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Home My WebLink About200-0537. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved ProgramOperations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-23A Extended Patch, Change Pools Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-053 50-029-20795-01-00 10337 Conductor Surface Intermediate Liner Liner 9023 78 2598 7694 1379 1996 8810 20" 13-3/8" 9-5/8" 7" 2-3/8" 8760 34 - 112 33 - 2631 31 - 7725 7476 - 8855 8308 - 10304 34 - 112 33 - 2631 31 - 7703 7456 - 8803 8276 - 9024 Unknown 470 2670 4760 5410 11780 none 1490 5380 6870 7240 11200 8270 - 10200 4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 29 - 8855 8239 - 9025 Structural 3-1/2" Baker SB-3A 7217 7235 7217 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PUT RIVER OIL / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 29 - 8803 16 823 2648 10310 2897 158 0 0 768 252 323-538 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 7235 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Mill Plug , By Grace Christianson at 10:09 am, Jun 04, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.06.04 09:38:17 - 08'00' Bo York (1248) DSR-6/4/24 RBDMS JSB 060624 WCB 8-29-2024 ACTIVITYDATE SUMMARY 12/25/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Mill CIBP Travel to DS2, MIRU. Pump 1" drift ball. Make up Yellow Jacket 1.88" milling BHA. RIH and tag fill at 8655' clean out down to CIBP at 8809'. Make wiper trip above perfs then RIH and mill CIBP and push to 10,207'. POOH. M/U NS 2.72 drift. RIH, tag at 7685. attempt to work past without success. POOH, L/D drift. M/U 1.69" milling assembly w/2.8" Opticut/MM Crayola mill. RIH **Continued to WSR on 12/26/23** 12/26/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Mill CIBP Continue RIH w/YJ milling assembly 2.8" crayola mill. Tag at 7515' Mill from 7,500 down to 8295 and dry drifted to deployment sleeve. Ream through area again and dry drift 7500-8310. POOH and lay down 2.80" milling BHA. Made up 2.23" junk mill BHA and RIH. Tagged deployment sleeve at 8,310' and rolled through, worked mill from 8,310-8,314' and saw motor work below 8,312'. Made 10 passes across deployment sleeve but never saw a reduction in motor work. Attempted to dry drift through deployment sleeve but tagged up at 8,312'. POOH and made up BOT 2.24" polish mill. RIH and attempted to clean up deployment sleeve for 2 hours but could not get a clean drift. Discussed with OE and decided to run a lower packer instead of stinging into the deployment sleeve. POOH and found reamer section of polish mill worn smooth. Make up Northern Solutions packer/PTSA drift and RIH. Tag deployment sleeve at 8,314' CTMD, POOH and re-tag while pumping and saw 100psi circ pressure increase. PUH ~10' and painted white flag at 8,300'. POOH and lay down drift BHA. Perform 7 day BOP test. **Continued on WSR 12/27/23** 12/27/2023 LRS CTU #1 w/1.5" Blue Coil. Job Objective: Install Extended Patch Finish weekly BOP test. M/U NS lower packer assembly and RIH. Set lower packer assembly in deployment sleeve @ 8308' MD (8313' CTM). POOH and OH deploy upper patch section. 9.2 PPG fluid needed for KWF. M/U Upper packer assembly w/ snap latch and RIH. Sting in to lower packer and confirm latch. Set upper packer, good indication of good set. WHP increased to 1200psi once packer set. Top of patch @ 8187' MD. P/U clean and POOH pumping FP down backside. Confirm patch gone at surface and begin rig down. **Job in Progress** 12/28/2023 LRS CTU #1 w/ 1.5" Blue Coil. Job Objective: Mill CIBP, Set Patch RDMO ***Job Complete*** 12/28/2023 ***WELL S/I ON ARRIVAL*** ATTEMPT TO EQUALIZE RSG PLUG S/D @ 8,263' SLM (no psi change) RAN 10' X 1.75" PUMP BAILER S/D @ 8,256' SLM (real sticky, recovered 1/2 gal. sandy drIlling mud) RAN 10' X 1.5" PUMP BAILER S/D @ 8,260' SLM (recovered 1/2 gal. drilling mud) ***CONTINUE 12/29/23*** 12/29/2023 ***CONTINUE FROM 12/28/23*** BAIL FROM 8,260' SLM DOWN TO 8,270' SLM (3 GAL. looks like drilling mud) RAN 1.80" CENT. 1.75" LIB, S/D @ 8156' SLM (top of patch) 8,187' MD (depths from awgrs) ***CONTINUE 12/30/23*** Daily Report of Well Operations PBU 02-23A mill CIBP and push to 10,207'. POO Daily Report of Well Operations PBU 02-23A 12/30/2023 ***CONTINUE FROM 12/29/23*** BAIL FILL FROM 8,270' SLM TO 8,280' SLM (recovered 7 gal.) ***CONTINUE ON 12/31/23*** 12/31/2023 T/I/O=100/700/200 (Assist slickline) TFS U3. Pumped 4 bbls of 60/40 followed by 88 bbls of DSL down the TBG to load for slickline. Slickline left in control of well upon departure. 12/31/2023 ***CONTINUUE FROM 12/30/23*** BAIL @ 8,280' SLM ATTEMPT TO EQUALIZE RSG @ 8,308' MD BAIL @ 8,280' SLM STUCK @ 8,280' SLM PUMPED 88 BBLS DIESEL 4 BBLS 60/40, CAME FREE BAIL @ 8,280' SLM ***CONTINUE 1/1/24*** 1/1/2024 ***CONTINUE FROM 12/30/23*** MULTIPLE ATTEMPTS TO LATCH PLUG @ 8,278' SLM W/OUT SUCCESS RAN POCKET BRUSH TO ATTEMPT TO CLEAN FISHING NECK BAILED ~3 CUPS FROM 8,278' SLM RAN 2-3/8" GR, LATCH PLUG @ 8,278' SLM (UNABLE TO RELEASE GR) ***CONTINUE 1/2/24*** 1/1/2024 T/I/O=730/700/200 (Assist slickline) TFS U3. Pumped 50 bbls of crude down the TBG to attempt to free up slickline. bled back 21 bbls to attempt to lower TBG pressure. No change shortly after starting bleed. *Job continues to 1-2-24* 1/2/2024 ***CONTINUE FROM 1/1/24*** DROP CENTRALIZED CUTTER BAR (DIDN'T CUT) DROP SECOND CUTTER BAR, CUT WIRE @ 8,150' SLM (ESTIMATED) POLLARD UNIT #59 WEATHER HOLD ***WELL LEFT S/I*** *****2 CUTTER BARS & 1 SLICKLINE TOOLSTRING LEFT IN HOLE, SEE LOG***** ***1-1/4" ROPESOCKET & SLICKLINE TOOLSTRING = 34.06' OAL *** 1/2/2024 *Job continues from 1-1-24* (Assist slickline) TFS U3. Pumped 5 bbls of crude down the TBG to assist slickline with dropping cutter bar. Slickline left in control of well upon departure 1/6/2024 ***CONTINUED FROM 01/02/2024*** PULLED BOTH CUTTER BARS FROM TOP OF PATCH @ 8,187' MD RAN BARBELLED 2.5" CENTRALIZERS & 2.12" BLINDBOX TO 8,187' MD. JARRED DOWN 15 MINS. WIRE MARKS ON BLIND BOX. MADE 2 RUNS W/ 3 1/2" BRUSH AND 3 PRONGED WIRE GRAB TO 8156' SLM (SMALL BITES ON WIRE, NO RECOVERY). RAN 2.5" CENT, 3' x 1 3/4", 2.5" CENT, 2.12" BLIND BOX TO 8156' SLM. JARRED DOWN 30 MINS. ***CONTINUED ON 1-7-23*** Daily Report of Well Operations PBU 02-23A 1/7/2024 ***WSR CONTINUED FROM 1-6-23*** RAN 3 12" BAIT SUB, 3 1/2" BRUSH, AND 3 PRONGED WIRE GRAB TO 8156' SLM. NO WIRE RECOVERY. ***JOB SUSPENDED FOR INCOMING WEATHER*** 1/8/2024 ***WELL S/I ON ARRIVAL*** RAN 3 1/2" BRUSH, AND JUNK BASKET W/ 2.25" WIRE FINDER TO 8154' SLM. UNABLE TO GET A BITE ON WIRE. ***MOVE TO WEATHER TICKET *** 1/9/2024 ***COME OFF WEATHER TICKET*** MULTIPLE RUNS TRYING TO FISH WIRE FROM THE TOP OF PATCH @ 8,187' MD RAN JUNK BASKET W/ 2.70" WIRE FINDER TO 8155' SLM; RECOVERED ~3' OF WIRE RAN 2.70" LIB TO 8155' SLM. CLEAN FISHNECK. RAN 3 1/2" GR TO PATCH @ 8187' MD. LATCHED CLEANLY AND SHEARED GR. ***WELL S/I ON DEPARTURE*** 2/26/2024 LRS CTU #1 Objective: Fish NS 2-3/8" patch MIRU ***In progress*** 2/27/2024 LRS CTU #1 Objective: Fish NS 2-3/8" patch Continue RU. MU 2-1/8" fishing BHA. RIH, latch Patch, Pull Free on 1st jar lick. Confirm clean movement up 10 feet. WHP increased instantly by 200 psi. Stack back down, pump off GS. PUH 25', start circulating 9.2 ppg KWF around the hole. Never got KWF to Surface, took gas returns for several bbls pumped before decided to save remaining KWF and latch back up to patch. Latch Patch, POOH, pump 8.4 KCL down CTBS at 3 bpm to sweep any potential gas from well bore. Shut down @ 5000', stop pumps. WHP static @ 205 psi. Order more KWF, 9.2 ppg. POOH keeping hole full. Confirm Patch is on at surface, Master closed 9 turns, open 9 turns. Begin well kill. ***In progress*** 2/28/2024 LRS CTU #1 Objective: Fish NS 2-3/8" patch L&K well with 9.2ppg brine. Undeploy 2.-3/8" patch. All equipment retrieved. Missing a couple elements on the snap latch. FP well with 38bbl. RDMO. ***Complete** 3/3/2024 ***WELL S/I ON ARRIVAL*** (Profile modification) RAN 4-1/2" BRUSH & 3.70" 3-PRONG WIRE GRAB TO XO AT 3,005' MD (no recovery) ***CONTINUE ON 3/4/24 WSR*** Daily Report of Well Operations PBU 02-23A 3/4/2024 ***CONTINUED FROM 3/3/24 WSR*** (Profile modification) RAN BAITED 3-1/2" BRUSH & 2.62" 2-PRONG WIRE GRAB TO 8,100' SLM (no recovery) RAN 2.50" BLIND BOX TO FISH AT 8,256' SLM RECOVERED ~100' WIRE w/ 3-1/2" BRUSH & 2.62" 2 -PRONG WIRE GRAB 2 x ATTEMPTED TO PULL FISH AT 8,252' SLM (shucked dogs) RAN 3-1/2" BAIT SUB & 2.50" WFD RELEASABLE OVERSHOT TO FISH AT 8,252' SLM (jarred 2 hr, no movement) ***CONTINUE ON 3/5/24 WSR*** 3/5/2024 ***CONTINUED FROM 3/4/24 WSR*** (Profile modification) JARRED ON FISH AT 8,255' SLM FOR 5 HRS (no movement) ***CONTINUE ON 3/6/24 WSR*** 3/6/2024 ***CONTINUED FROM 3/5/24 WSR*** (Profile modification) JARRED ON FISH AT 8,251' SLM FOR 4 HRS (no movement) 3-1/2" BAIT SUB & 2.29" WFD HD RELEASEABLE OVERSHOT LEFT PLANTED ON FISH ***WELL LEFT S/I ON DEPARTURE*** 4/18/2024 ***WELL S/I ON ARRIVAL*** RAN 3-1/2" GS S/D @ 8,243' SLM, JAR FOR 30 MIN. PULL BAIT SUB/OVERSHOT ASSEMBLY RAN 2.29" WEATHERFORD RELEASABLE OVERSHOT S/D @ 8,244' SLM JAR FOR 30 MIN. (sheared) RAN 2.29" WEATHERFORD RELEASABLE OVERSHOT S/D @ 8,244' SLM JAR FOR 20 MIN. (grapple broke) RAN 3-1/2" BAITSUB, BOWEN OVERSHOT 1.25" GRAPPLE S/D @ 8,244' SLM, JAR FOR 1 HOUR ***CONTINUE 4/19/24*** *****3/8" X 7/8" PIECE OF GRAPPLE LIH***** 4/19/2024 ***CONTINUE FROM 4/18/24*** RAN 3-1/2" PRGS S/D @ 8,250' BLM (1 HR 3K TO 4K) PULLED OVER SHOT RAN 3-1/2" BAKER BAITSUB OVERSHOT S/D @ 8,250' BLM (20 MINUTES LIGHT JARRING, PULL TO 9,100 LBS) RAN 3-1/2" PRGS S/D @ 8,250' BLM (JAR FOR 2.5 HRS @ 4,500 LBS) ***CONTINUE 4/20/24*** Daily Report of Well Operations PBU 02-23A 4/20/2024 ***CONTINUE FROM 4/19/24*** JARRED ON TOOLSTRING @ 8,250' BLM FOR 1-1/2 HRS (5,000# licks, 5 hours total) ALTERNATE JAR LICKS & PULLING A 8,000# BIND RDMO SO COIL CAN COME PULL HIGHER BIND W/ TEMPRESS INSTEAD OF US JUST DOING JAR LICKS & BREAKING TOOLSTRING ***WELL LEFT S/I ON DEPARTURE*** ****BOWEN OVERSHOT FROM BAKER LIH ON FISH, BAITSUB: 3" 1-1/2" MT x 3" GS PROFILE (2.71" od, .55' long)/ OVERSHOT: 2-5/16 SERIES 20 (9402 grapple, 2.32" od, 1.36' long), OAL=23"**** 5/3/2024 LRS CTU #1 - 1.50" BlueCoil .134"WT Job Objective: Recover RSG and tool string, re-install EXT patch Travel to location. MIRU CTU. Function test BOPs. M/U LRS 1.75" BHA w/DJN. RIH and tag the top of the FN at 8244' CTMD. Wait on Powervis for 5 hours. Jet on FN and pump 10 bbls sweep off bottom and chase out of hole. Make up short fishing BHA with Jar, Tempress agitator, and 3-1/2" hydraulic GS. RIH, latch up with GS. Jarred 1 time and pulled fish free. POOH, hang up at prod mandral and work through. POOH ...Continued to WSR on 5/4/24.. 