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Home My WebLink About204-179MWD / GR, MWD / GR / PWD, MWD / GR / RES / DEN / NEU / PWD, USIT RECEIVED by James Brooks on 4/12/2023 at 9:55 AM Abandoned 3/25/2023 JSB RBDMS JSB 042623 xGDSR-5/2/23MGR03AUG2023 4.12.2023 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2023.04.12 09:14:18 -08'00' Monty M Myers ACTIVITYDATE SUMMARY 11/16/2022 ***WELL S/I ON ARRIVEL*** DRIFTED 20' x 3.70" DUMMY WHIPSTOCK, FREELY & SLOW (70 to100 fpm) TO 10,910' SLM w/ NO ISSUES ***JOB COMPLETE, WELL LEFT S/I*** 11/20/2022 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP DRIFT WITH 3-1/8" GUN GAMMA TO 10954' MD TO CORRELATE GAMMA RAY FOR 4.5" X 7" WHIPSTOCK. ***CONTINUED ON 11-21-2022 WSR*** 11/21/2022 ***CONTINUED FROM 11-20-2022 WSR*** PT PCE 250LP-2500HP SET 4.5" X 7" BAKER WHIPSTOCK AT 10810' MD @ 23.4 DEG LOH. CCL STOP DEPTH=10796.6' MD. CCL TO TOW=13.4'. LOG CORRELATED TO SLB TEMPERATURE LOG DATED: 5- DEC-2004 ***WELL LEFT S/I ON DEPARTURE*** 12/16/2022 T/I/O = 1000/540/30. Temp = 100°. IA FL (pre-AOGCC MIT). On PW. IA FL @ surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 12/17/2022 T/I/O=876/556/28 AOGCC MIT IA PASSED to 1620 psi ( Witnessed by Brian Bixby ) Pump 1.4 bbls diesel down IA to test. IAP lost 29 psi 1st 15 min & 4 psi 2nd 15 min Bled back 1.4 bbls FWHPs=872/550/25 3/23/2023 CTU#9 1.75" Coiled Tubing (.156 Wall) Job Scope: Mill Window MIRU CTU#9. *** Job Continued on 3-24-23*** 3/24/2023 CTU#9 1.75" Coiled Tubing (.156 Wall) Job Scope: Mill Window MIRU CTU#9. Perform BOP test (AOGCC Witness Waived by Austin McLeod) *** Job in Progress*** 3/25/2023 CTU#9 1.75" Coiled Tubing (.156 Wall) Job Scope: Mill Window MIRU CTU#9. Perform BOP test (AOGCC Witness Waived by Austin McLeod). Complete BOP test. MU BOT window milling assembly and RIH. Tag the pinch point at 10807 ctmd. Load the well with 140 bbls 2%kcl with 10 bbl 60/40 meth cap. See motor work at 10803.9' ctmd and begin time milling. *** Job in Progress*** 3/26/2023 CTU#9 1.75" Coiled Tubing (.156 Wall) Job Scope: Mill Window Sufficient fluid on location, Continue window milling from ~10806'. Make it to 10817.3 ctmd and have to PUH for water. Fluid reloaded. RBIH and continue milling from 10817 ctmd. *** Job in Progress*** 3/27/2023 CTU#9 1.75" Coiled Tubing (.156 Wall) Job Scope: Mill Window Sufficient fluid on location, Continue window milling from ~10817.3 ctmd. Mill to 10823.3 ctmd. Make reaming passes through window. Dry drift thru window to TD clean. No weight slack off or over pull going thru and out window. POOH. Freeze Protect Coil w/ Diesel. Bullhead Tbg Freeze Protect to 2500' tvd (3657' md) with 56 bbls Diesel. Remainder of Tbg full of Slick 2% KCL. Mill / Stream Reamer Gauged: 3.79" Nogo. 3.80" Go. Looks good. Rig Down CTU. ***Job Complete*** Daily Report of Well Operations PBU V-120 Daily Report of Well Operations PBU V-120 3/28/2023 T/I/O=285/150/0. Pre CDR2. Set 4" H TWC #713 @120". TWC LTT (PASS), Pulled 4" CIW Upper Tree. Installed CDR Tree and Kill line . PT Tree against TWC to 500 / 5000 psi. Pulled 4" H TWC #713 @120".(Pass). Install 4 x 7 x-over and PT against SV to 3500 psi BOP Crteria. (PASS). ***Job Complete*** Final WHPs 285/150/0. 4/1/2023 T/I/O = BPV/150/30. Temp = SI. Bleed WHPs (pre rig). Dry hole tree installed. No wellhouse or scaffolding. IA and OA FL both near surface. Bled OAP to BT from 30 psi to 0 psi in 10 min (all gas). Bled IAP to BT from 150 psi to 0 psi in 5 min (all gas). Monitored for 30 min. WHPs unchanged. Final WHPs = BPV/0/0. WV = C. MV = O. IA & OA = OTG. 17:30 Activity Date Ops Summary 4/3/2023 Continue rig move to V-pad. 4/4/2023 Continue with spotting modules. Modules in place, Safe-out mud module to remove tires off damaged jack cylinder. Rig accepted at 10:00. Complete MIRU checklists. Get good leak tight test on SV, MV. Remove tree cap, install BOPs. Install test risers. Continue greasing valves. M/U nozzle. M/U injector to well. Flush and Fluid pack surface lines. Fill reel forward w/ 10 bbls MeOH followed by fresh water for BOP test. Test MP line connection, good. Line up valves for 1st BOP test. Test BOPs as per Hilcorp and AOGCC Regs. All tests 250 / 3500 psi. Test witness waived by AOGCC Inspector Kam StJohn. Test 1: IRV, Stripper, C7, C9, C10, C11 F/P on IRV. Test 2: Blind/Shear, R2, BL2, C15 - Pass. 4/5/2023 Continue testing BOPs as per Hilcorp and AOGCC Regs. All tests 250 / 3500 psi. Test witness waived by AOGCC Inspector Kam St. John. Test 3: Annular (2-3/8"), TIW#1, B1, B4 Pass. Test 4: Upper 2-3/8" Pipe / Slip, TIW#2, B2, B3 Pass. Test 5: Lower 2-3/8" Pipe / Slip, C5, C6, C8, TV2 Pass. Test 6: Choke A, Choke C Pass. Accumulator drawdown test. Test 7: C1, C4, TV1 Pass. Test 8: 3" Pipe / Slip, C2, C3 Pass. Remove testing risers. Space out to floor with drilling risers. Install weight bar in PDL. PT drilling risers and drillers side PDL to 3500#. MU Nozzle and stand-by for KCL, Had a flat tire on way out to location. Pump forward at maximum rate for slack management. Fluids arrived location. Rih w/ BHA#1 Nozzle for bottom kill. Open well to closed choke. 196 psi. Rate: 0.35 bpm in, 0.75 bpm out. Circ pressure: 347 psi. Mud Weight: 8.45 ppg in, 6.97 ppg out Holding 220 psi. Circulate bottoms up from 10750' at max rate. Rate: 4.26 bpm in, 4.17 bpm out. Circ pressure: 3374 psi. Mud Weight: 8.26 ppg in, 8.27 ppg out Choke is wide open. WHP = 220 psi from line friction to tiger tank. Flow check well with 1% KCL in well. Well is flowing with 8.4 ppg KCL. No build up when well shut in. Begin circulating 8.7 ppg mud around. 8.7 ppg mud at surface. Flow check well and confirm no flow. POOH. POOH for build BHA. - Rate: 1.55 bpm in, 1.18 bpm out. Mud Weight: 8.66 ppg in, 8.74 ppg out. Circ pressure = 1401 psi. OOH - Flow check well and confirm no flow. L/D nozzle BHA #1. M/U and deploy BHA #2 - Build BHA. RIH with build BHA #2. Rate: .48 bpm in, .99 bpm out. Mud Weight: 8.67 ppg in, 8.78 ppg out. Circ pressure = 786 psi. IA = 0, OA = 0. Log Tie In from 10580' @ 5 fpm. Correct - 11.5'. RIH past window clean. Tag @ 10834'. P/U and establish drilling parameters. 4/6/2023 Drill 4.25 build from 10834 MD to 10930'. Free spin: 3158 psi, 2.80 bpm. Rate: 2.85 bpm in, 2.80 bpm out. Circ pressure: 3158 - 3361 psi. Mud weight: 8.63 ppg in, 8.78 ppg out, ECD: 10.10 ppg. ROP: 20- 65 fph, WOB: 1.5- 3.5KLBS. Drill 4.25 build from 10930' -10972'. Free spin: 3314 psi, 2.65 bpm. Rate: 2.65 bpm in, 2.62 bpm out. Circ pressure: 3314 - 3361 psi. Mud weight: 8.65 ppg in, 8.88 ppg out, ECD: 10.41 ppg. ROP: 28 fph, WOB: 2.5 KLBS. Drill 4.25 build from 10972' - 11150' Landed Build. Free spin: 3480 psi, 2.76 bpm. Rate: 2.76 bpm in, 2.75 bpm out. Circ pressure: 3480 - 3361 psi. Mud weight: 8.67 ppg in, 8.81 ppg out, ECD: 10.56 ppg. ROP: 28- 90 fph, WOB: 2.5 KLBS. Landed build. Wiper to window. Rate: 2.79 bpm in, 2.75 bpm out. Circ pressure: 3502 psi. Mud weight: 8.83 ppg in, 8.88 ppg out, ECD: 10.55 ppg. Pull through window without issue. Perform jog. Open EDC. Jet tray and chase up to tubing tail. Pump sweeps to surface. Close EDC. Rih to bottom. Pump 20 bbls HiVis. Tail with 11.0 ppg KWF. POOH to L/D build BHA. Rate: 1.53 bpm in, .25 bpm out. Circ pressure: 934 psi. Mud weight: 11.05 ppg in, 8.88 ppg out, ECD: 10.92 ppg. OOH - flow check well and PJSM. Establish ~ 30 bph loss rate. L/D build BHA. M/U and RIH with Lateral BHA. RIH with lateral BHA #3.top at 500' and test agitator - good test. Rate: .53 bpm in, .27 bpm out. Circ pressure: 217 psi. Mud weight: 11.05 ppg in, 8.88 ppg out. IA = 0 psi, OA = 0 psi. Log tie in from 10630' @ 5 fpm. Correct - 11' Displace well to 8.7 ppg mud. Rate: 2.28 bpm in, 1.69 bpm out. Circ pressure: 2600 psi. Mud weight: 8.77 ppg in, 11.16 ppg out. 8.7 ppg mud circulated back to surface. Close EDC and RIH through window clean. Drill 4.25 lateral from 11149' to 11170'. Free spin: 4266 psi, 2.73 bpm. Rate: 2.83 bpm in, 2.82 bpm out. Circ pressure: 4308 - psi. Mud weight: 8.78 ppg in, 8.98 ppg out, ECD: 10.6 ppg. ROP: 5 - 15 fph, WOB: 2.95 KLBS. POOH to investigate BHA after slow ROP and unable to see any motor work. Pull through window clean. Open EDC. Rate: 3.1 bpm in, 2.32 bpm out. Circ pressure: 3141. Mud weight: 8.81 ppg in, 8.96 ppg out, ECD: 10.98 ppg. Stop coil at 3281' to replace leaking pack-off. Secure coil with annular and upper 2-3/8" rams. Coil up weight 18k. Replace pack-offs and dynamically test. Verify no visible leaks. Continue POOH - Test agitator @ 300' and no vibration noted. OOH - PJSM and prepare to PUD lateral BHA. Pressure undeploy lateral BHA. 50-029-23225-60-00API #: Well Name: Field: County/State: PBW V-120A Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 4/6/2023Spud Date: 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Wednesday, May 3, 2023 9:51 AM To:Brodie Wages Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: V-120 window milling BOP test Attachments:Schlumberger 9 03-25-23 Revised.xlsx Thanks Brodie. Attached is a revised report changing the Number of Failures to 3 and correcting the formatting. Please review and update your copy or let me know if you disagree. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brodie Wages <David.Wages@hilcorp.com> Sent: Wednesday, May 3, 2023 7:23 AM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] RE: V‐120 window milling BOP test Hello Phoebe, Please see attached updated 10‐424 specifying the stripper size as well as the failed valves. The drawing below labels each valve for your reference. We can start including the RU diagram in 10‐424s that we submit when we mill windows with service coil. Please let me know if any further information is needed. PBU V-120PTD 2041790 rig up diagram attached; jbr 3 David “Brodie” Wages Ops Engineer C: 713.380.9836 From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Thursday, April 27, 2023 9:02 AM To: Brodie Wages <David.Wages@hilcorp.com> Subject: [EXTERNAL] RE: V‐120 window milling BOP test I was following up on this email. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Thursday, April 20, 2023 4:43 PM To: Brodie Wages <David.Wages@hilcorp.com> Subject: RE: V‐120 window milling BOP test Brodie, The remarks include the valves downstream failed; which No. Valve(s) failed? The Stripper size was missing; please advise. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 4 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brodie Wages <David.Wages@hilcorp.com> Sent: Tuesday, March 28, 2023 3:58 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Shiloh Wagoner <Shiloh.Wagoner@hilcorp.com> Subject: V‐120 window milling BOP test Mr Regg, Please see attached 10‐424 form for window milling operations performed on V‐120 on 3/24‐23. Please advise if any further information is needed. David “Brodie” Wages Ops Engineer C: 713.380.9836 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Some people who received this message don't often get email from david.wages@hilcorp.com. Learn why this is important 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. SLB CTU9 Rig Up Diagram STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:9 DATE:3/25/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041790 Sundry #322-568 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4000 Annular:Valves:250/3500 MASP:2440 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Other Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 4.06"P Trip Tank NA NA Annular Preventer 0 NA Pit Level Indicators NA NA #1 Rams 1 Blind/Shear P Flow Indicator NA NA #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 1.75" Pipe P H2S Gas Detector P P #4 Rams 1 1.75" Slip P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2.06"P Time/Pressure Test Result HCR Valves 1 2.06"P System Pressure (psi)3000 P Kill Line Valves 2 2.06"P Pressure After Closure (psi)2250 P Check Valve 1 2.0"P 200 psi Attained (sec)2 P BOP Misc 0 NA Full Pressure Attained (sec)8 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):0 NA No. Valves 14 FP ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 20 P Coiled Tubing Only:#2 Rams 18 P Inside Reel valves 1 FP #3 Rams 11 P #4 Rams 12 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:17.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 03/22/23 15:42 Waived By Test Start Date/Time:3/24/2023 10:20 (date)(time)Witness Test Finish Date/Time:3/25/2023 3:50 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Schlumberger Initial weekly BOP test for milling a window and 10' of rat hole with a coiled tubing unit. All downhole work will be fully lubricated. Block valves C12 and C13 downstream of Micro Motion failed during high PT test #1. Greased, re-tested and passed. Inner reel valve (U9) failed during low PT test #6. Greased, re-tested and passed. Diesel used for all pressure tests. Bottle precharge 1250 psi. Dan Johnson Hilcorp Shiloh Wagoner PBU V-120 Test Pressure (psi): Shiloh.wagoner@hilcorp.com Form 10-424 (Revised 08/2022)2023-0325_BOP_SLB9_PBU_V-120        333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov February 8, 2023 Mr. Stan Golis Senior Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-22-034 Notice of Proposed Enforcement – Rescinded Failure to Test BOPE Thunderbird Rig #1 Prudhoe Bay Unit V-120 (PTD 2041790) Dear Mr. Golis: The Alaska Oil and Gas Conservation Commission (AOGCC) issued a Notice of Proposed Enforcement on December 15, 2022, for failure to function-pressure test blowout prevention equipment (BOPE) before the next wellbore reentry after use of that equipment may have compromised its effectiveness (20 AAC 25.285(f)(2)). The BOPE use occurred during a tubing workover using the Thunderbird #1 pulling unit at Prudhoe Bay Unit V-120. Pursuant to 20 AAC 25.535(c), Hilcorp North Slope LLC (Hilcorp) timely requested an informal review of the proposed enforcement action. An informal meeting was held with Hilcorp on January 17, 2023, and Hilcorp followed up with a letter dated January 19, 2023, that summarized the events that occurred relative to the BOPE use. Hilcorp insists that the BOPE use was a planned event to close in the well and circulate out any gas trapped below the production packer. Hilcorp argues that there are “planned, preemptive” reasons for closure of BOPE that commonly occur during well operations that do not trigger testing the used components. Hilcorp also argues that the effectiveness of the BOPE was not compromised during the event in question, as evidenced by the ability to maintain deliberately imposed back-pressure on the choke line and beneath the closed annular preventer with no leaks observed during the circulation. Regarding Hilcorp’s request for clarification on what BOPE use is required to be reported: -AOGCC does not require reporting or testing of BOPE equipment when BOPE is used for circulating or when back pressure is needed on an annulus for working tools, bullheading, etc. -AOGCC does not require reporting or testing of BOPE equipment when BOPE is used for routine use such as closing the blind rams to protect the wellbore from potential dropped objects or for pressure testing. Docket Number: OTH-22-034 Notice of Proposed Enforcement – Rescinded February 8, 2023 Page 2 of 2 -AOGCC does require reporting as provided in Guidance Bulletin 10-003 when the BOPE component(s) integrity may have been compromised. -AOGCC does require reporting as provided in Guidance Bulletin 10-003 when there is unexpected flow from the wellbore and BOPE is utilized. This is not intended nor is it feasible to delineate the reporting obligation for every BOPE use scenario. Based on the information presented by Hilcorp during the informal review and in its letter received January 19, 2023, AOGCC rescinds the Notice of Proposed Enforcement. Should you have any questions about this action please contact Mel Rixse at 907-793-1231 or mel.rixse@alaska.gov. Sincerely, Brett W. Huber, Sr. Jessie L. Chmielowski Gregory C. Wilson Chair, Commissioner Commissioner Commissioner cc: Aras Worthington (aras.worthington@hilcorp.com) Phoebe Brooks Mel Rixse RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.02.06 14:14:31 -09'00' Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.02.07 14:50:59 -09'00' Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 15:11:30 -09'00' Hilcorp Alaska, LLC Aras Worthington Senior Technical Advisor for Alaska Operations 3800 Centerpoint Dr., Suite 1400 Anchorage, Alaska 99503 January 19, 2023 Chairman Brett Huber Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 VIA EMAIL AND CERTIFIED MAIL Subject: Docket Number: OTH-22-034 Notice of Proposed Enforcement Failure to Test BOPE Thunderbird Rig #1 Prudhoe Bay Unit V-120 (PTD 2041790) Dear Chairman Huber, Hilcorp Alaska, LLC (Hilcorp) would like to clarify the record and the sequence of events leading up to this Notice of Proposed Enforcement. Hilcorp requested and participated in an Informal Review of this Notice on Tuesday, January 17, 2023. However, there was not a sufficient quorum of AOGCC personnel at the Informal Conference. Accordingly, Hilcorp presents this written summary of events that occurred on the rig workover at issue. Hilcorp began workover operations on PBU V-120 on October 30, 2022, to prepare the well for a CTD sidetrack planned later in the winter. The main scope of the workover was to upsize the production tubing from 3-1/2” to 4-1/2” for CTD sidetrack purposes. Hilcorp had been in communication with AOGCC regarding the proposal to work on V-120 past the date of October 31st, which was the original deadline date for concluding wellwork with Thunderbird #1 prescribed by Other Order 192. Hilcorp appreciated the AOGCC working with us on the completion of this workover so that the CTD sidetrack could be scheduled later in the winter. The workover was completed on November 4th, 2022. After rigging up and testing blowout preventer equipment (BOPE) on October 31, 2022, the tubing hanger was pulled, releasing the production packer. As part of planned operations, the annular BOPE and TIW valve were closed to preemptively bullhead and/or circulate out potential packer gas which may have been trapped under the packer. This operation was By Samantha Carlisle at 1:20 pm, Jan 19, 2023 completed on November 1, 2022, and some packer gas was noted upon circulation of bottoms- up from the well. Approximately 75 psi of back pressure was deliberately held on the choke line as part of standard procedure for circulating the well out. This standard procedure and precaution is to keep any gas that may be entrained in the circulation fluids from expanding too rapidly and misting into the return tank which in turn could cause a small spill. There was gas noted in the fluid returned from the well, so this was an appropriate precaution, and no spill occurred. The annular and TIW valves were opened after the circulation operation and the rig resumed pulling tubing and the released packer out of the well. On November 1st, 2022, AOGCC Senior Petroleum Engineer Mel Rixse contacted David Wages, the Hilcorp Operations Engineer, indicating that he wanted a BOP closure report as per Industry Guidance Bulletin 10-003 which reads: “AOGCC regulations governing secondary well control equipment and procedures require an operator to report any instance of blowout prevention equipment (BOPE) use to prevent the flow of fluids from a well.” Mr. Wages drafted and e-mailed that report on the same day, November 1st, 2022. The report stated that: “The BOPS were NOT used to control a well control event, the closure was only to allow for pumping operations.” On November 2nd, 2022, Mr. Rixse e-mailed Mr. Wages quoting 20AAC 25.035 (e) (10) (C) “…if any BOP equipment components have been used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using a non- compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;” And Mr. Rixse stated that: “I am missing where Thunderbird tested the annular and TIW valve prior to re-entry.” Mr. Wages responded via e-mail on November 2nd, 2022: “As discussed, please see attached revision to the 10-0003 notification form. We had intended to be explicit about not performing additional BOPE testing but I wasn’t clear in the first draft that I had sent yesterday. Please advise of your guidance on this.” The attached revision to Mr. Wages’ email contained the following verbiage highlighted in yellow under “Actions Taken/To be Taken” “We are not planning to re-test BOPE because we did not close the annular to control flowing fluids from the well. The annular was closed preemptively to facilitate removal of potential packer gas from the wellbore.” To the best of our knowledge, no response to this email was received. On December 21, 2022, Hilcorp received the Notice of Proposed Enforcement via certified mail. Hilcorp believes