The URL can be used to link to this page

Home My WebLink About168-076Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240509 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D NCIU A-18 50883201890000 223033 5/1/2024 READ Multiple Array PProf PBU B-05D 50029202760400 213069 4/24/2024 HALLIBURTON RBT PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT PBU D-18B 50029206940200 215001 4/21/2024 HALLIBURTON RBT TBF A-07 50733200360000 167046 4/17/2024 HALLIBURTON RBT TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Please include current contact information if different from above. T38771 T38772 T38773 T38774 T38775 T38776 T38777 T38778 T38779 TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 12:46:46 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Installed AVE GL System Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,000 feet N/A feet true vertical 10,222 feet N/A feet Effective Depth measured 9,410 feet See Schematic feet true vertical 8,653 feet See Schematic feet Perforation depth Measured depth 2,390 - 9,360 feet True Vertical depth 2,176 - 8,603 feet 4-1/2" L-80 7,760 (MD) 7,805 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 9,330 (MD) 8,574 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Hemlock Oil, Middle Kenai B, C, D & E Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 2,570psi 4,790psi 3,090psi 3,950psi 6,890psi 1,044 1,028 Burst Collapse 1,540psi measured TVD Production Liner 7,520 7,488 2,337 Casing Structural 6,860 6,830 7" 7,520 7,488 9,826 9,064 1,044 Conductor Surface Intermediate 13-3/8" 9-5/8" 8,160psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 168-076 50-733-20143-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018731 Trading Bay / Hemlock Oil, Middle Kenai B, C, D & E Oil Trading Bay ST A-18 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 36 Gas-Mcf MD N/A 279 Size 317 81766 0 2670 114 323-423 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 16. Well Status after work: L G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Coldiron at 11:14 am, Mar 08, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.03.08 10:44:00 - 09'00' Dan Marlowe (1267) RBDMS JSB 031424 Revised By: CRR 03/08/24 SCHEMATIC Trading Bay Unit Well: A-18 PTD: 168-076 API: 50-733-20143-00 Completed: 02/29/24 KB ELEV = 101’ PBTD = 9,550’ TD = 11,000’ ANGLE thru INTERVAL = 24.9q RKB to TBG Hngr = 37.00’ 5 3 5 D E Hemlock 4 13-3/8” 9-5/8” 7” 2 6 1 DV Collar 5,598’ 7 B C D XN CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 K-55 Seal Lock 12.515 Surf 1044’ 9-5/8” 43.5 N-80 Buttress 8.755 Surf 67’ 40 K-55 Buttress 8.835 67’ 4191’ 40 N-80 Buttress 8.835 4,191' 5,643’ 43.5 N-80 Buttress 8.755 5,643’ 7,520’ STAGE COLLAR 5,598' 5,600' 7-5/8” Scab 29.7# L-80 SLIJ-2 6.875 Surf 7,488’ 7” Liner 29 N-80 Buttress 6.184 7,489’ 9,826’ TUBING DETAIL 4-1/2” 12.6 L-80 IBT 3.958“ Surf 7,760' 3-1/2” 9.3 L-80 8rd 2.995” 7,760' 9,330' JEWELRY DETAIL NO. MD TVD ID OD Item 1 345' 345' 3.813 6.600 Baker S-5 TRSSSV 2 2,328' 2,122' 3.813 6.400 X-nipple:(Bypass Access Mandrel installed 3/3/24) 3 2,331' 2,124' 3.880 6.670 Hydratrieve Packer (shear to release at 40k) 4 2,337' 2,130' 3.813 5.680 Sliding Sleeve. Down to open (Open 3/2/24) 5 2,341 2,133' 3.750 5.040 Lower Polish Bore 6 7,759' 7,085' 2.992 3.500 XO 4 1/2" IBT X 3 1/2" EUE 8RD 7 9,281' 8,525' 2.750 4.280 XN NIPPLE (Plug set 3/2/24) 8 9,330' 8,574' 2.920 3.990 Mule Shoe GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,212' 2,022' 3.958 1" GLM Dummy 02/29/24 2 2,420' 2,202' 3.958 Casing Exhaust Mandrel (BK) 16 Dome 896 02/29/24 3 4,356' 3,887' 3.958 Casing Exhaust Mandrel (BK) 16 Dome 876 02/29/24 4 5,767' 5,191' 3.833 Casing Exhaust Mandrel (BK) 16 Dome 856 02/29/24 5 6,842' 6,214' 3.833 Casing Exhaust Mandrel (BK) 16 Dome 836 02/29/24 6 7,420' 6,765' 3.833 Casing Exhaust Mandrel (BK) Dummy 02/29/24 7 7,798 7,121' 2.867 Casing Exhaust Mandrel (BK) 16 Dome 816 02/29/24 8 8,542' 7,807' 2.867 Casing Exhaust Mandrel (BK) 16 Dome 796 02/29/24 9 9,223' 8,468' 2.867 Casing Exhaust Mandrel (BK) 24 Orifice 02/29/24 PERFORATION DETAILS ON PAGE 2 Revised By: CRR 03/08/24 SCHEMATIC Trading Bay Unit Well: A-18 PTD: 168-076 API: 50-733-20143-00 Completed: 02/29/24 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt. SPF Last Date Status B 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open B 26-7 2,567' 2,700' 2,331' 2,448' 133' 5 03/19/15 Open BZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open Hemlock 6,010’ 6,150’ 5,423’ 5,557’ 140’ 9/13/2013 Open D 54-9 7,320’ 7,436’ 6,669’ 6,780’ 116’ 9/13/2013 Open D 55-7 7,450’ 7,533’ 6,794’ 6,873’ 83’ 9/13/2013 Open D 55-7 7,544’ 7,570’ 6,883’ 6,908’ 26’ 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790’ 7,870’ 7,113’ 7,187’ 80’ 9/13/2013 Open D 56-1 7,904’ 8,030’ 7,218’ 7,333’ 126’ 9/13/2013 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104’ 8,158’ 7,400’ 7,449’ 54’ 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425’ 8,555’ 7,696’ 7,819’ 130’ 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610’ 8,650’ 7,872’ 7,910’ 40’ 9/13/2013 Open E 58-1 8,660’ 8,675’ 7,920’ 7,934’ 15’ 9/13/2013 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open E 60-0 8,916’ 8,965’ 8,167’ 8,215’ 49’ 9/13/2013 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 9,074’ 9,120’ 8,322’ 8,367’ 46’ 9/13/2013 Open E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210’ 9,290’ 8,455’ 8,534’ 80’ 9/13/2013 Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open Hemlock 9,330’ 9,360’ 8,574’ 8,603’ 30’ 9/13/2013 Open Well Name:TBF A-18 API #:50733201430000 Field:Trading Bay Field Start Date:1/26/2024 Permit #:168076 Sundry #:323-423 End Date:3/3/2024 1/26/2024 1/27/2024 1/28/2024 1/29/2024 1/30/2024 1/31/2024 Well Operations Summary Continue rig up, prep & test run Drawworks, rotary table, & both mud pumps, good, install winterization to rig cellar & start heating. Continue Rig activation, prep & install Kelly Rat hole, P/U, m/u & service Kelly, install kelly bushing to kelly. Wire in remote accumulator panel, power up system & test good. stand back kelly. MIRU, Dress Mud pumps, , Install utility lines from Drill deck to sub-base, Remove storage covers from Draworks & driller console, remove Desicant & drop Brushes on MP #2, install wall end panels to pits charge pump room. Continue to rig up, skid rig over well center & secure same, continue pull desiccant from Eq., energise & bump test. unload boats with heaters and fuel tanks, supply conesx, spot conexs on upper deick, spot bang board, rig up heaters, running heater trucks under sub base and shakers. Continue Rig activation, Tie back Rat hole, Pull Kelly, Finish fitting rat hole from Moidifications, spot test pump in cellar. Repair Motor on Glycol Heater. Daily Operations: Continue Rig Activation, Laid out and accounted for Koomey lines. Wired in Test Pump and checked rotation all good. Organized around rig and secure for standby. Release crew at 16:00hrs wait on ice breakup. Page 1 of 4 Well Name:TBF A-18 API #:50733201430000 Field:Trading Bay Field Start Date:1/26/2024 Permit #:168076 Sundry #:323-423 End Date:3/3/2024 2/15/2024 2/16/2024 2/17/2024 2/18/2024 2/19/2024 2/20/2024 Well Operations Summary Daily Operations: Work on rig projects while plan for rolling BOPE test, preform rolling BOPE test witness waived By inspector Jim Regg, tested with 2 7/8" TJ, 250/2500, good testd Gas alarms good, choke manifold, floor valves good. PVT alarms., circulated hole clean 463 bbls to production, Finish r/u flow nipple, P/u handling Eq, M/U 2 7/8" test joint, install mud line to rig, R/U test Eq., fill surface Eq with test water, attempt to fill test joint with test pump, pump not preforming. troubleshoot & repair, attempt to shell test bope with no luck, pressure falling off. narrow down to leak at wellhead. Discuss options with Engineer, Test choke manifold while waiting on plan forward. perform koomey draw down and house keeping Continue rig activation, unload boat, mix 3% KCL fill rig pits. Bullhead hole volume 385 bbls, pump 2.5 BPM, 470 psi, shut down monitor 1 hour pressure drop to 215psi. Install & nipple up 13-5/8 5m Bop's, Riser, mud cross, 13-5/8 5m double gate & 13-5/8 5m annular, torque flange bolts, install koomey hoses, choke and kill hoses, check precharge koomey bottles, function test BOPE, (Good), install bell nipple air boot sleeves and inflate boots. Continue Build 3% KCL fill rig pits 360 bbls, mix 45 bbl saturated salt pilll, pump & spot out of tubing @ 5840' let soak, build secound Saturated salt pill. 37 bbls, pump & spot accross upper perfs @ 2390', monitor well 60 min. tubing & annullus on vac. build volume in rig pits, pump satruated salt pill, down IA, lost prime on pump regained pime continue pumping , IA pressured up to 500 psi, Rig up and pump down tbg at 3 bpm at 86 bbl caught pressrue 150 psi, continue pumping got commucation on IA , Return line Choke plugged, clean out same. Build 261 bbls 3% KCL , pump down tbg with 3% KCL, swapping back and forth, to IA until getting returns from IA continue pumping taking returns to cutting box getting pill and oil back, pump 55 bbls getting dirty KCL back at cutting box, monitor well, while working on RIg Activation list, waiting on salt. Build 3% KCL in pits, Displace well with 3% KCL untill clean, taking return to trading bay pump total of 374 bbls of 3% 8.6 KCL shut down pump TBG on vacuum and IA on vacuum, set BPV nipple down tree, and remove from well room, prep hanger for nipple up, nipple up Riser and DSA. Page 2 of 4 Well Name:TBF A-18 API #:50733201430000 Field:Trading Bay Field Start Date:1/26/2024 Permit #:168076 Sundry #:323-423 End Date:3/3/2024 2/21/2024 2/22/2024 2/23/2024 2/24/2024 2/25/2024 2/26/2024 Cont. RIH with c/o assy f/2007' P/U 3 1/2" wk string, t/7104', pick storm packer and continue in hole to 7,337', set storm packer 234 ft. , test packer to 600 psi, pooh with landing joints, pick up kelly, install uper kelly valve and lower kelly test same to 250 low and 2500 psi, rack back kelly, Rih with storm packer running tool, make up to packer, tbg on vacuum. open by pass, annulus on slight vacuum. release packer, fill hole with 44 bbls FIW 3% KCl ,POOH with storm packer and lay down same R/U handling Eq, continue RIH from7104' t/ tag @8575', P/U kelly, r/u kelly, install Kelly hose test, good, Wash & ream in hole t/ 9379', up wt 130k, dn wt 95k, 50 RPM, 2-6 tq, pump 4 BPM, 550psi, Daily Operations: R/U & pull hanger & packer free @130k, POOH l/d 2 7/8" completion to the packer @ 364', L/D packer, secured esp cable, m/u test plug, set test joint 2 7/8", shell tested good, Tested BOPE as per Hilcorp & AOGCC expectations, 250/2500 witness was waived by inspector Josh Hunt, had FP on choke HCR, Tested w/ 2 7/8 & 3 1/2" TJ. BOP test concluded at 06:00 on 2/22. R/D test tools, Pull test joint, m/u landing joint, pull test plug, Cut & slip drill line 270', POOH w/ESP L/D 2 7/8" EUE 8rd 6.5# completion tubing f/6301' to pump assembly Pooh, laying out ESP assembly, Rig down summit, clear and clean floor, back load boat, pick up kelly, break out uper kelly valve and send to town, rig up to pick up 3-1/2 work sting, pick up 6" bit & bit sub, trip in hole picking up 3-1/2 12.95, P110, PH 6 work string to 1,954' dpm, pick up 6.6" string mill and bumper & oil jars. Well Operations Summary Wash and ream from 9379' to 9410', with 3/5 wob, 60 rpm, 2250 ft./lbs, pumping at 4 bpm at 650 psi., circulate 2.5 bottom up until clean, pump dry job, Pooh laying down 3-1/2 drill pipe and 3-1/2 PH 6 work string, lay out string mill assembly and jars, continue to pooh lay down bit & bit sub, Rig down handling tools, clear floor, Rig up 4-1/2 test joint & plug to test top rams , fluid pack surface lines Page 3 of 4 Well Name:TBF A-18 API #:50733201430000 Field:Trading Bay Field Start Date:1/26/2024 Permit #:168076 Sundry #:323-423 End Date:3/3/2024 2/27/2024 2/28/2024 2/29/2024 3/1/2024 3/2/2024 3/3/2024 R/u SL,RIH set TTP w/memory gauge in tbg tail at 9281'rkb. RIH and confirmed sliding sleeve is in the open position. Attempted to set BAM at 2343'slm with no luck. Found FL at 2050'. Pushed fluid away with gas. RIH and set BAM at 2343'slm. POOH. L/d SL. Production flow test well and seems to be circulating gas. Continue rig stack out check list. Continue R/U & test 4 1/2" TJ on upper rams, 250/2500 good. P/U Kelly break off kelly valves & spinner, make swivel back up & rack back, Trip in hole picking up 3-1/2 EUE tbg & 4-1/2 IBT tbg spacing out GLM as per design to 3,190 ft. depth at rpt time Continue in hole picking up 4-1/2" 12.6# IBT, L-80, to 8978 ft. pick up Baker TRSSSV, make up control line, test same to 5k, function valve 2 times and , visually witness valve function, continue in hole running control line to 9290 ft. pick up hanger and make control line hanger penertration, pressure up line to 5k, land hanger with 86k down wt. Run in lock downs, and rig up to set 7-5/8 x 4-1/2 LTC Hydratrieve Packer at 2325.97, Ran a total of 46 joints of 3-1/2 9.3#, EUE 8rd, L-80 tbg, & 229 joints of 4-1/2 , 12.6# IBT TBG, spacing GLM as per design, end of mule shoe assembly at 9326.09 TRSSV AT 339.23' R/u testing eq. Winterized test eq. due to weather conditions. Pressure up on tbg to 3400psi, held for 30mins and set production packer, MIT-IA to 2750psi, charted for 30min good test. R/d test eq. L/d Landing jt. Installed BPV, N/u BOP's and Riser. N/u and orientate production tree. Tested production tree to 5000psi good test, Pulled TWC and secured well. R/u SL. PT to 250low / 2500high. PASS. Pulled Bypass Access Mandrel (BAM) blacking sub at 2338'slm. Equalized and pulled standing valve at 2350'slm. Circulated top of well with gas lift. Rig crew worked on rig stack out list. Daily Operations: Well Operations Summary R/u SL run Xline confirmed BAM was set in the correct x nipple, Pull BAM and redress packing, RIH w/BAM and set in x-nipple at 2338'slm. Production flow test well. Gas lift appears to be unloaded well correctly.RDMO SL. Rig stackout complete. Page 4 of 4 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Friday, January 5, 2024 9:51 AM To:Ryan Rupert; McLellan, Bryan J (OGC) Cc:Harold Soule - (C); Wade Hudgens; Howard Hooter - (C); Dan Marlowe; Juanita Lovett; Brooks, Phoebe L (OGC) Subject:RE: BOP for upcoming Monopod A-18 RWO (PTD#168-076) Ryan ‐ As discussed this morning, the BOPE test pressure for Trading Bay State A‐18 RWO (Sundry 323‐423) is changed to 2500psi. Please make sure a copy of this email is aƩached to the Sundry approval that will be on the Monopod plaƞorm during the workover. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Thursday, January 4, 2024 10:57 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Harold Soule ‐ (C) <hsoule@hilcorp.com>; Wade Hudgens <Wade.Hudgens@hilcorp.com>; Howard Hooter ‐ (C) <Howard.Hooter@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: BOP for upcoming Monopod A‐18 RWO (PTD#168‐076) Jim/Bryan‐ We are targeƟng execuƟon within a month for the aƩached Monopod A‐18 RWO. There’s a sƟpulaƟon in the condiƟons of approval calling for an iniƟal BOP test to rated working pressure. However, the BOP stack we plan to use is the one currently in use onshore with Rig #401. It will be the one used for our next RWO on G‐33 offshore, and then this A‐18 RWO. It’s our standard Hilcorp owned BOP and is reﬂected in the sundry BOP diagram. Given this conƟnued service, Hilcorp is requesƟng to only test the BOP’s to 2500psi per the approved sundry. Hilcorp requests that we remove the iniƟal test to rated working pressure requirement. Please let us know your thoughts. Thank you, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Harold Soule - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Juanita Lovett Subject:Hak 56, 2-22-24 Date:Friday, February 23, 2024 7:45:34 AM Attachments:Hak 56 2-22-24.xlsx Morning Mr. Regg Been awhile since I have done a rolling test but as I recall this is how we have reported in the past, let me know if I need to send separate report for rolling test. Thanks Harold Soule Cell 907-227-9400 Monopod Office 907-776-7970 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:56 DATE: 2/22/24 Rig Rep.: B Hebert/ S Wilson Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11680760 Sundry #323-423 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250-2500 Annular:250-2500 Valves:250-2500 MASP:2093 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP #1 Rams 1 2-7/8"x5-1/2" var P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 4-1/16" 5M P Time/Pressure Test Result HCR Valves 1 4-1/16" 5M FP System Pressure (psi)3000 P Kill Line Valves 3 2-4 1/16 1-4" 5k P Pressure After Closure (psi)1325 P Check Valve 0NA200 psi Attained (sec)29 P BOP Misc 0NAFull Pressure Attained (sec)171 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6@2400 P No. Valves 16 P ACC Misc 1FP Manual Chokes 2P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 17 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams NA #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:30.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/15/24 2:44 PM Waived By Test Start Date/Time:2/20/2024 12:30 (date) (time)Witness Test Finish Date/Time:2/22/2024 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Josh Hunt Hilcorp Rolling test performed as per approved procedure on 2-20-24 with 2 7/8" TJ (hanger would not hold pressure); witness waived by Jim Regg; pump rates for rolling test were 250psi - 8 GPM, 2500psi - 17 GPM. No leaks past annular, pipe rams or blind rams, no body leaks detected. Choke manifold, floor valves, gas alarms & PVT tested good. 2-21-24 19:00, after pulling & L/D packer from 364' we hung string off with test plug and performed regular BOPE test w/ 2 7/8" & 3 1/2" TJ - failure on accumulator (fitting on HCR line worked loose; bad thread, replaced both fittings); failure on choke HCR, cycled & re-test good. Test time reflects start of rolling test to finish of regular test. HAK Harold Soule/Ed Hooter Trading Bay ST A-18 Test Pressure (psi): hsoule@hilcorp.com hsoule@hilcorp.com Form 10-424 (Revised 08/2022) 2024-0222_BOP_Hilcorp56_TB_ST_A-18 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,000 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 2,570psi Production 4,790psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/15/2023 9,8262,337 2-7/8" 9,064 D&L Hydroset II-A Twin Seal Pkr & Baker TE-5 SSSV w/ BX Profile 364 (MD) 364 (TVD) & 303 (MD) 303 (TVD) Perforation Depth MD (ft): 7,520 2,390 - 9,360 7,488 7" 2,176 - 8,603 6,8307-5/8" 7,488 13-3/8" 9-5/8"7,520 1,044 MD 3,950psi 3,090psi1,028 6,860 1,044 Length Size Proposed Pools: 6.5# / L-80 TVD Burst 6,549 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 168-076 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20143-00-00 Hilcorp Alaska, LLC Trading Bay ST A-18 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: Convert ESP to GL Trading Bay Hemlock Oil, Middle Kenai B Oil, Middle Kenai C Oil, Middle Kenai D Oil, Middle Kenai E Oil Same 10,222 9,413 8,658 2093 N/A N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:43 pm, Jul 26, 2023 323-423 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.07.26 12:22:36 - 08'00' Dan Marlowe (1267) BJM 8/10/23 Initial BOP test to Rated Working Pressure. Subsequent BOP tests to 2500 psi X DSR-7/31/23 CO-2O 10-404 MDG 7/31/2023 GCW 08/10/2023JLC 8/10/2023 08/10/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.10 14:00:14 -08'00' RBDMS JSB 081123 Convert to GL RWO Well: Monopod A-18 Well Name:A-18 API Number:50-733-20143-00-00 Current Status:Failed ESP Oil Producer Leg:n/a Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:168-076 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,953 psi @ 8,603’ TVD 6.6ppg to deepest perf (2015 survey) Max. Potential Surface Pressure: 2093 psi Using 0.1 psi/ft Brief Well Summary Monopod A-18 is a multizone producer completed across 6000’+ TVD of sands. The well has been produced on ESP since 2017 until it recently died in February-2023. A deep gas lift completion is proposed to replace the ESP. The Annular Velocity Enhancement (AVE) System has been primarily used to dewater gas wells with long perforation intervals, and the need to get gas lift far below the production packer (SPE paper #130256). Monopod wells should be a great application for this technology with stacked pay sometimes exceeding 6000+’ TVD. The goal of this project is to pull the failed ESP and replace with an AVE gas lift completion for deep lift Pertinent wellbore information: - Max Inclination: 34 degrees at 3,350’ MD - March-2017: RWO to install ESP for better drawdown o Used 8.5ppg 3% KCL (no issues) o 3” SL bailer tagged at 9290’ MD (mid-Hemlock) o 6” cleanout assembly tagged at 7900’ MD and milled / washed down to 9413’ MD. o Ran ESP completion to 6665’ MD - March-2015: RWO to add B/C perfs o Used 8.5ppg 3% KCL o Tagged fill at 9350’ MD (bottom perf Hemlock) with a 6” bit. Overpulls at 9146’ and 8890’ o Added B and C sands (weighted up to 9.0ppg after shooting: Virgin offtake) o Ran GL completion with lift at 2259’ MD (2062’ TVD) - September-2013: RWO to return well to production o Used 9.5ppg 3% KCL o Cemented in 7-5/8” scab liner back to surface to remediate leak in 9-5/8”. Passed MIT o Liner cleanout had to mill from 7700 – 9500’ MD (tight spot at 8800’ MD) o Reperf’d most of Hemlock, E, and D sands (no B/C sands open at this point) o Ran GL completion with lift at 5900’ MD (5317’ TVD) - 2005: Shut in due to suspected hole in 9-5/8” casing at ~1700’ MD Convert to GL RWO Well: Monopod A-18 RWO Procedure: 1. Prepare Monopod rig #56 for RWO operations 2. Circulate well to production: a. Work over fluid will be filtered inlet water (8.4ppg) b. KCL may be added in concentrations of 1-6% which would raise the EMW slightly c. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading d. Tubing volume = 38bbls e. IA + Liner volume ~371bbls 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Ram(s) needed to handle 2-7/8”, 3-1/2”, and 4-1/2” pipe 4. BOLDS and unseat hanger 5. Shear up to release packer and POOH laying down ESP completion 6. RU SL for D&T 7. D&T well to evaluate need for cleanout 8. PU 3-1/2” workstring 9. MU 7” liner cleanout assembly 10. RIH and mill/cleanout 7” liner to target depth = 9400’ MD 11. POOH and lay down cleanout BHA and workstring 12. PU, RIH with AVE Gas Lift completion per below a. Completion to be run open ended b. Completion to be run with live GLV’s below packer and DGLV above c. Plug or B&R/Catcher to be set just below production packer once completion landed d. Bypass access mandrel (above packer) to be RIH with blanking sleeve installed e. All depths below are approximate Depth Item 300’ MD TRSSSV As needed Traditional GLM Just above packer Bypass access mandrel (blanked off) ±2,350’ MD Production packer Just below packer Sliding sleeve As needed Casing exhaust GLM’s Bottom of completion XN-profile (no plug for running) 13. Land AVE GL completion 14. Drop B&R or place plug below packer, and set production packer 15. MIT-T to 2500psi 16. MIT-IA to2500psi (charted) 17. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC, and demob RWO crew Convert to GL RWO Well: Monopod A-18 Post-Rig 1. MIRU SL and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. Pull isolation sleeve from bypass access mandrel above packer 4. Pull B&R / tubing plug 5. Drift and tag to PBTD 6. Set TTP in bottom of completion 7. Ensure SSD is open 8. Set Packer bypass downhole tool 9. RDMO SL 10. Place well on production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. Packer bypass assembly diagram (AVE) 6. BOP Drawing 7. Fluid/Flow Diagrams 8. RWO Sundry Change Form Revised By: JLL 01/23/2023 SCHEMATIC Trading Bay Unit Well: A-18 PTD: 168-076 API: 50-733-20143-00 Completed: 03/12/2017 KB ELEV = 101’ PBTD = 9,550’ TD = 11,000’ ANGLE thru INTERVAL = 24.9q RKB to TBG Hngr = 37.00’ 2 4 5 D E Hemlock 1 13-3/8” 9-5/8” 7” 3 DV Collar 5,598’ B C Top of Fill 9,413’ 3/08/17 Tbg Punch 5,840- 5,843 X CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 K-55 Seal Lock 12.515 Surf 1044’ 9-5/8” 43.5 N-80 Buttress 8.755 Surf 67’ 40 K-55 Buttress 8.835 67’ 4191’ 40 N-80 Buttress 8.835 4,191' 5,643’ 43.5 N-80 Buttress 8.755 5,643’ 7,520’ STAGE COLLAR 5,598' 5,600' 7-5/8” Liner 29.7# L-80 SLIJ-2 6.875 Surf 7,488’ 7” Liner 29 N-80 Buttress 6.184 7,489’ 9,826’ TUBING DETAIL 2-7/8” 6.5# L-80 8rd EUE 2.441 Surf 6,549’ JEWELRY DETAIL NO. MD TVD ID OD Item 39’ 39’ Seaboard Hanger 11” O.D. Body & 3-1/2” EUE 8rd Lift Thread w/ 3” H Style BPV Profile 1 303’ 303’ 2.312 4.620 Baker TE-5 Safety Valve w/BX Profile 2 364’ 364’ 2.930 6.670 D&L Hydroset II-A Twin Seal Packer w/vent valve 3 2,297’ 2095’ 2.441 4.500 GLM 4 6,473’ 5,865’ 2.313 3.668 X-Nipple 5 6,549’ 5,937’ N/A 4.000 Discharge: Bolt-on 6,550’ 5,938’ N/A 4.000 Pumps - 400 Series 125 SF1750 (2) 400 Series 076 SFGH2500 (1) 6,615’ 6,000’ N/A 4.000 Gas Separator - 400 Series UT 400X Vortex (2) 6,620’ 6,004’ N/A 4.000 Intake 6,638’ 6,021’ N/A 4.560 Motor – 456 Series FMS 180 HP/2597V/48A 6,665’ 6,047’ N/A 4.560 Centralizer/Anode PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD)Btm (TVD) Amt. SPF Last Date Status B 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open B 26-7 2,567' 2,700' 2,331' 2,448' 133' 5 03/19/15 Open BZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open Hemlock 6,010’ 6,150’ 5,423’ 5,557’ 140’ 9/13/2013 Open D 54-9 7,320’ 7,436’ 6,669’ 6,780’ 116’ 9/13/2013 Open D 55-7 7,450’ 7,533’ 6,794’ 6,873’ 83’ 9/13/2013 Open D 55-7 7,544’ 7,570’ 6,883’ 6,908’ 26’ 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790’ 7,870’ 7,113’ 7,187’ 80’ 9/13/2013 Open D 56-1 7,904’ 8,030’ 7,218’ 7,333’ 126’ 9/13/2013 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104’ 8,158’ 7,400’ 7,449’ 54’ 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425’ 8,555’ 7,696’ 7,819’ 130’ 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610’ 8,650’ 7,872’ 7,910’ 40’ 9/13/2013 Open E 58-1 8,660’ 8,675’ 7,920’ 7,934’ 15’ 9/13/2013 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open E 60-0 8,916’ 8,965’ 8,167’ 8,215’ 49’ 9/13/2013 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 9,074’ 9,120’ 8,322’ 8,367’ 46’ 9/13/2013 Open E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210’ 9,290’ 8,455’ 8,534’ 80’ 9/13/2013 Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open Hemlock 9,330’ 9,360’ 8,574’ 8,603’ 30’ 9/13/2013 Open Revised By: JLL 07/25/23 PROPOSED SCHEMATIC Trading Bay Unit Well: A-18 PTD: 168-076 API: 50-733-20143-00 Completed: Future KB ELEV = 101’ PBTD = 9,550’ TD = 11,000’ ANGLE thru INTERVAL = 24.9q RKB to TBG Hngr = 37.00’ 5 3 5 D E Hemlock 4 8” ” 7” 2 6 1 DV Collar 5,598’ 7 B C D XN CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 K-55 Seal Lock 12.515 Surf 1044’ 9-5/8” 43.5 N-80 Buttress 8.755 Surf 67’ 40 K-55 Buttress 8.835 67’ 4191’ 40 N-80 Buttress 8.835 4,191' 5,643’ 43.5 N-80 Buttress 8.755 5,643’ 7,520’ STAGE COLLAR 5,598' 5,600' 7-5/8” Scab 29.7# L-80 SLIJ-2 6.875 Surf 7,488’ 7” Liner 29 N-80 Buttress 6.184 7,489’ 9,826’ TUBING DETAIL 4-1/2” 3.958 “ Surf ±8,000’ 3-1/2” 2.995” ±8,000’ ±9,200’ JEWELRY DETAIL NO. MD TVD ID OD Item 1 ±300’ ±300’ TRSSSV 2 ±2,340’ ±2,132’ Bypass access mandrel: WL Crossover assembly installed 3 ±2,350’ ±2,141’ Production Packer 4 ±2,360 ±2,150’ Sliding sleeve 5 ±2,365’ ±2,154’ Seal bore 6 ±8,000’ ±7,306’ 4-1/2 x 3-1/2” Crossover 7 ±9,200’ ±8,445’ 3-1/2” XN-profile with plug installed PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD)Btm (TVD) Amt. SPF Last Date Status B 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open B 26-7 2,567' 2,700' 2,331' 2,448' 133' 5 03/19/15 Open BZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open Hemlock 6,010’ 6,150’ 5,423’ 5,557’ 140’ 9/13/2013 Open D 54-9 7,320’ 7,436’ 6,669’ 6,780’ 116’ 9/13/2013 Open D 55-7 7,450’ 7,533’ 6,794’ 6,873’ 83’ 9/13/2013 Open D 55-7 7,544’ 7,570’ 6,883’ 6,908’ 26’ 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790’ 7,870’ 7,113’ 7,187’ 80’ 9/13/2013 Open D 56-1 7,904’ 8,030’ 7,218’ 7,333’ 126’ 9/13/2013 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104’ 8,158’ 7,400’ 7,449’ 54’ 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425’ 8,555’ 7,696’ 7,819’ 130’ 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610’ 8,650’ 7,872’ 7,910’ 40’ 9/13/2013 Open E 58-1 8,660’ 8,675’ 7,920’ 7,934’ 15’ 9/13/2013 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open E 60-0 8,916’ 8,965’ 8,167’ 8,215’ 49’ 9/13/2013 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 9,074’ 9,120’ 8,322’ 8,367’ 46’ 9/13/2013 Open E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210’ 9,290’ 8,455’ 8,534’ 80’ 9/13/2013 Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open Hemlock 9,330’ 9,360’ 8,574’ 8,603’ 30’ 9/13/2013 Open GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date TBD TBD GLM TBD TBD Casing Exhaust GLM Monopod Platform A-18 Current 03/21/2016 Monopod Platform A-18 Proposed 07/19/2023 Casing head, Shaffer KD, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2'’ LPO, Tubing head, S-8, 11 5M x 11 5M, w/ 2- 2 1/16 5M SSO, w/ BG bottom w/ 2- 2 1/16 5M WKM-M valves Monopod Platform A-18 13 3/8 X 9 5/8 X 7 5/8 X 4 1/2 Casing spool, S-8, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, w/ BG bottom w/ 2- 2 1/16 5M WKM-M valve Tubing hanger, SME-CL, 11 X 4 ½ EUE lift and susp, w/ 4'’ Type H BPV profile, 2- 3/8 CCL, Alloy material Valve, Double master and swab, CIW-FLS, 4 1/16 5M FE, HWO, EE trim BHTA, Bowen, 4 1/16 5M FE x 7'’ Bowen quick union top Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Adapter, Cactus-EN-6.25'’, 11 5M stdd x 4 1/16 5M stdd top, w/ 2- 1'’npt control line exits 13 3/8'’ 9 5/8'’ 7 5/8'’ 4 ½’’ Monopod Platform 2018 BOP Stack Hi l c o r p M o n o p o d R i g 5 6 Fl o w D i a g r a m LE G E N D : Fl u i d s P u m p e d F l u i d s R e t u r n e d Va l v e O p e n V a l v e C l o s e d Ga t e V a l v e B a l l V a l v e Bu t t e r f l y V a l v e L o T o r q V a l v e Au t o m a t i c C h o k e M a n u a l C h o k e Pr e s s u r e G a u g e K n i f e V a l v e MU D P U M P 4.3 0 ' PI T S Y S T E M CH O K E M A N I F O L D Ch o k e L i n e Pa n i c L i n e C1 2 C1 3 C1 5 C1 4 C1 6 A B C4 C5 C6 C7 C2 C1 0 C9 C1 1 C8 C3 P HC R 1 Op e n Cl o s e d Clo s e d Op e n Op e n Op e n Op e n An n u l a r VB R BL I N D Su c Ɵon MU D P U M P SHAKER SHAKER Ki l l L i n e Tr i p T a n k P P C1 C GA S B U S T E R HC R 2 4” De m c o ki l l l i n e Fl o w l i n e P P Hi l c o r p M o n o p o d R i g 5 6 Fl o w D i a g r a m Re v e r s e C i r c u l a t i n g 4” De m c o ki l l l i n e LE G E N D : Fl u i d s P u m p e d F l u i d s R e t u r n e d Va l v e O p e n V a l v e C l o s e d Ga t e V a l v e B a l l V a l v e Bu t t e r f l y V a l v e L o T o r q V a l v e Au t o m a t i c C h o k e M a n u a l C h o k e Pr e s s u r e G a u g e K n i f e V a l v e MU D P U M P 4.3 0 ' PI T S Y S T E M CH O K E M A N I F O L D Ch o k e L i n e Pa n i c L i n e C1 2 C1 3 C1 5 C1 4 C1 6 A B C4 C5 C6 C7 C2 C1 0 C9 C1 1 C8 C3 P HC R 1 Op e n Cl o s e d Op e n Op e n Op e n Op e n Cl o s e d An n u l a r VB R BL I N D Su c Ɵon MU D P U M P SHAKER SHAKER Ki l l L i n e Tr i p T a n k P P C1 C GA S B U S T E R HC R 2 Fl o w l i n e P P 4 11 C To G a s Bu s t e r Wh i t e N o r m a l l y O p e n 3- 6 - 7 - 1 5 Bl a c k N o r m a l l y C l o s e d 1- 2 - 4 - 5 - 8 - 9 - 1 0 11 - 1 2 - 1 3 - 1 4 - 1 6 Fr o m BO P 14 13 10 12 3 2 8 1 B 5 6 7 A 9 16 15 D ToPanic Lin e To Sending Unit Monopod Rig 51 Choke Manifo ld It e m 3 & 5 4, 1 3 , 1 5 , 1 6 1- 2 , 6 - 1 2 , 1 4 A B- C D Ğ Ɛ Đ ƌ ŝ Ɖ Ɵ Ž Ŷ 3 1 / 8 5 M V e t c o 2 2 0 0 T G a t e V a l v e 4 1 / 1 6 5 M C a m e r o n G a t e V a l v e 3 1 / 8 5 M C a m e r o n G a t e V a l v e Sw a c o 2 9 / 1 6 1 0 M S u p e r C h o k e 3 1 / 8 5 M C a m e r o n H 2 M a n u a l C h o k e 3 1 / 8 5 M C a m e r o n H 2 P o s i Ɵve C h o k e In s t a l l 4 1 / 1 6 5 M A P I in s t r u m e n t Ňan g e b e l o w pa n i c l i n e w / ½ n p t d r a i n po r t s Mo n p o p o d V a l v e Al i g n m e n t – Lo n g W a y Va l v e Po s i Ɵon ( O - Op e n / C - Cl o s e d Mo n p o p o d V a l v e A l i g n m e n t – Re v e r s e Va l v e P o s i Ɵon ( O - Op e n / C - C l o s e d An n u l a r O A n n u l a r C VB R O V B R O Bl i n d O B l i n d O C1 C C 1 C C2 C C 2 C C3 O C 3 O C4 C C 4 C C5 C C 5 C C6 O C 6 O C7 O C 7 O C8 C C 8 C C9 C C 9 C C1 0 C C 1 0 C C1 1 C C 1 1 C C1 2 C C 1 2 C C1 3 C C 1 3 C C1 4 C C 1 4 C C1 5 O C 1 5 O C1 6 C C 1 6 C HC R 1 C H C R 1 C Wi n g 1 ( W 1 ) O W i n g 1 ( W 1 ) O HC R 2 C H C R 2 C Wi n g 2 ( W 2 ) O W i n g 2 ( W 2 ) O De m c o 4 ” K i l l L i n e C D e m c o 4 ” K i l l L i n e O Sta n d P i p e V a l v e ( S P 1 ) O S t a n d P i p e V a l v e ( S P 1 ) C Ce m e n t L i n e ( C L 1 ) C C e m e n t L i n e ( C L 1 ) C Tr i p T a n k 1 ( T T 1 ) C T r i p T a n k 1 ( T T 1 ) C Re v e r s e L i n e ( R V 1 ) C R e v e r s e L i n e ( R V 1 ) O Mu d P u m p 1 ( M P 1 ) O M u d P u m p 1 ( M P 1 ) O Mu d P u m p 2 ( M P 2 ) O M u d P u m p 2 ( M P 2 ) O Mu d P u m p 3 ( M P 3 ) O M u d P u m p 3 ( M P 3 ) O Mu d P u m p 4 ( M P 4 ) O M u d P u m p 4 ( M P 4 ) O Pit O u t l e t 1 ( P O 1 ) O P i t O u t l e t 1 ( P O 1 ) O Pit O u t l e t 2 ( P O 2 ) C P i t O u t l e t 2 ( P O 2 ) C Pit O u t l e t 3 ( P O 3 ) C P i t O u t l e t 3 ( P O 3 ) C MP 3 SP 1 PO 3 PO 2 MP 4 MP 1 MP 2 MP 3 MP 4 MP 1 MP 2 W2 W 1 W2 CE M E N T LI N E W1 TT 1 TT 1 RV 1 RV 1 CL 1 PO 1 PO 3 PO 2 PO 1 H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l : T r a d i n g B a y S t A - 1 8 ( P T D 1 6 8 - 0 7 6 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a te d t o t h e AO G C C b y t h e r i g w o r k o v e r ( R W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . Se c P a g e D a t e P r o c e d u r e C h a n g e N e w 4 0 3 Re q u i r e d ? Y / N HA K Pr e p a r e d By (I n i t i a l s ) HA K Ap p r o v e d By (I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Juanita Lovett; Dan Marlowe Subject:RE: [EXTERNAL] TBU St A-18 (PTD 168-076) AVE GL completion Date:Thursday, August 10, 2023 8:45:08 AM No check valve there, but all GLV’s are traditional ones with check valves, so wellbore fluids are isolated from the injection tubing below the packer, and isolated from the production casing above the packer. The envelope is maintained by GLV’s, in the same way as a traditional completion would be. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 8, 2023 12:08 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] TBU St A-18 (PTD 168-076) AVE GL completion Ryan, In the proposed AVE GL completion for this well, is there a check valve in the assembly where gas enters the tubing from the Inner annulus, similar to a screened orifice in a normal GL valve? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU C-07 50029212660000 185002 1/20/2023 AK E-LINE Perf Paxton 6 50133207070000 222054 1/24/2023 AK E-LINE Perf TBF A-07 50733200360000 167046 1/13/2023 AK E-LINE CBL TBF A-18 50733201430000 168076 1/22/2023 AK E-LINE Tubing Punch TBU D-09RD 50733201310100 181080 1/18/2023 AK E-LINE LDL Please include current contact information if different from above. By Meredith Guhl at 11:24 am, Feb 06, 2023 T37486 T37487 T37488 T37489 T37490 TBF A-18 50733201430000 168076 1/22/2023 AK E-LINE Tubing Punch Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.02.06 11:33:21 -09'00' STATE OF ALASKA *KA OIL AND GAS CONSERVATION COIVOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing 3 Operations shutdown ❑ Performed: Suspend 0 Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other:Combo Gas Lift/ESP Comoletion9 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development I] Exploratory❑ 168-076 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphicEl Service 0 6.API Number: Anchorage,AK 99503 50-733-20143-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai B,C,D&E Oil&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,000 feet Plugs measured N/A ilp,CEI'I E D true vertical 10,241 feet Junk measured N/A fee L� rI Effective Depth measured MA 2 2 2017 p 9,413 feet Packer measured 364 feet true vertical 8,656 feet true vertical 364 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 1,044' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,520' 9-5/8" 7,520' 6,860' 3,950 psi 2,570 psi Intermediate Production 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,337' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation depth Measured depth 2,390-9,360 feet True Vertical depth 2,176-8,603 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 6,549'(MD) 5,937'(TVD) Packers and SSSV(type,measured and true vertical depth) D&L Hydroset II-A 364'(MD) Baker TE-5 Safety 303'(MD) Twin Seal Pkr 364'(TVD) Valve w/BX Profile 303'(TVD) wNent Valve 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/ASCANNED 1 i L'' .z i 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: 71 290 0 790 96 Subsequent to operation: 132 245 300 90 85 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratlgraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil (J Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-636 / Contact Dan Marlowe(907)283-1329 Email dmarlowehilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature yJ. eft Phone (907)777-8356 Date 3''tis,11 Form 10-404 Revised 5/2015 3—�is—17 RBDIVIS ,i,v MAR 2 2 2017 Submit Original Only Trading BUnit II • SCHEMATIC • Well:A-18ay PTD: 168-076 API:50-733-20143-00 Hilcorp Alaska,LI,C Completed:03/12/2017 CASING DETAIL Size Wt Grade Conn ID Top Btm RKB to TBG Hngr= 37.00' 13-3/8" 61 K-55 Seal Lock 12.515 Surf 1044' 43.5 N-80 Buttress 8.755 Surf 67' ". III - 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 40 N-80 Buttress 8.835 4,191' 5,643' Iv 1 r\ 43.5 N-80 Buttress 8.755 5,643' 7,520' 2 STAGE COLLAR 5,598' 5,600' 7-5/8"Liner 29.7# L-80 SLIJ-2 6.875 Surf 7,488' 13-3/8^ 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL 2-7/8" I 6.5# I L-80 I 8rd EUE I 2.441 I Surf I 6,549' JEWELRY DETAIL NO. MD ND ID OD Item 39' 39' Seaboard Hanger 11"0.0.Body&3-1/2"EUE 8rd Lift Thread w/ 3"H Style BPV Profile 1 303' 303' 2.312 4.620 Baker TE-5 Safety Valve w/BX Profile 2 364' 364' 2.930 6.670 D&L Hydroset II-A Twin Seal Packer w/vent valve 3 2,297' 2095' 2.441 4.500 GLM 4 6,473' 5,865' 2.313 3.668 X-Nipple 6,549' 5,937' N/A 4.000 Discharge:Bolt-on 6,550' 5,938' N/A 4.000 Pumps-400 Series 125 SF1750(2)400 Series 076 SFGH2500(1) 6,615' 6,000' N/A 4.000 Gas Separator-400 Series UT 400X Vortex(2) 5 6,620' 6,004' N/A 4.000 Intake 6,638' 6,021' N/A 4.560 Motor-456 Series FMS 180 HP/2597V/48A 6,665' 6,047 N/A 4.560 Centralizer/Anode ,, a r PERFORATION DETAIL B Zone Top(MD) (MD) (ND)Top Btm(ND) Amt. SPF Last Date Status ;-DV Collar 1324-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open 5,598' B 26-7 2,567' 2,700' 2,331' 2,448' 133' 5 03/19/15 Open BZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open X a C B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open " C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open 5 C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open 9.5/$.. C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open = = C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open g► D C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open A _ll Hemlock 6,010' 6,150' 5,423' 5,557' 140' 9/13/2013 Open D 54-9 7,320' 7,436' 6,669' 6,780' 116' 9/13/2013 Open D 55-7 7,450' 7,533' 6,794' 6,873' 83' 9/13/2013 Open D 55-7 7,544' 7,570' 6,883' 6,908' 26' 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open - D 56-1 7,790' 7,870' 7,113' 7,187' 80' 9/13/2013 Open E D 56-1 7,904' 8,030' 7,218' 7,333' 126' 9/13/2013 Open = D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open --..= D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104' 8,158' 7,400' 7,449' 54' 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 9/13/2013 Open E 58-1 8,660' 8,675' 7,920' 7,934' 15' 9/13/2013 Open Hemlock E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open Top of FM 9,413' _ E 60-0 8,916' 8,965' 8,167' 8,215' 49' 9/13/2013 Open 3/08/17 - E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open % /6! E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 9,074' 9,120' 8,322' 8,367' 46' 9/13/2013 Open KB ELEV=101' E61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open PBTD=9,550' TD= 11,000' Hemlock 9,210' 9,290' 8,455' 8,534' 80' 9/13/2013 Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open ANGLE thru INTERVAL=24.9° Hemlock 9,330' 9,360' 8,574' 8,603' 30' 9/13/2013 Open Revised By:JLL 03/20/17 M ! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-18 Monopod Rig 56 50-733-20143-00 168-076 3/4/17 3/12/17 Daily Operations: 03/04/17-Saturday Skidded over A-18 well. Installed seismic clamps then installed handrails, walkways, beaver slide, flow lines, gas buster and circ lines. Laid down 13 5/8" riser in order to R/U S/L. Welder repositioned/repaired hand rail beside beaver slide. Moved slickline lubricator to beaver slide and positioned wireline unit. Production began bleeding 800 PSI off annulus, 90 PSI on tb. R/U S/L. M/U Run #1: 2 7/8" Daniels kick-over tool, 1 1/2" spang& oil jars, knuckle, 10' of 1 1/2" stem, RS- pulled inside lubricator and tested to 2000 PSI. hrs)well Opened p (2345 TIH to 2,259' andulled valve, Pparaffin OOH. Heavy y pa affin on tool string. R/D S/L. Mixed 150 bbls of 3% KCL to top of active while prepping tree to circulate and kill well. Bled annulus down from 200 PSI to 45 PSI. Pumped 200 bbls 3% KCL at 4 BPM 0 PSI w/ monitored returns going to flare (casing pressure dropped from 45 PSI to 0 PSI). Shutdown pump, casing dead, tb on vacuum. Shut-in well while building 40 bbl sized salt pill. 03/05/17-Sunday Finished building salt pill. Pumped pill 2 BPM 0 PSI (LW) w/returns lined up to production, no returns. Shut down pump, tb on vacuum. R/D hose and NOS rep set BPV. B/0 hardware from tree then N/D tree. Cleaned up hanger top and lift threads then installed blanking sub. Pulled tree and lowered 13 5/8" x 11" 5m riser. N/U BOPE. Checked koomey nitrogen precharge. Cleared and cleaned rig floor. Began bleeding 185 PSI casing pressure down thru flare. M/U 3 1/2" 8rd test jt w/ pumpin, SV, IBOP on top, LH release ported sub on btm. Screwed into blanking sub and filled test jt, stack and choke manifold. Pretested BOPE. Tied pump into annulus (0 PSI on annulus), used charge pump to push 100 bbls 3% KCL @ 4 BPM-shutdown charge pump.Tied annulus back into production-50 PSI on annulus- bled pressure down to zero thru flare and shutin annulus. Monitored pressure every hr. Rig crew cont. w/housekeeping and organizing.Annulus pressure 16 PSI after 6 hrs. Began building salt pill. 0530 hrs annulus pressure at 46 PSI- bled pressure down to 26 PSI and lined up to pump KCL down annulus. • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-18 Monopod Rig 56 50-733-20143-00 168-076 3/4/17 3/12/17 Daily Operations: 03/06/17- Monday Finished building 40 bbl salt pill. Pumped 50 bbls of 3% KCL down annulus w/charge pump- bled off 70 PSI pressure-setup to gravity feed KCL down annulus. Tested BOPE w/2 7/8 & 3 1/2"T.I to 250 PSI low 2500 PSI high as per Hilcorp and AOGCC requirements. Had FP while testing with 2 7/8"Ti on annular& rams, functioned both & re-test good. Performed successful koomey draw-down test. Witnessed by Brian Bixby& Lou Laubenstein/AOGCC. Pulled test jt & blanking sub. Pumped 57 bbls down annulus w/charge pump. Screwed into hanger and R/U hose- pumped 110 bbls down tubing @ 2 BPM w/ returns going to well clean tank, initial pressure was 285 PSI, 5 mins in pressured dropped to 45 PSI getting gas &fluid returns- monitored well. Pumped 124 bbls down tb @ 2 BPM 45 PSI w/returns going to well clean tank (40 PSI on casing). Shutdown pump- both sides on vacuum. NOS rep pulled BPV. M/U landing jt w/safety valve and pumpin-screwed into hanger and pulled pkr free at 18k over- hanging weight is 27k. Pumped 115 bbls down tb @ 2 BPM 150 PSI (45 PSI on annulus) taking returns to well clean tank. Shut down pump and lined up to fill hole w/charge pump taking returns over shaker- initial fluid losses are 23 bph. Pulled hanger to surface and NOS rep worked hanger. B/O L/D hanger and landing jt. POOH w/recovered 2 7/8" production string laying singles in flying pipe rack. Recovered 72 jts 2 7/8"tubing, WLEG,X- nipple, 7 5/8" Packer, Chem inj Mandrel, GLM, SSSV, 38 cannon clamps. Cleared and cleaned rig floor and beaver slide. Moved flying pipe rack to M/V and positioned slickline unit. 03/07/17-Tuesday R/U Pollard slickline and TIH w/3" bailer, tagged at 9,287'. POOH. R/D slickline. M/U BHA#1: 6" x 1 5/8" Varel rock bit, 2- 5" x 1 1/2" boot baskets,4 11/16" x 2 1/16" bit sub w/float,4 3/4" x 2 1/4" NOV oil & bumper jars, 5-4 3/4" x 2 1/4" spiral DCs, 4 3/4" x 2 1/4"Accjar, 5" x 2 11/16" x-o sub= 202.99'.TIH w/BHA on 3 1/2" 12.95# P-110 PH-6 workstring filling pipe every 20 stands to 6,897' (72 stands out of derrick). Ran in PH-6 singles off deck strapping, drifting and torqueing to 7500 FPT to tag at 7,922'. Worked pipe to pull free, unable to circulate, started OOH wet. Laid 5-singles down and attempted to break circulation (7,766'), unable to circulate, pulled 7-stands (pipe started pulling dry). Pumped 60 bbls @ 2 BPM 185 PSI (7,114')then tripped back in to 7,766'. Circulated 450 bbls @ 5 BPM 750 PSI.Attempted to test Kelly valves but failed. R/U hose to continue circ while waiting on M/V w/3 1/2" DP and replacement valve. Received valve and DP- broke off valve from Kelly and M/U new valve. Tested upper& lower Kelly valves to 250 PSI low 2500 PSI high as per Hilcorp and AOGCC requirements. M/U Kelly in string and began washing/reaming from 7,766'to 7,929' (at report time). Fluid losses at report time = 5 BPH. 03/08/17-Wednesday Continued washing down (reaming when necessary) w/6" Varel rock bit (BHA#1)from 7,929' picking up 3 1/2" IF DP off deck, running in w/ Kelly. Washed/reamed to 9,413' (called deep enough). 1900 hrs pumped friction reducer. Circulated 1 1/2 hole volumes (600 bbls) @ 6 BPM 1250 PSI while working pipe - returns clean. P/U 135k S/O 110k RotW 120k. Presently 14 BPH fluid losses. B/O Kelly and blew down circ system -set back same. POOH. Stood back 5-stands of 3 1/2" IF DP- laid down 36 DP singles to 7,766'. Laid down 9 singles of PH-6 tb to 7,482'. M/U hose and circ 1 1/2 hole volumes (450 bbls) @ 5 BPM 800 PSI- returns clean. Gather tools and equipment necessary to slip &cut drill line. Slipped and cut 165' of drill line. Present fluid loss is 12 BPH. • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-18 Monopod Rig 56 50-733-20143-00 168-076 3/4/17 3/12/17 Daily Operations: 03/09/17-Thursday Continued POOH from 7,482'to BHA. B/D BHA(using steam cleaner to flush friction reducer from tools). Laid down all DCs, jars and boot baskets. M/U scraper for 7 5/8" casing and TIH to 470'-circ clean. P/U Kelly and changed out lower Kelly valve-set back Kelly. POOH laying down 3 1/2" DP- B/O scraper& bit sub. Cleared and cleaned rig floor while off-loading pipe and equipment onto M/V. Positioned Summit equipment on pipe deck and rig floor. Held PJSM w/Summit,Tripoint, rig & crane crews, WSM & Mr. Kozub. P/U motor w/gauge- M/U centralizer/anode on btm-serviced motor. M/U upper& lower tandem sections, 1st pump w/intake & 2-gas separators and 2nd pump. Pulled out to top of motor. Hung Summit sheaves for power cable and flat pack. Made flat pack and power cable connections (checking continuity)- lower assy in hole clamping and servicing as needed. M/U 3rd pump and handling jt w/discharge and ported pressure sub. Plumbed control line into ported pressure sub- installed splice clamp at splice on 1st jt of tb. R/U air slips& McCoy tongs. M/U single #2 then M/U 'X' nipple w/pups. Summit checked continuity. CIH-234' at report time. Fluid losses currently= 10 BPH. 03/10/17- Friday Continued in hole w/ESP/SPM assy picking upIT2 7/8" 6.5# L-80 tb from 234'.. Summit checked continuity every 1000' and installed clamps as needed. Installed GLM w/pups on top of single#131 (4,387'). CIH to 6,290'. M/U Tripoint 7 5/8" (6.670") DLESP hyd set retv pkr. Plumbed flat pack control lines and power cable thru pkr. Hooked up vent valve and functioned/tested same. Checked continuity on power cable. Ran in 1-single then M/U SSSV-functioned/tested same- locked open valve w/5000 PSI.TIH w/ last 8-jts of production string. M/U hanger and landing jt- began plumbed all control lines and power cable thru hanger. Present fluid losses= 10 BPH. 03/11/17-Saturday Finished plumbing all control lines and power cable thru hanger-checking function and continuity as applicable. P/U 69k S/0 56k-eased down and landed hanger. Tripoint dropped prong and let fall to seat while filling tb. R/U test pump once tubing was full and pressured up to 3800 PSI- held pressure on chart for 30 mins- released pressure. R/D hose from tubing v and R/U hose on annulus-filled annulus and pressured up to 1700 PSIheld on chart for 30mills plus-good test- released pressure. R/U Pollard slickline w/full lubricator-tested same. Made two runs in well retrieving prong and plug. R/D slickline. B/O landing jt- installed BPV. M/U ported sub on landing jt and screwed back into hanger-flushed stack, choke and circ system w/ Baraclean-followed by clean hot water- blowed down system. L/D jt. Clean & N/D BOPE individually for transport to Dolly Platform. NOS rep prepped tb hanger and spool before lowering tree into well bay. 0515 hr lowered tree onto tb head. Began N/U. 03/12/17-Sunday Began installing valves and flow lines on tree- production connected all control lines and power cable. NOS rep tested hanger void to 500 PSI f/5 mins 5000 PSI f/ 15 mins. Began breaking down rig- removed trolley cranes from cellar,stripped mud pump#1, began cleaning shakers, offloading equipment to M/V. Finished w/valves&flow lines on tree- pulled BPV and set 2-way check- shell tested tree to 5000 PSI f/ 15 mins- pulled 2-way check and turned well over to production. • • SOF Tit \ 1 yy.,& THE STATE Alaska Oil and Gas of® TT ®® si(A. Conservation Commission _` 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 L S Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager ,4 i Hilcorp Alaska, LLC SA*1E 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, D, E Hemlock Oil Pools, Trading Bay St. A-18 Permit to Drill Number: 168-076 Sundry Number: 316-636 Dear Mr. Golis: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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 P. oerster Chair DATED this lday of December, 2016. RDDMSL -J , L51017 • • gECEIVED STATE OF ALASKA 6 ALASKA OIL AND GAS CONSERVATION COMMISSION 375DECE 2 2211 /1(11 1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Combo Gas LIN ESP 0' Completion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 ' 168-076 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 0 No 0 Trading Bay St A-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 ' Trading Bay Field/Middle Kenai B,C,D&E Oil&Hemlock Oil Pods 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 11,000 ' 10,241 . 9,550 • 8,791 865 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,489' 9-5/8" 7,520' 6,860' 3,950 psi 2,570 psi Intermediate Production 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,337' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2,390-9,360 ' 2,176-8,603 2-7/8" 6.5#/L-80 2,372 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hyd Ret Packer&SSSV 2,297'(MD)2,095'(TVD)&331'(MD)331'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch I] Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/15/2017 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name Stan W.Golis ,Q Title Operations Manager Signature D U Phone (907)777-8356 Date 12'"(w I Z. t I. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \ _ (I 3 Liz Plug Integrity ❑ BOP Test 67 Mechanical Integrity Test ❑ Location Clearance ❑ � Other: y Z 50o fel s c.; 80 IN\SF ILI ll II L Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /o.a 410I-I RBEN S LL— JAM 252617 APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: /2 - 3 6 /A i1 /Xi ic. e- )_ / I L i -` Submit Form and Form 10-403 Revised 11/2015 OPRolt . ili�A 'OrJIA lid for 12 months from t �e�ap rov I Attachments in Duplicate • • Well Work Prognosis Well: A-18 Hilrnrp Alaska,LEA, Date: 12/21/2016 Well Name: Monopod A-18 API Number: 50-733-20143-00 Current Status: Oil Producer(Gas Lifted) Leg: N/A Estimated Start Date: February 15, 2017 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 168-076 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 1,083 psi @ 2,176'TVD 0.498 psi/ft(9.57 ppg)6/7/10 SIBHP Maximum Expected BHP: 1,083 psi @ 2,176'TVD 0.498 psi/ft(9.57 ppg)6/7/10 SIBHP Maximum Potential Surface Pressure: 865 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The A-18 well was last worked over in 2015 completed in the B, C, D, E and Hemlock as a gas lifted producer. This procedure will replace the existing completion with a combo Gas Lift/ESP completion to increase drawdown. / Last Casing Test: 03/21/2015 at 2,297' 1,500 psig for 30 minutes on chart Procedure: 1. MIRU Monopod Platform Rig#56. 2. Pull Gas Lift valve and circulate hydrocarbon off of well through open pocket. 3. Work over fluid is FIW&salt as needed to balance well, BOP's will be closed as needed to circulate the well. 4. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test): 5. Monitor well to ensure it is static. 6. POOH and recover tubing and packer. 7. PU and RIH w/cleanout assembly to±9,450'. POOH. 8. PU and RIH with new completion consisting of the ESP, Packer,Gas Lift Mandrel, Packer Vent Valve, SSSV. 9. Set Packer at±350'. Pressure test to 1,500 psi and chart for 30 minutes. �"`— 10. ND BOP, NU wellhead and test. '.�• 11. Turn well over to production. 