5/4/2024 LRS CTU #1 - 1.50" BlueCoil .134"WT Job Objective: Recover RSG and tool string, re-install EXT patch Continue POOH. Recovered 37.5' of fish with RSG, PTSA, packer assembly and SL tools still attached. All upper packer elements missing. M/U LRS slim BHA, RIH jetting down to 8320' CTMD, pump gel sweep and chase OOH. Make up venturi with 2.70 mule shoe and RIH. Venturi across production mandrels, GLM #1 and 2, and reciprocate at top of liner. Paint green reference flag 30' above first set down. POOH maintaining hole fill. Recover all but 1/3 of middle packer element, retrieve upper and lower with only small chunks missing, and ~1/2 cup of 1/8" thick scale chips. Make up lower LTP assembly with Mono-Pak packer and PTSA. Tie-in at the flag and confirm stung into the liner top. Set LTP with PTSA (no RSG) at 8300' MD, POOH. Load well w/9.3ppg brine. Deploy NS ext patch RIH ...Continued to WSR on 5/5/24......... ***1/3 of middle packer element pushed into the liner and left in hole**** 5/5/2024 LRS CTU #1 - 1.50" BlueCoil .134"WT Job Objective: Recover RSG and tool string, re-install EXT patch Sting patch snap latch (6.5k release) into LTP and set with top at 8185' MD. Confirmed Set, PT to 2022psi for 30 min, ending pressure 2009psi. POOH, L/D NS setting tool BHA. M/U LRS slim FCO BHA and RIH. Tag bridge in liner at 9056' CTMD. Hard jetting to break crust and then clean out to 9086 before loosing returns an injectivity established. Overpulls at the R-Nipple and snap latch but able to work through with minimal returns established. Confirm injectivity of 1.3 bpm at 680 psi. FP coil and tubing with diesel as slickline will be setting a dream catcher. Rig down CTU. ***Job Complete*** jg Sting patch snap latch (6.5k release) into LTP and set with top at 8185' MD g Set LTP with PTSA (no RSG) at 8300' MD, POOH. 1 Carrie Janowski From:David Bjork Sent:Monday, January 29, 2024 1:03 PM To:Carrie Janowski Subject:FW: [EXTERNAL] RE: PTD 200-053 Well 02-23A Sundry 323-538 Follow Up Flag:Follow up Flag Status:Flagged fyi From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, January 26, 2024 8:09 PM To: David Bjork <David.Bjork@hilcorp.com> Cc: Bo York <byork@hilcorp.com>; Arvell Bass - (C) <Arvell.Bass@hilcorp.com>; JD Martin <Jonathan.Martin@hilcorp.com> Subject: [EXTERNAL] RE: PTD 200-053 Well 02-23A Sundry 323-538 Dave, Appreciate the update. If you would include this email in the 10-404 and include a line for the ‘change to the approved program’ there will be a paper trail. Approved. 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: David Bjork <David.Bjork@hilcorp.com> Sent: Friday, January 26, 2024 1:05 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Bo York <byork@hilcorp.com>; Arvell Bass - (C) <Arvell.Bass@hilcorp.com>; JD Martin <Jonathan.Martin@hilcorp.com> Subject: PTD 200-053 Well 02-23A Sundry 323-538 Mel, CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 tŚŝůĞĞǆĞĐƵƟŶŐƚŚŝƐũŽďǁĞǁĞƌĞƵŶĂďůĞƚŽƐƟŶŐŝŶƚŽƚŚĞůŝŶĞƌƚŽƉĂƚϴ͕ϯϬϴŌ͘ tĞĂƩĞŵƉƚĞĚƚŽĐůĞĂŶƵƉƚŚĞůŝŶĞƌƚŽƉ without success. The job scope was slightly modiĮed to set a new lower patch packer above the liner top then run the seal assembly, 3jts of tubing and upper packer. A slickline plug was placed in the PTSA and upper patch successfully ran.tŚŝůĞĚƌŝŌŝŶŐďĞĨŽƌĞƌĞƚƌŝĞǀŝŶŐƚŚĞ^>ƉůƵŐƚŚĞƚŽŽůƐƚƌŝŶŐďĞĐĂŵĞƐƚƵĐŬŝŶƚŚĞƉĂƚĐŚĂŶĚƐŚĞĂƌĞĚŽī͘ tĞŶĞĞĚƚŽƌŝŐƵƉƐĞƌǀŝĐĞĐŽŝůĂŶĚƉƵůůƚŚĞƵƉƉĞƌƉĂƚĐŚƐĞĐƟŽŶƚŽƌĞĐŽǀĞƌƚŚĞƚŽŽů-string. The wellbore will be circ’d to 9.2ppg KWF prior to pulling the upper patch then monitored and Įlled as noted in the ‘extended deployment’ sundry. The upper patch and 3 joints and PTSA will be layed down and reran as noted in the ‘extended deployment’ sundry.dŚĞǁĞůůǁŝůůďĞĐŽŶĮƌŵĞĚĚĞĂĚĂŶĚĐŽŶƟŶƵŽƵƐŚŽůĞĮůůǁŝůůďĞƵƟůŝǌĞĚ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƟŽŶƐ͘ Regards, Dave Bjork FS1 OE 564-4672o 440-0331c From: Carrie Janowski <Carrie.Janowski@hilcorp.com> Sent: Thursday, October 5, 2023 11:26 AM To: David Bjork <David.Bjork@hilcorp.com> Subject: FW: [EXTERNAL] Completed Sundry 323-538 FYI Carrie Janowski Regulatory Tech, Prudhoe Bay East Team Hilcorp North Slope (907) 564-5179 office (907) 575-7336 cell From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Thursday, October 5, 2023 11:20 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed Sundry 323-538 Hello, ƩĂĐŚĞĚŝƐƚŚĞĐŽŵƉůĞƚĞĚ^ƵŶĚƌǇĨŽƌWhϬϮ-23A. CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 02-23A Mill Plug & Extended Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-053 50-029-20795-01-00 ADL 0028308 10337 Conductor Surface Intermediate Liner Liner 9023 78 2598 7694 1379 1996 8810 20" 13-3/8" 9-5/8" 7" 2-3/8" 8760 34 - 112 33 - 2631 31 - 7725 7476 - 8855 8308 - 10304 2450 34 - 112 33 - 2631 31 - 7703 7456 - 8803 8276 - 9024 none 470 2670 4760 5410 11780 8810 1490 5380 6870 7240 11200 8270 - 10200 4-1/2" 12.6# x 3-1/2" 9.2# 13Cr80 29 - 88558239 - 9025 Structural 3-1/2" Baker SB-3A No SSSV Installed 7235 7217 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 10/15/2023 Current Pools: PUT RIVER OIL , PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.09.26 14:34:34 -08'00' By Grace Christianson at 4:08 pm, Sep 29, 2023 323-538 SFD 10/4/2023MGR03OCT23 2450 10-404 DSR-10/2/23*&:JLC 10/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.05 09:01:14 -08'00'10/05/23 RBDMS JSB 100523 Plug mill and patch Procedure 02-23A PTD: 200-053 Well Name:02-23A plug mill and extended patch API Number:50-029-20795-01 Current Status:Offline Uncompetitive Rig:CTU Estimated Start Date:10/15/2023 Estimated Duration:1day Regulatory Contact:Carrie Janowski Permit to Drill Number:200-053 First Call Engineer:David Bjork (907) 440-0331 (c) Second Call Engineer: AFE Number:235-03864 Cost / IOR Current Bottom Hole Pressure:3,330 psi @ 8,800’ TVD 7.3 PPGE Max. Anticipated Surface Pressure:2,450psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 1300psi (Taken on 1/25/2020 DHD) Min ID:1.969” ID – liner top @ 8,308’MD Max Angle:95 Deg @ 9,965’ Brief Well Summary: June 2000 CTD sidetrack into Z1B that was converted to a Put river producer in 2004. Objective: The objective of this procedure is to mill up the cast iron bridge plug covering the Z1B perfs and run an extended patch across the put river perfs. Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Patch, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the patch. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen, it will either be killed by bullheading while POOH or circulating bottoms up. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with patch setting tool. 3. RIH with motor and mill assembly, mill up CIBP at 8,810ft and push to 10,200ft. 4. Bullhead 150 bbls of KWF, 8.4 ppg 1% KCl or 8.5 ppg down the tubing to the formation. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 99 bbls b. 4-1/2” Tubing – 3,005’ X .0152bpf = 46 bbls c. 3-1/2” Tubing – 5,302’ x 0.0087bpf = 46 bbls d. 2-3/8” Liner – 1,892’ X .0038bpf = 7.2bbls 5. At surface, prepare for deployment of extended patch. 6. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying patch to ensure the well remains killed and there is no excess flow. Perform drill by picking up safety joint with TIW valve and space out before MU of patch. - mgr o mill up the cast iron bridge plug covering the Z1B perfs and run an extended patch across the put river perfs. Plug mill and patch Procedure 02-23A PTD: 200-053 7.Pickup safety joint and TIW valve and space out before MU patch assembly.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of patch. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 8. Break lubricator connection at QTS and begin makeup of extended patch per schedule below. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 02-23A Extended Patch Schedule 9. MU and RIH with deployment sleeve seal assembly, 3 jts of 2-3/8” tubing and 3-1/2” Mono-Pak liner top packer. Sting in with seal assembly and hydraulically set the packer. POOH 10. RDMO CTU. 11. RTP. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Sundry Change Form Patch Interval Patch Length Weight of patch (lbs) 8,200ft – 8,308ft 108ft’500lbs (4.7ppf) extended patch Make up PCE. -mgr Plug mill and patch Procedure 02-23A PTD: 200-053 Current Wellbore Schematic Plug mill and patch Procedure 02-23A PTD: 200-053 Plug mill and patch Procedure 02-23A PTD: 200-053 Coiled Tubing BOPs Plug mill and patch Procedure 02-23A PTD: 200-053 Standing Orders for Open Hole Well Control during Perf Gun Deployment (Utilize same methodology and percautions for extended patch) Plug mill and patch Procedure 02-23A PTD: 200-053 Equipment Layout Diagram Plug mill and patch Procedure 02-23A PTD: 200-053 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date • • OF Ty ` (41///7,/ 8� THE STATE Alaska Oil and Gas 4 .. :---- - p f LAsKA Conservation Commission ,:-.1),-- __=_.;. AA T 333 West Seventh Avenue , 2-T- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF 10- -ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone Drill Site 2 and 18 PE SLAHNE BAR BP Exploration (Alaska), Inc. 3 02017. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Put River Oil Pool, PBU 02-23A Permit to Drill Number: 200-053 Sundry Number: 316-618 Dear Mr. Stone: 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. w. 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, f Cathy P. Foerster Chair, Commission DATED this?l day of December, 2016. • RBDMS fit- GU r 2 2016 STATE OF ALASKA 410ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Profile Modification ®' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-053 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0. 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20795-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I I PBU 02-23A iD 9. Property Designation(Lease Number): 10. Field/Pools: Ef LZ r rE. L UI ADL 0028308 ' PRUDHOE BAY,PUT RIVER OIL/PRUDHOE BAY,PF -I EV(. E & -4- 11. Z11. PRESENT WELL CONDITION SUMMARYa Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 40 4E- s CO 10337 , 9023 , 8810 8760 8810 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91.5#H-40 34-112 34-112 1490 470 Surface 2598 13-3/8"72#L-80 33-2631 33-2630 4930 . 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5"Baker SB-3A Packer Packers and SSSV MD(ft)and ND(ft): 7236, 7218 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic 0 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stone,Christopher be deviated from without prior written approval. Email Christopher.Stone@bp.com Printed Name Stone,Christopher Title DS 2&18 PE SignatureThr1,491"%---- Phone +1 907 564 5518 Date 1alL1tati, COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 \( Q - 62 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No IL Subsequent Form Required: /0 4 Q 4' APPROVED BYTHE Approved by: t p:/ ._ COMMISSIONER COMMISSION Date:J Z 2)_4 VTv / /i0//C iii2...vC1(a ORIGINAL RBDMS DEC 222013 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate of fz11 Wit'` /L i - •i6> • m CO mcD o O O O O O O Ns (O OO N iT O CON- OO 110 C N 6C) N- N O2 U y 0 0 0 0 0 0 0 O L 0) M N— LL) (0 O M O 6) O N d O N- O U1 cr 00 N N M O) N- O N O LO .� (O N M CO O O O) N OO OO 00 O M OO i i I i i I i H N- co co co �t M ' O) O) Ns O) O M M M N O N N O OD 00 OO M 4.0 N �- O N tiO co V M co to O T- r (O M d' a0 M O O = N OO 00 CO CO M O) O 0 Q < M O N ao (o N � c�) — MNO0) 0 M M M M N O Cl Oo ,7);o 0o 2 M • O MD Mm o ` 0. 000rn o � 000 d' 10° OO °ODU = J J Q 00 m M y N N- *k cn N It 0 CD CO QO N O _ CO b U1 03 Ns 01 N °I 6N 0) �' CO t a+ CD 141 00 CD Ca a0 O) O) N � co O J N OND O ~ N (O W W 1— < < CO• W UWW 0• 0 0- 1 Cto Z Z O D t F" z z » 0 (n Z Z J J F-- f-- • • a) N R m N CO � CO Lo _ V N- O CO N p, d M M M LO w CO CO CO Cr) CV p N 0 0 0 o p CO 0) CA C)) C)) H a O N N- tU w N CO O N- CO a Cn O M 4 0 d co co M co co W p N 0 0 0 0 > p coO) rna) Cr O 2 cc w o 0 o wm z W N a O W 0 y 5 5 Y U 0 > m OU c0n < Y Y 2 O - - J U U w w 1 zcj E j= LU UJ Zd• Nd' co O O 0COC) 0) 0OU _ 2 Op -i0:1) p a W a 00 U w & & Z ~p Z w W w a H Q Q < 2 2 2 O m cn cn cn cn ca Q N a 0 N 1° w O O o O o O = � NCO 'Tr C C) M N r- LO CO CO Baa) O 2 — = f- f- a _1 a ` z 2 O co cn cn v) 0- 113 O U LL U) U) (n U) 1 a a a a_ a • Qmmmm a 0 a) a) a a) F y 00 0 0 .- 0 D D 0 • 0 0 0 0 o W -j Z O N N N NZ p. d < N W .m o) O) o) cm0 O w W 0 w U p W u t N N N N N Z a W W W W O CO OO CO Co CO m Q ° ? w J _' J p CL < < m (L mcn u_ U U � I ct m E M M M m M N N N N N W a v) O W N Cr w N N N N N m CL d [L U —I d d W D_ oCOOo < < m mw (r) o_ • ® • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 02-23A Well Type: Natural Flow Producer API Number: 50-029-20795-01 Well Activity Conventional 4 Classification: Activity Description: Toggle Ivishak&Put River Cost Code/AFE: APBNRWOS Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg 108, bopd: Job Type: Profile Modification • Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory N/A requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Primer Seconder Required? Yes y y Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Well Intervention Engineer: Tyson Shriver Contact numbers: (907)564-4133 (406)690-6385 Lead Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Date Created: November 17,2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 7/18/2016 240 5156.2 bwpd, 4,804 19,998 89 0 278 WC 95.55% Current Status: Operable Shut In Inclination>70°at Depth(ft) 9,144' MD Recent H2S (date,ppm) 8/25/2016 20 • Maximum Deviation (Angle and ppm Depth) 95° 9,965' MD Datum depth,ft TVDss 8,100'TVDss Dogleg Severity(Angle and Depth) 41° 9,161' MD Reservoir pressure(date, 1/22/2016 3,529 psi Minimum ID and Depth 1.969" 8,308'MD psig) Reservoir Temp,F 172°F Shut-in Wellhead Pressure 1,600 psi Known mech. integrity VR plug stuck behind IA blind flange on front of the well problems(specifics) Last downhole operation(date, 9/4/2016 Pulled BHP gauges from 7270' MD operation) Most recent TD tag(date,depth, 1/21/2016 8568' SLM 2'x 1.5"stem, 1.75"SB toolstring OD) Surface Kit Fit-for-Service? If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, 02-23A is currently a Put River producer which is SI due to lack of injection support from 01-08A. The background information, offset injector,01-08A, is SI due to a corrosion issue at DS-12 preventing seawater injection. The etc: injection system is expected to be repaired in 2017(most likely late 2017). Without injection,02-23A is not a viable Put Producer,as the pressure of the reservoir would quickly drop below bubble point,hence • the reason it is SI awaiting the DS-12 seawater line repair to be completed. Prior to 02-23A being a Put River producer, it was an Ivishak only producer from 2000-2004. At the time the Ivishak was SI,it was producing 540 bopd and 24.0 mmscfpd(44,000 GOR). At today's facility MGOR,this would equate to a 223 IOR well. Since the DS-12 repair is not expected to occur in the near term incorporating the ability to toggle between the Put and Ivishak adds value by restoring the well to immediate Ivishak production. • The objective of this intervention is to mill the CIBP isolating the Ivishak perforations,set a LTP with the ability to toggle between the Put and Ivishak and produce solely fro the Ivishak while awaiting the restoration of the DS-12 seawater lines. S • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Configure well to be able to toggle between Put and Ivishak production while injection into 01-08A is down. Specific Intervention or Well Objectives: 1 Configure well to be able to toggle between Put and Ivishak production. 2 3 Key risks,critical issues: Mitigation plan: 6/2/15 caliper log inidcated scale from 7340'to 8320', Ensure wellbore is clean of scale deposits @ LTP 1 increasing in severity with depth. Scale was also noted to setting depth. be heavy within the 2-3/8"liner down to 8215'. 2 Milling out of tubing/liner. Ensure RP is followed to avoid damage to the tubing/liner during milling operations. Kill well during milling CIBP to ensure minimal 3 Cross Flow between Put River&Ivishak crossflow occurs during the time both reservoirs are open to one another. Ensure the right mill is used during milling operation 4 Milling scale can be very time consuming ie;turbo scale mill. Contact APE/Intervention Engineer if milling operations appear to be challenging. 5 LTP not set correctly-cross flow between reservoirs. Set plug in LTP and PT to confirm integrity and isolation from Put River Summary Step# Service Line Activity 1 C Mill scale restrictions and CIBP©8810' 2 S Run LTP assembly and set in the 2-3/8"deployment sleeve at 8308' MD. 3 F Assist SL with testing LTP. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1.) Mill scale from 7340'to top of liner at 8308'. 1 C 2.) Mill scale deposits in liner from 8308'to CIBP at 8810'. 3.)Mill 2-3/8"CIBP 8810' and push to PBTD. 1.)Set PTSA style LTP-run with plug set in R-Nipple and sleeve in the"open position". 2.)Set blanking sleeve across sliding sleeve. 2 S 3.) Fullbore to assist with test of PTSA to 1500 psi. 4.) Pull blanking sleeve, pull plug from R-Nipple. 5.) Reset blanking sleeve in sliding sleeve. 3 F Assist SL with test of LTP assembly to 1500 psi. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 600 MMSCFD: 24 BWPD: 0 Expected Production Rates: FTP(psi): 850 Choke setting: 80 PI(bfpd/psi dp) Post job POP instructions: POP well to LP(use GL for KO if necessary),establish flow, obtain a well test(2 within the first 2 weeks) and await further instructions (HP vs LP flow)from APE. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc TREE= 4-1/16"CtW WELLHEAD= FMC • NO1TESTBG&WELL AGLE70"@91ACT11�1TOR= BAKEC 02-2 3AUR B. ,_ 64 BF.ELEV= KOP= 6200' Max Angle= 95°@9965' ) L 2164' —14-1/2"AVA TRSV SSSV PIP,D=3.81" Datum MD= 8918' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347' —1 2631' / 3005' —{4-1/2"X 3-1/2"XO 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958" H 3006' GAS LFT MANDRELS M) TVD DEV TYPE VLV LATCH FORT DATE TOP OF 3-1/2"TBG H 3006' 3189 3189 1 MMG-5-7 DOME RK 16 12/14/11 L 5727 5727 1 MMG-5-7 DOME RK 16 12/14/11 7006 6990 9 MMG-5-7 DMt' RK 0 06/25/00 7121 7103 9 MI3-5-7 SO RK 24 12/14/11 Minimum ID = 1.969" @ 8308' TOP OF 2-3/8" LINER *xi 7232' H9-5/8"X 3-1/2"BAKER SB-3A PKR • 7270' —13-1/2"OTIS X Fi2OFLE NW,D=2.813" PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 7336 7317 7 OM(LT) DM( RK 0 06/30/00 6 7452 7432 6 OM(LT) DM( RK 0 06/30/00 TOP OF 7"LNR H 7476' . 7476' —EST TOP OF CMT BEHIND 7"LPR ,••( REVERSED CMT OFF LNR TOP) • • 9-5/8"CSG,47#,L-80,D=8.681" --I 7725' —A ' EST TOP OF CMT BO-IND 3-1/2"TBG H 8000' I *,„ TOP OF 2-3/8"LNR —{ 8308' *. • .' TOP OF HFSTOCK H 8857' •'.�, 4, •� W 3-1/2"TBG PUPK�-I H 8881'-8901' �',•1\ 8810' _-11-314"BAKER CDP SET 08/29/04 3-1/2"CUP H 9026' �� , ` 3-1/2"TBG,9.3#,13-CR,.0087 bpf,110=2.992" J— 9033' -41,,. 