that the annular and TIW did not need to be re-tested because they had not been used for well control purposes and that use of the equipment did not compromise the equipment’s effectiveness since it was closed on pipe that it was designed to close on. The 75 psi of back-pressure deliberately held on the choke line was also exerted underneath the annular BOPE and the BOPE did not leak during the circulation so there was no reason to believe it was not in serviceable condition, and in fact had effectively just passed another low- pressure test while pumping. It is also worth noting that this all occurred only one day after the full BOPE test upon rig up on the well. This initial test witness was waived by AOGCC Inspector Austin McLeod. Hilcorp respectfully asserts that a planned event using the BOPE as a means to close in the well and force circulation either by bullheading or circulating out the choke line does not compromise the BOPE effectiveness. Hilcorp also notes that BOPE is commonly used to close in the well for other reasons such as closing the blind rams to prevent dropped tools from falling into the wellbore or closing the pipe rams or annular BOPE for casing pressure tests. Hilcorp does not re-test immediately after use of BOPE in cases like these unless we have a reason to believe the BOPE have been compromised (e.g. visible leak, visible damage, or closing the BOPE on something it is not designed to be closed on). None of these indications were present when we used the BOPE on V-120. Hilcorp requests that AOGCC clarify this issue, so we are in compliance with AOGCC’s interpretations of when BOPE need to be re-tested. We would propose that any planned, preemptive closure of the BOPE should not trigger a re-test unless there are reasons to believe the BOPE have been compromised per the above. Hilcorp encourages the AOGCC to dialogue with other operators on the North Slope as they may share Hilcorp’s interpretation. Hilcorp appreciates the Commission’s consideration of this issue, and we look forward to your guidance and direction. Hilcorp respectfully requests that this NOV be withdrawn given the lack of clarity surrounding this event. Sincerely, Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643), ou=Users Date: 2023.01.19 13:09:23 -09'00' Aras Worthington (4643) Aras Worthington Senior Technical Advisor for Alaska Operations, PE Hilcorp Alaska, LLC Hilcorp Alaska, LLC Aras Worthington SeniorTechnical Advisor for Alaska Operations 3800 Centerpoint Dr., Suite 1400 Anchorage, Alaska 99503 January 10, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 VIA EMAIL AND CERTIFIED MAIL Subject: Docket No: OTH-22-034 Notice of Proposed Enforcement Failure to Test BOPE Thunderbird Rig #1 Prudhoe Bay Unit V-120 (PTD 2041790) Dear Commissioner Chmielowski, Hilcorp Alaska, LLC (Hilcorp) received the referenced Notice of Proposed Enforcement letter via certified mail on December 21, 2022. As per email sent by Hilcorp to Mel Rixse on December 28th, 2022, Hilcorp requested an informal review of this Notice of Proposed Enforcement. Mr. Rixse acknowledged receipt of this email on December 29th, 2022. We look forward to meeting to discuss the particulars of this Notice of Proposed Enforcement at your convenience. Sincerely, Aras Worthington Senior Technical Advisor for Alaska Operations, PE Hilcorp Alaska, LLC Phone: 1-907-564-4763 Mobile: 1-907-440-7692 Email: Aras.Worthington@Hilcorp .com Cc: Mel Rixse James Regg Stan Golis Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643), ou=Users Date: 2023.01.10 15:32:01 -09'00' Aras Worthington (4643) 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 15, 2022 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 9693 Mr. Stan Golis Senior Operations Manager Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-22-034 Notice of Proposed Enforcement Failure to Test BOPE Thunderbird Rig #1 Prudhoe Bay Unit V-120 (PTD 2041790) Dear Mr. Golis: Pursuant to 20 AAC 25.535, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby notifies Hilcorp North Slope, LLC (Hilcorp) of a proposed enforcement action. Nature of the Apparent Violation or Noncompliance (20 AAC 25.535(b)(1)). Hilcorp failed to comply with 20 AAC 25.285(f)(2). Basis for Finding the Violation or Noncompliance (20 AAC 25.535(b)(2)). Hilcorp performed workover operations on Prudhoe Bay Unit Well V-120 between October 31 and November 4, 2022, pursuant to sundry permit 322-469, approved on August 18, 2022. The workover was performed with Thunderbird Rig #1. Blowout prevention equipment (BOPE) was function pressure-tested to 3000 psi on October 31, 2022. Decompletion operations commenced with the tubing hanger pulled to the rig floor. Hilcorp reports that the annular preventer and floor safety valve were closed at 10:20 pm on October 31, 2022. Fluids were then pumped down the inner annulus (IA) to displace gas into the perforations and prevent the flow of fluids from the well. Circulation through the rig choke equipment was performed with 75 psi on the choke. Two wellbore volumes of fluid were circulated to ensure the gas was evacuated from the well. Normal operations were resumed without first function pressure-testing the BOPE annular. Workover operations continued on well V-120 until Thunderbird Rig #1 was shut down for the winter on November 4, 2022. Failing to function pressure-test the BOPE before the next wellbore entry after use of that equipment may have compromised its effectiveness and is a violation of 20 AAC 25.285(f)(2). Docket Number: OTH-22-034 Notice of Proposed Enforcement December 15, 2022 Page 2 of 3 Proposed Action (20 AAC 25.535(b)(3)). For this violation, the AOGCC intends to impose a civil penalty on Hilcorp under AS 31.05.150 in the amount of $34,000.1 In addition to the imposed civil penalty, Hilcorp will be requested to provide AOGCC with the following: - a copy of the written management of change procedure(s) that correct the violation; and - a detailed written explanation that describes how recurrence of the violation will be prevented. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. Rights and Liabilities (20 AAC 25.535(b)(4)). Within 15 days after receipt of this notification – unless the AOGCC, in its discretion, grants an extension for good cause shown – Hilcorp may file with the AOGCC a written response that concurs in whole or in part with the proposed action described herein, requests informal review, or requests a hearing under 20 AAC 25.540. If a timely response is not filed, the proposed action will be deemed accepted by default. If informal review is requested, the AOGCC will provide Hilcorp an opportunity to submit documentary material and make a written or oral statement. If Hilcorp disagrees with the AOGCC’s proposed decision or order after that review, it may file a written request for a hearing within 10 days after the proposed decision or order is issued. If such a request is not filed within that 10-day period, the proposed decision or order will become final on the 11th day after it was issued. If such a request is timely filed, the AOGCC will hold its decision in abeyance and schedule a hearing. If Hilcorp does not concur in the proposed action described herein, and the AOGCC finds that Hilcorp violated a provision of AS 31.05, 20 AAC 25, or an AOGCC order, permit or other approval, then the AOGCC may take any action authorized by the applicable law including ordering one or more of the following: (i) corrective action; (ii) suspension or revocation of a permit or other approval; and (iii) imposition of penalties under AS 31.05.150. In taking action after an informal review or hearing, the AOGCC is not limited to ordering the proposed action described herein, as long as Hilcorp received reasonable notice and opportunity to be heard with respect to the AOGCC’s action. Any action described herein or taken after an informal review or hearing does not limit the action the AOGCC may take under AS 31.05.160. Questions regarding this notice should be directed to Mel Rixse at 907-793-1231. 1 AS 31.05.150(g) requires AOGCC to consider nine criteria in setting the amount of a civil penalty. Proposed penalty amount is $25,000 for the initial violation and $3,000 per day for the 3 days well operations continued without testing the BOPE used for well control or equivalent purposes, or that use may have compromised the used equipment’s effectiveness. Docket Number: OTH-22-034 Notice of Proposed Enforcement December 15, 2022 Page 3 of 3 Sincerely, Jessie L. Chmielowski Commissioner cc: Aras Worthington (Hilcorp) Phoebe Brooks James Regg Mel Rixse Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.15 09:16:26 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-120 PRUDHOE BAY UN BORE V-120 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 V-120 50-029-23225-00-00 204-179-0 W SPT 6494 2041790 1624 876 879 875 874 28 37 37 37 INITAL P Brian Bixby 12/17/2022 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UN BORE V-120 Inspection Date: Tubing OA Packer Depth 556 2018 1989 1985IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB221217152652 BBL Pumped:1.4 BBL Returned:1.4 Thursday, January 26, 2023 Page 1 of 1 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Sunday, December 4, 2022 4:09 PM To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC) Cc:Oliver Sternicki Subject:Hilcorp (PBU) November 2022 MIT forms Attachments:NOV 2022.zip All, Attached are the completed AOGCC MIT forms for the tests completed by Hilcorp in November 2022. Well: PTD: Notes: 14‐14 1811020 MIT‐T per Sundry #322‐240 A‐17A 206125 4‐year MIT‐IA M‐205 2221270 Initial MIT‐T, MIT‐IA & MIT‐OA NK‐25 1970680 4‐year MIT‐IA P‐10A 2150660 2‐year MIT‐IA per AA AIO 3.030 PSI‐06 2020790 4‐year MIT‐IA V‐120 2041790 MIT‐T & MIT‐IA per Sundry #322‐568 Z‐25 1881590 MIT‐IA for AA Application Z‐34 2120610 MIT‐T & MIT‐IA per Sundry #322‐277 Z‐34 2120610 Initial MIT‐IA per Sundry #322‐277 Z‐223 2220800 Initial MIT‐IA Please reply with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity Rayn.holt@hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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ubmit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2041790 Type Inj N Tubing 0 3650 3610 3600 Type Test P Packer TVD 6479 BBL Pump 2.6 IA 0 0 0 0 Interval O Test psi 1620 BBL Return 2.5 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2041790 Type Inj N Tubing 2000 2800 2800 2800 Type Test P Packer TVD 6479 BBL Pump 2.0 IA 0 3630 3610 3605 Interval O Test psi 1620 BBL Return 2.0 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:AOGCC Rep Kam St.John waived witness rig MIT-IA RWO sundry 322-568 Notes: Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / V Pad Anthony Knowles 11/04/22 Notes:AOGCC Rep Kam St.John waived witness rig MIT-T RWO sundry 322-568 Notes: Notes: Notes: V-120 V-120 Form 10-426 (Revised 01/2017)2022-1104_MIT_PBU_V-120_2tests                J. Regg; 4/13/2023 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Thursday, November 17, 2022 9:50 AM To:PB Wells RWO WSS Cc:Regg, James B (OGC) Subject:RE: Thunderbird 1 10-424 10/31/2022 Attachments:Hilcorp Thunderbird 1 10-31-22 Revised.xlsx; Hilcorp Thunderbird 1 10-05-22 Revised.xlsx Daniel, Attached is a revised report replacing the test result from the #3 Rams to “NA” based on the quantity 0 and adding 3 to the # of Ntgn. Bottles (same revision on the 10‐05‐22 report attached). Please update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Sent: Monday, October 31, 2022 5:02 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: PB Wells RWO WSS <PBWellsRWOWSS@hilcorp.com> Subject: Thunderbird 1 10‐424 10/31/2022 Phoebe, Attached is the BOP test from Hilcorp Thunderbird Rig 1 on GPB V‐120 Thank you, Daniel Scarpella Hilcorp North Slope LLC., Alaska | Sr. Well Site Supervisor | PBU Wells Team 907.230.2692 cell | 907.659.5580 office | H 2154 | alt. Anthony Knowles Well Interventions: daniel.scarpella@hilcorp.com Rig Operations: pbwellsrwowss@hilcorp.com P.O. Box 340067| DP PBOC 38 | PBOC 20| Prudhoe Bay, AK 99734 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. PBU V-120 PTD 2041790) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:Thunderbird 1 DATE:10/31/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041790 Sundry #322-469 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2413 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Other Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" x 5M FP Pit Level Indicators P P #1 Rams 1 2 7/8x5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 1 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 3 3 1/8"P Pressure After Closure (psi)1400 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 0 NA Full Pressure Attained (sec)145 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):3@2150 P No. Valves 8 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 16 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:4.0 HCR Choke 3 P Repair or replacement of equipment will be made within 0 days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/30/2022 00:10 Waived By Test Start Date/Time:10/31/2022 9:30 (date)(time)Witness Test Finish Date/Time:10/31/2022 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Test Fluid is 50/50 methonal/water mix. Tested with 2 7/8" and 4 1/2" test mandrels. Test one passed the low test of 250 psi, then on way to the high the Annular started leaking. Cycled bag and passed the High Test of 3000 psi. Brandon Stiffler Hilcorp Alaska LLC. Daniel Scarpella PBU V-120 Test Pressure (psi): bstiffler@thunderbirdfs.com pbrwowss@hilcorp.com Form 10-424 (Revised 08/2022)2022-1031_BOP_Hilcorp_Thunderbird1_PBU_V-120 ==========North Slope LLC             J. Regg; 12/27/2022 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector V-120 (PTD #204179) RWO complete Date:Tuesday, November 8, 2022 8:54:49 AM Attachments:MIT PBU V-120A 11-04-22.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, November 7, 2022 9:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector V-120 (PTD #204179) RWO complete Mr. Wallace, Injector V-120 (PTD #204179) RWO is complete. AOGCC waived witness rig MIT-T and MIT-IA (see attached 10-426) passed on 11/04/22. At this time, the well is classified as OPERABLE. Online AOGCC witnessed MIT-IA will be performed once the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Saturday, September 3, 2022 9:20 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector V-120 (PTD #204179) Tubing Cut pre-Rig Mr. Wallace, Injector V-120 (PTD #204179) had the tubing cut on 09/02/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2041790 Type Inj N Tubing 0 3650 3610 3600 Type Test P Packer TVD 6479 BBL Pump 2.6 IA 0 0 0 0 Interval O Test psi 1620 BBL Return 2.5 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2041790 Type Inj N Tubing 2000 2800 2800 2800 Type Test P Packer TVD 6479 BBL Pump 2.0 IA 0 3630 3610 3605 Interval O Test psi 1620 BBL Return 2.0 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:AOGCC Rep Kam St.John waived witness rig MIT-IA RWO sundry 322-568 Notes: Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / V Pad Anthony Knowles 11/04/22 Notes:AOGCC Rep Kam St.John waived witness rig MIT-T RWO sundry 322-568 Notes: Notes: Notes: V-120 V-120 Form 10-426 (Revised 01/2017)MIT PBU V-120A 11-04-22 (002) 1RQH 1RQH By Samantha Carlisle at 8:52 am, Sep 23, 2022 'LJLWDOO\VLJQHGE\7UHYRU+\DWW '1FQ 7UHYRU+\DWW RX 8VHUV 'DWH 7UHYRU+\DWW '65 %23(WHVWWRSVL 9DULDQFHWR$$&L$OWHUQDWHSOXJSODFHPHQWDSSURYHG 0*52&76)'*&: Jessie L. Chmielowski Digitally signed by Jessie L. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector V-120 (PTD #204179) Tubing Cut pre-Rig Date:Tuesday, September 6, 2022 3:23:17 PM From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Saturday, September 3, 2022 9:20 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector V-120 (PTD #204179) Tubing Cut pre-Rig Mr. Wallace, Injector V-120 (PTD #204179) had the tubing cut on 09/02/22 in preparation for the upcoming Rig. The well will now be classified as NOT OPERABLE until it has competent production tubing. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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dŚĞWƌĞŵŝĞƌƉĂĐŬĞƌŝƐĐƵƚƚŽƌĞůĞĂƐĞ ď͘ dŚĞǁŝŶĚŽǁŝƐ Ϯϭ͟ůŽŶŐƐƚĂƌƚŝŶŐϭϳ͟ĨƌŽŵƚŚĞƚŽƉŽĨƚŚĞƉŝŶƚŚ ƌĞĂĚƐ͕ƐĞĞĚƌĂǁŝŶŐĂƚƚĂĐŚĞĚ Đ͘ ŽŶƚĂĐƚK ƌŽĚŝĞtĂŐĞƐϭ;ϳϭϯͿϯϴϬͲϵϴϯϲ Žƌ tǇĂƚƚZŝǀĂƌĚϭ;ϱϬϵͿϲϳϬͲϴϬϬϭ ƉƌŝŽƌƚŽĐƵƚĨŽƌ ĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞŝŶ͘ Ě͘ ŽƌƌĞůĂƚĞƚŽdƵďŝŶŐdĂůůǇĚĂƚĞĚ ϯͬϭϵͬϮϬϬϱ͘ ϭϬ͘ ZDKůŝŶĞ͘ WƌĞͲZtKΎEŽƚĞ͗ĞƉĞŶĚŝŶŐŽŶƚŝŵŝŶŐŽĨƌŝŐŵŽǀĞ͕ǁĞůůŬŝůůĂŶĚKWŝŶƐƚĂůůĂƚŝŽŶƐƚĞƉƐŵĂǇďĞƉĞƌĨŽƌŵĞĚŽŶƌŝŐ ƌĂƚŚĞƌƚŚĂŶƉƌĞͲƌŝŐ͘ dŚĞǁĞůůǁŝůůďĞƐŚƵƚŝŶΕϭŵŽŶƚŚƉƌŝŽƌƚŽǁŽƌŬŽǀĞƌ͕ƚŚŝƐǁŝůůŐŝǀĞƚŚĞƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞŽŶƚŚŝƐŝŶũĞĐƚŽƌƚŝŵĞƚŽ ĨĂůůŽĨĨĂůŝƚƚůĞďŝƚǁŚŝĐŚǁŝůůĂůůŽǁƵƐƚŽƌĞĚƵĐĞ<t&ĚĞŶƐŝƚǇ ͘ϵ͘ϬƉƉŐŝƐƚŚĞŵĂǆĞǆƉĞĐƚĞĚ<t&ĚĞŶƐŝƚǇ͘ ϭϭ͘ ^ƉŽƚWƵŵƉdƌƵĐŬ͕ZhĂŶĚWd͘ ϭϮ͘ ŝƌĐƵůĂƚĞ ŝŶ ĂƚůĞĂƐƚ ϯϴϬ ďďůƐ ŽĨ ϭϬ͘Ϭ ƉƉŐ ďƌŝŶĞ ƚŚƌŽƵŐŚ ƚƵďŝŶŐ ƉƵŶĐŚŚŽůĞƐ Ă͘ ϭϬƉƉŐŶĞĞĚĞĚǁŚĞŶĨƌĞĞǌĞƉƌŽƚĞĐƚŝŶƚŚĞǁĞůů ď͘ ŶŶƵůĂƌsŽůƵŵĞƚŽƉƵŶĐŚŚŽůĞƐ͗ϮϳϵďďůƐ Đ͘ dƵďŝŶŐsŽůƵŵĞƚŽƉƵŶĐŚŚŽůĞƐ͗ϵϮďďůƐ Ě͘ dŽƚĂůǀŽůƵŵĞƚŽƉƵŶĐŚŚŽůĞƐ͗ϯϳϭďďůƐ Ğ͘ sŽůƵŵĞĨƌŽŵƉƵŶĐŚŚŽůĞƐƚŽďŽƚƚŽŵƉĞƌĨ͗ϯďďůƐ ϭϯ͘ ŝƌĐƵůĂƚĞŝŶ Εϴϴ ďďůƐ;ΕϮϱϬϬĨƚͿĨƌĞĞǌĞƉƌŽƚĞĐƚ Ă͘ ůůŽǁƚƵďŝŶŐĂŶĚ/ƚŽh ƚƵďĞ͘ ϭϰ͘ ZDK ƉƵŵƉĞƌƐ ϭϱ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞůů͘ ϭϲ͘ 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ƚƵďŝŶŐĐƵƚ ŝŶĐƵƚǁŝŶĚŽǁ͕ĚŝƐĐƵƐƐǁŝƚŚK͘ Ϯϯ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞ ϯͲϭͬϮ͟ƚƵďŝŶŐ͘ Ϯϰ͘ WhŶĞǁ >ͲϴϬ ϰͲϭͬϮ͟ĐŽŵƉůĞƚŝŽŶ ĂŶĚƌƵŶƉĞƌ sͲϭϮϬ WƌŽƉŽƐĞĚŽŵƉůĞƚŝŽŶZƵŶŶŝŶŐKƌĚĞƌ͘ Ă͘ >ŽĂĚ/ǁŝƚŚŝŶŚŝďŝƚĞĚ<t&ďƌŝŶĞ ď͘ >ĂŶĚƚƵďŝŶŐǁŝƚŚŵƵůĞƐŚŽĞͬt>'ΛΕϭϬ͕ϳϮϱ͛ Ă͘ WĂĐŬĞƌŵƵƐƚďĞǁŝƚŚŝŶϮϬϬ͛ŽĨƚŽƉƉĞƌĨ͘ Đ͘ ŶƐƵƌĞZ,ƉůƵŐďŽĚǇƉƌĞͲŝŶƐƚĂůůĞĚŝŶůŽǁĞƌŵŽƐƚyƉƌŽĨŝůĞ Ϯϱ͘ >ĂŶĚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚ Z/>^͘ >ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘EŽƚ Ğ WŝĐŬͲƵƉĂŶĚƐůĂĐŬͲŽĨĨ ǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ Ϯϲ͘ ƌŽƉďĂůůĂŶĚƌŽĚĂŶĚŚǇĚƌĂƵůŝĐĂůůǇƐĞƚƚŚĞƉĂĐŬĞƌƉĞƌŵĂŶƵĨĂĐƚƵƌĞƌ͛ƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ Ă͘ ŽŶĚƵĐƚD/dͲdƚŽ ϯϱϬϬ ƉƐŝĂŶĚD/dͲ/ƚŽ ϯ͕ϬϬϬƉƐŝĨŽƌϯϬ ŵŝŶƐ;ĐŚĂƌƚĞĚ͕ƐƚĂƚĞǁŝƚŶĞƐƐĞĚͿ Ϯϳ͘ ^ŚĞĂƌĐŝƌĐǀĂůǀĞŝŶƐŚĂůůŽǁ'>DĂŶĚĐŝƌĐĨƌĞĞǌĞƉƌŽƚĞĐƚ͘ Ϯϴ͘ ůĞĞĚƚƵďŝŶŐƉƌĞƐƐƵƌĞďĂĐŬƚŽΕϬƉƐŝ͘ ^Ğƚ WsǁŝƚŚ dt ŝŶƐĞƌƚ͘ Ϯϵ͘ ZDK dŚƵŶĚĞƌďŝƌĚtKZŝŐ ĂŶĚĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚ͘ DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϯϬ͘ ZhĐƌĂŶĞ͘EKW͘ ϯϭ͘ EhƚŚĞƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂŶĚƚƌĞĞ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚĂŶĚƚƌĞĞƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϯϮ͘ WƵůů WsǁŝƚŚ dt ŝŶƐĞƌƚ͘ ϯϯ͘ ZĞƉůĂĐĞ ǁĞůůŚŽƵƐĞĂŶĚ ŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ ^ůŝĐŬůŝŶĞ ϯϰ͘ ^ƉŽƚ^ůŝĐŬůŝŶĞƵŶŝƚ͕ZhĂŶĚWd͘ ϯϱ͘ Z/,ĂŶĚƉƵůů Z,ƉůƵŐĨƌŽŵ yƉƌŽĨŝůĞĂƚцϴϲϴϬ͛D ϯϲ͘ ZDK ĂŶĚƚƵƌŶǁĞůůŽǀĞƌ ƚŽŽƉĞƌĂƚŝŽŶƐ͘ ;ĐŚĂƌƚĞĚ͕ƐƚĂƚĞǁŝƚŶĞƐƐĞĚͿ KRXUQRWLFH d' ŚĂŶŐĞͲKƵƚ tĞůů͗ sͲϭϮϬ Wd͗ϮϬϰͲϭϳϵ KƉĞƌĂƚŝŽŶƐ ϯϳ͘ KďƚĂŝŶK'ǁŝƚŶĞƐƐĞĚ^s^ƚĞƐƚǁŝƚŚŝŶϱĚĂǇƐŽĨƉƵƚƚŝŶŐǁĞůůŽŶůŝŶĞ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ WĂĐŬĞƌƵƚŽŶĞ^ĐŚĞŵĂƚŝĐ ϰ͘ KW^ĐŚĞŵĂƚŝĐ ϱ͘ ^ƵŶĚƌǇ ŚĂŶŐĞ&Žƌŵ d' ŚĂŶŐĞͲKƵƚ tĞůů͗ sͲϭϮϬ Wd͗ϮϬϰͲϭϳϵ d' ŚĂŶŐĞͲKƵƚ tĞůů͗ sͲϭϮϬ Wd͗ϮϬϰͲϭϳϵ d' ŚĂŶŐĞͲKƵƚ tĞůů͗ sͲϭϮϬ Wd͗ϮϬϰͲϭϳϵ sͲϭϮϬƵƚƚŽƌĞůĞĂƐĞƉĂĐŬĞƌ/ŶĨŽ d' ŚĂŶŐĞͲKƵƚ tĞůů͗ sͲϭϮϬ Wd͗ϮϬϰͲϭϳϵ +LOFRUS 1RUWK6ORSH//&+LOFRUS 1RUWK6ORSH//&Changes to Approved Rig Work Over Sundry Procedure'DWH 6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO 96XQGU\ $Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ &KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKH ULJ ZRUNRYHU5:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH-XO\ MEMORANDUM TO: Jim Regg -Z P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 10, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-120 PRUDHOE BAY UN BORE V-120 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN BORE V-120 API Well Number 50-029-23225-00-00 Inspector Name: Matt Herrera Permit Number: 204-179-0 Inspection Date: 12/7/2020 Insp Num: mitMFH2O1208160334 Rel Insp Num: Packer Depth Well I V-120 1Type Inj w TVD I 6494 Tubing PTD 2041790 ��Type Test, SPT iTest psi 1624 IA T -- BBL Pumped: ed: avRTST ,BBL Returned: 2 OA — Int p 3.1 rp Notes: MIT -IA Performed to 2000 PSI per Operator Pretest Initial 15 Min 30 Min 45 Min 60 Min 950 9"951 _ 951 606 2008 1962 1953 118 133 - 140 141 -- — — Thursday, December 10, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ‘---- e,,? /z I-Z (( DATE: Wednesday,December 07,2016 P.I.Supervisor �lj SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-120 FROM: Bob Noble PRUDHOE BAY UN BORE V-120 Petroleum Inspector Src: Inspector Reviewed By:T�� P.I.Supry I!(Z_ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-120 API Well Number 50-029-23225-00-00 Inspector Name: Bob Noble Permit Number: 204-179-0 Inspection Date: 12/4/2016 Insp Num: mitRCNI61204155312 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-120 ' Type Inj W 'TVD 6494 Tubing 1171 1169 - 1172_ 1173 - PTD 2041790 ' Type Test SPT Test psi 1624 IA 1 364 1889 - 1837 1830 Interval 4YRTST P/F P ✓ OA 233 - 257 - 264 - 264 - Notes: SCANNED APR 0 0 2U17. Wednesday,December 07,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 18, 2012 TO: Jim Regg i P.I. Supervisor r' l �' t1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -120 FROM: Lou Grimaldi PRUDHOE BAY UN BORE V -120 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V - 120 API Well Number 50 - 029 - 23225 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 204 - 179 - Inspection Date: 12/16/2012 Insp Num: mitLG121216131239 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well v -120 ' ( Type Inj G ' TVD 6494 - IA 383 1784 i 1752 1742 • PTD 2041790 " Type Test SPT Test psi 1623 • OA 129 - 131 I 133 133 - Interval 4YRTST _ P/F I P - Tubing 2366 , 2369 2365 2365 ' Notes: 2 Bbl's pumped, 2 Bbl's returned. Good solid test. NNEp NPR 112D13 SCA Tuesday, December 18, 2012 Page 1 of 1 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~ r,~~ August 14, 2009 ~.~~'~~~~~'"~ ,~y ~ 1? ~ ~~" ~~~ ~ ~ bp ~~VE~~~~ ocT ~ ~ zoo~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Al~lta ~il & Gas Cons. Gammi~einn Anchcr~pe ~,b~ ~' t ~~' ~- ~ a. c~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger 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) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 025 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7l12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 5002923o83ot00 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780t00 NA 2.5 NA 34 6l30l2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA t2.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA t3.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-21o 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ",-'~^ 2080200 50029233830000 NA 1.75 NA ~b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 MEMORANDUM To~ Jim Regg P.I. Supervisor I~Z~ ~ ~' I ~~~ FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January O5, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-120 PRUDHOE BAY UN BORE V-120 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.' lbie--- Comm Well Name: PRUDHOE BAY UN BORE V-120 Insp Num' mitJJ08 1 2301 0 1 645 Rel Insp Num: API Well Number' S0-029-23225-00-00 Permit Number: 204-179-0 ./ Inspector Name' Jeff Jones Inspection Date: 12i29i2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ V-120 ~i~TypC III]. ~ w ~ T~ ~ 6494 ~ IA ~ 800 , 4000 i~ 3920 3900 /~ : P.T. ~I 2041790 TypeTeSt ~, SPT ~I TOSt pSl 1623.5 ~ QA ~,' -T - 260 380 --i--t----- 380 j 380 j~ Interval 4YRTST P~' P Tubing' 1400 7380 --F- ~ 1400 7400 Notes' 4.2 BBLS methanol pumped. 1 well inspected; no exceptions noted. ~ Monday, January O5, 2009 Page l of I 1 " rvt.~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2041790 Well Name/No. PRUDHOE BAY UN BORE V-120 Operator BP EXPLORATION (ALASKA) INC SI'...J.. l' Jit ~ ~ API No. 50-029-23225-00-00 MD 11140 TVD 6996 Completion Date 4/12/2005 Completion Status WAGIN Current Status WAGIN UIC Y ~._--- ---_.._,-----~-~ ---~~--_._--,.~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes - --~~~_. ----_.~--~._- -----~~_.~ DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR, MWD 1 GR 1 PWD, MWD 1 GR 1 RES 1 DEN 1 NEU 1 PWD, Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval OH/ " Start Stop CH Received Comments 0 11140 10/20/2004 -"I 0 11140 1 0/20/2004 4352 11000 Case 2/11/2005 TEMP LOG/GRlCCL 4352 11000 Case 2/11/2005 USIT/GRlCCL 0 11140 Open 10/4/2006 ~CDR, Density, Neutron 27 -Sep-2006 0 11140 Open 10/4/2006 TVD COR, Density, -r:ëUtron 27-Sep-2006 i 0 0 Open 10/4/2006 ROP,GR,DRHO,NP~ w/Graphics -~ ..-- Log/ Electr Data Digital Dataset S' Mool~~t Number Name o 0 Asc Directional Survey pt Directional Survey og Temperature ¥og Cement Evaluation 'k" 14158 Density og 14158 Density ~ C Lis 14158 I nduction/Resistivity Well Cores/Samples Information: Log Log Run Scale Media No 5 Blu 5 Col 25 Blu ~1) 25 Blu ì"b Name Interval Start Stop Sent Received Sample Set Number Comments - ADDITIONAL INFORMA~ON Well Cored? Y Ifr:¡) Chips Received? ~ Analysis ~ Received? Daily History Received? ~ Formation Tops c:1. N _.~~~- Comments: ~"~~-~- DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2041790 Well Name/No. PRUDHOE BAY UN BORE V-120 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23225-00-00 MD 11140 TVD 6_9._9_6_~_c_oiro:...._.tio_n Date 4/12/2005 Compliance Reviewed By: . ~. Completion Status WAGIN Current Status WAGIN UIC Y Date: a, 3_~ <.J..t7 e - 10/02106 SclJlumberger NO. 3985 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Borealis Well Job# Log Description Oate BL Color co V·120 40010983 OH EOIT OF MWO/LWD 09/27/04 2 1 V·115 40010304 OH EOIT OF MWD/LWO 03/31/04 6 1 V·115PB1 40010304 OH EOIT OF MWO/LWO 03/24/04 6 1 V-202 L1 40009877 OH EOIT OF MWD/LWO 11/30/03 2 1 V·202 L2 40009877 OH EOIT OF MWO/LWO 12/06/03 2 1 1·100 40013292 OH EOIT OF MWO/LWO 04/13/06 2 1 1·100PB1 40013292 OH EOIT OF MWO/LWO 04/05/06 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANO RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. PetroteChnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Date Delivered: Received by: . RECEIVED tJI~ dO~/-110 d )L.1J5ð OCT 0 4 2006 ~ 011 & Gas Cons. Commission Anchcrage ~_.t . STATE OF ALASKA a ALASKA AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG " t~ (þ 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended IBI WAG 1b. Well Class:/·.(!fh~j FFt 20AAC 25.105 20AAC 25.110 o Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic IBI Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/12/2005 204-179 304-367 / 305-029 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/19/2004 50- 029-23225-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/26/2004 PBU V-120 4897' NSL, 1547'WEL, SEC. 11, T11N, R11E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1000' NSL, 2487' EWL, SEC. 36, T12N, R11E, UM 82.1' Prudhoe Bay Field 1 Borealis Pool Total Depth: 9. Plug Back Depth (MD+TVD) 1115' NSL, 2561' EWL, SEC. 36, T12N, R11E, UM 11037 + 6899 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 590753 y- 5970146 Zone- ASP4 11140 + 6996 Ft ADL 028238 TPI: x- 594700 y- 5976858 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 594773 y- 5976975 Zone- ASP4 (Nipple) 2264' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes DNo NIA MSL 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR 1 PWD, MWD I GR / RES / DEN / NEU / PWD, US IT 22. (.;ASING, LINER AND CEMENTING RECORD CASING WT. PERFT, .~ETTI\!>[)t=F>TH !\AD SETTING DEPTH TVÞ ~?Z~ i i...,."......... SIZE GRADE ·iIQP. IJ:SOTTOM Top BOTTOM RECORD 20" 94# H-40 29' 109' 29' 109' 42" 1260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 4110' 28' 2722' 12-1/4" 649 sx AS Lite, 291 sx Class 'G' 7" 26# L-80 26' 11122' 26' 6978' 8-3/4" 286 sx Class 'G', 159 sx Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24. i ·i "ii Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 3-1/2", 9.2#, L-80 10715' 10601' MD TVD MD TVD 10778' - 10864' 6660' - 6739' 25.. ACID,. FRACTURE, CEME~"§~YE~E,~~8¡ ¡ 10940' - 10968' 6809' - 6835' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): May 16, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BSL GAs-McF WATER-BSL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFl JUN 1 4 2005 r'\nlrl\\! i\ I (Dr Form 10-407 Revised 12/2003 CONTI' I D. RMR~J $IdE ' ....... Revi$ed:. .06l08t9~¡ Put C?I"!., Injection ,.,..,).".\./ <..".". ",.\ ".'>''''''.'<: .,.._"',;1';;'",<. \.;c!j;:,<,·....:.>.......,_..... 28. t GEOLOGIC MARKERS 29. RMA TION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4532' Ugnu M Sands 7047' Schrader Bluff N Sands 7561' Schrader Bluff 0 Sands 7898' Base Schrader 1 Top Colville 8703' HRZ 10492' Kalubik 10693' Kuparuk C 10777' Kuparuk B 10969' 2930' None 4157' 4408' 4570' 4971' 6393' 6580' 6659' 6836' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date O~/08Ios PBU V-120 Well Number Prepared By Name/Number: Drilling Engineer .. Terrie Hubb/e, 564-4628 Shane Gagliardi, 564-5251 204-179 304-367/305-029 Permit No.1 A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg "V. J I P.I. Supervisor N.?f? 0t {4/ D'5" DATE: Tuesday, May 31,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-120 PRUDHOE BAY UN BORE V-120 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :sBf-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-l20 Insp Num: mitLG05053011285I ReI Insp Num: API Well Number: 50-029-23225-00-00 Permit Number: 204-179-0 Inspector Name: LOll Grimaldi Inspection Date: 5/30/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! V-120 :Type Inj. i w j TVD I 6496 I IA j 420 3000 I 2910 I 2900 i I I i P.T. i 2041790 !TypeTest i SPI i Test psi I 1624 i OA ! 390 510 ! 490 i 490 I i I Interval INIIAL P/F P Tubing I 2370 2370 I 2370 i 2370 ! I ¡ Notes: Good test, 3.1 bbl's pumped. Tuesday, May 31, 2005 Page 1 of 1 _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COM SiaN WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED MAY 1 2 Z005 Alaska Oil & GIJS COilS. Commission 1 a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended 181 WAG 1 b. Well Clas . 101ft; 20AAC 25.105 20AAC 25.110 o Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/12/2005 204-179 304-367 I 305-029 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/19/2004 50- 029-23225-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/26/2004 PBU V-120 4897' NSL, 1547' WEL, SEC. 11, T11 N, R11 E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1000' NSL, 2487' EWL, SEC. 36, T12N, R11E, UM 82.1' Prudhoe Bay Field / Borealis Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1115' NSL, 2561' EWL, SEC. 36, T12N, R11E, UM 11037 + 6899 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: x- 590753 y- 5970146 Zone- ASP4 11140 + 6996 Ft ADL 028238 TPI: x- 594700 y- 5976858 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 594773 y- 5976975 Zone- ASP4 (Nipple) 2264' MD Mu .. .. -- ---. _._h_ 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo NI A MSL 1900' (Approx.) 21. Logs Run: MWD I GR, MWD I GR / PWD, MWD / GR / RES I DEN I NEU / PWD, USIT 2. CASING, LINER AND CEMENTING RECORD CASING :SETTING UEPTH MO :SETTING UEPTH TVO HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING. RECORD PULLED 20" 94# H-40 29' 109' 29' 109' 42" 260 sx Arctic Set (ADDrox.) 9-5/8" 40# L-80 28' 4110' 28' 2722' 12-1/4" 649 sx AS Lite, 291 sx Class 'G' 7" 26# L-80 26' 11122' 26' 6978' 8-3/4" 286sx Class 'G', 159 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 3-1/2",9.2#, L-80 10715' 10601 ' MD TVD MD TVD 10778' - 10864' 6660' - 6739' 25. ACID. FRACTURE:, CEMENT SOUEI;ZE, Em 10940' - 10968' 6809' - 6835' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet NIA Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED + OIL -BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ëê:!~71"¡:(;i¡-\ RBDMS 8FL MAY 1 6 2U05 flIo/¿f~ n '; L J;~¡ .-1 GP \..... l Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~8. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4532' Ugnu M Sands 7047' Schrader Bluff N Sands 7561' Schrader Bluff 0 Sands 7898' Base Schrader I Top Colville 8703' HRZ 10492' Kalubik 10693' Kuparuk C 10777' Kuparuk B 10969' 2930' None 4157' 4408' 4570' 4971' 6393' 6580' 6659' 6836' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~ T'tl T h· I A . t t Teme Hubble I e ec nlca SSIS an Date OS~I 0 PBU V-120 Well Number 204-179 304-367 I 305-029 Permit No. I A roval No, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By NameINumber: Drilling Engineer: Terrie Hubb/e, 564-4628 Shane Gagliardi, 564-5251 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form ~nd in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 3/28/2005 8:07:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-120 V-120 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/17/2004 21 :00 . 00:00 3.00 MOB P PRE Move rig to V-120i location. 9/18/2004 00:00 - 03:00 3.00 MOB P PRE SPOT & LEVEL RIG & PITS ON V-120, RU INTERCONNECT & SPOT CUTTINGS TANK 03:00 - 07:00 4.00 RIGU P PRE CIO 16" BOOT FOR 20", NU RISER & DIVERTER SYSTEM, TAKE ON FRESH WATER, RIG ACCEPTED AT 03:00 HRS 07:00 - 12:00 5.00 RIGU P PRE MIX SPUD MUD, PREP 111 JTS DP IN PIPE SHED, RU FLOOR TO SPUD 12:00 . 17:30 5.50 RIGU P PRE CON'T RU FLOOR, MIX SPUD MUD, ADJUST PRESS FOR TQ BOOST ON TO, MU 6 5/8" QUILL CONN & TQ T/40k & CLAMP, INSTALL BAILS, REVERSE HOSES ON TO LINK TILT & ADJUST SAME 17:30·21:00 3.50 RIGU P PRE PU 111 JTS 4" DP AND STAND BACK SAME 21 :00 - 22:30 1.50 RIGU P PRE PU 24 JTS 4" HWDP AND STAND BACK SAME 22:30 - 23:30 1.00 RIGU P PRE PJSM BHA, PU 1 JT 5" HWDP, JARS, 1 JT 5" HWDP, COLLAR STD 23:30 . 00:00 0.50 RIGU P PRE FUNCTION DIVERTER SYSTEM (TEST WAIVED BY J. CRISP WI AOGCC) HELD PRE-SPUD MEETING AT TOUR CHANGE WI CREW AND SERVICE HANDS (23:00 HRS). 9/19/2004 00:00 . 01 :00 1.00 RIGU P PRE Bring BHA to rig floor & RU gyro. 01 :00 - 03:00 2.00 RIGU P PRE MU BHA #1 as per DO. Adjust motor & orient. 03:00 . 03:30 0.50 RIGU P PRE Fill hole & all lines. Check for leaks. 03:30 - 06:00 2.50 DRILL P SURF Drill f/1 08' to 357', 58k up, 56k dn, 57k rt wt, 500 gpm, 620 psi, 15k wob, 40 rpm, 4k tq. Spud V-120 at 03:30 hrs, 108'. 06:00 - 06:30 0.50 DRILL P SURF CBU at drlg rate & TOOH fljar std, 65k up, 56k dn. 06:30 - 12:00 5.50 DRILL P SURF Con't drlg f/357' to 1006', 72k up, 66k dn, 68k rt wt, 200 spm, 600 gpm, 1400 psi on, 1200 psi off, 50 rpm, 37k wob, 5k tq on, 2.2k tq off. AST . 3.08 hrs I ART· 1.67 hrs 12:00 - 17:30 5.50 DRILL P SURF Last Gyro at 900', RD gyro equip, con't drlg f/1006' t/1660', 77k up wt, 56k dn wt, 60 rt wt, 680 gpm, 230 spm, 2480 psi on, 2210 psi off, 30-40K wob, 50 rpm, 6.2k tq on, 3k tq off. 17:30 - 18:30 1.00 DRILL P SURF CBU 2x at 680 gpm, rotate & recip, 50 rpm, 2.7k tq off, monitor well. 18:30 - 20:00 1.50 DRILL P SURF POOH f/1660' t/1146', pull25k over, pmp f/1156' t/973' at 600 gpm, 1600 psi, con't POOH. 20:00 - 20:30 0.50 DRILL P SURF Std back BHA. 20:30 - 21 :00 0.50 DRILL P SURF Change out bit, MU new Hughes MX-C1 bit. 21 :00 - 21 :30 0.50 DRILL P SURF Clean & clear rig floor. 21 :30 - 23:00 1.50 DRILL P SURF Adjust motor to 1.5 deg, LD UBHO sub, CO MWD, orient MWD. 23:00 - 00:00 1.00 DRILL P SURF PU collar std, jar std, 8 std 4" hwdp. AST . 2.5 hrs I ART - 1.78 hrs RD Gyro at 12:00 hrs 9/20/2004 00:00 - 01 :00 1.00 DRILL P SURF Con't TIH wlBHA #2 taking surveys every std from 900', hole taking wt f/950' to 1380'. 01 :00 - 01 :30 0.50 DRILL P SURF MU TDS at 1565', stage pumps up & wash last std dn at 650 gpm, 2000 psi, 50 rpm, 74k rt wt, 2.6k tq. Printed: 10/1/2004 9:08:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -120 V -120 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/20/2004 01 :30 - 12:00 10.50 DRILL P SURF Con't drlg from 1660' to 3445', 94k up, 66k dn, 78k rt wt, 230 spm, 680 gpm, 3200 psi on, 2950 psi off, 80 rpm, 35k wob, 7.5-8.5k tq on, 4.5k tq off, survey & backream each std. AST = 2.87 hrs I ART = 3.28 hrs Added 300 bbls new spud mud at 2800' TMD. Some hydrates f/2400' to 2800' TMD. Substantial hydrates f/2800' to 3435'. 12:00 - 14:00 2.00 DRILL P SURF Con't drlg f/3435' t/4121' TO, up 116k, dn 62k, rt 83k, gpm 615, spm 210, psi on 3550, psi off 3300, rpm 80, tq on 11 k, tq off 5.1 k, wob 24k, flo 50%. 14:00 - 16:30 2.50 DRILL P SURF CBU 3x, rot & recip at 640 gpm, psi 3360, 105 rpm, tq off 5.1 k, monitor well, pooh, 112 up, 77 dn, no pumps. 16:30 - 20:30 4.00 DRILL P SURF POOH, pull dry to 2090', pull30k over, same at 2065', wipe ok, swabbing @2030', MU TO & BR f/2030' t/1840', 630 gpm, 2200 psi, 60 rpm, tq 5k, attempt pull no pump's, swabbing, MU TO pump out of hole f/1751' t/1471', pooh dry f/1471' to 804', no problems. 20:30 - 00:00 3.50 DRILL P SURF RIH took wt at 1760', wiped ok, con't RIH taking wt f/2050', filled pipe at 2418', RIH to 2525', held up, mu td & wash & ream f/2525' t/bottom at 4121', 200 gpm, 750 psi, 25 rpm, tq 5k, to avoid sidetracking well. AST = .13 hrs I ART = 1.7 hrs TO surface hole at 4121' TMD - 2727' TVD 9/21/2004 00:00 - 02:00 2.00 DRILL P SURF Circulate and condition hole 3x BU at 4121', stage up pumps to 620 gpm, 3180 psi, 100 rpm, 87k rt wt, 6.5k tq, hole cleans up at BU. 02:00 - 05:00 3.00 DRILL P SURF Monitor well, POOH 120k up, 66k dn, std back dp, hwdp, jar & collar std, hole looks good on TOOH, displacement correct. 05:00 - 06:30 1.50 DRILL P SURF LD BHA #2. 06:30 - 07:00 0.50 DRILL P SURF Clear & clean floor, send out jewelry. 07:00 - 08:00 1.00 CASE P SURF Make dummy run wlhanger, co bails, RU Franks tool. 08:00 - 09:00 1.00 CASE P SURF RU casing equipment. 09:00 - 12:00 3.00 CASE P SURF PJSM, Baker-Lock shoe track, check floats, RIH w/9 5/8" 40# L-80 BTC-MOD casing, fill every jt, centralizers as per running detail, MU tq to 8200 ft Ibs using BOL 2000 NM pipe dope. 12:00 - 16:30 4.50 CASE P SURF Con't running 9 5/8" BTC-MOD 40# csg, f/667' t/4109', dope w/BOL 2000, tq t/8.2K ft Ibs, fill ea jt, instal TAM clr between jts 76 & 77. 16:30 - 17:00 0.50 CEMT P SURF RD fill tool, MU cmt head, up 163,dn 92 17:00 - 18:30 1.50 CEMT P SURF Stg up pmp's t/12 bbls/min, 835 psi, circ & cond mud. 18:30 - 19:00 0.50 CEMT P SURF PJSM wlDowell, TP, Co Rep, NAD crew, MI, TAM f/cement job. Line up Dowell, pmp 5 bbl water to test lines to 3500 psi. 19:00 - 22:00 3.00 CEMT P SURF Pmp 75 bbl Mud Push - 10.1 ppg, drop bottom plug, 515 bbls 10.7 ppg lead cmt, 60 bbl tail cmt 15.8 ppg, drop top plug and KO w/10 bbls water, switch to rig pumps to displace cement w/296 bbls mud at 8-9 bbl/min, reduced to 2 bpm fllast 10 bbls, bump plug at 296 bbl, CIP @21:30 hrs, attempt to test csg per Well Plan, pumped casing off bottom at 2900 psi (called off Printed: 10/1/2004 9:08:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -120 V -120 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/21/2004 19:00 - 22:00 3.00 CEMT P SURF test), bleed off psi & check floats (held), 161 + bbls cement back to surface. 22:00 - 00:00 2.00 CEMT P SURF Flush diverter, LD cmt head, landing jt, csg tools f/rig floor. 9/22/2004 00:00 - 00:30 0.50 CEMT P SURF Super sucker on cellar, lay down long bails on TO & send out. 00:30 - 02:30 2.00 DIVRTR P SURF NO diverter system & CO 20" nipple to 16". 02:30 - 03:30 1.00 BOPSU P SURF Install csg head & tbg spool, Tq alien bolts in csg head to 350 ft Ibs, test MM seal in csg head to 1000 psi f/10 min. 03:30 - 07:00 3.50 BOPSU SURF NU BOP stack & all related surface equipment, RU test equipment. 07:00 - 10:30 3.50 BOPSU SURF Test BOP's & all related surface equipment to 250 psi 14000 psi, annular preventer to 250 psi 13500 psi, witness of test waived by J. Spalding AOGCC. 10:30 - 11 :00 0.50 BOPSU SURF RD test equipment, blow dn all lines. 11 :00 - 11 :30 0.50 BOPSU SURF Install wearring & RILDS, RU to PU pipe. 11 :30 - 12:00 0.50 DRILL P PROD1 PU drill pipe singles f/pipe shed. 12:00 - 17:30 5.50 DRILL P PROD1 PU drill pipe singles, MU stands & stand back in derrick (135 jts DP). 17:30 - 18:00 0.50 DRILL P PROD1 RU floor in prep to PU BHA, PJSM wlDD & MWD. 18:00 - 21:00 3.00 DRILL P PROD1 MU BHA #3, PU 6.75 motor, fit sub, nm stab, LWD/CDR, MWD, ADN, 2NM DC, svr sub, jar std, XO, 25 jt 4" HWDP, ghst rmr, test TAM clr to 1000 psi - OK. 21 :00 - 21 :30 0.50 DRILL P PROD1 Cut & slip 43' drlg line. 21 :30 - 22:00 0.50 DRILL P PROD1 Service TO. 22:00 - 00:00 2.00 DRILL P PROD1 PU dp 1x1 fIshed w/RIH, test MWD at 1500'. 