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Home My WebLink About188-137CAUTION: 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Rixse, Melvin G (OGC) To:Jerimiah Galloway Cc:Torin Roschinger; Joleen Oshiro Subject:20220907 1014 APPROVAL 30 day POP END 1-01 (PTD# 188-137) Flow Under Evaluation Date:Wednesday, September 7, 2022 10:19:30 AM Attachments:image001.png image002.png Jeremiah, Hilcorp is approved to POP END 1-01 for a 30 day evaluation period. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Torin, Joleen From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, September 6, 2022 2:29 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: Re: [EXTERNAL] RE: END 1-01 (PTD# 188-137) Flow Under Evaluation Request Mel, I transposed the numbers for the depth. The px plug was set in the nipple located at a depth of 11,208 MD. Jerimiah Get Outlook for iOS From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, September 6, 2022 1:46:02 PM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: [EXTERNAL] RE: END 1-01 (PTD# 188-137) Flow Under Evaluation Request Jeremiah, Just curious, was that an inflatable at 11,802’ MD? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, September 6, 2022 11:51 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: END 1-01 (PTD# 188-137) Flow Under Evaluation Request Mel, END 1-01 (PTD# 188-037) is currently a Not Operable producer due to TxIA communication. A patch was pulled in 2014 and plug set to secure the well and has been shut in since. On 9/3/2022, a plug was successfully set at a depth of 11,802’ MD and a successful CMIT-TxIA passed to 2500 psi proving competent production casing. The plug has been pulled, a gas lift design and SSSV has been set. Hilcorp requests to flow the well under evaluation for 30 days to evaluate production and suitable tubing repairs. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 anydissemination, 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 acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 anydissemination, 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 acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 18 2020 1. Operations Abandon Li Plug Perforations Li Fracture Stimulate Li Pull Tubing LJ .Operations shutdown Li Performed: Suspend ❑ Perforate El Other Stimulate ❑✓ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 21 Re-enter Susp Well ❑ Other: Oil Safe AR / Install Patch ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑✓ 188-137 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20242-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018731 Trading Bay St A-25RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Trading Bay Field / Middle Kenai C Oil and Middle Kenai D Oil Pools 11. Present Well Condition Summary: Total Depth measured 8,730 feet Plugs measured N/A feet true vertical 6,071 feet Junk measured 7,814 feet Effective Depth measured 7,814 feet Packer measured 6,477 & 6,530 feet true vertical 5,340 feet true vertical 4,436 & 4,467 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 214' 20" 214' 214' Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Production 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 6,658 - 8,622 feet Tme Vertical depth 4,552 - 5,986 feet 9.2# 1 L-80 6,519 (MD) 4,461 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / N-80 6,541 (MD) 4,473 (TVD) D&L Hyd Iso Pkr 6,477 (MD) 4,436 (TVD) Packers and SSSV (type, measured and true vertical depth) FB -1 Packer 6,530 (MD) 4,467 (TVD) SSSV N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing soak Treatment descriptions including volumes used and final pressure: 2,475 gallons Oil Safe AR, Final pressure: Tubing -160, Casing -362. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 1 0 0 0 Subsequent to operation: 0 0 1 0 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑� WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-484 Authorized Name: Dan E Marlowe Contact Name: Dan Marlowe Authorized Title: Operatio anager Contact Email: Amarlowe@�filcorp.com Authorized Signature: Date: C)2 &,Leo Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 511 , �� RBDMSLA/ p.1®ZM Submit Original Only wi RKB to TBG Head = 37.73' PBTD = 8,676' TD = 8,730' MAX. HOLE ANGLE = 66 K r� SCHEMATIC CASING DETAIL Monopod Platform Well: A-25RD (Inj) PTD: 188-137 API: 50-733-20242-01 Completed: 02/13/2017 SIZE WT IGRADEJ CONN ID TOP BTM. 20" Conductor ID Surf 214' 13-3/8"61# 37.73' K-55 Butt 12.515" Surf 1,317' 9-5/8" 474 N-80 Butt 8.681" Surf 1,366'Tow 7" 29# N-80 Butt 6.184" Surf 8,726' 4,790' 6,5101 TUBING DETAIL 4.000" 4.500" 3-1/2" 9.2# L-80 IBT/Mod 2.992" Surf 6,519' 3-1/2"IPC 9.3# N-80 055 -HTC 2.992" 6,511' 6,541' Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 02/11/20 by AL JEWELRY DETAIL NO. Depth MD Depth TVD ID OD Item 1 37.73' 37' 2.992" 6.250" Tubing Hanger 2 6,477' 4,436' 4.000" 5.870" D&L Hydraulic Isolation Packer 3 6,498' 4,448' 2.813" 4.430" X Nipple 4,790' 6,5101 4,455' 4.000" 4.500" Non -Sealing Overshot 4 61511' 4,456' 2.992' 3.5001' E -Line Cut (7.5' swallow with overshot) 20' 6,519' 4,461' 4.000" 5.750" Bottom of Cut Lip Guide 5,313' 6,529' 4,466' 2.98" 4.25" Baker Locating Sub D53-0 6,530' 4,467' 2.98" 3.986" Baker Seal Assembly 11'X 3.986" X 2.98" 5 6,541' 4,473' 2.98" 8,072' Mule Shoe on bottom of seal assembly 5,546' 6,530' 4,467' 4.000" 5.875" Baker Model FB -1 Packer 7", 29# X 4" D54-5 6,532' 4,468' 4.000" 5.016" Baker Seal Bore Extension 8' 6,541' 4,473' 2.937" 5.687" Crossover 3-1/2" DSS X 3-1/2" 8rd. box 6 6,542' 4,474' 2.992" 4/1/1989 3-1/2", 9.34, N-80 ]PC Tubing Pup Joint D55-7 6,545' 4,476' 2.750" 4.00" Otis'X' Nipple 8' 6,546' 4,476' 2.992" 8,346' Joint of 3-1/2", 9.3#,N-80, IPCTubing 7 6,575' 4,493' 2.937" 5.25" Wireline Re-entry Guide Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 02/11/20 by AL Perforation Detail Sand Top (MD) Btm (MD) Top (TVD) Bon (TVD) Amt Accum SPF Last Perf Date Present Condition C-7 6,658' 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open C47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open C51-6 7,788' 7,828' 5,320' 5,351' 40' 20' 10/4/2015 Open C51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open D53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open D 53-8 8,072' 8,085' 5,546' 5,556' 13' 8' 4/1/1989 Open D54-5 8,142' 8,158' 5,602' 5,614' 16' 8' 4/1/1989 Open D54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open D55-7 8,263' 8,303' 5,698' 5,731' 40' 8' 4/1/1989 Open D 56-1 8,346' 8,463' 5,765' 5,859' 117' 8' 4/1/1989 Open D57-2 8,502' 8,622' 5,890' 5,986' 120' 8' 4/1/1989 Open Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 02/11/20 by AL Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-25RD Slickline 1 50-733-20242-01-00 1 188-137 11/10/19 11/24/19 Daily Operations: 11/10/19-Sunday Rig up treatment lines. Pressure test Discharge lines to 2500/500. Pressure test Suction lines to 150. Pump 9 each 275 gallon totes Oil Safe AR (2,475 gallons). Initial Pressures: T-0, IA-0. Final Pressures: T-160, IA-362. Max Pressures: T- 1278, IA-1440. Purge treatment lines with 2 bbls FIW. Rig Down and secure well for 3-5 day soak. G lL S,9�E 11/11/19 - Monday No operations to report 11/12/19-Tuesday No operations to report 11/13/19 - Wednesday No operations to report. 11/14/19 - Thursday No operations to report. C 11/15/19 - Friday ARRIVE MONOPOD. W/L MEETING, JSA PERMIT, ORIENTATION. SPOT EQUIPMENT. RIG UP SLICKLINE. P/T LUB. & WLV'S TO 2000PSI, GOOD TEST. RIH W/ 2.25" DD BAILER TO 4662' W/ TOOL TO 4677'. FELL THRU TO 7795'KB. TAG W1 TOOL POOH. FULL SCALE & MUD. RIH W/ 2.74" G-RING TO 4924'KB W/ TOOL WOULD NOT FALL, POOH. RIH W/ 2.63" G-RING TO 4926'KB W/ TOOL 4928'KB, POOH. RIH W/ 2.5" G-RING TO 4928'KB W/ TOOL, WOULD NOT FALL, POOH. RIH W/ 2.3" PINEAPPLE BROACH -SIT 598' HAND SPANG TO 609', FELL THRU, MAKE SEVERAL PASSES. CONT. TO 655'KB W/ TOOL FELL TO 4925'KB W/ TOOL 4933'KB FELL THRU TO 6600' PASS TUBING TAIL, POOH. OOH LAY DOWN LUB. CUT WIRE RE-HEAD. HAVE PRODUCTION FLOW WELL OVER NIGHT. SHUT DOWN FOR NIGHT. TURN IN PERMIT. LAY DOWN FOR NIGHT. 11/16/19-Saturday MORNING MEETING, JSA PERMIT. P/U LUB. STAB ON RISER. RIH W/ 2.56" PINEAPPLE BROACH TO 5890' W/ TOOL TO 5944'KB, FELL THRU. CONT. TO 6600'KB, POOH. OOH, STAND BY TO INJECT FLUID. RIH W/ 2.68" PINEAPPLE BROACH TO 4963'W/ TOOL TO 5022'KB, FELL THRU TO 5134'. W/ TOOL TO 5141' KB FELL T06600'KB, POOH TO 6542'KB. HUNG UP @ X-NIPPLE, W/ TOOL CAME THRU, HUNG UP 6496' KB X-NIPPLE, W/ TOOL CAME THRU. POOH, STAND BY TO INJECT FLUID. OOH LAY DOWN & CHECK TOOLSTRING. CUT WIRE, CONT. TO STAND BY. RIH W/ 2.78" PINEAPPLE BROACH TO 326'KB, W/ TOOL TO 375'KB, FELL TO 401'KB, W/ TOOL TO 507'KB, FELL TO 3792' - 3804'KB, 4806'KB TO 4884'KB, FELL TO 4963'KB, W/ TOOL TO 5061'KB, WOULD NOT FALL POOH. CREW C/O CHECK TOOLSTRING. STAND BY TO INJECT. RIH W/ SAME TO 5064'KB W/ TOOL TO 5111'KB WOULD NOT FALL, GETTING STICKY & LOSING SPANG ACTION, POOH. OOH LAY DOWN & CHECK TOOLSTRING. SECURE WELL FOR NIGHT. TURN IN PERMIT. CLOSE OUT TICKET. CREW REST. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-25RD Slickline 50-733-20242-01-00 1 188-137 11/10/19 1 11/24/19 Daily Operations: 11/17/19-Sunday MORNING MEETING, JSA PERMIT. RIH W/ 2.72" STAR BIT TO 5280'KB. W/ TOOL FELL THRU, CONT. TO 6600'KB, PASS TUBING TAIL. POOH, RIH W/ 2.78" PINEAPPLE BROACH TO 5113'KB, SIT, W/ TOOL TO 5156'KB, POOH. STAND BY FOR CRANE. RIH W/ SAME TO 5158'KB, W/ TOOL TO 5205'KB, WOULD NOT FALL- STICKY, POOH. HAVE PROD. START INJECTING FLUID. RIH W/ 2.75" G-RING TO 5225'KB, W/ TOOL TO 5418'KB, WOULD NOT FALL, POOH. RIH W/ 3 1/2" BRAIDED LINE BRUSH WHILE INJECTING WATER TO 4575'KB, W/ TOOL CAN NOT PASS, POOH. REDRESS BLB. RIH W/ SAME WHILE INJECTING FLUID W/ TOOL FROM 5000' TO 6600'KB, TUBING TAIL, POOH. RIH W/ 2.78" BROACH TO 5207'KB, W/ TOOL TO5305'KB, POOH. LAY DOWN LUB. STUFFING BOX LEAKING. REHEAD, CUT WIRE, CHECK TOOLSTRING. RIH W/ SAME TO 5306'KB, W/ TOOL TO 5420'KB, WOULD NOT FALL, POOH. OOH LAY DOWN LUB. SECURE WELL FOR PRODUCTION TO INJECT FLUIDS OVER NIGHT. TURN IN PERMIT. CLOSE OUT TICKET, CREW REST. 11/18/19 - Monday MORNING MEETING, JSA PERMIT. P/U TOOLSTRING STAB IN LUB. RIH W/ 2.75" G-RING TO 5433'KB, W/ TOOL FELL TO 5509'KB, W/ TOOL TO 5721'KB, POOH. RIH W/ 3 1/2" BRAIDED LINE BRUSH WHILE INJECTING FLUIDS, W/ TOOL FROM 5000' TO TUBING TAIL @ 6600'KB, POOH. RIH W/ 2.78" PINEAPPLE BROACH TO 5422-KB, W/ TOOL TO 5600'KB, POOH. OOH, STAND BY TO INJECT FLUIDS. RIH W/ SAME TO 5606'KB, W/ TOOL TO 5726'KB, POOH. RIH W/ 2.75" G-RING TO 6034'KB, W/ TOOL TO 6076'KB, FELL TO 6120'KB, W/ TOOL TO 6148'KB, FELL THRU TO 6548'KB, TAG X-NIPPLE, POOH. RIH W/ 3 1/2" BRAIDED LINE BRUSH WHILE INJECTING FLUIDS, W/ TOOL FROM 5000' TO TUBING TAIL @ 6600'KB, POOH. RIH W/ 2.78" PINEAPPLE BROACH TO 5728'KB, W/ TOOL TO 5950'KB, POOH. OOH, LAY DOWN. CHECK TOOL STRING, CUT WIRE, RE-HEAD. HAVE PROD. INJECT DOWN TUBING. RIH W/ SAME TO 5951'KB, W/ TOOL TO 6053'KB, WOULD NOT FALL, POOH. OOH, LAY DOWN LUB. SECURE WELL FOR NIGHT. CLOSE OUT TICKET. TURN IN PERMIT. LAY DOWN CREW. 11/19/19-Tuesday MORNING MEETING JSA PERMIT. P/U LUB. STAB ON RISER. RIH W/ 2.75" G-RING TO 6096'KB W/ TOOL DOWN TO 6114'KB FELL TO 6548'KB TAG X-NIPPLE. POOH, RIH W/ 3-1/2" BRAIDED LINE BRUSH WHILE INJECTING TO 4988'KB W/ TOOL TO 5027'KB POOH. REDRESS BLB, RIH W/ SAME W/TOOL TO TUBING TAIL MAKING SEVERAL PASSES FROM 4900' TO 6600' POO. RIH W/ 2.78" PINEAPPLE BROACH TO 6055'KB W/ TOOL TO 6300'KB POOH HAVE PROD. INJECT FLUID 1HR. RIH W/ SAME TO 6307'KB W/ TOOL TO 6543'KB TAG 2.75" NIPPLE MAKE SEVERAL PASSES POOH. RIH W/ 3-1/2" BRAIDED LINE BRUSH WHILE INJECTING TO 4977'1<13 SIT W/ TOOL MAKE SEVERAL PASSES CONT. TO 6478'KB W/ TOOL TO 6600'KB MAKING SEVERAL PASSES THRU PACKER, OOH LAY DOWN CHECK TOOL STRING CUT WIRE BE- HEAD PIN D&D HOLE FINDER & PREP FOR MORNING. CREW REST. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay StA-25RD Slickline 50-733-20242-01-00 1 188-137 11/10/19 11/24/19 Daily Operations: 11/20/19 - Wednesday MORNING MEETING, JSA, PERMIT. P/U LUB. STAB ON RISER. RIH W/ 2-1/2" JDC W/ 3-1/2" D&D HOLEFINDER TO 6,478'KB, W/ TOOL, SET- STANDBY FOR P/T. TEST- FAILED, PULL UP TO 6468'KB, W/ TOOL, SET-P/T FAILED. PULL UP TO 5,468'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 4,468'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 3,468'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 2,468'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 1,468'KB, W/TOOL, SET, P/T FAILED, PULL UP TO 4,68'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 12', W/ TOOL, SET, P/T FAILED. POOH, REDRESS TOOLS, STAND BY FOR PROD. TO TEST T. HANGER. RIH W/ SAME TO 6,485'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 4510'KB, W/ TOOL, SET, P/T FAILED. PULL UP TO 2,310'KB, W/ TOOL, SET, TUBING PRESSURE DROP 30# IN 10MIN. BLEED I.A. TO 100PSI. FELL OFF TO (0) PULL UP TO 2,260'KB W/ TOOL SET - GOOD TEST. POOH, LAY DOWN LUB. SECURE WELL FOR NIGHT. CREW REST. 11/21/19 -Thursday MORNING MEETING, ISA, PERMIT. P/U LUB. STAB ON RISER. RIH W/ 2-1/2" JDC W/ HOLE FINDER TO 3,000'KB, W/ TOOL, SET P/T GOOD TEST. POOH, DISCUSS PLAN FORWARD. RIH W/ 2.78" PINE APPLE BROACH TO 5,395' SIT, W/ TOOL, FELL THRU, MAKE SEVERAL PASSES CONT. TO 6,498'KB. TAG X -NIPPLE, MAKE SEVERAL PASSES THRU PACKER. POOH. RIH W/ 3-1/2" BRAIDED LINE BRUSH WHILE PUMPING FLUIDS DOWN HOLE TO 5,034'KB, W/ TOOL TO 5,052'KB, FELL TO 5,093', W/ TOOL TO 5,180'KB, FELL TO 5,220', W/ TOOL TO 6,200'KB, FELL TO 6,600' PASS TUBING TAIL. POOH -OOH, CUT WIRE RE -HEAD CHECK TOOL STRING. RIH W/ 2-1/2" JDC W/ HOLE FINDER TO 3,400'WLM, W/ TOOL, SET, STAND BY FOR P/T— FAILED. PULL UP TO 3,350'WLM, SET TOOL, P/T GOOD. POOH, REDRESS HOLE FINDER. RIG DOWN SLICKLINE. SECURE WELL FOR PROD. DEPART PLATFORM HEAD TO GRANITE POINT PLATFORM. 11/22/19 - Friday No operations to report. 11/23/19 -Saturday CALLOUT FOR CHOPPER. ARRIVE @ PWL SHOP GATHER TOOLS. ARRIVE ON MONOPOD, SIGN- IN/PERMIT/JSA/WIRELINE SAFETY MEETING, BEGIN RU SLICKLINE, PT LUB TO 2,600 PSI, PASS,RIH W/2.5 JDC W/3.5" DO HOLE FINDER TO 3,600'WLM, SHEAR PIN AND PULL UP TO 3,390' WLM. SET AND STANDBY FOR TUBING TEST, FAIL, PULL UP TO 3,380' WLM, TEST FAIL, PULL UP TO 3,370' WLM, TEST TWICE AND PASS, POOH,OOH, RE -PIN HOLE FINDER, CHANGE ROLL PINS IN ROLLER BOOGIES, RIH W/SAME TO 3,375' WLM, FAIL TEST, PULL UP TO 3,372' WLM, FAIL TEST, = ABLE TO ISOLATE HOLE IN TUBING BETWEEN 3,370' WLM - 3,372' WLM, POOH, OOH, RIG OFF WELL, TURN OVER TO PRODUCTION, CREW REST. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay St A-25RD Slickline 50-733-20242-01-00 188-137 11/10/19 11/24/19 Daily Operations: 11/24/19 -Sunday FINISH MOVING FROM A-21RD, STANDBY FOR CHOPPER TO DELIVER PATCH AND TOOLS. MOVE WIRELINE UNIT, RU ON WELL AND ADD 25FT OF LUBRICATOR, BUILD PATCH AND DRESS PACKOFFS AND TOP AND BOTTOM STOPS UPON ARRIVAL. PT LUBRICATOR TO 1,800 PSI, GOOD, RIH W/3" GS AND AD -2 STOP TO 3383 WLM, SET STOP POOH, OOH, RE -PIN GS, ADD KNUCKLE JOINT TO BOTTOM OF SPANGS, RIH W/3" GS AND 20FT PATCH TO 3,364' WLM,OOH, RE - PIN GS, RIH W/3" GS AND PACKOFF W/STINGER ASSEMBLY TO 3,360' WLM. RIH W/ 3" GS AND AA -STOP TO 3358 WLM, SET STOP, POOH. RD SLICKLINE. FINISH PAPERWORK. PRESSURE TEST FAILED. WELL TO REMAIN SHUT-IN EVALUATING OPTIONS. THE STATE 01ALAV —K1Z GOVERNOR MIKE DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Trading Bay Field, Middle Kenai C and Middle Kenai D Oil Pools, Trading Bay St A-25RD Permit to Drill Number: 188-137 Sundry Number: 319-48A Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gcv Enclosed is the approved application for the 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, Je e . Price Chair DATED thiaq day of October, 2019. MDWS OCT 3 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 95 oun RECEIVED OCT pr:5 Zl opp�l�2 el I? AOGVC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑� Operations shutdown[-] Suspend ❑ Perforate ❑ Other Stimulate ❑� f Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Oil Safe AR / Install Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hiloorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 188-137 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20242-01-00 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 Trading Bay St A-25RD 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADL0o18731 I Trading Bay Field / Middle Kenai C Oil and Middle Kenai D Oil Pools 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): 8,730 6,071 7,814 5,340 1,612 psi N/A 7,814 Casing Length size MD ND Burst Collapse Structural Conductor 214' 20" 214 214' Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Production 8,726' 7"8,726' 6,069' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation DepthND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,658 - 8,622 4,542 - 5,986 3-1/2" 9.2#/ L-80 & 9.3# / N-80 6,519 & 6,541 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): D&L Hydraulic Isolation Packer / FB -1 Packer & N/A 6,477 (MD) 4,436 (ND) 16,530 (MD) 4,467 (ND) & N/A 12. Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: 11/1/2019 Commencing Operations: OIL E]WINJ ❑✓ WDSPL E] Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hllcorp.com Contact Phone: (907) 283-1329 �� Authorized Signature: Date: 1D �� I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3�q-ugy Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: RBDMS -0"/rOCT 3 0 2019 Rost Initial Injection MIT Req'd? Yes No E-1 ,J Spacing Exception Required? Yes ❑ No Subsequent Form Required: CJ —1 o4-( APPROVED BY Approved by: l COMMISSIONER THE COMMISSION ,AI SI Date: � rove �- G/, a�tG �� L'19� �'l r - Submit Form and l/ m 70-403 R6vise 4/2 17 Approved application is a ' n f t e of approval. '/ Attachments in Duplicate ems/ %D11Jl11e t) 1 A # "-7 a ff Hileurp Alaska, LLC Well Prognosis Current Bottom Hole Pressure: 2,066 psi @ 4,542' TVD (6,658' MD) 0.455 psi/ft (8.75 ppg) survey 07/25/2015 Maximum Expected BHP: 2,066 psi @ 4,542' TVD (6,658' MD) 0.455 psi/ft (8.75 ppg) survey 07/25/2015 Max Potential Surface Pressure: 1,612 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. This project will cleanout the tubing, find the leak and install a tubing patch to restore tubing x IA integrity. Phase I: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±2,000 psi (treatment pump limit). 3. Pump ±2,400 gallons Oilsafe AR (synthetic acid) p l`� 4. Shut down pump and let for ±72 hours. 5. Rig down pumping equipment 6. Turn over to production Phase II: 1. Rig up slick line and pressure test to 1,500 psi. 2. Cleanout tubing to full drift. 3. Run diagnostic tools to locate tubing leak. 4. Install tubing patch across hole. 5. Pressure test IA to 1,500 psi and chart for 30 minutes. / 6. Rig down slick line and lubricator. 7. Turn well over to production. 8. Place well on injection. it 9. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. Attachments: 1. Wellbore Schematic Current 2. Wellbore Schematic Proposed 3. Fluid Flow Diagrams 4. Oilsafe AR—Technical Data Sheet A-25RD API Number: 50-733-20242-01 : Waterflood Injector Leg: NA rt Date: WCoontact: November 01, 2019 Rig: NSA Req'd? 403 Date Reg. Approval Rec'vd: ntact: Juanita Lovett (8332) Permit to Drill Number: 188-137 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: 2,066 psi @ 4,542' TVD (6,658' MD) 0.455 psi/ft (8.75 ppg) survey 07/25/2015 Maximum Expected BHP: 2,066 psi @ 4,542' TVD (6,658' MD) 0.455 psi/ft (8.75 ppg) survey 07/25/2015 Max Potential Surface Pressure: 1,612 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. This project will cleanout the tubing, find the leak and install a tubing patch to restore tubing x IA integrity. Phase I: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±2,000 psi (treatment pump limit). 3. Pump ±2,400 gallons Oilsafe AR (synthetic acid) p l`� 4. Shut down pump and let for ±72 hours. 5. Rig down pumping equipment 6. Turn over to production Phase II: 1. Rig up slick line and pressure test to 1,500 psi. 2. Cleanout tubing to full drift. 3. Run diagnostic tools to locate tubing leak. 4. Install tubing patch across hole. 5. Pressure test IA to 1,500 psi and chart for 30 minutes. / 6. Rig down slick line and lubricator. 7. Turn well over to production. 8. Place well on injection. it 9. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. Attachments: 1. Wellbore Schematic Current 2. Wellbore Schematic Proposed 3. Fluid Flow Diagrams 4. Oilsafe AR—Technical Data Sheet RKB to TBG Head = 37.73' Monopod Platform SCHEMATIC Well: A-25RD(Inj) PTD: 188-137 API: 50-733-20242-01 Completed: 02/13/2017 C A QYW I_ TIrrP A TT SIZE WT I GRADE F CONN ID TOP BTM. 20" Conductor ID Surf 214' 13-3/8" 61# K-55 Butt 12.515" Surf 1,317' 9-5/8" 47# N-80 Butt 8.681" Surf 1,366'TOW 7" 29# N-80 I Butt 6.184" Surf 8,726' 4,790' 6,510' 4,455' TUBING DETAIL 4.500" Non -Sealing Overshot 4 6,511' 4,456' IBT(Mod 2.992" Surf 6,519' 3-1/2" ]PC 1 9.3# N-80 I DSS -HTC 1 2.992" 1 6,511' 1 6,541' PBTD = 8,675' TD = 8,730' MAX. HOLE ANGLE = 65 ° ) Z 3� Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 06/13/19 by JUL JEWELRY DETAIL NO. DMD epth Dept TVD ID OD Item 1 37.73' 37' 2.992" 6.250" Tubing Hanger 2 6,477' 4 ,436' 4.000" 5.870" D&L Hydraulic Isolation Packer 3 6,498' 4,448' 2.813" 4.430" X Nipple 4,790' 6,510' 4,455' 4.000" 4.500" Non -Sealing Overshot 4 6,511' 4,456' 2.992" 3.500" E -Line Cut (7.5' swallow with overshot) 20' 6,519' 4,461' 4.000" 5.750" Bottom of Cut Lip Guide 5,313' 6,529' 4,466' 2.98" 4.25" Baker Locating Sub D 53-0 6,530' 4,467' 2.98" 3.986" Baker Seal Assembly 11'X 3.986" X 2.98" :J 5 6,541' 4,473' 2.98" 8,072' Mule Shoe on bottom of seal assembly 5,546' 6,530' 4,457 4.000" 5.875" Baker Model FB -1 Packer 7", 29# X 4" D54-5 6,532' 4,468' 4.000" 5.016" Baker Seal Bore Extension 8' 6,541' 4,473' 2.937" 5.687" Crossover 3-1/2" DSS X 3-1/2" 8rd. box 6 6,542' 4,474' 2.992" 4/1/1989 3-1/2", 9.3#, N-80 ]PC Tubing Pup Joint D55-7 6,545' 4,476' 2.750" 4.00" Otis 'X' Nipple 8' 6,546' 4,476' 2.992" 8,346' Joint of 3-1/2", 9.3#,N-80,IPC Tubing 7 6,575' 4,493' 2.937" 5.25" Wireline Re-entry Guide Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 06/13/19 by JUL Perforation Detail Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Accum SPF Last Perf Date Present Condition C-7 6,658' 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open C47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open C51-6 7,788' 7,828' 5,320' 5,351' 40' 20' 10/4/2015 Open C51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open D53-8 8,072' 8,085' 5,546' 5,556' 13' 8' 4/1/1989 Open D54-5 8,142' 8,158' 5,602' 5,614' 16' 8' 4/1/1989 Open D54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open D55-7 8,263' 8,303' 5,698' 5,731' 40' 8' 4/1/1989 Open D56-1 8,346' 8,463' 5,765' 5,859' 117' 8' 4/1/1989 Open D57-2 8,502' 8,622' 5,890' 5,986' 120' 8' 4/1/1989 Open Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 06/13/19 by JUL Monopod Platform PROPOSED Well: A-25RD(Inj) PTD: 188-137 API: 50-733-20242-01 Completed: 02/13/2017 RKB to TBG Head = 37.73' CASTNG DF,TATF, PBTD = 8,675' TD = 8,730' MAX. HOLE ANGLE = 65 ° Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 10/18/19 by ILL GRADE CONN ID TOP BTM. Depth MD uctor ID Surf 214' 1 # K-55 Butt 12.515" Surf 1,317' RIPC9 6,477' 4,436' Butt 8681" 5.870" D&L Hydraulic Isolation Packer 3 6,498' 4,448' 2.813" 4.430" XNipple 4,790' 6,510' 4,455' TUBING DETAIL 4.500" Non -Sealing Overshot 4 # L-80 IIT/Mod 2.992" Surf 6519' 6,519' # N-80 DSS -HTC 2.992" 6,511' 6,541' Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 10/18/19 by ILL JEWELRY DETAIL NO. Depth MD Depth TVD ID OD Item 1 37.73 37' 2.992" 6.250" Tubing Hanger 2 6,477' 4,436' 4.000" 5.870" D&L Hydraulic Isolation Packer 3 6,498' 4,448' 2.813" 4.430" XNipple 4,790' 6,510' 4,455' 4.000" 4.500" Non -Sealing Overshot 4 6,511' 4,456' 2.992" 3.500" E -Line Cut (7.5' swallow with overshot) 20' 6,519' 4,461' 4.000" 5.750" Bottom of Cut Lip Guide 5,313' 6,529' 4,466' 2.98" 4.25" Baker Locating Sub D 53-0 6,530' 4,467' 2.98" 3.986" 11' 'e ..5 Baker Seal AssemblM,1�,29 20' 6,541' 4,473' 2.98" 8,072' le Shoe on bottom of seal assembly6,530' 5,546' 5,5561 4467' 4,000" 4/1/1989 er Model FB -1 Packer 7", 29# X 4"6,532' D54-5 8,142' 4,468' 4.000"er 5,614' Seal Bore Extension6,541' 8' 4/1/1989 4,473' 2.937" 8,187' ssover 3-1/2" D55 X 3-1/2" 8rd. box66,542' 5,638' 5,682' 4,474' 2.992"2", 4/1/1989 9.3#,N-80 IPCTubing Pup Joint6,545' D55-7 8,263' 4,476' 2.750"'X' 5,731' Nipple6,546' 8' 4/1/1989 4,476' 2.992"t 8,346' of 3-1/2", 9.3#, N-80, IPCTubing7 5,765' 6,575' 4,493' 2.937" 4/1/1989 eline Re-entry Guide Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 10/18/19 by ILL Perforation Detail Sand Top (MD) Btm (MD) Top (TVD) Btm (ND) Amt Accum SPF Last Perf Date Present Condition C-7 61 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open C47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open C51-6 7,788' 7,828' 5,320' 5,351' 40' 20' 10/4/2015 Open C51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open D53-8 8,072' 8,085' 5,546' 5,5561 13' 8' 4/1/1989 Open D54-5 8,142' 8,158' 5,602' 5,614' 16' 8' 4/1/1989 Open D54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open D55-7 8,263' 8,303' 5,698' 5,731' 40' 8' 4/1/1989 Open D56-1 8,346' 8,463' 5,765' 5,859' 117' B. 4/1/1989 Open D 57-2 8,502' 8,622' 5,890' 5,986' 120' 8' 4/1/1989 Open Fish: 6/7/2019 7,814' - (3'9" x 1.25" P.T. GAUGES W/ 113/4" x 1.25" KNUCKLE JAR W/ 2'x 1.5" STEM W/ 1.73" ROLLERS) Total Length: 6.8' Revised: 10/18/19 by ILL u A r R A S d (��ll I �I�IjI It 1 � z � gm 0 g2 € m OB Safe AIM In a safe yet functional replacement for Iradidonallaydracldoric sold treatments and other commonly used oWield acid treatments. Itis aon-regutaledbyUS DOT, Canadian TDO endcardes a triple aerobasadon, materials hdomladonayatem score. OUSate AR40 biodegrades In10 daysorleae andis approvedby fheUS EPA as a➢eslgnadfm the Emdromnenlpmduct. Ourstandard 011esfe AR®formula Includea iron control agents, dednutsiliers, end requires no organic acid additions or corrosion irdtibitore undermost conditions. • An•xotHant vholoo tot fncy spearha•d lraunnnly lnjsallenw•9ond dls. ponlp•1handatmvLrsaaIts • Rv Irs. = Moulaadd sddalon• to hWp r•hrd rotation rail • Rltudard farmula lncledaa•udaaWt mdds-muhgiar system • Raqulraa as loon uvnirolagoal addlllsnfor most applications • EPA DIR W.I.;blodagradable to 10 drys orlon;approvadto, dineldk- ohar9a;Mots with Cle ang radlmb and DRi ingredlanb apptaed Who EPA • ads an moat mstalr4 piping and pumping equipmont • Non two. non fuming; non mulagaNe;.VOG'a • No s000ndary oonlWnmmt rogubed a par ckoplaaa-701P.A.0, • Elenlnabs foubNa • An exaa8enl oholo•forowbovorpmj•olo,bullhead lnalmaNs andcw*Mr tnadhllon • RagWras ne addliloml earrodon InhUlord p formwt appllaatloa • 100%blodoaradabl•, aaldfna andnalursAy lMWited DISSOLVING PROPERTIES ACIDTYPE I %CaCO' OB safe An 60% solution 98.70% OB Safe ARO 30% Solution 34.00 7 %NCI 48.48% 16% HCI 87.89% 7% HCI+ l00gplof83%AcelicAcid 73.08% 10%HCI+ 100gptofBB%Ace3cAcid 87.87% 10% Acetic Auld 21.00% 18%Acego Acid 83.09% Eaehtan •bows•nrduvledd0l,alNolrchotmalM4ptndNeoM of adu9on•naallogadbaeaktoreMelloaT. TYPICAL PHYSICAL PROPERTIES t with HIO based on the Irate required for the Note; OB Safe Aft® concentrate contains iron control agents and de-mulsiAexa. No organic acid orcorroelon inhibitors are required due "a power of ourpotentedSyntech®. A typical ratio for unsold fno is ons part OB Safe AHA and one pmt &O. Blending ratios maywry based on apecWc applications and recommendations from your consul tanto at Hea r band Energy I STOMGEAND HANDLINGt Motu AWhas a storage We olbetter than one year. Keep Conlainerclosedwhennotinuse. As With all chemlcalproducts andnmteriala,takeoaceealowhmeyoustorethem. Safety glasses are auggeatedfor usewhenhand8ng Ddsproducl. No special gloves, orprotectlw equipment are requlredwhen handling this product. WItanpumping tlds product, It iealrongly rowmmendedto we mmufaclwerapprmedlt sowupiingsorfillings.DDNOTUSE ALUMINUM PIWINOS. 