12. Conduct SVS per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form raaing isay unit • • • :Pi ell:A-18 • 11 SCHEMATIC D:168076 I:50-733-20143-00 Hilcoru Alaska,LLC Completed:03/22/15 RKB to TBG Hngr= 37.00' CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 _ Seal Lock 12.515 38' 1044' J ,,,,„ 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' J 4 9-5/8" 40 K-55 Buttress 8.835 6T 4191' „, } 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' w 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' = 1 13-3/8" STAGE COLLAR 5,598' 5,600' - t�‘+"t L ne$ 29.78 L-80 SLIJ-2 6.875 Surf 7,488' i f x 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' i, TUBING DETAIL ,, 2-7/8" I 6.58 I L-80 I 8rd EUE I 2.441 I Surf I 2,372' JEWELRY DETAIL NO. Depth (TVD) ID OD Item 37.0' Tubing Hanger d 1 331' 331' 2.441" 4.313" SSSV " A'4 2 2,259' 2,062' 2.441" 4.500" Orifice-1/GLM A 2 M u 4 3 2,278' 2,079' 2.441" 4.500" Chemical Injection Mandrel x '1' 3 r 4 2,297' 2,095' 2.441" 6.700" Hydraulic Retrievable Packer 4 5 2,341' 2,135' 2.313" 3.668" X Nipple A ' 6 2,372' 2,160' 2.500" 3.700" WLEG LA f I 5 armor 7 6 PERFORATION DETAIL a B Zone Top(MD) (MD) (ND)Top Btm(ND) Amt. SPF Last Date Status ',ADV Collar B 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open EV5,598' B 26-7 2,567' 2,700' 2,331' 2,448' 133' 5 03/19/15 Open EEBZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open 1 B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open til C B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open L,: 6 B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open CC-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open ,,nye C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open �, y %-= 9-5/8" C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open /j ,•( = C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open /1 o C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open ', C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open D . C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open / 4-2.4D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open ct±',l' - Hemlock 6,010' 6,150' 5,423' 5,557' 140' 9/13/2013 Open = D 54-9 7,320' 7,436' 6,669' 6,780' 116' 9/13/2013 Open = D 55-7 7,450' 7,533' 6,794' 6,873' 83' 9/13/2013 Open D 55-7 7,544' 7,570' 6,883' 6,908' 26' 9/13/2013 Open -1.7. D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open = D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790' 7,870' 7,113' 7,187' 80' 9/13/2013 Open E D 56-1 7,904' 8,030' 7,218' 7,333' 126' 9/13/2013 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open i_ D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104' 8,158' 7,400' 7,449' 54' 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 9/13/2013 Open Hemlock E58-1 8,660' 8,675' 7,920' 7,934' 15' 9/13/2013 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open Top of Fill 9,457' -.- -=-=_ E 60-0 8,916' 8,965' 8,167' 8,215' 49' 9/13/2013 Open 3/17/15 E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open 9' A 7 E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 9,074' 9,120' 8,322' 8,367' 46' 9/13/2013 Open KB ELEV=101' E61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open PBTD=9,550' TD= 11,000' Hemlock 9,210' 9,290' 8,455' 8,534' 80' 9/13/2013 Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open ANGLE thru INTERVAL=24.9° Hemlock 9,330' 9,360' 8,574' 8,603' 30' 9/13/2013 Open Revised By:JLL 04/21/15 • Trading Bay Unit Well:A-18 PROPOSED PTD: 168076 API:50-733-20143-00 Hilcorp Alaska,LLC Completed: FUTURE RKB to TBG Hngr= 37.00' CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 3 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' y' S 5' 9-5/8" 40 K-55 Buttress 8.835 6T 4191' IIIM 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 2 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' ¢' 13-3/8" STAGE COLLAR 5,598' 5,600' 7-5/8" 29.78 L-80 SLIJ-2 6.875 Surf 7,488' �/r/ i, Liner x7(" f 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL 2-7/8" I 6.58 I L-80 I 8rd EUE I 2.441 I Surf I ±6,375' til JEWELRY DETAIL NO. MD ND ID OD Item 37.0' . Tubing Hanger 1 ±300' ±300' SSSV °s 2 ±350' ±350' Packer w/Vent Valve 3 ±2,260' ±2,063' 2.441" , Orifice-1/GLM " 4 ±6,300' ±5,701' X-Nipple "y a 5 ±6,500' ±5,891' Bottom of ESP A C �t,L PERFORATION DETAIL Btm Top a ' Zone Top(MD) (MD) (TVD) Btm(TVD) Amt. SPF Last Date Status k. - B B 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open " B 26-7 2,567' 2,700' _ 2,331' 2,448' 133' 5 03/19/15 Open ,, DV Collar BZNS6S 2,880' 2,900' 2,606' 2,623' 20' S 03/19/15 Open •.. 5,598' BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open ' 7 B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open B 33-6 3,334' 3,384' 2,996' 3,038' 50' 5 03/19/15 Open I, B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open 4 C B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open .„ C 49-4 4,535' 4,576' 4,051' 4,088' 41' S 03/19/15 Open C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open 4 Ili C 49-4 4,925' 4,980' 4,408' 4,459' 55' 5 03/19/15 Open i 9-5/8 C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open 1 A - C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open C 51-6 5,451' 5,690' 4,893' 5,117' 239' 5 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open id D Hemlock 6,010' 6,150' 5,423' 5,557' 140' 9/13/2013 Open D 54-9 7,320' 7,436' 6,669' 6,780' 116' 9/13/2013 Open F_-: D 55-7 7,450' 7,533' _ 6,794' 6,873' 83' _ 9/13/2013 Open = D 55-7 7,544' 7,570' 6,883' 6,908' 26' 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open EE D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790' 7,870' 7,113' 7,187' 80' 9/13/2013 Open = D 56-1 7,904' 8,030' 7,218' 7,333' 126' 9/13/2013 Open = D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open E D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open - D-57-2 8,104' 8,158' 7,400' 7,449' 54' _ 9/13/2013 Open = D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 9/13/2013 Open E 58-1 8,660' 8,675' 7,920' 7,934' 15' 9/13/2013 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open Hemlock E60-0 8,916' 8,965' 8,167' 8,215' 49' 9/13/2013 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open Top of F111 9,457' _ E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open 3/17/15 E 60-5 9,074' 9,120' 8,322' 8,367' 46' _ 9/13/2013 Open V A E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210' 9,290' 8,455' 8,534' 80' 9/13/2013 Open KB ELEV= 101' Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open PBTD=9,550' TD=11,000' Hemlock 9,330' 9,360' , 8,574' 8,603' 30' 9/13/2013 Open ANGLE thru INTERVAL=24.9° Revised By:JLL 10/20/16 • • • Monopod Platform A-18 Current 09/14/2013 II :tlaeku.1.1.t: Monopod Platform Tubing hanger,SME-CL,11 X A-18 3'A EUE lift and susp,w/3" 13 3/8 X 9 5/8 X 7 5/8 X Type H BPV profile,3-3/8 3 1/2 CCL,Alloy material BHTA,Bowen,3 1/8 SM X 2.5 Bowen quick union 111 ■ nl Valve,Swab,WKM-M, ,; , 3 1/8 5M FE,HWO,DD trim Valve,Wing,WKM-M, IMO" ill, 3 1/8 5M FE,w/15"OMNI operator,DD trim o Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim w on Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim i.i .1n X3 1�1 1111 Control line I� Van.■:_Ir ice' 1�.1��u�;._ Tubing head,S-8,11 5M x I11 ill 11 5M,w/2-2 1/16 SM SSO, - 111 2- w/BG bottom A. w/2-21/16 SM WKM-M H H . .I�[b�• MI-i.-, valves 1:1 ga arii��a I�I��lir= Casing spool,S-8,13 5/8 3M 111 I I 1U��1 100. x 11 5M,w/2-2 1/16 5M SSO,w/BG bottom ` , �.�{Iy�, • w/2-21/165M WKM-M1, ` IiM '1 valve Irl 111: Casing head, Shaffer KD, 135/83MX 11 1®i 13 3/8 SOW,w/2-2" LPO, i ILII -- 1_1. 4I�•l•°', Nor • i Monopod Platform A-18 Proposed 10/25/2016 Hilrnrp Alaeku.Ll.t Monopod Platform Tubing hanger,Seaboard- A-18 - ESP-EN,11 X 3 1/2 EUE lift 133/8 X 95/8 X 75/8 X and Suspw/3"Type H BPV 3 1/2 profile,2-h CCL,Prepped for BIW Kwik Lok penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union v ar . Valve,Swab,WKM-M, "'01''' 3 1/8 5M FE,HWO,DD trim 8 Valve,Wing,WKM-M,31/8 Valve,Wing,WKM-M,2 1/16 i SM FE,w/15"OMNI 5M FE,HWO,DD trim _ - operator,DD trim 111177 • Irks*Ill l Ix. Valve,Master,WKM-M, , _ 11 3 1/8 5M FE,HWO,DD trim }}{{ gMb Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ iim _ .. Ill 4 11/16 pocket,w/2-h CCL, riiported for BIW penetrator .ei _ A� Tubing head,S-8,11 5M x — 11 5M,w/2-2 1/16 5M SSO, IsiI min w/BG bottom w/2-21/165M WKM-M �� "' Ail� - �� valves 'I !9 VI II�` �I i'�0I_I• . -II i r 1.1 ii , , .� _.._ii it 1,��ii.= Casing spool,S-8,13 5/8 3M 1o1 ii 'I 111 x115M,w/G2 bottom 5M �� _ 550,w/BG bottom I. � �� w/2-21/165M WKM-M I' �� -M lef ll1 111111-1-11 valve 1 N.; f . 0 n Casing head, s Shaffer KD, 13 5/8 3M X 13 1.1 133/8 SOW,w/2-2" I F) LPO, M I I�111■ )e • • • II Monopod Platform 2016 BOP Stack 10/24/2016 Hilrorp:1btrkti.1.IA,, Bottom of air boot flange Rig Floor iii iv 5'below rig floor 111 "Ill_lit Ali 1111111 asa W. far Cr Hydril r GK 13 5/8-5000 Ill Ill lit III lil il III III III III III 26.25' -� - - -- - - -- 2 7/8 x 5 variable cares c. _CIW U I' e 4.67' c� ® ,. 135/85M z AV. Blind O iii lil di iii iii 2 1/16 5M manual and 21/165M manual and 2.26' HCR valves for choke side (l 1 111 i 1 i��I I I HCR valves for kill side , ,0.. lit '...c — 1 - i 11.4°. 'I ). '11, lil lil lel iii IU II II ill III in Ili la Drill deck Riser 135/85M FE X 13 5/8 5M FE 14.20' I I lil di Oil lil 1111. 111 I11 Iii III III Spacer spool ` l 13 5/8 5M FE X 1.41' lil III lit lil III 111 III 24-'420071 -' O ^ o L.• T= = 8 - T o9 co m¢. i �� uuuuu u - '`u u°ouuouuoou uouuouoovuuo°0000u gIK o �O ......• i >Eik _ a Vfffaaa ill y.01\ :#..: ..- .0-t 3 g<_ _sE E E E i _ of 9N.: ��,• Q�� .�\ 31 <>muuc3uu uuuuuuuuz =3ogVFallgieo 'o' ..„- 1! O � r�000uuouuoouuuuuuuovuouououuu00000uuo` a ip5 fd8 O @ 00.E 3 _ __ S 8 s �'rcfff��0, Z2 vNM PM' ¢I�gn, 8: �: g g Q ,id a d a o o o •s Nu: it a°C>m u u u 3 u u u',O Fi u u u uu u u i 3 i 3°gV.-a E E E F d s s i IA .3 9 8 < 9 a 2 43111§§.40°.43111§§.40°. a g a 41.11§wm 8 ? $ E- 3 lili - M M 1013 >"yym ,$ x C M M MV LL>' m 3 3 / u -4up$.oe ¢ U 1AypL°'!O illi Il 3 U 7 !i 0 2 ! 3 HMI C 1 fs 411111111/=:::) IIIIIMIll C 8 . e e$. 8 $ 4g F i -- F £ f — - Hi= I1 E 3)E f 1F _ F x � gg ? � o ----r4: 4 - ® 3 ® f F " `• 10 A A c • �.SRRKERi o a O r ~ • 6 qk .... - i►- exam s `n.. ......41:t4 '} y+ 1 l M3 J ® ' O s 2 2 E 1 --hF Ai- —44- \\-, • • Monopod Rig#56 BOP Test Procedure Flileorp Alaska,ITCAttachment#1 Attachment #1 Hilcorp Alaska, LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru the flare to atmosphere. 2) Load well with FIW to kill well. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Check well is static, shoot fluid levels if necessary. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. Clean and inspect lift threads(screw sub into threads, count the number of turns). Install blanking sub if using one. 2) NU BOP 3) Test BOPE per Monopod Rig#56 BOPE test procedure. Initial Test(i.e.Tubing Hanger is in the Wellhead) Rolling BOP Test If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept test joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set BPV and/or have lift-threads prepped for test joint. d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. o 4110 Monopod Rig#56 BOP Test Procedure Hilrorp,Alaska,LLC Attachment#1 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator or hanger leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC- guy.schwartz@alaska.gov )and Mr.Jim Regg(AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness.As outlined and approved in the sundry, proceed as follows: 5) With stack out of the test path, test choke manifold. 6) Conduct a rolling test: a. Test the rams and annular with the pump continuing to pump, holding a constant pressure on the equipment (monitor the surface equipment for leaks to ensure integrity). b. Record the pumping rate and pressure. 7) Once the BOPE tests are completed, test the remainder of the system following the normal test procedure (PVT, gas detection, etc.) 8) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment, list pressures and rates. 9) Pull hanger to surface (May require tubing cuts to free tubing) 10) Remove the old hanger, MU a new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. 11) Test BOPE per Monopod Rig#56 BOPE procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Riq 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open X"valves above valve 16, remove sensor above valve 3, and close all standpipe manifold valves. Fill stack w/water through kill line fill BOP and CMV's to top of annular. Close annular preventer X2 to get air out and continue to fill to top of dart valve. Close dart valve and continue to fill until fluid is seen out of CMV#5&#3. Cont.fill till fluid comes out%" valves above CMV 16, close valve 16&4"kill valve on mud line. Open bleed line on standpipe manifold Have a hand in wellhead room w/casing valve open monitoring it open ended or to a gauge during all tests. In freezing temperatures, blow down mud line back through MP bleeder.Shell test. Test w/31/2 TJ 1) Close pipe rams, Open Annular, test CMV 3,5,15& 16, dart valve,pipe rams, 4"demco kill line valve, t/250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests) • Monopod Rig#56 BOP Test Procedure flaeorp Alaska.Lu: Attachment#1 2) Close TIW open dart valve, CMV's 8,9,12,13,14 kill line HCR, open CMV 15& 4"Demco kill line valve(drain gas buster "U"tube immediately in freezing temps) 3) Close CMV's, 1,7,10,11, manual kill line valve, open CMV's 8,9,12,14, &kill line HCR 4) Close CMV's 2,4,6, open valves 1,7& 13 5) Close HCR choke line, open CMV 2 6) Close manual choke line valve, open HCR choke line valve Preform Accumulator test....then pull Ti With test jt in hole&system up to pressure. 1) Turn off electric& air pumps 2) Record accumulator pressure(+-3000psi) 3) Close Annular,pipe ram's, & her valves, open pipe rams to simulate blinds 4) While pressure is stabilizing check pressure in nitrogen bottles& record. 5) Record accumulator pressure 6) Turn on electric pump& time seconds to pressure up 200 psi, turn on air pumps& time till unit pressures up to 3000 psi&shuts off. (time will start from time electric pump starts till all pumps shut off) 7) Back out test jt&pull, close blinds, install test hose to choke manifold outside valve 5, close valves 2,4,6, open valve 11, choke HCR& inside choke line valve 8) M/U 2 7/8 t/j, close annular,fill test jt w/test pump till tiw/dart valve is full, then close, test 9) Close pipe rams, open annular, close tiw, open dart valve FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Test PVT system 3) Double check all rams and valves, for correct operating position 4) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. f e • J c N aN+ d 4' 0 EtC co o a) V qac cot 0 Qa) U Q as C• ° Q _, E � E rn c -0 U c d N E N = o.m C 3CL Q Z'•- 73 a) y O N N N Q Q 73 i co.m o `)v •- a 0_ m 00- CO LI.) - coa.) ra tri o• N �V L Z rn ›- C0-C Z CD C U N N L L O U o ° co o Ta CG) m o ° co d p c a) ao o_ a) � C 3 a: a Q e �asC WC 0 d w a) E L U = =ai or. O l • a o a) .. a _ a) `° 0) co a) a'n C a) .CO CO 'C c U w0 w a v LN T oo > 0 c U a ° a m r 0 CL• oO 0. 03 ` 4 Q O. ea � Q 0 co o coEO X Q y o a) us ca rn X = a 0 c11 O N , 0. N N 0 nll CD ii 0 U X Q 'u. ao O + o UO U U Z a m E 2 co V Q V in cnn QQ co OQ a • OF TMJ • • '14 I///��6A THE STATE Alaska Oil and Gas F�►;._-s�� o fLASI�:A Conservation Commission _ A 5 f} = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF r Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager FEB 2 7 2.0 17, Hilcorp Alaska, LLC SCANNED 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Trading Bay Field, Middle Kenai B, C, D,and E, and Hemlock Oil Pools, TBS A-18 Permit to Drill Number: 168-076 Sundry Number: 316-525 Dear Mr. Golis: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, W6 Cathy P. Foerster Chair DATED this 14 day of October, 2016. RBDMS LA/OCT 1 4 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 12 2016 APPLICATION FOR SUNDRY APPROVALS / /�/wD�/'+/q-//,‘20 AAC 25.280 4�V 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. CTU Clean Out w/N2 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0. 168-076' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay StA-18 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai B,C,D&E Oil&Hemlock Oil Pods • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): • 11,000 • 10,241 • 9,550 • 8,791 865 psi N/A 9,550 Casing Length Size MD ND Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,489' 9-5/8" 7,520' 6,860' 3,950 psi 2,570 psi Intermediate Liner 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,337' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 2-7/8" 6.5#/L-80 2,372 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hyd Ret Packer&SSSV i 2,297'(MD)2,095'(ND)&331'(MD)331'(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development El r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/1/2016 OIL 0. WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ El Op Shutdown El Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name S tan W.Golis l Title Operations Manager Signature `�" az (-.ArC). Phone (907)777-8356 Date (D / 1 r ( I b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test A Mechanical Integrity Test ❑ Location Clearance ❑ Other: - 14 S°0 ---�"� o' Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El Nod Subsequent Form Required: 1 0 r_ 44 0y RBDMS LL OCT 1 4 2016 aiieefp,- ,...e.,,c,4_,,.. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:/0 / 4--/,‘i0I13 iC ClgiLplcUAtfor ja./ /c I Submit Form and Form 10-403 Revised 11/2015 12 months from the date of approval. Attachments in Duplicate • Well Work Prognosis Well: A-30 Hilcorp Alaska,IAA: Date: 10/11/16 Well Name: Monopod A-18 API Number: 50-733-20143-00 Current Status: Oil Producer(Gas Lifted) Leg: N/A Estimated Start Date: 11/01/2016 Rig: Coil Tubing Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 168-076 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904(M) Second Call Engineer: Stan Golis (907)777-8356 (0) Current Bottom Hole Pressure: 1,083 psi @ 2,176'TVD 0.498 psi/ft(9.57 ppg)6/7/10 SIBHP Maximum Expected BHP: 1,083 psi @ 2,176'TVD 0.498 psi/ft(9.57 ppg)6/7/10 SIBHP Maximum Potential Surface Pressure: 865 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The A-18 well was last worked over in 2015 completed in the B,C, D, E and Hemlock as a gas lifted producer. This procedure will unload kill weight fluids used during the workover that we suspect to be limiting productivity. Last Casing Test: 03/21/2015 at 2,297' 1,500 psig for 30 minutes on chart Procedure: 1. MIRU 1.5" Coil Tubing. 2. NU BOP and test to 250psi low 4500psi High,(Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out any fill to±9,457'. Circulate bottoms up. If returns are not present, see attached Standard Well Procedure—Nitrogen Operations. Fluids will be Filtered Inlet Water.All returns will be through gas buster to open top rig tanks(non-enclosed) or to production header. 4. POOH to ±9,457', line up returns to production header. 5. Return well to production via gaslift and begin pumping nitrogen per standard operating procedures to unload kill weight brine from bottom of the well taking all returns to production system. 6. POOH with coil and rig down. Attachments: 1. Well Schematic Current/Proposed (Same) 2. Coil Tubing BOP Drawing 3. Standard Well Procedure—Nitrogen Operations 4. Flow Diagrams 5. RWO Sundry Revision Change Form SCHEMATIC •• Trading Bay Unit Well: A-18 Hilcoru Alaska,LLC Completed: 03/22/15 RKB to TBG Hngr=37.00' CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' I*; 9-5/8" 40 K-55 Buttress 8.835 6T 4191' x 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520 c 13-3/S" STAGE COLLAR 5,598' 5,600' 7-5/8" 29.78 L-80 SLID-2 6.875 Surf 7,488' I 4' Liner e y.� 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' °"t TUBING DETAIL r' _ �" 2-7/8" I 6.58 I L-80 I 8rd EUE I 2.441 I Surf I 2,372' 4 I J 6MJEWELRY DETAIL NO. Depth easured ID Item t 37.0' Tubing Hanger ' Web 2 v 1 331' 2.441 SSSV y' PA 3 > 2 2,259' 2.441 Orifice-1/GLM t A 3 2,278' 2.441 Chemical Injection Mandrel 4 4 2,297' 2.441 Hydraulic Retrievable Packer 4 ! • pod Platform C d Tubing BOP II 09/21/2016 Hilrarl.Alaska.1,1.E Lubricator to injection head 70 1 - __ e t 1� i /C_ Blind/Shear 4 1/16 10 Blind/Shear =I ---- -c= Blind/Shear Blind/Shear_ _ _li ®OO c_ __ Slip Slip :j — —_ __ C ——f f = Pipe Pipe _ _ _ rd !, n _ 111( 1 t rill iiiiik 40 111=1111 i II Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M tt... tti, I. Valve,swab,WKM, 3 1/8 5M FE, HWO .„0(—p 1'` ®� u.NO n. n l (i) iiilip / >'`_ ^`•,. Valve, master,WKM, ..E 3 1/8 5M FE, HWO '�� 1 04' ... III • STANDARD WELL PROCEDURE 'Merril) 1Iaaka, i.i.0 NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure supplier has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 09/23/2016 FINAL v-offshore Page 1 of 1 • • • two EQ o A > aL F aC > "d � ,, > OA '' > > F w C � S 0 z O -I F� SHAKER. s > W ...7 °-> r t0 - O O x w L I I- g F d R - -_ '4 I X Z°-a'O of S -I I— I SHAKERY u .--lr--� u > on y 5 4.8. b E d I •4 0 7 © ` w > c7 w Q a N - a ',1�. = I V— • i ti I'i c E n o a Qa a __ o 011 • 0 Z 9 tq m Y I— mro V N N Z /..44,45".-,-.--.—��:*'o CI.._�1j�— \ z v ( --r a }w i 0„ n 11 R la 0 4'... o tin. - Ti (�■4'' • 1 'I�='II ��I��r�h IlIIIUIII� �I AI - @ U h ti •'p v�.,Y 1i m J 6 9 m to S m ;x°1 r,..`9 c:, O.j o o y�O 2 vl UJ a� o E co H cotn C m U r•. I. ■ c l7 n y C V Y O V V V Nir•• le: eD e u0.1 v 1.11 U r 1.141 0•011 U u m c to •a u a • r•• ui OLL ry Z U 2 V• Y O • x CO m U Vi a • 2, a, o / >. � 2 0 fl a 00 2k ° § / « � E � c 0o c ) u = § X ft f / < \ / Y ) k -0 f0� / 0 .§ a = § .\ C) C) 00 L. CO AI $ 0 a)» CO2 o 2J 1, 0 co / 15L. 9 5 a) .-/ § / 2 / C co k» & Q ® \ § ig — _c CO Q \ C) � � 0 CD .2 E § 0 3 j e @ O 2 0 .g ED a- 44t 2 O / = k R § e C) ±> § 2 = 2 / ■ Cl) = ■ c « g c W 2 $ % 0 0 2 @ o > a 1 o k a. e ■ 0.4 « / \ 0 C g 2 % \ E C _D Q § X f » & r _� 0 / 7 o / aus _ 0 2 c. � w0 11 / > 2 iz o p .. _ % $ v oG > q \ // O a / U @ m < < CO < I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COW___SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate 0 Other El Complete Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdowri❑ Stimulate-Other El Re-enter Suspended WePI❑ 2.Operator 4 Well Class Before Work: 5.Permit to Drill Number. Name: Hilcorp Alaska,LLC Development El Exploratory❑ 168-076 rR E C E I V E D 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphik❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00 4 P R 2 2 2 015 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-18GCC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay Field/Middle Kenai D Oil,Middle Kenai E Oil,Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,000 feet Plugs measured N/A feet true vertical 10,241 feet Junk measured 9,550 feet Effective Depth measured 9,550 feet Packer measured 2,297 feet true vertical 8,791 feet true vertical 2,095 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,482' 9-5/8" 7,520' 6,860' 3,950 psi 2,570 psi Intermediate Liner 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,377' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 2,372'(MD) 2,160'(TVD) 2,297'(MD) 331'(MD) Packers and SSSV(type,measured and true vertical depth) Hyd Ret Pkr 2,095'(ND) SSSV 331'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAY 0 4 2015 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: 108 0 283 753 110 Subsequent to operation: 86 223 0 772 98 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ El SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-122 Contact Dan Marlowe Email dmarloweCn�hilcorp.com Printed Name Dan Mario • 10"-- Title Operations Engineer Signature i Phone (907)283-1329 Date 4/22/2015 Z,S. /� RBDMS APR 2 3 2015 Form 10-404 Revised 10/2012 �j '/� /� Su it Original Only 21O '.0 Trading Bay Unit II SCHEMATIC Well: A-18 Hilcorp Alaska,LLC Completed: 03/22/15 RKB to TBG Hngr= 37.00' CASING DETAIL Size Wt Grade Conn ID Top Btm _ 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' a o 13-3/8" STAGE COLLAR 5,598' 5,600' w 7-5/8" 29.7# L-80 SLIJ-2 6.875 Surf 7,488' i. Liner s - . 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL 2-7/8" I 6.58 I L-80 I 8rd EUE I 2.441 I Surf I 2,372' P d JEWELRY DETAIL Measured ,y NO. Depth ID Item r 37.0' Tubing Hanger inlell 2 a 1 331' 2.441 SSSV Al ii# 3 2 2,259' 2.441 Orifice-1/GLM x x 3 2,278' 2.441 Chemical Injection Mandrel 4 4 2,297' 2.441 Hydraulic Retrievable Packer 5 5 - 5 2,341' 2.313 X Nipple I 6 6 2,372' 2.50 WLEG $ PERFORATION DETAIL _ B Zone Top(MD) (MD) (ND)m Top Btm(ND) Amt. SPF Last Date Status f -'',AB 24-6 2,390' 2,455' 2,176' 2,233' 65' 5 03/19/15 Open DV Collar B 26-7 _ 2,567' 2,700' 2,331' _ 2,448' _ 133' 5 03/19/15 Open 5,598' s E BZNS6S 2,880' 2,900' 2,606' 2,623' 20' 5 03/19/15 Open w , BZNS9S 3,120' 3,143' 2,813' 2,833' 23' 5 03/19/15 Open B 31-8 3,168' 3,210' 2,855' 2,891' 42' 5 03/19/15 Open t B 33-6 3,334' 3,384' 2,996' _ 3,038' 50' 5 03/19/15 Open '- C B 41-3 3,480' 3,510' 3,118' 3,143' 30' 5 03/19/15 Open B 44-7 3,903' 3,984' 3,479' 3,550' 81' 5 03/19/15 Open C C-2 4,078' 4,130' 3,634' 3,681' 52' 5 03/19/15 Open C C-3 4,164' 4,240' 3,712' 3,781' 76' 5 03/19/15 Open , C C-4 4,308' 4,420' 3,843' 3,945' 112' 5 03/19/15 Open t = C 49-4 4,535' 4,576' 4,051' 4,088' 41' 5 03/19/15 Open , - 9-5/8" C 49-4 4,854' 4,884' 4,343' 4,371' 30' 5 03/19/15 Open s = C 49-4 _ 4,925' 4,980' 4,408' _ 4,459' 55' 5 03/19/15 Open C 50-0 5,150' 5,176' 4,615' 4,638' 26' 5 03/19/15 Open C 50-6 5,240' 5,398' 4,697' 4,843' 158' 5 03/19/15 Open A - D C 51-6 5,451' 5,690' 4,893' 5,117' 239' S 03/19/15 Open D 53-0 5,752' 5,910' 5,176' 5,327' 158' 5 03/19/15 Open J Hemlock 6,010' 6,150' 5,423' 5,557' 140' 9/13/2013 Open = D 54-9 7,320' 7,436' 6,669' 6,780' 116' 9/13/2013 Open D 55-7 7,450' 7,533' 6,794' 6,873' 83' 9/13/2013 Open = D 55-7 7,544' 7,570' 6,883' 6,908' 26' 9/13/2013 Open = D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790' 7,870' 7,113' 7,187' 80' 9/13/2013 Open D 56-1 7,904' 8,030' 7,218' _ 7,333' 126' 9/13/2013 Open E D 55-7 7,910' 8,030' 7,224' 7,333' _ 120' 7 Jan-75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open 0-57-2 8,104' 8,158' 7,400' _ 7,449' 54' 9/13/2013 Open D 57-2 _ 8,380' 8,516' 7,654' _ 7,782' 136' 23 Jun-79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' _ 7,941' 114' 19 Jun-79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 9/13/2013 Open E 58-1 8,660' 8,675' 7,920' 7,934' 15' 9/13/2013 Open Hemlock E 58-7 8,734' 8,832' 7,991' _ 8,086' _ 98' 16 9/13/2013 Open Top of Fill 9,457' - E 60-0 _ 8,916' 8,965' 8,167' 8,215' 49' 9/13/2013 Open 3/17/15 - E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open -.s_o, /27,..13,*14.NrloVski.r.-00,3 oVskiJ'' % 7" E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 Jun-79 Open E 60-5 _ 9,074' 9,120' 8,322' 8,367' 46' 9/13/2013 Open KB ELEV= 101' E61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210' 9,290' 8,455' 8,534' _ 80' 9/13/2013 Open PBTD=9,550' TD=11,000' Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open ANGLE thru INTERVAL=24.9° Hemlock 9,330' 9,360' 8,574' 8,603' 30' 9/13/2013 Open Revised By:JLL 04/21/15 Hilcorp Alaska, LLC HileorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 Daily Operations: 03/11/15-Wednesday Skid rig over A-18.Secure same.Set BPV.Nipple down tree.Verify lift threads to be 3 1/2"8rd.Lock SSSV open. Install blanking sub. M/U 2 7/8"test joint with left-handed Acme thread.M/U on blanking sub and mark at rotary table.18 BPH loss rate. Install riser. Nipple up BOPE. 17 BPH loss rate. Install 2 7/8"test joint.function test BOPE.Fill stack. 03/12/15-Thursday Shell test BOPE as per sundry 250 L/3000 H.Had leak on both uni bolt conn.and TDS IBOP failed.Chg/out uni-bolt gaskets and trouble shoot IBOP and obtain good shell test. Contact State man Mr.John Crisp of good shell test and to travel to heliport.Blow dn TDS. Work on chinking rig and house keeping State man Mr John Crisp pn1aratiaa..Watform orientation.PJSM test BOPE as per AOGCC regulations on 2-7/8"and 3-1/2"test joints @ 250L and 3000H.Had(1)fail/pass test#3 function TPR trapped air re-test ok.Test#5& #11 questionable.Driller retested(ok). Pull 3-1/2"test jt.L/dn blanking sub.Pull BPV.M/up landing joint. 20"X 13-3/8"=0 psi,13- 3/8"X 9-5/8"=270 Psi.9-5/8"X 7-5/8"=15 Psi.Daily brine lost to well=372 bbls.Total brine lost t/well=1252 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls. Sweep well to production w/25 bbls to clean KCL.BOLDS. Pull hanger off seat and up in to riser 14'clearing seals from packer.P/U wt 85K. Circ STS at 8 BPM/770 psi with high gas 513 units and loss rate at 17 BPH. Lay down tubing hanger and landing joint. POOH laying down completion string.17 BPH loss rate. 03/13/15-Friday Continue pooh cleaning,inspecting,gas lift completion string and chking against running tally.Complete tubular recovery t/seal assy removed indexing mule shoe and save same.Recovered 2 extra cannon clamps&was shy(2)1/2"SS band as per running tally.No norm detected above back ground and no anomalies noticed. Clean clear floor install wear ring and house keeping. Service traveling/rotary/handling equipment w/static loss rate of 17 BPH. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=270 Psi.9-5/8"X 7-5/8"= 15 Psi.Daily brine lost to well=481 bbls.Total brine lost t/well=1733 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls. Ditch magnet 30 lbs.String magnet 20 lbs.Boot baskets 1 lbs. P/up M/up Bha#1=6-3/4"MM packer mill,(5)4-3/4"junk baskets Bit sub w/float,X-tree XP string magnet,4-3/4"bumper sub,4-3/4"oil jar,pump out sub,(9)4-3/4"Dc's,4-3/4"acc jar=345.03'. Rih w/ bha#1 on 3-1/2"dp out of derrick t/2,632'. Circ btm up at 8 BPM @ 1500 psi to load power generation system for Elect and Nov hand w/max gas of 81 units.Trouble shoot TDS. Continue RIH out of derrick t/5,856'. Kelly up,fill pipe,brk circ 6 bpm @ 1025 psi. Establish parameters: up/dn/rot 126/87/103k @ 80 rpm w/off btm tq of 12,700 ft/lbs.Wash dn tag @ 5,914' p/up initiate rotation tag prk @ 5,911'. Mill prk f/5,911't/5,916'w/2-18 WOB,80 rpm @ 8-9k on btm tq @ 6 bpm @ 1120 psi.Used various parameters to mill up packer.Chase packer to 5,925'. Circulate through gas buster with F/O choke at 6 BPM/1050 psi.High gas of 555 units. 26 BPH loss rate while circulating. RIH on elevators from 5,925'to 6,710'without issue. Circulate gas out at 8 BPM/1750 psi.High gas of 470 units. 19 BPH loss rate while circulating. RIH on elevators from 6,710'to 7,403'.Set down 10 K and solid at 7,403'. Circulate gas out at 8 BPM/1900 psi.High gas of 360 units. Blow down top drive.POOH with BHA#1.16 BPH loss rate. Work BHA#1.A 1.59'piece of the mill stinger is missing.Recovered 20 lbs off string magnet.Recovered 1 lbs out of boot baskets.Recovered 30 lbs off ditch magnets. Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 Daily Operations: 03/14/15-Saturday Make BHA#2:Spear w/4.01"nominal catch,double pin sub,bit sub,BS/OJ,pump out sub,9 ea 4 3/4"DC's,Acc Jars=316.37. Rih w/ Bha#2 t/6,235'.Had false fire alarm in living quarters.Secure well and equipment.All hands mustered at secondary safe briefing area.Continue Rih w/Bha#2 f/6,235't/7,386'Kelly up brk circ. Circ btm up clear well of gas w/high gas of est few hundred units very active bell nipple(purge clean and chk gas detector)w/losses @ 18 BPH. Blow dn TDS and obtain static loss @ 18 BPH.POOH slow t/BHA#2. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=210 Psi.9-5/8"X 7-5/8"=15 Psi.Daily brine lost to well=413 bbls.Total brine lost t/well=2146 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 30 lbs.String magnet 20 lbs.Boot baskets 1 lbs. Wash dn @ 2 bpm @ 350 psi looking for fish.Set dn engage fish @ 7,479' (@ TOL)set dn and pushed fish dn hole t/7,481'w/30k dn wt.P/up 30k over and set grapple and bleed jars.Cock and Fire jar @ 40k over.straight pull @ 45 over fish pull free w/+/-10k extra drag.Work fish 45'up to 30k dn wt X3 to ensure catch. Work Bha#2.Grapple from spear missing.No recovery. P/U M/U BHA#3:6"x 4 3/4"MM shoe,XO bushing,top sub,double pin sub,2 ea boot baskets,bit sub,BS/OJ,pump out sub,9 ea 4 3/4" DC's,Acc Jar=326.43. RIH w/BHA#3 P/U rabbit and strap 66 jts of 3-1/2"13.3# S-135 DP. 15 BPH loss rate. Continue RIH w/BHA #3 w/DP out of derrick to 7,460'.Fill pipe+/-every 2,500'. 17 BPH loss rate. Establish parameters:P/U,S/0,Rt=152,100,118 @ 10K ft/lbs 80 RPM. 8 BPM/1700 psi. Mill on packer/fish from 7,480'to 7,481'. 21 BPH loss rate while circulating.Minimal gas units at bottoms up. 03/15/15-Sunday POOH to BHA#3.w/loss rate @ 18 bph. Work Bha#3.Burning shoe face 100%used and egged.Ld cutting structure shows wear.Pipe Id no marks.Recovered 2#out of boot bsk and ditch magnets recovered#26. P/up m/up Bha#4=5-7/8"short catch 0/shot loaded w/4-3/4"basket grapple,double pin,bit sub w/float,bumper sub,oil jar,POS,(9)Dc's+acc jar=313.66',one std dp. Loss rate+/-18 bph. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=260 Psi.9-5/8"X 7-5/8"=10 Psi.Daily brine lost to well=505 bbls.Total brine lost t/ well=2651 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 40 lbs.String magnet 20 lbs.Boot baskets 3 lbs. Rih w/bha#4 w/dp out of derrick and fill pipe every+/-every 2,500' t/7,420'loss rate+/-18. Establish parameters:P/U,S/O,= 145,100,@ 8 BPM/1700 psi. P/U,SO,=142,98,@ 2 bpm @ 120 psi.Engage fish @ 7,478',work tools attempt catch had some slight pressure increase and packing off and injecting. No over pulls,maybe 5k heavy.Plow dn&perform static loss Up t/30 BPH. Service rig:Top drive. POOH to BHA#4.22 BPH loss rate. Work BHA#4.No recovery.Some marks on inside taper of overshot lip.No marks on grapple. M/up BHA #5:6"x 4 3/4"MM shoe,X0 bushing,top sub,double pin sub,2 ea boot baskets,bit sub,string magnet, BS/OJ,pump out sub,9 ea 4 3/4"DC's,Acc Jar=338.05. RIH to 2,680'with BHA#5. Service rig and equipment. RIH to TOF at 7,470'. 27 BPH loss rate. Establish parameters:P/U,S/0,Rt=145,100,121 @ 10K ft/lbs.6 BPM/1000 psi.Mill on packer/fish at 7,478'. 28- 31 BPH loss rate while circulating. 03/16/15-Monday Continue Milling on packer/fish at,7 478'_t/7,479.5'w/avg loss rate while circ @ 28 bph. Blow dn TDS.POOH t/BHA#5 w/avg loss rate @ 25 BPH. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=260 Psi.9-5/8"X 7-5/8"=10 Psi.Daily brine lost to well=626 bbls.Total brine lost t/well=3277 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 156 lbs.String magnet 65 lbs. Boot baskets 11 lbs. Work BHA#5.Recovered 9#iron off string magnet,8#large chunks iron and brass out of junk bsks and 36#off ditch magnets.Mill 1/4"out gage,face of mill 110%used and ID cutting structure chipped and ID and pipe behind had marks 7-8". M/up BHA#6:5-7/8"short catch o/shot loaded w/4 1/2"basket grapple,double pin sub,bit sub,string magnet,BS/OJ,pump out sub,9 ea 4 3/4"DC's,Acc Jars=325.28. 22 BPH loss rate. RIH fill pipe t/5,081'. Slip and cut 110'of drill line. 18 BPH loss rate. Continue RIH from 5,081'to 7,460'. Establish parameters: 145 K P/U,104 K 5/0,3 BPM/280 psi. Engage fish at 7,478'. Set down 10 K, pick up to 175 K.Set down 20 K,pick up to 175 K.Fish came free with additional 8 K over P/U weight. POOH slow with BHA#6. 20 BPH loss rate. Work BHA#6.Had full recovery of fish:packer,pups,x nipple and WLEG. 9 lbs off of string magnet.36 lbs off ditch magnets. 22 BPH loss rate. Make up BHA#7:Casing scraper assembly. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 i1y Operations., . 03/17/15-Tuesday Make up BHA#7 clean out assembly.Trip in hole to 2,690'. Service rig,crown,blocks,swivel,top drive,drwks,and ST-80. Wash f/ 8,422't/8,616'without tagging anything.Circ btm up to chk well gas/oil @ 8 bpm @ 2060 psi w/high gas of 736 units and lots of oil. Loss rate of 15 bph blow dn tds. Continue to stage in 7"csg looking for fill to 8,958'.Circ hole clean at 9 BPM and 2775 psi.1000 units of gas and a loss rate of 15 BPH.Getting a lot of oil back on bottoms up. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=260 Psi.9-5/8"X 7- 5/8"=10 Psi.Daily brine lost to well=468 bbls.Total brine lost t/well=3745 bbls.Daily sized salt to well=0 bbls.Total SS to well= 80 bbls.Ditch magnet 156 lbs.String magnet 65 lbs.Boot baskets 11 lbs. RIH f/8,958't/9,352'and set down 15k.Pick back up to 9,275'w/it dragging up to 20k over up wt. RIH filling pipe at 5,100'and 7,472'.Go through 7"liner top at 7,489'and we didn't see anything.Continue RIH to 8,422'. Wash f/9,275'to 9,362'.Circ hole clean at 9 BPM 2775 psi.750 units of gas for the high.Up wt 193k,do wt 107k,Rt wt 145k. Wash dn to 9,379'.Wash and ream f/9,379't/ 9,457'.90 spm,2780 psi.60 RPM w/10k torque. Couldn't make any hole past 9,457'due to stalling rotary,and working out of tight spots.Decided to call new TD at 9,457'which puts us 97'below lower perfs and 93'above PBD. Circ hole clean and get rigged up to change over to new 3%KCL.Recovered 4 bbls of sand back for entire clean out. Hold PJSM w/everybody involved in displacing well and shipping to production.Test line to 1000 psi. Pump clean 3%KCL down tbg w/#1 pump taking dirty returns to mud pits and pumping the dirty fluid to production w/#2 pump at a max of 2 BPM and 450 psi.Adjusting BPM to maintain pressure on production line.Pumped 430 bbls before getting clean return to surface. Monitor well w/a loss rate of 13 BPH.Blow down TD.POOH to 8,200'while still pumping dirty 3%KCL to production at 1.5 BPM.Had to pull 25k over at 9,146'and 8,890'. Continue POOH laying dn DP f/8,200 t/7,000'.Laid dn 78 stds.Finish pumping to production.Pumped a total of 490 bbls. RD production shipping lines and flush all rig equip lines w/clean KCL. Continue POH with BHA#7 standing 3 1/2 DP back in the derrick. 03/18/15-Wednesday Finish POOH to BHA and LD BHA.Recovered 16 lbs off string magnet,with three 1"X 1/2"thick chunks of packer.Recovered 31 lbs out of boot baskets with a couple lbs of bigger chunks from the packer.Clear floor of tools. Pull wear ring and flush out stack.MU 3 1/2 test jt and purge system. Test BOPS to 250 psi low and 3000 psi high on 3 1/2 and 2 7/8.No failures.BOPE test was waived by Jim Regg,AOGCC.Loss rate during test 18 BPH. Rig dn test equip and blow down lines.Monitor well.Loss rate seemed to go up to 24 BPH then fell back to 18 BPH. RU to run perf guns.Make up safety jt.PJSM on running perf guns. P/U 60 4 1/2" pert gun per running tally (16bph loss rate). Crew change out. Continue P/U&run 41/2"perf guns.16bph lose rate. 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"= 50 Psi.9-5/8"X 7-5/8"=265 Psi.Daily brine lost to well=472 bbls.Total brine lost t/well=4217 bbls.Daily sized salt to well=0 bbls. Total SS to well=80 bbls.Ditch magnet 0 lbs.String magnet 16 lbs.Boot baskets 31 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 ' 03/19/15-Thursday RIH picking up 4 1/2 perf guns.Run a total of 167 guns. PU firing head,1 jt 2 7/8 tbg,Ported flow sub,2 jts 2 7/8 tbg,XO,and RA sub. RIH on 3 1/2 DP and land out 4'low DPM on the up stroke.RU circ and safety valve.Loss rate 18 BPH. RU e-line to correlate.Run correlation log and send logs to town for verification.POOH w/e-line and RD same. Received confirmation that we had the pipe set good to place shots where they were required.Top shot at 2,390'and bottom shot at 5,910'.RU drop bar assem and fire guns off at 12:40 hrs.Monitor well for 10 min with tbg on a vac.Started circ at 4 BPM and got returns back after pumping 20 bbls.80 bbls away and we started getting oil back.Pumped 165 bbls at 4 BPM,335 psi.High for gas was 310 units. Shut down and shut in to monitor pressure.Pressure leveled off at 100 psi on csg and 20 psi on DP. Start pumping again and got returns at 4 bbls away.Raise pump rate to 4 BPM at 375 psi with a high of 335 psi,and a loss rate of 47 BPH.Getting back a lot of oil mixed in with the KCL. Shut do pump and check for pressure on DP and ann.No press,so we opened the bag.Started pumping w/well open and welded 2"nipple on pump in sub broke off.It was about 5'in the air and it stayed hanging there by the safety chain.Pump was shut down and valves were closed on both sides. Laid down drop bar circ assem and screwed into TD to circ. Circ at 5 BPM and 245 psi.Had a high of 808 units of gas, but most of it was breaking out of the crude oil.26 BPH loss rate. Shut down and get a static loss rate(Static loss rate 22 bph). PJSM- POOH stand back drill pipe and L/d 8"pup.While pulling out we encountered gas breaking out of the completion fluid @ 4,478'- stopped.Install safety valve and monitored well(max units of gas was 300). POOH F/4,478'-2,383'periodically stopping flow check and let gas break out of brine. Pull last send out and rack back.M/U safety valve and xo on to one jnt.of drill pipe and set aside for well control while laying down 4 1/2 guns. PJSM on lying down 4 1/2 gun assembly. L/D 4 1/2 gun assembly.Drain&wash every jnt. (Periodically flow checking and allowing gas to break out of brine). 20"X 13-3/8"=0 psi,13-3/8"X 9-5/8"=50 Psi.9-5/8"X 7-5/8"= 265 Psi.Daily brine lost to well=427 bbls.Total brine lost t/well=4644 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 0 lbs.String magnet 0 lbs.Boot baskets 0 lbs. Monitor well 1bbl.gain but higher the normal gas readings 500 to 700 units. Decided to make up xo and run in two stands of drill pipe.After m/u the first stand,and slacking off,fluid started coming through the drill pipe(because the drill pipe being smaller than the guns),slips was set safety valve was stabbed and well was shut in. 2,570'of gun in the hole. Well shut in with 0 psi on the back side gaining to 120. Make up Top drive to work string.Start pumping 1.5bpm @ 200 psi holding 80 psi back pressure to circ.oil cap out.Shut pumps down and monitor pressure and stabilized @ 90psi. Continued this process until oil cap is out of the hole and pressure is O. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 Daily Operations: 03/20/15-Friday Circ oil and gas cap off well at about 120'through ported sub on top of perf guns.When gas starts coming down we shut in well and let more gas migrate.Then pump cap off again until pressure on back side is 0 psi.Open well and circ until gas unit fell down from 360 units to 250 units.Shut down and monitor well.Well still had slight flow.Start circ again but gas units increased to 500 and we started gaining fluid. Shut well in with upper rams monitoring ann press while weighting up 90 bbls of 3%KCL to 9 ppg.Pressure built to 50 psi. Pump 20 bbls of 8.6 KCL around holding 100 psi back pressure on choke,and follow it with 10 bbls of 9 ppg KCL.Close choke and bullhead 66 bbls of 9 ppg KCL at 2 BPM with a starting pressure of 275 psi and a final pressure of 545 psi.Shut down and lock pressure in.Bled back to 100 psi in 10 min.Opened choke and confirmed there wasn't any pressure on back side.Open rams and monitor well. MU dart valve on top of TIW and RIH to 510'at circ sub and 3,022'at bottom of guns.Well started flowing.Screw in TD and circ out gas bubble w/a high of 1050 units of gas. Continue to circ and wt up system to 9 ppg. Well stable.RIH to 796'and the well started flowing.Shut in and circ oil [about 15 bbls pure oil]and gas out.3740 units.Gas died down to 400 units.Shut down and monitor well. No flow but gas still breaking out. Stage in the hole 1 stand at a time and circ bottoms up after each stand to 1,366'at circ port. Highest gas units 650. Trip in hole to 1,942'and circ bottoms up.Then trip in to 1,942'and 3,334'circ bottoms up each time.Highest gas units 600.Maintain 9 ppg mud wt. Continue RIH to 4,896'at circ sub and 7,406'at bottom of guns. Circ @ 6bpm 660 psi and weighting up light spots to 9.0 ppg.Total pumped of 9.0 ppg.brine was 476 bbls.High gas units 565 and leveling off @ 150 units. Shut pumps down and monitor well for static loss rate(12bph). CBU to assure that well is under control @ 6bpm 660 psi.Total 171 bbls Max gas units 269 leveling off to 155 units. POOH to the top of the Guns. The hole took on the average 4 bbls per 5 stand.Max Gas was 200 units during the trip to the guns. Monitor well while rigging up to L/D Perf Guns. L/D Perf guns f/2,537'to 2,193'(16 guns). Crew change. L/D Guns. Total L/D 147 Guns. 20"X 13-3/8"=0 psi,13-3/8"x 9-5/8"=80 Psi.9-5/8"X 7-5/8"=260 Psi.Daily brine lost to well=239 bbls.Total brine lost t/well=4883 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 0 lbs.String magnet 0 lbs.Boot baskets 0 lbs. 03/21/15-Saturday Continue POOH laying do 4 1/2 pert guns,All guns laid dn and all shots fired.Well taking 8 BPH. RD perf equip.Clean and clear rig floor. RU test equip and test BOPs that were used in well control to 250 and 3000 psi.Test upper rams,dart valve,TIW valve,Kill line HCR,Choke line,Choke manifold valves,2,4,5,9,15,and 16.All tests passed.RD test equip. RU to PU 2 7/8 gas lift completion. _ Checking all connections to make sure they are bucked up.PU to chem injection mandrel and RU control line sheave.RIH PU and drifting 2 7/8 EUE tbg.Installing cannon clamps on every other collar.MU SSSV at 330'and test same.Valve opens at 1700 psi. Continue RIH. MU hanger and tie in control lines.SSSV was pumped open to 5400 psi.Land hanger @ 34k blocks and top drive pick up =48k slack off 47k(38 total cannon clamps&9 total bands clamps). RILDS.RU Drop bar assem. Pressure up dn tbg to 3500 psi and set packer.Hold pressure for 30 min.Bleed off pressure off tbg. Test back side to 1500 psi for 30 min.nn.a.chart.Use chart recorder. Install BPV. N/D BOP.Suck out stack and flowbox.Remove flow box flange.Remove bell nipple.Remove annular flange.Remove mouse hole.Blow down all lines.Install strong back on bop stack. Crew Change. 20"X 13-3/8"=0 psi,13-3/8"x 9-5/8"=80 Psi.9- 5/8"X 7-5/8"=260 Psi.Daily brine lost to well=397 bbls.Total brine lost t/well=5289 bbls.Daily sized salt to well=0 bbls.Total SS to well=80 bbls.Ditch magnet 0 lbs.String magnet 0 lbs.Boot baskets 0 lbs. Continue N/D bops.Bolt springbuck onto the annular. Remove cellar stairs to upper level.Pick up BOP stack and move to the side.Pull 13 5/8 riser from wellhead and move to top deck. N/U Tree and install and Actuator. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 3/11/2015 3/22/2015 Daily Operations: 03/22/15-Sunday Nipple up tree and test void.MU safety valve and choke.Start to MU flow line and realized it needs modified.Get measurements and pull flow line down. Pull BPV and install TWC.Test tree to 250 and 5000 psi._Pull TWC,Lock SSSV open w/4500 psi,and RU slickline. Test lubricator to 250 and 5000 psi.Had to change out 1502 valve on side port of lubricator. Go over slickline PJ checklist.Run#1 JDC and recover drop bar.Run#2,Daniels kick over tool and attempt to recover dummy f/GLM.No recovery.Run#3,Run same kick over tool and recover dummy.Run#4,Run in and set live valve in GLM.Run#5,RIH and pull dummy f/chem inject mandrel.Run#6,Set live valve in Chem inject mandrel.Run#7,Pull RHC plug.RD slickline.[Tbg had built up to 250 psi]. Moved 2 riser extensions onto rig floor.Moved bell nipple off the rig floor.Cleaned and organized. Well Kill:Pumped 35bbls of SSP @ 2bpm 20 psi do to 5 psi.Chased with 47bbls of KCL @ 3bpm 400 to 650 psi(Totaled pumped 82bbls Max Psi.650). PJSM and prepare to skid rig. iPuA--� f)Tb r(Bo7&c, Regg, James B (DOA) From: Marvin Rogers - (C) <mrogers@hilcorp.com> _ Sent: Friday, March 20, 2015 5:17 PM h71 3f z51 t6 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Trudi Hallett; Lenward Toussant - (C); Ted Kramer Subject: BOP used in well control Mr Regg Monopod Rig 56, A-18 While POH laying down our perf guns the well started to flow this morning. We PU our safety jt and had to shut in using our upper rams. We had 46 of the 164 gun layed dn. We then circ out an oil and gas influx. We ended up staging back in the hole circ every few stands and weighting up from 8.6 ppg to 9 ppg. We did get in close to the bottom of the perfs where we got the well killed. We will be POH shortly and plan on testing all the BOP equip used to kill the well. Thank you UHilcorp Alaska, LLC DSM Monopod Platform [907] 776-6675 E-Mail: mrogers@hilcorp.com tNNE© 73rk A-1P / O-77C) Regg, James B (DOA) From: Marvin Rogers - (C) <mrogers@hilcorp.com> Sent: Saturday, March 21, 2015 12:59 PM , 7 _'t'5((. To: Regg,James B (DOA); Brooks, Phoebe L (DOA) 1` Cc: Juanita Lovett; Lenward Toussant - (C) Subject: Monopod equip used in well control test. Attachments: 3-21-15 Well control BOP test notes.pdf Mr Regg Monopod Rig 56, A-18. We finally got out of the hole and got all our perf guns layed dn.The attached list is the equip we used in the well control situation. Our test started at 11:00 hrs and we were finished by 11:30 hrs.All tests passed! We are currently starting to PU our gas lift completion. UHilcorp Alaska, LLC makVt:!/I, R��1e1"S DSM Monopod Platform [9071776-6675 E-Mail: mrogers@hilcorp.com 1 kt.wpod fiF HILCORP 1730(A--li2, . 1 , 1 BOP TEST SHEET , , Prt logcru,0 -DATE: RIG CONTRACTOR: KUUKPIK RIG# 56 NEM 10:30:00 AM WELL NAME. A-18 TYPE OF OPERATION- (DRILLING I WORKOVER/OTHER): WORKOVER HILCORP REP: r—ROGERS/TOUSSANT RIG SUPERVISOR: BORGEN/DAVIESON SUPERINTENDENT: N/A TESTING COMPANY: N/A DP SIZES: 3.5 BOP SIZE&RATING: 13.5/8/5000 Test# Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail UPPER VARIABLE RAMS,HCR ON KILL LINE,31/2"DART VALVE, 1 CHOKE MANIFOLD VALVES#4,#5,#15,#16,31/2". 250- 3000- P/P UPPER VARIABLE RAMS,HCR ON KILL LINE,31/2"TIW VALVE, ... 2 CHOKE MANIFOLD VALVES#2,#4.#5,#9#16 5/5 - 250- 3000 P/P 3 5/5 4 5/5 5 5/5 6 '5/5 7 5/5 8 5/5 9 5/5 10 5/5 11 5/5 411 ME II 5/5 11.1.1 Ell 111111 = MI=allilMalli lE1111111111K1 allEll. 1 111M Millir1111111111111111111111111111111 = I Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure Final Pressure Re-charge Time Hiicer epresentativ Signature 1— Rig Supervisor Signature: Contract Testing Representative Signature: 1 ,; \�F�j,�,s7 THE STATE Alaska Oil and Gas "�` �"' °fALASKA Conservation Commission • ttit 333 West Seventh Avenue .i'1" Anchorage Alaska 99501-3572 ITh;, GOVERNOR BILL WALKER g Main: 907.279.1433 O .4LAS�� SCANNED Ml n ,�.) Fax: 907.276 7542 www.aogcc.alaska.gov Trudi Hallett Operations Engineer /4' \,..y6., Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai D and E and Hemlock Oil Pools, TB ST A-18 Sundry Number: 315-122 Dear Ms. Hallett: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, ' Iet- Cathy . Foerster Chair DATED this /D day of March, 2015 Encl. r RECEIVED MAR 0 5 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.214n 1 Type of Request: Abandon❑ Plug for Redrdl 0 Perforate New Pod 0 Repair Well❑ Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pul Tubing 0 Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: Complete 074 0 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: L/ y Hilcorp Alaska,LLC • Exploratory ❑ Development 0 + 168-076 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00-00 . 7.If perforating 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93B r Will planned perforations require a spacing exception? Yes ❑ No 0 f Tracing Bay ST A-18 • 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai D Oil,Middle Kenai E Oil,Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth ND(ft): Effective Depth MD(ft) Effective Depth ND(ft): Plugs(measured). Junk(measured). 11,000- 10,241 " 9,550 8,791 N/A 9,550 Casing Length Size MD TVD Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,482' 9-5/8" 7,520' 6,860' 3,950 psi 2,570' Intermediate Liner 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,377' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade' Tubing MD(ft) See Schematic i See Schematic 3-1/2" 9.2# /RTS-8 5,959 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) Model D Perm Packer / SSSV Packer 5,916'(MD)5,333'(ND)/SSSV 316'(MD)316'(ND) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development.0 Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/10/2015 Oil 0 Gas 0 WDSPL ❑ Suspended 16.Verbal Approval Date' WINJ 0 GINJ 0 WAG ❑ Abandoned C Commission Representative: GSTOR ❑ SPLUG C 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thalletta()hilcorp.com Pnnted Name TTrruudi Hallllllett Title Operations Engineer Signature /11.40141,�^ Phone 907-777-8323 Date 3/5/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number / 3l5 - 122 Plug Integrity ❑ BOP Test ® Mechanical Integrity Test ❑ LocationpClearance ❑ l Other y_ 3 ' IDSL 13a, -mss frost i- c z ZZ:O /.f':. J Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required. / ` b -U 0 11 APPROVED BY Approved by: ,44.e....404...._e/ COMMISSIONER THE COMMISSION Date. 3 -/0 _/S_ 3.1 /,3' / /lS i116 3-,..-.5 ORIGINAL ,, tiff- RBDMSA' MAR 1 1 2015 Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis Well: A-18 Hilcorp Alaska,LLC Date: 3/5/2015 Well Name: Monopod A-18 API Number: 50-733-20143-00 Current Status: Water Injector Leg: N/A Estimated Start Date: March 10,2015 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 168-076 First Call Engineer: Trudi Hallett (907)777-8323 (0) (907)301-6657 (M) Second Call Engineer: Ted Kramer (907) 777-8420(0) (985)867-0665 (M) AFE Number: Current Bottom Hole Pressure: 2,943 psi @ 6,654' TVD (7,305 MD) Using BHP survey from 2009 Maximum Expected BHP: 2,943 psi @ 6,654' ND 21`{3 - GGOr›L % ZZ g 3,�s� AA 25.280 Max. Allowable Surface Pressure: �si (Using .1psi/ftgradientper 20 C p (b)(4)) Zzsl3ps� . . Brief Well Summary A-18 is a Tyonek and Hemlock gas lift producer that was last worked over in 2013.This workover will consist of pulling the current completion, perfing add'I sands,and running new gas lift completion. Procedure: 1. Skid Monopod Rig#56 and RU over A-18. 2. Circulate hydrocarbons off well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250psi LOW and 3,000psi HIGH. 4. Unseat Hanger and pull tubing free of seals. POOH laying down production tubing. 5. RIH and recover production packer at 5,181'. POOH with same. 6. RIH and clean out to 9,550 and circulate clean. 7. RIH with TCP guns and perforate per program. IA 8. PU and RIH with gas lift production tubing string w/ packer @ +/- 2300' and hang off same. Test to 1500 psi charting for 30 min. 9. ND BOPE, NU wellhead and test. 10. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current /Proposed Wellhead Diagram(same) 4. BOP Stack Trading Bay Unit SCHEMATIC Well: A-18 Hiicore Alaska,LLC Completed: 09/20/13 CASING DETAIL RKB to TBG Hngr= 37.00' Size Wt Grade Conn ID Top Btm 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 1 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 1 9-5/8" 40 K-55 Buttress 8.835 67' 4191' ' 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' t, 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' e 13-3/8" STAGE COLLAR 5,598' 5,600' 7-5/8„ 29.7# L-80 SLID-2 6.875 Surf 7,488' �' Liner _ P7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL d J 3-1/2" I 9.5# I RTS-8 I I I Surf I 5,959' i 2 .> JEWELRY DETAIL tMeasured NO. ID Item 3 A« Depth DV Collar 5,598' 37.0' Cameron 5M Tubing hanger w/3.5 8rd Box x 1 316' 2.812" SSSV 4 1e 2 2,174' 2.920" RTS-8 GLM 3 3,684' 2.920" RTS-8 GLM w 4 4,601' 2.920" RTS-8 GLM 5 5 5,181' 2.920" RTS-8 GIM 6 5,727' 2.920" RTS-8 GLM 6 7 5,867' 2.920" Chemical Injection Mandrel i 8 5,916' 4.000" Model"D"Permanent Packer w/Seal assembly 9 5,948' 2.813" X Nipple 6 10 5,959' 2.992" WLEG a I - 9 1. a == 10 Fish 1 09/17/13 Half of the packer slip cone and bottom packer slips pushed to bottom. 9,550' J &�j� PERFORATION DETAIL A _ 9-5/8" Top Btm Top Btm Zone (MD) (MD) (ND) (ND) Amt. SPF Last Date Status D Hemlock 6,010' 6,150' 5,423' 5,557' 140' 09/13/13 Open = D 54-9 7,320' 7,436' 6,669' 6,780' 116' 09/13/13 Open D 55-7 7,450' 7,533' 6,794' 6,873' 83' 09/13/13 Open D 55-7 7,544' 7,570' 6,883' 6,908' 26' 09/13/13 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 1/89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 6/79 Open -- D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 1/89 Open D 56-1 7,790' 7,870' 7,113' 7,187' 80' 09/13/13 Open - E D 56-1 7,904' 8,030' 7,218' 7,333' 126' 09/13/13 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 1/75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 11/70 Open D-57-2 8,104' 8,158' 7,400' 7,449' 54' 09/13/13 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 6/79 Open 0 57-2 8,425' 8,555' 7,696' 7,819' 130' 09/13/13 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 6/79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 09/13/13 Open Hemlock E 58-1 8,660' 8,675' 7,920' 7,934' 15' 09/13/13 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 09/13/13 Open _ E 60-0 8,916' 8,965' 8,167' 8,215' 49' 09/13/13 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 6/79 Open /// 7" E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 6/79 Open E 60-5 9,074' 9,120' 8,322' 8,367' 46' 09/13/13 Open KB ELEV=101' E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 11/70 Open PBTD=9,550' TD= 11,000' Hemlock 9,210' 9,290' 8,455' 8,534' 80' 09/13/13 Open ANGLE thru INTERVAL=24.9° Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 11/68 Open Hemlock 9,330' 9,360' 8,574' 8,603' 30' 09/13/13 Open Revised By:JLL 10/21/2013 14 PROPOSED Trading Bay Unit Well: A-18 HilcoruAlaska,LLC Completed: Future CASING DETAIL RKB to TBG Hngr= 37.00' Size Wt Grade Conn ID Top Btm _ 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 4 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' ., T t e 13-3/8" STAGE COLLAR 5,598' 5,600' 7-5/8" 29.78 L-80 SLIJ-2 6.875 Surf 7,488' i , Liner , y 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL r 2-7/8" I 6.58 I L-80 I 8rd EUE I I Surf I ±2,340' ,9 '� 1 Measured JEWELRY DETAIL i, NO. ID Item Depth t, i114 17 37.0' Tubing Hanger 2 H p 1 ±300' SSSV 1 23 a 3 ±2,300' Orifice-1/GLM s rr 3 ±2,300' Packer s 4 ±2,330' X Nipple 1 I _ I 4 V 5 ±2,340' WLEG 5 I. / PERFORATION DETAIL m Top lo t B Zone Top(MD) (MD) (TVD) Btm(TVD) Amt. SPF Last Date Status e B 24-6 ±2,390' ±2,455' ±2,176' ±2,233' ±65' Future -, DV Collar 826-7 ±2,567' ±2,700' ±2,331' ±2,448' ±133' Future 5,598' i, 4 BZNS6S ±2,880' ±2,900' ±2,606' ±2,623' ±20' Future } BZNS9S ±3,120' ±3,143' ±2,813' ±2,833' ±23' Future B 31-8 ±3,168' ±3,210' ±2,855' ±2,891' ±42' Future J B 33-6 ±3,334' ±3,384' ±2,996' ±3,038' ±50' Future C B 41-3 ±3,480' ±3,510' ±3,118' ±3,143' ±30' Future B 44-7 ±3,903' ±3,984' ±3,479' ±3,550' ±81' Future C C-2 ±4,078' ±4,130' ±3,634' ±3,681' ±52' Future ; C C-3 ±4,164' ±4,240' ±3,712' ±3,781' ±76' Future 1 C C-4 ±4,308' ±4,420' ±3,843' ±3,945' ±112' Future 1 i C 49-4 ±4,535' ±4,576' ±4,051' ±4,088' ±41' Future 9-5/8" C 49-4 ±4,854' ±4,884' ±4,343' ±4,371' ±30' Future C 49-4 ±4,925' ±4,980' ±4,408' ±4,459' ±55' Future ti = C 50-0 ±5,150' ±5,176' ±4,615' ±4,638' ±26' Future C 50-6 ±5,240' ±5,398' ±4,697' ±4,843' ±158' Future I D C 51-6 ±5,451' ±5,690' ±4,893' ±5,117' ±239' Future 0 53-0 ±5,752' ±5,910' ±5,176' ±5,327' ±158' Future Hemlock 6,010 6,150' 5,423' 5,557' 140' 9/13/2013 Open D 54-9 7,320' 7,436' 6,669' 6,780' 116' 9/13/2013 Open D 55-7 7,450' 7,533' 6,794' 6,873' 83' 9/13/2013 Open 0 55-7 7,544' 7,570' 6,883' 6,908' 26' 9/13/2013 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 Jan-89 Open 0 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 Jun-79 Open D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 Jan-89 Open D 56-1 7,790' 7,870' 7,113' 7,187' 80' 9/13/2013 Open D 56-1 7,904' 8,030' 7,218' 7,333' 126' 9/13/2013 Open E D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 Jan-75 Open D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 Nov-70 Open D-57-2 8,104' 8,158' 7,400' 7,449' 54' 9/13/2013 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 Jun-79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 9/13/2013 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 Jun-79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 9/13/2013 Open E 58-1 8,660' 8,675' 7,920' 7,934' 15' 9/13/2013 Open Hemlock E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 9/13/2013 Open E 60-0 8,916' 8,965' 8,167' 8,215' 49' 9/13/2013 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 Jun-79 Open r 7" E 60-5 9,066' 9,116' 8,314' 8,363' S0' 8 Jun-79 Open E 60-5 9,074' 9,120' 8,322' 8,367' 46' 9/13/2013 Open KB ELEV=101' E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 Nov-70 Open Hemlock 9,210' 9,290' 8,455' 8,534' 80' 9/13/2013 Open PBTD=9,550' TD=11,000' Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Nov-68 Open ANGLE thru INTERVAL=24.9° Hemlock 9,330' 9,360' 8,574' 8,603' 30' 9/13/2013 Open Revised By:JLL 03/04/15 Monopod Platform A-18 Current 09/14/2013 H�irurp thtsku.1,1.(, Monopod Platform Tubing hanger,SME-CL,11 X A-18 3 Y EUE lift and susp,w/3" 133/8X95/8x75/8x Type H BPV profile,3-3/8 3 1/2 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 111 mffii Valve,Swab,WKM-M, '.0 4 3 1/8 5M FE,HWO,DD trim • , Valve,Wing,WKM-M, 31/85MFE,w/15' OMNI operator,DD trim I lir o Valve,Master,WKM-M, O. 3 1/8 5M FE,HWO,DD trim - ®0 _nl Oo Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim O. $1,ze X3 111' •I Control line �Z�IIEI Tubing head,S-8,11 5M x lii Ilglfabk 11 5M,w/2-2 1/16 5M SSO, � - , w/BG bottom w/2-21/165M WKM-M 11i�• • � valves Kt" II 9 is- _ag riniP 6i-.i.■= Casing spool,5-8,13 5/8 3M 3313 I' _ pi 1i1 x115M,w/2-21/16 SM SSO,w/BG bottomt-ic Ii- I. 1iIa- Jill Casing head, Shaffer KD, " 13 5/8 3M X 1111 ' 1/1 13 3/8 SOW,w/2-2" LPO, ■ i'1' ,f10fT; \.1. Caa7l j C Monopod Platform 2013 BOP Stack 03/12/2013 Hilrurp:Alaska. Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 950' Pipe lii;lii■iilriiii fit o i I - 01)IItill 1f11[fl1 tIl 3.74' Shaffer 13 5/8 SM iii lii iii iii I 26.25' Shaffer LXT 2 7/8.5 Variables 2.50' 133©M s . Blind . I'1 III I 1.76 . '11 �1 � �1: �� • l Mud Cross 135/85MFEXFE w/31/8 5M EFO WI 2 1/16 5M Choke and Kill valves wi Unbolt end 1t 1,:1' il' il• connections for lines 2.83' �� Dual Cameron Flex rams Ili i7;717 11I; II .70' 1 J14111441 It V Drill deck 14.20" UOCD 1911 Riser 14.20' 135/8 SM FE 8135/85M FE 111 Eitl ffil ffil III 1111 Spacer spool 1.5' 135/85M fIX 11 I1M I 111= Ili 111111 III i Wellhead @ 15.00' RECEIVED STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMM ION OCT 2 2 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC, 1.Operations Abandon❑ Repair Well p , Plug Perforations ❑ Perforate p , Other El Install Gas Lift Performed: Completion Alter Casing ❑ Pull Tubing El • Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory❑ 168-076 . 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 . Trading Bay St A-18 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • Trading Bay St/Middle Kenai D Oil,Middle Kenai E Oil,Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,000 feet Plugs measured N/A feet true vertical 10,241 feet Junk measured 9,550 feet Effective Depth measured 9,550 feet Packer measured 5,916 feet true vertical 8,791 feet true vertical 5,333 feet Casing Length Size MD ND Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,025' 3,090 psi 1,540 psi Surface 7,482' 9-5/8" 7,520' 6,860' 3,950 psi 2,570 psi Intermediate Liner 7,488' 7-5/8" 7,488' 6,830' 6,890 psi 4,790 psi Liner 2,377' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.5# /RTS-8 5,959'(MD) 5,374'(ND) 5,916'(MD) 316'(MD) Packers and SSSV(type,measured and true vertical depth) Model"D"Perm Pkr 5,333'(ND) SSSV 316'(ND) 12.Stimulation or cement squeeze summary: ,;; Intervals treated(measured): t*E® )�'� ' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 5 Subsequent to operation: 135 50 568 1000 70 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IS - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p • Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-097&313-445 Contact Ted Kramer Email tkramert hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature .�%'%I � Phone (907)777-8420 Date 10/21/2013 Form 10-404 Revised 10/2012 ��y/3 RBDMS OCT 2 5 2tr 1!,.mit Original Only,,,,, • Trading Bay Unit • SCHEMATIC Well: A-18 Nikon)Alaska,LLC Completed: 09/20/13 CASING DETAIL RKB to TBG Hngr= 37.00' Size Wt Grade Conn ID Top Btm i i 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' j ! 1 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' 13-3/8" STAGE COLLAR 5,598' 5,600' 7-5/8" 29.7# L-80 SLIT-2 6.875 Surf 7,488' Liner 7"Liner 29 N-80 Buttress 6.184 7,489' 9,826' TUBING DETAIL 3-1/2" 9.5# RTS-8 I I I Surf I 5,959' I um 2 JEWELRY DETAIL Measured 0 INF .4 3 NO. Depth ID Item Dv Collar 37.0' Cameron 5M Tubing hanger w/3.5 8rd Box IR 5,598' 1 316' 2.812" a 2 2,174' 2.920" SSSV RTS-8 GLM 3 3,684' 2.920" RTS-8 GLM 4 4,601' 2.920" RTS-8 GLM 5 11, 5 5,181' 2.920" RTS-8 GLM i , 6 5,727' 2.920" RTS-8 GLM ; i e 1 i 7 5,867' 2.920" Chemical Injection Mandrel �/w " 8 5,916' 4.000" Model"D"Permanent Packer w/Seal assembly 9 5,948' 2.813" X Nipple 8 10 5,959' 2.992" WLEG i 1 9 tFish 09/17/13 Half of the packer slip cone and bottom packer slips pushed to bottom. 9,550' PERFORATION DETAIL 9-5/8" Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) Amt. SPF Last Date Status D Hemlock 6,010' 6,150' 5,423' 5,557' 140' 09/13/13 Open D 54-9 7,320' 7,436' 6,669' 6,780' 116' 09/13/13 Open = D 55-7 7,450' 7,533' 6,794' 6,873' 83' 09/13/13 Open D 55-7 7,544' 7,570' 6,883' 6,908' 26' 09/13/13 Open D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 1/89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 6/79 Open = D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 1/89 Open = D 56-1 7,790' 7,870' 7,113' 7,187' 80' 09/13/13 Open E D 56-1 7,904' 8,030' 7,218' 7,333' 126' 09/13/13 Open D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 1/75 Open c D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 11/70 Open D-57-2 8,104' 8,158' 7,400' 7,449' 54' 09/13/13 Open D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 6/79 Open D 57-2 8,425' 8,555' 7,696' 7,819' 130' 09/13/13 Open E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 6/79 Open E 58-1 8,610' 8,650' 7,872' 7,910' 40' 09/13/13 Open c Hemlock E 58-1 8,660' 8,675' 7,920' 7,934' 15' 09/13/13 Open E 58-7 8,734' 8,832' 7,991' 8,086' 98' 16 09/13/13 Open _ E 60-0 8,916' 8,965' 8,167' 8,215' 49' 09/13/13 Open E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 6/79 Open ////////////////////////////////////////////// 7-- E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 6/79 Open E 60-5 9,074' 9,120' 8,322' 8,367' 46' 09/13/13 Open KB ELEV= 101' E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 11/70 Open PBTD=9,550' TD= 11,000' Hemlock 9,210' 9,290' 8,455' 8,534' 80' 09/13/13 Open ANGLE thru INTERVAL=24.9° Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 11/68 Open Hemlock 9,330' 9,360' 8,574' 8,603' 30' 09/13/13 Open Revised By:JLL 10/21/2013 • • Hilcorp Alaska, LLC • Nileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 Daily Operations: 08/11/13-Sunday Remove beaver slide.Skid rig north 20'.Move jacks and skid rig over well center A-18.Install seismic clamps.Install pony sub,beaver slide and catwalk.Install handrails and secure after rig move.Install mud line to rig.Install blower ducting.Hook up deluge line.Mix 230 bbls 9.5 ppg 3%KCL.Rig up circulating lines on A-18 tubing.Pressure test to 1500 psi.Tubing @ 380 psi before starting.Bullhead 75 bbls of 9.5 ppg 3%KCL down tubing @ 1 BPM with maximum psi of 710 psi.Shut down bullhead.FCP=450 psi.Bleed down tubing and 9 5/8"annulus to 0 psi until well is static on both.13 3/8"annulus=50 psi.Monitor well for zero flow for 30 minutes.Set BPV. Nipple down tree.Tree flange bolts were corroded and had to be driven and cut out.Verify that tubing hanger threads are 3 1/2 EUE. Dress tubing spool flange.Fluid loss today 3%KCL 75 bbls.Total 3%KCL loss 75 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls -Loss rate average-0 BPH-Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 0 lbs. 9 5/8"/0 psi./13 3/8"/50 psi. 20"/0 psi 08/12/13-Monday Clean and dress tubing spool after removing tree.Install Riser.Nipple up bop's,torqueing riser,connect jumper for BOP hoses. Removing lifting bar from bop's,install bell nipple,&installing flow riser.Remove bell nipple to extend same.Function test bop's from remote station.Finish torquing up BOP.Install gas buster flow line.Install flow nipple.Make up test joint.Test BOPE at 250 L/3000 H on 5"and 2 7/8"and test annular at 250 L/3000 H on 5"and 2 7/8".Test witnessed by Chuck Scheve(AOGCC).All tests were good,no failures.Lay down test joint.Make up landing joint and circulating lines.Back out lock downs.Pull tubing hanger loose @ 95K by working several times.Work string up in 5K increments until string had free movement @ 115K.Pull tubing hanger to floor @ 92K without additional overpull.WLEG now+/-10'above packer @ 7438'.Well slightly flowing and bubbling.Circulate through choke manifold and gas buster @ 2-3 BPM/950-1400 psi.Had 56 bbls of 8.6 ppg dirty FIW in returns before getting 9.5 ppg drilling mud. Continue circulating and diverting drilling mud to RFR tank for a total of 337 bbls.13 3/8"annulus increased from 40 psi to 90 psi while circulating. **Gas monitor on possum belly failed,however the drilling mud was not gas cut.Shut down after circulating surface to surface volume.Open annular preventer.Observed well to be static.P/U weight 85K.Lay down landing joint and tubing hanger.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average- 0 BPH-Recovered 0 lbs ditch mags-0 lbs boot bskt total metal recovered 0 lbs. 9 5/8"/0 psi./13 3/8"/90 psi.20"/0 psi 08/13/13-Tuesday POOH laying down 3 1/2"completion string.Had full recovery of seals and WLEG.Minimal holes in tubing.Clear/clean rig floor,pipe deck,etc.Install wear bushing.Well is static.Make up BHA#1:8 1/2"packer mill,tripple connect sub,3 ea.7"boot baskets,bit sub w/float,bumper sub/oil jars,XO,9 ea.6 1/4"drill collars,XO=316.66,RIH with BHA#1 to 2685'.Circulate @ 5 BPM/425 psi with high of 440 gas units.RIH with BHA#1 2685'-5146'.Circulate @ 5 BPM/450 psi with high of 600 gas units.Back load 2 ea.ISO's with a total of 184 bbls of 9.5 ppg KWM from displacement.RIH with BHA#1 5146'-6300'picking up 5"drill pipe.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 0 lbs ditch mags.0 lbs boot bskt. total metal recovered 0 lbs. 13 3/8"annulus=75 psi. 20"annulus=0 psi. 08/14/13/13-Wednesday RIH with BHA#1.(8 1/2"packer mill,triple connect sub,3 ea.7"boot baskets,bit sub w/float,bumper sub/oil jars,XO,9 ea.6 1/4" drill collars,XO)=316.66'. F/6,447'T/7,438'looks to be fill. Circ and cond fluid at 7,438'at 5 bpm 36 psi max gas 390 unit fluid wt out 9.4 ppg,had excessive amount of sand on btms up. Wash down to 7,441'tagging top of WD pkr at 7,441'. Milling on 9 5/8 Otis WD packer f/7,441'tot/7,444'.Push packer to top of 7"liner at 7,491'dpm.Recovered 51 lbs metal f/ditches.Pump 25 bbls hi-vis sweep circ out same at 8 bpm 800 psi.Flow check(well static)POOH to change BHA.Lay down BHA#1.Recovered 112 lbs out of boot baskets.Pick up BHA#2:Itco spear with 5.008 nom catch,bumper sub/oil jars,XO,9 ea.6 1/4"drill collars,XO=303.43'.Clear rig floor.Service rig.Well is static.RIH with BHA#2 to 7,470'.Pick up Kelly.Establish parameters:P/U 170K,S/0 130K 8 BPM/750 psi. Circulate bottoms up @ 8 BPM/750 psi.5 units of gas at bottoms up.Engage fish @ 7,491'while circulating @ 3 BPM/300 psi.Set down 15K and work into fish to 7,493'.Pump pressure increased to 800 psi.Pick up and set down 6 times.Set Kelly back.POOH with BHA#2.Occasional 5K overpull on trip out.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 68 lbs ditch mags.112 lbs boot bskt. Total metal recovered 180 lbs. 13 3/8" annulus=65 psi. 20"annulus=0 psi. • • Hilcorp Alaska, LLC Hilc.orp Alaska,IAA: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 Operations: 08/15/13/13-Thursday POOH with BHA#2:Itco spear with 5.008 nom catch,bumper sub/oil jars,XO,9 ea.6 1/4"drill collars,XO=303.43'.POOH w/ BHA #2,lay down spear and fish,fish total 1.0 ft.Make up BHA#3=8-1/2 bit, 9-5/8 csg scraper,bit sub w/float,bumper sub/oil jars,X0,9 ea.6 1/4"drill collars,XO=307.80'Trip in hole w/BHA#3 filling pipe every 25 stands tagged top of liner at 7,492'.Circ and cond hole at 6 bpm,pump 15 bbls hi vis sweep and circ same around.0 gas units.Continue to circulate @ 8 BPM/700 psi while waiting on logging tools.POOH with BHA#3 and lay down 9 5/8"scraper assembly.Housekeeping and rig maintenance while waiting on logging tools.Well is static.Rig up e-line and lubricator.Repair electrical plug on unit.Calibrate,program and troubleshoot communication problems with CAST tool/CBL/40 arm caliper logging tool.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 32 lbs ditch mags.0 lbs boot bskt. total metal recovered 212 lbs. 13 3/8"annulus=65 psi. 20"annulus=0 psi. 08/16/13-Friday Logging tool set down @ 1,050'. RIH with Halliburton CAST tool/CBL/40 arm caliper logging tool to 3,500'. RIH with Halliburton CAST tool/CBL/40 arm caliper logging tool to 7,480'.Had tight spot @ 6,450'but able to work through.Log from 7,480'to surface. Rig down e-line and Halliburton logging tools. Well is static.RIH with 3 stands of 41/4"drill collars and make up storm valve.Set storm valve @ 185'.Test @ 500 psi.Good test.Pull wear bushing.Nipple down BOPE.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 0 lbs ditch mags.0 lbs boot bskt. total metal recovered 212 lbs. 13 3/8"annulus=65 psi. 20"annulus=0 psi. 08/17/13-Saturday Nipple down BOPE and change out 13-5/8 3m.x 115m tubing spool to 135/8 3m x 11""5m csg spool.Install riser and BOP stack and nipple up same.Test head and pack off to 2500 psi for 15 min good test. Remove hoist,nipple up bell nipple. Rig up test jt and test BOP's and related surface equipment to 250 psi low,3000 psi high.Annular BOP to 250 psi low and 2500 psi high.Test w/5"and 2- 7/8 pipe. Conduct Koomey draw down test. Test witness waived by Mr.Jim Regg w/the AOGCC at 10:14 AM 8/17/13.Set wear bushing. L/D test jt.RIH to 184'and wash down to top of RTTS. Screw into RTTS.P/U 5K over and release RTTS,well was static.L/D circ hose and head pin.POOH and L/D RTTS BHA.M/U BHA#4,6"bit,bit sub w/float,XO,1 jt 4"dp,XO,8 1/2"string mill,6 1/4 bumper sub,6 1/4 oil jar,X0,9 each 6 1/4 DC's,XO.RIH filling pipe at 2500'@ 5 BPM/275 PSI,continue in hole depth at rpt time 6,635'. 08/18/13-Sunday Continue TIH w/bha#4,6"bit,bit sub w/float,XO,1 jt 4"dp,X0,8 1/2"string mill,6 1/4 bumper sub,6 1/4 oil jar,X0,9 each 61/4 DC's,XO.=345.89. P/u wt 205 k s/o wt 115k,work down into 7"liner f/7,492'to 7,495'tagging fill at 7,495'.Lay down two singles& pick up Kelly. Brk circ at 5.5 bpm/300 psi p/u wt 190k w/s/o wt 130k RWT 160k,wash and rotate on fill f/7,495'to 7,521'w/ RP 15/ 13000 FTLBS,5K WOB,Pump 18 bbls HI VIS PILL. Pick up out of liner circ out same at 11 bpm/1015 psi. At btm got back mud and sand. Max gas 295 units,continue to circ out gas,pick up to 7,446'shut down pump monitor well for 1 hr.Well static. RIH to 7,521' with no pump. Had no fill. Circ btm up at 10.5bpm 950 psi had no gas back. Flow check well(well Static)Pooh w/BHA#4.Lay down BHA#4. Service Rig.PU BHA#5,7 5/16 polish mill with a 8 1/4 no go at 8.10',bumper sub,oil jars,X0,9 DCs,XO=310.76'. RIH to top of liner at 7,492',and Kelly up.Attempt to work polish mill into liner to no avail.Try several RPMs,Bit Wts,and pump volumes with no change.No gas on bottoms up.Set Kelly back.POOH t/BHA.Stand back DCs,7 5/16"Polish mill was cut down to 7"for 1"of the mill.Break down mill and lay do tools.Service rig and perform derrick inspection.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 32 lbs ditch mags.0 lbs boot bskt. total metal recovered 244 lbs. 13 3/8"annulus=45 psi. 20"annulus=0 psi.[Shipped 240 bbls brine to Trading Bay]. 08/19/13-Monday Waiting on tools.Rig up e-Line.Run 6.14 gauge ring to 29'below liner top and tag fill.POOH and PU 6.6 gauge ring and RIH to bottom of liner top polish bore at 7,502'DPM.POOH and rig down e-line.PU BHA#6=6 3/4"tapered mill,XO,Top dress mill,Bumper sub,Oil jars,XO,9 DCs,XO,=312.04.RIH to top of 7"liner at 7,492',rotate inside liner at 7,492'had 150 psi increase in pump pressure. Ream f/7,492't/7,500' 0/5 WOB,17,000 ft lbs,circ btm up no gas.POOH lay down bha#6. Pick up BHA#7.PU 7"tapered mill,XO,Top dress mill,Bumper sub,Oil jars,XO,9 DCs,XO,=312.04. Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 32 lbs ditch mags.0 lbs boot bskt. total metal recovered 244 lbs. 13 3/8"annulus=45 psi. 20"annulus=0 psi. • • Hilcorp Alaska, LLC Hikorp .Iaskn.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 Daily Operation$ :. 08/20/13-Tuesday RIH with 7"taper mill to top of liner at 7,492'.Clean out liner top polish bore f/7,492'to 7,500'. Circ hole clean. No gas on bottoms up.POOH to BHA. Stand back DCs and lay dn BHA. Mill had slight wear on gauge section of mill and no-go also had wear marks where it had tagged the liner.Service rig.Work on wt indicator.Cut drilling line 102',and slip same.Clean floor and prep to PU BHA# 8=7"csg mule shoe jt 10'long,XO,X0,XO,Bit sub[float],bumper sub,oil jars,X0,9 DCs,XO,=316.65. RIH 7,470'filling pipe every 2,500'.Break circ and pump 81 spm w/355 psi. Slack off dn to top of liner and gained 100 psi at 7,491',continue slacking off and pump pressured up and packed off at 7,495'.Shut pump down and slack off to 7,498'where we started taking wt. Attempt to circ and pump pressured up to 1100 psi and held.PU and pressure bled back to 0 psi at 7,490'.Circ 1 1/2 bottoms up with no gas.POOH laying dn 18 jts and standing 70 stds back.Lay dn 9 DCs and BHA. Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 13 3/8"annulus=45 psi. 20"annulus=0 psi 08/21/13-Wednesday Finish laying down 6 1/2"DCs.Strap,drift,and tally 4"DP.PU and stand back 21 stds in the derrick.PU 6-4 3/4 DCs and stand them back in the derrick.Pull wear bushing and set test plug. Change upper rams to 7 5/8.Rig up to test with 7 5/8 test jt.Test bag to 250 low and 2500 psi high.Test upper rams to 250 low and 3000 psi high. Rig down and lay dn test equip.Pull valves and fittings from Hydro-matic tank.Install new valves and fittings in the Hydro-matic Fluid Level Adjusting Tank.Put glycol pump on system and test new valves and fittings.Working on drain system.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 9 5/8 X 13 3/8"annulus=50 psi. 13 3/8 X 20"annulus=0 psi 08/22/13-Thursday Waiting on csg equip.Finish testing and securing Hydro-matic tank.Work on winterizing sub base.Plumb in lines for taking cmt returns off annulas valves during the cmt job.Insulate behind OBM storage tank.Rig up line for production overboard line.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH. Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 9 5/8 X 13 3/8"annulus=50 psi. 13 3/8 X 20"annulus= 0 psi 08/23/13-Friday Waiting on csg tools. P/U tools for running csg and spot them on the rig floor.Rack and strap 22 jts of 7 5/8 STL csg.Rig up to run csg. Make up 7"seal,XO,2 jts csg,Float,and 1 jt of csg.Fill csg and check float.Float held.Run 7 5/8"csg. Run 49 jts STL and cross over to SLID-2.Continue RIH with 7 5/8 SLIJ-2 csg. Had 4900'in at 0600 hrs.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 9 5/8 X 13 3/8"annulus=35 psi. 13 3/8 X 20"annulus=0 psi 08/24/13-Saturday Pick up and run 7 5/8 csg.to 7481'.PU extra jt and find top of liner at 7485'. Work into seal bore on liner top 4'.Could see 7"csf stinger sliding in.Taking wt at 7489'.PU and space out with hanger and landing jt.Land out with bottom of stinger at 7488'.Rig up and circ. Rig down.Rig up to cmt.and cmt return tanks.Pump 3 bbls H2O,Test lines to 3000 psi,Pump 18 bbls mud push.Drop bottom plug.Batch up and pump 183 bbls.Drop top plug,Pump 10 bbls H2O,Displace with rig pump.Got back 18 bbls cmt through ann valve. Plug bumped 1 bbl early with a final pressure of 2100 psi.Pressure up to 2600 Psi and press bled down when pump shut down.Bled back to check float.Got back 4.4 bbls and floats held.Cmt in place at 2335 hrs.Open valves on cmt manifold and break down head. Had slight flow develop from csg,flow started increasing. Install head pin and valve,shut in and rig up circ hose.Open valve and csg had 230 psi.Bump pump in attempt to set plug.Pressure bled from 2400 psi to 1400 psi.Float failed.Lock in 1400 psi on csg and WOC.Wash out and pump out stack.Flush hoses and clean out tanks.Monitor pressure on 7 5/8 csg.Pressure was at 1350 Psi at 0600 hrs. Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 9 5/8 X 13 3/8"annulus=140 psi. 13 3/8 X 20" annulus=0 psi Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 08/25/13-Sunday Wait on cmt.Press had bled down from 1400 psi to 956 psi.Bleed off to trip tank.Got back 2.10 bbls and stopped.Monitor for 15 min with no flow.Back out landing jt.PU pack off and run same.Lay dn landing jt and prep stack for nipple dn.Nipple dn BOPs.Install tbg spool,tighten bolts and test to 2500 psi,Good test.Nipple up BOPS.Rig up to test BOP.Witness on BOP test was waived by Jim Regg, AOGCC. Test hydril to 250 low and 2500 Psi high,Test all other BOP equip to 3000 Psi high.Perform accumulator test.Tested BOPs on 4"and 2 7/8".Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 20 lbs ditch mags.0 lbs boot bskt. total metal recovered 264 lbs. 9 5/8 X 13 3/8"annulus=0 psi. 13 3/8 X 20"annulus=0 psi 08/26/13-Monday Rig dn BOP test equip and set wear ring. PU BHA#9-6 3/4"bit,Bit Sub[float],6 DCs,jars,accelerator,XO=212.64'. RIH with pipe out of the derrick=2187'.RIH picking up 4"DP to 4136'.RIH picking up 4"DP. Tag at 7338'. Kelly up,Drill cmt f/7338't/7346'.Drill hard cmt f/7346 t/7402'.Circ hole clean,got back cmt and black rubber.Test csg to 1200 psi for 30 min on a chart,good test.Drill f/ 7402't/7404',Drill float at 7404'.Continue drilling hard cmt to top of 7"XO sub at 7480'.Circ hole clean at a high rate,100 spm 1900 psi,recovered cmt and rubber.POOH to BHA.Lay dn jars and bit,stand back DCs. Rig up e-line to log.Run CBL.Fluid loss today 3% KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 31 lbs ditch mags.0 lbs boot bskt. total metal recovered 295 lbs. 9 5/8 X 13 3/8"annulus=0 psi. 13 3/8 X 20"annulus=0 psi 08/27/13-Tuesday Run CBL and rig down e-line.PU BHA#10=6"bit,2 Boot Baskets,Bit sub,oil jars,Bumper sub,6 DCs,Acc jars,XO=228.19'.RIH to 7453'and kelly up. Drill cmt f/7480 t/7520'and clean out fill to 7582'.Started holding wt like we taged fish early.Planned depth for fish was 7595'.Circ hole clean.Rack back Kelly. L/D 2 singles,TOH from 7582'to 228'(BHA). Break and L/D boot baskets and bit. Clean boot baskets.Recovered 2 ea.packer slip dies and fill debris.P/U BHA#11 as follows:6"Scallop Bottom Shoe,Rolling Dog Overshot,1 jt 5 3/4"Wash Pipe,Double Pin Sub,3 ea.Boot Baskets,Bit Sub w/Float,4 3/4 Lub Bumper Sub,4 3/4 Oil Jar,6-4 3/4 DC's,4 3/4 Accelerator Jar,XO Sub.Total BHA Length=270.59'.TIH from 270'to 3565'.FIll pipe,CBU @ 8bpm with 1100 psi.Continue TIH to 7527'(77 stds).P/U 10'pup jt and 1 single.P/U Kelly.Obtain parameters and attempt to wash over fish @ 7582'. 93K DN,150K PU,115K Rotate,5-10k WOB,40 RPM,8-10k TQ,5 bpm @ 560. PU off fish,kill rotary and set 15K down on fish.PU off fish with no over pull.Increase rotary to 70 RPM and WOB to 15K.Attempt to wash over fish with no success.Set Back Kelly.Flow Check well.TOH from 7582'to 270'(BHA).Stand Back 4 3/4"DC's.Pull fishing assembly to surface and inspect same.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 16.5 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 30 lbs ditch mags.0 lbs boot bskt. total metal recovered 325 lbs. 9 5/8 X 13 3/8"annulus=0 psi. 13 3/8 X 20"annulus=0 psi 08/28/13-Wednesday PU BHA#12=6"flat bottom metal muncher shoe,Rolling dog overshot,1 jt washpipe,Boot basket,X0,3 Boot baskets,bit sub, bumper sub,oil jars,6 DCs,Acc jars,XO=270.16'.RIH to top of fish at 7582'.Mill on junk and fish f/7482't/7486'.Started milling over faster f/7486't/7610',continue milling and washing down to 7643'.Looks like fish is inside washpipe.5 BPM,550 psi,7k torque, 50 RPM,2 to 8 bit wt. No gas,no losses to the well,and recovered 1 bbl sand.Circ 1-1/2 bottoms ups.Monitor well with no losses, POOH to BHA,break mill shoe.Had a 4-1/2"section of wireline wt bar wedged in the end.No recovery in washpipe,30 lbs of iron in junk baskets.P/U BHA#13 as follows:5-3/4"Scallop Bottom Shoe,Rolling Dog Overshot,1 jt 5-3/4"Wash Pipe,Double Pin Sub,3 ea. Boot Baskets,Bit Sub w/Float,4-3/4"Lub Bumper Sub,4-3/4"Oil Jar,6-4-3/4"DC's,4-3/4"Accelerator Jar,XO Sub.Total BHA Length =269.53'.Service rig and associated equipment.TIH with 4"DP from 270'to 7620'(78 stds).Pick Up Kelly and establish parameters. Break circulation @ 5 bpm with 650 psi, 93K DN, 150K PU, 120K Rot, 40 RPM, 7500 ft/lb off bottom torque. Shut down rotary and tag TOF @ 7643'.PU and establish rotation @ 60 RPM. Wash down to 7661'with little to no WOB.Shut Down and Shut in well due loss of power on platform. Monitor well.Start powering up rig,open up to well,check for flow,well static.Continue washing down f/ 7661'to 7719', @ 5 bpm, 60 RPM,4-6K WOB.Pump pressure increased from 650 psi to 750-800 psi and could not make hole. Note: Made 76'total this run from 7643'to 7719'. No losses to the well bore during fishing operations.Flow check well. Set back Kelly. Prep to TOH from 7719'.TOH Standing back 4"Drill pipe from 7719'to 5073'.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 16.5 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 70.5 lbs ditch mags.30 lbs boot bskt. total metal recovered 425.5 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=13 psi • • Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 [laity Operations: u ... . 08/29/13-Thursday POOH to BHA,hole taking proper fill.Break dn BHA.No recovery in mill or washpipe.Recovered 10 lbs of sand and silt in boot baskets.Also recovered a 2"long chunk of iron that looked like a rock.PU BHA#14=Bladed concave junk mill,3 Boot baskets,Bit sub,Bumper sub,oil jars,6 DCs,Acc Jars,XO=234.47'. RIH to 7680'. Kelly up.Milling and washing junk and fill f/7716't/7903', pumping 8 BPM,1300 psi,50 RPM,and running 8k to 12k on the torque.Started loosing circ,slow dn pump and PU 30'off bottom and regained partial circ.Had+/-60 bbl loss while still pumping 3 BPM.Pumped and spotted a 10 bbl size salt pill.PU and monitor well. After 20 min losses were at 48 BPH.Spotted another 10 bbl size salt pill. After 25 min loss rate was down to 25 BPH.Decided to go back to milling at a reduced pump rate.Mill f/7903't/8010'at 5 BPM 530 psi,with a loss rate of 18 BPH. Mill from 8010'to 8505' .5.5 bpm,650 psi,50 RPM,9K TQ, 3-5K WOB,158K PU, 95K S0, 125K Rot. Fluid Loss while Milling @ 6 BPH. Footage @ Midnight 7716'-8505'(789'@ 8 hrs Milling)AROP=98.6 FPH. Mill from 8505'to 8796'(291'@ 3hrs Milling)AROP 97 FPH, 5 bpm, 630 psi,50 RPM,9K TQ, 3-5K WOB,175K PU, 104K SO, 130K Rot.Flow Out 45%. Fluid Loss while Milling @ 5-6 BPH.Started taking weight @ 8796'.Mill from 8796'to 8823'with 10-15K WOB,8-10K TQ,6 BPM, 850 psi 90-100 RPM.Not making hole.PU off bottom,wash down with no rotation and tag withl5K.Circulate bottoms up.Flow check well,Set back Kelly,Prep to TOH from 8823'. Note:Total cleanout footage made today=1107'. No losses while circulating bottoms up.Fluid loss today 3%KCL 172 bbls.Total 3%KCL loss 189 bbls.Sized Salt Pill 20 bbls.Total sized salt pill loss 0 bbls-Loss rate average-0 BPH.Recovered 166 lbs ditch mags.0 lbs boot bskt. Total metal recovered 450 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi 08/30/13-Friday POOH to BHA.Break Mill and Boot Baskets out.Mill was worn down 2"and center was cored.Also had chunk of wireline tool stuck in the mill.Recovered 11 lbs of sand from Boot Baskets w/a couple chunks off the packer.PU BHA#15=6"Metal munching flat bottom rotary Mill,Rolling dog overshot,washpipe,Xo,3 boot baskets,XO,bumper sub,oil jars,6 DCs,acc jars,XO.=271.06'.RIH to 8800', space out so we would end up with enough Kelly.Mill over junk from 8823'to 8916',(93').Starting milling with 5 BPM,760 psi on bottom,50 RPM,5-10K WOB,8K free TQ,172K PU,102K SO, 129K Rot. Pump pressure gradually increased to 1600 to 1700 psi on bottom and 1300 psi off bottom @ 4 BPM, with 10-15K WOB.8K TQ,Tried more WOB but could not make hole.Hole taking 4 BPH while Milling. Circulate Bottom up. Rack back Kelly.L/D single,pull 1 stand, L/D single and 2 pups. Flow check well. Well static. No losses during CBU. TOH from 8752'to 5452'. Hole taking calculated hole fill.Continue to TOH from 5452'to 270'(BHA),L/D Accelerator Jar,Stand back DC's.Break out Metal Muncher Shoe. No fish in wash pipe. Break down and clean out junk baskets. L/D Wash Pipe Assembly. Recovered 15 lbs metal from Junk Baskets.MU BHA#16 as follows:6"OD Bladed concave junk mill,3 Boot baskets,Bit sub,Bumper sub,oil jars,6 DCs,Acc Jars,XO=234.41'. TIH from 234'to 4473'.Fill Pipe.Fluid loss today 3%KCL 64 bbls. Total 3%KCL loss 253 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Daily Loss rate average-2.6 BPH.Recovered 112 lbs ditch mags.0 lbs boot bskt. total metal recovered 562 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi 08/31/13-Saturday RIH with 6"bladed concave mill to 8900'.Mill and wash f/8916't/9081'.Hit bridge or junk.Mill on junk f/9081't/9106'.Kept changing parameters to get it to drill,30 to 70 rpm,3 to 15k bit wt,3 BPM to 7 BPM,250 to 1000 psi.At 9106'the press increased by 800 psi.Mill may be cored out.Rack back Kelly,L/D 2 singles.Monitor well with 6 BPH static losses. TOH from 9000'to 234',L/D Acc Jars,rack back DC's,Break off Mill,Clean out boot baskets. Recovered 3"long piece of sinker bar that was jammed inside ID of the Mill.Recovered 13.5 lbs Sand/Metal from boot baskets.PU BHA#17=6"Metal Muncher Flat Bottom Rotary Mill,Rolling dog overshot,5-3/4"Washpipe,Xo,3 boot baskets,Bit Sub,Bumper Sub,Oil Jars,3-1/2"Pump Out Sub,6 DCs,acc jars,XO.=272.74'.TIH from 272'to 8472'.Continue TIH from 8472'to 9038',pick up 15'space out pup,PU single,M/U Kelly,Break Circulation and establish parameters @ 5 BPM w/700 PSI,180k UP,104K DN,133K Rot,70 RPM,9K,Tag TOF @ 9106'. Attempt to Mill and wash over fish from 9106'. Encounter stall outs while trying to wash over with very little WOB.Continue to adjust parameters as needed and attempt to wash over fish @ 9106'.Fluid loss today 3%KCL 55 bbls.Total 3%KCL loss 308 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls- Daily Loss rate average-2.3 BPH.Recovered 99 lbs ditch mags.29 lbs boot bskt. total metal recovered 690 lbs. 9-5/8"X 13-3/8" annulus=0 psi. 13-3/8"X 20"annulus=0 psi. • Hilcorp Alaska, LLC • Hilcurp.t�a LL(' Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 Daily Op*rations, 09/01/13-Sunday Attempt to mill over fish and junk at 9106'.Couldn't get mill to cut,tried several parameters.POOH to BHA,break mill shoe,L/D wash pipe. Break out and clean boot baskets.Recovered 2 lbs sand and metal fines.PU BHA#18=Bladed metal muncher junk mill,3 boot baskets,bit sub,bumper sub,oil jars,pump out sub,6 DCs,acc jars,XO=236.31'.Service Rig.Repair Mouse hole cover.TIH from 236' to 9001',PU 3 singles,PU Kelly,Tag TOF @ 9106'.Begin Milling from 9106'to 9117'.Pump 5.5 BPM,750 PSI,50 RPM @ 8K TQ,180K PU,108 SO,132 Rot. Reached depth of 9117'@ 2100 hrs. Attempt to mill past 9117'with no success. Mill partially plugged. Made 11'this run.(11'@ 4 hrs milling=2.75 FPH AROP). Adjusted parameters as needed 0-20 WOB,0-70 STK,20-100 RPM.Set Back Kelly. Monitor Well. Static Loss @ 6 BPH,TOOH from 9100'to 6450',drop circ sub shear dart,pooh to 6360'.Pressure up and shear open circ sub @ 1200 psi.Continue to TOOH from 6360'to 236',L/D Accelerator Jar,Stand back DC's.Break out Mill. Break down and clean out junk baskets. L/D BHA in preparation to Test BOPE. Recovered 14 lbs metal/Debris from Junk Baskets.OD of Junk Mill was tapered to a bull nose.Pull Wear Bushing,PU Kelly,M/U perforated stinger to Kelly and flush stack prior to testing BOPE.L/D Stinger. Rig up to test BOP.Fluid loss today 3%KCL 13.5 bbls.Total 3%KCL loss 321.5 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls- Daily Loss rate average-.50 BPH.Recovered 218 lbs ditch mags.2 lbs boot bskt. Total metal recovered 879 lbs. 9-5/8"X 13-3/8" annulus=0 psi. 13-3/8"X 20"annulus=0 psi. Notice to test BOP sent to AOGCC via email on 9/1/13 @ 8:26 AM. Louis Grimaldi of AOGCC waived witness via email 9/1/13 @ 12:50 PM. Static Loss @ 2 BPH @ 05:00 HRS 09/02/13-Monday Rig up to test BOPS.Test Hydril to 250 psi low and 2500 psi high on 4"and 3 1/2". Test all other BOP equip to 250 psi low and 3000 psi high.Test upper pipe rams w/4"and 3-1/2".Perform accumulator test.Witness of test waived by Lou Grimaldi,AOGCC.PU BHA#19 =6"4 bladed concave metal muncher junk mill,3 Boot baskets,Bit sub,Bumper sub,Oil jars,Pump out sub,6 DCs,Acc Jars,XO= 236.33'.RIH to 9096',Kelly up,Break Circulation,establish parameters,5 BPM @ 670 PSI,50 RPM w/10K TQ,178K PU,101K S0,135K Rot.Load sweep in pipe,fan bottom when sweep was at the Mill.Start Milling from 9117'to 9121'.Encounter 800 psi pressure spike to 1500 PSI.Pick up off bottom with same pressure off bottom.Appear to have cored out Mill.Dry tag with no rotation @ 9121'.Set Back Kelly, TOOH from 9121'to 8907'.Drop circ sub bar,open circ sub,flow check well,well static. Continue to TOH from 8907'to 5040'.Continue to TOH from 5040'to BHA,L/D Acc Jars,rack back DC's,Break off Mill,Clean out boot baskets. Recovered 13 lbs Metal from boot baskets. Mill was cored with junk in the OD of the Mill.PU BHA#20=6"OD x 4'ID Metal Muncher Flat Bottom Rotary Mill,Rolling dog overshot,5 3/4"Washpipe,Xo,3 boot baskets,Bit Sub,Bumper Sub,Oil Jars,3-1/2" Pump Out Sub,6 DCs,acc jars,XO.=271.64'.TIH from 270'to 6300'with Mill Shoe BHA.Fluid loss today 3%KCL 13.5 bbls.Total 3% KCL loss 321.5 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls-Daily Loss rate average-.50 BPH.Recovered 61 lbs ditch mags. 14 lbs boot bskt. Total metal recovered 954 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi 09/03/13-Tuesday RIH to 7450'with BHA #20=6"OD x 4'ID Metal Muncher Flat Bottom Rotary Mill,Rolling dog overshot,5-3/4"Washpipe,Xo,3 boot baskets,Bit Sub,Bumper Sub,Oil Jars,3-1/2"Pump Out Sub,6 DCs,acc jars,XO.=271.64'.Cut drilling line 150 ft&service rig.Circ thru cmt line at 5 bpm 195 psi. Trip in hole to 9105',Pump 12 bbls sweep and pump down hole and sweep btm with same,tagged up at 9121'dpm. Milling on Wireline tools at 80 RPM/8k ft bls torque,pu wt 180k,rt wt 131k,s/o wt 105k.Milled f/9121'to 9138'dpm wob 2/4k,pumping at 5 bpm at 700 psi,pipe stalled out,pick up pipe,Pump 6 bbls sweep and circ same. Milling f/9138'to 9141' while finish pumping out sweep not making any more hole. Flow check(well static).POOH slow from 9141',L/D Acc Jars,rack back DC's.Break off Mill,recovered 4 pieces of wire line tools equaling 45 inches long jammed inside shoe,below rolling dogs. Recovered 18'3"long perf gun in rolling dog and wash pipe.Clean out boot baskets and recovered 28.5 lbs Metal from boot baskets. Total length of fish recovered this trip=22 ft. Fire head assembly was fished below the guns.PU BHA#21=6"OD x 4-1/2"ID Metal Muncher Flat Bottom Rotary Mill, Rolling dog overshot, 5-3/4"Washpipe, Xo, 3 boot baskets, Bit Sub, Bumper Sub, Oil Jars, 3- 1/2"Pump Out Sub, 6 DCs, acc jars, XO.=272.72'.TIH from 272'to 4512'@ midnight.Continue TIH from 4512'to 9038'(93 stds). P/U 5'pup,stand 94 and Lay down top single=93 stds and double=9106'.M/U Kelly.Break Circulation and establish parameters @ 5 BPM w/700 PSI,180k UP,105K DN,133K Rot,60 RPM,7K Off BTM TQ,Tag TOF @ 9141'.Mill and wash over fish from 9141'to 9156', 5-10K WOB,9-10K TQ.50-80 RPM.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 321.5 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls Daily Loss rate average-.0 BPH.Report Time Loss to Well=0 BPH Recovered 136 lbs from ditch mags.Recovered 41.5 lbs from Boot Baskets.Total metal recovered 1076 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi • I Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 pally Op :ns: 09/04/13-Wednesday Mill and wash over fish from 9,141'to 9,156',5-10K WOB,9-10K TQ.50-80 RPM5 BPM w/700 PSI,180k UP,105K DN,133K Rot,60 RPM.Pooh to BHA.Lay down shoe and boot baskets.Recovered total of 10.20 ft section of 2-1/8"perf gun making total of 29.0 ft of perf gun recovered. Service Rig.Pick up BHA#22=6"OD x 5"ID Scallop Bottom Rotary shoe, Rolling dog overshot, 5-3/4"Washpipe, Xo, 3 boot baskets, Bit Sub, Bumper Sub, Oil Jars, 3-1/2"Pump Out Sub, 6 DCs, acc jars, X0.=271.90.TIH from 272' to 9,131'(94 stds).M/U Kelly.Break Circulation and establish parameters @:5 BPM w/680 PSI,173k UP,101K DN,133K Rot,60 RPM,9K Off BTM TQ. Tag TOF @ 9150'. Mill and wash over fish from 9,150'to 9,160'. Stopped making hole @ 9,160'. 0-15K WOB, 9-10K TQ. 20-80 RPM, 0-6 BPM.Set Back Kelly.Flow Check Well with 0 BPH Losses. TOH from 9,150'to 272'.L/D Acc Jars,rack back DC's. Break off Mill and Rolling dog Overshot.Recovered a 5'3"section of 2-1/8"perf gun. Clean out boot baskets and recovered 9.5 lbs Metal from boot baskets. Lay down 5 3/4"Wash Pipe.Fish Recovered this run=5.30'Perf Gun.Total Fish Recovered=38.00'P/U BHA#23=6" Six Bladed concave junk mill, 3 Boot baskets, Bit sub,Bumper sub, oil jars, 3-1/2"Pump Out Sub, 6 DCs, Acc Jars, XO=235.94'.TIH from 235' to 8,950'.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 321.5 bbls. Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls Daily Loss rate average-.0 BPH. Report Time Loss to Well=0 BPH Recovered 142 lbs from ditch mags.Recovered 14 lbs from Boot Baskets Total metal recovered 1,232 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi 09/05/13-Thursday P/U single and MU Kelly.Break circulation and establish parameters @: 5 BPM w/6100 PSI,181K UP,105K DN,134K Rot,60 RPM,8K Off BTM TQ.Tag TOF @ 9,158'. Mill on junk from 9,158'to 9,161'. 5-10K WOB, 9-10K.Lost Gear Coupling between Transmission and Rotary Table.Waiting on parts to repair. Treated fluid in hole with Bleach in preparation to for fluid swap.Monitor well on Trip Tank while cleaning pits.Mixing new 9.5 ppg fluid and making ready for fluid swap. Static Loss @ 2 BPH @ Midnite. Static Loss @ 1/4 BPH @ 05:00 hrs.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 321.5 bbls. Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls Daily Loss rate average-.0 BPH. Report Time Loss to Well=0 BPH Recovered 101 lbs from ditch mags.Recovered 9.5 lbs from Boot Baskets Total metal recovered 1,342 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus=0 psi. 09/06/13-Friday Down for repairs. Hooking up lines f/mud pumps to production.Filling pits#1&#2 with FIW water with 3%KCL.Displacing well with clean 9.5 PPG FIW with 3%KCL&transferring dirty fluid to Trading Bay. Shipped 830 bbls dirty brine to Trading Bay.Cleaning return pits and shakers.Building 9.5 ppg FIW w/3%KCL surface while waiting on coupling to return f/machine shop.Weld Fast Coupling to flanged sleeve.Install coupling onto rotary shaft.Install and flange up transmission,rotary and traction motor.Mechanic done with alignment and installation of rotary @ 03:00.Test run rotary @ 0-80 RPM with no issues. Install floor plate.Break Circulation and establish parameters @: 5 BPM w/620 PSI,181K UP,105K DN,127K Rot,60 RPM,9K Off BTM TO.Tag TOF @ 9,161'.Mill on junk from 9,161'to 9,167'. 5-10K WOB, 9-10K. Continued building surface volume of 9.5 ppg brine.Build 400 bbls surface volume. Monitoring well with trip tank.1 BPH losses @ 05:00 hrs.Fluid loss today 3%KCL 18 bbls. Total 3%KCL loss 339.5 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls. Daily Loss rate average-3/4 BPH. Report Time Loss to Well=1 BPH Recovered 0 lbs from ditch mags.Recovered 0 lbs from Boot Baskets. Total metal recovered 1,342 lbs. 9-5/8"X 13-3/8"annulus=0 psi. 13-3/8"X 20"annulus =0 psi. • Hilcorp Alaska, LLC • F,ilcurp:th,t,ka.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 Daily Opgrapons: 09/07/13-Saturday Continue to Mill on junk from 9,167'to 9,168'with 5-10K WOB, 9-10K @: 5 BPM w/638 PSI,171K UP,105K DN,133K Rot,60 RPM, 9K Off BTM TQ. Not making hole @ 9168'. Monitor well with no losses or flow.Lay down single and TOH from 9,095"to 2,305'. Had 20K overpull @ 8,400'.Continue top TOH from 2,305'to 235'. L/D Acc Jars,rack back DC's. Break off Mill.Clean out boot baskets and recovered 11.5 lbs Metal from boot baskets.Service Rig.Pick up BHA#224=6"OD x 5"ID Metal Muncher Flat Bottom Rotary shoe, Rolling dog overshot, 5-3/4"Washpipe, Xo, 3 boot baskets, Bit Sub, Bumper Sub, Oil Jars, 3-1/2"Pump Out Sub, 6 DCs, acc jars, X0.=270.70'. TIH from 270'to 4,980',fill pipe,cont.TIH to 9,150'. P/U 5'and 15'pup. M/U Kelly. Break Circulation and establish parameters @: 5 BPM w/680 PSI,180k UP,105K DN,132K Rot,60 RPM,9K Off BTM TQ. Tag TOF @ 9,168'. Mill and wash over fish from 9,168'to 9,190'. 0-15K WOB, 9-10K TQ. 20-80 RPM, 0-6 BPM.Encountered torque and stall outs at 9,190'and noticed increase in sand at shakers.P/U off bottom and CBU @ 9 BPM with 2040 PSI with no excess amount of debris in returns at bottoms up. Attempt to wash and rotate back to bottom @ 9,190'.Could not get past 9,187'.Experiencing pack off issues and no change in toque with 15k WOB.Set Back Kelly,monitor well with no losses or flow.TOH from 9,187'to 270'. L/D Acc Jars,rack back DC's. Break off Mill and Rolling dog Overshot.Recovered a 8.30'section of 2-1/8"perf gun.Clean out boot baskets and recovered 35 lbs Metal. Fish Recovered this run=8.30'Perf Gun. Total Fish Recovered=46.40'.Fluid loss today 3%KCL 18 bbls. Total 3%KCL loss 339.5 bbls. Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-3/4 BPH. Report Time Loss to Well=0 BPH,Recovered 280 lbs from Ditch magnets.Ditch magnets total=1,498 lbs.Recovered 11.5 lbs from Boot Baskets.Boot Basket total=273.5 lbs.Total metal recovered=1,633.5 lbs. 09/08/13-Sunday P/U BHA#25 Rotary shoe wash pipe Assembly BHA#25=6"OD x 5"ID Metal Muncher Flat Bottom Rotary shoe, Rolling dog overshot, 5-3/4"Washpipe, Xo, 3 boot baskets, Bit Sub, Bumper Sub, Oil Jars, 3-1/2"Pump Out Sub, 6 DCs, acc jars, XO.= 271.30'. Trip in hole to 9,105'p/u single. Milling on junk f/9,185'to 9,192'w/80 rpm 9k ft#,pumping 5 bpm 670 psi,P/u wt 174, Rt/wt 134k,s/o wt 104k. Pump 13 bbls sweep circ out same at 7 bpm 1230 psi. Set Back Kelly,monitor well with no losses or flow. TOH from 9,192'to 270'. L/D Acc Jars,rack back DC's. Break off Mill and Rolling dog Overshot.Recovered a 18"section of 2-1/8"perf gun and a 3.7"OD x 1-3/4"ID x 2"long piece that may have been a gauge ring. Clean out boot baskets and recovered 33 lbs Metal. Fish Recovered this run=8.30'Perf Gun. Total Fish Recovered=47.90'. P/U BHA#26=6"Six Bladed Concave Metal Muncher Junk Mill, 3 Boot baskets, Bit sub,Bumper sub, oil jars, 3-1/2"Pump Out Sub, 6 DCs, Acc Jars, XO=236.48'. Service Rig.TIH with BHA #26 from 236'to 6,360'.Continue to TIH from 6,360'to 9,158'.P/U Kelly.Break Circulation and establish parameters @: 5.5 BPM w/794 PSI,182k UP,105K DN,135K Rot,60 RPM,9K Off BTM TQ. Encounter Tight Spot/Junk @ 9,187'. Mill on junk from 9,187'to 9,192'. 0-15K WOB, 10-13K TQ. 40-80 RPM, 5-6 BPM.Could not make hole after 9192'. Monitor well with no losses or flow.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 339.5 bbls. Sized Salt Pill 0 bbls. total sized salt pill loss 0 bbls Daily Loss rate average-0 BPH. Report Time Loss to Well=0 BPH Recovered 124 lbs from Ditch magnets. Ditch magnets total=1,622 lbs. Recovered 68 lbs from Boot Baskets. Boot Basket total=341.5 lbs. Total metal recovered=1,963.5 lbs.Notified AOGCC via email of up coming BOP Test on 9/8/2013 @ 02:43 AM. • • Hilcorp Alaska, LLC • Hilcorp AlaAso.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 fly Op s: A . , A,, Asy4o, 09/09/13-Monday Set Back Kelly,monitor well with no losses or flow. TOH from 9,192'to 236'.L/D Acc Jars,rack back DC's. Break off Mill.Clean out boot baskets and recovered 65 lbs Metal.Lay down all BHA components in preparation to test BOP.Pull Wear Bushing. Make up Perforated DP Pup Jt(Flushing Tool)Flush Stack Lay down Flushing tool.Rig up BOP test Joint and associated equipment.Test 13-5/8" BOP to 250/3000 psi with as follows:Annular(4"size), Upper Variable Pipe Ram(4"size), Annular(3-1/2"size), Variable Pipe Ram(3 1/2"size), Blind Rams, Choke HCR, Choke Manual,Kill Line HCR,Kill Line Manual,Upper Kelly Valve,Lower Kelly Valve,16 Choke Manifold Valves,Dart Valve,Full open Safety Valve.Function Manual and Power Choke with 1500 psi.Perform Accumulator Test. All Test's were Pass.Witness of test waived by Lou Grimaldi,AOGCC.Pull Test Plug. Set Wear Bushing.Break down and lay down test joint.6"MM Flat Bottom Rotary Shoe,Catcher Bushing,Wash Pipe Extension,XO Bushing,Reverse Cir Junk Basket,Double Pin Sub, Boot Basket,Boot Basket,Boot Basket,Bit Sub W/Float,Bowen 4-3/4"Lub Bumper Sub,Bowen 4-3/4"Oil Jar,3-1/2"Pump Out Sub, (6)4-3/4"DC's,Bowen Accelerator Jar,Rig Cross Over Sub.BHA length=251.54'.Service Rig.TIH from 251'to 9,111'.PU 2 singles. M/U Kelly @ 9,173'.Break Circulation and establish parameters @: 7 BPM w/1550 PSI,180k UP,105K DN,133K Rot,60 RPM,9K Off BTM TQ.Tag top of junk @ 9,189'.Wash and Mill from 9,189'to 9,200'.Taking torque and weight and 10-13K TQ @ 9,200'.P/U off bottom and increase pump to 8 BPM w/1900 psi.Wash down to 9,200'Mill from 9,200'-9,211'(CIBP @ 9,200')(Hemlock Perf @ 9,210').Noticed oil at shaker w/3/4 bbl pit gain. P/U off btm and flow check well.Well static.Continue to Mill from 9,211'to 9,217' with 5K WOB,9-10K TQ.Appear to be chasing the Bridge Plug down hole.Started taking weight @ 9,217'with no torque or pump pressure increase.Pick up off btm . Tag btm with no rotation @ 9,217'with 15K down. Flow Check Well.Well Static.Set Back Kelly. TOH from 9,173'to 7,840'.Fluid loss today 3%KCL 0 bbls. Total 3%KCL loss 339.5 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls. Daily Loss rate average-0 BPH. Report Time Loss to Well=0 BPH.Recovered 65 lbs from Ditch magnets. Ditch magnets total= 1,687 lbs. Recovered 11 lbs from Boot Baskets.Boot Basket total=352.5 lbs.Total metal recovered=2,039.5 lbs. 09/10/13-Tuesday POOH with BHA#27.Monitor well. L/D BHA.Empty JB-118 lbs metal recovered.M/U BOPE wash tool and flush metal from stack. Recovered 25 lbs metal from BOPE.Work on knife valve and RPM sensor.Service rig.M/U BHA#28-6"6 blade mill-3ea 4-7/8"JB-4 3/4"BS w/float-4-3/4"bumper sub-4-3/4"oil jar-4-11/16"pump out sub-6 ea 4-3/4"DC-4-3/4"Accel jar-4-3/4"XO-OAL 235.90'. RIH with BHA#28-obtain parameters puw 185k-sow 107k-rtw 136k @80 rpm-trq 9k-5 bpm/670 psi. Milling plug from 9,215'-9,217'. Mill/push plug debris to 9,264'.Mill plug from 9,264',CBU-408 gas units-1/2 bbl sand,small amt of rubber and crude across shakers-gas units 130. Mill plug at 9,264'and wash/push to 9,470'.Coupler on rotary broke again.Circ/cond hole.Flow check hole 1.5 bph loss. POOH with BHA#28.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 339.5 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls. Daily Loss rate average-0 BPH.Report Time Loss to Well=0 BPH.Recovered 339 lbs from Ditch magnets. Ditch magnets total=2,026 lbs. Recovered 10 lbs from Boot Baskets. Boot Basket total=363 lbs.Total metal recovered=2,389 lbs. 09/11/13-Wednesday LD BHA#28.Service rig.Monitor well 0.5 bph loss.Pull rotary table, traction motor hatch,break bolts on rotary coupler hubs.RU E- line run GR/CCL from—9,500'-—1,000'.RD E-line.PU BOPE wash tool, wash BOPE clean of metal. Recovered 14 lbs metal. LD wash tool. RIH with 6"bit,bit sub,6 ea 4-3/4"DC on 4"DP to—9,500'to change well over to clean 9.5 ppg 3%Brine. RU head pin and lines. Start changing well over to clean 9.5 ppg 3%KCL. 09/12/13-Thursday Build volume,clean trip tank,flush choke man gas buster.Clean shakers and ditch,clean sand trap and pull rotary table.POOH with BHA#29. LD-BHA. Clean rig floor and rig. RU-RIH with E-line 6.02 GR to 9,550'.