9/23/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Con't to single in the hole f/1500' t/3835', 124k up, 55k dn. 01 :00 - 02:00 1.00 DRILL P PROD1 Circ air out of system at 3835', test 9 5/8" csg to 3500 psi f/30 min & chart - OK. 02:00 - 04:00 2.00 DRILL P PROD1 Wash & ream down & tag flc at 4024', drill shoe track, rat hole & 20' new hole to 4141' at 184 spm, 450 gpm, 1880 psi, 40 rpm, 83k rt wt, 7-8k tq, 124k up, 55k dn. 04:00 - 04:30 0.50 DRILL P PROD1 Displace to well f/spud mud to new 9.0 ppg LSND mud at 12 bpm, 1150 psi, 50 rpm, 78k rt wt, 6k tq. 04:30 - 05:00 0.50 DRILL P PROD1 Pull bit up inside csg, perform LOT to EMW 13.95 ppg. 05:00 - 00:00 19.00 DRILL P PROD1 Place bit outside casing, obtain initial PWD ECD value of 9.93 ppg with modeled ECD at 9.68 ppg (.25 ppg differential). Drilled ahead f/4141' t/5056' with typical drilling parameters as follows: 126k up, 65k dn, 88k rt wt, 236 spm, 580 gpm, 2200 psi on, 2080 psi off, 100 rpm, 5k-15k wob, 7k tq on, 6k tq off. The actual PWD ECD was maintained within avg of .5 ppg of the calculated ECD. Drilled ahead f/5056' t/6829' with typical drilling parameters as follows: 151 k up, 72k dn, 100k rt wt, 230 spm, 565 gpm, 2750 psi on, 2580 psi off, 100 rpm, 10k tq on, 8k tq off, 5k-15k wob. The actual PWD ECD was maintained within avg .5 ppg of the calculated ECD. ART = 7.77 hrs lAST = 2.43 hrs 9/24/2004 00:00 - 00:00 24.00 DRILL P PROD1 Con't drilling in the 8 3/4" hole f/6829' t/9193' wlo problems, 5k-18k wob, 575 gpm, 100 rpm. Typical drilling parameters f/6829' t/8134' as follows: 156k up, Printed: 10/1/2004 9:08:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-120 V -120 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/24/2004 00:00 - 00:00 24.00 DRILL P PROD1 80k dn, 108k rt, 3300 psi on, 3100 psi off, cal ecd 10.28, act ecd 10.52. Typical drilling parameters f/8134' t/9193' as follows: 182k up, 83k dn, 118k rt, 3670 psi on, 3550 psi off, cal ecd 10.41, act ecd 10.74. AST = 3.03 hrs I ART = 12.49 hrs 9/25/2004 00:00 - 00:00 24.00 DRILL P PROD1 Con't drilling ahead in 8 3/4" hole f/9193' t/1 0,753' wlo problems. Increased mud weight 10.1 ppg at 10,100' TMD prior to drilling into the HRZ wl"spike" fluid f/mud plant. All drilling trends "positive" while monitoring PWD values to stay within the pre-designated .7 ppg differential (not a problem). Managed drilling torque w/2-3% Lubetex additions. Backing off pump rates to manage pump pressure within liner rating. Directional work going well toward TO, however, needing a periodic slide to keep from dropping too much angle. Will TO interval per Geologist. Drilling parameters as follows: 202k up, 106k dn, 146k rt wt, 214 spm, 525 gpm, 4040 psi on, 3900 psi off, 100 rpm, 5k-12k wob, 14.6k tq on, 14k tq off, cal ecd = 10.8 ppg, act ecd = 11.05 ppg. ART = 14.28 hrs lAST = 4.74 9/26/2004 00:00 - 07:00 7.00 DRILL P PROD1 Con't to drill f/10,753' TMD to 11,140 ft, some torque building while drilling to TO (treated with 2-3% Lubetex), 220k up, 114k dn, 152k rwt, 510 GPM, 3850 psi off, 4000 psi on, 100 rpm, 16-17k tq, 8-15 wob. Cal ECD = 10.781 ACT ECD = 10.92. ART = 4.73 hrs lAST = 1.1 hrs Final well TO = 11,140 TMD I 6996 TVD 07:00 - 10:00 3.00 DRILL P PROD1 Pump 30 bbls wt'ed sweep, circ 3xbu at 510 gpm, 3850 psi, 110 rpm, monitor well. Cal ECD = 10.781 Act ECD = 10.75 10:00 - 14:30 4.50 DRILL P PROD1 Monitored well. POOH 10 stds t/1 0,190', 236k up, 115k dn, pump slug, short trip to 9 5/8 shoe at 4109', pu1l10-20k over f/4600' t/4300', wk pipe ok, 120k up I 70k dn at shoe wlo pump. Flow checks & Hole fill showing well static. 14:30 - 15:00 0.50 DRILL P PROD1 CBU at shoe, 550 gpm, 2020 psi, 70 rpm, 82k rt wt, 4.3k tq. 15:00 - 16:00 1.00 DRILL P PROD1 Slip & cut 40' drilling line, check brakes, clean & inspect underneath drawworks, grease crown. 16:00 - 16:30 0.50 DRILL P PROD1 Service top drive. 16:30 - 19:30 3.00 DRILL P PROD1 TIH flshoe t/11 ,058',fill pipe at 6600' & 9100', hit obstruction at 10,800', pu wk pipe wlo success, mu tds & fill pipe, wk by obstruction wlo problem. Trip sheet showing well static. 19:30 - 22:30 3.00 DRILL P PROD1 MU tds at 11,058', fill pipe & stage pumps to 400 gpm, wash & ream to TO at 11,140' (no problems), cbu x 3 at 530 gpm, 3950 psi, 110 rpm, 152k rwt, 17.5k tq, bu #1 brought back significant returns, pumped a 25 bbl high wtIhigh vis sweep on bu #2 (did not see much in returns), circulated bu #3 wlnot much on Printed: 10/1/2004 9:08:50 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-120 V-120 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/26/2004 19:30 - 22:30 3.00 DRILL P PROD1 shakers. Cal ECD = 10.78 ppg I Act ECD = 10.77 22:30 - 00:00 1.50 DRILL P PROD1 Monitored well, pump dry job, begin trip out of hole for casing, 250k up, 115k dn. 9/27/2004 00:00 - 05:00 5.00 DRILL P PROD1 Con't POOH, std back 4" HWDP, open hole looked good, monitor well @ shoe & prior to LD BHA - OK, hole fill correct. 05:00 - 07:00 2.00 DRILL P PROD1 Flush BHA wlwater, LD BHA #3,5" HWDP, jars, NMDC's, ADN MWD LWD, motor, bit. 07:00 - 07:30 0.50 DRILL P PROD1 Clean & clear floor. 07:30 - 09:00 1.50 CASE P PROD1 Flush stack, pull wear ring, install test plug, change top rams tJ7", test door seals to 3500 psi. 09:00 - 1 0:30 1.50 CASE P PROD1 Pull test plug, make up dummy run wllanding joint, ru csg running equip. 10:30 - 17:30 7.00 CASE P PROD1 PU shoe track, ck floats - OK, con't run 7" 26# L-80 BTC-Mod production csg 1X1, MU tq 8000 ft Ibs using BOL 2000 NM pipe dope, filling every jt in, breaking circ every 10 jts in while inside the 9 5/8" casing. 17:30 - 18:00 0.50 .CASE P PROD1 Circ BU X 1.5 at the 9 5/8" shoe, 4 bpm - 250 psi, 5 bpm - 310 psi, 6 bpm - 375 psi, 125k up, 80k dn wlo pumps. 18:00 - 00:00 6.00 CASE P PROD1 Con't RIH wlcsg to 7000', fill every jts & break circ every 5 jts, displacement correct, some gas hydrates at surface @6500' (monitored well to confirm), con't to RIH. 9/28/2004 00:00 - 09:00 9.00 CASE P PROD1 Con't to RIH wIT', 26#, L-80, BTC-M casing to 11,122' ft. Fill every joint, break circ every 5 joints. Average MU Torque, 8,000#. CBU at 8,000' while RIH, 168 GPM, 425 PSI. Note: At 9,700', hole started taking fluid. Slow running rate to 2 min/joint. Lost 31 bbls during casing run. 09:00 - 09:30 0.50 CASE P PROD1 MU landing joint and land casing. 350K UP, 102K ON. RD fill-up tool. MU cement head. 09:30 - 12:30 3.00 CASE P PROD1 Break circulation and stage pumps up to 6 BPM (252 GPM), 760 PSI. Loss of 57 BBLS during circulation. 380K UP, 100K ON. 12:30 - 15:30 3.00 CEMT P PROD1 Change over to cement unit. Pump 5 bbl mud push. Test lines to 4,000 psi, OK. Pump 35 bbls mud push. Drop bottom plug. Pump 129 bbls 12 ppg lead cement followed by 34 bbls 15.8 tail cement at 6 bpm. Drop top plug. Switch to rig pumps and displace cement with 423 bbls of 10.3 ppg mud. Bump plug with 4,000 psi and hold for 30 minutes, OK. Bled off pressure, check floats, holding OK. Cement in place at 14:33 hrs. Note: Reciprocated pipe until top plug away. 100% returns throughout cement job. 15:30 - 16:00 0.50 CEMT P PROD1 Blow down all lines. RD cement head. Retrieve and lay down landing joint. 16:00 - 16:30 0.50 WHSUR P PROD1 Install 7" pack-off. Run in lock down screws and gland packing nuts. Torque to 450 ftllbs. Test pack-off to 5,000 psi for 10 minutes, OK. 16:30 - 17:30 1.00 CEMT P PROD1 Rig down casing equipment, change out bails and flush BOP with ported sub. 17:30 - 19:00 1.50 CASE P PROD1 Install test plug. Change upper pipe rams to 3.5" x 6" Printed: 10/1/2004 9:08:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -120 V -120 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/17/2004 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 9/28/2004 17:30 - 19:00 1.50 CASE P PROD1 variables. Test door seals to 3,500 psi. 19:00 - 20:00 1.00 CEMT P PROD1 Install wear bushing and run in lock down screws. Make up cleanout BHA with scraper. 20:00 - 00:00 4.00 CASE P PROD1 RIH with cleanout assy to 9,000'. 9/29/2004 00:00 - 00:30 0.50 CASE P PROD1 Continue to RIH with cleanout assy from 9,000' to 10,575'. 00:30 - 01 :00 0.50 CASE P PROD1 Service TDS. Clear 7" x 9.625" annulus with drilling mud as per RP. 3 BPM. ICP 600 psi. FCP 700 psi. Shut in pressure 530 psi. 01 :00 - 01 :30 0.50 CASE P PROD1 Continue RIH from 10,575' to tag float equipment at 11,036'. 01 :30 - 02:30 1.00 CASE P PROD1 Displace well to brine. Pump 25 bbl Hi-Vis sweep followed by 8.9 brine at 8 BPM, 3,600 psi. Continue circulating until returns clean. Pumped a total of 580 bbls brine. Rotated and reciprocated drill pipe during circulation. 02:30 - 03:30 1.00 CASE P PROD1 Slip and cut drill line. 03:30 - 04:30 1.00 CASE P PROD1 POOH. Stand back a total of 25 stands. 04:30 - 10:30 6.00 CASE P PROD1 Continue POOH laying down drill pipe. 10:30 - 12:00 1.50 CASE P PROD1 LD BHA. 12:00 - 13:00 1.00 RPRIN P SURE Pull wear bushing. Rig up to run 4.5" tubing. Note: Pumped 75 bbls dead crude down 7" x 9.625" annulus for freeze protection. Pump at 2.5 BPM. ICP=850 psi FCP=1,OOO psi SIP=900 psi. 13:00 - 16:30 3.50 RPRIN P SURE PJSM. MU WLEG. RIH with 111 joints of 4.5", 12.6#, L-80, TC-II tubing. MU torque 3,800 ftllbs using Jet Lube Seal Guard pipe dope. 16:30 - 18:00 1.50 RPRIN P SURE MU tubing hanger and landing joint. 80K UP WT 55K ON WT. Land tubing at 4,351.77'. Run in lock down screws and torque LOS and gland packing screws to 450 fVlbs. Install TWC and test from below to 2,800 psi. 18:00 - 20:00 2.00 WHSUR P SURE Nipple down BOP. 20:00 - 22:00 2.00 WHSUR P SURE Nipple up adapter flange and 4 1/8", 5M production tree. Test tree to 5,000 psi. 22:00 - 22:30 0.50 WHSUR P POST PJSM. Rig up DSM and pull TWC with lubricator 22:30 - 00:00 1.50 WHSUR P POST PJSM. Rig up hot oil. Pump 75 bbls diesel down 7" x 4.5" annulus to freeze protect well. Pump at 2.5 BPM. ISP 225 psi. 9/30/2004 00:00 - 00:30 0.50 WHSUR P POST Allow diesel freeze protection to U-Tube. 00:30 - 01 :00 0.50 WHSUR P POST DSM install BPV and test from below to 1,000 psi. 01 :00 - 02:00 1.00 WHSUR P POST Rig down Hot Oil and DSM. Remove secondary annulus valve and secure tree and cellar. 02:00 - 12:00 10.00 WHSUR P POST Off load brine from pits (Note: Truck delayed due to wide impassable on Spine Road). Perform rig maintenance, service TDS, adjust rotary hose, replace blower hose safety cable, replace brake handle shaft bearing, check Koomey control panel. Cleaning rig and preparing for move to V-106. Rig released @ 12:00 hrs. Printed: 10/1/2004 9:08:50 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -120 V-120 COMPLETION Start: 3/11/2005 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 3/14/2005 3/16/2005 18:00 - 00:00 6.00 MOB P SURE Move camp and shop from Niakuk pad to V-pad 3/17/2005 00:00 - 06:00 6.00 MOB P SURE Move Satellite Camp and Mechanic Shop FI NK-38A TI V-120 06:00 - 07:00 1.00 MOB P SURE Break out pits, lay derrick over. Prepare to move rig 07:00 - 10:30 3.50 MOB P SURE Wait on Roads and Pads Heavy Equipment to Clear Snow Berms On Access Road Bewteen Niakuk and L-Pad 10:30 - 12:00 1.50 MOB P SURE Move Pits and Substructure to L-Pad 12:00 - 14:00 2.00 MOB P SURE Wait On Snow Removal Between L-Pad and East Dock Road. 14:00 - 00:00 10.00 MOB P SURE Move Pits and Substructure to West Dock Beach Rd.l Oxbow Road Intersection 3118/2005 00:00 - 22:00 22.00 MOB P SURE Move Rig FI West Dock Beach Rd.l Oxbow Rd. Intersection TI V-Pad. 22:00 - 00:00 2.00 MOB P SURE PJSM-Inspect Derrick and Raise Same 3/19/2005 00:00 - 01 :00 1.00 MOB P SURE Lay Mats and Herculite Around V-120 01 :00 - 04:00 3.00 MOB P SURE Spot Substructure and Pit Complex Over Wellhead 04:00 - 05:00 1.00 MOB P SURE PJSM-Raise Pipeshed Skate Chute, Organize Rig Floor 05:00 - 08:30 3.50 MOB P SURE PJSM-Bridle Down Blocks, Hang Back Bridle Lines in Derrick, Pin Blocks to Top Drive Rig Accepted @ 0600 hrs. 3/19/2005 08:30 - 09:30 1.00 WHSUR P WHDTRE PJSM-Check Inner Annulus Pressure, o psi. PIU DSM Lubricator and Install on Production Tree. Remove BPV. RID Lubricator and UD Same. Tbg. Pressure 0 psi. 09:30 - 10:00 0.50 WHSUR P WHDTRE Safety Meeting-Well Review/PJSM 10:00 - 11 :00 1.00 WHSUR P WHDTRE Install Double Annulus Valve on IA 11 :00 - 12:00 1.00 WHSUR P WHDTRE RIU Circulating Lines to Tbg. Annulus and Tbg. (top of tree). Pressure Test Lines to 3,500 psi. 12:00 - 15:00 3.00 WHSUR P WHDTRE Reverse Circulate WI 8.5 ppg. Seawater Down IA Taking Freeze Protection FI Tbg. TI Slop Tank @ 1 bpm. (38 bbls. diesel recovered). Pump Down Tbg. WI Seawater Taking Returns from IA. to Slop Tank @ 2 bpm.l125 psi. (84 bbls. diesel recovered) 15:00 - 16:00 1.00 WHSUR P WHDTRE Blow Down Circulating Lines, Check Pressure on Well 0 psi., Install TWC and Test from Below to 1,000 psi. 16:00 - 17:00 1.00 WHSUR P WHDTRE PJSM-N/D Production Tree & Have FMC Visually Inspect Tree, Adaptor Flange and Tbg. Hgr. Threads. Tree Ready For Reuse, Tbg Hgr Threads Good Shape. 17:00 - 21:30 4.50 BOPSU WHDTRE NIU BOPE's 21 :30 - 22:00 0.50 BOPSU WHDTRE PJSM-P/U & MIU Test Jt. with TCII XO on Btm. RIH with Test Jt. and Screew into TBG Hgr. RlU Test Lines and Chart 22:00 - 00:00 2.00 BOPSU RREP WHDTRE Repair Test Pump-Sheared Bolts on Suction Manifold. Suspect Frozen Discharge Manifold. Replace Bolts, Pop-Off, 'O"-Rings 3/20/2005 00:00 - 01 :00 1.00 BOPSU RREP WHDTRE Repair Test Pump 01 :00 - 05:30 4.50 BOPSU WHDTRE Test All Rams, Annular, Choke & Kill Line Valves, Choke Manifold, Floor Safety Valves and Top Drive Well Control Valves to 250 psi Low 13,500 psi High. All Pressure Tests Held 5 min. on Low and High Tests. AOGCC Witness of Test Wavied By Chuck Sheeve. Test Witnessed By BP Supervisor Rodney Klepzig 05:30 - 06:00 0.50 BOPSU P WHDTRE RID Test Equipment & Blow Down Top Drive 06:00 - 07:00 1.00 PULL P SURE RIU Landing Jt, XO & Screw into Tbg. Hgr. BOLDS 07:00 - 07:30 0.50 PULL P SURE Pull Tbg. Hgr. to Rig Floor & UD Same. Up WI. 75K 07:30 - 13:30 6.00 PULL P SURE POH wI 4.5" 12.6# L-80 TC-II Tbg. Recovered 111 Jts. 13:30 - 14:00 0.50 PULL P SURE RID Tbg. Tongs, Change Elevators, Clean & Clear Rig Floor 14:00 - 15:00 1.00 PULL P SURE PJSM-Slip & Cut Drlg. Line Printed: 3/28/2005 8:07:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-120 V -120 COMPLETION Start: 3/11/2005 Rig Release: Rig Number: Spud Date: 9/19/2004 End: 3/14/2005 Service Top Drive, Blocks & Crown Install Test Plug & Test Jt. Test Lower Pipe Rams to 250 psi low/3,500 psi high. AOGCC Witness of Test Waived by Chuck Sheeve. Test Witnessed by BP Drlg. Supervisor Jeff Cutler 16:30 - 17:00 0.50 RUNCMP PJSM-R/U Torque Turn Tongs & Equipment 17:00 - 17:30 0.50 RUNCMP PIU & MIU 3.5" 9.2# L-80 TC-II Tail Pipe Assy. Baker Lock each Connection Under Packer 17:30 - 00:00 6.50 RUNCMP RIH wI 3.5" 9.2# L-80 TC-II Tbg., Use Jet Lube Seal Guard on Connections, Torque Turn each Connection tJ 2300 ftIlbs 3/21/2005 00:00 - 12:00 12.00 RUNCMP RIH wI 3.5" 9.2# L-80 TC-II Tbg. Dope Each Connection With Jet Lube Seal Guard, Torque Turn Each jt. to 2300 ftIlbs. PIU & M/U Tbg.Hgr. and Land Same. 12:00 - 12:30 0.50 RUNCO RUNCMP RILDS, Install TWC and Test tJ 1,000 psi fl Below. 12:30 - 14:30 2.00 BOPSU P OTHCMP PJSM-N/D BOPE's and Secure to Pedestal 14:30 - 16:00 1.50 WHSUR P OTHCMP NIU Adaptor Flange and Production Tree 16:00 - 16:30 0.50 WHSUR P OTHCMP Test Tree tJ 5,000 psi 16:30 - 17:00 0.50 WHSUR P OTHCMP Pull TWC & R/U to Reverse Circulate 17:00 - 17:30 0.50 WHSUR P OTHCMP Test Lines tJ 4,000 psi 17:30 - 20:30 3.00 WHSUR P OTHCMP Reverse Circulate 93 bbls. Clean Seawater Down Annulus Taking returns from Tubing to Slop Tank Followed by 131 bbls. Corrosion Inhibited Seawater and then 151 bbls. Clean Seawater. Final Circ. Rate and Pressure, 3 bpm @ 400 psi. 20:30 - 22:00 1.50 WHSUR P OTHCMP Drop Ball (1-5/16") and Rod. Pump Down Tubing and Attempt to Set Pkr. Unable to Pressure Up. Increase Pump Rate to 3 bpm Trying to Pump Balli On Seat, wlo Success. Increase Pump Rate to 5 bpm, wlo Success. Surge Pumps with 0/5 bpm Trying to Dislodge Ball, w/o Success. Reverse Circulate and Respot Corrosion Inhibited Seawater. Circulate Down Tubing @ 5 bpm and Attempt to Set Pkr., wlo Success. Respot Inhibited Seawater. 22:00 - 00:00 2.00 WHSUR N DPRB OTHCMP After Confering with Anchorage Personal, Decision was Made to Use Schlumberger Slickline to Push Rod and Ball to Bottom. Wait On Slickline Unit. 3/22/2005 00:00 - 01 :00 1.00 WHSUR N DPRB OTHCMP PJSM-Spot and RU SLB Slickline utilizing 0.125" wire. MU 2" overshot shear down tool w/2.6" bell guide. 01 :00 - 02:00 1.00 WHSUR N DPRB OTHCMP RIH wlslickline and tag @ 5,745' - GLM w/DCR shear valve and RKP latch. Latch up and work ball and rod through. RIH to 10693'. Jar down and shear pins on overshot and release ball and rod. 02:00 - 03:00 1.00 WHSUR N DPRB OTHCMP POH w/slickline. Pins sheared on overshot. RD slickline. 03:00 - 04:30 1.50 WHSUR P OTHCMP Set Packer w/4,200 psi. Chart and hold for 30 minutes. Bleed tubing pressure to 2,500 psi. Pressure up the annulus to 4,000 psi. Chart and hold for 30 minutes. Bleed off tubing pressure and then bleed off annulus pressure. Pressure up on the annulus to 2,800 psi and shear the OCR valve. Pump 3 bpm @ 400 psi to confirm fully open. 04:30 - 06:00 1.50 WHSUR P OTHCMP RU LRHOS and reverse circulate 150 bbls Diesel into the 7" x 3.5" annulus to freeze protect the well. 06:00 - 07:00 1.00 WHSUR P OTHCMP Allow diesel to u-tube from annulus to tubing. 07:00 - 09:00 2.00 WHSUR P OTHCMP Blow down all surface lines. Install BPV and test to 1,000 psi - good test. RD LRHOS. Secure the well and release the rig @ 0900 hours 3/22/2005. Printed: 3/28/2005 8:07:29 AM . . V-120 Prudhoe Bay Unit 50-029-23225-00-00 204-179 Accept: Spud: Release: Ri: 09/18/04 09/19/04 09/30/04 Nabors 9ES Accept: Spud: Release: Ri: 03/1 9/05 N/A 03/22/05 Nabors 9ES POST RIG WORK 04/10/05 PULLED B&R FROM RHC PLUG BODY AT 10,679' SLM. PULLED STA #1 & STA #2, RUNNING IN HOLE TO SET ST A #2. 04/11/05 SET RK-LGLV IN STA #2,2634' SLM AND RK- S/O IN STA #1,5727' SLM. PULLED RHC PLUG BODY FROM X-NIP AT 10,686' SLM. DRIFTED WI 2.50" DUMMY GUN & SAMPLE BAILER. TAG PBTD AT 11,004' SLM. NO SAMPLE. 04/12/05 PERF WITH 2.5" POWERJETS 4 SPF, 10940' - 10968' AND 10778' - 10864'. c.. 2.8 7€J" Schlumberger V-120 Survey Report Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 31.280° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.10 ft relative to MSL Sea Bed I Ground Level Elevation: 53.60 ft relative to MSL Magnetic Declination: 24.786° Total Field Strength: 57589.886 nT Magnetic Dip: 80.798° Declination Date: September 18, 2004 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North .) True North: +24.786° Local Coordinates Referenced To: Well Head Report Date: 26-Sep-04 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad / Plan V-120 (N-X) Well: V-120 Borehole: V-120 UWIIAPI#: 500292325500 Survey Name I Date: V-120 / September 26,2004 TortI AHD I DDII ERD ratio: 182.209° /7930.10 ft/6.362/1.134 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatILong: N 70.32816943, W 149.26398020 Location Grid N/E YfX: N 5970146.490 ftUS, E 590752.780 ftUS Grid Convergence Angle: -+{).69306719° Grid Scale Factor: 0.99990936 . Comments Measured Inclination Azimuth Sub·Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (dea/100 ft) (ftUS) (ftUS) RTE 0.00 0.00 0.00 -82.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970146.49 590752.78 N 70.32816943 W 149.26398020 First GYD-GC-MS 100.00 0.32 302.71 17.90 100.00 0.01 0.28 0.28 0.15 -0.23 0.32 5970146.64 590752.54 N 70.32816984 W 149.26398211 200.00 0.37 303.30 117.90 200.00 0.03 0.88 0.88 0.48 -0.74 0.05 5970146.96 590752.03 N 70.32817074 W 149.26398620 300.00 1.94 17.25 217.88 299.98 1.68 2.74 2.33 2.27 -0.51 1.87 5970148.76 590752.24 N 70.32817564 W 149.26398432 400.00 3.43 24.09 317.76 399.86 6.29 7.42 6.73 6.62 1.22 1.52 5970153.12 590753.92 N 70.32818751 W 149.26397035 500.00 6.57 26.43 417.37 499.47 14.96 16.13 15.31 14.48 4.98 3.15 5970161.02 590757.59 N 70.32820898 W 149.26393979 600.00 10.43 26.61 516.25 598.35 29.69 30.91 30.02 27.70 11.59 3.86 5970174.32 590764.03 N 70.32824509 W 149.26388624 700.00 15.51 26.52 613.67 695.77 52.05 53.35 52.43 47.77 21.62 5.08 5970194.51 590773.82 N 70.32829992 W 149.26380490 800.00 20.01 36.26 708.90 791.00 82.44 83.78 82.65 73.55 37.72 5.38 5970220.48 590789.60 N 70.32837035 W 149.26367433 Last GYD-GC-MS 900.00 23.61 35.36 801.73 883.83 119.47 120.92 119.51 103.68 59.43 3.62 5970250.87 590810.95 N 70.32845268 W 149.26349823 First MWD+IFR+MS 944.28 24.49 34.04 842.17 924.27 137.48 138.97 137.50 118.52 69.70 2.33 5970265.83 590821.04 N 70.32849321 W 149.2.6 1038.39 28.39 29.53 926.42 1008.52 179.35 180.85 179.36 154.17 91.66 4.66 5970301.74 590842.56 N 70.32859060 W 149.2 0 1131.22 31.49 28.80 1006.86 1088.96 225.64 227.17 225.67 194.63 114.22 3.36 5970342.46 590864.63 N 70.32870112 W 149.26 2 1224.02 34.73 28.97 1084.58 1166.68 276.28 277.86 276.34 239.00 138.71 3.49 5970387.13 590888.58 N 70.32882236 W 149.26285534 1319.11 38.11 29.59 1161.08 1243.18 332.69 334.30 332.78 288.23 166.33 3.58 5970436.69 590915.59 N 70.32895685 W 149.26263138 1412.27 40.96 30.48 1232.93 1315.03 391.97 393.60 392.07 339.56 196.02 3.12 5970488.36 590944.66 N 70.32909706 W 149.26239059 1505.47 43.01 29.61 1302.20 1384.30 454.30 455.94 454.41 393.52 227.22 2.29 5970542.70 590975.20 N 70.32924449 W 149.26213753 1599.04 46.87 29.28 1368.42 1450.52 520.35 522.02 520.49 451.07 259.70 4.13 5970600.63 591006.98 N 70.32940171 W 149.26187412 1694.03 51.79 29.69 1430.31 1512.41 592.34 594.05 592.52 513.77 295.16 5.19 5970663.74 591041.68 N 70.32957298 W 149.26158654 1784.16 53.43 31.28 1485.04 1567.14 663.94 665.65 664.12 575.47 331.49 2.30 5970725.87 591077.26 N 70.32974153 W 149.26129185 1879.46 56.17 31.05 1539.97 1622.07 741.80 743.52 741.97 642.10 371.79 2.88 5970792.98 591116.74 N 70.32992355 W 149.26096505 1972.82 55.74 31.01 1592.23 1674.33 819.16 820.88 819.31 708.38 411.67 0.46 5970859.74 591155.81 N 70.33010464 W 149.26064162 2066.25 55.77 31.34 1644.81 1726.91 896.39 898.11 896.54 774.46 451.65 0.29 5970926.29 591194.98 N 70.33028516 W 149.26031736 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Sld( do31 rt-546 ) Plan V-120 (N-X)\V-120\V-120\V-120 Generated 10/19/2004 8:01 AM Page 1 of 4 Comments Latitude Longitude N 70.33046858 W 149.25998553 N 70.33065477 W 149.25965378 2346.46 60.59 30.48 1791.33 1873.43 1135.18 1136.90 1135.31 979.27 574.43 2.62 5971132.54 591315.27 N 70.33084464 W 149.25932145 2439.97 59.84 29.98 1837.78 1919.88 1216.32 1218.06 1216.47 1049.39 615.29 0.93 5971203.14 591355.28 N 70.33103619 W 149.25899001 2534.30 61.22 30.55 1884.18 1966.28 1298.43 1300.18 1298.59 1120.31 656.68 1.55 5971274.56 591395.80 N 70.33122995 W 149.25865425 2627.69 62.72 30.65 1928.07 2010.17 1380.86 1382.62 1381.02 1191.27 698.65 1.61 5971346.01 591436.90 N 70.33142378 W 149.25831387 2722.31 61.73 30.40 1972.16 2054.26 1464.57 1466.33 1464.74 1263.38 741.17 1.07 5971418.63 591478.54 N 70.33162078 W 149.25796894 2814.82 60.62 30.16 2016.76 2098.86 1545.60 1547.38 1545.79 1333.37 782.03 1.22 5971489.10 591518.56 N 70.33181197 W 149.25763743 2908.07 61.30 30.18 2062.03 2144.13 1627.11 1628.91 1627.31 1403.85 823.01 0.73 5971560.06 591558.67 N 70.33200451 W 149.25730506 3002.18 60.60 29.91 2107.73 2189.83 1709.36 1711.18 1709.58 1475.07 864.20 0.78 5971631.77 591598.99 N 70.33219905 W 149.25697090 3095.76 61.93 31.00 2152.72 2234.82 1791.41 1793.23 1791.63 1545.80 905.79 1.75 5971702.99 591639.72 N 70.33239226 W 149.25. 