7"LNR,29#,13-CR .0371 bpf,D=6.184" J 9235' •or PERFORATION SUMMARY i••I REF LOG:PFC-GR ON 12/29/91 PBTD H 10267' • ANGLE AT TOP PERF:89°@ 8270' Note:Refer to Production DB for historical perf data 2-3/8"LNR,4.6#,L-80,.0038 bpf,ID=1.995" -1 10303' SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8270-8296 C 08/29/04 1-11/16" 4 9180-9450 C 06/23/00 1-11/16" 4 9540-9630 C 06/23/00 1-11/16" 4 9680-9760 C 06/23/00 1-11/16" 4 9800-10200 C 06/23/00 DATE REV BY COMMENTS DATE REV BY CONVENTS FRUDHOEBAY UNIT 1982 ORIGINAL COMPLETION 09/21/11 RCT/PJC GLV GO(08/30/11&09/19/11) WELL 02-23A 06/25/00 SIDETRACK 10/31/11 JMD TREE C/0(10/10/11) PERMT No:"2000530 02/02/02 RIV IP CORRECTIONS 12/16/11 LEO PJC PILL TTP/GLV G0(12/14/11) API No: 50-029-20795-01 08/17/03 CMD/TLP PERF ANGLE CORRECTION 08/08/16 CJWJMD SET FLOW-THRU SUB w/GAUGES SEC 36,T11 N,R14E, 1917'FNL&58'FWL 03/18/10 JCMYSV GLV G0 09/07/16 JUJMD PULLED X-LOCK/GAUGES(9/4/16) 09/17/11 RCT/PJC GLV OPEN/SET PX PLUG(8/30/11) BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~~_- _~_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) ~"~"Color items: o Diskettes, No. r3 Maps: f Grayscale items: [] Other, NofType D Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds TOTAL PAGES: ~'~/// NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL [] Other Project Proofing PROOFED BY: BEVERLY BREN ~/~SHERYL MARIA LOWELL [] Staff Proof By: Date: Scanned (done) PAGES: SCANNED BY'. (at the time of scanning) BEVERLY BREN VINCENT ~ MARIA LOWELl. DATE: IS/ RESCANNEDBY; BEVERLY BRE~HERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done} • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 06-3 0 o 0 2-13 + �6 ✓ August 22, 2011 N Mr. Tom Maunder i k k " Alaska Oil and d Gas Conservation Commission � � C,, 333 West 7 Avenue Anchorage, Alaska 99501 �� '1 �' A 4t.10 Su Corrosion Inhibitor Treatments of GPB DS -02 � 0j 0 4 , Dear Mr. Maunder 44,4 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 ~~~~" 'to ~... ~", MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 02-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/29/04 PERFORATE PUT RIVER: KILLED AND FREEZE PROTECTED WELL. SET 1.75" CIBP IN 2. 3/8" LINER AT 8810'. REVISED FROM 8900' BECAUSE SET DOWN AT 8862'. PERFORATED UNDER BALANCED 440 PSI FROM 8270-8296'. REF SLB - MEMORY CNL DATED 23-JUNE-2000 WITH 2.5" PJ 2506, 6 SPF, GUN. WHP'S RECORDED ON MEMORY GAUGE AT SURFACE. NO PROBLEMS RIH OR POOH. TURNED WELL TO ASRC TO POP FOR PIGGYBACK TEST. 08/29/04 T/I/O=2250/1300/125 LOAD & KILL (ASSIST E LINE, PERFORATING) SPEAR IN W/ 5BBLS NEAT METHONAL FOLLOWED W /200 BBLS FILTERED 1 % KCL, CAP W /38 BBLS 50/50 METH/WATER. LOADED TUBING WITH 28 BBLS 50/50, AND HELD 200 PSI WHILE PERFORATING. FWP=0/1250/150 08/29/04 Set CIBP @ 8810' FLUIDS PUMPED BBLS 66 50/50 Methanal/Water 200 Filtered 1 % KCL 5 Neat Methanal 271 TOTAL Page 1 TREE = F tIIC GEN 3 WELLHEAD = I'vtEVOY ACTUATOR = ? KB. ELEV = 64' BF. ELEV - KOP= 6200' Max Angle = 95 @ 9965' Datum MD = 8918' Datum TVD = 8800' SS 02-23A SAFETYNOTES: HORIZONTAL WELL - 70. @ 9144' AND 90. @ 9230' . CHROME 4.1/2" TBG & 7" LNR 2164' 4-1/2" A VA lRSV SSSV NP, 10 = 3.81" TOP OF 3-1/2" TOO . 13-3/8" CSG, 72#, L-80, 10 = 12.347" 3005' 4-1/2" X 3-112" XO 4-112" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" ST MD 1 3189 2 5727 3 7006 4 7121 GAS LIFT MAI\ÐRELS NO rEV TYÆ VLV LATCH 3189 1 MMG-5-7 DOME R< 5727 1 MMG-5-7 DOME R< 6990 9 MMG-5- 7 DMY R< 7103 9 MMG-5-7 DMY R< PROWCTION MANffiELS PORT DATE 16 06130100 16 06130/00 L 09112/04 Minimum ID = 1.969" @ 8308' TOP OF 2-318" LINER ST MD NO rEV TYÆ VLV LATCH PORT DATE 5 7336 7317 7 OMI(LT) DMY R< - 06130/00 6 7452 7432 6 OMI(LT) DMY R< - 06130/00 PERFORATION SUMMARY REF LOG: PFC-GR ON 12/29/91 ANGLEATTOPÆRF: 89 @ 8270' tlbte: Refer to A"oduction DB for his1Drical perf dam SIZE SFf NTffiVAL Opn/Sqz DATE 2-1/2" 6 8270 - 8296 0 08129/04 1-11/16" 4 9180 - 9450 0 06123/00 1-11/16" 4 9540 - 9630 0 06123/00 1-11/16" 4 9680 - 9760 0 06123/00 1-11/16" 4 9800 - 10200 0 06123/00 7232' 9-5/8" X 3-112" BAKERSB-3A PKR 7270' 3-1/2" 011S X PROALENIP, 10 = 2.813" 7476' EST TOP OF CMT BB-III\Ð 7' LNR (REVffiSEDCMTOFF LNRTOF1 9-518" CSG, 47#, L-80, D = 8.681" 1-3/4" BAKffi asp SET 08l29IU4 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, 10 = 2.992" 17" LNR, 29#, 13-CR, .0371 bpf,lD = 6.184" H D/l.TE RBI BY COMMENTS DATE REV BY COMMENTS 1982 ORIGINAL COM PLErION 00/12/04 WRMLF GLV C/O 06/25100 SIŒTRACK 02/021U2 RN/TP CORREC110NS 08l17m CMOITLP PERF ANGLE CORRECTON 06l11IU4 JD'KAK CORREC110NS 08l29IU4 MDCITLP SEr BAKffi asp PRUDHOE BAY lJ'.JIT WELL: 02-23A PffiMIT tIb: 2000530 API tIb: 50-02~20795-01 SEC 36, T11 N, R14E, 1328.62' FEL & 2067.05' FNL BP Exploration (Alaska) Permit to Drill 2000530 MD 10337 'I-VD DATA SUBMITTAL COMPLIANCE REPORT 916/2002 Well Name/No. PRUDHOE BAY UNIT 02-23A Operator BP EXPLORATION (ALASKA) INC 9023 Completion Dat 6/25/2000 J Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20795-01-00 UIC N REQUIRED INFORMATION Mud Log N_9o Sample N_9o Directional Survey No (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH / Dataset CH Received Number Comments DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log Log Run Type ~ ..... _Fret ......................... Name Scale Media No .T~. 8150 8850 L CL'/'''' MCNL 2 FINAL 13815 C ~'/' ~, ~"'~.. 9752 1 R / SRVY LSTNG 8693 L ~L/ . TVD GR 5 FINAL 8871 L ~,,"~. MD GR 5 FINAL 8871 R -~'" LIS Verification. FINAL 8850 D .~-D"" .... 10105 FINAL 8850 10262 Case 10335 Open 11718 CH CH 10337 OH 10331 OH 10331 OH 10340 CH 10335 CH 10/3/2000 09752 8150-10262 5/7/2001 10105 8850-10335 10/3/2000 13815-11718 10/3/2000 9752 SCHLUM MCNL 7/14/2000 BHI 8693-10337. 5/7/2001 8871-10331 BL, Sepia 5/7/2001 8871-10331 BL, Sepia 5/7/2001 8850-10340 BL, Sepia 5/7/2001 10105 8850-10335 Well Cores/Samples Information: Interval Name Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMA(~N Well Cored? Y/~ Chips Received? ""~'Y-/-N-- Analysis '"Y-./-N .......... R ~.n~.ivP. d ? Comments: Daily History Received? Formation Tops ~")/N Permit to Drill 2000530 DATA SUBMITTAL COMPLIANCE REPORT 91612002 Well Name/No. PRUDHOE BAY UNIT 02-23A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20795-0'1-00 MD 10337 TVD 9023 Completion Dat 6/25/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: ~ Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Prudhoe Bay North Slope, Alaska 02-23A Contains the following: !i ~. ~LAS Format disk 5,t, Measured Depth GR print ii'l TVD-GR print sent By: JosefBerg Received ~_~/.a_~_~O~ .~ _ ~ Date: April 20, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVED HAY 0 ? 2.001 9~25~OO Schlumberger NO. 544 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'i-i'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 l'i~. 1'~o Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-23A 20279 MCNL (PDC) ~ ~'~<~'?.-- 000623 I I 1 D.S. 5-10B 20330 MCNL .-P. ~q ~' % 000728 I I 1 D.S. 7-35 20309 RST ~ c~-O 000712 I I 1 D.S. 15-07B 20353 MCNL ~ ~"'t ~"~ 000813 1 I I OCT 000 DATE: . _ ~..aS~ 0il,& Gas bT)ns. ........ *' Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. INTEQ 7260 Homer Drive, Anchorage, AK 99518 Wednesday, July 12, 2000 State of Alaska AOGCC Lori Taylor 3001 Porcupine Street, Anchorage, AK 99501 Dear Lori Taylor: This letter is intended to correct Well Header Information for an End of Well Survey distributed recently. The End of Well Survey in question was acquired by Baker Hughes INTEQ' MWD on Well 02-23A, Prudhoe Bay Unit, North Slope, Alaska for BP Exploration Alaska, Inc. This survey was acquired from 24 May 2000 through 20 Jun 2000. The information that was corrected is the Operator name, which was reported as Phillips Alaska, Inc. The Operator name has been corrected to BP Exploration Alaska, Inc. Thankyou. Sincerely, Brij Potnis Technical Support Engineer RECEIVED JUL 1 4 2.000 Aiaska. Oil & G~s (;OHS. [;ommissior~ Anchorage STATE OF ALASKA ALA~,,xA OIL AND GAS CONSERVATION COM,,,,,$SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification o! Service Well Oil r~ Gas D Suspended D Abandoned D Service 2. Name of Operator~~ 1 I 7. Permit Number BP Exploration (Alaska), Inc. 200-053 3. Address 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612 50-029-20795-01 4. Location of well at sudace ~.. ............... 9. Unit or Lease Name 1915' FNL, 5221' FEL, Sec. 36, T11N, R14E, UM (asp's 686834, 5949264) ~ ~;%"':: ?, · : . Prudhoe Bay Unit ,, . At Top Producing Interval !~~!: 10. Well Number 2402' FNL, 181' FEL, SEC 35, T11 N, R14E, UM (asp's 686607, 5948774) 02-23A 2071' FNL, 1330' FEL, SEC 35, T11N, R14E, UM (asp's 685450, 5949077) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. RKB 64 feetI ADL 28308 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband.__ -,"~.~,.~ 115. Water Depth, il offshore 16. No. of Completions May 8, 2000 June 21,2000 Jun_~_~.s~,eee ~'/'~-)~"~,:~I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness o1' Permafrost 10337' MD /9023' TVD 10267' MD /9025' TVD YES ~] No DI 2164' feet MD 1900' (approx) 22. Type Electric or Olher Logs Run MWD & GR, Mem CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 78 30" 470 Sx AS II 13-3/8" 72# L-80 Surface 2631' 17-1/2" 2300 Sx Fondu & 400 Sx PFC 9-5/8" 47# L-80 Surface 7725' 12-1/4" 500 Sx Glass G & 300 Sx PFC 7" 29# 13CR 7476 8855' 8-1/2" 375 Sx Class G 2-3/8" 4.6# L-80 8308' 10304' 3" 14.5 bbls 15.8 ppg LARC 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) 9180' - 9450' MD; 9037' - 9034' TVD; @ 4 SPF 4-1/2" 3006' 7232' 9540' - 9630' MD; 9033' - 9033' TVD; @ 4 SPF 3-1/2" 8855' 9680' - 9760' MD; 9036' - 9034' TVD; @ 4 SPF 9800' - 10200' MD; 9035' - 9025' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary lot details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 6, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/8/2000 3.0 Test Pedod >I 4341 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -214 psi 24-Hour Rate > 2318 10062 63 28. CORE DATA Brie~descdpt~~n~f~~th~~~gy~p~r~sity~~ractures~a~~are~~di~sand~ressence~f~~~~gas~r~ater. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved April 18, 2000 (Permit ~200-053) , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 1 B GEOLOGIC MARKER~ MEAS. DEPTH 8446' 8555' 9070' TRUE VERT. DEPTH 8409' 8443' 8515' 8995' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 02-23A CT Sidetrack Drilling Operations + Survey. 32. I hereby cert~ that the following is tree and correct to the best of my knowledge. Signed _~/~~~_~,,,..../~, , ~ Title PAl Coil Tubin.q Drilling En.qineer Lamar L. Gantt INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28; If no cores taken, indicate "none". Form 10-407 ,,,, 9:?000 02-23A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 5/07/2000: 5/08~2000: 510912000: 5/10/2000: 5/22/2000: 5/23/2000: 5/24/2000: 5/25~2000: 5/26/2000: 5/27/2000: 5/28~2000: 5/29/2000: 5/30/2000: 5/31/2000: 6/01/2000: 6/02/2000: 6/3/2O00 - 6/14/2000: 6/15/2000: 6/16/2000: 6/17/2000: 6/18/2000: 6/19/2000: MIRU CTU. PT'd equip. RIH & tagged TOC @ 8810' MD. Ran tie-in log f/8590' - 8640'. Milled cement to 8850'. PT'd tbg to 1500 psi - bled to 1477 in 15 min. POOH. RIH w/window'milling BHA to BTM. Milling window off TIW Whipstock through the 3-1/2" tbg & 7" liner. TOW = 8857' & BOW = 8864'. Drilled into FM to 8866'. Drilled to 8873' & POOH. RIH w/Crayola mill & dressed window interval & OH. POOH. FP'd well. RDMOL. MIRU Nabors CDR. Tested BOPE - witnessed by AOGCC inspector. RIH. RIH to 8000'. Unable to pull off BTM. Troubleshoot. Begin hydraulic clutch repairs. Performed CTU maintenance. Accepted rig @ 2200 hrs. Completed CTU maintenance. POOH. RIH w/BHA. Logged tie-in. Tagged BTM @ 8871'. Drilled ahead to 8873' & POOH. RIH. Drilled to 8915'. Drilled to 8932' & POOH. RIH & drilled to 8985'. POOH. PT'd BOPE. RIH & drilled to 9045' MD. POOH. RIH & drilled to 9140'. Performed LOT to EMW of 9.1 ppg. Drilled to 9190' & POOH. RIH & drilled to 9215'. POOH. Pulled BHA into injector due to depth encoder problem. Repair injector & performed CTU maintenance. Performed CTU maintenance. Cyber computer problems. CTU on standby. Waiting on computer software upgrade for Cyber. Performed CTU maintenance. Performed functional checkout of computer system. RIH to 4000' & POOH. RIH & tagged BTM @ 9215'. POOH. RIH & drilled to 9465'. Drilled ahead to 9696'. Drilled to 10105' MD. Sidetrack Summary Page I ,ll)l._ 2 1 2000 .A!a~ka Oil & Gas,,,,,'~',,~,,. Commission Anchorage 02-23A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 6/20/2000: 6/21/2000: 6/22/2000: 6/23/2000: 6/24/2000: 6/25/2000: 6/26/2000: 6/29/2000 - 6/30/2000: Drilled to 10276' & POOH. Tested BOPE - witnessed by AOGCC Rep. RIH & drilled to TD @ 10337'. Conditioned OH for liner run. POOH. RIH w/2-3/8" 4.6#, L-80 FL4S Liner & landed it @ 10304' MD. TOL = 8308'. PBTD = 10267'. Released f/liner. Prep for cementing of liner. Pumped 14.5 bbls of 15.8 ppg LARC to cement liner in place (1:1 returns). Contaminated Cement w/Biozan & jetted contaminated Cement f/wellbore. POOH. RIH w/Mem CNL/GR tool. Logged well & POOH w/logging tools. PT'd liner lap to 2000 psi - lost 128 psi in 15 min. RIH w/Perf guns to PBTD & shot 840' of Initial Perforations f/: 9180' - 9450' MD (Zone lB) 9540' - 9630' MD (Zone lB) 9680' - 9760' MD (Zone lB) 9800'- 10200' MD (Zone lB) Used 1-11/16" carriers & shot all Perfs @ 4 SPF, overbalanced press & random orientation. POOH w! guns. ASF. Began RD. Rig released 1300 hrs. Completed RDMOL. RIH & set LGLV's. Placed well 02-23A on initial production & obtained a valid well test. Sidetrack Summary Page 2 ,It)!... 2 1 2000 /~aska 0i-; ,~ bas u,.,,~. Commission Anchorage BP Exploration Alaska, Well : 2-25A, 50-029-20795-0 Locefion -' Nodh Slope, Aleske 84O0 8500 8600 8700 8800 8900 9000 Structure : D.S. 2 Field : Prudhoe Be}, <- West (feet) 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 500 200 100 0 1 O0 I i I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I I Creoted by potnls Dote plotted : lO-Jut-2OO0 Plot Reference is 2-23A. Coordinetes ere in feet reference 2-23, True Verticol Depths ore reference RKB-blSL=64FT. Brij Potnis 267-6613 --- Boker Hughes INTEG --- 9100 .2_2,~~le- in Point ~~ Projected tO TD 2-23 12 ~ Tie-in Point JUL 2 2000 ,~aska O~ a Gas Cons. Commission Anchorage 2-25 T1 2-25 T2 Projected to TD i i i i i i i i i i i 1' i i i i i i i i i i i i i i i i i i i i i i ' i i i i ~ 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 1900 2000 Vertical Section (feet) -> Azimuth 282.00 with reference 0.00'N, 0.00 E from 2-25 100 100 200 O 300 -+' 400 Q) 500 I 6OO 7OO 800 9OO BP E~loration Alaska, Inc. D.S. 2 2-23A 2 -23 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 2-23A Our ref : svy367 License : 50-029-20795-01 Date printed : 12-Jul-2000 Date created : 10-Jul-2000 Last revised : 10-Jul-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 686727.040,5951179.040,999.00000,N Slot location is n70 15 58.601,w148 29 21.128 Slot Grid coordinates are N 5949263.800, E 686834.100 Slot local coordinates are 1917.42 S 59.51 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 0MJ~NI ssq6nH m~M~S Xq P!O=@qds 998I - ~M~ID sq~ 6u!sn p~ndmoo pu~ &MMM u! s~u!p~ooD PIeD · ~ ~uoz - ~s~I~ s! 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D.S. 2,2-23A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : 2-23A Last revised : 10-Jul-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 8693.00 8583.71 460.07S 133.01W Tie-in Point 10337.00 8959.50 151.91S 1388.70W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 2-23 T2 685653.000,5948902.000,999.00 8960.00 332.41S 1189.78W 24-Mar-2000 2-23 T1 8965.00 581.00S 371.00W 24-Mar-2000 8400 8500 8600 8700 8800 8900 9000 Tie-in Point BP Exploration Alaska, Inc. Structure : D.S. 2 Field : Prudhoe Bay Well : 2-25A, 50-029-20795-01 Location : North Slope, Alaska <- West (feet) 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 I I I I I I I I I I I I I I I I I I I I [ I I I I I I I I I I I I Created by potnis Date platted : 10-Jul-20OO Plot Reference is 2-2~A, Coordinates are in feet reference 2-2;5. True Vertical Depths are reference RKB-MSL=64FT, Brij Potnis 267-6615 --- Raker Hughes INTEQ --- ~ted [o TD 2-23 12 RECEIVED JUL Alaska Oil & 6as Cons. Oommission Anchorage lO0 100 I 2-23A v~3 Plan I ~ 2-25 T1 2-23 T2 Projected to TD 9100 i i i i i i i i i i' i i i i [ i i i i i i i i i i i i i i I i i i i i i i 200 1 O0 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 1800 1900 2000 Verficol Secfion (feet) -> Azimuth 282.00 with reference 0.00 N, 0.00 E from 2-25 200 o 300 ~ 400 (1) Q) 5o0 1 V 6OO 7O0 8OO 900 BP E~loration Alaska, Inc. D.S. 2 2-23A 2-23 - Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 2-23A Our ref : svy367 License : 50-029-20795-01 Date printed : 12-Jul-2000 Date created : 10-Jul-2000 Last revised : 10-Jul-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 686727.040,5951179.040,999.00000,N Slot location is n70 15 58.601,w148 29 21.128 Slot Grid coordinates are N 5949263.800, E 686834.100 Slot local coordinates are 1917.42 S 59.51 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED JUL 1 4 2000 Alaska Oil & Gas Cons. 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D.S. 2,2-23A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 2-23A Last revised : 10-Jul-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 8693.00 8583.71 460.07S 133.01W Tie-in Point 10337.00 8959.50 151.91S 1388.70W Projected to TD Targets associated with this wellpath Target name Geographic Location SSTVD Rectangular Coordinates Revised 2-23 T2 685653.000,5948902.000,999.00 8960.00 332.41S 1189.78W 24-Mar-2000 2-23 T1 8965.00 581.00S 371.00W 24-Mar-2000 RECEIVED JUL 1 4 2000 Alaska 0il & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount ~'~~~ Commissioner THRU: BlairWondzell .~~ P.I. Supervisor ~¢% ~.l On FROM: Jeff Jones ~ Petroleum Inspector NON- CONFIDENTIAL DATE: June 21, 2000 SUBJECT: Blowout Preventer Test Nabors CDR-1 Phillips Petroleum DS-2 #23A 200-53 PBU/EOA Operator Rep.: Andy Kirk Contractor Rep.: Paul Haynes Qp. phone: 659-5545 Rig phone: 659-5544 Op. E-Mail: Rig E-Mail: cdrl_supervisor@ppco.com Test Pressures Rams: 3500 psi Annular: 2500 psi Choke: 3500 psi P/F P/F Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P Upper Kelly Lower Kelly Ball Type Inside BOP Quantity P/F N/A N/A 1 P N/A Visual Alarm P P P P BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #-4 Rams #5 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quantity Size/Type P/F 1 7 1/16 5K I 7 1/16 5K P 1 blind/shear P I 2" pipe P 1 2 3/8 PIS F 3 P 1 P 2 P N/A CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector P F P P F F Quantity P/F Inside Reel valves 1 F ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 2900 P Pressure After Closure 1850 P 200 psi Attained 15 sec. P Full Pressure Attained 1 min. 1 P Blind Switch Covers: All P Nitgn. Bottles (avg): 2~2100 P On June 19, 2000 1 traveled to Phillips Petroleum's Drill Site 2 #23A where personnel on Nabors Drilling rig CDR- 1 were preparing to test BOPE. The testing proceeded as scheduled and was performed in a safe and proficient manner by Nabors Drilling personnel with 5 failures. The 2 3/8" pipe/slip rams failed the pressure test and after repeated attempts were replaced with 2 3/8" pipe rams and passed the re-test. The mud system flow indicator failed the audible alarm test. The H2S gas alarm system in the mud pits failed the audible and visual test, and after calibration the audible H2S alarm passed the re-test. There is currently no yellow low level H2S warning light mounted at the mud pits, and I was informed that