(snug at 8,003')Cont cleaning rig. MU-RIH with HES/EZSV on E-line. GR-CCL-set on depth at 9,458'-good surface indication plug set.Check set- BP in place. POOH RD E-line. Cont cleaning rig. Service rig. Prep to PU/Run TCP guns. Set up rig floor for guns.MU safety jt. Fluid loss today 3%KCL 34 bbls. Total 3%KCL loss 374 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1.5 BPH.Report Time Loss to Well=0 BPH.Recovered 17 lbs from Ditch magnets. Ditch magnets total=2092 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=381 lbs.Total metal recovered=2473 lbs. • • • Hilcorp Alaska, LLC Hik.orp Alaska.LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 , „ rr';Ai Daily Operations: 1444: 09/13/13-Friday PU-RIH with TCP guns on 4"DP to 9,366'. RU/RIH with E-Line GR/CCL log correlation for perfs-adjust+9 to place on depth with btm shot at 9,364'. POOH-stand back E-line.Space out DP for 9'adjustment to be on depth. RU RIH with eline,run GR/CCL to verify TCP guns on depth. RA tag at 5,908', placing btm shot at 9,364'. RD E-line. RU bar drop lubricator.Drop bar, good surface indication guns fired.Fluid dropped out of sight-fill hole with 87 bbls. TCP-4-1/2"-6 spf-super deep penetration(34.9"deep-.38"diameter) guns-total perfs 1,143'. Monitor well for losses. Fluid loss today 3%KCL 48 bbls.Total 3%KCL loss 422 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-2 BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=2092 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=381 lbs.Total metal recovered=2473 lbs. 09/14/13-Saturday Circ.out perf gun gas.Load well with 63 bbls brine.Spot 40 bbl SSP. RD circ head and bar drop lubricator.Monitor well,60 bph loss. POOH with DP and TCP guns. Fluid loss now at 6 bph. CBU-min gas to surface 14 units-6 bph loss. Cont POOH with DP.LD-TCP cross overs.POOH LD TCP guns, keeping hole full.Monitor gun gas-6 bph loss. Clean/clear rig floor of TCP gun equip. PU/MU Tri Point 7-5/8"model'D'permanent packer. RU E-line equip. RIH to set packer at 5,800'. Fluid loss today 3%KCL 395 bbls. Total 3% KCL loss 817 bbls.Sized Salt Pill 40 bbls. Total sized salt pill loss 40 bbs.Daily Loss rate average-16 BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=2092 lbs.Recovered 0 Ibs from Boot Baskets. Boot Basket total=381 lbs.Total metal recovered=2473 lbs. 09/15/13-Sunday RIH with pkr on E-line.When logging up the tool string jumped and communications to E-line unit was lost.No signal and no weight. POOH-cable had pulled out of rope socket.RD E-in.RIH with DC/DP,cut 117'drlg line-slip 77'back onto drum.POOH.LD 54 jts DP- std 2 stds DC back on drillers side. Service rig-6 bph loss. MU/RIH with BHA#1-5-3/4"overshot-3-1/2"pump out sub-xo+oal 9.09'. Obtain parameters at 7,423'-puw 143k-sow 95k-rtw 112k-rpm 30-rtq 7k-4 bpm-270 psi. Engage fish at 7,453',pump press inc to 350 psi-apply wt down to nogo at 7,456'-pump inc to 1,100 psi.PU and saw slight overpull.POOH slowly 6 bph loss. LD BHA#1- 5-3/4"overshot.Recovered E-line tools and pkr setting tool-without pkr. Setting tool pins had sheared as designed when setting pkr indicating pkr is set. E-Line tool rope socket clean with no damage.Service equip/housekeeping. PU/MU BHA#2-3-1/4"'C'spear-4- 3/4"bumper sub-4-3/4"oil jar-4-3/4"pump out sub-6ea 4-3/4"DC-xo=oal 210.34'. RIH with BHA#2-engage fish at 3,239',work to move fish, pull 45k over-fish would not move.Release spear-pkr set at 3,239'. POOH to pick up pkr mill assy. Fluid loss today 3% KCL 144 bbls.Total 3%KCL loss 961 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 40 bbls.Daily Loss rate average-6 BPH. Recovered 0 lbs from Ditch magnets.Ditch magnets total=2092 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=381 lbs. Total metal recovered=2473 lbs. 09/16/13-Monday POOH-LD BHA #2.MU BHA#3-6-3/4"PRT w/pkr mill-2 ea 4-3/4"boot bskts-4-3/4"bit sub(w/flt)-4-3/4"bumper sub-4-3/4"oil jar 4-3/4"pump out sub-6 ea 4-3/4"DC-4-7/8"xo-4-7/8"xo-oal 225.46'.RIH with BHA#3. Obtain parameters-puw 70k-sow 59k-rtw 65k-bpm 7-psi 835-rpm 80-tag fish at 3,239'.Mill on pkr-unable to make progress. POOH,LD BHA#3. Recover 11 lbs metal from boot bskts-30 bph loss. MU BHA#4-3-1/4"'C'spear-4-3/4"bumper sub-4-3/4"oil jar 4-3/4"pump out sub-6 ea 4-3/4"DC-4- 7/8"xo-oal 210.34'. 40 bph loss.RIH to 3,206'-Obtain parameters-puw 72k-sow 61k-tag fish at 3,239'-mill on pkr-unable to make progress.Spot 20 bbl SSP-let fall 30 mins. Ran in hole and tagged pkr at 3,241±-set down 10k- PU clean-RIH to 3,249'±- make connection. RIH wino pump to 3,281'-no indication we have fish. POOH. Start BOPE test before midnight.POOH,LD BHA#4- recovered 1 pkr element and 1 spacer ring.Remove wear ring. MU BOPE test tools -18 bph loss. Test BOPE as per HAK-Kuukpik- AOGCC procedures-250 psi low/3000 psi high/2500 psi annular-no failures so far.Witness of test waived by Jim Regg 9/16/13 via email. Fluid loss today 3%KCL 450 bbls.Total 3%KCL loss 1410 bbls.Sized Salt Pill 20 bbls.Total sized salt pill loss 80 bbls Daily Loss rate average-19 BPH. Recovered 0 lbs from Ditch magnets.Ditch magnets total=2092 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=381 lbs.Total metal recovered=2473 lbs. • • • Hilcorp Alaska, LLC Hileorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-18 50-733-20143-00 168-076 8/11/2013 9/20/2013 RaiC opera 9 � .., . r4, • 09/17/13-Tuesday Finish testing BOPs to 250 psi low and 3000 psi high.Rig down test equip and install wear ring.PU fishing BHA,Spear,Bumper Sub,Oil jars,Pump out sub,6 DCs,XO=210.34'. RIH to 7,435'. PU Kelly and obtain parameters.Work spear dn and tag TOF at 7,468',Set down 10k on fish. Pump Pressure increased 150 psi. PU to 7,435'and set Kelly back. Started flowing back up DP. Install floor valve and head pin.Circ full circ at 3 BPM and 350 psi.Had a light spot of about 10 bbls just before bottoms up.No signs of gas.Hole took 11 bbls while circulating.Monitor well w/hole taking 10 BPH and POOH to BHA. Observe occasional 10k overpull-work fish through wear ring by picking up and going down. LD BHA#5-recovered packer and tbg tail assy-slip cone(the base pkr slips slide on when setting)was broken leaving one half of cone in well and bottom pkr slips.Drain stack,did not see anything down to the wear ring. (cone dimension 5"w x 3"h x 3/4"x1/4"thick taper/2ea in hole).Clear floor of fishing tools-16 bph loss. RU E-Line lubricator. E- Line unit not functioning.RD E-Line equip. MU BHA#6-6"tri cone bit-4-3/4"bit sub-4-3/4"bumper sub-4-3/4"oil jar-6 ea 4-3/4"DC- 4-7/8"xo=oal 209.69'.RIH with BHA#6 for gauge and push junk to bottom. Fluid loss today 3%KCL 339 bbls.Total 3%KCL loss 1749 bbls.Sized Salt Pill 20 bbls.Total sized salt pill loss 80 bbls.Daily Loss rate average-19 BPH.Recovered 19 lbs from Ditch magnets. Ditch magnets total=2133 lbs.Recovered 0 lbs from Boot Baskets. Boot Basket total=391 lbs.Total metal recovered=2524 lbs. 09/18/13-Wednesday RIH w/6"bit to 7,749'.Hole taking 10 BPH.Circ bottoms up at 4.5 BPM at 500 Psi,Max 35 units,Monitor well 10 BPH. POOH and lay dn BHA.Rig up E-Line. Run 6.25 gauge ring junk basket to 5,980'.POOH and lay dn tools,8 BPH loss. RU and pick up Model D permanent packer.Set in slips and connect firing head.PU with E-Line to ensure line secure.Remove tugger and lower lubricator.RIH with packer on E-Line,correlate and set Pkr at 5,916'.RD eline equip.RU tbg running equip.RIH with 3-1/2"completion strings.Hook up control line to inj valve and test 1000 psi-10 min.Install Canon clamps on top of every other jt-111 jts in the hole -out of 184 jts. Fluid loss today 3%KCL 193 bbls.Total 3%KCL loss 1942 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 80 bbls.Daily Loss rate average-8 BPH. Recovered 19 lbs from Ditch magnets. Ditch magnets total=2149 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=391 lbs. Total metal recovered=2540 lbs 09/19/13-Thursday Run 3-1/2"gas lift completion as per program.Installing bands and cannon clamps.Sting into packer at 5,916'with seal 11'.PU to up wt 60k,dn wt 50k.Test seals to 400 psi.Good test.PU and space out.Install hanger and tie in control lines.Land hanger with good indication of seals going into packer.Ran 41 SS bands and 89 cannon clamps.Run in lockdowns and test backside to 1200 psi for 30 min on chart.Good test.Rig dn test equip and pull landing jt.Install BPV. Nipple dn BOPs.Pull rotary table. N/D flow nipple-air boots. R/U bridge crane strong back to Hydril. N/D single gate/riser.Remove stairs to cellar.Remove stack from riser w/blocks-transfer to bridge crane. N/D riser/tbg spool. Prep wellhead for tree. Lower tree assy to wellhead room. N/U tree.Torque tree to spec. H/U control lines. Install actuator valve-test hgr void-5000 psi-good. Pull BPV-set TWC-test tree 5000 psi-good. Pull TWC-R/D test equip. Prep to R/U slickline.PT lubricator 1800 psi. RIH#1-2.79"GR-would not pass thru SSSV(2.813")-POOH.M/U 2.75"GR-Prep to skid rig-spot jacks-R/U safety valve on tree.RIH#2 with 2.75"GR to 5,930'(slm)-POOH. Remove flow and degasser lines. Prep to skid rig. RIH#3-set AD-2 stop(catcher plug)at 5,920'(slm). Spot jacks. RIH#4-pull DV from injection valve at 5,867'-(5,879'slm). Prep to skid rig.RIH#5-pull DV from GLM at 5,727'(5,740'(slm). Fluid loss today 3%KCL 64 bbls.Total 3%KCL loss 2006 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 80 bbls.Daily Loss rate average-0?6 bph BPH.Recovered 0 lbs from Ditch magnets. Ditch magnets total=2149 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=391 lbs.Total metal recovered=2540 lbs. 09/20/13-Friday Wireline-Run#6, Pull dummy valve f/GLM at 5,180',5,193'WLM. Run#7 Pull dummy valve f/GLM at 4,601',4,615'WLM.Run#8 Pull dummy valve f/GLM at 3,684',3,694'WLM. Run#9 Attempt to Pull dummy valve f/GLM at 2,173',2,183'WLM.Didn't get valve. Run#10 Attempt to Pull dummy valve f/GLM at 2,173',Still didn't get valve.Run#11 Pull dummy valve f/GLM at 2,173',2,183' WLM.Recovered dummy.Run#12,Run live valve and set in GLM at 2,173'. Run#13,Run live valve and set in GLM at 3,684'.Run# 14,Run live valve and set in GLM at 4,601'. Run#15,run live valve and set in GLM at 5,180'.Run#16,run live valve and set in GLM at 5,727'.Run#17,run valve and set in Chemical Injection Mandrel at 5,867'.Run#18-RIH retrieve AD-2 stop at 5,920'. Prep for rig move. RD slickline unit.Prep to skid rig-remove hand rails-stairs-cut weld tacks on walkway to cellar-move misc items with crane. Release Rig 56 from well A-18 at 2400 hrs 9/20/13.Total fluids to recover from well workover -2006 bbls 9.5 3%KCL 80 bbls Sized Salt Pill-total 2086 bbls to recover.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 2006 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 80 bbls.Daily Loss rate average-0 bph BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=2149 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=391 lbs.Total metal recovered=2540 lbs. Regg, James B (DOA) From: Marvin Rogers - (C) [mrogers@hilcorp.com] Sent: Tuesday, August 27, 2013 4:40 PM To: DOA AOGCC Prudhoe Bay Subject: Monopod Csg and cmt report, A-18 Attachments: Monopod A18 Casing and Cementing report.xlsx Hilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com TIIf �7113 &� Skj, '4-1S Prb /680-74.0 lk Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No. Trading by unit, Monopod A-18 Date County Kenai peninsula Boro State Alaska Supv. £,u A, CASING RECORD TD Shoe Depth: 7490.00 PBTD: 25 -Aug -13 Marvin rogers 9470.00 Csg Wt. On Hook: up wt 220k do wt 140k Type Float Collar: Csg Wt. On Slips: Wt on Hanger 140k Type of Shoe: Fluid Description: Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: Float No. Hrs to Run: 25 NA Casing Crew: Weatherford 9.6 3% KCL CEMENTING REPORT Liner top Packer?: Yes x No Preflush (Spacer) Casing (Or Liner) Detail Setting Depths No. of Jts. Size Wt. Grade THD Make Length Bottom Top Seal Assem 7" 29 N80 BCT 10.00 7,490.00 7,480.00 XO 7" X 7 5/8" 29 L80 STL 1.14 7,480.00 7,478.86 2 7S/8 29.7 L80 STL 74.51 7,478.86 7,404.35 F. Collar 7S/8 29.7 L80 STL 2.08 7,404.35 7,402.27 47 75/8 29.7 L80 STL 1,775.67 7,402.27 5,626.60 XO 75/8 29.7 L80 STL 2.12 5,626.60 5,624.48 138 75/8 29.7 1 L80 SLIJ-11 5,574.84 5,624.48 49.64 2 pups, hang 75/8 29.7 L80 BCT 7.12 49.64 42.52 RKB Volume pumped (BBLs) Lead Slurry 41.08 42.52 1.44 Totals Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Csg Wt. On Hook: up wt 220k do wt 140k Type Float Collar: Csg Wt. On Slips: Wt on Hanger 140k Type of Shoe: Fluid Description: Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: Float No. Hrs to Run: 25 NA Casing Crew: Weatherford 9.6 3% KCL CEMENTING REPORT Liner top Packer?: Yes x No Make Test Head To Remarks: Seaboard 2500 WELLHEAD Type Tbgf head Serial No. H318362 Size 11" W.P. 5000 PSIG 15 MIN pass OK Preflush (Spacer) Type: Mudpush II Density (ppg) 10.6 Volume pumped (BBLs) 18 Lead Slurry Type: LiteCRETE Yield 1.85 ft3/sk Density (ppg) 11 Volume pumped (BBLs) 183 / 530 sx Mixing / Pumping Rate (bpm) 4.6 Tail Slurry Type: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: 3 % KCL Density (ppg) 9.6 ' Rate (bpm): 5 Volume (actual / calculated): 340 bbls FCP (psi): 2100 ' Pump used for disp: Rig pump Plug Bumped? x Yes No Bump press 2600 Casing Rotated? Yes x No Reciprocated? Yes x No % Returns during job 100 - Cement returns to surface? x Yes No Spacer returns? x Yes No Vol to Surf: 18 bbls Cement In Place At: 0:00 Date: 8/24/2013 Estimated TOC: surface Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type: w 0 Density (ppg) Volume pumped (BBLs) M;zing / Pumping Rate (bpm): u) Post Flush (Spacer) 0 z 0 Type: Density (ppg) Rate (bpm): Volume: U Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Make Test Head To Remarks: Seaboard 2500 WELLHEAD Type Tbgf head Serial No. H318362 Size 11" W.P. 5000 PSIG 15 MIN pass OK • • s w w,\ I THE STATE Alaska aS nf "N"P"■.r--. 4 j A LAsKA COnSCrVati011 Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4"ALA-SY'1". is t 4 ,.v Anchorage, Alaska 99501-3572 o , �4t Main: 907.279.1433 �� t.` t° �� Fax: 907.276.7542 S Dan Marlowe Operations Engineer / 6 --- Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai D, Middle Kenai E, and Hemlock Oil Pools, Trading Bay Unit ST A-18 Sundry Number: 313-445 Dear Mr. Marlowe: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, .a/ r Daniel T. Seamount, Jr. Commissioner DATED this Z f/da of August, 2013. Y � Encl. , , • • . lit. ,-,: ,:-„,,,-: ,-_, :, - „ ,,,:, :.,,,, 141w 1. r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION =' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25-2R0 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair WeN❑ Change Approved Program Suspend Plug Perforations ❑ Perforate 0 • Pull Tubing ' Time Extension ❑ Operations Shutdown,❑ Re-enter Susp.Well ❑ Stimulate❑ After Casing❑ Other. nstall Gas Lift Completion 9 ' 2.Operator Name: 4.Current Well pass: 5.Permit to Dill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0, 168-076 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20143-00-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93 Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay ST A-18 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Middle Kenai D Oil,Middle Kenai E Oil,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): 11,000 10,241 9,200' 8,445' 9,200' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 1,006' 13-3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,482' 9-5/8" 7,520' 6,860' 3,950 psi 2,570' Intermediate Production Liner 2,377' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7,485'-7,620' 6,827'-6,955' 3-1/2" 9.2# N-80 7,474' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): , Otis WD Packer / Otis DK BV SSSV Packer 7,438'(MD)6,782'(ND)/Otis DK BV SSSV 303'(MD)303'(ND) 12.Attachments: Description Summary of Proposal 9• 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Cl , Exploratory ❑ Stratigraphic❑ Development:0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Operations are in progress Commencing Operations: Oil 0 ' Gas ❑ WDSPL ❑ Suspended C 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned C Commission Representative: GSTOR ❑ SPLUG C 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe @hilcorp.com Printed Name Dan Marl w Title Operations Engineer Signature Phone 907-283-1329 Date 8/14/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 513 N l Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: f 30'v ,s�. 8v� Ir:s!' RBDMS OCT 1 0 20j Spacing Exception Required? Yes ❑ No II Subsequent Form Required: /4 —Y Q LI APPROVED BY / 1 3 Approved by: COMMISSIONER THE COMMISSION Dated J ORIGINAL ,�g .z.0./3 Submit Form and Form 10-403(Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Juanita Lovett From: Dan Marlowe Sent: Wednesday,August 14, 2013 2:30 PM To: Schwartz, Guy L(DOA) Cc: Ted Kramer;Juanita Lovett; Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076' Guy Currently we are on step#7.We have the tubulars removed and are currently washing down to the packer. The easiest way to explain the perf changes is with the following table comparing original to current plan: Originally Proposed Current Proposal Top MD Btm. MD Feet Top MD Btm. MD Feet Comment 6,010 6,150 140 in addition to original proposal ✓ 7,320 7,436 116 in addition to original proposal 7,450 7,533 83 7,450 7,533 83 Same as original proposal 7,544 7,570 26 7,544 7,570 26 Same as original proposal 7,790 7,870 80 7,790 7,870 80 Same as original proposal 7,910 8,030 120 7,904 8,030 126 more than original proposal 8,104 8,158 54 in addition to original proposal 8,425 8,555 130 8,425 8,555 130 Same as original proposal 8,610 8,650 40 8,610 8,650 40 Same as original proposal 8,660 8,675 15 8,660 8,675 15 Same as original proposal 8,734 8,832 98 in addition to original proposal ✓ 8,916 8,965 49 8,916 8,965 49 Same as original proposal 9,074 9,120 46 9,074 9,120 46 Same as original proposal 9,146 9,176 30 9,146 9,176 30 Same as original proposal 9,210 9,316 106 9,210 9,290 80 Less than original proposal 9,330 9,420 90 9,330 9,360 30 in addition to original proposal Total 815 Total 1143 Procedurally to change to a gas lift completion we have two different scenarios Scenario 1-Can run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390' (+/-). RD E-line. 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 1 • i 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. Depending on log results,repair 9-5/8"casing either by running a or running a 7-5/8"liner to surface. 10. Fill casing with FIW. RIH with a test plug to '-5,800'and set. Pressure test casing to 1,200 psi. Chart same. 11. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 12. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 13. Pick up TCP guns above perforations,monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 7,910'(+/ ),PU and run permanent production packer and set at+/-5,800' . PU and run gas-lift completion with seal assembly stabbing into production packer at+/-5,800' 16. ND BOP,NU wellhead and test. 17. Turn well over to production. 18. Complete No-Flow test Scenario 2—Cannot run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390'(+/-). RD E-line. 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 10. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 11. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 12. Preset permanent production packer w/packer plug at+/-5,800' 13. Depending on log results,repair 9-5/8"casing either by running a casing expandable liner patch OF running a 7_5/8" liner 14. Fill casing with FIW. RIH with an inflatable test plug to 77450'—5,700'and set. Pressure test casing to 1,200 psi. Chart same. stabilizer-120014-witla-TCP-guns, 7 ^40ri CT7.Pull packer plug, PU and run gas-lift completion with seal assembly stabbing into production packer at+/-5,800'. 19. ND BOP,NU wellhead and test. 2 • • 20. Turn well over to production. 21. Complete No-Flow test Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(cr�.hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday,August 14, 2013 11:41 AM To: Dan Marlowe Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, Where are you currently in the workover program? Are the new proposed perfs only the Hemlock 6010-6150' and D54- 9 7320-7436' ? I will need a revised procedure for the Gas lift completion where it deviates from the original sundry procedure. ...you can submit that by email to me. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Dan Marlowe [mailto:dmarlowe @hilcorp.com] Sent: Wednesday, August 14, 2013 10:24 AM To: Schwartz, Guy L(DOA) Cc: Ted Kramer; Juanita Lovett Subject: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Guy We are currently in the middle of the workover on Monopod A-18. We have had a couple of changes to the original completion plan—see attached schematic • Added perfs—Spacing reviewed and still compliant • Changed to gas-lift completion instead of ESP I have also included two proposed wellhead diagrams dependent on how we have to repair the casing Let me know if you need me to provide any further information Dan Marlowe Hilcorp Alaska, LLC Operations Engineer 3 • 0 Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe @hilcorp.com Hilcorp A Company Built on Energy 4 II II) • Trading Bay Unit SCHEMATIC wen: A-18 Hilcorp Alaska,LLC Completed: 2/77 CASING AND TUBING DETAIL RKB to TBG Hngr=37.00' SIZE WT GRADE CONN ID TOP BTM. Tree connection:?? 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' ■ L 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' it 1 9-5/8" 40 N-80 Buttress 8.835 4191 5643' 9-5/8" 43.5 N-80 Buttress 8.755 5643' 7520' Stage Collar 5598 5600 7"Liner 29 N-80 Buttress 6.184 7489' 9826' Tubing: 3-1/2" 9.2 N-80 Butt 2.992 37 7474' JEWELRY DETAIL Suspected hole at NO. Depth ID Item 1700'-2050' 37.0' 10"x 4"Cameron 5M Tubing hanger,XO to 2.7/8"Butt 1. 303' 2.75 3-1/2"Otis,"DK"BV SSSV Nipple, 2. Camco 3-1/2"MMG MDL Gaslift Mandrels GLM#1. 2198' 2.875 Camco MMG GLM GLM#2. 3513' 2.875 Camco MMG GLM IM GLM#3. 4645' 2.875 Camco MMG GLM 2 GLM#4. 5537' 2.875 Camco MMG GLM U / GLM#5. 6249' 2.875 Camco MMG GLM Mb GLM#6. 6867' 2.875 Camco MMG GLM GLM#7. 7364' 2.875 Camco MMG GLM 3. 7403' 2.75 Otis"XA"Sliding Sleeve M 4. 7437' 3.00 Locator Seal Assy.w/20'of seals. 5. 7438' 3.5 Otis"WD"Pkr 6. 7472' 2.625 Otis"XN"Profile Nipple,2.75 7. 7473' 3.5 WLEG btm 7474' 8. 9200' Baker Drillable Bridge Plug.Set to temporarily isolate Hemlock 0 3 production,250 BOPD on 11/28/70 4 9. 9270' CI BP. '' FMEill 5 Wireline Summary 9/85 CTU Cleanout f/7819'to 9205'.Found 1/16"to 1/8"coal,shale&cmt in returns @ 7955'. 6 1/89 CTU Clean Out to 9184'.Found tight spot w/2-1/8"guns @ 7880' 7 1/89 FISH 22.6'x 2-1/8"Gun,2'x 1-11/16"CCL,2'x 2"magnet,5'x 1- @7595' 11/16"Weight bar,0.6'x 1-3/8"Cable Head.Total 32'long 10/21/91 Tagged fill w/3-1/2"scratcher @7595' 4/27/96 Tagged fill w/3-1/2"scratcher @7543' D 12/30/03 Tagged fill w/2.62"GR @7580' 4/28/05 Tagged fill @ 7577'KB,got sample(sand),ran 2.74"GR to`XN' @7577' Nipple @ 7472'KB. PERFORATION DATA Accum. Date E Zone Top Btm Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered w/Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered w/Fill D 55-7 7,910' 8,030' 120' 7 1/75 Covered w/Fill — D 56-1 8,060' 8,130' 70' 4 11/70 Covered w/Fill Hemlock D 57-2 8,380' 8,516' 136' 23 6/79 Covered w/Fill 9 8,524' 8,550' 26' 4 11/70 Covered w/Fill E 58-1 8,568' 8,682' 114' 19 6/79 Covered w/Fill E 58-7 8,734' 8,832' 98' 16 6/79 Covered w/Fill E 60-0 8,916' 8,988' 72' 12 6/79 Covered w/Fill KB ELEV=101' E 60-5 9,066' 9,116' 50' 8 6/79 Covered w/Fill PBTD=9,200' TD=11,000' E 61-1 9,146' 9,176' 30' 4 11/70 Covered w/Fill ANGLE thru INTERVAL=24.9° Hemlock 9,210' 9,265' 55' 4 11/68 Temporary Isolated by BP Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP Revised By:TDF 1/21/2013 . . II 0 Trading Bay Unit PROPOSED Well: A-18 Hilcorp Alaska,LLC Completed: Future RKB to TBG Hngr=37.00' CASING DETAIL , ■ Size Wt Grade Conn ID Top Btm J - i 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 1, • 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' tea/8" 9-5/8" 40 N-80 Buttress 8.835 4,191' 5,643' 9-5/8" 43.5 N-80 Buttress 8.755 5,643' 7,520' Repair 9-5/8" STAGE COLLAR 5,598' 5,600' casing either by 7"Liner I 29 I, N-80 Buttress 6.184 7,489' 9,826' running a casing TUBING DETAIL expandable liner patch or running 3-1/2" I 9.5# I RTS-8 I I I Surf I ±5,991' a 7-5/8"liner 2 JEWELRY DETAIL • 3 • ND Measured ID Item Depth 4 �\ 1J p, 37.0' 10"x 4"Cameron 5M Tubing hanger,XO to 3-1/2"Butt 5 I - 1 ±300' SSSV ±2,188' SF0-1 GLM 6 3 ±3,697' SF0-1 GLM 4 ±4,590' SF0-1 GLM il. 7 5 ±5,189' SF0-1 GLM 8 6 ±5,740' SFO-1 GLM MIL 9 7 ±5,570' SF0-1 Chemical Injection Mandrel ■ , 8 ±5,800' Packer 10 9 ±5,830' X Nipple own. 10 ±5,831' WLEG I PERFORATION DETAIL A 9.5/8" Top Btm Top Btm Last Zone (MD) (MD) (TVD) , (ND) Amt. SPF Date Status / D Hemlock ±6,010' ±6,150' ±5,423' ±5,557' 140' Future D 54-9 ±7,320' ±7,436' ±6,669' ±6,780' 116' Future D 55-7 ±7,450' ±7,533' ±6,794' ±6,873' 83' Future Re-pert/Open D 53-8 7,485' 7,533' 6,827' 6,873' 48' 4 1/89 Open D 55-7 ±7,544' ±7,570' ±6,883' ±6,908' 26' Future Re-perf D 53-8 7,544' 7,620' 6,883' 6,955' 76' 4 1/89 Open D 53-8 7,550' 7,590' 6,889' 6,927' 40' 6 6/79 Part covered w/fill E D 54-9 7,734' 7,890' 7,061' 7,205' 156' 13 1/89 Covered w/fill _ D 56-1 ±7,790' ±7,870 ±7,113' ±7,187' 80' Future Re-perf D 56-1 ±7,904' ±8,030' ±7,218' ±7,333' 126' Future Re-perf D 55-7 7,910' 8,030' 7,224' 7,333' 120' 7 1/75 Covered w/fill D 56-1 8,060' 8,130' 7,360' 7,424' 70' 4 11/70 Covered w/fill D-57-2 ±8,104' 8,158' ±7,400' ±7,449' 54' Future Re-perf D 57-2 8,380' 8,516' 7,654' 7,782' 136' 23 6/79 Covered w/fill D 57-2 ±8,425' ±8,555' ±7,696' ±7,819' 130' Future Re-perf Hemlock 8,524' 8,550' 7,790' 7,814' 26' 4 11/70 Covered w/fill E 58-1 8,568' 8,682' 7,832' 7,941' 114' 19 6/79 Covered w/fill = E 58-1 ±8,610' ±8,650' ±7,872' ±7,910' 40' Future Re-perf % E 58-1 ±8,660' ±8,675' ±7,920' ±7,934' 15' Future Re-perf j/ 7„ E 58-7 ±8,734' ±8,832' ±7,991' ±8,086' 98' 16 6/79 fpe rf/Covered KB ELEV=101' PBTD=9,470' TD=11,000' E 60-0 ±8,916' ±8,965' ±8,167' ±8,215' 49' Future Re-perf ANGLE thru INTERVAL=24.9° E 60-0 8,916' 8,988' 8,167' 8,238' 72' 12 6/79 Covered w/fill E 60-5 9,066' 9,116' 8,314' 8,363' 50' 8 6/79 Covered w/fill E 60-5 ±9,074' ±9,120' ±8,322' ±8,367' 46' Future Re-perf E 61-1 9,146' 9,176' 8,392' 8,422' 30' 4 11/70 Covered w/fill Hemlock ±9,210' ±9,290' ±8,455' ±8,534' 80' Future Re-perf Hemlock 9,210' 9,265' 8,455' 8,509' 55' 4 11/68 Isolated by BP Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 11/68 Isolated by BP Hemlock ±9,330' ±9,360' ±8,574' ±8,603' 30' Future Re-perf Revised By:JLL 08/13/2013 • • „ it Monopod Platform A-18 Proposed 08/14/2013 Ililrnrp thiskn.LId. Monopod Platform Tubing hanger,SME-CL,11X A-18 3%EUE lift and cusp,w/3' 133/8X95/8X75/8X Type H BPV profile,3-3 8 3 1/2 YP P / CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 11 lir Valve,Swab,WKM-M, * 3 1/8 5M FE,HWO,DD trim _�Yyl o �. Valve,Wing,WKM-M, ... 3 1/8 5M FE,w/15"OMNI 7 _ operator,DD trim 1 Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim leP AI III plirel Valve,Master,WKM-M, t - 3 1/8 5M FE,HWO,DD trim imi X3 ICI •' Ii1 Control line II I. Tubing head,S-8,11 5M x III III 11 5M,w/2-2 1/16 5M SSO, - - w/BG bottom J w/2-2 1/16 5M WKM-M no aim - /valves I A ME W G ccS), =.ii Aid', ,,14.2iG■= S, Casing spool,S-8,13 5/8 3M Ip l p1 Iui x 11 5M,w/2-2 1/16 5M , _ I SSO,w/BG bottom - l I-i II' 4Il! ' '•�, 7 ;ea" valve 1 f 11—, II ' I/1 Casing head, g Shaffer KO, _1111 : 13 S/8 3M X mg it•l 13 3/8 SOW,w/2-2" I c.) APO, a l pin ;M.I.. 1'111r • 0 .. lii Monopod Platform A-18 Proposed 08/14/2013 IGlenrlr VasLa.1.1.t Monopod Platform Tubing ha nger,SME-CL,11 X A-18 3'A EUE lift and susp,w/3" 13 3/8 X 9 5/8 X 3 1/2 Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I _i MID u. Valve,Swab,HWO,DD trim .' 3 1/8 5M FE,HWO,DD trim � �g' Valve,Wing,WKM-M,3 1/8 . 5M FE,w/15"OMNI Valve,Wing,WKM-M,21/16 operator,DD trim 5M FE,HWO,DD trim 75 ir, - \ - --�, D Valve,Master,WKM-M, • 3 1/8 5M FE,HWO,DD trim Ix.ONO III lin :re ilk Valve,Master,WKM-M, - 31/8 5M FE,HWO,DD trim .. .0 _.,rte—_�� ?i Tubing head,S-8,13 5/8 3M � � op :fin. x 11 5M,w/2-2 1/16 5M l�l • I♦1 r// SSO,w/BG bottom -- w/1-21/165MWKM-M i L - 6) valves g I-. III 1111[ 49111 t'� I 1111-1. 1o1 i' " um Casing head, ,_ Shaffer KD, ll 11 135/83MX 6 13 3/8 SOW,w/2-2" iii 'HM 1�!1 111-h LPO _ I! . • Monopod Platform 2013 BOP Stack 03/12/2013 II ,,•,,, sl,., t 111 Rig Floor Bottom of air boot flange 5'below rig floor 16" 14.72' 9.50' Pipe 1ii!ill iii IllIii Iliii1.7 •Ill 334' Sh 3.35/85M I I I I I I 1 1 1 11 I III 26.25' AI Shaffer LXT -- 2 7/8-5 Variables 2.50' 135/85M _-- _ i■l-1 ----. Blind 1 r/,, lit I11 I'i •Ill- 1/,41 1.76 Ig, 1.Q. � Cross �, 4 • Ili 111 111• i 2 � '1358u5MFEXFE. II i .: w/31/85M EFO w/21/165M Choke and Kill valves w/Unibolt end connections for lines I1IOU ,I1 III i _ 283' - . I _ _ -- Dual Cameron Flex rams :, .:,...,. I Flirt'. 11I .70' Ili III Iii Ilt Ill i Drill deck 14. r UOCI 191 F Riser 14.20' 135/85M FE X135/85M FE III '.i II∎-I- 1.il 11.11't 111 11 1I Spacer spool 1.5' 135/S5M FEX113M ,i 1! '.I..-i.. ii:: Wellhead @ 15.00' • Schwartz, Guy L (DOA) From:• Schwartz, Guy L(DOA) Sent: Friday,August 16, 2013 11:18 AM To: 'Dan Marlowe' Cc: 'Roby, David S (DOA) (dave.roby @alaska.gov)'; Bettis, Patricia K(DOA) Subject: RE: 10-403 Monopod -A-18 - Revision -Submitted 08-15-13.pdf 4" 3 ( 3- '-NS Dan, As we discussed you have verbal approval to proceed with the RWO as proposed ( whether expandable liner or 7 5/8" casing back to surface ) in your attached sundry. The well will now be completed as a gaslift producer as opposed to a ESP as originally proposed. The TCP perforations must wait until sundry approval is granted from the AOGCC. rii)/ Guy Schwartz �1\60 ‘,4 pt) Senior Petroleum Engineer �� . AOGCC �f5 907-444-3433 cell 907-793-1226 office From: Dan Marlowe [ma ito dmarioore a hiico_m com] Sent:Thursday, August 15, 2013 8:56 AM To: Schwartz, Guy L(DOA) Subject: 10-403 Monopod -A-18 - Revision - Submitted 08-15-13.pdf Headed your way this morning as requested • Bettis, Patricia K (DOA) From: Davies, Stephen F (DOA) 5t qcorf 4`" t )151/3 Sent: Monday, August 19, 2013 10:39 AM 141 To: Dan Marlowe Cc: Schwartz, Guy L (DOA); Bettis, Patricia K(DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Thanks Dan, I appreciate your help with my questions. Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-7934224 Fax: 907-276-7542 From: Dan Marlowe [mailto:dmarlowe @hilcorp.com] Sent: Monday, August 19, 2013 10:37 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Steve Three wells are completed in the NW quarter section of Section 3,T9N, R13W. There are no other active wells completed in the hemlock zone in the Kokanee Fault Block. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(ahilcorp.com Hilcorp A Company Built on Energy From: Davies, Stephen F (DOA) [mailto:steve.davies@ alaska.gov] Sent: Friday, August 16, 2013 10:43 AM To: Dan Marlowe Cc: Schwartz, Guy L(DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, How many wells are completed in the NW quarter section of Section 3,T9N, R13W? Will the planned perforations in A-18 be less than 660' from the nearest offset wells open to the same defined pools? 1 What is the distance from the new Hemlock perforations at 6010' in A-18 to the nearest Hemlock perforations in the Kokanee Fault Block? Thanks, Steve Davies AOGCC From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Thursday, August 15, 2013 8:34 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Good eye sir, I should have explained that in my prior email cause it made me scratch my head as well initially This well crosses through a substantial fault and the uppermost perf Zone is actually a section of the Kokanee Fault Block. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowehilcorp.com Hilcorp A Company Built on Energy From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, August 14, 2013 3:41 PM To: Dan Marlowe Cc: Schwartz, Guy L(DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, In the drawing that you sent this morning (file name: A-18 Proposed 08-13-13 (2) )the uppermost perf Zone from 6010' to 6150' is labeled "Hemlock". Unless there is a substantial fault in the well, could you correct this error on the final submittal to AOGCC? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Dan Marlowe [mailto:dmarlowe@ hilcorp.com] Sent: Wednesday, August 14, 2013 2:30 PM To: Schwartz, Guy L(DOA) 2 •• Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Guy Currently we are on step#7. We have the tubulars removed and are currently washing down to the packer. The easiest way to explain the perf changes is with the following table comparing original to current plan: Originally Proposed Current Proposal Top MD Btm. MD Feet Top MD Btm. MD Feet Comment 6,010 6,150 140 in addition to original proposal 7,320 7,436 116 in addition to original proposal 7,450 7,533 83 7,450 7,533 83 Same as original proposal 7,544 7,570 26 7,544 7,570 26 Same as original proposal 7,790 7,870 80 7,790 7,870 80 Same as original proposal 7,910 8,030 120 7,904 8,030 126 more than original proposal 8,104 8,158 54 in addition to original proposal 8,425 8,555 130 8,425 8,555 130 Same as original proposal 8,610 8,650 40 8,610 8,650 40 Same as original proposal 8,660 8,675 15 8,660 8,675 15 Same as original proposal 8,734 8,832 98 in addition to original proposal 8,916 8,965 49 8,916 8,965 49 Same as original proposal 9,074 9,120 46 9,074 9,120 46 Same as original proposal 9,146 9,176 30 9,146 9,176 30 Same as original proposal 9,210 9,316 106 9,210 9,290 80 Less than original proposal 9,330 9,420 90 9,330 9,360 30 in addition to original proposal Total 815 Total 1143 Procedurally to change to a gas lift completion we have two different scenarios Scenario 1-Can run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390' (+/-). RD E-line. 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. Depending on log results, repair 9-5/8"casing either by running a or running a 7-5/8" liner to surface. 10. Fill casing with FIW. RIH with a test plug to 7,150' 5,800' and set. Pressure test casing to 1,200 psi. Chart same. 11. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 3 . • 12. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 13. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 7/140' (+/ ),PU and run permanent production packer and set at+/-5,800' 4-5,—PU and run gas-lift completion with seal assembly stabbing into production packer at+/-5,800' 16. ND BOP, NU wellhead and test. 17. Turn well over to production. 18. Complete No-Flow test Scenario 2—Cannot run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390' (+/-). RD E-line. 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 10. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 11. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 12. Preset permanent production packer w/packer plug at+1-5,800' 13. Depending on log results, repair 9-5/8"casing either by running a casing expandable liner patch ec ..7 5/8" line.. 14. Fill casing with FIW. RIH with an inflatable test plug to 7,450' 5,700'and set. Pressure test casing to 1,200 psi. Chart same. , • „ - - - - - -• 7,440-(+44.Pull packer plug, PU and run gas-lift completion with seal assembly stabbing into production packer at+1-5,800'. 19. ND BOP, NU wellhead and test. 20. Turn well over to production. 21. Complete No-Flow test Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 4 • Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe a(�.hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, August 14, 2013 11:41 AM To: Dan Marlowe Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, Where are you currently in the workover program? Are the new proposed perfs only the Hemlock 6010-6150' and D54- 9 7320-7436' ? I will need a revised procedure for the Gas lift completion where it deviates from the original sundry procedure. ...you can submit that by email to me. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Wednesday, August 14, 2013 10:24 AM To: Schwartz, Guy L(DOA) Cc: Ted Kramer; Juanita Lovett Subject: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Guy We are currently in the middle of the workover on Monopod A-18. We have had a couple of changes to the original completion plan—see attached schematic • Added perfs—Spacing reviewed and still compliant • Changed to gas-lift completion instead of ESP I have also included two proposed wellhead diagrams dependent on how we have to repair the casing Let me know if you need me to provide any further information Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarloweahilcorp.com Hilcorp A Company Built on Energy 5 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, August 16, 2013 10:43 AM To: 'Dan Marlowe' Cc: Schwartz, Guy L (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, How many wells are completed in the NW quarter section of Section 3,T9N, R13W? Will the planned perforations in A-18 be less than 660' from the nearest offset wells open to the same defined pools? What is the distance from the new Hemlock perforations at 6010' in A-18 to the nearest Hemlock perforations in the Kokanee Fault Block? Thanks, Steve Davies AOGCC From: Dan Marlowe [mailto:dmarlowe @hilcorp.com] Sent: Thursday, August 15, 2013 8:34 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Good eye sir, I should have explained that in my prior email cause it made me scratch my head as well initially This well crosses through a substantial fault and the uppermost perf Zone is actually a section of the Kokanee Fault Block. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(a�hilcorp.com Hilcorp A Company Built on Energy From: Davies, Stephen F (DOA) [mailto:steve.daviesCaalaska.gov] Sent: Wednesday, August 14, 2013 3:41 PM To: Dan Marlowe Cc: Schwartz, Guy L (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, In the drawing that you sent this morning(file name: A-18 Proposed 08-13-13 (2) )the uppermost perf Zone from 6010' to 6150' is labeled "Hemlock". Unless there is a substantial fault in the well, could you correct this error on the final submittal to AOGCC? 1 ` • • Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 From: Dan Marlowe [mailto:dmarlowe(ahilcorp.com] Sent: Wednesday, August 14, 2013 2:30 PM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Guy Currently we are on step#7. We have the tubulars removed and are currently washing down to the packer. The easiest way to explain the perf changes is with the following table comparing original to current plan: Originally Proposed Current Proposal Top MD Btm. MD Feet Top MD Btm. MD Feet Comment ' 6,010 6,150 140 in addition to original proposal 7,320 7,436 116 in addition to original proposal 7,450 7,533 83 7,450 7,533 83 Same as original proposal 7,544 7,570 26 7,544 7,570 26 Same as original proposal 7,790 7,870 80 7,790 7,870 80 Same as original proposal 7,910 8,030 120 7,904 8,030 126 more than original proposal 8,104 8,158 54 in addition to original proposal 8,425 8,555 130 8,425 8,555 130 Same as original proposal 8,610 8,650 40 8,610 8,650 40 Same as original proposal 8,660 8,675 15 8,660 8,675 15 Same as original proposal 8,734 8,832 98 in addition to original proposal 8,916 8,965 49 8,916 8,965 49 Same as original proposal 9,074 9,120 46 9,074 9,120 46 Same as original proposal 9,146 9,176 30 9,146 9,176 30 Same as original proposal 9,210 9,316 106 9,210 9,290 80 Less than original proposal 9,330 9,420 90 9,330 9,360 30 in addition to original proposal Total 815 Total 1143 Procedurally to change to a gas lift completion we have two different scenarios Scenario 1-Can run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390' (+/-). RD E-line. 2 • • 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. Depending on log results, repair 9-5/8"casing either by running a or running a 7-5/8" liner to surface. 10. Fill casing with FIW. RIH with a test plug to 7050' 5,800'and set. Pressure test casing to 1,200 psi. Chart same. 11. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 12. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 13. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 7,410' (+/ ),PU and run permanent production packer and set at+/-5,800' -PU and run gas-lift completion with seal assembly stabbing into production packer at+/-5,800' 16. ND BOP, NU wellhead and test. 17. Turn well over to production. 18. Complete No-Flow test Scenario 2-Cannot run packer through casing repair: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3. ND Wellhead, NU BOP and test to 250 psi low/3,000 psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4. RU E-line. RIH and cut tubing at 7,390' (+/-). RD E-line. 5. POOH with 3-1/2"tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly,engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9-5/8"casing to 7,489'. POOH with Work string. 8. RU E-line. RIH with casing inspection logs and log the 9-5/8"casing looking for casing damage. 9. PU 7"casing C/O assembly on workstring. RIH cleaning out 7"casing from 7,489'to 9,470'. Circulate hole clean and POH with same. 10. PU TCP perf guns and run into hole. RU E-line. Use e-line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 11. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 12. Preset permanent production packer w/ packer plug at+/-5,800' 13. Depending on log results, repair 9-5/8"casing either by running a casing expandable liner patch or maning_a_7_542.4ifter, 14. Fill casing with FIW. RIH with an inflatable test plug to 7,450' 5,700'and set. Pressure test casing to 1,200 psi. Chart same. 3 • • 7,440' (+/ ),Pull packer plug, PU and run gas-lift completion with seal assembly stabbing into production packer at+/-5,800'. 19. ND BOP, NU wellhead and test. 20. Turn well over to production. 21. Complete No-Flow test Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe @_hilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, August 14, 2013 11:41 AM To: Dan Marlowe Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K(DOA); Davies, Stephen F (DOA) Subject: RE: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Dan, Where are you currently in the workover program? Are the new proposed perfs only the Hemlock 6010-6150'and D54- 9 7320-7436' ? I will need a revised procedure for the Gas lift completion where it deviates from the original sundry procedure. ... you can submit that by email to me. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Wednesday, August 14, 2013 10:24 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Juanita Lovett Subject: Monopod Trading Bay ST A-18 Sundry 313-097, PTD 168-076 Guy We are currently in the middle of the workover on Monopod A-18. We have had a couple of changes to the original completion plan—see attached schematic • Added perfs—Spacing reviewed and still compliant • Changed to gas-lift completion instead of ESP 4 • • I have also included two proposed wellhead diagrams dependent on how we have to repair the casing Let me know if you need me to provide any further information Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(a�hilcorp.com Hilcorp A Company Built on Energy 5 • OF Ti w�� \ \ I %% s9 THE STATE Alaska Oil and Gas 1, oft 1L1 SKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O � � SCANNED MAR 1 8 2013 Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Ted Kramer t 6 s - a 6 Sr. Operations Engineer �/ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai D and E and Hemlock Oil Pool, Trading Bay ST A -18 Sundry Number: 313 -097 Dear Mr. Kramer: 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, di Cathy P Foerster «ay Chair DATED this of March, 2013. Encl. , • • • Q STATE OF ALASKA �� 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 252Rn I V -E 1�0 Lil 1°13 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑- Change Approved Program ❑ Suspend I=1 Plug Perforations ❑ Perforate El - RA Tubing Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install ESP • El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 168 -076 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20143 -00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93 Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay ST A -18 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018731 Middle Kenai D Oil, Middle Kenai E Oil, 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): ,,,'ggg Junk (measured)a 11,000 10,241 9,200' 8,445' V70 f 9,200' 2 '1,6) 13 1 7,51§ . .NIA Wie( Casing Length Size MD TVD burst Collapse Structural Conductor 1,006' 13 -3/8" 1,044' 1,028' 3,090 psi 1,540 psi Surface 7,482' 9 -5/8" 7,520' 6,860' 3,950 psi 2,570' Intermediate Production Liner 2,377' 7" 9,826' 9,064' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,485' - 7,620'. 6,827' - 6,955' 3 -1/2" 9.2# N -80 7,474' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis WD Packer / Otis DK BV SSSV Packer 7,438' (MD) 6,782' (TVD) / Otis DK BV SSSV 303' (MD) 303' (TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic Development: i0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/4/2013 Oil CI Gas ❑ WDSPL ❑ Suspended E 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned E Commission Representative: GSTOR ❑ SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer(ct�hilcorp.com Printed Name Ted Kramer �s�'._�d Title Sr. Operations Engineer Signature ,./4 Phone 907 - 777 -8420 Date 2/22/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l � ; Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: goo b r Sz, 60 t c s t ,� 2 5 r , s ; , A -..' - _r )(-- o 5c-4-6 b /. -S 1 / hQ� r (� Gtl/w -� AQ Gt_. s SLt I ►-� r� 4 - • Spacing Exception Required? Yes ❑ No 4( R Subsequent Form Required: /O - 410 R BGMS MAR 0 q 201 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 - iii. -43 ORIGINAL Mfr ,., Submit Form and Form 10 - 403 (Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Post Office Box 244027 Anchorage, AK 99524 -4027 Hilcorp Alaska, LLC 3800 100 terpoint Drive Anchorage, AK 99503 Phone: 907 /777 -8300 February 25, 2013 Fax: 907/777 8301 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: Amended 403 for Trading Bay ST A -18 (Permit to Drill No. 168 -076) Dear Commissioner Foerster, Hilcorp Alaska, LLC ( "Hilcorp "), as Operator of the Trading Bay Field, hereby resubmits a revised Application for Sundry Approval for Trading Bay ST A -18. See Exhibit A, attached (Revised 403). This revision clarifies Hilcorp's request to return A -18 to production by performing necessary repairs, which include pulling tubing and reperforating within the Middle Kenai D, E and Hemlock Oil Pools. On February 20, 2018, AOGCC requested Hilcorp to provide maps for the Middle Kenai D, Middle Kenai E, and Hemlock Oil pools that show the wellbore trace and perforation intervals of wells completed in these pools within 660 feet, true measured distance, to the Trading Bay St A -18 well. AOGCC also requested Hilcorp include the perforation intervals for the Trading Bay St A -18 well on the maps. This request is reasonable and Hilcorp is pleased to comply. Conservation Order 93 governs spacing exceptions for the Middle Kenai D, E and Hemlock Oil Pools. In relevant part, Rule 4 (Spacing Acreage) states: "Not more than four (4) completed oil wells shall be allowed in each of the defined pools in any governmental quarter section." Rule 5 (Spacing Footage) states: "No oil well shall be completed in any defined pools closer than 660 feet, true measured distance, to any other oil well in the same defined pools." (emphasis added). As shown on Exhibit B, there are five wells in the NW quarter section of Section 3, Township 9 North, Range 13 West, Seward Meridian. Well A -28, A3RD and A3RD2 are abandoned, and therefore not relevant. In addition to the subject well (A -18), wells A -28RD and A -03RD3 are completed within defined pools. Therefore, Hilcorp's proposal to return A -18 to service is compliant with Rule 4 of Conservation Order 93. Hilcorp's proposal to return A -18 to service is also compliant with Rule 5 of Conservation Order 93. Exhibit B illustrates the true measured distance, both horizontally and vertically, of all wells within a 660' radius of well A -18. Given the complex structure and stratigraphy of the Trading Bay Field, the projected horizontal radius (i. e., "bulls- eye ") of applicable wellbore paths is not relevant. Although each well targets production from the Middle Kenai D, E and Hemlock Pools, all such completions Trading Bay Field • • Revised ST A -18 403 Sundry Request February 22, 2013 Page 2 of 2 are isolated by discontinuous fault block systems that are vertically separated by depths greater than 660 feet apart. For example, Exhibit B demonstrates that A -18's closest horizontal perforation to A- 03RD3 exists within the Hemlock Pool. In A -18, the top of the Hemlock is located at a depth of -8,333 feet, whereas the corresponding depth in A -03RD3 lies at -6,506 feet. Therefore, the true measured (vertical) distance between A -18 and A -03RD3 is 1,830 feet. Because this distance (1,830') is significantly greater than the minimum (660') distance required by Rule 5, the proposed reactivation of A -18 does not require a spacing exception under Conservation Order 93. Such complexities are difficult to illustrate when projected onto a standard two - dimensional plot. If you require additional technical information on this issue, please contact Mr. Matt Frankforter, Senior Geologist, at 777 -8376. In the near future, Hilcorp, as the sole working interest owner and Operator of the Trading Bay Field, will propose amendments to Conservation Order 93 to allow unlimited spacing in the oil bearing sands of the Middle Kenai B, C, D, E and Hemlock Pools (except that no well should be open to producing these sands closer than 500' to a lease boundary marking a change in ownership). This proposal will be consistent with Conservation Order 250 and 252, which eliminated spacing restrictions within the undefined sands lying above the Trading Bay Field's Middle Kenai B pool and the undefined sands lying below the Hemlock Oil Pool. Moreover, such a proposal will be consistent with Conservation Order 93A, which expressly allows commingling within the wellbore across all defined and undefined pools, without any requirement for production to be allocated to respective pools and /or sands. Such an amendment will significantly reduce the administrative burden of both Hilcorp and the Commission, particularly in instances such as here, where the objective is to simply return an existing well to production by re- perforating previously produced ✓ pools. We would much appreciate the Commission's thoughts on this matter, and look forward to discussing this issue with you and your staff in the near future. Sincerely, David W. Duffy Hilcorp Alaska, LLC Enclosures: Exhibit A (404 Form) and Exhibit B (A -18 map). EXHIBIT B: A-18 -y- k-' Active Completion --A -28 RD I I Shut -in Completion TBS -01 I 1 Abandoned Completion Proposed Completion TS -02 ' i I po a .,..„, HEM • A -03RD3 ,,... � E ir A -18 too Va. ,- .6506 ZE t`f -A - �" 36 HE3 4 �` -563 NW1 /4, Section 3, E =' T09N, R13W, S.M. '-- A -03RD2 A -2: ` A -03RD 5 --A -15 D �: D • e I ,, - - %-A -01 �i HILCORP ALASKA, LLC TRADING BAY COMPLETION INTERVALS - -TBS -01 A 0 500 ■ FEET 1 OCTO■ lm/WH 7 R'fl ALI - . ‘ • • RECEIVED STATE OF ALASKA JAN 2 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A9, cc 20 AAC 25.280 is1 t -2/2IJI 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ • an e Approved Program Ll Suspend ❑ Plug Perforations ❑ Perforate 2 • PuN Tubing CI - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Install ESP • ❑ 2. Operator Name: 4. Current Well Class: 5. Pe to Drill Number. HilcorpAlaska, LLC Exploratory ❑ Development 2 168-4 6 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. • • Number Anchorage, AK 99503 ;1 733 - 20143 -00-00 , 7. If perforating: 8. Well Name =nd Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93 Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading pity ST A -18 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018731 • Middle Kenai D Oil, Middle Kenai E Oil, Hemlo9K Oil a 11. s P RESENT WELL CONDITION SUMMARY -rr Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Hugs (measured): 1,11, d Junk (measured); • 11,000 10,241 9,200' 8,445' ,, cri z'}p 4 I, 9,200'• a.1 7,515 'Nett 4101 Casing Length Size MD TVD Burst Collapse Structural Conductor 1,006' 13 -3/8" 1,044' i / 1,028' 3,090 psi 1,540 psi Surface 7,482' 9 -5/8" 7,520' / 6,860' 3,950 psi 2,570' Intermediate Production i Liner 2,377' 7" 9,826' u/ 9,064' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,485' - 7,620' • 6,827' - 6,955' 3 -1/2" ✓ 9.2# N -80 7,474' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis WD Packer / Otis DK BV SSSV Packer 7,438' (MD) 6,782' (TVD) / Otis DK BV SSSV 303' (MD) 303' (TVD) 12. Attachments: Description Summary of Proposal I] Yes Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ /Exploratory ❑ Stratigraphic Development:❑ Service El 14. Estimated Date for / 15. Well Status after proposed work: Commencing Operations: 4/4/2013 � / Oil ❑ Gas ❑ WDSPL ❑ Suspended 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned Commission Representative: / GSTOR ❑ SPLUG C 17. I hereby certify that the foregoing is true and correct to the best ofAiy knowledge. Contact Ted Kramer r `r "f Email tkramer(cilhilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature - ( Ph a 907 - 777 -8420 Date 1/25/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5t 3./Dt.t3 Plug Integrity ❑ BOP Test ❑ � Mechanical Integrity Test ❑ Location Clearance ❑ Other: t / / Spacing Exception Required? Y ` ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10 (Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: A -18 Hilcorp Alaska, LL Date: 1/25/2013 Well Name: Monopod A -18 API Number: 50- 733 - 20143 -00 Current Status: SI oil producer (Gas Lifted) Leg: N/A Estimated Start Date: April 4, 2013 Rig: Monopod Rig #56 Reg. Approval Req'd? 10 -403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 168 -076 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Trudi Hallett (907) 777 -8323 (0) AFE Number: 1320027 Current Bottom Hole Pressure: 3,450 psi @ 7,474' (6,816 TVD) From 6/7/10 survey =0.506 psi /ft. grad. Maximum Expected BHP: - 4331 psi @ 9,318' MD (8,561 TVD) Using a .506 psi /foot Gradient Max. Allowable Surface Pressure: -Opsi (Based on 4331 psi @ 8,561' - 8,561 X .55 psi /ft. fluid gradient - calculated from last production test. ) Brief Well Summary The A -18 well was drilled and completed as an oil well in the Hemlock formation in the late 1960's. These Hemlock zones were later isolated by plugs and the D and E zones perforated. The well developed a 9 -5/8" X 13 -3/8" communication in 2005 and was shut in. Drilling mud was pumped down the production tubing by 9 -5/8 "annulus through the leak and up the 9 -5/8" X 13 -3/8" annulus. The current re- completion plan involves removing the current gas lift completion, cleaning out the well to +/- 9,470' MD. The (9 -5/8" casing will then be repaired either by a casing patch or running a 7 -5/8" tie back liner. The well will then be perforated and placed on an ESP for artificial lift. Brief Procedure: 1. MIRU Monopod Platform Rig. 2. Circulate Hydrocarbon off of well. 3000 P 'L 3. ND Wellhead, NU BOP and test to 250 psi low0,090psi high. (Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 4- r � L r� t. v�� °" • 4. RU E -line. RIH and cut tubing at 7,390' ( + / -). RD E -line. 5. POOH with 3 -1/2" tubing string and lay down the same. 6. PU Mill and wash pipe and RIH to 7,438'. Burn over Otis WD Packer. RIH with Spear assembly, engage packer and POOH with same. 7. PU and RIH with Work string and Scraper and C/O assembly cleaning out 9 -5/8" casing to 7,489'. POOH with Work string. 