316 Stainless Steel, polypropylene, polyethylene are recommended, aNppedinbul tankertruckstromthe faostly. SmaBerpackeging quantities are available Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Tuesday, May 21, 2019 9:09 AM To: Dan Marlowe Cc: Schwartz, Guy L (CED); Juanita Lovett; Holly Tipton Subject: RE: Monopod A-25rd PTD 188-137 Dan, Approved for monitoring and diagnostics as per below. If the MITIA fails I would anticipate Hilcorp to come up with the repair scenarios to get a passing MITIA, rather than look to a temperature survey for ongoing operations. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7t" Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(@alaska.¢ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Monday, May 20, 2019 9:58 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com>; Holly Tipton <hotipto n @hilcorp.com> Subject: Monopod A-25rd PTD 188-137 Chris Seems like we might have some Tubing by IA communication with this well. We'd like to get some approved diagnostic time with this well. Keeping the well shut down, we'd like to perform a MIT -IA and then bring the well back online for no more than a month to further monitor the IA pressures as the increase may just have been strongly thermal. If the MIT -IA is not successful, then bringing this well back online will allow us to establish an accurate downhole thermal profile to hopefully prove the water is going where it's supposed to be going with a temp survey. Please let me know if you would like anything additional to consider this request. Attached are the well's schematic and 90 day TIO plot. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 07,2017 TO: Jim Regg r7 P.I.Supervisor ��y�73 �(( 7 SUBJECT: Mechanical Integrity Tests C HILCORP ALASKA LLC A-25RD FROM: Lou Grimaldi TRADING BAY ST A-25RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ii(Z NON-CONFIDENTIAL Comm Well Name TRADING BAY ST A-25RDAPI Well Number 50-733-20242-01-00 Inspector Name: Lou Grimaldi Permit Number: 188-137-0 Inspection Date: 3/2/2017 Insp Num: mitLG170304102900 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-25RD Type Inj W TVD 4466 Tubing 1000 1000 - 1000 - 1000 . PTD 1881370 Type Test SPT Test psi 1650 - IA 0 1650 - 1650 - 1650 - - BBL Pumped: I BBL Returned: I OA 20 25 - 25 - 25 Interval 1 INITAL P/F P Notes: Good initial test of recent workover.All required paperwork supplied by operator. ✓ % QED APR 2 8 K117 Tuesday,March 07,2017 Page 1 of 1 STATE OF ALASKA Alt OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Performed: Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Replace Tubing 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 188-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20242-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-25RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools 11.Present Well Condition Summary: RECEIVED Total Depth measured 8,730 feet Plugs measured N/A feet true vertical 6,071 feet Junk measured N/A feet MAR 9 $ ?Du Effective Depth measured 8,675 feet Packer measured 6,477&6,530 feet .r true vertical 6,028 feet true vertical 4,436&4,467 feet �+' +�« Casing Length Size MD TVD Burst Collapse Structural Conductor 214' 20" 214' 214' Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Production 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 6,658-8,622 feet 5C,ANNEO APP 0 3 20 I? True Vertical depth 4,542-5,986 feet 3-1/2" 9.2#/L-80 6,519'(MD) 4,461'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 6,541'(MD) 4,473'(TVD) D&L Hyd Iso Pkr 6,477'(MD)4,436'(TVD) Packers and SSSV(type,measured and true vertical depth) FB-1 Pkr 6,530'(MD)4,467'(TVD) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1789 1938 1938 Subsequent to operation: 0 0 746 47 1626 14.Attachments(required per 20 PAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 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: 317-032 Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature '61.40. 4• Phone (907)777-8356 Date 314 I Lo(l L 1�� - 1 RBDMS Lt 3sry .t� 7 Form 10-404 Revised 5/2015 yet. ,�y�� """ _ LU I/ Submit Original Only Monopod Platform . H SCHEMATIC • Well: A-25RD (Inj) PTD: 188-137 API: 50-733-20242-01 Completed: 02/13/2017 RKB to TBG Head=37.73' CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. L20" Conductor Surf 214' a 13-3/8" 61# K-55 Butt 12.515" Surf 1,317' 9-5/8" 47# N-80 Butt 8.681" Surf 1,366'TOW 7" 29# N-80 Butt 6.184" Surf 8,726' TUBING DETAIL 3-1/2" 9.2# L-80 IBT/Mod 2.992" Surf 6,519' E , 3-1/2"IPC 9.3# N-80 DSS-HTC 2.992" 6,511' 6,541' Z JEWELRY DETAIL NO. DMthepth D DTVD ID OD Item 1 37.73' 37' 2.992" 6.250" Tubing Hanger i. 2 6,477' 4,436' 4.000" 5.870" D&L Hydraulic Isolation Packer 3 6,498' 4,448' 2.813" 4.430" X Nipple 6,510' 4,455' 4.000" 4.500" Non-Sealing Overshot 4 6,511' 4,456' 2.992" 3.500" E-Line Cut(7.5'swallow with overshot) 6,519' 4,461' 4.000" 5.750" Bottom of Cut Lip Guide 6,529' 4,466' 2.98" 4.25" Baker Locating Sub 6,530' 4,467 2.98" 3.986" Baker Seal Assembly 11'X 3.986"X 2.98" 5 6,541' 4,473' 2.98" Mule Shoe on bottom of seal assembly 6,530' 4,467' 4.000" 5.875" Baker Model FB-1 Packer 7",29# X 4" 6,532' 4,468' 4.000" 5.016" Baker Seal Bore Extension 6,541' 4,473' 2.937" 5.687" Crossover 3-1/2"DSS X 3-1/2"8rd.box 6,542' 4,474' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint 2 6� 6 6,545' 4,476' 2.750" 4.00" Otis'X'Nipple 6,546' 4,476' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing 13 3 7 6,575' 4,493' 2.937" 5.25" Wireline Re-entry Guide 4 5 • K6 Perforation Detail 11111 II Sand Top Btm Top Btm Accum Last Present (MD) (MD) (TVD) (TVD) Amt SPF Perf Date Condition 7 C-7 6,658' 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open 8 C 51-6 7,788' 7,828' 5,320' 5,351' 40' 20' 10/4/2015 Open C 51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open C D 53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open Zone D 53-8 8,072' 8,085' 5,546' 5,556' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 5,602' 5,614' 16' 8' 4/1/1989 Open D 54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open D, D 55-7 8,263' 8,303' 5,698' 5,731' 40' 8' 4/1/1989 Open Zone D 56-1 8,346' 8,463' 5,765' 5,859' 117' 8' 4/1/1989 Open D 57-2 8,502' 8,622' 5,890' 5,986' 120' 8' 4/1/1989 Open /1 \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 03/01/17 by JLL • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Monopod Rig 56 50-733-20242-01 188-137 2/5/17 2/14/17 Daily Operations: 02/05/17-Sunday Rig and crane crews and WSMs at heliport awaiting transportation to Monopod. 1130 hrs all personnel loaded onboard. M/V then departed for platform arriving at 13:30 hrs. Personnel gathered for platform briefing from J Lee, tool pusher and WSM. Uncovered drawworks, ST80 and driller's console. Began clearing and organizing rig floor, pulled rotary table cover (cautioning off area)then hooked up brushes on traction motor, bolted hatch on cuttings tank, put plugs in centrifugals in pit area and reserve tank, began dressing mud pump#1 w/4.5" liners. Began installing 6" liners in#2 mud pump- hung bridge cranes. Pressures: 3-1/2"=0 PSI, 7"=0 PSI, 9-5/8"= 67 PSI, 13-3/8"= 0 PSI. 02/06/17- Monday Continued working on mud pumps,filled hydraulic reservoir, R/U hoses and power lines to hydraulic unit, prepped tuggers and rigging to move TD support rail out of way. Rig floor and cellar cleaning ongoing. Finished dressing#2 mud pump with 6" liners, filled rod wash,tested hyd pump, continued cleaning and organizing pump room mixing area- raised TD support rail and secured- began staging BOPs in cellar,fired up drawworks and tested same. N/U and suspended BOP stack, function tested mixers, charge pumps and agitators, transferred fluid from pill pit to active, staged hyd jacking unit. Brought Pollard EL unit onboard w/crew and perf tools. Held PJSM with prod, crane and rig crews, skidded rig over A-25 well. Pressures: 3-1/2"=0 PSI, 7"=0 PSI, 9-5/8"= 67 PSI, 13-3/8"= 0 PSI. 02/07/17-Tuesday Finished with rig move to A-25RD, secured clamps on both sections. R/U EL unit w/full lubricator, prod pressured tested same to 1,500#s. Replaced/installed handrails as needed around rig and facility (after move). ELine Run#1 TIH w/ 1' 0 phase 1-9/16" RTG Idd 5 SPF (rollers in tool string) to 6,530', pulled correlation stri,p_andperfed 6470'-_6,480', P.QOH and rigged to side. Rigged up circulating hose to pump down tb taking returns from 7" annulus to production.Tested circ lines to 800 PSI. Circulated hole volume at 2.8 BPM 1,100 PSI, stopped circ 0 PSI on tbg & casing. R/D E-Line. M/U high pressure mud line, hung SRLs in derrick and performed derrick inspection, hung blower truck for drawworks. R/U accum lines in cellar and deluge fire suppressant to rig, prepped to string up/change out traveling block. Swapping drill line from TD block to conventional block. 02/08/17-Wednesday Installed drill line to drawworks. Slipped 40' of line onto drum, wrapped dead man and secured clamps. Unhung blocks and laid out TD block. P/U kelly w/shuck and set in place. Began working on rig heaters. Finished securing kelly& shuck. Hookup heater truck to rig floor, hung divider blanket in cellar, began laying out accum lines. R/D circ line from top of tree after checking well. Broke off swab valve and NOS rep set BPV then worked tb head. Began breaking corroded bolts at tb head. M/U choke and kill valves on mud cross. M/U 11" adapter to 13 5/8" risor. Hung flow line for gas buster and flow nipple. Continued N/D tree. 1330 hrs lifted tree from cellar. Cleaned threads in hanger, around body and ring groove. M/U 3 1/2" 8rd test sub in hanger, lowered and bolted riser w/ 11" adapter. Bolted up HCRs and manual valves on mud cross. Began dressing floor w/ handling tools and tongs. Pressures: 3 1/2"=0 PSI, 7"= 0 PSI, 9 5/8"= 67 PSI, 13 3/8"=0 PSI. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Monopod Rig 56 50-733-20242-01 188-137 2/5/17 2/14/17 Daily Operations: 02/09/17-Thursday Finished N/U 13 5/8" stack. Installed air boot flange on hydril. Hung BJ tongs, hooked up kill &choke lines. Finished hooking up accum lines. Hung hyd tb tongs, hung kelly spinner air hoses, chained stack off,function tested accum unit, hooked up Kelly hose. Installed mouse hole, setup test pump, setup trip tank, work on HP grease gun. Began gathering pipe and subs to rig floor for 3 1/2" test joint. 02/10/17- Friday Function tested tb tongs. Finished setting up handling tools on rig floor,greased choke manifold, rigged up trip tank and filled lines, tested trip tank flowline valve. M/U 3 1/2" test jt. Prod fired up steam system and checked all heaters and lines. Landed test jt w/assistance from NOS rep. R/U FIW to test pump. Continued rigging up pipe handling equip. Filled stack w/ FIW and shell tested then tested thru choke manifold valves 250 PSI low/3000,PSI high. Fired up second heater and ran truck lines as needed. Performed house cleaning in preparation for AOGCC rep to witness BOP test. 0400 hrs closed hydril on test jt and tested 250 PSI low/2500 PSI high. 02/11/17-Saturday Finished hydril pretest 250 PSI low/2500 PSI high. Filled choke manifold with FIW. Performed successful BOPE test 250 PSI low/3000 PSI high ( annular 2500 PSI high) as per Hilcorp and AOGCC requirements witnessed by Mr. Lou Grimaldi/AOGCC. PVT system not complete. CanRig tech working on active pit levels. Rigged down test pump and blew down choke manifold. R/U FIW to fill trip tank. Function tested TT pump,flow meter,TT G/L& PVT. B/D test jt and M/U landing jt. Had some difficulty backing out blanking sub from top of hanger. Pulled BPV and M/U landing jt into hanger. R/U manual TT gauge, bolted drip pan around risor. R/U drain hose and chained down mouse hole while CanRig tech continue work on pit 1 & 2 PVT, 1820 hrs PVT problem solved &tested. Picked up on string and hanger moved off tb head at 30k, worked pipe from 40k to 140k (max) in increasing_increments with no sign of seals pulling from pkr. Decision was made to R/U ELine. Pulled 20k over string weight and set slips, broke off pup and reinstalled SV. Began offloading 3 1/2" PH6 workstring from M/V. R/U Pollard ELine w/full lubricator,tested lub to 1500 PSI. ELine Run #1 TIH w/2 3/8" chem cutter w/2- 1 11/16" wt bars and 3- 2.77" rollers plus CCL&feed-thru jars to 6,494'. Logged down thru XA sleeve then set down at 6,509'. Had to shear jars to get free. P/U to 6,330'then recorded tb collars manually down to XA sleeve at 6,494'. P/U 2' and fired cutter at (,�C 6,500' (8' from CCL to cutting head) (all depths correlated to tb schematic). POOH. RTS. Picked up on string and cut, moved ./-"1 uphole at 62k. Rigged ELine down. Pulled hanger to surface and NOS rep worked same. Rig crew discussed JSA then began BSc POOH w/ recovered 3 1/2" DSS-HTC production tubing. 100 jts OOH at report time = 3,084'. 15 bbls FIW added to trip tank while POOH (10.4 bbls disp/4.6 bbls actual loss). • +• Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Monopod Rig 56 50-733-20242-01 188-137 2/5/17 2/14/17 Daily Operations: 02/12/17-Sunday Finished POOH w/ recovered 3 1/2" DSS-HTC production tubing from chemical cut-208 jts (6,440.16')+sliding sleeve (3.50') + 1-cut piece (9.31') + hanger w/ pup (4.09') + RKB (37.73') = 6,494.79 (PM). B/D XA sleeve off cut piece, cleared floor, strapped 1st row of workstring. M/U BHA#1 6" x 1 5/8" Varel rock bit, 5 1/4" x 1 1/2" casing scraper,4 3/4" x 2" bit sub, 5" x 2 11/16" X-Over= 7.86'. Serviced rig and fixed leak at valve body on hyd tongs.TIH w/ BHA#1 picking up 3 1/2" 12.95# P110 PH6 workstring off deck strapping, drifting and torqueing to 6200 FPT to 6,511' (PM).Tagged stub lightly w/ single#210 then P/U off same. Began onloading production string and hardware along w/Tripoint hand from M/V. M/U SV & pumpin sub. Lined up to pump LW then pumped 4250 stks (2 hole volumes) w/#2 pump @ 6 BPM 1230 PSI (minimal fine solids in returns at btms up). B/O line and blew down system. POOH racking back workstring in derrick. L/D BHA-70 stands in derrick. 02/13/17- Monday Finished L/D BHA, cleaned & cleared floor, prepped t/p/u completion. M/U non-sealing overshot w/extension, x-over, pup jt, X nipple, 2- pup jts, x-over, 5.870" perm hyd pkr,x-over on 10.10' pup= 52.68'. Changed out to McCoy tongs.TIH w/ pkr assy picking up 3 1/2" 9.3# L80 IBT/Mod production tb strapping, drifting and torqueing to mark on pin end. Checked P/U at 6,470'. P/U 64k S/O 40k.Tagged 18' in on single 205 = 6,520' (covered 7.5' of stub w/extension).Tripoint rep spaced out prod string w/slick jt under hanger pup. Landed hanger and NOS rep ran in hold-down pins. Lined up LW and pumped 165 bbls of FIW treated w/CRW132 corrosion inhibitor chased w/55 bbls clean FIW at 2 BPM (as directed by Tripoint) 270 PSI sending returns to production. Dropped prong and R/U test pump to pressure up on tb to set pkr. 02/14/17-Tuesday (?— t" Pressured upon tb to 3800#s to set Tripoint perm hyd iso pkr @ 6,477'. H Id for 30 mins then bled off. NOS rep packed off hanger. R/U on annulus and pressured up to 1500#s for 1 hr,go ed off pressure. R/U Pollard SL. M/U Run #1 and pulled inside lubricator,tested lubricator to 1500#s.TIH and retrieved prong, POOH. M/U Run #2 TIH and retrieved plug at 6,497', POOH. M/U Run#3 TIH running 2.25" gauge thru EOT at 6,575', POOH. R/D SL. Pulled landing jt and set BPV. Ran landing jt back in and blew down risor to flowline. Pulled landing jt. De-energized koomey lines and hooked cellar trolley cranes to BOPS, separated stack from risor, N/D risor and lifted to rig floor. Assisted production w/tree components while NOS rep tested tb hanger, 500#s f/5 mins 5000#s f/ 15 mins. Prepped hoses to circ well. Offloaded ESP equip, KCI and downhole equip from M/V. Assisted production w/tree components while NOS rep tested tb hanger, 500#s f/5 mins 5000#s f/ 15 mins. Prepped hoses to circ well. Offloaded ESP equip, KCI and downhole equip from M/V. Installed blind flanges, pulled BPV& installed 2-way check. Shell tested tree to 5000#s f/ 15 mins, solid test. Pulled 2-way check,finished N/U tree. Began preparation to skid to A-13. Removed flow lines, beaver slide, cat walk, cellar walkway, choke house walkway and handrails on N side upper deck. Removed heat trunk lines and cellar tarps. Turned well over to production at 0300 hrs. • 773aA-- (4) Regg, James B (DOA) f 9'i31 From: Larry Greenstein <Igreenstein@hilcorp.com> ��77 Sent: Wednesday, February 15, 2017 3:39 PM 1 / AC-1k To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA);Wallace, Chris D (DOA) Subject: MIT TBU A-25RD 02-14-2017 Attachments: MIT TBU A-25RD 02-14-17.xlsx;A-25RD Schematic 2017-01-18 PROPOSED Option B.doc Gentlepeople, Here is the WO MIT report for the newly recompleted Monopod A-25RD well performed on 2/14/17. As this MIT appears to show full mechanical integrity, our plans are to bring this well on injection by the middle of next week. Although the packer depth is estimated on the schematic, is shows that the required minimum test pressure of 1500 psi is more than adequate. The updated and accurate schematic will accompany the 404 reporting on the specifics of the WO. Thank you Larry r n,N SCANNED MAYI 1 to i • 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regct falaska.aov AOGCC.Insoectorsaalaska.aov' phoebe.brooks(cialaska.aov chris.wallacet alaska.ctov OPERATOR: Hilcorp Alaska,LLC I 1 I I �/ FIELD/UNIT/PAD: Trading Bay Field/Trading Bay Unit/Monopod Platform 2. ,rel• f DATE: 02/14/17 OPERATOR REP: Mike Foust/Harold Soule AOGCC REP: N/A Well A-25RD Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1881370' Type Inj N Tubing o 0 00 0 o Type Test P Packer TVD 4461 7 BBL Pump 0.1 ' IA o 1540 ' 1540 ` 1540 ' 1540 - 1540 " Interval , 0 Test psi 1500 BBL Return 0.1 - OA 65 65 65 65 65 65 Result P Notes: Workover MITIA with plug in X-nipple,TIW valve open to monitor tubing Flow (/ Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT TBU A-25RD 02-14-17slsri Monopod Platform • PROPOSED 0 Well: A-25RD (Inj) PTD: 188-137 API: 50-733-20242-01 Completed: FUTURE RKB to TBG Head=37.73' CASING DETAIL J L SIZE. WT GRADE CONN ID TOP BTM. 20" Conductor Surf 214' 13-3/8" 614 K-55 Butt 12.515 Surf 1,317' 9-5/8" 47# N-80 Butt 8.681 Surf 1,366'TOW 7" 29# N-80 Butt 6.184 Surf 8,726' TUBING DETAIL 3-1/2" 9.24 L-80 IBT/Mod 2.992 Surf ±6,520' L , 3-1/2"IPC 9.3# N-80 DSS-HTC 2.992 ±6,520' 6,494' L JEWELRY DETAIL NO. Depth Depth ID OD Item MD TVD 1 ±37.73' ±37' Tubing Hanger 2 ±6,480' ±4,461' Injection Packer 3 ±6,510' 2.813" X Nipple 4 ±6,520' Non-Sealing Overshot 5 ±6,520' 2.992" E-Line Cut 6,529' 2.98" 4.25" Baker Locating Sub 6,530' 2.98" 3.986" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly 6,530' 4.000" 5.875" Baker Model FB-1 Packer 7",29# X 4" 6,532' 4.000" 5.016" Baker Seal Bore Extentsion 6,541' 2.937" 5.687" Crossover 3-1/2"DSS X 3-1/2"8rd.box 7 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint 6,545' 2.750" 4.00" Otis'X'Nipple _ 6,546' 2.992" Joint of 3-1/2",9.34,N-80,IPC Tubing o 2 8 6,575' 2.937" 5.25" Wireline Re-entry Guide f 6 X 3 r 4 5 IBE 6 X 7 Perforation Detail 8 Top Btm Top Btm Accum Last Present = Sand (MD) (MD) (ND) (TVD) Amt SPF Perf Date Condition C-7 6,658' 6,824' 4,542' 166' 16' 3/4/2008 Open C C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open Zone C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open C 51-6 7,779' 7,828' 49' 8' _ 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' _ 13' 8' 4/1/1989 Open D 54-S 8,142' 8,158' 16' 8' 4/1/1989 Open 'D' D 54-9 8,187' 8,243' _ 56' 8' 4/1/1989 Open Zone D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open D 56-1 8,346' 8,463' _ 117' 8' 4/1/1989 Open D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open /1 \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 01/18/17 by JLL • IP' To we �\�yy�8 THE STATE Alaska Oil and Gas OfALAC}(A Conservation Commission 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ,SSP Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis . Operations Manager SC0453 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Trading Bay Field,Middle Kenai C and D Oil Pools, TBS A-25RD Permit to Drill Number: 188-137 Sundry Number: 317-032 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, 'K)1 Daniel T. Seamount, Jr. Commissioner DATED this3' day of January, 2017. RBDMS o - 3 2017 • • RECEIVED STATE OF ALASKA JAN 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing 0 - Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace Tubing, 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 188-137 - 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ ❑ + 6.API Number. Anchorage,AK 99503 50-733-20242-01 N 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A /hcN,,Ant. Will planned perforations require a spacing exception? Yes 0 No 0 I Trading Bay St A-25RD ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 - Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools 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): 8,730- 6,071 • 8,080 • 5,551 • 1,612 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 214' 20" 214' Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Production 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,658-8,622 • 4,542-5,986 3-1/2" 9.3#/N-80 6,494 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): FB-1 Packer ' 6,530'(MD)4,467'(ND) 12.Attachments: Proposal Summary El Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/15/2017 OIL ❑ WINJ 0 ' 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 Title Operations Manager Signature SL W Phone (907)777-8356 Date I ( 1lb (lo(7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness rundry Number: � ,-7- 032 Plug Integrity ❑ BOP Test Mechanical Integrity Test V Location Clearance ❑ s.- SE 113b la Other: th 33Ot-/'2 44 So1-t-.5 �) '+� !Ali t(1 G9'S c'.t2 m ( T--- I A U 'C 5-4-G- ( z c* - f k 1 G cJF ti, Post Initial Injection MIT Req'd? Yes Mr No ❑ V RBDIVIS , L---FEE.'3 - 3 2017 Spacing Exception Required? Yes ❑ No 5i Subsequent Form Required: / 0—Li 04-1 APPROVED BY /(3,777 Approved by: COMMISSIONER THE> COMMISSION Date: /AO- RploG A f' —` Submit Form and Form 10-403 Revised 11/2015 0 ai l tjtM i9 v id for 12 months from the date of approval. Attachments in Duplicate 1r s L.. 7 7/' • • Well Work Prognosis Well: A-25RD Ha�rP Alaska,►tc Date:01/18/2017 Well Name: A-25RD API Number: 50-733-20242-01 Current Status: Waterflood Injector Leg: NA Estimated Start Date: February 15, 2017 Rig: Rig 56 Reg. Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-137 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: 2,066 psi @ 4,542'TVD(6,658'MD) 0.455 psi/ft(8.75 ppg)survey 07/25/2015 Maximum Expected BHP: 2,066 psi @ 4,542'TVD(6,658'MD) 0.455 psi/ft(8.75 ppg)survey 07/25/2015 Max Potential Surface Pressure: 1,612 psi Using 0.1 psi/ft gradient per 20 MC 25.280(b)(4) Brief Well Summary • Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. This • project will restore tubing integrity. y'4 's live-.4.- Procedure: 1. Skid rig 56 and RU over A-25RD. 2. Open sliding sleeve or punch holes above packer and circulate any hydrocarbons off of well. Workover fluid will be FIW and salt as needed for well control. BOP's will be closed as needed to circulate the well. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. 4. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut.Circulate fluids from well. *Contingency if seals will not pull free from seal bore assy: RU E-line.Cut tubing in middle of first full joint above XA sleeye @ ±6,520'. POOH and RD E-line. 5. POOH, LD tubing. 6. RIH with bit and scraper to±6,520'. Circulate clean. POOH. 7. PU injection packer and tubing. RIH +1-6,520'. 1.0 8. Spot^'2%by volume Packer fluid on backside. 9. Space out and land the tubing hanger and set packer. 10. Conduct WO MIT, pressure test annulus to 1,500 psi and chart for 30 minutes. 11. Set BPV. NU tree,test same. 12. Place well on injection. 13. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection.,/ Attachments: 1. Wellbore Schematic Current 2. Wellbore Schematic Proposed 3. BOP Drawing 4. Wellhead Diagram Current 5. Wellhead Diagram Proposed 6. Fluid Flow Diagram 7. RWO Sundry Revision Change Form Monopod Platform III. 11 SCHEMATIC • Well: A-25RD (Inj) PTD: 188-137 API: 50-733-20242-01 Completed: 04/07/1989 API#50-733-20242-01 CASING DETAIL RKB toTBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. L20" Conductor Surf 214' 13-3/8" 61# K-55 Butt 12.515 Surf 1,317' 9-5/8" 47# N-80 Butt 8.681 Surf 1,366'TOW 7" 29# N-80 Butt 6.184 Surf 8,726' TUBING DETAIL L , 3-1/2"IPC 9.3# N-80 DSS-HTC 2.992 Surf 6,494' Z JEWELRY DETAIL NO. Depth Depth ID OD Item MD TVD 1 37.73' 37' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 4,446' 2.75" 4.25" Otis'XA'Sleeve 3 6,498' 4,448' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 4,466' 2.98" 4.25" Baker Locating Sub 5 6,530' 4,467' 2.98" 3.986" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 4,473' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4,467' 4.000" 5.875" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4,468' 4.000" 5.016" Baker Seal Bore Extentsion C 6,541' 4,473' 2.937" 5.687" Crossover 3-1/2"DSS X 3-1/2"8rd.box D 6,542' 4,474' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 4,476' 2.750" 4.00" Otis'X'Nipple F 6,546' 4,476' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing G 6,575' 4,493' 2.937" 5.25" Wireline Re-entry Guide Slickline/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. _ 2 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. 3 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. 4 A ; 5 C Perforation Detail D Top Btm Top Btm Amt Accum Last Present E X Sand F (MD) (MD) (TVD) (TVD) SPF Perf Date Condition C-7 6,658' 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open G C 47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open C 51-6 7,788' 7,828' 5,312' 5,351' 40' 20' 10/4/2015 Open C C 51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open Zone D 53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open D 53-8 8,072' 8,085' 5,546' 5,556' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 5,602' 5,614' 16' 8' 4/1/1989 Open D, D 54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open Zone D 55-7 8,263' 8,303' 5,698' 5,731' 40' 8' 4/1/1989 Open D 56-1 8,346' 8,463' 5,765' 5,859' 117' 8' 4/1/1989 Open f \ D 57-2 8,502' 8,622' 5,890' 5,986' 120' 8' 4/1/1989 Open PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 01/18/17 by JLL Monopod Platform • PROPOSED Well: A-25RD (Inj) , ll PTD: 188-137 API: 50-733-20242-01 Completed: FUTURE RKB to TBG Head=37.73' CASING DETAIL J L SIZE WT GRADE CONN ID TOP BTM. 20" Conductor Surf 214' 13-3/8" 61# K-55 Butt 12.515 Surf 1,317' 9-5/8" 47# N-80 Butt 8.681 Surf 1,366'TOW 7" 29# N-80 Butt 6.184 Surf 8,726' TUBING DETAIL ),' 9.21i L-80 IBT/Mod 2.992 Surf 3-1/2"IPC 9.3# N-80 DSS-HTC 2.992 ±6,520' 6,494' Z JEWELRY DETAIL Depth Depth NO. MD ND ID OD Item 1 ±37.73' ±37' Tubing Hanger �. 2 ±6,480' Injection Packer 3 ±6,510' 2.813" X Nipple 4 ±6,520' Non-Sealing Overshot (4. ¢..,*':j c 5 ±6,520' 2.992" E-Line Cut 6,529' 2.98" 4.25" Baker Locating Sub 6,530' 2.98" 3.986" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly 6,530' 4.000" 5.875" Baker Model FB-1 Packer 7",29# X 4" 6,532' 4.000" 5.016" Baker Seal Bore Extentsion 6,541' 2.937" 5.687" Crossover 3-1/2"DSS X 3-1/2"8rd.box 7 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint y 6,545' 2.750" 4.00" Otis'X'Nipple 4C,{pL1 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing 2 ` Vt., 8 6,575' 2.937" 5.25" Wireline Re-entry Guide X 3 P`"v 4 5 11, 118', ,/ - 6 X Perforation Detail Top Btm Top Btm Accum Last Sand Amt Present Condition ' 8 (MD) (MD) (ND) (ND) SPF Perf Date C-7 6,658' 6,824' 4,542' 4,642' 166' 16' 3/4/2008 Open _ C 47-5 7,062' 7,159' 4,790' 4,854' 97' 16' 3/4/2008 Open -'C' C 51-6 7,788' 7,828' 5,312' 5,351' 40' 20' 10/4/2015 Open Zone C 51-6 7,779' 7,828' 5,313' 5,351' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 5,448' 5,479' 38' 20' 10/3/2015 Open D 53-8 8,072' 8,085' 5,546' 5,556' 13' 8' 4/1/1989 Open D 54-9 8,187' 8,243' 5,638' 5,682' 56' 8' 4/1/1989 Open =,p, Zone I /1 N PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 01/18/17 by JLL • . 11 Mon pod Platform A-25RD Current 12/14/2015 Hilenrp:Ux.ka,1.11 . Monopod Tubing hanger,CIW-DCB- A-25RD FBB,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 7 X 3 1/2 and 3 1/2 DSS-HT susp, w/3"type H BPV profile, 6''4"EN-410SS BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 1.1 1.1 Valve,Swab,CIW-FL, ®� ,_ 3 1/8 SM FE,HWO,FF trim , p�� ° Valve,Wing,CIW FL, ll �./ 3 1/8 5M FE,HWO,FF trim 164::;41,C:#:$41 il iimis® ► ft Valve,Master,CIW-FL, 3 1/8 5M FE,HWO,FF trim .ox A`®r� Ifs (fTi ur a :Nil • , • Ii._ Tubing head,CIW-DCB, 13 5/8 3M X 11 5M,w/2- ill III Valve,WKM-M,2 1/16 5M 2 1/16 5M EFO,X-bottom ill 0 FE,HWO,AA prep w/1 4 VR profileiti; c : I Hi1110:(0')001 Ni.j., • lit 1 • -: 1.1.r. a•/ .I; Valve,CIW-F, Casing spool,CIW-WF, I i I -- 111 2 1/16 5M FE,HWO,AA 13 5/8 3M X 13 5/8 3M, '1IrIij III-I•'' 111 __ lei �I I Casing head,OCT-22, it 135/83MX13"SOW Iii --- — Iii bottom,w/2"LPO '® 2"LP plug valve ) _ MII SII■IMIsII� "El II • Monopod Platform A-25RD Proposed 01/23/2016 Hilmar.%ii..ka,LU Monopod Tubing hanger,CIW-DCB- A-25RD FBB,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 7 X 3 1/2 and 31/2 EUE susp,w/3" type H BPV profile, 6 W'EN-17-4SS BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I nI m III spoi: m Valve,Swab,CIW-FC, lk 3 1/8 5M FE,HWO,FF trim 41 -/ Valve,Wing,SSV,WKM-M, 3 1/8 5M FE,15"Safeco ' oper,FF trim 0 / NIIIK i. _ii._q Valve,Master,CIW-FC, op,et 3 1/8 5M FE,HWO,FF trim `•,, I st [Hl '. Tubing head,CIW-DCB, 13 5/8 3M X 11 5M,w/2- l- I Valve,WKM-M,2 1/16 5M 2 1/16 5M EFO,X-bottom ® : FE,HWO,AA ,jj :t :iIiIiu'? Iu .L.. . in ` �' Valve,CIW-F, Casing spool,CIW WF, ni � IIIi 2 1/16 5M FE,HWO,AA 13 5/8 3M X 13 5/8 3M, ivcom w/2-2 1/16 5M SSO I� ®/ 0 '_ L1- III _ r iii Casing head,OCT-22, 111 13 5/8 3M X 13"SOW III: — iii bottom,w/2"LPO 41 2"LP plug valve . •iiu1MIII i . lir • • Monopod Platform 2016 BOP Stack 10/24/2016 Hilrnrp Alnmkn.ILIA, Bottom of air boot flange Rig Floor A / 5'below rig floor 16" Pipe I l III I!I Ifni, 4.54' P" Hydril ° GK 13 5/8-5000 111 lit It 1111i1 111 111111 111 III 26.25' iNWE -- - 2 7/8 x 5 variable rams -I[�u © i 4.67' - ■ o—� - IIII 13 5/8 5M 6�' '—_ I11 111 111111 111 2 1/16 5M manual and 21/165M manual and 2.26' HCR valves for choke side 'CR valves for kill side � `^-� : :::::i: � E 111 111 Irl ill l!i Drill deck V Riser 13 5/8 5M FE X 135/85M FE 14.20' lit tit tit tit 1111 4110 11.1 111 111 111 1!1 13 5/8 5M FE X 1.41' • lit filtfl tlll • • 0 Vii^ i, O ° gd. °u O` i\ u 0 0 u u 0 u u 0 0 uu u u u u u 0 u u O v o 0 u u u 0 0 0 0 0 o u u O Se 1..r. c " 1 %_ O ED( I La,• f, `i u k V F f e a o.. .73 3 .. ,' ."Z .I'Z '� {{ � �rylQO EEEEdu i �. �. �. Fa 0�I „.. u mo V v.aavv000 °ts/ � e` ,fig �'� a`>muuvvuu uuvuuu i3i3 "Hu�cffEEaaa t Pii IA . t O m o -'I- •4-4k .-Liv I, CDC) - 000uuouuo 000000.000000000uu.o0000oo 114111 o N O ,Ithi0 fo€ iii!2 is _> fsookY ^S t ° E u n o 0 0 0 g.• O 1 $< mu 4> CoY; uuo, GuC6uuuuus3i3 -E i33 o ss (Do--; 0 ,I F a ; 9 o Q Ji 5 e'� v • V 2 > 6 P V a / ,1 > .0.,�°, - to ... N.- i- #. A :i IA 3G� - �a wu.1 a ...3 aim3 ! O. ., a 6r a 2 a _ 2 li1 . 11 3 _ 2 ill ! I a 3 € `aA e9 2' k �A �; m i z ;8 i fr. - - ,, Io - - a < m i -Q 3 � 38g 7 4 IR lE 7 x a E f a H L 54, A 0 e ! 1 Ad — V $ V I li a IE '1`- f i in #i DoE '14 4 i f swI dt l M0 4 4 o D I -�°F 1 i 0 _,, v„ • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LLCAttachment#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 flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static shooting fluid levels if necessary right before ND/NU. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test per standard Monopod Rig#56 BOPE test procedure. 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 2-way valve, or prepare lift-threads to accept landing 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 2-way check valve by hand, or MU landing(test)joint to lift-threads d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator 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: a) Nipple Up BOPE . • Monopod Rig#56 BOP Test Procedure Hilcarp Alaska,LLC Attachment#1 b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f) 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 and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same,and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. a. Open HCR1, HCR2,W1,&W2, all Choke valves except C15,open'A"valves above valve C16, remove sensor above C3,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 C5&C3. Continue to fill till fluid comes out 34"valves above C16,close valve C16&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. s • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Note: When testing, pressure up with pump to desired pressure,close MP1 and/or MP2 to trap pressure and read same with chart recorder. 2) Referencing the attached schematics test rams and valves as follows. a) Close W1 (inside gate valve on choke side of mud cross)and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open W1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each,as follows: (Valve numbers are in reference to Flow Diagram) i) Close pipe rams, Open Annular,test C3,C5, C15&C16, dart valve,4" demco kill line valve,t/ 250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests).After test, open same. ii) Close TIW open dart valve,C8, C9,C12,C13, C14, HCR2, open C15, &4" demco kill line valve (drain gas buster"U"tube immediately in freezing temps) iii) Close C1, C7,C10, C11,W2,open C8,C9, C12,C14, & HCR2 iv) Close C2, C4,C6,open valves Cl, C7, &C13 v) Close HCR1,open C2 vi) Close manual choke line valve,open HCR choke line valve e) Close HCR1. This is the HCR(the hydraulic controlled remote)valve just outside W1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR,close W1. f) Blind Rams. Make sure test ioint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). • I Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Back out test jt& pull,close blinds, install test hose to choke manifold outside valve C5,close valves C2,C4, C6, open valve C11, HCR1,&W1 10) If testing on multiple pipe sizes M/U 2nd test joint,close annular,fill test joint w/test pump till tiw/dart valve is full,then close,test 11) Close pipe rams,open annular,close tiw,open dart valve 12) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 13) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) 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. . 0 0 2 � ac2O @ = 0 £ k � 2 063 6 0T c 77 02e .q 0 2 0.a. § ) « E — co � 3 e 7 c F § I 0� co E » < £ k / 10) k � � �� > -0 i �� \ �\ a. gE % \ 2a a a 2 % � � 2 0 0 Wk % �.- Co W of 0 - 0 > CD I- � & V 2 g in � E ■ ■ » coo c0 Q 2 % � k13 $ L. E 'di © 2 $ • :a a I- 2/ <15 770) a) a)c §c 2 . Cl) w0 c W ,>. 2R c @@§ ce a § O a. e ■ « al0 0a. . 4Cd 2 § \ E 0 _2 Q $ R 2 » 0 ■ 11 2 0 f 0 Q x 7 � « it 0 ELI CD ii- p .. k % $ RI 0 E0 . § a O v k k 0 o. a_ • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, November 21, 2016 9:11 AM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#315-745 PTD: 188-137 -Trading Bay St A-25RD ..« . Juanita, AOGCC will withdraw sundry 315-745 as requested below. Regards, t. .,qqe Guy Schwartz ��®�� II Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALffY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent: Friday, November 18,2016 3:07 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#315-745 PTD: 188-137-Trading Bay St A-25RD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to pull completion, reperf and/or add additional C-ZN sands. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: ilovett@'hilcorp.com RBDMS !.L Jai 1 6 2017 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMM ION FEB 2 2 2016 3 . REPORT OF SUNDRY WELL OPERATIONS ,. ,'-,, 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Did not install patch U 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: /uta-_(A e_.;, ,',. Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 188-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service 2 6.API Number: Anchorage,AK 99503 50-733-20242-01 7.Property Designation(Lease Number): 8.Well Name and Number ADL0018731 Trading Bay St A-25RD 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools 11.Present Well Condition Summary: Total Depth measured 8,730 feet Plugs measured N/A feet true vertical 6,071 feet Junk measured N/A feet Effective Depth measured 8,080 feet Packer measured 6,530 feet true vertical 5,551 feet true vertical 4,467 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Perforation depth Measured depth 6,658-8,622 feet SC MA MAR 4 X016 True Vertical depth 4,452-5,986 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 6,494'(MD) 4,446'(TVD) Packers and SSSV(type,measured and true vertical depth) FB-1 Packer 6,530'(MD)4,467'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): ~ N/A nao(4' Treatment descriptions including volumes used and final pressure: /' tg N/A iiik) 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 0 200 Subsequent to operation: 0 0 1276 1532 1532 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 D Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSP❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLU4 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: 316-051 Contact Trudi Hallett(907)777-8323 Email thallettc(Dhilcorp.com Printed Name Stan W.Golis Title Operations Manager St Signature 1c. r(..-, Phone (907)777-8356 Date 2/3-Z /I(o / '-‘,74;`%(0 7‘ Form 10-404 Revised 5/2015 �� 'r' /2 / BDMS ( te FR L 3 2016 Submit Original Only 0 SCHEMATIC • Monopod Platform . in Well: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 I 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L \ JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" CeAK ? 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" III 2 3 4 Slickline/Fish/Fill Information: _ 3/3/08:Ran 2.262"GR and tag fill at 8080'. A 4 , 5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B I 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X Perforation Detail F Accum Last G " Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =,C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open D' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open A \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 10/08/15 by JLL ' • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Wireline 50-733-20242-01 188-137 2/1/16 2/7/16 Daily Operations: 02/01/2016- Monday- Revised from Weekly ON LOCATION - PRE-WIRELINE MEETING -JSA—PERMITS. RIG UP W/L- PT LUB- FAIL C/O 0-RING - PRESSURE TEST- 2000PSI—PASS. RIH W/3 1/2 BO SHIFTING TOOL WITH POSITIVE KEYS TO 6,492' KB TAG SLIDING SLEEVE IN DOWN POSITION. FLAG WIRE—POOH. RIH W/3" GS WI 3 1/2 AD-2 STOP TO 6,492' KB WT PASS NIPPLE, OOH WI SHEARED STOP. RIH WI SAME TO 6,499' KB WT-SET STOP. POOH. RIH W/3" GS W/WEATHERFORD PACKOFF PATCH (LOA- 14' - 12'1.5" ELEMENT TO ELEMENT)TO 6,499' KB WT SET PATCH—POOH. RIH WI 3" GS WI A-STOP TO 6,485' KB WT SET STOP—POOH. SECURE WELL- RETURN TO PRODUCTION FOR MIT. Pressured up 7" casing to 1650 p.s.i. bled down to 1470 p.s.i. one hour burped well. Re-pressured to 1650 bled down to 1480 p.s.i. one hour. Rigged down pressure equipment and prepare to pull patch on 2/3/16. 02/02/16 Tuesday- Revised from Weekly ATTEND MORNING MEETING -JSA--PERMIT. RIG UP W/L. RIH WI 3" GS TO 6,485' KB WT LATCH A—STOP. POOH. OOH W/A—STOP. RIH WI 3" GS TO 6,487' KB SET DOWN.TAP DOWN TO ENSURE ELEMENTS ARE SET. POOH. STANDBY FOR MIT. MIT FAILS. BLED OFF 90-150 PSI OVER 4 PRESSURE TESTS. RIH WI 3" GSTO 6,487' KB WT TO LATCH PATCH. PULL TO RELEASE ELEMENTS. ALLOW PRESSURE ON BACK SIDE TO BLEED OFF. RESET PATCH. POOH. STANDBY FOR MIT. FAILS PRESSURE TEST. RIH W/3" GS TO 6,487' KB WT LATCH PATCH. POOH. OOH W/ PATCH. RIH W/3" GS TO 6,499' KB WT PULL AD-2 STOP. OOH W/STOP. RIG DOWN W/L. STANDBY FOR TOOLS. RIG UP W/L. RIH W/3" GS WI AD-2 STOP TO 6,504' KB WT. SET AD-2 STOP. POOH. RIH WI 3" GS W/ PATCH (12' 6" LOA)TO 6,504' KB WT. SET PATCH, POOH. RIH WI 3" GS WI TOP PATCH PIECE (13' LOA) 6,592'KB WT. STAB INTO BOTTOM PATCH—SET. POOH. RIH WI 3" GS W/A-STOP TO 6,529' KB WT, SET STOP. POOH. RIG DOWN W/L. SECURE WELL. RETURN TO PRODUCTION FOR MIT. CLOSE OUT PERMITS AND STANDBY FOR MIT. PERFORM MIT PRESSURE TEST. 02/05/2016- Friday ATTEND MORNING MEETING -TGSM - PERMITS-JSA. SKID RIG. RIG UP W/L- PT LUB 2000 PSI -GOOD. RIH WI 2.5" JDC WI DD HOLE FINDER TO 6,480' KB SET DD HOLE FINDER. STANDBY FOR PT. PRESSURE TEST TUBING TO 500. HOLD FOR 15 MIN - PASS. PRESSURE TEST AT 1650 PSI - PASS. POOH. RIH WI 3" GS TO 6,480' KB LATCH -A-STOP- POOH. OOH W/A-STOP. RIH W/3" GS TO 6,482' KB WT LATCH PATCH - POOH. RIH W/3" GS TO 6,491' KB LATCH PATCH PIPE- POOH._OOH W PATCH. RIH WI 3" GS TO 6,504' KB WT LATCH AD-2 STOP- POOH. SKID RIG OVER WELL-TO SAFELY HANDLE 20' PATCH PIECES. RIG UP W/L . PT LUB 2000 PSI -GOOD. RIH W/3" GS WI AD-2 STOP TO 6,492' KB BOBBLE THROUGH SLIDING SLEEVE -CONTINUE IN HOLE TO 6,535 ' KB-SET DOWN, WT TO PASS. FALL TO 6,541' KB COULD NOT PASS. SHEAR AD-2 STOP. RIG DOWN W/L. SECURE WELL. CLOSE OUT PERMIT. • 1110 H i lcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Wireline 50-733-20242-01 188-137 2/1/16 2/7/16 Daily Operations: 02/06/2016-Saturday ATTEND MORNING MEETING -TGSM -JSA- PERMIT. LUBRICATOR WAS NOT BROKE OFF WELL-THEREFORE NO PRESSURE TEST REQUIRED. RIH W/2.75" BRAIDED LINE BRUSH TO 6,492' KB. FALL THROUGH SLIDING SLEEVE -TO 6,543' KB. BOBBLE THROUGH X NIPPLE. BRUSH FROM 6,490' KB- 6,555' KB FOR 30 MINS- POOH. RIH W/3" GS WI AD-2 STOP TO 6,540' KB WORK PAST SEAL BORE ASSEMBLY. SHEAR AD-2 STOP AND GS AT 6,555' KB (NEED TO SET AT 6,546' KB) POOH. RIH WI 3" GS TO 6,555' KB WT LATCH AD-2 STOP. PULL UP HOLE TO 6,548' KB WT SET STOP- POOH. RIH WI 3" GS W/ PATCH 23' 3.75" LOA TO 6,548' KB (TOP OF PATCH AT 6,525' KBI SET PATCH POOH. RIH W/3" GS WI PATCH LOA 21'11"TO 6,525' KB (TOP OF PATCH 6,503' KB) WT SET PATCH POOH. RIH WI 3" GS W/PATCH LOA 21'10" to 6,503' KB WT-COULD NOT SHEAR- POOH. OOH WI GS PIN HALF SHEARED. REDRESS WEATHERFORD PACKOFF. RIH WI SAME TO 6,503' KB WT SET PATCH - POOH. RIH WI 3" GS W/A-STOP TO 6,481' KB WT SET STOP- POOH. RIG DOWN W/L-SECURE WELL-STANDBY FOR MIT. CLOSE OUT PERMITS. L 02/07/2016-Sunday- Revised from Weekly ATTEND MORNING MEETING -TGSM - PERMITS—JSA. STANDBY FOR SECOND MIT—FAIL. PUMPED DOWN BACKSIDE TO 500 PSI - 15 MIN.TUBING AND ANNULUS EQUALIZED AT 300 PSI. RIG UP WL. RIH W/3" GS TO 6,481' KB WT LATCH A—STOP, POOH. OOH W/A—STOP. RIH WI 3" GS TO 6,482' KB WT LATCH TOP PATCH PIECE, POOH. OOH W/ PATCH. RIH WI 3" GS TO 6,503' KB WT LATCH MIDDLE PATCH PIECE, POOH. OOH W/ PATCH. RIH WI 3" GS TO 6,526' KB WT LATCH BOTTOM PATCH PIECE, POOH. OOH W/ PATCH. RIH WI 3" GS TO 6,548' KB WT LATCH AD-2 STOP, POOH. OOH W/AD-2 STOP. RIG DOWN W/L. RETURN WELL TO PRODUCTION. CLEAN AREA AND STAGE EQUIPMENT. taoF Tk ewP�� I//7,,s THE STATE Alaska Oil and Gas ��►,-z-��, OfA L /` SKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis MED FEB 0 8 ZOlb Operations Manager I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C and D Oil Pools, Granite Pt St A-25RD Permit to Drill Number: 188-137 Sundry Number: 316-051 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. Foerster Chair DATED this ZS day of January, 2016. RBDMS JAN 2 9 2016 0 • RECEIVED STATE OF ALASKA ns 104{6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Ll Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Patch ' II 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC • Exploratory ❑ Development ❑ 188-137 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service U. 6.API Number. Anchorage,AK 99503 50-733-20242-01 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 ❑1 Trading Bay St A-25RD 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0018731 , Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools . 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): 8,730 6,071 . 8,080 ' 5,551 -1458 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Production 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,658-8,622 • 4,452-5,986 3-1/2" 9.3#/N-80 6,494 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): FB-1 Packer - 6,530'(MD)4,467'(TVD) 12.Attachments: Proposal Summary 2 Wellbore schematic [] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service E 14.Estimated Date for 15.Well Status after proposed work: 2/8/2016 Commencing Operations: OIL ❑ WINJ U ; 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 Trudi Hallett(907)777-8323 Email thallett( hilcorp.com Printed Name Stan W.GolisTitle Operations Manager Signature t-+ (44 Phone (907)777-8356 Date 1 I Z 5 1 l Co , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number -''S 3 Lt — 0 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test wi Location Clearance El Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /b ^ 11 O`-/ pAPPROVEDBY /—2 --C 6 Approved by: COMMISSIONER THE COMMISSION Date: -i -fiw r^/� NAL i4a j�.�IS. RBDMS G JAN Z 9 2016 tSubmiForm ane For 10-ao3 Revised 11/2ot5 ® Al V e valid for 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis Well: A-25RD Hileorp Alaska,LLC Date: 1/25/2016 Well Name: A-25RD API Number: 50-733-20242-01 Current Status: Waterflood Injector Leg: NA Estimated Start Date: 2/8/2016 Rig: NA Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-137 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 2066 psi @ 4,542' TVD (6,658' MD) Based on pressure survey 7/25/2015 Maximum Expected BHP: 2066 psi @ 4,542'ND (6,658' MD) Max Potential Surface Pressure(MPSP): ^'1458 psi Using 0.1psi/ft gradient form top proposed perforation @ 4108'ND (5,880' MD) (20 AAC 25.280(b)(4) Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. Wellbore diagnostics indicates that the "XA" sleeve is leaking.This job entails running a tubing patch to isolate the sleeve in order to regain integrity.''However, if the initial patch just isolating the XA sleeve does not remediate the leak, a longer patch will be run and set just above the X-Nipple. Procedure: 1. Rig up slick line and pressure test lubricator to 1,500 psi. 2. Make initial drift and tag run w/2.5" GR. POOH. 3. RIH w/tubing patch to+/-6,490'to +/-6,510' (WLM). 4. Pressure test patch. 5. Rig down slick line and lubricator. 6. Conduct in house MIT, pressure test annulus to 1,500 psi and chart for 30 min. • Contingency Plan if the leak is still present: 1. Rig up slick line and pressure test lubricator to 1,500 psi. 2. Pull patch at+/-6,490'to +/-6,510'. 3. Re-run extended patch to+/- 6,490'to+/-6,540' (WLM). 4. Pressure test patch. 5. Rig down slick line and lubricator. 6. Conduct in house MIT, pressure test annulus to 1,500 psi and chart for 30 min. 7. If successful MIT, place well on injection continuously monitoring pressures and rates. 8. Schedule initial MIT with AOGCC as well as a temperature profile log within 2 weeks of stable injection. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 0 SCHEMATIC Monopod Platform Well: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 1.. 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" ... C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#, N-80,IPC Tubing /i S le G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" 2 • 3 4 <AA14,.... Slickline/Fish/Fill Information: N3/3/08:Ran 2.262"GR and tag fill at 8080'. A = 5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B \ l 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X Perforation Detail F Accum Last G N Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =,C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open - D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open _ D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open _= D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open 'D' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open ,1 \ PBTD=8,675' TD=8,730' MAX. HOLE ANGLE =65 ° Revised: 10/08/15 by.ILL ~ PROPOSED Monopod Platform Well: A-25RD (Ind) en As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' Z , JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" j 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing Patch G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" ±6,490 111111 2 ±6,510 3 4 Slickline/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. A = a • = 5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B ",/ 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X Perforation Detail F Accum Last G" Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open = C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open _ D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open • D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open p' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open EE A \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 01/21/16 by 1LL • • t 1 of TBS, 0,14 I//7. tv THE STATE Alaska Oil and Gas � of TAsKA Conservation Commission 333 West Seventh Avenue T. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Th. Main: 907.279.1433 OF ALA6 ' Fax: 907.276.7542 www.aogcc.alaska.gov r-Cr 00't+ 1 2.'3% Stan Golis Operations Manager 3 �f Hilcorp Alaska, LLC I 3800 Centerpoint Drive, Suite 1400 u Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C and D Oil Pools, Trading Bay St A-25RD Sundry Number: 315-745 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, P.),e,(17L,- Cathy . Foerster Chair DATED this GT day of December, 2015 Encl. RBDMSLIDEC 2 9 2015 • • RE DEIVED STATE OF ALASKA DEC 14 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 12/23/LS APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well O Operations shutdown L: Suspend ❑ 1,,j3 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ELI Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Inlection U Completion 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ 188-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service Ei. 6.API Number. Anchorage,AK 99503 50-733-20242-01 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 93B • Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ Trading Bay St A-25RD • 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools 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): 8,730 . 