3190.11 61.21 30.69 2197.63 2279.73 1874.37 1876.20 1874.60 1617.03 948.33 0.82 5971774.72 591681.40 N 70.33258685 W 149.25 3283.15 61.02 30.69 2242.58 2324.68 1955.84 1957.66 1956.06 1687.09 989.91 0.20 5971845.27 591722.12 N 70.33277822 W 149.25595104 3375.71 60.61 30.71 2287.71 2369.81 2036.64 2038.47 2036.87 1756.57 1031.17 0.44 5971915.24 591762.53 N 70.33296803 W 149.25561633 3469.95 62.57 29.44 2332.55 2414.65 2119.51 2121.36 2119.75 1828.30 1072.70 2.39 5971987.46 591803.19 N 70.33316398 W 149.25527941 3563.84 62.19 29.57 2376.08 2458.18 2202.66 2204.55 2202.94 1900.70 1113.67 0.42 5972060.35 591843.27 N 70.33336175 W 149.25494700 3656.58 61.73 29.04 2419.67 2501.77 2284.46 2286.40 2284.78 1972.08 1153.73 0.71 5972132.20 591882.47 N 70.33355674 W 149.25462194 3749.70 61.12 29.08 2464.21 2546.31 2366.18 2368.18 2366.53 2043.56 1193.45 0.66 5972204.15 591921.32 N 70.33375200 W 149.25429966 3840.84 60.65 29.41 2508.56 2590.66 2445.75 2447.80 2446.14 2113.04 1232.35 0.60 5972274.08 591959.37 N 70.33394178 W 149.25398404 3936.77 60.11 29.07 2555.97 2638.07 2529.09 2531.20 2529.52 2185.80 1273.09 0.64 5972347.33 591999.22 N 70.33414056 W 149.25365351 4029.64 61.41 30.04 2601.34 2683.44 2610.09 2612.23 2610.55 2256.29 1313.06 1.67 5972418.29 592038.34 N 70.33433311 W 149.25332916 4061.52 61.37 30.17 2616.60 2698.70 2638.07 2640.22 2638.54 2280.50 1327.10 0.38 5972442.67 592052.08 N 70.33439925 W 149.25321525 4136.97 59.59 30.76 2653.78 2735.88 2703.71 2705.87 2704.19 2337.09 1360.38 2.46 5972499.65 592084.67 N 70.33455383 W 149.25294518 4236.28 59.16 30.62 2704.37 2786.47 2789.17 2791.33 2789.65 2410.58 1404.00 0.45 5972573.65 592127.39 N 70.33475457 W 149.25259126 4330.71 60.70 30.43 2751.68 2833.78 2870.88 2873.05 2871.36 2480.98 1445.51 1.64 5972644.54 592168.04 N 70.33494686 W 149.25225447 4423.67 61.84 31.18 2796.36 2878.46 2952.39 2954.56 2952.87 2550.99 1487.25 1.42 5972715.04 592208.93 N 70.33513810 W 149.25191571 4517.51 61.26 31.00 2841.07 2923.17 3034.90 3037.07 3035.37 2621.64 1529.86 0.64 5972786.20 592250.68 N 70.33533110 W 149.25156998 4610.65 61.39 32.44 2885.76 2967.86 3116.61 3118.79 3117.06 2691.15 1572.82 1.36 5972856.22 592292.79 N 70.33552097 W 149.25122135 4703.82 60.14 33.03 2931.26 3013.36 3197.88 3200.09 3198.29 2759.54 1616.78 1.45 5972925.13 592335.92 N 70.33570777 W 149.25.1 4796.71 60.43 33.63 2977.31 3059.41 3278.51 3280.76 3278.86 2826.95 1661.11 0.64 5972993.06 592379.43 N 70.33589189 W 149.25 9 4890.61 60.49 34.82 3023.61 3105.71 3360.09 3362.46 3360.38 2894.49 1707.06 1.10 5973061.15 592424.55 N 70.33607639 W 149.250 03 4984.05 60.31 34.65 3069.76 3151.86 3441.19 3443.70 3441.41 2961.26 1753.35 0.25 5973128.46 592470.03 N 70.33625877 W 149.24975637 5077.39 60.02 34.90 3116.20 3198.30 3522.01 3524.67 3522.17 3027.77 1799.53 0.39 5973195.52 592515.39 N 70.33644043 W 149.24938160 5168.79 60.90 34.48 3161.26 3243.36 3601.38 3604.19 3601.50 3093.15 1844.79 1.04 5973261.44 592559.85 N 70.33661902 W 149.24901434 5262.04 61.14 33.51 3206.44 3288.54 3682.86 3685.76 3682.95 3160.78 1890.40 0.95 5973329.61 592604.63 N 70.33680375 W 149.24864421 5354.76 60.58 33.38 3251.59 3333.69 3763.79 3766.75 3763.86 3228.36 1935.03 0.62 5973397.71 592648.44 N 70.33698833 W 149.24828197 5448.50 61.19 33.03 3297.20 3379.30 3845.64 3848.64 3845.69 3296.88 1979.88 0.73 5973466.77 592692.45 N 70.33717550 W 149.24791799 5542.80 60.95 31.35 3342.82 3424.92 3928.16 3931.17 3928.20 3366.72 2023.84 1.58 5973537.13 592735.57 N 70.33736626 W 149.24756115 5634.48 60.75 29.83 3387.48 3469.58 4008.22 4011.24 4008.26 3435.64 2064.59 1.46 5973606.53 592775.47 N 70.33755452 W 149.24723044 5727.49 61.09 28.36 3432.69 3514.79 4089.44 4092.52 4089.50 3506.67 2104.11 1.43 5973678.03 592814.13 N 70.33774853 W 149.24690963 5821.11 60.46 28.81 3478.40 3560.50 4171.05 4174.23 4171.13 3578.41 2143.20 0.79 5973750.23 592852.35 N 70.33794450 W 149.24659233 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Sld( d031 rt-546 ) Plan V-120 (N-X)W-120W-120W-120 Generated 10/19/2004 8:01 AM Page 2 of 4 Comments Latitude Longitude N 70.33813893 W 149.24627117 6007.62 62.04 30.15 3568.46 3650.56 4334.27 4337.54 4334.39 3720.69 2223.38 1.36 5973893.45 592930.79 N 70.33833312 W 149.24594151 6101.34 60.49 29.29 3613.52 3695.62 4416.42 4419.72 4416.55 3792.05 2264.12 1.84 5973965.30 592970.66 N 70.33852804 W 149.24561078 6193.75 60.41 31.05 3659.09 3741.19 4496.79 4500.11 4496.93 3861.55 2304.52 1.66 5974035.27 593010.21 N 70.33871787 W 149.24528284 6286.37 62.23 30.54 3703.54 3785.64 4578.04 4581.36 4578.18 3931.35 2346.12 2.02 5974105.56 593050.96 N 70.33890852 W 149.24494518 6381.84 62.24 29.95 3748.02 3830.12 4662.50 4665.84 4662.66 4004.33 2388.67 0.55 5974179.04 593092.62 N 70.33910785 W 149.24459976 6474.73 61.68 29.88 3791.68 3873.78 4744.47 4747.82 4744.63 4075.39 2429.56 0.61 5974250.59 593132.64 N 70.33930195 W 149.24426783 6568.28 60.82 29.11 3836.68 3918.78 4826.44 4829.84 4826.63 4146.77 2469.94 1.17 5974322.45 593172.15 N 70.33949693 W 149.24393999 6662.39 60.24 29.42 3882.98 3965.08 4908.32 4911.77 4908.53 4218.25 2509.99 0.68 5974394.40 593211.33 N 70.33969216 W 149.24361482 6756.00 59.06 29.47 3930.28 4012.38 4989.06 4992.55 4989.29 4288.59 2549.70 1.26 5974465.21 593250.19 N 70.33988430 W 149.24329243 6850.23 60.69 29.98 3977.57 4059.67 5070.53 5074.05 5070.78 4359.37 2590.11 1.79 5974536.46 593289.74 N 70.34007761 W 149.24~. 6943.23 60.36 29.78 4023.33 4105.43 5151.47 5155.01 5151.73 4429.57 2630.45 0.40 5974607.14 593329.22 N 70.34026936 W 149.242 7036.25 59.85 29.87 4069.69 4151.79 5232.09 5235.66 5232.36 4499.53 2670.56 0.55 5974677.57 593368.47 N 70.34046045 W 149.24231123 7130.04 60.49 30.44 4116.35 4198.45 5313.43 5317.02 5313.72 4569.88 2711.43 0.86 5974748.41 593408.49 N 70.34065260 W 149.24197938 7223.72 60.55 30.37 4162.45 4244.55 5394.98 5398.57 5395.27 4640.22 2752.70 0.09 5974819.23 593448.90 N 70.34084471 W 149.24164427 7316.47 59.57 30.44 4208.74 4290.84 5475.34 5478.94 5475.64 4709.53 2793.38 1.06 5974889.03 593488.73 N 70.34103404 W 149.24131400 7409.10 61.39 31.04 4254.38 4336.48 5555.94 5559.54 5556.25 4778.81 2834.58 2.04 5974958.79 593529.09 N 70.34122324 W 149.24097946 7501.80 62.19 31.50 4298.20 4380.30 5637.62 5641.23 5637.93 4848.63 2876.98 0.97 5975029.11 593570.64 N 70.34141394 W 149.24063517 7594.29 62.17 31.48 4341.36 4423.46 5719.42 5723.03 5719.72 4918.38 2919.71 0.03 5975099.37 593612.52 N 70.34160446 W 149.24028824 7688.27 61.25 31.61 4385.90 4468.00 5802.18 5805.79 5802.47 4988.91 2963.01 0.99 5975170.41 593654.95 N 70.34179708 W 149.23993671 7781.17 60.60 30.82 4431.05 4513.15 5883.37 5886.98 5883.66 5058.35 3005.09 1.02 5975240.34 593696.19 N 70.34198673 W 149.23959503 7874.78 60.97 32.26 4476.74 4558.84 5965.07 5968.68 5965.35 5127.97 3047.82 1.40 5975310.48 593738.08 N 70.34217690 W 149.23924799 7969.40 61.43 29.69 4522.33 4604.43 6047.97 6051.59 6048.25 5199.06 3090.49 2.43 5975382.07 593779.87 N 70.34237105 W 149.23890154 8061.40 60.97 32.68 4566.66 4648.76 6128.58 6132.21 6128.85 5268.02 3132.22 2.89 5975451.52 593820.77 N 70.34255940 W 149.23856264 8154.37 60.40 33.21 4612.18 4694.28 6209.61 6213.27 6209.86 5336.05 3176.31 0.79 5975520.07 593864.02 N 70.34274520 W 149.23820467 8247.46 59.71 33.08 4658.64 4740.74 6290.23 6293.93 6290.45 5403.59 3220.41 0.75 5975588.13 593907.30 N 70.34292965 W 149.23784654 8342.02 60.00 32.76 4706.13 4788.23 6371.96 6375.71 6372.17 5472.23 3264.85 0.42 5975657.30 593950.90 N 70.34311712 W 149.23748567 8435.51 60.08 32.70 4752.82 4834.92 6452.94 6456.70 6453.12 5540.37 3308.64 0.10 5975725.95 593993.86 N 70.34330321 W 149.23713003 8529.32 59.63 32.89 4799.93 4882.03 6534.03 6537.83 6534.20 5608.56 3352.58 0.51 5975794.67 594036.97 N 70.34348946 W 149.23.2 8622.67 59.18 33.55 4847.44 4929.54 6614.34 6618.18 6614.48 5675.78 3396.60 0.78 5975862.41 594080.17 N 70.34367305 W 149.23 3 8715.89 58.31 32.80 4895.81 4977.91 6693.98 6697.87 6694.11 5742.48 3440.21 1.16 5975929.63 594122.97 N 70.34385521 W 149.236 59 8809.09 57.69 33.16 4945.20 5027.30 6772.99 6776.91 6773.10 5808.78 3483.23 0.74 5975996.44 594165.18 N 70.34403629 W 149.23571219 8902.45 56.10 31.76 4996.19 5078.29 6851.17 6855.11 6851.27 5874.76 3525.21 2.12 5976062.91 594206.35 N 70.34421648 W 149.23537127 8996.20 53.94 31.69 5049.93 5132.03 6927.98 6931.92 6928.07 5940.09 3565.60 2.30 5976128.72 594245.95 N 70.34439491 W 149.23504323 9089.68 50.53 33.00 5107.17 5189.27 7001.85 7005.80 7001.94 6002.52 3605.12 3.81 5976191.62 594284.70 N 70.34456541 W 149.23472231 9183.91 45.97 33.88 5169.90 5252.00 7072.08 7076.09 7072.16 6061.18 3643.83 4.89 5976250.74 594322.70 N 70.34472561 W 149.23440790 9277.57 42.31 33.22 5237.11 5319.21 7137.24 7141.30 7137.31 6115.52 3679.88 3.94 5976305.51 594358.08 N 70.34487402 W 149.23411509 9370.02 39.69 32.54 5306.87 5388.97 7197.86 7201.95 7197.92 6166.45 3712.81 2.87 5976356.82 594390.39 N 70.34501310 W 149.23384762 9463.20 36.25 33.16 5380.32 5462.42 7255.16 7259.27 7255.21 6214.61 3743.89 3.71 5976405.35 594420.89 N 70.34514463 W 149.23359516 9558.75 32.40 33.74 5459.21 5541.31 7308.99 7313.14 7309.04 6259.56 3773.58 4.04 5976450.66 594450.02 N 70.34526740 W 149.23335409 9651.66 28.95 33.29 5539.11 5621.21 7356.35 7360.53 7356.39 6299.07 3799.75 3.72 5976490.47 594475.72 N 70.34537529 W 149.23314148 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-120 (N-X)\V-120\V-120\V-120 Generated 10/19/2004 8:01 AM Page 3 of 4 . Comments Latitude Longitude 9745.60 27.73 32.98 5621.79 5703.89 7400.92 7405.12 7400.95 6336.41 3824.13 1.31 5976528.10 594499.64 N 70.34547727 W 149.23294349 9839.02 26.70 33.61 5704.87 5786.97 7443.62 7447.85 7443.64 6372.12 3847.58 1.14 5976564.09 594522.65 N 70.34557480 W 149.23275302 9932.91 24.93 32.39 5789.39 5871.49 7484.48 7488.73 7484.50 6406.40 3869.86 1.97 5976598.64 594544.51 N 70.34566841 W 149.23257207 10025.72 23.12 31.26 5874.15 5956.25 7522.26 7526.51 7522.28 6438.50 3889.79 2.01 5976630.97 594564.05 N 70.34575607 W 149.23241014 10118.72 20.95 28.95 5960.36 6042.46 7557.14 7561.40 7557.16 6468.66 3907.32 2.51 5976661.34 594581.21 N 70.34583844 W 149.23226778 10213.27 20.22 29.29 6048.87 6130.97 7590.36 7594.64 7590.38 6497.70 3923.49 0.78 5976690.57 594597.03 N 70.34591776 W 149.23213637 10306.22 20.65 33.37 6135.97 6218.07 7622.79 7627.08 7622.82 6525.40 3940.37 1.60 5976718.47 594613.57 N 70.34599340 W 149.23199929 10398.90 19.47 32.51 6223.03 6305.13 7654.56 7658.87 7654.59 6552.07 3957.66 1.31 5976745.35 594630.54 N 70.34606625 W 149.23185884 10493.54 19.97 34.01 6312.12 6394.22 7686.48 7690.80 7686.50 6578.77 3975.17 0.75 5976772.25 594647.73 N 70.34613916 W 149.23171656 10587.48 22.01 34.49 6399.82 6481.92 7720.08 7724.45 7720.10 6606.58 3994.12 2.18 5976800.28 594666.33 N 70.34621510 W 149.23156269 10679.95 20.74 33.41 6485.93 6568.03 7753.74 7758.15 7753.76 6634.53 4012.95 1.44 5976828.46 594684.82 N 70.34629143 W 149.23. 10774.32 21.41 33.50 6573.99 6656.09 7787.65 7792.08 7787.66 6662.84 4031.65 0.71 5976856.99 594703.18 N 70.34636875 W 149.231 10867.11 22.50 31.91 6660.05 6742.15 7822.33 7826.77 7822.34 6692.04 4050.39 1.34 5976886.41 594721.55 N 70.34644848 W 149.23110562 10959.70 22.70 33.01 6745.53 6827.63 7857.90 7862.36 7857.91 6722.06 4069.48 0.51 5976916.65 594740.29 N 70.34653047 W 149.23095049 11053.75 21.92 32.65 6832.54 6914.64 7893.59 7898.06 7893.60 6752.06 4088.84 0.84 5976946.88 594759.28 N 70.34661239 W 149.23079324 Last MWD+IFR+MS 11068.40 21.80 33.03 6846.13 6928.23 7899.04 7903.51 7899.05 6756.64 4091.80 1.27 5976951.50 594762.18 N 70.34662491 W 149.23076921 TO ( Projected) 11140.00 21.80 33.03 6912.61 6994.71 7925.62 7930.10 7925.63 6778.93 4106.29 0.00 5976973.97 594776.40 N 70.34668579 W 149.23065147 Survey Type: Definitive Survey NOTES: GYD GC MS - ( Gyrodata - gyro compassing m/s - Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) Leaal Description: Northing /VI rftUS1 Easting IXI rftUS1 Surface: 4896 FSL 1547 FEL S11 T11 N R11 E UM 5970146.49 590752.78 BHL: 1114 FSL 2715 FEL S36 T12N R11E UM 5976973.97 594776.40 . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-120 (N-X)W-120W-120W-120 Generated 10/19/2004 8:01 AM Page 4 of 4 TREE = 4-1/16" CrN . WELLHEAD = FMC GEN 5 V-120 S. NOTES: TOC 7" CSG CMT CACULATED Á"ctûÄröR - -4 KB. ELEV = 82.10' BF. ELEV = KOP= 400' ) 69' H4-1/2" X 3-112" XO, 10 = 2.992" I Max Angle = 63 @ 2628' Datum MD = 6682' :7'" : =-----i 973' H 9-5/8" TAM PORT COLLAR I """r""""'.===-"",".=="""'ff_==.=.=<=._ Datum ìVD = 6000' SS 14-1/2" TBG, 12.6#, L-80, .015 bpf, 10 = 3.958" I 69' ( · 2264' !-i3-1/2" HES X NIP, 10 = 2.813" I I WA TER INJECTION MANDRELS ST MD ìVD DEV 1YÆ VLV LATCH PORT DATE w L 2 2644 2017 63 MMG DMY RK 0 04/30105 1 5737 3519 61 MMG DMY RK 0 04/30105 19-5/8" CSG, 40#, L-80, 10 = 8.835" H 4110' I~ .. Minimum ID = 2.813" @ 2264' I 6994' H 7" MARKER w IRA TAG I 3-1/2" HES X NIPPLE · I I 10580' H3-1/2" HES X NIP, 10 = 2.813" I :'8: .2:S. 10601' H 7" X 3-1/2" BKR PREMIER PKR, ID = 2.875" I · I 1 10656' H3-1/2" HES X NIP, 10 = 2.813" I · I 1 10703' 1--13-1/2" HES X NIP, ID = 2.813" I 13-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.990" I 10715' I- -. 1 10715' -þ-1/2" WLEG, 10 = 2.905" I I 1 HELMDTTNOTLOGGED I ÆRFORA TION SUMMARY REF LOG: MWD ON 01/03/05 ANGLEATTOPÆRF: 22 @ 10778' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 10750' H7" MARKERw/RA TAG I 2-1/2" 4 10778 - 10864 0 04/12/05 2-1/2" 4 10940 - 10968 0 04/12/05 10975' H7" MARKERw/RA TAG I I PBTD I 11037' I 17" CSG, 26#, L-80, .0361 bpf, ID= 6.276" I 11122' I DATE REV BY COMMENTS DATE REV BY COMMENTS GPB BOREALIS 09/20/04 LV SUSPENDED w /4-112" TBG WELL: V-120 03/22/05 JDM/TLH ORIGINAL COM PLETION ÆRMrT No: 2041790 04/26/05 RMH/TLH GLV C/O (4/11) & ADÆRF (4/12) API No: 50-029-23225-00 04/30105 KSB/PJC C/O GL V SEC 11, T11N, R11E, 4896' FSL, 1547' FEL BP Exploration (Alaska) . . :k~ -(79 02/11/05 Scblumberger NO. 3335 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Bath Company: Alaska 011 & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # BL CD Log Description Date Color V-120 10687715 TEMPERATURE LOG 12/05/04 1 V-120 10667715 US IT 12/05/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ k" J Date Delivered; ~ , , ~ ,-;:] 'ç: - 'ç: ~\ ~ (iJ ^ ~v fÆ IJ fe, mJ J )\\ ~,áù~~/;~ /i /. rXtJt¡- /'7 9 i FRANK H. MURKOWSKI, GOVERNOR i / ALASIiA OIL AND GAS / CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-120 Sundry Number: 305-029 Dear Mr. Crane: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a ·day or weekend. A person may not appeal a Commission decision to Superio ourt unless rehearing has been requested. DATED thiS!l. day of February, 2005 Encl. · STATE OF ALASKA . ALASKA OPAND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 \}-Ic, A:- ·z.ICfJ too$' Dß 2(9 1. Type of Request: Re-Enter·öpS.~own o Abandon o Repair Well o Plug Perforations o Stimulate BOther o Alter Casing o Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development D Exploratory 204-17(/ 304-367 /' 3. Address: D Stratigraphic 181 Service /' 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23225-00-00 7. KB Elevation (ft): 82.1' 9. Well Name and Number: PBU V-120 / 8. Property Designation: 10. Field I Pool(s): ADL 028238 Prudhoe Bay Field / Borealis Pool 11. PRESENT WELL CONDITION SUMMARY > >. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11140 6996 11036 6898 None None Casina Length Size MD TVD Burst Collapse Structural 109' 20" 109' 109' 1490 470 Surface 4112' 9-5/8" 4112' 2723' 5750 3090 Pr 11122' 7" 11122' 6978' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: 1 Tubing MD (ft): None None 4-1/2",12.6# L-80 (Kill String) 4352' Packers and SSSV Type: None Packers and SSSV MD (ft): None 12. Attachments: 13. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory D Development 181 Service D Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 11 , 2005 DOil DGas D Plugged D Abandoned 16. Verbal Approval: Date: 181 WAG D GlNJ DWINJ D WDSPL Commission R~resentative: 17. I hereby certify th~~e foregoing is true and correct to the best of my knowledge. Contact SA-ane Gagliardi, 564-5251 Printed Name Lo II Crane Title Senior Drilling Engineer SiQnature !~ """--( /c;- Prepared By NameINumber. Phone 564-4089 Date '2 J7-0:...- Terrie Hubble, 564-4628 L/' Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3L::::5'::' /~:::)?' D Plug Integrity IJ('BOP Test D Mechanical Integrity Test D Location Clearance Other: Te s,t- BoP£- to.......¡SSOO ps.t'. S""oeq".~~D +. RBDMS BFL FEB 1 v RBDMS 8FL FES 1 0 200, Date ~I ¿ Appmv~~,. I~. ~r.b( APPROVED BY COMMISSIONER THE COMMISSION Form 10-403 ~e( OQ ~ S/bmfln Duplicate f) (' j Oì\llJl~lAL . . Well: V-120 AFE: BRD5M4173 Nabors 7ES Classification: Completion AFE Amount: Days: 15.7 $ 3,011 M Estimated Completion Date: February 11, 2005 Prepared By: Shane Gagliardi WELL OBJECTIVES: ,. NO ACCIDENTS, SPILLS OR ENVIRONMENTAL VIOLATIONS 2. REVIEW AND FOLLOW ALL PROCEDURES 3. NO POLICY OR REGULA TORY VIOLA TIONS 4. RETRIEVE EXISTING 4-W' KILL STRING AND RE-RUN 4-112" L-80 COMPLETION No portion of this work is so urgent that time cannot be taken to do it with"ut injuring yourself or others ~ J@~<~ Ops. Drill~ineer Dat~enior Drilling Engineer Distribution: Mike Schultz Bruce Smith Shane Gagliardi/Well File Nabors rig 7ES Baker M-I Nabors Schlumberger Contacts Rotary Drilling Manager Senior Drilling Engineer Operations Drilling Engineer Borealis Team Leader GC-2 Control Room Area Managers Production Engineer " I 2->1'-=-,' .