this system operates independent of the gas detection system on the rig floor. The inside reel valve failed the pressure test but was replaced and re-tested by rig personnel. I advised the operator's representatives, Andy Kirk and Mark Johnson, that they must have BOPE rams providing for pipe, slip, cutting and blinding operations on the coiled tubing in service ( 2" ) installed and correct the remaining failures prior Summary: On June 19, 20001 witnessed a weekly BOPE test and a random gas detection alarm system test on Nabors Drilling rig CDR-1 performing a re-drill operation of Phillips Petroleum's Drill Site 2 well # 23A. Total Test Time: 12 hrs. Number of failures: 5 Attatchments: '1 cc: BOP Nbrs CDR1 6-20-00 JJ 6/22/00 I-Fwd: AOGCC BOPE testing requirements] Subject: [Fwd: AOGCC BOPE testing requirements] Date: Wed, 21 Jun 2000 21:43 '06 -0800 From: Jeff Jones <jeff_jones~admin.state.ak.us> Internal To: blair_wondzell <blair_wondzell~admin.state.ak.us> Subject: AOGCC BOPE testing requirements Date: Wed, 21 Jun 2000 21:42:02 -0800 From: Jeff Jones <jeff_jones~admin.state.ak.us> T o: cdr l_supervisor <cdr l_supervisor~ppco, com> Gentlemen, this letter is a follow up on our earlier communications regarding the BOPE test I witnessed on Nabors Drilling rig CDR-1 DS-2 well #23A on June 20, 2000. Please be advised that the AOGCC regulations require that you have BOPE rams installed in the stack that provide for pipe, slip, cutting and blinding operations on the coiled tubing in service ( 2" ) . You will be required to have this BOPE configuration and correct the failures in the gas detector alarm system in the mud pits and flow indication alarm on the rig floor prior to spudding in the next well. Please keep the AOGCC Inspection group updated on your progress in this matter, and contact us if you have any questions. Thank you for your cooperation, Jeff Jones AOGCC Petroleum Inspector 659-2714(North Slope) 1 of I 6/22/00 8:14 AM STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report ~(~,,/~(-t( Submit to: bl@ir_wondzell@@dmin.state.ak.us Contractor: Nabors Rig Rep.: Paul Haines Operator: Phillips Rep.: Andy Kirk Well Name: DS2-23A Location: Section: 36 Operation: Drlg: X Test: Initial: X Test Pressure: Rams: 250/3000 john_spaulding@admin.state.ak, us and bob_fleckenstein@admin.state.ak, us Rig No.: CDR #1 DATE: Rig Phone: 659-5544 Rig Fax: Op. Phone: 659-5545 Op. Fax: E-Mail ..... ~ ........... PTp'E200-053 j? Meridian: Township: ~ Range: Workover: X Explor.: Weekly: Other: Annular: 250/3000 Valves: 5/22/00 Umiat 250/3000 MISC. INSPECTIONS: TEST DATA P/F P/F Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P FLOOR SAFETY VALVES: Quantity P/F Upper Kelly 0 Lower Kelly 0 Ball Type 0 Inside BOP 0 BOP STACK: Quantity Size/Type P/F Stripper 1 7 1/16 P Annular Preventer 1 7 1/16 P #1 Rams 1 2" pipes P #2 Rams 1 Blinds P #3 Rams 1 2 3/8 pipes P #4 Rams 1 2 3/8 slips P #5 Rams 0 Choke Ln. Valves 1 3" P HCR Valves 1 3" P Kill Line Valves 2 2" P Check Valve N/A CHOKE MANIFOLD: Quantity P/F No. Valves 15 P Manual Chokes 1 P Hydraulic Chokes 1 P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Quantity P/F Inside Reel valves 2 F ACCUMULATOR SYSTEM: Time/Pressure System Pressure Pressure After Closure 200 psi Attained Full Pressure Attained Blind Switch Covers: All stations Nitgn. Bottles (avg): P/F ~ Test F~.sults Number of FailureS: ~ Test Time: (/_8~ Hours Components tested 30 ~ ~-~ ~ment ~ equipm---'~nt ~-~ ~e ma e~d-b~within ~ days. Notify the North Sl--'~pe Inspector 659-3607, follow with written confirmation to Superviser at: blair_wondzell@admin.state.ak.us Remarks: Flange and door leaks on stack, tightened and tested "OK" Reel valve leaked, replaced. Coil used during ail tests, too much volume to show smafl leaks, aquire test joint for next test. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector 24 HOUR NOTICE GIVEN YES X NO Date 5/21/00 Time 0800 Test start 0600 Finish 1400 Waived By Witness Lou Grimaldi BOP Test (for rigs) L.G. 5/12/00 Bop cdr 6~7~00 ALASKA OIL AND GAS : CONSERVATION COPI~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Larmar L. Gantt AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re~ Prudhoe Bay Unit 02-23A ARCO Alaska, Inc. Permit No.: 200-053 Sur. Loc.' 1915' FNL, 5221' FEL, Sec. 36, T11N, R14E, UM Btmhole Loc.' 2244' FNL, 1213' FEL, Sec. 35, T11N, R14E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH_FdCOMMISSION DATED this { ~nae, day of April, 2000 dlf/Enclosurcs cc: Department of FiC', & Game. Habitat Section w/o encl. Deparlmcnt of Em'ironmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill E~ Redrill [~] I lb. Type of well. Exploratory BI Stratigraphic Test E~ Re-entry F~ Deepen r'~ J Service D Development Gas D Single Zone [~] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1915' FNL, 5221' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 2240' FNL, 5274' FEL, SEC. 36, T11N, R14E, UM At total depth 2244' FNL, 1213' FEL, Sec 35, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 28311,3036' @ TD feet No Close Approach feet 16. To be completed for deviated wells Kickoff deplh: 8860' MD Maximum hole angle 91 o 18. Casing arogram size Hole Casing 3" 2-3/8" )ecifications FL4S RKB 64 feet 6. Property Designation ADL 283O8 7. Unit or property Name Prudhoe Bay Unit 8. Well number 02-23A 9. Approximate spud date April 26, 2000 Development Oil Multiple Zone D 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #U-630610 Amount $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10153 MD / 9025 TVD 17. Anticipated pressure (see 20 AAC 25.035 Maximum surface 2450 psig At total depth Settin~l Depth To Bottom TVD 9025' e)(2)) TVD) 3300 psis! @ 8800' Quantity of Cement (include stage data) 10 bbls17 ppg Cement 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9235 feet true vertical 9168 feet Plugs (measured) Tagged PBTD @ 9118' MD on 1/28/1998. Effective Depth: measured true vertical Casing Length Size Conductor 78' 20" Surface 2567' 13-3/8" Production 7661' 9-5/8" Liner 1759' 7" 9118 feet Junk (measured) 9055 feet Cemented Measured depth 470 Sx AS II 78' 2300 Sx Fondu & 400 Sx PF C~ ~ 2631' 375 Sx Class G 9235' True Vertical depth 78' 2631' 7725' RECEDED Perforation depth: measured 8936' - 8937'; 8978'- 8982'; 9094'- 9100'; 9118'- 9134'. MAR 1 2000 true vertical 8881'-8882'; 8921'-8925'; 9032'-9038'; 9055'-9071' Gas Cons. Commissi0p Anch0fa(ie 20. Attachments Ddlling fluid program Filing fee E] Property Plat D BoP Sketch r~ Diverter Sketch D Drilling program [~] Time vs depth plot F~ Refraction analysis F~ Seabed report F~ 20 AAC 25.050 requirements E] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~)~ ~), ~~.~ Title: AAI Coil Tubing Drilling Supervisor Lamar L. Gantt Questions? Carl Stephen Ward @ 265-1305. Date Prepared b)/ Paul Rauf 263-4990 Permit Number J Conditions of approval Samples required sulfide measures ~ Yes Hydrogen Required working pressure for DOPE F~ 2M; Yes ~] No Mud log required D No Directionalsurvey required ~ Yes D ~1 3M; E] 5M; F~ 1OM;El '~)3~00psiforCTU Oth er:. Approved by Commission Use Only APl number Approval date ~ J ) J See coverletter 50- o ~'Z- ~- ~ ~' '~ 5'-'4 ! .z_//j ¢//0 0 Jfor other requirements Yes ~ No No by order of V/ / Commissioner the commission Date ~. (_..~ ORIGINAL SIGNED. ElY Robert N. Chrfsfan~.q Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 2-23A CT Sidetrack and Completion Intended Procedure Objective: P&A well with 17 ppg cement. Mill window from mechanical whipstock. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: P&A existing perfs and place cement behind straddle interval. Install mechanical whipstock. Mill window from whipstock in straddle interval through both the 3-1/2" tubing and 7" casing at 8860' md. Drill 10' of formation and perform leak-off test to 9.0 ppg, 0.5 ppg above the highest anticipated mud weight (8.5 ppg polymer mud). Directionally drill a 2-3/4" (3" bi-center) well to access Zone 1 reserves. Planned TD is 10153' md. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal wells at Pad 3 or CC2A. RECEIVED MAR b l 2_000 Oil & Gas Ca'ts. Commis~n And~o~age March 30, 2000 DS 02-23A Potential Drilling Hazards POST ON RIG No H2S production has been measured from this well. BHP: 3330 psi @ 8800' ss (7.4 ppg EMW), BHT 195 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2450 psi. High perm, gas saturated intervals are expected across the Sadlerochit. No major faults are anticipated. Drilling will be done with 8.5 ppg mud. RECEIVED ~AR ~ ~ 200O Alaska Oil & Gas Cons. Commi~ior~ An~orego March 30, 2000 DS 02-23A )SED CT HORIZONTAL ,OK 4-1/2" @ 3005' SSSV @ 2164' 3-1/2",9.2#, 13CR Production Tubing 9-5/8' Casing to 7725' Baker SB-3A Packer @ 7232' Whipstock @ 8860' BlastJoints @ 8931'-8942' & 8973'~8987' Shoot Circ holes @ 8990' - 8995' Baker FB-1 Packer @ 8997' XN Nipple 9031' 3-1/2" Production Mandrel @ 7336' & 7452' Top of 2-3/8" Liner @ +/- 8000! Top of P&A Cement @ 88901 "-Top of 7" Liner @ 7476' Shoot Circ holes @ 8820' - 8840' Mill Window through 3-1/2" tubing & 7" Casing. Tubing Tail @ 9032' 7" Liner & Perfs P&A'd with 17 ppg Cement FL4S 4.6# Liner Cemented & Perforated 0153' 7" Shoe @ 9235' Pca 3/30/2000 85OO 8600 8700 8800 8900 9000 9100 ARCO Alaska, Inc. Structure : D.S. 2 Well : 2-23PB1 F~eld : Prudhoe Bay Location : North Slope, Alaska <-- West (feet) Dote plotted : 29-Mor-2OOO Plot Reference is 2-23A Version ,~1. Coordinotes are in feet reJerence 2-23, True Vortical Depths are reference RKB-MSL=64FI', --- Baker Hughal INTEQ --- 1440 1360 1280 1200 1120 1040 960 880 800 720 640 560 480 400 320 240 160 80 0 [ I I I I I I I I I I I I I i I [ I I I I i I i I i I I I i I I I I I i 2-2,5 T2 TD Tie on - 85~3.71 lvd, 480.07 $, 133.01 Kick off Po[l~t 4 - Landing Point Tie on - 15.75 Inc, 8693.00 Md. 8583.71 Tvd, 