6,071 8,080. 5,551 • 1,458 psi ^ N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,658-8,622 . 4,452-5,986 3-1/2" 9.3#/N-80 6,494 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): FB-1 Packer , 6,530'(MD)4,467'(TVD) 12.Attachments: Proposal Summary El Wellbore schematic D 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/29/2015 OIL ❑ WINJ I] - 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 Trudi Hallett(907)777-8323 Email thallett@hilcorp.com Printed Name Stan W.GolisTitle Operations Manager Signature ,_, "" ` 3 ( >. Phone (907)777-8356 Date `2- I 11-1 11S- COMMISSION 1S- COMMISSION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number 3I5 --ry5 Plug Integrity ❑ BOP Test V Mechanical Integrity Test Location Clearance ❑ Other: X Lj,4 e.-�.s AA-('T- /A q,4-(-- r s-'+F.�s4-z.., ..GKJ + C.1 pzo-kcb" �4,. '` 3000 �s. e 'j r feu. :.1 _&c_ Post Initial Injection MIT Req'd? Yes No ❑ 51- �,/ re-s- Spacing Exception Required? Yes ❑ No LX" Subsequent Form Required: /6 .y6 t Lel-, APPROVED BY Approved by: P COMMISSIONER I THE COMMISSION Date: /2-24—/S� l�� OrR,fG4cPl4nAv1li , �I~� '�/ J (Z�y�� Submit Form and Form 10-403 Revise /2015 d for 12 months iig� 6LO�apprgy .2015 Attachments in Duplicate • • Well Work Prognosis Well: A-25RD Hilcorp Alaska,LLC Date: 12/14/15 Well Name: A-25RD API Number: 50- 733-20242-01 Current Status: Waterflood Injector Leg: NA /4"- Estimated Start Date: December 29, 2015 Rig: ICk #E 56 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-137 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 2066 psi @ 4,542'TVD (6,658' MD) Based on pressure survey 7/25/2015 Maximum Expected BHP: 2066 psi @ 4,542'TVD (6,658' MD) Max Potential Surface Pressure(MPSP): "' 1458 psi .7 Using 0.1 psi/ft gradient from top proposed perforation @ 4,108'ND (5,880' MD) ( 20 AAC 25.280(b)(4) Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. This project will pull current completion, reperf and/or add additional C-ZN sands to increase injectivity in the main II-A Fault Block. Procedure: tt5t. 1. Skid rig and RU over A-25RD. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,00_ 0 psi HIGH. 3. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate fluids from well. M.° *Contingency if seals will not pull free from seal bore assy: RU E-line. Cut tubing in middle of first full joint above XA sleeve @ ±6, 80'. POOH and RD E-line. 4. POOH, LD tubing. 5. RIH latch onto tubing stub above upper packer. � 6. POOH with seals and LD tubing. {` r 7. Mill and retrieve upper injection packer. 7 8. Clean out 7" csg to PBTD @ ±8,675'. Circulate with FIW to clean wellbore. POOH. M frt. C 3 9. PU retrievable test packer and RIH to ±5,800'. Set packer, test casing to 2,500 psi and chart for 30 minutes. 10. POOH 200' and PU storm packer. RIH and set same at 200' and hang off string. Pressure test to 1,500 psi and chart. Release from storm packer, POOH. Replace tubing head. ,f- -Fest 6/0-7, 11. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. grL4:t-s 12. PU TCP guns and RIH and perforate per Perf Recommendations. 13. After detonation, circulate perf gas, confirm well is static, POOH. 14. PU injection packer and tubing. RIH +/-5,800'. • Well Work Prognosis Well: A-25RD Hilcorp Alaska.GCC. Date: 12/14/15 15. Spot 1-2% by volume Packer fluid on backside. 16. Land the tubing hanger and set packer. 17. Conduct WO MIT, pressure test annulus to 1,500 psi and chart for 30 minutes. 18. Set BPV. NU tree, test same. 19. Place well on injection. Well is expected to take between 4,000 and 5,000 bwpd at full header pressure and new perforations. / 20. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. ✓ e- / r trt—:x-c t?„,_ Attachments: 4"6.1b„,_ ,- .,_ 5 7 C' 4_ ' `�1 • 1. Current Wellbore Schematic J 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. Proposed Wellhead Diagram 6. Fluid Flow Diagram 7. RWO Sundry Revision Change Form i` SCHEMATIC • Monopod Platform Well: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: / J \ 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. , 2 6,494' 2.75" 3-1/2" Otis`XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" iMi 2 1. 3 4 ( Slickline/Fish/Fill Information: E. 3/3/08:Ran 2.262"GR and tag fill at 8080'. A _ = _ 5 Si)J 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B ce 6 /iT)� 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D i.../0) E al Perforation Detail F Accum Last GIM1Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open .,C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open 'D' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open /1 \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 10/08/15 by JLL • PROPOSED •! Monopod Platform . 11Well: A-25RD (Inj) As Completed: Future API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 4-1/2"TK-69 Coated 12.75 L-80 Hydril 53311 3.958" Surf ±5,840' Z JEWELRY DETAIL NO. Depth ID Item 1 37.73' Tubing Hanger 2 ±5,800' Packer 3 ±5,830' 'X'Nipple 4 ±5,840 Wireline Re-entry Guide Slickiine/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. Perforation Detail Accum Last iB 00 Sand Top Btm Amt SPF Perf Date Present Condition 2 > C-1 ±5,880' ±5,966' ±86 Future C-2 ±6,056' ±6,085' ±29 Future C-5 ±6,289' ±6,404' ±115 Future 3C-7 ±6,658' ±6,824' ±166' Re-perf Open C-7 ±6,856' ±6,890' ±34 Re-pert 4 C 47-5 ±7,062' ±7,159' ±97' Re-perf Open C 48-7 ±7,264' ±7,284' ±20' Future C 50-0 ±7,473' ±7,486' ±13' Future CZNS2 ±7,564' ±7,575' ±11' Future _.C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 ±7,779' ±7,828' ±49' Re-perf Open D 53-0 ±7,949' ±7,986' ±37' Future D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 ±8,072' ±8,085' ±13' Re-pert Open D 54-5 ±8,142' ±8,158' ±16' Re-pert Open D 54-9 ±8,187' ±8,243' ±56' Re-pert Open D 55-7 ±8,263' ±8,303' ±40' Re-pert Open 'D' D 56-1 ±8,346' ±8,463' ±117' Re-pert Open Zone D 57-2 ±8,502' ±8,622' ±120' Re-pert Open A \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 12/14/15 by J LL r • , nMonopod Platform A-25RD Current Hivup:Nadi.,LL(. 12/14/2015 Monopod Tubing hanger,CIW-DCB- A-25RD FBB,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 7 X 3 1/2 and 3 1/2 DSS-HT susp, w/3"type H BPV profile, 6''A"EN-41055 BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union 1.1 ..t 114,z b Valve,Swab,CIW-FL, 3 1/8 5M FE,HWO,FF trim ' '" j$1°-St Valve,Wing,CIW-FL, 3 1/8 5M FE,HWO,FF trim N / •�1/16, [®/j® 0,, Valve,Master,CIW-FL, ® � 3 1/8 5M FE,HWO,FF trim d we (ID ® ff1l [ Tubing head,CIW-DCB, _ 13 5/8 3M X 11 5M,w/2- �� ISI Valve,WKM-M,2 1/16 5M 2 1/16 5M EFO,X-bottom : FE,HWO,AA prep w/1'/VR profile illif •N 1 (opellIU.I..I•I • I i I IIII ��ll 5. Valve,CIW-F, Casing spool,CIW-WF, IIIA ' ISI 2 1/16 5M FE,HWO,AA 13 5/8 3M X 13 5/8 3M, '� ��a "- 4 w/2-2 1/16 5M SSO ill II I (cfreAl �II-U' III IU 111 ie a." Casing head,OCT-22, al li 135/83MX13"SOW III III bottom,w/2"LPO 0 2"LP plug valve 0 III 1114111141E, 0 • , llMonopod Platform A-25RD Proposed 12/14/2015 H lrnrr tasku.I.IS: Monopod Tubing hanger,CIW-DCB- A-25RD FBB,11 X 4 1/2 EUE lift 133/8X95/8X7X41/2 and 4'''AEUE 8rdsusp,w/ 4"type H BPV profile, 6''A"EN-17-4PH material BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel 11 1.1 ■ 1.1 111.11 IOW II1L ,111 'PP bilk Valve,Swab,CIW-FC, „ o 41/16 5M FE,HWO,FF trim ff`, Valve,Wing,WKM-M, � 3 1/8 5M FE,w/15"Safeco 111r - 11.1./� operator,FF trim Full Stainless Steel 0 Valve,Master,CIW-FC, ®®(, 11 4 1/16 SM FE,HWO,FF trim , � 11741111110.1111 In all . . Tubing head,CIW-DCB, , Hi.. 13 5/8 3M X 11 5M,w/2- let �� Valve,WKM-M,2 1/16 SM 2 1/16 5M EFO,X-bottom ® R,� 0 FE,HWO,AA prep w/1'A VR profile I I. 1:(0-)..1 i I• tIt . 'I ,•_____. .. •1 Valve,CIW-F, Casing spool,CIW-WF, t I t i III 2 1/16 5M FE,HWO,AA 135/83MX135/83M, c� 0 w/2-2 1/16 5M SSO I MIIIIII �a/,oMIIIIi i.; III III � le Ir ; 1+ Casing head,OCT-22, I 13 5/8 3M X 13' SOW III — Ill bottom,w/2"LPO �J 2"LP plug valve Iii WM11111 I' ill s. • • • IIMonopod Platform 2016 BOP Stack-workover 12/14/2015 11Me 1,/%Lrsku.1.U. gMillirl Bottom of air boot flange Rig Floor • 5'below rig floor 16' Pipe 1iiMillititafii� 0 affil in, art affil (fel n 3.14' Shaffer z6.zs' 135/8SM 1 I iii III III III 2 7/8 n 5.5 variable Shaffer _� ® �,_ 2.83' 7 1 -• Blind 2 1/16 SM manual and 21/16 SM manual and 1.76' 9(f v,lves for c oke side 1il•i Q'I 'ISI 1 1; HCR valves for kill side I re°1•0„ I 0 i[i ill■1i1■midi{ i11 - ---- I_I lel _I ISI Drill deck Riser 135/85M FE X 13 5/8 SM FE 14.20' 14.20' 1:11 rill rffi rffi Li LUAU till Spacer spool 135/85M FE X 1.41' 11 5M I III III III III III • "a PI 1 voo—o—oo—....,.....o.,00—000000— ®0 O • I O O E N ®` 1 .� a I L►•-- i �2 uVff Epgp� ' > tlO, L► �• O► su .-x3d5 0.d. 0 $ 1 4maC60uuuuuxx 222 st/ iif L/• j O O j O O O V V O D U O O u u U V U V V O U V O u O V O D U V O O O O O u u 1 g O O © , gYgY�� — 111 gaa lt y SS i c1 mu aea�€€CER.cS 5 5 aoo'5 22 Zs• Z >–Ctl03Y13C80uuuu Cui3i3d„5r.nff ds pan II .11 5 6 E s 41 5 9 � 3 In . w w w� > w' Sz " w3mi er�a' w .3 .11$ZdsO .41$gd0O ggg 1 y 1 g1 l a wu Vmml 2 n '41.9 �i a I a $j �i 7g 1112 0 g 8 „ r V ff l ----=1.1r111011A=1 4 V "-- ]f D f f f ao N A : �' ? . f F I t4 8 F F Y 1 'A __l A 0 V -IN- MUM g8 G A -4 sxm u `d l w . E� . o 71) `-D Tp 1.10 F g....t O --ISI- iT --IV- E y • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,r u; Attachment#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. • Monopod Rig#56 BOP Test Procedure Hilcorp 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. Rig 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open%"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 Ti 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) • ! H Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LLC. 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. • • � Fim / > � 2 O C) a ■ § 2 E 0 o / \ 2 O.� § / � « E ® § cm f 13.1 (7m ® > @ / § f 0 = » < E =• 0 k � 5 � �� > = f �� C D.§ gE §• .- M ) ■ 3 w 2 2 2 m CU $ / cu o O E/ 2 J X X / / CD X ¥ -0 X - > $ 0 a e O kv K/ k x a) ) X = C g % / a 20 co / U' J \ « £ t ( L. 2 / '% 2 4C.) � / / a U) \ / a. a U) �% § C § / ,. . co ■ c -o m0 C W > 2 $ . (r)@ o > w El § U 0 a. a. % Q O gco > 0 : X E = 0 Q 41:3) 2• » I— ,-4 e m : 0 Q C q / w e $ 2 Clo m S x \ 6 < it a .. _ . . 0 . > O U0 $ : U C Q ■ > � 2 /0 Ua / 2 2 k 9 • • 5 SHED SEP:2-12016 A-25RD Cement Evaluation Log Review Alberto Abouganem Stephens DISCLAIMER All interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages, or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule 3chlumber er 9 • • . Contextual information Logs provided Cement Evaluation Tool (CET), dated 22-March-1989 — 8-ultrasonic transducers (45deg separation) Cement Bond Tool (CBT), dated 22-March-1989 — Attenuation CBL, Variable Density Log (VDL) Assumptions Single casing size/weight Top section of the log used for "free-pipe" baseline Information missing: Volume of cement pumped Planned TOC of the cement job Losses, if any Centralizer placement Schlumberger • • $tom. ( shows scattered solids in a ._44." } channel-like pattern. =-« ; ;: _ ' - Without the information on _ _ C _ _ 1?I'1 the cement job(volumes, I 5300 r ! ' - "i 1 1 p �. losses,expected TOC is ., 1 ..1! { —2-.2.- _A ::P."+" , not possible to interpret t -_- . ,S ou 4 _ whether the solids are from _ s ,�... 472 } the cementing job or ' - - ! settlement from the solids � - -, on the mud — `r -- t I� - - 41$ —E— F ...es__• 1 f 1.!1.)1 Si , 5400 —ç i d Fi. rL a1J .771 • 1 '�"`---- I It , Both CET and CBL " 1_....H., If ""' — measurements showa E. .;rte_ �_ ,i!i • • -_ -Ill i 11 r'11 "free-pipe"response. e-- . . . R S 5500 r}---- '' sem' f. ,.,._.--. 1 ( (t ,` 1 ll __,5-1-_ _.. .: 1 . 111)‘\\,n} CET shoes an increase of <.� . _____ _ ' ; . . . - -MIE --_ --• solid material,with a z. .< ,_ i ° ,,5• channel induced by, E i -, presumably,casing in . . 5600 �' • :_ ' __ contact with the formation. i ' — = 1 ,i i j• CBL agrees showing an 1 , '`, Kl iii 1-"`-• � � j increase in attenuation and , 1 f : r - �.. tit i ate arrivals shows ...,...6'.....f _-' . r. /P., dampening. rf I III , ill .f 14 as.a him t_ p H }Jr . . ',1 1 5700 .p., 1 ) _ .... .. - _ _ . : : -, ( Both CET and CBL a �� measurements show ` ,- - ,! f, . "free-pipe"response. • I RI ' ir.! II ).1 / f f E - H .t fit, i I _ : > , Acoustic impedance map '6' ,..'. . shows scattered solids in a h 4 .2. S . r� i i channel-like pattern. i 1 . � F _ ,n .� aL � _: a' ,,,� - This section presents the ----5 . ' ,;, ....,=---- most solids coverage of the ,.r . , . r-- - d.,,. ^.' 5900 } yitill:.� interval with 30ft length,but a� —, I 'm..7 .•—.� -� II " is not above the interest c a ! .., _d ;. zone.A liquid pocket is w— t V. present i I 1 ix• y i ,, ,� Acoustic impedance map.111M - U I I, shows scattered solids in a ", -fi 1 17z^ channel-like pattern. • • - • I4000 t-w_ , :,r , , 11 :: y r r . . r , r # " 4100 • • • A41.G IN�.:® 7 t 1 7 w 11 I K •'-'s i'.—f----"•-.7 '-.7 '''' ' -- i y 4200 3 d ' .. ' ` ; .t' Iii` LJ(1I III 4300 ,_ . -Z1:5I .... �.� f ps .. 0 -. _ _ 1 � a �:Tama; ts 1 . , iii - { 4400 _: s '..,.,„_...! 1 211 --_ _ L.; 41 I __ . y ! i The upper interval is made - 4_ 1 .?� t h PP k of mostly"free-pipe" ., '—;;:,:.4.1.-=—• - ,#• response, with some ..-_-...1.;;;,.... -- _ 0 sections of scattered ----, 4500 _ I S.No indication of solid n o ;, ; _ _ I i; ,•.: '. —i _ isolating intervals. 411'1 d "maw4600 y ,� _. t �' '1•� �-- 1 I 6 { S 3 X11. . 4700 : )1 7 ' i•ll � + h 1._ ...‘ -4,41^ 711111111 .. :.a1 ••"r • 1. - e'• ��NI 4 —— - — 4800 •i —_ .[..1 ` 1_-• ,_ r:. 'i-.t . tom' • t . . . t- • L �a I E _. _ - :,.., - -..-• ••• . ! 41, --- 4900Alir �• i Y '- 4912 4920ft exhibits an ? 3 Kms .,! -.c. - :..,I r• �- - increase on both CET and ___ _.. `� .' , CBT measurements. This - is precisely above a collar " ...�. . .''i �.aia� a -- - • _ r;�a : LA_ and its suspected to be - + 1 ' "--d �e _ - settlements(mud solids or 5000 'At a «. : cementi pumped this high) ; i 5c= Rim!. , i t ..-..k.• r � i r Ia a) T d a� . . 1 5100 :„ __ EI, • }' i.z _ 4 5200 - • Conclusions and Recommendations Conclusion: There is no indication of a fully isolated interval above the interest zone to be perforated. Scattered solids are observed in section, but mostly channeled. Less than 100ft of cumulative interval is present, although some of the individual intervals are too short to be considered long term barriers (<10ft). The requirement is for 500ft Recommendations: After such a long time, the downhole cement bonding condition might have changed since it was logged, due to, and not limited to, contaminated cement (long curing time), mud settlements (appearing as solids on the log), formation swell against the casing (appearing as solids in the log), cement damage due to temperature and stress cycles, and many others effects. Changes have been observed in just a couple of weeks between logs, some others nothing changed over years. Depending on the requirement for isolation (top of cement/solids, or channels verification), its recommended to re-run the logging suite in the 7" casing USIT (successor of the CET tool) , to allow for channel identification CBL (Attenuation based CBL would be preferable for a direct comparison) VDL For not-cement targets as in mud settlements that will not permit squeeze, or formation collapse, its recommended to add a Flexural Attenuation measurement Isolation Scanner (IBC) (both USI and Flexural in a single tool) Schiululierger • Recommendations After such a long time, the downhole cement bonding condition might have changed since it was logged, due to, and not limited to, contaminated cement (long curing time), mud settlements (appearing as solids on the log), formation swell against the casing (appearing as solids in the log), cement damage due to temperature and stress cycles, and many others effects. Changes have been observed in just a couple of weeks between logs, some others nothing changed over years. Depending on the requirement for isolation (top of cement/solids, or channels verification), its recommended to re-run the logging suite in the 7" casing USIT (successor of the CET tool) , to allow for channel identification CBL (Attenuation based CBL would be preferable for a direct comparison) VDL For not-cement targets as in mud settlements that will not permit squeeze, or formation collapse, its recommended to add a Flexural Attenuation measurement Isolation Scanner (IBC) (both USI and Flexural in a single tool) SchIumerger References From CET to USIT: Modernizing Cement Evaluation (1991 ) ittp://www.slb.com/-/media/Files/resources/oilfield_reviev prs91/apr91/7 modernizing.pdf SPE/ADC 119321 Identification and Qualification of Shale Annular Barriers Using Wireline Logs during Plug and Abandonment Operations IPTC 10546 A Novel Ultrasonic Cased-Hole Imager for Enhanced Cement Evaluation kIuniIierger • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 23, 2015 11:12 AM To: 'Trudi Hallett' Subject: RE:A-25RD RWO (PTD 188-137) Trudi, A couple more thoughts: 1)would like to see a temperature)21 done a couple months after the well is put on line to verify no channeling of water uphole. I'll put a temperature log request in the sundry. 2) The 12 ppg cement is likely very hard to pick up with the CET/CBL log due to its low compressive strength. I have not looked at the CBT/CET logs in detail but there must be an interface somewhere in there. The G class at 15.8 ppg has much high compressive strength. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED SEP 2'0 2016 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at(907-793- 1226 )or(Guy.schwartz@alaska.gov). Original Message From: Schwartz, Guy L(DOA) Sent:Tuesday, December 22, 2015 2:49 PM To: 'Trudi Hallett' Subject: RE:A-25RD RWO (PTD 188-137) Got the CD ..thanks. Looks like fairly good agreement between CET and CBT. I will approve sundry pendinLupdated CBL log for the very top perforation at 5880-5996' MD. There appears to be enough cement to prohibit migration below 5900 ft. The other perf intervals look ok to go ahead with (6056 ft and below) but will look at new CBL anyway. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov). Original Message From:Trudi Hallett [mailto:thallett@hilcorp.com] Sent:Tuesday, December 22, 2015 12:00 PM To:Schwartz,Guy L(DOA) Subject: Re:A-25RD RWO(PTD 188-137) That works. I assumed we would need to run a newer CBL as part of the sundry anyhow.Thanks,Guy. Sent from my iPhone On Dec 22,2015,at 11:44 AM,Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov» wrote: Trudi, Looks like they squeezed the casing several times after the CET/CBL was run too. So casing is likely better than the logs show above 6400 ft md. . Could run a CBL as part of the sundry to get a updated view of the bond log. Based on that the new CBL higher perforation intervals could be approved. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793- 1226)or(Guy.schwartz@alaska.gov<mailto:Guy.schwartz@alaska.gov>). From:Trudi Hallett[mailto:thallett@hilcorp.com] Sent:Tuesday, December 22, 2015 11:32 AM To:Schwartz, Guy L(DOA) Subject: RE:A-25RD RWO (PTD 188-137) Also—SLB's domain champion for Well integrity is stopping by this afternoon to take a look at the logs with me as well. If he has some better insight I will pass that along.Thanks! Thanks- 2 • • Schwartz, Guy L (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Tuesday, December 22, 2015 11:27 AM To: Schwartz, Guy L(DOA) Subject: RE:A-25RD RWO (PTD 188-137) Hello Guy- I have reviewed both the CET and the CBT and appears we have spotty cement from about 4100'down to 5540'.We then have about 120'interval of isolation from 5540'-566o'. Both these logs were ran on 3/21/1989— We scanned in the intervals—they are too large to send by email. I am having our GEO tech put them on a CD and will send it over to you for your reference/review. Some additional data: CFERAr/ON sJI041 t9 r-25 Redrili v 11 Drilled 6 1r2- holt to the total depth of g/)0'. Larculateu / V" �� and conditioned the nod. � to run 7- easing. C "01° 2) Ran /" N-Bite milt,. fluff Casing to 871$'. Court ai t reciprocate pipe. Mixes e'o pa pea a lea, slurry of 750 sacks Speereilte cement w/.5% CfR-3. .6L naiad too, .456 t6-7 and l+% KG. at 1 .1 ppg. followed with tail ce'iertt of 500 lacks class •y" ws.2% Cf$-1, .5% t41am 344, .id* Lex mixed at 15.E ppCJ. Displaced the plug with moue area bumped plug with 2200 psi. matt roil return. tnrode,a,Jt tsar ;ata. 3) %poled down &PC, set the slips and larwea casing. tut ort ca5ind er.] installed Cao spool. Ireitaliees wellhead. s) Cietned pits and laid down 5" drili pipe. Released rig at 0430 smuts Cp 2-3-d skit to excessive ice and very law temperatures. Performed a squeeze job on 3/25/1989 3/23/89 9675' Ran CZF/CERAR from.8630'-1300 w/14oD PSI on the Casing. Attempted to run GYRO survey but could net get deeper then 33C00. Ras Sonic Array/OIL/0R from 8612'-2478'. Sonic tool indicated problems W/the cement above 6600'. 3/24/89 8675, Ani base line temp log from 8670'-100'. Flowed 7' X 9-5/8• annulus& renin temp log. Mettle up i ran noise log from 70000-1000, Located entry $ 6520' MO. Reran .0 MO wavy fess 8650' to ve fade. Made up perforating gins I pressure tested lubricator. tS 3/25/89 8675' RIK 6 perforated 4 SPF from 6492,-6490'. Closed blind YY��_ n rams I broke don perta .cr 8 ret1425 POI $ 1-1/8 DPM. I'/ RIR Wiest retainer & est S 6389'. Mixed pimped 254 Sacks Wass 'G7' cement. Final press 2350 PST $ 1 DPM. CIP O 1400 MRS 3/25/89. P00S. 3/26/89 8675' Waite moot. Cleaned ed cut cut fro'6350'-6381'. Sled F� down 7' z 9-5/8' annulus to 90 PSI. Press ire:reamed to 1 120 POI in 7 Wee. Milled out hand[art & retainer to 86754. Attempted to teat perforations to 1500 PSI bit 111 �� ,y could only hold 1225 PSI. (I A/ in�D 1 'Lv 1 'Z� • • • 3/27/89 8675' POOR & picked up a 7" cmt retainer. RIH 4 set retainer 0 6461'. Circulated 6 obtained a Crew+ 12400 PSI & 1/4 BM. Mixed i paged 200 sac of class "G". Pinel salt pews 2350 PSI 0 1/4 SPM. Cement in place at 0844 tarn. POCH. anducted weakly BCP test. Wait an amt. RIM 4 trigged hard cement at 6469'. 3/28/89 8675' Drilled out cat 4 tat retainer to 6519'. Cleaned out to 8675'. Press tested perforatiress 0 6490' to 1500 PSI. Pressure bled to 1435 PSI in 10 min. Rigged up wireline E. stoat 4 bpi from 6656' to 6654'. RIR with met retainer F. set 0 6592'. Obtained Cr 3oen 12925 PSI 11/8 BPM. Missed I. gaped 482 sx of class 'S" cat. Final mgz press was 2000 PSI 0 1/2 SPH. CIP I 2300 IIB. POCtt 4 wait an oemat. 3/29/69 9675' RIR to 6040' 6 wait an cst. Cleared out ant b retainer to 6665'. RIM to 8675' 6 circulated 5 asx3ditianed arid. 3/30/89 8675' Pressure tested perfs 0 6656'-6654' 6 6492'-6490' to 1500 poi. Sled darn to 1435 PSI in 10 wire. POOR & laid down 3-1/2' drill pipe. Picked up bit, scrapper & 3-1/2" RIG 4 RIR to 8674'. Circulated 6 conditioned. Raped high viscosity sweep 4 fIW until return fluid was clean. 3/31/89 9675' Circulated well w/MIN. Cleaned mud pita 6 surface linea. Displaced well w/73 APF conpletian fluid. POOH. Give me a shout if you need additional data or have any questions. I appreciate it. Thanks- TrtA444/ From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, December 16, 2015 11:32 AM To: Trudi Hallett Subject: RE: A-25RD RWO (PTD 188-137) There should be more cement uphole from 6700 ft based on volume pumped. Look at CBT and actual cement report for the job. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Trudi Hallett [mailto:thallett@hilcorp.com] Sent: Wednesday, December 16, 2015 11:14 AM To: Schwartz, Guy L (DOA) Subject: RE: A-25RD RWO (PTD 188-137) I attached the CBL for your review.The current pkr depth is ±200 above the top of cement.One could argue there is spotty isolation up higher,but I am not convinced after further review. 2 Thanks • • Trwdi/ From: Trudi Hallett Sent: Wednesday, December 16, 2015 10:35 AM To: 'Schwartz, Guy L(DOA)' Subject: RE: A-25RD RWO (PTD 188-137) Good morning,Guy— I finally located the CBL and appears the TOC is @a 675o',which is well below the proposed top shot. I will get with the Reservoir engineer and come up with an alternate packer set depth—which most likely is going to be the same depth as the current completion. Do you want to return the sundry,or should I just send the new depth on a change of program?The scope will be the same—just different depth based on the bond log. Thanks- Tru,ofi/ From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@aalaska.gov] Sent: Tuesday, December 15, 2015 4:21 PM To: Trudi Hallett Subject: RE: A-25RD RWO (PTD 188-137) Trudi, You don't have send log to me...just review it and pdf a few pages that show the critical areas above the perfs. You could scan and send those to me. The TOC should also extend several hundred feet above the packer too. And no... I am staying in town for holidays. Not sure where to go but will likely hit the ski slopes. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Trudi Hallett [mailto:thallett©hilcorp.corr] Sent: Tuesday, December 15, 2015 3:59 PM To: Schwartz, Guy L (DOA) Subject: RE: A-25RD RWO (PTD 188-137) Oh,Yes—we will be firing Rig 56 back up for this project.Apologies for that. 3 •• And,yes absolutely, I will dig out the cement bond log and send it over to you. t will be in the morning.Are you on vacation over the holidays? Thanks- From: Schwartz, Guy L (DOA) [mailto:quy.schwartz( alaska.gov] Sent: Tuesday, December 15, 2015 3:49 PM To: Trudi Hallett Subject: A-25RD RWO (PTD 188-137) Trudi, Assume you will be using rig 56 for the workover. Didn't specify on the sundry. Also can you provide a cement assessment on 7" casing to verify good bond above the new perfs and packer. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALLY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-U26)or(Guy.schwartz@alaska.gov). 4 STATE OF ALASKA • ALlikA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown 0 Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory 0 188-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: RECEIVED Anchorage,AK 99503 50-733-20242-01 7.Property Designation(Lease Number): 8.Well Name and Number: IJEU 14 Z015 ADL0018731 Trading Bay St A-25RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): A0GCC N/A Trading Bay Field/Middle Kenai C Oil and Midd a menai D Oil Pools 11.Present Well Condition Summary: Total Depth measured 8,730 feet Plugs measured N/A feet true vertical 6,071 feet Junk measured N/A feet Effective Depth measured 8,080 feet Packer measured 6,530 feet true vertical 5,551 feet true vertical 4,467 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Perforation depth Measured depth 6,658-8,622 feet v 4 &ir MO f V lir. yY fj),-, True Vertical depth 4,452-5,986 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 6,494'(MD) 4,446'(TVD) Packers and SSSV(type,measured and true vertical depth) FB-1 Packer 6,530'(MD)4,467'(TVD) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 197 429 568 Subsequent to operation: 0 0 0 425 50 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 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 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: 315-558 Contact Trudi Hallett(907)777-8323 Email thallettAhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 3-L,, `3 Phone (907)777-8356 Date t 2/1 y /15 4j . /zv2of_ / =ifi- /2- �RBDMS DEr 212015 Form 10-404 Revised 5/2015 I./ Submit Original Only • • Monopod Platform SCHEMATIC Well: A-25RD (Inj) . 11 As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 614 K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' Z \ JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80, IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" 2 3 4 Slickline/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. A 5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B N I 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X , Perforation Detail F Accum Last G 1/4NSand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =,C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 79' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open _ D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open _'D' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open A \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 10/08/15 byJLL • • IIHilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-25RD 50-733-20242-01 188-137 10/3/15 10/4/15 Daily Operations: 10/03/15-Saturday START RIG-UP, PERMITS,JSA. BREAK FOR W/L MEETING/LUNCH. BACK TO RIG-UP. BUMPED UP READY TO PRESSURE TEST. LEAK BELOW BOPS. CHANGE 0-RING. PRESSURE TESTING. PRESSURE TEST TO 2500 GOOD. R#1 P#1 CK CCL. ARMING GUN. 0 @SWAB BUMPED UP. RIH R#1, P#3, GUN#1 - 20', TAG @ 8,080'. R#1, P#4, CORRELATE FROM 8,020'. SEND IN CORRELATION PASS. FIRED @7,968' TS CCL 8.5 7959.5' - 20' GUN L 8.5 /7,959.5' - PSI 0. POOH. RS GOT HOLES. RIH GUN #2 -18'. R#1, P#9, CORRELATION PASS ON DEPTH. FIRED @7,950'TS CCL 10.3 7,939.7' - PSI 0. POOH. RS GOT HOLES. SECURE WELL FOR NIGHT. 10/04/15-Sunday MORNING MEETING, PERMITS,JSA. RIG UP FOR DAY. STABBED ON 0 @ SWAB OPENING SWAB. RIH GUN #3—20'. SAT DOWN 7,918'. CORRELATION PASS R#1, P#13, ON DEPTH 7,808'TS CCL 8.5 7,799.5'. FIRED PSI -0. POOH. RS GOT HOLES. LAID DOWN, SECURED WELL. RIGGED UP FOR GUN#4-20' &TAG RUN. RIH PSI 0. SAT DOWN @ 7,918'. CORRELATION PASS R#1, P#20, FIRED PSI 0 7,788'TS CCL 8.5 @ 7,779.5'. POOH. RIH &TAG @ 7,907'. POOH. RS GOT HOLES. RIG DOWN. RIGGED DOWN /STANDING BY FOR BOAT. fr \ \,.77 €,N - 7S '/f `(o • STATE OF ALASKA • ALAI OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate El Pull Tubing❑ Operations shutdown El Performed: Suspend ❑ Perforate El Other Stimulate CI(Acid) sing El Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Cl Re-enter Susp Well El Other: El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory ❑ 188-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20242-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-25RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools 11.Present Well Condition Summary: Total Depth measured 8,730 feet Plugs measured N/A RECEIVED true vertical 6,071 feet Junk measured N/A feet DEC 14 2015 Effective Depth measured 8,080 feet Packer measured 6,530 feet true vertical 5,551 feet true vertical 4,467 feetGCC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 ,160 psi 7,020 psi Perforation depth Measured depth 6,658-8,622 feet W `EE, 0 4 rr: b True Vertical depth 4,452-5,986 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 6,494'(MD) 4,446'(TVD) Packers and SSSV(type,measured and true vertical depth) FB-1 Packer 6,530'(MD)4,467'(TVD) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 6,658'—8,622' Treatment descriptions including volumes used and final pressure: 107 bbls 10%Hydrochloric Acid.Final Pressure 1250 psi @ 0.4 bpm.60 bbls FIW displacement.Let soak+/-4 hrs.80 bbls of FIW post flush.Final pressure 1010 psi© 0.5 bpm. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 197 429 568 Subsequent to operation: 0 0 0 425 50 14.Attachments(required per 20 AAC 25.070,25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development El Service El Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑ Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ El 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: 315-645 Contact Trudi Hallett(907)777-8323 Email thallettOhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature L,, Phone (907)777-8356 Date 1Z/ I y () Form 10 404 Revised 5/2015 r Z L RBD �w�. 2 2015 ie. Submit Original Only � SCHEMATIC • Monopod Platform .,llWell: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 I 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: / \ 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth ID Item 1 37.73' OW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint 'U) E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" . 7. �' F 6,546' 2.992" Joint of 3-1/2",9.3#, N-80,IPC Tubing .Ll N G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" 2 7ni•sv✓`' 3 4 ./------____—. Slickline/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. A5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X Perforation Detail F Accum Last G Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =,C, C 51-6 7,788' 7,828' 40' 20' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 20' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open -= D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open 'D' D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open A \ S GSc h v."-c/`�`"- PBTDMAX.HOLE 8,675' TD=8,730' .c /— MAX.HOLE ANGLE =65 "�Tj r_.rc4_ L. Bevis d: 10/08/15 byJLL i alf (D • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-25RD Pumping 50-733-20242-01 188-137 11/19/15 11/19/15 Daily Operations: 11/19/2015-Thursday R/u circulating lines, tested t/2000, changed out lit that had a leak, re-tested good.,Pump FIW @ .4 bpm, 1250 psi, ann 480. Start pumping 10% HCL@ .5 BPM 1500 psi. Annulus pressure steadily dropping t/360 psi. At 65 bbls pumped, ann pressure started rising. Stopped pumping & it cont. t/rise stopping @660psi. Tubing pressure @ 50, 30 min ann pressure dropped t/ 65. Resumed pumping @.25BPM 1000 psi, ann pressure equalized in 20 min & maintained. Pumped 107 bbls HCL, chased w/60 bbls FIW.,Shut down let soak 4 hrs. Chase w/80 bbls FIW .5 BPM FCP 1010psi, @ .5 BPM. Shut down, tubing&Ann. pressures went t/0 in 20 min. .A--A0c) -el F TFl� I ,v THE STATE Alaska Oil and Gas ofA LAsKA. Conservati®n Commissi®n 333 West Seventh Avenue 71- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®A'ALASY'F* Fax: 907.276.7542 www.aogcc.alaska.gov iCANppggK Trudi Hallett 3 Operations Engineer 1�$ "' t Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C and D Oil Pools, Trading Bay St A-25RD Sundry Number: 315-645 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, Pa, Cathy P. oerster Chair DATED this 2r day of October, 2015 Encl. RBDMS CT 2 3 2015 • • • RECEIVED STATE OF ALASKA OCT 1 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION j f a fi LS APPLICATION FOR SUNDRY APPROVALS A OGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate Q(Acid)' Alter Casing El Change Approved Program ❑ Plug for Redrii❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number. Hilcorp Alaska,LLC• Exploratory ❑ Development ❑ 188-137 . 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic Cl Service 0 , 6.API Number. Anchorage,AK 99503 50-733-20242-01 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 CI No CI✓ Trading Bay St A-25RD• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 ' Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8,730 6,071 , 8,080 • 5,551 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,658-8,622 4,542-5,986 3-1/2" 9.3#/N-80 6,494 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker FB-1 Packer • 6,530'(MD)4,467'(ND) 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ 3velopment❑ Service CI • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/27/2015 OIL ❑ WI NJ CI • WDSP❑ Suspended ❑ 16.Verbal Approval: Date: GAS El WAG ❑ GSTOO SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallettehilcoro.com Printed Name i 1 Trudi Hallett Title Operations Engineer 1 Signature ttit(--(21tit Phone (907)777-8323 Date 10/13/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10-- y d y APPROVED BY Approved by: 4.// COMMISSIONER THE COMMISSION Date: /9 -..-2-1--1,C MS�SC.00T Z 3 2ORIGI �o/W�is- RBD N A L „1..e- (%��-- ,a_.�,_�S_ Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 14 • • • Well Work Prognosis Well: A-25RD Hilcorp Alaska,LLC Date: 10/12/15 Well Name: A-25RD API Number: 50-733-20242-01 Current Status: Waterflood Injector Leg: NA Estimated Start Date: October 27, 2015 Rig: NA Reg. Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-137 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 2066 psi @ 4,542'ND(6,658' MD) Based on pressure survey 7/25/2015 Maximum Expected BHP: 2066 psi @ 4,542'ND(6,658' MD) Max Anticipated Surface Pressure(MASP): 2,000 psi treatment pump pressure limit '"--. Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. Total fluid injected has decreased and is believed to have been caused by scale formation in the well bore and perforation tunnels. Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. 1. MIRU pumping equipment. 2. Pressure test surface lines to 2,000 psi (treatment pump relief valve limit). 3. Mix chemicals and pump in the following sequence: a. Pump FIW down tubing. b. Pump +/-4,500 gallons (107 bbls) of±10% Hydrochloric Acid @ .5 to .75 bpm until empty. c. Chase with FIW at same rate to displace tbg volume (±60 bbls) 4. Shut down pump and let acid soak for>_4 hours. 5. Pump FIW to push chemical into formation (±80 bbls) 6. RD Pumping equipment. 7. Return well to injection. Attachments: 1. As-built Schematic SCHEMATIC • Monopod Platform Well: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: / \ 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis'XA'Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" MIME 2 lIl3 4 Slickline/Fish/Fill Information: 3/3/08:Ran 2.262"GR and tag fill at 8080'. A = t V 5 7/18/07:Ran 2.00"Gauge Ring to 8080'. No note of tagging. B I 6 5/30/95:Ran 2.25"Gauge Ring to 8552'. No note of tagging. C D E X Perforation Detail F Accum Last G "N Sand Top Btm Amt SPF Perf Date Present Condition C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =,C, C 51-6 7,788' 7,828' 40' 10/04/2015 Open Zone C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open D 53-0 7,950' 7,988' 38' 10/03/2015 Open D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D54-5 8,142' 8,158' 16' 8' 4/1/1989 Open =-- D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open 'D' D 56-1 8,346' 8,463' 117' , 8' 4/1/1989 Open Zone D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open A \ PBTD=8,675' TD=8,730' MAX.HOLE ANGLE =65 ° Revised: 10/08/15 by 1 LL • OF Tit, • P�� ,�� THE STATE. Alaska Oil and Gas of Conservation Commission . y_= 333 West Seventh Avenue u'lx Fv GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®A, -ALAS Y'24 Fax: 907.276.7542 m '.twww.aogcc.alaska.gov tJAAi 4 Li Trudi Hallett Operations Engineer ( 37 Hilcorp Alaska, LLC SS 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C and Middle Kenai D Oil Pools, Trading Bay St A-25RD Sundry Number: 315-558 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, Cathy . Foerster Chair DATED this I' day of September, 2015 Encl. RBDMS EP 11 2016 • 0 RECEIVED SEP 082015 STATE OF ALASKA I3'5 9 Juli /s ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program El Plug for Redrii❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development El 188-137 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service II - 6.API Number: Anchorage,AK 99503 50-733-20242-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 93B / Will planned perforations require a spacing exception? Yes ❑ No CI Trading Bay St A-25RD - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 ' Trading Bay Field/Middle Kenai C Oil and Middle Kenai D Oil Pools • 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): - 8,730 - 6,071 -8,080 J 5,551 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317' 1,304' 3,090 psi 1,540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,350' 6,870 psi 4,760 psi Liner 8,726' 7" 8,726' 6,069' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,658-8,622 • 4,542-5,986 3-1/2" 9.3#/N-80 6,494 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FB-1 Packer 6,530'(MD)4,467'(TVD) 12.Attachments: Description Summary of Proposal C1 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic El svelopment❑ Service ❑� • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/22/2015 OIL ❑ WINJ I]• WDSFO Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTO❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi "`-'2D Hallett Title Operations Engineer Signature ��'" - ,/— "`/ Phone (907)777-8323 Date 9/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: `( '—‘40 Li APPROVED BY Approved by:CIICCC� P9w.....,1L4,---- COMMISSIONER THE COMMISSION Date: 9 -//- /S '� 111 115" i_ "t-rr.rpt" Cc� 1 1 '1015 A q�1'7/3- ORIGINAL RB0Ms ubmit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 14 • • Well Work Prognosis Well: A-25RD Hilcorp Alaska,LLC Date:09/09/15 Well Name: A-25RD API Number: 50-733-20242-01 Current Status: Waterflood Injector Leg: NA Estimated Start Date: September 22, 2015 Rig: NA Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-137 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 2066 psi @ 4,542'ND(6,658' MD) Based on pressure survey 7/25/2015 Maximum Expected BHP: 2066 psi @ 4,542'ND (6,658' MD) Max Anticipated Surface Pressure(MASP): 1612 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well A-25RD2 is a waterflood injector completed in the Trading Bay Field Middle Kenai C and D Oil Pools. This project will reperf and/or add ±418' sands to increase injectivity in the main II-A Fault Block. Procedure: 1. MIRU E-line unit. 2. Correlate on depth. 3. Add perforations per perforation request: Zone Bench Top, MD Btm, MD Total Ft C C7 ±6658' ±6821' ±163 C C7 ±6856' ±6890' ±34 C 47-5 ±7064' ±7156' ±92 C 48-7 ±7264' ±7284' ±20 C 50-0 ±7473' ±7486' ±13 C CZNS2 ±7564' ±7575' ±11 C 51-6 ±7779' ±7827' ±48 D 53-0 ±7949' ±7986' ±37 4. Rig down E-Line. 5. Return well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic •U • 0 Monopod Well No. A-25RD (Inj.) Revised 3/3/08 As Completed 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 F r 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: / \ 3-1/2"(Plastic Coated) 9.3# N-80 DSS-1-ITC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth ID Item 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis AA' Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly I A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing 2 G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" 3 4 A E. , = 5 B 6 c Slickline/Fish/Fill Information: D 3/3/08: Ran 2.262"GR and tag fill at 8080'. E X 7/18/07: Ran 2.00"Guage Ring to 8080'. No note of tagging. F 5/30/95: Ran 2.25"Guage Ring to 8552'. No note of tagging. GN 1 PERFORATION DATA Atxun Last Zone Zorn Sand Top Bim Pnt SPF R9lfCite Present Contrition C 0.7 6,656 6,824 165 16 34/2008 Cpen C 47-5 7051 7,159 97 16 3/4/2008 Cpen - C 51-6 7,779 7,828 49 8 4/1/1989 (den 'D' D 53-8 8,072 8,085 13 8 4/1/1989 Cpa, Zone D 54-5 8,142 8,153 16 8 4/1/1959 Cpen D 54-9 8,187 8,243 56 8 11/1989 4en d D 56.7 8,263 8,300 40 8 4/1/1989 Cpen PBTD=8,675' TD=8,730' D %-1 8,346 8,463 117 8 4/1/1989 Cpen MAX.HOLE ANGLE =65 ° D 57-2 8,52 8,622 120 8 4/1/1989 Cpen A-25RD Schematic 2015-09-01 DA 1 L: 3/4/2U08 By: BCA PROPOSED • Monopod Platform Ei • Well: A-25RD (Inj) As Completed: 4/7/89 API#50-733-20242-01 CASING AND TUBING DETAIL RKB to TBG Head=37.73' SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8"casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2"(Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' L , JEWELRY DETAIL NO. Depth IDItem 1 37.73' CIW 10" X 5M 3-1/2"Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis`XA' Sleeve 4.25"X 2.75" 3 6,498' 2.992" Joint of 3-1/2",9.3#,N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25"X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11'X 3.986"X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7",29# X 4" B 6,532' 4.000" Baker Seal Bore Ext.5.016"X 4" C 6,541' 2.937" Crossover 3-1/2"DSS X 3-1/2"8rd.box. 5.68"x 2.937" D 6,542' 2.992" 3-1/2",9.3#,N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2"Otis'X'Nipple 4"X 2.75" F 6,546' 2.992" Joint of 3-1/2",9.3#,N-80,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide,5.25"X 2.937" 2 3 4 Slickline/Fish/Fill Information: 3/3/08: Ran 2.262"GR and tag fill at 8080'. B � 6 7/18/07: Ran 2.00"Gauge Ring to 8080'. No note of tagging. o 5/30/95: Ran 2.25"Gauge Ring to 8552'. No note of tagging. 0 E X Perforation Detail FAccum Last G N ✓ Sand Top Btm Amt SPF Perf Date Present Condition C C-7 _ ±6,658' ±6,821' ±163' Future C-7 6,658' 6,824' 166' 16' 3/4/2008 Open C C-7 ±6,856' ±6,890' ±34' Future -`C' C 47-5 7,062' 7,159' 97' 16' 3/4/2008 Open =Zone C 47-5 ±7,064' ±7,156' ±92' Future EEC 48-7 ±7,264' ±7,284' ±20' Future C 50-0 ±7,473' ±7,486' ±13' Future C CZN52 ±7,564' ±7,575' ±11' Future C 51-6 ±7,779' ±7,827' ±48' Future '0' C 51-6 7,779' 7,828' 49' 8' 4/1/1989 Open Zone D 53-0 ±7,949' ±7,986' ±37' Future D 53-8 8,072' 8,085' 13' 8' 4/1/1989 Open D 54-5 8,142' 8,158' 16' 8' 4/1/1989 Open D 54-9 8,187' 8,243' 56' 8' 4/1/1989 Open PBTD=8,675' TD=8,730' D 55-7 8,263' 8,303' 40' 8' 4/1/1989 Open MAX.HOLE ANGLE =65 D 56-1 8,346' 8,463' 117' 8' 4/1/1989 Open D 57-2 8,502' 8,622' 120' 8' 4/1/1989 Open Revised: 09/01/15 by JLL . 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 08,2013 TO: Jim Regg kol 1, P.I.Supervisor ir, ? SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A-25RD FROM: Jeff Turkington TRADING BAY ST A-25RD Petroleum Inspector Src: Inspector Reviewed By: P.1.Supry ,1gr---- NON-CONFIDENTIAL Comm Well Name TRADING BAY ST A-25RD Inspector Name: Jeff Turkington API Well Number 50-733-20242-01-00 Permit Number: 188-137-0 Inspection Date: 9/27/2013 Insp Num: mitJAT130929152549 Re!Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-25RD - 1-Type Inj w 4VD F - I IA T 800 :1 1585 . 1 1520 - 1480' T 1450 :I 1440 _, 4466 I -1 I PTD• 1881370 - Type Test I SPT ITest psi 1500 OA . 0.1 -. 0.1 . 0.1 0.1 0.1 0.1 . 1 Interval 4YRTsT P/F F 1Tubing 2200 -1 2215 .1 2240 2250 2260 2260 Notes: Retest to follow(mitJATI31008113300). - SCANNED DE Tuesday,October 08,2013 Page 1 of 1 . • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 08,2013 TO: Jim Regg �� ICA0.1l3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A-25RD FROM: Jeff Turkington TRADING BAY ST A-25RD Petroleum Inspector Src: Inspector Reviewed Bx._ P.1.Supry..,1g1.--- NON-CONFIDENTIAL Comm Well Name TRADING BAY ST A-25RD API Well Number 50-733-20242-01-00 Inspector Name: Jeff Turkington Permit Number: 188-137-0 Inspection Date: 9/27/2013 Insp Num: mitJAT131008113300 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' A-25RD ,,Type Inj I W TVD 4466 IA 1 1680 1630 . 1 PTD 1881370 Type Test SPT Test psi, 1500 j OA 1 0.1 . ' 0.1 • 0.1 Interval 4YRTST p/p P Tubing' 2260 . 2260 • 2260 - Notes: Because of falling below the required test pressure,the IA was pumped up(without depressure)to 1680 PSI. ,, re4et SCANNED DEC 3 2010 • Tuesday,October 08,2013 Page 1 of 1 i MEMORANDUM To: Jim Re P.I.Supggisor I ~~'D~13I~~ FROM: Lou Grimaldi Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 13, 2009 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA A-25RD TRADING BAY ST A-25RD Src: Inspector NON-CONFIDENTIAL Reviewed By: RL Suprv ~~~ Comm Well Name: TRADING BAY ST A-25RD API Well Number: 50-733-2o2a2-o1-0o Inspector Name: Lou Grimaldi Insp Num: mitLG090922162929 Permit Number: 188-137-0 Inspection Date: 9/22/2009 Rel Insp Num: ~ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ A-25~~~TypeInj. ~~w T~ P.T.DI isai3~o ~ p est srT Testpsi aabb ' IA isoo ` OA s~o bi oo ~ ~ ~ ! ~szo i iaso ~ ~ ~ ~ ~ ' ---- -- --- a~TST F _ Interval _ P/F - - I / Tubin _ g --- 1800 1760 f ~ _ _~ - - -- - 1820 I 18 0 _ I ~ _ Notes' ~ test pressure fell below 1500 psi (minimum). Pressured back up and retested. ,~ ~.~'~:a~u'b9~~ `~~~ '~it.,l 1t ~ ~~ ;~~~~ Tuesday, October 13, 2009 Page 1 of 1 ~ - ~' • • Page 1 of 3 ti{,~F~d ~? - ~STz <~ Regg, James B (DOA) n ~~' - ~ ~ ~`~ ~ ~ 3 From: Lambert, Steve A [salambert@chevron.com] ~ ~ ~~ ~ Z~ 0`1 Sent: Friday, June 12, 2009 2:09 PM ~G To: Regg, James B (DOA); Owen, Claude D; Greenstein, Larry P Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT Attachments: A-25RD Pressure Data 6-11.xlsx ~ Jim we will add G-14ARD to the Ti0 report and leave the well shut-in until the waterflood is restarted and the well has passed the MIT. We have a similar situation with well A-25RD on the Monopod. This well was due for an MIT on May 5, 2009 but ~ the waterflood has been on a severely restricted status since April 13. The well was shut-in at that time and has not been returned to injection. We will not return the well to injection until the well has passed the MIT. The injection plot for A-25RD is attached. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 909 West 9th Avenue, Anchorage Alaska 99501 Tel 907 263 7658 salambert@chevron.com - c i ay C R!?!-' .~! _. :. f. ww~4o From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, June 12, 2009 9:30 AM To: Lambert, Steve A; Owen, Claude D; Greenstein, Larry P Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT Thank you for the explanation -sounds like the delay in performing MIT was unavoidable. My preference would be to have an inspector witness the MIT while the well is injecting (with well thermally ~ stable). Since waterflood is SI and in lieu of doing an MIT right now, I suggest adding (until well is put back on injection) G-14ARD to the "CI Master Well List TIO Report" that Larry Greenstein provides to us monthly. What do you think? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Thursday, June 11, 2009 5:55 PM To: Owen, Claude D; Greenstein, Larry P; Regg, James B (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT 6/12/2009 Grayling G-14 MIT • • Page 2 of 3 Jim attached is the injection plot for well G-14ARD. You are correct the MIT was due on April 6. As you can see from the plot, the well was shut-in for the period March 01, 2009 to April 18, 2009 due to a failure in the injection flowline. The flowline was repaired and the well was returned to injection on April 19 and remained on injection until April 27 when most of the waterflood was shut-in. As you stated there were issues with the volcano which affected operations during this period of time. The platform oil production was shut-in an April 5 and remains shut-in. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 909 West 9th Avenue, Anchorage Alaska 99501 Tel 907 263 7658 salambert@chevron.com From: Owen, Claude D Sent: Thursday, June 11, 2009 12:03 PM To: Greenstein, Larry P; Martin, J. Hal; Lambert, Steve A Subject: FW: Grayling G-14 MIT From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, June 11, 2009 10:23 AM To: Owen, Claude D Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W Subject: RE: Grayling G-14 MIT Our records indicate the M!T for TBU G-14ARD (PTD 1910990) is on a 4-year test cycle and was due April 6 (last test done 4/6/2005). Why the delay in testing? I understand there may be some issues with shutdowns caused by Redoubt volcano - is the well currently injecting? Looks like G-14ARD did inject 28 days in February, none in March, and 9 days in April (don't have May data in our system yet). Please have someone send us a plot of pressure data (tubing, inner annulus, outer annulus) for past 90 days for review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Owen, Claude D [mailto:owenc@chevron.com] Sent: Wednesday, June 10, 2009 3:54 PM To: Regg, James B (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W Subject: Grayling G-14 MIT Mr. Regg, Chevron Grayling Platform needs to perform a state witnessed mechanical integrity test on well G-14 A RD. At 6/12/2009 Grayling G-14 MIT • • Page 3 of 3 your convenience, please have one of your representatives contact the facility to schedule a date and time for the test. Thank you, Dave Owen Lead Operator Chevron Grayling Platform 907-776-6630 6/12/2009 ~~3c~ A--zs ~!~ a-25rd Pressure Observations 2500 2000 1500 - Hours Tubing - 7" ~9 5/8" X13 3/8" ~20~~ --- ____-- - Rate 4/05 - Monopod oil production shut down. Most of water injection shut-in 4/12-13 - 2 day injection test. Decided to maintain minimal waterflood during production shut down d N d d 1000 I 500 0 02/ 03/08/09 03/28/09 04T/Fi7~09 05/07/09 05/27/09 lsoo 1600 1400 1200 1000 a m 800 600 400 200 0 ./09 • Chevron >~- DATE Tune 9, 2008 ~ncisco Castro Chevron North erica Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#1~~~~®JUN ~. 