(//j'~ </11", Date Rotary Drilling Manager ' Date 1 Copy Server Original 6 copies E-mail E-mail E-mail E-mail Name Mike Schultz Lowell Crane Shane Gagliardi Gil Beuhler Main Contact number B. Robinson / S. Croghan Bruce Smith Attachments: Tubing Tally Current Well Schematic Proposed Well Schematic Work CellI Pager Home 564-4896 240-8075 622-9355 564-4089 240-8054 868-7711 564-5251 632-6789 373-1481 564-5143 440-8001 653-7001 659-4912 659-4236 x 521 659-4902 659-4236 x 521 564-5093 440-8008 345-3948 . . Current Well Information Well Name: V-120 API Number: 50-029-23225-00 PTD: 204-179 ~u~l:e~P;~tus: ~~~~~~~Cd CJpç. ~LufJ,w^- W4A- BHP: 2600 psi @ 6600' TVDss TKUP. BHT: 1550 F @ 6600' TVDss TKUP. Mechanical Condition: Tubing: 4-%", 12.6#/ft, L-80 TCII tubing @ 4352' MD TO / PBTD: 11122' MD/11037' MD Kick Off Point: 300' MD Max Angle (to packer): 62.720 at 2628' MD Head: FMC Gen 5 . Tbg. Spool: FMC 11" Gen 5 5M Tbg. Hanger: FMC 11" x 4-%" NSCT Tbg. Head Adapter: FMC 11" 5k stdd bottom x 4-1/16" 5k stdd top Tree: CIW 4-1/16" 5M BPV Profile: 4" CIW 'H' BPV SSSV: None Control line: None Perforations: None Tubing Fluids: Annulus Fluids: PPPOT - IC: PPPOT - T: 8.9 ppg brine / diesel 8.9 ppg brine / diesel Materials Required for Workover Operations Completion: -10600' 1 1 1 2 4 3-%",9.2#, L-80 TCII Tubing Tree currently on well is new and will be reused Tubing hanger/adapter flange (see note above) 3-%" x 7" Baker Premier Production Packer GLM: 3-%" x 1.5" MMG 3-%" X Nipples Short Sco~ Well V-120 was drilled September of 2004 and was suspended prior to initial completion. A USIT log was run on 5 / December 2004 to evaluate cement quality for isolation in the Kuparik and Schrader Bluff sands. The kill string currently in the hole will be pulled and stood back. Any tubing that does not pass a visual inspection of body and connection will be laid down. Run completion with Baker Premier permanent packer and GLM mandrels. V-120 Page 2 . . Hazards and Continqencies ***See Pad Data Sheet for details of previous wells drilled on L Pad 1) Hydrogen Sulfide · V-pad is not considered an H2S drill site. Standard Operating Procedures for H2S precautions should beré"Viewed and followed at all times. · Reference SOP: Hvdroaen Sulfide 2) Well Control Pressures · Production Section max anticipated BHP: · Production Section max surface pressure: · Planned completion fluid: 3) Rig Move Issues and Shut-in Requirements · There should be no surface shut in requirements for the rig move to V-120. The V-120 is at the end of the well row. 2600 psi (7.6 ppg EMW) @ 6600' TVD - Kuparuk 1940 psi (based on BHP & full gas column at 0.1 psi/ft) r If.9PPg brine / 6.8 ppg diesel Reference SOP: Dri/língIWorkover Close Proximity Surface and Subsurface Wells Workover Fluid Program and Properties: 8.9 ppg brine and 6.8 ppg diesel Present Casingrrubing Program: CsglTubing WtlFt Grade Conn Top Bottom 20" 91.5# H-40 Welded Surface 110' 9-5/8" 40# L-80 BTC Surface 4109' 7" 26# L-80 BTC-mod Surface 11122' 4-%" Tubing 12.6# ·L-80 TCII Surface 4352' Proposed Tubing Program: 3-W'Tubing 9.2# L-80 TCII Surface 10600' The DroDosed tubina Droaram is to re-use the existina tubina exceDt for ioints that fail an on site visual insDection of the threads and tube body. Pre-RiCl Operations o 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time. PPPOT-T and IC. o 2 Set a BPV in the tubin han er. o 3 Remove the wellhouse & flow line. Level the ad as needed for the ri . V-120 Page 3 . . V-120 Detailed Operations * Complete a pre-rig inspection with the Pad Operator prior to the rig moving on the well * * Notify the AOGCC representative 24 hours in advance to witness BOP testing * 1. Note any tubing and annular pressures (trapped gas). Bleed-off as required prior to MIRU. MIRU Nabors 7ES. RU to the tree to circulate out the diesel freeze protection. Pull BPV with lubricator. Confirm the amount of diesel used to freeze protect on the hand over form. Circulate out the diesel freeze protection and displace it with seawater. Confirm the well is dead. 2. Set and test TWC. ND tree and adapter flange. Send tree and adapter in for inspection and/or repairs only if needed. The adapter and tree will be re-used on th~1I if possible. 3. NU BOPE. Test the BOPE to 250 psi low and 35~~"Ypsi high. Test the annular to 250 psi low and 3500 psi t"" high. Pull the TWC with lubricator. v/' 4. PU landing joint and screw into the tubing hanger. The tubing hanger running threads are 4-W' NSCT, the bottom connection is also 4-%" NSCT. 5. Pull and lay down the 4-%" tubing. Send tubing in for inspection and re-use on other wells. ~ 6. Prepare to run tubing. Run the 3-%", 9.2#/ft, L-BO TCII tubing. Rabbit the tubing and jewelry before RIH. See RP Completion Desian and Runnina. · Unique Wireline Entry Guide · 10' 3-%" 9.2# L-BO TCII pup joint · HES 3-%" X nipple · 1 joint 3-%" 9.2# L-BO TCII tubing · HES 3-W' X nipple with RHC plug · 1 joint 3-%" 9.2# L-BO TCII tubing · Baker 3-%" x 7" Premier packer · 10' 3-%" 9.2# L-BO TCII pup joint · HES 3-%" X nipple · 10' 3-%" 9.2# L-BO TCII pup joint · 3-W' 9.2# L-BO TCII tubing · 10' 3-W' 9.2# L-BO TCII pup joint · 3-%" MMG GLM #1 with DCK @ 5727' MD/3513' TVD · 10' 3-%" 9.2# L-BO TCII pup joint · 3-%" 9.2# L-BO TCII tubing · 10' 3-%" 9.2# L-BO TCII pup joint · 3-%" MMG GLM #2 with dummy valve @ 262B' MD/2010' TVD · 10' 3-%" 9.2# L-BO TCII pup joint · 3-%" 9.2# L-BO TCII tubing · 10' 3-W' 9.2# L-BO TCII pup joint · 3-%" X nipple @ 2253' MD/1BOO' TVD · 10' 3-%" 9.2# L-BO TCII pup joint · 3-W' 9.2# L-BO TCII tubing · 3- W' Space out pups · 4-%" x 3-%" x-oxer V-120 Page 4 TREE 4-1/16" CPN WELLHI;AD = FMC ACTUATOR- KB. ELEV = BF. ELEV = i<OP- Max Angle = Datum MD = Datum ìVD- I 9-5/8" CSG, 40#, L-80, 10 = 8.835" I I 4-1/2" TBG, 12.6#, L-80, TC11, 10 = 3.958" . ....... 4109' µ H 4352' I I PBTD I 11037'MD 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" I 11122'MD DATE REV BY COMMENTS 930/04 LV Suspended wI 43524112 tbg DATE REV BY V-120 SAFETY NOTES: Three dow nhole pressure/tel11> gages. One set above Schrader ,one on either side of X-nipple below injection mandrels. . -'" I ~. 973' H 9-5/8" TAM PORT COLLAR , ¡.... ~ DWm.. Freeze protect to 2700' "\ 8.9 ppg brine ~ COMMENTS GPB BOREALIS WELL: V-120 PERMIT No: 204-179 API No: 50-029-23225 BP Exploration (Alaska) 4-1/16" CrN W8..LHEAD = FMC ACTUATOR = KB. ELEV = 82.1 BF. ELEV = KOP = 300' Max Angle = 62.72 Datum MD = Datum lVD = . 4-1/2" X 3-1/2" X-Over I I 2253'MD H 3-1/2" HES X NIP, ID = 2.813" I 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 4109' Minimum ID = 2.813" @ XXXX' 3-1/2" HES X Nipple 3-1/2" lEG, 9.2#, L-80 TCII, .00870 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: TCPÆRF Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE V -120 XXXX' I PBTD I 17" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" DATE 08/03/04 02/03/05 COMMENTS PRoroSED COMPLETION (Pl) PRoroSED COMPLETION (P3) DATE REV BY NM STG REV BY COMMENTS . 1 jt 4-1/2" TBG, 12.6#, L-80 TCII, .01522 bpf. ID = 3.958" 973' M D H 9-5/8" TAM PORT COLLAR I 4352' M D H TOC Not Logged I GAS LIFT MANDRELS ST MD lVD DEV ïYÆ VLV LATCH roRT DATE 2 2628' 2010 63 MMG Du BK-5 1.5" 1 5727' 3514' 61 MMG DCK BK-5 1.5" IXXXX'MDH 3-1/2"HESXNIP, ID = 2.813" I 110600' MDH 7" X 3-1/2" Premier A<R, ID = 2.875" I (' IXXXX'MD- 3-1/2" HES X NIP, ID = 2.813" I I XXXX' MD 1-1 3-1/2" HES X NIP,ID = 2.813" XXXX' MDH 3-1/2" WLEG I GPB BOREALIS WELL: V-120 ÆRMrr No: 204-179 API No: 50-029-23225 BP Exploration (Alaska) . . d TUBING SUMMARY RIG Nabors 9ES Date 9/27/2004 WELL # V120 TUBING 4.5 L·80 TC 11 TBG WT. 12.6 111 JTS ON RACK 111 JTS RAN 23.50 OKBTO TS 4323.65 FT ON RACK 4323.65 FT RAN ITEM Description includes: SIZE, TYPE, CONNECTION (JTS #-#) ITEM ID OD LENGTH TOP BOTTOM 4.5" WLEG 3.998 5.022 1.39 4350.38 .4351.77 111 jts 4.5" 12.6#, L 80, TC11 Tbg 3.998 5.022 4323.65 26.73 ' 4350.38 4.5", 12.6#, L-80 TC- Hanger Pup 3.958 4.500 2.42 24.31 26.73 FMC 11" x 4.5" TC~ Hanger ( TC- Lift Threads) .81 23.50 24.31 Nabors 9ES RT to TS 23.50 23.50 SCHLUMBERGER Survey report Client.......... .........: BP Exploration (Alaska) Inc Field. . . . . . . . . . . . . . . . . . . .: Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-120 API number..... ..........: 50-029-23225-00 Engineer.......... .......: St. Amour Rig:.....................: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 53.60 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 82.10 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 31.28 degrees 26-Sep-2004 10:50:40 Spud date................: Last survey date. . . . . . . . . : Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 19-5ep-04 26-Sep-04 122 0.00 ft 11140.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date............: 18-Sep-2004 Magnetic field strength..: 1151.54 HCNT Magnetic dec (+E/W-).....: 24.84 degrees Magnetic dip.............: 80.82 degrees ----- MWD survey Reference Reference G..............: Reference H. . . . . . . . . . . . . . : Reference Dip.......... . . : Tolerance of G...........: Tolerance of H...........: Tolerance of Dip...... . . . : Criteria --------- 1002.68 mGal 1151.78 HCNT 80.80 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.91 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.91 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ò ~,-/71 SCHLUMBERGER Survey Report 26-Sep-2004 10:50:40 Page 2 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.32 302.71 100.00 100.00 0.01 0.15 -0.23 0.28 302.71 0.32 GYR None 3 200.00 0.37 303.30 100.00 200.00 0.03 0.48 -0.74 0.88 302.93 0.05 GYR None 4 300.00 1. 94 17.25 100.00 299.98 1. 68 2.27 -0.51 2.33 347.41 1. 87 GYR None 5 400.00 3.43 24.09 100.00 399.86 6.29 6.62 1. 22 6.73 10.40 1. 52 GYR None 6 500.00 6.57 26.43 100.00 499.47 14.96 14.48 4.98 15.31 19.00 3.15 GYR None . 7 600.00 10.43 26.61 100.00 598.35 29.69 27.70 11.59 30.02 22.70 3.86 GYR None 8 700.00 15.51 26.52 100.00 695.77 52.05 47.77 21.62 52.43 24.35 5.08 GYR None 9 800.00 20.01 36.26 100.00 791.00 82.44 73.55 37.72 82.65 27.15 5.38 GYR None 10 900.00 23.61 35.36 100.00 883.83 119.47 103.68 59.43 119.51 29.82 3.62 GYR None 11 944.28 24.49 34.04 44.28 924.27 137.48 118.52 69.70 137.50 30.46 2.33 MWD IFR MS 12 1038.39 28.39 29.53 94.11 1008.52 179.35 154.17 91.66 179.36 30.73 4.66 MWD IFR MS - 13 1131.22 31.49 28.80 92.83 1088.96 225.64 194.63 114.22 225.67 30.41 3.36 MWD IFR MS - 14 1224.02 34.73 28.97 92.80 1166.68 276.28 239.00 138.71 276.34 30.13 3.49 MWD IFR MS - 15 1319.11 38.11 29.59 95.09 1243.18 332.70 288.23 166.33 332.78 29.99 3.58 MWD IFR MS 16 1412.27 40.96 30.48 93.16 1315.03 391.97 339.56 196.02 392.07 30.00 3.12 MWD IFR MS - 17 1505.47 43.01 29.61 93.20 1384.30 454.30 393.52 227.22 454.41 30.00 2.29 MWD IFR MS - 18 1599.04 46.87 29.28 93.57 1450.52 520.35 451.07 259.70 520.49 29.93 4.13 MWD IFR MS - 19 1694.03 51.79 29.69 94.99 1512.41 592.34 513.77 295.16 592.52 29.88 5.19 MWD IFR MS - 20 1784.16 53.43 31.28 90.13 1567.14 663.94 575.47 331.49 664.12 29.94 2.30 MWD IFR MS 21 1879.46 56.17 31.05 95.30 1622.07 741.80 642.10 371.79 741.97 30.07 2.88 MWD IFR MS . - 22 1972.82 55.74 31.01 93.36 1674.33 819.16 708.38 411.67 819.31 30.16 0.46 MWD IFR MS - 23 2066.25 55.77 31.34 93.43 1726.91 896.39 774.46 451.65 896 . 54 30.25 0.29 MWD IFR MS - 24 2159.56 59.09 31.37 93.31 1777.13 975.02 841.61 492.56 975.15 30.34 3.56 MWD IFR MS - - 25 2252.68 58.13 30.56 93.12 1825.64 1054.50 909.76 533.46 1054.63 30.39 1. 27 MWD IFR MS 26 2346.46 60.59 30.48 93.78 1873.43 1135.18 979.27 574.43 1135.31 30.40 2.62 MWD IFR MS - 27 2439.97 59.84 29.98 93.51 1919.88 1216.32 1049.39 615.29 1216.47 30.38 0.93 MWD IFR MS - 28 2534.30 61. 22 30.55 94.33 1966.28 1298.43 1120.31 656.68 1298.59 30.38 1. 55 MWD IFR MS - 29 2627.69 62.72 30.65 93.39 2010.17 1380.86 1191. 27 698.65 1381.02 30.39 1. 61 MWD IFR MS - 30 2722.31 61. 73 30.40 94.62 2054..26 1464.57 1263.38 741.17 1464.74 30.40 1. 07 MWD IFR MS SCHLUMBERGER Survey Report 26-Sep-2004 10:50:40 Page 3 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2814.82 60.62 30.16 92.51 2098.86 1545.60 1333.37 782.03 1545.79 30.39 1. 22 MWD IFR MS - 32 2908.07 61.30 30.18 93.25 2144.13 1627.11 1403.85 823.01 1627.31 30.38 0.73 MWD IFR MS - 33 3002.18 60.60 29.91 94.11 2189.83 1709.36 1475.07 864.20 1709.58 30.36 0.78 MWD IFR MS - 34 3095.76 61. 93 31.00 93.58 2234.82 1791. 41 1545.80 905.79 1791.63 30.37 1. 75 MWD IFR MS - 35 3190.11 61.21 30.69 94.35 2279.73 1874.37 1617.03 948.33 1874.60 30.39 0.82 MWD IFR MS 36 3283.15 61.02 30.69 93.04 2324.68 1955.83 1687.09 989.91 1956.06 30.40 0.20 MWD IFR MS . - 37 3375.71 60.61 30.71 92.56 2369.81 2036.64 1756.57 1031.17 2036.87 30.41 0.44 MWD IFR MS - 38 3469.95 62.57 29.44 94.24 2414.65 2119.51 1828.30 1072.70 2119.75 30.40 2.39 MWD IFR MS - 39 3563.84 62.19 29.57 93.89 2458.18 2202.66 1900.70 1113.67 2202.94 30.37 0.42 MWD IFR MS - 40 3656.58 61.73 29.04 92.74 2501.77 2284.46 1972.08 1153.73 2284.78 30.33 0.71 MWD IFR MS 41 3749.70 61.12 29.08 93.12 2546.31 2366.18 2043.56 1193.45 2366.53 30.29 0.66 MWD IFR MS - 42 3840.84 60.65 29.41 91. 14 2590.66 2445.75 2113.04 1232.35 2446.14 30.25 0.60 MWD IFR MS - 43 3936.77 60.11 29.07 95.93 2638.07 2529.09 2185.80 1273.09 2529.52 30.22 0.64 MWD IFR MS - 44 4029.64 61.41 30.04 92.87 2683.44 2610.09 2256.29 1313.06 2610.55 30.20 1. 67 MWD IFR MS - 45 4061.52 61.37 30.17 31.88 2698.70 2638.07 2280.50 1327.10 2638.54 30.20 0.38 MWD IFR MS 46 4136.97 59.59 30.76 75.45 2735.88 2703.71 2337.09 1360.38 2704.19 30.20 2.46 MWD IFR MS - 47 4236.28 59.16 30.62 99.31 2786.47 2789.17 2410.58 1404.00 2789.65 30.22 0.45 MWD IFR MS - 48 4330.71 60.70 30.43 94.43 2833.78 2870.88 2480.98 1445.51 2871.36 30.23 1. 64 MWD IFR MS - 49 4423.67 61.84 31.18 92.96 2878.46 2952.39 2550.99 1487.25 2952.87 30.24 1. 42 MWD IFR MS - 50 4517.51 61. 26 31.00 93.84 2923.17 3034.90 2621. 64 1529.86 3035.37 30.27 0.64 MWD IFR MS 51 4610.65 61.39 32.44 93.14 2967.86 3116.61 2691.15 1572.82 3117.06 30.30 1. 36 MWD IFR MS . - 52 4703.82 60.14 33.03 93.17 3013.36 3197.88 2759.54 1616.78 3198.29 30.37 1.45 MWD IFR MS - 53 4796.71 60.43 33.63 92.89 3059.41 3278.50 2826.94 1661.11 3278.86 30.44 0.64 MWD IFR MS - 54 4890.61 60.49 34.82 93.90 3105.71 3360.09 2894.49 1707.06 3360.38 30.53 1.10 MWD IFR MS - 55 4984.05 60.31 34.65 93.44 3151.86 3441.19 2961.26 1753.35 3441.41 30.63 0.25 MWD IFR MS 56 5077.39 60.02 34.90 93.34 3198.30 3522.00 3027.77 1799.53 3522.17 30.72 0.39 MWD IFR MS - 57 5168.79 60.90 34.48 91.40 3243.36 3601.38 3093.15 1844.79 3601.50 30.81 1. 04 MWD IFR MS - 58 5262.04 61.14 33.51 93.25 3288.54 3682.86 3160.78 1890.40 3682.95 30.88 0.95 MWD IFR MS - 59 5354.76 60.58 33.38 92.72 3333.69 3763.79 3228.35 1935.03 3763.86 30.94 0.62 MWD IFR MS - 60 5448.50 61.19 33.03 93.74 3379.30 3845.64 3296.88 1979.88 3845.69 30.99 0.73 MWD IFR MS SCHLUMBERGER Survey Report 26-Sep-2004 10:50:40 Page 4 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5542.80 60.95 31.35 94.30 3424.92 3928.16 3366.72 2023.84 3928.20 31.01 1. 58 MWD IFR MS - 62 5634.48 60.75 29.83 91.68 3469.58 4008.21 3435.64 2064.59 4008.26 31.00 1.46 MWD IFR MS - 63 5727.49 61. 09 28.36 93.01 3514.79 4089.44 3506.67 2104.11 4089.50 30.97 1. 43 MWD IFR MS - 64 5821.11 60.46 28.81 93.62 3560.50 4171.05 3578.41 2143.20 4171. 13 30.92 0.79 MWD IFR MS - 65 5914.47 61. 00 29.32 93.36 3606.14 4252.43 3649.60 2182.77 4252.53 30.88 0.75 MWD IFR MS 66 6007.62 62.04 30.15 93.15 3650.56 4334.27 3720.69 2223.38 4334.39 30.86 1. 36 MWD IFR MS . - 67 6101.34 60.49 29.29 93.72 3695.62 4416.42 3792.05 2264.12 4416.55 30.84 1. 84 MWD IFR MS - 68 6193.75 60.41 31.05 92.41 3741.19 4496.79 3861.55 2304.52 4496.93 30.83 1. 66 MWD IFR MS - 69 6286.37 62.23 30.54 92.62 3785.64 4578.04 3931.35 2346.12 4578.18 30.83 2.02 MWD IFR MS - 70 6381. 84 62.24 29.95 95.47 3830.12 4662.50 4004.32 2388.67 4662.65 30.82 0.55 MWD IFR MS 71 6474.73 61. 68 29.88 92.89 3873.78 4744.47 4075.39 2429.56 4744.63 30.80 0.61 MWD IFR MS - 72 6568.28 60.82 29.11 93.55 3918.78 4826.44 4146.77 2469.94 4826.63 30.78 1.17 MWD IFR MS - 73 6662.39 60.24 29.42 94.11 3965.08 4908.32 4218.25 2509.99 4908.53 30.75 0.68 MWD IFR MS - 74 6756.00 59.06 29.47 93.61 4012.38 4989.06 4288.59 2549.70 4989.29 30.73 1.26 MWD IFR MS - 75 6850.23 60.69 29.98 94.23 4059.67 5070.53 4359.37 2590.11 5070.78 30.72 1. 79 MWD IFR MS 76 6943.23 60.36 29.78 93.00 4105.43 5151.47 4429.57 2630.45 5151.73 30.70 0.40 MWD IFR MS - 77 7036.25 59.85 29.87 93.02 4151.79 5232.09 4499.53 2670.56 5232.36 30.69 0.55 MWD IFR MS - 78 7130.04 60.49 30.44 93.79 4198.44 5313.43 4569.88 2711.43 5313.72 30.68 0.86 MWD IFR MS - 79 7223.72 60.55 30.37 93.68 4244.55 5394.98 4640.22 2752.70 5395.27 30.68 0.09 MWD IFR MS - 80 7316.47 59.57 30.44 92.75 4290.84 5475.34 4709.53 2793.38 5475.64 30.67 1. 06 MWD IFR MS 81 7409.10 61.39 31.04 92.63 4336.48 5555.93 4778.81 2834.58 5556.24 30.67 2.04 MWD IFR MS . - 82 7501.80 62.19 31.50 92.70 4380.30 5637.62 4848.63 2876.98 5637.93 30.68 0.97 MWD IFR MS - 83 7594.29 62.17 31.48 92.49 4423.46 5719.42 4918.38 2919.71 5719.72 30.69 0.03 MWD IFR MS - 84 7688.27 61. 25 31.61 93.98 4468.00 5802.18 4988.91 2963.01 5802.47 30.71 0.99 MWD IFR MS - 85 7781. 17 60.60 30.82 92.90 4513.15 5883.37 5058.34 3005.08 5883.65 30.71 1. 02 MWD IFR MS 86 7874.78 60.97 32.26 93.61 4558.84 5965.06 5127.97 3047.82 5965.34 30.73 1.40 MWD IFR MS - 87 7969.40 61. 43 29.69 94.62 4604.43 6047.97 5199.06 3090.49 6048.25 30.73 2.43 MWD IFR MS - 88 8061.40 60.97 32.68 92.00 4648.76 6128.58 5268.02 3132.22 6128.85 30.73 2.89 MWD IFR MS - 89 8154.37 60.40 33.21 92.97 4694.28 6209.61 5336.05 3176.31 6209.86 30.76 0.79 MWD IFR MS - 90 8247.46 59.71 33.08 93.09 4740.74 6290.23 5403.59 3220.41 6290.45 30.79 0.75 MWD IFR MS SCHLUMBERGER Survey Report 26-Sep-2004 10:50:40 Page 5 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8342.02 60.00 32.76 94.56 4788.23 6371.96 5472.23 3264.85 6372.17 30.82 0.42 MWD IFR MS - 92 8435.51 60.08 32.70 93.49 4834.92 6452.93 5540.36 3308.64 6453.12 30.85 0.10 MWD IFR MS - 93 8529.32 59.63 32.89 93.81 4882.03 6534.03 5608.56 3352.58 6534.20 30.87 0.51 MWD IFR MS 94 8622.67 59.18 33.55 93.35 4929.54 6614.34 5675.78 3396.60 6614.48 30.90 0.78 MWD IFR MS - 95 8715.89 58.31 32.80 93.22 4977.91 6693.98 5742.48 3440.21 6694.11 30.93 1.16 MWD IFR MS 96 8809.09 57.69 33.16 93.20 5027.30 6772.98 5808.78 3483.23 6773.10 30.95 0.74 MWD IFR MS . - 97 8902.45 56.10 31.76 93.36 5078.29 6851.17 5874.76 3525.21 6851.27 30.97 2.12 MWD IFR MS - 98 8996.20 53.94 31.69 93.75 5132.03 6927.97 5940.09 3565.60 6928.07 30.97 2.30 MWD IFR MS - 99 9089.68 50.53 33.00 93.48 5189.27 7001.85 6002.52 3605.11 7001.94 30.99 3.81 MWD IFR MS - 100 9183.91 45.97 33.88 94.23 5252.00 7072.08 6061.18 3643.83 7072.15 31.01 4.89 MWD IFR MS 101 9277.57 42.31 33.22 93.66 5319.21 7137.24 6115.52 3679.88 7137.31 31.04 3.94 MWD IFR MS - 102 9370.02 39.69 32.54 92.45 5388.97 7197.86 6166.45 3712.81 7197.92 31.05 2.87 MWD IFR MS - 103 9463.20 36.25 33.16 93.18 5462.42 7255.16 6214.61 3743.89 7255.21 31.07 3.71 MWD IFR MS - 104 9558.75 32.40 33.74 95.55 5541. 31 7308.99 6259.56 3773.58 7309.04 31.08 4.04 MWD IFR MS - 105 9651. 66 28.95 33.29 92.91 5621.21 7356.35 6299.07 3799.75 7356.39 31. 10 3.72 MWD IFR MS 106 9745.60 27.73 32.98 93.94 5703.89 7400.92 6336.41 3824.13 7400.95 31.11 1.31 MWD IFR MS - 107 9839.02 26.70 33.61 93.42 5786.97 7443.61 6372.12 3847.58 7443.64 31.12 1.14 MWD IFR MS - 108 9932.91 24.93 32.39 93.89 5871.49 7484.48 6406.40 3869.86 7484.50 31.13 1. 97 MWD IFR MS - 109 10025.72 23.12 31.26 92.81 5956.25 7522.26 6438.50 3889.79 7522.28 31.14 2.01 MWD IFR MS - 110 10118.72 20.95 28.95 93.00 6042.46 7557.13 6468.66 3907.32 7557.16 31.13 2.51 MWD IFR MS 111 10213.27 20.22 29.29 94.55 6130.97 7590.35 6497.70 3923.49 7590.38 31.12 0.78 MWD IFR MS . - 112 10306.22 20.65 33.37 92.95 6218.07 7622.79 6525.40 3940.37 7622.82 31.13 1. 60 MWD IFR MS - 113 10398.90 19.47 32.51 92.68 6305.13 7654.56 6552.07 3957.66 7654.59 31.13 1.31 MWD IFR MS - 114 10493.54 19.97 34.01 94.64 6394.22 7686.47 6578.77 3975.17 7686.50 31.14 0.75 MWD IFR MS - 115 10587.48 22.01 34.49 93.94 6481. 92 7720.08 6606.58 3994.12 7720.10 31.16 2.18 MWD IFR MS 116 10679.95 20.74 33.41 92.47 6568.03 7753.74 6634.53 4012.94 7753.75 31.17 1.44 MWD IFR MS - 117 10774.32 21. 41 33.50 94.37 6656.09 7787.65 6662.84 4031.65 7787.66 31.18 0.71 MWD IFR MS - 118 10867.11 22.50 31.91 92.79 6742.15 7822.33 6692.04 4050.39 7822.34 31.18 1. 34 MWD IFR MS - 119 10959.70 22.70 33.01 92.59 6827.63 7857.90 6722.06 4069.48 7857.91 31.19 0.51 MWD IFR MS - 120 11053.75 21.92 32.65 94.05 6914.64 7893.59 6752.06 4088.84 7893.60 31.20 0.84 MWD IFR MS . SCHLUMBERGER Survey Report 26-Sep-2004 10:50:40 Page 6 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11068.40 21. 80 33.03 14.65 6928.23 7899.04 6756.64 4091.80 7899.05 31.20 1. 27 MWD IFR MS 122 11140.00 21.80 33.03 71.60 6994.71 7925.62 6778.93 4106.29 7925.63 31.21 0.00 Projected To TD [(c)2004 IDEAL ID8 1C_02] . . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No V-120 Date Dispatched: 2-Sep-04 Installation/Rig Nabors 9ES Dispatched By: J.Bosse Data No Of Prints No of Floppies Surveys 2 1 ~/ ^ . / ~uvÁ r) rJJ Please sign and return to: James H. Johnson Received By: BP Exploration (Alaska) Inc. ~ crst'-- Petrotechnical Data Center (LR2-1) )JH L( 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private )C) \.{ -17 '1 I:; 'i J¿ ~u~uŒ (ill ¡. I I I FRANK H. MURKOWSKI, GOVERNOR / ¡ I f j ¡ C::<O t./ - I 7'1 . AI~SIiA OIL AlQ) GAS CONSERVATION COMMISSION / l 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V -120 Sundry Number: 304-367 Dear Mr. Crane: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF TjlE COMMISSION DATED this~ day of October, 2004 Enc!. " ~iGJ\- 1011/2001 .. STATE OF ALASKA _ ALASKA O~ND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 ~~o .. ^ oJ ï:::-J' > 1. Type of Request: <fqJ,fQ Ji,¡ -~Q-~-~--~J~tJ- o Abandon o Repair Well o Plug Perforations o Stimulate o Oth ,14i'" I" .""., , o Alter Casing o Pull Tubing o Perforate New Pool o Waiver o Time E~eHêpz, <001 o Change Approved Program a Operation Sh~own o Perforate o Re-Enter Suspended Well I?:'h O/~J' 0/'"190'... . Co~"- 2. Operator Name: 4. Current Well Class: 5. Permit To [)rill Number "'J'J'IQ BP Exploration (Alaska) Inc. o Development o Exploratory 204-179 / 'I) 3. Address: o Stratigraphic 181 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23225-00-00 7. KB Elevation (ft): Plan RKB = 81.5 9. Well Name and Number: PBU V-120 / 8. Property Designation: 10. Field I Pool(s): ADL 028238 Prudhoe Bay Field I Borealis Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11140 6996 11036 6898 None None CasínQ Lenqth Size MD TVD BUrst CollaPse Structural r.nnrllJr.tnr 109' 20" 109' 109' 1490 470 Surface 4112' 9-5/8" 4112' 2723' 5750 3090 Intp.rmp.rli~tp. Production 11122' 7" 11122' 6978' 7240 5410 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): None None 4-112", 12.6# L-80 (Kill String) 4352' Packers and SSSV Type: None Packers and SSSV MD (ft): None 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program 14. Estimated Date for Septem þe'f"3"o.)004 15. Well Status after proposed work: Commencing Operations: DOíl o Gas o Plugged o Abandoned 16. Verbal Approval: .