0.00 Vs / / / ..., Kick off Point ~ 4 - Londincj Point ,3 /~,i:'''''~ 2-23 T1 ," ... RECEIVED MAR ~51 2O00 Alaska Oi~ & Gas Co~s. Commission An~orage 200 1 1 O01000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 ,300 400 500 600 700 800 900 Vertical Section (feet) -> Azimufh 8;5.11 wifh reference 460.07 S, 155.01 W from 2-25 160 240 320 - ~ - 400 (- 480T - --+- - 560 1 v 72O 800 RECEIVED MAR 1 2000 Proposal Calculations RUg~' '~r~0~[&~--~ Gas"" .Coordinates provided in: TRUE and GRID relative to Wellhead ...... uoas. mm saon INTEQ Al~0~0ra~Jo and ALASKA STATE PLAN Company: ARCO Alaska~ Inc, Rig: Nabors 3s Job No: Wall: 2-23A Field: Prudhoe Bayz Alaska AFE No: Calculation Method: Minimum Curvature Mag, Declination: 27.260 API No: Vertical Sect, Plane: 83.110 TRUE Grid Correction: 1,420 BHI Rep: Vertical Sect, Plane: 81,690 GRID Total Correction: 25,840 Job Start Date: Measured Depth from: RKB Dip: 80.710 Job End Date: True Vertical Del)th: Sea levd RKB Height: 64.00 Meas, Incl, TRUE GRID Subsea Coords, - TRUE Coords, - ASP Coords, - GRID Dogleg Vertical Tool Face Build Turn Depth Angle Azi, Azi, TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Commen~~ (de~) (de~) (de~) (IX) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) (°/100ft) (°/100t't) 8693.00 15.75 215.10 213.68 8583.71 -460.07 -133.01 5948800.60 686711.50 -463.20 -122.60 0.00 0.00 -16.00 0.00 0.00 Tie in Position 8700.00 15.78 215.07 213.65 8590.45 -461.63 -134.10 5948799.02 686710.45 -464.78 -123.65 0.38 -1.27 -16.00 0.43 -0.43 8718.00 15.84 215.00 213.58 8607.77 -465.64 -136.92 5948794.93 686707.73 -468.87 -126.37 0.38 -4.55 -16.00 0.33 -0.39 8743.00 15.93 214.91 213.49 8631.81 -471.25 -140.84 5948789.23 686703.95 -474.57 -130.15 0.38 -9.11 -15.00 0.36 -0.36 8768.00 16.03 214.81 213.39 8655.85 -476.90 -144.77 5948783.49 686700.16 -480.31 -133.94 0.38 -13.70 -15.00 0.40 -0.40 8793.00 16.12 214.71 213.29 8679.87 -482.58 -148.72 5948777.70 686696.35 -486.10 -137.75 0.38 -18.30 -15.00 0.36 -0.40 8800.00 16.15 214.69 213.27 8686.59 -484.18 -149.83 5948776.08 686695.29 -487.72 -138.81 0.38 -19.59 -15.00 0.43 -0.29 8818.00 16.21 214.62 213.20 8703.88 -488.31 -152.68 5948771.88 686692.54 -491.92 -141.56 0.38 -22.91 -15.00 0.33 -0.39 8843.00 16.30 214.53 213.11 8727.88 -494.07 -156.65 5948766.02 686688.71 -497.78 -145.39 0.38 -27.55 -15.00 0.36 -0.36 8860.00 16.37 214.47 213.05 8744.19 -498.01 -159.36 5948762.02 686686.10 -501.78 -148.00 0.38 -30.71 78.00 0.41 -0.35 Kick off Point 8868.00 16.82 220.43 219.01 8751.86 -499.82 -160.75 5948760.17 686684.76 -503.63 -149.34 22.00 -32.31 72.00 5.62 74.50 8893.00 19.20 236.55 235.13 8775.65 -504.85 -166.53 5948755.01 686679.10 -508.79 -155.00 22.00 -38.65 56.00 9.52 64.48 8899.40 20.00 240.00 238.58 8781.68 -505.97 -168.35 5948753.83 686677.31 -509.97 -156.79 22.00 -40.59 18.00 12.50 53.91 1 8900.00 20.12 240.12 238.70 8782.24 -506.08 -168.53 5948753.73 686677.13 -510.07 -156.97 22.00 -40.78 18.00 20.00 20.00 8918.00 23.91 243.21 241.79 8798.93 -509.26 -174.47 5948750.39 686671.27 -513.41 -162.83 22.00 -47.07 15.00 21.06 17.17 8943.00 29.25 246.23 244.81 8821.28 -514.01 -184.59 5948745.40 686661.27 -518.40 -172.83 22.00 -57.68 12.00 21.36 12.08 8968.00 34.63 248.38 246.96 8842.49 -519.10 -196.80 5948740.01 686649.20 -523.79 -184.90 22.00 -70.41 11.00 21.52 8.60 8992.82 40.00 250.00 248.58 8862.22 -524.43 -210.86 5948734.33 686635.27 -529.47 -198.83 22.00 -85.01 7.00 21.64 6.53 2 8993.00 40.04' 250.01 248.59 8862.36 -524.47 -210.97 5948734.29 686635.16 -529.51 -198.94 22.00 -85.12 7.00 22.22 5.56 9000.00 41.57 250.31 248.89 8867.65 -526.02 -215.27 5948732.63 686630.90' -531.17 -203.20 22.00 -89.58 7.00 21.86 4.29 9018.00 45.50 251.00 249.58 8880.701 -530.12 -226.97 5948728.24 686619.31 -535.56 -214.79 22.00 -101.68 6.00 21.83 3.83 9043.00 50.96 251.81, 250.39 8897.35 -536.06 -244.64 5948721.871 686601.79 -541.93 -232.31 22.00 -119.93 6.00 21.84 3.24 9068.00 56.44 252.52 251.10 8912.14 -542.22 -263.81 5948715.23' 686582.78 -548.57 -251.32 22.00 -139.71 5.00 21.92 2.84 9093.00 61.91 253.131 251.71 8924.95 -548.56 -284.31 5948708.39 686562.44 -555.41 -271.66 22.00 -160.82 5.00 21.88 2.44 9100.00 63.44 253.29~ 251.87 8928.16 -550.35 -290.27 5948706.45 686556.53 -557.35 -277.57 22.00 -166.95 5.00 21.86 2.29 9118.00 67.39 253.69 252.27 8935.65 -555.00 -305.96 5948701.41 686540.96 -562.39 -293.14 22.00 -183.09 5.00 21.94 2.22 9143.00 72.87 254.20 252.78 8944.14 -561.50 -328.54 5948694.35 686518.54 -569.45 -315.56 22.00 -206.29 4.00 21.92 2.04 9168.00 78.35 254.69 253.27 8950.35 -567.99 -351.86 5948687.29 686495.39 -576.51 -338.71 22.00 -230.22 4.00 21.92 1.96 9184.67 82.00 255.00 253.58 8953.20 -572.29 -367.72 5948682.60 686479.65 -581.20 -354.45 22.00 -246.47 62.00 21.90 1.86 3 9193.00 82.39 255.75 254.33 8954.33 -574.37 -375.70 5948680.32 686471.72 -583.48 -362.38 10.07 -254.65 62.00 4.68 9.00 9200.00 82.71 256.38 254.96 8955.24 -576.04 -382.44 5948678.48 686465.02 -585.32 -369.08 10.07 -261.54 62.00 4.57 9.00 9218.00 83.56 258.00 256.58~ 8957.39 -580.00 -399.86 5948674.09 686447.70 -589.71 -386.40 10.07 -279.31 62.00 4.72 9.00 9243.00 84.74 260.23 258.81 8959.94 -584.70 -424.28 5948668.79 686423.40 -595.01 -410.70 10.07 -304.12 61.00 4.72 8.92 9268.00 85.93 262.46 261.04 8961.97 -588.45 -448.91 5948664.43 686398.87 -599.37 -435.23 10.07 -329.021 61.00 4.76 8.92 9293.00 87.12 264.68 263.26 8963.49 -591.24 -473.71 5948661.03 686374.16 -602.77 -459.94 10.07 -353.97' 61.00 4.76 8.88 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Vertical Tool Face Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (de~) (ft) Lat. (Y) Dev. (X) Lat. (Y) Dev. (X) Lat. (Y) Dev. (X) (°/100ft) (°/100ft) (°/100ft) 9300.00 87.46 265.31 263.89 8963.82 -591.85 -480.68 5948660.24 686367.21 -603.56 -466.89 10.07 -360.96 61.00 4.86 9.00 9318.00 88.32 266.90 265.48 8964.48 -593.07 -498.62 5948658.58 686349.30 -605.22 -484.80 10.07 -378.92 61.00 4.78 8.83 9343.00 89.52 269.11 267.69 8964.95 -593.94 -523.60 5948657.09 686324.35 -606.71 -509.75 10.07 -403.83 61.00 4.80 8.84 9353.00 90.00 270.00 268.58 8965.00 -594.02 -533.60 5948656.76 686314.35 -607.04 -519.75 10.07 -413.76' 89.00 4.80 8.90 4 - Landing POini 9368.00 90.01 270.75 269.33 8964.99 -593.92 -548.60 5948656.49 686299.36 -607.31 -534.74 5.00 -428.64 89.00 0.07 5.00 9393.00 90.03 272.00 270.58 8964.98 -593.32 -573.59 5948656.47 686274.36 -607.33 -559.74 5.00 -453.38 89.00 0.08 5.00 9400.00 90.04 272.35 270.93 8964.98 -593.06 -580.59 5948656.56 686267.36 -607.24 -566.74 5.00 -460.29 89.00 0.14 5.00 9418.00 90.05 273.25 271.83 8964.96 -592.18 -598.56 5948657.00 686249.36 -606.80 -584.74 5.00 -478.04 89.00 0.06 5.00 9443.00 90.07 274.501 273.08 8964.94 -590.49 -623.51 5948658.07 686224.39 -605.73 -609.71 5.00 -502.60 89.00 0.08 5.00 9468.00 90.09 275.75 274.33 8964.90 -588.25 -648.41 5948659.68 686199.44 -604.12 -634.66 5.00 -527.05 89.00 0.08 5.00 9493.00 90.11 277.00 275.58 8964.86 -585.48 -673.25 5948661.84 686174.53 -601.96 -659.57 5.00 -551.38 89.00 0.08 5.00 9500.00 90.12 277.35 275.93 8964.85 -584.60 -680.20 5948662.54 686167.57 -601.26 -666.53 5.00 -558.17 89.00 0.14 5.00 9518.00 90.13 278.25 276.83 8964.81 -582.16 -698.03 5948664.54 686149.68 -599.26 -684.42 5.00 -575.58 89.00 0.06 5.00 9543.00 90.15 279.50 278.08 8964.75 -578.31 -722.73 5948667.79 686124.89 -596.01 -709.21 5.00 -599.64 89.00 0.08 5.00 9568.00 90.17 280.75 279.33 8964.68 -573.91 -747.34 5948671.57 686100.18 -592.23 -733.92 5.00 -623.55 89.00 0.08 5.00 9593.00 90.19 282.00 280.58 8964.60 -568.98 -771.85 5948675.89 686075.56 -587.91 -758.54 5.00 -647.29 89.00 0.08 5.00 9600.00 90.20 282.35 280.93 8964.57 -567.50 -778.69 5948677.20 686068.68 -586.60 -765.42 5.00 -653.90 89.00 0.14 5.00 9618.00 90.21 283.25 281.83 8964.51 -563.52 -796.24 5948680.75 686051.03 -583.05 -783.07 5.00 -670.85 89.00 0.06 5.00 9643.00 90.23 284.50 283.08 8964.41 -557.52 -820.51 5948686.14 686026.62 -577.66 -807.48 5.00 -694.22 89.00 0.08 5.00 9668.00 90.25 285.75 284.33 8964.31 -551.00 -844.65 5948692.07 686002.34 -571.73 -831.76 5.00 -717.40 89.00 0.08 5.00 9693.00 90.27 287.00 285.58 8964.19 -543.95 -868.63 5948698.52 685978.18 -565.28 -855.92 5.00 -740.37 89.00 0.08 5.00 9700.00 90.28 287.35 285.93 8964.16 -541.88 -875.32 5948700.42 685971.45 -563.38 -862.65 5.00 -746.76 89.00 0.14 5.00 9718.00 90.29 288.25 286.83 8964.07 -536.38 -892.46 5948705.49 685954.18 -558.31 -879.92 5.00 -763.11 89.00 0.06 5.00 9743.00 90.31 289.50 288.08 8963.94 -528.29 -916.11 5948712.99 685930.33 -550.81 -903.77 5.00 -785.63 89.00 0.08 5.00 9768.00 90.33 290.75 289.33 8963.80 -519.69 -939.58 5948721.01 685906.65 -542.79 -927.45 5.00 -807.90 89.00 0.08 5.00 9793.00 90.35 292.00 290.58 8963.65 -510.58 -962.86 5948729.54 685883.15 -534.26 -950.95 5.00 -829.92 89.00 0.08 5.00 9800.00 90.35 292.35 290.93 8963.61 -507.94 -969.35 5948732.02 685876.61 -531.78 -957.49 5.00 -836.04 89.00 0.00 5.00 .. 