precautionary rm f/9048'-9110'. Drl 12-1/4" hole f/9110'-9400'. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date ]Title 11/29/82 Drilling Superintendent AR3B-459-2-B I Number all daily well history forms consecutively as they are prepared for each well. JPag~ no. ARco Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska McArthur River County or Parish Lease or Unit Cook Inlet - Kenai ADL #18730 IState Alaska IWell no. K-23 Date and depth as of 8:0.0 a.m. 02/22/78 02/23/78 02/24/78 02/25/78 02/26/78 02/27/78 02/28/78 03/01/78 03/02/78 Complete record for each day while drilling or workover in progress 9645', (235'), Drlg Wt. 10.2, Vis 48, PV 19, YP 8, PH 10, Sol 14, Oil 0 Drl & surv to 9645'. Precautionary rm 9432'-9492'. 9880', (235'), LD sq DC's Wt. 10.2, Vis 44, PV 17, YP 6, PH 10, Sol 14, PH 10, Oil. 0 Drl & surv to 9880'. Tst DP rams, blind rams, manifold, inside BOP, lower & upper kelly cock to 3000 psi. Tst Hydrl to 1800 psi. 9891' (11'), RIH Wt. 1~.2, Vis 45, PV 18, YP 7, PH 10, Sol 14.5, Oil 0 LD sq DC's, MU BHA, RU DA, DD & surv to 9891'. POOH, MU BHA, RIH. 9939', (48'), Drlg w/DD Wt. 10.5, Vis 45, PV 18, YP 7, PH 10, Sol 17, Oil 0 Fin RIH, wsh & rm 9831'-9891' DD & surv to 9939' , · 9992', (53'), DD Wt. 10.5, Vis 47, PV 20, YP 8, PH 10.5, Sol 17, Oil 0 DD f/9939'-9941', POOH w/DOT on DA, in parted. PU Kelly, circ, wrk pipe, POOH to retrv DOT tls. Cut drl in, RIH, DD & surv 9941'- 9992'. 10,051', (59'), Waiting on fsh'g tls Wt. 10.5, Vis 44, PV 11, YP 6, PH 10, Sol 17, Oil 0 DD f/9992'-10,001', made 2 std wiper trip. Drl 10,001'-10,051', lost 500# pmp press. POOH, lk'g f/wshout. Tls parted@ top of sq DC's. Btm fsh @ 10,051', top @ 9923'. Mx Black Magic pill while waiting on fsh'g tls. 10,063', (12'), Drlg Wt. 10.5, Vis 44, PV 17, YP 10, PH 10, Sol 17, Oil 0 MU BHA w/9-5/8" overshot, RIH, latched onto fsh @ 9923' POOH rec'd fsh. Drl to 10,063'. 10,248' (185'), Drlg Wt. 10.¢, Vis 47, PV 20, YP 8, PH 10.5, Sol 17, Soltex 4#/bbl Drl & surv 12-1/4" hole to 10,248'. Survey: 10,071', 44-1/4°, S45E 10,328', (80'), Prep to pull DD Wt. 10.5, Vis 47, PV 20, YP 7, PH 10.5, Sol 17, Soltex 4#/bbl Drl, DD & surv 12-1/4" hole to 10,328', circ, retrv DOT. Survey: 10,197', 47-1/2°, S45E The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 12/13/82 Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. [Pag~ no. ARCo Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially, Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil strin9 until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska Cook Inlet - Kenai Lease or Unit McArthur River ADL #18730 Complete record for each day while drilling or workover in progress 03/03/78 03/04/78 03/05/78 03/06/78 03/07/78 03/08/78 03/09/78 03/10/78 IState Alaska Well no. K-23 10,385', (57'), MU BHA w/bit #24 Wt. 10.5, Vis 43, PV 16, YP 5, PH 10, Sol 17, Soltex 4#/bbl POOH, wsh 30', circ. MU wrk'g dble, DOT tl, rn on DA In. DD f/10,328'-10,385', tst choke manifold while drlg. Pull DOT. Pull DD, tst BOPE, PU BHA. 10,492' (107'), POOH Wt. 10.~, Vis 48, PV 19, YP 3, PH 10, Sol 17, Soltex 4#/bbl RIH, rm 10,265'-10,385'. Drl 12-1/4" hole f/10,385'-10,492'. POOH, chg bit, RIH, rm 10,292'-10,452', lost 500 psi pmp press. Pmp pill, start out of hole. Survey: 10,415', 46-1/4°, S37E 10,663', (171'), Drlg Wt. 10.5, Vis 45, PV 18, YP 5, PH 10, Sol 17, Soltex 4#/bbl POOH, locate wshout in shock sub #816. Chg btm assy, RIH, rm to 10,492'. Drl 12-1/4" hole f/10,492'-10,663'. 10,842', (179'), Drlg Wt. 10.5, Vis 45, PV 18, YP 5, PH 10, Sol 16, Soltex 4#/bbl Drl 12-1/4" hole to 10,842'. _ _ Survey: 10,584', 49°, S35E 11,066', (224'), Stuck @ 8725' Drl 12-1/4" hole to 11,066', POH, pipe stuck @ 8725'. Wrk pipe, circ, retry survey° RU DiaLog on DA, stopped @ 6935', POOH. Rn freepoint, pipe free @ 7399', partially stuck f/7715'-7770'. Pull freepoint tls. 10,842', (0'), Circ out Black Magic Pill Wt. 10.5, Vis 45, PV 17, YP 5, PH 10, Sol 16, Oil 0 Circ, wrk'g stuck pipe @ 8725'. Mx Black Magic pill, displ w/ 59 bbls mud w/180 bbls around fsh & 70 bbls left in pipe. Wrk stuck pipe, pipe pulled free. 11,212' (146'), Drlg Wt. 10.~, Vis 52, PV 22, YP 9, PH 10, Sol 16, Oil 0 Circ out Black Magic @ 8725', RIH w/bit #27, rm 7313'-8807', wsh'd 11,000'-11,066' drl 11 066'-11,212' 11,377' (165!)4~ RIH w/bit #28, Wt. 10.~, Vis , PV 17, YP 6 PH 10, Sol 17, Oil 0 Drl & surv to 11,377'. Tst BOPE to 3000 psi. Survey: 11,267', 48-1/2°, S31E The above is correct Signature /~~i ~ For form preparation and d~tribu~ion ~ see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 12/13/82 Drilling Superintendent AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin9 until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska 'Cook Inlet - Kenai I Lease or Unit McArthur River ADL #18730 Complete record for each day while drilling or workover in progress 03/tl/78 03/12/78 03/13/78 03/14/78 03/15/78 03/16/78 03/17/78 03/18/78 IState Alaska lWell no. E-23 1!,732', (355'), Drlg Wt. 10.7, Vis 48, PV 21, YP 9, PH 10.5, Sol 17, Oil 0 Fin RIH, drl to 11,732'. 11,767', (35'), On btm, prep to drl Wt. 10.7, Vis 43, PV 17, YP 7, PH 10, Sol 16, Oil 0 Drl & surv to 11,687', POOH. Move crown to line up more w/hole, tst blind rams & pipe rams to 3000 psi, tst Hydrl to 1600 psi. Retrv'g tl parted in hole & fsh'd out w/tst plug. Chg BHA, RIH w/bit #29, rm 11,739'-11,769'. 12,139', (372'), Drlg Wt. 10.7, Vis 48, PV 17, YP 5, PH 10, Sol 16', Oil 0 Drl f/11,767'-12,139'. 12,399', (260'), RIH w/bit #30 Wt. 10.7, Vis 46, PV 16, YP 5, PH 10, Sol 16, Oil 0 Drl & surv to 12,399' POOH chg BHA Survey: 12,334', 52°, S31E 12,526', (127'), Wait on fsh'g tls Wt. 10.7, Vis 51, PV 20, YP 8, PH 10.5, Sol 16, Oil 4% Drl 12-1/4" hole to 12,526', att to pull off btm to come out of hole to locate wshout, DP parted. POOH, top of fsh @ 5672'. 12,526', (0'), RIH Wt. 10.7, Vis 48, PV 18, YP 6, PH 10.5, Sol 16, Oil 4% Rn #1, 10-5/8" OD overshot, 6-1/2" bskt grapple w/mill contrl & pack-off, engaged fsh @ 5672', slipped off, POOH. Rn #2, dressed overshot w/6-3/8" grapple, engaged fsh. POH, rec'd fsh. 12,526' (0'), Rng 9-5/8" csg Wt. 10.~, Vis 49, PV 19, YP 8, PH 10.5, Sol 16, Oil 4 Fin RIH, rm 12,450'-12,526', C&C f/csg. Chg to 9-5/8" rams, tst Hydrl to 1800 psi. RU, begin rn'g 9-5/8" csg (18 its in). 12,526' (0'), Prep to DO cmt Wt. 10.~, Vis 49, PV 17, YP 8, PH 10.5, Sol 16, Oil 4% Rn 331 its, 9-5/8", 47#, S & N butt csg w/FS @ 12,495', FC @ 12,410'. Cmt w/lO00 sx C1 G cmt w/-75% D-31, .3% D-19 & .1% D-6. Displ w/rig pmp. Bumped plug. CIP @ 0700 hrs, 03/18/78. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITitle 12/13/821 Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and folIowing setting of oil string until completion. District lCounty or Parish l State Alaska Cook Inlet - Kenai Field ILease or Unit McArthur River [ ADL #18730 Complete record for each day while drilling or workover in progress Date and deptin as of 8:043 a.m. 03/19/78 03/20/78 03/21/78 03/22/78 03/23/78 03/24/78 03/25/78 03/26/78 Alaska JWoII no. K-23 12,596', (70'), Drlg Wt. 10.7, Vis 49, PV 18, YP 7, PH 11.5, Sol 16, Oil 4 Chg to 5" pipe rams, tst BOPE. RIH, DO fit @ 12,410', drl med firm cmt to 12,450' & shoe @ 12,495'. CO soft stringer cmt to 12,526v. Drl 8-1/2" hole f/12,526'-12,596'. 12,750'~ (154'~¢ Drlg Wt. 10.o, Vis , PV 20, YP 6, PH 11.5, Sol 15, Soltex 4#/bbl Drl 8-1/2" hole to 12,614', rm 12, 512'-12,618', drl to 12,750'. 12,832'. (82'), RIH Wt. 10.6, Vis 49, PV 19, YP 7, PH 11, Sol 15, Soltex 4#/bbl Drl & surv 8-1/2" hole to 12,832'. Survey: 12,754', 47-3/4°, S28E 12,944' (112') RIH w/2-3/8" tbg tail Wt. lO.g, Vis 4~, PV 18, YP 6, PH 11, Sol 14, Oil 0 Rm 12,782'-12,832' drl 12 832'-12 944' POOH RIH w/2-3/8" tbg tail , , , , · 12,445' PB, (0'), Circ Wt. 10.6, Vis 47, PV 18, YP 6, PH 11, Sol 14, Oil 0" Circ, fin RIH w/2-3/8" tbg hanging @ 12,940'. Pmp 20 bbls 10#/bbl caustic wtr pre-flush, followed w/236 sx C1 G cmt w/10% sd, .2% D-19, & .75% D-31L. Displ w/192 bbls mud. CIP @ 1100 hrs, 3/22/78. MU BHA, RIH. 12,613'~ (103' [65' cmt]), DD Wt. 10.o, Vis 47, PV 17, YP 5, PH 12, Sol 14, Oil 0 RIH, top of cmt @ 12,445' CO hard cmt f/12,445'-12,510' C&C f/DD POOH, MU DD & RIH. RU Schl, rn DOT on WL. DD 12,510'-12,565', POOH w/DOT. DD 12,565'-12,613'. 12,707' (94') Drlg Wt. 10.g, Vis g6, PV 17, YP 4, PH 11.5, Sol 14, Oil 0 POOH w/DOT tl. RIH w/bit #36, rm 12,510'-12,613'. Drl 12,613'-12,707'. 12,737', (30'), RIH Wt. 10o6, Vis 46, PV 16, YP 4, PH 11.5, Sol 14, Oil 0 Drl, DD & 'surv to 12,737'. Read out on DOT quit, POOH w/WL. Ln bad 70' above ti. Reheaded WL & RIHo The above is correct Signature ~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate JTitle 12/13/82 Drilling Superintendent AR3Bo459-2-B Number all daily well history forms consecutively as they are prepared for each well. JPage no. 9 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section wilt be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form, 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting ol oil string until completion. District Field Alaska McArthur River County or Parish Lease or Unit Cook Inlet - Kenai IState ADL #18730 Alaska JWell no. K-23 Date and depth as of 8:00 a.m. 03/27/78 03/28/78 03/29/78 03/30/78 03/31/78 04/01/78 04/02/78 04/03/78 Complete record for each day while drilling or workover in progress 12,857', (120'), Drlg Wt. 10.6, Vis 47, PV 18, YP 5, PH 11, Sol 14, Oil 0 Resolder Schl stranded in. DD to 12,764', POOH. MU BHA, chg out pipe spinner, RIH, rm 12,720'-12,764' drl to 12,857' 13,058'. (201'), Drlg Wt. 10.6, Vis 47, PV 18, YP 5, PH 11, Sol 14, Oil 0 Drl & surv to 13,058'. Survey: 12,826', 53-3/4°, S19E 13,316', (258'), Prep to cut drl In Wt. 10.6, Vis 49, PV 22, YP 8, PM 11, Sol 15, Soltex 4#/bbl Drl & surv 8-1/2" hole to 13,316', POOH, breakdn BHA. Survey: 13,205', 69°, S19E 13,349' (33'), Drlg Wt. 10.g, Vis 46, PV 18, YP 6, PH 10.5, Sol 15, Soltex 4#/bbl Chg BHA, RIH w/bit #40, power failure on #1EMD. Pulled in csg to 12,119' & circ. Repair EMD & contrl panel. RIH, rm 13,256'-13,316~ Drl 8-1/2" hole f/13,316'-13,349'. 