~ 181 WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Neil Magee, 564-5119 Printed Name Lowell Crane Title Senior Drilling Engineer SiQnatureL ):k ... .L~,- rol (,.0" f~L- (0 Nt. Prepared By Name/Number: Phone 564-4089 Date 101 I 10,,\ Terrie Hubble, 564-4628 , Commission Use Only I Sundry Number: . ~ 4· 3 (p -¡ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: S"b'eq"em~..^ I C -. 40 s V' ttvVl' ¡,q; (( 1'" i~<) t'vt ð--f...Æ v..~t ',: Yl (. . v Appmved· U APPROVED BY Date /ô/ ¡ /r;tf ,/ ..,/ COMMISSIONER THE COMMISSION Form 10-403 R~ o~ "'--"" S/bmifln Dúplicate ORIGINAL R80MS Bfl. OCT 0 7 200~ bp . . To: Winton Aubert - AOGCC Date: September 30, 2004 From: Neil Magee - BPXA GPB Drilling & Wells Subject: V-120 Sundry- Suspend Well Awaiting Completion Equipment API No. 50-029-23225 Dear Mr. Aubert, Attached is a Sundry Application for the V-120 well. As a result of the delay in the arrival of some critical completion components - feed through packers and downhole pressure/temp gages we have elected to I' postpone the completion until early January. The well was left with production casing run/cemer]ted and pressure tested, production casing filled with kill wt brine and a kill string / x-mas tree installed. ./ Once operations recommence the well details will remain the same as in the original Permit to Drill Application. If you have any questions or require any additional information, please contact me at 564-5119. Scope Completion Operations 1. MIRU Nabors 9ES 2. Nipple up and test BOP's. 3. Circulate out diesel freeze protect and recover kill string. 4. Perforate Schrader intervals 5. Complete well with a 4-1/2" x 3-1/2" completion string. 6. ND and install surface tree. / 7. Rig down and move off. Neil Magee Prudhoe Bay Drilling Engineer V-120 Sundry Application TREE'" WELLHEAD - 'W"'''''''' "m""""" ,~",,,ww~~n'~ ACTUATOR = ,..·.,ù,.,,"'~,~w·,··,···'·'wum.·m~__'N KB. ELEV = ,-.-.-.-__._.___.__m_.m,mmw""""WU,'^''''WW'^''·_'N,,'''' , BF. ELEV = i<õP---;=~w, N"'W""^""" ~)(.~~§I!~m~ Datum MD = Dail.Jm~fV·D·;~~~-~~-~~ 4-1/16" CrN FMC . V-120 / m--'_~__=m' I 9-5/8" CSG, 40#, L-80, 10 = 8.835" I ....... 4109' µ 1 4-1/2" TBG, 12.6#, L-80, TC11, ID = 3.958" H 4352' I 1 PBTD I 11037'MD 17" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1 11122'MD DA TE REV BY COMMENTS DA TE REV BY 930/04 LV Suspended wI 43524112 tbg - 8.9 ppg brine COMMENTS .......1 973' ~ SAFETY NOTES: Three dow nhole pressure/temp gages. One set above Schrader ,one on either side of X-nipple below injection mandrels. H 9-5/8" TAM PORT COLLAR 1 ~ Freeze protect to 2700' ~ GPB BOREALIS WELL: V -120 ÆRMrT No: 204-179 API No: 50-029-23225 BP Exploration (Alaska) . ~1r~1rŒ (ill~ ~~~~[{~ . AlfASIiA. OIL AlÐ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-120 BP Exploration (Alaska) Inc. Permit No: 204-179 Surface Location: 4896' NSL, 1547' WEL, SEC. 11, T11N, RIlE, UM Bottomhole Location: 1121' NSL, 2581' EWL, SEC. 36, T12N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). BY ORDER q~ THE COMMISSION DATED thisjbday of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. lNG Æ- 'ì I i41lCtC'4 . STATE OF ALAS. RECEIVED 1IIJLASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 42004 PERMIT TO DRILL 20 MC 25.005 Alaska Oil & Gas Cons. Commission 1a. Type of work II Drill o Redrill rb. Current Well Class o EXPlorato7 0 Development ". !::! ,.._..ple Zone ORe-Entry o Stratigraphic Test III Service 0 Development Gas o Single Zone 2. Operator Name: 5. Bond: IS! Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU V-120 ./ 3. Address: 6. Proposed Depth: 12. Field / Pool(s): / P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11200 rvD 7014 Prudhoe Bay Field I Borealis Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 028238 4896' NSL, 1547' WEL, SEC. 11, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1016' NSL, 2512' EWL, SEC. 36, T12N, R11E, UM September 19, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1121' NSL, 2581' EWL, SEC. 36, T12N, R11E, UM 2560 9500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool Surface: x-590753 y- 5970146 Zone- ASP4 (Height above GL): = 81.5 feet V-103 is 1850' away / 16. Deviated Wells: Kickoff Depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.0~ Maximum Hole Angle: 61 deQrees Downhole: 3497 Surface: 2803 18. C¡:§!OgRrogrnm: sPeeificatiOl'îs êe!iing ~þ~h Xc.f.':"'·'· .. Size Top ",:: Bõttôm V' <>0"""<>1 Hole Casinq Weiaht Grade CouDlina Lenath MD rvD MD rvD (includina staae data) 42" 20" 91.5# H-40 Weld 80' Surface 110' Surface 110' 60 sx Arctic Set (Approx.) 12-114" 9-5/8" 40# L-80 BTC 4129' Surface 4129' Surface 2742' 52 sx AS Lite, 290 sx Class 'G' '" 8-3/4" 7" 26# L-80 BTC-M 11200' Surface 11200' Surface 7014' 86 sx Class 'G', 160 sx Class 'G' /' " W ~k- 19. pRESENT WELl.. GONDITIOl'fSuMMÄRY (To be C()mpl(tt~for~e<I!iIIANP.~~Øn~!'Y Ope,.ä~iÔOI:!) : Total Depth MD (ft): Total Depth rvD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): GÍ;1sin9" < .,....... .·..Length.,,·'· / SiZe)' . ..... .',' Ti')····>/.,·.·.: :. ..··.MI:J' .' .....irvD,.···.··· Structural CondlJr:tor . Production Liner Perforation Depth MD (ft): perfOration Depth rvD (ft): ~'" 20. Attacnments IS! Filing Fee, $100 o BOP Sketch IS! Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IS! Drilling Fluid Program IS! 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify thati/;f/oregoing is true and correct to the best of my knowledge. Contact Neil Magee, 564-5119 Printed Name Low Crane Title Senior Drilling Engineer Siqnature~...,.-Gc"{ þr;¿~ Prepared By Name/Number: Phone 564-4089 Date <1-1l{ . C '-ì Terrie Hubble, 564-4628 ....... ........ if '.'5l!Æ' .....'... i.:i.. .... ....; "'i;h)i;:"; '.., '....."j, .., .ii.·.';· " i' ,ii' i;i ., ...,ii,:;",iii+·i: : Permit To Dr'itr API Number: Permit APprovtJ !(oj ~t See cover letter for Number: .20 il ~. ¡-1 9 n 7 43""12S 50- :z. - ..,..¿ .¿..- . Date: other requirements Conditions of Approval: Samples Required 0 Yes )(1' No Mud Log Require 0 Yes )8 No Hydrogen Sulfide Measures 0 Yes ~No Di~~ctional Survey Requ!red . ~ Yes 0 No Othe,Teçt g~ 40:>00 r.<¡ /vi. IT, C-e;.cw.( ßlútÚ\ 10 1 ~1U{~c J, . " Pu ñ "s (I. )li) -' '^-l \'-nv_te '"£,op~ Tee;, f- t'1J .~~ IS l1··e r 1U l( ~(l. 9~A¥ ~/ AuDroved U 'ÇØ¡ n D 1 ~ I t\ I ~ I APPROVED BY THE COMMISSION Date Form 1 0-401 ~visedœ2004~ 'J . , , '.f I I \I I ,- ,ßub¢it In Óuplicate · . IWell Name: V-120 Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): 'Injector Surface Location: X = 590,752.78' Y = 5,970,146.49' As-Built (Slot SF) 4896'FSL, 1547'FEL, Sec. 11, T11N,R11E /' Target Location: X = 594,725.00' Y = 5,976,875.00' Kuparuk 1016'FSL,2768' FEL,Sec. 36, T12N,R11E / Bottom Hole Location: X = 594,792.26' Y = 5,976,981.22' 1121' FSL, 2699' FEL, Sec. 36, T12N, R11 E / , AFE Number: I BRD5M4173 I I Estimated Start Date: 19/19/2004 , ~ 11200' I 'TVD: 17014' I I Rig: 'Nabors 9ES /' , Operating days to complete: 115.7 I RT/GL: 128.5' I I RKB: 181.5' I Well Design (conventional, slim hole, etc.): I Ultra Slimhole Injector , Objective: , Kuparuk injector. ,./ The injection interval is 1850' MD away from the nearest wellbore V-103 producer. The well approaches within 9500' of the nearest Prudhoe Bay property line. c IT b" p aSln gJ U Ing rogram: Hole Csgl WtlFt Grade Co~ Length Top Btm Size Tbg O.D. / MDITVD MDITVD bkb 42" 20" Insulated 91.5# H-40 WLD 80' GL 11 0/11 0 12 W' 9 5/8" 40# L-80 BTC 4129' GL 4129/2742' 8%" 7" 26# L-80 BTC-m 11200' GL 11,200/7014' Tubing 4%" 12.6# L-80 TC-II 1 0811 ' GL 10811 '/6657' / 9-5/8" burst 5750 psi, collapse 3,090 psi 7" burst 7,240 psi, collapse 5,410 psi 4-1/2" burst 8,430 psi, collapse 7,500 psi V-120 Drilling Program- Draft Page 1 . . Mud Program: Initial Base PF to to SV SV toTD 8.5- 9.0 8.5-9.0 8.5- 9.0 8 %" Production Hole Interval Density (ppg) Upper 9.5 Interval Top of HRZ toTD 4129' -11200' : YP PV pH LSND API Filtrate 6.0-8.0 26-32 12-18 9.0-9.5 26-32 12-18 9.0-9.5 4-5.5 Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2141' 600 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 2141'-4129' 680 4" 15.7# 110 3200 10.2 N/A 18,18,18,16 .942 Production Hole: 8 3/4" Interval Pump Drill Pipe AV Pump PSI fCD Motor Jet Nozzles I TFA GPM (fpm) ("/32) C ?) ppg-emw In- 4129' - 11200' 540 4" 15.7# 209 4200 11.2 N/A 3x14,3x15 .969 Directional: Ver. Anadrill(P2) (Slot NX) (Previouslv V-118 conductor.) KOP: 300' Maximum Hole Anale: 61 deg at 1,961' MD Close Approach Wells: All wells pass major risk criteria. V-03 -14' @ 450' Gyro service on standby during kick-off due to well proximity. IFR-MS corrected survevs will be used for survev validation. V-120 Drilling Program- Draft Page 2 Lo Surface . Production Hole . Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Formation Markers: TVDss 885 1575 1695 1705 2035 2210 2560 2865 2905 3255 3800 4105 4350 4515 4870 5170 5780 6375 6575 6650 6650 6795 6945 NP V-120 Drilling Program- Draft MWD I GR None None MWD/GR/PWD MWD/GR/RES/DEN/NEU/PWD (GR real time) USIT [0·\ Page 3 . . Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 11.5 ppg EMW Target surface shoe Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casin Size 9-5/8" Surface Basis: Lead: Based on conductor set at 110', 2031' of annulus in the permafrost @ 250% excess and 1238' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -3379' MD Total Cement Volume: Lead 515 bbl / 2889 ft / 5 s of Dowell ARTICSET Lite at 10.7 and 4.4 k. Tail 60 bbl / 336 ft 29 sks of Dowell Premium 'G' at 15.8 and 1 .17 c r Ma +30% excess volume ov Schrader Ma sand sks of Dowell G at 12.0 ppg Tail ks of Dowell G at 15.8 ppg and V-120 Drilling Program- Draft Page 4 . '. Well Control: / Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the need to test the production casing to 4000 psi for MI service considerations the BOP equipment will be tested to 4000 psi. ,,/ The tests will be conducted on a 14 day frequency. Except for significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. - ../" Diverter, BOPE and drilling fluid systøm schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: 3497 psi @ 6945' TVDss 7uparuk A · Maximum surface pressure: 2803 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi) ~/ · Planned completion fluid: 8.9 ppg filtered brine / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-120 Drilling Program- Draft Page 5 . . DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is installed. The well was previously reserved for V-118. (Slot NX) 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: .. 1. MIHU Nabors 9ES. /' 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/LWD and directionally drill surface hole to approximately 100~ TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing back to surface. Bump plug with 3500 psi and /'" hold/chart for 30 minutes. Note - A Tam port collar will be run as a contingency if surface drilling is problematic. 5. NO riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. // 6. MU 8-3/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip as / needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to intermediate TO at approximately 150' MD' below top Kuparuk B in order to evaluate the / entire Kuparuk interval. (TO estimated at 11,200' MD). 10. Run and cement the 7" production casing. Test casing to 4000 psi. 11. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 12. RIH with bit and scrap)fer and displace well over to 8.9 ppg brine. POOH LOOP. 13. Run USIT from FC to TOC. ../ 14. Perforate select Schrader interval. ....-- 15. Run a 4-1/2" 12.6#, TC-II by 3-1/2", 9.2#, TC-II, L-80 completion assembly. Set packers and test the / tubing to 4000 psi and annulus to 4000 psi for 30 minutes. 16. Shear OCR valve and install TWC. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect well by pumping diesel to GLM with OCR valve, shear, and allow to equalize. 19. Rig down and move off. /- V-120 Drilling Program- Draft Page 6 . . V-120 Drilling Program Job 1: MIRU Hazards and Contingencies ~ V-Pad i~designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ Well V-03 is 15' to the West. Plan to shut in well on move in. It is desired to return the well back to production as soon as operationally feasible after spud. >- Check the landing ring height on V-120. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" OperaüonalSpecifics · See the attached As-Built for the V-120 conductor location on V-Pad. Note the conductor was previously reserved for V-118. · Post Drilling Permit with Summary of Drilling Hazards in doghouse prior to spud. · Review the V-Pad data sheet and post in doghouse and field office. Job 2: Drillina Surface Hole >- There is one close approach issue in the surface hole. V-03 approaches with a center to center -' distance of 14' at 450'. A gyro will be required during kick-off. >- Hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) · clean (additional circulating, sweeps, etc). Refer to the attached MI Mud Program for a complete set of hole cleaning graphs and recommended sweeps. · When TD is reached, let drilling assembly sit no more than 10' off bottom with high flow rates and high rpm. Then work pipe no more than 40' off bottom while pumping sweeps and cleaning hole. · If significant tight hole conditions are encountered on the final trip out of the hole make a full wiper trip run with the directional assembly. V-120 Drilling Program- Draft Page 7 . . . The on-site geologist will be needed throughout the surface hole section for correlation of formation markers and selection of an interval TD. The casing will be set to cover the SV1 sands, and the TD is expected at -100' TVD below the top of the SV1 sands in the first good competent shale (as required to fit casing strap and allow appropriate rat hole). Job 3: Install Surface Casina . Hazards and Contingencies )0> It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1000'MD to allow remedial cementing. )0> "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" Job 7: Drillina Production Hole Hazards and Contingencies )0> V-120 is not expected to cross cross any faults in the production hole section. Lost circulation is considered a minimum risk however significant losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. )0> KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk B target depth, gauge hole, a fracture a. ient of 11.5 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 5gbls. LOT on V-Pad have ranged from 12.5 ppg to 15.5 ppg in the SV-1 formation. Contact .e"Órilling Manager if LOT is less than 11.5 ppg. ).> There are no "close approach" issues with the production hole interval of V-119. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2 " Operating Practices" .:. "Shale Drilling- Kingak & HrZ" V-120 Drilling Program- Draft Page 8 . . Job 9: Case & Cement Production Hole/Run USIT Hazards and Contingencies >- The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the Schrader Ma and the tail will cover from the shoe to 500' above the top of Kuparuk interval. >- A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "G Seal" may be placed across the Schrader and Ugnu to h€ilp arrest mud dehydration if losses were experienced while drilling this interval. >- Ensure a minimum hydrostatic equivalent of 10.1 ppg on the HRZ during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. >- Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately Y2 volume of casing-casing annulus prior to freeze. After freeze protecting the 7" x 9-5/8" casing outør annulus with 78 bbls of dead crude (2750' MD, 2000'TVD), the hydrostatic pressure will be 7.9 ppg vs 8.6 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. >- A cement bond log (USIT) will be run to confirm injection zone isolation. This will be done with the ~ rig prior to running the completion. Send results of USIT log into Anchorage office as soon as possible for evaluation. Notify Bruce Smith (home 345-2948, W 564-5093) upon obtaining results for review for possible remedial cemEmt work. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 10: Perforate Well Hazards and Contingencies / >- The Schrader interval of the well will be TCP perforated prior to running the completion. After placing a brine perf pill weighted to 9.t> ppg the well will be perforated across a 9.2 ppg EMW reservoir for an overbalance of 100 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. / >- A USIT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. Notify Bruce Smith (H. 345-2948, W. 564- 5093) immediately upon obtaining results of USIT log for review of possible remedial cement work. Reference RPs .:. See attached Initial Perforating Pro(~edures V-120 Drilling Program- Draft Page 9 . . Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill while running the completion and verify proper safety valves are on the rig floor. The well will be underbalanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. ~ Well Integrity: The well will be un-perforated and production casing tested to 4000 psi. A TWC will be installed and tested from below to 1000 psi for 30 minutes prior to nippling down the BOP's. A second annulus valve will be in place on the tubing spool flange during completion operations. (This valve will be removed at rig release.) The annulus above the packer will be tested to 4000 psi to verify packer/annulus integrity. The well will have a RHC plug installed in the lower XN with seawater above. A ball and rod will be on sea at rig release. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus V-120 Drilling Program- Draft Page 10 Comments RTE Base Gubik Bid 1.5/100 Bid 2.5/100 Cry 4/100 SV6 SV5 End Cry Base Perm Fault Crossing SV4 Faulted V-120 (P2) Proposal Schlumberger Survey I DLS Computation Method: Minimum Curvature /Lubinski Vertical Section Azimuth: 31.280° Vertical Section Origin: N 0.000 II, E 0.000 II TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.1011 relative to MSL Sea Bed I Ground Level Elevation: 53.60 II reiatlve to MSL Magnetic Declination: 24.906° Total Field Strength: 57589.325 nT Magnetic Dip: 80.798° Declination Date: 20-Sep-04 Magnetic Declination Model: BGGM 2004 North Reference: True North Total CorrMag North·) True North: +24.783° Local Coordinates Referenced To: Well Head Report Date: 13-Sep-04 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure / Slot: V-Pad / Plan Y-120 (N-X) Well: Pian Y-120 (N-X) Borehole: Plan Y-120 UWUAPI#: 50029 Survey Name / Date: Y-120 (P2) / July 19, 2004 Tort/AHD/DDI/ERDratio: 100.772°/7941.31 ft/6.106/1.132 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70.32816943, W 149.26398020 Location Grid N/E YIX: N 5970146.490 ftUS, E 590752.780 ftUS Grid Convergence Angle: .¡{).69306719° Grid Scale Factor: 0.99990936 . Latitude Longnude N 70.32816943 W 149.26398020 N 70.32816943 W 149.26398020 N 70.32816943 W 149.26398020 N 70.32817251 W 149.26397481 N 70.32818379 W 149.26395503 600.00 6.50 30.56 517.34 599.44 15.25 15.26 13.14 7.76 2.50 O.OOG 2.50 0.00 5970159.72 590760.38 N 70.32820532 W 149.26391730 700.00 10.50 30.59 616.22 698.32 30.03 30.03 25.86 15.27 4.00 O.OOG 4.00 0.03 5970172. 53 590767.74 N 70.32824007 W 149.263. 800.00 14.50 30.60 713.83 795.93 51.67 51.67 44.49 26.29 4.00 O.OOG 4.00 0.01 5970191.29 590778.53 N 70.32829096 W 149.263 900.00 18.50 30.61 809.69 891.79 80.06 80.07 68.93 40.74 4.00 O.OOG 4.00 0.01 5970215.90 590792.68 N 70.32835773 W 149.26364979 980.20 21.71 30.61 885.00 967.10 107.63 107.63 92.65 54.78 4.00 O.OOG 4.00 0.00 5970239.79 590806.43 N 70.32842254 W 149.26353597 1000.00 22.50 30.61 903.34 985.44 115.07 115.08 99.06 58.57 ~OO O.OOG 4.00 0.00 5970246.24 590810.15 N 70.32844005 W 149.26350521 1100.00 26.50 30.62 994.32 1076.42 156.53 156.54 134.74 79.69 4.00 O.OOG 4.00 0.00 5970282.17 590830.82 N 70.32853753 W 149.26333399 1200.00 30.50 30.62 1082.18 1164.28 204.24 204.25 175.80 103.98 4.00 O.OOG 4.00 0.00 5970323.52 590854.62 N 70.32864969 W 149.26313695 1300.00 34.50 30.62 1166.50 1248.60 257.95 257.97 222.03 131.35 4.00 O.OOG 4.00 0.00 5970370.07 590881.42 N 70.32877598 W 149.26291507 1400.00 38.50 30.62 1246.87 1328.97 317.42 317.44 273.20 161.64 4.00 O.OOG 4.00 0.00 5970421.60 590911.09 N 70.32891579 W 149.26266941 1500.00 42.50 30.62 1322.90 1405.00 382.34 382.37 329.08 194.71 4.00 O.OOG 4.00 0.00 5970477.87 590943.48 N 70.32906844 W 149.26240117 1600.00 46.50 30.62 1394.21 1476.31 452.42 452.45 389.38 230.41 4.00 O.OOG 4.00 0.00 5970538.60 590978.44 N 70.32923318 W 149.26211167 1700.00 50.50 3D.63 1460.46 1542.56 527.29 527.33 453.82 268.56 4.00 O.OOG 4.00 0.00 5970603.48 591015.80 N 70.32940921 W 149.26180231 1800.00 54.50 30.63 1521.32 1603.42 606.61 606.65 522.07 308.96 4.00 O.OOG 4.00 0.00 5970672.21 591055.38 N 70.32959567 W 149.26147459 1897.13 58.39 30.63 1575.00 1657.10 687.52 687.57 591.71 350. 