9818.00 90.37 293.25 291.83 8963.50 -500.96 -985.94 5948738.58 685859.85 -525.22 -974.25 5.00 -851.67 89.00 0.11 5.00 9843.00 90.39 294.50 293.08 8963.33 -490.84 -1008.80 5948748.13 685836.74 -515.67 -997.36 5.00 -873.15 89.00 0.08 5.00 9868.00 90.41 295.75 294.33 8963.16 -480.23 -1031.43 5948758.18 685813.85 -505.62 -1020.25 5.00 -894.35 89.00 0.08 5.00 9893.00 90.42 297.00 295.58 8962.98 -469.12 -1053.83 5948768.73 685791.19 -495.07 -1042.91 5.00 -915.25 89.00 0.04 5.00 9900.00 90.43 297.35 295.93 8962.92 -465.93 -1060.06 5948771.77 685784.88 -492.03 -1049.22 5.00 -921.05 89.00 0.14 5.00 9918.00 90.44 298.25 296.83 8962.79 -457.53 -1075.98 5948779.77 685768.76 -484.03 -1065.34 5.00 -935.85 89.00 0.06 5.00 9943.00 90.46 299.50 298.08 8962.59 -445.46 -1097.87 5948791.29 685746.581 -472.51 -1087.52 5.00 -956.14 89.00 0.08 5.00 9968.00 90.48 300.75 299.33 8962.39 -432.92 -1119.49 5948803.30 685724.65' -460.50 -1109.45 5.00 -976.10 89.00 0.08 5.00 9993.00 90.49 302.00 300.58 8962.17 -419.90 -1140.83 5948815.78 685702.99: -448.02 -1131.11 5.00 -995.73 89.00 0.04 5.00 10000.00 90.50 302.35 300.93 8962.11 -416.17 -1146.76 5948819.36 685696.97' -444.44 -1137.13 5.00 -1001.16 89.00 0.14 5.00 10018.00 90.51 303.25 301.83 8961.95 -406.42 -1161.89 5948828.73 685681.61 -435.07 -1152.49 5.00 -1015.01 89.00 0.06 5.00 10043.00 90.53 304.50 303.08 8961.73 -392.49 -1182.64 5948842.15 685660.51 -421.65 -1173.59 5.00 -1033.94 89.00 0.08 5.00 10068.00 90.55 305.75 304.33 8961.49 -378.11 -1203.09 5948856.02 685639.72 -407.78 -1194.38 5.00 -1052.52 89.00 0.08 5.00 10093.00 90.56 307.00 305.58 8961.25 -363.28 -1223.22 5948870.34 685619.23 -393.46 -1214.87 5.00 -1070.72 89.00 0.04 5.00 10100.00 90.57 307.35 305.93 8961.18 -359.05 -1228.79 5948874.43 685613.55 -389.37 -1220.55 5.00 -1075.75 89.00 0.14 5.00 10118.00 90.58 308.25 306.83 8961.00 -348.02 -1243.02 5948885.11 685599.06 -378.69 -1235.04 5.00 -1088.55 89.00 0.06 5.00 10143.00 90.59 309.50 308.08 8960.75 -332.33 -1262.48 5948900.31 685579.21 -363.49 -1254.89 5.00 -1105.99 89.00 0.04 5.00 10153.00 90.60 310.00 308.58 8960.64 -325.93 -1270.17 5948906.51 685571.37 -357.29 -1262.73 5.00 -1112.85 0.00 0.10 5.00 T.D. RECEIVED 4AR 31 2000 ARCO ALASKA, INC, TRSSSV Tubing Casing XO Tubing Gas Lift Mandrel/Dummy Valve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Dummy Valve 3 Gas Lift MandreVDummy Valve 4 PKR XO NiP Production Mandrel/Dummy Valve 5 Production Mandrel/Dummy Valve 6 NiP Liner BLJJT Perf BIJJT PKR XO MOE XO NOGO ~'~ Prudhoe Bay 02-23 02-23 APl: 500292079500 Odg Complfe: 12/19/91 SSSV Type: Last W/O: 12/19/91 Annula~ Fluid: DfeseFg.6 NaCI Ref Log Date: 12/13/91 Reference Log: BHCS RKB: 64 ff Last Tag: TD: 9235 ffKB Last Tag Date: Max Hole 17 dag @ 9093 Angle: Angle @ TD: 17 dag @ 9235 Rev Reason: Put 2nd packer on schematic (kak) Last Update: 1/26/00 Depth Comment 7725 Window {~ 7725, in 9-5/8" Csg. other (plUgs?quips; etc~)~ JEWELRy Depth TVD Type Description ID casing Strings - AIl 4 7121 7103A-MMG-5 CA RD 1.5 RK 0.000 0 12/19/91 prod uCtiOn Ma nd reis/Valves RECEIVED MAR 3 1 200¢ C T Ddlling Wellhead Detail ~ CT Injector Head I -~-' Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Inl~"tion ~-~ ' I_ . Otis ?' INL~ Oui~: I' . ' I Connect I I Alignment Guide Flange Ram 7-1/16', 5M BOPT-ypeE Dual Gate Ranged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Annular BOP (Hyddl),7-1/16" ID 5,000 psi working pressure Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Ddlling spool 7-1/16", 5M by 7-1/16', 5M Ram Type Dual Gate BOPE Manual over Hydraulic ~ 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (S.S") 2" Pump-In Hanger Fire resistant Kelly Hose to ' Flange by Hammer up 1/4 Tum Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus RECEIVED I/',,,'-'-,,R ~1 2000 ,Naska Oil &'Gas Coas. Commission AnChorage ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT ACCL P.O. BOX 102776 ANCHORAGE, AK 99510-2776 PAGE 1 OF '~ FEBRUARY 18, 2000 TRACE NUMBER: 225127218 CHECK NUMBER: 225127218 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3OO1 PORCUPINE DRIVE ANCHORAGE AK 99501 AMOUNT PAID : $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES:(907) 263-4422/4988 (FAX) P.O. 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"':':':::":'::":""' ..... "":;:"'<:'?':' ....... '"':'~:':;"'"'::::':" .... :":':":'" ...... ."'.. ::..':.'-'- WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION WELL NAME ,,~ .2.--,2~PROGRAM: exp ~ COMPANY ENGINEERING APP~ DATE INIT CLASS GEOLOGY tt ARE~ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ®N ®U 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,_5'-o cb psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Y ~"'"' ,,,~ ~/,~ Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [exploratory/dnly] With proper cementing records, this plan dev"~ redrll ><~ sew __ wellbore seg __ ann. disposal para req ~ 31. 32. II A,B .R D/AT~ 33. (A) will conta.~waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not.dontaminate fres_bwcter'~ or causej:idll;m43wcas-te .-7--.. Y N to s/udrace; /------"~/~-,-~"-~ ~ (C) y~ill not imp~chanical integrity of the well used for disposal; Y N (D) ill(w___~.Qot~mage producing formation or impair recovery from a Y N pool; and /E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ,~'_.<",~ UNIT# .///~?',.-~ ON/OFFSHORE GEOL.~GY: ENGINEERING: UIC/Ann .u, lar COMMISSION: Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD Ol/O5/Ol BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD Ol/O5/Ol 44351 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM. UNIT Data Type STRT. FT 8850. 0000: STOP. FT 10340. 0000: STEP. FT 0. 5000: NULL. -999 . 2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM. UNIT Value SECT. 36 TOWN N llN RANG 14E PDAT MSL EPD F 0 LMF RKB FAPD F 64 DMF KB EKB F 64 EDF F N/A EGL F N/A CASE F N/A OS1 DIRECTIONAL -Remarks (1) (2) (3) (4) (5) CWLS log ASCII Standard -VERSION 1.20 One line per frame Information .......... Starting Depth Ending Depth Level Spacing Absent Value PHILLIPS Alaska, 'Inc. 02-23A Prudhoe Bay Unit 1915' FNL, 5221' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 21-Jun-00 500292079501 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Ail depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. Well 02-23A was drilled to TD @ 10331 feet MD (8959' SSTVD) on Run 10. The well 02-23A was kicked off at 8873 feet MD(8756' SSTVD) . £6LL 8I- E99£ 6I- 6IL9 P£69 £I- P6PI 5968£'6- ISOE0'8- PSLLP'5- LL6SE'9- E9068'P- 99LP£'E- SgELI'I- £8£LT'I- 6£SLL6'O- PI6985'0 91898'5 899P8'9 91898'5 9I~8£6'O- PI698S'0- ~T698S'O- PT698S'O- ET£S6I'0 E09T6£'0 PSOT ESSTL £- 80SSP 9- PSL£P S- EO66P P- 8P£90 9- '9E 'CT 'SC '89 'OS '6S '86 'T6 '90 '68 0T S6 £P 00 69 ~t 69 LS 'T6 'S9 '£8 T066 'PO L686 'OT L£86 '08 E£86 'ES tSt6 '68 T9L6 '£8 60L6 'LB P896 SL96 't£ S£96 6E96 '6T 9096 '£T 0096 'S6 L9S6 '6T EE 6£S6 'tS SO'SIS6 TE'O6P6 '8£ TL 9£P6 '69 £8 £SP6 8L TIC6 '0£ 0£ ESE6 L6 S956 PS 9556 S5 56T6 S9 T9T6 9£T6 £TT6 L606 8S06 £006 9668 £868 8£68 8~68 £T68 II68 P688 0566 ti66 TS86 9P86 86£6 8IL6 5696 S896 S£96 £I96 P096 5£S6 TPS6 9TS6 I6P6 £SP6 90£6 £8 ££~6 TT'0956 69'6T56 6£'9056 £E'£6T6 08'£9T6 8E'££T6 £T'STT6 PS 8606 8S 0906 6S P506 85 8006 PS 9668 0£ £868 £9 EP68 9£ P568 ET £T68 ££ 6688 '£8 8S88 06 P988 ~A~a I~IHS SAHflD hg TS £5 J~ IS £5 ~ LO £5 ~g 80 £5 hi 90 £~ ~ 90 £5 ']~ 66 I5 '~ 66 I5 ;~ £S'8T OT ~ £S'8T 6 ;~ SO 8T 8 ~g £T LT L J~ 80 8T 9 ~ 90 8T S ~ 90 8I ~ 50 8T ~g 00 ti ~ 00 ti T :SLZS~MO HOSNZS (s2Tun I4~-aM_N) [~MN] Id~-aM/4 X?~ ?mm~D <- k'~DdO :SDIMONZNN 'sAaA~ns ieuoT~oaATa aqj oq PaTidde u@aq seq saal6ap 95'LE go UOThOa/Ioo uoT~eUTIOa~ OTJaU6eN ~ (8) ' (00-80-t0 'SMS) Xd~ Xq PaTiddns (IO~qUoo qqdaa X~mT~d) Dad ~ oq psq~Tqs q~dsp us~q s~q pu~ I~UT~ sT ~q psqu~s~ad ~q~p ~UA (t) · ~ssggo qTq oq ~osu~s oq @np p~65oI qou s~m (C[AISS ,6568) GN q@~ I££0I o~ (~AASS ,0968) GM q~ 5I£0I mol~ I~O~uT @q~ (9) O0000S'O :~u~oeds ~@~M :s~!u~ ~T~O$ ~daa ~o~ i~o!~do (~ =~nIe~) ~m~op sm UOT~O@~Tp 6UT66Oq s~Xq ~T :ST ~ZTS ~m~ mn2~ 0 :sz ~clX2 p~oo~ (P9 #ZdX£) ClM00ZM L~fNMOM ~ 0'0 £ISdOM dOM 0'0 LIX~fHD MD I dZG0 M~fN0 £~I~ M~H0 'O0-6n~-LO p@q~p XwM emm~D m~6~qmnTqoS ~ sT p~sn D~d sql 'f '~p ~x pI~!~ ~q~ mo~ p~!p~ n~q s~q p~n~s~cd ~p ~q£ 'I O00'T UOTSa~A ~TTa ~m~ iiiiiiiiiiiiiiiiiii ~smI~ ~doIS q~oM NDOD qTu~ X~S @oqpn~d N~ ~£g-g0 NM · ouI '~s~IV SdIq%IHd ND 0SI ~jx'p~m SNOD :Z~S~L NOIAY~4MOMNI ~ PgOI 800£ 8£P8 £8£E 60LI 61- 8108 LI- IL66 LI- 585 8I- ~£I TO0' ~MM :q~6u~I p~oo~ mnmTxeM :qq6usI p~ooe~ mnmTuTM i '0'IEEOT '[ICpEOI i 'L'ISIOI '9'9LIOI i 'g'STIOI 'S'TPIOI i '6'8000I 'I'8~00I i '68'L566 '69'5L66 i '9S'6£66 '9S'£S66 i 'I6'£066 '6~'9~66 £EI I :STT~qns ~d~L Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 F/HR 4 .... Total Data Records: 36 Tape File Start Depth = 8850.000000 Tape File End Depth = 10335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 45 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FTTE~ HEADER **** MWD .002 1024 Length 4 4 ___ 8 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN PHILLIPS Alaska, Inc. WN 02-23A FN Prudhoe Bay Unit COLIN North Slope STAT Alaska *** LIS COMMENT RECORD *** 1!!1!!!!!1!1!!!111! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MWD Code Samples Units Size Length 68 1 API 4 4 68 1 F/HR 4 4 8 Total Data Records: 36 Tape File Start Depth = 8850.000000 Tape File End Depth = 10335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 45 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD Ol/OS/Ol 44351 01 **** REEL TRAILER **** MWD 01/05/01 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes 000005'0 = 000000'5££0Z = 000000'0588 = OOSE 666- 0895 OI6I 96 0619 £9I 085I OC 0£6E £6I 09£9 OEI£ 086£ CE 00£/ LI 0956 0g 0656 058£ SE 000Z'££I OZSO'SZ OOSE'666- OOSE'666- SdO~ 000005'0 = 000000'5£COI = 000000'0588 = SIq :actXq sT 9 aIT~qns 6uTo~ds Ia~aq @IT~ MqdaG q~eqS aIT~ ~d~ 00SE 666- PLZ0 00I 06L6 99 £IZ6 PP P868 05 LSS5 0L 9EIL £P ZOZ£ 0E Z6SO 08 TSZL 9Z ~699 £P 6895 PC IZT8 ET STSL 9£T ES90 ~T OOS~ 666- 005['666- dO~ OOSE' 666- 000 0066 ' EL 000 095E'89 000 OTIS ' 0£ 000 0£60 ' PS 000 09~ ' 9P 000 OOSS ' ZET 000 08L6'9£ 000 06P9 ' 9L 000 0650 ' PA 000 OTSP' 9IT 000 OSOP'6Z 000 000T'L/ 000 OLS9 · PI7 000 00P6 · ST 000 019L'6£ 000 005['666- 000 005Z'666- 000 0 S£501 0 00£0l 0 00g0l 0 00IOT 0 0000l 0 0066 0 0086 0 00£6 0 0096 0 0056 0 00P6 0 00£6 0 OOZ6 0 0016 0 0006 0 0069 S 05~8 0 0588 H~dM~ SIq :ad/iq sT £ aIT~qns OOSE'666- OOSZ'666- 98T£'89 TS6S'TP 60gP'68 6SSS'9TI £T88'96 ELO6'Z£ OL95'L6 TSSO'L9 S06T'0TT 0508'8~ 9LS£'SZ 9586'51 LEIS'ST 060£'8 LT8£'6 0000 SECOT 0000 OO£OT 0000 OOEOT 0000 OOTOT 0000 O000T 0000 0066 0000 0086 0000 00L6 0000 0096 0000 0056 0000 00P6 0000 00£6 0000 OOZ6 0000 0016 0000 0006 0000 0068 O00S 0588 0000 0588 H~d~ SIq :aclKq sT Z alT~qns -- SIq :actKq sT I ~IT~qns