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Phone:907-444-7218 Rep.: E-Mail Well Name: PTD #22021490 Sundry #322-089 Operation: Drilling: Workover: x Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:2670 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8x 4 1/2 VBR P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1650 P Quantity Test Result 200 psi Attained (sec)23 P No. Valves 11 P Full Pressure Attained (sec)130 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 3@2166 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:6.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5-23-22 4:00AM Waived By Test Start Date/Time:5/23/2022 18:30 (date) (time)Witness Test Finish Date/Time:5/24/2022 0:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Hilcorp Tested With 50/50 methonol water. No fails Matt Rivera/Will Ragsdale Hilcorp Daniel Scarpella/ Arvell bass PBU W-37A Test Pressure (psi): pbrwowss@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0524_BOP_Thunderbird1_PBU_W-37A 9 +LOFRUS1RUWK6ORSH//& 9 9 9 9 9 9 999 9 9 9 -5HJJ +LOFRUS1RUWK6ORSH//&K X 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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220601 0934 Completed tubing hanger work. W-37A tubing hanger work PTD 202-149 Date:Wednesday, June 1, 2022 9:36:44 AM From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, June 1, 2022 9:17 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] W-37A tubing hanger work PTD 202-149 Mel, The work went very well and according to plan. I’m just getting the rig morning report together including the detail on wellhead work to pass along to you. Once BOPs were ND, they were able to get a better grip on the landing joint with tongs closer to the bound connection and were able to back it out and set the TWC. Tubing hanger seals were replaced, tree was installed and hanger and tree tested successfully. We will be performing the final MIT-IA today before pulling the securement plugs with Slickline. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, June 1, 2022 9:10 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] W-37A tubing hanger work PTD 202-149 Wyatt, How is the tubing hanger seal and landing joint removal work going on W-37A? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). 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 herebynotified 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. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: W-37A (PTD#202149) RWO Failed Tubing Hanger Seal Date:Wednesday, June 1, 2022 9:35:37 AM From: Rixse, Melvin G (OGC) Sent: Sunday, May 29, 2022 6:51 PM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: W-37A (PTD#202149) RWO Failed Tubing Hanger Seal Wyatt, As you will have two tested barriers to reservoir on the IA when you pressure test the plug set at 9276’ MD, and you will have two barriers to the reservoir on the tubing when you set the test plug at 9168’ MD, Hilcorp has approval to proceed as per your plan below: Note: To confirm the tubing, packer and casing have integrity downhole, Hilcorp made up a landing jt and pressure tested the tbg to 3500 psi for 30 mins w/ no leak off followed by an MIT- TxIA combo to 2500 psi w/ no leak off. Plan forward from Wyatt Rivard (Hilcorp OE): Slickline Pull ball and rod and RHC Set plug in XN nipple in top of cemented liner @ 9276’. Pressure test plug to 2500 psi. Set plug in X nipple below packer @ 9168’. Pull DCR valve in upper GLM FP Tbg and IA (after freeze protect, assure well remains dead – mgr) Set DGLV in upper GLM Set TWC and RD Thunderbird Wellhead Remove BOPE Replace tubing hanger body seal with tubing hanger in place. Install tree and test. MIT-IA Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 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. 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Sunday, May 29, 2022 5:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: W-37A (PTD#202149) RWO Failed Tubing Hanger Seal Hello Mel, The Thunderbird 1 has finished running the new completion and setting packer on W-37A (PTD# 202149) under sundry 322-089. Unfortunately, the tubing hanger failed to test and, upon inspection, it appears that part of the rubber element rolled during installation. To confirm the tubing, packer and casing have integrity downhole, we made up a landing jt and pressure tested the tbg to 3500 psi for 30 mins w/ no leak off followed by an MIT- TxIA combo to 2500 psi w/ no leak off. Going forward, we would like to proceed to set two downhole plugs with slickline, set a TWC and then rigdown the rig and repair the tubing hanger seals once BOPs are nippled down. Please let me know if this an acceptable path forward Plan forward. Slickline 1. Pull ball and rod and RHC Set plug in XN nipple in top of cemented liner @ 9276’. Pressure test plug to 2500 psi. Set plug in X nipple below packer @ 9168’. Pull DCR valve in upper GLM FP Tbg and IA Set DGLV in upper GLM Set TWC and RD Thunderbird Wellhead 1. Remove BOPE Replace tubing hanger body seal with tubing hanger in place. Install tree and test. MIT-IA Thank You, Wyatt Rivard 5096708001 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. 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WĞƌĨŽƌŵdĞƐƚƉĞƌ ͞dŚƵŶĚĞƌďŝƌĚηϭdĞƐƚWƌŽĐĞĚƵƌĞ͟ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Ě͘ dĞƐƚsZƌĂŵ ĂŶĚŶŶƵůĂƌ ŽŶϮͲϳͬϴ͟ ĂŶĚϰͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Ğ͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ Ϯϭ͘ WƵůů dtŝŶƐĞƌƚĂŶĚWs͘ ϮϮ͘ ZŝŐƵƉƐƉŽŽůĞƌƐĨŽƌ^^^sĐŽŶƚƌŽůůŝŶĞ͘ Ă͘ tĞůůŚĂƐϰͲϭͬϮ͟^^^sŶŝƉƉůĞĂƚϮϭϰϳ͛D͘DŝŶŝŵĂů ŚŝƐƚŽƌŝĐŝŶĨŽĂǀĂŝůĂďůĞ ŽŶǁŚĂƚǁĂƐ ĂĐƚƵĂůůǇƌƵŶďƵƚϭϵϴϴǁĞůůƉƌŽŐƌĂŵŝŶĐůƵĚĞĚƉůĂŶƐĨŽƌ͞ĂƐƵďƐƵƌ ĨĂĐĞƐĂĨĞƚǇǀĂůǀĞǁŝƚŚĚƵĂů ĐŽŶƚƌŽůůŝŶĞƐ͙͟ Ϯϯ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌ͕K>^ĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ ΕϵϮϬϬ͛ŽĨϰͲϭͬϮ͟ϭϮ͘ϲη ƚƵďŝŶŐǁĞŝŐŚƐΕ ϭϭϱŬůďƐ;ĚƌǇͿ Žƌ ϭϬϬ<ůďƐ ;ďƵŽǇĞĚďǇϴ͘ϰ ƉƉŐĨůƵŝĚͿ ď͘ /ĨƉƵůůĞĚƵƉƚŽ ϮϯϬ<ůďƐ ;ϴϬйŽĨϰͲϭͬϮ͟ǇŝĞůĚƐƚƌĞŶŐƚŚͿ ǁŝƚŚŶŽŚĂŶŐĞƌŵŽǀĞŵĞŶƚ͕ZhĞůŝŶĞ ĂŶĚƉĞƌĨŽƌŵϮŶĚ ƚƵďŝŶŐĐƵƚĂƚ цϵϮϭϬ͛ ŵŝĚũŽŝŶƚ͘ Ϯϰ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞ ϰͲϭͬϮ͟ƚƵďŝŶŐ ǁŚŝůĞ ƐƉŽŽůŝŶŐ ^^^sŽŶƚƌŽů>ŝŶĞ͘ 5HYLHZZHOOKLVWRU\WRGHWHUPLQHZKHWKHUWRGU\URGRUOXEULFDWH%39UHPRYDO 1RWH8WLOL]LQJIUHH]DEOHIOXLGV'LOLJHQFHUHTXLUHGWRDVVXUHZHOOFRQWURO HTXLSPHQWVWD\VDERYHIUHH]LQJSRLQWRIIOXLGV d' ŚĂŶŐĞͲKƵƚ tĞůů͗ tͲϯϳ Ă͘ ƵĞƚŽ ĂŐĞ ĂŶĚ ĐŽƌƌŽƐŝŽŶŽĨƚƵďŝŶŐŝƚǁŝůůďĞũƵŶŬĞĚ͘ ď͘ ƐƐƵŵĞǁĞůů ŚĂƐĚƵĂůĐŽŶƚƌŽůůŝŶĞƐĐŽŶŶĞĐƚĞĚƚŽ^^^sEŝƉĂƚϮϭ ϰϳ͛D Ă͘ EƵŵďĞƌŽĨĐůĂŵƉƐ ĂŶĚ ĐĞŶƚƌĂůŝǌĞƌƐƵŶŬŶŽǁŶ͘ Ϯϱ͘ WĞƌĨŽƌŵ ĐĂƐŝŶŐ ĐůĞĂŶŽƵƚͬĨŝƐŚŝŶŐ ƌƵŶƐ ǁŝƚŚϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐ ŽƌƐůŝĐŬůŝŶĞ ĂƐŶĞĞĚĞĚŝĨ ĐŽŶƚƌŽů ůŝŶĞƐ ĂŶĚ ĐůĂŵƉƐ ŶŽƚƌĞĐŽǀĞƌĞĚ͘ Ϯϲ͘ DhϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐǁŝƚŚŽƵƚƐŝĚĞĐƵƚƚĞƌŽƌƉĂĐŬĞƌŵŝůůĨŽƌĐŽůůĂƉƐĞĚϰͲϭͬϮ͟ƚƵďŝŶŐĂƚ ΕϵϮϰϮ͛D͘ Ϯϳ͘ Z/,ĂŶĚ ĐƵƚͬŵŝůů ƚŚƌŽƵŐŚĐŽůůĂƉƐĞĚ ƚƵďŝŶŐƐĞĐƚŝŽŶĚŽǁŶƚŽƚŽƉŽ Ĩϯ͘ϳ͟ĚĞƉůŽǇŵĞŶƚƐůĞĞǀĞĂƚ ΕϵϮϱϳ͛ D͘ WKK,͘ Ϯϴ͘ Z/,ǁŝƚŚƐůŝĐŬůŝŶĞŽƌϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐ ĂŶĚĐŽŶĨŝƌŵĂĐĐĞƐƐŝŶƚŽϯͲϭͬϮ͟ůŝŶĞƌƚŽƉ Ϯϵ͘ WhŶĞǁ ϯͲϭͬϮ͟ĐŽŵƉůĞƚŝŽŶ ĂŶĚƌƵŶƉĞƌ tͲϯϳ WƌŽƉŽƐĞĚŽŵƉůĞƚŝŽŶZƵŶŶŝŶŐKƌĚĞƌ͘ Ă͘ KǀĞƌƐŚŽƚƚƵďŝŶŐƐƚƵď ĂƚΕϵϮϱϳ͛D ĂŶĚƐĞƚ ƉĂĐŬĞƌĂƚцϵϭϲϬ͛D ď͘ ŶƐƵƌĞZ,ƉůƵŐďŽĚǇƉƌĞͲŝŶƐƚĂůůĞĚŝŶůŽǁĞƌŵŽƐƚyƉƌŽĨŝůĞĂƚцϵϮϮϬ͛ D Đ͘ &ƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐͬ/ĂƐŶĞĞĚĞĚƉƌŝŽƌƚŽƉĂĐŬĞƌƐĞƚŽƌƵƚŝůŝǌĞĂƐŚĞĂƌŽƵƚ'>sĨŽƌƉŽƐƚƐĞƚ ĨƌĞĞǌĞƉƌŽƚĞĐƚ͘ ϯϬ͘ >ĂŶĚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚ Z/>^͘ >ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘EŽƚ Ğ WŝĐŬͲƵƉĂŶĚƐůĂĐŬͲŽĨĨ ǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ ϯϭ͘ ƌŽƉďĂůůĂŶĚƌŽĚĂŶĚŚǇĚƌĂƵůŝĐĂůůǇƐĞƚƚŚĞƉĂĐŬĞƌƉĞƌŵĂŶƵĨĂĐƚƵƌĞƌ͛ƐƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ Ă͘ ŽŶĚƵĐƚD/dͲdƚŽ 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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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F C' E I V E D REPORT OF SUNDRY WELL OPERATIONS ed 1. Operations PertormAban don ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Opestid5ut o n2019 11 Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Chan d Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 1:1 Re-enter Susp Well ❑ Other 9 ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 202-149 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6API Number: 50-029-21855-01-00 7 Property Designation (Lease Number): ADL 028263 8. Well Name and Number: PBU W -37A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10352 feet Plugs measured 10190 feet true vertical 9084 feet Junk measured 10310 feet Effective Depth: measured 10190 feet Packer measured 9372 feet true vertical 9004 feet Packer true vertical 8467 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 43-123 43-123 Surface 2637 13-3/8" 43-2680 43-2680 5020 2260 Intermediate 9593 9-5/8" 40-9633 40-8688 6870 4760 Liner 281 7" 9403-9684 8493-8732 Liner 1095 3-1/2"x 3-3/16"x2-7/8" 9257-10352 8370-9084 13450 13890 Perforation Depth: Measured depth: 9927-10300 feet True vertical depth: 8883-9058 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 38-9476 38-8555 Packers and SSSV (type, measured and 4-1/2" TIW HBBP-R Packer 9372 8467 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 116 757 92 793 255 Subsequent to operation: 340 2406 112 538 247 14. Attachments: (required per20 MC 25.070,29 071, a 2s 2es) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Peru, Cale Contact Name: Peru, Cale Authorized Title: Petroleum Engineer Contact Email: Cale.Peruabp.com Authorized Signature:Date: Contact Phone: +1 9075644522 Form 10404 Revised 04/2017 /�jy17 „vicu�6a�lg RBDMS —r"�'oEC 19 2019 Submit Original Only Daily Report of Well Operations PBU W -37A ACTI V ITYDATF c i uwww w ov ****WELL S/I ON ARRIVAL****(pert) SET 4-1/2" WHIDDON CATCHER @ 9235' SLM. PULL RM-OGLV FROM STA #1(9177' MD) SET RM-OGLV IN STA #1(9177' MD) PULL EMPTY 4-1/2" WHIDDON CATCHER FROM 9235' SLM. EQUALIZE 3-1/2" XX -PLUG @ 9276' MD. 11/16/2019 ****CONT WSR ON 11-17-19**** ****CONT WSR FROM 11-16-19****(pert) RUN KJ, 2.50" CENT, 10'x 1-3/4" PUMP BAILER W/ MSFB TO 9250' SLM. RUN KJ, 5'X 2.25" DO BAILER W/ SHEARABLE EQ DEVICE BOTTOM TO 9250' SLM(eq device not sheared) RUN KJ, 10' X 2.25" PUMP BAILER W/ 3-1/2" SNORKLE BOTTOM TO 9250' SLM. PULL P PRONG FROM 3-1/2" PXN PLUG BODY FROM 9250' SLM. PULL 3-1/2" PXN PLUG BODY FROM 9255' SLM. DRIFT W/ 30'x1.75" DD BAILER, TAG BTM AT 10,146' SLM. RAN 20'x3.70" DUMMY WHIPSTOCK TO 2,200' SLM. ***WELL TURNED OVER TO DSO*** ***DRIFTED TO 2,200' SLM W/ 20'x3.70" DUMMY WHIPSTOCK FOR SUBSIDENCE 11/17/2019 SURVEILLANCE*** ***WELL SHUT IN ON ARRIVAL**** PERFORATE 10075-10107' WITH 1.56" PERFECTA, 6 SPF, 60 DEG PHASE. CCL TO TOP SHOT 2.8'. CCL STOP DEPTH 10072.2'. 11/29/2019 ***JOB CONTINUES ON 30-NOV-19 WSR*** ***JOB CONTINUES FROM 29-NOV-19 WSR*** PERFORATE 10032'-10064'W/ 1.56" PERFECTA, 6 SPF, 60 DEG PHASE. CCL TO TS 2.8'. CCL PERFORATE 10000'-10032'W/ 1.56" PERFECTA, 6 SPF, 60 DEG PHASE. CCL TO TS 2.8'. CCL STOP 9997.2' PERFORATE 9959'-9991'W/ 1.56" PERFECTA, 6 SPF, 60 DEG PHASE. CCL TO TS 2.8'. CCL STOP 9956.2' PERFORATE 992T -9959'W/ 1.56" PERFECTA, 6 SPF, 60 DEG PHASE. CCL TO TS 2.8'. CCL STOP 9924.2' 11/30/2019 ***JOB COMPLETE, PAD OP NOTIFIED*** TREE= 4-1/16' CNV WELLHEAD= CAMERON ACTUATOR= CNV -SH 3000 KB. ELEV = 90.99' BF. ELEV = 51.53' KOP= 3200' Max Argle = 67' 10048' Dafen MD = 9942' Datun TVD = 8800' SS 1 13-3/8' CSG, 6811, L-80, D = 12.415' 1 Minimum ID = 2.37" @ 9742' 33116" X 2-7/8" XO bpf,D=2.99' H 9276' TOP 4-12' TBG, 12.6#, L-80-0152 bpf, D = 3.958'9476' 9-5/8' CSG, 4711, L-80, D = 8.681'-9833 MiPSTOCK —I 9 D = 6.276• X9694 PERFORATION SUMMARY REF LOG: BHCS ON 09/01/88 ANGLE AT TOP PERF: 57' @ 9927' Note: Refer to Production DB for Nstorical perfdata SIZE SPF INTERVAL OpnfSqz I DATE 1.56' 6 9927-9991 O 11/30119 1.56' 6 10000-10064 O 11/30/19 1.56' 6 10000 -10010 O 05/15/16 1.56' 4 10025 -10032 O 0925/15 1.56' 6 10025 -10032 O 05/15/16 1.56' 4 10042-10057 O 0925/15 1.56' 6 10042-10057 O 05/14/16 1.56' 6 10070 -10090 O 05/14/16 2' 4 10070 -10120 O 12/05/02 1.56' 6 10075-10107 O 1129/19 2- 4 10130-10180 O 12105/02 2- 4 10210.-10260 c 17/05/02 2- 4 10280 -10300 C 12/05/02 14-12' CAMOO SSSV NP, D=3.813' 1 r_ee � ivru•uno�, ST MD TVD DEV TYPE VLV I LATCH I PORT DATE 5 3152 3059 10 MERLA DOME RA 16 09111/06 4 6323 5776 32 MERLA DOME RM 16 09111A6 3 8030 7222 31 MERLA DOMEJ RA 1 16 09/11/06 2 8914 7982 30 MERLA DMY RM0 04114A4 1 9177 8210 31 MERLA SO RM I 20 11/16/19 926T —� 3.70' BKR DEPLOYMENT SLV, D=3.00- 3-1 r2- .00' 3-12' HES XN NP, D = 2.750' 9278' 3-12' X 33/16' XO, ID 1372' 9518'X4-12'TAN HBBP-R PKR,D=4.0' �MLLOLT WENd]OW 9684' - 9690' 9742' 3-3/16' X 2-7/8 3-3/16' LMR, 62#, L-80, .0076 bpf, D = 2.80' 9742' FISH:MLLEDC6P(01/01/16) - 2-7/8' LNR, 6.16#, L-80, .0055 bpf, OMMENTS DATE REV BYMADPERFS4 DATE REV BY COMMENTS 09115/88 GRV OMPLETION 02/14/17 KDP/JMD TREE C/O 01/17/16 12MSM2 DAVA(KACK (W -37A) 03/07/19 NLW/JMD 312' XNaUD PULLED 03/30116 10/02/15 JCM/JMDPERFS 092526/15 03/07/19 MWJMD SET 312' XXN PLUG W/PORTS 01/06/16 SW/JMD SET (01/02(16) 12/12/19 CJWJMD GLV C/O (11116/19 0323116 RCT/JMD0321116 12112/19 RCB/JMD PULLED PXN PLUG 11/17/19 05116/16 KS/JMD 5114-15116) 12112/19 TJS/JMD ADPERFS (11 2 9 5 0/1 9) PRUDHOE BAY UNIT WELL: W -37A PERMIT No: 1021490 API No: 50-029-21855-01 T11 N, R12E, 1321'SNL & 145, SP ExploraSon (Alaska) STATE OF ALASKA 4111LASKA OIL AND GAS CONSERVATION COMMI 111 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate a Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-149 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21855-01-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PBU W-37A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10352 feet Plugs measured 10190 feet 4 nn true vertical 9084 feet Junk measured feet J U N 1 2016 16 Effective Depth: measured 10190 feet Packer measured 9353 feet s true vertical 9004 feet Packer true vertical 8451 feet f3 C Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"Conductor 43-123 43-123 Surface 2639 13-3/8"68#L-80 42-2681 42-2681 5020 2260 Intermediate 9594 9-5/8"47#L-80 39-9633 39-8689 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10000-10010 feet 10025-10032 feet 10042-10057 feet 10070-10090 feet 10090-10120 feet 10130-10180 feet 10210-10260 feet 10280-10300 feet True vertical depth: 8921-8926 feet feet 8933-8936 feet 8940-8946 feet 8951-8959 feet 8959-8972 feet 8976-8999 feet 9013-9038 feet 9048-9058 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-9476 37-8555 Packers and SSSV(type,measured and 4-1/2"TIW HBBP-R Packer 9353 8451 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED DEC 0 7 2016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 195 128 1281 268 Subsequent to operation: 366 2263 108 910 256 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature „e .r !r"�— �j Phone +1 907 564 4424 Date 6/14/16 Form 10-404 Revised 5/2015 V7-1— 7/$ { 1� Submit Original Only W6 RBDMS W i r� 2016 , • . a) N o 0 0 0 R corn COO C N r,_r I- OOCN co co LC) co O co 10 (0 d) N IC) (") CO 00 00 CO CO N O (D CO f. N. O 10 N CO 00 CO CO 6) CO 11111111 H O N N- C) N d) f. CO 0) N. ti CO CO CO Cr CO 00 00 00 00 0100 N N (o N 00 C) N- V 00 M N- 7- O CO N N- O O .0 N O O) O O O ✓ q 1 1 1 I I 1 1 a Q00 CO N M C) N 0) 10 I� O tt N. V CO 0)) 0)) 0)) 0) CO COC a O O O O O co 00 00 CO J 4t 4t a) -O CO 1# N a) co •U) N C CO CO Cfl *k N U ao 00(.) NM '700 I"- 1 C) C) N V — cn O C) 'Cr O 7- O C) C CO Cfl In N (fl N C)) (fl O) J W C 0 Q U W W U O tY CC C c Z Z W W W W W pp Q j H Z_ Z_ Z_ Z_ j U Cn Z J J J J 40 II / R 4 co w ƒ c, / / ƒ / % , \ E ma < < oƒ - m Zo z � � wO I / a \ ¥ 0 o - LL C 11 \ G \ ® mG OCO ‹/ I / /1 �k >- < U ? I / as < % ƒ o m - 0 E o " 2 R < z cr DO_ si 2 r0 z0 b / � � = e ± z 0 - 6 s / Q m .g / a < R * o ± '5 w . / / / 0 \ 0 b / E % En C) W o Ft / , / p / 0 t m : 2 c / » Ox- R c - • - 2 O o� � / c ors Li < cZ ƒ ƒ / J 2 / ? / E / 2C � � e L < \ % Et \ / Ek * 0 / o Z ‘- - - < 2 / ± - 2 Cr = - 0 0 ~ f i06Hfw � L8 G z m Oto \ , ctq / _ R DW < OD- cn / a OUJ \ E / / 0 ,0fn6 ƒ E - « f \ / \ O ± ± u oi - \ / a0IE ?EweE ± < oo0� _ zI— I= cC < / / ± ± 2 / (i) - < < I - I - - ± La « e : m ± t : / S I : t I I r : a L < (0 o 0 0/ d/ 0/ ,- 5 A • o co \ r r\ < IF4 E= " 4-1/16"CNV WELLHEAD= CAMON • 7 A ! SA NOTES: ACTUATOR= AXELSON V I°'3 ! l KB.ELEV= 90.99' BF.ELEV= 54.14' KOP= 3200' Max Angle= 67"@ 10048' 2147' —14-1/2"CAMCO SSSV NP,D=3.813" Datum MD= 9942' Datum TVD= 8800'SS GAS LIFT MADS [ 13-3/8"CSG,68#,L-80 D=12.415" H 2680' 'ST MD TVD DEV TYPE VLV LATCH(PORT DATE 5 3152 3059 10 PU LA DONE RA I 16 09/11/06 LI 4 6323 5776 32 MERLA DONE RM 16 09/11/06 3 8030 7222 31 M3:LA DOM: RA 16 09/11/06 Minimum ID =2.37" @ 9742' 2 8914 7982 30 MRA DM' RM 0 04/14/04 1 9177 8210 31 M32LA SO RA 20 09/11/06 3-3/16" X 2-7/8" XO 9257' — 3.70"BKR DEPLOY MENT SLV,0=3.00" 9276' 1-13-1/2'HES XN NP,ID=2.7501 3-112"LNR 8.81#,L-80,.0087 bpf,D=2.99" H 9276' ► ►� I , ► ,' 9278' H 3-1/2"X 3-3/16"XO,0=2.80" • r/ Oh --- 01 TOP OF 7"LNR H 9403' .O ' II w v ► s ► 0� 1 0� 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" —I 9476' ,i. .