19 4.00 O.OOG 4.00 0.00 5970742.34 591095.76 N 70.32978590 W 149.26114023 1900.00 58.50 30.63 1576.50 1658.60 689.97 690.02 593.82 351.44 4.00 O.OOG 4.00 0.00 5970744.46 591096.98 N 70.32979166 W 149.26113011 1961.36 60.95 30.63 1607.43 1689.53 742.96 743.00 639.41 378.43 4.00 O.OOG 4.00 0.00 5970790.37 591123.42 N 70.32991622 W 149.26091117 2141.72 60.95 30.63 1695.00 1777.10 900.62 900.68 775.09 458.76 0.00 O.OOG 0.00 0.00 5970927.00 591202.09 N 70.33028687 W 149.26025963 2162.32 60.95 30.63 1705.00 1787.10 918.63 918.69 790.59 467.94 0.00 O.OOG 0.00 0.00 5970942.61 591211.08 N 70.33032920 W 149.26018523 2162.34 60.95 30.63 1705.01 1787.11 918.65 918.71 790.60 467.95 0.00 O.OOG 0.00 0.00 5970942.62 591211.09 N 70.33032924 W 149.26018515 Well Design Ver 3. 1 RT-SP3.03-HF4.00 Bld( d031rt-546) Plan V-120 (N-X)\Plan V-120 (N-X)\Plan V-120IV-120 (P2) Generated 9/13/2004 3:17 PM Page 1 012 Comments SV3 W 149.25772964 SV2 W 149.25642731 SV1 W 149.25382235 9-5/8" Csg W 149.25307800 UG4A W 149.25155200 UG4 4633.96 60.95 30.63 2905.00 2987.10 3079.28 3079.48 2649.93 1568.78 0.00 O.OOG 0.00 0.00 5972814.96 592289.25 N 70.33540836 W 149.251_ UG3 5354.86 60.95 30.63 3255.00 3337.10 3709.47 3709.71 3192.24 1889.86 0.00 O.OOG 0.00 0.00 5973361.06 592603.71 N 70.33688970 W 149.2486 UG1 6477.39 60.95 30.63 3800.00 3882.10 4690.77 4691.07 4036.69 2389.82 0.00 O.OOG 0.00 0.00 5974211.42 593093.38 N 70.33919628 W 149.24459031 Ma 7105.60 60.95 30.63 4105.00 4187.10 5239.93 5240.27 4509.28 2669.62 0.00 O.OOG 0.00 0.00 5974687.31 593367.42 N 70.34048707 W 149.24231881 Na 7610.23 60.95 30.63 4350.00 4432. 10 5681.06 5681.43 4888.89 2894.37 0.00 O.OOG 0.00 0.00 5975069.58 593587.54 N 70.34152392 W 149.24049394 Cry 4/100 7717.22 60.95 30.63 4401.94 4484.04 5774.59 5774.97 4969.38 2942.03 0.00 90.70G 0.00 0.00 5975150.63 593634.21 N 70.34174375 W 149.24010701 End Cry / Target 7769.85 60.95 33.04 4427.50 4509.60 5820.59 5820.97 5008.46 2966.29 4.00 O.OOG -0.01 4.58 5975190.00 593658.00 N 70.34185050 W 149.23991001 OA 7950.05 60.95 33.04 4515.00 4597.10 5978.05 5978.50 5140.52 3052. 17 0.00 O.OOG 0.00 0.00 5975323.08 593742.27 N 70.34221119 W 149.23921269 Top Co/ville 8681.14 60.95 33.04 4870.00 4952.10 6616.87 6617.62 5676.32 3400.60 0.00 O.OOG 0.00 0.00 5975863.00 594084.16 N 70.34367451 W 149.23638333 Drp 4/100 8849.85 60.95 33.04 4951.92 5034.02 6764.28 6765.11 5799.96 3481.00 0.00 180.00G 0.00 0.00 5975987.59 594163.05 N 70.34401218 W 149.23573038 8900.00 58.94 33.04 4977.03 5059.13 6807.67 6808.51 5836,35 3504.66 4.00 180.00G -4.00 0.00 5976024.26 594186.27 N 70.34411156 W 149.23553819 9000.00 54.94 33.04 5031.57 5113.67 6891.43 6892.31 5906.60 3550.35 4.00 180.00G -4.00 0.00 5976095.05 594231.10 N 70.34430342 W 149.23516718 9100.00 50.94 33.04 5091.82 5173.92 6971.18 6972.10 5973.48 3593.84 4.00 180.00G -4.00 0.00 5976162.45 594273.78 N 70.34448610 W 149.23481390 9200.00 46.94 33.04 5157.48 5239.58 7046.53 7047.49 6036.69 3634.94 4.00 180.00G -4.00 0.00 5976226.14 594314.11 N 70.34465871 W 149.23448009 CM2 9218.21 46.22 33.04 5170.00 5252.10 7059.75 7060.72 6047.78 3642.16 4.00 180.00G -4.00 0.00 5976237.31 594321.18 N 70.34468899 W 149.23442153 9300.00 42.94 33.04 5228.25 5310.35 7117.13 7118.12 6095.90 3673.45 4.00 180.00G -4.00 0.00 5976285.80 594351.89 N 70.34482041 W 149.23416737 9400.00 38.94 33.04 5303.77 5385.87 7182.62 7183.64 615Q.82 3709.17 4.00 180.00G -4.00 0.00 5976341.15 594386.94 N 70.34497041 W 149.23387727 9500.00 34.94 33.04 5383.67 5465.77 7242.68 7243.73 6201.20 3741.93 4.00 180.00G -4.00 0.00 5976391.92 594419.08 N 70.34510799 W 149.23361119 9600.00 30.94 33.04 5467.58 5549.68 7297.02 7298.10 6246.78 3771.57 4.00 180.00G -4.00 0.00 5976437.85 594448.17 N 70.34523247 W 149.23337043 9700.00 26.94 33.04 5555.07 5637.17 7345.39 7346.48 6287.34 3797.95 4.00 180.00G -4.00 0.00 5976478.72 594474.05 N 70.34534324 W 149.233. End Drp 9792.67 23.24 33.04 5638.98 5721.08 7384.66 7385.77 6320.28 3819.37 4.00 O.OOG -4.00 0.00 5976511.91 594495.07 N 70.34543319 W 149.232 CM1 9946.14 23.24 33,04 5780.00 5862.10 7445.18 7446.32 6371.04 3852.38 0.00 O.OOG 0.00 0.00 5976563.06 594527.46 N 70.34557182 W 149.23271407 Top HRZ 10593.67 23.24 33.04 6375.00 6457.10 7700.53 7701.80 6585.20 3991.66 0.00 O.OOG 0.00 0.00 5976778.88 594664.13 N 70.34615670 W 149.23158273 Top KLB 10811.32 23.24 33.04 6575.00 6657.10 7786.37 7787.67 6657.19 4038.48 0.00 O.OOG 0.00 0.00 5976851,42 594710.07 N 70.34635330 W 149.23120243 Target 10882.06 23.24 33.04 6640.00 6722.10 7814.26 7815.58 6680.59 4053.69 0.00 O.OOG 0.00 0.00 5976875.00 594725.00 N 70.34641720 W 149.23107883 TKO / C4 10892.94 23.24 33.04 6650.00 6732.10 7818.55 7819.87 6684.19 4056.03 0.00 O.OOG 0.00 0.00 5976878.63 594727.30 N 70.34642703 W 149.23105981 11050.74 23.24 33.04 6795.00 6877.10 7880.78 7882.13 6736.38 4089.98 0.00 O.OOG 0.00 0.00 5976931.22 594760.60 N 70.34656956 W 149.23078409 TKB / LCU 11050.76 /23.24 33.04 6795.01 6877. 11 7880.79 7882.14 6736.38 4089.98 0.00 O.OOG 0.00 0.00 5976931.22 594760.60 N 70.34656957 W 149.23078407 TO / 7" Csg 11200.74 23.24 33.04 6932.83 7014.93 7939.93 7941.31 6785.99 4122.24 0.00 O.OOG 0.00 0.00 5976981.22 594792.26 N 70.34670505 W 149.23052200 LeQal Description: NorthinQ IV) rftUS] EastinQ IX) rftUS] Surlace : 4896 FSL 1547 FEL S11 T11N R11E UM 5970146.49 590752.78 Target: 4624 FSL 3856 FEL S1 T11N R11E UM 5975190.00 593658.00 Target: 1016 FSL 2768 FEL S36 T12N R11E UM 5976875.00 594725.00 BHL: 1121 FSL 2699 FEL S36 T12N R11E UM 5976981.22 594792.26 Well Design Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) Plan V-120 (N-X)\Plan V-120 (N-X)\Plan V-120IV-120 (P2) Generated 9/1312004 3:17 PM Page 2 of2 2400 g 0 0 N ~ ê ::::- ~ II 3600 () ëti u (/) Q ~ 4800 WELL FIËlD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Schlumberger V-120 (P2) Magnetic Parametars Model: BGGM2004 Surface location Dale: $eptember20, 2004 Lat: N701941.410 FS 57590.1 nT Lon: W149155Q.329 NAD21 Alaska state Planes, Zone04, US Feet Northing: 5970146.49ftUS GridConv: +0.69306719- Easting: 590752.78I1US Scale Fact: 0.999909356 TVO Raf: Rotary Tabla (82.10 ft above MSl) SrvyDate: September13,2004 MisceIlaoeous Slot: PlanV_120(N_X) Plan' V-120(P2} Dip: 80.798' MagDEic: ...24.783· o 1200 4800 7200 8400 2400 3600 6000 o .."v........"....., -RTE ,,-_._.."',,--- _Bid 1.5/100 ~:~d 2.51100 I---Crv4l100 \ ,6 ~ End ;rv ault Crossing """¡¡:"7 Baso Porm "~ U"eo '- ~ S'II.2 "-.. ~ ". '~ ~ "-.... 01 " :rv 41100 , ~'-"T :nd Cry I Targot AiK '- .Dn 41100 ,"":~::"7 ~ ~ yndDrp \M1 \ ,...- ",. .Targo ~~Hÿ \KU/lA 'D/7" cs~~ LIClJ 1200 6000 o 1200 2400 3600 4800 6000 Vertical Section (ft) Azim = 31.28°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-W 7200 8400 o . 1200 2400 3600 . 4800 6000 . . Schlumberger WEll V-120 (P2) FIELD STRUCTURE V-Pad Magnetic Pal3melenl Model: BGGM 2004 ^ ^ ^ Z ¢? 0' o o ~ ê Co ~ II Q) ëti u en en v v v Prudhoe Bay Unit - WOA Dip: 80.798' Mag~: +24.783' SurfaceLocalion Date: September 20, 2004 Lat: N701941.410 FS: 57590.1 nT Lon: W149155O.329 Miscellaneous Slot: Plan V-120(N-X) Plan" V-120(P2} lVDRef: RotaryTabtfJ(82.10ftaboveMSL} SrvyDate: ~ber13.2004 . . > . '..H.......................ru...........H........»....«.....~.H..'......»......................~..H........,..H............H....,.~".............................. . ¡ ~::SLP'1 / ! ~! ~~ ... ........................t....m.....~..m...... ·m·· ..]m....m .··._··r;...· .-................................ _m_m-rmmTmmm_m ..............·..'....H. ,................_.................... · . · . · . --"---1-'--'- ·t-··-- 7000 .... ............. ........... ....~....... 6000 5000 4000 3000 ....,............."..H.. NAD27 Alaska Stale Planes. Zone 04, US Feet Northing: 5970146.49ftUS GñdConv: +0.69300719' Easting: 590752.78 ftUS Scale Fact: 0.999909356 o 1000 4000 2000 3000 H·-t.... · . · . · . · . · . -T--r- 2000 · . · . ........................,............"..A'......"...AA............."'...., · . · . · . · . · . · . · . 1000 · . · . . ." '.. ...'.....A.. .,.,.. ,.. ....;. .,., ,HAA ,...." "H ......,..,.... ¿...,. .".. ...,..,.. "'AA, ..,.., ""A'~'"'''' Fault fross;n ¡ ¡ o · . · . · . , . .".,.."....."'..."....."'..........,,,.,.,.......,,,..."'.,.."'..."'....".......,..."....."...".....-.....,...........".....,.,."............,.............,....,",..., · . . . · . . . · . . . · . . . · . . . · . . . · . . . .. . .. . .. . ,. . RTE o 1000 2000 3000 <<< W Scale = 1(in):1000(ft) E >>> 4000 7000 6000 5000 4000 3000 2000 1000 o . . Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Monday, September 13, 2004 Neil Magee Prudhoe Bay V·120 (P2) BP Exploration Alaska Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type MWD MWD + IFR + MS Start Depth 28.50'md 1 AOO.OO'md End Depth 1 AOO.OO'md 11,200.74'md Close Approach Analysis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Note: From magnetic scans in Compass, it is recommended to run a Gyro compassing tool from surface to 600+ feet MD due to possible offset magnetic interference from surface casings. This is only a recommendation, and may not be needed, depending on MWD readings during surface drilling. Close Approach Drillinq Aids to be provided: A drilling map and a traveling cylinder, will be provided. Checked by: Scott Delapp 09/13/04 . . Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined setection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 11200.74 ft Maximum Radius: 10000.00 ft Reference: Error Modet: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/14/2004 Validated: No ptanned From To Survey ft ft 28.50 1400.00 Planned: Plan #2 V1 28.50 11200.74 Planned: Plan #2 V1 Version: 2 Toolcode Tool Name MWD MWD+IFR+MS MWD - Standard MWD + IFR + Multi Station Casing Points Summary PB V Pad Plan V-112 (S-A) Plan V-112 V1 Plan: PI 344.90 350.00 425.67 6.37 419.30 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 346.77 350.00 385.34 7.55 377.80 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 346.98 350.00 217.33 6.45 210.88 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 347.35 350.00 196.04 6.46 189.59 Pass: Major Risk PB V Pad Plan V-210 (N-G) Plan V-21 0 V4 Plan: PI 400.03 400.00 295.64 7.01 288.64 Pass: Major Risk PB V Pad Plan V-211 (N-C) Plan V-211 V2 Plan: PI 352.27 350.00 355.41 6.20 349.21 Pass: Major Risk PB V Pad Plan V-212 (S-D) Plan V-212 VO Plan: V 391.30 400.00 385.93 8.49 377.44 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 349.27 350.00 90.08 7.36 82.72 Pass: Major Risk PB V Pad Plan V-2a06 (N-M) Plan V-2a06 VO Plan: V 397.12 400.00 166.14 8.56 157.58 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 536.40 550.00 187.19 11.02 176.16 Pass: Major Risk PB V Pad V-01 V-01 V15 299.59 300.00 235.71 5.20 230.52 Pass: Major Risk PB V Pad V-02 V-02 V12 250.50 250.00 265.91 4.42 261.49 Pass: Major Risk PB V Pad V-03 V-03 V7 449.58 450.00 13.98 6.93 7.05 Pass: Major Risk PB V Pad V-100 V-100 V7 298.50 300.00 184.12 5.00 179.12 Pass: Major Risk PB V Pad V-101 V-101 V7 393.93 400.00 337.80 6.45 331.36 Pass: Major Risk PB V Pad V-102 V-102 V5 348.00 350.00 218.38 6.88 211.51 Pass: Major Risk PB V Pad V-103 V-103 V6 398.26 400.00 74.97 6.65 68.32 Pass: Major Risk PB V Pad V-104 V-104 V13 347.35 350.00 280.50 5.69 274.81 Pass: Major Risk PB V Pad V-105 V-105 V13 397.00 400.00 150.88 6.47 144.41 Pass: Major Risk PB V Pad V-106 Plan V-106A V5 Plan: P 397.39 400.00 102.82 6.45 96.37 Pass: Major Risk PB V Pad V-106 Plan V-106APB1 V2 Plan 397.39 400.00 102.82 6.45 96.37 Pass: Major Risk PB V Pad V-106 V-106 V10 397.39 400.00 102.82 6.10 96.72 Pass: Major Risk PB V Pad V-107 V-107 V5 395.37 400.00 250.10 5.84 244.26 Pass: Major Risk PB V Pad V-108 V-108 V7 249.78 250.00 372.25 4.23 368.02 Pass: Major Risk PB V Pad V-109 V-109 V2 346.44 350.00 372.90 5.91 366.99 Pass: Major Risk PB V Pad V-111 V-111 V25 448.75 450.00 42.44 8.08 34.36 Pass: Major Risk PB V Pad V-113 V-113 V6 345.58 350.00 399.22 5.20 394.02 Pass: Major Risk PB V Pad V-114 V-114 V5 300.27 300.00 347.28 4.95 342.33 Pass: Major Risk PB V Pad V-115 V-115V5 347.52 350.00 180.12 5.59 174.53 Pass: Major Risk PB V Pad V-117 V-117V9 298.30 300.00 191.17 5.12 186.05 Pass: Major Risk PB V Pad V-119 V-119V13 392.04 400.00 359.72 6.71 353.01 Pass: Major Risk PB V Pad V-201 V-201 V8 346.57 350.00 236.13 5.61 230.52 Pass: Major Risk PB V Pad V-202 V-202 V9 394.31 400.00 310.64 6.89 303.75 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 567.87 600.00 322.53 9.85 312.69 Pass: Major Risk PB V Pad V-213 V-213 V5 953.55 1000.00 120.48 15.95 104.54 Pass: Major Risk PB V Pad V-216 V-216 V8 448.53 450.00 57.36 7.90 49.46 Pass: Major Risk I I I I ---~-~-- ~--- Field: Prudhoe Bay Site: PB V Pad Well: Plan V-120 (N-X) Wellpath: Plan V-120 294 .. 200 ··100 27 Plan V-2a06 (N-M) (Plan V-2a06) 100 200 294 V-OIJ.V-OJ) Plan V-205 (S-P) ("\Il'!'l:¥~h) Plan V-206 (S-Sj-fJJà~WUl!ij) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] -- . . Polygon I 2 3 4 Site: p.A.d Drillin~t Conf.: 95% Description: Map Northing: 5976875.00 ft Map Easting : 594725.00 ft Latitude: 70020'47.102N Xft -148.19 151.82 148.19 -151.82 Target: V-120 Ku.t Wel1: Plan V-120 (N-X) Based on: Planned Program Vertical Depth: 6640.00 ft below Mean Sea Level Local +N/-S: 6680.57 ft Local +E/-W: 4053.69 ft Longitude: 149°13'51.884W Map E ft 594575.00 594875.00 594875.00 594575.00 yft 151.82 148.19 -151.82 -148.19 Map N ft 5977025.00 5977025.00 5976725.00 5976725.00 5900 5800 5100 5500 5500 54-00 D D D D D D D D D D D D 0 a- D N m -=f- o 0 m -=f- -=f- -=:J- -=f- -=f- ~ ~ TREE =- WELLHEAD = ACTUA TOR = KB. ELEV = ~BTäEV; 4-1/16" CrN FMC . V-12' SAFETY NOTES: Three dow nhole pressure/temp gages. One set above Schrader ,one on either side of X-nipple below injection mandrels. .___U_umum"·,·m.,.·~,...".,w.,... ~~_~.~~I~..~ Datum MD = Õatum lVO = '~__Aw_~__~m__·~~_~m~ ........ I XXXX' H 9-5/8" TAM PORT COLLAR I PERFORA TION SUMMARY REF LOG: TCP PERF GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH 4 2000 KBG-2 Dummy BK-5 3 3500 KBG-2 DCK BK-5 WA TERFLOOD MANDRELS ST MD lVD DEV TYÆ VLV LATCH 2 MMG-W Dummy RKP 1 MMG-W Dummy RKP PORT DATE I 2200'MD H 4-1/2" HES X NIP, 10 = 3.813" I 9-5/8" CSG, 40#, L-80, ID = 8.835" I PORT DATE Minimum IC = 2.81" @ XXXX' 3-1/2" HES X NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H XXXX' I XXXX'MD -l 4-1/2" HES X NIP, ID - 3.813" I HES 3-1/2" BHG Gages 7" X 4-1/2" BKR PREMIER A<R, 10 = 3.875" 4-1/2" X 3-1/2" XO, 10 = 2.992" I c :;;. 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I TBD -i 3-1/2" HES X NIP, 10 = 2.813" I 10600' MD 7" X 3-1/2" Premier A<R, 10 = 3.875" XXXX'MD 3-1/2" HES X NIP. ID = 2.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE IXXXX' MDI XXXX' MDI 3-1/2" HES X NIP, 10 = 2.813" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 3-1/2" WLEG, 10 = 2.875" I¿ I PBID 11200'MD 11118'MD I 7" CSG, 26#, L-80, .0383 bpf, 10 = 6.276" DATE REV BY COMMENTS 08/15/04 NM PROPOSED COMPLETION (P2) DA TE REV BY COMMENTS GPB BOREALIS WELL: V-120 ÆRMIT No: API No: BP Exploration (Alaska) . . V-120 Well Summary of Drillina Hazards ./ POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 2150' MD and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Intermediate Hole Section: · A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The intermediate hole section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk B 9.8 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. · Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous we II bores which encountered faults in the Colville. Loss circulation is considered to be a minor risk in this well. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies . TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 142 DATE (f1--/4"0 Lf b~òi~6FHE ÞeWO~/~~Cc-' $ Ire· Où W- ' Gt). 130LlAn£ First National a k Alaska ~~~ "Mastercard Check" Anchorage, AK 99501 MEMO YJ \~O . .:.252000(;01:1111 .1,11'(; 2 27111.55(;"- 0.1, 2 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME jJß' C-! (/-/2-0 PTD# 20tj- /71 Exploration Stratigraphic .x Development Servi ce CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new weJJboresegment of LATERAL existing well . Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot bole must be dearly differentiated In both name (name OD permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject -to fuD EX CEPTJ ON " compliance with 20 AAC 25..055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa cing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1baJl 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample j¡iter:va)s tbrough target zones. .. . e o Well bore seg Annular Disposal Program SER On/Off Shore On PRUDHOE BAY, BOREALIS OIL - 640130 Well Name: PRUDHOE BAY UN BORE V-120 ALASKA) INC Initial ClasslType SER 11WINJ GeoArea Unit - Administration Permit fee attaçhejj - - - - - · .Yes ~ - - - - - - - - - 2 .Leasen\.Jmberappropri¡;¡te . . .Yes - - - - - 3 .U.niq\.Je weltn.am~.a[1d oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s .. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ v _ _ _ _ 4 WellJQCÇlted ina.defioe.dppol . . . - - - - - .Y~s - - - - - 5 WellJoc¡;¡t~d proper .distance. from driJIing \.Jnitb.o\.Jnd.ary .Yes - - - - 6 WellJoc¡;¡t~d pr.oper .distance. from otlJer welJS. . - - - - · .Yes - - - - - 7 .Sutfiçieot.acreage.ayail¡;¡ble indrilliog unjt. . . .Yes - - - - - 8 Jf.deviated, js weJlbore platJnclu.ded . . - - - - · .Y~s - - - - - 9 .o.perator ooly affected party. . - - - - · .Y.es - - - - - 10 .Oper.ator bas.apprppriate.b.ond inJorce . . . . . . . . . . . . . . . . . .... . .. . .Yes .. . - - - - - - - - - - - - - - - - - - -- 11 Permit can be issued without conserva.tion order - - - - · .Yes - ~ - - - Appr Date 12 Pe(l1Jit c:a[1 be issued wjtlJQut administrathie.appr.oval . . . Yes - - - - - - -- - - - - - RPC 9/14/2004 13 Can permit be approved before 15-day wait Yes 14 Well Joc¡;¡ted within area and.strataauthorized by.lnjectipo Order # (p\.JtlO# incomments).{For. Yes 81024, NO WELLS IN 80R.. 15 .All w¡:¡lls.withiJl.1l4.l1JiLe.area.of reyi¡:¡w jd.entified (For servjq;¡.wellonly). . . . . . . . . . . . . . . .Y~s .. . - - - - - - - - - - - - - - - - - - - - 16 Pre-produ.ced injector; duraUonof pre-Productipn I~ss than. 3 months. (For.service well only) . . NA - - -- 17 AÇMP.finding.of Con.si.stency.h.as beenjss\.Jed. for. tlJis pr.oject .NA - Engineering 18 .Conductor string. provided . . - - - -- .Yes 20"@ 110'.. - - - - 19 .S.urfaœ .casiog protects alLknown USQWs . . .Yes 20 CMT. vol adeQu.ate. to Ci rc.u late. oJl.cond.uctor. & SUJf.cJ>g . .Y~s Ade~uate excess. . . 21 .CMT v.ol adequate. to tie-in .long .string to. surf csg. . No 22 .CMTwill coyer.a!1 kl]own.prod\.Jctiye borizons. . . · .Yes - - - -- - - - - - 23 .C.asing designs adequa.te for C,T~ B.&permafr.ost . . · .Yes 24 .Ajjequ.ate.tankageoJ re.serve pit. . . . . . . . . . . . · .Yes Nabors.9.ES. 25 Jf.a.re-d(iIL bas.a 10-403 for ¡;¡bandonmeJlt be¡:¡n ¡;¡PPJoved . .NA New welt . - - - - - - 26 .Adequ¡;¡te .wellbore separ¡;¡tjo.n .proposed. . . . . . . . . . . . . . . . . . . . .. .Yes .. . - - - . - - - - - - - - - - - - - - -- 27 Jf.djverter required, does jt meet reguJations. - - - - - . . . .Yes Appr Date 28 .Drilling flujd. program schematic.& eq.uip Jist.adequate. . · . .Yes Max MW.10Jppg.. . WGA 9/14/2004 29 BOPEs,dp .they meet reguJation . . . . . . . . . . · Yes 30 .BOPEpress ra.ting appropriate;.test to (pu.t psig iJl.comments). . . .Yes Test tp 4000. psi. .MSF' 2803 psi. 31 .Chokemanifold compJies w/API RF'-53 (May 84). · . .Y.es - - - -- 32 WQrk will pçcU( withoutoperatjon .sbutdown. . · .Yes - - - - 33 .Is presence of H2S gas. prob.able. . . . . . . N.o NoLal1 H2S pad. . 34 MeçlJanicaLcpndjUol1pfwells withio80R yerifìed (For. service well onJy) · . .Yes NO wells witlJio AOR. Geology 35 Permit ~an be issued w/Q hyd(ogen. s.ulfide measures. Yes 36 .Data.preseoted on. pote.ntial pveJpres.sure .zooeJ>. . . . . NA Appr Date 37 .S~ismic.analysjs. of slJaJlow gas.zpnes. . . . . NA RPC 9/14/2004 38 Seabed .coodjtjpo survey.(if off-shore) . . . . . . . . . NA 39 . CQntact nam.elphone.forwee~ly progress reports [exploratpryo[1lyl NA - - Geologic Date: Engineering Date ~~y Commissioner: Commissioner üTs 111Cf-!~