13,558', (209'), POOM w/bit #40 Wt. 10.6, Vis 46, PV 18, YP 5, PM 11, Sol 15, Soltex 4#/bbl Drl & surv 8-1/2" hole f/13,349'-13,558'. Survey: 13,387', 69°, S19E 13,632', (74'), Drlg Wt. 10.6, Vis 47, PV 20, YP 6, PH 11, Sol 15, Oil 5% Chg BHA, RIH, rm 13,261'-13,558'. Drl & surv 8-1/2" hole to 13,632'o Survey,: 13,498', 64-3/4°, S18E 13,830'. (198'), POOM w/bit #41 Wt. 10.7, Vis 49, PV 20, YP 6, PH 11, Sol 15, Oil 5% Drl 8-1/2" hole to 13,830', twist off @ 156' RKB, POOH. MU screw in jt, RIH, screwed into fsh, POH to bad ti jt. Repl 3 damaged jt's. RIH, circ, surv, POM, ck'g f/belled ti jts on way o~t. 13,902'. (72'), Drlg Wt. 10.6, Vis 47, PV 20, YP 6, PH 10.5, Sol 15, Oil 5% Fin POH. RIH w/bit #42, rm 12,885'-13,090', 13-731'-13,830'. Drl 8-1/2" hole f/13,830'-13,901'. Survey: 13,751', 60°, S16E The above is correct For form preparation and d'T~ribut~n see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate JTitle 12/13/82 Drilling Superintendent AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. ARco Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores~ Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska Cook Inlet - Kenai Field ILease or Unit ,~.~cArthur River I ADL #18730 Alaska JWell no. K-23 Date and depth as of 8:00 a.m. 04/04/78 04/05/78 04/06/78 04/07/78 04/08/78 04/09/78 04/10/78 04/11/78 Complete record for each day while drilling or workover in progress 14,078', (176'), Prep to tst BOPE Wt. 10.6, Vis 48, PV 21, YP 7, PH 10.5, Sol 15, Oil 7 Drl 8-1/2" hole f/13,902'-14,078', POOH. 14,220' (142'), Drlg Wt. 10.g, Vis 46, PV 19, YP 5, PH 10.5, Sol 15 Tst BOPE to 3000 psi & hydrl to 750 psi MU BHA rm 12 990'-13,020' 14,010'-14,078'. Drl 14,078'-14,220'. 14,293' (73'), POOH w/bit #43 Wt. 10.g, Vis 53, PV 25, YP 10, PH 10.5, Sol 15 Drl to 14,293', twisted off @ 1674', POOH. RIH w/overshot, att to wrk over fsh; unsuccessful. MU burn shoe on overshot, RIH, mill over fsh, pulled free. POOH to fsh, LD fsh'g tls. RIH, wsh'd & rm'd 14,228'-14,293'. C&C. 14,300' (7'), Drlg Wt. 10.g, Vis 46, PV 18, YP 5, PH 10.5, Sol 15 POOH w/bit #43. Tst Hydrl to 1800 psi. MU BHA, RIH, drl 14,293'- 14,300'. Survey: 14,221', 55-1/4°, S14E Wt. 10./, Vis , PV 20, YP 5, PH 11, Sol 16 Drl to 14,573'. 14,700', (127'), POOH f/logs Wt. 10.7, Vis 45, PV 18, YP 5, PH 10.5, Sol 16 Drl & surv to 14,700'. Survey: 14,524', 60° 14,700', (0'), POOH f/7" lnr Wt. 10.7, Vis 46, PV 19, YP 6, PH 10.5, Sol 16, Oil 0 POOH. RU Schl, rn DIL/SP 14,691'-12,482' (btm @ 14,700', FS @ 12,482'). Rn BHC/Sonic/GR f/14,678'-12,482'. RD $ch. RIH, rm 14,635'-14,700', C&C hole, POOH. 14,700'-TD, (0'), POOH Wt. 10.7, Vis 47, PV 18, YP 6, §ph 20.6, Sol 26 RU & rn 64 its, 7", 29#, N-80 butt csg w/FS @ 14,700', sub @ 14,659', lnd'g sub @ 14,620'. Pmp 70 bbls 10#/bbl caustic pre-flush, followed by 800 sx C1 G cmt w/2.5% D-19, 1% D-31L, 6% KCL & .3% A-2o Displ w/295 bbls mud. CIP @ 2400 hrs, 04/10/78. Did not bump plug. Rev out 170 sx cmt, cut drl In, POOH, LD 51 its, 19.5# Grade E DP. The above is correct __ Signature /C~~)/~ (' For form prep~ratio~ and"~istri~)ution' -- see Procedures Manual Section 10, Drilling, Pages 86 and 87 JDate 12/14/82JTitle Drilling Superintendent AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. JPage no. 11 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in Which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:04) a.m. Alaska Cou.ty or Parish Cook Inlet - Kenai McArthur River ,ease orUn~t ADL ~18730 'Complete record for each day while drilling or workover in progress 04/12/78 04/13/78 04/14/78 04/15/78 04/16/78 04/17/78 04/18/78 State Alaska IWell no. K-23 14,700' (0'), POH w/bit & 9-5/8" csg scrpr Wt. 10.~, Vis 48, PV 20, YP 6, PH 12, Sol 16, DJ] 5 Fin LD 5" E DP, tst BOPE. MU BHA w/#34 bit & 9-5/8" csg scrpr, measure in hole, DO firm solid cmt f/12,009'-12,198' (TOL @ 12,166'). C&C mud, tst csg & lap to 3000 psi, POOH. 14,670', (0'), RIH w/WSO tls Wt. 10.7, Vis 48, PV 20, YP 6, PH 12, Sol 16, Oil 5 Fin POH. RIH w/BHA, DO stringers cmt f/12,166'-12,176', slid to 14,533', stringers to 14,581'. Drl solid, hard cmt f/14,581' to top of LC @ 14,619'. Tst csg to 3000 psi. DO solid hard cmt to 14,670'. Tst csg to 3000 psi. Circ hole cln, POOH. MU Howco WSO tst tl, RIH on 5" DP. 14,670' PBD, (0'), RD CBL, Prep to rn gyro Wt. '10.7, Vis 48, PV 19, YP 6, PH 11.5, Sol 16, Oil 5 RIH w/tster, POH, WSO okay. RU & rn CBL/CCL/GR f/14,630'-13,600' w/o centralizers and under 1000 psi. POOH. RU to rn gyro. 14,670' PBD, (0'), Logging Wt. 10.7, Vis 48, PV 19, YP 6, PH 11.5, Sol 16, Oil 5 Rn gyro to 12,000' POOH left tls in hole RU, rn Schl FDC/CNL , , · · Wait on fsh'g tls. 14,670' PBD, (0'), RIH to chg over to salt wtr Wt. 10.7, Vis 49, PV 19, YP 6, PH 11.5, Sol 16, Oil 5 Fin rn'g FDC/CNL, POH. RIH w/5-3/4 OD guide, overshot dressed w/ oversize contrl, 2-7/8" bskt grapple. Engage fsh, POH, rec'd fsh. Rn gyro on DA in, POH. RIH w/open ended DP to displ w/salt wtr. 14,670' PBD, (0'), RIH w/FB-1 pkr on DP 9.1 ppg salt wtr w/6% KCL Fin RIH, rev out mud w/filtered Inlet wtr. Rev out Inlet wtr w/ 9.1 ppg salt wtr mx'd w/frsh wtr 20#/bbl KCL & wt'd up w/NaC1, POHo MU & rn 9-5/8" Bkr FB-1 pkro 14,670' PBD, (0'), POOH w/spear 9.1 ppg salt wtr Fin RIH w/FB-1 pkr, set @ 3170'; failed to wrk free. Drop ball, set pkr w/3000 psi, POH. Rn 8-3/8" x 7-1/16" wsh over shoe w/retrv'g stringer, wsh over pkr~ POOH; no recovery. Redress pkr puller, RIH, found top of fsh @ 3314'. Engage fsh, POH; no recovery. RIH w/Bowen spear, engage fsh @ 12,154', POOH; no recovery. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate I Title 12/14/82 Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. AR'CO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska LeaSe or Unit McArthur River ADL #18730 Compiete record for each day while drilling or workover in progress 04/19/78 14,670' PBTD, 14,700' TD, RIH 9.1 ppg salt wtr 04/20/78 04/21/78 04/22/78 04/23/78 Cook Inlet - Kenai IState Alaska K-23 RIH w/PRT, took hold of fsh @ 12,154', jarred free, POOH. RU & rn 8.4" OD GR on DA in to TOL @ 12,166' DPM. Rn 3-1/8" x 20' perf gun to 14,645'. RIH w/Bkr 9-5/8" FB-1 pkr 14,670' PBTD, 14,700' TD, RU to rn tbg 9.1 frsh salt wtr Fin RIH w/FB-1 permanent pkr, set @ 12,053'. RIH w/Bkr 6" x 3' seal assy, cut 80' drl In. Fin RIH w/seal assy & set in pkr @ 12,053'. Tst pkr to 2000 psi. Chg pipe rams to 4-1/2", tst to 3000 psi. Tst Hydrl to 1800 psi. Instl OCT spacer spool. 14,670' PBTD, 14,700' TD, ND BOPE 9.1 ppg frsh salt wtr Rn 4-1/2" tbg f/production string, lnd tbg hgr (mule shoe @ 12,144', X nipple @ 12,110', seal assy @ 12,064'). Tst seal assy w/3000 psi, tst hgr pack-off w/3000 psi. Instl BPV, ND BOPE. 14,670' PBTD, i4,700' TD, Gas lifting well Fin ND BOPE, NU & tst tree to 5000 psi. Tst lub to 2500 psi. RIH w/perf gun, gas lifted 500 bbis salt wtr f/well. Perf'd lnr @ 4 HPF f/14,146'-14,136'. Flowed well 1/4 hr before shutting in, POOH. RIH w/#2 perf gun. 14,670' PBTD, 14,700' TD, Gas lifting well Gas lifted well w/600 bbls ont. Perf lnr f/14,136'-14,120' @ 4 HPF Flowed well 1/4 hr aft perf'g before shutting in. The above is correct Signature f ~- )~k.. "~--" (~'~_ ~.~ (~/~] 'L~~ ~' '1°''e For form prep~'~ati({n and distrib'~ion see Procedures Manual Section 10, Drilling, Pages 86 and 87 12/14/82 ITM Drilling Superintendent AR3Bo459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. 13 AliCe Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. County or Parish Cook Inlet - Kenai Lease or Unit ADL #18730 Title District Alaska Field . · · · McArthur River Auth. or W,O. no. IAccounting cost. center code State Alaska I we. no. K_23 Drill & Complete Operator Spudded or W.O. begun Spudded· A.R.Co, W.I. ARCO Alaska, Inc. Date Complete record for each day reported Date and depth as of 8:00 a.m. Old TD ' ' Released rig 04/14/7.8 0200 Hrs. Classifications (oil, gas~ etc.) 0'[1 1/19/78 14,670' PBTD, 14,700' TD, RR Gas lift well. Shut well in, POOH. INew TD Date 14~700' 04/24/78 ProduciRg method Flowing l!otal number of wells (active or inactive) on this~ cst center prior to plugging and I bandonment of this well 1 our Prior status if a W.O. 0100 Hours 'N/A RR @ 0200 hrs, 04/24/78. 14,670' Depth Ki'nd of rig Type completion (single, dual, etc.) Single Rotary Official reservoir name(s,) Cook Inlet Potential test data Well no. Date Reservoir Producing Ir~terval CJI'or gas. Test time Production' .. Oil on .test Gas per day · . · : Pump size, SPM X length Choke size T.P; C,P, Water % GOR Gravity Allowable Effective date · corrected · . · · · The above is correct IDate ITitle i2/14/82 Drilling Superintendent For form preparation and distribution, see Procedures Ma'nual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well; iPage J~o DiviNon of AtlanticRIchfleld(~?~ ~ny. Form ! 0-4,0:3 REV, 1-10-73 Submit -Intentlonf' in Triplicate & "°Subsequent Reports"' In Duplicate STATE O~ ,-.LASKA 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,) -~.' ~Pi NUMERICAL CODE 50-133-20313 6. LEASE DESIGNATION AND SERIAL NO. ~ ~" oil ~ GAS l--1 WELLT-~ WELLLJ OT.ER NAME OF OPERATOR ' Union Oil Co. of CalifOr.nia* ADDRESS OF OPERATOR 9. 909 W. Ninth Ave., Anchorage, AK 99502' 4. LOCATION OF WELL At surface *. 697' N & 8I' W of SE COrner- Sec 17, T9N, R13W, SM ELEVATIONS (Show whether DF, ET, GR, et~) K.B. 100' above MLLW Check Appropriate Box To Indicate Nature of Notice, Re · ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay unit 14. WELL NO. K-23 (21-27) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock :11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2'7, T9N, R1.3W, SM 3.2. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: .,. TEST WATER SHUT-OFF E~ PULL OR ALTER CASING FRACTURE TREAT : MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ' ~ ABANDONMENT*REPAIRING WELL ~ FRACTURE TREATMENT ALTERING, CASING OR ACIDIZING , (Other~eperforate existinq intervals__ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) D~CRIBE PROPOSED OR COMPLETE~OPERATIONS (Clearly state all pertinent details, and 9ive pertinent date% including estimate~ date of ~artlng any proposed work. The following intervals were reperforated.on September 24: · 1411'0-14131 DIL 14137-14158 DIL The following interval was perforated on September 30: · 14180-14194 D.IL on ~ofl lqo. ~~ :?~'~ted ~ *ARCO Oil & Gas COmpany., Suboperator SIGNED C. H. C.0se, , TITLE_ District Engineer m m m DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE, DATE Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submi t °'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 d rill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 7. IF INDIAN, ALLOTTEE OR TRIBE NAME O,L ~ GAS ~ WELLL-J WELL OTHER NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil Co. of California* Trading Bay Unit ADDRESS OF OPERATOR 909 W. Ninth Ave.. Anchorage, AK 99502 4. LOCATION OF WELL At ~ ~ace 697' N & 81' W of SE Corner Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc) K.B. 100' above MLLW 14. Check Appropriam Box To Indicate Nature of Notice, Re 15. APl NUMERICAL CODE 50-133-20313 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 9. WELL NO. K-23 (21-27) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 27, T9N, R13W, SM 12. PERMIT NO. ~ort, or Other Data NOTICE Of INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT H MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (other)=Reperf Existinq Intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL ALTERING CASING · ABANDONMENT* FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSEDOR COMPLETED' OPERATIONS (.Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. We propose to reperforate the following in~cervals: 14110 - 141'31 DIL /o'- .... 14137 - 14158 DIL ~''~ ..... . ~I.'.:~ /.~ /~ ....... .., .- *ARCO Oil and G~s Company, Suboperato~ 16. I hereby certify that the foregoing is true and correct '2 ¢ .yi . - C. H.-gase TITLE District Engineer DATE 9/16/80 (This space for State offic se) . · · ,. COMMISSIONE~ APPROVED BY TITLE. .' CONDITIONS OF AVPROVAL, IF ~NY: ~Y 0,qD:,~ OF T'~ CO~IMISSION See Instructions On Reverse Side DATE Returned Document Transmittal Union Oil Company of Cai~' -qia tiState Division of T Oil & Gas 3001 Porcupine Drive Anchorage: AK 99504 Attention: H. W. 'Ku~ TRANSMITTING THE FOLLOWING: FROM R. C. Warthen Union ~ -= ~-*~= u~l Co ~~ AT P.O. Box 6247 Anchorage, AK. 99502 iELEPHONE NO. er TRADING BAY UNIT K-23 21-27) Set Bluelines Set SEpias PLEASE ACKNOWLEDGE RECEI] BY SIGNING AND RETURNING CO] OF DOCUMENT TRANSMITTAL. DATE: FORM 1-2M02 (REV. 11-72t PRINTED Document I ransml[1:al · ' Union Oil Company of Califpr-nia union DATE SUBMITTED' ACCOUNTING MON+H . TO ~ {.-~ 4- ~ 7 ~ ' FROM ()il & Gas A~ 300i Perc~l',ine Dr. ~. Union ('~';i (;o. of ~chora~5, e, !~{. Cuki:Cornia 99594 TRANSM~&~HE~L~i~i~gIer ~ChO~'~qe, AK. 9950 , , , TBUS K- 2 3 .,, ~ Directional o..rx, eys .. , .... .. . ~ , , .... REC~I~D: ,¢ ~-i' ' FORM 1-2M02 (REV. 11-72) PRINTED IN U S.A, Form P--7 SUBMIT IN ~ .~£~IC&TE* STATE OF ALASKA ',See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: "ou, F~ dAS f-~ F-~ DRY Other WELL WELL b. TYPE OF COMPLETION: WELL OVER EN BACK REMVR. Other 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR 909 W. 9th Ave., Anchorage, AK 99501 LO¢tTION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 698' N '& 81' Iq of SE ct. Sec 17, TPN-R13Iq, SM At top prod. Interval reported below 17' N & 1707' E of Siq ct, Sec 22, TPN-R13Iq, SM At total depth 475' S & 1837' E of NW cr. Sec 27, T9N-R13W, SM 5. API NLrM.Ei~CAL CODE 50-i33,-20313 r~R 6. LEASE DESIGNATION A2qD SERIAL N(~. ADL 18730 ~.~0 7. IF INDIAN, ALLOTTF/E OR TRIBE NA/VIE 8. UNIT,FAttlVI OR LEASE NAME Trading Bay Unit 9. WELL NO. ./ K-23 (21-27) 10. FLEI.2D AND POOL, OR WILDCAT' McArthur River (HemlOck) 11. SEC., T., R., M., (BOTTOM HOL]~ OI~IECWIVE) Sec. 27 T9N-R13w, SM/' 12. PHtLMIT NO. 78-4 1-19-78 [ 4-9-78 i 4-24-78 I 100' RKB 18. TOTAL DEPTH, ~ & TVD[19. PLUG, B~CK MD & TVD~0. I~ 1V[ULT1PLE CO3/I~L., 21. 'INTERVALS "DRILLED BY , , / ' -- -- ~ [ I-~OW 1ViA.NY* ROTARY TOOLS [ 14,700 & 9808 [ 14,670 & 9793' ISingle Ail '! CA.,,~NoneTOOLS 22. PRODUCING IN~VAL(S), OF ~IS C~TIO~, BOSOM. N~E (~ AND ~)* 23. WA,S DIRE~ONAL !i,100 ~ (9493 TvD) Top Hemlock ] su~v~Y~ 14,450 ~ (9691 TVD) Top B-#4 i Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, Sonic/GR, CBL/CCL/GR, FDC/CNL __ ! CASIHG RIgCORD (Report all strings set in well) CASING SIZE D~aX~rH SET. (MD) 24" 384' 13-3 [55 5005 9-5/8" 47# 95 12 HOLE S~E C~%iLNTING RECOlq~ AMOUN'T PULLED Pile 17-1/2" 500 sx "G" neat 1000 sx class "G" 26. LINER I~EC O~ SIZE '~ TOP(MD) : I BOTTOM(MD) 28. PERFORATIONS OP~.-/N TO PRODLYC~iOI~ (Intervai, size ~d number) 4 HPF 14,100' - 14,146' 27. TUBING RE C~O P~D sc~N (MD) size. [ DEP~a SET 4--1/2" I 12~144' 29. -ACID, SHOT, FgACTURE, C~iIE:NT SQUEEZE, ~C. D~I INT~V~ ~ PACt~Ea SE~ (MD) 12,064 ' USED DATE FIRST PrtODUCTION 4-23-78 DAT~ OF T~ST, ~HOUlqS TESTED '[CHOI{E SiZE [PROD'N FO~ 4 - 23- 78 ~ 12 ~ ~s'r~~,~ al. mS~Os~TiON oF o~S (Mold, ~ed for t, el, vented, etc.) 32. LIST OF ATTACHMENTS i:'RODUCTION t)/? '~}01} (;t ..... ~' ~ODUCTION METHOD (Flowh~g. gas lif'L pumping--size and type of pump) [W~,S_T~S (Produc~ or Gas Lift I Producing OI~BBL. ~CF. WA~BBL. I GAS-OIL !' 3268 I i IWA~BBL. l OIL GRAVITY~Alii (COPA~.) t TEST WITNESSED BY Drillin~ummary & Gyro Survey 33.'1 hereb~~t~~ and attached information is complete and correct as determined from all:available records SIGN~[F'/-;"JrJ'~? Ir[. [ ITLE _, Dist.Drlg. S.pt. DATE 5/5/78 · i I I I (// *(See Instructions and Spaces [or Additional Data on Reverse Side) *Atlantic Richfield Company sub-operator. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on: all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this for,~ and in any att,]chef,ants. Items 20, and 22:: If this well is completed for separate, prcduction from more than one interval zone (multiple completion), so state in item 20, and in iten~ 22 show the prcJuci~.9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce,J, show- ing the adlditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shouIJ show the details of any mul- tiple stage cementing anct the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF' ~'()t{MA'I"ION TT~'I'S INCLUI)IN(; INTEI[VAL TE.STED, I'IIE~SUIIE DATA ~ ~'OVERI~' OF OIL. GAS. 35. G~GIC MARK~ WAT~ AND MUD Top of Hemlock 14,100' 9493' B-~2 14,170~ 9533' B-~3 1~,3~7~ 9635~ B-~ 1~,~50~ 9691~ ~ ....... , ...... r- .,, -, .... .......... . ........... , , _.. Eastman / I Whipstock l')~ A PETROLANE CQMPANY REPORT of SUB'SURFACE DIREC TIONA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY K~-23 WELL NAME COOK INLET LOCATI ON JOB NUMBER TYPE OF SURVEY A478 GO297 GYROSCOPIC Radius of Curvature Method of Computations DATE 5-1-78 SURVEY BY EDWARD J. BUTLER OFFICE ALASKA GYROSCOPIC SURVEY K B ELEV. 100 FT, .._(:OM P UTE D ._.. F_ OR_E AS T.MA N__.W H I P S T OC K. __BY_..F._., .... M_, _L.I_N D_$ EY_._6 N D__A.. $ ~ O.CI_A_._T.E $. ........................................................................................................... R.~ C.O.R.D _..o.E_S Y R.V_~.Y .............................................................................................................................. ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER _D..._E?__T_H.____A.N._..G...L..E__ ..... _D._.EP%_~ ............. S.E..A_ ............ D!.REC D ! STANCE ANGLE DEG/IOOFT DISTANCE D M DEG, D M ,S 0 0 0 0,00 '100,00 N29,00W 82,00 N z+~+,'O0 E 93.05 N 28 13 2 E 0,000 50 0 15 49,99 -.~0,00 Nzg,00W 82,09 N ~3,94 E 93,~1 N 28 9 39_~~..00 -20,91 ~50 0 20 149,99 49,99 S13,00E 82,21 N 44,02 E 93,25 N 28 10 1 E 0,680 -21,04 .__~..5...0_ 0.__~.5_.__.3...~_9_.~_?.9. .... _2_.~.9.,_~..9..__S2X.~_OO.._W. 81,06 _N_ ......... ~3..~_~3 E 9~.~..9!__.N_._._~8__ ~+oo o ~5 ~99..,~.8 ....... Z..9_9.._,.~8 .... S_3~,.oow_ .... ~_O__?.__~_.?__N__ ~+S,O~ E9~.28 N Ze 8 2~ E z+51 0_.~5 .... .~5.0.,..98 ....... _350,98 ...... N 9,00E ...... 80,63 bt ~+2_,59._E ........... 9!.,!_9 .... N_.__2.7__.5.0__~+4 E 2,887 _.___5_0...0.. .... ~._.~._5.___~.97_j_9.7 ...... 3_9.9.....,_97 ...... N!!,.OO~.J. .... 8.~._:__7..0___N ~_2..,_5.__7.__E____92,13 N 27 ~1 36 E 2,041 600 4 0 ~99,83 z+99,8~ N 6,00E 86,69 N z+2,~6 E 96,49 N 26 2 ~0 E 2,252 700 5 S_0____6.9._.9_?_~.9. 599,A9 ....... NIOj_OOE ..... 9~,._89_N. .......48.751. E 10~:3_9. .... N____2~__.3_8 S E ~,.~00 800 $ 1,5 798,96___.69..8__,.96 .... N~9,._QOE 104,79 N ~+6_:.QT_.._E. ............ _X..!_~_:..~._.7___N_Z3_ 44 1 E__0o758 900 & 0 898..,39 .... _798.,39 N~+~+_,_OOE .... ~_1.3_,8~__N___ 5_1._,.60 E 12__~_:.97__N____2_/+__2_._~ 22 E 0,~70 1000 6__~0_____997.,80 ....... 89_7,80 ...... N79,00E ...... !.:8_,..9.3._.N_ .... 61._..:.02_E ....._1.33,67__N__2_7 9 ~+5 E 0,672 1~00 6 30 ~097,~5__ _99_7,.15 .... S74,00E__~8,4~+ N 72,22 E ].~8,72 N Sl 2.2__33 E 1200 8 ~0 1196,29 1096,29 ...... S69,00E 114_,_.3_0 N 84,60 E ' 142,..2_0__N_36___30 27 E 1300 10 15 1__2_9_~_,.9_.5___.1_!94_,_95 ......$70_,50E 108,66 N 99,88 E 147__,.5_9 N__~.2____35__21 E __L~..o_...O._~..Z_i~-~-~ .... ~__392.,9~___~2..92..9~ ...... S~8.OOE_ ...... ~0~..:...27_._.8. ~8,~ E _~.~.~..,.~_(: N ~+~ ~_.~._.~_~._g~ 1_6_00___X?___0____1586.__36___!486_,36 .... S6~,OOE 79,6_2_N___~_6_~,23 E 1..8_2...:.51 N 64 8 3 E ~..,._500 1700 19 0 1681,46 1581,46 S63,00E 65,83 N 191,88 E 202,86 N ?l 3 43 E 2,003 __1_8_00_._22_ .... 0 !_.7_.75_,___!_2 .... !__67.5,.12 ....... S61,OOE ..........4 9_ ., ~+ O.__N..___~ 2. 2 _,_8 0__. .E_ ........ 2_2__8__.....2.1_ N._77 29 52+ E 3,013 ~900 2~+ 0 1867,16 1767,~6 S.6_2_,..00E 30,7.5_~_ _2_.5..7_:_!_.3__...E_____2_5_8_,_..9..7_.N__.8.3___l.0.._.~.~ _E ...... Z,_0__0.7 1,751 1.753 - 2 O ,~..6___. - Z .0...,_.7_~B_ -20,63 -21,07 -21.79 -3~+, 37 --~ ~ ................. 3 ........................................................................... GY.R.OS£QPIC_SURVEY APR-! L--20, .... 1978 RECORD OF SURVEY DEPTH ANGLE DE:PTH ,SEA DI 27O0 2800 2900 3000 3100 3200 43_15 25.4_!_.3.2 ...... 244!._, 32 4 5 45 2.6!.2..,_6...4__ .... 25 ! 2, 64 ..... 56 O,._5.0E .... 1.9_7.,. ~.8.__.~__ ...... _676_,...4...5_g 723~ 90__.._5...._.?.~+ .... ~.0 ........ ~_E__2..~.~_.l.~_ ~_~.,.06_ 50__0 ....2_.?.~ 5.~_9.~__ 2 6~ 5_, 9~ .......... 562~..5_~E ...... 34Q~._.5_!__15 2998,5! ..... 2898,51 ........ ,$62,50E .......... 41_~ ,_! 6_ $__1_! 0.! ,2 ~ g ..~1~6,5g ..... ~.__~.9___.23_.__.2_~E 0_.~90 110.1.3_?_ 3600 52___~ 2.!22.e86 .... 30.22.,84_ ..... 562,0_0E 48_7_~_~_Q_S 1239J76 .... E ...... 1332~_!3_5_._68._}2._.~.~__E 0..,_50.0 125'_ ~_ ...... 4_0_Q0__5.~__0~363~21 .... 3263,21_ $62,00E 637~50 .... $ .... 1522_~_03 E ~6~0~.~5__.~_7_%6___2~_E O~.~_Z2~ 4~.~_3~_5 .... _3__~8~0_~3~_338_Q,23 .... 562.00E ...... 7!.~_~64._~ 166_~_,.23._E ...... !8!1_~7~___66~_~.8 ..... 7._E__ 0.750 4300 53. .....0 35~?_~.89__3~39_,89__561,50~___7_51_~._~3 S 1735.93 E 18.?~.,6.6 .... S__~6__~ 17 E _~_~.~_!5 ~5~5~_.30 ...... 36~8,50.__3558 ~.50__560.00E ...... 82~, 7_7__~___1~_77..__2_.~_E_ _~0__52_e..~__.~__6~!~_~6 E ~,_6_60 4600 54 30 ..... 37!.6,57 ...... 36!.6,.57 .... ~62~00.E ..... _8_6~_~_~~!.?~6_~_~.~__E _.2..!3~.'_,.1~__~._65__~..8__~.~ 1_..628 4700 5(f .....0 37.75e00 36~_5,.00 ..... 56!,50E ..... _9.~b_~65_._S___2.~_~__?~.~5_E 22~1~_.~._.~_~.~._~7 E ~800__.5~_ 0 .... 3533_.,_7_7__3733,77 ..... S61.OOE .... 9.~.5,5.6._.5__20..9.ff, aB__E 229~,7_5_ 5_65 .... 39_.5.7_E~ 0,~05 2195,95_ RECORD OF SURVEY ALLC A L CU LA_T._.! ON S .._P ERFOB~ M.E D__ B %_]~.~_.EL ECIg.~NX_~L_C_Q~J FUIF. d3_ TRUE, M_E A_ ,~ ._LD_R _DEPTH ANGLE DEPTH SUB DRIFT TOTAL COORDINATES C L 0 S...U... R_.E.__~ ..... 6_.E___VE_~R~_.TY ~.__E.C_T~_O.N__ ~EA DIREC D.LSTANCE ANGLE D 1'4 $ DEG. 5800 5 ! 0 ~463 · 36 _~3.63..,..~.6 .... S62 ~.~5.~..E~..3..~.~.~7-~-S~.~.~-7~.~`8~..-E.~.~3~..Q.?.9..~.~2:Q-..$-..6~.-~.~2 E__ 5. ~_~I~ __~ O_ II_ .~_p ~_5 _2.6 ~ I6...3.. ..... .~.~_ 2.6_ ~ 63_. .... S61., 00E___!_~.~.8._,._..~2_$. ..... ~._8..~._:_.0..7_. .... E~_ ~_k~_..7.,_5 _3_ $._.6_~ 3.8__Q__E ........ 60.0_.0__50._~5 .... ~5_90...o07 ..... ~90._~07 ........ $6.~_.:.5.0E ...... !_3_8.5___._.60__S__2.9!!....__.8~__E ........... ~22~..,_70 ..... $_.6..._~_3~ e E _~6~.9.0.__50 ..... O. 4.._6.5.3..,__8..5__~.5.53._,..~ ..... $6! ,..5..0. E__.~22..:_35__S .2.._9..?..9.......53 E 3.~O1.°62_.S_64__2..8...__~.g_E 6200 50 0 /~718,13 46].8,1_3 S6~,OOE 1/~57,43 S 3047,63 E 3~78,1-8 S 6z~ 26 31 E i-~-;~'~--E" -~-~-~"~ Z~-'s--'~-'~ ~--i'~ ~ o. ~ 6400 5';) 0 48/+7,02 ~747,02 S6z~,00E ].525,66 $ 318~,48 E 3531,09 S 6/* 2/* 4 E 0,638 6600 52___.3.0 ...... _~9_'7_~._'_.2.%__4.87..3.~2:~ .... S6!,50E__~_5_9.8__'.20.__$___332_!_'..60 E 3686_'.!0._$_6.~ 18 ~8 E 2,000 ~__7_o. 9_.~.g .... 0._50__39..,._9_~__4~?_..._*..~ .... S6._O_...OOE ~ ~_.,.9,_.S..___s_~..~.0_._5.~_E ...... __.3._7.9.~_..o._.z_S_9~_~.~._.~.0 E ~.057 _~_~__0_0_._5.~ 050.94__,_.6__]. 4_9_.9..~.:.61 ..... S5.9_~ §gE ~._6_.7.7_?._0. Z____s. .... 3~59,57 E 38~_4._,6~__5_.6_4.____8_~.5..__E.__2_:927 6900 55 0 5].52,68 5052,68 S62,.00E___1___7_.~6._,_8__4._S .3_5__~_9,.60 E 3.92..5,__9Q__$._._64__ ..... ~. 2 E 1,953 7000 56 ~5 5zo~.:~k~.'__5.~_o_~._,~4 ..... s59.,.50E__~TAT.._,.~Z_.s. 3..6.._o_z..:_.~_E_..._~p_.o_.I~.:2~_s_63_~_.~_7 E ~_.,...:l,._3_S 7~_99._58_~.5 _5_2_6_3_.:__2__~___5_~6.3_:_2~_ ..... S6~_:00.E__!_?_98_._9~__S_ 3_6_!~._,_62__E___?092,2_~ .... S__.63__55_~9__E _~_00__~0___0__53.~_~_,~ 5Z.~_~..,_~ ...... s~O:_O0.E ~e,~.~ s S?50_.~..~__~__E. _~_!Z~_:.eg_._S___~_3 .5~ ~ E ~.~0~ 7300 58___30~..3_6..~__,..68~__5265.,68 .... _S6!.?00E _!_8~3.k8 s 3825,11 E__ k26_3..,68_.S___6...3_~7 3 E 7500 57 30 5~71,66 5371,66 $61,00E___!96_7___,_00_~___3_97_2..~3 .... E__ ~_3.3,02_~_.63___~9__._3! E ??'~ o-~'~-'~ 0---~-~ ~ o-;-~'~----~"~ ~'? z 2":'j~.il s~ 2., o o ~____zo ~_7_:. ~ ~__ ~___~_.~ _.2..o_._,_~ e ..... 1._: O Z .~ 30 Z_l_, 99_ __ 0 · 390 __3. ~..0_ .3_. _0.~.].~0 1.915 3252.95 3326,90 3~00,86 3629°16 37__0 _7._,__56__ 0 .~_7._6 _ .~ 2 0_1_ .... . 81._ O, 869 _~28~,.6~ 0 .~33 ~+ 60_0_.. ~87.__._ S_ _6.3_3 ~+__~7___E_ .......... RECORD OF SURVEY COHPUTER HEA$, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES -~-P-Y~-A~%-E ......... ~E'~"fH ............ --SEA ............ ~I R ~-'~- D M DEG. 8800 50 0 6238.96 6138,96 555,00E 2513,88 $ 4865,28 E 5476,36 $ 62 ~0 28 9~00 ~6 ...... 3P 6~38~_~0.~ ......6338._~4 .....~56,00E 2639,89 S 5050,9~ E 5699,Z9 5 62 2~ 2Z E--1,500 9300 ~5 ..... ~...57.6..?.~6 .... 6.476,..66 .... 55.5_~00E_]_7.~_~_~_0.2_5]!_!0_~08 E 58~2,40 5 9_~..~Q__~ ~_~ ~_.66.~ 7 ,.6 8 .... 6~__~_, 68 ...... S 53 · 00 E~27 62_, ~0_5 .... 5 ~.~.?_, 03__.~__5_~ ~ 2. ~ 08_5__6 ~ ....... 8 ].?_~_. !__~ _~._02 9500 4~ ..... 0 .... 67!9,.3.~ ~619~31 ...... 554,50E .... 2803.,66_.S ....... 52_~.3._~..3~__~ ___598!,!2 .... 9600 44 30 6,7_9,0.~,?~__.6690~_9~ .... 35 E Q,.e,~O_O 93.~Q._.~5 .... 30_ ...... 686!.6~_676!_,.6~ .... S54,50E__28857.2_.~__S___~3.~_7_,_~7_~ ...... 6120_,¢2 9850 ~___~ ~6_.5..~92___6865.,92 ..... S52,00E___29..5~_,3_~_.5~:~5~.~.~.~.59 E 6226.~9~_..5__~1__43 5 E~Q_~.~O 9900 45 0 7000_~9.7_ ...... 6700t97 SS~,OOE .... 29723_5_8__S 1.383 _5_3_9..1_,_~ ~ 1_ 55:39,06 RECORD OF SURVEY ......................................... TRUE _D_. _O__~_~_E_G_ MEA$. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES iC_.__L___~__S__~_~__~__.5_ ........ -l~-~'~"T-H--'~,-fl~Gi~E ....... -DE'P'T-H .................. ~'EA ................. DiREC D ! ST ANCE ANGLE DEQ.L!.O_DFT BEG. D M $ ~.O_igO._!!__~ ...... 7.6.79,6..L_75_7_.~67 ........ $43,00E__}511.63 S 6005.99 E__6957.26 S 59 41 8 E 1.509 6831.89 11100 48 15 7811,38 7711,38 S~O,OOE 3623,90 S 6106J20 E 7100,59 S 59 18 42 E 1,342 6981,24 ~J..!99_._48.._}.9 .....89.78,2! 797_8.,_2! ......... 533,.0_0E ...... 38.69_760_.S .....6_2_74_~_3..4__[ ..... 7~.7~__,.{~.__5 _58 20 ZZ E 0,937 1 ~ 600 50 0 B 1437.4.8 .... .804~._,48 ....... S3!~..00E ...... _39_}}...~..~._~__%~_!~_!.8 ~].~.}_?..,..~_~.._$_5..8. ...... ~. 39_~ .~.!.gD 11900 51 o 8333~..97_~82_..33_~77 .... 532,Qg..E__~._3.0.,.~8 s 6437,30 E 7648,46 5 57 18 52 E 0,392 12015 50_~5 .... ~_9Q69.53 .... 83_06.?..53 ..... 532,09E__?ZO6_..~__.5___6~_aS_..~5.8__E~__7_7_a~_~.~.~_~__~_7_~_~4 E __0.2~7 76~ TOP OF L_I~E_R__DE!EC_T_~p_._AT__i_2_!_60 .,__.M .._ D. -Ti-~i"5-'S-i--l-S--~-S~'a-,'9'~ ..... ~-a-~"e9 S20.OOE z~407.47 5 6602.~3 E 7938,38 5 56 ~6 Z9 E -i~-5-i-5--~2 .... 0----87i9;-6~---'86'19';'~6 522,50E--~"~'-~-9%-57--5 ..... 6~-~'7'56 E 807i.86 5 55 41 33 E -i-~%-i s-sO ..... o---87~-'~;"s'9 '~_~'~h.~.'"~"'~4_e Oj'OE~___~_~j~O'"~"~--~--'~g'~'~7~'~-'~---'-~'~-3-'~-"~ ~ s ~ ~ 2 ~ ~ 6 E 2 · 35 4 8 !_5___3 _,_.~t 2,159 8223.32 3,020__ ARCO K-23 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER DEPTH ANGLE__DEPTH SEA DZREC DISTANCE ANGLE D M DEG, D M S 13015 59 45 9017.63 8917.63 slg.ooE 4924.07 $ 6809.76 E 8403.52 S 1~165 66 0 9085,79 8985,79 S16.50E 5051,24 S 6850.43 E 8511,~7 S 53 ~5 ~7 E 4,086 848~.~_ -~-~-2'f5~ 68 0 9['0-'~"~3-3' .... 90-05-*"33 ....$iSmSOE 5095,48 S 6863,12 E 8547.89 $ z~.~__~_ a_¢_} 0 .... ~_~._5_7 ,a 5 ........ ~.o 5 ~, 65 .... S z ~, 0_o [ ..... 52.~ 0.,_~.?_.. _S_L._~_90 ~_~.~ ~__~ .... _~. 6 S..0.~ .8_ ! ..... 14215 54 ~0 9_5_77_~_9~__9~7.7.~94 Sl6.00E 5931.77 5 7_l. 2~_~..}.Q__~_?27.2?Q! lt+t+15 57 30 969!,92_959~._,_92 ..... 51.5..,00E 6 09 0_, 2.8_ 5__~_.159 ._~50 E_ _9~07~.08 ..... S_..~.9._39_._!1 E 1~65 58 X5 9718,51 9618.51 S16.00E 6131,27 S 7180.10 E 9~1,73 S ~9 30 18 E 14515 59 45 97-~'m;'26~--96~'~26 ....... S15150f-----6'~7-2-i7'~'--~ .... 7i'~-f;-~'~E--~'4--~"~'9'8 .... 5--4~'----2'i--~'6 E la615 63__0__~79.2._,07 .... 9692,.07 .... s1a,O0E.~6257_,.~9 s 7213,18 E __2.0Sa 9~+~.~_.?_0__0_ 3.743 9476.52 3.826 9512.72 4,178 9563.73 9610.81 BOTTOH HoLE ~L:Os'U'RE ..... :9--~-i'b';-§"l"- F~'ET"'-~,T-"~---Z~8--z+ 7 30 E ARCO K-23 GYROSCOPIC SURVEY APRIL 20~ 1978 TRUE N AL~E ..... ~.. _ D E P_TH .D_ E_P.T.H ____ANGLE ~.UB SEA TOP B-1 14100 9511,64 5841,20 S 7101,26 E 9194,98 S 50 33 38 E 9411~,~4 .. _ --~-£-A-$-OR'E'D-'I~E'P'Ti%--AN']~--OT'H'E'R-'D-A'TA-'FOR .... EgERY EVEN 100 FEET OF SUB SEA DEPTH. - TRUE MEASURED VERTICAL SUB MD-TVD ............ ~i'~'I3"T'i~ ........................ tSE-'P-T~ ......... '~E-A--~-I FFERENCE VERTICAL CORRECTION TOTAL COORD INA'lES 200 200, 100 0 0 82,01N 43.85 E 300 300, 20'0 0 0 81.50 N 43.74 E 400 400. 300 0 0 80.47 N 43.04 E 500 ................. 500-~ ..... ~00 0 0 81,70 N 42.57 E .................. 600 .......................... 6oo., ................ 5.00 .................... 0 ............................ 0 .................. ~.~.,.e%..N .......... ~2.36 E 701 700, 600 0 0 94.94 N 43,52 E 801 800. 700 1 I 104.89 N 46.11E 902 900. 800 1 0 1002 1000, 900 2 1 1103 1100. 1000 2 0 1204 1200. 1100 3 1 1305 1300. 1200 5 2 140 ? ............ 14oo. ........... 1300 ................ ? ............................ 2 113 · 93 N 5 !....__7__2_g. 118.97 N 61.,.24 E 118,35 ..N..__7 114,10 N 85,!2 g 108.35 N 100,72 E 100-64 N 119,81 E 1510 1614 1720 1827 1936 2048 2163 1500, 1400 10 3 1600, 1500 14 4 - 17'0':o';----~oo ............. 19 ........................... 5 1800, 1700 ........... 26 7 1900, 1800 ............... 36 10 2'0oo', -~9Oo .......... 48 ........................... 2100. 2000 62 1~ 90,31 N 142.05 E 77,81N 167,94 E 62,87 N 197e66 E 44,46 N 231,76 E 23,77 N 270,36 E 0.86 N 315.18 E 24,14 5 365,41 E 2278 2394 2515 2644 2782 2-9'29 3084 32/+2 3402 3726 3Sgz 4062 4233 4400 2200. 2100 ........78 2300, 2200 94 2400. 2300 115 2500, 2400 144 2600'~' -2500 ......... i81 2700'. 2600 ............. 229 Z'800. 2700 ......... 284 ........... 2900, .......... 2800 ..... 3000. 2900 402 3i'00-'; 3000 ....... 462 3200; ........ 31oo ....... 52-~ 3300. 3200 592 3400. 3300 662 3500. 3400 733 3'600'~ 3500 ........... 800 16 16 Z! 29 37 4'8 ~8 60 50.59 S 416.56 E 76,81 5 469.79 E 108,02 S 530,15 E 146,10 S 601,75 E 191.37 S 685,15 E --2'43;80 S 779,47 E 299;~5--'$ .... 8-84e10 E 359;6-3-S ..... 992;-37 E 414.89 5 1102.66 E 60 64 66 70 71 67 473,73 $ 1214,05 E 533.91 S 1327,96 E 661.09 S 1566,40 E 726.18 $ 1688.65 E 789'"5~-"$ 1'8o6";'5~ .... E ARCO K-23 GYROSCOPIC SURVEY APRIL MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE DEPTH DEPTH SEA DI,FFERENCE VE R T I CAL CORRECTION TOTAL COORDINATES 4571 3700. 3600 871 71 857,0/+ .S i927,67 E 47~.2 :3800, 3700 942 71 923,12 $ 20/+9,67 E 67 987.72. $ 2].66.9:3 __/+O.,,09..L __ 390~ .... l 069 .6 o 1 o ~ 8,2 5 $ gA7,.6.~.,3,.~ ...... 5383 /+.2..0..o, ........ ~!oo ..... !183 ........................... 5_7 ..................... .~..~,82,37 $ 2/+89,~8 5543 4300, ~200 12~3 60 1221.03 5 2599,7/+ E 5700 /+/+00, /+300 1300 585-8- .............. ~5oo;" /+/+oo ............ ~327 48'00, ......... 4700 ...... 1526 6482 ........................ -4900' ......... ~800 ....... 1582 57 1276.14 S 2707,/+1 E ? ................ 5'7 1333.10 5 2815,/+8 E 139i";-2'~--"~S ........ 2921.99 E 57 1/+~8.11 $ 3028,12 E 5/+ 1500.86 $ 3134./+5 E 5'6 1554';50-5 .......... 32Z+0,50 E 6809 698'3 7 I71 7365 755'2 7735' 7915 8089 8258 8422 ~82 50'0 '0~, ..... ~*'g 0 0 ..... 1-6'z~ z~ 62 5'-100'~- ......... 5000 ........ t 709 ................... --65 5200 * ......... 5100 ......... 1783 ............................... 7/+ '5300' ..... 5200 ........ 1871 88 54'00' ..... 5300 ....... 1965 9'4 5500; ...... 54'00 ....2052 87 5600', 5500 ...... 2135 83 5700' .... 5600 ....... 2215 80 5800' ........ 5700 ........ 2289 ........................ 7~ 5900'~-~'5800'~2358 69 6000. 5900 2~22 64 61'00; ......... 6000 .... 2~82 ................... 60 8739 6200' .......6100 ...... 2539 --'8894 630'0 ,- 6200 259~ 90/+-4 6400 ~,----6300 .... 26 9 1 g 0 6500'* ......6400 .... 2 690 933-3 6600-,- ...... 6500 ...... 2 733 94'73 6700' ..... 6600---2773 '9'6'1'3 68'00"~; ..... 6700 .....28'I 2 975-5 -- 9898 ~O'03'S-- 3351,95 3590. 3'728';'59--E 3-87 57 55 5O 4O 39 6 9o o', ......... 68 oo 2854 .............................. /+ 2 29 o 8;'69--$ ...... 5-~;29-;'-30-E 700'0'; ...... 6900 ...... 2898 44 297'1--;-g-9- S ...... ~-510.39 E 7'i0'0', ....7000 .... 2'9'38 40 3035;-~'i'-5 ..... 5'5'~.~5 E -~'A~-C'~--~-'~-2"~- ............................................................... GYRO$COP ! C SURVEY A.PRiL~20.~_1978 100 FEET OF SUB SEA DEPTH, D EP'T'~- ....................... D'E'P-T F~----SE'A-'-~"~ FF'E R'E'N'~-E (-OR'R'E C T ! ON TOTAL COORDINATES '~-O'-le"O '72'00'; .......... 7 i'O'O ........ 29'8o ~-0"3'2~ 7'3'0-0"~ ........ 72'0-0 ..... 3'02'5' 'i'"0-~7-i ..................... 7~0'0"~ ....... 73 O0 ...... 30'71 '~-0 ~-2-/~ ................ 750'0--~ ......... 7~"00 .... -3124 !0778 '76'0'0 ~-- ..... 75'0'0 ....... 3178' 1093-'1 77 O0 ~ .................. 7600 ....... 3231 -1-ro~-s- .................. 78oo-~ ..... 77oo ......... 32e3 'I"~"2'3/+-- 7'900, '78'00----3'3'3 z~ 1 ~ 383 .............. 6000', ......... 7900 ....... 3'3'82 ~2 310~,05 5 5658.15 E 45 3178,18 S 5732.91 E 46 3259./+4 5 5801,2/+ E 53 3352,12 $ 5870.59 E 3~42.96 $ 59~4.63 E 53 3528.77 5 6021,88 52 3614.13 5 6097.96 51 3703,92 5 6167,30 4B 3796,12 S 6227.6~ 1 i-53'~ ................... 8100' ......... 8000 ....... 3'z; 3'3' ..................... 51 3890,/+9 5 6287,73 t 1 ~ e 8 82 o o, ..... ~"ib o 3 ~+ 8 e .............. .5. 5 .......................... .3...99.!.~..~_ ~._._S ...... .6_3. ~._9.:. 76 8300, 8~00 85"0'0";~-~'0o 3 E 4095,00 5 6z~1~+.80 E 4198~81 5 6480.06 E 430/+.26 5 6544.20 E 1 z 3~"3 ....... 12~83 1-2-6/+2 8800'; .......... 87oo .... 38~2 59 1280~ 8'900, 88oo ........ 39o~+ 62 12981 9000, 8900 3980 76 13 z 01 9 t 00--; 9000 .... ~ 00 t 20 z ................... 2o.o, ....... 7 6 ........................... 6 13694 1-3 89-5 14079 14252 14430 14632 8'6'0'~'; ....... 85'00 ...... 3723 60 ~2,98 5 6605.3~ E 87'oo', ........... 86oo ......... 3'783 ........................ 60 ................................. ~5'Z~";'4'Z'-'s ...... ~'6'57' ~'e E ~639,98 5 6706.58 E ~758,52 5 6753.~8 E ~896,57 $ 6800,00 5083,08 $ 6859,35 9300, 9200 ~39~ 118 9"~'oo', ......... ~3oo ..... ~"~9'5 tot 9~06, .... 9~00--'4579 8~ 9500, 9500 ~6'52 ............................ 73 ~700. 9600 ....~73o 78 9~00, 9700 ..... ~'832 .................. i'02 5327.80__~ .... ~.39,o2 5511.42 $ 6996.58 E 5676,36 $ 7052.95 E 5824,56 S 7096.65 E 5960,66 S 713/+,58 E 6102,52 $ 7172,74 E __ 5272,43 S 7216e73 E E E I~ E .......................................................... TRUE HE.A SU RED ............... V ER ~..~ CAL ...................... SUB DEP._T_H DE P. IH ....................... 5 E A ......IO. iAL__~C.O,.OR. QINAIE,.5. 1.000 ....................... .99 7:, ............. 8.9.7.~ ................... ~. ~. 8 .~.9_ ~_~._N .......... 61_ ~._.0_ 2 3 ..00_0 ~ 7 .~ 5 ~ ........... Z ~ _~ ~ ~ ............. 2_69, ~ 3_ 5_._~ 2 6~_ ~ ~ _ E_ 6000 ........................ ~90..~ .......... ~90~ ................ t~85~_~0_S _2.~._t~_~_.~8 E ,: 9.QQQ ............... 637.0~_ ...... 6270, 2598,83 S ~990,03 E ~0000 7072, 6972, '3018,04 S 556~,73 llO00 ........................ 77~5" .......... 76-~5'~ .............. 3-5'67;~'7 S 6056,97 E 12000 8397'; ...... 8297" ~"19"~-['~'8 S--S~78,42 E 13000 ...................... 9 O1 O; ........ 89'10' .................. ~911-,'96-S ...... 68'05-~-'22 E I400:0 ...................... 9455", ....... 9355, ................... 57'61"~7 8--S ..... '- 7078'-",0 9 -E .... ' ........ ! ........................................... ' ' ,_. HORIZONTAL, ..VIEW i ' ' ' ~ ' ""-" '- '~ ............. ~ ...... ' ..... : ...... ~ .............. :"'-'~ -':'! .......... SCALE .l"=.---It'300' ' - . . , ......... ,~ ........ : . , ............................................ i - · - ; ' ' __ : '-" ?'-'T. '.-.jT-OYR OS CO PI C SURVEY , .... : ..... 31iloo ...... : ' ' ' ; ....... ............... , ...... ; ~ : ................ ............................... : ....... .... ' ........... 7600 ............. : ...................... '8400 ................ ; .................. : .................. : 8800 : .............. : ......................... ; ........ . ..... , ....... . ...... ~ .......... 9EO0 .............. . ..... ;, . ......... . .... : -' - . ........... '960( : ~ '- - ' ---~ ~ ........ - _'~ ' TYB_=____9,8~0' ................ '.-:.[ ....... ::__:: ....................... -::: ..........:} ................... :':: ......... :_.:-.-.:T..:_:_.~: ....... ' ........ : ..... :...: ........ TMD=I4,700' ........................... . .............. , ......................................................................... , ..... ' ; ..... T ....................... ................. , .................. ~. . . .................. ,. .......................... .. . : . -: -.. --:- ...... : '7:'. ~--, _.:... _: .'_ :.---:-:~ .'-'_: .... : ...................... : __ i.... ' " ; ' ' .... VERTICAL SECTION - SCALE I": I000' ~'-------~ eoo~ ~ RADIUS OF CURVATURE ~ ....................... GYROSCOPIC SURVEY .................. ~~ .................. [ ALL DEPTHS SHOWN ~oo ..................................................... ................. eooo ~- TVD = ~0' TMD = 14,700' '1 K-23 C L n. c · -, .~_W P, E _S .... D I S T ,~. ;'..: C E A r4 G L E: r) M S D E GL. ~ 0 0 F T D i.&_T__A_B.C_,.~ ': -;" · 7 -':. - l :-,. ::: 7 :'l. 54 -4. 'F;,-,.,:,o [.)"'::tFI Vi::;:iTICAL £Ui::;. D"'0. tFT T"'"" ~::IT $ C L O $ U ;-< F S <" .- ',, t ,,~L C :", r' c: i"," E " c r::'V;::'ik I TY ECT_I ....... _ , ...... ,,.. ..... ,..,,. ,., .¢ ...,,¢ ~ r',: E P T ?i...," "',, 5:', L i::: ....... b ;. !-' T i-.t c;.--' A 'i) t '"' cc' [) i ,c.: T A ;", C E A ?4 G L E ..... ~T ""L)~i.~.~ ..... ,., t ',, ~,_ ~. __ "', ",' '"'. ~..- ,'u ~ ';,; I{;!00 2P 0 1'7'71..3 ~ "',:2, E ~8.97 ¢,; '~3':" :2 ,5-: 242o'~ ;"4 6;0 4:+ 30 r:. 3,,~G .......... _ . ..... ~671. ,.3~' $,,! i,,., .... , ................. I" ' ....... n.' "3 E. 2 '7, r.:.. ~ - r::, ~ · 03 ,;,] .... ], 9 ':2 ....... i., ¢~. 0 136,::.'75 ],~62,73. ............ $02. ~¢E lc,8;~ i,l 275.~,... ,75' i"4 ,,5 51 5z,,,~. ,~ ..... ,.; 27 0 ],951 ...::~.3 t.~;:51,.~3, .....S6'~.o;)E.,.,. ©~v?, _,.S 3!5.49 ~: 3] ~,,49 S t~9, .52 4 E :~.",,ql,, 237·3~.__ ,,:.",~ ,"~,-.. ~) ~,-,.¢o,.,-..., ........... 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(') '~.., '-s"' 4 ~''~ ....... .") 454 · ~ c, 2 ~ ':':' z.:,. ,.. r. ~.'> $ 62 ,., ,.-,' ~- 14 f:, c~ .!g c: 604 o < ~.~ P' 62_ 2., 6 ~,.., S 7 r,.,. '-':2 ..,, ~' ,- 3, 7 ~':, 0 5:.:, ': ,, 34. 2'!0,':'~ 4.3 1.5 ~527. :~'''' 2z,';!'" 5.A S~?.O(.)E !6:1,,I ~ S 6&5,.09 E 6i~:5.37 S 74 45 60 r: '~,,200 - ,,'., ,'- ,.' ,"5 f~ ~ - ~) ' U" ~ ' ...... '4 $ 72 19 17 E 2 774 '" o ,'. . ~' f', ':- 6 ¢ ~54 "~': ~' ~' ~: F' 2 a 2 · 7 '.3 ,5 ; ';..-. 2.. n 4 i::. f; 32 ,, ,:. . . ' .... ~-' ........ ':3 ~ (!; ,::. ........ ,, . ¢: .... ?.· :::.: 4 £ 5 ~ ,, ~, ..... -. _ .'.,~()..'::C~ ;;(.:i (j .:')797,, ..... . ;'~2,, 2, a27."? .... 562. ':)(.;'L: 2!!,a.'~ O, .,. S :f:f:;{,,, :}!9 F "C7.6;:-",:. . S 71 2'-2 4;",, E ! ,.:'". 1-62 '" '" "" 3. 2. 4 Z3 .5 c .:i !' :, · ~ ,: ,:, , .3" $ 7 ¢'' 4 '~l:":',;i ............. ¢''; ':*"'" 27"-}1.4.'~. 269.'~ · ,._'~ S~:,2o'...~,. .. "' r: 9ii:4 ., ,... 5 1 ¢. E 0.¢"*1 ...... 911.74 '~'-v;o. ,. 7 ..5 6,5 ..57 5 E .5 ., I)9,1_ .Tv T o l,l ,::,' ......... ..... , ,, ....... ."~'37.~ " ,.56 ,3r~E 2067,~? b 'a!3f::,Tc, L.. q- 2.'75 7 ~, ,,.,,"' 0 D ¢., 3 a., ..,¢ ':,,, 12 · .69 551 ,? .... . R e., S 6 o.,.,. ,,,'", ~,~" E Z ! 0 cs',,, · a ~.:" ,,c 4 .'; 2 ::~ . ,:,c, ~ [:. 4 72 r;,, · 9 .,,:~ S ..... ., 9 · 5; · 3 z (; · 8 "~,,S 4 3 C ¢' ........... 4 C; :",.'~--' ........ 35 E .+(,,~,.~.,::a S ~! :: ;3 r'~ 5 r, 1 ~' ~:, '7 .?: 5 · ~ 356" (5.33 S':; r) :"' 0 E 219 ! ,, 91 ~; 437 .~ ,, "' '" ~'" :' 4, o 9.97 ....... ,-~ ' , .- ¢' , ,,. ,,.. · .... * 52 F'.. z,~5'{.3,26 6t'''r' 5z+ '" ~:7,~ t~ ,:.,~.aS.~~ S$0,. ,. ........ .,,;i':. ~-,97:1 0.t 63 t6 6 E i,''~ '""' 82. r'~r';53 ';~(3 5F~44.Sa 57a4.":'q' ~!},c "'":.,6 2,273,76 q 4¢';1".49 - ~' ~ ~" ..... . ......... o 4') 4. 56' 3o,37 d 3'...'" 0 !5.:° ..... 3 () 593 ~',., , 47 ~ F" 1.35,47 ..¢. 5 o,> ~ ,:""' O. ,i:' .... 2 '~ ! 4,62 ..,c. /-. 57 !.;, 4 c. ,.?.. .~r;' _,~ 3 (: , !: 1 S, 6 '~,, 1 t:' 5 .>':' ~,. I · 0 O $ .:/966 · 4 i ;.:":",:7, 4 ;. ?: ;-.! '? , a. 1 !-- 5/.. .<3 , 3:) :5 .62' Z6 3 i i,GS.,¢" ')p5(}.43 __ .... ~. c7-/.0'~: 52 !1 12 E ].,<.62 ::;'7~-,-,5:~. ?. ~ :: '1 £: r.. 9:':{ 7 4.:, T.:i, 7'AL ~'',~.,''~;.:,'![)I!!,ITE'S C L C' S U F,!: E~c SJVi7RITY SECTIO,I' ........ ., 719:5072 7095, ,~ ...... ..., .... ::: .......... .!, E 6¢C.'4...,..0 :::, ,51 8 22 E 2,279 63; ...... )53 1 '"' ..:q ('.:" 4 x., ,': ~ o, ' ', c, 54 r': .b "' 3 1 B: .i. 17 5 r._, -? 4 "- a 8 S ,50 ,x. ,. , ;~..c.L.!,° 7'16 .,~.:., 4. , · 7 1"7, ~'::' 2C,~' u:, ' q ~' i!:; {: ,t' 72 . ......... 1'~,4'",'' ....... 4t," 15 739~.34, .... 72!"::) , ?,4" ,..Sa.,~,O:.)[!" 324S~1" .... :, 5'/?x.77 [:' :il,'~,,,,.,,,'" ~.~. ~,'" 60 43 :~4" E 2.594 &493,64 IC;;'':r'' 40 n 74.""3,c4 73""C,,czl ,S':~':;,::..;'' E33C7.57 c r8"-¢ =" ¢ - .... ,,,. ,,..-: i ~:1.) 4 ::: $ n "'t z, r, 5 ,, 8 o-! ';, r, !5 "q ~':: "::' ' .................., ...... :::,, 537. t: 33 ~,7.89 o~' 5B?'5.4., '~ ~':'~.. ~:,77g.19. q 6'3 i2 4i E 1.241 {:641..~ t07"r~ 49 45 -"%q(').5,': 7~3'3,,5',3 S3q,,Or2, E 34°7,,Z]. S no31.46 K ~:,':~-0.40 S ';' .... ' ..... .... ' 9 ~:' ':~ "' fi 1 · ! 7 O 671 v. 1,.,,?_%_ ! 1 n {) 0 4 ,o,,~ 0 '"z, 727032 76 ? '7, 32 $ 4. ? '"~" ~"' ' 0 ~{~ o ,:.:; a ~' 7 C! " ' ,,. . ::.-. , ~. ., ,** 75fi 0°:41,9!3 ! 1 o ,-. .... i' "'~ '- " "7 7,5 R ~" · ':.,. 6 1,..,"" '7:3 l.., ,,,,,,:,,, n,,. . q,, ::': C, · q,. _l I. l :! · '77 ,,,: ~:::' 7. 13 ! t :') '~ 1 ! r', ~. 1 C. "0. 7 "' '~ i b, [: 6 r,, - ..... - .... ' * ......... ,.. , ; ,B, 1 6 ! 306 I 3 ,:", O · l 20 ~,':. 5 2 133.95 : i ~ 2 I z~ ,,) :; 140,.,,'"'. ! ',.~ ") C · ':-? 3 ~. z.,,. 5 ~'::,t l ,,:.', r..,',, 42 1stv 150.:',. 'l,,r~C I~ : ?:!3 19 i,~ i54.24 ......... ..~, _,,?,,, , t~ !:;,~ -' !.' "'" , ~,,, ,. ,,. .~. ~ :7 ('~ ,, I 7, ;:,., $ ~-.: · 4. ! ~,~ t 8.. 2 ..... · 2 2 1"72° 1700. I :':, :',r'.. 2" ':, ' .... 21/:,,90 , ..~ ......... :,~:. ,, ~<5i'~ ]. ~: 3 :.,., , , c, ..,, ~,,~, ~, ,, ~,., . [ ? 0~', .,.,. . ",~ ~ ';- .... ::: ~ . ':~ ~-~ :4 ,-:50,.37 , ....... . ....... , -, 8 ,~,67 ..... -81 E ............. ' . ..:, S 2!1b,'.51 4~,+! 99 ~, 37;',,.~, I04! .c:. i(:,2,.',C:7 $ 2222,78 ':g 7<,)00 5t~6, 50:36. 1777,49 $ ':L~!:!,Oi!~, !1'?00 7727, 7627, 359f.,45 S 60[:2,94 E-- 12C:UO ~..;.:3'77, 8277, 4.7'29,07 S 64~;?,60 if S U f~ A PETROLANE ~PANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY K-23 WELL NAME COOK INLET, KING SALMON PLATFOP~ LOCATION JOB NUMBER A478 G0297 TYPE OF SURVEY GYROSCOPIC (Tangential Computations). SURVEY BY EDWARD J BUTLER OFFICE ALASKA DATE 4,-,13-78 ~ . "i _~; '- : ....." 'SCALE !": IOOO' ....... ; ATLANTIC RICHFIELD CO. .......... ~'~ ..... ~-'~'"~'? ~". .... ~"-?~-~ ....... .-","-~ .......... ]~-'(~'] ............ W;E'L~-~'NO[-' k~23 ..................... .' .... ........ ~ .......... TANGENTIAL METHOD : ; .................. GYROSCOPIC S.URVEY . .~ ~ - .............. , : .......... : .... ' ........ : .......... TVD = 9~8 . .~ .... - ........... ~ ............ : ..... TMD= 14~700' .... . ........ ~ - .... ~ ................ , _.. , '; ........ ~ .......... ~ .............................. : ...... VERTicA'E SECTION SCALE I"= IOOO' ATLANTIC RICHFIELD CO ................. WELD-! NO.- TANGENTIAL METHOD GYROSCOPIC SURVEY Union Oil and Gas Division: Western Region Union Oil Company California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 April 13, 1978 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Gilbreth: Enclosed is the following forms for your information: TBUS G-17, GRAYLING PLATFORM Subsequent Sundry Notices and Reports on Wells Well Completion Report ~ ..... ~i:~US K-23,..kI~G SALMON PLATFORM ~..~-u-ndry ~ot'i~].ce" and Reports on Wells I~Tb'h-~tFl~F-~e p o r t TBUS D-15, DOLLY VARDEN PLATFORM Monthly Report TBUS D-7, DOLLY VARDEN PLATFORM Monthly Report TBUS G-I~ GRAYLING PLATFORM Monthly Report Sincerely yours, Dist. Drlg. Supt. REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE ( \LASKA 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.) ,PI NUMERICAL CODE 50-133-20313 6. LEASE DESIGNATION AND SERIAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME NAME OF OPERATOR ~¢ 8. UNIT, FARM OR LEASE NAME Union Oil Company of CalifOrnia Trading Bay Unit ADDRESS OF OPERATOR 9. WELL NO. 909 West Ninth Ave., Anchorage, AK 99501 K-23 (21-27) LOCATION OF WELL At surface 10. FIELD AND POOL, OR WILDCAT McArthur River (Hemlock) 698' N 7 81' W of SE cr Sec 17, T9N-R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 27, T9N-R13W, S.M. 12. PERMIT NO. 7~-4 ~ort, or Other Data NOTICE OF INTENTION TO: .. FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON* REPAIR WELL [ I CHANGE PLANS (Other) Increase Measured Depth Permitted SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING 5HOOTING 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. As pe? verbal agreement from Hloyle Hamilton to Richard Knowles on 4-6-78, we propose the following changes: 9-5/8" set @ 12,495' 7" liner set 12,200' to 14,850' Proposed depth of 14,850' MD, 9908' TVD These changes only increased the measured depth permitted and not the true vertical depth. *Atlantic Richfield Company - Sub-operator 16. , hereby c,eftT~ that the foregoing is true and correct . (This s~ce for State office u~) CONDITIONS O~P;~VAL, '~ANY; TITLE DATE. 4/12/7R See Instructions On Reverse Side STATE OF ALASKA SUBMIT IN I~U?LICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~LL NAME OF OPERATOR Union 0il Company of California* ADba~SS or 909 West 9th Ave., Anchorage, AK 99501 4 lOCATION OF WF~L 698' N & 81' W of SE cr Sec 17, T9N-R13W, SM ~: API NU~iERICAL CODE 50-133-20313 6 LEASE DESIGNATION AND S~IAL NO, ADL 18730 ? IF INDIA~T. AL/OY~rZE OR TRIBE NAIVE 8. L,~'IT FAR~ OR LEASE NAME Trading Bay Unit 9 WELL NO :-23 (21-27) 10 FLF, J~D AND POOL, OR IVI'LDCAT __McArthur River (Hemlock) n SEC. r.. n.. M (SO~O~ ~O~ O~~ Sec 27, TgN-R13~, S~ 12 PE~LMIT .78-4 13. REPORT TOTAL DEk~i~PI A'r F~;D OF MONT!q. CHJk~NGF. S IN HOLE SIZE. CASING A~ C~ENT!NG JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~FO~TIONS. ~STS ~ ~SULTS FISHING JO~ JL~$K ~ HO~ AND SIDE-~.ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~S ~ HO~ CO~ITIONS Drilled 12-1/4" directional hole to 11,066'. Stuck DP while POH. Fished and soaked pipe free w/250 bbl Black Magic. Drilled 12-1/4" hole to 11,377', sheared pin in kelly bushing. Replaced same and drilled to 12,526'. Jumped box in DP tool joint and dropped string. Fished and recovered same. RU and ran 313 jts. of 9-5/8" 47# N-80 and S-95 Buttress csg. shoe @ 12,495' and FC @ 12,410'. Cmt'd w/1000 sx retarded class "G" cmt. Tested casing and drilled 8-1/2" hole to 12,944'. Plug back 8-1/2" hole to 12,445' w/236 sx class "G" cmt. Drilling 8-1/2" directional hole @ 13,700' on 4-1-78. *Atlantic Richfield Company sub-operator , ~') , /( , ~OTE--Report on this form is required for each calendar ~nth~ regardless of the Itotus of adorations, and must ~ flied In duplicate with th e oil and gas con.ervotion commiffie by the 15~ of the 6uGcNding man~. unle~ ~therwile ~r~cted. DRILLING SUMMARY Spudded well @ 1 am 1-19-78. Drilled cement 365' to 384' in 24" conduc- tor. Drilled and gyro surveyed to 547' and hit hard spot. Could not identify. Set cement plug 547' to 332'. Dressed off plug to 458', ran Dyna Drill and drilled to 644'. POH, ran 12-1/4" bit and directionally drilled to 2353' where bit torqued up. Ran oriented impression block, could not identify. RIH w/sidetracking BHA and started reaming @ 2222'. Undercut hole to 2283'. POH and PU directional drilling assembly and drilled to 5060'. POH and PU 17-1/2" assembly. Opened 12-1/4" hole to 17-1/2" hole to 5060'. ?OH, ran 13-3/8" csg w/shoe @ 5005' and FC @ 4919'. Cemented 13-3/8" csg w/120 bbl. caustic preflush, 4585 cuft of 3% gel class "G" followed by 500 sx of "G" neat. C.I.P. @ 8 pm 2-5-78. Full returns w/clean cement to surface. Installed pack-off, ND 20" stack. NU and tested BOPE. RIH to FC, tested 13-3/8" to 1500 psi, drilled FC, cement, shoe and 10' of new formation and tested shoe to 12.5 ppg. Directionally drilled 12-1/4" hole to 8040'. Conditioned mud with 4#/bbl soltex. Directionally drilled to 10,051', POH and left 128' of BHA w/bit @ 10,051'. RIH w~overshot and recovered fish. Drilled 12-1/4" directional hole to 11,066'. Stuck DP while POH. Fished and soaked pipe free w/250 bbl Black Magic. Drilled 12-1/4" hole to 11,377', sheared pin in kelly bushing. Replaced same and drilled to 12,526'. Jumped box in DP tool joint and dropped string. Fished and recovered same. Ran 313 jts. of 9-5/8" 47# N-80 and S-95 Buttress csg. shoe @ 12,495' and FC @ 12,410'. Cmt'd w/1000 sx retarded class "G" cmt. Tested casing and drilled 8-1/2" hole to 12,944'. Plug back 8-1/2" hole to 12,445' w/236 sx class "G" cmt. Drilled 8-1/2" directional hole to 14,700' and conditioned hole for logs. Ran DIL and Sonic/GR. Ran 7" 29# N-80 liner w/shoe @ 14,700' and top @ 12,166'. Cemented w/800 sx class "G" cmt. PU two stands and reversed out 170 sx. Strapped in hole and tagged firm cmt. @ 12,008', drilled out to top of liner. POH. RIH w/6" bit and casing scraper, cleaned out to landing collar @ 14,619'. Tested casing to 3000 psi. Drilled out hard cement to 14,670' and retested. OK. Ran WSO test on liner lap as per well plan. Ran CBL/CCL/GR, Gyro survey, and FDC/CNL logs. RIH w/DP and reversed out mud w/filtered inlet water. Mixed 6% KCL brine in fresh water and weighted up to 9.1 ppg w/NaC1. Spotted Dril-S pill in liner and POH. RIH w/Baker packer and prematurely set @ 3280'. Fished to recover packer. Ran 3-1/8" x 20' dummy gun to 14,645'. Ran Baker FB-1 packer on WL and set @ 12,053' DP measurement. Ran packer seal assembly on DP and tagged up @ 12,053'. Tested w/2000 psi above and below packer. PU to 12,046' and reversed hole. Ran 4-1/2" completion assembly. Tested tubing and packer w/3000 psi OK. Installed BP valve. ND BOPE, NU and tested Xmas tree. Gas lifted brine out of tubing & perf'd 4 HPF 14,100' - 14,146'. Ran WL BHP bomb to 13,900' and GL well on 12 hr test. GL @ rate of 3268 B/D w/l% water. Released well to Production Dept. and released rig @'2 am 4'24-78. ]z.// .5-0 ,0 ' q~/ ~ 7 ., · .. .. ... · . / Union Oil and Gas D;'"don: Western Region Union Oil Company of California P'O' B°x 6247 Anch°rage' Alaska 99501 )'"'I'~ '- i"i .... C ~'[-C:L h~J'C.. ' ~;1'/:~ Telephone' (90'7)276-7600 FNC;,~',~L' , March 14, 1978 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 5 ... 2 Gr'OL 3 GEOL REV .................. DRAFT ........... S~c ..... I cON;:,; 2: Dear Mr. Gilbreth' RE' TBUS G-17 - GRAYLING PLATFORM _TBU~7_F,~- DOLLY VARDEN PLATFORM - TBUS K-~- KING SALMON PLATFORM Enclosed for yo.ur information are two (2) copies of the Monthly Report for the above projects. Sincerely yours, '---Jim .R). Ca 11 ender Dist. Drlg.'Supt. Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Getty Oil Co. Phillips Petroleum Co. Chevron USA USGS Harry Lee RECEIVED MAR I 6 1978 DiviSion of Oil ,:'].~ld Gas ~nn~tff'~a[jon An~h~r~ F~rm No. P--4 R,~V, 8-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NA/~E OF OPERATOR ~ Union 0il Company of California 3. ADDRESS OFOPE~ATOR 909 ~. 9th Ave., Anchorage, AK 99501 4 LOCATION OF WELL 698' N & 81' W of SE cr Sec 17, T9N-R13W, SM SUBMIT ~N DI/PLICAT~: ~ AP! NUA{ERICAL CODE 50-133-20313 6 LEASE DES:GN'A.T'ION AND SEIilA ADL 18730 8. L~IT ~A~i OR LEASE ~ '' -'~'raa~n~ Bay Unit 9 W~LL NO K-23 (2~-27) I0 9~LD ~HD P~L. OR WrLoC~' MzArthur River (He~loCk)~j "n SEc,T..R ~{ (BOSOm Sec 27, T9N-R13W, 11. PERMIT HO ~ ' '~ ~ 78-4 13. REPORT TOTAL DEPTH AT END OF MONTH. CHAXG~ IN HOLE SIZE. CASING AND CHF~TING JOBS INCLI;DING DEPTH SET ~ VOL~ USED, P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ JL~K ~ HO~ AND SIDE-T~.ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CONDITIONS Report of operations for the month of February, 1978. Opened 12-1/4" hole to 17-1/2" hole to 5060'. POH, ran 13-3/8" csg w/shoe @ 5005' and FC @ 4919'. Cemented 13-3/8" csg w/120 bbl. caustic preflush, 4585 cu ' of 3% gel class "G" followed by 500 sx of "G" neat. C~I,P.'@ 8~pm 2-5'78. Full returns w/clean cement to surface. Installed pack-off, ND 20" stack. NU and tested BOPE. RIH to FC, tested 13-3/8" to 1500 psi, drilled FC, cement, shoe and 10' of new formation and tested shoe to 12.5 ppg. Directionally drilled 12-1/4" hole to 8040'. Tested Koomey unit and BOPE, OK. Conditioned mud with 4#/bbl. Soltex, drilled to 9880', tested all BOPE. Directionally drilled to 10,051', POH and left 128' of BHA w/bit @ 10,051'. RIH w/overshot and recovered fish. Directionally drilling 12-1/4" hole @ 10,248' on March Ist. MAR 1 5 lttz Divislo. of rill zoo' ~'-,~ ',:~,:t,' i ;I~&Ri:;7',';:JjOFt *Atlantic Richfield Company is the sub-operator. ,-~.i,e~ v Dist. Drlg Supt 3/14/78 SIG~ /~i ~ ' ' ~~W~'~ ~T~ ' ' / / u[[[I n. ~a[ i~[u~r- _ --Reoort this form is required for each calendar ~nth~ regardless of tM status of oDeratiofls, and must ~ flied In duplicate with the off ~ oil and gas conservaflon commiflee by the 15~ of the su~c~ding m~n~, u~le~ ~fherwisa ~ir~cted. E~PAR~~ OF NA~%AL ~~CES Division of Oil and Gas ~rvation Hoyle H. m~il~n . /~~~ Chief Petroleun Eng~n~r~v~ Feb~y 21, 1978 wi~s B~ T~"i A~ King Platfom, Well No. K-23, Pezmit No. 78-4 ~~-_ 15, 1978- I left my ~ at 6:00 ~4 for check in at ~--"-_t6"-Kenai at 6:45 AM. Purpose of the trip was to witness BOP test on the K~ug Salm~ Platfcxm on Well No. K-23. I arrived on the King ~ Platfozm at 8:45 AM. Tests on n~mifold began at 10:00 AM 2/15/78 and finished at 12:30 ~4 2/16/78. There were five valves that leaked ~ before it would test. The manifold was tested to 5000 psi. The Swaco sL~erchoke was also tested to 5000 psi. There was a positive and adjustable choke on manifo~ OK. Thur~,._Febi~ 16, j~1978 - T~e upper and lower kelly were tested to '50~0 psi ~ alsO--~e-baI1 valve on the floor. ~ upper kelly tested OK, but the io~r kelly and the ball valve ~ the floor failed. Testing stoppe~ at 2:30 AM. ~%e bowl ~ in the casing head was stuck and testing of BOP stack could not be dc~e. The Parker crew had tried to pull protector out frcm 8:00 PM 2/15/78 to 6:00 AM 2/16/78. Finally Tristate was ca_]_led out with a spear and pulled the bc~l pr~ at 8:00 AM. Testing of BOPs started at 9:00 AM and finished at 11:30 AM. The pipe rams ~ tested to 3000 PSI, the ann~,~la~ preventer was tested to 1800 PSI, the inside and outside kill val~es and choke valves were tested to 3000 PSI. The check valve was disabled and put back toge~ and tested to 3000 PSI. The test stem was pulled and the blind rams w~re tested to 3000 PSI. The re~Dte cc~trols and master cc~~ operated satisfactorily. I also ~ out the aocumulator with all air and pumps shut off. Annular preventer, pipe rams, and blind rams w~re closed with 1800 PSI left cn master gauge, indicating. accumula~ was in good shape and no leaks in control lines or preventer seals. Jack Murr~ was the operator for Arco. Nitrogen back up bottles had 2250 PSI each. ~s~: I witnessed the tests of BOPs and components. ~nen tests ~ tests were sattsfac~ exc~ for the lower kelly and the drill stem safety valve on the floor. Aroo is to call our office in c~e day when 8:30 AM. Jack Murray called 2/17/78. Lower kelly and floor valve were replaced and. tested to 3000 PSI and held out. Drlg. Permit No. Opera torA, .~ ?~z9 Satisfactory T~v?e Inspection Yes No Item (~0 Location,General ( ) ( ) 1. Well Sign (~ ( ) 2. General Housekeeping ~,))) ( ) ( ) 3. Reserve Pit-( )open( )filled ( ) () () 4. Rig () ( )Safety Valve Tests ( ) ( ) ( ) 5. Surface-No. Wells (~) ( ) ( ) ( ) 6. Subsurface-No. Wells !~! ( ) (-) Well Test Data __.m I~ ( ) ( ) ( ) 7. Well Nos. __, ,__, ( ) ( ) ( ) 8. Hrs. obser , __, (~ ( ) () () 9. BS W ,-- ' () ( ) ( ) 10. Gr. BDI~--' ' , ( ) () Final Ab~ndonF~ent (~ ( ) Ala. ~ Oil and Gas Conservation Commit.~ce Field Inspection Report Wel 1/Platfm Sec T Represented b _y~'~£/.F'?/' .... ame & Number_/,~---.2 ~ SatisFactory Type Inspection ~ No Item 0<),.. BOPE Tests 21 22 23 24 25 26 27 ( ) ( ) 11. P~ Marker (~) ( ) 28. Pipe Rams~'m~'psig ( ) ( ) 12. Water well-( )capped( )plugged (~YO ( ) 29 Kelly & Kel'ly-~-~ck 9~m~psi.q ( ) ( ) 13. Clean-up ~ ~ 30 Lower Kel 1 vul .... · .Y -,-~ ~ psiq ( ) ( ) 14. Pad leveled A ((~ ( ) 31. Safety Floor valves-~BV ~Dart Total inspection observation time~hrs~ays Total number leaks and/or equip, fa~l~res ~ Remarks .... " ~ ~.. ~ cc'l~:,.~/.~--:~/ Zotify in J days or when ready--Inspected by/~~jFy~ Date .- "'~ '- 15. ~~sing set (a~gT~m,~ 16 'luid-~X)wtr.--~mud ( ) oil 17 Master Hyd. Control S~s.~-~' psig 1 . R~mote Contro 20 Drilling spool-~~F "outlets Kill Line-(~') CEeck valve Choke Flowline ( ) HCR valve Choke Manifold ['1o. valvs.~__flqs~,~ Chokes- (~) Remote ~ Pos. (9(! A.dj ~ -- Test Plug-(~)Wellh'd( )csg( )none Annular Preventer ~ps i~ B1 ind Rams ~F~']DSl.q Union Oil and Gas DU'"'""on: Western Region Union Oil Company o, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 February 14, 1978 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBUS G-9, TBUS G-17 ~__G]tA__YL I NG PLATFORM ~MON PLATFORM TBUS D-7 DOLLY VARDEN PLATFORM Dear Mr. Gilbreth' Enclosed for your informtion are two (2) copies each of the Month Reports for the above captioned projects. Sincerely yours, '-oLi~. Cal Iender Dist. Drlg. Engr. CC' Marathon Oil Co. Atlantic Richfield Co. Chevron USA Getty Oil Co. Amoco Production Co. Phillips Petroleum Co. USGS Harry Lee Form No. ~. 8-1-70 STATE OF ALASKA SUB~rr n~ mmLICA~ OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUMERICAL CODE 20-133-20313 LEASE DESiGi~A%qON AND SE]RIAL NO ADL 18730 7 IF rMDIA~, AL~)¥TEE O]~ TIRIBE NAME 0 IL ~ G&S [] OT~ EI~ ~'ELL ~LL NAME OF OPI~q, ATOR Union Oil Company of California ~D~hsss or' oP~'o~ ' 909 W. 9th Ave., Anchorage, AK 99501 4 LOCATION OF V~F-~ 698' N & 81' W of SE cr Sec 17, T9N-R13W, SM 8. L'.'IT FARM OR LEASE NAuME 11 SEC . T.. R.. M (BOTTOM HOLE, Sec 27, T9N-R13W, SM 12 PERMIT 78-.4 RF_~ORT TOTAL DEP~IYH AT F_2qD OF MONT/4, CHeuNG]ES IN HOLE SIZE, CASING AD C]L-MF34TING JOBS INCLtYI)ING DEPTH SET ~ VOL~ USED, P~O~TIONS, ~STS ~ ~SULTS FISHIA~G JO~ JLZqK IN MOLE AND SIDE-~.ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~;G~ ~ HO~ ~I~ITIONS Report of operations for the month of January 1978. Spudded well @ 1 am 1-19-78. Drilled cement 365' to 384' in 20'~ conductor. Drilled and g%ro surveyed to 547' and hit hard spot. Could not identify. Set cement plug ~'~'~'[~'"~'§§~"~-~ ....... ~r~'~'~'~'~i~'~~'~;",~'~an Dy~"~ill 'and drilled to 644'. POH, ran 12-1/4" bit and directionally drilled to 2353~ where bit torqued up. Ran oriented ~m~p~lg~p~B~:~b~ock,~_.~o~ld..npt identify. RIH w/sidetracking BHA and started reaming @ 2222'. Undercut hole to 2283'. POH and PU directional drilling assembly and drilled to 5060'. POH and PU 17-1/2'~ assembly. Opening 12-1/4" hole to 17-1/2'~ @ 2430' on 2-1-78. *Atlantic Richfield Company is the sub-operator. ~4, I hereby certify that the foregoing is true and correct s,s~ (]ke~_..~, ~_/& ~/)=:~ Dist. Drlfi..__S_uJ?t: ~ _2/14/78 ~ u Illl I\, b~ I IClIU~! ' · NOTE -- Rel)orI on this form is recluired for each calendar month~ regardless of t~- Itotus of operation~, and ~.~-I~ filed in duplicate with the oil and gas conservation commiffee by the 15~ of the su~c~ding men~, u~le~ etherwiea d~rected. January 6, 1978 Tra~ Bay Unit K-23 (21-27) Union Oil ~Oompany of California Sta~ ~t No. Distr£ct Lm~ ~ Union Oil ~y of Califo~mia Box 6247 ~~, Alaska 99502 ~osed is the approved ~lica~ for permit to drill the above referenced Well at a locat/~ in Section 27, Township 9N, Range 1~, SM. A directi~ml Fmny rivers in ~/aska and their drainage systems have been classified as important for the sp~Tdz~g or migrati~ of anadrcmous fish. ~Operations in ~ a~eas are subj~ to AS 16.50.870 and the regulations prcmulgated there~ (Title 5, Alaska ;~dr~tstra~ve Code). Prior to ~ing ~tions ~ may be ocn~ by the Hsbitat Coo~tc~'s office, Dep~rtment of Fish and C~m~. Pollution of any wat~ of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations ~gat~d thereunder fritle 18, Alaska Administ~a~ Cod~, Ch~er 70) and by the F~ Water Pollution Control Act, as ~- Prior to ~ing operatic~s you may be cum~ by a representativ~ of the Department of Env~tal fkazservation. Pursuant to AS 38.40, Local t~tre Under State t~ses, the. Alaska Department of Labor is bein~ notified of the issuance of this permit to drill. office within 48 hours after ~he w~ll is ~. ~ ~xu~ a~so ~e to se n~tified so that a repxesentativ~ of the Division my be present to witness testing of blowout preventer equ~t before surface casing shoe is drilled. R. T. A~&~c~ T.B oU. K-23 (21-27) -2- January 6, 1978 In t~ event of suspension or ~mdom~t please give t=his office adequate ~ notification so that we may have a witness present. Very truly ~, ~~ Oil ~ C~ ~~~ ~~ Enclosure Department of Fish and ~, Habitat Section w/o encl. De~t of En~nta! ~ation w/o encl. Division w/o er~l. · Form 10-401' REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL b. TYPE OF WELL OIL GAS OTHER DEEPEN L-~ SINGLE ZONE ~-~ NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR 909 W. 9th Ave.,. Anchorage, .AK 99501 4. LOCATION OF WELL At surface 698'N & 81'W of SE cr Sec 17, T9N-R13W, SM At proposed prod. zone , 1600' E of NW er Sec 27, T9N-R13W, SM 13. DISTANCE iN MIlES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 24 miles NW of Kenai SUBMIT IN TRI' 'XTE (Other instructn reverse side. blULTIPLE ZONE API No. 50-133-20313 6. LEASE DESIGNATION AND SEPdAL NO. ADL 18730 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-23 (21-27) 10. FIELD AND POOL, OR WILDCAT" ' gcArthur River (Hemlock) 11,SEC., T., R., bi., (BO'FI'OM HOLE OBJECTIVE) Sac 27, T9N-R13W, SM 12. 14. BOND INFORMATION: T~E Statewide Surety and/or No. Federal Insurance Co. ' #8011-34-40 ~o..t $100,000. O0 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to ne, areyt drig,.unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COblPLETED, OR APPLIED FOR, FT. 1000' · 16' No. OF ACRES IN LEASE 3840 19. PROPOSED DE~tt 9987' TVD, 14,500' 17. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK ~LL START 100' RKB January 1, 1978 23. PROPOSEDCASINGANDCEMENTINGPROGRAM 'SIZE'OFHOLE sIZEOFCASIN~ WEIGHTPERFOOT'.'I''GRADE [_ SET+INGDE~fi.' '~'* 'Qu~ntityofcement .... . 17-i/2" ...... i3-'3/8'i' .72# ~"68#. N-~0 & K-~5' .'5000~ 650 sx w/10% gel + 6.00. sx "G" .12~1/4" 9-5/8." 47# N-8~ & S.~95 12,000' 700 sx "G" W/l% D-31 .. · 8-1/.2" ," ...7~' l~ne'r{ . 29# . N-80 !l,700r!4,5Q0 700 sx 'IG" w/l% D-S1' · , We propose to directionally drill a Hemlock producer to approximately 14,500' MD (9987' TVD) with a 9 to !0 ppg fresh water mud. Logs will be run at TD. A 2000 psi Hydril will be installed on the 24" conductor pipe. A 5000 psi Hydril and double ram preventer will be installed on the 13-3/8" and 9-5/8" casing. All BOPE equipment will be operationally tested each trip and pressure tested weekly. ?~ f~, *Atlantic Richfield Company - Sub-operator .... e*10% gel is equivalent to 2.5% gel by weight of mixed water l3i¥l$iOfi ~! IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present~roductive zone new productive zone. If proposal ia. to drill or deepen directionally, give pertinent data on subsurface locations and m~surRd'h'n'-d vertical depths. Give blowout preventer prog~arn. , ,':" . ,, : ~is space for S.tate office use) ~ ~ ~NDITIONS OF APPROVAL, IF ANY: SAMpL~ ~D CORE CHIPS REQUIRED ] · ;{~D LOG OTHER REQUIREMENTS: DIRE~IONAL SURLY REQUIRED A.P.I. NUMERICAL CODE ~YES ~ NO 1978 TIYLE District Land Manager 50-133-20313 PERMIT NO.. 78-4 APPROVAL DATE -- *See Instruction On Reverse Side january 6 ,, 1978 DATE Januarsf 6, 1978 · K-6 1 I4.-23 + 14,500' MD ,: 3o 2'9 27 AttanticRichfieldCom WELL LOCATION MAP TRADING BAY UNIT K-23 (23.-27) CHECK LIST FOE :,£'.' '~.;LLL ?[RMITS Company · Yes No Remarks 1. Is the permit fee attached ..................... Lease & Well No. '~_/~,L.~, "~/~'-~_--~ 2. Is well to be located in a defined pool .............. K~J~, 3. Is a registered survey plat attached ................ 4. Is well located proper distance from property line ......... 2~/~.~~ 5. Is well located pFoper distance from other wells .... ., ..... 6. Is sufficient undedicated acreage available in this pool ...... 7. Is well to be deviated ....................... 8. Is operator the only affected party ................ ,_~L~ 9. Can permit be approved before ten-day wait ............. 10. Does operator have a bond' in forCe,. ................. ~$ ll. Is a conservation order needed ...... ' ............. 12. is administrative approval needed ....... Is conductor string provided 13 14. Is'enouQh cement used to cirCulate on conductor and surface .... .., 15. Will cement tie in surface and intermediate or production strings .. 16. Will cement cover all known productive horizons .......... 17. Will surface casing proteCt fresh water zones . . . ' 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~ psig 20. Has DMEM approved Plan of Operation ................ .. Additional Requirements' Approval ReCommended- Geol og~: Engi neeri ng: TRM JAL FI~H ~~JCM ~ HWK .~/~.------~ ECS ~ ~RAD Revised 11/17/76