•• •� • ••• 4 MLLOUT WNDOW 9684'-9690' 9-5/8"CSG,47#,L-80,0=8.681" —j 9633' :• '00 P • .•4 WHPSTOCK H9684• — • • %c. 9742' —1 3-3/16"X 2-778"XO,D=2.37" 7"LNR,26#,L-80,.0383 bpf,ID=6.276" —I —9684' 10190 _I—{23/100"BKR CBP(01/02/16) ( ORATION SUMMARYN%w\ ._- 10304' PBTD REF LOG:BHCS ON 09/01/88 __._.� ANGLE AT TOP PERF: 62'@ 10000' /� Note:Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn/Sgz DATE 1.56" 6 10000-10010 0 05/15/16 m*" -mo 1.56" 4 10025-10032 0 09/25/15 1.56" 6 10025-10032 0 05/15/16 3-3/16"LNR 6.2#,L-80,.0076 bpf,D=2.80" ]-1 9742' . 1.56" 4 10042-10057 0 09/25/15 [FISH:MILL®GBP(01/01/16) I-.--10310' CTIVID 1.56" 6 10042-10057 0 05/14/16 1. 6 10070-10090 0 05/14/16 2-7/8"LNR,6.16#,L-80,.0055 bpf,D=2.37" —i_ 10352' 2" 4 10070-10120 0 12/05/02 — 2" 4 10130-10180 0 12/05/02 2" 4 10210-10260 C 12/05/02 2" 4 10280-10300 C 12/05/02 DATE REV BY COMMENTS DATE REV BY COMvENTS FRUDHOE BAY UNIT 09/15/88 GRV ORIGINAL COMPLETION 10/02/15 JCMYJM.7 SET CIBFTADFERFS(09/25-26/15) WELL. W-37A 12/05/02 DAV/KK CTD SIDETRACK(W-37A) 01/06/16 SW/JMD MLLED 8 SET OBP(01/02/16) PERMIIT No:"2021490 12/21/02 JBITLH GLV CIO 03/23/16 RCT/JM)SET XN-IIA(03/21/16) API No: 50-029-21855-01 03/16/04 JLJ/KAK GLV CIO 05/16/16 KS/JM) ADPERFS(05/14-15/16) SEC 21,T11N,R12E,1321'SNL&1452'VW_ 04/14/04 JLJ/KAK GLV GO 05/19/16 NLW/JMJ PULLED IUD(03/31/16) 09/11/06 DAVITLF,GLV 00 BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, June 04, 2016 3:53 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead;AK, OPS WELL PAD W; Peru, Cale; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; McVey, Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: OPERABLE: Producer W-37A (PTD#2021490) TIFL Passed Verifying Two Barriers All, On 05/22/16 Producer W-37A (PTD#2021490)was classified as Under Evaluation after report of sustained inner annulus (IA) casing pressure over MOASP. A TIFL passed on 06/04/16 verifying two competent barriers. This well has been reclassified as Operable. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 907.564.5102 SC•iittaHW JUN 1 0 2016; C: 907.943.0296 H: x2376 Fro D&C Well Integrity Coordinator Sent: Mona , ay 23, 2016 11:52 AM To: AK, OPS GC2 O , K, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D ireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; A GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS WELL PAD W; Peru, Cale; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C ProjectsWell Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; McVey, A frriera•-• 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 3; Munk, Corey; Obrigewitch, Beau, •- us, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras 3 Subject: UNDER EVALUATION: Producer W-37A (PTD #2021490) Sustained Inner Annu + asing Pressure over MOASP All, 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, May 23, 2016 11:52 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead;AK, OPS WELL PAD W; Peru, Cale; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; McVey, Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer W-37A (PTD#2021490) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer W-37A (PTD #2021490) TIO Plot 2016-05-23.docx All, Producer W-37A(PTD#2021490)was reported to have sustained inner annulus (IA) casing pressure over MOASP on May 22, 2016. Pressures were confirmed to be TBG/IA/OA= 2440/2440/40 psi. Gas lift header pressure is approximately 1900 psi.The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Set Downhole Plug 2. Fullbore: Perform MIT-T and CMIT-TxIA 3. Well Integrity Engineer/Anchorage PE: Additional diagnostics as needed A copy of the TIO Plot has been included for reference. Please reply if in conflict with proposed plan. Thanks, SCANNED MAY 2 5 2Q16 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWeIIlntegrityCoordinator@BP.com From: AK, D&C We - Coordinator Sent: Saturday, November 07, s 0:48 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Fie • IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operation erintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East We S.t Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Ens..-er; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Pe Whitney; Sayers, Jessica; Dickerman, Eric �\ Subject: OPERABLE: Producer W-37A (PTD #2021490)TIFL Passed .� 1 �a� • Producer W-37A(PTD#2021490 ) TIO Plot 05/23/16 Well W-37 3.00: • +Tb) to 2.00G -.-OA -• _-+' ODA -�-0009 On 7.000 07/2316 010816 03ie'lE :3'YE :322'6 0329'b 017,5''E 07".2.1E Cd'4•a -.i615 050Y76 pglCg 05II:M STATE OF ALASKA • 41,LASKA OIL AND GAS CONSERVATION COMMI IIIK REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill CIBP/5CtC/e9D Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-149 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21855-01-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PBU W-37A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEI / ED Total Depth: measured 10352 feet Plugs measured 10190 feet S� true vertical 9084 feet Junk measured 10309 feet JAN 14 2016 Effective Depth: measured 10190 feet Packer measured 9353 feet true vertical 9004 feet Packer true vertical 8450.91 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 43-123 43-123 Surface 2639 13-3/8"68#L-80 42-2681 42-2681 5020 2260 Intermediate 9594 9-5/8"47#L-80 39-9633 39-8689 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10025-10032 feet 10042-10057 feet 10070-10120 feet 10130-10180 feet 10210-10260 feet 10280-10300 True vertical depth: 8933-8936 feet 8940-8946 feet 8951-8972 feet 8976-8999 feet 9013-9038 feet 9048-9058 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-9476 37-8555 Packers and SSSV(type,measured and 4-1/2"TIW HBBP-R Packer 9353 8450.91 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Milled previous CIBP @ 10061',pushed down hole to PBTD.Set new CIBP @ 10190'CTMD. Treatment descriptions including volumes used and final pressure: ES' j- E Via, A `;;� ` k, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 60 545 40 962 248 Subsequent to operation: 4 213 160 1276 252 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 1/13/16 Form 10-404 Revised 5/2015 Y`t-L 1/0 Z Z11 1 Y RBDMS Lt, JAN 1 9 2016 Submit Original Only .deo.4 /.6 • • m rn 0 oO co m °) O N I� oo CC) 0 N 'CrCO 0 • 0 0 0 N N-C 0 co ch pp in Co CO � rnr— NNvu) ch co 00 CO N- co cc IC) N O Co M N- N O CC) N CO CO CO CO 0) CO H O N- N C) N 0) N- CO 0) N- Cr `Cr CO CO CON CO CO CO CO CO CDC) CO N V N Cfl C N 00 CO N `Cr 00 co C CO CO N f-- co O N CA °) O 0) (D C) O p . Q < N- CO Cr) N Cr) M LO 0 N c.1 N- CJ C7) °) 0) o) • coC a OO O O0 o 00 cc coOo J 00 00 J = (3) -0 0000 N CO CO N N O C° _ CO _� CO U) U 00 _ N U oN COCO M ti C i i N V t a)0 CO °) O ( Ch ) C CO co Lc) N (fl Cb J N W V N C9 O W Q C W W U U 0 u CC CC C Z Z 1 W W W W W Q D H Z_ Z _Z Z_ D U U) Z J J J J H 0 • w N ai Cr)O) C = Y CD O L ._ C H } J a) f0 CO 0_ U O 11J CO a) � m � p Dp° Z20) m D C L O U O a O , N N O = N O O � > O cn Q O N O .- O .a O M 0Q ,- N N it O 0 0 I- N 0 0 12 O V = -0 0 a O r= O Y "6 as O N O Q� 2- as O O 3 aU U O •U J O 0 N E L 0) 0).- - O 5 -O N L C N QN- c �-L� (B N .O O cu N O a) C E a iu voi U 0 oo 0 �1CD N 4- Q N C�j N o_ N V 5 to O •co �= O 0 C a. O \ U v D 0 U c\" -. Z' O >- O 0 L O O 6) p _cJ ca0 > a E C �' U N c a) L o p •?i 0 O V = O E m L < O C a) ..6 .0 _,' a- \ p ct O E a) O O U (Q 2 O— O a O J -a N (n >, 73 aL U' Z O co H Qpm = m mH ° � m o 00 0 m O N- U e -0 U U = �p U U N o_J. D U Y co 0 \ O = z U = li j .73 M a)co C E u) 4a. o �. o a) a. _c alE �0 a) 14- a) _ a) 0 V N L0 U 00 - O JO C O - O W O � U � OE cC L - UH C a f� CO \ M 05@ C p a6 O .� CO is od CO t = c\i - cow _ tea_ Oa a) o r•-•O d 2 L - a_ 0 U) r3 Cr) - co -.-% Q t E ,- _ re w-m a fl-U �-m 3 Q N m - } Q O o ns O _ EU a) oN ami cm o - Ha) ,-- as O > -0 O _c ~ O O = U = O C"-O O \ 0 I- -, H aE >> i Q* H -0 C rn ZNI . o � H Qo o U � c � U E mein m CO 0 °(13 0 ) ., -a w O a) 0_ w ° � 75. 0U o D �a 0 o - EP .g .g -occ - - O cY) p m a. CO c Z a. CSJ 2 N D 0 0 0 ) 0 (0 i' U _a O - D cD S c0 CDO O v) to N CZD Qih O . U) H - - * H o o - 'c6 O H O Y N p co p N r H o N 4 c) 8-9- 0oO 2 E « 0 0 D E o_a. : O a_ in Q U a. U a. Z O U) (-.i : m W Q (r) L1) 0 _p CO } O O O O N O O H \O ,_ N N _0 ' N 5 CO Mm CO I� N N N N- 0 Q 11,1*= 4-1/16'OW Vial_FEA D= CANE:RON W-37A ;Alit NOTES: AClUA TOR= AXE3_SON KB.ELEV= 90.99' BF EV= 54.14' KOP= 3200' 2147' —14-1/2"CAMCO SSSV PAR 0=3.813' Max Angle= 57 @ 10048' Datum MD= 9942' Datum TVD= 8800'SS GAS UFT MANDRELS 13-3/8"CSG,68#,L-80,0=12.415" H 2680' d IST MD ND DEV TYPE VLV LATCH FORT DATE 5 3152 3059 10 PARLA DOLE RA 16 09/11/06 4 6323 5776 32 P.ERLA COW RM 16 09/11/06 3 8030 7222 31 MERLA [OKE RA 16 09/11/06 Minimum ID = 2.37" @ 9742' 2 8914 7982 30 PERLA DMY RM 0 04/14/04 3-3/1 6" X 2-7/8" X0 1 9177 8210 31 MERLA SO RA 20 0911 1/06 9267' — 3.70"BKR DEPLOY WENT SLV,13=3.00" 9276' 3-1/2'HES XN NP,ID=2,750" 3-1/2"LNR,8.81#,L-80,.0087 bpf,ID=2.9T — 9276' k 9278' — 3-1/2"X 3-3/16-X0, =2.80" --- IP • 4 4 g°4 1'$ TOP OF 7'LM t — 9403' 4 4 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" — 9476' 4 •A4 .00 0'4 •4 Mt_I.OUT WINDOVV 9684'-9690" 9-5/8'CSG,47#,L-80,ID=8.681" H 9633' •V •4 ••4 • 0• •4 ••4 •4 P• I •4 k 9742' H 3-3/16"X 2-7/8"XO,ID=2 37' V$A-IPSTOCK 9684' 1114% 10190' —23/100'BKR GBP(01/02/16) 444414.1 1%p 41444.44 44144444.4.4.4. 4\i\ 10304' FEETD I 7"LNR 26#,L-80,.0383 bpf,D=6.276" — 10265' veAvAvAvAvAve ....... SIrWo. .1101,wa' PERFORATION SUMAARY -mor REF LOG:BHCS ON 09/01/88 [ 3-3/16'LM,6_2#,L-80,.0078 bpf,SD=2.80' — 9742' ANGLE AT TOP FERE: 65°ai 10025' Note Refer k Roducbon DB for historical pert data FISI-t PALLED CE3P(01/01/16) — 10310'CTMD SIZE SW FATERVAL Opri/Sqz DATE 1.56" 4 10025-10032 0 09/25/15 2-7/8"LNR,6 16#,L-80, 0055 bpi,D=2.37" —{ 10352' 1.56' 4 10042-10057 0 09/25/15 2" 4 10070-10120 0 12/05/02 2' 4 10130-10180 0 12/05/02 2' 4 10210-10260 C 12/05/02 2" 4 10280-10300 C 12/05/02 DATE REV BY COMA3NITS DATE REV BY COROAENTS PRUDHOE BAY INT 09/15/88 GRV ORIGINAL COM PLETION 10/02/15 JOAJAD SET CERACPERFS(09/25-26/15) WELL W-37A 12/05/02 DAVIKK CTD SIDETRACK(W-37A) 01/06/16 SW/J1.0 PALLED&SET CEIP(01/02/16) PERMIT INEcc'2021490 12/21/02 JB/TLH GLV C/O AR No 50-029-21855-01 03/16/04 JLJ/KAK GLV 00 SEC 21,T11N,R12E,1321'SNL& 1452'VVB_ 04/14104 JLJ/KAK GLV C./0 09/11/06 DAV/TLH GLV BP Exploration(Alaska) S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, November 07, 2015 10:48 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; jim.regg@alaska.gov'; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric Subject: OPERABLE: Producer W-37A (PTD #2021490) TIFL Passed All, Producer W-37A(PTD#2021490) passed a warm TIFL on November 07, 2015 confirming two competent barriers in the wellbore. The well is reclassified as Operable and may be brought online as needed. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAY 1 12016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator(a)BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, November 04, 2015 7:59 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov'; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric Subject: UDNER EVALUATION: Producer W-37A (PTD #2021490) Sustained Inner Annulus Casing Pressure over MOASP All, Producer W-37A(PTD#2021490) was reported to have sustained inner annulus casing pressure over MOASP on November 01, 2015. The pressures were confirmed to be TBG/IA/OA= 2100/2060/100 psi. A subsequent cold TIFL failed on November 03, 2015 indicating a potential lack of two competent barriers in the wellbore. At this time,the well has been reclassified as Under Evaluation for additional diagnostics. 1 • • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Wednesday, November 04, 2015 7:59 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; jim.regg@alaska.gov'; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric Subject: UDNER EVALUATION: Producer W-37A (PTD #2021490) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer W-37A (PTD #2021490) TIO Plot.docx All, Producer W-37A(PTD#2021490)was reported to have sustained inner annulus casing pressure over MOASP on November 01, 2015. The pressures were confirmed to be TBG/IA/OA= 2100/2060/100 psi. A subsequent cold TIFL failed on November 03, 2015 indicating a potential lack of two competent barriers in the wellbore. At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Cold TIFL—FAILED 11/03/15 2. Operations: Place on production 3. Downhole Diagnostics: Warm TIFL 4. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO Plot has been included for reference. Please call with any questions or concerns. Thank you, MAY 1 1 2016 Whitney Pettus S`ppNE� (Alternate:Kevin Parks) .BAP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • • Producer W-37A(PTD#2021490) TIO Plot November 04, 2015 Well w 37 aaco 3 CO {"Me to —111— ..-410— + OA 411 7 0C4- DOA OOOA On i ttC.. 09415 0911,15 09'1915 0925.15 10.02'5 l 100915 15'415 102615 1(1' '15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:5c 71—G6(3p I " 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-149 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21855-01-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PBU W-37A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: .„ 1 ' Total Depth: measured 10352 feet Plugs measured 10061 feet true vertical 9084 feet JunkiiC i01`- measured feet �J 2 1,, � ;'i Effective Depth: measured 10061 feet Packer measured 9353 feet true vertical 8947 feet Packer sss " true vertical 8451 feet `"" � -I Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 43-123 43-123 Surface 2639 13-3/8"68#L-80 42-2681 42-2681 5020 2260 Intermediate 9594 9-5/8"47#L-80 39-9633 39-8689 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10025-10032 feet 10042-10057 feet 10070-10120 feet 10130-10180 feet 10210-10260 feet 10280-10300 True vertical depth: 8933-8936 feet 8940-8946 feet 8951-8972 feet 8976-8999 feet 9013-9038 feet 9048-9058 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-9476 37-8555 Packers and SSSV(type,measured and 4-1/2"TIW HBBP-R Packer 9353 8451 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): F y��y Treatment descriptions including volumes used and final pressure: SCAN EQ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 420 1864 1470 253 Subsequent to operation: 112 1838 16 688 247 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Af[yt„M_ C.W .