8. RU E -line. RIH with casing inspection logs and log the 9 -5/8" casing looking for casing damage. 9. Depending on log results, repair 9 -5/8" casing either by running a casing expandable liner patch _P or running a 7 -5/8" liner. .- 1 " 4.- . • 10. Fill casing with FIW. RIH with a test plug to 7,450' and set. / Pressure test easing to 1,200 psi. Chart same. 11. PU 7" casing C/O assembly on workstring. RIH cleaning out 7" casing from 7,489' to 9,470'. Circulate hole clean and POH with same. • • Well Prognosis Well: A -18 Hilcora Alaska, LL Date: 1/25/2013 12. PU TCP perf guns and run into hole. RU E -line. Use a -line to place Perf guns on depth and perforate well according to the approved Perf Request Form. 13. Pick up TCP guns above perforations, monitor well by shooting fluid levels allowing the well to stabilize. POOH with TCP guns. 14. RU Schlumberger. PU ESP building into the well. RIH with ESP on 2 -7/8" production tubing and set at 7,440' ( + / -). 15. ND BOP, NU wellhead and test. 16. Turn well over to production. (.4-Le N v Fit) (4.) s f !ti Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing • III • Trading Bay Unit SCHEMATIC Well: A-18 Hilcorp Alaska, LLC Completed: 2/77 CASING AND TUBING DETAIL RKB to TBG Hngr = 37.00' SIZE WT GRADE CONN ID TOP BTM. Tree connection: ?? 13 -3/8" 61 K -55 Seal Lock 12.515 38' 1044' 9 -5/8" 43.5 N -80 Buttress 8.755 31' 67' J 9 -5/8" 40 K -55 Buttress 8.835 67' 4191' o 1 9 -5/8" 40 N -80 Buttress 8.835 4191 5643' 9 -5 /8" 43.5 N -80 Buttress 8.755 5643' 7520' Stage Collar 5598 5600 7" Liner 29 N -80 Buttress 6.184 7489' 9826' i� Tubing: 3 -1/2" 9.2 N -80 Butt 2.992 37 7474' MIO 4:1 JEWELRY DETAIL Suspected hole at NO. Depth ID Item 1700' - 2050' 37.0' 10" x 4" Cameron 5M Tubing hanger, XO to 2-7/8" Butt IM 1. 303' 2.75 3 -1/2" Otis, "DK" BV SSSV Nipple, 2. Camco 3 -1/2" MMG MDL Gaslift Mandrels GLM #1. 2198' 2.875 Camco MMG GLM GLM #2. 3513' 2.875 Camco MMG GLM GLM #3. 4645' 2.875 Camco MMG GLM 2 GLM #4. 5537' 2.875 Camco MMG GLM • G LM #5. 6249' 2.875 Camco MMG GLM M GLM #6. 6867' 2.875 Camco MMG GLM GLM #7. 7364' 2.875 Camco MMG GLM 3. 7403' 2.75 Otis "XA" Sliding Sleeve M 4. 7437' 3.00 Locator Seal Assy. w/ 20' of seals. 5. 7438' 3.5 Otis "WD" Pkr 6. 7472' 2.625 Otis "XN" Profile Nipple, 2.75 M 7. 7473' 3.5 WLEG btm 7474' / 8. 9200' Baker Drillable Bridge Plug. Set to temporarily isolate Hemlock MI 3 G production, 250 BOPD on 11/28/70 I / _ ` � 4 9. 9270' CI BP. 5 Wireline Summary 9/85 CTU Cleanout f/ 7819' to 9205'. Found 1/16" to 1/8" coal, shale & cmt in returns @ 7955'. E • 6 `` ?F 1/89 CTU Clean Out to 9184'. Found tight spot w/ 2 -1/8" guns @ 7880' 7 \ I`t� 1/89 FISH 22.6' x 2 -1/8" Gun, 2' x 1- 11/16" CCL, 2' x 2" magnet, 5' x 1- @7595' b / 11/16" Weight bar, 0.6' x 1 -3/8" Cable Head. Total 32' long �, � /� 10/21/91 Tagged fill w/ 3-1/2" scratcher @7595' 4/27/96 Ta gged fill w/ 3-1/2" scratcher @7543'. @7580' D 12/30/03 Tagged fill w/ 2.62" GR 4/28/05 Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' @7577' Nipple @ 7472' KB. PERFORATION DATA Accum. Date E Zone Top min Amt. SPF Last Opr. Present Condition D 53 8 7,485' • 7,533' 48' 4 1/89 Open D 53 8 7,544' 7,620' . 76' 4 1/89 Open • D 53 -8 7,550' 7,590' 40' 6 6/79 Part covered w/ Fill D 54 -9 7,734' 7,890' 156' 13 1/89 Covered w/ Fill D 55 -7 7,910' 8,030' 120' 7 1/75 Covered w/ Fill • D 56 -1 8,060' 8,130' 70' 4 11/70 Covered w/ Fill Hemlock D 57 -2 8,380' 8,516' 136' 23 6/79 Covered w/ Fill • 8,524' 8,550' 26' 4 11/70 Covered w/ Fill E 58 -1 8,568' 8,682' 114' 19 6/79 Covered w/ Fill �/ E 58 -7 8,734' 8,832' 98' 16 6/79 Covered w/ Fill 1 E 60 -0 8,916' 8,988' 72' 12 6/79 Covered w/ Fill KB ELEV =101' E 60 -5 9,066' 9,116' 50' 8 6/79 Covered w/ Fill PBTD = 9,200' TD = 11,000' • E 61 -1 9,146' 9,176' 30' 4 11/70 Covered w/ Fill ANGLE thru INTERVAL = 24.9° Hemlock 9,210' 9,265' 55' 4 11/68 Temporary Isolated by BP Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP Revised By: TDF 1/21/2013 r, .,, ... n 0 • Trading Bay Unit PROPOSED Well: A -18 HilcorpAlaska,LLC Completed: Future RKB to TBG Hngr= 37.00' CASING DETAIL Size Wt Grade Conn ID Top Btm J 1 13 -3/8" 61 K -55 Seal Lock 12.515 38' 1044' 9 -5/8" 43.5 N -80 Buttress 8.755 31' 67' 9-5/8" 40 K -55 Buttress 8.835 67' 4191' s -9 /s 9 5/8" 40 N -80 Buttress 8.835 4,191' 5,643' 9 -5/8" 43.5 N -80 Buttress 8.755 5,643' 7,520' Repair -5/8" STAGE COLLAR 5,598' 5,600' 1 ` c asing either by 7" Liner I 29 N -80 Buttress 6.184 7,489' 9,826' running a casing TUBING DETAIL 1 expandable liner - . runnin, 2 -7/8" I 6.4 I L -80 EUE 8RD 2.441 37' ±7,340' a 7 -5/8" liner l JEWELRY DETAIL • ' ✓ ✓✓ NO. Depth ID Item 1 37.0' 10" x 4" Cameron 5M Tubing hanger, XO to 2 -7/8" Butt 2 ±7,440' ESP PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt. SPF Last Date Status 2 D 55 -7 7,450' 7,533' 6,794' 6,873' 83' 12 Future Open I ' D 53 -8 7,485' 7,533' 6,827' 6,873' 48' 4 1/89 Open R �� D 55-7 D 53 8 7,544' 7,544' 7,570' 7 6 20' 6,883' 6 883' 6,908' 26' 12 Future Open ( 6 955' 76 ' 4 1/89 Open + D 53 -8 7,550' 7,590' 6,889' 6,927' 40' 6 Future Open - D 54 -9 7,734' 7,890' 7,061' 7,205' 156' 13 Future Open D 56 - 1 7,790' 7,870 7,113' 7,187' 80' 12 Future Open D 55 -7 7,910' 8,030' 7,224' 7,333' 120' 7 Future Open A 9 - 5/ 8 " D 56 -1 8,060' 8,130' 7,360' 7,424' 70' 4 Future Open D 57 -2 8,380' 8,516' 7,654' 7,782' 136' 23 Future Open D 57 -2 8,425' 8,555' 7,696' 7,819' 130' 12 Future Open D 8,524' 8,550' 7,790' 7,814' 26' 4 Future Open EE E 58 -1 8,568' 8,682' 7,832' 7,941' 114' 19 Future Open E 58 -1 8,610' 8,650' 7,872' 7,910' 40' 12 Future Open E 58 -1 8,660' 8,675' 7,920' 7,934' 15' 12 Future Open E 58 - 7 8,734' 8,832' 7,991' 8,086' 98' 16 Future Open E 60 - 0 8,916' 8,965' 8,167' 8,215' 49' 12 Future Open E 60 -0 8,916' 8,988' 8,167' 8,238' 72' 12 Future Open E E 60 -5 9,066' 9,116' 8,314' 8,363' 50' 8 Future Open E 60 - 5 9,074' 9,120' 8,322' 8,367' 46' 12 Future Open E 61 - 1 9,146' 9,176' 8,392' 8,422' 30' 4 Future Open Hemlock 9,210' 9,316' 8,455' 8,560' 106' 12 Future Open Hemlock 9,210' 9,265' 8,455' 8,509' 55' 4 Future Open Hemlock 9,280' 9,318' 8,524' 8,562' 38' 4 Future Open Hemlock 9,330' 9,420' 8,574' 8,663' 90' 12 Future Open Hemlock A 7„ KB ELEV = 101' PBTD = 9,470' TD = 11,000' ANGLE thru INTERVAL = 24.9° Revised By: JLL 1/25/2013 • • Monopod Platform 2013 BOP Stack IIiIi.urp Alm.ka. Luc 01/10/2013 IIIIEW 1i1 it iil lii Ifi If' 111 al Annular Preventer Shaffer Spherical 135 /85MFEX135 /85Mstdd top Shaffer 3.74' 13 5/8 5M 1111 111 111 111 1 Double gate Shaffer SL c.4 ShSL 13 5/8 5M stdd X stdd 10" operators . , 2.83' perators 2.83' =�- .. - � ) =' Mud Cross 135 /85MFEXFE III 111111111 III w/ 3 1/8 5M EFO r? I - . �j�� ill ! ' 1 ] Ii t 2.00' wl2 1116 5M Choke and Kill AEI .Q 15°V.-.11i . , _� i 1 valves w/ Unibolt end 111- II1■IIIJI1.111 - connections for lines a Shaffer SL Single gate i!Oh i - 1.44' Shaffer SL = 13 5/8 5M stdd X stdd III II, Riser 13 5/8 5M Flange X 13 5/8 5M Flange 14.20' 'I 1I Crossover spool ljjl III 1.50' 135/85MX115M • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, February 12, 2013 10:48 AM To: 'tkramer @hilcorp.com' Subject: Application for Sundry Approval: Trading Bay ST A -18 Good morning Ted, I started to review Hilcorp's sundry application for the Trading Bay St A -18 well this morning. I would appreciate receiving maps for the Middle Kenai D, Middle Kenai E, and Hemlock Oil pools that shows the wellbore trace and perforation intervals of wells completed in these pools within 660 feet, true measured distance, to the Trading Bay St A- 18 well. Please also include the perforation intervals for the Trading Bay St A -18 well on the maps. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793 -1238 1 e e FRANK H. MURKOWSKI, GOVERNOR AIfASIiA OIL AND GAS CONSERVATION COMMISSION Tim Brandenburg Drilling Manager UNOCAL P.O. Box 196247 Anchorage, Alaska 99519 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Trading Bay State A-18 (168-076) Sundry Number: 306-082 , '\-·~';;~:'i :~i¡~í~\~ì~ì,!:;..... ,.)'ì,¡,íI(fIiI\ l'f~o1b \~1) Dear Mr. Brandenburg: 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. You have requested that a 60-day period following the completion of well work be granted prior to demonstrating that the well is incapable of flowing ("no-flow test"). Successfully demonstrating no-flow will allow the well to not be equipped with the sub-surface safety valve required by 20 MC 25.265 (a)(2). When either the surface or sub-surface safety valve fails in wells equipped with both valves, the Commission practice is to allow the well to continue to operate for 14 days while repairs are accomplished. It is the Commission's position that the 14-day allowance is applicable for A-18. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A:g on may not appeal a Commission decision to Superior Court unless rehe in has been requested. DATED this~ day of April 2006. Enc!. 1. Type of Request: a STATE OF ALASKA - AÞ ALA~ OIL AND GAS CONSERVATION COM~ION . "'L7 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: RECEIVED MAR 0 8 2006 Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: Suspend Repair well D Pull Tubing D ìssion Waiver -I Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Development Stratigraphic o D Service Exploratory D D 168-076 ~ 6. A~.Numb~ ;S...q-öb 7'J3 . .' 50-~-20143-00 , PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 101' (MSL) 8. Property Designation: Monopod Platform 11. Total Depth MD (ft): 11,000' Casing Structural Conductor Surface Intermediate Production Liner Length 9. Well Name and Number: A-18 10. Field/Pools(s): Trading Bay D,E, Hemlock PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9,210' 8,450' (BP) Size MD TVD ./ Total Depth TVD (ft): 10,241' Plugs (measured): 9,200' Junk (measured): N/A Burst Collapse 1,006' 7,482' 13-3/8" 9-5/8" 1,044' 7,520' 1,028' 6,860' 3090 psi 3950 psi 1,540 psi 2,570 psi Perforation Depth MD (ft): 7485-9318' (see attachment) Packers and SSSV Type: Otis WD Packer at 7438', 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sket 14. Estimated Date for 2,337' 7" Perforation Depth TVD (ft): 6827-8561' TVD 7,489-9,826' 9,064' Tubing Grade: N-80 Packers and SSSV MD (ft): Otis DK BV at 303' 8160 psi 7,020 psi Tubing MD (ft): 7474' Tubing Size: 3-1/2" Date: .j 13. Well Class after proposed work: D. . Exploratory D Development 0 Service D .~ 15. Well Status after proposed work: Oil 0 Gas D Plugged D Abandoned WAG D GINJ D WINJ D WDSPL D D Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~Qrìè 907-276-7600 Date COMMISSION USE ONLY 4/15/2006 Neil Magee 263-7804 . ,~~., /' <'~ '--"""'" ~ Conditions of approval: Notify Commission so that a representative may witnê~s Sundry Number: óL Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: \-.}OÇ:.\o~-\-é,,>\-~~~\- \t)<ë.. cc~~'--~ ~\ ~'0è-\~~ \,-\ ~'f:>O-Ç-~~<ê\"\ ~\o..~Q~C-~S~'SCL~~ ~\~~~~~~~ w\~\~.L.-l~ ~O~ eÄc;.~~ Q ~"~Õ\\~"I :s:.~~oo:~\~~\.~~~ Subsequent Form Required:? ' \. ~ - · ""-. COMMISSIONER APPROVED BY THE COMMISSION Date: tf-' -0 Þ Approved by: ~~;-~R8DMS 8FL APR 5 2006 \ AFE 164784 .4 :y/-ðl ~ '#,6 Submit in Duplicate e e Chevron === Neil Magee Drilling Engineer Union Oil Company of California P.O, Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7804 Fax 907 263 7884 Email mageen@chevron.com March 6, 2006 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West th Avenue Anchorage, Alaska 99501 Re: Monopod A-18 Jet Pump Conversion (Waiver Request) Mr. Maunder: Union Oil requests a temporary waiver of AOGC Regulation 20MC 25.265 to minimize the expense and added complexity involved with running dual SSSV's in the well as we are confident that the well will pass a "No Flow" test. Union Oil Company proposes that a "No Flow" test will be conducted within 60 days of first production from the well following the workover to replace tubing and cleanout fill scheduled for 28 April 2006. If the well is unable to pass a "No Flow" the well will be shut in and isolated with a tubing plug pending a workover to recomplete the well in a different manner which will satisfy AOGCC req uirements. .. Background: Prior to the workover the well produced at 494 bbl/day gross production, 77% cut under gas lift mode. A successful "No Flow" on the well was conducted on 28 '" February 2006. At the time of the "No Flow" test, fill covered the lower portion of the Tyonek D interval and the entire Tyonek E interval. (See attached well schematic.) The proposed workover will entail cleaning out fill across these existing perforations. The attached memo on A-18 Reservoir Performance indicates an expected reservoir pressure gradient of .3 psi/ft from the commingled D and E intervals thus able to meet the requirements for a No Flow completion. Union Oil Company suggests that in light of the high likelihood that the cleanout of the well will not expose abnormally pressured reservoir, the well will be recompleted without SSSV's and be subject to a confirming No Flow test" within 60 days. .' . Please contact me at 263-7804 if you have any questions concerning this application. Sincerely, ~tJr Neil Magee Drilling Engineer Attachments Union Oil Company of California I A Chevron Company http://www.chevron.com e e Chevron === Memorandum To: From: Date: Re: Neal Magee Steve Lambert March 2, 2006 A-18 Reservoir Performance Well A-18 was initially completed as a dual Hemlock and D & E sand producer in November 1968. The Hemlock productivity declined and in December 1970, the well was recompleted as a single string D & E sand producer. The well is completed in the Subthrust block of the Trading Bay Field. The completion contains 5 E zone sands and 5 D zone sands. A total of 1,129' of perforations are open for production. The well has a history of sand production, and fill has been cleaned out of the wellbore 3 times. A-18 has also been reperforated 4 times and acid stimulated 3 times over its history. As shown on the attached production curve, the well has shown a positive response to all previous cleanouts. --- Initial D and E sand pressure measured in the A-18 wellbore in 1968 was 3,257 psi at the datum depth of 7,571' TVD. This equates to a reservoir pressure gradient of .43 psi per foot. . A static pressure measured in the wellbore in July of 2005 following a 2 month shutdown indicated a pressure of 2,250 psi at the datum depth. This represents a pressure gradient of .3 psi per foot and a drop in reservoir pressure of 1,007 psi from initial conditions. " Cumulative production from well A-18 in the D and E sands is 3,913,000 barrels of oil and 3,889,000 barrels of water. Based on the relatively constant gross production from this well over the last 30 years, it is believed that the reservoir pressure is being partially maintained by influx from an adjacent reservoir~ This reservoir is believed to be the Hemlock Texaco Spurr reservoir which is juxtaposed with the D & E sands across a fault. Pressure transient analysis has indicated this fault is approximately 200' from the wellbore. This juxtaposition of the reservoirs across the fault is believed to an ow pressure communication across all the zones even though fill in the wellbore may be limiting production. The recent pressure measurement and understanding the geological structure gives us confidence that the pressure in the wellbore will not exceed the pressure measured in the July 2005 test. Based on this analysis, A-18 will pass the no flow test following the wellbore cleanout. cc: D.A. Cole © Chevron 2005 Chevron .. I -18 Production ry MONOPOD Platform Cumulative Oil Prod: 3913 Mbbl Cumulative Gas Prod: 2994 MMcf Cumulative Water Prod: 3889 Mbbl . . 100 BJ BJ 4) 2J o : -+- Water C~t("4 ) ~lIs!Sel,c ; , : . , , ---~.. _..~- - -+- - -{-- - ~--- ~ -.- .....) , '.......1. .....;......1. .....:......... 1968 69 70 92 93 94 95 96 97 98 99 2000 01 02 03 04 05 1am "i.' ~.. . L... :,,; ! , .... ·..·1 ,t/'~Iœ': !:j '.¡I \ :\!\Î'/ :¡J' , - ...... .. 1\) \' I , ..... .... ~~ R ,;.('JJ[ 'I (~1J! \\ > .~.. . " " , , ,'".. :' ~ : 1 Y \ : ~ - ---"-c-~"rl-" --r- oo ___ .. ___~__ ___ ... .. .. __,.. l..-_ ___.. __,.. .. .. n,_ .. -~-- -~-- -J -- i- ---~.. -;-- n. ;.... '.......;........,. :::~::L: L: L::::::::: ::~:::~\ .. '''~''i~~''~~~¿~~iï2¡¡'' T' r"~ :/ / \ : ~ .:' :r: :~::::: :q¡I:'~~:(ÇDJrt1w.ø )i: : :::::::::: :':::ªiji,ii~:~:~!>H~ Raœ«(" : Xl....·.... .... .. ··r~~i=~<$as¡OlliRatio tÇff~1 V --. :95 ;;....... . "~:.:¡=~:'" WäïërìÏ1j:Ra~¡ëpj{ ~b d) / 7e : ...... /: '''':'''' ; , i 1968 69 70 71' n' 73 74 75 76 "V 83 84 85 86 87 88 æ 90 91 92 93'94 95 96 97 98 99 2000' 01 02 03 04 05 06 1.p1Ud and WrClt.glf œ.œJ2OC615:07:æ Date 1(1)) 100 10 + -Reperfs DOC ID Previous Fill Clean- Outs _ -Acid Stimulations 3 Chevron Pressu isto . Initial reservoir pressure measured in November 1968 : 3257 psi @ 7571' TVD - pressure gradient .43 psi/ft. Static reservoir pressure measured in July 2005: 2250 psi @ 7571' TVD - pressure gradient .3 psi/ft. © 'Chevron 2005 DOC ID 4 UNQCAL8 e e Trading Bay Unit Well # A-18 Completed 2/77 API# 50-733-20143-00 RKB to TBG Hngr = 37.00' Tree connection: ?? SIZE 13-3/8" 95/8" WT CASING AND TUBING DETAIL GRADE CONN III K-55 Seal Lock 12.515 N B TOP 38' 31' BTM. 1044' 67' - 3. -80 uttress 8.755 J 1 9-5/8" 40 K-55 Buttress 8.835 67' 4191' c:::::!L: 9-5/8" 40 N-80 Buttress 8.835 4191 5643' 9-5/8" 43.5 N-80 Buttress 8.755 5643' 7520' Stage Collar 5598 5600 - 7" Liner 29 N-80 Buttress 6.184 7489' 9826' .tI. ~ Tubin..: 3-1/2" 9.2 N-80 Butt 2.992 37 7474' - Ó JEWELRY DETAIL I S d h 1 I NO. Depth I III Item uspecte 0 e at I 37.0' I I 10" x 4" Cameron 5M Tubing hanger. XO to 2-7/8" Butt - 1700' -2050' I 1. 303' I 2.75 I 3-1/2" Otis, "DK" BV SSSV NiDDle, 2. C~mCf) 3-1I2":\I:\IG MOL Gaslìn Mandrels GI/Vi #1. 2198' 2.875 Cameo MMG GLM - GLM #2. 3513' 2.875 Cameo MMG GLM GUI #3. 4645' 2.875 Cameo MMG GLM 2 GL'\'!!!". 5537' 2.875 Cameo MMG GLM . - .. (1)\1 #5ð 6249' 2.875 Cameo MMG GLM GLM #6. 6867' 2.875 Cameo MMG GLM GLM #7. 7364' 2.875 Cameo MMG GLM 3, 7403' 2.75 Otis "XA" Sliding Sleeve - 4. 7437' 3.00 Locator Seal Assy. w/ 20' of seals. S. 7438' 3.5 Otis "WD" Pkr - 6. 7472' 2.625 Otis ")eN" Profile NiDDle, 2.75 7. 7473' 3.5 WLEG btm 7474' 8. 9200' Baker Drillable Bridge Plug. Set to temporarily isolate Hemlock .. 3 Droduction, 250 BOPD on 11/28/70 4 9. 9270' CIBP. ~5 Wireline Summary 9/85 CTU Cleanout f/7819' to 9205'. Found 1116" to 118" coal, shale & cmt ~ in returns @ 7955'. 6 1/89 CTU Clean Out to 9184'. Found tight spot wI 2-118" guns @ 7880' 7 1189 FISH 22.6' x 2-118" Gun, 2' x 1-11116" CCL, 2' x 2" magnet, 5' x 1- @7595' 11116" Weight bar, 0.6' x 1-3/8" Cable Head. Total 32' long 10121/91 Tagged fill wI 3-112" scratcher @7595' ~ 4/27/96 Tagged fill wi 3-112" scratcher @7543' D 12/30103 Tagged fill wI 2.62" GR C?0 @757f .~ 4/28105 Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' Nipple @ 7472' KB. k' PERFORATION DATA Accum. Date E Zone Top 8tm Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered wI Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered wI Fill 8 D 55-7 7,910' 8,030' 120' 7 1/75 Covered wI Fill D 56-1 8,060' 8,130' 70' 4 11/70 Covered wI Fill Hemlock D 57-2 8,380' 8,516' 136' 23 6/79 Covered wI Fill 9 8,524' 8,550' 26' 4 11/70 Covered wI Fill E 58-1 8,568' 8,682' 114' 19 6/79 Covered wI Fill E 58-7 8,734' 8,832' 98' 16 6/79 Covered wI Fill - E 60-0 8,916' 8,988' 72' 12 6/79 Covered wI Fill 61 4 5 KB ELEV= 101' PBTD = 9,200' TD = 11,000' ANGLE thru INTERVAL = 24.9° E 60-5 E 61-1 Hemlock Hemlock 9,066' 9,146' 9,210' 9,280' 9,116' 9,176' 9,265' 9,318' 50' 30' 55' 38' 8 4 4 4 6/79 11/70 11/68 11/11/68 Covered wI Fill Covered wI Fill Temporary Isolated by BP Isolated by BP A-I8 Schm 2-77 Comp REVISED: 10/5/00. DRAWN BY: SLT e Trading Bay Unit Well # A-I8 Proposed Hyd.Completion RKB to TBG Hngr = 37.00' SIZE wr GRADE CONN ID TOP BTM. API # 50-733-20143-00 13-3/8" 61 K-55 Seal Lock 12.515 38' 1044' 9-5/8" 43.5 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 9-5/8" 40 N-80 Buttress 8.835 4191 5643' 9-5/8" 43.5 N-80 Buttress 8.755 5643' 7520' Stage Collar 5598 5600 7" Liner 29 N-80 Buttress 6.184 7489' 9826' .. ~ Tubing: Long String ~) 2-7/8" 6.4# L-80 BTC (SCC) 2.441 37' 7390' Short String 2-7/8" 6.4# L-80 BTC (SCC) 2.441 37' 7391' 1700' -2050' JEWELRY DETAIL NO. Depth ID Item 37.0' Cameron Dual Tubing Hanger 1. +1-7390' 2.441 Pup,2-7/8" 6.4#, L-80 IBT (SCC) Tubing 2. +1-7400' 2.250 Oilwell Hydraulics 2-1/2" Type 'A' BHA . . 3. +1-7419' 2.441 Crossover, 2-7/8" EU 8rd. Box X 2-7/8" Buttress Pin 4. +1-7420' 2.441 I Joint 2-7/8",6.4#, L-80 Buttress Tubing 5. +1-7450' 9-5/8" x 5" OTIS BWD Packer with SBE 6. +1-7460' 2.441 Wireline Reentry Guide SHORT STRING +1-7391 ' 1.995 2-7/8" 6.4#, L-80, IBT (SCC) Tubing A A. +1-7392' 1. 995 Crossover, 2-7/8" Buttress Box X 2-7/8" EUE Pin 7. 9200' Baker Drillable Bridge Plug. Set to temporarily isolate Hemlock production, 250 BOPD on 11/28/70 1 8. 9270' CIBP 2 Wireline Summary 3 Date Activity 5 9/85 CTU cleanout from 7819'-9205', 4 1/89 CTU cleanout to 9184' I ~ 1/89 FISH 22.6' x 2-1/8" gun. 2'xl-l1/16" CCL, 2'x2" magnet, 5' x I" weight 6 bar, .6' x 1-3/8" cable head (Total 32' long) F 10/91 Tag fill with scratcher at 7595' 4/96 Tag fill with scratcher at 7543' D 12/03 Tag fill with 2.62" GR at 7580' 4/28/05 Tag fill at 7577', Ran 2.74" GR to XN at 7472' Casing Leak encountered during pressure test 6/28/05. Well Shut In. ,/' PERFORATION DATA Accum. Date E Zone Top Btm Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered wI Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered wI Fill D 55-7 7,910' 8,030' 120' 7 1/75 Covered wI Fill 7 D 56-1 8,060' 8,130' 70' 4 11/70 Covered wI Fill + Hemlock D 57-2 8,380' 8,516' 136' 23 6/79 Covered wI Fill " 8 8,524' 8,550' 26' 4 11/70 Covered wI Fill f E 58-1 8,568' 8,682' 114' 19 6/79 Covered wI Fill E 58-7 8,734' 8,832' 98' 16 6/79 Covered wI Fill E 60-0 8,916' 8,988' 72' 12 6/79 Covered wI Fill ...¿1 ........../ i/ )"""'- - , , , v r Fill CASING AND TUBING DETAIL KB ELEV = 101' PBTD = 9,200' TD = 11,000' ANGLE thru INTERVAL = 24.9° E605 E 61-1 Hemlock Hemlock 6/79 11/70 11/68 11/11/68 9,066 9,146' 9,210' 9,280' 9,116 9,176' 9,265' 9,318' 50 30' 55' 38' 8 4 4 4 Co e ed wI Covered wI Fill Temporary Isolated by BP Isolated by BP DRAWN BY: NM 2/21/06 (Updated) e VŒ lID~ ~~~~æffi\ e "".,4SIiA. OIL A1Q) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR March 30, 2006 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent U nocal PO Box 196247 Anchorage, Alaska 99519 . '-"'1_""'--" .___. RE: No-Flow Verification Trading Bay State A-18, PTD 168-07~tlH:,\i~m~1~Yj í " \. $. Dear Mr. Myers: The Alaska Oil and Gas Conservation Commission witnessed attempted no flow tests at Unocal's Monopod platform, Trading Bay State Well A-18 on February 17 and 28, 2005. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for several hours. Neither test has provided conclusive evidence that the perforated interval will demonstrate no flow to surface. As such, the subsurface safety valve must be installed, tested, and maintained in proper working condition as required in 20 AAC 25.265. The Commission did not approve the no flow test attempt on February 17 because of the uncharacteristic lack of gas or liquid flow from the well. Subsequent review of wireline work logs by the inspector indicated the possibility of a wireline plug left in the well. Unocal reentered Well A-18 and retrieved a wireline plug set in the tubing abùve the perforated interval. The no flow test performed February 28 followed the same test procedures. Again, an uncharacteristic lack of gas or liquid flow from Well A-18 during the test indicated the possibility of additional obstructions, preventing the true evaluation of the unassisted flow potential of the perforated interval. Work records for the retrieval of the tubing plug appear to support the Commission's concerns and indicated that the perforated interval may be covered by fill. The Commission will allow the removal of the subsurface afety valve from Well A-18 only when a definitive no flow result has been d ed 0 the Commission. cc: Bob Fleckenstein e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -:J P.I. Supervisor Ka11 3/2\ \O~ DATE: February 28,2006 SUBJECT: No-Flow Test Chevron / Monopod PL T Well #A-18 1 b PTD- 1680760 ~'6 .... Ó Trading Bay Unit February 28, 2006: I traveled to Chevron's TBU Monopod Platform in Cook Inlet to witness a No-Flow Test on oil producer well A-18. FROM: Jeff Jones Petroleum Inspector J" ;\~~lt:¡';\ ·j",,".e . ) -..¡.¡.,~- Chevron Lead Operator Eric Braun performed the test today in a safe and proficient manner. Prior to the test we inspected the well, verified to the extent possible an open flow path from the well bore and discussed the test procedure. Well A-18 was lined up from the tree top swab valve through an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and a 3/4" hose terminating in an open top container. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes (see below). Unassisted gas flow from the well was below the measurable range of the flow meter and no liquid was produced during the test These flow conditions appeared unusual to me for a No-Flow test: I could detect no gas flow from the well at all and not a drop of liquid was produced. I asked Mr. Braun to "shoot a fluid level" in the well bore, but he indicated that no equipment to accomplish this task was onboard. I then reviewed the well bore schematic and wireline service reports. Recent wireline service reports indicate that significant difficulty was encountered setting and retrieving a tubing plug due to solids in the tubing and the well bore schematic indicate In my opinion, due to a previous failed No-Flow test on 2/17/06 and the indications of solids in and immediately below the tubing string, AO.G.C.C. witnessed verification of an open flow path from the well bore perforations to atmosphere is recommended prior to granting a No-Flow determination for this well. Summary: I witnessed a No-Flow Test performed on Chevron's Trading Bay Unit well A-18 on the Monopod Platform; further demonstration of an open flow path is recommended prior to granting No-Flow status. Attachments: Well bore schematic & wireline service reports (3) V Ç£i. Chris Meyers / Eric Braun (Chevron) Gas 8:30 < 180 SCFH none 9:00 < 180 SCFH none 9:30 < 180 SCFH none 10:00 < 180 SCFH none 10:30 < 180 SCFH none 11:00 < 180 SCFH none 11:30 < 180 SCFH none Start Test End Test Produced to open top container through Annor-Flow meter model #3461-03TO calibrated: 12/14/05 Total liquid produced: none ffiJ02 Page I of I NO-FLOW Monopod PL T A-18 retest 2-28-06 JJ.xls r"-UI" . rWl1.ar·t.t (',llr'e.l1ne !nç r-Hi\ .I'!U. . ';:~ ( '¿O.)- (.llö r- e.o. ¿ ( ¿¡:J\::IQ I!I.). .).lr-l'!. .... ¿ e lIOCAL ALASKA RESOURCES WELL SERVICE REPORT Date: ..2 -...u -- {¿, Work being done: fl., fJ Supervisor: WireHne Unit Number: T reG Valve Condition Fluid Level if Identified Zero Wireline at: Minimum Tubing ID: Start Tbg, & Csg. PSI I-J/¡4. ,.. ..-. 1130 (J../o I.u.o 1 2Q J530 j(¿,2.r 8C>ð iCfðO 20\0 ::lttr -:z-ZoO ,. - ¡Work Stríng Detail: j ~/I 'We!1 Number Location: AFE# I Charge Code: Pollard Wlreflne Crew: Total WlraHne MII~s; Max Depth (KB): Well KB: Max Tool OD: Ending Tb & Clg PSI A - IS' f'Ylc/l(;) ~ 2S --1 ,6' MlT Un !t ¡ Oescrlptlon of any ¡ too!, or debrf, 11ft ¡ In the hole: Brief Summary of Total Work Com leted fOUl HounI Worked 17 (0....... .. KLL. Total Toot CQst ;l. S"5' d- Total Hour Coat Day. : ~ Cumuratllle Cost: f' {Þ H2S PÞM .r:>lfr WIre Tltst Code: Approved by: !:-C--- I-I'!UI'1 pollard Wirel ine: Inc e UNOCAL ALASKA RESOURCES WELL SERVICE REPORT FAX NO.:907 283~7118 e Feb. 27 20Ø6 03:31PM P3 Date: Work being done: . Supervìsor: (; WìreJÎne Unit Number: fI1f).~ Tree Valve Condition Fluid Levtl if Identified Zero Wireline at: MinImum Tubing 10: Start T bg. &. Csg. PSI Tim 'Well Number Locatíon; AFE# I Charge Code: Pollard Wlrellne Crew: Total Wlreline MH~s: Max Depth (Kè): Well KB: Max Tool 00: EndIng Tbg & Csg PSI In Unit V-- Wf .--1 í -1 1,$0"-1 b:..l /336 -,S- 'hr. ,700 .{)t> -- rwOJi( String Detail: : ,~ ; D8Sc;:rlptlon of any ¡ tools or d.orll I.ft \ In tht hole: Brief Summary of Tota! Work Com leted -- 1128 PPM ..:t.- Total Hour Coat Day'# : Cumul.tl1(8 Cost: WlrlJ Te.t Code: ...r 0- .,~.. · ........- - . ~ n IMI n £'U '-"10] ..-._....~...... --~ API# 50-733-20143-00 e e Trading Bay Unit Well # A-IS Completed 2/77 CASING AND TVBING DETAIL RKB to TBG Hn9r = 37.00' Tree connection: 11 Ð::3 KB ELEV = 101' PBTD = 9,200' TD = 11,000' ANGLE thru INTERVAL = 24.9° A-IS Schm 2-77 Comp SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Seal Loek 12515 38' 1044' 9-5/8" 435 N-80 Buttress 8.755 31' 67' 9-5/8" 40 K-55 Buttress 8.835 67' 4191' 9-5/8" 40 N-80 Buttress 8.835 4191 5643' 9-5/8" 435 N-80 Buttress 8.755 5643' 7520' Stae:e Collar 5598 5600 7" Liner 29 N-80 Buttress 6.184 7489' 9826' Tobin!!:: 3-1/2" 9.2 N-80 Butt 2.992 37 7474' JEWELRY DETAIL NO. D~h ID Item 37.0' I 10" x 4" Cameron 5M Tubing hanger, XO to 2-7/8" Butt 1. 303' 2.75 I 3-1/2" Otis, "DK" BV SSSV Nipple, 2. Cameo 3-1/2" MMG MDL Gaslift Mand"els GLM #1- 2198' 2.875 Cameo MMG GLM GLM #2. 3513' 2.875 Cameo MMG GLM GLlI--1 #3. 4645' 2.875 Cameo MMG GLM GLM #4. 5537' 2.875 Cameo MMG GLM GLM #5. 6249' 2.875 Cameo MMG GLM GLi\-I#6. 6867' 2.875 Cameo MMG GLM GLM #7. 7364' 2.875 Cameo MMG GLM 3. 7403' 2.75 Otis "XA" Sliding Sleeve 4. 7437' 3.00 Locator Seal Assy. w/ 20' of seals. S. 7438' 35 Otis "WD" Pkr 6. 7472' 2.625 Otis "XN" Profile Nipple, 2.75 7. 7473' 35 WLEG blm 7474' 8. 9200' Baker Drillable Bridge Plug. Set to temporarily isolate Hemloek production, 250 BOPD on 11/28/70 9. 9270' CIBP. 5 Wireline Summary CTU Cleanout f! 7819' to 9205'. Found 1116" to 118" coal, shale & cmt in returns @ 7955'. CTU Clean Out to 9184'. Found tíght spot wI 2-118" guns FISH 22.6' x 2-118" Gun, 2' x 1-11/16" CCL, 2' x 2" magnet, 5' x 1- 11116" Weíght bar, 0.6' x 1-3/8" Cable Head. Tota132' long Tagged fill wI 3-1/2" scratcher Tagged fill wI 3-112" scratcher Tagged fill w/ 2.62" GR Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' Nípple @ 7472' KB. @7595' @7543' @7580' @7577' 9/85 1189 1189 @ 7880' @7595' o 10/21/91 4/27/96 12/30103 4/28/05 E PERFORATION DATA , Accum. Date I i I I Zone ! Top Btm I Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' I 76' 4 1/89 Open D 53-8 7,550' 7,590' I 40' 6 6/79 Part covered wI Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered wI Fill D 55-7 7,910' I 8,030' 120' 7 1/75 Covered wI Fill D 56-1 8,060' 8,130' 70' 4 11/70 'Covered wI Fill D 57-2 8,380' 8,516' 136' 23 6/79 Covered wI Fill 8,524' 8,550' ! 26' 4 11/70 Covered wI Fill E 58-1 8,568' i 8,682' 114' 19 6/79 Covered wI Fill E 58-7 8,734' 8,832' 98' 16 6/79 Covered wI Fill E 60-0 8,916' 8,988' 72' 12 6/79 Covered wI Fill E 60-5 9,066' 9,116' 50' 8 6/79 Covered wI Fill E 61-1 9,146' 9,176' 30' 4 11/70 Covered wI Fill Hemlock 9,210' I 9,265' 55' 4 11/68 Temporary Isolated by BP Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP Hemlock REVISED: 10/5/00 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '1&'? ..3IZtDcO P.I. Supervisor ) r/l FROM: Jeff Jones Petroleum Inspector DATE: February 17, 2006 SUBJECT: No-Flow Test Chevron I Monopod PL T Well #A-18 PTD - 1680760 Trading Bay Unit February 17, 2006: I traveled to Chevron's TBU Monopod Platform in Cook Inlet to witness a No-Flow Test on well A-18. Chevron Lead Operator Eric Braun performed the test today and prior to the test we inspected the well and discussed the procedure. Well A-18 was lined up from the tree top swab valve through a 1/2" hose to an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and terminated in an open top container. Mr. Braun indicated to me that the well was previously flow tested by platform personnel and that the flow path was open from the well bore perforations to the open top container. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the well was below the measurable range of the flow meter and no liquid was produced during the test. These flow conditions appeared unusual to me for a No-Flow test: i.e. imperceptible gas flow and no liquid produced. I reviewed the well bore schematics and wire line work reports and noted that a tubing plug appeared to have been set in the well and not removed prior to the test. I then requested that Mr. Braun provide verification that the plug had been removed. Mr. Braun contacted a Pollard wire line representative and Mr. Hal Martin (Chevron Optimization Engineer) and was unable to confirm that the plug had been removed. Mr. Martin indicated to me that breakdowns in communication, reporting and recordkeeping were likely the cause of the incident. Well A-18 failed the No-Flow test and does not meet the AOGCC requirements for a No-Flow status determination at this time because a wire line plug was left in the tubing. Summary: I witnessed an unsuccessful No-Flow Test on Chevron's Trading Bay Unit oil producer well A-18 on the Monopod Platform. A wire line plug was found to be set in the tubing, apparently without the knowledge of the operator. Attachments: none /. Ç£i. Chris Meyers I Eric Braun (Chevron) 10:30 11:00 11:30 12:00 12:30 1:00 PM I :30 PM Gas < 180 SCFH < 180 SCFH < 180 SCFH < 180 SCFH < 180 SCFH < 180 SCFH < 180 SCFH none none none none none none none Start Test End Test Produced to open top container through Annor-Flow meter model #3461-03TO calibrated: 12/14/05 Total liquid produced: none Wire line plug left in tubing prior to test: failed test ffiJ02 Page I of I NO-FLOW Monopod PLT A-18 2-17-06 JJ.xls e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ Z( (u.p P.I. Supervisor '(\0[1 . 2( j. FROM: Jeff Jones Petroleum Inspector DATE: February 17, 2006 SUBJECT: No-Flow Test Unocall Monopod PL T A-18 PTD- 1680760 Trading Bay State Field February 16,2006: I traveled to Chevron's Trading Bay State field Monopod Platform in Cook Inlet to witness a No-Flow Test on well A-18. Chevron Lead Operator Eric Braun performed the test today and prior to the test we inspected the well and discussed the procedure. Well A-18 was lined up from the tree top swab valve through a 1/2" hose to an Armor-Flow model # 3461-03TO flow meter (180 SCFH to 1800 SCFH span) and terminated in an open top container. Mr. Braun indicated to me that the well was previously flow tested by platform personnel and that the flow path was open from the well bore perforations to the open top container. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the well was below the measurable range of the flow meter and no liquid was produced during the test. These flow conditions appeared unusual to me for a No-Flow test: Le. imperceptible gas flow and no liquid produced. I reviewed the well bore schematics and wire line work reports and noted that a tubing plug appeared to have been set in the well and not removed prior to the test I then requested that Mr. Braun provide verification that the plug had been removed. // Mr. Braun contacted a Pollard wire line representative and Mr. Hal Martin (Chevron Optimization Engineer) and was unable to confirm V that the plug had been removed. Mr. Martin indicated to me that breakdowns in communication, reporting and recordkeeping were likely the cause of the incident. Well A-18 failed the No-Flow test and does not meet the AOGCC requirements for a No-Flow status determination at this time because a wire line plug was left in the tubing. Summary: I witnessed an unsuccessful No-Flow Test on Unocal's Trading Bay State well A-18 on the Monopod Platform. A wire line plug was found to be set in the tubing. Attachments: none Ç£i. Chris Meyers I Eric Braun (Chevron) Gas 10:30 < 180 SCFH none 11:00 < 180 SCFH none 11:30 < 180 SCFH none 12:00 < 180 SCFH none 12:30 < 180 SCFH none 1:00 PM < 180 SCFH none 1:30 PM < 180 SCFH none Start Test End Test Produced to open top container through Annor-Flow meter model #3461-03TO calibrated: 12/14/05 Total liquid produced: none Wire line plug left in tubing prior to test: failed test. ffiJ02 Page I of I 2006-0217 _No-Flow 3BF _Monopod_A-18Jailjj.xls (~ Y¡ :, ,¡/JD ~, " rr .,\:~ . -11\ . 'I i? æJLlr~Ulb ~,_. ;(:¡nil "I, I Ur II' p r ,! :I ·,:,P '\.) ]j IU; ~:::f-) ~. '¡~~\il 1,1\ '--. i ï~\ ;i! / 1\ \ (.~ /' ,I 'j '! ./ i ; ï ",', ,u=:~ 1 LJ L~i ¡:Ç) r-' / ,\ \ ,/ !j \ " ,¡-¡I !-i ,U 333 W. -rH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI. GOVERNOR AI1ASKA. OIL AlQ) GAS CONSERVATION COMMISSION Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 \6£6/01 b Re: Trading Bay Field, A-18 Sundry Number: 306-022 ~CANNEg) FED 1 ($ 20D5 Dear Mr. Brandenburg: 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. When providing notice for" a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ DATED this/S;ay of February, 2006 Encl. Chevron .. Neil Magee Drilling Engineer Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7804 Fax 907 263 7884 Email mageen@chevron.com January 16, 2006 RECEIVED JAN 1 7 2006 Alaska Oil & Gas Cons C .. . OJnrnIBSIOß Anchorage Tom Maunder Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Re: Monopod A-18 Jet Pump Conversion (Form 10-403) Mr. Maunder: Union Oil is proposing to recover the existing gas lift completion from Monopod A-18 well and replace it with a dual string hydraulic completion in the Tyonek 0 and E. The well is currently shut in due to a breach of the production casin~ which occurred during a pressure test in June óf last year. The purpose of this letter is to advise you of what steps will be undertaken to ensure the well may be safely returned to production. (Note: Attached is a copy our correspondence of 22 November 2005 concerning the re- completion of this well) As detailed to you in the1 0-404 from Gary Eller dated August 22, 2005, diagnostics indicated that the well has an apparent production casing leak. The well was secured with a wireline retrievable bridge plug until a determination was made on how to safely return the well to production. In summary, during an attempt to pressure test the 9%" casing to 2,700 psi to facilitate installing a tubing jet pump completion, the casing suddenly dropped at 2,400 psi test pressure. Following the failed pressure test diagnostics were undertaken to assess the nature of the failure. Wellhead diagnostics confirmed the 9%" wellhead seals to be intact. Following these tests a number of pressure - temperature surveys were performed to help identify the location of the casing failure. The surveys indicate that there is a good likelihood that there is a casing leak between 1,700' and 2,050'. In view of production casing integrity issues, the re-completion will include (A), an isolation production packer which would not normally be included in a dual string hydraulic completion which is sub-normally pressured (5.1 PPG EMW) and (8), a production annulus pressure detection system incorporated into the surface production system tõ alert the production operator of a packer or tubing breach so the well may be shut in. These measures should ensure that the production annulus above the packer is not subjected to well bore pressure and may be quickly contained should a leak occur. Union Oil Company of California I A Chevron Company http://www.chevron.com Tom Maunder Alaska Oil & Gas Conservation Commission Page 2 Please contact me at 263-7804 if you have any questions concerning this application. Sincerely, r~dF Neil Magee Drilling Engineer Attachments Cc: Tim Brandenburg Union Oil Company of California I A Chevron Company http://www.chevron.com 'òts <} IS! ( STATE OF ALASKA "' Iv C1If" ALASKA OIL AND GAS CONSERVATION COMMISSION t~ RE "..../)~()(, APPLICATION FOR SUNDRY APPROVALS)./,LJ CEIVED 20 MC 25.280 v O~, Operational shutdown U Perforate U wa/A1tLJ1 ï 2006 Otherl:J Plug Perforations 0 Stimulate 0 AlaalfãcUW8ñS Perforate New Pool 0 Re-enter Suspended we~ Cons. COfrtmission . . orane 4. Current Well Class: 5. Permit to ~mbep. Development 0 Exploratory 0 168-076 Stratigraphic 0 Service D 6. API Number: 50-133-20143-00 .../ Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 101' (MSL) 8. Property Designation: Monopod Platform 11. Total Depth MD (ft): 11,000' 1. Type of Request: Casing Structural Conductor Surface Intermediate Production Suspend U Repair well D Pull Tubing 0 9. Well Name and Number: A-18 10. Field/Pools(s): Trading Bay D,E, Hemlock PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 10,241' Effective Depth MD (ft): 9,210' Effective Depth TVD (ft): 8,450' (BP) MD TVD Plugs (measured): 9,200' Junk (measured): N/A Length Size Burst Collapse 1,006' 7,482' 13-3/8" 9-5/8" 1,044' 7,520' 1,028' 6,860' 3090 psi 3950 psi 1,540 psi 2,570 psi Liner 2,337' 7" 7,489-9,826' 9,064' 8160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7485-9318' (see attachment) 6827-8561' TVD 3-1/2" N-80 7474' Packers and SSSV Type: Packers and SSSV MD (ft): Otis WD Packer at 7438', Otis DK BV at 303' 12. Attachments: Description Summary of Proposal l:J 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory D Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/1/2006 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager ~ c~( ~hone 907-276-7600 ~ ~ - COMMISSION USE ONLY Signature Contact Neil Magee 263-7804 Date 1- IS-D~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Cf)Lo ....- 0 ¿l.(;L; Plug Integrity D BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other:Cc"~~~\:-J;;\-...~,,,\-\~ \ ·~{J·?-\-t'~·~, Approved _ ': RBDMS 8ft FEB J 6 2DOS COMMISSIONER APPROVED BY THE COMMISSION Date: cP --/S- ~oÞ I GIN A L AFE 164784 Submit in Duplicate Monopod A-IS Proposed W orkover and Recompletion Objective: The well is currently a 3-112" gas lift completion which has been shut in due to production casing failure. The objective of the workover is to recover the current completion, assess the ruptured production casing, cleaning out fill across the Tyonek D and E intervals and re-complete the well with a Kobe jet pump. Well Status: A downhole failure occurred in the well on 6/7/05 while attempting to test the 9-5/8" production casing to 2700 psi ahead of a planned through tubing jet pump installation. A sudden pressure drop occurred at 2400 psi while applying pressure to both the 9- 5/8" and 3-112" tubing strings. Immediately after the failure the tubing read 620 psi and the 9-5/8" casing read 360 psi. Follow up pumping and pressure/temperature surveys indicate that there is a casing leak estimated at1700' to 2050' MD. The 9-5/8" casing takes fluid at 1.6 BPM with 450 psi pump pressure. The tubing string appears to be standing full however will not pressure test. (Took 30 minutes to bleed from 1500 to 380 psi.) Indications are that a small leak may be present in the string above the tailpipe plug. The well is secured with a PXN plug and 5' prong set in the tailpipe at 7472'. The safety valve was removed 6/7/05 and records do not indicate it was re-installed. The last slickline tag offill was 4/28/05 at 7577' with a 2.74" GR. After a coil cleanout in January 1989, a 32' long 2-118" gun and weight bar was lost in the hole. The fish is at least 7595' deep. (Schematic attached) No attempts have been made to recover or pass by this fish. Status / Specs: Tubing: 3-112", 9.2#, N-80, Butt, 2.992" ID Tubing tail: 2.75" PXN plug /prong installed in nipple at 7472' Prod. Casing: 9-5/8",40#,43.5#, N-80 and K-55 (See Schematic) Liner: 7",29#, N-80 @ 7489' to 9826' Safety Valve: 3-112" Otis DK Ball Valve at 303'(removed 6/6/05) GLM's: Gas lift valves are in place WH Connection: 3-112" Bowen Min.ID/Depth: 2.625" in XN Nipple @ 7472' PBTD: 9200' Packer Depth (MD): 7438' Gauge /Date: Fill Tagged @7577' KB on 4/28/05 w/ 1-3/4" sample bailer retrieved sample of sand. Monopod A-18 AOGCC 1 RKB to THF: Max Deviation: 2.84" braided line brush run to 7500' on 7/15/05 37' 33° at 1558' and 3437' MD H2S Concentration: No well reading - Facility Gas Lift System is 90-120 PPM. A H2S safety technician and a full complement of H2S equipment will be onsite. Condition of Wellhead: The wellhead was tested on 6-10-05 by Cameron (Rich Holliday). Tubing hanger tested to 4600 psi for 15 minutes 9-5/8" casing secondary seals (upper) appear to leak. The primary seals (lower) have been pressure tested to 350 psi to verify integrity. Pre- W orkover Work: Open XA sleeve at 7403' for tubing circulation. Remove PXN plug and prong. Wellhead: Function test alllockdown screws. Clean scale and chase threads in valve profile of tubing hanger. W orkover Fluid Required The estimated pore pressure of the Tyonek D sand is 1800 psi. This equates to a 5.1 ppg EMW at top perforated interval. The desired workover fluid is 3%KCL/FIW (8.6ppg) Special Concerns: Suspect 9-5/8" casing burst at 1700-2000'. Suspect tubing corroded as indicated by scale recovered in bailing runs while attempting to recover plug in XN. Hole in tubing as evidenced by failed pressure test. Monopod A-18 AOGCC 2 W orkover Procedure Summary: 1. Skid rig over well RJU hardlines to casing annulus and line out to choke manifold. Pressure test lines to 3000 psi. (Lines WP to be 5000 psi.) Note: SSSV was removed 6/6/05. PXN plug and prong set at 7472' (removed during pre-work) XA at 7403' to be opened during pre-work. 2. Check for well pressure, bleed off and confirm dead. Attempt to load well with 8.6 ppg (3%FIW/KCL) by pumping down the tubing string and taking returns up the annulus. Tubing/casing capacity to packer at 7438' is 526 bbls Tubing capacity = 65 bbls (.0087 bbl/ft), Casing capacity = 461 bbls( .062 bbl/ft) Clear tubing by bullheading 10bbls. 3. Install TWC and recover tree. Note: Cameron DCB-FBB 10" Nom tubing hanger (6-1/4" seal neck) 3-1/2" EUE TOP x BTM with 1/8" control line prep. Note: Have Sweeney hydraulic wrench available. 4. Confirm condition and type of hanger threads (Reported as 3-1/2" EUE.) tubing hangar top. Note: Have wellhead engineer verify that all pressure has been bled from all lines and all voids associated with the tree, seal flange, tubing hangar, tubing spool and any other potentially energized void immediately prior to removal. Wellhead engineer should ensure hangar lock pins have been checked for free movement prior to the start of rig operations. 5. NIU 13-5/8" BOP's as shown below: BOP Arrangement: Annular Preventer Pipe Rams Blind Rams Mud Cross Pipe Rams Test BOP per Unocal and AOGCC specifications. Test rams 250 psi low, 3000 psi ./ high. Annular 250 psi low, 1500 psi high. Complete Unocal Alaska BOP Checklist and Contractors Checklist and fax to office. Monopod A-I8 1: f'..DC;,C c.. k... \--Co '~?v\.( \ WOCC /~ 3 6. Note: Notify AOGCC 24 hours in advance of BOP test. 7. Hold Pre- W orkover Safety Meeting. Brief crews on safety and environmental concerns and handling of NORM pipe and potential presence ofH2S. 8. Monitor well for pressure. 9. Rill with 3-1/2" landing joint and engage tubing hanger (3-1/2" EUE). Attempt to pull tubing string free from Otis WD packer at 7438', if free pull seals free and circulate one tubing volume to clear any gas migration below packer. Tensile strength of the 3-1/2" 9.2#N-80 BTC tubing is 207K-Lbs. No tubing caliper has been run however considering the age of the tubing (installed 1977), indications of a small leak in recent pressure test and slickline reports in which scale has been picked up, the maximum recommended overpull is 70% of the tensile strength or 145K-lbs. The estimated overpull to recover the tubing is 68K-Lbs( tubing weight in air) + 10K-Lbs (sealoverpull) = 78K-Lbs. 10. POOH laying down tubing and spool control line from 305'.Once GLM's are laid down have them sent to Pollard for valve removal and refurbishment. Tubing to be junked. Note: Have TIW and X-over to 3-1/2" Butt available. Note: All tubing recovered from well to be handled and inspect for NORM contamination in accordance with NORM Guidelines (1997 Guidelines Attached) Note: In the event tubing plugs with scale during recovery have hot tap tool available. 11. Install bore protector in wellhead. Make up packer milling BHA: 12. Rill and swallow WD packer at 7438'. (Min ID= 5", OD=8-l/4", Length 4.00') Mill approximately 2' until packer falls down hole. Circulate bottoms up and POOH. 13. Rill with fishing assembly to recover packer and tailpipe assembly. 14. Wash down last two joints before tagging packer. Establish up and down weights and rotation prior to engaging. Monopod A-18 AOGCC 4 15. Engage packer/tubing stub and POOH laying down packer assembly. Change Out DCB Tubing Spool (Provisional) · Make up RTTS. drill pipe and 6 drill collars. (confirm weight) Set RTTS approximately 10' below wellhead. · With well secure remove nipple down 13-5/8" BOP's. · Remove Cameron DCB 13-5/8" 3M x 10" 5M tubing spool. · Install and test replacement DCB tubing spool. Test seal to 3000 psifor 30 minutes. Note: Exercise caution when doing wellhead work. Restrict rig floor activities so as not to endanger personnel working below. . Nipple up BOPE and shell test to 3000 psi. 16. Make up clean-out assembly. Cleanout assembly is designed to swallow 32' long perforating gun fish and wash ahead to approximately 9210' (See Step 17 for details of fish) Note: A calcium carbonate pill(s) will be prepared ahead of time (See Baroid Recommendation) and spotted after tagging fill to seal off the perforations so that circulation may be established to clean the sand from the wellbore. 17. Rffi to top offill estimated at 7577'. Wash fill to retainer at 9210' allowing perforating assembly at approx. 7595' to fall to bottom as fill is removed. Total length of fish is 32 f1. (Drawing attached.) 18. Circulate well clean Monitor returns for estimate of formation sand recovered. 1623' = 60 bbls fill. POOH with clean out assembly. 19. Make up and Rffi with clean out assembly: 20. Circulate hole clean and POOH to 7300'. Wait for one hour to allow any sand debris to settle. Rffi and tag plug. 21. POOH and lay down clean out assembly. Monopod A-18 AOGCC 5 RUN COMPLETION Note: This well is not capable of flow and will not have a SSSV installed. 1. Install and test dual 2-7/8" rams in upper ram cavity and test to 3000 psi. 2. Rig up APRS e-line. Run GR/Junk basket to TOL at 7489'. Run and set permanent packer at 7400' . Note: Top of existing perforations at 7485', TOL at 7489'. 3. Recover wear bushing. Rig up to run completion. Pick up completion as follows. Dope pin connections only using a small paint brush with lead free modified dope. Lone Strine Baker Locator Type Seal Assembly with 4.5" OD NITRILE Elastomers, 2- 7/8" Butt box up x ~ mule shoe down Centralizing sub (3.5" OD x 2.5" ID with three 8-3/8" fins 1 joint 2-7/8" 6.4 lb/ft L-80 Butt tubing Otis X nipple profile (2.313") 1 joint 2-7/8" 6.4 lb/ft L-80 Butt tubing KOBE (?) 2-1/2" Double BHA Cavity Pup 2-7/8" EUE 6.4 lb/ft Box x Pin x-over 2-7/8" EUE 8rd Pin x 2-7/8" Butt Box Pup joint 2-7/8" 6.4lb/ft L-80 Butt tubing 2-7/8" 6.4 lb/ft L-80 Butt tubing to surface 3-112" EUE Box x 2-7/8" But pin II" Cameron Dual Split hanger 3-1/2" EVE x 3-1/2 EUE" Top Short Strine Pup 2-7/8" EVE 6.4 lb/ft Box x Pin Crossover 2-7/8" EUE 8rd Pin x 2-7/8" Butt Box Pup joint 2-7/8" 6.4lb/ft L-80 Butt tubing 2-7/8" 6.4 lb/ft L-80 Butt tubing to surface 3-1/2" EUE Box x 2-7/8" But pin II" Cameron Dual Split hanger 3-1/2" EVE Btm x 3-1/2 EUE" Top 4. Rill with assembly torquing connections to make up marks on buttress connections. (Circulate well to inhibited packer fluid.) Note: Have TIW and X-over to 2-7/8" Butt available. Note: Packer Fluid is 1 % Baker Petrolite CRW-132F mixed in FIW Monopod A-18 AOGCC 6 5. We will be unable to test packer integrity by performing tubing x annulus pressure test due to production casing leak. To "test" packer, bullhead down tubing and observe annulus for returns.. 6. Space out, MU and land dual tubing hangers with 3-1/2" EUE landing joint. Land hangers. Ensure control line ports blanked off. Drain stack prior to lowering hanger onto tubing spool to visually confirm that hanger is seated properly. Engage lock down screws and install BPV's. Note: Land seal locator 18" above packer. 7. Rig up slickline on long string. Install standing valve and dummy pump. Bundle test Kobe cavity, short and long string to 3000 psi. Recover dummy pump Nipple Down/Release Ri2 1. ND BOP's and NO 3-1/2" dual block tree and tubing head adapter. (Have production verify tree orientation.) Recover BPV's and set two way checks. Pressure test tree and neck seals to 500/3000 psi for 10 minutes on chart. Ensure inj ection line port off seal flange has needle valve installed. 2. Install production annulus pressure detaection with control room monitoring capability. Monopod A-I8 AOGCC 7 'UNOCALi> API# 50-733-20143-00 RKB to TBG Hngr = 37.00' Tree connection: 11 ":=d 1 ¿, U - - 2 . _I -. -. .. 3 4 70;;;;;::::::::: SIZE WT 13-3/8" 61 9-5/8" 43.5 9-5/8" 40 9-5/8" 40 9-5/8" 43.5 Stage Collar 7" Liner 29 Tubing: 3-1/2" 9.2 ~ o Suspected hole at 1700' -2050' NO. . 1. 2. GL1\1#I. GLM #2. GLM #3. GLM #4. GL1\1#::'. GLM #6. (;1.1H #7. 3. 4. 5. 6. 7. 8. 9. 5 9/85 6 1/89 1/89 - ~- "':B:3' = - 10/21/91 4/27/96 12/30103 4128105 D Trading Bay Unit Well # A-18 Completed 2/77 CASING AND TUBING DETAIL GRADE CONN ll) K-55 Seal Lock 12.515 N-80 Buttress 8.755 K-55 Buttress 8.835 N-80 Buttress 8.835 N-80 Buttress 8.755 TOP 38' 31' 67' 4191 5643' 5598 7489' BTM. ]044' 67' 4191 ' 5643' 7520' 5600 9826' 37 7474' N-80 6.184 @ 7880' @7595' @7595' @7543' @7580' @7577' PERFORATION DATA Accum. Date E Zone Top Btm Amt. SPF Last Opr. Present Condition . , D 53-8 7,485' 7,533' 48' 4 1/89 Open - D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered wI Fill . D 54-9 7,734' 7,890' 156' 13 1/89 Covered wI Fill "'"'"- .