2D08 Anchorage, AK 99501 ~ Q$ r X35 ~'~ /~ ~,~- L WELL. LOG TYPE SCALE LOG DATE INTERVAL LOGGED RUN # B-LINE ~p NOTES -LAS, PDS, DLIS COMPLETION TB ST A-25RD RECORD 5" 4-Mar-08 6660-7092 1 1 1 PDS COMPLETION TB ST A-01 RD RECORD 5" 5-Mar-08 5697-6140 1 1 PDS COMPLETION TBU K-18RD RECORD 5" 21-Feb-08 10800-12400 1 1 PDS COMPLETION TBU K-26 RD RECORD 5" 24-Feb-08 10303-10323 1 1 PDS PERFORATING TBU G-22 RECORD 5" 3-Ma -08 10122-10229 PS-2 i i -DLIS-PDS PERFORATING TBU M-17 RECORD 5" 16-Feb-08 7298-7381 PS-11 1 1 PDS PERFORATING TBU M-17 RECORD 5" 14-Feb-08 7296-7391 PS-9 1 1 PDS POSISET PLUG SETTING TBU M-17 RECORD 5" 11-Feb-08 6889-7430 PS-8 1 1 PDS PRESSURE TEMPERATURE TBU M-17 LOG 5" 15-Feb-08 5636-7398 PS-10 1 1 PDS DEPTH TBU M-17 DETERMINATION 5" 3-Feb-08 5782-7374.5 PS-7 1 1 PDS PERFORATING TBU M-17 RECORD 5" 19-Feb-08 5832-5856 PS-12 1 1 PDS POSISET PLUG SETTING TBU M-01 RECORD 5" 7-Jan-08 4792-5151 PS-2 1 PDS PERFORATING TBU M-01 RECORD 5" 18-Jan-08 4532-4580 PS-3 1 PDS HAPPY CEMENT BOND PDS, LAS, VALLEY B-12 LOG - SCMT 5" 18-Mar-08 3559-10315 1 1 1 DLIS COMPLETION PDS, DLIS, LRU C-01 RD RECORD 5" 14-Ma -08 4679-4759 1 1 FMA PERFORATION SRU 32A-15 SHOOT RECORD 5" 10-Mar-08 5554-5582 1 1 PDS f ~}O -a~~ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907: 263 7828. Received ~~ Date: STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAR 2 0 2008 Alaska Oil & Gas Cons. Commission 1. Operations Abandon Repair Well ---_ Plug Perforations Stimulate Other ~~ e Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ 188-137 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^~ 6. API Number: 50-733-20242-01 7. KB Elevation (ft): 9. Well Name and Number: 101' A-25RD 8. Property Designation: ~, / ~, ~` 10. Field/Pool(s): Monopod Platform - ADL-9fr~1 ~ ~1 '~ ~ ~1^+-~. Trading Bay Field/Middle Kenai C Oil 11. Present Well Condition Summary: Total Depth measured 8,730 feet Plugs (measured) tlOne true vertical 6,071 feet Junk (measured) NOne Effective Depth measured 8,080 feet true vertical 5,551 feet ~~~~y t~ ~fttt~S~ ~~ APFi ~ `~' LUUU Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1317' 13-3/8" 1317' 1349' 3090 psi 1540 psi Intermediate Production 1366' 9-5/8" 1366' 1349' 6870 psi 4760 psi Liner 8726' 7" 8726' 6068' 8160 psi 7020 psi Perforation depth: Measured depth: See 8tt8Ch SChematlC True Vertical depth: $ee AttBCh SChem BtlC Tubing: (size, grade, and measured depth) 3-1/2" N-80 6494' Packers and SSSV (type and measured depth) Baker FB-1 Pkr - 6530' 12. Stimulation or cement squeeze summary: Intervals treated {measured): 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 1400 ~ 420 1800 Subsequent to operation: 0 0 1600 ~ 420 1800 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service^ ' Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 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: 308-005 Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~' c____.~ ~""-' hone 907-276-7600 Date 3/14/2008 Form 10-404 Revised 04/2006 ~ ~ t ~ ~ L C~~c"~~tf~ ( ~~ ~ Submit Original Only IVVJ 111 111 ///~~, ( ~ ,~ '~~ a,6~~. ,~ -~ . ~G. ,:;~', Chevron ~ ~ Monopod - Well No. A-25RD (Inj.) Revised 3/3/08 As Completed 4/7/89 API # 50-733-20242-01 RKB to TBG Head = 37.73' CASING AND TUBING DETAIL SIZE WT GRADE CONK ID TOP BTM. 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mi119-5/8" casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2" (Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' NO. Depth ID JEWELRY DETAIL Item 1 37.73' CIW 10" X SM 3-1/2" Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis `XA' Sleeve 4.25" X 2.75" 3 6,498' 2.992" Joint of 3-1/2" , 9.3#, N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25" X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11' X 3.986" X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7", 29# X 4" B 6,532' 4.000" Baker Seal Bore Ext. 5.016" X 4" C 6,541' 2.937" Crossover 3-1/2" DSS X 3-1/2" 8rd. box. 5.68" x 2.937" D 6,542' 2.992" 3-1/2", 9.3#, N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2" Otis `X' Nipple 4" X 2.75" F 6,546' 2.992" Joint of 3-1/2" , 9.3#, N-80 ,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide, 5.25" X 2.937" Slickline/Fish/Fill Information: 3/3/08: Ran 2.262" GR and tag fill at 8080'. 7/18/07: Ran 2.00" Guage Ring to 8080'. No note of tagging. 5/30/95: Ran 2.25" Guage Ring to 8552'. No note of tagging. Zone 5'artd Tap PERFORATION DATA Adam Btrn Arrt SPF Last Perf Datie Prese* Cattdrdon C G7 6,656 6,ffi4 166 16 3~4lL008 ~ C 47~ 7062 7,159 - 97 16 342006 ~ C 51~ 7,779 7,8~ 49 8 4/1/198.9 Cpen D 53S 8,071 8,086 13 8 4/1/1969 ~ D 54-5 8,142 8,156 16 8 411/1989 ~ D 54-9 8,187' 8,243' 56 8 4/1119ffi Chen D 55-7 8,26:1 8,30Ct 40 8 4/1/196.9 Open D 56-1 8,345 8,463' 117 8 4/1/198.9 ~ D 57-2 8,5Q2' 8,527 120 8 4/1/1989 Cpen DATE: 3/4/2008 By: BCA PBTD = 8,675' TD = 8,730' MAX. HOLE ANGLE = 65 ° A-25RD Schematic .doc • • ...~~,~r'~n Chevron -Alaska Weekly Operations Report Well Name Field Name APUUWI Lease/Serial A-25RD TRADING BAY, 507332024201 ADL0018731 Primary Job Type ~~ Primary Wellbore Affected Perforating -- _ _ - Main Hole IJobs --- Pertorafing 1'rUeii Service I UVVDA... ~ ~`~~ ~3~ ~~ 101.0 3/3/LUUtS I I Daily Operations 3/312008 per ~~ ~~~~~. i '',Ran _ . ." ~ I ,jrn t,,-I fill a( EI( i' R ~n luuiinv'Jun b r iiCp 3/4/2008 )per ~.~ , IPerl :. ~" PJ G I I ii'J 6,t1~,_~~ I-li . ;c faun i; '-, K._ 111 l; (i;,iii , ,,~iQ' 3/5/2008 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California JA~1 ~ ~ ~~~$ PO Box 196247 ~~ Anchorage, AK 99519 Re: Trading Bay Field, Middle Kenai C Oil Pool, A-25RD Sundry Number: 308-005 Dear Mr. Brandenburg: ~~ `~ L~~ 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. Sincerely, DATED this day of January, 2008 Encl. '~ STATE OF ALASKA ~ ~ J,p,N 1 Q ZQQS ,~~, ALASKA OIL AND GAS CONSERVATION COMMISSION ISo t APPLICATION FOR SUNDRY APPROVAL~i'~ko Dli ~ Cis Cons. Co-~nission 20 AAC 25.280 l#~1C~tOC8Q8 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q ~ Waiver ^ Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ;~~j Union Oil Company of California Development ^ Exploratory ^ /fi'g`-/,~ %~ ~' (~ 3. Address: Stratigraphic ^ Service ^ ~ 6. API Number: P.O. Box 196247, Anchorage, AK 99519 50-733-20242-a1 ~~~ ~~ry 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q ~ A-25RD 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~ ~` ~, C~ c;}% f ~ ~~< Mono od Platform, ADL-18371 /~~ x~ /~ ~^~} Tradin Ba Field _ _ r ~ /~ 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,730' 6,071' ~ 8,730' 6,027 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,317' 13-3/8" 1,317 1,303' 3090 psi 1540 psi Intermediate Production 1,366' 9-5/8" 1,366' 1,349' 6870 psi 4760 psi Liner 8,726' 7" 8,726' 6,068' 8160 psi 7020 psi Perforation Depth MD (ft) Perforation Depth TVD (ft) Tubing Size: Tubing Grade: Tubing MD (ft) See Attached Schematic See Attached Schematic 3-1 /2" N-80 6,494' Packers and SSSV Type: Packers and SSSV MD (ft): Backer FB-1 6.530' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: ~ c ~ J~ Detailed Operations Program ^ BOP Sketch ^ ~ ~ ~ Exploratory ^ Development (i~ Service i.l~ 15. Estimated Date for 1/20/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C Brandenburg Title Drilling Manager Signature ,..,.,n, Phone Date 1/3/2008 '~.~... COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~g ~~~ ~ ~ r (~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ <.J~ Other: -.... R '. f ~S 111 ~ °' iUOV Subsequent Form Required: t , ~~ APPROVED BY ~y x Approved by: CO MI TONER THE COMMISSION ~ Date: /!~ ""Qu Form 10-403 Revised 06/2006 Submit in CLr6~icat~~~©Q aRIGINAL ~ ~``~`~~ Chevron • • Trading Bay Unit Well # A-25RD 1-3-OS PROCEDURE SUMMARY: MIRU slickline, run gauge ring and 2" dummy gun. Bail fill if required. Reperf the Tyonek C-7 and 47-5 Zone. A-25RD REVISED BY: BCA I/3/08 • API # 50-733-20242-01 RKB to TBG Head = 37.73' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mi119-5/8" casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2" (Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' • Monopod Well No. A-25RD (Inj.) As Completed 4/7/89 O. Depth ID JEWELRY DETAIL Item 1 37.73' CIW 10" X SM 3-1/2" Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis `XA' Sleeve 4.25" X 2.75" 3 6,498' 2.992" Joint of 3-1/2" , 9.3#, N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25" X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11' X 3.986" X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7", 29# X 4" B 6,532' 4.000" Baker Seal Bore Ext. 5.016" X 4" C 6,541' 2.937" Crossover 3-1/2" DSS X 3-1/2" 8rd. box. 5.68" x 2.937" D 6,542' 2.992" 3-1/2", 9.3#, N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2" Otis `X' Nipple 4" X 2.75" F 6,546' 2.992" Joint of 3-1/2" , 9.3#, N-80 ,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide, 5.25" X 2.937" Slickline/Fish/Fill Information: 7/18/07: Ran 2.00" Guage Ring to 8080'. No note of tagging. 5/30/95: Ran 2.25" Guage Ring to 8552'. No note of tagging. PERFORATION DATA ~«,,, tit Zone Sard Top Btrn Arrt SPF Fief Date Resent Cornitian C G7 6,658 6,824' 166 8 4/1/1989 ~ C 47-5 ~ 7,a64 7,159' ~l5 8 4/1/198.9 Chen C 51~ 7,779' 7,828 49 8 4/1/1989 ~ D 538 8,072' 8,05'i 13 8 4/1/1989 C{~en D 545 8,142' 8,156 16 8 4/1/1989 ~ D 549 8,18P 8,243' 56 8 4/1/1969 ~ D 56-7 8,263' 8,303' 40 8 4/1/1989 Open D 5G1 8,345 8,463 117 8 4/1/1989 Chen D 57-2 8,552' 8,622' 120 8 4/1/1989 C{~en DATE: 7/23/07 By: BGA PBTD = 8,675' TD = 8,730' MAX. HOLE ANGLE = 65 ° A-25RD Schematic .doc Chevron Monopod Well No. A-25RD (Inj.) Proposed As Completed 4/7/89 API # 50-733-20242-01 RKB to TBG Head = 37.73' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61# K-55 12.515 Surf 1,317' 9-5/8" 47# N-80 8.681 Surf 1,366' Section Mill 9-5/8" casing 1,366' 1,436' 7" 29# N-80 Butt 6.184 Surf 8,726' Tubing: 3-1/2" (Plastic Coated) 9.3# N-80 DSS-HTC 2.992 Surf 6,494' NO. Depth ID JEWELRY DETAIL Item 1 37.73' CIW 10" X SM 3-1/2" Tubing Hanger. 2 6,494' 2.75" 3-1/2" Otis `XA' Sleeve 4.25" X 2.75" 3 6,498' 2.992" Joint of 3-1/2" , 9.3#, N-80 IPC Tubing 4 6,529' 2.98" Baker Locating Sub 4.25" X 2.98" 5 6,530' 2.98" Baker Seal Assembly 11' X 3.986" X 2.98" 6 6,541' 2.98" Mule Shoe on bottom of seal assembly A 6,530' 4.000" Baker Model FB-1 Packer 7", 29# X 4" B 6,532' 4.000" Baker Seal Bore Ext. 5.016" X 4" C 6,541' 2.937" Crossover 3-1/2" DSS X 3-1/2" 8rd. box. 5.68" x 2.937" D 6,542' 2.992" 3-1/2", 9.3#, N-80 IPC Tubing Pup Joint E 6,545' 2.750" 3-1/2" Otis `X' Nipple 4" X 2.75" F 6,546' 2.992" Joint of 3-1/2" , 9.3#, N-80 ,IPC Tubing G 6,575' 2.937" Wireline Re-entry Guide, 5.25" X 2.937" Slickline/Fish/Fill Information: 7/18/07: Ran 2.00" Guage Ring to 8080'. No note of tagging. 5/30/95: Ran 2.25" Guage Ring to 8552'. No note of tagging. Zone Send Top PERFORATION DATA Adam Btm Arrt SPF Last. Petf Die Present Cartd6on C G7 6,668' 6,ffi4 166 12 1/??/08 Cpen(Flnpose re-pe~f) C 475 7,064' 7,156' 95 12 1/??/08 C{~en(Rnposer C 51-6 7,779' 7,828' 49 8 4/1/1989 ~ D 53S 8,072' 8,085 13 8 4/1/1989 Open D 545 8,142 8,156 16 8 4/1/1989 ~ D 549 8,18T 8,243' S6 8 4/1/198.9 Cpen D 567 8,263' 8,303' 40 8 4/1/1989 Open D 56-1 8,346' 8,463' 117 8 4/1/1989 C}~en D 57-2 8,502' 8,67'1 12D 8 4/1/1989 ~ DATE: 7/23/07 By: BGA PBTD = 8,675' TD = 8,730' MAX. HOLE ANGLE = 65 ° A-25RD Proposed Schematic .doc MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P .1. Supervisor K'o/1 b{?ì 10 :;: DATE: Thursday, May 19, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA A-25RD TRADING BAY ST A-25RD Src: Inspector ~'1·""·: ,&;8....., I:\,;;:,\:"ti' .. \ C%"d FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv....15'.e.... Comm Well Name: TRADING BAY ST A-25RD Insp Num: mitJJ050512093237 Rei Insp Num: API Well Number: 50-733-20242-01-00 Permit Number: 188-137-0 Inspector Name: Jeff Jones Inspection Date: 5/5/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A-25RD Type Inj. w TVD 4285 IA 580 2250 2100 2050 P.T. 1881370 TypeTest SPT Test psi 1071.25 OA 320 320 320 320 Interval 4YRTST P/F P Tubing 1500 1500 1500 1500 Notes: one well room inspected; no exceptions noted. sctl\NNEl) J~U(1 0 9 200'5 Thursday, May 19,2005 Page I of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 P 1~ M A T E RIA 1~ THIS MA C:LORIWIFILM.IX)C E E E W UNDER R K E R Ill ! ' STATE OF ALASKA ALASK^ OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION .OR RECOMPLETION REPORT 1. Status of Well Classification of Service Well ,, InjeCtion Oil ~ GAS J SUSPENDED ~ ABANDONED ~ SERVICE ~' , 2. Name of Operator 7. Permit Number Union Oil Company of California (UNOCAL) 88-137 3. Address 8. APl Number P.O. BOX 190247, Anch, AK., 99519-0247 5933-20242-01 4. Location of well at surface 9. Unit or Lease Name 1617' N & 551' W F/SE Corner, Sec. 4, T9N, R13W, S.M. Trading Bay State At Top Producing Interval 10. Well Number 6658' MD, 4541' TVD 1600' S & 3649' W F/Surface Loc. TBS A-25RD At Total Depth ..2~r.~I;.7/..~.,/)//.., ,~ R,,~,,~---'",/~¢/~ ,~.~7-F~/~/~ /~ ~...~.) ~,,~ 11. Fieldand Pool ~730' MD, 6095' TVD 18'54' S & 4964' W F/Surface Loc. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Trading Bay RT 101' MSLI ADL 18371 Tvonek "C&D" Zone~ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 0 ~-09-89 1-3 ]-89 4-O7-Rq .~--~---~ 69. feet MS L One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional SurveY/ I 20. Depth where SSSV set 21. Thickness of Permafrost 8730 'MD/~· ~'~' 8675 'MD/605I · YES [] NO []I N/A feet MD N/A 22. Type Electric or Other Logs Run ' 23. CASI NC, LINER AND YE~VI-E~'I'FiQ'G--(R ~-(~R SETTING DEPTH MD CASING SiZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# K-55 0 1317' 17-3/4' 950' sxs 9-5/8" 47# iN-80 0 6068' 12-1/4' let 2650 sx 2nd 1800 sxs ,,, 7" 29# N-80 0 8726' 8,1/2' 1250 sxs 180M# (9 5/8" window - 1366'-1,~36') 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD - interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See Attached 3-1/2" 6576' 6529' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAl_ USED .... Se~ Attached History 27. PRODUCTION/EST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR ~OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAS-OILRATIO TEST PERIOD ,, Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (curt) Press. 24-HOUR RATE I~ 28. CUR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED - 2 ]99O AJaska Oil & Gas Cons. C0mmiSSiq[~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS , , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Envi ronmental Signed Title HanageF Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this Well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (D.F, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 MONOPOD TBS A-25RD PERFORATION RECORD JUNE 27, 1989 DEPTH MD 6658 - 6824 7064 - 7159 7779 - 7828 8072 - 8085 8142 - 8158 8187 - 8243 8263 - 8303 8346 - 8463 8502 - 8622 DEPTH TVD 4541 - 4641 4790 - 4852 5312 - 5350 5545 - 5555 5601 - 5613 5636 - 5681 5698 - 5729 5764 - 5858 5889 - 5985 INTERVAL FT. 166 95 49 13 16 56 40 117 120 RECEIVED MAR - 2 'lggO Alaska Oil & Gas Cons. Commissior~ Anchorage UNOCAL WELL RECORD SHEET A PAGE NO. LEASE Trading Bay St. WELL NO. TBS A-25RD FIELD Trading Bay LOCATION: 1617 N and 551' W of the SE corner Sec 4, T9N, R13W,..S.M. Conductor ~2 PERMIT NO. 88-137 SERIAL NO. TD 8730' TVD 6095' DEVIATION (BHL) 1854' S and 4964' W of surf COMPANY ENGINEER ..McLean, Lynch, Graham SPUD DATE 01-03-89 COMP. DATE 04- CONTRACTOR Pool Arctic AlaskaRIG NO. --5 TYPE UNIT Oilwell 860 DRILL PIPE DESCRIPTION 5", 19.5~, Grade E & 5-135 ELEVATIONS: WATER DEPTH 62' RT TO OCEAN FLOOR 163' RT TO GL 101' RT TO DRILL DECK 26.28' RT TO PRODU TpN DECK 45 CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 13-3/8" 61~ Butt K-55 1317' 800sxs "G" w/l/2 CF parlite/sx 4% gel, 1% D-31, and 2% CaCl2 and 150 sxs "G" w/4% CaCl2 9-5/8" 47~ Butt N-80 6068' 2650 sxs 1st stage.- abandoned 1800 sxs 2nd stage 1350 sxs "G" (Milled window in 9-5/8" csg F/1366'-1436') KOP at 1375' w/l/2 CF perlite w/sx,.l% D-31 and 4% gel and 450 sxs "G" cmt. DVC 2605'. 7" 29~ Butt N-80 8726' 750 sxs "G" spherelite w/0.5% CFR-3, 0.6% Halad 344, 0.45% HR and 3% KCI and 500 sxs "G" tail w/0.2% CFR-3, 0.5% Halad 344, 0.08% LWL PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 3-25-89 6490'-6492' 8675' Squeeze Sqz'd w/ 454 sxs Squeeze Sqz'd w/ 482 sxs Producing "C" Producing "C" Producing "C" Producing "D" Producing "D" Producing "D" Producing "D" Producing "D" Producing "D" 3-28-89 6654'-6656' 8675' 4-01-89 6658'-4824' 8675' Production 4-01-89 7064'-7159' 8675" Production 4-01-89 7779'-7828' 8675' Production 4-01-89 8072'-8085' 8675' Production 4-01-89 8142'-8158' 8675' Production 4-01-89 8187'-8243' 8675' Production 4-01-89 8263'-8303' 8675' Production 4-01-89 8346'-8463' 8675' Production 4-01-89 8502'-8622' 8675' Production INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMAR Water Injection Well WELL HEAD ASSEMBLY TYPE: Cameron-Shaffer CASING HEAD: CASING SPOOL: TUBING HEAD: TUBING HANGER: Shaffer 13-5/8"-3000~ X 13-3/8" CSG SOW w/2 ea 2" LP outlets CIW 13-5/8"-3000~ X 13-5/8"-3000~ WF CSG Spool (7" CSG) CIW 13-5/8"-3000~ X 11"-5000~ DCB TBG Spool CIW 3-1/2" EUE TBG Hanger, DCB-FBB TUBING HEAD TOP: 11"-5000~ MASTER VALVES: 3-1/2"-5000~ Saltwater Tree CHRISTMAS TREE TOP CONN: MAR - 2 1990 AJasJ .0j! & Gas Cons. Commissio / nchomge OIL CO. OF C~r.TFf~NIA Page No. 4 of 11 DATE E.T.D. 01/03/89 2780' 1/04/89 2780' 1/05/89 1470' 1/06/89 1470' 1/07/89 1470' DETA~R OF OP~ATI(~{S, D~SCRIPTI0~S & RESULTS Moved rig to A-25 RD. Circulate well with filtered inlet water. Installed BPV. ND tree. NU BOPE. Test ok. Iaid down 3-1/2" kill strife. Ran in hole with 8-1/2" bit on 5" drill pipe. Ran in hole with 8-1/2" bit to 2780'. Tripped for 9-5/8" HOWfD cement retainer. Set same at 2702'. Char~ed over fluid to 64 pcf GEL/FIW system. Stabbed into retainer. Break=k~4n of 3/4 BPM at 1100 psi. ~ 350 sxs "G" cement with 2% CaC1 at 15.6 ppg. 330 sxs thru reta/ner and 20 sxs left on top. Cement in place at 1110 hours. Tripped for retainer #2. Set same at 1500'. Annulus would not hold pressure. Breakdown thru retainer 1-1/2 BPM at 600 psi. Pumped 300 sxs "G" c~ment with 2% CaC1 at 15.6 ppg. 285 sxs thru retainer and 15 sxs left on top. C~ment in place at 1710 hours. Pulled out of hole for RTT~. Ran in hole with 9-5/8" RTTS and worked down the hole testir~ the casin~. Located the holes f~m 1388'-1398'. Tested the ~us to 1000 PSI and held for 30 m/nutes. Pulled out of hole to 1150' ar~ mixed and pumped 290 sxs class "G" with 2% CaC1. Squeezed 245 sxs into formation ar~ left 50 sxs in the casin~. Pulled out of hole with RTTS and waited on cement for 6 hours. ~ up 8-1/2" bit and cleaned out to 1470'. Pulled out of hole and made up section mill. Began millir~ at 1366' ar~ cc~~ to 1370'. Cc~~ milling section from 1370'-1380'. Pulled out of hole due to pressure drop. Found ja~ par~d. Ran in hole with overshot. E~3a~ed ar~ recovered fish - mill, BS, XO, I-DC, XO, stab and lower jar body. Ran in hole with mill. Milled section from 1380'-1389'. Cont/nued milli~ section in 9-5/8" casir~ from 1389'-1432'. ~ a trip to change mill at 1414'. HO04 RECEIVED GaS Cons. Comnli$$JO.D /t, nchorage No. 5 of 11 1/08/89 1470' 1/09/89 20'/1395' 1/10/89 342 '/1737 ' 1/11/89 497'/2234' D~TA_ TTR OF OP~b%TICI~, D~SC~IPTI(~T~ & R~JLT~ Continued millir~ 9-5/8" sectice~ from 1432'-1436' (70' of ~). Circulate. Pulled out of hole. Jars parted at surface. (Same place as fish #1). Ran in hole with 15" underreamer. Ur~erreamed 15" hole frc~ 1366'-1436'. Tripped for 2-7/8" tubin~ tail. Could not ~ter 9-5/8" casing stub at 1436'. Pumped balanced plug at 1436' :200 sxs "G" c~m~nt, 0.5% CFR-3, & 2% CaC1 at 16.5 ppg. Cement in place at 1355 hours. Pulled out of hole to 1150'. Rev~_~sed out. Pulled out of hole. Held 300 psi on plug for 2 hours. ND BOPE. Removed DCB spool. Installed 7" casing hanger. NU BOPE. Nippled up BOPE. Tested same as per re~H~ents - ok. Ran in hole. Cleaned out soft c~m~ent frc~ 1154'-1270'. Waited on c~m~m~t. Clean out from 1270'-1331'. Pressure tested 9-5/8" casin~ to 1000 psi - ok. Cleaned out cement to 1375'. Circulate. Performed LOT = 128 pcf ~. Pulled out of hole. Ran in hole with drillin~ ~HA. Directic~ally drilled 8-1/2" hole from 1375'-1395'. Directic~] ly drilled 8-1/2" hole from 1395'-1461'. Pulled to 1350'. LOT = 146 pcf ~. Cleaned ~_~ pits. D/rectic~a]ly drilled from 1461'-1737'. Pulled out of hole. Pulled out of hole. Ran in hole with ~HA #7 (~ud motor with 3' kick sub). Ori~ted motor for m~dmum kuild and ~ectic~l]y drilled 8-1/2" hole from 1737'-1955', could not get any build. Pulled out of hole. Ran in hole with ~HA #8 (60' belly). Rotary drilled 8-1/2" hole from 1955'-2234'. ~ good build but hole turni~ slightly to the left. Pulled out of hole - hole tight from 1914'-1821'. Singled out with pump. Checked for flow - negative. Pulled out of hole. C~ed ~ to mud motor. H004 RECEIVED MA,~ - 2 ]ggO Alaska Oil & Gas Cons. CommissioP Anchorage UNICN OIL (DO. OF CALI~ Pa~3e~. 6 of 11 T~'ASE TRADZZq~ BAY STATE RTE E.T.D. DETAr~R OF OP~TIC~, DRSCStIPTIC~ & 01/12/89 585'/2819' 1/13/89 696'/3515' 1/14/89 512'/4027' 1/15/89 521 '/4548 ' 1/16/89 461 '/5009' 1/17/89 590'/5599' 1/18/89 339'/5938 ' Ran in hole a~ oriented mud motor 60° right of high side. Directi~ly drilled 8-1/2" hole from 2234'-2509'. Circulate a~ tr~ for ~A cha~e. Ran in hole with ~HA #10 (60' belly) a~ reamed tool run from 2319'-2509'. Drilled 8-1/2" hole frc~ 2509'-2819'. Drilled a~ surveyed from 2819'-3210'. Circulated bottoms up and pulled out of hole. Picked up Baroid loggi~ tool (GR-RIL) and ran in hole. St~ at 3135' ar~ reamed to 3210'. Drilled fro~ 3210'-3515'. Pulled out of hole for bottom hole assembly cha~e. Pulled out of hole to cha~e out bottum hole assembly. Recovered loggi~ data. Ran in hole and stopped at 3030'. Reamed to 3090' and oontin~ running in hole. Drilled frc~ 3515'-3965', then wiped the hole. Continued to drill from 3965'-4027'. Con~ drillirz3 from 4027'-4330'. Pulled out of hole and unloaded logging information. Tested BOPE. Cut and slipped line. Ran in hole with no tight spots. Drilled frc~ 4330'-4548'. Conti~ to drill from 4548'-4705'. Circulated and cor~iti~ drillir~ mud. Pulled out of hole to chan~ out the ]H~A. Made up new BHA and ran in hole. Drilled from. 4705'-5009'. Circulated ~ oo~tic~ to pull out of hole. Pulled out of hole and changed the bottom hole assembly. Ran in hole and reamed from 4979'-5009'. Drilled 8-1/2" hole from 5009'-5350'. Wiped the hole to 4925' · Drilled from 5350'-5599'. Drilled from 5599'-5783'. Circulated then wiped the hole to 4850'. Ran in hole a~ rig power failed. Restored power a~ ccm~ed to drill to 5938'. Pulled out of hole. ~ up new ~HA ar~ ran in hole to casir~ shoe. Wait on generator repairs. Con~ into the hole and reamed from 5897'-5938'. H004 Page No. 7 of 11 r~ TRADII~ BAY STATE W~. NO. A-25 RTE E.T.D. 1/19/89 463'/6401' 1/20/89 71 '/6472 ' 1/21/89 365'/6837' 1/22/89 95'/6932' 1/23/89 0'/6932' 1/24/89 87'/7019' 1/25/89 311 '/7390' 1/26/89 266'/7656' DRT~_~-q OF OP~C~S, DENCRI~~ & RESUL~ Drilled 8-1/2" hole fr~m 5938'-6Z14'. Circulated and wiped hole. Tight hole at 5942' and s~me swabb~. Ran in hole ~ drilled from 6414'-6369'. Torque and drag increase. Circulated ar~ wiped hole to 4890'. Ran in hole and drilled from 6369'-6401'. Encounte~ drilling break, checked flow (slight), circulated ar~ raised mud Cironated a~n raised mud weight to 88 pcf. Drilled 8-1/2" hole f. rcm 6401'-6472'. Circulated an~ pulled out of hole. Hole not taking proper fill. Ran in hole a~ circulated 90 pcf fluid around. Pulled out of hole and unloaded MND loggirg data. Tool failed at 6060'. Cha~ed out tools and r,an in hole. Reamed and logged from 6060 '-6152'. Cc~~ loggirg from 6152'-6375'. Drilled 8-1/2" hole from 6472'-6650'. Wiped hole with a few-tight spots and s~me swabbirg. C~ntinued to drill fr~m 6650'-6837'. C~ntin~ drilling from 6837'-6932'. Pulled out of hole a~ tested BOPE. Ran in hole to casirg shoe to _rep?~r hook. Well flowirg slightly. Ran in hole and stopped at 6561'. Hole packir~ off. Worked down to 6601'. Cc~~ to work down to 6618'. Hole packirg off. Pulled out of hole to charge out the bottom hole assembly. Ran in hole to 9-5/8" casirg shoe. Unable to lock hook. ~m-ged out blocks. Kelly hose frozen. Thawed out Kelly hose, well flowirg slightly. Ran in hole to 6546'. Worked down to 6932'. Circ, cleaned a~ cc~~~ hole. Drilled 8-1/2" hole 6932'-7019'. Circ ar~ cc~di~. Dropped sirgle shot survey. Pulled out of hole for ~HA change. Ran in hole. Reamed ~ logged from 6830'-6922'. Drilled 8-1/2" hole from 7019'- 7257'. Short tripped to 6320' with no problems. Drilled to 7390' ar~ pulled out of hole for ~aA charge. Finished runnirg in hole ar~ drilled from 7390'-7609'. Short trip to 6Z15'. C~ti~ drillirg from 7609'-7656'. H004 Page No. 8 of 11 NO. A-25 1/27/89 199'/7855' 1/28/89 284 '/8139 ' 1/29/89 232'/8371' 1/30/89 334'/8705' 1/31/89 25'/8730' 2/1/89 8730' 2/2/89 8730' H004 DETA~R OF OP~%%TIC~S, DESCRIPTIC~S & RESULTS Drilled from 7656'-7855'. Circulated & cor~liticned mud & POC~. Chmged out BHA. Ran in hole, worked through tight spot from 6578'-6610'. Cont/nued drillirg to 7855' · Continued to drill 7855'-8042'. Short trip to 6360'. Drilled 8042'-8139' · Drilled from 8139'-8228'. Circulated & cca~ i tioned mud. POC~. Bariod tool failed to log last 100' of hole. Ran in hole & relogged from 8071'-8228'. Drilled from 8228'-8371'. Drilled from 8371'-8505'. Circulated & conditi~. Short trip. Drilled from 8505'-8705'. Drilled 8-1/2" hole 8705'-8730'. Circulated clean. Mad__e short trip to 6000'. Circulated & POCH. Laid down MND tools & non-ma~ tools. Ran in hole w/BHA #22 (bit, stab, 10' LC, 8 1/16" stab, 1 DC, stab, i DC, stab, 1 hwdp, jars) to 9-5/8" shoe. S~ mocks to 10 lines. Ran in hole to 8730'. Circulated & ~iti~ mud. Circulate and coDditioned mud at 8730'. Pulled out of hole - laid down HNDP and BHA. Charged to 7" casirg rams. Rigged up a~t ran 7" 29# N-80 butt. casir~ to 8726' - unable to reciprocate casirg. Circulate and Circulate and cc~iftioned ~___~__. Mixed ar~ pumped 20 bbls of 13 ppg spacer. Dropped bottom plug and pumped 750 sx of Spherelite cement with . 