-- Phone +1 907 564 4424 Date 10/21/15 Form 10-404 Revised 5/2015 V 77- I°`Z7-ll RBDMS ,OV L i t015 Submit Original Only to�2'"/5_ • • N O O O O N CO CO CO U I% O O 0 - N f� M 3 O 00 V V m 1.0 CO COCO M c- O) N. N- N LC) CO CO CO N- CO CO 10 N O CO CO N- N 00 00 00 00 CA 00 I— O N N- M N O) I- CO O) N- N- d' co co co I"- CO CO CO CO CO C — co CO N NCD M 00 CO N- CO co CO O N N- O M N O 0) 0) 0) 0) C.) CI mill I I I 4.a ICC Q • M N M V 'Cr CO N N N- O O O O C L� co 0. 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Z 4) „ F- z O CI W I- Y Q ❑ c L.,_ 0_ 5 j j azU < 0 c' pw � � co01 CL Ow03 '� zm - ~ ct w z CE % o ❑ �•`� 0_ 0 m X x0 _ Q ❑ m W > _ap CDp D Ot o n a� >- N � N � OaU) L i''' C) 17.117/. 75 -- CD fX •( ° m F- r a ° � wF�- X ( °6 � v u � CCz uJacwno o ° w Qm � a QD � ct b II Q Q O J J CC 0 0 w6 -J F- O * W 2 F- b CO N J N U p ❑Z (j j Q Q a' J4) Nw `,`' E OEo ° oswz ❑ ON2UOc,i OO fl- o - >, Q "' � ❑ F- II < W LI] CL II Q0) 0 aE -r 3 x Xpoo � Zoz z � � awz � ❑ mw0 Lo * ~ � <cONN � NO OLOw wzOClUF- w W LI - W CD c Q U) 0 O to O - >§ >§ D F- W O D D D (O w U) LoD W M r Z � 2F- PL -- II F- II > > O ❑ z ~ = ZZ � 2U' MN- = J (DOW � 55 � ❑W O� o > D I IIWII- F- .• - F- zzwmJo0E- 2 � � 0.1 � ❑ ❑ JF- LO .— F O � � � WOO � a0 � WOv �F- JLL J _ CO UU 'F- Hw010 wF- F- E2 II O W Q *kI._ N0 ❑ OJmmd. LZJJm as C W W > 0Q ? � � zozo � � JOOcnZco ❑ QJOp 3Q W -CD � � > z ❑ C ❑ oOQOw * ? 0C ❑ CD -- \ 00 coS * ❑ ❑ * * F= ©ci) * ccT- ocT- OJF- > * * JCt � = Ii. « if 5 < W F- LU L to LU LU cn>- O O O o o F- M V N N N C M M (O > CV L CO r (N CD N N N 0 O O O) Q TREE= 4-1/16"OW 411) I WELLI-AD= CAMERON W-37Asit NOTES: ACTUATOR= AXELSON KB.ELEV= 90.99' BF.ELEV= 54.14' KOP= 3200' 2147' —14-1/2"CARCO SSSV NP, =3.813- Max Angle= 37 @ 10048' DatumW13= 9942' Datum TVD= 8800'SS GAS LFTA4ANDRELS r 133/8 CSG 68#,L 80 HD=12.415" H 2680 J IL§r TVD DB/ TYRE. VLV LATCH FORT DATE 5 3152 3059 10 WERLA DOME. RA 16 09/11/06 LI 4 6323 5776 32 PLA DONE RA4 16 09/11/06 3 8030 7777 31 MERLA CONE RA 16 09/11/06 Minimum ID =2.37" @ 9742' 2 8914 7982 30 WERLA [MY RA 0 04/14/04 3-3/16" X 2-7/8" XO 1 9177 8210 31 NERD\ SO RA 20 09/11/06 9257' — 3.70"BKR DEPLOYMENT SLV,ID=3.00" L 9276' H 3-1/2"HES XN ID=2.750" 3-1/2"LNR,8.81#,L-80,.0087 bpi,D=2.99" H 9276. • 9278' H 3-1/2"X 3-3/16"XO,13=2.80" 4 4 1 4 4 4 1 4 /IP Oh oil M 041•MI 70P OF 7'LNR 9403' '• • •• 4 A / • 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3,958* H 9476' '44 •4" •• •• 4 .O••4 • .•4 MILOUT WINDOW 9684'-9690' • 0* •4 ••4 9-5/8'CSG,47#,L-80, =8.681" H 9633' • • •4 .•4 • 4• •4 .•4 • •4 9742' IH 3-3/16-X 2-7/8"XO,D=2.37" WI-O3S-TOCK 8684' - N% 10061' —12-7/8"BKR CIBP(09126/15) 14.44T4V 44444444 .414.4•414.4•4. .4...44. - 10304' H pup] 41•4144p 7"L1'42.,26#,L-80,.0383 bpf, =6.276" — 10266' veAvAvAvAvAye ArSzs. PERFORATION SUIVOAARY REF LOG:BHCS ON 09/01/88 3-3/16"LMk 6.2#,L-80,.0076 bpf,13=2.80" H 9742' ANGLE AT TOP FERF: 65" 10025' Note.Refer to Rod uction DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 1.56' 4 10025-10032 0 09/25/15 I 2-7/8"LNR,6.16#,L-80,.0055 bpf.I)=237" H 10352' 1.56" 4 10042-10057 0 09/25/15 2" 4 10070-10120 C 12/05/02 2" 4 10130-10180 C 12/05/02 2' 4 10210-10260 C 12/05/02 2" 4 10280-10300 C 12/05/02 DATE REV BY COIVIMINTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/15/88 GRV ORIGINAL COMPLETION 10/02/15 Jaw.svAD SET CI3P/ADPBTS(09/25-26/15) WELL: W-37A 12/05/02 DAV/KK CTD SIDETRACK(W-37A) PERIVIIT No:'t021490 12/21/02 JB/TLH GLV CIO AR No: 50-029-21855-01 03/16/04 JUIKAK GLV C/O SEC 21,T11N,R12E,1321'SNL&1452'VVEL 04/14/04 JLJIKAK GLV C/O 09/11/06 DAV/TLHGLV C/O BP Exploration(Alaska) r a ¢ (Z i O,�,Z v Q4,W I, vl m J m v CU L l/�_11 r U ia'IY (tiD 11 w a) O b Q� Y U > \` co Q C 0 Ny V K N co O o OL L c w �. ap '-' H >, x'$csi u 7 o co co o v YV E O O O a a. a A IV ,=,a 4-+ -O ,, Cr) L V y G ' a' NQ • � '7 C0 A - a) O -; ya ) Oa a Q a a a s a$ a L c c ra .41aa2aaa aaEaE E y rp E -,-- ,-- Z01) N N N N V V N N N h � C et, CLI a VI Z K ... 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O::Z - J Lt-q Well History File Identifier Organizing (done) ¡rWo-Sided 1111111111111111111 0 Rescan Needed 1 RESCAN DIGITAL DATA ~skettes, No. 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Color Items: œGreyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: BY: Helen~ria) 0 Other:i Date: , "<3 ()s- 1 Date: I 1.'3 05 Isl ~ Is! VVt r NOTES: Project Proofing BY: Helen Maria Scanning Preparation I x 30 =..=50 + ~ = TOTAL PAGES3fþ (Count d0es. no~ include cover sheet) ./lAD Date: I '3 OS 151 V V", 1 BY: Helen Maria Production Scanning Stage 1 Page Count from Scanned File: 3..5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Date: / /1 if 'DS" Is! ~ YES ' NO If NO in stage 1, page(s) discrepancies were found: BY: Helen ~ Stage 1 BY: BY: Helen Maria Date: 151 1 1 Date: 151 Quality Checked 1111111111111111111 Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, August 20, 2013 12:56 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS Well Pad SW; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: W Pad Producers with Sustained Casing Pressures during TAR All, The below producer wells are ready to be brought online Under Evaluation for further diagnostics after their IA exceeded MOASP during TAR: W-16A(PTD#2031000) W-21A(PTD#2011110) r _, '� W-22 (PTD#1881100) SCENE W-36(PTD#188106 W- A PTD#20214901) W-38A(PTD#2021910) , Should a well fail the warm TIFL,an email will be sent to the AOGCC with a plan forward.The producer well below will be brought online Under Evaluation to evaluate OA over MOASP for further diagnostics. W-01A(PTD#2031760) The DART results will be relayed in a separate email. Please call with any questions. Regards, Laurie Climer (:llter flak':.ia k DrNbr; 7 BBPP Alaska - Well Integrity Coordinator rn.l.3 V V Olga 4dt +'1 WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator(aBP.com 1 '&4 W-374 202 0 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelIIntegrityCoordinator @bp.com] Sent: Friday, June 14, 2013 10:12 PM 1<eff 61,7113 To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Longden, Kaity; AK, OPS Well Pad SW; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Weiss, Troy D Subject: OPERABLE: Producer W-37A(PTD#2021490) Passing TIFL All, Producer W-37A(PTD#2021490) passed a TIFL on 06/13/2013, confirming two competent barriers.At this time the well is returned to Operable status and may remain online. Thank you, Laurie Climer 14Iternrrtc.luck I7ishr•oua BP Alaska - Well Integrity Coordinator GIN FEB 2 0 2014 SCANNED WIC Office: 907.659.5102 WIC Email: AKDCWelllntegritVCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, June 03, 2013 5:20 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Servi -s Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Longden, Kaity; AK, 6'S Well Pad SW; 'jim.regg @alaska.gov'; 'Schwartz, Guy L(DOA)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinate , Holt, Ryan P; Weiss, Troy D Subject: UNDER EVALUATION: Producer W-37A (PTD #2021490) Sustai d Inner Annulus Casing Pressure Above MOASP All, Producer W-37A(PTD#2021490)was reported with sust•• ed inner annulus casing pressure above MOASP on 06/01/2013. The pressures were tubing/inner annulu outer annulus 2460/2460/10 psi. A subsequent cold TIFL failed on 06/02/2013. The well is reclassified as Under E uation and is placed on a 28 day clock for evaluation. Plan forward: 1. DHD: Place well on production an• perform warm TIFL 2. Slickline: Changeout orifice gas ' t valve if warm TIFL does not pass A copy of the TIO plot and wellbore schematic are included for reference. Please call with any questions. 1 Pgoc. w-374 Regg, James B (DOA) Z1`teiD From: AK, D&C Well Integrity Coordinator[AKDCWeIllntegrityCoordinator @bp.com] �� ` Sent: Monday, June 03, 2013 5:20 AM /�j To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Longden, Kaity; AK, OPS Well Pad SW; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Weiss, Troy D Subject: UNDER EVALUATION: Producer W-37A(PTD#2021490) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer W-37A(PTD#2021490)Wellbore Schematic.pdf; Producer W-37A(PTD# 2021490)TIO Plot.docx All, Producer W-37A(PTD#2021490) was reported with sustained inner annulus casing pressure above MOASP on 06/01/2013. The pressures were tubing/inner annulus/outer annulus 2460/2460/10 psi. A subsequent cold TIFL failed on 06/02/2013. The well is reclassified as Under Evaluation and is placed on a 28 day clock for evaluation. Plan forward: 1. DHD: Place well on production and perform warm TIFL 2. Slickline: Changeout orifice gas lift valve if warm TIFL does not pass A copy of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Thank you, SCANNED �(f)= 2460 cc? Jack Disbrow 6 670P`� Bp Alaska-Well Integrity Coordinator Global ?'eil MI = s, 1, Organ tCzatior? Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator @bp.com 1 40 4"1"so88 � I O _M _03 ,M- � O • O M � _n M 11°1 a _4 t�3 O M 0. H C rn d N MC O u • o CD a • °m co O n. co H TREE= 4-1/16"CW W ELL HEAD= CAMERON VV-37A SAFETY NOTES: ACTUATOR= AXELSON KB.ELEV= 90.99' BF.ELEV = 54.14' KOP 3200' Max Angle= 67 @ 10048' 2147' I-4-1/2"CAMCO SSSV NIP,ID=3.813" Datum MD= 9942' Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80, ID=12.415" -I 2680' I--4 ` _ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE LI 5 3152 3059 10 MERLA DOME RA 16 09/11/06 4 6323 5776 32 MERLA DOME RM 16 09/11/06 Minimum ID = 2.37" 9742 3 8030 7222 31 MERLA DOME RA 16 09/11/06 2 8914 7982 30 MERLA DMY RM 0 04/14/04 3-3/16" X 2-7/8" XO 1 9177 8210 31 MERLA SO RA 20 09/11/06 9257' H 3.70"BKR DEPLOYMENT SLV, ID=3.00" I 9276' H 3-1/2"HES XN NIP, ID=2.750" 3-1/2"LNR,8.81#,L-80,.0087 bpf,ID=2.99" —I 9276' - J 9278' J 3-1/2"X 3-3/16"XO, ID=2.80"I d 4Ib TOP OF 7"LNR H 9403' -41 N.A. 4 P1 vi i *1 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" —I 9476' I �4 0 OA*, *��1 MILLOUT WINDOW 9684'-9690' 9-5/8"CSG,47#,L-80, ID=8.681" --I 9633' I , OA WHIPSTOCK 9684' 9742' J-I 3-3/16"X 2-7/8"XO, ID=2.37"I 111111111 k k�� i�i 10304' -I PBTD I 1'1'1'1'1'1'1'11'1 1111111111111111 1111 • i�1�1� ao 7"LNR,26#,L-80,.0383 bpf, ID=6.276" 10265' ►uu 3-3/16"LNR,6.2#,L-80,.0076 bpf, ID=2.80" , 9742' PERFORATION SUMMARY REF LOG:BHCS ON 09/01/88 ANGLE AT TOP PERF: 65 @ 10070' 2-7/8"LNR,6.16#,L-80, .0055 bpf,ID=2.37" H 10352' I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10070- 10120 0 12/05/02 2" 4 10130- 10180 0 12/05/02 2" 4 10210- 10260 0 12/05/02 2" 4 10280- 10300 0 12/05/02 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/15/88 GRV ORIGINAL COMPLETION WELL: W-37A 12105/02 DAV/KK CTD SIDETRACK(W-37A) PERMIT No: 2021490 12/21/02 JB/TLH GLV 0/0 API No: 50-029-21855-01 03/16/04 JLJ/KAK GLV 0/0 SEC 21,T11N,R12E, 1321'SNL&1452'WEL 04/14/04 JLJ/KAK GLV C/O 09/11/06 DAV/TLH GLV 0/0 BP Exploration(Alaska) EIVED STATE OF ALASKA • . OKA OIL AND GAS CONSERVATION COM SION MAY 2 9 2013 REPORT OF SUNDRY WELL OPERATIONS Gcc 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Othe ✓ Mill Plug • Performed: Alter Casing ❑ Pull TubingD Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown Stimulate - Other al . Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmental . Exploratory ❑ 202 -149 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21855 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028263 PBU W -37A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL.. 11. Present Well Condition Summary: Total Depth measured 10352 feet ' Plugs measured None feet true vertical 9083 feet Junk measured None feet Effective Depth measured 10304 feet Packer measured 9372 feet true vertical 9059.99 feet true vertical 8467.17 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 37 - 117 37 - 117 0 0 Surface 2644 13 -3/8" 68# L -80 36 - 2680 36 - 2679.98 5020 2260 Intermediate None None None None None None Production 9598 9 -5/8" 47# L -80 35 - 9633 35 - 8688.46 6870 4760 Liner 862 7" 26# IJ4S 9403 - 10265 8493.46 - 9040.44 0 0 Perforation depth Measured depth 10070 - 10120 feet 10130 - 10180 feet 10210 - 10260 feet 10280 - 10300 feet True Vertical depth 8950.97 - 8971.87 feet 8976.32 - 8999.28 feet 9013.37 - 9037.91 feet 9048.01 - 9058 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 34 - 9476 34 - 8555.37 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" TIW HBBP -R Packer 9372 8467.17 Packer None None None SSSV 12. Stimulation or cement squeeze summary: ( 6 4 r, n Intervals treated (measured): ��KO tIUN , "J 10070'- 10120', 10130'- 10180', 10210'- 10260', 10280'- 10300' Treatment descriptions including volumes used and final pressure: 1450BBL 2% KCL W /FLOVIS, 780BBL 2% KCL W /F103, 42BBL POWERVIS 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 200 2571 648 0 219 Subsequent to operation: 353 2270 1329 1806 396 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development al • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil is , Gas ❑ WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summ BP.com Printed Name Nita Summerha s Title Petrotechnical Data Technician Signatu / Phone 564 -4035 Date 5/29/2013 (r r A / 4( RBDMS MAY 2 9 201 1 ►3 Form 10 -404 Revised 10/2012 "- Submit Original Only • Daily Report of Well Operations ADL0028263 ASRC Test Unit #2 DAD Acid Stimulation. MIRI.:a, wa• ®a ve on VI 37, needs replaced. Continue R/U Inlet W -37, Outlet W- 36. ** 4/27/2013 Continued on WSR 4/28/13 ** T /I /O = SI /800 /0 Conduct PJSM. Barriers= MV & SSV. Verified by bleeding tubing pressure off MV & SSV independently. LTT Passed. Removed old SV (4 1/16 CIW FL). Install new SV (4 1/16 FMC 120). Torqued SV X Flowcross and SV X Tree Cap flanges to 976 FT -LBS. Pressure tested new swab valve through Tree cap 200 -300 psi low (PASSED) and 5000 psi high (PASSED). Tests charted and saved to TRP folder. Bled tree pressure to 0 psi, closed swab valve 23 1/2 turns. Rigged down, Job Complete. 4/28/2013 ASRC Test Unit #2 ** Continued from WSR 4/27/13 ** DAD Acid Stimulation. Continue R /U. STBY for Swab 0 /0. STBY for Personell. STBY For Pad -Op. Continue R /U. Inlet W -37, Outlet W- 36. ** 4/28/2013 Continued on WSR 4/29/13 ** ASRC Test Unit #2 ** Continued from WSR 4/28/13 ** DAD Acid Stimulation. Complete R /U. PT I/L and 3rd Leg. STBY for CTU. Inlet W- 4/29/2013 37, Outlet W- 36. ** Continued on WSR 4/30/13 ** CTU #9 1.75" coil Job Objective: Acid job AOL, PJSM RU CTU. Rlh w/ 1.75' x 0.1" CTC with, 2' x 1.075" checks, 2' x 4.575" stinger, 2' x 4.25" stinger, 2.28' x 0.525" BDN. tryed to jet through the obsticles in the well at 10040' CTM. Unsuccessful. POOH. RIH with BOT 1.75" x .29" CTC, 1.69" x 1.5' DFCV, 1.69" 6.61' Bowen Oil Jars, 1.69" x 1.36 Hyd Disc (1/2" Ball), 1.69" x .93' Dual Circ sub (3/8" Ball 5K Burst) 1.69" x 7.64' Extreme X motor, 2.0" x .49' x- over, 2.30" x 1.25' Gen 2 Turbo Scale mill Total = 20.07' 4/30/2013 «Job continued on 05 -01 -13 WSR» ASRC Test Unit #2 ** Continued from WSR 4/29/13 ** DAD Acid Stimulation. STBY for CTU. CTU MIRU. CTU Tag & POOH. CTU 0/0 Tools for Mill. CTU RIH. POP Well. G/L @ 1.0 mmscf /d Inlet W -37, 4/30/2013 Outlet W- 36. ** Continued on WSR 5/01/13 ** ASRC Test Unit #2 ** Continued from WSR 4/30/13 ** DAD Acid Stimulation. Continue Assisting CTU w/ Milling Portion of Job. 3rd Leg CK down/ Divert Gel Sweeps to FB Tank. CTU POOH/ Check Tools. 