~ ~~":': D 55-7 7,910' 8,030' 120' 7 1/75 Covered wI Fill 8 D 56-1 8,060' 8,130' 70' 4 11/70 Covered wI Fill - Hemlock D 57-2 8,380' 8,516' 136' 23 6/79 Covered wI Fill -..... 9 8,524' 8,550' 26' 4 11/70 Covered wI Fill E 58-1 8,568' 8,682' 114' 19 6/79 Covered wI Fill - E 58-7 8,734' 8,832' 98' 16 6/79 Covered wI Fill ./"~:.>-....... E 60-0 8,916' 8,988' 72' 12 6/79 Covered wI Fill KB ELEV = 101' E 60-5 9,066' 9,116' 50' 8 6/79 Covered wI Fill PBTD = 9,200' TD = 11,000' E 61-1 9,146' 9,176' 30' 4 11/70 Covered wI Fill ANGLE thru INTERVAL = 24.9° Hemlock 9,210' 9,265' 55' 4 11/68 Temporary Isolated by BP Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP A-18 Schm2-77 Comp REVISED: 10/5/00 DRAWN BY: SLT Buttress N-80 2.992 Butt JEWELRY DETAIL DCI)th ID Item 37.0' 10" x 4" Cameron 5M Tubing hanger, XO to 2-7/8" Butt 303' 2.75 3-]/2" Otis, "DK" BV SSSV Nipple, Cam(:o ~~·V2" MMG MDL Gaslìft Mandrds 2198' 2.875 Cameo MMG GLM 3513' 2.875 Cameo MMG GLM 4645' 2.875 Cameo MMG GLM 5537' 2.875 Cameo MMG GLM 6249' 2.875 Cameo MMG GLM 6867' 2.875 Cameo MMG GLM 7364' 2.875 Cameo MMG GLM 7403' 2.75 Otis "XA" Sliding Sleeve 7437' 3.00 Locator Seal Assy. wi 20' of seals. 7438' 3.5 Otis "WD" Pkr 7472' 2.625 Otis "XN" Profile Nipple, 2.75 7473' 3.5 WLEG btm 7474' 9200' 9270' Baker Drillable Bridge Plug. Set to temporarily isolate Hemlock production, 250 BOPD 011 11/28/70 CIBP. Wireline Summary CTU Cleanout fl 7819' to 9205'. Found 1116" to 118" coal, shale & cmt in returns @ 7955'. CTU Clean Out to 9184'. Found tight spot wi 2-118" guns FISH 22.6' x 2-118" Gun, 2' x 1-11116" CCL, 2' x 2" magnet, 5' x 1- 11116" Weight bar, 0.6' x 1-3/8" Cable Head. Total 32' long Tagged fill wi 3-112" scratcher Tagged fill wi 3-1/2" scratcher Tagged fill wi 2.62" GR Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' Nipple @ 7472' KB. Trading Bay Unit Well # A-I8 Proposed Hyd.Completion UNOCAL6> CASING AND TUBING DETAIL GRADE CONN ID K-55 Seal Lock 12.515 N-80 Buttress 8.755 K-55 Buttress 8.835 N-80 Buttress 8.835 N-80 Buttress 8.755 SIZE 13-3/8" 9-5/8" 9-5/8" 9-5/8" 9-5/S" Stage Collar 7" Liner Tubing: Long String 2-7 IS" Short String 2-7/S" WT TOP BTM. 38' 1044' 31 ' 67' 67' 4191' 4191 5643' 5643' 7520' 5598 5600 7489' 9826' 37' 7390' 37' 7391 ' RKB to TBG Hngr = 37.00' API # 50-733-20143-00 61 43.5 40 40 43.5 29 N-80 Buttress 6.184 BTC 2.441 BTC 2.441 ,¿, ~ 6.4# L-80 o 6.4# L-80 Suspected hole at 1700'-2050' JEWELRY DETAIL ID Item Dual Tubing Hanger 2.441 Pup, 2-7/8" x 10',6.4#, L-80 Buttesss Tubing 2.250 Kobe 2-112" Type 'A' Parallel Bottomhole Assembly 2.441 Crossover, 2-7/8" EU 8rd. Box X 2-7/8" Buttress Pin 2.441 1 Joint 2-7/8",6.4#, L-80 Buttress Tubing 9-5/8" x 5" OTIS BWD Packer with SBE 2.441 Wireline Reentry Guide NO. Depth 37.0' 1. +1-7390' 2. +1-7400' . . 3. +1-7419' 4. +1-7420' 5. +1-7450' 6. +1-7460' A. +1-7391 ' B. +1-7392' SHORT STRING 1.995 Crossover, 2-7/8" Buttress Box X 2-3/8" Buttress Pin 1.995 Pup, 2-3/8" x 8' L-80 Buttress Tubing A B Wireline Summary 9/85 CTU Cleanout fl 7819' to 9205'. Found 1116" to 118" coal, shale & cmt in returns @ 7955'. 1189 CTU Clean Out to 9184'. Found tight spot wi 2-118" guns @ 7880' 1/89 FISH 22.6' x 2-118" Gun, 2' x 1-11/16" CCL, 2' x 2" magnet, 5' x 1- @7595' 11116" Weight bar, 0.6' x 1-3/8" Cable Head. Total 32' long 10/21191 Tagged fill wi 3-112" scratcher @7595' 4/27/96 Tagged fill wi 3-112" scratcher @7543' 12/30103 Tagged fill wi 2.62" GR @7580' 4/28/05 Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' @7577' Nipple @ 7472' KB. NOTE: CASING LEAK ENCOUNTERED 6/8/05 - WELL SHUT IN PERFORATION DATA Accum. Date Zone Top Btm Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered w/ Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered wi Fill D 55-7 7,910' 8,030' 120' 7 1/75 Covered wi Fill D 56-1 8,060' 8,130' 70' 4 11/70 Covered wi Fill D 57-2 8,380' 8,516' 136' 23 6/79 Covered wi Fill 8,524' 8,550' 26' 4 11/70 Covered wi Fill E 58-1 8,568' 8,682' 114' 19 6/79 Covered wi Fill E 58-7 8,734' 8,832' 98' 16 6/79 Covered wi Fill E 60-0 8,916' 8,988' 72' 12 6/79 Covered wi Fill E 60-5 9,066' 9,116' 50' 8 6/79 Covered wi Fill E 61-1 9,146' 9,176' 30' 4 11/70 Covered wi Fill Hemlock 9,210' 9,265' 55' 4 11/68 Temporary Isolated by BP Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP DRAWN BY: NM 10/21/05 (Updated) 2 5 ,.""""*"".",,~ 6 - - - D - - - E - - - 8 Hemlock 9 - ~~ KB ELEV = 101' PBTD = 9,200' TD = 11,000' ANGLE thru INTERVAL = 24.9° Top Of CIW 11' 5k DC-B Spool y 13.15 .. Top of drill deck " " ~ " D 31/16" 5M Manual gate Kill line C 31/16" 5M Manual gate Kill line B 41/16" 5M Manual gate valve A 41/16" 5M Foster HCR Valve " 2.18' I .. I.. :' I8-~- ..,.~. ""',,,',"'" r "":"',' ,:',~,:, ,::,',,:C, ',,:_ ~_ I ---. - ~ ;i',,~~-' ~""I '~, ~ ~~' 135J~:!~M, ,A ',::, B" " , ' ,', ',,', !VI~~ c:rca.~ +-0 _ \C/;L~-,' "''1~'" 3 1/16"SM x 4 1/16"SM DSA I 11'~¡~!¡1 r ) \.. , <",:.,~'" '<' ~..''''~ ; ','-"_"c',' ,. ~~ :,".'W.,,':"' :'i,,',,' ";.',' :':",";'; ....."":.":: 0'[ ~~:~~; .":-~ ' .; -:'-_~ n~ '. .:, -..,: . -': ....:.'.: . - I". ,', ,;',: '.' ',', ,,",,', ,'. ,',",',',,'..'," ',III!H, ',',"'H, ~_ .' . __~, '._ '.' _ .-,,',' ,_ ..,'< ,~', "',", ' .',',',. " . - ¡.~". . Monopod BOP Stack Top of Rotary Table RKB = 39.60' - /.Btm ofRT Beam :I: Blm ofT~'y Beam · ""I 26.25' 20.38' 19.31' .. T "'''',/ ill " ~ .... . í iM~:~~~:!$s!~::- .. .. Monopod A-18 Summary of Hazards POST THIS NOTICE IN THE DOGHOUSE Decompletion/Recompletion · Potential exists for trapped pressure below fill that will be released as the tubing back-off is carried out. A hot tap tool will be ready on location to release trapped pressure while tubing is recovered. · Significantly underpressured reservoir sands (5.1 PPPG) will be encountered A heightened awareness of kick detection, downhole fluid levels and management of the mud system volume will required. · A H2S safety technician and a full complement of H2S equipment will be onsite. Safety technician will conduct drills service equipment and refresh crew members I the proper use of equipment. · Diagnostics performed prior to the workover indicates that there is a hole in the 9-5/8" production casing somewhere between 1700'-2050'. · NORM is expected in the recovered tubing. Review NORM Handling Guidelines attached to the Workover Program for safe handling specifics prior to pulling tubing. HYDROGEN SULFIDE - H2S . Monopod is designated as an H2S drill site. Facility readings indicate 90-120 PPM H2S casing head gas. Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies [Fwd: Monopod A-IS (403 Clarification)] Subject: [Fwd: Monopod A-18 (403 Clarification)] From: Thomas Maunder <tom _maunder@admin.state.ak.us> Date: Tue, 14 Feb 200614:17:01-0900 To: Neil Magee <mageen@chevron.com> CC: Jim Regg <jim_regg@admin.state.ak.us> Hi Neil, Thanks for looking into our questions. I will reexamine the sundry with this new information. One point in your reply. If a "no-flow" test is conducted, arrangements should be made for a Commission Inspector to witness. Please have the platform people coordinate with the Inspectors or Jim Regg. Jim's number is 793-1236. Tom Maunder, PE AOGCC -------- Original Message -------- Monopod A-18 (403 Clarification) Tue, 14 Feb 2006 13:12:11 -0900 Mage e, N e i 1 .~,~.~9,:=:,~.ì.9.:S~.~,~~,~,Y.Eg,!.:,,,:,.g.?T0.,::~, Thomas Maunder <tom rnaunder@adrnin.state.ak.us> Subject: Date: From: To: Tom, Attached is the response to your questions on the A-18 completion. Please let me know if you or Jim have any other concerns. Regards, Neil -------- Original Message -------- Subject: TBF A-18 Date: Fri, 27 Jan 2006 15:34:04 -0900 From: Thomas Maunder <tom maunder@admin.state.ak.us> o rg an i z at ion: S tat e o'f·"·":AIã"ii3·k·ä·""·""""'"·"",,·,,,,·,,""''',,....·,,'',..,'''''''''"'''"'"""."",,,,,,,.,,,,.,,,,.,,,,,,......,,,"....,,,..,,"..,,,..,,,...... To: N e i 1 Mag e e ,~:.~~.?:,g,:::.:::.9.:~~?þ.J2n.:"'S:.?.!.~.:~, CC: Jim Regg <:) im reg9'@admin. state. .:~_~:.:.~..~..::~ Neil, As I mentioned on the phone, Jim Regg and I have examined Unocal's proposal to workover TBF A-18 and have a couple of questions. 1. As discussed, the option of a 7" tieback makes the project uneconomic. 2. You propose to test the production packer by pumping down the tubing. This may give some positive differential, however if there is a small leak it is doubtful that it would be determined. What other method might be employed to assure the integrity of the packer? Is a temperature surveyor other log an option? 3. You state it is Unocal's plan to employ pressure sensors to monitor the tubing annulus for any leaks. In the procedure it is stated that it is possible to pump into the 9-5/8" casing and out the leak at 1.6 bpm at 450 psi. How would a small leak be recognized? Does detecting a leak depend on where it might be located (deep or shallow) and from either the power or production string? 4. We have examined our records and we do not show that A-18 has demonstrated "no flow". If the well is to be equipped without a SSSV, the well needs to be no 1 of2 2/14/20062:17 PM [Fwd: Monopod A-18 (403 Clarification)] flowed. It might be possible to conduct such a test prior to starting the workover, however that would be a decision that Unocal would need to consider/make. 5. In step 17, it is stated to clean out to the retainer at 9210'. The drawing indicates the retainer is at 9200'. Thanks in advance for looking into these issues. I look forward to your reply. Torn Maunder, PE AOGCC Content-Type: application/msword Content-Encoding: base64 20f2 2/14/20062: 17 PM AOGCC Questions: Question 1. You propose to test the production packer by pumping down the tubing. This may give some positive differential, however if there is a small leak it is doubtful that it would be determined. What other method might be employed to assure the integrity of the packer? Is a temperature survey or other log an option? Response: We plan to achieve a positive pressure test of the packer by injecting down the tubing and monitoring annulus response via an Echometer. A baseline will be established beforehand, and during injection we will monitor the annulus for a fluid level change. Admittedly a very small leak will be difficult to diagnose, however the risk of formation fluids leaking by the packer during well operations is expected to be mitigated once the well is brought on line. A packer leak under well operating conditions would manifest itself as a hydrostatic drop rather than a hydrostatic rise in the annulus as the flowing bottom hole pressure is estimated to be 600 psi at the planned 600B/D production rate thus unable to support a column that could reach the expected damaged casing at 2000' MD. As described in Question 2 below, we plan to verify annulus integrity via quarterly bundle tests in conjunction with Ecometer readings to diagnose fluid movement in the annulus. Question 2. You state it is Unocal's plan to employ pressure sensors to monitor the tubing annulus for any leaks. In the procedure it is stated that it is possible to pump into the 9-5/8" casing and out the leak at 1.6 bpm at 450 psi. How would a small leak be recognized? Does detecting a leak depend on where it might be located (deep or shallow) and from either the power or production string? Response: Two pump-in tests were performed on the A-18 well as part of the diagnostics following the burst of the casing. An initial pressure test of the 9-5/8" casing performed on 7/18/2005 yielded a steady state pump in rate of 450 psi at 1.6 bpm. A subsequent pump-in test on 8/3/2005 indicate that at a steady injection rate of 1.08 bpm at 295 psi, the production casing took fluid. A leak in either string which fully displaced the annulus above the leak point to fluid would exert a pressure of 657 to 770 psi at the expected leak point of 2050'. Based on these pump in tests it does not appear that we could detect a "small leak" with confidence. The production fluid side is expected to be operating at between 120 to 150 psi while the power fluid side will be operating at approximately 3200 psi. A leak of any consequence in the power or production fluid side would manifest itself by an increase in fluid rate to maintain the power side pressure. A flow /' meter with an alarm set to monitor an increase in flow rate will be installed in the power fluid side to alert production personnel should additional power fluid be required. A small leak on the production side would not be easily diagnosed solely monitoring production rate and pressures. To provide a measure of confidence that the production tubing has not developed a small leak, a ,/ quarterly "bundle test" of the power fluid and production tubing strings is planned to verify integrity. In addition, if production characteristics change, ~n Echometer will be employed to diagnose if fluids are entering the production annulus. 3. We have examined our records and we do not show that A-18 has demonstrated IIno flow". If the well is to be equipped without a SSSV, the well needs to be no flowed. It might be possible to conduct such a test prior to starting the workover, however that would be a decision that Unocal would need to consider/make. Response: Platform personnel are preparing to "No Flow" the well at this time. We will advise when this is completed or alternatively plan on installing SSSV's. 4. In step 17, it is stated to clean out to the retainer at 9210'. The drawing indicates the retainer is at 9200'. Response: The retainer is at 9200' rather than 9210'. I've made the correction to the program. RE: [Fwd: TBF A-18]--message 1 Subject: RE: [Fwd:TBF A-18]--message 1 From: "Magee, Neil" <mageen@unoca1.com> Date: Thu, 02 Feb 2006 10:53:58-0900 To:J'hô.m~sMaûndêr<to111_Jllalli1def@åêÜrîih:statê.ak.us> Tom, We're getting together this week to address the issued you've raised and formulate a response. Regards, Neil -------- Original Message -------- Subject: TBF A-18 Date: Fri, 27 Jan 2006 15:34:04 -0900 From: Thomas Maunder <tom rnaunder@admin.stat.e.ak.us> Organi zation: State o·f·....A·f·as"j{·a·· ........................................ To: Ne i 1 Magee .:~,~,?:.9.~~,~,?:!.~~~þ.P..':mçg'!~':?:. CC: Jim Regg .::::j im. r(:~9:S·:I@adm.in. stat(~; . a.~.~~~~:: Neil, As I mentioned on the phone, Jim Regg and I have examined Unocal's proposal to workover TBF A-18 and have a couple of questions. 1. As discussed, the option of a 7" tieback makes the project uneconomic. 2. You propose to test the production packer by pumping down the tubing. This may give some positive differential, however if there is a small leak it is doubtful that it would be determined. What other method might be employed to assure the integrity of the packer? Is a temperature surveyor other log an option? 3. You state it is Unocal's plan to employ pressure sensors to monitor the tubing annulus for any leaks. In the procedure it is stated that it is possible to pump into the 9-5/8" casing and out the leak at 1.6 bpm at 450 psi. How would a small leak be recognized? Does detecting a leak depend on where it might be located (deep or shallow) and from either the power or production string? 4. We have examined our records and we do not show that A-18 has demonstrated "no flow". If the well is to be equipped without a SSSV, the well needs to be no flowed. It might be possible to conduct such a test prior to starting the workover, however that would be a decision that Unocal would need to consider/make. 5. In step 17, it is stated to clean out to the retainer at 9210'. The drawing indicates the retainer is at 9200'. Thanks in advance for looking into these issues. I look forward to your reply. Tom Maunder, PE AOGCC 1 of 1 2/2/2006 12:06 PM , ' 9000 Report d¡¡¡te: 6122/2006 , ì ¡ , I " " ) '\66 -"07Cç UNOCAL@> ,''<i''''- Alaska J. Gary Eller Advising Completion Engineer Unocal Alaska Tel 907-263-7848 Cell 907-351-1313 Fax 907-263-7847 E-mail: ellerg@unocal.com August22,2005 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. ih Ave., Ste. 100 Anchorage, AK 99501 -~ t>.\.\G '}. .\ l\)\)S ~~r" Re: 90/8" Casing leak in Monopod Well A-iS, Trading Bay Field Dear Mr. Maunder: Unocal has confirmed that there exists a leak in the 9%" production casing of well A-18 on the Monopod platform, Trading Bay Field. The 9%" casing apparently failed during a casing pressure test on June 7, 2005. The attached 10-404 provides data that was obtained in July and August while evaluating the failure. The evaluation determined that the leak occurs between 1,700' to 2,000' MD. The well has been secured with a wireline retrievable plug in the tubing tailpipe at 7,472' MD. Unocal is still evaluating options for returning the well to production. Please contact me if I can be of further assistance. Sin~~ ~ìler ~ ~ AdviSi~ompletion Engineer _ '....J"...... 1-' ''''....7 SCANNED NOV 2 3 l005 Union Oil Company of California I Unocal Alaska 909 West 9th Avenue. Anchorage. Alaska 99501 http://www.unocal.com ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 101' 8. Property Designation: Monopod Platform 11. Present Well Condition Summary: Total Depth measured 11 ,000 true vertical 10,221' Effective Depth measured 7,595' true vertical 6,931' Casing Structural Conductor Surface Intermediate Production Liner Length Size 1,006' 7,489' 13-3/8" 9-5/8" 2,337' 7" Perforation depth: AUG 2 4 2005 it? f":" '_1'~, \.1"... 'f "', 'Ii' ':,"., W~.;', ¡\~J Stimulate U Other ~ ~'\\tl "'~"'ê'äsirlg leak WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 4:r! G3~ - ServiceD 6. API Number: 50-733-20143-00 9. Well Name and Number: A-18 10. Field/Pool(s): Trading Bay/D, E, Hemlock Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D cb (b8 ~- CJ70 feet feet Plugs (measured) 9,200'; 9,270' Junk (measured) Fish @ 7,595' feet feet MD TVD Burst Collapse 1,028' 3,090 PSI 1,540 PSI 6,860' 3,950 PSI 2,570 PSI 9,064' 8,160 PSI 7,020 PSI 1,044' 7,520' 7,489'-9,826' Measured depth: 7,485' to 9,318' See schematic for full detail. True Vertical depth: 6,827' to 8,561' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 3-1/2" 9.2# N-80 @ 7,474' Otis DK BV SSSV Nipple @ 303'; Otis WD packer @ 7,438' Treatment descriptions including volumes used and final pressure: n/a Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure n/a n/a n/a n/a n/a n/a 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl n/a n/a x Contact J. Gary Eller 263-7848 Printed Name Timothy C. Brandenburg ·7 CJ' C' J( Signature <-----=~. I ) ~ Form 1 0-404 ~::ed 04/2004 Tubing Pressure n/a n/a Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: n/a __ Title Drilling Manager 7 - <-1) R \ G t~eA~6.-7. 60.0 // AFE 164358 ' f<;BD1/L5 Datel:S ~ "2""2 -05 :,l5 (t¿'1 Submit Original Only UNOCALe ) API# 50-733-20143-00 ) Trading Bay Unit Well # A-IS Completed 2/77 SIZE WT 13-3/8" 61 9-518" 43.5 9-5/8" 40 9-5/8" 40 9-5/8" 43.5 Stage Collar 7" Liner 29 Tubing: 3-1/2" 9.2 CASING ANI) TUBING DETAIL GRADE CONN ID TOP BTM. K-55 Seal Lock 12.515 38' 1044' N-80 Buttress 8.755 31' 67' K-55 Buttress 8.835 67' 4191' N-80 Buttress 8.835 4191 5643' N-80 Buttress 8.755 5643' 7520' 5598 5600 N-80 Buttress 6.184 7489' 9826' N-80 Butt 2.992 37 7474' RKB to TBG Hngr = 37.00' Tree connection: ?? ~1 ,J. a ~ u 2 . . _I ~~4 . ~~ 5 6 0::::::::::: 7 NO. 1. 2. GLM. #1. GL1\1. #2. GL.M 1t3. GLM #4. GL1VI. #:5. GLM. #6. GL.M #7. 3. 4. 5. 6. 7. 8. 9. 9/85 1/89 1/89 D 10/21/91 4/27/96 12/30103 4/28/05 JEWELRY DETAIl.. Depth II> Item 37.0' 10" x 4" Cameron 5M Tubing hanger, XO to 2-7/8" Butt 303' 2.75 3-1/2" Otis, "DK" BV SSSV Nipple, Cam(~o 3-l/2"MMG MDL Gaslifl Mandrels 2198' 2.875 Cameo MMG GLM 3513' 2.875 Cameo MMG GLM 4645' 2.875 Cameo MMG GLM 5537' 2.875 Cameo MMG GLM 6249' 2.875 Cameo MMG GLM 6867' 2.875 Camco MMG GLM 7364' 2.875 Cameo MMG GLM 7403' 2.75 Otis "XA" Sliding Sleeve 7437' 3.00 Locator Seal Assy. wI 20' of seals. 7438' 3.5 Otis "WD" PIer 7472' 2.625 Otis "XN" Profile Nipple, 2.75 7473' 3.5 WLEG btm 7474' 9200' 9270' Baker Drillable Bridge Plug. Set to temporarily isolate Hemlock production, 250 BOPD on 11/28/70 CIBP. Wire line Summary CTU Clean out f/7819' to 9205'. Found 1/16" to 1/8" coal, shale & cmt in returns @ 7955'. CTU Clean Out to 9184'. Found tight spot wi 2-1/8" guns FISH 22.6' x 2-1/8" Gun, 2' x 1-11/16" CCL, 2' x 2" magnet, 5' x 1- 11/16" Weight bar, 0.6' x 1-3/8" Cable Head. Total 32' long Tagged fill wi 3-1/2" scratcher Tagged fill wI 3-1/2" scratcher Tagged fill wI 2.62" GR Tagged fill @ 7577' KB, got sample(sand), ran 2.74" GR to 'XN' Nipple @ 7472' KB. @ 7880' @7595' @7595' @7543' @7580' @7577' PERFORATION DATA Accum. Date E Zone Top Btm Amt. SPF Last Opr. Present Condition D 53-8 7,485' 7,533' 48' 4 1/89 Open D 53-8 7,544' 7,620' 76' 4 1/89 Open D 53-8 7,550' 7,590' 40' 6 6/79 Part covered wI Fill D 54-9 7,734' 7,890' 156' 13 1/89 Covered wI Fill D 55-7 7,910' 8,030' 120' 7 1/75 Covered wI Fill D 56-1 8,060' 8,130' 70' 4 11/70 Covered wI Fill = Hemlock D 57-2 8,380' 8,516' 136' 23 6/79 Covered wI Fill 9 8,524' 8,550' 26' 4 11/70 Covered wI Fill E 58-1 8,568' 8,682' 114' 19 6/79 Covered w/ Fill - E 58-7 8,734' 8,832' 98' 16 6/79 Covered wI Fill ~ E 60-0 8,916' 8,988' 72' 12 6/79 Covered wI Fill E 60-5 9,066' 9,116' 50' 8 6/79 Covered wI Fill KB ELEV = 101' E 61-1 9,146' 9,176' 30' 4 11/70 Covered wI Fill PBTD = 9,200' TD = 11,000' Hemlock 9,210' 9,265' 55' 4 11/68 Temporary Isolated by BP ANGLE thru INTERVAL = 24.9° Hemlock 9,280' 9,318' 38' 4 11/11/68 Isolated by BP A-18 Schm 2-77 Camp REVISED: 10/5/00 DRAWNBY:SLT "I j Lease/Serial ADL0018731 I Primary Wellbore Affected Main Hole ~ Water Depth (It) 'AEENo."g >'¿ '. l:~I:ler .. Qö Eng ] 164358 ".--....-....-..--.------.--...--..-..------.--.- Daily Operations 7/14/200509:30 -7/15/2005 00:00 Operations Summary Run static BHP survey to 7400'. AttemJ?~.Ë.~!.~~~~.~.~~.~~!_~~.~~_!!~.~~ nipple a~!~72' KB. 7/15/2005 06:00 - 7/16/2005 00:00 Operations Summary Make numerous attempt to set PXN plug without success. Finally set plug after brushing nipple and flushing with water. Pump 27 bbl FIW into tubing, , tubing has slow leak. Shut down for weekend. __._""_._'"____._._____,__._,____,____._.__._,.,_ .__________.__.___._____.....___u_ _'_' __ .~._.,.._,_,__,,_.____,__,.._.,.__.__~____. . ~___ '""_..""'_""'_"'__"'" _.__.__.._"___.. I 7/18/2005 09:00 - 7/19/2005 00:00 opi:iratiõ-ñs Summary 1 Tag fluid at 2035'. Run baseline pressure & temperature survey. Pump FIW down the 9-5/8" casing at 1.6 bpm with 450 psi. Apparently fill casing after , 60-75 bbl pumped. Pressure increase noted on 13-3/8" casing and tubing. Shut down after pumping 230 bbl. RU slickline, run follow-up pressure & temperature survey looking for indications of casing leak. ."._".,_._"_._,.___,,_n__._ -----_._,.,.._---'"-"'--"-_._-_._------_.._.._-~-'"_.. ______..______"'..________,.__.__..__.__,___.__.w.,_....._._....____.__.._____._.,..__.__,._.__ .._--_.._---_.._._--,---~_."_..-"_.,"_._,,._-,---_._-,---"------"--~,--......,----,_..-_.,--"----- __.~__.,.____.___,,_....__._..,____,...___..____._________·___'__·_~'···_______··_'·___·_·""__.·_._..·._·W .__~__._.____._____..__.____.,....._,.....~,__,,_.___,_.__~...._..__m,___.__....._h__,___,__.__.__.__. ._" _,,__,_ -,,-, ~--_._.."..__._-.."..'-'._""._'._-""'-'-----'''----'--_.-.._..----~-_._._.. .-,.-...- ""-'---"'-"--- ..------------ _'_"_"___"__."_~""____""'_____"''''_'''.__.._...'_.___.__..__._,_.______'._______,__"_,._,___."___.. "".._._.__h.______...,.,.__. 7/19/200500:00 -7/19/200518:00 Operations Summary Finish running post-injection pressure & temperature survey. Analysis pending. RDMO slickline. I 8/3/200509:30 - 8/3/200517:00 ..--.--.---------. .---.......--.-------...-..-.-. 1 Operations Summary .__._.....___.__.....·._n._._.._·_..._._·..._··....···· ~ Pressured tubing to 1500 psi. Took less than 1 bbl to pressure up, but tubing will not test. Repeated two more times with same results. Pump into . 9-5/8" casing. Pressured up and stabilized within 10 bbl, indicating casing was full. Pumped 105 bbl total at 400 psi into 9-5/8" casing. Noted pressure increase in tubing and 13-3/8" casing. Pressure tested tubing once again to 1500 psi. Bleed was slower, but still will not test. RD pump. ---~----_._._.._-,---- -. .-..-......"...--,-..--,.....-..-,--.---...-. ._, ,..,. -~~........_,..__.._....__._-_.,.".,_...,~..- __.. .,_..~._,__w_..__ _....,._...._._..____...w_ ~._. _ ... _.. _ ._ ....,__..._______.._,___.__". ,___.___ __.n......".._~_~.~__ '''_R'_'''"_~'' ,__,~. ...._..._...._.._...__._,,_.._..,,_ ...,., ,._.. '. ,_._..... "m'. ..._. ...~__ I :ï:' CD J! 4000 - è :ä5 I .c ., c. 5000 CD o Field: o o Pressure (psia) 1600 2000 2400 3200 3600 2800 400 800 1200 1000 11 I I I I Pressure-Temperature Profile I r, " ft y" ,I" ß I I Note: Fluid level is at 2050' MD for baseline survey, whereas tubing is - l ;'\, I full following injection into 9-5/8" · \,' casing. Therefore temperature I '\ variations above 2050' MD not "\\ meaningful. Survey does confirm · I that 9-5/8" casing has integrity - · '\, below 2200' however. "\" l' \'\",,), I I I · I · · ,~ \ ,l,¡, · · , 'I, t ~" , · 'I. · , H , II .. I ~, , illllII 2000 3000 6000 1000 8000 9000 70 80 90 100 110 120 130 140 150 Temperature (Deg. F) Pressure-Inj Pressure-Base Perfs ........... Temperature-Inj Valve ........... Temperature-Base Report date: 8/22/2005 , ' - ., CD J! 4000 - ~ o :ä5 I .c Õ. 5000 CD o w o o Pressure (psia) 1600 2000 2800 3200 3600 400 2400 800 1200 1000 1 I I I 1 Pressure-Temperature Profile '1 Dull #u," ' 111 , _.. ___ UN '" -. If 1)1::".,"1 ¡¿,¡ , I , , , £ ~ . I , , I , H I I , I , I , I "- ..~1R , Note: Comparison of temperature data while RIH vs POOH following injection into the 9-5/8" casing. Tubing is full the entire time. Temperature curves diverge above I' 1700'. Both curves also show significant '\11 cooling below the 13-3/8" casing shoe at 1044' MD. Conclusion is that the 9-5/8" leak is at ±1700' MD, and injected fluids are leaking off beneath the 13-3/8" casing shoe. I I ..,... I I 2000 3000 6000 1000 8000 9000 70 80 90 130 140 150 100 110 120 Temperature (Deg. F) Pressure-POOH Pressure-RIH Perfs Valve -Temperature-POOH -Temperature-RIH Report date: 8/22/2005 Monopod Well A.1S, 1/18/2005, AFE 164358 PSI Pressures before annular fill up, TBG 0 PSI, 13 3/8" Casing 40 psi, 9 5/8" Casing 100 psi. 650 Fluid level found in Tubing @ 2035' RKB (Slick Line) 95/8" 2256' RKB( fluid level shot old style) 600 550 500 Found master valve closed opened up to get tubing pressure. 450 400 350 300 250 200 150 100 50 I) 75 90 Total 105 120 135 150 @ 1.6 bbls per min. 9 5/8" Casing Pressure 3/8" Casing Pressure. 165 180 195 210 31/2" Tubing Pressure 20:24 HRS 22:45 hrs 10r 100 psi 225 230 Monopod Well A-18, 8/3/2005, AFE 164358 PSI . . ,., 15:43 hrs 80 psi 50 psi 650 Pressures before annular fill up, TBG 10 PSI, 133/8" Casing 90 psi, 95/8" Casing 27 psi. Fluid level found in Tubing @ well head. 1500 psi test tbg again 600 550 500 450 400 350 300 250 200 150 100 50 16:30 hrs 10 sec 1 30 min 180 psi o 100 @ 1.08 bbls per min. 9 5/8" Casing Pressure 20 40 30 50 60 Total b 133/8" Casing Pressure. 105 105 3 1/2" Tubing Pressure MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor o~%'° \ DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety ValVe Tests Monopod Platform ,Trading Bay Field Thumdav, Ar~rii 5, 2001: I traveled to UNOCAL's Monopod Platform and. witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thoroUgh job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates IWitnessed the testing of 18 wells and. 53 components, with four failures, The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. I indicated to Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location I inspected the platform and found it very clean and it appeared to be in excellent condition. $ .u..mmarv: I witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. Monopod Platform, 18 wells, 53 components. 4 failures, 7.5% failure rate. ~Plafform inspection conducted. Attach...m..e.n.t: SVS TBF Monopod Platform 4/5/01 JJ NON-CONFIDENT,,I,A~, SVS TBF Monopod Platform 4-5-01 JJ Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Date: Field/Unk/Pad: Trading Bay Field Monopod Separator psi: LPS 65 HPS 4/5/01 ':; ........... f'l'lJ:-:- ........... ......... i:~i' ....... ='t'~' "~ ~:'' V.. ..... i'"'""~" '~" "' .... l':" ''T :'*'" ""~ ........ '~1 Well Permit Separ Set ~ Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLW A-01RD 1901470 '651 45 42 P P P O~ A,~02 1660490 65 45! 26 3 P .~ ;~3 4/5/01 OIL A-03RD3 1971300 65! 451 42 P P P OIL! A-04 1670020 A,06 1670250 6'~ "45 "'45 p p ~.43 .... OIL A-07 1670460 65 45 42 P P .P OIL A-09RD 18 I036'0 A-10 1670760 A-i~.I ' 17~240i 65 45 '43 P e ;~[3'" ' 'OIL 'A_ 13 ' '16806201' 65 45 41 P P ' ' OIL A- 14 1680270 A-15 1680330 65 45 45 P P P OIL A-16RD 1880380 .... 65 '45 41/42.. e P 'P ..... OIL , , A-17RD 1810670 65 45 43 P P P OIL A, 18 ~ e' 1680760 65 45 47 P P P OIL A-21 1700470 65 A_22 17003i0 '65' 45 44 e P P ' OIL A-23 1700590 A-23DpN 1720200 '~ ' A-24RD 1810400 ' ' 65 45 '41 P P P oiL 'A-2'~RD1 19~0630 ' ' ~5 45 43! e P P ~ OIL A-28RD 1890920 65 45 45 P P P OIL A-30 1730140 A-32 1770180 65 45 44 P P P OIL i , Wells: 18 Components: 53 Failures: ~4 Failure Rate: 7.5% l'"1901)a¥ Remarks: A- 13 & A-21 reported as No-Flow wells. SSSV's removed for repair: A-02 out since 2/24/00, A-11 out since 11/7/99. A-02 pilot repaired and retested "OK". A-06 SSSV failed to close. A- 16 RD is a dual completion. 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ Unocal North America, ~ Oil & Gas Division ~ Unocal Corporation ,, P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCA. April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms.. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very ~truly, G u ' Regional Drilling Manager GSB/lew CO~;DUCTOR 1 2 3 4 5 6 7 8 9 10 ll 12 13 14 15 16 17 18 19 20, 21 22 ._2.q___ ~. 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, SECTION 4, TgN, ' ,,' "Y" : 2,523,126 LAT.': 60°53' 48.65. "X" : 218,871 LONG. : 151°34' 43.51'' ~ "Y" COORD.. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137,.2 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 2,523,133.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 "X" COORD. WELL # FSL FEL ., 218,880.9 A-28 1621 554 218,883.2 A-25 1617 551 218,883.9 A-30 1612 551 218,883.2 1608 551 218,881.3 A-27 1605 '553 218,876.8 A-23 .1601 557 218,873.0 A-21 and RD 1600 561 218,869.0 A-22 1600 565 218,864.6 A-14 1601 570 218,861.1 A-13 1604 573 218,858.8 A-17 1608 576 218,858.1 A-8 1612 577 218,858.8 A-15 1616 577 218,860.7 A-24 and RD 1620 574 218,865.2 A-29 1624 570 218,869.0 A-9 and RD 1625 566 218,873.0 A-19 1625 562 218,877.4 A'IB 1624 558 218,875.7 A-11 1619 559 218,878.6 A-3 1616 556 ,. 218,870.8 A-1 1618 564 218,873.9 A-7 1615 561 .~?.1R. R7F;. 9 A-4 1611 558 218,867.0 A-6 1600 "568 218,878.1 A-32 1607 556 218,863.9 A-12 and RD 1617 571 .218,875.0 A-20 1604 559 218,865.1 A-2 1613 570. 218,868.1 A-16 1610 566 218,871.1 A-26 1606 563 218,863.4 A-10 1609 571 218,866.3 A-5 and RD 1605 568 1 &2 AL) . OIL AND GAS CONSERVATION CO.MME N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing ~ Alter casing __ Repair well ~ Pull tubing 2. Name of Operator . ~ 5. Ty@e of Well: Union 0,i.1 Company of California (UNOCAL) Development~,~c ...... " '0247, AnCh' ~'k., 9 0~/ Exploratory__ 3'AOOresCi.0. BOX 1'9 9519- 47 Stratigraphic__ Service __ Other 6. Datum elevation (DF or KB) RT 102.' above MSL 7. Unitf~Pa~.~ ~nye Field 4. Locatio.~o~e,l, ~sTa~8, W from At top of productive interval 7550' MD, 2665' N, AteffecC~ptl~D, 3165'N, At total dep. th llO00' MD, SE cor., Sec. 4, T9N, R13W, SM 886' E of Surface Location i053' E of Surface Location 3206' N, 839' E of Surface Location 8. Well~]~b~rl8 9. Permit numbedapproval number 8-894 APl hum 10. 5O-- t)eJ3-20143 11. Field/Pool Tyonek "D" & "E" feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11000 ' 10221' feet Plugs(measured) 8ridge Plug 9200' feet 9200 ' feet Junk (measured) 844.5 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 1044' 13 3/8" 1000 sxs 1044' 1029' 7520' 9 5/8' 2600 sxs 7520' 6860' 2339' 7" 450 sxs 7489' - 9826' 6831' 9064' See Attached true vertical Tubing (size, grade, and measured de pth) 3 1/2", N-80, Butt, Mule Shoe 7474' Packers and SSSV (type and measured deCtlf~][. S "WD" Perm Pkr ~ 7438' Otis "OK" 8 32I' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 167 600 280 870 89 1200 119 Tubing Pressure 105 740 125 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil xx Gas~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~']~oy~.%b%~rts Title Environmental Engineer Oatc02/3/89 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Zone D 53-8 53 -8 53-8 54-9 55-7 57-2 57-2 57-2 57-2 57-2 58-1 58 -7 58 -7 58-7 60-0 60-0 60-0 61-1 Current Perforations Depth - MD 7485' - 7533' 48' 7544' - 7600' 56' 7600' - 7620' 20' 7734' - 7860' 120' 7910' - 8030' 120' 8060' - 8130' 70' 8380' - 8444' 64' 8444' - 8492' 48' 8492' - 8516' 24' 8524' - 8550' 26' 8568' - 8682' i14' 8734' - 8750' i6' 8750' - 8820' 70' 8820' - 8832' 12' 8916' - 8988' 72' 9020' - 9050' 30' 9066' - 9096' 30' 9146' - 9176' 30' Depth - TVD 6731' - 6873' 6883' - 6936' 6936' - 6955' 7061' - 7178' 7223' - 7333' 7306' - 7424' 7654' - 7715' 7715' - 7759' 7759' - 7782' 7789' - 7814' 7831' - 7941' 7991' - 8006' 8006' - 8074' 8074' - 8086' 8165' - 8237' 8268' - 8298' 8314' - 8343' 8392' - 8421' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend_ Operation shutdown __ Re-enter suspended well m Alter casing __ Repair well m Plugging m Time extension ~ Stim~.date __ Change approved program __ Pull tubing __ Variance ~ Perforate ~ Other 2. Name of Operator ~ ! 5. Type of Well: Union 0il Company of California (UNOC~L)' Development__ Exploratory ~ 3. Address / Stratigraphic__ P.O. Box 190247~ Anch~ Ak.~ 99519-024~ Service~ 4. Location of well at surface 1624' N, 558' W from SE cDr. Sec 4, TgN, R13W, S.M. At top of productive interval 6. Datum elevation (DF or KB) 101' RT above MSL 7. Unit or PropertY name Trading Bay Field 8. Well number 9. Permit number 7550' MD, 2665' N, 886' E of Surface Location At effective depth 9200' MD, 3165' N, 1053' E of Surface Location At total depth llO0' MD~ 3206' N~ 839' E of Surface Location ~" 68-76 IO.-API number 50-- 133-20143 11. Field/Pool Tyonek "D" & "E" 12. Present welt condition summary Total depth: measured true vertical 11,000 ' feet Plugs (measured) 10,221 ' feet Bridge Plug 9,200' Effective depth: measured true vertical 9,200 ' feet Junk (measured) 8,445 ' feet Casing Structural Length Size Cemented Measured depth True vertical depth Conductor Surface Intermediate Production Liner 1,044' 7,520' 2,339' 13-3/8" 1000 sxs 9-5/8" 2600 sxs 7" 450 sxs 1,044' 7,520' 7,489'-9,826' 1,029' 6,860' 6,831'-9064' Perforation depth: measured true vertical See Attached .RECEIVED Tubing (size, grade, and measured de pth) Packers and SSSV (type and measured depth) 3-1/2" N-80 Mule Shoe $ 7 474' Aias~.¢!l~GasCo~'.C,0maisS~ Otis "WD" Pe=m Pk~ ~ 7~4~8~ ,0t&s "DK" ¢ ~2[~ 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation December 4, 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I herel:)yCertify that ?e fqreCg is/true and correct to the best of my knowledge. Signed Roy D. ~ ~~Ti~e Environmental Engineer /, ~' FOR COMMISSION USE ONLY Conditions of approval: Notify/Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ~-c ~ Mechanical Integrity Test_ Subsequent form required 10- Dme 11/30/88 lAPProvalNo- ~- ~;;¢ ORIGINAL SIGNED BY Approved by order of th&(~N~i~i~TH ApprOved Copy Returned Commissioner feet ,,, , Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Zone 53-8 54-9 55-7 57-2 57-2 57-2 57-2 57-2 58-1 58-7 58-7 58-7 60-0 60-0 60-0 61-1 Current Perforations Depth - MD 7,550'-7,590' 40' 7,790'-7,850' 60' 7,910'-8,030' 120' 8,060'-8,130' 70' 8,380'-8,444' 64' 8,444'-8,492' 48' 8,492'-8,516' 24' 8,524'-8,550' 26' 8,568'-8,682' 114' 8,734'-8,750' 16' 8,750'-8,820' 70' 8,820'-8,832' 12' 8,916'-8,988' 72' 9,020'-9,050' 30' 9,066'-9,096' 30' 9,146'-9,176' 30' Depth - TVD 6,889'-6,927' 7,113'-7,169' 7,223'-7,333' 7,306'-7,424' 7,654'-7,715' 7,715'-7,759' 7,759'-7,782' 7,789'-7,814' 7,831'-7,941' 7,991'-8,006' 8,006'-8,074' 8,074'-8,086' 8,165'-8,237' 8,268'-8,298' 8,314'-8,343' 8,392'-8,421' trf RECEIVED -'"' 1 lq88 Oil .& Gas Cons, 1) 2) 3) 4) MONOPOD PLATFORM TBS A-18 PROPOSED PROCEDURE Rig up wireline and retrieve ball valve with slickline from 321'. MIRU coil tubing unit and clean out fill from 7,880' to 9,200' using viscosified FIW with 3% KCL. Reperforate the following intervals using thru-tubing guns. 7,485'-7,53~'~ 7,544'-7,620'; 7,734'-7,860' Return well to production. 7,485'-7,533' 48' 7,544'-7,620' 76' 7,734'-7,860' 126' Total 250 ' Proposed Perforations 6,827'-6,873' 6,883'-6,955' 7,061'-7,178' trf ~-"'-~-CASIN G ABANDONMENT l,) Rotary Table Me&au~ement at O.DO' Ii,) Cameron Tubing Hufl~er Ill,) I~ 318', 61e, J-SS C&aing at 104~' IV.) Top ~", 29~, N-S0 Casing at 74~9' V,) ~ 5i~', 40&43.5', N-GO Ca~in~ at VI.) Baker Bridge PI~* at 9200' VII.) ~oltom ol t~ule Shoe D ZDIIE E ZDIIE 11 TUBING DETAIL . 3 1/2",9.2'P~ N-80 't'U~ING I.) Oils 'DK' Ball Valve at 320.~4' 2.) Camco Ga~ [.tit t,4an0rel St :3.) CAmco Gas Lilt Manctrel ~t! ~t~.7~' 4.) Camco Ga~ Lilt Mandrel at 4644,83' 5.) Camco Gas Lilt Mac,ret at 55~6.81' 6.) Camco Gas Ll~t Man0rel at 7.) Camco Gas Lilt Menorel , 9.) Ott~ "XA' Sleeve et T403,3S' 10.) Lecator Sub ~t 7437.20* 11.~ Otis 'WP' Perm. Packer with Seal from T4~8.00' tO 7462.D0' 12,~ Otis 'XN* NiDole ~t 7~71.59' PERFORATIONRECORD DA TE INTERVAL CC)ND/TIC)IV' 11130170 B330*-B444' 57"~E Sd, 8492'-~516' 51-2 $~. S~50'-Sa20' 58-7 S~, Open 8916'-~ga8' ~0-0 S~. O~en 906e*-9096' ~0-0 $d, Open 7550'-7590' 53-8 Sd. ODe~ 77g0'-7550' ~4-g 7910'-8030' 5~-7 ~d. OPe~ B060'-B130' 55-7 $0. ODefl ~524'-85S0' 57-2 Sd. Open ~734'-6750' 58-7 ~d. OPe~ BB20'-SS32' 5a-7 Sd. Open ,.9020'-gC~0' 60-0 9096~-g11B' 60-0 S~. Open WELL TBS A-18 WELL $CHEMATI~ TOTAL P. 5 ·d~ ~t ~ q 1.1__ Jl i i i i- i ALA, .,')OIL AND GAS CONSERVATION COk SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~Other~ 2. Name of Operator Union Oil Company of California 3. Address P. O. Box 190247 Anchorage, AK. 99519-0247 4. Location of well at surface 1624'N & 558'W F/ SE Cor., T9N, R13W, S.M At top of productive interval ' 5. Datum elevation (DF or KB) RT 101' MSL feet 6. Unit or Property name Trading Bay Field 7. Well number TBS A-!8 8. Permit number 647 'N & ~e8p0t~E ~/ Surface Location t effective 3166'N & 1053'E F/ Surface Location At total depth 3_~6'N _~ R_39'E F/ ~urf_ace Location 9. APl number 10. Pool TraSing Bay 11. Present well condition summary Total depth: measured true vertical 11,000 feet Plugs (measured) 10,221 feet Effective depth: measured feet Junk (measured) true vertical 9200 feet 8445 Casing Length Size Cemented Measured depth Structural Conductor Surface 1044' 13-3/8" 1000 sX 1044' I nte rmed iate Production 7520 ' 9-5/8" 2600 sx 7520 ' Liner 2339' 7" 450 SX 7489 '-9826' Perforation depth: measured See Attached R E C E IV E D true vertical OCT0 ? 1987 True Vertical depth 1029' 6860' 6831'-9064' Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80. Mule Shoe @ 7474' Alaska 0ii & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage Otis WD Perm Packer @ 7438'. Otis "DK" Ball Valve @ 321'. 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If 6~l~6~a-I-~as-~er6~l~ approved Name of approver Date approved 15. , hereby certify that the foregoing is true and~_o,r~t to the best of my knowledge Signed~z.;, ,/~/~/Z?~/j,...~ ~'itle Enviro~ntal Engineer Rev D. Roberts Oommission Use Only Conditions of approval Notify commission so representative may witness ~ Approval Q Plug integrity Q BOP Test Q Location clearancel NO. Approved by ? ~all~ Form 10-403 Rev ~12-1-85 Commissioner by order of ,//~) S the commission Date -- 7-~ Submit in triplicate~.j TBS A-18 Perforation Record 7485' - 7620' 7713' - 8030' 8060' - 8130' 8378' - 8550' 8568' - 8682' 8734' - 8860' 8916' - 9012' 9020' - 9123' 9136' - 9176' 6827' - 6955' 7042' - 7333' 7360' - 7424' 7652' - 7814' 7831' - 7941' 7991' - 8113' 8167' - 8261' 8268' - 8369' 8382' - 8421' 0386N RECEIVED OCT 0 ? 1.9o87 ,Alaska Oil & Gas Cons. Commission Anchorage TBU A-18RD PROCEDURE: 1. Retrieve ball valve with slickline. 2. Clean out fill using viscosified diesel and coiled tubing. Fill is at 8967' (233' of fill). 3. Reperforate existing intervals with thru-tubing guns. 4. Return well to production. TIME: 5 Days 0386N RECEIVED OCT o ? 1987 Alaska Oil & Gas Cons. Commission Anchor~De Dear Mr. Gilbreth' Union Oil and Gas D~.-~,~on: Western Region Union Oil Company o~ ~;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union November 15, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 PorcuPine Drive Anchorage, AK 99502 A-4, MONOPOD PLATFORM Enclosed for your files are two (2) copies of the completed Well Histories for the above captioned projects. cc' Marathon Oil Co. USGS Harry Lee Sincerely yours, k~jm R~ Cal 1 ender D]'~%-~. Drl g. Supt. RECEIVED NOV 1 ? !971 Division Ot Oil & ~ gen~erVatlon Union Oil and Gas D;'~sion: Western Region ! Union Oil Compan~ /California P.O. Box 6247. Anchorage, Alaska 99502 Telephone: (907) 276-7600 union May 13, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99502 RE' -'2 TBS A-13 MONOPOD PLATFORM Dear Mr. Hamilton: Enclosed for your information are two (2) copies of the Monthly Report of Drilling and Workover Operations for the above captioned projects. Si ncerely yours., Jim R. Callender Dist. Drlg. Supt. CC: Marathon Oil Co. Rodney Smith - USGS Harry Lee. RECEIVED MAY ~. 6 1971 Form No. P--4 1R~V. 3-1-70 STATE Or/ALASKA SUBMIT IN DUPLICAT~ OIL AND GAS CONSERVATION COMMITi'EE MONTHLY RE!PORT OF 'DRILLING AND WOR'KOVER OPERATIONS 2. NAME OF OPERATOR UniOn Oil Co. of California 3. ADDRESS OF' O~)~:~4.'X'OP. ' Box 6247, Anchorage, Alaska 99502 4, LOCATION OF WEZ.,L Conductor #18, 1624'N & 558'W from SE Corner, Section 4, T9N, R13W, S.M. ~--X~,I Nu~.~uc,~u CODE , 50-]33-20]43 LEASE DESIGNATION A.X'D SEI~IAL NO. ADh-18731 IF INDIAN, ALOTTEE O~ TRIBE ~AME 8. L~IT.F.~ OR LEASE Tradinq 8ay State 9 WE~ NO 10. F~ ~ND P~L. OR WILDCA~ Tradinc 8av-~idd] a ~ ssc, T.,~., ~..'(~O~ ~o~ o~ Sec. 3, T9~, ~]3~, S.~. 12. P~IT 68-76 13. REPORT TOTAL DEPTH AT EATD OF MONTH, CI-I3L,\'GES IN HOLE SIZE, CASING AND CE/VIENTING JOBS INCLUDING DEPTH SET A_ND VOLU1VCf~ USED. PERFOI:LATIONS. TESTS AiNTD RESULTS FISHING JOB~ JU/NTI{ LI%T HOL]~: ALND SIDE-TRACKED HOLE A.ND ANY OTI/fER SIGNIFICANT CH.A~GES IN HOLI~ CONDITIONS. 7 4/27/77 " " Commenced W.O. operations on TBS A-18 at 12:01 a.m. 4/27/71 RU Dowell. Thru tbg. acidized the "D" & "E" Zone w/ 21,000 gal. of 12-3 mud acid in 7 stages using a total of 8000# of Unibeads for diversion. Initial pumping pressure 0 psi. Final displacement pressure 2300 psi. Released rig to TBS A-16 at 12:00 noon 4/27/77. ii 14. I hez~by certify that the fo,~oing is tr~ and co.rll~ ~~.~~~ ~ ~..~t~ Dist. Drlg. Supt. 5/13/77 NOTE --Re~ort on ~im f~ i~ requi~d ~r ~ cQlendQr ~th~ regQrd~ss ~ the ,tat~ of o~t~, ~d must ~ filed in dupli~te ~th the oil and gQS co~ervatbn commiflfl by the 15~ of the suGc~ding mn~. ~le~ otherwise directed. ~'Form 10~-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. ~vLLLL~['~ GAS D OTHERWELL 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL Atsu,ace Conductor #18, 1624'N & 558'W from SE Corner, Section 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ll2' RT above MLLW Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO= 14. TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) !'------1 PULL OR ALTER CASING La MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 50-] 33-20143 6. LEASE DESIGNATION AND SERIAL NO. APL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-18 (11-3) 10. FIELD AND POOL, OR WILDCAT Trading Bay-Middle Kenai D & E 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, RI3W, S.M. 12. PERMIT NO. 68-76 )ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertinent details, and give pertinent dates, including estimated date of starting any proposed work. ~ TBS A-18 has been repaired as reported 11/16/76. 1. Commenced well repair operations over TBS A-18 at 12:01 a.m. 2/23/77. Killed well with Dril-S workover fluid. 2. Removed X-mas tree. Installed and tested BOPE. 3. Pulled and layed down 4 1/2" production tubing string. 4. Retrieved 3 1/8" casing gun stuck @8894' TMD. 5. CO fill from 8894' to 9200' (bridge plug). 6. Recompleted well with 3 1/2" production string and side pocket gas lift mandrels. 7. Returned well to production 12:00 p.m. 2/28/77. 8. Thru tubing acidized well 4/27/77. RECEIV :D MAY - 1977 Division of Oil and Am, ho, Dist. Drl9. Supt. DATE- 5/2/77 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side '*Form 1~.403 Submit "1 ntentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. V~/~LLBWELLGAS O OTHER 2. NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR Box 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL Atsurface Conductor #18, 1624'N & 558'W from SE Corner, Section 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 112' RT above MLLW 14. CheCk Appropriate Box To Indicate Nature of Notice, Re! 5. APl NUMERICAL CODE 50-133-20143 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-18 (11-3) 10. FIELD AND POOL, OR WILDCAT Trading Bay-Middle Kenai D & E 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R13W, S.M. 12. PERMIT NO. 68-76 3orr, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEC~UENT REPORT OF; FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. TBS A-18 has been repaired as reported 11/16/76. 1. Commenced well repair operations over TBS A-18 at 12:01 a.m. 2/23/77. Killed well with Dril-S workover fluid. 2. Removed X-mas tree. Installed and tested BOPE. 3. Pulled and layed down 4 1/2" production tubing string. 4. Retrieved 3 1/8" casing gun stuck @8894' TMD. 5. CO fill from 8894' to 9200' (bridge plug). 6. Recompleted well with 3 1/2" production string and side pocket gas lift mandrels. 7. Returned well to production 12:00 p.m. 2/28/77. 8. Thru tubing acidized well 4/27/77. RECE[VED MAY - g 1977' Division of Oil and E;~.s C'snse~ation Anchor~9~ 16. I hereby certify i~Zg~is true and correct TITLE Dist. Drlg. Supt. DATE 5/2/77 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side RECEIVED MAY - 1977 Union Oil and Gas D' '~n: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union May 2, 1977 Mr. Hoyle Hami 1 ton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Hamilton. Enclosed for your approval are two (2) cop~..~--e~,~.~[~the Subsequent Sundry Notices and Reports on Wells form ~Bs A-~'Monopod Platform, and the subsequent Sundry Notices an~rts on Wells form and completed Well History for TBU D-2A RD (WO). Si ncerel y yours, ;Yim~. Cal 1 ender District Drlg. Supt. CC' USGS - Rodney Smith Harry Lee Marathon Oil Co. Atlantic Richfield Co. Chevron USA Amoco Production Co. Getty Oil Co. Phillips Petroleum Co. P,S, Also enclosed for your approval are t~_~es of a Sundry Notices and Reports on Wells form fo ~BS A-32.. Form 10-403 REV. 1-10~73 Submit 'l ntentions" in Triplicate & "Subsequent Reports" in DUll, Ii. cate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this fOrm for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' OIL I~i GAs r--] WELL[''I WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 W, 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface Conductor #18, 1624' N & 558' W from SE · Corner Section 4, TDN, R 13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) R,T, 101' MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20143 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay State 9. WELL NO. A-1R ¢11-3} 10. FIELD AKID POOL, OR WILDCAT Tradinc~ Bay - MiHHI~ K~n~i 'iF E, 11. SEC., T., ~ M., (E~OTTOM HOLE OBJE-CT-I-~E) Sec. 3, T9N, R 13W, SM 12. PERMIT NO. 68-76 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L_J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG 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. Following a workover to replace tubing and remove a stuck gas lift valve and perforating gun, well TBS A-18 produced at a rate approximately 250 BOPD less than anticipated. An acid stimulation treatment is proposed to regain this productivity. The procedure is as follows: · 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Rig up wireline and set tubing plug to pressure test tubing. Pull plug and rig up Dowell. Premix 8000 lbs. OS90 diverter in 4,000 gal. emulsified 15% diesel and 85% - 5% HCl. Pump 1000 gal 15% HCl with additives. Pump 3000 gal 12% HCl - 3% HF with additives. Pump 750 gal diverter emulsion. Repeat steps 5 & 6 three times. Pump 3000 gal 12% HCl - 3% HF with additives. Pump 500 gal diverter emulsion. Repeat steps 8 & 9 twice. Displace with 65 bbls filtered inlet water. Return well to production or gas lift. This work is proposed for April 25, 1977 (Verbal approval from R. DoHola~ a/lq/77) TITLE District En,clineer DATE April lq 1977 16. I hereby certify that the foregoing Is true and correct (This space for State office use) APPROVED av ~ ~ , ~'I~~ T IT LE /~.~-'~..~, CONDITIONS OF APPROVAL, IF ANY-.,// See Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL F~ GAS r"-I WEL-,--, WELL' ' OTHER 2, NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 W, 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #18, 162q' N & 558' W from SE 5. APl NUMERICAL CODE 50-133-20143 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay State 9. WELL NO. A-I~ (11-~ 10. FIELD AND POOL, OR WILDCAT Tradinc~ Bay - Middl~ E~n~i IlK ~ 11. SEC., T., Ft.., M., (E~OTTOM HOLE-OBJE~CT-IVE) -- Corner Section 4, T9N, R 13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) R.T. 101' MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re] Sec. 3, T9N, R 13W, SM 12. PERMIT NO. 68-76 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated (late of starting any proposed work. Following a workover to replace tubing and remove a stuck gas lift valve and perforating gun, well TBS A-18 produced at a rate approximately 250 BOPD less than anticipated. An acid stimulation treatment is proposed to regain this productivity. The procedure is as follows: . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. Ricj up wireline and set tubing plug to pressure test tubing. Pull plug and rig up Dowell. Premix 8000 lbs. OS90 diverter in 4,000 gal. emulsified 15% diesel and 85% - 5% HCl. Pump 1000 gal 15% HCl with additives. Pump 3000 gal 12% HCl - 3% HF with additives. Pump 750 gal diverter emulsion. Repeat steps 5 & 6 three times. Pump 3000 gal 12% HCl - .3% HF with additives. Pump 500 gal diverter emulsion. Repeat steps 8 & 9 twice. Displace with 65 bbls filtered inlet water. Return well to production or gas lift. This work is proposed for April 25, RECEIVED 1977 (Verbal approval from R. Dougla~ Lt/1q/77.1 DATE April lq. lq77 16. I hereby certify that the foregoing is true and correct TITLE District Enqineer (This space for State office use) See Instructions On Reverse Side ,, DATE Copy l~olUmed Union Oil and Gas r )n: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union March 15, 1977 Mr. Hoyle Hami 1 ton Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Re' TBS A-18 TBS A-2 Dear Mr. Hamilton' Enclosed for your information are (2) copies of the Monthly Report and Workover Operations for the above captioned projects. Sincerely yours, r~~_J"~ 1 end ~e ~A~.., Dist. Drlg. Supt. CC: Marathon Oil Co. USGS - Rodney Smith Harry Lee Ft)rm ~o. P.--4 STATE oF- )ALASKA OIL AND GAS CONSERVATION CO/W~ITI'EE SUBMrT l~ DUPLICATI~- MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS 0IL WKLL 2.NAM._F. OF OP]~J[TOR Union Oil Company of California ~~ns~s ~F o~o~ " P. O. Box 6247, Anchorage, Alaska 99502 ~ Loc~.~Or~ OF ~'.~- ' Conductor #18 1624'N & 558'W from SE Corner, Section 4, T9N, RI3W, S.M. AP~ NU~{EmCAL 50-]33-20]43 LEASE DESIGNATION AND SEi~IAL NO. ADh ]873] Lq'IT F.~I%M OR LEASE NA~IE ' ' Trading Bay State ',¥~LL NO A-J8 (1]-3) 10 FLF, JhD A-"~D POOL. 0i9. %VILDCAT Trading Bay-Middle Kenai D & E ll SEC , T. R., /%{. ('BO'I~OM MOl~ OB~.CT~ Sec. 3, T9N, R13W, S.M. __ 12 PERMIT NO 68-76 13. REPORT TOTAL D~T~i AT EI~D OF MONTH, CI4A.NGES IN HOLE SIZE, CASING A~ C~F~TING JOBS INCLUDING DEl'TH SET ~ VOL~ USED, P~O~TIONS, ~TS ~ ~SULTS FISHING JO~ JL~K ~ HO/~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS 2/23/77 2/24/77 ll ,O00'TD 9200' ETD bridge plug 9 5/8" csg. @7520' 7'l csg. @ 7488'-9826' Otis RH Pkr. @7431' ll,O00'TD 9200'ETD BP 9 5/8" csg. @752O' 7" liner 7488'-9826' Commenced WO operations on TBS A-18 at 12:01 a.m. 2/23/77. Displaced tubing and annulus above pkr. losing fluid to formation. Treated mud w/ CaCO_q~ to stop fluid loss. Installed BOE. ECEIVED Killed well above pkr. ~7431'. Tried to pull pkr. free. RU GO Int. tbg. cutter. Cut ~ 39.58'. Pooh 81 jts. tbg. Well bubbled gas. XO to 5" DP. RIH & circ. Pooh w/ remaining fish above cut. Layed dwn. fish. Made up Tri State O.S. 2/25/77 2/26/77 2/27/77 11,000'TD 9200' ETD BP 9 5/8" csg.@ 7520' 7" liner @ 7488'-9826' Otis Mod WD permadri 11 pkr. @7440' II II II Ran 4 1/2" O.S. to top of fish @3958' Jarred fish and pkr. @7431' free. Pooh w/ fish. Found 4 i 2" ' / G.L. valve in pkr from mandrel @7393' in pkr. bore. RIH w/ 6" bit & 7" csg. scraper to fill @8818'. Washed to 8843'. Pooh. RIH w/ O.S. to top of 31/8" OD perf. gun @ 8894'. Pooh. Recovered perf. gun left in hole from previous work. RIH w/ 6" bit. C.O. fill from 8894'-9200'. Pooh. RIH w/ 6" bit & 7" scraper to 9200'. Pooh. ~ RIH w/ 9 5/8" scraper to top of liner @7489'. Pooh. RU GO Int. RIH w/ W.L. gage & junk basket. Pooh. RIH w/ Otis Type WD Permadrill pkr. on W.L. set 14.1 her~by~rtify that th~x~l~Jis tFt[~ ~ ~ · m~~_~~~%~~- :~ Dlst. Drlq. SUp~. ~-- 3/15/77 '"~',-.~ond gas conservatbn commiffee by the 15~ of the succ~ding mn~, ~le~ etherwisa d~rected. '. Page 2 March 15, 1977 6 2/28/77 74.40'. RD GO Int. RU & run single 3 1/2" tbg. string w/ accessories. Install BPV & nipple dwn. " " Nippled up X-mas tree. Tested to 5000 psi -o.k. Displaced Dril-S WO fluid above pkr. @7440' w/ filtered salt water. Installed ball valve @302'. Turned A-18 over to production 12:00 p.m. 2/28/77. Union Oil and Gas D~'~sion: Western Region Union Oil Company. ~California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Dear Mr. Hamilton: November 16, 1976 Mr. Hoyie Hamilton Division of Oil & Gas 3001 Porcupine ~ive ~chorage, Alaska 99504 A-16, m-4, A-13,'[A-l~~ Enclosed for your approval are three copies each of the Sundry Notices and Reports on Wells forms for the above captioned wells. Sincerely. yours, ~llende~~ Dist. Drlg. Supt. Sm Encls. [ , Form ! 0-403 REV. 1.10.73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" In Duplicate STATE ~ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) NUMERICAL CODE · 50- 133 - 20143 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 7. ,F ,ND,AN. ALLOTTEE OR T.,BE NAME OIL k----! GAS r-'! WELLr- I WELLI ! OTHER NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil Company of California Trading Bay State 3. ADDRESS OF OPERATOR P. O. Box 6247, A..nchorage, Alaska 99502 ..... 4. LOCATION OF WELL At,,,~,c. Conductor %18, 1624'N & 558' W from SE corner, Section 4, TgN, R13~Ar, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 112 R. T. Above MLLVV Check Appropriate Box To Indicate Nature of Notice, Re 14. 9. WELL NO. A-lS (11-3) 10. FIELD AND POOL, OR WILDCAT Trading Bay - Middle Kenai D & t 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R13W, S.M. 12. PERMIT NO. 68-76 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT. OFF _~1 REPAIRING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multi01e 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 ~late of starting any proposed work. ( It is planned tp pull tbg., remove stuck gas lift valve and replace 4 1/2" tbg. w/3 1/2" tbg. for improved gas lift utilization on well TBS A-18, Monopod Platform. PLAN OF PROCEDURE 1. Rig up over well TBS A-18, Kill well with Dril-"S" workover fluid. (Note: tbg. will have to be perforated or fluid bullheaded due to stuck gas lift valve. 2. Remove X-mas tree. Install and test BOPE. 3. Pull and lay down 4 1/2" production string. 4. Retrieve 3 1/8" csg. gun stuck @8933' TMD. 5. C.O. fill from 8933' to bridge plus ~9200'. 6. Recomplete well with 3 1/2" production string and side pocket gas lff~ .mandrels. 7, Return well to production. st~mal;e4 ~.tartin. g da;~e: December, i, 1976. stlmate(] ~peratInq..-l-lme; mine %~1 ~avS ]6. I hereb~lfy that the foxing Is tree and correct . DATE $SSV be installed and tested before putting well on production. See Instructions On Reverse Side J Zone "D" Zone "D" Zone "D" Zone "D" Zone "n" Zone "D" Zone "E" Zone "" E" Z on e ~"'E" Zone "E" Zone "E" Zone ~"' E"Zone Hemlock Hemlock Interval 7550-7590 7790-7850 7910-8030 8060-8130 8380-8516 8524-8550 8568-8682 8734-8832 8916-8988 9020-9050 9066-9116 9146-9176 9210-9265 9280-9318 Present & Proposed Perforations Footage Condition 40' 60' 120' 70' 136' 26' 114, ' 98' 72' 30' 50' 30' 55' 38' _ . Open for Production Open for Production Open for Production Open for Open for Open for Open for Open for Open for Open for Open for Ope n for Isolated Isolated Production Production Prod uction Prod uction Production Production Production Production Production Below BP @9200' Below BP @9200' GAS LIFT VALVES 4--1/2". CX Mandrel ~.' 25~3' 4--1/2" CX ~h~ndrel '~' ~: 3976' 4-1/2" OX ,Iandret C 5196' -;-1/2" OX Mandret ~ 6078' 4-1/2" GX Mand.-el ,Q.' 6829' .4-1/2" OX Mand:'e! ~ 7393' ' TUBING DATA · 4-1/2" Buttres~ Tubing ~ 7446' · ,o ETD 9200' O! · · .- . · 13-3/8" Casing 1044' · 7431' Otis RH Packer -. · 7489~ Top 7" Liner 9-5/8" Casing 7520' 9200' Baker Bridge Plug 7" Liner 9 82 G' .. _ _ ii il i m _ _ mi _ I · · I WELL SCIIEMATIC TP, ADING BAY FIELD Form 10-403 REV. 1-10~73 ,. Submit "intentions" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA 0IL 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.) WELL GAS O OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At su trace Conductor #18, 1624'N & 558'Wfrom SE corner Section 4, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) R.T. 101' HSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 6. LEASE DESIGNATION AND SER 7. IF INDIAN, ALLOTTEE OR TRIB~[ 8. UNIT, FARM OR LEASE NAME A. 18 (11 - 3 ) Trading Bay - ~dd~ 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T9N, R13W, SM 12. PERMIT NO. ~8-7~ )ort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (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, includi.ng estimated date of starting any proposed work. Trading Bay State A-18 was logged and selectively reperforated during operations begun January 21, 1975. The operations proceeded as follows: 1. Ran gamma-ray log across ~xisting production perforations. 2. Washed production tubing with 15% HCL. 3. Pulled O~is gas lift valves. 4. Reran gamma-ray log over the Upper "D" Zone perforations. 5. Perforated the following intervals' 7840' -7890' 50' 8385-8445' 60' 8580' -8610' 30' 8610'-8640' '30' 2" Slim Dikone jets at 4hpf 2" Slim Dikone jets at 4 hpf 2" Slim Dikone jets at 4 hpf 3-1/8" Jumbo Jets at 3hpf AND GA~ ANCHORAG~ All perforations were Shot under drawdown conditions through tubing. It should be noted that the Proposed interval from 7940-7960 was not perforated due to an anomaly found in the ganmm-ray log. 6. Ran new' gas lift valves. 7. Returned well to production January 25, 1975 16. I hereby certify that the foregoing is true and correct ~..A., C~rnhnm . TITLE DATE (This sl3ace for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE . DATE See Instructions On Reverse Side Form 10-a,03 REV. 1-10-~73 SUbmit "1 ntentions" in & "Subsequent Reports" in Duplicate~ ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE DI¥1S O SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O,L ~ GAS {--1 WELLm-'l WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #18, 1624'N & 558' W from SB corner Section 4, TgN, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) R. T. 101' MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re ~d~)~20143 6. LEASE DESIGNATION AND SERIALi~iO. ~L 18731 ~i" ..... ~-~..~ ,. '.~, Trad~ Bay State 10. FIELD AND POOL, OR WILDCAT T~ading Bay-~ddle Kenai '~~ 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 3, TgN, R13W, SM 12. PERMIT NO. 68-76 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF= WATER SHUT.OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (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. Trading Bay State A-18 is currently completed as a single string "D-B", Zones producing well. Over the past several months-the Well has suffered from severe calcium carbonate scale deposition. It is proposed to selectively ~perforate three "D" Zone and one "E" Zone sand. Along with the reperforation, 40 feet of additional sand will be perforated. The proposed procedure is~ as follows: 1,/"i'R~' gammas..=ray log across the entire perforated interval. 2".:i/A¢idi~ashlt~ 4=1/2!?, tubing to facilitate pulling Otis gas lift valves. 3:<,;J/Pull gaS"iift valves. 4. Clo:se~ ,C2¢~ Handrels}~@:' 2563 and 3976' md. '""~":' ~"'-,,. ~,7840.-7890 50 (7850-7890 are additional perforations) ;O,.:, 7940-79.60 '. 60' 8580-8640 60' The perforations will be shot with 3-1/3" shaped charge guns @ 5 holes/ft thru tubing under drawdow~ conditions. 6. Renm new gas lift valves. 7. Return well to production This work is proposed for January 21, 1975. 16. I hereby ~r~ify t~ t~e,~regoing is true and correct t [_x~. R. Cml 1 m~.d~.r _.-~. ..T P~V -- - (This sDace for State off. J~ use) ~, APPROVEOBY ~ ITLE. , ~'~"~~L~ , CONDITIONS OF APPROVAL, IFAN d - See Instructions On Reverse Side T IT LE DATE _Bist __r~_ ~__~ _ -q, mer~ ~_te~_e~t DATE ~ ~' ~ 9-3069 ' ' & "Subsequent Reports" in Duplicate : # STATE OF AL~KA ~, API NU1VLEILICA. L CODS OIL AND GAS CONSERVATIO, N: COMMI~EE 50-133-20143 . I N-'~ t. ~ '-Z~ SUN~ No?ICES AND RJPORTS ON WJL~ ( J 4 ~Ng '-~; (DO ~Ot use t~is [otm ~ot ~?p~a}~.m.drJH ot to ~eege~ ~ ~873~ Use "*~g~C*Z~ON ~O~ ~z~rr--" ~o~ ~.e~'p~obos~Ua J o[~ 2. NAME OF OPE~TOR 8. UNIT, F~ O~ L~SE NAME 909 W. 9gh Avenue, Anchorage, Alas~ 99501 A-18 (11-3) ] SE~~ ,~-~c, Conductor #18, 1624'N & 558'W from SE Tradin~ Ba~-Middle ~ai ',~ corner Section 4, T9N, ~3W, SM. u. ssc., ~., s.. ~., ~oz~ ~o~ O~E~IVE) Sec. 3, T9N, R13W, SM. R.T. 101.' MSL [ 68-76 14. ' Check APproPriate Box To I,ndi,cate Nature of N~ti'ce, Report, or Other D~te ' NOTICE OF INTENTION TO : TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE [ I ABANDON.* REPAIR WELL CHANGE PLANs ,__ iOther) SUBgEQUENT R~PORT OF: WATER SHUT-OFF FRACTURE TREATMENT [--i ALTERING CASING SHOOTING OR ACIDIZING ]------{ ABANDONMEN'Ts (Other) Recompletion' (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates,~4ncluding estimated date of starting any proposed work. Trading Bay State A-18 is currently dually completed thru 2-7/8" from the Hemlock Zone, Middle Kenai "E" Zone and the Middle Kenai "D" Zone. The Hemlock is currently shut in due to low productivity. The Middle Kenai ."E" & "B" Zones are commingled and produce thru the short string via gas lift at the rate of 650 BOPD. It was proposed to temporarily abandon the Hemlock, perforate additional "E" and "D" sands, return well to production with the "E" & "D" Zones commingled and producing thru a single string of 4-1/2" tbg via gas lift. 1. Moved rig over well A-18 on 11/26/70. Shifted sleeves and ~i].~'d ~)w/70# ft3. Inverted Emulsion Mud. reViSiON OF C;L AND GAS 2. R~oved tree, install~ and tested BOE. Pulled & laid do~ d~i~lstrings. 3. let BP on vireline ~ 9200', isolating the H~lock Zone. 4. Set retrievable BP ~ 2000'. Replace existing tbg head w/12~ 3000# x 10" 5000# tbg head. 5. Reinstalled BOP's. Retrieved BP ~ 2000' Smbrnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR ~'ER~IT--" 'for such'p~o~)osal~.) 5. API NUMERICAL CODE 6. LEASE DEC~IGNATION AND SERIAL NO. 1. 7. IF INDIA-~T, A.L~LO'r'r~:E OR TRIBE NA/VLE OIL ~-] GAS ~ W~LL W~LL OTHE~ 2. NAME OF OPE~TOR ~. UNIT~FA~ OR L~SE NAME Un,on 0~1 Company of California 3. ADDreSS O~ OPE~ATO~ 4. LOCATION OF WELL At surface 9. W-ELL NO. TBS A-18 (11-3) 10. FI~L.D AND POOL, OR WILDCAT 11. SEC., T., R., M.,' (BOTTOM HOLE OBJECTIVE) 12. P ER1ViIT 13. ELEVATIONS (Show whether DF, RT, GR, etc. I Check Appropriate Box To Indi,cate Nature of N~H'ce, Report, o,r Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACXDIZE J J ABANDONs REPAIR WELL CHANGE PLAN8 __ ~Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , ABANDONMEI~T* (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. . . . 10. 11. 12. 13. Perforated the following intervals with 4" carrier guns two 1/2" hpf: 8380'-8444' 8492'-8516', 8568~-8682' 8750'-8,820', 8916!-8988' 9066'-9096' ~ , ~ · Perforated the following intervals with 4" carriers, four 1/2" hpf: ~ ~ ' ' ' ' ' 63'-8!3'0', 844~' 7559 -7590 , 7790 -7850 , 7919-80~0 , 80 -849~' 852~'-8550' , , ! , , I , 8734 -8750 , 8820 -8832 , 9020 -9050 , 9~96 -9116, 9146 -9176'. Ran junk pusher with 8-1/2" gauge ring to top of liner @ 7~89'. Ran Single string of 4-1/2" buttress tbg complete w/gas lift assemblies, ball valve and hydroset Otis pkr @ 7431'. Removed BOE's, installed 10" 5000# x 4-1/2" Cameron block tree. Changed over from Invermul to diesel. Set and tested pkr to 1400#. Placed well on production with Middle Kenai "E" & "D" zones commingled thru a single string of 4-1/2" tbg via gas lift. ~ Moved rig off well A-18 @ 12:00 Midnight 12/1/70. 16. I hereby certify is true and correct SIGNED (~hts ~p&ce for State APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TXTLE Dist. Drl~. Supt. DATE i2/4/7o TITLE DATE See Instructions On Reverse Side J ·. :.F~r~ p-~3'., ;, J S~brnit "intentions" in ~pli~te . ~/ ~ "Sub~quent Repo~s" ~ Dupli~te '~ ~v. g-~" J C, I STATE O'F A KA ;: OIL AND ~AS CONSERVATIO, N COMMI~EE 50-I D3-20I 4~ ~_ J_~8 ENg " ~. g~s~ g~x~o~ SUND~Y NOTICES AND ~EPO~T5 ON W~ ...... (Do not use this form for proposals ~ drill or to de~pen Use "AP~U~CATION 'FO~ ~E~iT=" ~or such'p~o~osaI~) ADL 1873 I 2. NAME OF OPE~TOR 8. UNIT, FA~ O.R L~SE NAME Union Oil Co. of California Tradin9 Bay State J 909 West 9th Avenue, Anchorage~ Alaska A-18 (11-3) Tradi nn ~nv - ~'~ Conductor ~18, 1624'N & 558'W from SE Corner n.s~c.,~..~..~..(~o~o~o~ Section 4, T9N, RI 3W, SM o~w) Sec. 3, T9N, RI3W, SM 13. (; [ I Ol' RT Above MSL I 68-76 · ~4. Check ApproPriate Box To I;nc{icate Niat'ure of N~ti'ce, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER ~IHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J j ABANDON* REPAIR WELL CHANGE PLANS ,Other) Recomp I etion SUBSEQUENT REPORT OF: WATER 8ItUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING 8HOOTING 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. Trading Bay State A-18 is currently dually completed thru 2-7/8" tubing strings from the Hemlock Zone, Middle Kenai "E' Zone and the Middle Kenai "D" Zone. The Hemlock is currently shut-in due to Iow productivity. The mi. ddle Kenai 'E" & "D" Zones are commingled and produce thru the short string via gas lift at the rate of 650 BOPD.-' It is proposed to temporarily abandon the Hemlock, perforate additional Sands, and return the well to production with the 'E" & 'D" Zones commingled producing thru a single string of 4-1/2" tubing via gas lift. PROCEDU RE: I. Move over Well A-18: kill well with 70#/ft3 invert emulsion fluid. 2. Remove tree, install & test BOE. Pull & lay down dual strings of 2-7/8" 3. Set bridge plug @ 9200', isolating the Hemlock Zone. 4. Set retrievable bridge plug ~ 2,000'. Replace existing tubing head w/12" X I0" - 5,000# tubing head. 5. Reinstall BOP's. Retrieve bridge plug @ 2,000'. R.EV. 9-30-6 9 Submit "Intentions" in Triplicmt~ & "Subsequent Reports" m Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON W.ELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'ER~iT~-'' 'for such'P~o~osal~J 1. [2 w £LL WELL OTHER 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF wELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. 14. Check Appropriate Box To I,ndi,cate Nature of N~tlc'e, Re, ~. API NLrNLERICAL CODE 6. LEA-sE DESIGNATION AND SERIAL NO. 7. IF INDIA.N, A.LLOTTE~ OR TRIBE NAiVLE 8. UNIT, FAR.IV[ OR LE, ASE NAME Trading Bay State A-18 ' 10. FIELD ~D POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PE'R1VIIT N'O. )ort, or Other Data ' NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR ~'ELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS tOther) ~UBSEQUENT REPORT OF: WATER SI{UT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEI~T$ (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 an)' proposed work. 6. Perforate the following intervals with 4" carrier guns two I/2" HPF: 7550'-7590' 8524'-8550' 7790'-7850' 8570'-8682' 7910'-8030' 8688'-8694' 8060'-8130' 8734'-8832' 8384'-8516' 8920'-8988' 9020'-9050' '9066'-9116' 9146'-9176' 7. Run single string of 4-1/2" tbg complete w/gas lift assemblies, ball valve, and with a hydroset pkr at 7450'. 8. Remove BOP's and install I0" - 5,000# X 4-1/2" sol id block tree. 9. Change over from invert emulsion fluid to diesel. I0. Set & test pkr. II. Place well on production, with Middle Kenai "E" & "D" Zones commingled thru a single string of 4-1/2" tbg, via gas lift. ~.Tk,/lei lev COnDiTiOnS OF X~PRb~XL,~F Dist. Drilling Supt. ~tT~ See Instructions On Reverse Side !1-19-70 Approved Copy Returned .UNION OIL & GAS DIVISION- A NCI!O R AG E D I STR I CT ~ .~,lC'~ T~ ~. 'I .~,A,., o4, t TA L TO' STATE OF ALASKA DATE' May 19, 1969 FROM' G. H. Laug~h. baum.,._J_r_,_____ 'r~a~ ..... i *ted hercwi th are ta..,~ fo1 1 m,~ ~ p~-~. Run No. Final Sepia Blue Scale 1! Inau~tion Electrical Log Dual Induction Laterl. og BtiC Sonic/Cal~per I,og Bt-lC Sonic/Gm, ma R~y BIIC Sonic./Caliper/Oa~?aa Ray l,og Formation Sonic Log Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) tligh Resolution Dipmeter (HDT) CDS! Srte~tv Print CDH or Printout CD<~I o~ Polywog Plot Cn~4 P ' .... o:~ar Plots Proximity Hicrol og/Calipe~ Gamma Ray-Neutron Log Gamma Ray Collar Ce}nent Bend l.og Sidewall Neutron Porosity Log I..aterlog 3 Mud log Core Descriptions, Conventional, Core Descrlptions, Sidewal Core Analysis For~r=a t ion 'rests Directional Surveys Core Chips Smnple Cut (.:,,.,.m ~a Gamma) RECEIVED MAY 2 1 1969 DIVISION OF OII AND GAS ANCHOSAGE RECEIPT iaiu:,n RECEIPT TO' Uni.~,,, O5.1 & Gas Divizion ' l?este~'n':Reb-ian Anchorage Dist ri. ct 2305 [.,~..~,al i .,a,.Ja Attn: Rochelle Carlton Anchorage, A!aska 9 UNION OIL CO. OF CALIFORNIA ALASKA -DISTRICT Transmittal DATE' FRObi: __,,U~_~pn O~LC_o. of C_ _ a=lifomnia WELL NANE' Transmitted herewith are the following' Run No. Sepia Blue Scale Induction Electrical Log __2ii_ Dual Induction Latero!og BtlC Sonic/Caliper Log BHC Sonic/Gamma Ray . BHC Sonic/ Caliper/Gamma Ray Log Formation Soni~ Log (Fs) Density-Gamma Log Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) CDM or High Resolution Dipmeter CDM Safety Print CDM or Printout CDH or Polywog Plot CDM Polar-Plots Proximity-Hicrolog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log B~dlog Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core' Analysis Core Chips Sample Cut Drill Stem Test Directional Surveys J anuar, z_' 1_6__,_!~96_9 TBU A-18 6 TBU G-18 JAN 1 v 1969 :>wmo~ o~ o~t ^t~:) OAS Receipt acknowledged' .~d..//.!_~ Date: /-/~-~:~') -Return receipt to' Union Oil Co. of California, 2805 Denal~ St. Anchorage, Alaska Rochelle Carlton 99503 Form No. P--4 REV. 9-30-~ STATE OF ALASKA 'i. SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O:F DRILLING AND WORKOVER OPE:RATIONS 2, NAME OF OPI~%ATOR Union 0il Co. of California ADDRESS OF OPF-AR~TOR 507 W. Northern Lights Blvd., Anchorage 99503 4. LOCATION O'F W~:LL Conductor 18, 1624' & 558' W ~rom SE corner Section 4, TgN, SM ~,ApI NI3AIERICA~L CODE 50-133-20145 LEASE DESIGNATION AND SERIAL NO. ADL 18731 7. IF INDIA]q, ALOTTEE OR TRIBE NAME 8. I/NIT,FkP~{ OR LEASE NkME Trading Bay State 9. WELL NO. A-18 (,11-.-3) 10. ~iEI,D AND. POOL, OI~.~I(~%T Kenai ~ _ Tradin~ Bav -Hemlock i1. SEC., T., 1~., M., (BO/'TOM HOLE OBJECTnrS) Sec. 3, T9N, R13W, SM 12. PERMIT NO. 68-76 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ ¥OLLrI~ USED. PF-~ORATIONS. TF, STS ~ RESULTS, FISHING JOB~. JLrNK IN HOLE AND SIDE-/q~ACKED HOLE AND A_NY 07~-IER SIGNIFICANT C'KA~GES IN HOL]~ CONDITIONS. A-18 (Cont.) tbg. as short string. Stabbed into RH - 2pkr @ 8312'. Removed BOE § installed Xmas Tree. Changed over from weighted salt water to diesel oil. Set ~ press tested pkrs. Opened gas lift mandrels in SS @ 40S4 & in LS @ 21S2'. Using gas lift gas, brought SS in flowing. Long string would not flow. SI pending installation of gas lift valves. RIG RELEASEB 9-00 P.M. 11-17-68. DIVISION OF OiL AND OAS sm~:~ ,//~[// ,/ ~ =~ Dist. Drilling Supt. ,:,^,~ 12-15-68 , , 7 /' / ' ', --' NOTE~Report on this for~ is required for each calendar month, regardless of the status o! operations, a.~ m~st II~ filer i~ ~.~licat~ with the Division of Mi~es & yi~erals by the }5.th of the succeeding moath, unless otherwise directed. OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF D.RILLING AND WORKOVER OPERATIONS , . 50-133-20143 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 W~LL W~LL OTHER 2. NA_~IE OF OPERATOR 8. U/N'IT,FA1R~I OR LEASE NA2~E Union 0il Co. of California Trading Bay State 3, AD~'RESS OF OPEP,.ATOR 507 W. Northern Lights Blvd.~ Anchorage, Ak 99503 4.LOCA~ON OF WELL Conductor 18, 1624' ~ 558' W from SE corner Section 4, TgN, SM 9. WELL NO. A-18 (11-3) 10. FI~ A-ND POOL. OR WILDCAT Middle Kenai Tradin~ Bay - Hemlock i1. SEC., T., k., M.. (BO~'POM HOI2Z o~nzE) Sec 3, T9N, R13W, SM. lZ. PE1R2VIIT NO. 68-76 REPORT TOTAL D~IP~I-I AT F_2qD OF MON/~I, CI-I~NGES IN HOLE SIZE, CASING ~ CE1VIF_~NG JOBS INCLU~~;~SET ~ VOL~ USED, P~O~TIONS. ~TS ~ ~SULTS. FIS~NG JO~, J~K ~ HO~ ~D SIDE-~CKED HO~ Trading Bay State A-18 (11-3), November, 1968 mVmON Cont. drlg 8-1/2" hole to 11,000' TD. Ran Schlumberger DIL, HRD, ~ Ga~a Density Logs. Ran 7" 29~ N-80 buttress csg w/special clearance couplings on TIW liner hangar. ~ng w/shoe ~ 9826', w/top of hangar 8 7489'. Cemented w/450 sx Class "G" mixed w/l% CFR-2. CIP 6:00 a.m., 11-19-68. RI w/5-1/2" dp ~ 6-1/8" bit. Found top of cement in 7" liner ~ 9677'. Changed over from mud to weighted inlet water. Pressure tested liner lap - 0K. Ran cement bond log ~ Ga~a Ray Co~elation Log. Perforated 4 1/2" hpf for DST ~1 9210-9265, 9280-9~18. RI w/Howco DST tools. Set pkr'~ 9167'. Took 20" initial flow, 1-1/2' init'iai shut in, 6 hr flow period, and 8 hr final SI period.. Zone flowed 100% water a 288BPD rate. Reversed 25 bbl 100% water, and 125 bbl::?:W/,~% oil, 50% water.~. I~=4082~, IFr])=1570~, FF1=2152~, ISIP=3755~, IF2=2250~, FF2=5477~, FSIP=3755~, FH=4082~. Set Howco CI BP ~ 9270'. RI w/Howco test tools. Set pk~ ~ 9167'. DST ~2 9210'-9265'. Took 15" IF, 1-1/2 hr ISI, 8 hr. flow period,.8 hr~fin~!-SI period. Zone flowed oil ~ 425 BOPD rate, 28.2~, 8% cut. IHP=4082~, IF1=849~, FF1=1598~, ISIP= 5755~, IF2=1647~, FF2=5100~, FSIP=5755~, FHP=40829. RI w/Howco CI, BP set a 9,000'. Perf 4-1/2 HPF from 8600-8650'. RI w/Howco test tools. Pkr set ~ 8550'. DST ~5: 8600'-8650'. Took 15 min IF, 1-1/2 hr ISI, 8 hr flow, 8 hr final SI period. Zone flowed oil ~ 97~ BOPD rate, 50.2~, 0.7% cut. IH=~787~, IF1=1~57~, PF1=2152~, ISIP=54119, IF2=2299~, FF2=2871~, FSIP=5395~, PH=3787~. RI with 6-1/8" bit to BR ~ 9,000'. Drld on plug. CO to plug 8 9270'. Circ clean. Perforated w/Lane Wells 4-1/2" hpf 9096'-9066; 8988-8916; 8820-87S0; 8680-8650; 8600-8568; 8514'-8492; 8444-8380. Ran 2-3/8" ~ 2-7/8" 14. I hereby eertiiy ~ foregc~/ngr~s~e, and ~ 17/~ ] iJIlllI Dist Drlg Supt NOTE--Repo~ on this form ~ required for each ~lendar month, regardless of the status of operations, an~ mu~ ~ file~ in dupli~te with the Division of Mines & Minerals by the lSth of the succeeding month, unless othe~ise dire~ed. ~. Form, P--7 ~t " ' SUBMIT IN DUPI,I( " ~t,ll[]'l= OF ]III[.i~SKA (See other In- structions on OIL AND GAS CONSERVATION COMMITTEE reve,-se II I WELL COMPLETION OR RECOMPLETION REPORT AND' LOG b. TYPE OF COM?L~.TION: · ,','ELL OVER ~EN BACK Ii. EsvR. Other 2. NAME OF OPERATOR Union 0il Company of California ~, AI~DRESS OF OPERATOR . :507 West Norther~: Lights Blvd'., Anchora§e~Alaska 99503 LOCATION OF wELL-Y((Rdl~or, t location clearly andrin ,accordance with any $.~ate requirements)* ,tsurfac~ CondUctor 18, 1624'N & '558'W from SE'corner Sec. 4, --T9N, ,. R13W SM~ - At top prqd. inte~i'al ~eperted, below ~t total di~pth /"'(S~e Midd!e:i:Kenai ComPletion) 13. DA. TE Si:~rD,D F.r~ [1~. D~TE~.D. RE~¢HED [15. DATE CO,IViP .StJS.P O~ ABAND. 8/2~)68 TOTAL DEPTH, IV//) & TVD~9.. PLIIG, B~CK MD::& TVD~0. IF.,1VUJLTIiPLE CO1VI~L,, [ 21. 000MD'")~ '~'' :: . ' ,.. ~.: [ MOW.; ~Y* ] ROTARY TOOLS 11'~ 10,24t~ 9270~, 8498VD] Dual 0-11,000 PRODUCING ~VAL(S), .OF ~IS CO~P~TIO~, BOSOM, N~E (~ AND ~)* Hemlock: 9210 '~ .- 8439 VD, 9265 ~ - 8493 VD' ~E ~CT~ AN~ OTH~ ~GS~ R~ H~, Gam~ -~'Densityi DIL ., CASING R~IC~ltD (Report ~ all strings set in well) 50-133-20143 6. L~ASE Dk-~IGN.&TION AND SERIAL NO. ADL 18731 ~. 1F II~IAN, ALLOTTEE OR TRIBE NAiVIE il..UNIT,F.a2d-VI OR LEASE NAME .Trading Bay State 9. "WELL NO. A-~8 (11-3) i0. FIELD A/~D PI)OL; OR WII_iICAT ?!'Tra~ing.~Bay Hemlock n,..SEc., ~T., R., m.. (BOTTO~ HO~ :O~VE) ;:~ec. 3 TqN R13w. sM 12; P~IT 68.76 ! i16. ELEVATIONS (D'F, RKB, RT, GR, .~PC)* {17. ELEV. CASINGHEA~D R.T. 101' MSL , ~, ~J INTERYALS DR£LLgD BY I CABLE TOOLS None 23. W~S D!REC~'IO,N.~L SURVEY 1VIAD E Yes t[ cmi~. ~'TI~a ~co~ 26. LINER RECO'I%D si.z~7'1 't TOp(MD) 7489 BO'TTOM (MD) ! SACKS C~WI~T* 9826 45O 28. PERFO1R~kTIONS OPFAW TO PROI)UC rlON (Interval, size and '~umber) 4 1/2" holes per foot 9210 - 9265 I 30. PRODUCTION I A2VIOUNT PULLED:~ 1,000 sx I None see attachedi ~heet). None 27. TUBING RECORD ' SC*P~EEH (mD) SIZE D~laTH gET (NID) [ PACK~ SET (~). None 2-7/8" 9184: ' [ 9146 ACID, SHOT, F~'U~, C~ 'SQU~ZE, m~-I ~:~V~:::., {D) ~ ~A~Q~T ~D ,KID O,F ~~. ~ .: i DATE FIRST PRODUCTION 11/23/68 n~TZ or TmST. [HOURS TF_~TED 'lCX-IOKE' SIZE PROD'N FOR 11/23/68 ! - 24 'i 90/64 TEST PER!OD.~ mmz~. 100 ~ 960 'lm'H°~~'[ 578 31. DISPOSITION OF OAS (8old, used for fuel, vented, etc.) Vented "32. ~m~ o~' a~CH~r~*s FRO'DUCTION METHOD (Flowh~g, gas lift, pumping--size and type o£ pump) Gas Lift OIL--BBL. {,' , 578 181- ' 9-5/8" csg cementing detail 33. I hereby certify ~th~ SIGNED ~ [] ff.l~., WELL .STATUS (Producing or ~t-~) Producing GAS--1VZCF. WATEH~BBL. [ G~S-OIL I{2ETIO WATEP~BBL. lOlL GRAVITY-APl (CORR.} ~ 16 I 29,6 fo~goilag and attached information is complete and correct as determined from all:available records ,. 'Tal~ey) , - *(Se/Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS .Gene. rah This form is designed f6r submitting:a complete and correct well completion report and log. on i.,all types of lands and leases'-in Alaska. :. ... ::ltemi; 16: Indicate which elevation is u'sed as '~ reference (where not Otherwise shown) for depth'measure- i~ment~ given.'in cther spaces on this form and i'r~ any attachments. · '..Item~ 20,:ia.n.'d 22:: If this well is-..~om~ieted fo:r separate .!production from more:ilthan one interval zone i?mu!!iple'completion), so state in'~item 2Q, and in item-22 show the p, cducing'' interval, or intervals, :"top(s), bottom(s) and name"(s) (if 'any) ::fori only lthe int.e, rval reported in item 30. Submit a separate report- '~;'(pao~)' on this form, adequately identified, for~each additional interval to be seperately produced, shOw. ~i' ing"the a'ckJitional data pertinent, to such interval. ..,~ · . ":lt®m~26: ;'Sacks Cement": Attached suPpjemental, records.for this well should show the details of any mul- ':': tiple stage cementing and the location' of the cementihg ·tool. Item'S28: Submit a separate completion report on this form for each interval to be separately ProdUemd. "(See'!instruction for items 20 and-22 above). . i'~"SU{~/X]V['~,~,y OF, ~",O~VI'ATiON .'"[~TS INCLUDIN(; INTErVAl. T~TED. P~UR~ DATA ~ ~OV~ O~ OIL. O~. -- .. 35. G~GIC MARK~ :~ WAT~ AND MUD ,._ "-~ ~A~ . ... .. .. . . Top Hemlock 9208 8437 .. .. . . .. CORE DATA, A~ACI[ .BRIEF D~cRIPI~ONS OF LITHOLOGY. POHOSITY. FRAC~H~. App~NT DIPS- ,., , .., ,; ' ;'.~ } .AND DETECTEI) SHOWS OF OIL, G~ OR WA~. '~ '"i ,. *, . ~ i . .. .'..~ . ,'None . · ~- .. ~'V~or m ,P--7~ STATE OF ALASKA SUBMIT IN DU '~ ,~ e o~h6 st ructions on OIL AND GAS CONSERVATION C~MMITTEE reveri~e side) 5.. API ~CAL CODE ,, ' ~ ' ........ 50-133-20143 WELL cOMPLETION OR RECOMPL~:¥10N la. TYPE OF WELL: on, ~DRY b. TYPE OF COMPLETION: ~ ~z ~VELL OVER EN BACK ~SVR. h 2. NAME OF OPERATOR ;~"' ~nxon 0~1 Co~pany of California .... . ...... ~ . -: . ..... ~07 We's~ Norther~' Lights. Bl~d.., Anghorage:~ ,Alas~ At su~ace .Cofiduc~°r',, .... ~!8,..~., 1624.?~&... : 5!8'W,~ fr~. ~ ~ cor~e~.,Sec At top prod. Inter, il ~ePgrte~ below-i ..... At t~'~al aleph293'1~ North`& I019'E of sUrfaCe location '" 32~1"~ a 792'E', o~ surface tocatio~ ~s. ~t. ~A~ T.~. ~c~ ~. ~*~ co~ susP 26. LINER P~EC'O'I~D SIZE :TOP (MD) BO,~TOM (IViD) 7489 9826 ~OI~E sIZE :~FI~.. Ai~TD POOL. OR WILDCAT . :fading Ba7 - Middle Kena± gCTIVE) seC~3, TON,R13W, SM. [1~ :PEP,~.IT N'O. RT, ,GR, .~]~C)* 117. ELEV. CASINGHEAD ~,~ ""i ' iNTEI~¥ALS DRILLED BY BOTARI;_ --r--~OLSt O00i't ': '~ ' [ CABLE TOOLS 0-11 : '~ . None ~rg)* ~..,~ :,,,z 23. WAS DIREC~O,N~ ~ :.2,.~ ~ [SURVE~ ~DE ! ~: ~ , I Yes AIVf OUlkTT PULLED SACKS,:C~WIENT* ,v.'. SI~RE~ (iViDO 27. :~-~ 1{t9 .~OP.D SIZE ~r' DEI~X'i-I PACIiER SET (i~ID):I 28. PERFORATIONS OPF~I TO (Interval, size and 'nurnbe~) 4. 1/2'!:' Holes ,Peg Foot .... ~600 ,-8650 . '8820-8788 8750-87~ 9096~9066 8680,-8650 ~952-8966 8988-~8966 8514~8492 8952-8916 8444-8380 30. '.- _ PI%QDUC'TION 29. AC~D, SHOT, CEIVIENT ETC. '3 _ DATE ~iRST PRODUCTION .[ lgl~ODUCTION METHOD (Flowh~.g, gas~ Iii't, purnpi/~--size and type o£ pump) [WELL STATUS (Producing or . ,'~:' [ znut-in) 11 / 25 / 68 F,10win$, I Pr od uc ink DAT[ OF T[ST, [HOI/RS TE~TED IC~IoxE si. ZE [PROD'N FOR OIL---BBL. G/M..~--1VICF. WATER--BBL. [ GAS-OIL I{~TIO . . I . ~. I' ITEST PEIn!OD t FLOW, TUBING ~,~I~IG ~SD-R~ I~TI~D OIL--BBL.' GAS-~.NIC'F. WATER--BBL. Gi:L~.~-AI:~ (COP, R.) I 6 30 4 ~1. DISPOSITION or GAS (Sold, used for fuel, yen e , .) TEST WITNESSED BY Ven~ed ~2. LIST 0~' i~ACHMENTS ; 9-~/~" casin~ cemen~in~ ~eco~d' 33. I hereby certHy t~t~he for~in~ and attached information Is complete and correct as determined from alUavailable records / INSTRUCTIONS '** . ' ... .::General: This form is designed four submitting ja comp!.ete and correc! well com'pl~i!io.? report and log-: on all types of lands and leases in Alaska " -~ ": : .-' -' · .. .. ':ltem~:'! 16: Indicate which e!.'evati0n is u~'ed as :reference (where not otherwi~:e sho~,ni for depth'ih'~eas0re- ment9 given...in other spaces on thi.slform:iand i~i' any attachments. .. '~ltemj. 20~:.nd 22:: If fhis well is Completed for':separato production f'~'om more· than· one interval zone .:(muli.!ple:',completion);.so slote in'item'20,-an~ in item 22 show the p~c.duf:.ing inter,vlal, or intervals, -... /i'top(s)., bOttom(s) and name (s) (if any) for>onlyi:the interva'l reported in item 30. ,'sulbmit ;a separate report · '(paoe) on. tFi,is fc~im, adequately identif, ied~ fo/;;each adJclitional inte, val to be-~seperately.:produced, show- i:~ing the additional data pertinent.::ito such'~intei:{;al. . ' 'iJtem2.6: "Sa~:ks Cement":- Attached SulSPl~menfal records ,for this well'shoUld show the details of?any .mul- l' }iple:%tagb cementing :and the Iocation~ of,;, the ~ementing-' tool. .,,~ . · . -.~ , ,.~ ~ ' . /ltemi'.~8,'~Submit"a sep'arate completion r~port on this 'for.m for each interval to;'~, separately produ~l. · ;(See instruction for items 20 and' 22 above). ','4 :i ' ,. t.~' : >,'l'"A]{¥ OP"I~O~VI'ATION 'I~T$.]NCbUI')IN(; INTP-IriVAL'TESTED, P~U~[ DATA ~ ~OV~ OF OIL,'~, "; .... · 'J~-: ~.* wAT~ ~ND MUD ; ~A~ MEAS. D~ ~U~ V~T. 9210~9265, 9280~9318, 'Flwd~wtr 0 28:8 BWPD. Rev out ~25 BW + 25 BO: ' 6082~, IFP l~70~J',i..~ ...~, FFP ...2152~J, IClP 3755~, IFP2 '2250:,'.. FFp2, 3~77~,.. Hiddle [enai " '_P 375Mt .~ " ' :~' ' ' 57-2 0 :. 8362 766~0~' '..~ .,: ..:. 9210-9265, FiOd .o~1 0 625 BOPD. Rev out 150 BF, 75g ~:,~ 6082~ IFP 8~;~,:':'.FFP1 1598t~, I'ClP 3755~, IFP2:16~7~t,;FFP2 3100~, ;IP 3755~, FBP ~82~. . · ~ , 8600-8630~ Fiow~d o~1 0 973 gOPD.- I~P 3787~, IFP~::.l~37tJ, FFP!.2152, P 3411~, IFP2 2299, FFP2 2871, ~ClP"~3395~J,~FhP 3787tt. , . .. 'CE DATA. A~ACII ~RIE~ ~DmCRIPI~ONS ~F LITHOLOGY, POnOSITY. FnAC~Rm. APP~NT DIPS. . ~..,. .. .... . . .., .~ .. . ". ... . ... .... Cores T~ken. ..: ' ... . ; . .:.: LEASE UNIO. N OIL CO. OF C/4, LIYOf-~NIA ..~, WELL RECORD V TRADING BAY gAY STATE WELL NO. A-IS FIELD ' ' PAGe: NO. SIZE --9:--57 s 7t! WEIGHT 61 4O 40 CAE;lNG & TUBING RECORD THREAD GRADE DEPTH REMARKS -- I,ock ' J-55 1044 Cut w/900, sX neat: + 100 sx 22 C~aC,12, ami circ, Seal " 5643 Cmtd csg w/DV collar Q 5598' " N-80 -419J~ 1st S"=,-..~<~ae - 1900, sx CFR~2 . " 7520 2nd Stage - 1400 sx CFR-2 . - Buttre:,.,s " 9826 Cmt w/450 sx CFR-2 Liner ttangar 0 7489' .... ......... _____ PERFORATING RECORD D~TE I/',IT~¥_A, L E.,_TJD. p~~ ,. PRESENT CONDITIOI{ , 11/il/~. 921.0--9265 9269... DST._ Open to orod,mtion, ..,_ , ~ 8(}-2.~.I~ " Prod. uc t , S h~zr t~.~Lr -- ' D,~[ (,~ Prod Oo{m to oroductJon 11./1.,4 / 6~ 86~0-,8.~ 92~9 ~" ... 15 9096-9()66., Prod-ugtion " " " 89..5 ~89 ~. 5 . .. 868 g600~BB~g _-- -- INITIAL PRODUCTION __DATE INTERVAL-- N_.~ OIL C.UT GRAV. C.P. T.P. CHOKE ........... ,~- 90/6/' 12t 3f/i ' rm ga?~. 15ft' · 1!./25/~8 Sb~rin~ 1,2!2 0~5% 30.A° q60~) 240{~ 28/64 . .... ,, .... .... . , . -. .... ,. -- . ,,. ..... -- ~ .... _ ~-- , , WELL HE_AD AS E~MB, I.,Y TYPE: .. CASING HEAD: Sheller "KD" w/2" S.E. outlets SOW to 13-3/8" csg x 12" - 900 series CASING HANGER: Shaffer 12" nerainal - ~-~/~, ~.lodel KDKS CASING SPOOL: t2" 900 x 10"' 900 w/? - 1500/; sc,:~,c,~d out:],ot TUBING HEAD:__ Cameron Dual l.!odel DCB, ..~ TUBING HANGER: ... TUBING HEAD TOP' Ca:::eron So'lid g.l°~.k w/Haster valve a swab valve - dual MASTER VALVES: 2-9/l. 6"bc~re 2-7/g" API grd Thr .... UNION OIL CO. OF CALIFORNIA DRILIL. ING RECORD SHEET D PAGE 'NO. LEASE_ DATE g/29/68 3O 31. 911168 2 7 10 11 12 -. .].3 ' TRADING V~rELL NO., A-!8 FIELD TRADING E.T.D. ' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6].3 1069 1,558 2523 2784 2997 3309 3785 4288 4695 5O60 5739 6107 6270 6598 Moved rig frora A-17. SPUDDED 12-1/4" ' 1 · no e @ 6~00 AM Dr!d from 204' to 492'. POH, picked up Dynadriil, Dynadriiled from 492' to 613'. DDrld to 800'. POi{., picked up DA & drld to 11.00~ (corrected'TD !.069), POH, picked up 11-1/2" hole opener, Opened 12-1/4" hoIe to 17~1/2" hole from 204' to 1069'.' POH, RU to run csg,. Ran 13-3/8" csg set @ 1044'. Cmtd w/900 sx neat + 100 s× 2% CaC12 mixed w/Inlet wate, r' displaced w/875 ft3 mud, CIP @ 5:30 PM (8-30~68), Cement circ (apprOXo 100 s×), Rigged down mud., riser, cement h~d fallen down approx 30~, Mi,:ed up cat and du~npeJ in conductor, a,'round 13-3/8". ~-~o~ ~ C~ ...... g Detail 1043 98 1.0,4~.. 00 1.98 1042,00 1004,32 37.68 1004.32 i002,37 1,95 1002,37 38.00 964,37 38.00 TOTAL No. J 25 Baker Flex Flow Shoe 13-3/8, 6i~?~ J-55~ Seal Lock, N,S Baker Flex Flow CoIlar 61~ J-55 Seal 13-3/8, . ~r, Lock, N,S · -0- Landed ~ ~ , Be.~ou 1002.05 26 Casing Centralizers @ ].025' 924' 846' 769' 689' & 610' WOC 10 hrs. Cut off 13-3/8" csg, w61ded on Shaffer "KD" head, tstd packing to 15()0~ for 1,5 rain - OK. Rigged up BOP & Hydril. 1, Tstd blind rams to 1500~5 - OK. Picked up drlg assmby, RI}i, tstd pipe rams to ~u~, - OK, Drld float collar ~ 1002' f shoe ~ 1042'. Drld & surveyed 12-1/4" hole from 1069' go 1558'. Drld & surveyed 12-1/4" hole fro~ 1558' to 2523', POH to pick up DDrl, RIH and DDrld 12-I/4" hole from 2523' to 2776'. POH for DA chng, Rill & drld 12-1/4" hole from 2776' to 2784'. Survey ~ 2784' indicated 2* right hand turn. POll to pick up DDrl. RI}t & oriented DDrl. DDrld 12-1/4" hole from 2784' to 2997'. POH & RI w/DA for follow run, lost right hand turn, RI w/stabs!izod asamby, Reamed 400' to bottom. Drld to 3156'; DDrld to 3309' for Left }land turn. RI w/limber assmby. Drld to 3352'. POH, picked up locked in assmby, Drld & Surveyed 12-1/4" hole to 4288'. Drld & surveyed 12-1/4" hole to 4695', Drld b surveyed to 5060'. Drld & surveyed to 5543', Kelly hose blew out, replaced same, lost 3 hrs, Drld & surveyed to 5739'. Drid & surveyed to 6107'. Drld & surveyed to 6270'. Drld & surveyed to 6598'. UNION OIL CO. OF CALIFORNIA DIRILLING RECOIRD SHEET D PAGE NO... 2,_ LEASE._ .. · '0~1 T~' ~.,~.,). ~G BAY STATE WELL NO. A-18 FIELD TRADING BAY DATE ~ . E.,~T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 15 16 17 18 19 2O 21¸ 22 23 24 25 26 27 6778 6891 7042 71!1 72].2 7332 7623 7874 7874 7874 7320 7383 ......... 2~,, to 6778 . Drld & =,,~v-vf,?, to 6391' Drld & surveyed to 6983'. Drld & surveyed to 7042'. Drld & surveyed to 7111'. Drld & surveyed to 7212'. Drld & surveyed to 7332'. Dr!d & surveyed to 7623'. Drld 1.2~1/4" hole to 7874' Lost 600# prop press, POH to check for washout, Finislmd POH. Pulled 270,000~.~ into tight spot f~ 26!.0~, Lost ali. tool weigh.t upon con, lng through. After POH, found box on bumper sub had waghed ou~ and parted when co~tiag througa tight spot leaving all collars stabilizers, and bit in hole. RI to top of fish ~ 7422' w/ovf~rshot, Went down and circ over top of fish w/ 6~1/8" socket~, l,R~en over fish, press increase indicated circulation through bit, Then press dropped frota 2100# to 1600.~~ indicating packing rubber cutting out, After numerous unsuccessful attempts to latch onto fish w/socket, picked up and circ hole clean, POH unable to comt2 up above 2606', Free movement down, Jarred and worked pipe up through ~-,r~..~ key POi-i, .-~,~, ........... seat ~2606' picked up 12-1/4" bit, and 1.2-~ ~" · ~ -.. ~l~ stabilizer to RiH to wipe out key seat. Picked up Bow,~m Overshot & }ti}.{. Latched onto fish @ 7422'. Circ & worked pipe, then Began jarring. Cont jarring & working pipe 9~1/2 hfs w/no · 'c,~, Dia-Log t run free point. movement of fish Rlaoed up o Cont trying to ru.n free point but Could not get free point indicator and backed off shot below 7441'o Rigged down Die-Log. Released overshot from fish ~ 7422' and POt-I. RII{ w/open end drill pipe ~ 7420'. Mixed & pumped 250 sx Cie, ss '~G" cmt w/2% CaCt2 & 15% (38 sx) sand, m%xed w/Inlet water:, preceded w/50 Ft3 causv~ ....... , .... ~,a~e,. CIP 0 10:15 ~i. Pulled 7 stds dry, caaa wet, attempted to clear drill pipe. Cduld not circu!'ate w/3000~ POH, Found !9 j ts cemented up. WOC 9 hrs. RIH, found top cmt Q 7203' (Theo. Top ~ 7180'). Polished off cmt plug to 7320'. POi-i, picked up DD'cl, RIH, oriented a DDrld from 7320 to 7383'. Started out of hole w/bit a_ 3888', unable, to pull. Free circulation, Rigged up buraper sub above Rotary Tabl. e~ unable to knock fish loose. Rigged up D,A. l,og, Ran free point, found free point ~ top of Mono!, Backed off rd 3S09', leaving 1 jt H,W , monel kick-sub, D A., & 12-1/4" bit .in hole. POH, picked up Hydraulic jars &bur, tper sub & jar accelerator, ....... = ' pulled bit RIB, ,.,~,.,,~ax, into f'.rs~.,,*, jarred fish__ loose, started out of ho!e, to 3J.67' wlmre i.t stuck again. No action of jars-or bur:~per sub, believe top of fishing drill collars in key seat ~ 2892'. Picked up key seat wiper g made sa::~e up in drill s'~' -- .. . ......... t,~zng Ran fish back ' , oox~,n bole w/~ 287U'. Unable to get below this point. 'This typ9 of wiper would only drill .up, Pulled back up"& reraoved wiper and ~:ade welded blade string r ...... er ran in hole & rean~ad from 287S' to 2S~0' Started out of removed, string, reamer. Pulled 7 j ts (220') - hung up again, Drilled w/slips a w/pu~p oa DDrl for 4 hours', Fish came free. POH, recovared all fish except: 12~1/4" bit, bottom of DDrt (8-10" long) a 3' drive shaft, UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE 'NO. LEASE T,G~.b ~.,..(, [~AY STATE A--18 'I v,_~d) !?~, BAY ,. WELL NO. __ FIELD. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE 29 3O lO/1/6 /, 4 7434 7521. 7521. 7521 761.7 796(} 8307 ext'...n .... o.., HYD Jars, Bumper Sub, 3 Made t;.p short catch overshot w/4' '¢ ~ n 621/4:' D.C,~ 12-1/4" stab & 14 jts }i.W. RIH w/overshot @ 3015. Did not find fish, Reamed up w/stab, from 2895-~88~ in 3 hours. Preceded on in hol..e, hit bridge @ 4360'. Put Kelly on &circ out brJzdge~ RIH Lo bottom 7381'. POll, recovered all. of fish, Laid fish & fishing tools. Picked Drilling Assembly. RIH, drld & surveyed 12-1/4" hole from 7353~ to 7434' . Drld O surveyed 12-1/4" hole froze 7434' to 7521'. cite to 'condition a,d hol. e, P, o 3242~ and hung up, Drld up t-!/2~ and pulled F:i. nishea PO!t. RU S,.h,,u,,be~ger Ran DIL and Fi)C Logs. Schlumberger to 7519' . Ran S~NP, LL--3, }iRD & Sonic Logs. Shot 13 sidewall cores and rec. 8, Rigged down Schlumberger. L. ayed down 8'" collar. Prep to RI!! to cond mud. Rlti to 7521 and cond hole for csg. POH and rigged up to r~n 9-5/8" ass. Ran 46 jts 9-5/8" 43.5~-~ N~80 buttress casing, 34 jts 9-5/8 buttress casing, and 99 jts 9-5/,5" 40.0~,~ J-55 buttress casing~ Landed csg w/FS @ 7520', FC @ 7481' and liowco DV collar @ 5598'. Cmtd 1st stage w/1200 sz CFR-2 mixed w/iu!et ~(:ater. Bumped plug w/1300 psi. CIP @ 10:20 PI..10 Dropped bomb and opened DV collar. Began circ prior t:o craig 2nd stage.. ...... ~ w/in! Cent circ. until 12:30 Al4. Cmtd 2nd stage w/1400 sx t~i~-~ mixed . et ~ ..~-,. Plugs wtr. Bumped plug and closed DV collar w/2500 psi. C!P 2:20 ~)~ held OK. 9-_~5 8" Casin~.' Detail ~ jt 44 its lit 33 j ts 99 j ts 179 j ts B~=.e.,_ Model "G" Float Shoe 9-5/$" 43.5J! I~-80 Buttress Thread, ~;ew Casing Baker Nodal "G" Float Collar 9-5/8" 43.5// iq-80 Buttress Thread, hew Cas ins 9-.5/8" 40.0~/ N-SO Buttress Thread, 1,:: ew C a s i n g }iOWCO l)V Collar 9-5/8" 40.0~; 1~--80 Buttress Thread, New Casing 9-5/8" 40.0f7 J-55 Buttress Thread, New Casing 9--5/8" 43.5# N-80 Buttress Thread, New Casing Landed Below Rotary Table 2.65 7520.00 - 7517.35 34.38 75%7.35 - 7482.97 -2.00 7482.97 -. 7480.97 1837.77 7480.97 - 5643.20 43.55 5643,20 - 5599.65 2.15 5599.65 - 5597.50 1406.90 5597.50 ---. 4190.60 4123.30 4190.60 - 67,30 36°67 ~67,30 - 30.63 30.63 30.63 - 0.00 Removed ?;.OPE and riser assembly, Set 9-5/8" slips and cut off csg. Instld Cameron tbg head and tstd saree to 2500 psi - OK. Re-installed riser and BOPE, Tstd 'blind rams to 1500 psi - OK, Rill and drld out DV collar @ 559S'. Tstd pipe rams to 1.500 psi - OK. R!H and drld FC f~ 748i.' & FS @ 7520. Drld and surveyed 8~I/2'' hole from 7521 to 7617'. Dr]d & sr..rveyed c., ~z ,, ~-.,./2 hole front 761,7' to 7960'. · ' ~ ~ . ~ ~ ~ Drld & surveyed 8-1/9'' [tole from 7960" to 830~" Made ~.hor,. trips .~ ~g,t~ hole just off bot¢om on trip for new bit @ 8157 & on short trip 8268 Added 30 sack of medium ground nut. ~! to mud- LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD · 'I?I<ADiNO ]:,,~,.Y STATE ., SHEET D PAGE NO. NO. A-18 ,~,= BAY WELL FIELD_.. TRADT '~*~ DATE lO/S/6s 9 10 11 12 13-16 17 18 19-22 24 25 26 27 28 ~' EJT. D. DETAILS OF OPERATIONS, DESCRIPTIONS &-RESULTS 8511 8511 861.0 8695 8713 8824 9052 9746 10073 10376 1.0468 10468 10339 10180 Drld & surveyed 8-1/2" hole from 8307' to 8511'. No tight hole on short trip 0. 8311. Added find ground nut plu~ to mud. . -5 ' ' e Rill w/trow bit @ 8311 . Drld on junk, POH & exa,mzn~d bi~. Lost three cones, Rill w/junk bm .... et Recovered pieces of coal, no iron, RIH w/be. sket. Recovered only coal, RIH w/bit & dr!d to 8610'. brld to 8695, POll for bit changd. RIH w/bit, stuck @ 860'0'. Jarred on fish for 5 hrs., free circ., could not rotate, RU /)ia-Log from free point @ 8538'. }lacked off ¢.. 8507' leaving bit, 1 monel, stabilizer 1 steel D C in hole RiH w/bumper sub jars into f J.,,:., , ,,,~ jarred up for 30 mins~ fish ca~:ie loose POll, ~ .... overed all of ~ ~' 5~ '5 ~ ' fish. I!Ii{ & reamed from 8~1,> to 869 (from ~45 to 8695 rough to ream), Drl.d to 8713'. Drld & surveyed 8--1/2" hole to 8824'.. Drld &~,=*~,~',~)~o,,o' 8-!/2~'' hoxe" to 8988'. Slipped & cut drlg li~e, repaired broken air line (high clutch). Drld & surveyed 8-1/2" hole to 9052'. Tight hole @ 8982'o Reamed 8982' to 9052' . Drld & surveyed ° ~'~'' · o-,/z hole to 9632. POll w/bit #50, found 2 cones mzssing. RIH w/bJ~t & jt,.n¢, sub, Encountered undergage hole @ 9430'. Became stuck, worked loose. Reamed 9430 to 9470, had excessive, torque, cm.~ld not continue reaming.' POH, bit OK. RI}( & started reaming @ 9482 to 9632. Drld on bottom for 1 hr. POll, found junk sub full of iron. RIH & drld to 9746, l)r]d & surveyed from 9746 to 10073. I)rld & surveyed to 10376. Drld to 1.0468, }tad 1.8' drlg break (coal) became stuck, hacked off leaving bit, monel, 25 DC in hole. KIH, screwed into fish, jarred 3 hrs w/no movement, backed :off leaVigg .bit~ monel, 25 DC, sub, B.S. in hole. Top of fish @ 10368. RIB open er.,ded w/d,p. @ !0,'365'. Pumped 100 cuoft, cauSti,c wtr ahead,mixed 1.1.8 cu. ft. cmt w/251 sand, dS_splaced w/5 cu.ft, wtr, 950 cu,ft, mud (theoretical dx,~pla .... ~,~e~,_~ - 938 cu.ft..) Pulled 5 stands, found plugged. POH, found 28 its cmtd up. Rill w/bit, found cml @ ]..0,336. Drld firm cat to 10,339. POH. Rill open ended w/d.p. @ 10,340', pumped 50 cu.ft.'wtr, 50 cu,...~t, caustic water. Mixed 118 cu,ft~ neat w/201 sand w/Inlet wtr. .Displaced w/5 cu.ft. wtr, 970 cu.ft, mud (101 excess). Pulled 5 stands, circ bottoms up, No cmt. 'POI-i, RI w/bit found cmt at 10,177'. Circ to conditic, n mud. Dr]d firm cat to ]0,180. POH, RU Schlunberger.. UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE. BAY WELL NO.. A-18. FIELD r,u,~DIht,_ BAY DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE 10/29/68 3O 31. ll/1/6s 2 1.0 ~ E?T. D. 1018() 10253 1,0306 1.0428 10560 10560 10560 1062.l 10753 1J. 000 11,000 11,000 ] 1,000 Ran DIL, HP¢O did notope_ac~,r ~- Ran FDL, Bb'n.~, LL-3, SNP~ shot 29 sidewall samples retr~:ved 28, Polished off plug for DDrl. POH to pick up DDrl. RIB & attempted to take ~u..v..), sandlina parted. POll to retrieve instrument, spliced tail on sandline. oriented &'DDrld from 1.0253 to 10282. Drld b surveyed 8-1/2" hole to 10428'. Dr!d & ' ~ r,',~t ~ su~c3=e~ to 10560, tight hole on bottom, had to v:or~: out 6 joints, Finished Pr)ti, RI, started reaming @ 3.0380 when Rotary Drive Transmission want out, Waiti. ng on parts for Rotary Drive Transmio- q oS ~.OD-, Repaired trans:ai, ssion & Drld ~o 10,621, Drld & ,~m:w%..d to 10758 Tight hole -~' ~' RI & ~ ~' . co,,.in~, out. POH~ r ~¢meo bottom 200' " ~' . Conr~.nu,~a drlg. Drld & surveyed to 11000, circ 3/4 hfs on bottom, Pulled 15 j ts thru tight hole & reamed back-to bottom, continued Cop, g PO~i, ran Schlun~berger hRD & DIL Logs, HRD ~l¢,.~*tioned,,,¢.~.~,.~.. . Tore dox.-,.'n Schlumberger RIt.i> l,ayed downl5 jts, Reached 15 jla to bottom, Circulate bo t to.~:3s up. POH. Tight hole pulling out bottma 270', Ran HRD & Ganmm Density Logs. Rill to 9550' to condition hole for liner. B¢~g~n running 7" 29# .N-a0-Linc.~' '~ on TIW hanger, Finished running Liner. TIW hanger hung w/top @ 7489', shoe @ 9826, landing collar. @ 9738'. Puw. ped 50 cu.f~, caustic w.ater, 50 cu,ft. Inlet water ahead, Hixed 450 sx Class "G~* w/l% C}'R-2. Displaced w/1220 cu.fr, salt water. CIP 6:00 Ab[. Set TIW pkr.. Reversed out drill pipe, recovered approxSmately 20 sx cnt. 7" Liner Detail lit 14 jts .15 jt$ 24 j ts Baker Hodel G Float Shoe 7" 29# ~-80 Buttress New Baker ?.-lo,el G Float Collar 7" 29a . v iq-SO Buttress New TIW Land ir~g Collar 7" 29# N-S0 % L, t.~,.e~s New .... t 29# N-80 Pup Jo~p' 7" 7" 29# N-gO Buttress New Pup Joint 7" 29# N-S0 7" 29/~ N-80 Buttress New Cross Over' TIW Liner Hanger Total Length 2.38 60.85 1.80 42,72 1.00 583~73 11.75 620.61 14,66 993,42 1..00 23 ~ ,~,3 7489.00 2337.55 9824,07 9826.45 9783,22 9824.07 978!.42 9783,22 9738.70 9781 ~2 9737.70 9738.70 9153.97 9737.70 9142.22 9153,97 8521,61 '9142,22 - 8506,95 8521.61 7513.53 8506,95 7512.53 751.3.53 7512.53 I'icked tip 3-]./9'' drill pipe & RIH with r ~/o.,-'. 4- 2" ,~ o-~,./o bit on 1/. D,C, Fouled top 60' hi[~h ~ 9677' Changed over to Inlet .... -- & weig s ~a~e= hted ~'-,~ to 68~5 w/sal, t f potassiu:a chloride. UNION OIL. CO. OF CALIFORNIA DRILLING RECORD SHEET .D PAGE NO 6 LEASE.__ BAY STATE WELL NO. A-18 __ FIELD_ TRADING BAY DATE lll].ll~.s 12 13 9677' 9270' 9000' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Pressure tested lap to i000~9 for 15 min. - Pressure test OK, POll laying do~.m grade G dri].l pipe. R~n CBL, Gamma Ray Correlation Log & Collar Locator from 2500' to 9662',. Found top of liner @ 7487'. CBL indicated good cmt bo.nd behind 7" ].Sner up to 7790'. DST #i: Perfora~e~-_~ fr©m 9210~ to 9265' a~d fro:~'t 9280~ to 9318' w/4" csg guns spaced @ 4 holes per foot. Picked up ~lowco Drill Sr.e~; Test Tools and RIH. Set packer @ 91.67'. Loaded 500 psi gas cushion. Opened tool for 20 min and pressure increased to 700 psi. Closed tool for 90 minutes, Tool opened again through midnight~ Tool left: open u. ntS1 2 50 A-'M. Water surracec. @ 12:40 ~[, flowed 100% water @ 288 BPD. ~'irst 5.6 bbl - 93,000 ppm cl~ completion fluid from rat hole, Next 2011~ bbl water - 20~000 ppm cl-. Reversed o,~t 25~ bbl water 20,000 - 3.7,000 ppm cl followed by 25- bbl oil w/50% water cut 16,000 ppm el", 100i~ bbl 23.1~ AP1 oil w/50% cut (1% water~ 1% sd.~ 48% emulsion), Shut in tool for 8 hfs. Pulled pkr 1.oose & POll w/Haliburton Te. ster. DST #1 (971O' -~ 92~5' 9280' °-~ 9318') Inside Chart (9157') Out~ide Chart (9175*) IHP 4072 4082 IFP (!) 1267 1370 FF~ (1) 2100 2152 ICIP 3742 3755 IFP (2) 2166 2250 Max Flow Press 3526 3559 FFP (2) 3444 3477 FCIP 3758 3755 FHP 4072 4082 RI,*{ w/ltowco CI BP & ..... s,,t @ 9270' Rill w/Hcwco Test Tools & Set P=,c,..er~ ~-- @ 91.67', tail. ~o 91.80'. DST #2: 9210'- 9265' set pkr, Loaded 500 psi g~.. cushion, opened tool for ]..5 min. Pressure increased to 575 psi. Closed tool for 90 m.in° Opened tool @ 11:00 PM & reamed open thru midnight. Tool remained open until 11:0.0 AM. Liquid (oil) surfaced @ 3:30 AM, First emuls~..on, !/, sd, 18% wtr (el = 81,500 1/2 hour rate 4,2.5 b/d gross, 5% , ' .... - . Reverse. d out 50~5~ bb!, ~8.2° AP1. x~/8/~, cut (6/. wa~er~ 2% emt~l.s.~.on) 32,000 ppm el-, 50Jr w/27% cut (1.8% water, 2% sand, 7% emulsion) 37,000 ppm el-, 50Jr bbl w/20% cut (12% water, 1% sand, 7% emulsion) 30,000 ppm el-. Shut In too] for 8 hrs. Pulled pkr loose & POH w/Haliburton Tester, DST #2 .~!O' .- 926.5') Inside Chart (9157') Outside Chart (9175') !}I.P 4072 4082 IFP (1) 818 849 FFP (1) 1567 1598. ICiP 3740 3755 IFP (2) 1617. 1647 FFP (2) 3079 3100 FCIP 3742 3755 FHP 4072 4082 RIB w/Howco CI BP & set @ 9000'. Perforated from 8630'-8650' Wl,'Z" csg guns spaced 4 holes per foot, LEASE.__ UNION OIL CO. OF CALIFORNIA DRILLING RECORD BAY STATE SHEET D 7 PAGE NO A-18 TP&D I~G BAY WELL NO. , FIELD. DATE 1.6 1.7 9000' 9269' 9269' 9269~ DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Pcr'fo':ated from 860,q' - 8630' w/4" csg guns spaced 4 holes per foot., w/l!o't,:co test tools & se~ packer ~o~,~ tail to 8~6.>= ~', DST f~3: 8600 8650' Loaded 500 psi ~' cushion Surf i~ 1 hr a 15 rains, f~.o~'~.ng ~) 210~--FTP. Took 5 n~in initial flow (~ 973 BOPD,~ O, 7% ~.-=~'~xTM, 30,2~ AJ.I, , 1-1/2 hr initial shut iD, 8 hr flow, 8 hr shut in pressure, DST #3 ~8600' - 8650') Inside Chart Outside Chart IIiP 3775 3787 IFP (1) ].218 1337 FFP (1) 2033 2152 ~C!P ~394 3411 IFP (2) 2233 2299 ~FFP (2) 2847 2871 FCIP 3377 3395 t'~'~' 3775 ~ 3787 · £ l ,'-.' . POll & ].aid down ttowco Test Tools, RIH w/bit & dr!d CiPB @ 9000'. Drld & pushed plug to 9270', PO!l, RU Dresser Atlas: & perforated w/4" carrier gur~ 4 holes per foot as follows: . o~ , gAgg' ~v~g' 8680'..8650~ 8600' 9096'-9066' 8988'-,,~ou°~'~', 8952'-o~i6 , ~.... -~,~ , , - -' ' 8444' o~,,r,, 8750'~878~' 8~5~'~8966' 8568 ' 8,5.~.4 Atlas, RU to run tbg, ran 4 j ts 2-3/8" tbg & Guiberson Packer when tbg parted dropping ~arne in hole. Rtli w/7" outsid,." .................... d~'t ..... .~"'" gowen ove~ .... ~,.o~..q.';,, +' to 7489' (top lnr hm. xger), POH, RI with 5--3/4" Bm.;r:n overshot~ Latched. on fish @ 9!25'. PO~, recovered fish, RU to run tbg, Run long string ~/jewelry, Rap~ J. onS .~tring tbg~ Landed [~ 9184' w/Guiberso~ RH-I Packer ~ 9140' & Guiberson R!{-2 Packer &~ 8312', Ran short string~ stabbed in RH=2 Packer ~ 8312'. R!) BOPE & set C!W Dual Tree~ tstd same to 3000/~, OK. Dis-:~!accd salt ~.,ater w/da.e.~l ' 1~ '~o ., , Dxsp,~c~.,o salt water to RIG RE!,EASED ~ 9:00 PM 11/17/68, Gas lifting short string and ].ong string to bri~g on production., UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE.__ DATE TRAt)IL'G B.5.Y., STATi5 E. T. D. A--!8 TILAI)I~G WELL NO,_ FIELD_ DETAILS OF OPERATIONS, DESORIPTIONS & RESULTS 2-7/8" Tub.in.~ l)et. ai~ -- L¢'n~, Strin~ I,auded ]}e. low RT 2-7/8" }:;U~,X 2--~7/8" S.L. Pup 9 jt:~ 2-7/8" N-SO S.L. Tbg Ball Valve 59 jt~ 2-7/8" N-~O S,I~, 2-7/8" CX Mandrel 2,3110 60 jts 2-7/8"~ N-gO S,L; Tbg, 2~7/8~' CX Mandrel L9 jts 2-7/~''' o N--80 S,L, Tbg, 2-7/8" CX M¢.ndrel 34 jI:s ':'-7/°'' 2-7/8" CX 2).. j ts 2-7/8" i~.--80 S,L, Tbg, 2-7/8" x 2-3/8" S,L, 4 jts 2-3/8" N-SO S,-L. Tbg, 2-3/8'~ CX ~'-~,' 2--3/8" CX Mandr~.l' Ijt ~-3/8"" o .. ~---o0 S,I,,. Tbs, 2-3/8" EUE Srd x 2-3/S" S.L. Pup R!i2 (2-3/8 x 2-3/8) 7" 25 j~,: 2-3/~>'' . , ..... , N-80 $ t, 'rbg. X0 s]e~2vc o ~/~'~ 1 5t 2-3/8" ~-80 S.I.,. 2-7/8" x 9_~,o S,L. Swage . ' ~ ' 2-7/8" 2-.7/8" Eui; 8r,:, x g,I.,, Pup Rhl 7" x 2-7/8" 29~! Packer 2--7/8," x 2-3/8" S,L. X Landing ' ~ ',. 1 jt 2-3/, N-SO S L, Tbg. '2-3/8" S,L, x 2-3/8" EUE 8rd Pup Shear Sub 3000¢? 37,00 1,00 3.19 280,37 3 3a ].864,04 6.1,0 1896,23 6,10 1545,81 6,10 1075.94 6.10 664, O0 1.12 123,65 5,75 747,05 5,75 30,73 3,13 9,45 779,67 2,85 31,16 3,19- 6,54 1,12 1,20 3!,06 3,13. ,90 -"0~: 37 '00 37.00 38,00 38.00 41.19 41.19 321,56 321,56 324,91 324,91 2!.88,95 2188,95 2195,05 2195,05 4091,28 4091.28 4097.38 4097,38 f~ O,:~ 3( ' ~_ , !9 5643,19 5649.29 5649,29 6725,23 6725.23 673!,33 6731,33 7395 3~ 73°.=,,_¢, 33 7396 .45 7396,45 7520,i0 7520,10 7525,85 7525.85 8272,90 8272,9(3 8.278~ 65 8278.65 8309,38 8~09,38 8312,51 8312.51 8321.96 832!.96 93.01,63 9101,63 9104,48 9104,41~ 9].35,64 9135,64 9].56.76 9136,76 9139,95 91.39,95 9i46,49 9t46,49 9147,61 9!47,61. 9148,81 9148,8!. 9179,87 9].o .... 9179,87 '*'~ 00 9183,00 ~'~ 9.! ,~, 90 UNION OIL CO. OF CALIFOlqNIA DRILLING RECORD SHEET D PAGE NO. LEA.SE WELL NO.A-]'8 .FIELD_. TRADING DATE ~ E.'t]~. D, DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS I,anded below RT CIW t{ap, g er 2-7/8" EUE 8rd x 2-7/8" S.L. Pup 2-7/8" x 2~7/8" S.L. Pup w/collar Il II !~ II 11 II II It II !1 II Il Il !t II !1 I! 7 its 2-7/8" N-a0 S.I,, Ball Valve 60 j ts 2.~7/8~' N~80 S.L. Tbg. 2-7/8" CX La~dr,.1 61 jts 2-7/~'' o N-gO S,!,, Tbg, 2-7/8" CX Mandrel 50 j ts 2-.-7/8" N--80 S,L, Tbg, 2-7/8" CX Mandrel ' ~,,0 S L T b g, 34 jts 2--7/8" N-or , . 2-7/8" CX Mandrel 21 jts 2-7~°" -, , ~ i~-bO S.L. Tbg 2-7/8" S,L, x 2-~'~'' >ia S~I,. Swage 3 j ts 9-3/e~" ~' ~' l,-e50 Seal Lok 2-3/8" CX Handret 25 j ts 2-3/8" N-gO Seal Lok Tbg. 2 j ts 2-3/8" TM en S L Tbg Snap Lack-~ Pup 2-3/8" RH2 (2--3/g x 2~3/8) 7" 29# Dual 'N' No Go I,anding l.~ipple 37.00 -0- 37.00 !,00 37.00 38,00 2.50 38.00 40,50 4.20 40,50 44.70 6.07 44.70 50.77 6.02 50.77 56,79 . 5 , 94 3 15 56.79 z9 4,15 59, 94 64~09 219,69 64,09 28~,. 78 3.35 283.78 287.13 1865.50 .287.13 2152,63 6.10 2152,63 2158o73 1895.96 2158.73 4054,69 6 10 ~ ~.' 79 . ~0,~.69 4060. 1551,74 4060.79 5612.53 6,!0 5612,53 5618.63 1073,1,7 5618~ 63 6691,80 6.10 6691,80 6697,90 663.45 6697.90 7361.35 1,12 736!, 35 7362,47 94 50 7"~ 5,75 7456,97 7462.72 778.15 7462~72 8240.87 5.75 8240~87 8246.62 62,35 8246~62 8308.97 2,80 830~97 8311.77 9.30-8311.77 8321.07 .61 8~,,z1.07 8321.~8 UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO LEASE Trading Bay State WELL NO. A-18 FIELD Trading Bay DATE E.T.D, DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5/20/69 23 Checked pressure in 9-5/8" x 13-3/8" annulus. St;ut in pressure, 150 psi, bled to 0 psi. 12 hr build up to 185 psi. '9-5/8" x 13-3/8" annulus, 200 psi. 9-5/8" x tubing, 900 psi. Connected Halliburton unit to well & pressured annulus to 1700 psi, broke to 700 psi. Pumped 25 ft3/min @ 1200 psi. Mixed & pumped 25 sx BJ Gyp-Seal into annulus, reaching a maximum pressure of 1900 psi. Followed cement w/10 ft3 of water w/ pressure increasing to 2200 psi. CIP @ 3:30 pm. Immediate' shut in pressure 1500 psi. 9-5/8" x tubing annulus remained constant 900# throughout squeeze job. No communication between 13-3/8" casing ~ 9-5/8" casing. FIELD.. Tm~D I.b~(; BAY . , 55 ' LOCATION. Conductor No 1.8 1624'N and ..... 8 W from SE corn,-~ eer"-~- 4, T9~,!_, R13W A1 ~ Kenai }hor. o:..~h~ ,.. ~.. .... PERMIT NO 6 S-.76 T.D. 'r 731 SERIAL NO. ~_)L 18 T.V.D. DEVIATIOI~ (B.ltI.L.)' COMPANY ENGINEER SPUD DATE CONTRACTOR TYPE UNIT PAGE NO 8/29,/68 COMP. DATE~ I!./1.7/68 Caldr~l! RIG NO. g 860 E 0i~.,e!l DRILL PIPE DESCRIPTION.. 5" ELEVATIONS: WATER DEPTH R.T. TO OCEAN FLOOR' ti. T. TO MLLW R.T. TO DRILL DECK R.T. TO APPROVED: ' 174' 112' 22/07 40.82 MUDVE~. ! DEPTH & DEVIATION BIT RECORD ' -~ "~IT '" JET DEPTH; v: VERTICAL DATE DEPTH. !~O, SIZE MAKE TYPE SIZE OUT FEET }{OUn.S ANN. JET DIRECTIO~¢AL 8/29/68 20.4 1 12-]./4 Reed ST3-A 3/16 1069 865 9 T-2 B--1 ~0 204 ~iO1 2. Y-1/2 Smith 5 Point - 2059 865 6-3/4 OK for 31 1069 1RR 12-1/4 Reed ST3--A 3/16 1558 489 5 _1.05 525 T--2 B-.2 1/8" OG.~ 9/1/68 1558 2 " Sec, S3S-J 3/12 2523 965 15-1/2 " ' T-4 B-2 2 2523 [~ I ''' R.aad ST3-A 3/24 27~6 203= !1~1/2 75 - T-4 B--3 Dvn;idr:t.~Je..~' 2 2776 4 " Globe SST3 3/14 .2784 8 1/4 lr)5 385 T-! B--1 3 2784 5 " Reed ST3~A 3/24 2896 112 ..... 4 75 -. T~3 B-2 Dyr~Ari].] 3 2896 6 " " " " 2997 I01 4-1/2 " ~ " " " 3 2997 4RR ,i Globe SST3 3/14 306q 72 1-1/4 95 ....... ~ .... Jq. 0 T-1 B-1 POH. ch~ 4 3069 " " " " " 3156 87 1-1/2 " " T-2 B~2 ....... C AI~ 4 3156 7 " }iTC OSC:tG 3/24 3309 153 4-1/2 75 " T~.2 B~2 l)vn~dr~ ......... = ~-~ ~. 5 3309 6RR " Reed ST.37-A 3/14 3352 33 1-1/2 103 ~!5 T-I ..Brl 5 3352 8 " Sec, S3S~:J .." ' 3785_ - 433 11-1/4. " " T-3 B~2 1/8" OG ' 14" O~ 6 3785 9 " HTC O~Ci~,-~ 3/12 4137 352 ~-1/4 98 475 T-3 B~2 '" ' ..... ' ~', · 6 41.37 I3'0 ' ' i " ODG " 4288 151 5-1/4 " " '"I-~, '* B~2 7 428B 11 ...." " " " 4.5 lz~ ~ 224 7 " " T---4 B-2 7 45.!2 !2 " R~;~ed STIAG " 4760 248 ... 11 " " T-~2 B~I 8 4760 6RR] " . " ST3.-A " 4980 220 _ 7.. 98 475 T-2 8 ,9&O .].~. Globe ST3 " 5295 315 I1 " " T-3 B--2 9 5295 ..],4 " ". " " 5543 .258 8::~i/2 '" . ." T-3 .... Y~ ~I' r .... .9 5543 15 " HT(: ,~, 5739 !.gt) 8~!/~ l"00 ~]~ " .. 10 5739 1.6 ............. " Reed YT1AG " 5981 242 ~0xl,14 -" ". ... 1]~ 5)81 17I 'ST]3~G " 6069 ~8 3 lO0 " T-4 B-I Pulled i , I] 1 .. 6069 !..8 " HTC X~LC " 6129 rio..... 5-1/2 " " 7' - 4 , . _12 16]~29 1. gR~{ " HTC XSJR " 6226 97 7~!/2 " " OK for . 12 6206 20 " Sac ,,,',c ,, .. . . .... x.,~,~',,, 6440 .... 214 x. 1=!/4' 95_ 475 T-3 ]4 ... 6673 23. ..... " " " " 6798 1.25 14 " " T-3 15 6',a8 23 · ,, SeC, N4LC ,, 689]. 93 ~ 2-1/5 ,, ,, T_2 B-9 - ,. ~;, .r~ , ~ , . ,. ;:. . ............. 1 6 6gq] ~ 4R]:I. ". HTC X5 5" ~ " ....... R ~,/12..2/! 5 6983 92 !5 100 T-2 17 6983 .25 " " XDG 3/12 7042 59 13-!I4 96 480 T-.3+ B-1. 18 . 7042 26 " .... " " " 7111 69 13~1/2 " " T-2 '~.9 . 7!1.!. 27 " " X55R " 733% 221 40 " " T~2 B~'!+ ?0 73 ~ ,, ,, · 7874 .. 3.~ 2 " " - ...2 Lost in hole , _ _ 23 78Y .] ,,-1/4 1iTC XDR 3-3/4 v~Sq 63 9-1/2 l.)yn~ :!r~ l 1~d T.~4 B-4 3/4" _ 28 73.B~ 30 " . . " 0!)G 37] 3 752t 138 6-~/4 96 448 T-.3 · 10/2/68 7521 31 8-1/2 Reed YT1AC 3/t2 7617 96 7 240 45~~-.~ 3 .. .7&17 32 " " " " 7887 270 .!1' ]76 265 T-3 - 4 i 7F',8~7 33 " Reed " 3/14 8t57 " 9-3/4 ]75 260 T-3+ B-2 1/8" OG A 8157 34 " " SCb[ " 8327 ] 70 g-~/4 " " T-]. .... 5 8327 35 ,, ,i YT%AG " 8511 184 9 " " T-4 B-3 6 8511 36 " HTC XDG " " 0 2 " " B-6-3 Dr!d on 6 ' " 37 " " XDR L2-1'2-'1 5 8518 7 3 ,, '' IT-2 B~I. . .. 7 8518 38 " Reed YTIAG 3/14. 8610 92 6-1/4 " "' T-3 ........ 7 86!0 3Y " " " " 8695. 85 6 " " T-~ B-2 l ~"o OG 9 8695 40 " ti'fO I98C1G 3/9 9'746 5! 6 ~I04 330 T-3 ~ .... s746 4]. " ~eed YT1AG ~/9,1/13 8810 64 5-3/4 " " T-.4 3-2 1/ ~ 1.0 88[0 42R:t " :" SCH " " 8831 71 ll 154 450 _. 11 8881 43 " " YTiAG 3/10 8988 ].07 4 " " T-2 - 12 8988 .... 44 " "'' I ' ' ' ' ' 9052 64 6--3/4 i'66 qB"' a T-3 g-2 .....12 a059 4~ " ,, ,, ,, o.. 1 t t,~ >~' '~ >-3z- /'~, " " " " , . ......... , 13 -' 91.10 46 " "' ;Ow " 9123 !3 6-1 '~ " " 'r-~ ' 1 3 . 7 ~ "... YI'!A~' " 9!75 52 4-1/2 " " T-4 ~-2 1~, si-- " ~ ,, ........... .... ~- ,-, ~. :A~ _ " .... ' .... " JD I 9' ' 5 o?. ',~ -, · ,3sO " ~...~ ' SC:'{ " q6~, ~ ~/, ,, ,, hos~ ~ ~ 2~O ~ ~-- ~ ~ , . ~ ~ ~ .~ . , ..... ~, ~ ... . ,,.. , I i _ I t : I .. I _ UNION OIL CO. 'OF CALIFO'-'NIA DRILLING RECORD SHEET A ~ PAGE NO. 2 LEASE TRADING BAY STATE FIELD LOCATION.__ WELL NO A-1 S PERMIT NO.--~t ; SERIAL NO. T.D. __ T.V.D. DEVIATION (B.H.L.) · COMPANY ENGINEER SPUD DATE CONTRACTOR. TYPE UNIT DRILL PIPE DESCRIPTION, COMP. DATE RIG NO. ELEVATIONS: WATER DEPTH Il. T. TO OCEAN FLOOR R.T. TO MLLW Il. T. TO DRILL DECK R.T. TO PRODUCTION DECK APPROVED: BIT RECORD MUD VEL. DEPTH & DEVIATION' BIT JET DEPTH VERTICAL [] DATE DEPTH NO. SIZE 1ViAI~E TYPE SIZE OUT FEET HOURS A1YI~. JET DIRECTIOi~AL [] 10/18/68 9634 .52 8-]./2.. R~ed YSIG 3/10 9669 3.5 3-3/4 ].66 489 rl'-~ B-2 18 9~69 53' ,, ttTC X55R ,' 9770 101 i3-1/~ 166 489 T-2' BL]. -- i9 9770- 5"-: " Reed YTIAG " 9795 25 4-t/2 166. 489 T-4 B-3 1/8~' OG' 19 9795 55 " " SCM " 9816 21 " " " T-2 B-1 OK for rerur 20 9816 56 " IiTC os'IG "' 9867 51 5 " " T-4 B-3 -1/4" OG 20 9867 ...57 " " XI)G " .9935 68 . 5-1/4 " " T-3 B-2 1/8" OG .21 9935 58 " " ." " 10004 69 6 " " T-4 B-3 22 10004 59 " R=_d YS!G " T-4 B-3 1/8" OG 22 ].0045 60 " " YSIAG " 10110 106 5-1/2 " " T-2 B-2 24 10190 62 " ,, YSIG " 10263 73 .6 " ,, i['_2 B-2 . 25 1.0263 .63 " " YTIAG " 10376 113 9-1/2 " " T-3 B-2 26. 10376 64 " " " " 10468 92 6-3/4 " " Lost in hole . 30 10253 65 " " STIAG ,~-3/4 10287 34 5 - T-4 B-4 Dyna. dri!led 31 102o7 66 YTL,~G 3/].0 10340 53 ..5... 166 489 T-3 B-2 2. 10428 ..68 " 'Sec, S4TG 3/12 10560 1--32 12 155 29~" T-3 B-2 5 1,.0560 69 " " " 3/9 10648 88 1.1-i/4 115 380 7 10648 ..7.0 " hTC OSIG " ilO00 352 23-1/2 104 " T-1 B-4 , ~,, , , , I;MAsE__Trading Bay State I~iCI,D Trading Bay LOCATION Conductor 18_~. 1624'N ...... & 558'W from SE corner Section'4,. T9N, R13W, SM PERMIT NO. 68-76 T.D._ · DEVDiTION (B.H.L.) COMPANY ENGINEER · · · -' · WELL RECORD PAGE b!O. 1 WELL NO A-18 W.0. SPUD DATE 11/26/70 COMP. DATE 12/1/79. . CONTRACTOR WODECO __ RIG NO.3_6__. TYPE UNIT 860 E Oilwell DRILL PiPE DESCtlIPTION. .. SERIAL NO T.V.D. ADL 18731 Rardin, Shell WEIGHT THREAD 13-3/8" 61 se'allock GRADE J-55 J-55 N~80 l! 40 40 ELFWATIONS: WA'TEI[ DEPTit ,. tL T. TO O0I']AN FLOOR ' R.T. TO ~ !LLW R.T. TO R.T. TO APPROVED: 62' 174' 112 ' CASING f~ TUBING --J' DEPTH : RE t 10~'i 900 neat "G" 100 sx w/2% i 56~3' DV @ 5598' 4191' 1200 sx CFR-2 1400 sx CFR-2 · . sx CF~-2 liher top 22.07' 40.82' S.E. Talley)' S PERFORATING RECORD __~2kTg 11/30/71 8380-8444 8492-8.516 8568-8682 8750-8820 ~916-8988 9066-9096 7550-7590 7790-785'0 7910-8'030 8060-8'130 8524-8550 8734-8750 · 8820~8832 9020r9050 '9096-9116 9146'9176 E.T.D. 9200 Bridge plug @ 9200 isola~ Hemlo'ck Zone II Il II 11 II ,l II II III 'I:I.E A ,tQ_~L..... reperf :es ' reperfd with 2 hpf II II Il I! I! II II II l,] II perforated w/ 4 hpf o. .. II II · ii ii Il ll ' :"" ·i f / II II ,, ,, SF/: c~ , , ii ii . II Il II !1 INITIAL PRODUCTION IDAT~. JlITE__RVAL N_ET OIL CUT "GR~kV, C.P.. I ' T.p. . · , , ,',', . · . WELL I-i~~_S S E M B LY ._ TYPE: .::.CASING HEAD: S'~affer i'KD" sbw to i'3-3/8;' csg x Z2" '"" ~0'0 ·series . .. "-CASING ·HANGER: Shaffer 12" nominal' 9-5'/8" ~o'd. KDKS .. 'CASING SPOOL: .' ~TUBING HEAD: · .. Cameron 1:~"3000~' x 10" .500011:DC-FB'B I I ~ j ` j I ' l I ~11J ! ' ' ' ' Cameron single 4-1/2" donut : tdp '421/2" 8rd,. b'tm '4-i/2'" buttress-, '. ·-TUBING HANGER: TU~SMEAD TOP: MASTER VALVES:~ Cameron solid b. iock.-W/mast~r:and.'~wab.valVe . ' ~ I: :Iii I~ I - I '' I ' ' J Cameron -- '--' -. . . CHRISTMAS 'FREE TOP CONN.:~ 4-1/2"· EUE 8rd ': ---~ o . UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO LEASE.i Trading Bay State V~ELL NO..-A-18WO_FI~LDI. Trading Bay : DATE E.T.D. 11/26/70 27 28 29 & 30 12/l/70 9270' 9270' 9200' 9200' 9200' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved rig to A-18, Conductor #18. RU wireline. Shftd sleeves in long string. (Moved to Afl8 @.__12:_0_.0 .Noon _!.1/26/70.) Opened "CX" @.8272' above top dual pkr & "XO" @ 9101' above bottom single pkr in long string. Killed well w/ 70#/ft3 invermul. Instld BPV. Removed tree. Instld & tstd BOE. RU & began pulling and' laying down short string of tbg. Pulled & 1,d. short & long string of tbg. RU Dresser-Atlas. Ran wire- line junk basket & gauge ring to 9230'. Ran Baker BP On wireline & set @ 9200'. RD Dresser-Atlas. Ran Baker retrievable BP to 2000'. Did not set on first run. Ran second time. Set @ 2000' & tstd. Pulled riser & BOE. Removed 3000# tbg head. Instld 12" 3000# x 10" 5000# tbg head. Installed & tstd Cameron 12" 3000# x 10" 5000# tbg head. Reinstld & tstd BOE. RIH. Retrieved Baker retrievable BP. RU Dresser-Atlas. Perforated as follows: 4 holes.per foot 7550-7590 7790-7850 7910-8030 8060-8130 8444-8492 8524-8550 8734-8750 8820-8832 9020-9050 9096-9116 9146-9176 472' - four holes per foot, 1888 holes 374' - two holes per foot, 748 holes 2 holes per foot 8380-8444 8492-8516 8568-8682 8750-8820 8916-8988. 9066-9096 All perfs w/4" carriers. 29 runs - 18 hrs. Ran junk pusher with 8-1/2" gauge ring to liner top @ 7489'. Found hydril BOP would not open to allow passage of donut. RIH w/open end tbg to 7383'. Conditioned mud. POH. Changed hydril. Tested hydril for mechanical operation OK. Ran 4-1/2" tbg w/accessories as follows: 4-1/2" tbg run w/gas lift valves installed in mandrels. Dropped 2" packer setting ball thru gas lift valves. (See Otis tbg detail attached.) Landed tbg on Cameron DCF BB 10" Nom. donut. Tested to 3700# after installing Cameron single 4-1/2" xmas tree. RU to displace Invermul w/diesel displaced at 3 bbls per minute rate. Set Otis 4-1/2" single production pkr @ 7431'. Tested to 1400# OK. Moved rig to well A-21. · RIG RELEASED @ 12:00 MidniKht 12/.1/70. Well producing from Middle Kenai "E" &"D" zone. :?~. - ; .. . ~:'" J' !'" : ; ; t. i' ;'"i~ [...,..F-i.~ -: .. -i'! ,'.;::'~' '"' ! ! i' ' :~;'."L :_.i... [..i_. i: ~.":'.../! , t ! ~ 'I; "' .... I i ': ;:.' ' 'i 'i" t ~ ::: :", ~'"i '~ , j~' ~ / ', ........... SIZE; WEIGHT ,'GRADE THREAD DEPTH , I'll _ o 0 6AS LIFT EqUI~MENT 0 PACKERS AND ACCESSOR'ES TUBINGh,,I r ~ I I FHREADI '. DESCRIPTION OF EQUIPMENT AND SERVICES ESTIMATE ..... II ..... l I ' - , -- __ ~ II ' ' - ' . ~ ~; -/,L: ~,,,~' .,~:,.,.:4-~/ %/,' . .~- . , .- -- '- , - , ' ~' · "~" .F ,~ k :~ ' ._. I I "7 . ::/ .,. 4,2¢.. ~"¢,.~,~'" /b .... /,z~ /'/ · '"/~:~ _! I ... ~ ~ ,~ ...... I I ~ / / :.' ': ,' .W,.: ."/ - i ... '~ . 4- /,-- ,?/,~ .~.". ,,-~':' t V,:, /4- ,:, ,~ II - .... ' .... ' ' " /' / '~ I I '" ' ' '-il I - ¢ '/',/z;' ,-,..~ ..~ ...... ~ ¢ .. , ~.,':,.' "; 7 ', " ' /'" ~ II " ~ ,.~ ~ ~ '-tX:: ,"x w,, .,l. / ~../-./,? :~.; x..,~~ . ' -~ . ,. , .~ . :~ Z&': .', '..', ' ~ "- '" /.': ~., Z~ · *'? II '" ' " Ii ! I ,/.~',. Z;. ;,~ '"' / ,., ,~ ,~' c7 /? ~ ¢n~~ --' ~ ~ ~ t.-- ~/~-." '~/" /,: ..x.,.,,.? ,~4....,?/~ I ,.~-;..~' '-~.~'/',~ ',: ~: I I . , , · " , .',- ' , , ' · "~ ~. t.- /.':Z-"'""-/ i..' .<",-,'/t ~/ ! " "i-;¢ i I ' ." "" ' ' /' 1~ 7.~¢,'-: ' i.i., .. ,~ I ,",4.' 4'I ..... '~ . 7~. · ~ I /" _.. _. . II , . I ~ . I!1 TOTAL ESTIMATE. I II co..~,o. I II III. III - ;'1 !l. ~ I ii ... '~ 111. ' · I I1:' ~ ' ' I.~' . I~ . ' ~. ':':- :1:_. · ~'.' .. ~ ,.. ~ · ,. ~.,-.. · . FICI.D__ .LOCATION Conductor 18: 1624'N & 558'W from '~'- "'~' .'.-~ · WELL RECORD . PAGE Trading Bay State WELL No._A..-18 W_O. SPUD DATE 11/26/70 COMP. DATE 12/1170.. Trading Bay CONTF[ACTOR, WODECO ~ RIG NO.~_.__ SE corner Secgion'4, T9N, R13W, SM ]PE.RMIT NO. 68-76 TYP]3 UNIT 860 E Oilwell DRILL P1PE DESCRIPTION SERIAL NO. ADL 18731 T.D._ T.V.D. Rardin, Shell DEVI;1TION' (B.H.L.) COMPANY ENGINEER ELEVATIONS: ~,~,C-TI'EI[ DEPTH 62' ,. I:L T. TO O~EAN FLOOR 174 ' lt.T. TO MLL~V 112 ' R T TO DR~.,L DECK 22~.0~' ' D ~ , '~/ 40.82 ro ...... ~PROVEO: ~: Talley CASING ~z TUBING J slZk VZEIGHT THnEJD. ~MADE t DE~--]-- ' ~ , . . _ -13-3/8" 61 seallock J-55 -~' 900 neat "G" 100 sx W/2% C12-sorface .9-.5/8" 4~ 'i, J-55 5643' DV @ 5598'-' " 40 " N-80 4191' 1~00 sx CFR-2 · 43.5 " " 7520~ 1400 sx CFR,2 ' · . 7" '. 29 " ' " 9826' 450 sx CFR-2 liner t~p @'7~'89' . '4-1/2'~ ·12.60 buttress N-80' 7446, Otis 4-1/2" x '9-5/8'" RH pkr @ 7431' " .. PERFORATING RECORD '' ' ]- P~ESENT CONDITI'q:{ _~A3LE I~TERVAL E.T.D.. ~5~TQ1L_~ '~eperfd with 2 hpf 11/30/7~) 8380-8444 9200 reperf . ,.. 849228516 . ' ,, ,, .. .- - 8568-8682 Bridge plug " " ~.. · ' 8750-8820 ''@'9200 isolal:es' " " .'' '" ~916-8988 Hemlonk Zone " ~" .~ "'. ' . . 906629096 " m . ,, ..... . · 75~0-7590 " .p~rforated' w/ 4 ~pf _ '- . '· Y790-785'0 · " "-. ' "' "'' . " -- , · , ' : 7910-8030 " ' ..... 8060'-~130 .... ..- ' "" ' ' ' ~ 8444-8492 " " '" " . 8524-8550 " " " '8734-8750 " ' :' " " ~' 8820-8832 " '~ " ' ..... '~ '" ' "' ' 9020~9050 " ' ~'""'" " · 9096_9116 " .. .. . t ...:" " ' 9146-9176 · ~" '' "' '~ ~ ' " " ' ' ' ' '' - INITIAL PRODUCTIO!-~ -- DATE IIt~E._~¥~L N_ET OIL 'CUT , · ,, · · · · 7 CASING HEAD: -, "CASING 'HANGER: WELL I~~_S S E MB $.,Y · TYPE:· o S'~affer "KD" sbw to i'3-3/8;' csg x 12" ~)(50 'series .... o Shaffer 12" nominal' 9-5'/8" ~no'd. KDKs '' ' . 'CASING SPOOL: ---~TUBING HEAD: . . : Cameron 1~-" 3000~- x 10" .5000fl 'DC-FBB ' - ' ' ;" Cameron single 4-1/2" donut : top '421/2" 8rd;' b'tm-4-1/2"'buttress_-. 'TUBING HANGER: TOP' Cameron solid hiock w/master -and.--~wab. valve . ,r . MASTER VALVES: Camer°n CHRISTMAS 'FIIEE TOP CONN.:.. 4-1/2" EUE 8rd ': . · · : ., .-., . ,- ."'-'. .. , -..". , :,- .-.- ~... ... -. - .'.-~ .,.~ , ..,. · ,'. ~' : _.'?' . .( -:..', .. :. ... · .., ,~ . .- f ~ . , . ,~ ,'... .... "",'~', '~,'. ' ~ '" ~ ' ': '~' · '.' - .- . '':.."-.~' ~... C--.L · "...' -"-_'-f..'~',- ~.~ ~"."- ' :',.f..~,"~-z,'J:: f-'t :~.-'?; ;',-. . -' '.'~ '. UNION OIL CO. Of CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Tradi..n~ Bay State ~VELL NO. A_-18WO FI~.LD Trading Bay DATE E.T.D. 11/26/7o 27 29 & 30 ~ 12/1/7o 9270' 9270' 9200' 9200' 9200' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved rig to A-18, Conductor #18. RU wireline. Shftd sleeves in long string. (M. oved to A-18 @ 12:00 .N..oon 11/.26/70.) Opened "CX" @ 8272' above top dual pkr & "XO" @ 9101' above bottom single pkr in long string. Killed well w/ 70#/ft3 invermul. Instld BPV. Removed tree. Instld & tstd BOE. RU & began pulling and laying down short string of tbg. Pulled & 1,d. short & long string of tbg. RU Dresser-Atlas. Ran wire- line junk basket & gauge ring to 9230'. Ran Baker BP On wireline & set @ 9200'. RD Dresser-Atlas. Ran Baker retrievable BP to 2000'. Did not set on first run. Ran second time. Set @ 2000' & tstd. pulled riser & BOE. Removed 3000# tbg head. Instld 12" 3000# x 10" 5000# tbg head. Installed & tstd Cameron 12" 3000# x 10" 5000# tbg head. Reinstld & tstd BOE. RIH. Retrieved Baker retrievable BP. RU Dresser-Atlas. Perforated as follows: 4 holes per foot 7550-7590 7790-7850 7910-8030 8060-8130 8444-8492 8524-8550 8734-875O 8820-8832 9020-9050 9096-9116 9146-9176 .- ,. 472' - four holes per foot, 1888 holes 374' - two holes per foot, 748 holes 2 holes per foot 8380-8444 8492-8516 8568-8682 8750-8820 8916-8988 9066-9096 All perfs w/4" carriers. 29 runs - 18 hrs. Ran junk pusher with 8-1/2" gauge ring to liner top @ 7489'. Found hydril BOP would not open to allow passage of donut. RIH w/open end :bg to 7383'. Conditioned mud. POH. Changed'hydril. Tested hydril for mechanical operation OK. Ran 4-1/2" tbg w/accessories , as follows: 4-1/2" tbg run w/gas lift valves installed in mandrels. Dropped 2" packer setting ball thru gas lift valves. (See Otis tbg detail attached.) Landed tbg on Cameron DCF BB 10" Nom. donut. Tested to 3700# after installing Cameron single 4-1/2" xmas tree. RU to displace Invermul w/diesel displaced at 3 bbls per minute rate. Set Otis 4-1/2" single production pkr @ 7431'. Tested to 1400# OK. Moved rig to well A-21. · RIG RELEASED @ 12:00 Midnight. 12/1/~0. Well producing from Middle Kenai "E" &"D" zone. ~IZE WEIGHT GRADE THREAD - TOTAL ESTIMATE ~OMPLE~ION PROCEDURE O'R;ION OIL CO. OF CALIFORNIA''/~''~- DRILLING RECORD PAGE NO L E A S E TRADING BAY STATE W E L L N O A-18 F I E L D TRADING BAY STATE DATE 1988 12-28-88 12-29-88 12-30-88 12-31-88 01-01-89 01-02-89 0594N E.T.D. Feet )826'TD )826'TD )826 'TD )826'TD )826 'TD )826 'TD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skid rig from A-21 to A-18. Rigged up wireline and pulled ball valve at 320'. Tagged fill at 7826'. Rigged up coil tubing and surface equipment. Tested surface equipment. Test BOPE and ran in hole to 7000'. Established circulation and began injecting N2. Production having high tank level problems. Pulled to 7395' and stopped circulating. Production repaired problem. Ran in hole and tagged fill at 7866'. Cleaned out to 7873' but unable to work deeper. Circulated and pulled out of hole to pick up Dyna Drill. Ran in hole with Dyna Drill and mill. Began circulating at 7000' and cleaned out fill from 7873'-7890'. Short tripped and continued to clean out to 8190'. After cleaning out bridge to 8190' ran in the hole to 9184' without cleaning out additional fill. Pulled out of hole and laid down the mill and Dyna Drill. Picked up a jet washing tool and washed to 9100'. Pulled out of hole and rigged down coil tubing. Rigged up wireline and began perforating. Perforated the "D" zone with 2-1/8" through tubing guns at 4 SPF as follows: 7734'-7860' (120') 7600'-7620' (20') Continued to perforate "D" zone as follows: RECEIVED 7544'-7600' (56') 7485'-7533' (48') ~as~ 0il & Gas Cons. Commissio~ ~.%~ ~chorage Ran ball valve. Released rig at 2400 hours on 1/2/89. Notes: Run #1 (7840'-7860') gun stuck. Flowed well for 1-1/2 hours and freed. Run #12 gun fired out of cable head. Lost gun in the hole. * Fish is 2-1/8" OD gun (22.6'), 1-11/16" OD CCL (2'), 2" OD magnetic centralizer (2'), 1-11/16" OD sinker bar (5'), 1-3/8" OD cable head (.6'). Overall length 32'. Run #13 set down at 7595' without tagging lost gun. Gun misfired. 2/80 ATTACHMENT TO TRADING BAY STATE A-18 WELL COMPLETION OR RECOMPLETION REPORT ~%5/8" casing 0- Cementing Detail Howco "DV" Multiple Stage Cementing Collar @ 5598 1st Stage ~mmented w/1200 Sx Class "G" w/l% CFR-2 2nd Stage cemented w/1400 sx Class "G" w/l% CFR-2 ATTACHMENT TO TRADING BAY STATE A-18 WELL COMPLETION OR RECOMPLETION REPORT 9-5/8" casing -- Cementing Detail Howco "DV" Multiple Stage Cementing Collar @ 5598 lst Stage cemented w/1200 sx Class "G" w/l% CFR-2 2nd Stage cemented w/1400 sx Class "G" w/l% CFR-2 iV / ~E ,, TRADING BAY STATE UNIO I OIL CCr PN Y CALIFO II^ £LL RECORD · , ~'~LL ~), TBS A-18 FIELD TRADING BAY FIELD ;)ATE 1 2/23/77 2 2/24/77 2/25/77 4 2/26/77 5 2/27/77 6 2/'28/77 7 4/27/77 11,000' TD 9200'ETD bridge plug 9 5/8" csg. 7520' 7" csg. @ 7488' -9826' Otis RH i Pkr @7431" ll,O00'TD 9200'ETD 9 5/8" cs§. @7520' .: 7" liner 74~ 9826' ll,O00'TD! 9200'ETD BP 9 5/8" cs§. 7520' : 7" liner ~ 7488'-9826' Otis Mod: WD permad~i pkr@7440'i Same headinc · Same heading Same heading II II DETAILS OF OPERATIONS, DESCRIPTIOtlS & RESULTS .Commenced WO operations on TBS A-18 at 12-O1 a.m. 2/23/77. Displaced tubing and annulus above pkr. losing fluid to formation. Treated mud w/ CaCO3 to stop fluid loss. Installed BOE. _ Killed well above pkr. @7431'. Tried to pull pkr. free. RU GO Int. tbg. cutter. Cut @ 3958'. Pooh 81 jts. tbg. Well bubbled gas. XO to 5" DP. RIH & ci·rc. Pooh w/ remaining fish above cut; Layed dwn. fish.- Made up Tri State O.S. Ran 4 1/2" O.S. to top of fish @3958' Jarred fish and pkr. @7431 free. Pooh w/ fish. Found 4 1)2" G.L. valve in pkr. from @ mandrel @7393' in pkr. bore.. RIH w/ 6" bit & 7" csg; scraper to fill @ 8818'. Washed to 8843'. Pooh. RIH w/ O.S. to top of 3 1/8" OD perf gun @ 8894'. Pooh. Recovered perf gun left in hole from previous work. RIH w/ 6" bit. C.O. fill from 8894'-9200'. Pooh. RIH w/ 6" bit & 7" scraper.to 9200'. Pooh. RIH w/ 9 5/8" scraper to top of liner @7489'. Pooh. RU GO Int. RIH w/ W.L. gage & junk basket. Pooh. RIH w/ Otis Type WD Permadrill pkr. on W.L. set @7440'. RD Go Int. RU & run .single 3 1/2" tubing string w/ accessories. Install BPV & nipple dwn. Nippled up X-mas tree. Tested to 5000 psi - o.k. Displaced Dril-S WO fluid above pkr. @7440' w/ filtered salt water. Installed ball valve @302'. Turned A-18 over to production 12:00 p.m. 2/28/77.. Commenced W.O. operations on .TBS A-18 at'12:01 a.m. 4/27/77. RU Dowell. Thru tbg. acidized the "D" & "E" Zone w/ 21,000 gal. of 12-3 mud acid in 7 stages using a total of 8000# of Unibeads for diversion. Initial pumping pressure, 0 psi. Final displacement pressure 2300 psi. Released rig to TBS A-16 at 12:00 noon 4/27/77. UNIO['I OIL CCFNDANy OF CALIFOFa',IIA I' ELL lILCOlg TRADING BAY STATE I'ZLL 1,10, ._. (wo).. FlED TRADING BAY FIELD ~TE *M *K *J *I *H *E *D *C *B *A ETD JTS. 16 2O 23 29 37 43 62 DETAILS OF OPERATIONS, DESCRIPTIOIiS &.RESULTS TRADING BAY STATE A-18 (WO) TUBING DETAIL DESCRIPTION LENGTH Mule Shoe 5" X 3.50 ID X-over Sub 4 1/2" OD X 3,00 ID Landing nipple 3 1/2" .X 2,6~-5 3 1/2" Butt, Pup it, X-over Sub 3 3/4" X 3" Seal assy, 5" X 3 1/2" 9 5/8" X 3 1/2" Otis WD Perm. Pkr, Locator Sub 5 5/8" X 3,50 X-over Sub 4 5/16" X 3" 3 1/2" Bu{t, Tbg, "XA" sliding sleeve Otis 2,750 ID 4 5/16 OD 3 !/2" Butt, Tbg, Camco 3 1/2" "MMG" GL Mand, 3 1/2" Butt. Tbg. Camco 3 1/2" "MMG" GL Mand, 2,875 ID 3 1/2" Butt, Tbg. Camco 3 1/2" "MMG" GL Mand. 2. 875 ID 3 1/2" Butt, Tbg, Camco 3 1/2" "MMG" GL Mand, 2,875 ID 3 1/2" Butt, Tbg, Camco 3 1/2" "MMG" GL Mand, 2. 875 ID 3 1/2" Butt, Tbg, Camco 3 1/2" "MMG" GL Mand, 2. 875 ID 3 1/2" Butt, Tbg, Camco 3 1/2" "MMG" GL Mand 2,875 ID 3 1/2" Butt, Tbg, Ball Valve "DK" Otis 3 1/2" 2,75 ID -1,5" w/ BV in place, 3 1/2" Butt, Tbg, · Pup Jts, (3 ea.) K-Over Sub 3 1/2"' 8rd X 3 1/2" Butt, ,62 .90 .81 8.89 ,70 20.00 4.00 ,80 ,76 29,74 3.35 29.69 10.05 486.13 10.09 608.17 10.03 702,54 9,84 882.19 9,79 1122,30 9.75 1305,76 8.67 1892,91 2.50 243,43 21.09 ,42 1/2" Tbg, Hgt, 1.00 .T 37,00 BOTTOM 7473.92 7473.30 7472.40 7471.59 7462.70 7462,00 7442,00 7438.00 7437,20 7436.44 7406,70 7403.35 7373,66 7363.61 6877,48 6867.39 6259,22 6249,19 5546,65 5536.81 4654,62 4644,83 3522,53 3512,78 2207,02 2198:35 305,44 302.94 59.51 38.42 38.00 37,00 *A thru M - Detail for Well Schematic on page #5, TOP 7473,30 747-2,40 7471.59 7462,70 7462.00 7442.00 7438.00 7437,20 7436,44 '7406.70 7403.35 7373.66 7363,61 6877,48 6867,39 6259.22 6249,19 5546,65 5536.81 4654.62 4644.83 3522,53 3512,78 2207.02 2198.35 305,44 302,94 59.51 38,42 38. O0 37,00 -0-- .. UNION . OIL CO. OF CALIFORNIA i LEASE T.RADING BAY STAT~. _WELL NO. A-18 CONTRACTOR_ parker Drlg. Co. FIELD Trading R~y Field TYPE UNIT Oi!wcll 850 BEGAN: 2/23/77 COMPLETED: 2/28/77 ELEVATIONS: GROUND PERMIT NO. 68-76 SERIAL NO. ADL-18731 CASING HEAD ~OMPANY EN~G~NEER/o .'~ C~iswel]/Watson . AFE #371007 TUBING HEAD &PPROVED i_~,.~'~.~(~/~-~]'~!st. D_~']~mr., Supt. ) ROTARY DRIVE BUSHING MLLW 112' ,,m ~. ~ai~en~er CASING & TUBING RECORD 'SIZE D~H WEIGHT GRADE ~ REMARK~ 13 3/8" 1044' 61# J-55' 900 sx Neat "G", 100 sx. w/ .2% CaC12-returns to. Surface. 9 5/8" 7520' 40# & 43.5~ J55,*N80 2600 sx. CFR-2 w/ DV tool @ 5598'. 7" 9826' 29# N-80* 450 sx. CFR-2. Liner top @ 7489,. " 3 1/2" 7452' 9 5~ N-80 Otis 3 1/2" X 9 5/8"-WD perm. pkr. 0 7440' Buttress ' .. - · ~eal-ioc. .... ~ .... PERFORATING RECORD ~T~ ~ ~SnV~ I ' E'T'D' REASON I ' ' PRESENT CONDITION 11/30/ '0i 83~0-8444 9200' Productim~ 2 hpf Openfor production. 8492-8516 " ". " " " " 8568-8682 " " " " '" · " 8750-8820 " " " " " " ~?' 8916-8988 " " " " " " !, '- :- ,! I1 '!1 ' ' ' 7550-7590 9066-9096 '"' '"' 4 7910-8030 ,, ,, ,, 8060'-8130 ,, . ,, .. ,, ,, · ' 8524-8550 ,, ,, ,, DATE I INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF (IOR REMARKS 3/2/77 " 126 65.2 27.0 837 93 '" .--:' 447 i." 5983 :..-;--~L:.::.,:.!-._.:.:!:)'-::i-.:_;.'.. ,, WELL HISTORY PRIOR TO REPAIR ~OMPLETION DATE: 12/1/70 PRODUCING INTERVAL:, D & E Zones INITIAL PRODUCTION: LAST REGULAR PROD. & DATE: 31~/104 BPD; . . . . CUMULATIVE PRODUCTION: REASON FOR REPAIR: l~r~rlt ~ Reduce tbg. size to optimize gas lift & remove stuck gas lift valve. _ · ~ '-.: ,._ ._· .--... . Form D-IOO1-B UNION OIL CO. OF CALIfORNiA REPAIR RECORD SHEET B PAGE NO LEASE TRADING BAY STATE COMPLETION DATE: 2/28/77 DATE E.T.D. DATE INTERVAL 11/30/7~ 8820-8832 9020-9050 9096-9116 9146-9176 TYPE: WELL NO.. A-18 FIELD TRADING BAY FIETI) APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS ETD REASON PERFORATING RECORD Continued 'PRESENT CONDITION 9200 Production II II Il Il Il Il 4 hpf Open for production Il Il II II Il Il Il Il Il Il Il Il Cameron - Shaffor NFELL YIRAD ASSEMBLY CASING HEAD: Shaffer "KD" Sow to 13 3/8" csg. X 12" sow series, CASING HANGER:. Shaff~r 12" CASING SPOOL: TUBING HEAD: Cameron 12" 3NNN~ ~6 1N" qN00# DCB. TUBING HANGER: Cameron single 3 1/2" (]onut Top 3 ]/2" 8r8; btm. 3 1/2" Butt. TUBING HEAD TOP' Cameron solid block w/ mater & swab valve., MASTER VALVES: Cameron 3" 5000# lsingle swabe, single master, sinqle wing CHRISTMAS TREE TOP CONN.: 3 1/2" EUE 8rd. ~X,,~_ Tubin~ Han.~er. @ 37'. PAGE NO. 5 See Page #4 (Tbg. Detaii for detail of Schematic. 13 3/8" Csg. @ 1044'. J K L . f Oi{M 247 (Ni-'W 5,1,~t~I, Start 2/23/77 Top of 7" liner @ 7489' ~ 9 5/8" Csg. @7520' TRADING BAY STATE A-18 WELL SCHEMATIC Baker bridge plug @ 9200'. - Btm. of 7" liner @ 9826'. D ILA'W'H CKD. __ SC, ALE DA'rE Completed 2/28/77 uNIoN 0~-I~ ~o~PANY O,~ c;^£1FO-RN'IA 1 MUD RECORD PAGE NO TRADZI,iG BAY STATE A-18 up ~. T~-~ LEASE - WELL NO FIELD TYPE_ DISTRIBUTOR Baroi'.8 " . "= - Zsg sth @ 1069' Inle~ Water to s,n,~a~e De 8729/5. ']~81'2 75 35 8,0 10,0 28900 Tr 31 " - 10 1 2~23__. 7~ '39'" ...... ~0-,0... 9,~ 25600 8 " 14 2 2'284 73-1/2 '45 5,0 9.0 24750 8 " 12 _ 3 29~7 ' -75 40 3,8 9,0 22275 7 1/8 ",, . Dynadrilled 4 . 3309 75 44 4. ~-- '9,0' 21450 7 Tr,I ~1 ,i ' I 5 3785 7,5 42 ....... 4.8 -~,0 2145'0 ' 7 " , 7 4695 76 46 5,0 9,0 21450 6 Tr " 8 5060 7(~ 47 4,9 9.O 23100 7 ,, 15 9 5543 76 45 ~ 5,0 '-'9:0·26400 7 Tr 15 _ 10 5739 77 46 .. 4,8 8.8 28050 7 1/·8 16 .. 11 6105 77 46 4,8 8,8 28050 7 " " 12 .... 62..~O . 78 42 5,0 g,.0 31350 4.. 1/2 18 13 6600_ .78 ._ 50 5.0 9,5 29700 6 " " 14 6775 75 42 5,0 9,.0 28050 · 6 ., .... 16 . 15 6o09] .... 74-5 40 _.,5,0 9,71 28000 6 " 15 16 6985 .74 .... 41... 5,~0 9.0 29000 8 " 16 17 7042 73 ...40_ 5,0 9,0i 28000 8 1/4 " ,.. .1.8 71!], __ 73 ..Z~0..... 5,0 9 0 28000 6 " " .t9 72i_.5 72 /,,0 5,0 9,0 29800 6 Tr 16 20 .... 7332 71. 41 5,0 9,0 35000 8 " " Added.30 bbls diesel. 21 7620 74 40 5 ,.O 9~ 3 26000 8 1/4. " · .,, 22 78.59 74,5. . .42 _. 5,0 9,~ 33000 8 " " .... '" .o ~.? ~, ~ ~, ~ . __F~ . 7874 ~t,~5 42 5,0 9,.2_ 33000 8 " " t~z,,,h~d Cot DL' 24 i .. 782_4_ .. 76 46 4,8 9,0 32500 8 Tr " " 25 .. 7370 75 41 6 8 i2 0 32500 7 Tr ],5 Pol.~sn d off cement plug 26 7380 75 39 6,2 1.1.5 31350 7 " 27 7380 76.. /:6 .... 6.0. 10,0 _3.065.0 6 3/4 16 Backed off in Kev'Seat @ _,888 .28 ., -7430 76 47 6.] 9,5 30650. 5 i " ~ . · . . 29 .7521. 76. 46 5,8 9,~5 33000 7 ],/2 15 Lo~ed' 30 752,1, 76 . 46 5,8 9,5 33000 7 1/2 .... :'" " : ,..0/l/68 7521 77 5_2, 6,0 9,5 30500 6,0 3/4 16 Ran 9-5/8" csg 2. 760_0 74 40 6,8 11.~0 30500 5,0 Tr 14 --i ~ . '79..].0 75 A2 5..8 ]_0.,0 36302 7 " " 4 82.95 76 39 4,6 !0,0 33000 i6. " 1.3 .- 5 8480 75 40 4,4 1=000 _,33000 8 " 11 6 .... 851! 77 43 4,0 10 31500 8 Tr 12 · . 7 $(~5 7.6 46 4,3 10,1 33000 8 " 11 , 8 8695 77,5 50 4,.5 9,8 33000 8 1/4 13 i 9' I 8746 77 49 4,3 1.__0~0 33000 7 1./2 " ..' !0' 886A . 7_6__ 41 4,8 9,7 33000 7. " " _ 11 8920 ZJ 40 4,2 9,8 29?00 8, 3/4 ,12 ] 2 90_35__ ____74 ' 41 4 ,. 6 9.3 332,25 8 3/4 13 ... , ]3 9].10 74,5._ 42 4,5 9,4 33000 8 3/4 13 , 14 9175 ...75 Z~l 4,5 9.4 33000 7 3/4 1.3' .If, 0338 75 .41 /,,Iq 9~6 33000 7 " 12 ]6 053.0 75. 4? 4,6 9.8 33000 8 - " ].7 q6g? 76 46 4.8 9.4 33000 6' - 13 . ... I ] 8 ,,9766 75 1~6 4.6 9,6 330~0 8 Tr 11 · 19 ¢~295 75 42 /+..6 9.A 33000 6 " 20 9iL62._ 77 4~ 4.6 q.A 33000 6 Tr 13 ----2! ' 10006 76 6~ 4;7 9,8 3~525_. 8 " ' '" . . . .. 22 !0~L3 76 ..47 4, 5_ q.6 321.75 7 " . 2[~ ___76 A6 Z,,~_ q:& ~2175 7 3/4 13 .. 2'[: .... 7_~5 45 z~,.v 9:5 33000 8 3/4 . 2~ 76 /,.2 4,7 9.!,~ 33nOn 7 3/4 .1_2 26 IDA.E~_ 76 _ 48 t: ~ S q; 3 ~ ~Rd_350 7 " " F~ ,~bed .... · . .27 ~.46~L_ 76 .50--- !,~5 l_?, S 330-00 7 1 12 " .. ' 28 10].80+ 76 46 4.8 10,2 31350 5 -Tr " Plugged Back w/cmt 29 1.0253 76 60 ' _ 4,6 '11 30500 5 1/2 - .. 30 10253 Logged 31... 1.030(~ 76 60' 4.6 3.! 30500 5 1/2. 12 _ 11/1./6~ ~n4~'~ " " . . .~ ~,' ,'.,., 76 48 3,6 10 29700 8 .._ 2 10.569 76 68 3.6 10 29700 8 " " 3 __% 6____0__~__7 4__ 43 3.7 9,8 33000 7 " ". '~g4 J..O56p_J Si:ut 1)own f..:~- Ri..; .ile_pa~'- · ~ 10571 J 74 4~ 3-~2 9,5 313501 8' 3/4 12 UNI( ~,1 OIL CO, OF CALIFC~NIA SHEET B ~,~. MUD RECORD PAGE NO LEASE T~AD.~,':,~ ~,A~ STATE TYPE __ WELL NO. A-18 FIELD___ TRADING DISTRIBUTOR Baroid DEPTH WEIGHT ,_ W. ~.. PH SALT OIL SAND SOLIDS REMARKS · 6, ,11004 76 :75 4,0 9.5 30175 6 Tr 12 Reamed, Circ bottoms · 9 .1.1. ~.~'[4 76 .60 C, 0 9 4 ":.. ~' . 5 . . . ., ,, . ,__ ..... ,-- , . .... __ - -- . , , .. .... I I , -.. , .... -,. ........ ~ · . NEASURED DEPTH 4-92 613 675 736 799 ~052 1100 1156 1249 1400 1558 1727 19i2 2124 2551 2523 2579 265O 271i 2903 2967 3006 3069 3219 3247 32 ~9 ANGLE WELL UNIO:iN OIL COMPANY A-i8 V I A T I 0 N DIRECTION TVD COMP pREPARED SUB SEA 0 45' 2 O' 5 15' 8 9 45' 12 O' !6 O' 20 30' 25 2'! 45 31 30 32 O' 32 O' 33 30~ 32 O' 32 15' 31 15' 29 O' 28 15' 29 O' 29 O' 23 15' 28 O' 29 32 O' 31 O' 28 45' 29 O' 31 O' 32 45' 33 O' 65E 491 N'65E 551 50E 612 405 674 N 30~ N 24E N 24E N 24E N 21E. N 24E N 25E N 27E N 27E N 28E N 28E N 33E N 35E. N 35E N 39E N 37E N 30E N 2bE N 27E N 25E N 24E N 19E N 25E N 25E N 25E N 23E N 17E 734 795 861 948 t031 1073 1121 '1200 ].333 1460 1603 1760 1941 2140 2291 2340 2402 2458 2523 2593 2625 268O 2714 2770 2898 2922 2948 .95 390.95 .92 450.92 .66 511.66 .06 573.06 .18 633.18 .80 694.80 .17 760.17 .28 847.28 .49 930.49 .96 972.96 .71 i020.7'1 .58 1099.58 .72 i232.72 .48 1359.48 .80 .. 1502.80 .26 1659.26 .50 1840.50 .04 2039.04 .55 2190.55 .53 2239.53 .63 2301.63 .67 2357.67 .13..- 2422.13 ,63 2492.63 .85 2524.85 .71 2579.71 .90 2613.90 ,00 2669.00 .58, 2797.58 .' · 13 2821.13 .96 2847.96 L E T I 0 N R E P O R T FOR ALACAL BY SCS NOVEMBE TOTAL COORDINATES C L LATITUDE DEPARTURE DiSTA 2.72N 5.83E 6. 3.60N 7.73E 8. 7.19N 12.015 14. 13.80N 17.55E 22. 22.75N 22.72E 32. 34.71N 28.04'~ 44. 51.83N 35.'67E . 62. 81.59N 48'. 92E 95. 118.23N 62.985 133. !38.64N 72o07E 156. 165. i6N 84.445 18'5. 209.07N 106.81E 234. 283.20N 144.58E 317, 357.28N 183.97E 401. 436.35N 226,,01E 491. 519.14N 279.78E 589. 609.2oN 342.86E 699. 699.38N 405.98E 808 · 762.65N 457.215 889. 784.33N 473.555 916. 814.14N 490.765 950. 835.97N 500.94E 974. 866.50N 516o50E 1008. 902.65N 533.36E 1048. 921.05N 541.55~ 1068 . 952.21N 552.285 1100. 969.2tN 560.2tE 1119. 996.90N 573.11E 1149. 1066.91N 605.76E 1226. 1080.86N 611.68E 1241. 1097.52N 616.78E 1258. PAGE R 29,1968 TANGENTIAL O S U R E S DOG LEG NCE ANGLE ..... SEVERITY 44 N 65,00E. O. 53 N 65.00E 2. O0 N 59.07E .... 5, 33 N 51.82E 4. 15 N 44.96E 3. 63 N 38.93E 3. 92 N 34.53E 5. 13 N 30,945 4. 96 N 28.04E 5. 26 N 27.46E 5. 49 N 27.07E 6. '78 N 27.06E 1. 97 N 27~04E Oo 86 N 27.24E 1. 41N 27.38E O. 73 N 28.325 1. 08 N 29..36E O. 68 N 30.13E O. 20 N 30.945 t. 21N 31.12E 2. 62 N 31.085 4. 57 N 30.935 10. 76 N 30.79E 6. 45 N 30.575 2. 46 N 30o45~ 6. 78 N 30.t!5 4. 47 N 30.02E 9. 90 N 29o89E O. 89 N 29.58E !. 94 N 29.50E 7. 96 N 29.$.3E 10. 000 083 505 793 814 993 882 838 314 906 754 252 000 049 887 443 684 .... 991 196 172 777 085 612 199 71~ 369 586 396 333 299 2O4 METHOD SECTI DISTA 4.0 5.3 9.8 17.5 - 27.4 40.3 58.7 90.7 129.7 i51.6 1.80.3 228.3 309.2 390.4 477.2 570.3 672.7 775.1 848.6' 873.5 906.6! 930o2, 963.5~ 1002..6: 1022.4, 1055.2~ 1073.6, 1103.51 1179.3( 1194.2! 1211.6! MEASUKED D E V DEPTH ANGLE ~3L9 33 0~ 33 52 ~3 30' 3437 33 30 ' Z688 32 0~ . 37 Z 5 0 ' ~5~2 2~ 30' ~7~0 23 ~0' ~980 23 ~5 ' 5295 23 O' 55~3 20 O' 5~'~ 17 45' 598L YY O' 6165 i6 O' 6228 i5 45' 6~40 ~9 O' 6673 i9 0 ' 6708 19 O' 6923 19 15' ~042 i9 O' ' .2 15 i5' 7604 I~ O' 77 "~ 4 13 0 ' PLUGGED BACK TO 7374 15 O' 7404 16 O' 7521 18 O' 7617 lg 45 ' 7817 23 O' 7888 24 O' WELL UNION OIL COMPANY a-i8 I A T I 0 N DIRECTION TVD N N N N ND N 14E N 13E N 15E N N 16E N 16E N 17E N 13E N 11E N lie N iOE N iOE N liE N IOE N 9E N 2 E N. 2E N 2= N 2: N N 0z 0z 4z -. N 7E N lEE N 25E N 20E N ZOE N 21E 2982.51 3010.03 3080.91 3295.77 3378.43 3566.47 3592.45 3830.39 4035~82 4263.25 4464.62 4754.57 4987.62 5174.29 5405.71 5582.59 5641.50 5845.64 6063.94 0182.13 6300.14 6412.66 6692.45 6957.48 7142.61 7332, TVD = 0733.01 6761.85 6875.13 6963.48 7t47.58 7212.44 COMPLETION REPORT PREPARED FOR ALACAL BY SCS PAGE 2 SUB SEA NOVEMBER 29,1968 TANGENTIAL METHOD 2881.51 2909.03 2979.91 3192.77 3277.43 3465.47 3591.45 5729.39 393~.82 4.1~2.25 4363.62 4653.57 4886.62 5073.29 5304.71 5481.59 5540.30 5742.64 5962.94 6081.13 6199.14 6511.66 6591.45 6856.48 7041.61 6692.45, 6632.01 6660.85 6772.13 6862.48 7046.58 7111.44 TOTAL COORDINATES C L O S U R E S DOG LEG SECTi LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTA 1tt8.66N 622.05E 1279.98 N 29.07E 4.084 1i36.41N 626.15E 1297.49 N 28.85E 2.248 1181.73N 638.29E 1343.09 N 28.37E 1.298 1309.58N 674.95E 1473.29 N 27.26E 0.635 1357.04N 688.56E 1521.73 N 26.90E 1.785 1451.14N 715..54E 1617.96 N 26.24E 1.297 i507.32N 732.72~ 1675.97 N 25.92E 1.826 1567.16N 746.53E 1735.89 N 25.47E 1.282 1654.84~ 763.57E 1822.51 N 24.76E 0.423 1751,91N 782.44E 1918.70 N 24.06E 0.000 1839.17N 797.83E 2004.76 N 23.45E 0.214 1960.58N 819.20E 2124.66 N 22.67E 0.238 2043.64N 835.39E 2207.79 N 22.23E 1.218 2102.49N 845.76E 2266.22 N 21.915 1.159 2172.37N 856.835 2335.24 N 21.525 ·. 0.333 2223.06N 858.60E 2383.10 N 21.1!E 1.208 2239.60N 859.18E 2398.75 N 20.98E 0.409 2309.23N 861.61E 2464.74 N 20.46E 1.518 2385.04N 864.26E 2536.81 N 19.91E 0.000 2425.72N 865.68E 2575.56 N 19.64E 0.000 2466.q2N 866.40E 2614.64 N 19.35E 0.329 2505.66N 866.40E 2651.23 N 19.07E 0.346 2581.94N 866.40E 2723.43 N 18.54E t.293 2642.98N 870.67E 2782.70 N 18.23E 0.901 2685.62N 873.65E 2824.15 N 18.02E 0.000 LATIIUDE = 2581.94, D~PARTURE = 866.40 2592.72N 867o72~ 2734.07 N 18.50E 0o000 2600.71N 869.86~ 2742.33 N 18.49E 7.859 2633.48N 885.14E 2778.25 N 18.57E 3.021 2663.96N 896.23E 2810.68 N 18.,59E 2.480 2737.40N 922.96E 2888.81 N 18.63E 1.625 2764.36N 933.31E 2917.66 N 18.65E 1.516 1233.4 1251.6 1298.5 1431.4 1480.7 1578.5 1637.2 1698.6 1787.8 1886.6 1975.0 2097.9 2182.6 2242.2 2312.8 2362.4 2378.7 2446.9 2521o2 2561ol 2601.3 2639.0 2713.1 2773.5 2815°6 272B.9 2732.2 2767.6 2799.9 2877.5 2906.2 UNION OIL W E COMPANY MEASURED O E V I A T I O N DEPTH ANGLE DIRECTION 8109 823O 8317 85il 861.1 8747 8881 91t0 91 9262 9634 979b 9867 9936 10110 10263 10304 10342 10428 105bO 11000 ( CLOSUP, E L L. A-18 TVD C 0 M P L E PREPARED FOR .. SUB SEA 25 0 ' N Z4E 24 O' N 24E 22 O' N 22E 17 45' N 21E 16 45' N 20E 15 O' N i4E l 3 30 ' N OE 13 O' N 4W 12 0' N 2W · 11 15' N OE 10 O' N 2W 9 15' N 3W 8 O' N 31W 7 45' N 48W 7 15' ..N 49W 7 O' N 53W 8 0 ' N 64W 8 0 ' N 69W 6 30' N 90W 6 0" S 84W 7 0' S 73W 9 O' S 75W 16 0 ' N 81W 3338.71 N 13- 7412.73 7523.27 7613.21 7788.45 7884.21 8015.57 8145.87 8250.13 8312.73 8369.62 8433~63 8519.50 8887.88 9047.41 9118.83 9187.32 .... 9359.62 9511.13 9551.87 9589.66 9675.02 9805.40 1022'8.35 7311.73 7422.27 7512.21 7687.45 '7783.21 7914.57 8044.87 8149.13 8211.73 8268.62 8332.63 8418.50 _ 8786..88 8946.41 - .- 9017.83 9086.32 9258.62 9410. IB ..... 9450.87 9488.66 9574.02 9104.40 10127.35 35' E T I 0 N R E P 0 R T PAGE 3 ALACAL BY SCS NOVEMBER 29,1968 TANGENTIAL METHOD TOTAL COORDINATES C L 0 S U R E S DOG LEG SECTI LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISIA 2849.68N 971.30E 2894.64N 991.32E 29'28.33N 1004.93E 2980.70N 1025.03E 3007.78N 1034.89E 3041.94N 1043.40E 3073.22N 1043.40E 3097.23N 1041.73E 3110.53N 1041.26E 3121.84N 1041.26E 3133.12N !040.87E 3i47.09N 1040,14E 3191,47N 1013.47E 3205.99N 997.34E 3211.95N 990.48E 3217.02N 983.76E 3227.63N 962.00E 3235.26N 942.12E 3235.26N 937.48E 3234.85N 933.53E 3231.78N 923.50E 3226.44N 903.56E 3245.41N 783.77E 3010.67 N 18.82E 3059.68 N 18.90E 3095.97 N 18.94E 3152.03 N 1'8.97E 3180.84 N 18.98E 3215.91 N 18.93E 3245.52 N 18.75E 3267.73 N 18.58E 3280.19 N 18.50E 3290.92 N 18.44E 3301.50 N 18.37E 3314.52 N 18.28E 3348.52 N 17.615 3357.54 N 17.28E '3361.21N 17.13E 3364.07 N 17.00E 3367.94 N 16.59E.. 3369.65 N 16.23E 3368.35 N 16.15E 3366.86 N 16.095 3361.14 N 15.94E 3350.57 N 15.64E 3338.71 N 13.575 0.722 2998.C 0.826 3046.4 2.213 3082.4 2.317 3138.C 1.043 3166.~ 1.762 3201.E 2.796 3232.: 0.975 3255.: 1.702 3268.( 1.467 3279.( 2.004 3289.( 0.883 3303.: 1.164 3340.; 1.449 3350.~ 0.717 3354. 0.804 3358.: 1.003 ....... 3363., 0.454 3366.J 7.366 ..3364.' 2.163 3363. 1.852 3358. 1.529 3348. 1.949 .... 3338. ~'4EASURED DEPTH OOL 70;8 · 804 1132 124':~ 1367 1487 1606 1724 1842 1960 '2077 2192 2306 2420 2534- 264-8 2759 2 0 3!05 3222 334t 3461 3579 3698 38il WELL COMPLETION REPORT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH UNION OIL COMPANY A-18 PREPARED FOR ALACAL BY SCS TOTAL COORDINATES TVD SU6 SEA LATITUDE DEPARTURE 501,00 400.00 2.85N 6.12E 60i,~,~' 500.00 6.50N 11,18E 701,~.-.,.~ 600.00 17.81N t9.87E 801.00 700.00 36.07N 28.65E 90i.00 800.00 65.44N 4i.73E LOOI.O0 900.00 104.80N 57o83E I101.00 1000,00 153.6oN 79.07E i20t.00 1100.00 209.30N !06.93E 1301,00 1200.00 264.98N 135.29E i401.00 1300.00 322.52N-- 165.48E 150i.00 1400.00 379.63N 195,85E 1601.00 1500.00 434.80N 225,19E 1701.00 1600.00 487.78N 259,415 1801.00 · 1700.00. 539.39N 293,965 1901.00 1800.00 589.10N 328.765 2001.00 1900.00 636.25N 361.77E 2101.00 2000.00 681.66N 393.57E 2201.00 2t00.00 "~24.84N 426.59E 2301.00 2200.00 766.83N 460.37E 2401.00 2300.00 813.36N 490.31E 2501.00 2400.00 856.02N 5t1.16E 2601.00 2500.00 906,86N 535.23E 2701.00 2600.00 962.30N 556.98E 2801.00 2700.00 1013,77N 580.98E . 2901.00 2800.00 1068.34N 606.37E 3001.00 2go0.o0 1130.58N 624,80E 3101.00 '3000.00 1193.79N 641.7bE 3201.00 3100.00 t253.86N 658.975 3301.00 3200.00 1313.63N 6'76.11E 3401.00 3300.00 1368.33N 691.80E PAGE NOVEMBER 29,1968 MD-TVD DIFFERENCE VERTICAL CORRECTION 0 0 1 3 9 17' 31 48 66 86 105 123 141 159 176 191 2O5 219 233 247 258 273 289 304 321 340 360 378 395 410 0 0 1 2 6 8 14 17 18 20 19 . 18 18 - 18 17 15 14 14 14 14 11 15 16 15 17 19 20 18 17 15 TANGENTIAL METHOD ,EASURED ,EPTii 3924 4036 4146 4256 43 44. t 4583 4692 4801 4910 5020 5128 523T 534,% 5451 5551 5662 5767 5872 5970 6080 6395 650i 6601 6712 6818 6924 7030 WELL COMPLETION REP INTERPOLATED VALUES FOP, EVEN 100 FEET OF SUB SEA UNION OIL COMPANY A-18 PREPARED FOR ALACAL BY SCS TOTAL COORDINATES MD- TVO SUB SEA LATITUDE DEPARTURE DIFF 3501 360i 3701 3801 3901 4001 4101 4201 430i 4401 450t 4601 4'701 4801 4901 500L -5101 5201 530~ 5501 5601 5701 5801 5901 600~ 6101 6201 6501 6401 .00 3400.00 .00 3500.00 .00 3600.00 .00 3700.00 .00 38O0.00 .00 39O0.00 .00 4000.00 .00 4100.00 .00 4200.00 .00 4300.00 .00 440'0.00 .00 4500.00 .00 4600.00 .00 4700'.00 .00 4800.00 .00 4900.00 .00 5000.00 · 00 5t00.00 .00 5200.00 .00 5300.00 .00 5400.00 · 00. 5500.00 .00 5600.00 .00 5700.00 .00 5800.00 .00 59O0.O0 .00 6000.00 .00 6100.00 .00 6200.00 .00 6300.00 1418.37N 706 1466.53N 720 1511.02N 733 1554.40N 743 15~7.29N 752 t639.9'TN 760 1682.66N 768 '1725.34N 777 1768.27N 785 1811.60N . 792 1854.38N 800 1896.18N 807 t937.98N 815 1976.96N 822 2012.69N 829 , 2047.86N 836 2079.B8N 841 2110.55N 847 2i40o75N 851 2170.94N 856 2199.67N 857 2228.24N 858 2260.15N 859 2294.56N 861 2328.97N 862 2363.38N 863 2397.79N 864 · 2432.30N 865 2467.21N 866 2.501.65N 866 .15E .25E .57E .59E .39E .69E .98E .28E .33E .97E .51E .88E . .25E .43E · .37E .13E .69E .04E .82E .61E .78E .78E .IOE .30E .50E .70E .79E .40E .40E 423 435 445 455 464 473 482 491 500 509 519 527 536 543 55O 556 561 566 571 5'75 579 583 588 594- 600 606 611 617 623 629 0 R T DEPTH PAGE 2 NOVEMBER 29,1968 TANGENTIAL METHOD -- TVD ERENCE VERTICAL CORRECTION !3 12 10 . 10 9 9 9 9 9 9 10 9 5 6 6 5 6 '/~ E A S UR. E D dEPTH 7134 723~ 7341 7444 764'3 775~. 7341 7446 7551 7658 787o 7986 8206 831~ 8~1<) 852~ 8628 8 S~,~- 9~42 924~ 9445 954~ 9547 WELL COMPLETION REPORT IN[ERPOLATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH UNION OIL COMPANY A-18 PREPARED FOR ALACAL BY SCS TOTAL COORDINATES fro SUB SEA LATITUDE DEPARTURE 6501.00 0400.00 2529.~5N 866 6601.00 6500.00 2557.01N 866 6701.00 6600.00 2583.91N 866 6801,00 6700.00 2606.94N 868 6901.00 6800.00 2629.97N 869 700i.00 6900.00 2653.00N 871 710i.00 7000.00 2676.03N 872. 6701.00 6600.00 2584.21N 866. 6801.00 6700.00 2612.24N 875. 6901.00 6800.00 2642.88N 888. 7001.00 6900.00 2678.93N 901. 7101.00 7000.00 2718.82N 916. 7201.00 7100.00 2759.60N 931. 7301.00 7200.00 2802.08'N 950. '7401.00 7300.00 2844.68N 969. 7501.00 7400.00 2885.58N 987. 7601.00 7500.00 2923.'76N 1003. 7701.00 7800.00 2954.57N 1015. 7801o00 7700.00 2984.25N 1026. 7901.00 7800.00 3012.15N 1035. 800!.00 '7900.00 3038.15N 1042. SlOl..O0 8OO0.O0 3062.44N 1043. 8201.00 8100.00 3085.9tN 1042. 8301.00 8200.00 3108.03N 1041. 840i.00 8300.00 3127.37N 1041o 8501.00 84,00.00 3!44.08N 1040. 8601.00 8500°00 3156.91N 10~4. 8701.00 8600.00 3t68.95N 1027. 8801.00 8700.00 3i81.00N 1019. 8901.00 8800.00 3192.66N 1012. .40E .4O-- .54~ .1SE .37: 98-- 672 24E 56E 68E 20E 49E lie 07E 28E 08E OOE 32E 98E 46E 40E 52E 35E 07E 29E 24E OOE 76E 14E PAGE NOVEMBER 29,1968 MD-TVD DIFFERENCE VERTICAL CORRECTION 633 636 640 643 645' 648 650 640 644 65O 657 665 674 685 695 7O5 713 718 723 727 731 734 737 739 741 742 743 744 745 746 , 3 4 3 2 3 2 -10 4 6 7 8 9 11 10 10 8 5 5 4 4 3 3 2 2 - 1 1 1 1 1 TANGENTIAL METHOD EASURED EPTM 9745 9849 99b0 01 , 0253 0353 O454 0556 0659 0763 0867 0971 WELL COMPLETION REPORT IN'¥ERP(]LATEO VALUES FO;q EVEN 100 FEET OF SUB SEA DEPTH PAGE 4 UNION OIL COMPANY A-Z8 PREPARED FOR ALACAL BY SCS NOVEMBER 29,1968 TANGENTIAL METHOD IVD $lJ5 SEA 900i.00 9101.00 q20i.O0 9301.00 9401.00 9~01.00 9601.00 970L.00 9801.00 990Z.00 10001.00 I0101.00 10201.00 TOTAL COORDINATES - LATITUDE DEPARTURE MD-TVD DIFFERENCE VERTICAL CORRECTION 8900.00 3201.7~N 9000.00 32t0.47N 9100.00 3217.86N 9200.00 3224.02N 9300.00 3229.7iN 9400.00 3234.'75N 9500.00 3234.44N 9600.00 3230.72N 9700.00 3226.62N 9800.00 - - 3230.73N 9900.00 3235.21N 1002.03E 992ot9E 982.04E 969.40E 956.57E 943.45E 932.20E 919.53E 904.23E 876.48E .. 848.16E 10000.00 ...... 3239.70N .. 819.84E .... 10100.00 3244.18N 791.52E 747 1 748 - 1 749 1 750 1 751 1 '752 . 1 752 0 753 1 ......... 755 2 758 3 .......... 762 4 ?66 ........ 4 770 4 v, EASURED )EPTH 1000 2000 3000 6000 700 8000 9O00 t0000 i1000 W INTERPOLATED ELL COMPLETION REPORT VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH UNION OIL COMPANY A-18 PREPARED FOR ALACAL BY SCS TVD SUB SEA TOTAL COORDINATES LATITUDE DEPARTURE PAGE NOVEMBER 29,1968 984.00 883.00 97.52N L835.00 1734.00 556.54N 2709.00 2608.00 966.60N 3568.00 3467.00 !451.95N 4483.00 4382.00 1846.86N 542B.00 5B22.00 2177.60N 6372.00 6271.00 2491.ggN 7313.00 7212.00' 2807.60N 8261.00 8160.00 3099.72N 9250.00 9149.00 3220.92N 10228.00 10127.00 B245.41N MD-TVD DIFFERENCE VERTICAL CORRECTION 55 305 558 715 799 857 866 952 1041 975 783 .03E .96E .99E .79E .19E .OIE .40E .56E .64E .76E .77E 16 165 291 432 517' 577 628 687 739 750 772 16 149 126 141 85 60 51 59 52 11 22 TANGENTIAL METHOD Form No. 1:--4 REV, STATE OF ALASKA sus~rr IN mmucA~ OIL AND GAS CONSERVATIO'N COMMITTEE MONTHLY REPORT O'F :DRILLING AND WORKOVER OP~ATIONS WELL WELL OTH ~-ll 2. NAME OF OPEP~TOR Union 0il Company of California 3. ADDRESS OF OPEI:La-TOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCA~ON OF 'WI~,LL Conductor #18, 1624'N & 558'W from SE corner Section 4, T9N, R13W, SM. AP1 N~IE~CAJ~ ~ODE 50-133-20143 6. LEASE DESIGNA~ON AND S~IAL NO. ADL 18731 7. IF INDIA}~', ALOTTEE OR TRIBE NAME I~IT,F;u~ OR LEASE NAIVE Trading Bay State 9. WELL NO. A-18 (11-3) ~0. rLZUD ~-'~D POOL..-.~,~-- .. ~c~i/h¥'/'rt'ena~ & Trading Bay-Hemlock 11. SEC., T., R., M., (~OM HO~ o~ Sec. 3, T9N, R13W, SM. 12. PEP, MIT NO. 68-76 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING A1N-D C~ViENTING JOBS INCLUDING DEPTH SET AND VOLDqV/ES USED, PERFO-R.ATIONS, TESTS A_N'D R.ESULTS~ FISHING JOI~S, JUNK LN HOLE AND SIDE-TRACKED HOLE A/ND ANY O'I'~-IE.R SIGNIFICANT CI-La~ES IN HOLI~ CONDITIONS. TR~D.I..NG..BAY.STATE A-18 (!1-3). OCTOBER 1968 Ran Schlumberger_LL-3, HRD, Sonic Log, & SWS guns. Condition for casing. Ran 46 its 9-5/8", 43.5#, N-80 buttress .casing; 34 its 9-5/8", 40#, N-80; and 99 its 9-5/8", 40#, J-55 buttress casing. Landed w/shoe @ 7520'. Cmtd thru shoe w/1200 sxClass "G" cmt mixed w/CFR-2. Removed BOE & riser. Installed Cameron tbg head - tstd w/ 2500# - OK. Reinstalled riser & BOE, tstd w/1500# - OK. Drld 8-1/2" hole to 8511'. Lost 3 cones from bit, coul4 not recover Junk. Drld on junk 6'8511, sidetracked same. Drld 8-1/2" hole to 8695', stuck DP while RI @ 8600'. Backed off @ 8507'. RI w/jars, jarred & recovered all fish. Drld to 1046~'. Stuck DP while drlg @ 10468. Unable to rotate or move pipe. Backed off on top of 3rd drill collar, leaving bit, model & 2 steel drill collars in hole. RI & jarred ot fish, unable to circulate. Backed off top of fish @ 10368'. Plug across fish w/l18 sx ~land cmt plug. WOC. RI w/bit, found cmt @ 10339'.. Trmd to 10342'. RI w/oedp, hung @ 10342. Re-~ugged 8-1/2" hole w/l18 sx cmt w/20% sand. RI & drld firm cmt to 10180'. PO, ran Schlumberger DIL, HRD, & FDC logs. Polished off plug to 10253'. Dynadrilled & sidetracked original hole. Drill to 10282'. Now drilling. I CEIVEI) NOV 19 196f smx~ I~ L ~ ~ Dist. Drlg. Supt. ,ATt 11/15/68 . nt'E, ~aii e/e "--- -- .... NOTE--Report on t~s fOrm is required for each calendar month, regardless of the status of operations, an~ must ~ filed in duplicate with the Division of Min~ & Minerals by the 15th of the succeeding month, unless othe~ise directed. For~ No. ~--4 STATE OF ALASKA SUBMrr O~L AND GAS CONSERVATION CO~i~EE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS OIL ~ GA8 [] WELL WELL OTHER 2. NAME OF OPEI:LA. TOR Union Oil Company of California 3.' ADDRESS OF OPEP~TOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCA~ON O~ WEL~ Conductor #18, 1624'N & 558'W from SE corner Section 4 T9N, R13W, SM. AP1 N~IE~CAL CODE 50-133-20143 6. LEASE DESIGNATION AND S~IAL NO. ADL 18731 7. IF INDIAN, ALOT 1 £i OR TRIBE NAME 8. I/NIT,F~P~M OR LEASE NA~ME Trading Bay State 9. WELL NO. A-18 (11-3) 10. FI~:LD AND POOL. OR_%YILDCAT Bay_&iddleM: Kenai Trading l,,I~mloak i1, SEC,, T,, R., M., (BOO. rOM HOI~E OBJECTIVE) Sec. 3, T9N, R13W, S.M. 12. PERMIT NO. 68-76 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, PE/{FOR. ATIONS, 7~ESTS A/WD P~ESULTS, FISHI2qG JOinS, JLrNK 12q HOLE A/~D SIDE-TTLACKED HOLE ANT) .~NY OTI-~ SIGNIFIC;~NT CI-I_A/q~F~ lin HOLE CX)lxrDITIONS. TRADING BAY STATE A-18 (11-3) SEPTEMBER 1968 Drilled 12-1/4" directional hole to 7874'. Lost pump pressure, PO found box on bumper sub parted; Fished unsuccessfully. Ran in with open end drill pipe to top of fish @,7422'. Plugged 12-1:/4" hole w/250 sx Class "G" cmt w/2I CaC12 and 15I sand. Trimmed plug to 7320'. Dynadrilled and sidetracked hole from ~320T7383'. Drilled to 7521'. Ran Schlumberger DIL, FDC, SNP,'LL-3, RRD$ S~nic)and sidewall sample gun. Now prepa~ing to run 9,5/8" csg,. RECEIVED DIVISION O? Mlh/53 & MIN~.p~L ANCHORAG~ Ifil/ l'~r'~'~l ist. Drlg. Supt. hA,,'. 10/11/68 SIGNED -- U,V m~.l I ~' 'I'rTL~ ..... '' NOTE--RePort on t~is form is required for each calendar month, r eBardle$$ of the ~tatus of operation~, anO must be filed in duplicate with the Division of Mir~s & Minerals by the 15th of the succeeding month, unless otherwise directed. ! Union Oil CompF'""~,of California 2805 Denali Street,' Anchorage,, Alas~a 9~50,3 Telephone f907) 277-1481 ,~,ooe,"T T. Anaersom ~eptember 9, 1968 Director Division of Lands 344 Sixth Avenue Anchorage, Alaska 995(11 If~ST FORE LAND AREA Stat. e of Alaska ADL 18751, WForeL-6- Dear Sir' In accordance with the provisions of the captioned oil and gas lease, Trading 8ay State A-18 (11-3), drilling from the Monopod Platform located on State Lease ADL 18731 spudded on August 29, 1968. The proposed bottom hole location of said well is approximately SS0' South and 550' /!asr from Northwest corner Section 3, T9N, R13W, S.M. on .said lease, i Very truly yours, Robert T. Anderson RECEIVED DIVISION OF' MtN~5 & MiNERAL,~ ANCHO,~LAGE Po%m No. P---4 1REV. 'STATE O,F ALASKA OIL AND GAS .CONSERVATION COMMITTEE O.aUN ^NO We.KOV . O.m^nONS SUBMIT Eq DEPLICATE 1, WELL WELL OTHER 2. N~2~IE OF OP~TOR Union 0il Company of California 3, ADDRESS OF OPEI{ATOR 507 W. Northern Li~hts Blvd., Anchorage. Alaska 99503 4. LOCA~ON O'F wFJ_J~ Conductor #18, 1624'N &. 558'W from SE corner Section 4, TgN, R13W, SM. NLTMERI C ;~L CODE 50-133-20143 6. LE~kSE DESIGNATION AND SEEIAL NO. ADL-18731 7. IF INDIAN, ALOTTEE OR TRIBE NASXE 8. ~'IT,FAP~M OR LEASE NA-ME Tradin~ Bay State 9. WELL NO. -- - A-18 (11-3) lO. FIELD ~-ND POOL, o~H~lC%~Kenai & m~.o ~v- Hemlock O~~) Sec. 3, TDN~ R13W, SM ~. P~2~IVIIT 68-76 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-LA-NGES IN HOLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET ~ VOLU~ USED, PF~ORAT!ONS, T~STS ~2%r1) I{ESULTS. FISI4_ING JOt~S, JUNK LN HOLE AND SIDE-T~CKED HOLE AND A/~Y OTHEI{ SIGNIFICANT CHAN~ES IN HOL~ CONDITIONS. TRADING BAY STATE A-18 (11-,3), ,, AUGU,,ST 1968 SPUDDED 6:00 AM 8/29/68. ', Drilled directional 12-1/4" hole to 1100'. Opened 12-1/4" hole to 17-1/2" hole to 1069'. Ran 26 Jts 13-3/8", 61#, J-55 seal lock csg. Hung with shoe @ 1044' w/900 sx class "G" followed with 100 sx class "G" w/21 CaC12. Drilled 12-1/4" directional hole to 1~05'. Now drilling. . Cmtd. hereby certify e true and correct DiSt. Drlg. Superintendent -~ - =T,--- ~A','~ 9/9/68 ' ~ ~ -la.I..L~Y ~ ' NOT~'---"~$port on thc form is required fo~ each calendar month, regardless of the status with the Division of Minej¢ & Minerals by the 15th of the succeeding month, unless otherwise directed. FORM SA - I B t 25.5M 8/67 MEMORANDUM TO: J'-- FROM: Slate of Alaska DATE SUBJECT: FORM SA - I B 125.5M 8/67 ,.~"(~,~ .,~ '~"'" MEMORANDUM TO: l-- FROM': State of Alaska DATE : SUBJECT: Auauo~ 27, /068 Tradtng Bry State A-18 Union Otl COupmaF of California, Operator H~. RobaeC ~. Anderson Vnton Oil ~~ of Ca~~a ~ra~e, ilnh 99503 Xuclosed p],ease find t::be ~~ .~~~ for permit d~ cae =eferenced well. ~ell mmp~ and core chaps are ut Very truly 7ours, Thouas R. Harshall, Jr. Pe~oleum Supervtaor SUBMIT IN TRI1~ rTE (Other instruction-~ un reverse side) STATE O'F ALASKA OIL AND GAS CONSERVAIION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK ll~. TYPE OF WORK ~ DRILL WELL WELL OTHER ZONE 2. NAME OF OPERATOR Union Oil Company of California 3, ADDRESS O~ OPERATOR 2805-Denali Street, Anchorage, 'Alaska 99503 DEEPEN PLUG BACK [-] MULTIPLE ~] ZONE 4. LOCATIO~ ~ W L Atsur~ace ~on~ctor #18, 1624'N & 558'W from SF. corner Sec. 4, TgN, R1SW, SM. At proposed prod. zone Top Middle Kenai "D"' 1660'S & 135'E from NW cot. Sec. 3, T9N, R13W, S.M., Top Hemlock'r~'~~,~'~:~F, fr. NW cot. 13. DISTANCE IN MILES AND DIRECTION F-gOM NEAREST TOWN OR'POST OFFICe* Sec. 3, T9N~ R13~ Approximately 27 -air_miles_ N~rth Of Kemai,. Alaska SM 14. BOND INFORNIATION: STATEWIDE Pacific Insurance Company B # 55372 TYPE Surety and/or No. 15 DISTANCE FROM PROPOSED~: ' :;. '-, Y'!: ' 0_ - -',~ ?~:il6;2NO;~OF~ACRES IN*LEASE LOCATION TO NEAREST . ~, . : ! . PROPERTY OR LEASE LINE}'FT',-::'- '7} 550' '~:":; ::~ ": ~ ;-I:'--' '3840 00~: ' (Also to nearest drig, unit, if any) . ] . i1 ~ '- f '-~ ''--~ ' ~ ~i ...... .' · , ~-, , , 18. DISTANCE FROM PROPOSED~ LOCATION* ......... ..... ~fg.' PROPOSED DEPTH' TO NEAREST WELL DRILLI~H.G,- COM~L~, - :. i ': ~ - "[Ii: - ' ' ~ ' ' · ' OR APPLIED FOR, FT. ' ........ I~; .... : ~.':~!:i ~'" 2100' .-: '~I-9190!'MD::& 8581.'TVD. 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 101' RT above M.S.L. _ 23. ,?.c "~: ~: p:ROPOSEi~ 'CASiA~- ~ Alq, D: CEMENTING ~ i~ROGRAM API 50-133-20143 6. LEASE DESIGNATION AND SERIAL ADL 18731 L IF INDIAN. ALLO'~-r~ OR TRIBE NAJ~E 8. UNIT, FARNi OR LEASE NAiVIE Trading Bay State 9. WELL NO, A-18 (11-3) 10.~ELD ANDPOOL, OH~ILp~T . . - Mlaale Kenal Trading Bay- ~ Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T9N, R13W, S.M. ~o~t $100,000 ll?.~ NO,ACh'ES ASSlGNED TO 'Il-IlS WELL 20. ROTARY' ORCABLE TOOLS Rotan: :~i APPROX. D~TE WORK WILL ST~T* September 1. 1968 SIZE OF HOLE SIZE OF C~SI~l~ [:WEIGI~'i~E~''F''OO~' ,. qUANTIT' OF CEMEN~ _17~" 13-3/8" ' 61~ J-SS 1080' -1200 sacks ..12~" 9-5/8". ~,40g,,45.S.g~ 47.N~:P ~--.,. 9190' Drill 12~'hole to-1100',::. ;:Open: to,,.-,~z. ,. Cement 13-3/8", casing at ~I080' Install BOPE. DRill 12¼" directional hole to 9190'. Run electric logs. Cement 9-5/8" casing at 9190'. Dually complete for production. : ? " . . , (.; . . . Approximate Bottom Hole Location' 550'S & 550'E from NW corner Section 3, T9N, R13W, S.M. IN ABOVE SPACE' DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zofie. If Proposal is to drill, or deepen direct ~onally, give pertinent data on s~bsurface locations and measu~d and true verti~.al depths. GiVe' blowout "preventer program. 24.1. hereby certify that tJ~sF-~lm~jng Is Tru~l~r~ /~ ^ ' (This space for State o.f'~i~ce use) ' :"' coNDIT~NS O/F APPROVAL, IF ANY: ~xecutive Secretory APPROVED B5r ~ r' 'TITI~. t~'u$ .... DATE - ~ju: KO %~IL ~ %5OS *See Instructions Ond~'6~4~l~d~omrnJttee District Land Manager ,32 ADL 18775 5 J7 t' .33 ,4 9 A-9 UNION lTM +WTB.tI~ I ~6790 0 / T D 6528 A-6 ~ [ A-I // a-~ ~74~ ~ [~10,603 TD 8015 ]TD 7646 I I UNION I TD 7260 . I UN ION -M A RATHO N ADL 18751 (11-3) Hemle¢k MD 8190 ~ 7651 -'.1.,3 9 JO ,. R ISW / / / / / / / / / d TS-.4 / / TEX / TeS ~ TS'~)/ +TD 9,104 I MO !1!90 I I I l I I I I ~.~ A -3 TO 11:657 TS-! ~o 0 Z~ 3.5 ARcO TBS' I+ TO 10,950 T I0 N ADL 17597 ADL 18731 ADL 18776 ADL 17596 JJ ETB ~1 TD 10,364 T 9- ' N DATE: aueusT ~e, i9e8 TRADING BAY STATE A-18' , (~-3) I':= 2 l ~ 000. ALASKA DISTRICT' LOCATION PLAT TRADING BAY FIELD UNION OIL COMPANY 'OF CALFORNIA