5% CFR-3, . 6% Halad 344, . 45% BR-7 and 3% KCL mixed at 12.1 ppg. Followed with t~il slurry of 500 sx of class "G" with .2% CFR-3, .5% Halad 344, .08% LWL mixed at 15.6 ppg. Dropped top plug and displaced with 5 bbls of FIW ar~ 317 bbls of mud. Bumped plug with 2200 psi. Floats held ok. Cement in place at 1240 hours 2/2/89. Had full circulation throughout job but received no cement or spacer to surface. ~-~ed BOE. Landed 7" casir~ on CIW 7" x 12" slips with 180M#. Cut off casin~. Removed BOE. Installed and tested CIW 12" 3M x 10" 5M DCB spool. RECEIVED MAR - 2 1990 Alaska Oil & Gas Cons. Co Anchorage OIL CO. OF C~T,TF~EA PWe No. 9 of 11 T~ ~/14C, BAY STATE 2/3/89 8730' 3/21/89 8730' 3/22/89 8675' 3/23/89 8675' 3/24/89 8675' 3/25/89 8675' 3/26/89 8675' D~TA~ OF OPerATIC, DESC~tIPTIC~ & RESUL~ Fin/shed installi~ tree. Cleaned mud pits and lines. disassembled pumps. Laid do~n 5" drill pipe. Suspended opeatic~s due to cold weather. Released rig form a-25 at 2400 hours 2-3-89. began pickin~ up 3-1/2" drill pipe. ~ 7" x 9-5/8" annulus pressure was 400 PSI. bleed the pressure to 200 PSI ar~ built to 375 PSI in 2 hrs. Finished picki~ up 3-1/2" drill pipe. Circulated & cc~tioned mud @ 8633' to 92 PCF. Tested the casin~ to 2000 PSI for 15-minutes. Drilled plugs, float ar~ cement to 8675'. Circulated & pressure tested the casi~ to 2000 PSI. POC~ & nippled up lubricator. Rigged up wire ine & WI CE iCSTI a. Ran CET/CBT/GR from 8630'-1300' W/1000 PSI o~ the casi~. Attempted to run GYRO survey but could not get deeper then 3300'. Ran Sonic Array/f~L/GR from 8642'-2478'. Sonic tool i~cated problems W/the Ran base line temp log from 8670'-100'. Flowed 7" X 9-5/8" annulus & reran temp log. ~ up & ran noise log from 7000'-1000'. Located ~try @ 6520' ~3. Reran G~RO survey from 8650' to surface. Made up perforati~ guns & pressure tested lubricator. RIH & perforated 4 SPF from 6492'-6490'. Closed blin~ rams & broke down perforations @ 1425 PSI @ 1-1/8 BPM. RIH W/cmt reta/ner & set @ 6389'. Mixed & pumped 254 ~ class "G" cement. Final press 2350 PSI @ I BPM. ciP @ 1400 ms 3125189. Wait c~ cmt. Cleaned out cmt from 6350'-6381'. Bled down 7" X 9-5/8" annulus to 90 PSI. Press i~ to 120 PSI in 7 hours. Drilled out hard cmt & retainer to 8675'. Attempted to test perforations to 15000 PSI but would only hold 1225 PSI. H004 Page No. 10 of 11 T~ ~P,~)]:[~_~ BAY STA~ NO. A-25 DATE E.T.D. 3/27/89 8675' 3/28/89 8675' 3/29/89 8675' 3/30/89 8675' 3/31/89 8675' 4/1/89 8675' DET~_TrR OF OP~RATICIfS, D~ECRIPTIC~S & RESULTS POCH & picked up a 7" cmt reteine~. RIH & set ret_a~ner 6461'. Circulated-& ~ a breakdown @ 2400 PSI 1/4 BPM. Mixed & pumped 200 sx of class "G". Fix~l sqz press 2350 PSI @ 1/4 BPM. Cement in place at 0840 RIH & tagged hard cement at 6469'. Drilled out c~c & cmt retainer to 6519'. Cleaned out to 8675'. Press tested perforations @ 6490' to 1500 PSI. Pressure bled to 1435 PSI in 10 min. Rigged up wireline & shot 4 hpf from 6656' to 6654'. RIH with cmt retainer & set @ 6592'. Obtained hreaktown @ 2925 PSI @ 1/8 BPM. Mixed & pumped 482 sx of class "G" cmt. Final sqz press was 2000 PSI @ 1/2 BPM. CIP ~ 2300 HRS. POCH & wait ~n c~me~t. RIH to 6040' & wait ~n cmt. Cleaned out c~t & retainer to 6665'. RIH to 8675' & circulated & conditioned mud. Pressure testedperfs ~ 6656'-6654' & 6492'-6490' to 1500 psi. Bled do,n to 1435 PSI in 10 min. laid down 3-1/2" drill pipe. Pickedupbit, scrapper & 3-1/2" TBG&RIHto 8674'. Circulated& Pumped~~ity~& FIWuntil return fluid was clean. Circulated well w/FIW. Cleaned mud pits & surface lines. Displaced well w/73 PCF ccepletic~ fluid. POC~. reverse circulatic~ valve & perforat~ guns. RIH w/ guns & ~ up control head. Tied-in guns using gamma ray. Set packer & dropped the bar. Perforated the followir~ intervals at 8 8PF: 6658'-6824', 7064'-7159, 7779'-7828', 8072'-8085', 8142'-8158', 8187'-8243', 8263'-8303', 8346'-8463' 8502'-8622'. Shut in well & fluid level drop~ to +400'. Circula~ well though circulation valve. Release packer, circulated & well began to flow. Cc~~ circula~ w/well on choke. H004 Page No. 11 of 11 DATE E.T.D. DETAILS OF OP~C~, DE~i~XPTI(~$ & RE~ 4/2/89 8675' 4/3/89 8675' 4/4/89 8675' 4/5/89 8675' 4/6/89 8675' 4/7/89 8675' Cont~ circulation until well stable. POC~ & laid down perforatir~ guns. Picked up a bit & scraper & RIH. Lowered c~H~let/r~ fluid weight to 70 PCF & ~ slight flow. Increased fluid weight to 71 PCF & Check for flow & well flowir~ slightly. Spot 35 bbl of 73 PCF fl%~id & PO~. ~ up 7" BP & RIH to 2115'. Set plu~ & change out pipe rams. Tested BOPE @ 250 & 2000 PSI ((Hr). Rec BP & PO~. ~ up 7" PKR & RIH to 7910'. P%~ped 5 bbl I~ to 7910' the~ rev c~t to ta~k. Set PKR & established injection with FIW & 2100 PSI & 3/4 ~. Acidized "D" zone perfs (8072'-8085', 8142'-8158', 8187'-8243', 8263'-8303', 8346'-8463', 8502'-8622'. ) mixture, 54OO gal 6% ~CL~1.5% ~F mixture, & 12OOO ga~ FIW. Final press = 2290 PSI @ 3.14 BPM. Circ. Released R/TS. Perfs took 3-5 BPH. P(~. RIH with 7" RBP & RTTS. Set RBP @ 7249'. Set ~ ~ 6600'. Tested lines to 3000 Psi-ok. Acidized "C" zcme. Injectivity test = 2050 P~I ~ 0.75 BP~. Acidized with 2400 gal 7.5% FIW, 2730 gal 7.5% ~ mixture, 3530 gal 6% I~CL-1.5% HF mixture, & 8000 gal FIW. Final press = 1970 PSI ~ 1.4 BPM. Released RITS 9 6600'. Well flowed. SI well. Circulated 71.5 PLCF fluid to kill well. Well calm. RIH & recovered RBP 9 7249'. P~. RIH w/6" bit to 8974' EID. P(~. RIH w/ Baker 7" pkr assy. Set pkr 6530', tm'il 0 6576'. Tested pkr & 7" casin~ t/1500 psi-ok. PC~ laid d~wn 3-1/2" work strife. Laid down 3-1/2" work stri~. Ran 3-1/2" D~S-fIDC 9.3# N-80 IPC tubing. St_a___hbed into pkr. Test T/1000 PSI--(K. l.,~r'~led tubing. D~-plaoe annulus w/co.plUm H004 , ,, , r TUBING DETAIL: ~, ,~ ~- 1/'2", 9,5 #~ N- 8O, i I IPC T'BG, DSS- HTE: ! i 15-5/'B' 81# [,::-55 @ 151 7' , , I 1) OTIS "×A" SLEEqE ~ 8495' i i ; , 2) I~KER "FEI-I" PKR ~ 6550' 5'~ OTIS "×" NIPPLE ~ 15545' 4.tWL R:E-ENTR:Y GIJIDE ~ 6578' 9-5/E]" 47# N-~O 9-5/'B" ',,,YIN DFJ,¢¢ '--'5[ 685B'-6B24-' 1366' 1 4-36' ~-- 7054-'-.. - ~159' 7779'-TB2B' I B07~'-BOBS' , B1 4-2'-B 1 5FI' i B1 B285'-BS05' Et5 46'-B465"' i 8502'-B822' ~ohorage @ 8726' ........ 'WEll TBS A-25RD INJECTOR VCEi I SCHEMATIC UNION OIL COMPANY OF P_,AUFORNIA (dbo March 27, 1989 Mr. Robert C. Warthen Union Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519 Re: Boss Gyroscopic Survey Job No. AK-BO-90030 Well: A-25RD Trading Bay Unit Survey Date: March 24, 1989 Operator: Teer Mr. Warthen: Please find enclosed the "Original" and six (6) copies of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Directional Services Sperry-Sun Drlg. Svcs. Enclosures S E: .E..~ RY_- S.U hL... ANCHORA. GE ALASI<A IjNC~CA:L i:/i:': : ' :: :: ~:: : , DATE OF SLIRVEY MARCH 24, ::1.989 · : 'i :: : TRAEING BAY UNIT MARC:H 27~ 1':.~:--:':~ ,_lOB NLIMBER AK-BO-gC)0:30 !-...' ! ALA._-,F..~ KELLY BL..-:,HING ELEV 101 00 F'T : ........... OE~Rr-.~.T. QB_-_TEER VERTICAl, SECTION C:ALC:I_ILATEB AEON(3 CLOSURE ' :"T'R'I_IE . .................. L:-'I ~ '-: ' ..... "FI ~ "'-' COURSE = ~:, _IB-.:,EA L.-{ JRc, E .. MEASLIRED VERI' I (.":AL VERT I C:AL , I NCL I NAT I ON D I REC:T I lIN DEPI"H DEPTH E EF FH DES M I N E EL.',REE.:, 100 100, O0 - 1.00 (') ic' hi 4-5 69 2 o ..... 0 :200.00 '.;) 9. (') 0 0 1 '-'_'~ N '26 . :300 2':..:":;'. ""'- 98. 48 ...... · . ,:,.:: 1 :::::3 5 Iq :.:)4 '::':' 4. 00 .:, o,:, 75 2 ? 7 75 1 C) Pi'--' N 66 F-i F:; 00 4 ':7/7.00 :3':? 6.00 1 C) 4. 7 N 4 8.80 6C)C) ':"'.--~'-- '29 494.29 (") 52 ._, :: ._, .... .1_. N ~ 8.39 700 ' 69:3 'P C) F;';.~'? 9 (') ':' :"4 ~-, N Q ~-, 0 '~>(')(') '::":)":' (")Pi 792 05 0 'I.C) S 7 "::'T~ · . . i_t ......I H . .. i.. -- . -_ . 100 C) '-?.. ':'/.. ~,':-' 96 :-9_ c~.. 1 . 9/-,_ ,.,":' :37 S '2/-,_./-,_ 9 DOG.LEG ............... 'l"O .TI:IL ............ :...: ........ E F', T I C: A L SECT I ON SEVER I TV REC:TANGLILAR L. JuRD INA TE.=, DEG/100 NORTH/SOUTH EAE:T/WEST E 0 :'40 0 i° N (') 1'9 t -- . ii l__l . I . W O. :31 ........ O. 54, N O. 29 E-_ .~ ""':~ ...... ..... :,:. 1 2:1 N .~ 2F, E =; 6,4 =' 4'7 N 1':''-'= E :'::. '"::'? 1 ~;. 4 (") N :'::4 6,5 E = z-,F, 3(2) =;":' N 44 68 · -! ii -- .. n '-- .1'.. 1, ,.-.,~ W ._."";. 1c',_, 4/-_ ........ N 46 .41 E ':' 77 ~':' 75 N ~5 ~":' · ..$ · .m i!1 ii ................. = ,_ E 5.87 6'.:::. 70 N 45. 'F.'7 E .:,'-'. O1 .,=.it.?_. · :3C) N 4'7 . ,-:1-7 12 (')_ 0 I i '?. 1 37 10'P 0 37 12 z.._,'-":-' ':' 6, 5 . :'=:_.9 W A, :':: 6 4 ':' .... 1.5 N 2'-? ~ # '-! -- -- · I . 1300 1287.84 1186,. 84. 17 .... F', =', S 6, 6 .60 1400 1 '--":' 1 ::: (')1 ",':, (') '-, ') '-"-' ........ =. ...... :,(. I S 6:2 :::c.) ............ . ................. .,:5.~ .................. . _ . · 15C)0 14'7:3 '-'= · ,:,._, ~ 372 ':' =; 24 4 S P]'? ,":,'? 1600 15 6, 4.94 14- 6.:3. 'P 4 :24 4. C) S 5 C). 1 'F/ ..... 1700 ........... ! ' '-~" z :: .-',= - ,-.= ..... c,._. ~.._., ._/.:, ].. ............ l:_.!:,,_~ ,.,'_-~.q ............ ::.j. ........ Z ............. c, ._..,C). 50 1 :::. O_ ('). 1 '7 ~ 4,_, 0 :S' 1645 ,, L") .:,'" ~:..'":' ..='~ ._,":' 1 ._,c' H_ 1 .3 19 (-) ('~ 18.'2:6 2 '? .l -/":' ~ 29 '-.' ~'-"-' f=; 2. .............. · .._ z.,:, S _ 5(.') 2C)00 l'P'.::.'6.49 1825.49 ';.-:.'5 -1.(:) S 5(:). 5(:) ........... = 100 2(:) J. 5.91 1914.91 27 28 S 4.':~ 89 2400 '-." .--' T F, 21' '-' . = ..... :2174.21 31 I1 .:, 59 10 W · ::' F, (') 0 2:36 ('). 4:3 ":'":' ~':/ 4 :':: 31 5:3 ':' 6, 2.6, 9 W d....... _ .'.-' ._ ... ._~ .... 260C) 2443. 'P7 2:'::42.97. 3/.'1-46 'S 63. :30 W 27C)0 '-"~'-' 5":' - .'_::7 '-]':' · .'._..'4 24-2.'_::. 5Z S 64 1':? W · ._ .'# .~ ._1 a .- · -~, i-i "(- . . . . ..',:,L) .) 2601 97 '-"='- ' ' '-' . ..:.:,t) L) 97 40 .'2::_:: .:, 64 8(') W ..... 2?00 .... ":..'/_-,75.84 ........ 257.4.E!z. 1- . ,-1..4 ...... 1{:). .:E; 65. C) 14 3.77 ..'.'-'._,=' ...'-'. :30 S 377.11 2.01 277.72 S 422.81 2. :::':.? ..... ::-: 02. ' = ..... c,.:, 'E; ......... 471.77. :3. 18 :32 E:. 84 S:; 524. 'F' l ":' 6'? :':,' ~ A 0/-, S ._~,_,'z' 1 . ':.;":? .iL.= ~ _ _ . _ . .. :3../:':. 2: ........ :}.':,'_--: 4.6, :3 S ..... 64-:3.01 E ......................... ..-...:.:9. 'R .1. ........ -- -4:3. '-" ._ ,_-, <.-., E -17. -'Pi-,/._ 1,4 .............. 16.. :24, w 54. ss .) W 9:3.42.'_' 1,~J .......... '--m '--I , ......... 1.,:.,.-',, .06 ........ W 17:3.4 8 W .-'-'14 .38 --.,~.~ ~ .. .~ .) W 297. :2:7 ":":a')..~':~ W 440.55 W 492.18 W. .. 546.71 W 605.6,0 W 668.54 W .... 7:2: 5.6, 5 F;F'ERRY-'.:;I IN WEII F;I IF,'VEY I Nr"~ F:FIMF'ANY F'Ar"E 2 · : ANCHORAGE ALASKA UNOCAL : DATL:: OF SURVEY M.ARF:H 24, 1989 "'~ ...... '. I _ ............. '-'1 tRUF'Y A.s._-RI: F:OMpLITAT Z ON DATE BFC:;F; r~YRI-C-RF:F~F'I C .:., .... v TRAD ]-' NG BA'¥' LIN z "1" HARCH 2'7, .1 9L:',9 ,JOB NI..IHBER AI-'::-BO-90():..:.;O ALASKA K'EL.L.Y BLISHING FI_E:.V. .-..-.: lOl.C~O FT. OF'ERATOR-TEER ...................................................................................................................... . VER'FIC(-~L SEF:TION CALCULATED Ab]NG L..LU.:,JI-~E MEA,.~;LiRED" DEF'TH TRLIE .:,_ B-.:,EA. COLtRSE , ,. VERT I C:AL VERT I CAL.. I NCL INA]' I ON DEPTH [)FF'TH DEr'-~ M I N L-:L]LIRSE DOG-LEG .............. TOTAL. D I RECT ION '..3 E VF..CR I l"Y RE,_-: T ANGULAR riEGREES DE:I3 / 1 O0 IqORTH/::-;CIL.I'TH EAS']'/WEST 'SECT l ON 31C)O 280'.:.~..=;3 2708.5:3 51 22 S 64.19 W 32(.')(.') 2869,97 '276::.:. 97 · ,. 4 .1. :3 S ._ 7 :3:_:: :::300_ . 2926.04 ...'-"':":'.~'~,_, :3400 2977. F:_ 9. .-'-'-' ,=,'-' -7 ~= .... 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E~..GE .......... 3_: ANCHORAGE ALASKA UNOCAL DATE OF :--;I_IRVEY MARC:H 24, ' 1'-"-' "".-. ,:, .~ A..'._-RD L-:OMF'LITAT~C~N DATE ..................... ~_-!~--~--; GYROF;C:OPIC:..F-;URVEY TRADING BAY IJNI]' M~RC:H :27 l'-?F=o ,_lOB NUMBER a~..-'-pr'l-,..-/cx'y:,c~ 7 . --., I"-I/% ,~--" .. ." # ~ "--~. ALASKA KELLY BUSHZNG ELEV. = 10~.0C) FT. !3E'_E' B ~ T..O.B_-.:.T. E ER VERT_T C:nm" S:i--CTZ ON '::aL'6i]'E-~i-~:E6--'n'EON,:~ CL::,SURE . TRL.IE .=,_ID-.z, EPl I ULIR::;F f':F[I IRF;E ].".il-ii~-L MEA'._:;I_IRED VERT ] f_':A L VERT .T. I_-:AL I N(.~:L...T. NAT I I.-_IN lEI I RI-_-F:T I ON SEVER I TY DEF'TH DEF']"H I]EF'"rH I]E:G I'I I Iq I'iEGREES DEG/100 6000 6100 6:200 6:300 /:,400 6:=;00 6600 6700 6800 6900 7000 7100 4. 22:0 /:, 7 4119 67 ='- ~.:, S 73. 10 W 4276.....":' 1 4175 .21 ._.=;._':~ 6 S 74 . 0 W .............. 4:3:3:3.81 4232.,_,':' 1 F;.. 4 32 S 74 . F;._ 0 W 4.:::91. :36 ..1.290. :,3/:, 55 11 S 7:3. () 1,4 IREC'I'ANGLILAR COORD I NA'TIE'S VERT I (::Al .... 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F-190/-,_ _ _. 41 :::/-,_ _ ._,._,== N 8':/... :"-':(')_. W ~.'-". 2 (') .... 170/-,. 2'-? ...,':' 4057.6. 9. W 4:3'P/: ....... . W 1.72 1721.74 S 412L:.:. 2.'.:.: W 44./_",7. I'.-;4 W ':'. 91, ..17:35.94. ':; 4196. 18 W 4~:--:/-,./: W 2. (.'):2: 1748.21 S 4261./:,:3 W 4/:,02.3/:, W 1 '-":' 1 v ~::: ~,:, S 4.:,,' ._ /-, 2 W 4/-,/-,/-, 05 · .-I_1 · - .. I '-. l_l u ..... 1,4 1.4,:, 1 / :, 7.4._ .:, 4 .:, ¢, ,:., . 28.... W .................. .7..~: 7.. ......... ~., ............ W (') 9::,' 1 -'-'.=, 00 c- .... z; ..... 4449.71 1,4 478:_:,' . ._,':' 1 .... F, . W 4:347.2 L--.: 1,,,! 1 0::: 17:_--:1 ~1 .'_--; 4._10 O'.T, W i. 0 ~'~ 17:36.61.. :.i:.: ..... 4 Ss;'70. :34 1,.,I ..... 490 :i';. 6 ./:. ........ .-/6o · 7/_-, W (') 4. 8 1790 88 '.E; 4/:,5:o./-,() W 4'- '-' W (') 9/-, 1 '79 4:2:5:: S -1-690. ='-' ..... ...,.,..: N 5021. :23 W ('),.'.-::7 1796..5:3 S 47.=;(') '-'= W .. _='")-"-' '-'= W (:3. :34 1798. :36 S 48' ]. 0.2'0 W 51 :-],~. 14. W 0.4/:, 1797.56, S 4::-:7(}. 05 W .=', 191.81 _ ........................... F,'-' ,-' :34 W i. 09 17':":' '-7, F; S 4 '-?/-, c) ()/-, W 5276, = '= ,' ,' n ..... · .. - · H ri R I Z 0 N T A L D I ::2; P L. A C: E M E N T = ....-.. / 6 F E IS ']- A T ~:.:.; 0 U T'H 70 D E G ........ :3 M I N W E S T A T M D 8650 m .,..~I . I ........... -['HE F:ALC:LII_ATIC$1 F'ROCEDLIRES ARE BASED ON THE USE r'lF I"HREE 'l '-' . .. I:. IMEN.:.,IONAI_ RADI I..IL--.; OF C:LIRVATLIRE METHOD. ................................................. S. EEBI?Y_::_L:iUbI.._...WELL.._SL!.R.V.E~:I.N!_~_E:QHF~.N._Y_ ..................................................................................................... E'.E4..C,!E ....... ..4_[....' ANCHORAGE ALASKA UNOCAL DATE OF SURVEY MARCH 24, I989 A25...-_.SD C'.OMPUTATJ ON. DATE TRADING BAY LINI'¥ MARCH 27: 1989 ,_lOB NUMBER AK-BO-9003C) ALASKA KELLY BLISHING ELEV. = 101.00 FT. !-7!F._'E..~A.Z.!..--!~.7_.T.E...E_'..~ ................................................................................. I NFERFJLATED VALUES FOR EVEN lC~Oo FEE]' OF MEASUREKi DEPTH TRUE ................. SLID'ZSEA' ' 'rOTAL ..................................................................................................... MEASI_IREKI VERT I CAL VERT I CAL F~ECI'ANr~I_ILAR E:OORD I NATES MD-TVD VERT I C:AL. '~ I]EE;T.H .................. E!EF'I"H ................... .K!.E.F'J'H . . NQ.R].~H../..:.-E;C!L!TH ........ EAST~.W.E~---:T ......I).I_.F...F.E.~_E. NCE ................ c:OR.".RE.C:.~.! ON ........................................................................ 0 C). 00 - 1 (") 1. ("~ 0 0.00 100 0 ,:.;, o .::,. 96 '"" '-:'.' ..... ..... =,; 1 '-.-.',/-, 59 30 1'4 2000 1926.49 1 ,_,'='";' bi.,..._. 49 I..:,'-'1 .02.. :..-:.-; 36:'00 .-., -z : ,':.: O1 2644 C)l 4.1'::'i ':"=' S 40 C)0 ':":, 52 ~ 4:3 · _,.,:.._ ... 3 '1%_ C).. 4:2: 793 .04 c.._, 5 (*) C) 0 ::~ A 9 :'q =' "~ ..-:,.,=:; c-,,.-:, F~,= -. ........ , ........... .. .... .... , '11 ~('"~.), 60C)0 4167 .....':.;':':*~ 44:)66 c:,.-,..:.._., .t ,.'!.45. C)C) S 7(:)(:)(:) . 4749? '='~' ........ / *'-' ?';C) 1671. ()8 . .~ L) zl- ;:,~-o., _ . . ........ ::~ (*) (') (] ._.~i'~''''~-r,-,/ 46 r~.-,,-,/. ~'., 1 o ._,.:,,:, ,_*, 46 ~ 3,,-,/. '-'/.~l'" . .=, '_, ._ ,., 6 0 0 7.41 "-'- ' . .'/._, S · _,.~06 41 1799 '- 0.0 0 O. O0 47.47 E 7.04 7,¢)4 224 C) L=, t~ 7:3. = . ,_, 1 66, 4'7 7 OF;, 32 W '-'~ .,::._ 4 '--,'-? 1 o _'i 4. 7 _ ~ ... e.,m n ... ~ ~--~ ~ * m~) .'% I~. t'"m 1478. ':';'2 .. W ................ <'.4o.,_.:,!.7. 4..'-. :::.:..-!,;:: . '-'(' . F,?, 2301 20 W 1 ..:, .)/_', 4..5 ..... 7. ,=,'-"-.'..' 313 C) · '20 W 1,_, '=' ...,'-" ..-":'. 07 ._%.,:..'-' ._~. 62 · ':; c? 10 :=: 6 ' ' '-"-' F,'" '=' 0 ....... . w ..' .,s :_ '...'...._~.. 41 '" ":' ........... "'~ = .4 ~ ................................................. 4 .:, 7 ,U,. 34W 2512.54 .,_9/-_,.,_..'::,. ,r). 4 4'F.;/-,c) c)6 W .--'-,42.5'.-.-; 1::-:0 05 ............ :,EE ff(R.Y.,:.-:.,=, _IN_NELL ~ SUR VEYI.NG_ C.Cd':IE:AN.¥_ ....................................................................................................... RAGE :':"::~::'-~7'ii : : : ~ : : :: :' :: ANCi-IORAGE AL. ASKA UNF~CAL : DATE OF SURVEY :MARC:H .--~ l_m. TRADING BAY LINIT MARC:H 27, 1989 ,Jl]B NUMBER A L A S K A K E L L Y B U ~.:;H I N G E-" L !~E:E RA ~.QE;_L-...TEEB IN'TERF'CILAI'TE[I VAL_IJE'.L:; -I" ..... : . FLR EVF-:N iC)(') FEET Of--'.~l IB-~=:EA DEPTH TRLIE '-' { '-' .=,LIE -...:,EA TOTAL MEASLIREEI VERTIC:AL VERTICAL REF':TANF. iLILAR I_-:CIL-IF~[I I NATES MD-TVD VERTICAL 'l " '~ ' --' "- .... :.:-.L: ............. :-:'. ...... ~ ............. ': .... -:-~ ................ 2''_: ....".'. .E!. .E..F., T_ _I::! [_.E..F. [1:.! .......................... ..K.'_ELF._.T__H_ ....~ ....... NLt.?,,_..T..H_/...?_b!UT. H ........ . EA.=,]/WE.=, F [ I FFERENI_.E L. LIRREI..] I LIN 0 O. O0 --101. O0 O. O0 201 201.00 100.00 0.54 N :::_ o. 1 :30 ]. .00 2. (]. o.. 00 1 . ~.~:'" '-' N 402 401 O0 :::(3(] 00 '= F '= ~' f ...................... ~., .:_.~ 'j, :f:=~ ....~ .... · :,U4 ]:('J.. 1. O0 400. O0 1 ._, =. 92 N ~'= %'' :31 ::4 :, U._, 601,00 ._ ~.~ U. 00 . _ N 707 701.00 600.00 47.87 N _. ,::,(.) 1 00 700 c'~ c') ~;c;. ::: 9 N 907 90i. O0 800. O0 62.58 N : .:: : :: . ,-, - -~ -. - ~, ,- · . : '.. : .~ ' : ANL. HURAL, E ~-~LA.:,I-.'..A '-'l ' '1 .... ' : '--,"=: I_INOCAL DATE OF ..-,.IRVEY MAR_.H ~4, .1..-. .... . "'"'5 '-'II f':I'IMF'IITA'T'II_'IN DATE . I~;I.,::.'. ..--. !'~.L... ]"RAD I NG BAY LIN I T MARCH 27., 198'.-.? JOB NLIMBER AK-BO-'.-.-,00:'30 ALA'._:;I':::A KELL. Y BLISHING ELEV. := 101.00 FT. !:.LF.% ~&T.. 0~_-_ T,.EF-..~ : I NTERF'OLATED VALLIES :FOR EVEN 100 FEET OF SUB-SEA DEF:'TH MEASLIRED E EF TH DEPTH DEF'TH NORTH/SOLITH TRLIE .:, _IB-.-_-,EA VERT I CAL VERT I C:AL. 1971 1901.00 1 :::00.00 2089 2001. O0 1 '.-.700. O0 2197 2101.00 2000· 00 "':":' 1 :.3 2201 00 '-'100 00 24:30 2301.00 2200. O0 ..................................... 2548 2401.0,0 2300.00 2/=.70 2501. O0 2400 · 0,0 2798 2~01 · O0 2500. O0 2935 2701.00 2600. O0 3OF:,':.. 2801. O0 2700.00 · =,44 =. :3001 00 2':.-,'00 00 3661 3101 00 '-" ]' · .:,0 C 0 00 · =, ,::, ,._-,/. .-, .-, (- .=, ...... · =, .-. _~ 1 00 100.00 ,~1 I.i i.I _1 ii .... ._i 4111 :2:3 01.0 0 3':.' 0 0.0 0 4 3 4 :=: 3 4 01.0 0 :::::: 0 0.0 0 4._ 74 .......... :359.1 47'.-.?2 :3/:,01 · _ (.) 17 :37 c) 1 '['OTAL R E C: T A N G Lt I._ A R r=: 00 R O I N A '1" E .'i.:; 123.22 S 154../=,6 S 189. :::4 S 22'7, ~. 1._,':' MD- TVD VER T I C:A L · E A S.:!]/.W ~: :~!T_ .... ~! !E E ER E..N LTig_ .................... C O~.B..E.~!7.T_._!,. 214 · 5i.') W 70.72 10. 80 ":'=;':' ,q. 8 W 82 19 11 47 . . :2'74.06, W 96.08 1:3.88 :340.04 W 112. :32 16,. 24 ":":":' .%/-, f-:; 44 F.; '::, 1 W 147 17 1. ,9 02 ,...,i.i ,, · .... ·., · :320 '-:~:::: S .% o':' '-"- ..... :, /.::, W 16'? 40 '-"-' 24 mm ,- .., ~ . · ,'"-.~. · · '-".'74'~ 7¢) .'_--; 5:=-:1 24 W 197 73 2:=-: .... 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E HARCH ~:::7, 1989' ,tOB NJMBFR AK-BO-'F'C)03C) KELLY BUSHINI...] EL. EV, = _1_()1, O0 FT. FIF'ERATFIR-TEER INTERF'OL. ATED V~..d_LE.::, FOR EVEN lC)C) FEET OF' SLIB-SEA ~EF FH 'I"RLIE .z, LIB'-" ~-.z, EA'-'' TFiTF~L_ IdEASi..IRED VERT I C:AL. VERI' I CAL RECTANGLIL.~R C:CIORD I NATES MD-TVD VERT I CAL DEP.'['H DEF'TH /.E.F.FH NQR}]H~.::;O~ JTH ..... EA.z,T/WE.zL! L. IFEERENC:E CORRECTION ,:,...' :, 7 '7 (] 1 00 ._ 600 00 179 !'"-~ ........ S 47:30. '-' ") ,:,C W '::'":":¢'-' ._,,z, (..) 1 00 ::; 7 F) 0 00 17 .~ ,:,. S 4 :::,:') ::;. 4- 6 W . , ....... .z... '='""' . .... ':/'-' 24 ....... '-'"" 799 70 c,._, 2[ 6 '"" '':'~" ' ""' '-' .::, ::. L) .L ...... (")_ O. ~ :::c') (] 00 1 . S 4,z,,z,. ,, 1 ,.:,/. W ,:,: ...... 6007.41 F; 90/-,. 4. J_ 1799 9F; ::i; 49/-,(') 06 N 2566.29 24. ?4 2591. 11 ...... 24. 2615.93 24.82 2642, 5'.:.;' 26, 'T'HE"c:ALC:LiI'~TiON F,R°CED'LIRE}~i' LISE A LINEAR i Ni:'ERF'C,L. AT ION BETWEEN THE NEAREST 20 F'C.3T MD (FROM RADILIS OF F:LIRVATURE) F'FIINTS 5PERBY -SUN SCRLE :- 1 INCH TO 1000.00 / 1000.0 TRROING 8RT UNIT UNOCRL R25-RO H~CH 24. AK-80-90030 1989 TRUE NORTH -so~o. oo -4obo. 0o . -so~o. oo -2~ HORIZONTAL PROJECTION ~0. O0 --1000.00 --2000.00 SPERRY -SUN 0.00 5CRLE ;- 1 INCH TO 1500.00 / 1500.0 TBRO]N6 8R¥ UNIT UNOCRL R25-BO HRBCH 24. RK-88-90030 1989 1500.00 8000.00 4500.00 6000.00 7500.00 6007. ~' 8650 VERT I C~L PROJECT I ON I 1500.00 8000. O0 4500. O0 6000. O0 Eastman L_~. '~'~ -::I- ,,':-:, '! 'I ,::i-.'.::, I:-t h st ,a.F..:'_-'., r~ .i:-'.~,-,.~ t ;~.r~ ,:-t e.l--~'.:: ?'..r...~,. .14- ~- (]r..i:'~in r~,:,int ,::,f ],:,,:a] ,:,:,,:,r-dinates is si,:,';=:, '~::~- ~. .!:!. 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':i:, ,::)O. ~'),."') ...'.~ '7..' 2:3. '"~._,"- '.5 0 .~"-" '":' q-4 . 17' /--, 100. C)0 4'2'P :i:. 4 5;' -':1- ::~: :7': 2 2."'~ 4. J. 7 ,5, 2':") 0.0 0 4:3/:, O. ,'-, :5 ¥ '7 :-'.2 2 4 4-. 17 ,"-, :'3'."')0.0,:'-) 4,-% 2 9.7 U 4 5 5:2 2 4.,:%. i 7 F"aae._, = EASTMAN CHRISTENSEN, Anch,:,r.a.~e, A] a$1-..:a 11-0C:T-88 Well Pr-,:,file ( cc, nt i hued) Measur-,e,J Tr. ue Ver. t Inclir,. DePth DePth Dea Min .-- :z: 000.00._, ..... ~:, / o .45 ,_,c' 178 . !=, ..... o .~ ::: (') 1 . 00 8:342. "--"-' = '--~'-' .... :: .... .-...- 1. 4:2: 0 4:.-_-;0 4:2: ,:") -,$:3 (:) 4:3 0 4:3 ,.") 4:3 0 Azimuth De'4r. ees De.~ Min 244. 1'7 S64 ION 24-4. !7 S64 10W 244. 17 :_--:,541 (-) W 244, :1. 7 :'364 10 24-4. 17 :E:64 10W 244. 1. 7 S,.':, 410 bi 24-4 17 '-'/-;' . .z, c,,-, 1C.'.b~ 24-4. 17 S,54 1 '-'-~ W Re,] t~n ~[u 1 ~r. C ,:, o r. d i n a t e s Ver. tic~l :E: e ,_- t i c, n 1/_-, 29. 17:B t 650. Oc) S 1659., ! 1 L :.7 0 7.6:F.:S 195/::,, 2/:,:%; ':-2104.. :-3 ::'::3 :21 =''';' ...... 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'i.:,'2 i ':,sds:C). :=::3 2 ~.'~ :3 :::: 4 c) '.:!; ,~" ,] = ,'-/- t..,l 7642 ,, 67 = '" =--'' ..... =.._:, ,, 7'7 ! '.--,F:C~ 08 - ~ ., -! -T ~., '-- a ~,,' '--' - -" -- '," · :, r", ,=.V-, !-";2 '"" 4/422 44 W v,"-,6c: ()7 ='-' ~'-' 77 ._ .... ............. .:, ::, ,, .~.. 1979 . 4-4 6.-q (] 6 N'=":' 5:1 E 74.79 N 2 ',.=_: ._,':' .~-'.-" _,~ :_--:4.5:3 N27 4,£,E ':74.29 N27 1 Eastman P o s i t i o n or, Lue 1 1 A-=._RD MD TVD NL=: 272]', 1.46 22=:'7;0. O0 2767. :36 2410,00 2 :=~t} 3.2 7 2 4 :B 0.0 0 >::"="=' 17 2450 00 ~.. _1 ,_~ ..' · · 28 '75.08 2470.00 25? 10. 923 2 4'..7' 0.0 0 :' 9 4/=, 8 5;' "':'.~] 1 0 0 0 2 9',322.7 9 2 53 ()~ 0 0 :'-: i/=,2. :32:2/=,23 c). Or) '3 '.'. ':.-28.2 2 2 650.0 0 :32 3 4. L :3 2,"=. 7 0. C'- C) :3 2 '7 O., ,:;::, 3 '2,42,' 7., t}. 00 :3:305. 'P4 27 ]. 0. C)C.) 3:34 1. ::34 ? 7230.0 0 i",23'7 7 -'-'= . ,' ._., :2 /._.,C:.. C'.O ~:413. ,(:,5 2770. CAL_CL~LA'i' .[13i',l OF {]ETWEEN WELL'.=; 2 4 4 9..~]/-, 2'7 9,:}. (')0 · 3 4 :=i 5 · 4 6, 2 81 0.0 C:, :t5',7.21.. :-.-:7 2',3230. ', t~' I~ .- '~*' .--! ,"1 i%.- .- · .:.=,7. d/ ...'c ..... L),C)C) Cl,:,$est P,:,sitior, or, ~ell A-1._,° EN MD TVD NS EW 7 6, i. :'-':'; :=: W 2.5 4 2.5 1 2 2'P :2:. '? c) 7:=:8 72 W '-'='= C)= 2232~ ,6-'¢ ~ ." ._J / ._t · ._1 _ . 8 l 5 ''=/-, W '=,,:-, r') 7 Pi 9 2:3 '4'::, '-"-' · .--' _ ~ -- -_ ~ .... .' ,~ -~,~ :=: 42.4 0 W 2/=,4 0. 1 :=: 222 7 7. 1:2: .... :,._, 'S '--~ 2 6.. 0 22', W 2222=26. 22223 rE; 'P 42.0 6, W :=:42 c)O '.S 'P=."-' c):=', {.4 ,, . ...J ,Z, ,, ,. . 347.68 S 974.1i W 4<")2. ""= .Z' 41=. 22',4 · ._~ ~ : .... : .... -'-/ :=: 990.('.~1 W · : ..... =, :2: ',=; 1006. C:,8 .W :3/=, 4. :3 4S :I. 0 2:2 ,, 14W 22',/=,9.8'7 S :1 0:3 :=:. :21W 2,-7 5. ~1. 0:S 1 ,:]} 5 4. ':.:",22 W :--: L: 0 ,, ':T.' 4 S 10'70. :3 4 !.4 :7.:',!ii:,{.:, ,, 4 .. :5 ! 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O0 1:350 · 00 1:370.00 '205.2,:) W '2 t 7,74 W 2:30../:, 1 W 2= '~ '-..'._,, 8:3 I..,~ :L '.-7,,'2.07 W 117.50 S 6:38 E 1 '--~/-, '-'~ .... 1 c'; ..... :,._, W 11:3 /:,9 ':' . 2/:,E 2,' 01.66 W 120.:32 '.:;14 I7E '2 0,'_-,. 4'P W 12 2.4:3 S 1 :i-: 8 E ~ '? 7 7. :_J 0 2 ,'.-) C-)'2 ~-'-' . _ . , ._b.:~ 2 0 2:3.01 ':'jO5:-:: · 78 ! :390.00 i ':-/i o. oo 192:0.00 1 S' 5 ¢). 0C) 90.42 '.--; 97.07 '.:; 102.91 S '-'::' 11. :':-: 4 W ]. '- ~' 0/-, ::;22 c')F .~_ ,-'._ · _ - . 21'- 2:3 W 1:28 24 '-"-' = ...... :, .-' .j 49 E · ---2 21. 14 W 1:3 2. c] 2 E;2 9 '-' = C Al_ C I II AT I 0 hi 0 F - "-' .. _ I_I-_A.:,T D I'.STANCE BETWEEIq WELLS P ,:, s i t i o r, ,:, n w e 1 1 A- ...._ R D ! i M D T v D N :_:; EW Cl,:,sest Positior, ,:,n well A-11 MD TVD N'._:; EW 223 ,, ('.:.(':, S 2:'::¢). :.30 LE; c.,-:,/. ':7;',E: S 243.7~.]~ S I:?e.F : S07500, gl JCl 250,47 257, 2'.:-': :264.., :I. 5 2'7 ].. 0:~; [list&nce Dir. ect Between Betwee Wells Wells 2:--:0. ?2 W 141.66 S:E:L-, 54E '-~ '-, ~-~ (D . . ,~ ..... ..:..: ........ 3 W 1 .,1. 7 z.t,-} '.:; 4. (3 2 (') E 24 ~'~, 'F,' 6 W 154,01 '.:; 43 3'F." E 246.0 :.2 W 1 :'-, !. 23 :-:; 4,5 4'P E Eastman /" I]: ~ L t]:lJ L A T i l'_-i Fi O F LEA S T D ! F-'; T A N F:',-- BETWEEN WELLS Pc, siti,:,n on ~ell A-25RD Cl,:,sest ~,:,siti,:,n ,:,r, well A-3RD MD TVI] NF; EW MD TVD NS EW :34. :--:8 N :--:2. :36 N 10. ::::---: E 4. ,"_-,7 E 41 . 4':? Iq 4:_--:. 8:..-':; N R e .F : S C, 7 5 2,:]. 71_10 D i 5 t~nce We'l 1 s D i r.e c -I: Walls N 8 7 3 9 E · Iq :E:/_:., 1:3 E Eastman/ Pc, sition on we;1 ~-'25RD Mr; TVD NS CALCULAT I fin i]~ LEA'.E:T D I.:, T~.