3rd Leg CK Repaired/ PT'd. CTU RIH. Continue Assisting CTU w Mill 5/1/2013 Job. Inlet W -37, Outlet W- 36. ** Continued on WSR 5/02/13 ** • • Daily Report of Well Operations ADL0028263 CTU #9 1.75" Coil Job objective: Mill /Acidize RIH with BOT 1.75" x .29" CTC, 1.69" x 1.5' DFCV, 1.69" 6.61' Bowen Oil Jars, 1.69" x 1.36 Hyd Disc (1/2" Ball), 1.69" x .93' Dual Circ sub (3/8" Ball 5K Burst) 1.69" x 7.64' Extreme X motor, 2.0" x .49' x -over, 2.30" x 1.25' Gen 2 Turbo Scale mill Total = 20.07' to 10074' CTM. Tagged @ 10054 ctm and began milling. Milled down to 10125' ctm where milling became slow and more stalls prevalent. POOH to look at mill and motor. At surface the mill had a few buttons broke off and the motor was leaking from the bearing box. Decision was made to swap to a new motor and 2.3" Turbo Scale mill to 10122' CTM. Milling ahead. Currently at 10174' CTM at report time. Averaging .5' /min ROP 5/1/2013 « <Job continued on 05 -02 -13 WSR >» ASRC Test Unit #2 ** Continued from WSR 5/01/13 ** DAD Acid Stimulation. Continue Assisting CTU w/ Mill Job. CTU POOH to C/0 tools & motor. CTU RIH. POP Well. Continue Assisting CTU w/ Mill Job. 5/2/2013 Inlet W -37, Outlet W- 36. ** Continued on WSR 5/03/13 ** CTU #9 1.75" Coil Job objective: Mill /Acidize Millied to 10185, saw no motor work, PU and come down to 10181 saw no motor work again, After monitoring for 20 min decide to POOH and inspect the motor. Replaced motor and the disconnect. RBIH. Saw initial motor work at 10178' CTM, Milled ahead to 10218' CTM. Had problem with pump control, fixed and run back in hole. 5/2/2013 « <Job continued on 05 -03 -13 WSR »> CTU #9 1.75" Coil Job objective: Mill /Acidize Milled till 10220 ft, saw many stalls, decided to come out of the hole and rin in with different motor and bit. Rih w/ WFR 1.89" x .29' CTC, 1.688" x 1.76' MHA (9/16" Ball ), 1.68" x .60' Circ sub (1/2" ball, 5K Burst) 1.81" x 6.88' Jar, 1.68" x 9.41' ECTD motor#2, 2.1" x .4' x -over, 2.30" x .52' Parabolic diamond mill with non side tracking gauge OAL= 19.86' 5/3/2013 « <Job continued on 05 -04 -13 WSR »> ASRC Test Unit #2 ** Continued from WSR 5/02/13 ** DAD Acid Stimulation. Continue Assisting CTU w/ Mill Job. CTU Pump Down. 5/3/2013 Inlet W -37, Outlet W- 36. ** Continued on WSR 5/04/13 ** T /I /0= 2388/1185/ -5 Temp =S /I Assist coil/ Load IA (Acid stimulation) Pumped 5 bbls MEOH & 574 bbls crude to load IA. FWHP's= 2043/855/- 5/4/2013 2 Upon departure DSO notified CTU on well & in control of all VLV's CTU #9 1.75" Coil Job objective: Mill /Acidize Rih w/ WFR 1.89" x .29' CTC, 1.688" x 1.76' MHA (9/16" Ball ), 1.68" x .60' Circ sub (1/2" ball, 5K Burst) 1.81" x 6.88' Jar, 1.68" x 9.41' ECTD motor#2, 2.1" x .4' x -over, 2.30" x .52' Parabolic diamond mill with non side tracking gauge OAL= 19.86'. Milled to 10277 ft, Tag PBTD 10278 ctm. Circulate 10bb1 gel pill. POOH. Put a 2" JSN. Performed passing weekly BOPE test. LRS loaded IA with 574 bbls Dead Crude. Start Acid job, pumped 46 bbl KCL F103, 61 bbl Acid, 91 bbl KCL F103, 6 bbl Wax beads, 46 bbl KCL F103, 44bb1 Acid. 5/4/2013 « <Job continued on 05 -05 -13 WSR »> • • Daily Report of Well Operations ADL0028263 ASRC Test Unit #2 ** Continued from WSR 5/04/13 ** DAD Acid Stimulation. Continue cleaning up well. Inlet W -37, Outlet W- 36. ** 5/5/2013 Continued on WSR 5/06/13 ** CTU #9 1.75" Coil Job objective: Mill / Acidize Pumped remainder of Acid, 200 bbl of 2% KCL w/ F103 Overflush. POOH. Rig down coil, Turn over to ASRC for flowback. Depart location for E- 23C 5/5/2013 «JOB COMPLETE» ASRC T f Unit #2 ** Continued WSR 5/05/13 ** DAD Acid Stimulation. Continue cleaning up well. Inlet W -37, Outlet W- 36. ** 5/6/2013 Continued on WSR 5/07/13 ** ASRC Test Unit #2 ** Continued from WSR 5/06/13 ** DAD Acid Stimulation. Continue with 8 hr testi. Inlet W -37, Outlet W- 36. ** Job 5/7/2013 complete at 22:00 ** FLUIDS PUMPED BBLS 1450 2% KCL W /FLOVIS 780 2% KCL W/F103 42 POWERVIS 171 60/40 METH 5 METH 574 CRUDE 750 TOTAL TREE = 4-1/16" CNV WELLHEAD = CAMERON W�3 7A SAFETY NOTES: ACTUATOR = AXELSON KB. ELEV = 90.99' BF. ELEV = 54.14' KOP = 3200' 214T I— I4 -1/2" CAMCO SSSV NIP, ID = 3.813" I Max Angle = 67 @ 10048' Datum MD = 9942' Datum TVD = 8800' SS I 13 -3/8" CSG, 68 #, L -80, ID = 12.415" H 2680' I---A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ' 5 3152 3059 10 MERLA DOME RA 16 09/11/06 4 6323 5776 32 MERLA DOME RM 16 09/11/06 3 8030 7222 31 MERLA DOME RA 16 09/11/06 Minimum ID = 2.37" @ 9742' 2 8914 7982 30 MERLA DMY RM 0 04/14/04 3 -3/16" X 2 -7/8" XO 1 9177 8210 31 MERLA SO RA 20 09/11/06 ■ 9257' H 3.70" BKR DEPLOYMENT SLV, ID = 3.00" L 9276' H 3 -1/2" HES XN NIP, ID = 2.750" I 13-1/2" LNR, 8.81 #, L -80, .0087 bpf, ID = 2.99" I-1 9276' ►� ►� 9278' 1—I 3 -1/2" X 3- 3/16" XO, ID = 2.80" ►� • • • ♦ • "� ►ii I TOP OF 7" LNR 1 9403' �•�� 0 j! ��' • / • ■ / • / I4 -1/2" TBG, 12.6 #, L - 80, .0152 bpf, ID = 3.958" H 9476' •• ►•♦• 0 * ► • •4 MILLOUT WINDOW 9684' - 9690' I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I 9633' ♦• 1 WHIPSTOCK I 9684' , ��i �`. 9742' —I 3- 3/16" X 2 -7/8" XO, ID = 2.37" 1•• 10304' PBTD I 4 %4 I 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I 10265' ��Qat.��• I 3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" I 9742' PERFORATION SUMMARY REF LOG: BHCS ON 09/01/88 ANGLE AT TOP PERF: 65 @ 10070' I 2 -7/8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.37" H 10352' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 10070 - 10120 0 12/05/02 2" 4 10130 - 10180 0 12/05/02 2" 4 10210 - 10260 0 12/05/02 2" 4 10280 - 10300 0 12/05/02 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/15/88 GRV ORIGINAL COMPLETION WELL: W -37A 12/05/02 DAV /KK CTD SIDETRACK (W -37A) PERMIT No: 2021490 12/21/02 JB /TLH GLV C/O API No: 50- 029 - 21855 -01 03/16/04 JLJ /KAK GLV C/0 SEC 21, T11N, R12E, 1321' SNL & 1452' WEL 04/14/04 JLJ /KAK GLV C/O 09/11/06 DAV/TLH GLV C/O BP Exploration (Alaska) • - 37,a . Prt ?CZ 14q0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, June 07, 2012 7:19 PM ' /(81( To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: FW: OPERABLE: W -37A (PTD #2021490) Tubing integrity restored All, Please see the email below. My apologies from having missed you on the transmission of the email. Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 5trigkilia jUL 1 3 . al'4: Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, June 07, 2012 7:16 PM To: AK, D &C Well Integrity Coordinator; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Longden, Kaity; AK, OPS Well Pad SW Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: W -37A (PTD #2021490) Tubing integrity restored All, Producer W -37 (PTD #2021490) passed a TIFL on 06/06/12 confirming the tubing has integrity. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, June 05, 2012 2:55 PM To: AK, D &C Well Services Operations Te. ' Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt E - ; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Longden, Kaity; AK, OPS Well Pad Cc: AK, D &C Well Integrity Co. • inator; Walker, Greg (D &C); LeBaron, Michael J; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Sh,. e M 1 Regg, James B (DOA) 2u Z ' (4 From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator a©bp.com] Sent: Saturday, June 02, 2012 3:15 PM �4,'1 6(41,2_ To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Tin Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Longden, Kaity; AK, OPS Well Pad SW Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J; LeBaron, Michael J Subject: NOT OPERABLE: W -37A (PTD #2021490) Producer with Sustained Casing Pressure on IA During GC2 TAR Shut Down) All, The following producer was found to have sustained casing pressure on the IA during the shutdown for turnaround activity. The wellhead pressures were tubing /IA/OA equal to 2380/2320/0 on 06/02/2012. The immediate action is to perform a TIFL on the well to evaluate for IA repressurization. If the well fails the TIFL, a follow up email will be sent to the AOGCC the well with a plan forward. W -37A (PTD # 2021490) The well is reclassified as Not Operable until start -up operations commence and are stable. After start -up, the well will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 JUL 9sber) 201Z Cell (907) 752 -0755 Email: AKDCWeIllntegritvCoordinator (a�BP.com 1 12/17/10 Schkunberger NO. 5667 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 405 Alaska Oil 8 Gas Cons Comm Anchorage, AK 55503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, Al 99501 Well Job it Log Description Date BL Color CD NK-65A BCRD-00064 RST C - 10/21/10 a ... 1 G-09B 11649989 MCNL REDO -.-1 09/11107 EMIriy. 1 06-24A BCRD-00068 RST ` Jo ) - ()Q 11/12110 1 0, .?)W 1 01-06A BCRD-00063 RST —it 0 . 10/29/10 1 i 660 1 G-2913 AWJI-00113 Emmy _ .vmi 10/06/10 1 01 ,... r t , 1 W-37A BD88-00048 ...rie 09/12110 1 ff,,, re - I 1 05-07 BBKA-00077 LDL I — 4* / 11/24/10 64,9 1 12-29 B5JN-00067 USIT , IP 10/13/10 „...,, 1 1 K-126 BL65-00002 104 ',11;i:f.e1.5:i:telMIliffereirenSrEeirr., 11/21/10 .1 • ... — 1 17-16 BBSK-00036 PROD PROFILE I ''' A •— Ai: i 11/12/10 r .,.., 1 K-126 BCUE-00094 MEM PROD PROFILE i .--14, 11/22/10 10 (... V i • K-128 BCUE-00094 MEM PROD PROFILE 'i --/ el er 11/23/10 : 06 (i/ 1 12-04A B5JN-00069 USIT — .. A 11/02/10 _ , 1 1 09-25 AV1H-00048 erfflreL 1 06-02 BBKA-00075 SCMT Al - — • . 11/19/10 if - 1 1 18-13B BCZ2-00028 SCMT a O'i ... 11/07/10 ; 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 98503-2838 , A - ' MI 4 54Witik '- VW , 1110 ., ..„, . 0 .....• ix \ 11/01/10 swa berger NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2625 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job M Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/IBPSET RECORD 09115110 1 1 MPS -43 AYKP -00104 SCMT 08/26110 1 1 P7 -09 BCRJ -00036 PRODUCTION PROFILE -- 09/12110 1 1 W -37A BD88 -00048 MEM PRODUCTION PROFILE 1 C40 09111110 1 W -31A AZ2F -00064 MEM PRODUCTION PROFILE J 09116/10 1 06 -19A AWJI.00112 MEM PRODUCTION PROFILE 09119110 1 1 12 -05ALt BAUJ -00050 MEM PRODUCTION PROFILE 09120/10 1 1 PI-16 BCRJ -00049 INJECTION PROFILE 10106110 1 1 04 -03 BCRD -00059 PRODUCTION PROFILE 09/27/10 1 1 • P -03A AZ2F -00065 MEM INJECTION PROFILE / 10/06110 1 1 G -19B AWJI -00114 MEM PRODUCTION PROFILE 10104110 1 1 Y -36 BD88 -00058 MEM GLS 10/09/10 1 1 3.031) -33 BCZ2 -00025 PRODUCTION PROFILE 09111/10 1 1 L -214A BAUJ -00043 MEM INJECTION PROFILE 09/13/10 1 1 H -01A AWJI -00118 MEM PRODUCTION PROFILE 10/14110 1 1 16 -068 BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06/08/10 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE 10116/10 1 1 P2 -44 BCRD -00063 PRODUCTION PROFILE 10115110 1 G 1 6-13B AYKP -00091 CH EDIT PD 07/021`10 (0 1 02 -22B IOAKA0069 OH MWD /LWD EDIT 07107110 2 Q 1 W -1913 BCRJ -00034 CH EDIT PDC -GR (SCMT) 09107110 1 1 OWDW -SE APBPD3WELL RST REDO - PRINTS 09123110 1 OWDW -NW BBSK -00033 RST — 09124/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 I 201b D' 9701 . RECEIVED STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS l. 1. Operations Performed: AbandonD Alter Casing 0 Change Approved ProgramD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 91.00 8. Property Designation: ADL-028263 11. Present Well Condition Summary: Repair Well 0 Pluç¡ PerforationsD Pull TubingO Perforate New PoolO Operation ShutdownO Perforate 0 4. Current Well Class: Development ŒJ Stimulate Œ1 WaiverD ExploratoryD ServiceD StratigraphicO 9. Well Name and Number: W-37 A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth measured 10352 feet true vertical 9084.0 feet Effective Depth measured 10304 feet true vertical 9060.0 feet Casing CONDUCTOR SURFACE PRODUCTION LINER LINER LINER LINER Perforation depth: Length 110 2634 9588 281 21 464 610 Plugs (measured) Junk (measured) Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# L-80 7" 26# L-80 3-1/2" 8.81# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 TVD MD 47 46 45 9403 9257 9278 9742 157 - 2680 - 9633 - 9684 - 9278 - 9742 - 10352 47.0 46.0 45.0 8493.0 8369.0 8387.0 8777.0 157.0 - 2680.0 - 8688.0 - 8732.0 - 8387.0 - 8777.0 - 9084.0 Measured depth: 10070-10120,10130-10180,10210-10260,10280-10300 True vertical depth: 8951-8972,8976-8999,9013-9038,9048-9058 Tubinç¡ (size, ç¡rade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ 42 9476 9-5/8" Packer 4-1/2" Cameo SSSV Nipple @ 9372 @ 2147 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ Signature Form 10-404 Revised 4/2004 OCT 0 4 2006 . Commis:.:;:¡on Aröth~e Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 6. API Number 50-029-21855-01-00 None None Burst Collapse 470 2260 4760 5410 10530 7660 11160 1490 5020 6870 7240 10160 8520 10570 c: r;; <;005 _, ~ç' t.. RBDMS 8Ft D CT 0 4 20D6 Oil-Bbl SI 491 Representative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casin Pressure o 0 5,485 1679 Tubing Pressure o 284 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ GasD DevelopmentŒ) ServiceD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or NIA if C.O. Exempt: N/A Title Petroleum Engineer Phone 564-5174 L Date 1 0/2/06 . . 1 _ W-31 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/19/2006 {Scale Inhibitor Treatment} Pumped scale inhibition treatment for post acid lOR preservation. 09/19/2006 T/I/O=340/1200/500 {Scale Inhibitor Treatment} Pump 30 bbls crude followed by 200 bbls inhibitor I KCL . Shut Down while Schlumberger Pumps KCL . Pump 201 bbls EC6085A & 2% KCL down tbg. Pump 30 bbls crude for freeze protect after Schlumberger pump flush & over displacement. FWHP=500/800/120. 09/13/2006 TestEvent --- BOPD: 425 BWPD: 1,200 MCFPD: 6,746 AL Rate: 2,070 09/11/2006 PULL STA# 1 FROM 9150' SLM {1.5" DGLVI RA LATCH} PULL STA# 3 FROM 8008' SLM (1.5" DGLV I RA LATCH) PULL STA# 4 FROM 6296' SLM (1.5" OGLV I RM LATCH) PULL STA# 5 FROM 3127' SLM (1.5" DOME I RA LATCH) SET STA# 5 @ 3127' SLM (1.5" DOME, 16/64" PORT, 1521# TRO) SET STA#4 @ 6296' SLM (1.5" DOME, 16/64" PORT, 1520# TRO) SET STA# 3 @ 8008' SLM (1.5" DOME, 16/64" PORT, 1510# TRO) SET STA #1 @ 9150' SLM (1.5" S/O GLV 20/64" PORT) ALL RM LATCHES PULLED 41/2" WHIDDON CATCHER SUB @ 9206' SLM *** LEFT WELL SHUT IN *** 09/10/2006 ***WELL FLOWING ON ARRIVAL *** (gas lift for rate) RIG UP SLlCKLlNE, SET 41/2" WHIDDON CATCHER SUB @ 9206' SLM 08/30/2006 ASRC Well Test {Post Acid Stimulation Flowback} 2440.5 bfpd 861 bopd 63.19% W/C 1.266 mmscfld 2.0 mm G/L 1470 GOR 1150fwht 176 beans 08/21/2006 RIH w. 1.75" BDN, Kill well with 225 bbls 3% NH4CI followed with 82 bbls diesel to under balance well by 200 psi, Recip across perfs w. 50 bbls 3% NH4CI to cool BHT Pump 24 bbls 10% DAD w. 10 Xylene 24 bbls 8:2 Mud Acid 50 bbls flush w. 3% NH4CI WHP ranged from 880-1000 psi Parked CT above perfs and pumped 10 bbls 30ppt HEC gel in 3% NH4CI w. 0.5 ppg wax (200#) had problems with pump cavitations flushed out after w. 2 bbls 3% NH4CI and continued with 77 bbls 10% HCL (no Xylene), 75 bbls 8:2 Mud Acid followed by over flush of 195 bbls 3% NHCI. POOH. *** Job Complete*** 08/20/2006 Continue milling from 10,187' wi 2.2" three blade bullnose.junk mill. No further progress at 10,206'. POOH. MU new CTC and 2.1" three blade bullnose junk mill. Mill to 10,288' CTM and stall. Depth corrected with liner top tag = 10,304'. POOH. 08/19/2006 Mill to 10,112' with 2.23" flat four blade junk mill. No further progress. POOH. Wear on mill around outside edge. MU new MHA wi 2.20" three blade bull nose junk mill. RIH. Tag @ 10,116' continue to mill obstruction, fill, scale? 08/18/2006 Continue RIH. Tag top of fill @ 10,065' CTM. Attempted to jet away with flo pro sweeps with no sucess. Spot 10% HCL acid on obstruction and soak. Attempt to jet by @ 3.2 bpm after soak with no success. POOH. MU Weatherford motor and 2.30" mill. Tag at 10,072' CTM. Attempt to mill with very little progress. POOH. RIH w. same BHA and 2.29 3 bladed junk mill, tag obstruction @ 10072' start milling 08/17/2006 MIRU CTU #5. MU BHA wi 2" JSN. RIH. Bring well on line and RIH Page 1 . . 1_ W-31 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/08/2006 *** WELL S/I ON ARRIVAL *** (pre acid stem) RUN 2.25" CENT, SAMPLE BAILER SD @ 9836' SLM RUN 2.25" CENT, SAMPLE BAILER { 1.5" ROLLER STEM TOOL STRING} SD @ 10047' SLM, 23' FROM TOP OF PERFORATIONS ***WELL SII ON DEPARTURE*** ( NOTIFIED PAD OPERATOR) 03/03/2006 TIO = 20501150/10. Temp = SI. TBG FL {Post SI}. TBG FL @ 6967' {106 bbls} (below sta-4, OGL V). 02/25/2006 T/I/O= 290/170/20. Temp= Warm. TIFL PASSED (pre-acid stem). AIL line SI @ IA casing valve. IA FL @ 6323' (338 bbls) @ sta# 4 s/o. SI wing and stacked out tubing from 290 psi to 1200 psi in 1 hour. Tubing FL @ 1824' (28 bbls) above sta# 5. Monitored for 1 hour. Tubing pressure continued to stack out to 1750 psi. No change in tubing FL. No change in IA FL or lAP. Final WHP's= 1750/170/20. FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 9 50/50 Methanol Water 74 60/40 Methanol Water 82 Diesel 62 Crude 2272 1 % Extra Slick KCL Water 32 Flo Pro 5 10% HCL Acid 580 3% NH4CL Acid 24 10% DAD (10% Xylene) 77 10% DAD ( no Xylene) 99 8:2 Mud Acid 401 EC6085A & 2% KCL Water 3718 TOTAL Page 2 TREE = 4-1/16" CrN I I WELLHEAD = CAMERON W-37A SAFET OTES: ACTUATOR = AXELSON KB. ELEV = 90.99' BF. ELEV = 54.14' KOP= 3200' I 2147' 14-1/2" CAMCO SSSV NIP, ID = 3.813" I Max Angle = 67 @ 10048' . Datum MD = 9942' Datum ND = 8800' SS I 13-3/8" CSG, 68#, L-80, 10= 12.415" I î ~ ~ GAS LIFT MANDRELS 2680' ST MD TVD DEV TYÆ VLV LATCH PORT DATE l 5 3152 3059 10 MERLA DOME RA 16 09/11/06 4 6323 5776 32 MERLA DOME RM 16 09/11/06 3 8030 7222 31 MERLA DOME RA 16 09/11/06 Minimum ID = 2.31" @ 9142' 2 8914 7982 30 MERLA DMY RM 0 04/14/04 3-3/16" X 2-7/8" XO 1 9177 8210 31 MERLA SO RA 20 09/11/06 II I I 9257' 1'" 3.70" BKR DEA..OYMENT SLY, 10" 3.00" , 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.99" I 9276' I 9276' 1"'3-1/2" HES XN NIP, ID = 2.750'" - 9278' H 3-1/2" X 3-3/16" XO, 10 = 2.80" I i i I TOP OF 7" LNR I 9403' ~~ f¡ r-I 14-1/2" TBG, 12.6#, L-80, .0152 bpt, ID = 3.958" H 9476' I ¡ MILLOUT WINDOW 9684' - 9690' I I 9-518" CSG, 47#, L-BO, ID = 8.681" I 9633' ~ ~ I WHIPSTOCK I 9684' I ~ H 3-3/16" X 2-7/8" XO, ID = 2.37" , I 9742' ~ I 10304' .., PBTD , \ I 7" LNR, 26#, L-80, .0383 bpf. ID = 6.276" I 10265' Î . I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" I 9742' I / ÆRFORA TION SUMMA RY REF LOG: BHCS ON 09/01/88 ANGLEAT TOP ÆRF: 65 @ 10070' I 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.37" 10352' Note: Refer to Produetion DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10070 - 10120 0 12/05/02 2" 4 10130 - 10180 0 12/05/02 2" 4 10210 - 10260 0 12/05/02 2" 4 10280 - 10300 0 12/05/02 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 09/15/88 GRV ORIGINAL COMPLETION WELL: W-37A 12/05/02 DAV/KK cTD SIDETRACK (W-37A) ÆRMIT No: 2021490 12/21/02 JB/TLH GL V ClO API No: 50-029-21855-01 03/16/04 JLJ/KAK GLV ClO SEC 21, T11N, R12E, 1321' SNL & 1452' WEL 04/14/04 JLJ/KAK GL V ClO 09/11/06 DA V /TLH GLV ClO BP Exploration (Alaska) . . ''!.', .", ~.:. .,¡" ;<....'···r'·'···'················· . , ".. - MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) J~ ~à-~S-- DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021490 Well Name/No. PRUDHOE BAY UNIT W-37A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21855-01-00 MD 10352./ TVD 9084"'" Completion Date 12/5/2002 ,/ Completion Status 1-01l Current Status 1-01L UIC N ---_.-------_.~-~ ._----~._-----~,-~~---- REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes ---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, CCl, CNl Well Log Information: (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments -----.---- /' C lYr375 Induction/Resistivity ED {Og I nd uction/Resistivity 4:6'g Induction/Resistivity Rpt Directional Survey (EL}. W Directional Survey yb C 11374 Neutron ~'og Neutron 9682 1 0351 Open 12/20/2002 25 Blu 9700 10352 Open 12/20/2002 9700 10352 Open 12/20/2002 9631 1 0352 Case 12/11/2002 9631 10352 Case 12/11/2002 9145 10283 Case 12/20/2002 9195 1 0285 Case 12/20/2002 25 Blu 25 Blu -~----------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ---- ADDITIONAL INFORMATION Y/~ Well Cored? Daily History Received? ~/N ~/N Chips Received? ---XJ-N- Formation Tops Analysis Received? ~ ---------- ------------- Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021490 Well Name/No. PRUDHOE BAY UNIT W-37A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21855-01-00 MD 10352 TVD 9084 Completion Date 12/5/2002 Completion Status 1-01L Current Status 1-01L UIC N ------~----~._--------- <- -~-----~-~--~-------~--- V-o Date: '7 Ji~J..1J~ J--' Compliance Reviewed By: ..~ .---- ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon D After Casina 0 Change Approved Program D SuspendD Operation Shutdown 0 PerforateD VarianceD Annuar DisposalD Repair Well 0 Plua PerforationsD Stimulate. Time ExtensionD Other 0 Pull TubingD Perforate New Pool 0 Re-enter Suspended WellD ACID TREATMENT 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 91.00 8. Property Designation: ADL 028263 11. Present Well Condition Summary: 4. Current Well Class: Development. ExploratoryD 5. Permit to Drill Number: 202-149 6. API Number 50-029-21855-01-00 Stratigraphic 0 ServiceD 9. Well Name and Number: W-37A 10. Field/Pool{s): Prudhoe Bay Field I Prudhoe Bay Oil Pool Total Depth measured 1 0352 feet true vertical 9084 feet Plugs (measured) Junk (measured) Effective Depth measured 1 0304 feet true vertical 9060 feet Casing Length Size MD TVD Conductor 110' 20" 157' 157' Surface 2633' 13-318" 26801 2680' Intermediate 9586' 9-5/8" 9633' 8688' Liner 2811 7" 9403'-96841 8493'-8732' SideTrack Liner 1095' 3-3/16Ix2-7/8" 9257'-1 0352' 83691-90841 E .JUL () 2 2003 Alss!!.a nil & Cnr!~ ['O~~:i4,~¡~~¡'f~n B1Jr~t ~ Gbiìàps~' ,,' ¡ "",.,HI,! 40K A~'![:horag20 80K 2670 80K 4760 80K 5410 80K ( --- ) Measured depth: Open Perfs 10070'-10120',10130'-10180', 10210'-10260', 10280'-10300'. Perforation depth: True vertical depth: Open Perfs 8951'-8972',8976'-8999',9013'-9038',9048'-9058'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 54 15. Well Class after proposed work: Exploratory 0 Development. 16. Well Status after proposed work: Oil. GasD WAGD GINJD Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 9476'. 9-5/8"x7" PKR @ 9372'. 4-1/2" Cameo SSSV Nipple @ 2147'. Packers & SSSV (type & measured depth) 13 Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 248 1670 5605 10100 Copies of Logs and Surveys run - Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWa¡ne R. Schnorr Signature A%~ ~~L-~7 ./ Title Tubing Pressure 304 490 ServiceD WINJD WDSPLD Sundry Number or N/A if C.O. Exempt: N/A T echical Assistant Phone 907/564-5174 Date July 01, 2003 ORIGINAL Form 1 0-404 Revised 2/2003 RBDMS B~l JUL 0 3 20lB 04/23/2003 04/24/2003 04/25/2003 06/16/2003 06/24/2003 06/25/2003 06/29/2003 ) } W-37A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ACID: AC-TIFL ACID: AC-MONITOR ACID: DRIFT/TAG ACID: AC-MONITOR ACID: ACID TREATMENT; FILL CLEAN OUT ACID: ACID TREATMENT TESTEVENT --- BOPD: 1670, BWPD: 54, MCFPD: 10,100, AL RATE: 0 EVENT SUMMARY 04/23/03 T/I/O=330/440/110 TIFL PASSED (PRE-ACID); SI TBG FOR ONE HOUR TO STACK OUT TO 2200 PSI. MONITORED FOR ONE HOUR WITH NO INCREASE IN lAP AND THE IA FL REMAINED UNCHANGED @ 63231 (ST #4). FINAL SI TBG PRESSURE WAS 2370 PSI. WELL IS BOL WITHOUT AIL. FINAL WHp1s = 2220/440/110. 04/24/03 TIO= 300/500/130. TEMP = 84. MONITOR WHpls. (POST MITOA/TIFL). 04/25/03 DRIFT W/ 2.24" CENT, AND SAMPLE BAILER. TOOLS SIT DOWN @ 100001 SLM ( 66 DEGREEES ), BUT ABLE TO RIH TO GET TO 102501 SLM. ( HAD SMALL SAMPLE OF FORMATION SAND IN BAILER). «< RETURNED TO OPERATOR TO POP »> 06/16/03 2 QUART SAMPLES WERE TAKEN FROM THE FLOW LINE AND DELIVERED TO SCHLUMBERGER1S LAB. 06/24/03 MIRU COIL #5 WITH APC SEP. RIH WITH 2" JSN, TAGGED FILL @ 10,2711 CTMD. CLEAN OUT TO PBTD @ 102851 CTMD TAKING RETURNS TO THE GC. CIRCULATE KILL AND FLUID PACK WELL WITH 3% NH4CL. BULLHEAD INJECTION TEST DOWN BACKSIDE: (1677 PSI @ 3.2 BPM). START PUMPING 7.5% HCL (TITRATION 7.8°ic> HCL, IRON < 50 PPM) AND 8-2 MUD ACID (TITRATION 7.8% HCU 1.9% HF IRON < 50 PPM) STAGES. INITIAL INJECTION RATE 1.6 BPM 650 PSI. PUMPED ONE WAS BEAD STAGE AND WH PRESSURE INCREASED TO 1600 PSI @ 1.4 BPM. COIL PULLING VERY HEAVY, HAVE WAX AROUND NOZZLE. TAGGED HIGH OF BOTTOM PERFS @ 10250'. LOOKS AS IF ALL DIVERSION WENT TO BOTTOM PERFS. CONTINUED PUMPING PER SCHEDULE (RECIP ACROSS PERFS FROM 102501 TO 100701) OMITTING LAST 2 WAS BEAD STAGES DUE TO PLUGGING PROBLEMS. SEEING GOOD DIVERSION. INJECTING @ 1.4 BPM 1655 PSI. «< JOB IN PROGRESS »> 06/25/03 RIH JETTING 8-2 MUD AS PER SCHEDULE. PRESSURE DROPPED - 400 PSI ON MUD ACID STAGE. COMPLETE LAST ACID STAGE (8-2 MUD ACID) @ 993 PSI AND 1.6 BPM. PUMP 100 BBL 3% NH4CL OVERFLUSH @ 1330 PSI @ 1.6 BPM. UNABLE TO GET ANY DEEPER THAN 102751 CTMD. Page 1 ) ) W-37A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/25/03 LOOKS TO BE A WAX PLUG. POOH. TURNED WELL OVER TO APC FOR (CONTINUED) FLOWBACK. «< JOB COMPETED »> 06/29/03 TESTEVENT --- BOPD: 1670, BWPD: 54, MCFPD: 10,100, AL RATE: 0 BBLS 1 40 175 228 667 228 8 1347 FLUIDS PUMPED DIESEL FOR PRESSURE TESTING LUBRICATOR (1 TEST) 50/50 METHANOL WATER 20/0 EXTRA SLICK KCL WATER 7.5% HCL ACID NH4CL 8% - 2% HCUHF MUD ACID BIO TOTAL Page 2 ') TREE = 4-1/16" CIW WELLHEAD = CAMERON 'Ä triJi\fÓR;mmmmÄXELSON KB. B-EV~~~ m....... mOO-~'9'9ï BF:äB;ï;;;;mmnn~ KOP = 3200' mom on ...omo...ommnm... Max Angle = 67 @ 10048' ..........,~- nmnmmmm... Datum MD = 9942' '..m mum.. nmm..u.....,"---'" Datum TVD = 8800' SS 13-318" CSG, 68#, L-80, D = 12.415" H 2680' Minimum ID = 2.37" @ 9742' 3-3/16" X 2-718" XO 13-112" LNR, 8.81#, L-80, .0087 bpf,lD =2.99" H 9276' I TOP OF 7" LNR H 9403' 4-1/2"TBG, 12.6#, L-80, 0.0152 bpf, D =3.958" H 9476' I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9633' I WHIPSTOO< H 9684' W-37A I SAFETY NOTES: ) f) 2147' H4-112" C'AMCOSSSV NIP, ID= 3.813" ~ ST M) TVD ~ 5 3152 3059 4 6323 5776 3 8030 7222 2 8914 7982 1 9177 8210 L . 925T 9276' 9278' GAS LIFT MANDRELS DBI TYPE VL V LATCH 10 MERLA DO~ RA 32 MERLA SO RA 31 MERLA DMY RA 30 MERLA DMY RA 31 MERLA DMY RA PORT DATE 16 12/21/02 20 12/21/02 H 3.70" BKR DEPLOYMENT SL V, ID = 3.00" I H 3-112" I-ESXN NIP, ID= 2.750" I H 3-112" X 3-3/16" XO, ID = 2.80" I I MLLOUT WNDOW 9684' - 9690' 7"LNR, 26#, L-80, 0.0383 bpf, ID =6.276" H 10265' I I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID =2.80" H ... PERFORATION SUM'v1A RY REF LOG: BHCS ON 09/01/88 A NGLEA T TOP PERF: 65 @ 10070' t\bte: Refer to A"oduction DB for hislorical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 2" 4 10070 - 10120 0 12/05/02 2" 4 10130 - 10180 0 12/05/02 2" 4 10210 - 10260 0 12/05/02 2" 4 10280 - 10300 0 12/05/02 DA TE REV BY COM~NTS 09115188 GRV ORlGIN.A.L COMA...EllON 12/05102 DAViKK cm SIDErRACK(W-37A) 12/21/02 JB/tlh GLV CiO 9742' H 3-3/16" X2-7/8"XO, ID= 2.37" I l 2-7/8" LNR, 6.16#, L-80, .0055 bpf,lD = 2.37" H 10352' I DATE REV BY COM~S PRUDI-OE BAY Lt-JIT WELL: W-37A PERMT t\b: 2021490 API t-b: 50-029-21855-01 SEC 21, T11 N, R12E, 1321' SNL & 1452' We.. BP Exploration (Alaska) 23. CASING SIZE 20" 13-3/8" 9-518" WT. PER FT. Conductor 68# 47# 26# 6.2# /6.16# 7" 3-3/16" x 2-7/8" ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11... .~~:~-..~.''A. :ì..;~...-.'.J....,....... I.'. , ,.' : ,-.; : " . ~.J!ß;)"I ~!~::~ 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1321' SNL, 1452' WEL, SEC. 21, T11N, R12E, UM At top of productive interval 1458' NSL, 3563' WEL, SEC. 21, T11 N, R12E, UM At total depth 1555' NSL, 3314' WEL, SEC. 21, T11 N, R12E, UM x = 609969, Y = 5956501 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 91' ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/1/2002 12/312002 12/5/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10352 9084 FT 10304 9060 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,RES,CCL,CNL x = 611789, Y = 5958932 x = 609721, Y = 5956401 Classification of Service Well 7. Permit Number 202-149 8. API Number 50- 029-21855-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number W-37 A 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 2147' (Nipple) MD 1900' (Approx.) 7¿,Jl-vJ¡~ '7b'ð<l/ rYJb 8fø Ýt / TV?> GRADE CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' Surface 2680' Surface 9633' 9403' 9684' 9257' 10352' CEMENTING RECORD 8 cu yds 17-1/2" 3840 cu ft Cold Set II & III 12-1/4" 1985 cu ft Class 'G' 8-112" 1985 cu ft Class 'G' 3-3/4" 112 cu ft Class 'G' L-80 L-80 1J4S L,.80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 SPF MD TVD 10070' - 10120' 8951' - 8972' 10130' - 10180' 8976' - 8999' 10210' - 10260' 9013' - 9038' 10280' - 10300' 9048' - 9058' 27. Date First Production December 21,2002 Date of Test Hours Tested 1/17/2003 4 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 9476' PACKER SET (MD) 9372' ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 30 Bbls MeOH PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 772 GAs-McF 6753 GAs-McF WATER-BBL 0 WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL CHOKE SIZE 176 OIL GRAVITY-API (CORR) 0 GAS-OIL RATIO 8747 28. CORE DATA -." Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. sUb~rë~hi~', ; \'''\. f.L."" ,'<~"'~~_. ;if, No core samples were taken. Form 10-407 Rev. 07-01-80 RBDMS BFl 'F ?q Submit In Duplicate ) ') 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth r Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Shublik IB' Top of Shublik ICI Top of Shublik 'D' Top of Eileen Top Sadlerochit 45N 45P 44N 44P 43N 43P 42N 42P 41N 41P 31N 31P 9729' 9765' 9793' 9795' 9846' 9904' 9912' 99801 99821 10010' 100381 10123' 10130' 10177' 10205' 10265' 10272' 8767' 8792' 8810' 8812' 8841' 88711 88751 8911' 8912' 8926' 8938' 8973' 8976' 8998' 9011' 9040' 9044' 31. List of Attachments: " . Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~.Q;vtÙ¿ ~ Title Technical Assistant Date Ol. '2l{. D3 W-37 A 202-149 Prepared By NameINumber: Sondra Stewman, 564-4750 Well Number Permit No. I Approval No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. lïEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-37 W-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From~Tò Hòurs TaSk Code NPT Phèsé 11/27/2002 14:30 - 18:30 4.00 RIGU P PRE 18:30 - 19:30 1.00 RIGU P PRE 19:30 - 20:30 1.00 RIGU P PRE 20:30 - 00:00 3.50 BOPSUR P PRE 00:00 - 02:30 2.50 BOPSUR P PRE 02:30 - 02:45 0.25 STWHIP P WEXIT 02:45 - 06:00 3.25 STWHIP N DPRB WEXIT 11/28/2002 06:00 - 07:00 1.00 STWHIP P WEXIT 07:00 - 09:00 2.00 STWHIP N DPRB WEXIT 09:00 - 10:30 1.50 STWHIP N DPRB WEXIT 10:30 - 11 :30 1.00 STWHIP N DPRB WEXIT 11 :30 - 12:00 0.50 STWHIP N DPRB WEXIT 12:00 - 12:30 0.50 STWHIP P WEXIT 12:30 - 13:30 1.00 STWHIP P WEXIT 13:30 - 14:30 14:30 - 14:45 1.00 STWHIP P 0.25 STWHIP P WEXIT WEXIT 14:45 - 21 :00 6.25 STWHIP N SFAL WEXIT 21 :00 - 00:00 3.00 STWHIP N DPRB WEXIT 11/29/2002 00:00 - 03:40 3.67 STWHIP P WEXIT Start: 11/19/2002 Rig Release: 12/5/2002 Rig Number: N2 Spud Date: 8/18/1988 End: Move rig W-15a to W-37. Accept rig 14:30,11-27-2002. NU BOPE. Rig up equipment. Safety, TL, and pre-spud meeting. Continue RU. Spot cuttings tank. Tree valves leaking. Gas bubbling up thru master and swab. Call grease crew. Perform weekly BOP test. Witness waived by AOGCC's Jeff Jones. Testing all componets 250 psi low /3500 psi high. Finish testing BOPE. Drawdown test accumulator. Test CT inner reel valve to 3500 psi. PJSM. Review plan forward. Install lubricator cap. Open well 340 psi tbg pressure (IA 420 psi). Open choke line and bleed down to gas buster. .140 psi whp after 5 min flow and IA down to 50 psi..shut-in 10 min whp > to 160 psi. Close well in at master/swab valve. (First fluid from well was crude/gas which overloaded the gas buster. Approximately <1gal crude escaped from the gas leg and sprayed onto the next wellhouse W-36. Rig crews able to clean-up area. Spill reported.) Ordered out Tiger Tank and containment dyke for well kill ops. Master and swab valve is not completely holding Crew change meeting. Safety/ TL meeting. Wait on tiger tank and berm crew. 08:00 -- WHP = 290 psi; lAP = 150 psi; OAP = 125 psi. Spot divert tank. RU and PT hardline. Spill and cleanup about 1 gallon of methanol (on Pad) from broken valve on plastic jug in the hardline crew's truck. Finish RU. Safety meeting. Check pressures -- WHP = 300 psi; lAP = 160 psi; OAP = 130. Bleed down tubing to tiger tank. WHP and lAP bled down to zero in 5 minutes. OAP = 106'. Fill hole -- 6 bbls. lAP climbed to 260 psi. MU milling BHA. RIH keeping well open to divert tank. At 300', WHP increased to 125 psi. Ice plug in divert line? Try to blow down divert line with air. Methanol trailer will be here in 15 minutes. Line frozen solid. Moving coil in/out of hole at 2500' to keep warm. Rig-up hot air blowers and thaw out blow down line. Test with air and then meth to 500 psi. Bring pump on at min rate and RIH maintaining constant 200-250 whp taking returns to Tiger Tank. CTP 550-600 psi lAP 600 psi. lAP flucuating with CTP and ECD. RIH to pinch point on whipstock 9645.5' corrected CTD to 9650' and flagged pipe. Increased pump rate to 2.8 bpm circulate bottoms ups maintaining 200 psi on wellhead. Decreased pump rate down to 2.0 bpm trying to maintain IA below 1100 psi. lAP increased to 1150 psi maximum and OA 1005 psi. During later part of deplacement we tryed to bleed down the IA to no avail. Will doing so the the OA suddenly drop to 680 psi. (broke down??) After pumping 200 bbls total shutdown pump observe whp drop to zero. Shut-in observed well and whp stayed at zero psi. Open well to start milling operations. RIH to flag start milling window. RIW 17k, PU 36k, free spin Printed: 12/6/2002 2:00:01 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-37 W-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date FrOm.~ TO Hours Task. Code NPT Phase 11/29/2002 00:00 - 03:40 3.67 STWHIP P WEXIT 03:40 - 04: 15 0.58 STWHIP P WEXIT 04:15 - 06:00 1.75 STWHIP P WEXIT 06:00 - 07:15 1.25 STWHIP P WEXIT 07: 15 - 08:45 1.50 STWHIP P WEXIT 08:45 - 09:30 0.75 STWHIP P WEXIT 09:30 - 10:00 0.50 STWHIP N DFAL WEXIT 10:00-11:00 1.00 STWHIP N DFAL WEXIT 11 :00 - 11 :30 0.50 STWHIP N DFAL WEXIT 11 :30 - 12:00 0.50 STWHIP N DFAL WEXIT 12:00 - 13:30 1.50 STWHIP N DFAL WEXIT 13:30 - 14:00 0.50 STWHIP N DFAL WEXIT 14:00 - 14:30 0.50 STWHIP N DFAL WEXIT 14:30 -16:15 1.75 STWHIP N DFAL WEXIT 16:15 - 17:15 1.00 STWHIP N DFAL WEXIT 17:15 - 18:15 . 1.00 STWHIP N DFAL WEXIT 18:15 -18:45 0.50 STWHIP N DFAL WEXIT 18:45 - 21:10 2.42 STWHIP N DFAL WEXIT 21:10 - 00:00 2.83 STWHIP N DFAL WEXIT 11/30/2002 00:00 - 01 :15 1.25 STWHIP N DFAL WEXIT 01:15 - 01:45 0.50 STWHIP N DFAL WEXIT 01 :45 - 02:00 0.25 STWHIP N DFAL WEXIT 02:00 - 02:50 0.83 STWHIP N DFAL WEXIT 02:50 - 03:15 0.42 STWHIP N DFAL WEXIT 03: 15 - 03:30 0.25 STWHIP N DFAL WEXIT 03:30 - 07:15 3.75 STWHIP N SFAL WEXIT 07:15 - 09:15 2.00 STWHIP N DFAL WEXIT Start: 11/19/2002 Rig Release: 12/5/2002 Rig Number: N2 Spud Date: 8/18/1988 End: DescriptiÒnofOperatióm; 1700 psi. Average 3-5k wob and 300 psi motor work. Cut window from 9649.6' to 9653.9'. Never seen a stall. Exited earlier than normal. May be due to 54 deg RH set of whipstock. Normal window would +/- 7.9' Drilled formation from 9653.9' to 9670' 2.6 bpm @ 1700 psi free spin, 1730 psi on btm. (actually very little if any motor work.) Good formation samples from 9658', sample up from 9670' mostly steel. Clean up window area several times. RIH wo pump couldn't find bottom at 9670'. Run in/out of window in 10' intervals. Found bottom at 9693'. Did not try to drill anything at 9693'. Pull back into casing. Flo-Pro on location at 0545 preping to swap fluids. RIH again dry. TO getting deeper -- tag 9734' (ratty 9730' - 9734'). Slight overpull. PUH. RIH clean to 9738'. 5k OP. PUH. RIH at 2.8 BPM. Stall at 9738'. 10k overpull. All counters and flags jive. Swap well to mud. POOH. Call for SWS memory GR/CCL. LD milling BHA. Safety and TL meeting. MU SWS memory GR/CCL tool and carrier. Fix tugger wrap. Finish MU BHA. RIH. Log down 60 FPM from 9200' at minimum rate. Tag TO 9744.5'. Clean PU. Log up at 60 FPM to 9200 RIH. Lay in 15 bbls high vis (150k ish LSRV) pill on bottom (viscous base to help keep cement above next whipstock from swapping out). POOH. SB inj. LD logging tools. Wait on processing logs. Crew change safety and tech limit meeting. RU SWS and Baker tools for setting new whipstock at 30-35 deg RT set at 9680'. RIH w/ whipstock 100'/min. Tie-in and correlate to PDC log. No correction. Make several short passes at set depth to adjust whipstock tray angle. Settle for 15 rt. Fire setting charge RIH and confirm whipstock set. PUH also confirm loss of whipstock weight. So top of whipstock is at 9680' with 15 deg rt tray angle. NO PIP TAGS. TOH wi logging tools UD logging tools and whipstock setting tool. PJSM on plu BHA. P/U BHA #3 Stab on injector RIH 486'. Injector clanging and banging leaking on the drive motor hardline. Time gear cover loose. Call out mechanics. Circulating at min rate. Wait on mechanics. (cancel OS cementers) Doyan 14 is on access road also. Fix injector -- blown seal on piping. Tighten cover. RIH. Tag pinch point of whipstock 9677'. Correct depth (+7') Printed: 12/6/2002 2:00:01 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-37 W-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/19/2002 Rig Release: 12/5/2002 Rig Number: N2 Spud Date: 8/18/1988 End: Date From ~. To Hours Task. Code. NPT D~scription bfOperatiþns 11/30/2002 07: 15- 09: 15 2.00 STWHIP N DFAL WEXIT 09:15 - 09:45 09:45 - 10:15 10:15 - 10:45 0.50 STWHIP N 0.50 STWHIP N 0.50 STWHIP N DFAL WEXIT DFAL WEXIT DFAL WEXIT 10:45 -11:10 0.42 STWHIP N DFAL WEXIT 11 : 10 - 11: 30 0.33 STWHIP N DFAL WEXIT 11 : 30 - 11:45 0.25 STWHIP N DFAL WEXIT 11 :45 - 12: 15 0.50 STWHIP N DFAL WEXIT 12:15 - 14:00 1.75 STWHIP N DFAL WEXIT 14:00 - 15:00 1.00 STWHIP N DFAL WEXIT 15:00 - 15:30 0.50 STWHIP N DFAL WEXIT 15:30 - 20:40 5.17 STWHIP N DFAL WEXIT 20:40 - 21 :05 0.42 STWHIP N DFAL WEXIT 21 :05 - 00:00 2.92 STWHIP N DFAL WEXIT 12/1/2002 00:00 - 00: 15 0.25 STWHIP N DFAL WEXIT 00:15 - 05:45 5.50 STWHIP N DFAL WEXIT 05:45 - 07:45 2.00 STWHIP N DFAL WEXIT 07:45 - 09:45 2.00 STWHIP N DFAL WEXIT 09:45 - 11 :30 1.75 STWHIP P WEXIT 11 :30 - 12:30 1.00 STWHIP P WEXIT to 9684'. Put 6k down, no movement. 2k OP. PUH. Est circulation at 2.5 BPM; 2000 psi. lAP = 1300 psi. OAP = 500 psi. Note: with pumps down, lAP = 800 psi (500 psi ECD). Also note that OA does not appear to be in communication with IA as suspected yesterday. OAP staying at 500 psi while lAP is fluctuating during pumps on/off. RU cementers. Safety meeting. Bleed IA at 0.1 BPM as noted by difference bet! MMin and MMout. No gas. Pressure not bleeding down. Will continue to bleed as we displace our cement to the nozzle, then shut it in while we lay the cement in at lower rate. Pump 5 bbls water. SO and PT to 4000 psi. Pump 10 bbls 15.8 ppg Class G (2.5 hours thickening 150 deg BHCT --> 230 deg BHST). Follow with 10 bbls water to clean lines. Chase cement with rig pumps 3.0 BPM; 2300 psi. Reduce rate to 1.0 BPM with cement at nozzle. Let 2 bbls cement exit nozzle, then lay in 1: 1 to 9385' at 1.0 BPM; 800 psi CTP; 1100 psi lAP; 500 psi OAP. Pull to safety 9100'. Circ at 3.0 BPM (ECD giving us a little squeeze) while letting cement settle out. RIH 3.0 BPM; 30 FPM (3:1) washing excess cement to 9630' (hoping to leave at least 10' of good cement above old window top 9650'). POOH, chasing contaminated cement (dump 80 bbls). Flag pipe at 8500' EOP LD nozzle BHA. PU stinger. Wash stack. lAP = 750 psi. MU milling BHA #4. RIH slow parked at 9150' circ min rate(wait on cement) Lab says cement may have a problem. Still no comopressive strengh after 9 hrs. RIH to look for cement top at 9630' 2'/min at 2.6 bpm 16.2k RIW stopped at 9674'. Circulated green cement to surface. WOC. Called OS at midnight as planned. UTA shows cement has NOT even begun to set. RIH wash down to top of whipstock. No cement drilled. Begin milling window f/ 9681.4' (note: on this run, had corrected + 7' to flag that was painted after last run where whipstock pinch point was tagged and corrected to 9684'). So this 9681' milling may be some cement. Free spin 2125 psi. Mill first foot with avg 500' psi MW 3000 Ib WOB. Then time mill next two ft with avg 150 psi MW 1500 Ib WOB. No change in milling conditions at pinch point 9684'. Remainder of window time milled with about 200 psi MW and 500 - 1000 Ib WOB. Exit casing at 9690' with milling break (got wt back quickly). Significant metal on magnets. Mill 1 0' of formation slow (Shublik) to 9700'. Window: 9684'- 9690' Dress window. Downream showed 150 psi MW 9680 - 9684', cleaned up with several reaming passes. Drift dry -- no bobbles. Swap to new mud. POOH. LD milling BHA. Printed: 12/6/2002 2:00:01 PM ') ') Legal Well Name: W-37 Common Well Name: W-37 Spud Date: 8/18/1988 Event Name: REENTER+COMPLETE Start: 11/19/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2002 Rig Name: NORDIC 2 Rig Number: N2 Date From.~ To Höuts Task Code NPT Phase Descri ptionofOPërations 12/1/2002 12:30 - 13:00 0.50 DRILL P PROD1 Crew change safety meeting. 13:00 - 14:45 1.75 DRILL P PROD1 MU drilling BHA #5. Re-head CTC. Pull and PT. 14:45 - 16:15 1.50 DRILL P PROD1 RIH. Tag 9407' uncorrected CTM -- top of backed-off tailpipe that fell. Try again. Tag again. 16:15 - 16:45 0.50 DRILL P PROD1 Check TF/shallow hole test. Bring up pumps. TF 90L (programmed for 180). Orient high side. Went to 90R. Try RIH dry. Tag 9407. Trick TORC to go highside by sending it a 270 command. Worked. RIH clean. 16:45 - 17:00 0.25 DRILL P PROD1 RIH. Tag but fell thru 9442' (XN). Correct depth at flag (+8'). RIH highside thru window. Bobble at 9694'. Tag TO 9703 (pumps on would make it 9702). Pull uphole thru whip. 17:00 - 17:30 0.50 DRILL P PROD1 Log tie-in up from 9680'. No correction. 17:30 - 17:45 0.25 DRILL P PROD1 RIH to TO and orient TF to 60R. 17:45 - 18:00 0.25 DRILL P PROD1 Drill. 18:00 - 19:00 1.00 DRILL N SFAL PROD1 Lost power on #2 gen. Blown head gasket. #3 gen has problem with distributiion panel. Wait on electrician. 19:00 - 19:15 0.25 DRILL P PROD1 RIH tagged at window w/90R TF. Orient 41R 19:15 - 00:00 4.75 DRILL P PROD1 Directional drill f/ 9710' to 9785'. 2.9 bpm in/out free-spin 2730 psi on btm 2850'. 12/2/2002 00:00 - 02:15 2.25 DRILL P PROD1 Directionally drill f/ 9795' to 9850'. 2.8 bpm in/out 2750 spi free-spin 2950 on btm. 02: 15 - 02:30 0.25 DRILL P PROD1 Wiper trip to window. 02:30 - 04:50 2.33 DRILL P PROD1 Directionally drill f/ 9850' to 10001' (zone 4) 04:50 - 05:10 0.33 DRILL P PROD1 Wiper trip to window. 05: 10 - 06:00 0.83 DRILL P PROD1 Directionally drill f/1 0001' (zone 4) to 10040' -- end of planned build. Pump up survey. 06:00 - 08:00 2.00 DRILL P PROD1 POOH. Flag pipe 9500' EOP. 08:00 - 10:00 2.00 DRILL P PROD1 LD drilling BHA #5. M09 bit missing a blade containing three cutters. PU BHA #6 (resistivity, 1.04 deg motor, same TORC orienter, used STX404 bit) 10:00 - 12:15 2.25 DRILL P PROD1 RIH. Shallow test good. Send TF highside. RIH. Tag 9407' and 9424', but fell thru both spots. Correct depth at flag (+4'). RIH clean thru window. 12:15 - 12:40 0.42 DRILL P PROD1 Tie-in logging up starting 9730'. No correction. 12:40 - 12:50 0.17 DRILL P PROD1 RIH tag TO 10040'. 12:50 - 16:30 3.67 DRILL P PROD1 Drill, orienting most of the time on bottom while drilling. Stacking in shale streaks, otherwise pretty good slide. Drill to 10,240'. 16:30 - 17:00 0.50 DRILL P PROD1 Wiper to window. 17:00 - 18:15 1.25 DRILL N DFAL PROD1 Continuous azimuths have been bad since change in BHA (the azimuths were good in the build) -- speculate with ARC tool in ground, too much time between continuous incs and continuous azimuths, and this is source of problem. Get four off bottom surveys. 18:15 - 22:30 4.25 DRILL P PROD1 Drill f/ 10240' to 10349'. 2.8bpm in /2.8 out Drilling zone 3 since 10265'. Numerous stalls last 5'. Tryed small short trips nothing helps. Called this TO 22:30 - 23:00 0.50 DRILL P PROD1 TOH 60'/min @ 2.9 bpm. to 10060' 23:00 - 00:00 1.00 DRILL P PROD1 Log tie-in. Failed 1st pass. 12/3/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Continue tie-in. +3' correction. 01 :00 - 01 :25 0.42 DRILL P PROD1 RIH to TO. Seeing ledges or shale at 10162',10188'-10200', 10320' - TO at 10352'. 01 :25 - 02:05 0.67 DRILL P PROD1 Wiper trip to 10100'. Work several times down to TO and clean Printed: 12/6/2002 2:00:01 PM ) ') Legal Well Name: W-37 Common Well Name: W-37 Spud Date: 8/18/1988 Event Name: REENTER+COMPLETE Start: 11/19/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 12/5/2002 Rig Name: NORDIC 2 Rig Number: N2 Date Fróm""Tb Hours Task Code NPT Description of Oþeratibns 12/3/2002 01 :25 - 02:05 0.67 DRILL P PROD1 up area. Pull up to 10060'. 02:05 - 03:15 1.17 DRILL P PROD1 MAD pass area missed from previous BHA run 10060'-9740' 03: 15 - 06:00 2.75 DRILL P PROD1 TOH for liner 2.9 bpm 70'/min to surface. Run back in hole to 1000'. POH (no pump) filling backside with water for liner running ease. 06:00 - 07:00 1.00 DRILL P PROD1 LD BHA. Bit 3-3. Could see conglomeritic type wear, but rerunable -- lots of cutting structure left. 07:00 - 07:45 0.75 CASE P COMP Safety and TL meeting. 07:45 - 08:45 1.00 CASE P COMP RU to run liner. 08:45 - 11 :45 3.00 CASE P COMP MU combo 2-7/8" FL4S and 3-3/16" TCII string. 11 :45 - 12:45 1.00 CASE P COMP MU Baker liner running tool. (Crew change) 12:45 - 13:00 0.25 CASE P COMP Hold PJSM before MU of coil connector & pumping dart through coil. 13:00 - 14:00 1.00 CASE P COMP Install Baker connector. Test same. MU dart catcher. Load dart in reel. 14:00 - 14:45 0.75 CASE P COMP Pump dart through coil. Volume was 52.4 bbls. 14:45 - 15:30 0.75 CASE P COMP LD safety joint. Stab onto liner with coil. Get on well. 15:30 - 18:00 2.50 CASE P COMP RIH with liner. Correct minus 4' at EOP flag at 9000'. 38K# up, Liner on bottom. pick-up wt 47k. 18:00 - 18:45 0.75 CASE P COMP Load and pump .625" steel ball. (Hold PJSM and TL meetings) Ball on seat after pumping 43.6 bbls. Shear released with 3700 psi (2971 calculated). Pick-up wt 32k. Confirm liner release. Set down 14k. 18:45 - 20:15 1.50 CASE P COMP Displace Flo-Pro mud from OH and csg annulus with 120* 2% KCL.(begin with IA 1150 psi while pumping at 2 bpm) Mud taken back to MI for next well. (Hold PJSM with OS and crews about actual cement job steps. Batch mix 25 bbls cement, 20 pumpable up to wt at 19:50). 