~N_.E BETWEEN WELLS Cl,:,sest ~,:,siti,:,r, ,:,r, wel'l A-:2:RD EW M D T V D hi :3 I-- !4 :3:30.00 :350.00 370.00 :--: 4.88 N 1 (]) ~ :---: :2: E 1 '--";q ~./-,::. i ':.2,"-, 1.78 44.7./:, N :3 2. :3 6 N 4./:, 7 E i :2:0 0. ',:::8 12 7.5.5 :]-: 4 7. :2:0 I',.I '2 ?. 7:3 N 1. '7 :.3 W 1:315. '.:.)'? i 2:F'. ?. 18 4 9. F::3 N Re-F : S07521.7U0 D i s t m r, ,: e D i r e c t Be"'~. wee n BettCee Wel 1 s Wel 1 s 16:2. ':.--."7 E 1 ,":,7.0:3 N:::6 17E ! ,"_-,8. 'P7 E i :'-': I. 01 N84 4SE 174. ?:3 E 175. :.31 N:3:--: ::: 1E Eastman L P ,-, s i t i o r, ,-, n ~ e 1 I A- .--._ R D MD TVD NS C:ALC:ULAT ! ON OF. LEAST D I.=,7 ~t'.t_.r: BETWEEN WELL'._--; Cl,:,sest P,:,siti,:,r, ,:,r, well A-1 :2:.'2:0.00 :2:50. o0 :370.00 3:'? 0.0 0 14 ! 0.00 :;:24. 12 N E W M D T V D N L:; E W I. 0. :--: 3 E 1 '29'2.5:2:1271.42 :.~./'_-,'7 E 15:09. ::-: 1 1287.26 i. 73 W 1:327 ,, 0:2: ! :'-", c:,:.--:. 05 :_--:. :2:/_-, W i :2:44.21 1 :.-318. :2: ! 170.22 N 177. 1i N 1:2:3.97 lxl 1 '70. :5:2 lq R e t: : :.--.;07496.0 IJi]l Distance Direct Be';twee r, Betwe~ Wel 1 s Wel 1 s 1 .'.2~. 5:_:: W 149.02 N ' 9' 0 ~. 10.40 W. 1 .~ :::. 48 N .=, =-~ ..... . ._~ I ~, :[ 0.22 W 168. :'2,6, l',.I :3,? 10.04 W 178.65 N 0 35k 197. ,':-,.:-'; 1".-I 'i?. :::.: 6 W ]. ::39. :.7.: 1 Iq I 4./:,E P o s i t i c, n oh MD TVI] N::3 1.427., 00 .1. 4.1 C,. 00 t .¢48.4:3 t ~:3':}. O0 1 4,'59.9 5 3. 4 5 ("). C)() 1491.56 1.4'70.C'0 91.2-26 '[ 65,:}: 0 14,, ii 'L670.C, 0 :7:7. 12 I <.5 T..'O. 0() 60.;.27 1'710.00 17:E::--:. 62 17:--:0. 00 1:-::07. 1:3 1750.00 t :B:'::O. :E::3 '177(2). O0 A- ..' ._, R D T ! i'-IN 0 F LEA S T D I :_:;TAN E:E BETWEEN WELLS Closest Position ,:, n we i 1 A-7 E W M D T V [i N S E W :--.5:4.88 :32.26 '.-:"':'~ 7:3 26.9:3 N N 0. :3::: E 4 /_-.7 E 1.7:_--: W 8.36 W 0.24 N 0. :3:i_:: N O. 51 N (]), ' .,= ,'.:, .... N 2~. !2 21. 15 t. ::3. !. 4, :35 142. O. 115 i 4 i. 0.0:..:.: 14-:.70.09 14:--:(2). 02 1450.0:3 t .,:l. 4'iF~. 'P/.-. 146'P. 97 146'P. 'PO 0.7'.::':' i:.t ("),9:3 Iq 1.07 t",.I 1.2() N .1.. :2: i t'..I 1.4(.') hi 1,5(2) N 1.6o N I !. :5 i :3. O,i-, .a. sr.:3 O. 7:3 1489. :!:: ! ! 48'F.-'. 74 15(:)5.74 1509.67 1 ='-'"-' ' -' .... 15.49.59 1. 5.49. !5'2 :.3. 7, 02 1. 1 .--'-" 5. :--:4 7:!E:. 5 ("> t:4 :_--:7., 5:..']: !,4 '""' :31 W 7 "2, · , i,-,/- :,7.:7 W _ ].. ,'_-, 9 N 1, '79 N ].. 89 lq I. '..7-.':3 1'.1 ' 16 1':',' W 'L 2/_-,. :2 ::3 W 3. 3,:'i:,./-, 6, 14. 7 .. :2::3 .bJ 1649. ]. 7 ! ,'.':,45>. I 0 166,9.0::3 ! ,<:, 69.0 i 16:3:3, ,rs.. ,:,.. t/",_ :':::_ :::_, ':"... :1. 1707. ~-? 70v 59 :3::7::. 60 4:3.71 4:::. 95 17'2'7.50 1727.4.2 1747. :2::.5:1747· 24 17/_-,7. 14 176,7. ('_)5 · .'. 17 1'4 .=. 10 h.I 2. (2)4 fxl : S074'P7.01_10 Dx,stance Dire,:1 BOtmeer, .Betwe( Wel 1 s Wel 1 s A,,5:3 W :36.4:3 S1:3 14b ('). 4:3 W ':"-.' a C) S ':~ ':~ b 0.3:3 W '29.25 S 2:39E o.27 W 27.54 S17 4E 0. 17 I,..4 27,, 7/'-, S 32 4:3 E 0. C',4. W :3 (). 05 S47 42E O. C, 4 E ::"',':1.. 17 :E;6. 0 i 0 E (). 14 E :3'F.'.71 S69 54E \ ('-). 27 E 4,:':,. ::: 4 S 7': "i 7 E C,. 4 .i. E 5:>]. 77 ::-; 82 54 E 0. '.54 E ,.:!:, t. :E', :3 S',37 14 E '- "" ': '7,'"~ 42 N:39 2 (') E ~_'). ,._-,,:, - ...... .. . C). :31 E 79.4.,':, Iq :36 :':: 4 E 0.9!5 E :3:3.'?! N:34 I'?E 1.0:3 tE 'P:3.76 N82 26E i.22 E 108.97 N:30 51E · - ....E .1. 15." = = N 7'? :3 (") E 11 ,. ~ ,_1 ...I 1,4'iF; IE 1 :.:: O. 47 1'47 :!ii: 20 E 1.,'::,2 E 141.75 N77 igE 1 'P i tE 1 ...... 15 .... :,. 1 N76 29E 2.24 E !65.65 N75 '=E -.-., =':, I= 17:_:: 14 N7:.. .~.... m, ...~ ,.~, ~_ m 2.5?1 E ].90.'i-.?:--: N74:31E /-7-/Eastman Positi,:,r, ,:,r, udel i A-125RD ! I Id D T V £ N S ! 427. (')0 1448.4 :i-: 14'i..'.' I ,. :53 C;~Li":UL'A'F i I'iiN Ui: L~,:':i:5 i' 0 i:~, BETWEEN WEI_LS C'l,:,sest P,:,siti,:,r, ,:,n ~.,¢e! i A-4 E W M D T V D N :5; 1E W :1. :3:3 0 (",'-' 1:35 O. 00 1:2'70.00 1:39 O. O0 :34. 8',E: I':t · -_,o :2. A N 5-.':':--¢. 73 i",.I 26.9:3 N 10.8:3 E 4./-,7 E 1.7:--: W 8. :--:/_-, [..4 1:324.5'P 1315.96 4-1.48 N 1342.5:1 1333. 11 43.:5::3 I '-' ="--~ ..:,._, :.. :E: 7 1 .-:,'-' ._, :J ='" . 12 46 . 15 i:'.i 1:377.50 1367,21 4:_::, 19' I'4 R e t: : SO 7 4'P 8.01~10 14-! O. O0 t_ 4 :i: 0.00 14:50.00 147 C.). 0 :-./'4, 1.2 N 18,0/:, N 14. ',_::5 N ..... 21 W · :..'. 29 t.'-J 29.60 W :3'7, 1.5 !..,.1 l'J :L s 't a r, c e D i r. e c t Be,,t~ee n Betu~e.~ We~'l 1 s We l 1 s I. '!-'7; ,:ii. C., 0 !. 5 1 C:,. :-:} 0 :. 5 ::!:,:l.'., C.'. 0 ]. 550.0 '% 4 ,, 9:3 52 ,, !;"5 W ,:':..! ,22 L4 ,'.':,?.~ '7.4 N 7 c).. 74 ,::.'- 61 . E: 8 N 8:7:: 43 E 74 ~,.")tE w.r, ?= I:I:.E',('; 40E . ._ . / .,' # ./ ._1 . .. 7:5':. ~.'-' .:.,'-' E :5:4 , '.'-)_ 2 I',17 ::3 24 E ::: '.'.'.'. (')_ 6 E ':'.-..._, '= ./-,_ :3 N 7 ,...,/- 4 8 E ,: ..... :5::.-_: E 1 ".") 7,54 ~.4 / ._, :32 E ::3'!7,. ,'L-,:E: IE 119. 712 H74 ':"-::' ,J-7 E 1:3 2 ]. ':" lq7 'F.'7.75 iE 144.7:3 N7:3 !. 0 i. 4'2, E :L 57.47 N 7 '~7_-: 4 I o.:q 1 ':7,, ~ 170,4:3 " i 08 ,, 89 !E ;!. 8:i:. 6,S 11:2 ~,'-' . ...... :, E 1 '97 i ,.:':. hi /-7-7 Eastman ; , L. ALL. L,L~] TOl'q FIF L~.:,T DI'.:3TANCE BETWEEh! WELLS ReF : -'"-5'5. :--,~)/.,()., 71JL-I T V D N S 1:3:3 0.0 (} :7.:: ;~, ',?.'.:', N 1:3 5 A. 0 0 :3 2.23,i-, i'! 1. :--.', 7 0, C: 0 ";_' 9 ,, 7:3 lq 123':.-; 0, c:, C: 2,"_-,, 'P :5 C1,':,=,=st Positi,:,r, or, tuel i A-22 E t-'-.J M D T V D !'q :_:; E W i 0. :.3:3 4./:.7 1.7:::-: ::::. :'--:6 Distance f]ir-ec! B,J't :,~e e n Be tue-'.: We! 1 s Wel 1 s '! 7 ,, I/z, L'4 8 !. 4 7 ::; 2 0 2 5 t, :.2("} ,, :E: i t4 80. 53 S 18 2 1 2 :El',. 4- 7 W '7':P. 51 '.S 16 i5 L · .,_,' :'/-, 6:3 'N 7 ::: .4 6 :-:; 1:3 :'::_ ,-.--.,. L. 102.72 W '70. :21 :El;:2::'--: 0 10 :---',. :3:3 W 9:3..4 4 '2 / ].5;6, ]. 1:2,. 9 7 W 9 7 ,, 0 2 :El; 4.z,"' 4 9 1 1 ,--~ ',2:4 LI i ('}(') ''-~ 1 :El; 4 (':, ":"7' .. 4... ~m ...... · ..%.' l '-'--' -' -7,,p ,Z,/',Z.,, .. . 19 0:2:. 0:3 .l 9 ;27.5'.-.-.' i 'P 5 2. :3:2: , .. · - - .. ,_,..- ._~ ._ -_ .. t.-',., 5-' '%7 ..... / W 1 :El: 2.._, ='-.-J :_--; 6,1 1 :!, 1.6 4 W 1:2:9.4 4 ::_; 1,~ ol 46,, 77 :El;,'_-.{;. 14 t:astman f . , ':,,% ']: iA L F: L 1 _ A T :[ fi b.I i'] F' t. E A S T :01 '.E;'I' A l'q C I.-] BETWEEb, i WELI_S M L] T V ill N · 2 ! 0,-!,. 1 :B 1 ?'? 0.0 ':2 ! :B'7.'. :E:~!, ';;'01 O. ._l ?" ~, ...... m , . L-:l,:,$est P,:,siti,:,r'~ ,:,n ~e'l'i A-32 E W M El T V 0 I',1S E ~4 i;.;-~? ~: : ::_::(b 75 (2) 5. '7 I.J Iii '21 ',E: 7. :.2-4 2': 0 5 :]:,, 0 0 :I.41.4,:]) S :7.: :-_-:0,4 0 :.4 :21 z./, / / 2 0 :E:? ,, 4 :--: .0 :i ~ i: .-~ r, c ,..? 0 i r. ,~. c 't B e',!: uJe e r~ B e -!: tde -:i~ 1 :E:7. ';;' 4 :B Eastman Whip ock El i,'s 'L: a r, ,:-e D i r.e ,: B .e 'i: ~.j e e n 14 ,.". -i: t:J e !,4.::_, ] 'l s ~J.:.'._~ 'l ] s .i ::ii'.,::, ....... :!_:;,':.:., ~': ':.::0 'i;:::5: ':': ..... ........ ;. "7i :'::':;" :~!'? ;""- '!'.', "7-:3:2 .t ', }27 .:i ,.:: ..... ,, ::ii', ~'- ..... "~. '77' ' 2' !:::' !'" : r'- .............· , :-_'. :l. :2:3. q...., '::'"" :!i',,!, · ..., .,:. ,, . =._: ,':,". 0 !'.'i Eastman / ?" ':" :2, . :2, :5::3 F: l ,:, s e ,.~ t P ,:, s :L -i: -iL ,:, n ,:, n Lu c-, i '; ia,-- 10 .r-,! :lEI T ;7 D I',1:3 E W ';.':: z:. ,:.,. ,,!:.',, ,, !. A 2":?,'.".':,4 :, ':: !. :: % :3:3 ,, I --1- 2 2'iF' ! ,, "-' q." J:'~: .e 'F : :E:() 7 4'? 9.0 I._i ,' D ,.i s -t: ~ r, c .a D i r.e ,: Be 'f.- tue e r, Be 'bLue !.4 e '! '1 s H e l '1 s i 'i-.?'P. 14 :5!:!5 4. 5 :.5.: 1 ::: :3. ,C-, 2 :3 !5 '::; :3'7 .... ::,.::,4 1 ! 1'77'" ?':4 ""'- ' 't ' 1~7 ,"' .~'J "', ... L:,-J '::! ~' .. .: ..... ': ." ,l'], ..) ...i ,, ._- ... :3 6,!,, I -~% :.'.-i; :}3:3 8.2 ! W ,./'/Eastnmn ' . -- ~reswuro ~er ¢~Olur. /~C::~ ~o~. _' .... "', ....... .... ,- . .~ .. Zn~i~e aO~Te~~ .... ' ...~. ~ ........ __ . _ Unocal Oil & Gas Divis~'~'~ Unocal Corporation ~- Rd. Box 190247 Anchorage, Alaska 99519-0'247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL April 26, 1989 HAND DELIVERED TO: $ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Field - A-25RD "'l magnetic tape w/listing i blueline and I sepia of logs as follows: ~ NL --- Electromagnetic Wave Resistivity/Gamma Ray ~ Array Sonic "~-Array Sonic ""Sonic-Neutron Rorosity ~ Sonic-Neutron Rorosity PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: Cons. Commissior~ DATED: Anchorage Unocal Oil & Gas Divisi .... " Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska District DOCUMENT TRANSMITTAL March 28, 1989 HAND DELIVERED TO: ~ohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: Regarding: Trading Bay Field, A-25RD 1 copy of directional survey report PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU, RECEIVED BY: DATED: Unocal Oil & Gas Di )n Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Department Alaska District Hatch 1, 1989 C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Operation Shutdown Nonopod Platform Well A-25RO Dear Nr. Chatterton: Attached for your approval is an application for Sundry Approval to shut down drilling operations on the Honopod Platform. Operations were shut down at 2400 hours on 2/3/89 due to poor weather conditions and heavy ice in the inlet. Unocal will resume operations when conditions improve. Very truly yours, .. (~//4 .¢a.~ ~ ~: ..... &~:.~~'- C~: ~. (..~/?,;~ ~__ Candace fi, Lockwo¢/d Environmental Special±st CWL: cgs' 03/01/89 Attachment 0013n/22 STATE OF ALASKA "- AL. ~KA OIL AND GAS CONSERVATION COMM,._~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension ~ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other __ 2. Name of Operator ' ~ 5. Type of Well: Union Oil Company of California (UNO~AL) De. vel?pm, ent__ ...... m .... ------"-d ~-xp~oratory ~'. Address / Stratigraphic P.O. Box '190247, Anch' Ak.' 99519-02~7 Service from SE cor., Sec. 4, T9N, R13W, SM 1590' S & 3584' W f/Surface Location 1853' S and 4935' W f/Surface Locatic 1854' S and 4963' W f/Surface Locatic 4. Location of well at surface 1617' N & 551'W At top of productive interval 6615' MD, 4535 TVD, At effective depth 8642' MD, 6017' TVD, At total dep_th 8-730' MD, 6095' TVD, 6. Datum elevation (DF or KB) RT 101' MSL 7. Unit or Propertyname Tradlng Bay State feet 9. Permit number 88-137 10. APl number n 50-- 733-20242-01 ~1. FieJ.ld/PopJ /rao~_ng Bay Field 12. Present well condition summary Total depth: measured true vertical 8730 ' feet Plugs (measured) 609..5 ' feet 8642 ' feet Junk (measured) Effective depth: measured 6017 ' true vertical feet Casing Length Size Cemented Structural Conductor Sudace 1317' 13 3/8" 950 SXS Intermediate i366' 95/8' Production 8726 ' 7" Liner Perforation depth: measured true vertical None None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured d~ll~ Measured depth 1317' 1366' 8726' True vertical depth 1306' 1356' 6091' 13. Attachments Suspended Descriptionsummary°fproposaI.X_ Detailedoper~ionsprogram~ operation until weather breaks and ice clears from 14. Estimateddateforcommencingoper~ion March 15, 1989 Date approved 16. If proposal was verbally approved Russ Doug'las 2-6-89 Name of approver Status of well classification as: BOP sketch __ Cook Tnlet. Oil __ Gas __ Suspended __ ServicS~ater In ~ection 17. I hereby certify that Lhe foregoing is true and correct to the best of my knowledge. O. Signed '1~o~.' D. R~rts Title Environmental Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IAppr°val N°' 9.-"/ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- -- o - ORIGINAL SIGNED BY ..~:~ Approved byorderoftheCommissioner LONNIE C. SMITH ............ Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE OPERATION SHUTDOWN A-25 Redrill l) 2) 4) 5) Drilled 8 1/2" hole to the total depth of 8730'. Circulated and conditioned the mud. POOH to run 7" casing. Ran 7" N-80, 29#/ft., Butt casing to 8726'. Could not reciprocate pipe, Mixed and pumped a lead slurry of 750 sacks Spherelite cement w/.5% CFR-3, .6% Halad 344, .45% HR-7 and 3% KCL at 12,1 ppg. Followed with tail cement of 500 sacks class "g" w/,2% CFR-3, ,5% Halad 344, .08% LWL mixed at 15.6 ppg. Displaced the plug with mud and bumped plug with 2200 psi. Had full returns throughout the job. Nippled down BOPEi set the slips and landed casing. Cut off casing and installed DC8 spool. Installed wellhead. Cleaned pits and laid down 5" drill pipe. Released rig at 0400 hours on 2-3-89 due to excessive ice and very low temperatures. Plan to reactivate the rig in mid-March after ice clears. 0013n/23 December 1, 1988 Telecopy: (907)276-7542 P~r. Roy D. Roberts Environmental Engineer Union Oil Company of California P. O. Box 190247 Anchorage, Alaska 99502 Trading Bay State A-25RD Union Oil CompanY of California Permit No. 88-137 Sur. Loc. 1617'FNL, 551'F~qL, Sec. 4, T9N, R13W, SM Btmhole Loc. 755'FSL, 510'FEL, Sec. 4, T9N, R13W, SM Dear Mr. Roberts Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not indem~nify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to co_m~encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very~ truly ~purs, ,! k' . ' ~' I ~.~ /: ~h' V ' ' ~ ":" '/ Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COmmISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of 'wor~,: Drill ~ Redrill ~1 lb, Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil ~ Re-Entry ~ Deepen~'t Service .,~ Developement Gas ~ Single Zone ~ Multiple Zone ~X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union 0il Company of Californis (UNOCAL) 10~' RT above MSleet Trading Bay Field 3. Address 6. Property Designation Tyonek "C" & "D" P.O. Box 190247, Anch, Ak., .~9519-0247 ADL 18731 Zone 4. Location of welt at surface 7. Unit or property Name 1,-1617'N, 551'W f/SE coz., Sec. 4, TgN, R!~W lrading Bay State At top of productive interval 8. Welt nu ,mber 65t3',MD, 455i' TVD, 1650' S & 3500 ' W f/sur -'ace TBS A-25RD 8500'MD, 6036'TVD 2250 S & 4750 W f/sur'a~e .~...c~m~.r ..ur, 12. Distance to nearest I 13. Distance to nearest welt 14. Number of acres in property 15. Proposed depth~MD a,o ZVD~ property line 1 ~7n , feet , .~ .¢0 ! 8 F/A-24RD feet 3840 8343 'MD/6036' 16. To be completed for deviated wells - 17. Anticipated pressure (see 20 AAC 25.035 Kickoff depth 1~50 feet Maximum hole angle 57o0 Ma×imumsuHac~ ]800 ;si~AttotaiaepthrrVD) 2000 18. Casing program Settin9 Depth size Specifications Top Bottom ! Quantity of cement Hole Casing Weight i Grad% Coupling La nsgst h0i MD 1 TVD0 MD , TVD (include stage data) 8 1/2 7 29# N-8 Butt 0 85001 6000 1250 cu. ft. ~rrrl%lrh t 19. To be completed for Redrilt, Re-entry, and Deepen Operations. NOV u 7 ]988 Present well condition summary 7~7~6~ Total depth: truemeasuredvertical 5 ~ 9.5~ ' feetfeet Plugs (measured) ~.l~8k~. 0il & Gas Cons, ,.,, ~,nchorage. ,?' ......... Effective depth: measured 7,754 ' ' ' ' feet Junk(meas~r¢¢t- 2810" TOF-dua! 'tubFng sl:~ings true vertical 5,924' feet 2 7/8" L.S. and 2 3/8" S.S. Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ].317' 13 3/8" 950 SXS 1.317' 6068' 9 5/U" 800 SXS 1st stage 6068' 450Z' Intermediate 400 SXS 2nd stage Production 7758 '-5983 ' 7" 350 sxs 7754 ' 5924' Liner Perforation depth: measured See Attached true vertical 20. Attachments Filin.~g fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ,_m Time vs depth plot m,.. Refraction analysis .,~ Seabed report - 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my kr,owiedge Signed ~-~'~¢~. RcCv. D_ Rnn~t,F:, Title Fnvi ~-nnment~l Fno_ 1~/88 Commission Use Only Permit Numb~o APlnumber t tSeec°vertetter ¢'¢' - / 3~-'137 50-- ? ,~',.~ -2..o~ z./,,,Q~ o / Appr61'Y'~/~/88 for other requirements Conditions of approval Samples required ~ Yes ~]~' No Mud Icg required ~J Yes ~No Hydrogen sulfide measures I-q Yes ~ No Directional survey required ~ Yes % No Required worki~¢4'~,).~ BO~"~~¢~~~ 10M; ~ 15M/ Other:. by order of Approved by ~ ,,/' ,. Commissioner the cornmission Date' 11. Type Bond ise~ 20 AAC 25.025'~ Statewide Nat'l Fir Nur~B~r. Co. of Hartfor B5534278 '.l/~mou nt $200,000 TRADING BAY STATE A-25 REDRILL PROCEDURE 1. MIRU. Set BPV and test BOPE. 2. Abandon well as per program. Set cement retainer at 1500' in 9 5/8" casing. Mill a section from 1350' to 1475' and lay kick off plug. 3. Test the casing to 1000 psi. 4. Kick off plug and perform leak off test. 5. Redrill 8 1/2" hole from 1350'- to 8500'. 6. Run open hole logs. 7. Run and cement 7" casing. 8. Run CBL-VDL-GR in 7" casing. Perforate and squeeze as necessary for zone isolation. 9. Perforate and profile Tyonek "C" and "D" zones. Acidize if needed. 10. Run a single 3 1/2" injection tubing string. 11. Place well on injection. / "C" Zn. WELL A-25 PR£S£NT PROPOSED REDRILL PROPOSE9 Kill ~ String: 3.5" Tubing to '~3-~/8" 6~# K-55 274'7' ~. Casing 0 1317' ~ Window in 9-5/8" T.O.F. 0 2900' . Csg F/1350' to 1475' 9-5/8" 47# N-80 Casing 0 6068' ~ 7" Uner 0 7796' :: 7" Casing 0 8500' .,~ TBS A-25 PERFORATED INTERVAL MEASURED DEPTH 5694-5708 5775-5790 5874-5906 6080-6160 6170-6246 6348-6396 6498-6506 6658-6678 7192-7204 7254-7275 7316-7352 7450-7532 7572-7610 7630-7664 TRUE VERTICAL DEPTH 4189-4200 4257-4268 4339-4365 4510-4577 4586-4650 4734-4775 4860-4868 4997-5013 5446-5456 5499-5517 5551-5581 5663-5733 5767-5800 5817-5846 II. IV V_ +o 2;7'-17 CASING & ABANDONMENF DETAIL ...... I I.) Rotary Table Measurement at 0.00' !1.) CIW Tubing Hanger at 37.00' Iilo) 13 3/8",61~, K-55 Casing at 1317' IV.) Top 7",29,~ N-80 Liner at 5953' V.) 9 5/8",47~', N-80 Casing at 6068' VI.) 7~,29,~, N-80 Liner at 7796' TUBING DETAIL LONG STRING: 2 7/8';6.4,¢, & 2 3/8';4.6¢~ N-80 TUBING 1.) Otis Ball Valve Nipple at 246.86' , '" 2.) Otis *CX" Gas Lift Mandrel at 2545.26 3.) Otis 'OX" Gas Lift Mandrel at 3919.22', ' , 4.) Otis ~CX" Gas Lift Mandrel at 5068.93, 5.) Otis 'CX" Gas Lift Mandrel at 5581.45 6.) Otis ~RTH" Triple Packer from 5619.00' to 562,7,.76' 7.) 2 3/8' x 2 7/8" Buttress Crossover at 5906.02 ~ 8.) Camco 'KBMG Gas Lift Mandrel at 6062.26° b--"" 9.) camco 'KBMG" Gas Lift Mandrel at 6441.67° ~;::3 10) Camco 'KBMG' Gas Lift Mandrel at 6696.55" N · · ,, , ~ I 1.)Camco 'KBMG Gas Lift Mandrel at 6905.36 12.) Camco 'KBMG' Gas Lift Mandrel at 7066.44" 13.) Otis "XO' Sliding Sleeve at 7083.64' ° 14.) Otis Streight Slot Locater at 7098.26 , 15.) Otis Perm Packer with Seal Unit,-7099.42 ,to 7107.42 16.) Otis 'N" Nipple with Plug Set at 7108.27 17.) BottOm of Mule shoe at 7109.96' SHORT STRING: 2 3/8;4.6~, N-80 TUBING A.) Otis Ball Valve Nipple at 218.63' B.) Otis 'CX" Gas Lift Mandrel at 2491.80' C.) Otis 'CX' Gas Lift Mandrel at 3880.92' D.) Otis 'CX" Gas Lift Mandrel at 4914.47' E.) Otis '"OX" Gas Lift Mandrel at 5577.26' F.) Otis Seal Extension from 5617.59' to 5620.64' G.) Otis 'RTH' Triple Packer from 5620.64' to 5629.40' H.) Otis 'N' Nipple at 5637.14' ' 1.) Bottom ,of Otis Shear Sub at 5638.69' Dip Tube' I 1/2' J-55, K Tubing from 5619' to Camco BMG" Gas Lift Mandrel at 7066' PERFORATION RECORD DA TE INTERVAL CONDITiON 7630'-7664' .. 7572'-7610''%',,.Middle Kenai 'D' Zone-Open 7450'-7532' 7316'-7352' 7254'-7275'/ 7192'-7204' 6658'-6678'. 6498'-6506"~X,X 6348'-6396'% 6170'-6246' 6080'-6160' / 5874'-5906"/' 5775'-5790'/ 5694'-5708' · Isolated by Plug in 'N" Nipple Middle Kahan' 'C' _Z,~n.q--pl~%~,d____ ~ ~ , c- .~ ~ __ WELL A-25 WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA NO'NE' 6/.78/85 TRADING BAY STATE A-25 REDRILL MUD PROGRAM DEPTH FT. 1350-8500 WEIGHT PCF 75-80 VISCOSITY PV YP Sec./Qt dn/cm2 #/lOOft.2 35-50 8-15 15-25 GELS PH WATERLOSS C.C. 3/20 8.5-9.0 10-15 ANGLED FILL UP L'INE. , " " HYDRIL ~ [' ' . VALV~ . '. - ~ '~ .... ~ '. ~ ~ ~. GAT~ u~ GAT~'.. ~ f . GATE GATE.', '~'~ · ' ~ ~ ' K L " " ~,. { : . . ! L LINE ~ ~ ~...,. , .... .. - ~~~ -- C~M :, ,,.. .. · ., ' & ENT UNI ~ ,. " OPERATOR FURNISHED,' ',.,.. NOTES; 1. HYDRAULIC VALVES OPEN ~ t.' WELL NAME: AUTOMATICALLY WHEN ~ COgT~CrO~:, ~V~T~R IS CLOS~. ~;~: !' 'I: - ...... ' ~ ~ 2 FL~X HOSE ~) IS ~O B~ US~ STACK ..PRESSURE ~A~ING: ' CHOKE .LINE SiZE & MSP: IF NECESSARY WiTH DSS, NOTE: A~L~,.CHANGES MUST HAVE WRITTEN APPROVAL,APPROVAL. ~Y THE DISTR~CT DRILLING SUPERINTENDENT .. DEPT, APPROVAL 1 3 5/8'', BOPE'STACK 5M OR 1OM ALL DRILLI!NG OPERATIONS UNION' OIL COMPANY' OF __ 5-5E~ .$ I FROM ci (THU)lO.06,'88 16:55 ~ NO.5 i '-I ~rv - .... J CHOKE MANIFOLD UNOCAL PLATFORM ,RIGS 4-1'/16" & ~-1/8", 5M MSP u~ON ol~. cOM.~'~'i~"V'-'~'~--d-X-L~i-~;6~I,,', ..... PAGE 8 6OOO _ ~ 1000 . 2000 2323 TYD .- 51 O0 54.1 2OOO W, 54 1223 1336 W,3452 N,257 I, 4.051 S,33 0 200O 1000 . 1000 SCALE 1 =' ! O00F'T. t'lDt1350. 18'23' -22-31 SEC- 727 ,2611. 56'g' 3000 3984. 4.00O ......... 3204 .......... 3869 TAROET MD,6469. 43'0', 5801 6000 + 1000 0 1000 : V.SI~CTION PLANE' 964'37'W ......... SURVEY,SO7490}OUO.* : PROPOSAl'POO633.0UO · SCALE I',IO00FT- , 5035 514.7 2OOO 3000 4000 I'1D'8179. 43'0' .~,ez43. ~.-o' 5000 6000 I : ' UNOCAL': : ........... MONOPOD Pl'utro'~'~' ' ' T.m,,llr~g Bmy Field. Cook Inlef., Almmke WELL' A-2~RD SLOT' 2 lO0 900 800 700 600 500 400 200 100 100 100 100 200 :300 4OO 5OO 6OO TO0 4000 9OO 2500 2200 800 82OO [200 7600 1900 )0 :200 700 600 ;500 900 1600 2500 5OO ;00 ;00 :J 30 O0 1600 1300 19 O0 2200 / . 1^-~'"91 I~;,~:,,-,t 400 :300 200 100 1000 16OO I I 100 lO0 2O0 3O0 4OO 5O0 600 7O0 100 20O 800 400 500 6OO 700 800 900 1800 1 700 1 600 1 500 I I I I ~ ~ 400 SOO0 o~uu :400 1 400 I 1 300 1 200 I I .., 1 1 O0 1 000 900 800 I I I I '4400 000 2400 I 1 800 1 TO0 1 600 .. "~'~000 1800 J f400 ~ ~ ./' I · . ~ / /1800 ' ~ ~ 2800 / / /~000 / ~ ~ ~ 2200 ~ ~ / 240 2600 200 2400 2800 I 2000 i 2400 3000 ^-~. I I I I I i I 1500 1400 1BO0 1200 1100 1000 900 800 _ 100 = 2O0 _ 3OO _ 400 500 _ 600 _ 70O _ 800 _ 900 4700 4600 4500 4400 4300 4200 4100 4000 3900 3800 3700 I I I I I I I I I I I 1600 1700 1800 1900 2OO0 21 O0 22OO 2300 2400 5900 -- ~'"58o0 5700 --""5200 ... "5300 5600 ; ~Su.,,Q ~4~4uu ' ~uu ~'"'5500 '"5600 I I I I I I I 4700 4600 4500 4400 4300 4200 41 O0 ... "'5000 · · · ,3~.UU b 1 O0 bOO0 ~- ~'"4900 I I I I^-,?l~uu ! ! I 4000 3900 3800 3700 _ 1600 _ 1 700 _ 1800 _ 1900 _ 2000 _ 2100 _ 2200 _ 2300 _ 2400 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 I I I I I I I I I I I 60o _~=6oo . . . . . 26oo o ?00 -~ =.uu ~zuu ' ~u - 4800 :::)800 I ~oo 2~oo I 8OO ~ /2800 1100 _ ,00 1200 ,4O0 1 300 :3000 ! I 1400_ I I I I I I I I I .~400 ~ la-, r r~l 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 _ 6OO _ 700 _ 800 _ 9OO _ 1000 _ 1100 _ 1200 _ 1300 _ 1400 1100 12OO 1300 1400 1 5OO )600 1700 1800 1900 3500 3400 3300 3200 I I I I 3100 3000 2900 2800 2700 2600 2500 I I I I I I I - 13UUU .-'""4400 I 3500 I 3400 I 3300 · ~600 3200 I 4ooo~ - -' I 07494 200 ~ ~ ~' '~ "" 4000 I 3100 .000 I 3000 I 2900 I I I ~/.//~oo I 4RAO ...... J I^-' ?ROI ~ I I [ 2800 2700 2600 2500 . 1100 _ 1200 _ 1300 .1400 1500 _ 1600 _ 1700 _ 1800 _ 1900 100 900 800 700 600 L L 500 400 300 2OO 100 100 ,' 100 100 2OO 300 400 500 600 700 900 4000 22O0 8OO 700 2500 ~-2oo 7'600 1900 9oo ~0 ;200 ~4000 ---'-'-~r'~-----~ 1 7'00 600 300 · 1 ~OO 1600 2200 2500 500 400 1600 1900 6OO 1900 3OO 200 1Jo0 100 300 / 1000 3oo 1600 I I ! 100 200 300 400 500 6OO 700 100 150 200 25O 3OO 35O 400 450 500 9OO 85O 800 750 700 650 600 550 500 450 400 I I t I I J I I 8OO ,00 4000 8OO 26O0 800 9OO I 850 I 800 ooo 7000 75O I 700 8200 7600 7400 1 600 18oo 600 2200 800 18OO 650 I 6OO ~.0o0 I 18oo ,//~ '~ soo ! ,,/' i I~-~"' 'I J~l I I I 550 500 450 400 100 _ 150 200 25O .300 350 4OO 450 .500 MUD' ?P~T MONOP.OD I SCN[~NIAT~C ' ' TO MUD PITS -: TRIP TANK (50 ~z]L~) Mixin~ pit. ie one level below tho active eye.Lorn ' ..-~. RESERVE PIT .... <'3oo ~'~'/s)"" -[--' (100 t3BLS) DESANDER I 100 t] ~ L.,'.q DE~ILTER SUCTION PIT ( 'too I) RDaorvo Pit '2..) DeOas~or ' 2) 2-2bakers 4) Pit Level Indicator {Vjouai & Audio), O) THp T~ntc y) Pit ~ltators · 10) ~ixlno' Pit 5O 5O 100 150 2OO 250 300 350 450 400 35O ~000 4bboo 2OO 400 1 400 I 450 400 I 35O 300 I 20O i 400 1200 I 300 25O I 20O 1 50' 1 O0 50 1 2UU 1000 400 600 000 1000 2OO 1 200 1000 220O 1.0o 250 1400 12o0 1600 I I i I 200 1 50 1 O0 50 0 5O ~j. I0000 1000 j I 1 I ! 1 20O i I __ __ J I 0 50 5O 5O 100 1 50 2O0 250 300 35O C~LEC~ LiST FOR NE~A W~-L PF.R/~ITS IT~M APPROVE DATE (9 th. ruI3~ 10. (10 and 13) 12. 13. (14 ~h~ ZR) ]3OPE (23 thra 28) (29 ~hr~ 31) Company ~(D~ / Lease & Well No. ~ YES NO Is the permit fee attached .......................................... ~-- ---.. 2. Is well to be located tm a defined pool ............................. ~. Is well located proper dis~amce from propercy line .................. 4. Is well ~cca~ed proper distance ~rom other wells ...... , ............. 5. Is sufficient umdedicated acreage available in this pool ............ 6. Is well to be deviated and .is wel!bore plat included., .............. 7. Is operator the only affac=ad party .................... 2 ............ 8. Can permic be approved before fifteen-day-wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approva~ needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ........................ r 14. 15. 16. 17. 18. 19. 20. 2I. · 22. Is conductor string provided. ....................................... Will surface casing protect ail zones reasonably ~pectad to serve as an underground source of drinking water ..................... . . Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all kno%m productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. //,~, Is this well to be kicked off from an existing wellbore ............. ~,. Is old wellbore abandomment.procedure included on i0-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. ~or 29. 30. 31. Is a divar=er sysCem required ....................................... Is the drilling fluid program schematic and list of equipment adequate~' Are necessary diagrams and descriptions of ~ ~d BOPE attached. ~,, Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API R~-53 (May 84) .... Is the presence of H2S gas probable ................................. exploratory'and Stratigraphic wells: Are data presented on potential overpressure zones?. ................. Are seismic analysis data presented on shallow gas zones ............ If a~ offshore loc., are survey results of seabed conditions presented :6) Add: ~ology: ,~ / ~v: 08/11/88 011 32. POOL Leoo / V Additional requirements ..................................... INITIAL ~F-O. O~/OF~ CLASS STATUS AREA SHORE UNIT NO. ~.