20:15 - 21 :50 1.58 CEMT P COMP Bring OS on-line. Pump 5 bbls H2O ahead shutdown PT lines to 4k. (static IA 620 OA 500.) At 2 bpm follow with 20 bbls 15.8 ppg cement ( IA 735 psi OA 520). Load CT wiper dart. Pressure up 500 psi and launch dart - confirm. Continue with displacement with 30 bbl 2# bio switch to KCL pumping @ 2.0 bpm. (Open IA a 45 bbls away 800 psi initial varied 650-800 during remainder of displacement.) CT dart bumped at 53.2 bbl, LWD at 60.2 bbl. Floats held. CIP @ 21:45 hrs. Pressure up to 1000 psi and sting out of liner. 21 :50 - 00:00 2.17 CEMT P COMP Wash up on top of liner and chase any cement out of hole @ 2.25 bpm. Circulated about 30 bbls 9.8ppg fluid to surface. 12/4/2002 00:00 - 00: 15 0.25 CEMT P COMP UD liner running tools. 00:15-01:15 1.00 CEMT P COMP P/U swizzle stick and wash out BOP stack. 01:15 - 01:30 0.25 EVAL P COMP PJSM on picking up CNL tools. 01 :30 - 04:00 2.50 EVAL P COMP P/U BHA #7 04:00 - 06:00 2.00 EVAL P COMP RIH to 9100'. Correct at flag, no correction continue RIH 06:00 - 07:30 1.50 EVAL P COMP Log down at 60 fpm, circ at 0.5 bpm. Tag bottom at 10304' corrected. Apparently 10' of cement on landing collar. 07:30 - 08:00 0.50 EVAL P COMP Attempt to mill ahead to verify if cement or landing collar/wiper plug. Unable to mill ahead. 08:00 - 10:00 2.00 EVAL P COMP Log out of hole at 60 fpm. POOH. 10:00 - 12:00 2.00 EVAL P COMP Get off well. Stand back CSH. Handle source & LD cased hole logging tools. 12:00 - 16:00 4.00 EVAL P COMP Wait on cement compressive strength. {High silica flour content due to high BHT slows compressive strength Printed: 12/6/2002 2:00:01 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-37 W-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/19/2002 Rig Release: 12/5/2002 Rig Number: N2 Spud Date: 8/18/1988 End: Date Frorn~To Hours Task Code NPT 12/4/2002 12:00 - 16:00 16:00 - 18:30 4.00 EVAL P 2.50 EVAL P COMP COMP 18:30 - 19:00 0.50 EVAL P COMP 19:00 - 19:40 0.67 EVAL P COMP 19:40 - 20:15 0.58 EVAL P COMP 20:15 - 20:35 0.33 EVAL P COMP 20:35 - 23: 15 2.67 EVAL P COMP 23:15 - 00:00 0.75 EVAL P COMP 12/5/2002 00:00 - 01:15 1.25 PERF P COMP 01:15-01:40 0.42 PERF P COMP 01 :40 - 04:00 2.33 PERF P COMP 04:00 - 06:30 2.50 PERF P COMP 06:30 - 07:30 1.00 PERF P COMP 07:30 - 08:00 0.50 PERF P COMP 08:00 - 08:20 0.33 PERF P COMP 08:20 - 08:50 0.50 PERF P COMP 08:50 - 11 :30 2.67 DEMOB P COMP 11 :30 - 12:00 0.50 DEMOB P COMP 12:00 - 15:00 3.00 DEMOB P COMP 15:00 - 21 :00 6.00 RIGD P COMP development) Pressure test tbg to 2500 psi for 30 min. Held solid. Bleed tbg to 500 psi. Pressure IA to 2950 psi. Held solid for 30 min. Bleed off tbg & IA. OA remained stable at 290-300 psi during tests. Tech Limit meeting. Wait on Schlumberger perf guns. Bring perf guns into pipe shed PJSM on handling perf guns. P/U 250' of 2" HSD PJ 2006 4spf perf guns 1 BHA #8. PT Baker CTC to 3500 psi. Stab-on to well. RIH, no correction at flag, Continue RIH to bottom. Load and launch .625" steel ball. Follow with 10 bbl hi-vis KCL pill. ball landed on seat at 48 bbls away. Pressure up to 3050 psi and guns appeared to have fired. Lost +/- 1 bbl fluid. Perf depths: 10070'-10120, 10130'-10180', 10210'-10260', 10280'-10300'. all4spf TOH (have PJSM about handling fired guns) Stand back 1 1/4" CSH. Ud perf guns. All guns fired MU nozzle assy on coil. Stab on well. RIH to 2000'. Pump 30 bbls 60/40. Lay into 4-1/2" tbg. POOH. Shut dn pumping near surface to leave BOPS dry. Close master & swab. Displace coil with nitrogen. Blow down exterior lines. Bleed down reel and PJSM for unstabbing coil from injector. Unstab coil from injector and secure reel. NO BOPE and clean mud tanks. Same time drop out used 2 3/8" coil reel. Due to numerous simultaneous operations the offical Rig Release time will be 1700 hrs 12-5-2002 Jack-up @ 2100 hrs moving to W-32 W-37A Special Note in regards to the packer leak encountered on this well: Prepa 'ed By: Amy Frankenburg, Pad Engineer (564-4503) . 11/07/02: Caliper ShO'NS tubing in great cond 249 jts 1-10%, 2 jts 10-200/0 . 11/15/02: MIT-TxIA Passed to 3000 psi . 12/05/02: CTD complete, fixed TxlA comm. By cmt'ing liner top past packer . 12/22/02: POP post CTD sidetrack Printed: 12/612002 2:00:01 PM Well: Field: API: Perm it: Date ) ) W -37 A Prudhoe Bay Field / Prudhoe Bay Pool 50-029-21855-01 202-109 Accept: Spud: Release: Rig: POST-RIG WORK 12/07/02 ESTABLISHED OA INJECTION RATE OF 5 BPM @ 1310 PSI FOR 50 BBLS. 11/27/02 11/28/02 12/05/02 Nordic 2 12/19/02 T/I/0=0/180/150 (PREP FOR OA DOWN Sa) OA FL @ SURFACE. 12/20/02 SET 4-1/2" SLIP STOP CATCHER SUB @ 64241 SLM. PULLED 1-1/2" DV @ STA 4 (63021 SLM). 12/21/02 PULLED 1-1/2" DGLV @ STA 5,3128' SLM. SET GENERICS, 1500 # 1/4 PORT IN STA # 5, AND DUAL CHECK 5/16 ORIFICE IN ST A #4, PULLED SS CS, NO PROBLEMS. SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay We 11 . . . . . . . . . . . . . . . . . . . . .: W - 3 7 A API number. .... ..........: 50-029-21855-01 Engineer........ .........: M. Brown RIG: . . . . . . . . . . . . . . . . . . . . .: Nordic 2 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: GR Tie-In @ 9673 ft GL above permanent.......: -50000.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 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: 89.20 degrees 3-Dec-2002 14:17:49 Spud date.. . . . . . . . . . . . . . . : Last survey date. ........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 2 01-Dec-02 03-Dec-02 20 9631.60 ft 10352.00 ft ,,-,,' ----- Geomagnetic data ---------------------- Magnetic model...........: .BGGM version 2002 Magnetic date..... .......: 01-Dec-2002 Magnetic field strength..: 1151.32 HCNT Magnetic dec (+E/W-).....: 26.33 degrees Magnetic dip.............: 80.89 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G. . . . . . . . . . . . . . : H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip......... : Criteria --------- 1002.68 mGal 1151.32 HCNT 80.89 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.33 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.33 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 ~ SCHLUMBERGER Survey Report 3-Dec-2002 14:17:49 Page 2 of 2 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9631.60 31.92 242.04 0.00 8596.27 -2005.87 -2669.08 -1968.80 3316.65 216.41 0.00 TIP None 2 9678.50 31.32 242.91 46.90 8636.21 -2027.84 -2680.44 -1990.60 3338.76 216.60 1.61 MWD M None - 3 9708.50 37.09 262.00 30.00 8661.08 -2043.86 -2685.27 -2006.56 3352.16 216.77 40.41 MWD M None 4 9739.50 46.10 275.35 31.00 8684.28 -2064.32 -2685.53 -2027.02 3364.66 217.05 40.64 MWD M None 5 9769.79 49.75 281.66 30.29 8704.59 -2086.48 -2682.18 -2049.23 3375.41 217.38 19.57 SP None 6 9800.00 51.43 297.73 30.21 8723.84 -2108.20 -2674.32 -2071.06 3382.50 217.76 41.44 MWD M None 7 9834.50 57.01 313.56 34.50 8744.09 -2130.50 -2658.00 -2093.60 3383.50 218.23 40.51 MWD M None ~ 8 9864.50 60.02 324.77 30.00 8759.79 -2146.89 -2638.66 -2110.25 33 7 8 . 71 218.65 33.39 MWD M None - 9 9902.50 59.67 338.46 38.00 8778.95 -2162.05 -2609.86 -2125.82 3366.08 219.16 31.15 MWD M None - 10 9935.00 56.56 353.00 32.50 8796.18 -2168.51 -2583.25 -2132.65 3349.83 219.54 39.14 MWD M None 11 9974.50 58.27 13.11 39.50 8817.61 -2166.24 -2550.29 -2130.84 3323.32 219.88 43.05 MWD M None 12 10004.61 62.70 26.08 30.11 8832.49 -2157.08 -2525.71 -2122.02 3298.81 220.04 40.23 SP None 13 10047.91 66.65 41.65 43.30 8851.10 -2134.84 -2493.40 -2100.23 3260.07 220.11 33.73 SP None 14 10092.36 65.73 54.05 44.45 8869.11 -2104.40 -2466.17 -2070.17 3219.88 220.01 25.60 SP None 15 10132.48 63.10 58.28 40.12 8886.44 -2074.09 -2446.02 -2040.13 3185.15 219.83 11.53 SP None 16 10186.77 62.25 69.83 54.29 8911.43 -2030.54 -2424.95 -1996.88 3141.32 219.47 18.96 SP None 17 10222.50 61.16 74.53 35.73 8928.37 -2000.47 -2415.32 -1966.94 3114.91 219.16 11.98 MWD M None - 18 10262.50 59.55 81.79 40.00 8948.18 -1966.39 -2408.18 -1932.95 3087.98 218.75 16.28 MWD M None - 19 10295.50 60.14 87.88 33.00 8964.77 -1937.96 -2405.62 -1904.56 3068.28 218.37 16.05 MWD M None 20 10352.00 60.14 87.88 56.50 8992.90 -1888.97 -2403.81 -1855.59 3036.69 217.67 0.00 Projected TD ~/ ò W-37 A Schlumberuer Survey Report - Geodetic Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid NlE YIX: Grid Convergence Angle: Grid Scale Factor: 3.Dec.02 BP Exploration Alaska Prudhoe Bay Unit. WOA (Drill Pads) W.PAD / W.37 W.37 W-37 A 500292185501 W-37 A / December 3, 2002 244.139° /3951.06 ft / 6.045 / 0.439 NAD27 Alaska State Planes, Zone 4, US Feel N 701748.327, W 149541.102 N 5958932.080 ftUS, E 611788.960 ftUS +0.85225651 ° 0.99991420 Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Minimum Curvature / Lubinski 89.200° N 0.000 ft, E 0.000 fl MSL 0.000 ft relative to MSL Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: +25.800° 57514.869 nT 80.772° December 09, 2002 BGGM 2002 True North +25.800° Well Head ~ Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (C) (C) (ft) (ft) (ft) (ft) (O/1 OOft) (ftUS) {ftUS~ 9631.60 31.92 242.04 8596.27 -2005.90 -2669.03 -1968.83 5956234.30 609860.22 N 70 17 22.075 W 149 6 38.470 9678.50 31.32 242.91 8636.21 -2027.87 -2680.39 -1990.64 1.61 5956222.61 609838.58 N 70 17 21 .963 W 149 6 39.105 9708.50 37.09 262.00 8661.08 -2043.89 -2685.22 -2006.59 40.41 5956217.55 609822.70 N 701721.915 W 149639.570 9739.50 46.10 275.35 8684.29 -2064.35 -2685.48 -2027.05 40.64 5956216.98 609802.25 N 70 1721.913 W 149640.166 9769.79 49.75 281.66 8704.59 -2086.51 -2682.13 -2049.26 19.59 5956220.01 609780.00 N 70 1721.946 W 149 640.813 9800.00 51 .43 297.73 8723.85 -2108.23 -2674.27 -2071.09 41.42 5956227.54 609758.05 N 701722.023 W 149641.449 9834.50 57.01 313.56 8744.10 -2130.53 -2657.94 -2093.63 40.51 5956243.53 609735.28 N 70 17 22.183 W 149642.106 9864.50 60.02 324.77 8759.80 -2146.92 -2638.61 -2110.28 33.39 5956262.61 609718.34 N 70 1722.374 W 149 6 42.591 9902.50 59.67 338.46 8778.96 -2162.08 -2609.81 -2125.85 31.15 5956291.17 609702.35 N 70 17 22.657 W 149 6 43.045~' 9935.00 56.56 353.00 8796.19 -2168.54 -2583.20 -2132.68 39.14 5956317.68 609695.12 N 701722.918 W 149 643.245 9974.50 58.27 13.11 8817.62 -2166.26 -2550.24 -2130.87 43.05 5956350.66 609696.45 N 70 17 23.243 W 149 643.192 10004.61 62.70 26.08 8832.49 -2157.10 -2525.66 -2122.05 40.23 5956375.36 609704.90 N 70 17 23.484 W 149 6 42.935 10047.91 66.65 41.65 8851.11 -2134.87 -2493.35 -2100.26 33.73 5956407.99 609726.20 N 70 17 23.802 W 149 6 42.301 10092.36 65.73 54.05 8869.11 -2104.43 -2466.12 -2070.20 25.60 5956435.66 609755.85 N 70 1724.070 W 149 6 41 .425 10132.48 63.10 58.28 8886.44 -2074.11 -2445.97 -2040.16 11.55 5956456.26 609785.58 N 70 17 24.268 W 149 6 40.550 10186.77 62.25 69.83 8911.43 -2030.57 -2424.90 -1996.91 18.96 5956477.96 609828.52 N 70 1724.476 W 149 6 39.290 10222.50 61.16 74.53 8928.37 -2000.50 -2415.27 -1966.97 11.98 5956488.04 609858.30 N 70 17 24.570 W 149 638.417 10262.50 59.55 81.79 8948.17 -1966.42 -2408.1' 3 -1932.98 16.28 5956495.68 609892.18 N 701724.641 W 149637.427 W-37 A ASP Final Surveys. xis Page 1 of 2 12/9/2002-12:15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E}-W DlS Northing Easting latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 10295.50 60.14 87.88 8964.76 -1937.98 -2405.56 -1904.58 16.05 5956498.67 609920.53 N 70 17 24.666 W 149 6 36.600 10352.00 60.14 87.88 8992.89 -1889.00 -2403.75 -1855.62 0.00 5956501.21 609969.46 N 70 17 24.684 W 149635.173 ~ .",-". W-37 A ASP Final Surveys.xls Page 2 of 2 12/9/2002-12:15 PM ~ ~. """ ~ 1) W-37 A Survey Report - Geodetic Schlumberger Report Date: 3-Dec-02 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 89.200° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: W-PAD 1 W-37 TVD Reference Datum: MSL Well: W-37 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: W-37 A UWI/API#: 500292185501 Magnetic Declination: +25.800° /~ Survey Name 1 Date: W-37 A 1 December 3, 2002 Total Field Strength: 57514.869 nT Tort 1 AHD 1 DDII ERD ratio: 244.139° 13951.06 ft 16.045 / 0.439 Magnetic Dip: 80.772° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: December 09, 2002 Location Lat/Long: N 70 1748.327, W 149 541.102 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5958932.080 ftUS, E 611788.960 ftUS North Reference: True North Grid Convergence Angle: +0.85225651 ° Total Corr Mag North -> True North: +25.800° Grid Scale Factor: 0.99991420 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ¡O/100ft) (ftUS) (ftUS) 9631.60 31.92 242.04 8596.27 -2005.90 -2669.03 -1968.83 5956234.30 609860.22 N 70 1722.075 W 149638.470 9678.50 31.32 242.91 8636.21 -2027.87 -2680.39 -1990.64 1.61 5956222.61 609838.58 N 70 1721.963 W 149 6 39.105 9708.50 37.09 262.00 8661.08 -2043.89 -2685.22 -2006.59 40.41 5956217.55 609822.70 N 70 17 21.915 W 149 6 39.570 9739.50 46.10 275.35 8684.29 -2064.35 -2685.48 -2027.05 40.64 5956216.98 609802.25 N 70 1721.913 W 149 640.166 9769.79 49.75 281.66 8704.59 -2086.51 -2682.13 -2049.26 19.59 5956220.01 609780.00 N 70 1721.946 W 149640.813 9800.00 51.43 297.73 8723.85 -2108.23 -2674.27 -2071.09 41.42 5956227.54 609758.05 N 70 17 22.023 W 149 641.449 9834.50 57.01 313.56 8744.10 -2130.53 -2657.94 -2093.63 40.51 5956243.53 609735.28 N 70 17 22.183 W 149 642.106 ,~ 9864.50 60.02 324.77 8759.80 -2146.92 -2638.61 -2110.28 33.39 5956262.61 609718.34 N 70 1722.374 W 149 642.591 9902.50 59.67 338.46 8778.96 -2162.08 -2609.81 -2125.85 31.15 5956291.17 609702.35 N 70 17 22.657 W 149 643.045 9935.00 56.56 353.00 8796.19 -2168.54 -2583.20 -2132.68 39.14 5956317.68 609695.12 N 70 1722.918 W 149 6 43.245 9974.50 58.27 13.11 8817.62 -2166.26 -2550.24 -2130.87 43.05 5956350.66 609696.45 N 70 17 23.243 W149643.192 10004.61 62.70 26.08 8832.49 -2157.10 -2525.66 -2122.05 40.23 5956375.36 609704.90 N 70 17 23.484 W 149 6 42.935 10047.91 66.65 41.65 8851 .11 -2134.87 -2493.35 -2100.26 33.73 5956407.99 609726.20 N 70 17 23.802 W 149 6 42.301 10092.36 65.73 54.05 8869.11 -2104.43 -2466.12 -2070.20 25.60 5956435.66 609755.85 N 70 17 24.070 W 149641.425 10132.48 63.10 58.28 8886.44 -2074.11 -2445.97 -2040.16 11.55 5956456.26 609785.58 N 70 17 24.268 W 149 640.550 10186.77 62.25 69.83 8911.43 -2030.57 -2424.90 -1996.91 18.96 5956477.96 609828.52 N 70 17 24.476 W 149 639.290 10222.50 61.16 74.53 8928.37 -2000.50 -2415.27 -1966.97 11.98 5956488.04 609858.30 N 70 17 24.570 W 149 638.417 10262.50 59.55 81.79 8948.17 -1966.42 -2408.13 -1932.98 16.28 5956495.68 609892.18 N 70 17 24.641 W 149 637.427 W-37 A ASP Final Surveys.xls Page 1 of 2 12/9/2002-12: 15 PM Grid Coordinates Geographic Coordinates Station JD MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) n (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10295.50 60.14 87.88 8964.76 -1937.98 -2405.56 -1904.58 16.05 5956498.67 609920.53 N 70 1724.666 W 149 636.600 10352.00 60.14 87.88 8992.89 -1889.00 -2403.75 -1855.62 0.00 5956501.21 609969.46 N 70 1724.684 W 149635.173 .~ W-37 A ASP Final Surveys.xls Page 2 of 2 12/9/2002-12: 15 PM Scblullbepgop Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well D.S. 15-27 J'1;) 'OO(P D.S.7-09 J Î<6 - 0 7tn D.S. 5-28Atf3. 1- I g 5 D.S.16-20 J :S..ç?~S W-37A ñ1 - /4 c¡ W-37 A W-37 A W-37 A y Job# Log Description Date LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG PRODUCTION PROFILE 22532 MCNL 22531 ARC3 DATA 22531 MD VISION RESISTIVITY 22531 TVD VISION RESISTIVITY 12/08/02 12/12/02 12/11/02 12/04/02 12/04/02 11/02/02 11/02/02 11/02/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED DEC 20 2002 Alaska 0'1 & Gas Cons. Commission Anchorage Blueline NO. 2625 12/18/02 State of Alaska Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: Field: Prudhoe Bay Sepia Color Prints 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth CD ~' ~ . (X OJoyxJ ) c9,~'I'1 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-37 A Date Dispatched: 9-Dec-02 Installation/Rig Nordic 2 Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys Field Copy ASP (Alaska State Plane) 2 2 1 on floppy on floppy RECEIVED DEC 11 2002 ~3ka Oiï & Gas Cons. C<immi8sion Anchorsge. Received By: ~ {J~--- Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1 ) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ') ~1f Œ \ TONY KNOWLES, GOVERNOR AIfASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99510 Re: Prudhoe Bay Unit W-37A BP Exploration (Alaska), Inc. Pennit No: 202-149 Surface Location: 1321' SNL, 1452' WEL, Sec. 21, TIIN, R12E, UM Bottomhole Location: 1592' NSL, 3277' WEL, Sec. 21, TlIN, RI2E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits 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 pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ( ~Arf~lv>4' ~ C~}bechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~day of July 2002. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA (. STATE OF ALASKA .. )AND GAS CONSERVATION COMMk )ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 91' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028263 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number W-37 A 9. Approximate spud d~ 09/10102 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10383' MD I 8998' TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 65 Maximum surface 2337 psig, At total depth (TVD) 8675' I 3378 psig Setting Depth TOD Bottom Quantitv of Cement Length MD TVD MD TVD (include staae data) 9531 9430' 84251 10383' 8998162 cu ft Class 'G' \tJ6A- 7//1 (OL ~ I( r:>(2øÞ '2-- 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1321' SNL, 1452' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 1247' NSL, 3509' WEL, SEC. 21, T11N, R12E, UM At total depth 15921 NSL, 3277' WEL, SEC. 21, T11N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well I ADL 047452,15921 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 96551 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casing Weiaht Grade CouDlina 3-3/4" 3-3I16"x2-7/S" 6.2#/6.16# L-80 TCII / ST-L 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical (::(.'tIVl: ) Casing Structural Conductor Surface Intermediate Production Liner 1 0265 feet 9251 feet 9905 feet 8925 feet Length Plugs (measured) 3-7/8" Baker IBP at 9905' MD (03/02) ..¡ ("I q ff', iì I"" f L LUv¿ Junk (measured) Collapsed Casing at 9968' MD Size Cemented MD tW I~ Gons. Comcisslol Ai1c_e 110' 20" 2680' 13-3/8" 9633' 9-5/8" 862' 7" 8 cu yds Concrete 3840 cu ft Cold Set II & III 110' 2680' 110' 2680' 1985 cu ft Class 'GI 322 cu ft Class 'G' 96331 9403' - 10265' 8688' 8493' - 9251' ORIGINAL 20. Attachments Below Bridge Plug: Squeezed: 99601 - 9967', 9974' - 9980', 10000' - 10026', 10039' - 10066', 10076' - 10083' true vertical Below Bridge Plug: Squeezed: 8974' - 8980', 8986' - 8992', 9009' - 9033', 9045' - 9069', 9078' - 9085' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Sondra Stew man, 564-4750 21. I;:~:Y ::~~:::::he;iii,,~~~~:¿EE~~~ì~ee~ Date 7//1/ ð L Permit Number API Number Apprl)v~Bate See cover letter 20 G -/:7/ 50- 029-21855-01 '11^':,IYJ~ for other requirements Conditions of Approval: Samples Required 0 Yes 2g No Mud Log Fequlred 0 Yes L!I No Hydrogen Sulfide Measures t8I Yes 0 No Directional Survey Required ø Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: nst- BoèE ~ 'SSoO tO~¿. ()¡glnal Signed By Ca"'lmy ~lli Taylor Perforation depth: measured Approved By Form 10-401 Rev. 12-01-85 Commissioner by order of the commission Date si!th:lìcate ) ) BP W-37a CrD Sidetrack Summary of Operations: I A CTD through tubing sidetrack is planned for W-37. The coil sidetrack, W-37a, wjJJ.iexit the 7" liner in the Sag River formation and target Ivishak Zone 3 and 4. An existing inflatable bridge plug is isolating all perfs. Phase 1: Prep work. Planned for August 1, 2002. 1. Tubing integrity will be verified (production packer leaks) by setting a plug in the tail pipe and / pressure testing the tubing. Casing integrity and IBP integrity will be verified by a combo MIT on IA and tubing. / 2. Wline will dump bail 8bbls cement on top of existing inflatable bridge plug. 3. Wline will set a through tubing whipstock at 9655' . Phase 2: Mill window, Drill and Complete sidetrack: Planned for September 10, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Mud Program: . Phase 2: Mill with viscosified sea water, drill with Flo-Pro (8.6 - 8.7 ppg) I Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 3/16" TC II x 2 7/8" ST-L soJid, cemented and perf'd liner from TD to approx. 9430 MD (8425ss). Liner cement will be a minimum of 11 'bbls of 15.8 ppg latex cementfor top of cement at top of liner. Well Control: . BOP diagram is attached. ./ . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 65 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray, Resistivity will be run over all of the open hole section. Memory CNL will be run inside the liner. Hazards . / W pad has no production with H2S in excess of 100 ppm. The closest wells to W-37 have measured H2S readings of 10 ppm. No fault crossings . Reservoir Pressure Res. press. is estimated to be 33]8 psi at 8675'ss (7.5 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2337 psi. RECEI\!F JüL ~¡ 2 2002 Alaska Oil & Cons. Lu,;., Ancho~e TREE = 4-1/16" CIW WELLHEAD = CAMERON )\,CfUii:'fÖ¡:f;;"".""'.'.AXELS'öÑ 'RECELEV-;'.'.._'."'-"'-~-".'.'§Õ:'99ï 'BF:.'E[BT;.'."~.'.'.'.""...'....'&4":1"4ï' kõÞ.';;;;...'."'''.''''''''''''''.''.'''''''''''.'''3200ï ~~~~~~~~!~~~.~.v~.~~~~~.:~~~~~: Datum MD = 9867' ~"'''''''''-''''''''^"''''~''^..'''''N'''''''W~^...w..m'''''''''''''''''''''''''''','''''"^",H.......,,,.............,~ Datum TVD = 8800' SS ) 13-3/8" CSG, 68#, L-80, D = 12.415" 1--1 2680' ~ Minimu m ID = 3.725" @ 9444' 4-112" OTIS XN NIPPLE I TOP OF 7" LNR 1-1 9403' 1 4-1/2" TBG, 12.6#, L-80, 0.0152 bpt, D = 3.958" 1--1 9476' 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 9633' ~ PERFORATION SUrvtv1ARY REF LOG: BHCS ON 09/01/88 ANGLE AT TOP PERF: 27 @ 9960' Note: Rater to Production DB tor histori::al perf data S 12: E SPF IN1£RV A L Opn/Sqz ()å. 1£ 3-3/8" 4 9960-9967 S 09/24/94 3-3/8" 4 9974-9980 S 09/24/94 3-3/8" 4 10000-10010 S 09/24/94 3-3/8" 6 10010-10026 0$ 09/15/88 3-318" 6 10039-10066 0 <) 09/15/88 3-318" 4 10076-10083 S 09/24/94 1 PBTD H 10220' I 7" LNR, 26#, L-80, 0.0383 bpt, 10 =6.276" H 10265' I DA.1£ 09/15/88 02115/01 03105/01 09/08/01 03104/02 REV, BY COMI'vENTS GRV ORlGINA L COMR..E1l0N SIS-OAA CONVER1£D TO CANV AS SIS-LG FINAL RN/TP CORRECTIONS Tfvf\J/KK SET IBP DATE REV BY W-37 " L I I i i :8: :&. 1 f ~ 1 " ] ì ..~ COMI'vENTS .. I SAFETY ):s 2147' H4-1Ì2" CAr£O SSSV NIP, 10= 3.813" ~ GAS LIFT MANDRELS DEV TYPE VL V LA Ta-J 10 MERLA RA 32 MERLA RA 31 MERLA RA 30 MERLA RA 31 MERLA RA PORf DATE ST MD NO 5 3152 3059 4 6323 5776 3 8030 7222 2 8914 7982 1 9177 8210 9298' H4-112" OTISSLlDIf\K3 SLEEVE, 10= 3.813" I 9368' 1--14-112" 1BG SEAL ASSY I 9372' 1-!9-5/8" x 4-1/2" TIW HBBP-R A<:R, 10= 4.0" I 9411' 1-!4-112" OTIS X NIP, 10 = 3.813" I 9444' 1-!4-112" OTISXNNIp, 10= 3.725" I 9476' 1~4-112" 1BG TAIL, D = 3.958" I 9481' 1-1 EUvÐ'IT LOGGED 10/02188 I 9854' I-IMARKER JOINT I 9905' 1-13-7/8" BKR IBP (03/04/02) I/' 9968' l-f COLLAPSED CSG I RE ¡¡=~ ~." ,å j';~,,;-: -j E 1 f f~. Alaska on & Gens. LmmmSSIOf¡ Anchorage PRUDHOE BAY UNIT WELL: W-37 PERMT t-b: 88-0940 AA t-b: 50-029-21855-00 See. 21, T11 N, R12 E BP Exploration (Alaska) TREE = 4-1/16" CIW WELLHEAD = CAMERON ACruÃTOR';;'.""'AXELSON ...w.w.w"......,.,w.W'''''W''''''.',.',,,w''''''''Y'''',,,wuü'''''W'''''''W'-'.~,,...........,v."''''W.W;-.W"w.w.W.'''.' KB. ELE\! = 90.99' .. ~"W"'W"".....w.w.=,.w"w.....W".w.w..,......'."''''''''''''W'''''''.'...'m.'.~w~.~....w...w.'.'~.w..... BF. ELE\! = 54.14' "Rop;'""" ... " 320ÕÎ .....w.w.""....."'" . ..w.,,"...... .. . . . ........ .... ,,-'.... ..... -~,~w~~~!:w~w".~w~~^~,. ~~~g~ Datum MD = 9867' .w......u.W"W.'~'Ho'.'...'.'.w....w,...w...w.',W""=W""""''''''''''''",W.W'."'.W.'.'.'.W.'."'N.".W.'.W.W,-".W Datum TVD = 8800' SS ) W-37a Proposed Completion SAFEr -)TES Leaking Prod Packer to be isolated i by sidetrack liner cement. ~ :8: &. I I TOP OF 7" LNR l-t 9403' 'I I J' J~-~~~'! I DA TE REV BY COMMENTS 05/02/02 TS PROPOSED CTD SIDETRACK 13-3/8" CSG, 68#, L-80, 10 = 12.415" l-t 2680' ~ Minimum ID = I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-t 9476' 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-t 9633' ~ Proposed whipstock approx. 9655'- ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/01/88 ANGLE AT TOP ÆRF: 27 @ 9960' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9960-9967 S 09/24/94 3-3/8" 4 9974-9980 S 09/24/94 3-3/8" 4 10000-10010 S 09/24/94 3-3/8" 6 10010-10026 T&A 03/04/02 3-3/8" 6 10039-10066 T&A 03/04/02 3-3/8" 4 10076-10083 S 09/24/94 I PBTD l-t 10220' I 7" LNR, 26#, L-80, 0.0383 bpf, 10 = 6.276" l-t 10265' I DATE 09/15/88 02/15/01 03/05/01 09/08/01 03/04/02 REV BY COMMENTS GRV ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-LG FINAL RN/TP CORRECTIONS TMN/KK SET IBP 8 2147' ~14-1/2" CAMeO SSSV NIP, 10 = 3.813" I ~ GAS LIFT MANDRELS DE\! TYÆ VLV LATCH 10 MERLA RA 32 MERLA RA 31 MERLA RA 30 MERLA RA 31 MERLA RA PORT DA TE L ST MD TVD 5 3152 3059 4 6323 5776 3 8030 7222 2 8914 7982 1 9177 8210 I I 9298' r-4-1/2" OTIS SLIDING SLEEVE, 10 = 3.813" I ì 9368' 1~4-1/2" TBG SEAL ASSY I 9372' 1....J9-5/8" x 4-1/2" TIW HBBP-R PKR, 10 = 4.0" I 9411' I....J 4-1 /2" OTIS X NIP, 10 = 3.813" I IJ4-1/2" OTIS XN NIP, 10 = MlLLED I TO 3.30" 1~4-1/2" TBG TAIL, 10 = 3.958" I l-i ELMD TT LOGGED 10/02/88 I 9444' 9476' 9481' ~ l.,' ..' "'"'..'''' ',',.".. I TD l-t 10383' I f~~r1~]r~ I 9854' HMARKffiJOINT I F'~:::'::.~":::::~..C~;.::. - Proposed cement cap to back up IBP ~ 1 9905' 1-13-7/8" BKR IBP (03/04/02) I I 9968' l-t COLLAPSED CSG I ~ PRUDHOE BAY UNIT WELL: W-37A ÆRMIT No: API No: 50-029-21855-01 Sec.21,T11N,R12E BP Exploration (Alaska) Vertical Section 0 8550 8600 ::. TSGR 8650 - 8700 - 8750 ~-TSAD--- z-8800 - CD CD u. - ~8850 - top perf -Þ 8900 - 8950 ~31P -27P 9000 -=.-8,993 9050 - 9100 - relMS 500 .. W-37 1,000 Path Distance (Feet) 2,000 Angle @ K.O.- 32 deg MD:96SS 1 ,500 Marker Depths @Orig WeJlbore 27P 1 8,98Slft TVD 2,500 8,9931 8,9931ft TVD 3,000 3,500 TSGR 8,60Slft TVD 8,9491ft TVD 31P Kick Off 8,616 ft TVD 9,655 ft MD 3,343 ft Deprtr @KO ~ --.------ .-.-.----.---.-.--+----.----.----.-------.-...-----------,-,-------'---------'---------'------- MD KO Pt 9,655 MD New Hole 728 W-37a case 103 Total MD 10,383 May 1 5, 2002 TVDTD 8,998 Ted x4694 DLS deg/100 Tool Face Length Curve 1 10 4S 18 Curve 2 33 70 220 '~ Curve 3 33 87 190 Curve 4 12 90 300 Tot Drld:728 ft 10383 TD 728 ~---~._-_._------- W-37 I Well Name W-37 -1,000 - CLOSURE Distance 2,985 ft Az 217 deg NEW HOLE E/W (X) N/S (Y) Kick Off -1 ,940 -2,704 -1,500 - TD -1,784 -2,393 State Plane 610,005 5,956,539 Surface Loc 611,789 5,958,932 .~' ~ DLS ~ deg/1OO Tool Face Length Curve 1 10 4S 18 E Curve 2 /33 70 220 .g B Curve 3 33 87 190 c Ð Curve 4 12 90 300 :a >- -2,500 - 728 ,-,. W-37a Case 103 May 1 5, 2002 -3,000 - Ted x4694 I -3,000 -2,500 -2,000 X distance from Sfc Loc -1,500 -3,500 -1 ,000 Plan Name: 5/23/2002 15:05 Case 1 22 Drawn: All Measurements are from top of Riser top of bag bttm of bag middle of slips middle of pipes ,....--. middle of flow cross ~ middle of blind/shears middle of pipe/slips ) :.... Q) CJ) .- a:: III Schlume""" ' Blind/Shears 2 3/811 combi ram/slips Mud Cross variable bore pipe 3 1/2"-2 7/8" 2 3/811 combi ram/slips Flow Tee ........................ --_.~.-_.---.-.. r-- "-- ..................... --.-----.-..-..- ) 7/9/2002 BAG TOTs Mud Cross TOTs i 206977 ) ) DATE 7/01/02 CHECK NO. H206977 DATE INVOICE / CREDIT MEMO DESCRIPTION PERMIT TO DRILL FEE GROSS VENDOR DISCOUNT NET /01/02 CK062602E R.ECE1VED¡ WJ37f+ I' '1 1 (2 Lno-o? ¡¡,J U :..... ¡ .If.... MasRa Oil & Gas Cons. Commission Anchorage ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BPEXPLORATION,(ALASKA) INC. P.O..BOX 196612 ANCHORAGE, ALASKA99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAFFILlATE.OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 206977 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 TO THE ORDER OF 8.'.........' .p..,....... .,.rr.,......,.,......'..,"...<l. "'....'.....:;'.1°.\ .'...,....J,.t>j'r. ~I rll: ; ..~ Ii:.-" .,', """:-'~.I '. tIn,' :1i.t'¡' .. ..,.'. . .~.Jml" -".." ..~t...m STEI00 99501 $100.00***** PAY A.LASKA STATE ALASKA OIL & GAS CONSERVATION COMMISSION 333rW 7TH AVE ANCHORAGE,. AK. t:.)~ßlVA1..ID I.'1rn::R .. i;:j,:¡¡fl.~~~¡~'<>'..".". ..".~ f.{f.~{~\.~.}:~:t1¡j~;~t!'~~~ III 2 0 b q ? ? III I: 0... ~ 2 0 3 a q 5 I: 0 0 a ...... ~ q III « ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME vJ - ~7 Æ- . CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL Rev: 6/18/02 C\jody\templates CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well --'-' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SP ACING EXCEPTION DRY DITCH SAMPLE Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY AI)/ WELL NAME tgv ¿U- ]711 PROGRAM: Exp- Dev A RedrllZ- Se~ - Wellbore seg- Ann. disposal para req- FIELD & POOL G'~Ò/...c;D INITCLASS /Jp» /-~tJ GEOLAREA ~ld UNIT# //h..(O ON/OFFSHORE ~V :ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . r?J N . 2. Lease number appropriate. . . . . .. . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wens.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N . AErR -~I~ 12. Permit can be issued without administrative approval.. . . . . Y N IffY ~ 7(/ij°2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . \::!) N .ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . r<l)N 15. Surface casing protects all known USDWs. . . . . . . . . . . (2)N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~ f\t/ Ir 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ 18. CMT will cover all known productive horizons. . . . . . . . . . . N 19. Casing designs adequate for C, T,B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N CTDu ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . N '7IIGP/t? L . 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . Y N ^'11t- 24, Drilling fluid program schematic & equip list adequate. . . . . tý¿ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~ N ') ~ I APPR DATE. 26. BOPE press rating appropriate; testto~SO'" psig. N ÞtC,1 Z ~ ~ ( PSi' WCA- 711.~/oL 27. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . ~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . . YW 31. Data presented on potential overpressure zones. . . . . .. )fN Â J LJ 32. Seismic anaiysis of shallow gas zones. . . . . . . . . . . . . Y /L/c y"'{ \. !}fAR _~TE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N /f'~ "Ø~:? 34. Contact namelphone for weekly progress reports [exploratory onr Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for dispo (D) will not damage producing formation or impair recovery fr a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.4 . Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP9#G JDH J:J7(r,(çV ~¿ WGA \J-,J(:,ft- GEOLOGY APPR DATE P ~~2- /l)~ ~ v COT DTS °l/?J'lt. G:\geology\permits\checklist.doc Comments/Instructions: