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181-175
1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Tuesday, October 13, 2020 1:33 PM To:Winston, Hugh E (CED) Subject:FW: CANCEL sundry #320-412 for 12-07a (PTD#181-175) From: Carrie Janowski <Carrie.Janowski@hilcorp.com> Sent: Tuesday, October 13, 2020 1:32 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: David Bjork <David.Bjork@hilcorp.com> Subject: CANCEL sundry #320‐412 for 12‐07a (PTD#181‐175) All, Please cancel Sundry # 320‐412 for PBU 12‐07a (PTD# 181‐175) as this well passed a No‐Flow Test and will no longer need a Subsurface valve. Please let me know if you need any additional information for this request. Thanks, Carrie The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov October 8, 2020 Mr. Bo York Sr. Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 RE: No-Flow Verification Prudhoe Bay Unit 12-07A PTD 1811750 Dear Mr. York: On October 5, 2020 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-07A. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-07A. The test methodology used by Hilcorp Alaska LLC (Hilcorp) was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(A): (A) the measured liquid production is not greater than 6.3 gallons per hour, and the measured gas production is not greater than 900 standard cubic feet per hour. The well performance was monitored for approximately 3.5 hours consisting of three separate flow rate checks each preceded by 1-hour pressure build up periods. Gas flow rates and well pressures declined to zero in approximately 7 minutes once the well was open to flow through the test equipment. There was no liquid flow to surface during the no-flow test. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-07A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2020.10.08 15:32:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I<0-, ►t'(�'f 42� DATE P. I. Supervisor FROM: Lou Laubenstein SUBJECT Petroleum Inspector 10/6/2020 No Flow Test PBU 12-07A Hilcorp North Slope LLC PTD 1811750 10/5/2020: 1 arrived on location and met with Josh Prowant and Nate Boisso (Hilcorp North Slope) reps and reviewed the testing procedure and rig up they where going to use. The well had been shut in and was bled to 0 psi on the tubing, the gas lift was shut off, and the IA was also bled to 0 psi. The OA on this well has been cemented off and read 0 psi during this entire test. There was a 25 -foot length of 1 -inch Parflex hose connected to the tree cap jewelry which were'/2-inch NPT fittings. The hose hooked to a tee that had a calibrated Crystal pressure gauge and then the flow meter downstream of that. After the meter there was a 100 -foot Parflex hose that ran to an open top tank (length of hose seemed unusual). All calibrations of the equipment where current. , The followina table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas — scf/hr Liquid — al/hr 14:04 0/0/0 Shut in for build u 14:34 7/0/0 30 -minute pressure reading 15:04 13/0/0 2000+ - 0 Oen to flow 15:08 <900 0 15:10 0/0/0 0 scfh, 0 psi before shut in for build u 15:40 12/0/0 30 -minute pressure reading 16:10 16/0/0 2000+ 0 - Oen to flow 16:15 <900 0 16:18 0/0/0 0 scfh, 0 psi before shut in for build u 16:48 10/0/0 30 -minute pressure reading 17:18 16/0/0 2000+ 0 Oen to flow 17:23 <900 0 17:25 0/0/0 0 0 0 scfh, 0 psi ✓ ' Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: none - 2020-1005_No-Flow_PBU-12-07A_11.docx Page 1 of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y Jody Colombie at 12:00 pm, Oct 02, 2020 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN MGR02OCT20 10-404 Per 20 AAC 25.265 (h) (2) witnessed performance test by AOGCC. 24 hour notice. DLB10/02/2020 DSR-10/12/2020 X 2407 <HV<<<<<<<<<<<< Q5HTXLUHG" &RPP 10/13/2020 dts 10/12/2020 JLC 10/13/2020 RBDMS HEW 11/2/2020 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗ϭϮͲϬϳĂ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϰϬϵͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŝůtĞůů >ĞŐ͗Eͬ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗KĐƚϱ͕ϮϬϮϬ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϭͲϭϳϱϬ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗ZLJĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ Current Bottom Hole Pressure:3287 psi @ 8,800’ TVD Maximum Potential Surface Pressure:2407 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌLJ dŚĞŽďũĞĐƚŝǀĞŽĨƚŚŝƐŝŶƚĞƌǀĞŶƚŝŽŶŝƐƚŽŝŶƐƚĂůůĂŶĞǁ<ǀĂůǀĞǁŝƚŚĂĚũƵƐƚĞĚĐůŽƐŝŶŐƉƌĞƐƐƵƌĞŝĨĂEŽ&ůŽǁdĞƐƚ ĨĂŝůƐ͘dŚĞĐƵƌƌĞŶƚ<ǀĂůǀĞŝƐƐĞƚƚŽĐůŽƐĞĂƚΕϰϯϮƉƐŝΛϲϬΣ&͘dŚĞŶĞǁǀĂůǀĞǁŝůůďĞƐĞƚƚŽĐůŽƐĞĂƚΕϮϮϬƉƐŝ ƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞ͘dŚĞĐŽŵŵŽŶůŝŶĞŽĨϭϮͲϬϳĂĨůŽǁƐĂƚĂƉƉƌŽdžŝŵĂƚĞůLJΕϭϴϬƉƐŝ͘dŚŝƐĐŚĂŶŐĞǁŝůůĂůůŽǁŽƉĞƌĂƚŝŽŶƐ ƚŽŶŽůŽŶŐĞƌĂƉƉůLJĐŚŽŬĞĚďĂĐŬƉƌĞƐƐƵƌĞƚŽƚŚĞǁĞůůƚŽŬĞĞƉƚŚĞǀĂůǀĞŽƉĞŶ͕ǁŚŝůĞƐƚŝůůĐůŽƐŝŶŐŝĨĂƐƵƌĨĂĐĞ ŝŶƚĞŐƌŝƚLJŝƐƐƵĞŽĐĐƵƌƐ͘ dŽƚĞƐƚƚŚĞǀĂůǀĞǁĞǁŝůůŽƉĞŶƚŚĞƉƌŽĚƵĐƚŝŽŶĐŚŽŬĞƚŽĐŽŵŵŽŶůŝŶĞƉƌĞƐƐƵƌĞŽƌĚŝǀĞƌƚƚŽĂĚĞƉƌĞƐƐƵƌŝnjĞĚ ƐĞƉĂƌĂƚŽƌ͘dŽƌĞƐĞƚƚŚĞǀĂůǀĞ͕ƚŚĞǁĞůůǁŝůůďĞƉƌĞƐƐƵƌĞĚƵƉƚŽĂďŽǀĞƚŚĞƚƌŝƉƉƌĞƐƐƵƌĞƚŚĞŶŐƌĂĚƵĂůůLJƌĞŽƉĞŶĞĚ ƚŽƚŚĞŶŽƌŵĂůŽƉĞƌĂƚŝŶŐƌĂŶŐĞ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh^ůŝĐŬͲůŝŶĞ Ϯ͘ Z/,ĂŶĚƐĞƚƚŚĞƐƵďƐƵƌĨĂĐĞĐŽŶƚƌŽůůĞĚƐƵďƐƵƌĨĂĐĞƐĂĨĞƚLJǀĂůǀĞ͘ ϯ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ϰ͘ ŽŶĚƵĐƚĂ^s^ƚĞƐƚǁŝƚŚŝŶϱĚĂLJƐĂĨƚĞƌƐƚĂďŝůŝnjĞĚĨůŽǁ͘ Per 20 AAC 25.265 (h) (2) performance test to be witnessed by AOGCC within 5 days of stabilized production. 24 hour notice. tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ RECE VEb STATE OF ALASKA I • ALASKA OIL AND GAS CONSERVATION C SION REPORT OF SUNDRY WELL OPERATIONS APR 1 2 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations 0` CC° Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well RI Re-enter Susp Well 0 Other: OA WeIlLock Squeeze I . 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-175 3. Address: P.O.Box 196612 Anchorage, Development Il Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20409-01-00 7. Property Designation(Lease Number): ADL 028330 8. Well Name and Number: PBU 12-07A 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 10570 feet Plugs measured None feet true vertical 9093 feet Junk measured 10449,10450 feet Effective Depth: measured 10420 feet Packer measured 8619 feet true vertical 8961 feet Packer true vertical 7441 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 41-120 41-120 1530 520 Surface 2679 13-3/8" 40-2719 40-2719 5380 2670 Intermediate 9233 9-5/8" 38-9271 38-7963 6870/8150 4760/5080 Liner 1597 7" 8966-10563 7718-9087 8160 7020 Scab Liner 1791 4-1/2" 8709-10500 7511-9031 8430 7500 Perforation Depth: Measured depth: 10230-10373 feet True vertical depth: 8793-8919 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 36-8740 36-7536 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm 8619 7441 true vertical depth) 4-1/2"Weatherford PB SSSV 2016 2016 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA Cemented to surface.OA down squeeze performed with HES WeIlLock.Pumped 1.0 gallons of WeIlLock into OA before seeing returns from opposing casing port.1.25 gallons into annular space before pressure began rising. Once at recommended squeeze pressure monitored at 30 min intervals until minimal pressure loss.Daily monitors conducted by DHD getting pressures and temp on spool for fourteen days. Treatment descriptions including volumes used and final pressure: Pumped 2.25 gallons of WeIlLock into OA.Final IA Pressure=1770 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 442 313 2068 1542 206 Subsequent to operation: No Test Available 1770 495 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.2831 15.Well Class after work: Daily Report of Well Operations 10 Exploratory ❑ Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ 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: 318-028 Authorized Name: Oestgaard,Finn Contact Name: Oestgaard,Finn Authorized Title: Production Engineer Challenger Contact Email: Finn.Oestgaard@bp.com Authorized Signature: - ("D Date: 1—t1^t Ej Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 / - 4/4 q t- �j0710, f 71e i RBDMS rR I 3 1018Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) April 11, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Repair Well (OA Welllock Squeeze), covered under Approved Sundry #318-028 for Well PBU 12-07A, PTD #181-175. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Daily Report of Well Operations PBU 12-07A ACTIVITYDATE SUMMARY T/I/O=950/1740/160. Temp= 140°. OA down squeeze(prep). AL online,ALP= 1740 psi. Install heater in well house, bled treecap to 0 psi. 3/22/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 12:00 T/I/O=950/740/160. Temp Well 140°. OA spool temp=50° Job Scope: OA down sqz w/HES WeIlLock. Pumped 1.0 gallons of WeIlLock into OA before seeing returns from opposing casing port. Installed hydraulic filled manifold with Ascroft gauge on return side for monitoring pressure on OA. 1.25 gallons into annular space before pressure began rising. Once at recommended squeeze pressure monitored at 15 min intervals over 2 hour period. Continued process at 30 min intervals until minimal pressure loss. left pressure on OA. Daily monitors will be conducted by DHD getting pressures and temp on spool piece for fourteen days. Well secured and DSO notified of well condition. Note: Caution tags hung on both sides of OA stating Viton seals in 1502 connections temp rating of-20 deg F thru 400 deg. F. Post WeIlLock Treatment. 3/23/2018 ***Activity complete*** T/I/O=950/1740/2140. Temp= 140°. WHPs(post Wellock). OA spool temp= 102°. OA casing valve's removed, 2"valves installed. OAP decreased 160 psi since 16:30 hrs(3.5 hrs). OA spool temp increased 52°. 3/23/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 20:15 T/I/O=550/1740/1840. Temp= 140°. WHPs(post Wellock). AL online,ALP= 1740 psi. OA spool temp= 132°. OA casing valve's removed, 2"valves installed. OAP decreased 300 psi since 3/23/18 @ 20:15 hrs. OA spool temp increased 30°. Moved heater away from OA spool. SV=C. WV, SSV, MV=O. IA, OA=OTG. 09:15 3/24/2018 T/I/O=550/1740/0. Temp= 140°. WHPs(post Wellock). AL online,ALP = 1740 psi. OA spool temp =72°. OA casing valve's removed, 2"valves installed. OAP decreased 1840 psi psi since 3/24/18. OA spool temp decreased 60°. Heater on OA spool working fine, tree cap bled. SV=C. WV, SSV, MV=O. IA, OA=OTG. 09:30 3/25/2018 T/I/O=550/1740/2140. Temp= 140°. WHPs(post Wellock). AL online,ALP= 1740 psi. OA spool temp= 142°. OA casing valve's removed and intergal with cap installed. OAP increased 2140 psi since 3/25/18. OA spool temp increased 82°. Sample is setup(hard). Moved heater away from OA spool. SV=C. WV, SSV, MV=O. IA, OA=OTG. 08:30 3/28/2018 T/I/O=550/1740/600. Temp= 140°. WHPs(post Wellock). AL online,ALP= 1740 psi. OA spool temp= 100°. OA casing valve's removed and intergal with cap installed. OAP decreased 1540 psi since 3/29/18. OA spool temp decreased 42°. Sample is setup(hard). Moved heater away from OA spool. SV=C. WV, SSV, MV=O. IA, OA=OTG. 08:00 3/29/2018 T/I/O=550/1760/120(6 o'clock), 940(12 o'clock). Temp= 134°. WHPs(post wellock). ALP= 1740 psi and is online. OA spool temp= 130°, sample is set up(hard). TP increased 50 psi, IAP increased 20 psi in 12 hours. 3/31/2018 SV=C. WV, SSV, MV=O. IA,OA=OTG. 16:00 /1/0=500/1740/410. Temp= 134°. WHPs(post Wellock). ALonline,ALP= 1740 psi. OA spool temp = 100°. OAP decreased 300 psi&OA spool temp unchanged since monitor on 03/31/18. 3/31/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 04:40 T/I/O=570/1740/180(6 o'clock)/140(12 o'clock). Temp= 116°. WHPs(post wellock). ALP= 1740 psi and is online. OA spool temp=75°,sample is set up(hard). TP increased 20 psi, IAP decreased 20 psi, OAP @ 6 o'clock increased 60 psi, OAP @ 12 o'clock decreased 800 psi overnight. Heater in well house, away from OA spool,tree cap bled to 0 psi. 4/1/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 12:00 • • Daily Report of Well Operations PBU 12-07A T/I/O=580/1750/180. Temp= 120°. WHPs(post wellock). ALP= 1750 psi, open @ CV. OA spool temp=80°. Wellock sample is set up. TP& IAP increased 10 psi overnight. 4/3/2018 SV=C. WV, SSV, MV=0. IA, OA=OTG. 04:40 T/I/O=560/1730/270. Temp= 120*. WHP's. (Post wellock). ALP= 1730 psi&open to well. No change in TP or IAP, OAP increased 90 psi in-18 hours. 4/4/2018 SV=C. WV, MV, SSV=0. IA, OA=OTG. 23:45 T/I/0=560/1730/180. Temp= 120*. WHP's. (Post Wellock). ALP= 1730 psi&open to well. TP decreased 20 psi, IAP decreased 20 psi, No change in OAP in-12 hours. 4/4/2018 SV=C. WV, MV, SSV=0. IA, OA=OTG. 04:30 T/I/0=560/1730/0. Temp= 120*. WHP's. (Post Wellock). ALP= 1730 psi&open to well. No change in TP or IAP, OAP decreased 180 psi in-15 hours. 4/5/2018 SV=C. WV, MV, SSV=0. IA, OA=OTG. 19:40 T/I/O=540/1700/100. Temp= 120*. WHP's. (Post Wellock). ALP= 1700 psi&open to well. TP decreased 20 psi, IAP decreased 30 psi , OAP increased 100 psi overnight. SV=C. WV, MV, SSV=0. IA, OA=OTG. 04:20 4/7/2018 T/I/0= 1750/0/0. (Post Wellock). R/D OA&OA Comp. Intigral flanges. R/U OA&OA Comp. 3" FMC Gate Valves. Torque OA&OA Comp.to 401 ft lbs. (L7M RC). RDMO ***Job Complete*** 4/9/2018 FWHP=1750/0/0 T/I/0= 1700/1880/180. Temp=SI. Bleed IAP to 0 psi (Post Wellock). AL open @ CV,ALP= 1880 psi. IA FL @ 8501'(#1 S/0,455 bbls). Bled IAP from 1880 psi to 0 psi in 9 hrs. IA FL unchanged. OA needle valve plugged with wellock,when gauge removed pressure read 0 psi. Final WHPs= 1700/0/0. 4/9/2018 Valve crew in control of valves on departure. 18:30 hrs Fluids Summary Bbls Type 2.25 HES WellLock NEE= aWFETY NOT : WELL REQUWIES A SSSV WP3.LH60D= MCEVOY E12-07A 4-12'CHROME TBG&SCAB LNR ACTUATOR= BAKER G KB.BLP/= 80.0' EIF.BEV= Ws �- 110' '1 6A f 2018• H4-1/2'FES X PP.D=3.813` Mix Ante= 46' 7700' ' 141 2016• I—4-1/2'X-LOCK w/4-1/2'EQ DEV ICE&WFD 'Ilium MD 10330' 1j i.4 FB SSSV(02/11/18) ObhimTVD= "_ ___ 8800r SS ;, �e ke 2058' J---19-5/8'FES CBBYTER I 9-5/8'CSG,471,L-80 HYD 563 XO TO —{ 201r .... 207T H 9-5/8'ECP PKR L-80 BTC 9-5/W BOWEN CSG PATCH H 2103• 2367' }"�'� FOC I 2493' 9-5/8'FOC GAS LFT MAPS 113-3/8'CSG.res.L-80,D=12.34r H 2711' I—A ST MD TVD Caul/ TYPE VLV LATCH PORT DATE L 5 3014 3014 5 MAG DOLE FK 16 11/15/15 4 4690 4521 43 MIG DIN RC 0 05/03/09 Minknunl ID =3.726" 8719 3 6031 5515 44 MC DOM: RK 16 11115/15 2 7412 6537 43 11.13 DOE RC 16 11115/15 4-1/2" HES XN NIPPLE 1 8501 7348 39 MG SO R< 24 11/15/15 I I 8680' H4-12"FES X HP D=3.813" MI8811' H9-5/13'X 4-12"BKR S-3 Flat D=3.875' li: M 8848' H4-12"FES X HP.D=3.813' TOP OF SCAB LHRH 8709' s 8709• 19 5t8'X 7'BKR C-2 ZXP LTP 4� 1 w/Blot LNR HGR,D=6.30' .• I 1+1 8718' 1-14-12•FES XN PP ID=3.725' J 4-1/2'1BG,12.6#,13-CR-80 VAM TOP, H 8733' :4, 1,1 0152 bpf,D=3.958' •44 :i/ 8733' 5-12'WLEG,4.85' 1/'•• *�O�i 8738' H r X 4 12'XO.D=3.958' JTOP OF BOT TIEBACK SLEB/E H 8988' • 9-518'x r BOT MC LHR HGR 8972' 4'I• '4 �� ifs ,f •f 9-5/8'CSG.471.L-80,0=8.681' H 9271' 4 --"'' MLLOUT WINDOW(12-07A)9271'-9316' 4 PERFORATION SUMMARY �`� •41. FEF LOG:SLB CM/C 01/01/1982 s t ANGLE AT TOP PERF:28'410230' \!. 4, Note:Refer to Roduction DB for historical perf data X44 SIZE SPF INTERVAL Opn/Sqz DOTE '4 3-318' 4 10226-10252 S 05/01/09 44 2-718" 6 10230-10247 0 05/19/09 ♦44 414 10285' H7'MARKER JTS (2 019.3'&19.55 2-7/8" 6 10278-10285 0 05/19/0944 44 2-7/8" 6 103134-10354 0 05/19109 Aj 3-318' 8 103134-10362 S 05101/09 4* 3-3/8" 6 10354-10373 0 05/17/09 '4A ;, 3-3/8' 4 10374-10388 S 05/01/09 4. 3-3/8' 4 10397-10406 S 05/01/09 4• 3-318' 4 10418-10443 S 05/01/09 1j s • 3-3M' 4 10453-10460 S 05/01/09 4� 3-3/8' 4 10470-10490 S 05/01/09 44.AA-�414�....4•‘�‘ 4)�‘ PBTD 10420' 1 • tt,.44 i4t.'4.1�' '. ;�' 4 4-12`SCAB LHR 12.61,13CR-80 VAM TOP .0152 bpf.D=3.95$' H 10600' 1,,144,,'4% 10670' 10 • 7'LHR 290,L-80,.0371 bpf.D=6.184' —I 10666' 40►0,b DATE REV BY OOMM4TS DATE REN BY COMMENTS PRUDHOE BAY IMT 12130/81 ORIG COM PL (12-07A SDTRK) 11/16/15 JLSIJMD GLV C/O(11/15/15) WELL: 12-07A 04/28/97 LAST WORKOVBt 07/14/16 AV WORMS EDITS FEFMT Pb: 181-1750 06/04/09 D-14 RWO 12/12/17 MGS/JM]SET FLOW THRU SUB w/MBA GAUGI AR No: 50-029-20409-01 06/18/09 KNCITLH RWO SOZ PEWS CORRECTION 01/02/18 ZV/JM) PILLED X-LOCK w/DH GAUGES SEC 18,T1ON,R15E 459'FSL&10'FB 09/09/10 DB/..111D DWG DRAFT CORRECTIONS 02/15/18 CJWJM)SET)FLOCK w/B)DEV&PB SSSV 12/17/10 LBIJM3 ADDED SSSV SAFETY NOTE BP Bcploration(Alaska) RECEIVE.: STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMISSID R Q J n 2018 REPORT OF SUNDRY WELL OPERATIONS MAR 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations G t 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:PB Valve Design IZ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-175 3. Address: P.O.Box 196612 Anchorage, Development Ed Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20409-01-00 7, Property Designation(Lease Number): ADL 028330 8. Well Name and Number: PBU 12-07A 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 10570 feet Plugs measured feet true vertical 9093 feet Junk measured 10449,10450 feet Effective Depth: measured 10420 feet Packer measured 8619 feet true vertical 8961 feet Packer true vertical 7441 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 41-120 41-120 1530 520 Surface 2679 13-3/8" 40-2719 40-2719 4930 2670 Intermediate 9235 9-5/8" 38-9271 38-7963 6870/8150 4760/5080 Liner 1599 7" 8968-10567 7719-9090 8160 7020 Scab Liner 1791 4-1/2" 8717-10508 7517-9038 8430 7500 10230-10373 feet Perforation Depth: Measured depth: �} True vertical depth: 8793-8919 feet BONNE° ` Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 36-8740 36-7536 Packers and SSSV(type,measured and 9-5/8"x 7"Baker S-3 Packer 8619 7441 true vertical depth) 4-1/2"Weatherford PB Valve SSSV 2016 2016 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: 442 313 2068 1542 206 Subsequent to operation: No Test Available No Test Available No Test Available 1985 0 14.Attachments:(required per 20 MC 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 Q Gas 0 WDSPL 0 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: 318-008 Authorized Name: Oestgaard,Finn Contact Name: Oestgaard,Finn Authorized Title: Prod n Engineer Challenger Contact Email: Finn.Oestgaard@bp.com Authorized Signature: _ cot, Date: S—�°"1s Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 V7`- 3/,6/ r RBDM V MAR r 2G18 Submit Original Only 3(°47A • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 7, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for PB Valve Design, covered under Approved Sundry #318-008 for Well PBU 12-07A, PTD #181-175. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • Daily Report of Well Operations PBU 12-07A ACTIVITYDATE SUMMARY ***WELL SHUT IN ON ARRIVAL*** (SSSV Maintenance) DRIFTED TO SVLN AT 1992' SLM W/4-1/2" BRUSH &3.805"G. RING SET 4-1/2"WFD PB VALVE (SN: 16380-R/430psi Dome) IN SVLN @ 2016' MD RAN 4-1/2"CHECK SET(SHEARED/GOOD SET) 2/11/2018 ***CONT. ON 02/12/18 WSR*** ***CONT. FROM02/11/18 WSR***(SSSV Maintenance) PERFORM PASSING CLOSURE TEST ON WFD PB VALVE @ 2016' MD 2/12/2018 ***WELL LEFT SHUT IN, DSO NOTIFIED*** Fluids Summary Bbls Type 1 DIESEL TFC C#/1l r NOTES: WELL REQUIRES A SSSV .WELLHEAD=-- MCEVOY "'"4-'(72'CHROME'MG 8 SCAB LHR"' ACTUATOR= BAKER C 12-07A KB.H_E1/__._. 80.0' K ♦4 Ir 7= s 201$' H4-1/2"FES _ 7700' 20- 110• ` R4+ 2016' I-4-1/2*X-LOCK w/4-1/2'ED DEVICE&WFD 1t D®btmlAD= 10333' • t1 F$SSSV(02111118) Datum TVD= 860d SS * ,a 2058' H9-5/8"HES9-5/8"CSG,476,1-80 HYD 563 XO TO H 2018' • 2077' H9-518"Ea.PKR L-80 BTC 2367' H9-5/8"FOC 9-5/8"BOWEN CSG PATCH H 2103' 9-5/8'FOC GAS LIFT MANDRELS 13-3/8'CSG,724,1-80,D=12.347" --I 2711' ST MD TVD DEV TYPE VLV LATCH FORT DALE 5 3014 3014 5 MAG DOBE FIC 16 11/15/15 4 4690 4521 43 AMG Da FE 0 05/03109 Min knum ID =3.725 @ $719' 3 6031 5515 44 MMG 304E FE16 11/15/15 2 7412 6537 43 &NG DOVE RK 16 11/15/15 4-1/2" HES XN NIPPLE 1 8501 7348 39 LNG SO FE 24 11/15/15 I 8580' H4-1/2*HES X NMP,D=3.813" 61 Iii.4 8611' H9-58"X 4-1/2"BKR S-3 PKR,D=3.875' I 8848' H4-1/2"FES XMPD=3.813' TOP OF SCAB URI 8709' 8709' J—9-5/8'X 7"BKR C-2 ZXP LTP 1 141 w/BKR LIR HCS D=6.30' 0' 11 871$ ' H4-1/2'I-ES XN NIP,D=3.725' 4-1/2-TBG,12.6*,13-CR-80 VAM TOP, H 8733' :t 11a'4 `I 1/1 8733' 5-1/2"WLEG,4.85' .0152 W,D=3.958' 1114 +'4 1 3.958'0= 7"X 4-1/2"XO 114/449' , TOP OF BOT TM�ACK SLEEVE 8988' 1a1. 873H _ A. r'41111 9-518"X 7'GOT MC UPR HDR 8972' •' i `• 4 6 • 1 R1 Y� 9-58"CSG,47*,L-80,D=8.681' H 8271' + k f1�---" F+ELOUT MOM/ 9271'-9316' _ 1 PERFORATION SUMMARY i, L. FRF LOG:SLB CKJGf?JO(101/01/1982 \4Ilk ANaEAT TOP FB :28'@ 1023(Y sit t Note:Refer to Rtrduction DB for historical pert data �d�1 SQE SPF MBRVAL C nISgz DATE ,It 3-3/8" 4 10226-10252 S 05/01/09 4t 1 2-7/8' 6 10230-10247 0 05/19/09 '1 '1 10286' H 7-MARKER JTS (2 @ 19.3'&19.5') 2-7/8" 6 10278-10285 0 05+19/09 '4 t4 2-7/8' 6 10334-10354 0 05/19109 111 14 3-318" 8 10334-10362 S 05/01/09 44 ' 3-3/8" 6 10354-10373 0 05/17/09 44* s� 3-3/8" 4 10374-10388 S 05/01/09 11 3-3/8" 4 10397-10406 S 05101/09 41 3-318" 4 10418-10443 S 05/01/09 41 • 3-3/8" 4 10453-10460 S 05/01/09 14 0.14 1%,. 3-3/8" 4 10470-10490 S 03/01/09 141-�44404.�� 1stt 1 t1�:t'tl iq t PBTD 10420' 4%1044♦/1110 t: 11t, !141,-4111 4-1/2'SCAB UR,12.6*,13CR-80 VAM TOR .0152 bpf,D=3.958' H 10500' .4%,14104%4 10670' j--�'1C3 7'LPR,296,L-80,.0371 bpf,D=6.184' H 10666' it,441` DATE REV BY COFHwUJTS DATE REV BY COMMENTS PTOAHOEBAY INT 12/30181 Otic COMPL (12-07A SDTFOC) 11/16/151 JLS/JAD GLV CO(11/15/15) WFlL: 12-07A 04/28/87 LAST WOFi40VHt 07/14/16 JAD MINOR VMS FRITS PE BAIT No: 181-1750 05/84119 D-14 IWO 12/12/17 AIGS/JAidSET ROW THRU SUB w/ABM GAUGI AA No: 50-029-20409-01 06/18/09 1040 T1.H RM)SCZ F ERFS CORRECTION 01/02118 ZV/JAR PULLED X-LOCK w/DH GAUGES SFC 18,T10N,RISE 459'FSL&10'FEL 09/09/10 DB/AD DRLG DRAFT OOFRECf ONS 02/15/18 CJN'JAD SET X-LOCK w/EQ DB/&FB SSSV 12/17/10 M3/J6D ADDED SSSV SAFETY NOTE SP Exploration(Alaska) OF Tk • • THE STATE Alaska Oil and Gas i%%�s ofj /` sKA Conservation Commission 'wet tt===` = 333 West Seventh Avenue_ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF r a Q. Main: 907.279.1433 ' ALASFax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert %AWED G /11,6 Well Interventions Engineer BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-07A Permit to Drill Number: 181-175 Sundry Number: 318-028 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P)9-4-1 -L Cathy '. Foerster Commissioner DATED this /4 day of February, 2018. RET:APS L_ FE - J 2'c18 STATE OF ALASKA f pALASKA OIL AND GAS CONSERVATION COM N ,>.;,;,a„ C, `i.a • APPLICATION FOR SUNDRY APPROS 20 AAC 25.280 ry 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 43412 3tut2 ) O ee Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change p(�c�)y2(J �(9G4['� '❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other O II�cEMygi�[ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number. 181-175 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 - 6. API Number: 50-029-20409-01-00 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 12-07A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028330 PRUDHOE BAY.PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10570 9093 10420 8961 None 10449,10450 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 41-120 41-120 1530 520 Surface 2679 13-3/8" 40-2718 40-2718 4930 2670 Intermediate 9233 9-5/8" 38-9271 38-7963 6870/8150 4760/5080 Liner 1597 7" 8966-10563 7718-9087 8160 7020 Scab Liner 1791 4-1/2" 8709-10500 7511 -9031 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10230-10373 8793-8919 4-1/2"12.6# 13Cr80 36-8740 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 8618/7440 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: February 10,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions gin r Authorized Signature: N'''.1Date: /z 3/15 NIDate: USE ON Y Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 0 Other: RBDIVIS IL FEE v18 Post Initial Injection MIT Req'd? Yes 0 No°� Spacing Exception Required? Yes 0 No IZ( Subsequent Form Required: 1 7 4 o 4. APPROVED BYTHE t./64? Approved by: P COMMISSIONER COMMISSION Date:2.14/B v 2417 iii? ORIGINAL ,o, Sq�� (-2-c-rte Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. bp • • o • ik Well: 12-07A 12-07A OA WeIlLock Squeeze Sundry Well Interventions Engineer: Michael Hibbert (907) 903-5990 Pad Engineer: Finn Oestgaard (907) 564-5026 History 12-07A is a zone 4 gas lifted producer currently experiencing rapid OA repressurization. The well has an extensive history of OA pressurization starting back in late 2005 when it was shut in for repressurization of the OA from the IA. The well was worked over in 2009, which consisted of a scab liner over the production interval, new tubing and the OA was cemented. 2 days after the well was POP'd post workover the OA was showing signs of pressuring up, at a much quicker rate than previously due to the reduced annular volume. The well remained SI until 2015, when a Well Lock treatment was executed, which did not mitigate the repressurization. The following year 2 separate Squeeze Crete treatments were executed with the later of the 2 remediating the rapid repressurization of the OA. The NOL for this well has been increased to 1280 psi, to assist operations from constantly bleeding the OA to maintain some pressure standoff to the previous NOL of 1000 psi (OA pressure would build to -920 psi). The surface location of the wellhead requires the well to have a SSSV if the well is capable of naturally flowing to surface. The well recently failed a NFT and is currently scheduled to have a K valve set in the shallowest tubing nipple. This workscope is independent of the OA repressurization. The primary objective of this intervention is to remediate the OA repressurization. A passing MITIA to 3500 psi was performed 5/3/2009. The well passed a PPPOT-IC to 3500 psi on 3/18/16. Current Status The well is currently offline. The well is a gas lifted producer and is classified as "Operable" by BP. A K-valve will be installed prior to flowing the well. This job will be executed if the IA repressurization is not manageable by bleeds after the well is brought online. Objective Re-squeeze the OA with Well Lock to seal off IAxOA communication to gas. Procedure 1. ND OA Gate Valve, NU OA Integral. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 3000 psi per RPs. 0 0 TREE- CIW SAFETY NOTES: WELL REQUIRES A SSSV WL-FAO= TAZEVOY 127A -4-112-CHROME TOG&SCAB LW.' IACTLATOR- BAKER C - KB,EDI= 600° BF H_EV- 144 0 W333X' 2000hu 118a • '14,41 I I 2016" 1--14-112-I-ES X TAP,D=3.813" I A '= - ` .4 I 41 31 ' U Anglir- 48'.44 77exr • 4 /71 • 0. !Datum ft43= * - 10330' 4 44 11501J1711V13= WOO SS 4t,, 4: '1 9,v 20541' 1-19-5/0"FES CENIENTEB 9-518°CSC:474,L-80 WO 563 X0 TO 1-I 2018* I t-80 EiTC I - 2077" H9-515-8:33 e" 9-5/8"BOWEN CSG PATCHJ-j 2103^ 1 2367' Fig-sra-FOC I 24rn3' j-j9-5/8°FCC GAS LIFT MANDRELS [13-3/8"CSG,724,L-80.C-12.347" 11_2711'_i--4111 ST 143 TVD DEV TYPE VLV LATCH FORT DATE ..........g. 5 3014 3014 5 MAC DOW 141( 16 11/15/15 4 4890 4521 43 MG Mt/ RK 0 05/03109 3 6031 5515 44 WAG CONE FIK 16 11/15115 Minimum ID se 3.726"tg 8719' 2 7412 6537 43 MliG 004E FE 16 11/15/15 4412" HES XN NIPPLE 1 8501 7348 39 NIG SO FE 24 11/15/15 I m 8680' -14-1/2"1-ES X NIP,D.3.81r- 8611* 9-5/8*X 4-1/2'BKR 5-3 FICR.13=3_875" 1 let m I 11646' J-14-1/2"HES X MP ID 3.813:j TCP OF SCAB UNR H 117118' 8709" I-9-5/8-X r BKR C-2 TXP I.TP II M 4r 'V hr/UR LNR14014,10=6.30* ,• 14 ,.......„...._,,,,...................._-,_ N Ia 11 43/111. ]-14-1/2"HES XN 143.I)-3.725" t • 4-112.1BG,12.84,13-CR-90 VAM TOP, -i 11733" ".!, OJ •:"4 4,4 8733' 5-1/2-WLEG,4 85- OILIZ bpf,ID-3,970' Ilt, 6. XO '440.4 11739' H7"x 4-1/2.XO ID..3958° 1 ITOP Of 6-0I TIEBACK SLEEVE i NOW •.•• 4* 4 II ... tts 4" , 41 16-5/8*.X 7*SOT MC L144 HGRJ 11977 '04 •-' n 40, P 4EI P.4 0 0•• 95/8"cso,470, 80, MILLOLIT1414/400W(12-97A)9271'-9316' - 1, 1D--8.881" H 9271' I 4 __...------- 0 4 PERFORATION SUNIARY ,•4 4. 44k, SEE ion-sLa CINL/GRial,01/0111087 MCA F Ar TOP PR:c•241*6 10234/ 4.44. Note:Refer to Reduction DEI for historical perf data N7o, Ns ilk SE 1. SPF INTERVAL Op4i/Sqz DA1E r‘ii .11 Ilk 3-16" 4 10226-10252 S 05/01/00 •4 "4 . • 2-718' 6 10230-10247 0 05119/09 444• 44 10206 1---17-1AARKER.ITS (2 at 19.3'&19_51 ! ' 44 2-718. 6 10278- 10285 0 05/19/09 '• '4 2-718° 5 10334-10354 0 05119/09 44 33/8' 8 10334 10362 S 05/01/09 44 3-318' 6 10354-10373 0 05/17/09 3-3-3/8' 4 10314-10388 S 05101/09 14 I. 3.3/8" 4 10397-10406 S 05101/09 3 3/8" 1 10118 10113 6 06/01/00 4'• + % 3-318* 4 10453-11460 S 05101/09 e•11 ,••••°% 3-3/8' 4 10470-10490 S 06/01/09 • 444444), •*•••4014•N 4 s•4•",44.44er 4.1•1•44- r LRITII H 10420' lit.'4.4441'4% ..... trtot.li IN 111 104, i 4-112*SCAB LNR. 12.6*.13CR-80 YAM TOP,.0152 bpf,0 3.958" I-1 10560' 1 irk,1411:1%-44, 105743' 1D .14414414411‘ . ..„............_ 4941,4411*. I 7"LNR.,290,L-00,10371 bpf,ID.13.184* 1-1 106466' 1 tibl* • TAW REV BY couiveirs fl 'T REV SY commis ffILICHOF BAY urirr • .., 42/00/01 onto 0044ire. 112-07A 00711141 11/1C/15 A.CAIMD 130/CVO(11/1 5-115') WELL 12-07A 041211/40 LAST WORI034/ER 07114116 AM hANORINSS Errs PEFMT No: 181-1750 05/04/09 D-14 RWO 12/12/17 RIGS/AID SET FLOW11-FILI SUB w Alai GAUGI AR 50-029-20409-01 06118400 KM/I1-1-1 RA00 SQZ PEWS C1)FRECTI,M4 112118 ZVO41:4 FULLED X-LOCK w 1011 GAUGES S6 18,T1001,R15E 450 FSI.&10'FEL 09/09110 06/1,1) DRIB DRAFT CORM:TENS 12117/10 fie,JIAD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) 2 • • SOF T� gw\„\\��j��s� THE STATE Alaska Oil and Gas F� s� 7�, of A L KA Conservation Commission 333 West Seventh Avenue 2 �^ Anchorage,BILL WALKER Alaska 99501-3572 1111 OF Th Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Finn Oestgaard Production Engineer Challenger iCktl ` 16 c: BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-07A Permit to Drill Number: 181-175 Sundry Number: 318-008 Dear Mr. Oestgaard: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this/6 day of January, 2018. REDMS LL. F M - 1 2G18 O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Atter Casing 0 Other PB Valve Design 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 181-175 Address: P.O.Box 196612 Anchorage, Exploratory 0 Development 0. 3 9 AK 6. API Number 50-029-20409-01-00 . 99519-6612 Stratigraphic 0 Service 0 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Wilt planned perforations require a spacing exception? Yes 0 No IZ PBU 12-07A . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028330 • PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10570 • 9093 ' 10427 8967 10449/10450 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 41-120 41-120 1530 520 Surface 2679 13-3/8" 40-2719 40-2719 4930 2670 Intermediate 9235 9-5/8" 40-9273 40-7965 6870/8150 4760/5080 Production Liner 1791 4-1/2" 8717-10508 7517-9038 8430 7500 Liner 1599 7" 8968-10567 7719-9090 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10230-10373 8793-8919 4-1/2"x 5-1/2" 13Cr80/13Cr80 39-8741 Packers and SSSV Type: 9-5/8"x 7"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8619,7441 4-1/2"Camco TRDP-4A SSSV 2122, 2122 12.Attachments: Proposal Summary RI Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for Commencing Operations: 1/19/18 15. Well Status after proposed work: Oil I . WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Oestgaard,Finn be deviated from without prior written approval. Contact Email: Finn.Oestgaardlbp.com Authorized Name: Oestgaard,Finn Contact Phone: +1 907 564 5026 Authorized Title: Production Engineer Challenger i Authorized Signature: 0,-' Date: —1-i—I� VVV )COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: i . 6 IIInte ri Test ❑ Location Clearance Plug Integrity 0 BOP Test 0 Mechanicalg ty ❑ 9 9tY Other: E VED Post Initial Injection MIT Req'd? Yes 0 No N JAN 0 5 2018 Spacing Exception Required? Yes 0 No E Subsequent Form Required: f v -4 0 0c7-3A- a � �C APPROVED BYTHE Approved b ' �`� COMMISSIONER COMMISSION Date: 1 3Y) t) v-7—L. I/2'l'� ORIGINAL RED?JS i-',- 1' - 1 2G18 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ,(44/i Attachments in Duplicate ,ESI. l `%ig • • Ver.4 6/6/01 WOWireline Work Request 1 2-07A global wells organization Distribution Wireline(4) Well: 12-07A AFE: APBWELIRSL Reading File Date: 1/3/2018 Engineer: John Paul Kenda IOR: 50 FTS: Yes AWGRS Job Scope: SSSV Reg. H2S Level: Problem Description Install PB Valve to comply with State regulations. Well failed multiple No Flow Tests. Initial Problem Review Well relatively stable at 300 psi flowing wellhead pressure when choked back. Target this as design pressure and flow well at slightly greater flowing wellhead pressure. Remedial Plan -WIRELINE ACTION Install PB SSSV to comply with State regulations. Weatherford set PB Valve at 432 psi at 60 deg F. DSO please flow well at Wellhead Pressure greater than 300 psi. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: - (e.g. deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "PB"Valve Calculation Sheet Well: 12-07A Date: 01/03/18 Test Data Test Date 12/22/17 Gross Fluid Rate 2632 BLPD Flowing Well Head Pressure 302 psi Flowing Well Head Temperature 128 deg F GOR 1020 scf/bbl TGLR 1683 scf/bbl Design based on memory gauges installed in Well at 2016' MD X-Nipple "PB"Valve Setting Depth TVD 2016 ft Flowing Tubing Pressure With Gas Lift 512 psi Flowing Tubing Pressure Without Gas Lift NA psi Valve set to close at 300# Pwh Flowing Tubing Pressure @ 300# Pwh 512 psi DB"Valve Test Rack Set Pressure at 60 deg F 432 psi Valve Size 4-1/2" NOTE: Well needs to flow at> 300# Pwh Valve set to close at 300# Pwh • • Tubing Pressure at Valve 512 I - _ BPT(psis) 526 >1238 <1238 Temperature (deg F) at Valve 150 a 1.656E-05 0.000027486 b 1.20682 1.17406 Base Pressure 448.734426 c -550.4.3 -526.6034 Base Temp (TV-60) I 90 453.28014 443.9184623 lI _-- Corrected Pressure 443.918462 psia TCF 0.84331015 Pb @ 60 = 431.774796 T r Test Rack Pressure = 432 ___ TRS= CJtitV e SAFEIY NOTES: WELL REQUIRES A SSSV V4t3LHE.AD= MCEVOY **-4-112"CHROME TBG&SCAB LNR"' ACTUATOR= BAKER C KB.B_B/= 80.0' BF.LEIB/_ NA ► I L 2016' —I4-1/2"HES X NP,D=3.813" KOP= 3300' 20"COM) — 110' �ti N i -- Max Angie= 46"@ 7700' 11 Datum MD= 10330' • 44 ►44 Datum TVD= 8800'SS 4• �• 2068' I—9-5/8"Hes CEMENTER4� !�� 9-5/8"CSG,47#,L-80 HYD 563 XO TO H 2018' — 2077' —19-5/8"ECP PKR L-80 BTC 2367' —I9-5/8"FOC 19-5/8"BOWEN CSG PATCH —I 2103' 2493' H9-518-FOC GAS LFT MANDRELS 13_3/8"CSG,72#,L-80,D=12,347" —I 2711' 1-----4STMD ND DEV TY PE V VLV LATCH, FORT IY%TE 1-1 5 3014 3014 5 MAG DOME RK 16 11/15115 4 4690 4521 43 MG DMY RK 0 05/03/09 3 6031 5515 44 MAG DOME FE 16 11/15/15 Minimum ID =3.726" @ 8719' 2 7412 6537 43 WING DOME FE 16 11/15/15 4-1/2" HES XN NIPPLE 1 8501 7348 39 MMG SO RK 24 11/15/15 I ' 8680' —14-1/2"HES X NP,D=3.813" C. MI 8611' —9-5/8"X 4-1/2'BKR S-3 PKR D=3.875" I I-_8646' ]-14-112-1-ES X NP,D=3.813"J [TOP OF SCAB LNR I—I 8709' 1 ■ in8709' —9-5/8"X 7"BKR C-2 ZXP LTP '+ ``i w/BKR LNR HGR,D=6.30" 4 ' I? 8719' J--I4-1/2"FES XN NP,D=3.725" 44 4-1/2"TBG, 12-6#,13-CR-80 VAM TOP, H 8733' aA 11 0152 bpf,D=3.958" '4 �;i/ 8733' —I5-112"WLEG,4-85" 44 TOP OF BOT TEE33ACK SLEEVE — 8966' Op ��� .4j1{ 8739' ,—T X 4-112"XO D 3.958", 9-5/8"X 7"SOT MC LNR HGR H 897T �+ .4 1 • 9-518"CSG,47#,L 80,D=8 681" 9271' 7� ML LOUT WINDOW(12-07A)9271'-9316' l _-- �- 1r Z4 1+_ --- _ PERFORATION SUMMARY �t *4I* REQ LOG:SLB CNUGWCCL 01/01/1982 44 ANGLE AT TOP PET.28'@ 10230' \�44 " vIL Note fifer to Roductwn DB for historical perf data N4� SIZE SPF tNTE33VAL Opn/Sqz DATE v4 3-3/8" 4 10226-10252 S 05/01/09 l4 r4 2-7/8' 6 10230-10247 0 05/19/09 ft, �t10286' —r MARKER JTS (2 @ 19.3'&19.5') 2-7/8" 6 10278-10285 0 05/19/09 `4 i� 2-7/8" 6 10334- 10354 0 05/19/09 \41 '4\ 3-318' 8 10334- 10362 S 05/01/09 11 3-318" 6 10354-10373 0 05/17/09 �� 1�, 3-3/8" 4 10374- 10388 S 05/01/09 1♦1 3-3/8" 4 10397- 10406 S 05/01/09 11 3-3/8" 4 10418- 10443 S 05/01/09 11 f% 3-3/8" 4 10453- 10460 S 05/01/09 #. ff,1%\ 3-3/8" 4 10470- 10490 S 05/01/09 41 •4'14141444#)% 14141;44% FBro 10420' :4'4,44444. t., I �� — I 44$4,44•44.4k 44: .%44A4' �. 44,4:41% ( 4-1/2"SCAB LNR 12.6#,13CR-80 VAM TOP,.0152 bpf,ID=3.958" H 10600' '4,%0%. L_-„10670'J—ITD 7”LNR 29#,L-80,.0371 bpf,D=6.184" —I 10666' j ',,\tl DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UN T 12/30181 ORIG COM PL (12-07A SOTRK) 11/16/15 JLS/JMD GLV C/O(11/15/15) WELL: 12-07A 04/28/97 LAST WORKOVER 07/14/16 JMD MNOR WBS EDITS FERMT TT No: 181-1750 05/04/09 D-14 RWO 12/12/17 MGS/JMO SET FLOW TFRU SW w/MEM GAUGE AR No 50-029-20409-01 06/18/09 KNC/TLH RWO SOZ F€RFS CORRECTION 1/2/18 ZV/JMD PULLED X-LOCK w!DH GAUGES SED 18,T1ON,R15E 459'FSL&10'FE_ 09/09/10 DB/JMD DRLG DRAFT CORRECTIONS 12/17/10 MB/JMD ADDED SSSV SAFLJ Y NOTE BP Exploration(Alaska) Pict. 124y-7A Regg, James B (DOA) P11160/5'0 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, November 7, 2017 1:14 PM To: Regg, James B (DOA) g(i II(Z 1i1� Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Well Integrity Well Information Subject: Producer 12-07 (PTD#1811750) Failed No Flow Test Mr. Regg, Producer 12-07 (PTD#1811750) flow characteristics flagged a need for a no flow test. After failing the no flow test,the well is now considered capable of unassisted flow to surface. The well was left shut in and the plan forward will be: 1. Slickline: Install downhole gauges 2. Operations: POP well to gather data for SSSV design 3. Slickline: Pull downhole gauges 4. Gas Lift Engineer: K-valve design Please respond if in conflict of plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 SCANNED , I y;;: • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 31, 2016 5:21 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AKOpsProdEOCTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator;Youngmun,Alex; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey,Adrienne;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: Producer 12-07A(PTD#1811750) OA Normal Operating Limit Revised to 1,280 psi All, Producer 12-07A(PTD#1811750) now has a revised OA Normal Operating Limit(formerly MOASP)of 1280 psi. The NOL revision is via Management of Change ADW-MOC-9146,which applies to wells with OA's cemented to surface. An engineering design review of the well and wellhead system was completed and approved.A sign indicating the revised NOL has been installed. Please call or e-mail with any questions. Thanks, Adrienne McVey °Well �a, Well Integrity Superintendent—GWO Alaska ' NED Y`` �' (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegritvCoordinator@BP.com From: AK, UPT Well Integrity Sent: Sunday, October-O9; $16 4:51 PM To: AK, OPS FS1 OSM; AK, OPS F if OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AKOpsProdEOCTL; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB " ells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsite , OPS FS1 DS12 Operator; Youngmun, Alex; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, • Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'chris.wallace@alaska.gov' (chris.wallace@ala , •ov); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Stern ' Oliver R; Tempel,Troy; Worthington, Aras J Subject: OPERABLE: Producer 12-07A (PTD #1811750) OA Repressurization Manageable By Blee All, Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, October 09, 2016 4:51 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AKOpsProdEOCTL; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator;Youngmun, Alex; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras Subject: OPERABLE: Producer 12-07A (PTD #1811750) OA Repressurization Manageable By Bleeds Attachments: Producer 12-07A (PTD #1811750)TIO Plot 2016-10-09.docx All, Producer 12-07A(PTD#1811750)was reclassified Under Evaluation on 09/11/16, due to OA casing pressure above MOASP observed 2 days after the well was brought online. For the first 3 days after POP, the OA exhibited rapid repressurization after being bled to 0, but appeared to stabilize at 1100 psi. 6 days after POP, the well stabilized below MOASP, and did not require bleeding for the next 25 days. On 10/07/16,the well was shut in, and wellhead pressures monitored with wireless gauges.The shut-in OA build-up rate is approximately 150 psi/day, which is manageable by bleeds.The well is reclassified as Operable. NOTE: Although the well currently exhibits a manageable OA build-up rate (i.e. can be maintained below the current MOASP of 1000 psi with less than 2 bleeds per week) both online and shut in, BPXA is pursuing a Normal Operating Limit, aka MOASP, revision, based on the well's history of exceeding OA MOASP.The AOGCC will be informed before the operating limit is revised. Work Completed Plan Forward: 1. Downhole Diagnostics: Warm OA Repressurization Test—Completed 10/07/16, negligible OA build-up rate negligible 2. DHD: Cold OART—Completed 10/09/16, OA build-up rate —150 psi/day 3. Operations/Well Integrity Superintendent: Revise OA NOL—In Progress An updated TIO plot is attached for reference. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 • s Producer 12-07A(PTD#1811750) TIO Plot 10/09/2016 Well 12-07 t- � COO 06. 00A —a-0006 07/0416 07/16716 0772316 073016 0696116 06'13'16 0820:16 082716 040316 09'1016 041116 0926116 100116 1008'16 •• Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, September 11, 2016 11:13 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead; AKOpsProdEOCTL; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Youngmun, Alex; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO SUPT Well Integrity; McVey, Adrienne;Worthington,Jessica; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J; Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer 12-07A (PTD #1811750) OA Repressurization Rate Increased Attachments: Producer 12-07A (PTD #1811750) TIO Plot 2016-09-11.docx All, Producer 12-07A (PTD#1811750) has a cemented outer annulus, and has undergone 3 treatments since May 2015 to mitigate recurrent repressurization of the small void at the top of the OA. Most recently, the OA was treated with cement on 05/29/16.The OA pressure is stable under normal operating conditions (i.e. when the well is online and stable), but exhibits repressurization when the well is shut in, and when it is first brought back online. The well was brought online on 09/07/16, and was reported to have OA casing pressure above MOASP on 09/09/16. Confirmed pressures were TBG/IA/OA= 250/1540/1120 psi. The well is reclassified as Under Evaluation, in order to quantify the rate of repressurization at the void at the top of the OA, determine at what pressure it stabilizes, and to evaluate path forward. This may entail pursuing an increased OA MOASP via the Management of Change process,with AOGCC and Operations approval. Plan Forward: 1. Downhole Diagnostics: OA Repressurization Test—IN PROGRESS 2. Well Integrity Engineer/Superintendent: Evaluate for MoC for increased OA MOASP 3. Well Integrity Engineer: Additional diagnostics as required A TIO plot is attached for reference. Please reply if in conflict with proposed plan. SCANNED NOV 0 4 2015 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0: (907) 659-5102 C: (907) 943-0296 H: 2376 Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • i Producer 12-07A(PTD#1811750) TIO Plot 09/11/2016 Well 12-07 •V 30W —I—It 2000 +W lfN 1.000 OP e IPOSSIOWNW• r __ I I"."'I •1____11_1_ r __�__ 061116 'Mil 00;40'1:216 . . :_.. :(. OM0&1316 0&2'4 032716 03 32 Mil STATE OF ALASKA IlikLASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 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 Q Re-enter Susp Well 0 Other:OA Cement Squeeze Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-175 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20409-01-00 7. Property Designation(Lease Number): ADL 0028330 8. Well Name and Number: PBU 12-07A 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 10570 feet Plugs measured feet true vertical 9092 feet Junk measured 10449/10450 feet JUN 2 3 2016 Effective Depth: measured 10535 feet Packer measured 8717 feet true vertical 9061 feet Packer true vertical 7515.82 feet AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 41 -120 41-120 1530 520 Surface 2679 13-3/8"72#L-80 40-2719 40-2719 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet SCANNED A 4 U L True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP-4A SSV 2122 2122 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA @ Surface Treatment descriptions including volumes used and final pressure: 5.5 Gallons 14 ppg SqueezeCrete Cement,1 Bbl U67/F103 Mixture,2 Bbls Fresh Water,2.2 Gallons Hot Water/Detergent,1000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 281 561 1868 1488 214 Subsequent to operation: 321 370 1677 1533 221 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ 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 ❑ WINJ 0 WAG 0 GINJ 0 SUSP ❑ 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: 316-040 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro)"—<-:— /� Title PDC Principal Engineer Signature 4 G� ` Phone +1 907 564 4424 Date 6/23/16 Form 10-404 Revised 5/2015 VTL 1 O/-9-pc, RBDMS �U JUN Z 4 2016 /044 Submit Original Only • a) • 0• 0 0 0 0 0 0 0 0 0 co N O a Cr. O O C6) O N CL 00 CO Ln O N N Nr O V In LL) I- N- N- (.)U y 0 0 0 0 0 0 0 0 0 0 L CO CO f- LO I- Ln co co M • LU Cr) CO — CO V N- m ' V CO CO CC) LU CO CO CO 1"-- © O O) — N. 0) CO I- C)) N LO N ,- O N CO M CO M M CO CO CA O O LO Lf) N N N N- N O) 0) I- N CI I H C7O I� CA CO CO N L O O o 0 N r- 6) CO V V V CO CO L0 N- CO LL) N N I. Q> CAS � MO � CO ,- ELs) In O co L— CO r CV In N- N- N N N CA 0) O O CO CO c.) o a oC7ON- N- N- CO CO 00000 '- COrnC �! �t N- CO N- CS) M N- =N N N 0) CO CO CO r • • W LU LU O O r Q. OO Cb OOp O � o oo0ao00 O - J - O i O nn M •(i) N N. 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O 0 c .2 Nu_ NLLu_ LLu NNNNN m 0a00_ n- 0_ 0- 00000 a U) Q U) Q Q Q Q U) co co co co O a) a m H is 0) 0) 03 0) 0 0 0 o CD C:) 00 °) 0 °) °) °) 0 0 O • 0 0 0 0 0 0 0 0 0 0 0 0 W O W Z 0 c c 0 a W N N N N N N N N N N N N O W p W N W U) in Ln Lf) Ln Z W LJ U �W W LL W Lo Lf) Lr) L() Ln Lf) Lo a 0 J H J J J ct a. O Q 0 d (f) W W Lai d W W m CC E Q Q Q Q Q Q Q Q Q Q Q Q 000CD cp cp 000a cn o W NLL N CV N CV N N N CV N N CV CV ma. O_ O_ U J O O W 0_ = = = = = = < a CO m LL U V) i • Packers and SSV's Attachment PBU 12-07A SW Name Type MD TVD Depscription 12-07A PACKER 2084.17 2084.17 9-5/8" BOT External CSG PKR 12-07A SSSV 2122.32 2122.32 4-1/2" Camco TRDP-4A SSV 12-07A TBG PACKER 8716.97 7515.82 7" Baker ZXP PKR/HGR • • ii Co m a a c )_ c c 0 (n Qm _0 s� v • co a) -a L 3 ° 3 in 'in ai a) a) •�' 't - a) �U°`` cru _c u) c a) O0 in o �° 0- ..: tq N O a 0 O o V to to ° 4. (E a) Ndr, N_ > a a °c o O o o a) o 0C = C(atm � L 0 m O -o Q ° ° cm � � u) 3 _i . 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II @ .� Q I O (0Q II Q II O L Q IQm Q II Q Q II rnQ n Q Q c ami 0 E � cO NO E � O � � QUO QO � � 0 � a0 >+ H • d L O II H Q a) II H N II H a N II H < CO \O II o II co II II o Lco oO03 �2 o U rn o �� o rn o M a o C U co •S •* U N Q U c.v. p (0 V O ` p 6 U) 0 0 U) 0 0 U) p 11 > (� Q N II 10 a)co II I() 0 II C -0 II Lf) • O (O �' N U) p U) p N p C (/) .c D 3 > > @ n >cn j • > 8 > > o 11 m c r) c if) U) a (II co U) U) U c-U) U) N U) U) (o ° U) N E d o cn oM 0 O 2 U) (0 C f0 - cn o a) U) U) N a) N T c O = N H N H N U) .0 a) 0 5 II Z y u rn II c II c O 0 Ii j 0 n > U II > 0 O () E o > O ^o O vCCC > Oa *. ; O c c � � 0U I QU � 0U � HZO 0U) H 0 U)) U>) I`- c0icn � QLnOnH000LEcn HUcn F= )cnHU(n 0 0 0 00 0 0 0 0 N N N N V Lc.) (0 C) CO r r ,- i •- r (O CO CO CO p s • O E as Ea) CL (0 >' O < -g ti 7 9 LL N w r O M CO O a a a) a) p 22 2)a) m a� N X N U)o co °' CO 0_ -C a� u) v co m o D U_ (n CO LO u) m o - o TTS= CM/ S NOTES: WELL REQUIRES A SSSV NELLI-EAD= MCEVOY 2 f 7A "4-1/2'CHROME TBG&SCAB LNR"' UA ACTTOR= BAKER C KB.ELEV= 80.0' BF ELEV= NA KOP= 3300' 20"CON) -1 110' 11 ' ' 44 t 2016' —(4-1/2•HES X IMP,D=3.813" Max Angle= 46°@ 7700' 14 44 [ tum MD= 10330' �� 4• 2058' 9-5/8'FES CEMENTER Datum TVD= 8800'SS �4 �� ii 9-5/8"CSG,47#,L-80 XO TO L-80 BTC H 2018' 2077' 9-5/8"ECP PKR 9-5/8"BOWEN CSG PATCH —{ 2103' 'F 2367' H9-5/8"FOC — 2493' —I9-5/8'FOC GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.34r — 2711' , ST MD ND DEV TYPE VLV LATCH FORT DATE L 5 3014 3014 5 MMG DOME RK 16 11/15/15 4 4690 4521 43 MING DMY RK 0 05/03/09 Minimum ID =3.725" @ 8719' 3 6031 5515 44 MMG DOPE RK 16 11/15/15 2 7412 6537 43 WAG DOME RF( 16 11/15/15 4-1/2" HES XN NIPPLE 1 8501 7348 39 MMG SO RK 24 11/15/15 I ' 8580' —14-1/2"FEs X ' D=3.813" Z 8611' —19-58"X 4-1/2'BKR S-3 PKR,D=3.875" ' i 8646' H4-1/2"I-ES X MP D=3.813" TOP OF SCAB LM —1 8709' 8709' —9-5/8"X 7"BKR C-2 ZXP LIP •, 1 w/BKR LNR HGR,D=6.30" ' �4 8719' H4-1/2-FES XN NP,D=3.725' 4-1/2'TBG,12.6#,13-CR-80 VAM TOP, H 8733' AvI4 1r4 1' 8733' _H5-1/2"VVLEG,4.85" D .0152 bpf, =3.958" 'f' 'it TOP OF BOT TEBACK SLEEVE --1 8966' 4+4 41 8739' —{7"X 4 1/2"XO,D=3.958" *4 4t 9-5/8"X 7'BOT MC LNR HGR —( 8972' `44 0 1 44 t 4� 9-5/8"CSG,47#,L-80,D=8.681' H 271' I '4 44 MLLOUT WINDOW(12-07A)9271'-9316' PERFORATION S11AAAARY 4 X44 REF LOG:SLB CNUGR/(XL.01/01/1982 \,4 •� ANGLE AT TOP FBF:28°6 10230' ��•' Note:Feer to R'oduction DB for historical pert data _ '4 •� SIZE SPF INTERVAL Opn/Sgz DATE ��4 3-3/8" 4 10226-10252 S 05/01/09 Pi• 2-7/8" 6 10230-10247 0 05/19/09 `'•• ��$ 2-7/8" 6 10278 10285 0 05/19/09 `\!4 •i 10285' H7"MARKERJTS (2 @ 19.3'&19.5') 2-7/8" 6 10334-10354 0 05/19/09 `.44 44 3-3/8" 8 10334-10362 S 05/01/09 1• 3-3/8" 6 10354-10373 0 05/17/09 4 3-3/8' 4 10374-10388 S 05/01/09 444Ilk 3-3/8" 4 10397-10406 S 05/01/09 444 3-3/8" 4 10418-10443 S 05/01/09 44 3-3/8" 4 10453-10460 S 05/01/09 44 ,��, 3-3/8" 4 10470-10490 S 05/01/09 44 I•`4•444�V� 44 1.444444444.44 44%4:4.'a4 t% PBTD H 10420' v414.4444.41r4•�+: 4 4-1/2"SCAB LNR,12.6#,13CR-80 VAM TOP,.0152 bpi,D=3.958' 10500' ..,;4114,*� 10570' H1 7"LM ,29#,L-80,.0371 bpf,D=6.184' H 10565' 10' DATE REV BY COMvUJTS DATE REV BY COMMENTS PROD 4DE BAY LINT 12/30/81 ORIG COM PL (12-07A SDTRIC) 11/16/15 JLS/JM)GLV GO(11/15/15) WELL: 12-07A 04/28/97 LAST WORKOVB2 PERMIT No: 181-1750 05/04/09 D-14 RWO API No: 50-029-20409-01 06/18/09 KNCJTLH RWO SQZ PERES CORRECTI0N SEC 18,T10N,R15E 459'FSL&10'FE. 09/09/10 DB/.IA) DRLG DRAFT CORRECTIONS 12/17/10 PB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday,June 14, 2016 8:04 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator;Youngmun,Alex; Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey,Adrienne; Sayers,Jessica;Wallace, Chris D (DOA); 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 12-07A(PTD#1811750) OA Downsqueeze Re-Treat Complete All, Producer 12-07A(PTD#1811750) underwent a second OA cement down-squeeze on 05/29/16.The cement has had 15 days to cure. The well is reclassified as Under Evaluation, and should be brought online and monitored in order to evaluate the efficacy of the OA treatment. Work Completed/Plan Forward: 1. DHD: Prep OA, Bled IA, Pump Squeezecrete–DONE 05/29/16 2. DHD: Monitor for 7 days–DONE 06/05/16 3.Wait on cement for 14 days–DONE 06/12/16 4. OPS: POP Under Evaluation 5. DHD: Assist Operations with POP Use caution when bringing the well online, paying special attention to the OA. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey a.9; 7 Well Integrity Superintendent–GWO Alaska SCO ° JAN 0 b -�� (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, April 13, 2016 7:02 PT? —___ To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS-FSI Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, April 13, 2016 7:02 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Munk, Corey; Odom, Kristine; Regg,James B (DOA) Subject: NOT OPERABLE: Producer 12-07A (PTD #1811750) OA down squeeze complete All, Producer 12-07A (PTD #1811750) was recently treated with an outer annulus down squeeze in order to mitigate outer annulus repressurization. The outer annulus repressurization remains unmanageable by bleeds post treatment. The well has been reclassified as Not Operable until further repair diagnostics can be performed. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator APR 1 g 2016 Global Wells 50014 Gt Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AlC, D&C Well Integrity Coordinator Sent: Wednesdays April 06, 2016 6:45 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK,\D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A—;--Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects W II Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Morrison, -Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: UPDATE April 06, 2016: UNDER EVALUATION: Producer 12-07A (PTD/181-1. 0) OA down squeeze complete All, Producer 12-07A(PTD#1811750) had wireless gauges installed on April 04, 2016 to enable remote pressure reading capabilities prior to well shut in. As the well has had insufficient monitor time following shut in to evaluate if the recent outer annulus (OA) squeeze was successful in mitigating OA pressure previously found to be unmanageable by bleeds, 1 - i • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, April 06, 2016 6:45 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: UPDATE April 06, 2016: UNDER EVALUATION: Producer 12-07A (PTD #1811750) OA down squeeze complete All, Producer 12-07A (PTD#1811750) had wireless gauges installed on April 04, 2016 to enable remote pressure reading capabilities prior to well shut in. As the well has had insufficient monitor time following shut in to evaluate if the recent outer annulus (OA) squeeze was successful in mitigating OA pressure previously found to be unmanageable by bleeds, the Under Evaluation clock has been extended another 7 days to allow for further observation. The well will remain classified as Under Evaluation and is to remain shut in until diagnostics are complete. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend and obtaining well tests. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Plan Forward: 1. Operations: Bring well online—DONE 03/09/16 2. Downhole Diagnostics: Monitor well daily—DONE 3. Special Projects: Treat OA—DONE 03/11/16 4. Downhole Diagnostics: Monitor well during treatment cure period - DONE 5. Operations: SI well follow wireless gauge install—DONE 04/04/16 6. Downhole Diagnostics: OA pressure for 3 to 5 days—IN PROGRESS 7. Well Integrity Engineer: Additional diagnostics as needed Please call any questions or concerns. Thank you, APR 2 1206 Whitney Pettus (Alternate:Kevin Parks) BP Alaska/ s -Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Pfcti !Z Pm Jet 17. Regg, James B (DOA) From: Regg,James B (DOA) 6r (` 31151n,1�I/` Sent: Monday, March 14, 2016 7:09 PM � To: AK, OPS FF Well Ops Comp Rep; DOA AOGCC Prudhoe Bay Cc: Cocklan-vendl, Mary E;AK, D&C Well Integrity Coordinator;AK, OPS FS]. DS Ops Lead; AK, OPS FS1 Field OTL Subject: RE: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment Not sure how I missed this. Someone should have called (793-1236). The test can be delayed until the cement has cured. Sent from nm). Samsung Galaxy smartphone. SCANNED SEP 2 12016 Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep@bp.com> Date: 03/14/2016 6:42 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: "Cocklan-vendl, Mary E" <mary.cocklan-vendl@bp.com>, "AK, D&C Well Integrity Coordinator" <AKDCWellIntegrityCoordinator@bp.com>, "AK, OPS FS1 DS Ops Lead" <AKOPSFS1DSOpsLead@bp.com>, "AK, OPS FS1 Field OTL" <AK_OPSFSIFieldOTL@bp.com>, "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep@bp.com> Subject: RE: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep@bp.com> Date: 03/14/2016 6:42 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: "Cocklan-vendl, Mary E" <mary.cocklan-vendl@bp.com>, "AK, D&C Well Integrity Coordinator" <AKDCWellIntegrityCoordinator@bp.com>, "AK, OPS FS1 DS Ops Lead" <AKOPSFS1DSOpsLead@bp.com>, "AK, OPS FS1 Field OTL" <AK_OPSFS1FieldOTL@bp.com>, "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep@bp.com> Subject: RE: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment Johnny, I have not heard back from Jim or any of the Inspectors on our request. Please submit a request to test the well prior to the 3-5 day SI period for monitoring in step 5 below. I think I was told that there 1 was a 7 daycureperiod for th•cement, provided that is the time designated that would mean the well would be SI on 3/16 and the request to the AOGCC should be turned in tomorrow. Whitney, If I am wrong on the 7 days and it is longer, please advise, so Johnny can adjust the request to test. Thanks Lee From: AK, OPS FF Well Ops Comp Rep Sent: Saturday, March 12, 2016 10:51 AM To: Regg, James B (DOA); aogcc.inspectors@alaska.gov Cc: AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E; AK, D&C Well Integrity Coordinator; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OTL Subject: FW: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment Mr. Regg, Well 12-07A is due for a performance test since it missed the routine test month of January. It was last tested 10/16/15. Are you okay with this well not being tested within 5 days of stabilized flow while the cement cures? There is concern with the disruption of the flowing conditions until the cement is fully set. We can test the well after the cure time and then shut it in to monitor as described in step 5 below? Please advise. Thank you, Lee Hulme FF Well Ops Compliance Advisor BP Exploration (Alaska) Inc. 2 • Office: (907) 659-5332 Cell: (907) 229-5795 Harmony— 7187 (Alternate: Vince Pokryfki) From: AK, D&C Well Integrity Coordinator Sent: Saturday, March 12, 2016 10:40 AM To: AK, OPS FF Well Ops Comp Rep Subject: FW: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment FYI From: AK, D&C Well Integrity Coordinator Sent: Wednesday, March 09, 2016 10:15 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment All, Producer 12-07A(PTD#1811750) is now ready to be placed online.The well has been reclassified as Under Evaluation to help facilitate a warm treatment of the outer annulus(OA) which was previously found to be unmanageable by bleeds. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend and obtaining well tests. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Plan Forward: 1. Operations: Bring well online 3 • . 2. Downhole Diagnostics: Monitor well daily 3. Special Projects: Treat OA 4. Downhole Diagnostics: Monitor well during treatment cure period 5. Downhole Diagnostics: SI well and monitor OA pressure for 3 to 5 days 6. Well Integrity Engineer: Additional diagnostics as needed Please call any questions or concerns. Thank you, Whitney Pettus (atlt'rnute: Kevin t'arko BP Alaska-Well Integrity Coordinator "lam v4eI Nka r E at c€7 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, February 11, 2016 10:16 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Oper- ons Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB .st Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 0,-rator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; , OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, Jay-s B (DOA) (iim.regg@alaska.gov) Subject: NOT OPERABLE: Producer 12-07A (PTD #1811750) Sustained Out- nnulus Pressure Unmanageable by bleeds All, Producer 12-07A (PTD# 1811750) high o -r annulus pressure was unable to mitigated via well cycling and managed open bleeds. At this time, the well ha seen reclassified as Not Operable until additional wellwork can be performed. The well is currently shut in, and annuli pressures will be bled down in the interim. Please call with . y questions. `� 4 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, March 09, 2016 10:15 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Place online for Well-lock Treatment All, Producer 12-07A(PTD#1811750) is now ready to be placed online.The well has been reclassified as Under Evaluation to help facilitate a warm treatment of the outer annulus(OA) which was previously found to be unmanageable by bleeds. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend and obtaining well tests. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Plan Forward: 1. Operations: Bring well online 2. Downhole Diagnostics: Monitor well daily 3. Special Projects:Treat OA 4. Downhole Diagnostics: Monitor well during treatment cure period 5. Downhole Diagnostics: SI well and monitor OA pressure for 3 to 5 days 6. Well Integrity Engineer: Additional diagnostics as needed Please call any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED MAR 1 5 2016 BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coo or Sent: Thursday, February 11, 2016 10:16 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Fief OTL AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent;.AK, D&C Wireline Operations 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, February 11, 2016 10:16 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; Wallace, Chris D (DOA) Cc: 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; Sayers,Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: NOT OPERABLE: Producer 12-07A (PTD #1811750) Sustained Outer Annulus Pressure Unmanageable by bleeds All, Producer 12-07A(PTD# 1811750) high outer annulus pressure was unable to mitigated via well cycling and managed open bleeds. At this time, the well has been reclassified as Not Operable until additional wellwork can be performed. The well is currently shut in, and the annuli pressures will be bled down in the interim. Please call with any questions. Thank you, Laurie Climer (Filling in for Whitney Pettus) BP Alaska-Well Integrity Coordinator G' 6.0:k1 Vvefls Organizatton WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, Well Integrity Coordinator Sent: Friday, January 15, 2016 7:10 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, Q&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; I, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Con ers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD We tegrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spar; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov); Pettus, Whitney Subject: UNDER EVALUATION: Producer 12-07A (PTD #1811750) Sustained`MrtetAnnulus Pressure Unmanageable by bleeds "yM^ 1 • • OF 7w, ywPIy/ s THE STATE Alaska Oil and Gas N .,'s''d`-•a7,4� °fALASKA Conservation Commission lttz 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w Main: 907.279.1433 ALAS io-V .* Fax: 907.276.7542 February 9, 2016 www.aogcc.alaska.gov Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification PBU 1 - ` PTD 1811750 Dear Ms. Cocklan-Vendl: On December 27, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-07A. This test was triggered by indications that the well may have the ability to flow unassisted to surface. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-07A. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, the well demonstrated 6 psi tubing and 93 psi tubing-casing annulus pressures and no flow of gas or liquids at surface. Within 4 minutes pressures declined and stabilized at 0 psi for the tubing and the tubing- casing annulus remained unchanged with no flow of liquid or gas. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-07A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDC We IllntegrityCoordinator(a,bp.com Ryan Daniel, BPXA ti OF • • w�'�. I%%i�s THE STATE Alaska Oil and Gas " "�14 OfA LAsKA. Conservation Commission /14, � = 333 West Seventh Avenue ,_ , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w,h Main: 907.279.1433 OFALAS� Fax: 907.276.7542 WWW.aogcc.alaska.gov Jessica Sayers r Well Integrity Engineer I BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 SCANNED FEE?ti 1 6 20- Re: 0(Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU 12-07A Permit to Drill Number: 181-175 Sundry Number: 316-040 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this 2]Sday of January, 2016. fir'' RBDMS JAN 2 5 2016 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate U Repair Well RI • Operations shutdown 0 Suspend 0 Perforate o Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cmt Sqz OA m 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 181-175 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0, 99519-6612 Stratigraphic U Service ❑ 6. API Number: 50-029-20409-01-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No RI PBU 12-07A il EC E V D 9. Property Designation(Lease Number): 10. Field/Pools: ( 2.1 ADL 0028330 • PRUDHOE BAY,PRUDHOE OIL - JAN 2 2U 16 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): J rAgOC / 10570 , 9092 • 10535 9061 10449/10450 Casing Length 9 Size MD TVD Burst Collapse Structural Conductor 79 20"94#1-1-40 41 -120 41-120 1530 520 Surface 2679 13-3/8"72#L-80 40-2719 40-2719 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"Camco TRDP-4A SSV 2122, 2122 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program RI BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development H . Service 0 14.Estimated Date for Commencing Operations: 2/3/16 15. Well Status after proposed work: Oil m • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sayers,Jessica be deviated from without prior written approval. Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica / Title Well Integrity Engineer fif Signature / ��.✓' (d/ Phone +1 907 564 4281 Date I A\ COMMI SSION USE ONLY l"---- Conditions of approv I:N tify Commission so thata•representative may witness Sundry Number L( Integrity �,�^ 4 `C) Plug e9 ty 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No L( Subsequent Form Required: /0- 4 0 4 Approved by: t90_,L.,01/,—..._— APPROVED BYTHE COMMISSIONER COMMISSION Date: l—2/.76 v r 1/z1 //‘„ ORIGINAL RBDMS L L I it-l" ! 5 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate / L'=,%.>' • d mc, o (0 0 0 0 0 0 0 0 0 m N N CO M CO M O N O M M — LOCC01,- 01,- 01.00LONN C N 'tM V Lt) N- N- N- (O CO U vg 0 0 0 0 0 0 0 0 0 0 0 L co CO N- Cn N- CC) CO CO CO CO v- CO CO CO CO CO M CO N- p CA r f� O) Cr) N CO LO r- O N CO M CO CO CO CO CO CO O O O CO CO tO N N N 1,- 01 I I I I I I 1 I 1 1 CD N. O) CO M ON V 'Y cf' r- M CO 10 N- M Cf) Cf) 0 d) •— O O Io O (or"- co co N f� M o Cn Cn M M v N N N O M O O M CC0 CSO U 0 Qi i I i i i i i I i Q O O 2 ti O M 8 O 8 O � M MM M C N 'crN NO) rc'os. c CO MM _ r mn mm M WO oComoo O 0 oo °' O LMM a) M (5W0MpMUU J Q J 0 T- M A- M M = G> = 4k 4:k N *W *k (n J � � fn C� • - CO CO - Co N c O Cn C 0 C(1 -00 I,. N N 07) Cn o M r r a) O 4 4 Cf) Cf) .c 4- O O O V- C)) 0) Q m N- N- - O CD O CA CA C N- COO p M M N- CC) CO M M C) W W W W _Q _Q _Q _Q _ W 0 0 0 0 •y U U W W W W U o u_ X W ctctc Z Z Z ZtUWWWWWmmm O O Z Z Z Z Z Z_ 0 0 0 d h m• N OO 00 M W 00 N M r N O � pN- ? � CD O r 0 00 CO• C00 CO CO OD 00 CD OD CC)CD O O G O r- N co O I V N CO 00 N M . d• C) CO r r N- O (O If) LU M ' 00 o N- f- 00 00 Cn C) O C) C) O C) O > 00 M M 00 M 00 00 CO CO OD 00 d) 0 2 O O• 0 W Z H H Om J W N g g 5 U O > �a O O Q Y Y O 4.4 L M LU O LO CO N- 00 O VY COO J J J (n W W mm_ (N r 0r O OOMUj 071 O00000 U0WW _, Jr . rrrr Z _ ZO c d = = = z ‹ ..00 o r o 2 0 0 0 W Z o Z VW W W 22 2Ocnv~i (¢n (Jn va) (1) N- 0 Q a N 12 C -c CO CD f- M N ti 00 CO CD p_ N M stfes- M LU CO N- O r lO f,- O /Myt 0 0 0 O O O o O o O O O O W r r r r r r r r r r r r teaW 2 2 2 O u) (n cn to d O U c ° Nu_ NILlililiNNNNN a C3 d C3 a a a Q C3 C3 C3 CI CI a U) Q U) Q Q Q Q U) U) U) U) U) 0 m 0 d M M M M M rn rn rn rn rn rn rn rn 0 0 0 0 0 0 0 0 o 0 c O O O O O O O O O O O O W ONNNNNNNW Z 0 0 0 0 0 Q W mO) W N N N N N OZ W 0 W N W r _r r r r r Z 0_ '--1 W CC ll7 Ln In Q o J f- J J J Q a. OCn o D W < < W W u u U W MCC 0 E a N- N- N- ti ¢ ¢ ti N- N- N- Nx00000000000 LL CL cn O N tr W N N N N N N N N N N N N m a W W o J 0 0 w0 r r r r r r r r r r r r < < CCl 03 LL LL. NC/) 11 CY • • Packers and SSV's Attachment ADL0028330 SW Name Type MD TVD Depscription 12-07A PACKER 2084.17 2084.17 9-5/8" BOT External CSG PKR 12-07A SSSV 2122.32 2122.32 4-1/2"Camco TRDP-4A SSV 12-07A TBG PACKER 8716.97 7515.82 7" Baker ZXP PKR/HGR • • 04, Date: 01-20-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 12-07 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, MicroOA squeeze repair treatment with SqueezeCrete. This well exhibits high OA pressure when on-line. The well was previously treated with WeIlLock and was able to have manageable pressure when on-line until recently, in the last month. ,Well Detail Current Status: Under Evaluation Integrity Issues: Fully cemented OA; Has had previous WeIlLock treatment; Well rides the pressure limit when well is on-line Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 10/23/13: OA LLR 0.042 gpm @ 2500 psi > 05/11/15: OA treated w/Well-lock > 10/24/15: AOGCC NFT Passed witnessed by Lou Grimaldi > 11/15/15: Set DGLVs in sta#2, 3 & 5, set OGLV in sta #1 > 12/17/15: NFT Passed > 12/27/15: AOGCC NFT Passed 1 of 3 ! • Procedure: 1 D Strap TOC/WeIlLock in OA 2 D Place, Squeezecrete in OA, until clean, 11 SqueezeCrete returns are observed. Take returns to a grounded bucket. 3 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max), bump pressure three times 4 D Let well cure, POP under evaluation. 2 of 3 • • . • 11REE= CM/ SAFETY MOTES- WELL REQUIRES A SSSV 411:11.14EAD= MCEVOY •••411-112"CIPIROME TTIG A SC AS 1 912''' ACRIVICIR I, BARBI 12-07A .51F.REV A pa 33°0 110 i ''.• ; 2016' 144-1,0W HES X 6111,,67 " 103P= ' wittiia . 4 i 1.4 • Mix Anph,= 46'(I 770W •• •• 103 „..,•: V DmIxoniEs= 3D .... 2066' -filmy.I-Es cake.riiiii .0086 icrei------corio•Vs 41 4. X• El-W-CSG,471,L-S0 X6--701:970 MC arni- .... 21117T 9-501--L7F-SCPR4341 _ ..„.... ,.9 5113*GOWN CSfCIATC...._LII -I 2103' 1---- - 231r 96-FOC 31ST 1-F-512rFOZ1 GAS LEI W140115 1 13-31r CSG,724,1.10O.12_3477 - i-7-4171 r ST 1143 IVO MI TYPE VW'LATCH PORT TATE 5 3014 3014, 5 146G COME RK 16 11/15715 4 4690 4521 43 FAG OW Fs( 0 05/03.439 3 8031 5515, 44 PING COME FK 16 11/15/15 Minimum ID 7=3.725 (" 8719' 2 7412 6537 i 43 kii.iu now FE 16 11115/15 4Al2"HES XN NIPPLE 1 8501 1'3461 39 klite, SO - FK 24 11115/15 il I MC? I-44/2'HES X kr,ID=3.81r 1 gai 1' 11-51.7 X 4-1/7 DKR 33 RR 13=3.677 1 Col 11.11 mar ..-- L1LOP OF SCAB Oft 1--171-701r • a , wow I-9-sir x r stiftc-2 zxP cm I ........_ it w/DKR LAR NCR.13-6_30' 1 I 6 6, • 11.! y -----nsily-1---F-767'Pas X3419R O.3725'I 4-1/2"RIG,1260 R- . ,13-C110 VARA TOP, Mai= 0, . 6 11733' ri.6:202'IALEG_Allir .0152 bpi,ID,.3,95Ir ON, - ---- , 94,1 y Acxs ------,i 626r 7'X 4-11W il--1----ibesr TCP OF sorTiP3as ___}.-- 4 _.......__ er 14-5,6-x r Bur mc LIAR MR H- 8972* j' 4,4$ i, .41 ki a g x . • 4r 9-5/r CSO.47111 L-S0 In.8.681- -,71^ .4 114 ------- MELOUT AINDOVY412-07A4 927 I'-9316- ,i• •- PB;FORAIEN SLIWIARrf 41; • to FIEF LOO:ELS CPLIGIK731.0170171E62 ANGLEAT TOP PEAF:26'6 102317 Po 0421e Refer lo Rot ,OB for historical Fell data 114, * SEE 'SF1F PITERVAL OpnfSqi OATE ro 1-36r 4 10225.10252 S 0E001000 \ 4 2-rtr e lam lam' 0 05/1009 2-7Ir ei icon-10265 0, 06/1600 ' '4, FT442-irp 1 r MARKER JTS(2 0 10.3'8 10.5) 01. 2-7/W 6 10334-1E054 0 0501800 Isi 1. 3-316' 8 10334 10312 S 06/011170 Ii• 111' 3-3103' 13 10364 10373 0 06/170020 • 3-3.6* 4 10374-10368 S 05701,00 446 1111 3-3.6' 4 10307•,10406 S 05/0101 • 3-36' 4 10118-10443 S 050103 • GO 1 3-3.0' 4 10453-10460 S 050169 4 3-376" 4 10470-10400 S 0501709 .4 0-414 4441\ 41,414,4401,4,41% II'111;,411,6 0.44,o *i694.41 •0: "3/D[1 14424-3-]. ----- VA 14114470 14, 4-112'SCAB LW.12.66 1=640 VAA1 TOR 0l521ç4 ID.SS ' 10604r- -01141%01,1%. lam Ej '41401!"' ruaq,2914.L-80,43371 bpf,13=sior 047E REV BY C01,07ERTS CAM FILV BY I COMENTS 41.D40E MY 1.11611 maim, OM 0061Pl. I 12-07A 60TRI9 11/16/15.11' ' CAA/00(itin50/5) KUL 12-07A mug LAST WOFICOVER FiErogr Mx 161-1750 0104105 1114 R//0 AR 6). 504J21120400•01 06018/09-KNCM_74101050 SOZ FERPS CORRECTOR SEC 18,TION,R15E 45W FSL 4 10.FEL 09009/10 COMO CRLG DRAFT CORRECTIONS -12/17/10 NE11.1610 AGOE0 SSW SAFETY NOTE HP13qpicumtI5n(Auk. 3 of 3 • 110 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, January 15, 2016 7:10 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL; AK, OPS PCC Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard;Wallace, Chris D (DOA) 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; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA); Pettus, Whitney Subject: UNDER EVALUATION: Producer 12-07A (PTD#1811750) Sustained Outer Annulus Pressure Unmanageable by bleeds Attachments: Producer 12-07A (PTD #1811750) TIO Plot.docx All, Producer 12-07A (PTD#1811750)was reported to have sustained outer annulus (OA) casing pressure above MOASP on January 13, 2016. Operations reported the OA pressure to be 1800 psi on January 13, 2016. The pressures were confirmed to be TBG/IA/OA= 2060/2000/1960 psi on January 14, 2016 despite the OA having been bled several times throughout the two day period. As this time,the well has been reclassified as Under Evaluation as the OA no longer appears manageable by bleeds. Plan Forward: 1. Downhole Diagnostics: Hold open bleed on OA 2. Well Integrity Engineer: Evaluate for Well-lock re-treat 3. 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. ,, %WED JUN 0 2 2016 Thank you, Whitney Pettus (AItern ate: Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, October 12, 2015 9:02 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS F d-OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC 1 • • Producer 12-07A(PTD#1811750) TIO Plot January 15, 2016 1,17 21 OA 10155 10'215 101915 11915 111215 1.t, •'2S1, 1241,5 121015 121i< �� ,.. 122115 ,2?�15 ^."15 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � � IZh,I'IS DATE: 12/27/15 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU 12-07A BPXA - PTD 1811750 Sunday, December 27, 2015: I witnessed the No Flow verification for BP Exploration's well PBU DS12-07A in the Prudhoe Bay Unit. I met Ryan Holt (BP well integrity engineer) on location for the test. Mr. Holt explained that the gas-to-liquid ratio had —' increased calling for another No-Flow test. I monitored the well pressure build-up for 3 hours then had them open the well to an atmospheric tank to determine the time to discharge pressure. Note that the time column is in chronological order. There was no flow observed from the well in the open top tank. The following table shows test details: Pressures Flow Rate Time Remarks (psi) Gas - scf/hr Liquid - gal/hr 3:05 6/93/650 0 - 0 Open tbg to tank block valve 3:06 3/93/650 0 0 - Venting tbg to tank 3:07 3/93/650 0 - 0 Venting tbg to tank 3:08 3/93/650 0 0 No flow observed 3:09 0/93/650 0 • 0 No flow observed 3:10 0/93/650 0 0 Shut in tank block valve 3:11 0/93/650 0 - 0 No psi buildup observed 3:12 0/93/650 0 0 No psi buildup observed 3:13 0/93/650 0 0 No psi buildup observed 3:14 0/93/650 0 0 No psi buildup observed 3:15 0/93/650 0 0 Conclude test 1 Pressures are T/IA/OA Summary: I witnessed the no-flow test for BPXA well PBU 12-07A. It meets the criteria set forth for this type of test. Attachments: none ` CARNE 2015-1227_No-Flow_PBU_12-07A_lg.docx Page 1 of 1 T�� • w �w�@®F\I%i�s� THE STATE Alaska Oil and Gas ®fA LAsKAL Conservation Commission x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS r' Fax: 907.276 7542 www.aogcc.alaska.gov October 30, 2015 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O.Box 196612 Anchorage, AK 99519-6612 RE: No-Flow Verification PBU 12-07A 5GANNE° PTD 1811750 Dear Ms. Cocklan-Vendl: On October 24, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-07A. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-07A. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, the well demonstrated 5 psi tubing and tubing-casing annulus pressures and an unmeasurable flow of gas. Within 3 minutes pressures declined and stabilized at 1 psi for the tubing and 4 psi for the tubing- casing annulus with no flow of liquid or gas. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-07A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, -,aitti46 b . James B. Regg ( , Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFF Wel IOpsCompRep@bp.com AKDC WelllntegrityCoordinator@bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � ' I DATE: Sunday, October 25, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector PBU 12-07A BP Exploration Inc. PTD #1811750 Saturday, October 24, 2015: I witnessed the No Flow verification for BP Exploration's well PBU 12-07A in the Prudhoe Bay Unit. I met Beau Obrigewitch (BP well integrity . engineer) on location for the test. The details are contained in the table below. Note that the time column is in chronological order. The Tubing reading of 1 psi was due to hydrostatic pressure applied by the hydraulic fluid in hose strung from the wellhead above the gauge. There was no flow observed from the well in the open top tank. The following table shows test details: Time Pressures1 Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 0:00 1/3/320 0 0 Start recorder 10:40 A.M. 0:01 1/3/320 S/I S/I Shut Tubing to tank block valve. 3:00 5/5/320 -- _ Open tubing to tank block valve 3:01 2/5/320 -- -- Venting tubing to tank 3:02 2/5/320 -- -- Venting tubing to tank 3:03 1/4/320 -- -- No flow observed 3:04 1/4/320 -- -- No flow observed 3:05 1/4/320 S/I S/I No flow observed, S/I block valve 3:06 1/4/320 S/I S/I No buildup observed. 1 Pressures are T/IA/OA Summary: I witnessed the No Flow test for BPX well PBU 12-07A in the Prudhoe Bay Field. It meets the criteria set forth for this type test. Attachments: Test Data SCONED JUL 1 8 2010. 2015-1024_No-Flow_PBU_12-07A_lg.docx Mo -4- 'rec, -- Data Collection Report Chassis Left Scale Right Scale Serial Number 072717 073121 073105 Datatype Lower Upper Units PSI G PSI G Lower Upper DS12-07 NFT test 10-24-15 10 - — 10 9 — — — 9 8 - 8 7 - 7 6 - III 6 4 - all II 4 J - .- L -00 tx`bCo 00 00 0� 0�• 01'. Orl' 00 Elapsed Time hh:mm:ss PSIG PSI G S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, October 24, 2015 6:12 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator; Stechauner, Bernhard;Wallace, Chris D (DOA) 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; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 12-07A (PTD #1811750) Passing NFT, waiting for AOGCC approval All, Producer 12-07A(PTD#1811750) had a passing No Flow Test (NFT) performed on October 24, 2015, which once approved, will allow the well to be online without a SSSV. The well has been reclassified as Not Operable until BP receives formal approval from the AOGCC to operate. Please call with any questions or concerns. Thank you, Kevin Parks (Aire,n,,t0 l it„ey Pett,lc, SCANNED 1 12016 BP Alaska -Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, October 12, 2015 9:02 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; '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; Regg, James B (DOA); Pettus, Whitney; Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Producer 12-07A (PTD#1811750) Well-lock treatment Complete/Place on Production for No Flow Test All, Producer 12-07A (PTD#1811750) is now ready to be placed on production. The outer annulus was treated with Well- lock product on May 11, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds. This well requires a subsurface safety valve (SSSV) in order to flow. BP has been granted permission by the AOGCC to flow the well for up to fourteen days without a SSSV.The extended flow period will be used to obtain updated well tests needed to properly size the required SSSV pending the No Flow Test (NFT) results. At this time,the well has been reclassified as Under Evaluation to gather the necessary well tests and determine if the Well-lock treatment was successful. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend and obtaining well tests. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Plan Forward: 1. Operations: Bring well online 2. Downhole Diagnostics: Monitor well until thermally stable then monitor daily thereafter 3. Operations: Perform necessary well tests over a 14 day period 4. Downhole Diagnostics: Perform No Flow Test after 14 days 5. Slickline: Install downhole safety valve as needed 6. Well Integrity Engineer: Additional diagnostics as needed 2. Please call any questions or concerns. SCP34SNES Aura ® 4 ��� Thank you, Whitney Pettus (Alhernure: Kevin Parks) BP GW -Well Integrity Coordinator GYX ;;;.:0",s, WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, August 07, 2015 5:34 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC IL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites;AK, OPS FS1 DS12 Operator; Stechauner, Bernhard; Wallace, Chris D (DOA) 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; Regg,James B (DOA); Pettus, Whitney Subject: UNDER EVALUATION: Producer 12-07A (PTD #1811750)Well-lock treatment Complete/Place on Production for No Flow Test All, Producer 12-07A(PTD#1811750)outer annulus was treated with Well-lock product on May 11, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds. This well requires a subsurface safety valve (SSSV) in order to flow. BP has been granted permission by the AOGCC to flow the well for up to fourteen days without a SSSV.The extended flow period will be used to obtain updated well tests needed to properly size the required SSSV pending the No Flow Test(NFT) results. At this time,the well has been reclassified as Under Evaluation to gather the necessary well tests and determine if the Well-lock treatment was successful. The outer annulus pressure may exceed MOASP(1,000 psi)while determining the stabilization trend and obtaining well tests. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Plan Forward: 1. Operations: Bring well online 2. Downhole Diagnostics: Monitor well until thermally stable then monitor daily thereafter 3. Operations: Perform necessary well tests over a 14 day period 4. Downhole Diagnostics: Perform No Flow Test no later than day 14 5. Slickline: Install downhole safety valve as needed 6. Well Integrity Engineer: Additional diagnostics as needed Please call any questions or concerns. Thank you, SCANNED AUG 1 02015 Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator Gr WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI;,.,ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑❑ Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing I I Change Approved Program ❑ Plug for Rednll [l'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _Wellock Treatment_ 0 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development Q Exploratory ❑ 181-175-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-20409-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028330 PBU 12-07A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071): '10.Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summaryt� ,- ' '`^ , .. V Total Depth measured 10570 feet Plugs measured None feet I!_I^i U 9 20 1 true vertical9091 83 feet Junk measured See Attachment feet Effective Depth measured 10420 feet Packer measured See Attachment feet A.0(W.:CC true vertical 8959 39 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"94#H-40 40-119 40-119 1530 520 Surface 2678 84 13-3/8"72#L-80 39 5-2718 34 39 5-2718 27 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SC.A►NNEo . U L j Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). 39 5'-2718.34' Treatment descnptions including volumes used and final pressure 16 5 GALS WELLOCK 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation. 0 0 0 0 0 14.Attachments(required per 20 MC 25 070 25 071,&25 283) 15 Well Class after work Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil Q Gas U WDSPL Li 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 0 Exempt p N/A 31 S- 5 0 Contact Nita Summerhays Email Nita.Summerha s• b•.com Printed Name Nita um erh- Title Data Manager Signatu / 47j .ri, -1:' , i/ r Phone 564-4035 Date 6/8/2015 UTA }Il , f /S RBDMSA \JUN 1 1 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028330 T/I/O=SSV/220/5. Temp= SI. Treat cemented OA w/Wellock.AL spool dropped. Bled IAP to 0 psi. Bled OAP to 0 psi in 10 seconds and pulled bull plug from casing valve. Inserted tygon tubing through OA casing valve and tagged top of cement. Pumped 12 gallons Wellock into OA from bottom up to displace diesel and get clean Wellock returns. Re-installed bullplug and pumped an additional 4 gallons Wellock into OA to achieve pressure of 2500 psi. Squeezed Wellock for 50 min @ 2500 psi pumping an additional 0.5 gallons. Bled OAP to 0 psi. Purge w/N2 across OA and cleared Wellock from casing valves. Closed both OA casing valves and pressured up against with musol, cycled both casing valves open closed open. Increased OAP to 500 psi w/N2 and left N2 cap. Well head @ 100° @ 3 o'clock position. Heater in wellhouse. Above SSV bled to 0 psi. Monitored OAP&well temp while Well Lock cured. See log for details. ***Job continued on 05-12-15 AWGRS WSR*** 5/11/2015 T/I/O= SSV/Vac/430. Temp= SI. WHPs (Post Wellock-Get WH temps). AL spool dropped. Heater in WH. WH door open. Top of conductor is-90*. SV, WV, SSV= C. MV= O. IA, OA= OTG. 19:00. 5/12/2015 ***Job continued from 05-11-15 AWGRS WSR*** Monitor WHPs&Temp. (Well Lock). Monitored WHPs&OA casing spool temp. Heater trunk in wellhouse, SSV&tree cap void depressured. Final WHPs= SSV/0/430. 5/12/2015 SV, WV, SSV= C. MV= O. IA&OA=OTG. 04:50 FLUIDS PUMPED GALS 16.5 WELLOCK 16.5 TOTAL r Perforation Attachment ADL0028330 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 12-07A 5/19/2009 SQZ 10226 10230 8788.41 8791.92 12-07A 5/19/2009 APF 10230 10247 8791.92 8806.88 12-07A 5/19/2009 SQZ 10247 10252 8806.88 8811.28 12-07A 5/19/2009 APF 10278 10285 8834.16 8840.33 12-07A 5/19/2009 APF 10334 10354 8883.5 8901.14 12-07A 5/17/2009 APF 10354 10362 8901.14 8908.2 12-07A 5/17/2009 APF 10362 10373 8908.2 8917.9 12-07A 5/1/2009 SQZ 10374 10388 8918.78 8931.14 12-07A 5/1/2009 SQZ 10397 10406 8939.08 8947.03 12-07A 5/1/2009 SQZ 10418 10443 8957.62 8979.7 12-07A 5/1/2009 SQZ 10453 10460 8988.53 8994.71 12-07A 5/1/2009 SQZ 10470 10490 9003.54 9021.2 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF C10 Q.p 0 0 0 0 0 0 0 0 0 N N O N CO M (0 CO N- O 00 LO O I"- C N- O (O in N O I- N V Ln V Ln N N- CO U N o C C o 0 o C O C 0 i M M (O N- LC) I- LO CO CO NI- 3 LO c- CO r OD r (A V N- m r OO Cb CO 00 CO CO Nt 00 N- CD r MCD I� Nt NT O CD M • N r CO V I- CO CD QD up OO O N M OD O N r M O O r CO 0O 0 I- Lf) L0 CD CD N N N I- 1 i 1 1 1 1 N- M N- LO O O) O OD v- (3" (fl Ln O M M O d r I- O p O M M Ln N CO r M M CO LC) N- N N = U7 l!7 O O O r CO LC) M 1.0 O O Ln U0 I� M M CD U) CO A-- O O N N (A CD N 00 OO A- A- as() co QM MNt O COO OO O LU LU O CO M00 CO V N O) M r M r Nr M N 00 OD N N O) 00 co D OCD Lf) LO O CA CD O ▪ Q U °C)CD 0 ap? 0 ao U U � rOOJ0 - OJ - C C cp = �$ J # U 4# U) N *k • N (O *k co O It � (T CN COV =0 =0 • pD U NO N �O U7 OO CV .-- O Ln CD U0 4 O O) 4 LO t C7) CV O C� NO Ln O N- O C N- r- Lc) OM N CO r d r N N CO r N 00 Of Z Z Z Z app 0000 ctl U UOa. aOODDLLLZZ U Z ZIOL 101 0 Of D Packers and SSV's Attachment ADL0028330 SW Name Type MD TVD Depscription 12-07A PACKER 2081.57 2081.57 9-5/8" BOT External CSG PKR 12-07A PACKER 8616.35 7437.22 7" Baker S-3 Packer 12-07A PACKER 8714.37 7513.77 7" Baker ZXP PKR/HGR 12-07A 181-175-0 Junk Attachment SW Name MD Date Description 12-07A 10449 11/13/1994 IBP Rubber Element 12-07A 10450 9/2/1989 Baker Rubber Cover TREE, CM/ WELLHEAD= MCEVOY S. (NOTES: WELL REQUIRES A SSSV • ACTUATOR= BAKER C -0 ***4-1/2"CHROM E TBG&SCAB LNR*** KB.ELEV= 80.0' 7A BF.ELEV= NA f KOP= 3300' 1A 2016' —4-1/2"HES X NIP, ID=3.813" 20"COND — 110' 4 . ►'1 I Max Angle= 46°@ 7700' _ 1' 1 Datum MD= 10330' 1� �1� Datum TVD= 8800'SS 41 Or, 2058' H9-5/8"HES CEMENTER 1a r. ►ii 9-5/8"CSG,47#,L-80 XO TO L-80 BTC — 2018' 207T —9-5/8"ECP PKR 9-5/8"BOWEN CSG PATCH —I 2103' 2367' —19-5/8"FOC 2493' —9-5/8"FOC GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80, ID=12.347" —I 2711' A ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3014 3014 5 MMG DOME RK 16 05/12/09 4 4690 4521 43 MMG DMY RK 0 05/03/09 Minimum ID = 3.725" @ 8719' 3 6031 5515 44 MMG SO RK 20 05/12/09 4-1/2" HES XN Nipple 2 7412 6537 43 MMG DMY RK 0 05/03/09 1 8501 7348 39 MMG DMY RK 0 05/03/09 I I 8580' —4-1/2"HES X NIP, ID=3.813" m8611' —19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" I 8646' —4-1/2"HES X NIP,ID=3.813" TOP OF SCAB LNR 8709' 8709' —9-5/8"X 7"BKR C-2 ZXP LTP f� iv w/BKR LNR HGR, ID=6.30" ti 4 I I P, 8719' —14-1/2"HES XN NIP, ID=3.725" I 4-1/2"TBG, 12.6#,13-CR-80 VAM TOP, — 8733' A \ 02 i'1 ►y 8733' —5-1/2"WLEG,4.85" .0152 bpf, ID=3.958" •111 '41 TOP OF BOT TIEBACK SLEEVE 8966' 11 111 8739' —7"X 4-1/2"XO, ID=3.958" 11 111 1x11 9-5/8"X 7"BOT MC LNR HGR — 8972' 'r IJ . 1.:1:+illi 1 1 1 1 MILLOUT WINDOW(12-07A)9271'-9316'J 9-5/8"CSG,47#, L-80, ID=8.681" H 9271' �'_�� PERFORATION SUMMARY 7 NN �, REF LOG:SLB CNL/GR/CCL 01/01/1982 4,4' ANGLE AT TOP PERF:28°©10230' �N�t 1) Note:Refer to Production DB for historical perf data ��44 SIZE SPF INTERVAL Opn/Sqz DATE �\�1 3-3/8" 4 10226-10252 S 05/01/09 x\11 ,• 2-7/8" 6 10230- 10247 0 05/19/09 �1 •1, 10285' —17"MARKER JTS (2 @ 19.3'&19.5') 2-7/8" 6 10278-10285 0 05/19/09 '�11 11 2-7/8" 6 10334- 10354 0 05/19/09 11 3-3/8" 8 10334-10362 S 05/01/09 1 3-3/8" 6 10354- 10373 0 05/17/09 1111 •e\ 3-3/8" 4 10374-10388 S 05/01/09 11 3-3/8" 4 10397- 10406 S 05/01/09 11 44 3-3/8" 4 10418- 10443 S 05/01/09 11 i• 4 3-3/8" 4 10453- 10460 S 05/01/09 11 i ir1�1114\ 3-3/8" 4 10470- 10490 S 05/01/09 11�•1111114•44s .�.111•N: PBTD 10420' 1t. x.111' ` 11�1�1�;�;� 4-1/2"SCAB LNR, 12.64,13CR-80 VAM TOP, .0152 bpf, ID=3.958" 10500' `.111;;`► 10570' TD yo. 7"LNR,29#,L-80, .0371 bpf, ID=6.184" H 10565' Ok DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/30/81 ORIG COMPL (12-07A SDTRK) 05/19/09 KJB/TLH INITIAL PERFS WELL: 12-07A 04/28/97 LAST WORKOVER 06/18/09 KNC/TLH RWO SQZ PERFS CORRECTION PERMIT No: 181-1750 05/04/09 D-14 RWO 09/09/10 DB/JMD DRLG DRAFT CORRECTIONS AR No: 50-029-20409-01 05/04/09 PJC DRLG CORRECTIONS 12/17/10 MB/JMD ADDED SSSV SAFETY NOTE SEC 18,T1ON, R15E 459'FSL&10'FEL 05/12/09 BSE/TLH GLV C/O 05/15/09 JPK/TLH GLV CORRECTIONS BP Exploration(Alaska) ,t.t (Z-C'7A. pN� ( tel 17 550 Regg, James B (DOA) From: Regg,James B (DOA) Sent: Tuesday, May 19, 2015 12:22 PM `Cc'/cl 111 1/5 To: 'AK, D&C Well Integrity Coordinator' Cc: Wallace, Chris D (DOA) Subject: RE: Permission to flow 12-07A (PTD#1811750) pre NFT Thank you for the summary of our phone conversation. As discussed, and based on the justification below, BPXA is granted 14 days to flow PBU 12-07A without a SSSV. It is my understanding that the well will be equipped with a SSCSV (K-valve) if the well fails the no-flow test. This extended flow period will give BPXA the time to gather the well information needed to properly size the K-valve. Refer to Guidance Bulletin 10-004 ("Safety Valve Systems") regarding required approval of the K-valve before installation. Jim Regg Supervisor, Inspections AOGCC SCANNED MAY 2 12015 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Tuesday, May 19, 2015 11:30 AM To: Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator; Wallace, Chris D (DOA) Subject: Permission to flow 12-07A (PTD #1811750) pre NFT Jim, Per our conversation yesterday, BP would like to request permission to bring online Producer 12-07A(PTD#1811750) which is an artificial lifted well that is required to have a downhole safety valve set to operate. The current status of the safety valve is out. The well, a long term shut in that has been offline since 2009, recently had a surface casing treatment with well-lock. BP would like to request permission to flow the well for an extended period before obtaining a no flow test so that the well tests obtained are more indicative of long term production and are not anomalous due to the extended shut-in period. The well underwent a workover in May 2009 and was shut in shortly thereafter. The current thought is that 14 days should be sufficient for obtaining accurate well tests. Since the well was brought online briefly after the May 2009 work over and has been shut in since, a 14 day flow period after the well is brought online is being pursued instead of the standard 5 day window. Plan Forward: 1. Operations: Bring well online 2. Downhole Diagnostics: Monitor well until thermally stable then at minimum monitor daily thereafter 1 3. Operations: Perform necessary well tests over a 14 day period 4. Downhole Diagnostics: Perform No Flow Test 5. Slickline: Install downhole safety valve as needed Please let me know if you have any questions or concerns. I have included a copy of the wellbore schematic for reference. Thank you, Whitney Pettus r-111rwiu1 /ia°t i.1 l'ii/SI BP Alaska-Well Integrity Coordinator G& ' WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 TREE= _ CIW WELLHEAD= MCEVOY S V NOTES: WELL REQUIRES A SSSV ACTUATOR= BAKER C 1 2-O74 ** .,2"CFROM ETBG&SCAB LNR*** KB.ELEV= 80.0' BF.ELEV= NA KOP= 3300' H 1 /' 20"COND 110' r a i 2016' H4-1/2"HES X NIP, ID=3.813" Max Angle= 46"@ 7700' ♦, I 1� Datum MD= 10330' 1� 11. Datum TVD= 8800'SS 0 O,� 2058' —9-5/8"HES CEMENTER 1, 1A 9-5/8"CSG,47#,L-80 XO TO L-80 BTC — 2018' 2077' —9-5/8"ECP PKR 9-5/8"BOWEN CSG PATCH —I 2103' — 2367' —9-5/8"FOC 2493' —19-5/8"FOC GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80, ID= 12.347" —I 2711' 1ST MD TVD DEV TYPE VLV LATCH PORT DATE L 5 3014 3014 5 MMG DOME RK 16 05/12/09 4 4690 4521 43 MMG DMY RK 0 05/03/09 Minimum ID = 3.725" @ 8719' 3 6031 5515 44 MMG SO RK 20 05/12/09 2 7412 6537 4-1/2" HES XN Nipple 1 8501 7348 39 MMG DMY RK _ 0 05/03/09 I ' ' 8580' --I4-112"HES X NIP, ID=3.813" z 8611' —9-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" i ' ' 8646' --I4-1/2"HES X NIP, ID=3.813" TOP OF SCAB LNR — 8709' • 8709' —9-5/8"X 7"BKR C-2 ZXP LTP • �1 w BKR LNR HGR, ID=6.30" I I •� 8719' —1 4-1/2"HES XN NIP, ID=3.725" 4-1/2"TBG, 12.6#,13-CR-80 VAM TOP, — 8733' +�4 / \ 1 .0152 bpf, ID=3.958" �• it 8733' I5-1/2"WLEG,4.85" • 1 8739' H7"X 4-1/2"XO, ID=3.958" TOP OF BOT TIEBACK SLEEVE —I 8966' 11 1111 9-5/8"X 7"BOT MC LNR HGR — 8972' I A.4 �1,• 1 9-5/8"CSG,47#.L-80,ID=8.681" —I 9271' 1-- 1'_._..—- MILLOUT WINDOW(12-07A)9271'-9316' 1 PERFORATION SUMMARY r*4 4� REF LOG:SLB CNL/GR/CCL 01/01/1982 No , ANGLE AT TOP PERF:28"@ 10230' �•�$ 1� Note:Refer to Production DB for historical perf data 4 , SIZE SPF INTERVAL Opn/Sqz DATE \f.� 3-3/8" 4 10226- 10252 S 05/01/09 \\+1 �• `1 1 10285' -17"MARKER JTS (2 @ 19.3'&19.5') 2-7/8" 6 10230- 10247 0 05/19/09 \1 2-7/8" 6 10278- 10285 0 05/19/09 \\11 11\ 2-7/8" 6 10334- 10354 0 05/19/09 \\II 3-3/8" 8 10334- 10362 S 05/01/09 „ 3-3/8" 6 10354- 10373 0 05/17/09 111 , 3-3/8" 4 10374- 10388 S 05/01/09 11 3-3/8" 4 10397- 10406 S 05/01/09 11 � 3-3/8" 4 10418- 10443 S 05/01/09 1 i k 3-3/8" 4 10453- 10460 S 05/01/09 111-t�1ti.11�•.)k 3-3/8" 4 10470- 10490 S 05/01/09 1%�'�1�1�����#`I%,� PBTD 10420' • ?IiiI 4-1/2"SCAB LNR, 12.6#, 13CR-80 VAMTOP, .0152bpf, ID=3.958" --I 10500' • 10570' T7"LNR,29#,L-80, .0371 bpf, ID=6.184" —J 10565' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/30/81 ORIG COM PL (12-07A SDTRK) 05/19/09 KJB/TLH INITIAL PERFS WELL: 12-07A 04/28/97 LAST WORKOVER 06/18/09 KNC/TLH RWO SQZ PERFS CORRECTION PERMIT-No: 181-1750 05/04/09 D-14 RWO 09/09/10 DB/JMD DRLG DRAFT CORRECTIONS API No: 50-029-20409-01 05/04/09 PJC DRLG CORRECTIONS 12/17/10 MB/JMD ADDED SSSV SAFETY NOTE SEC 18,T1 ON,R15E 459'FSL&10'FEL 05/12/09 BSE/TLH GLV C/O 05/15/09 JPK/TLH GLV CORRECTIONS BP Exploration(Alaska) or . 4, II/7,s� THE STATE Alaska Oil and Gas pito - ofLASIc:A Conservation Commission F - - A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALAS*P* Fax: 907.276.7542 www.aogcc.alaska.gov Jessica Sayers NNE F. , , Engineering Team Leader BP Exploration(Alaska), Inc. 1S 1-n6 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-07A Sundry Number: 315-180 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster �,�Q Chair DATED this 2"day of April, 2015 Encl. RECEIVED STATE OF ALASKA M A k 31 '2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 4 ` GCC 20 AAC 25.280 V 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Change Approved Program C] Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Tiq, Ex`enson❑��r 41. Operations Shutdown El Re-enter Susp.Well❑ Stimulate CI Alter Casing❑ Other Well Lock O-Teehne r L Tenk 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development El • 181-175-0• 3.AddressStratgraphic ❑ Service ❑ 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20409-01-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU 12-07A Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028330• PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft). Plugs(measured): Junk(measured): 10570 ' 9092 • 10420 8959 None See Attachment Casing Length Size MD ND Burst Collapse Structural Conductor 79 20"94#H-40 40-119 40-119 Surface 2679 13-3/8"72#L-80 39.5-2718.34 39.5-2718 27 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: 'Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work. Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14.Estimated Date for '15.Well Status after proposed work: 4/7/15 Commencing Operations. Oil 0 • Gas El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Email Jessica.Sayers@BP Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature a 564-4281 Date 3 l 3o f l s Prepared by Garry Catron 564-4424 COMMISSION USE ONLY C Conditions of approval. Notify Commission so that a representative may witness Sundry Number: 315- -1St Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No RI' Subsequent Form Required: /u , 4e 4_ (._,)_464.2 APPROVED BY _ Approved by: / ( COMMISSIONER THE COMMISSION Date: 4 •Z - /-5 VTL 3/ 3iJirORIGINAL ayz-/‘ -.7- 51- 7C Form 10-403 Revised 10/2012 Approved application is valid for 12 months from ate of approval. Submit Form and Attachments in Duplicate RBDMS APR - 6 2015 ,40 Self-- JUNK SUMMARY ADL0312828 SW NAME MEAS_DEPTH MEAS_METHOD_CODE RUN DATE COMMENTS 12-07A 10449 JUNK 11/13/1994 IBP Rubber Element 12-07A 10450 JUNK 9/2/1989 Baker Rubber Cover o 'n 0 0 � v CO CO L = M J O O J J U U a) p_ 0 0 0 0 0 0 0 0 0 0 N N O N N-CO 00 CC) O (N-O LU N O CC) LU O O O N- p Lf) N- N LO LO N N- CO 0 11) 0 0 0 0 0 o O O o O L CO CO CO N- LO Lf) N- CO CO 7 LO V r- co N- N- CO C) -4- co co co co co co -4- co cococococoCovao a) U) CO m• - CO CO O 0O CO CO O CO • O 0 '- CA CO CO N- Lo LC) > CA CA N N- N N- N N- I- Q 0 V O V LO O O ~ O N- •- CO CO O LO O CO CO N- N N N >'s I- L Q E5)) Lo Lo 0 r- o O co Ln co c a) m °) 10 O N- Lo Lo — r) C) CV N C) N- 00 CO N O O N CT N 0) N 00 CO () o2 o) J e o F- o - CCoLoLoC) C`Oi O) co C) •ct CO I- U 00 00 O N N CO O LU LO 0, C)) C7) O 00 0U a060 (000UU o , CO �i OD J O O J i- CO a) *k Cn cr) N 4t CO * N. (O N =60 V V =co00 ON N Lf) �0\O -0\D L!) M N N L- O O V LU _c. O O O 6) N 0 C)) O) CA Lc) O N- O N- Lo O " 00 CO N C) N O N CO • Z Z Z 00 0000 w U U p p 000u_ Z Z1-1-1 w 0 0 0 0 CC m O Z Z cLccQ CCDDD 0QQ C/) H I- Perforation Attachment ADL0028330 Well Date Perf Code MD Top MD Base TVD Top TVD Base 12-07A ' 5/19/09 ' SQZ 10226 10230 8788 8792 12-07A 5/19/09 APF 10230 10247 8792 8807 12-07A ' 5/19/09 ' SQZ 10247 10252 8807 8811 12-07A 5/19/09 1 APF 10278 10285 8834 8840 12-07A 5/19/09 ' APF 10334 10354 8884 8901 12-07A 5/17/09 ' APF 10354 10362 8901 8908 _ 12-07A 5/17/09 APF 10362 10373 8908 8918 12-07A ' 5/1/09 SQZ 10374 10388 8919 8931 12-07A 5/1/09 SQZ 10397 10406 8939 8947 12-07A 5/1/09 ' SQZ 10418 10443 8958 8980 12-07A - 5/1/09 SQZ 10453 10460 8989 8995 12-07A 5/1/09 SQZ 10470 10490 9004 9021 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADLO02833O Well Facility Type MD Top Description TVD Top 12-07A PACKER 2082 9-5/8" BOT External CSG PKR 2082 12-07A PACKER 8616 7" Baker S-3 Packer 7437 12-07A PACKER 8714 7" Baker ZXP PKR/HGR 7514 12-07A PACKER 8775 4-1/2" BAKER S-3 PERM PACKER 7562 12-07A PACKER 8889 4-1/2"TIW HBBP PACKER 7654 12-07A PACKER 8929 7" Baker H Packer 7687 • To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 09-03-2014 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 12-07 WeIlLock MicroOA Treatment Objective • This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 04-15-09 CMIT-IA passed to 3500psi h Test: 2.54gal psi, LLR gpm 10-23-13 OA Shell @ 2500 0 05 Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 2400 psi; Seal-tite repair for microannular treatment was not successful Last H2S Reading: 07-15-2005 200 ppm Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 05/0409: RWO completed cement OA to surface > 06/28/09: DSO called in OAP not manageable when on line > 06/30/13: OA LLR 0.03 gpm © 2000 psi > 10/23/13: OA LLR 0.042 gpm @ 2500 psi Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WeIlLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 .., 'TREE= CM/ WELL HEA D= MCEVOY SAFETY NOTES: WELL REQUIRES A SSSV ACTUATOR= BAKER C 2. 1 -0 7/^t -4-1/2"CHROM ET BG&SCAB L KB.ELEV= Boo I4 R- BF.B_EV= NA KOP= 3300 .0"CONU 1 10' 171 II I 0*. / 2016' H4-1/2"HES X NIP,11=3.813' 1 2 & r* Max A...NIP= 46'@ T700' .1 liv F. Dater MD= 6800 55 10130'1 '0 Ili 6: 2058' I-%LLB'i-Es CaTEN-EP. I Oa t/rn'VD= 4 1,1 01. FA M 18' ,4 7#,L-89 X0 TO L-80 BTC 20Th' - 2077* F19-5/8"ECPITI.TR I r 19-5/Ff DOWEN CSC/PATCH H 2103' 236T 9-518'Foc 2493 -,-8'-'FOC CASLFT MANDRELS I 13-3/Iir'CSG,728,L-8 0,ID=12.347' H 2711' ST ku ND DB/ TY PE VLV LATCH FORT DAM lir 5 3014 3014 5 PSA DOLE Eh '16 091289 4 4 690 4521 43 WC LAN RK 0 05/03/09 Minimum ID=3.725"@ 8719' 3 6031 5515 44 LIMG SO FO,, 20 0571209 2 7412 6537 43 MLIG MN RK 0 05.101.09 4-1f2" HES XN Nipple 1 8501 7348 30 111.1G DMY Rx 0 05101.09 I B580. H4-1.21 FES X NIP,ID=3 8 13' 8611' -19-cv o'X 4-1..2'BAR 5-3 FV,R,ID=3.875' I OM MI I 8646' H4-1/2"HES X IMP,ID=3.8 13" I TOP OF SCAB LM R H 8709' 8709' -19-5/E X 7"BK R 0-2 ZXP LTP 111 Il IF, -0 v.;SKR Lh1R HGR,ID=6.30' Ir ,, 8719' 4-1/2'FES XN NIP,ID=3.725" I ...g 4-lir MFG, 12.60,1 3-CR-80 VA Id TOP, 8733' 1---- '4"•/ H a r* vii 8733' 5-1:2'A'LEC,4.8 5' .015 2 bpf,ID=3.%8'' Si, 44 .1 •1 8739 H 4-112'XO,LT=3.ass•I I-OP OF DOT leaAa<ci F-EvE 8966' .4 •• 0.1 *0 t 011 19-5781 X r BO"'MC LNR FIGR H 8972' 4- a. 111 0 0 1 41 oe I 9-5/8-CSC,478.L-80,ID=8.681' H 9271' 0 • 1________--- MILLOUTWITEOW(12-4714 9 271 -931E; I • 1 *4 PERFORATION STIMARY % i II. REF LOG:SLB CM-GRIOT:1 01/001982 1.0 ANGLE AT TOPPERF:28'f 19230' xo, Nate:Refer to Prodacttan DB f a hiStOTt al per'data A ,.i. CV r SPE INTERVAL OpN'Sqz DATE V-4 +.# 3-3/8" 4 119226-10252 S 2-7/8" 6 10230-10247 0 05/19/09 1 ..4 44,405 10285' r MARKER/TS (2. 19.3&195') I 2-7/8' 6 10278-10285 0 05o119/09 0 4 2-7/8" 6 10334-10364 0 0519/99 4 3-3/8" 8 10334-10362 S 05101/09 4i. • 111111 loilik:i., 3-318" 6 10254-10373 0 05/17AN 646 3-3/1? 4 10374-10388 S 05(01/09 * 3-3/13" 4 10397-1 0406 S 05/01/09 4 4 3-3/8" 4 10418-1 0443 S 05r0t09 64 ...1‘V 3-3#r 4 10453-104*-Z S 05/01/09 1• 4..0 4 6 444)x 3-3/8" 4 10470-10490 5 058)1109 4 444 4 4:4 4% 444,4:1044? PBTD 10420' I.--- vfie*444*.teVike, tio;41%4411,4444, I 4-1.2'SCAB LW.12.6*,13C R-80 VALI TOP..0 152 Not ID=3.958" H 10500' 1--- -4.8,1106 10570' ' illt4P. Jr LNP„29*,:_-80,.0371 ;-if.ID=6.184'H 10565' Q140- DA-E REV By COMENTS DATE REV BY COVRIarS PRUDHOE BAY UTIF 12/30/81 0111G CON1 P L?,12.07.1 S DiRK 1 0 SI S(00 KJar1H INIMAL PERFS WELL: 12-0 7A 04/28/97 LAST WORKOV ER 0 611809 KM3I'Uf RWO SOZ PERFS ODRREC-ION FERMIT No: 181-1750 05/04/09 D-14 RWO 090910 D13/.11AD DRLG DRA F.'CORRECTIONS AF : 50-029-20409-Cl 35/04.,09 PJC [48L0 coRREcTIDN.S 121 7/10 NE5010 ALCEO SSSV SAFETY NOTE SEC 18,TION,RISE 459 FSL&10'FEL 06112209 B SF'LH GLV GO 05'1509 JFK7-11.14 GLV CORRECTIONS BP Ex1:11oraUon(AJaska) 3 of 3 OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Regg, James B (DOA) From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, July 05, 2009 1:55 PM ~ ~~¢~~ To: Maunder, Thomas E(DOA) ~~~` Cc: Regg, James B(DOA); NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: 12-07A (PTD #1811750) Unmanageable OA Pressure Attachments: 12-07A TIO Plot.doc Hi Tom, Page 1 of 3 Yes, the pressurization of 12-07A is similar to that of L-220 in the sense that both are from an external shallow source, either a hydrate or shallow gas zone near the OA shoe. The difference with 12-07A is that the OA is / cemented to surface so that even a smali amount of repressurization becomes unmanageable because the volume of the micro-annulus through the cement is so small. Here is another TIO Plot for reference. / Please let me know if you have any other questions. Thank you, Anna ~Du6e, 2~. E. Well Integrity Coordinator GPB Wells Group Phone: (907) &59-5102 Pager: (907) 659-5100 x1154 ~ e~;','~,'~G,,~,e..x ~iLJ?,'. _ _. ~t)~~~'' From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July O1, 2009 7:50 AM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE: OPERABLE: 12-07A (PTD #1811750) Unmanageable OA Pressure Torin and Anna, Is this pressurization similar to L-220 (I think that is the well)? Is there a stabilizing pressure indicated with the steady data points near the end of May? Tom Maunder, PE AUGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, June 28, 2009 1:38 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: 12-07A (PTD #1811750) Unmanageable OA Pressure All, Well 12-07A (PTD #1811750) needs the OAP bled three times a day to keep it below MOASP making 8/4/2009 OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Page 2 of 3 it unmanageable by bleeds. The OA gas sample verifies the pressure is from hydrates, not IAxOA communication. The well has been reclassified as Not Operable. A TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, June 13, 2009 10:01 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Welis Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure All, Well 12-07A (PTD #1811750) is exhibiting manageable OA pressure. The OA pressure was last bleed on 06I10/09 from 350 psi to 0 psi. It has since repressured to 700 psi but appears to be stabilizing. The well has been reclassified as Operabie. A TIO plot has been included for reference. «12-07A TIO Plot.doc» Please let us know if the OA pressure becomes unmanageable. Thank you, Anna ~u6e, 2~.~. Well Integrity Coordinator GPB Wells Group Phone: (907) 859-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, June Ol, 2009 12:27 PM To: 'Regg, ]ames B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr East (FSl/2/CQTU/Seawater); GPB, FSi OTL; GPB, FSl DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany 8/4/2009 OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Page 3 of 3 Subject: UNDER EVALUATION: 12-07A (PTD #1811750) High OA Pressure - OA cemented to surface All, Well 12-07A (PTD #1811750) recently received a rig sidetrack during which the OA was cemented to surface. When the well was put on production the Operator bled the OA several times due what was believed to be thermal expansion. However, the OA continues to build pressure and further diagnostics are to be done. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: Bleed OAP - DONE, repressures to ~1100 psi overnight 2. D: Obtain IA and OA gas samples - DONE, waiting on results 3. D: Hold open bleed in an attempt to exhaust the gas source A TIO plot and welibore schematic have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/4/2009 PBU 12-07A PTD #181 1750 7/5/2009 TIO Plot 4,U00 3,000 2:000 1,000 ~ Tbg ~ IA -~ OA OOA -•-- OOOA -~ O n 04111/09 04l18105 04I25!09 051~2l09 05I09109 05116I09 05123I05 05130I09 Ofil06;'l9 OE113J09 O6I20/09 06J27r0~ 07f04%09 OPERABLE: 12-07A (PTD #11750) Manageable OA Pressure • Page 1 of 3 Schwartz, Guy (DOA sponsored) From: Schwartz, Guy (DOA sponsored) ~ ~~ ~~ ~-~ Sent: Thursday, June 18, 2009 9:12 AM To: 'NSU, ADW Well Integrity Engineer' Subject: RE: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Andrea, OK ... think I have it figured out. The well had a Rig Workover (not a sidetrack) done in May 2009 to run the 4 1/2" scab liner and OA was cemented to surface. The well was last sidetracked in 1981. (PTD # 1811750) . Looks like the OA has settled as indicated in the last TIO plot. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, June 17, 2009 9:50 PM To: Schwartz, Guy L (DOA) Cc: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Guy, Our records indicate the PTD of 12-07 is 1790860 and PTD of 12-07A is 1811750. Please let me know if your documentation does not reflect this and I can dig into the issue further. The well was sidetracked in May of this year, during which time the OA (new 9-5/8" and existing 13-3/8") was cemented to surface. I have included an updated wellbore schematic for your reference. I have also attached a 90-day TIO plot to demonstrate that the OA pressure is manageable below MOASP with infrequent bleeding. Please let me know if you have additional questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~;~r, ~.. av ~~~ i From: Schwartz, Guy (DOA sponsored) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, June 17, 2009 10:18 AM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure 6/18/2009 OPERABLE: 12-07A (PTD #1750) Manageable OA Pressure • Page 2 of 3 Anna/Andrea, Could you please clarify the well history a bit more for me. The email below states the well was recently sidetracked but the PTD indicates this was in 1981. Also, when was the OA cemented?? How is the pressure looking today on the OA after a few more days?? I just started my PE job at AOGCC so I am looking forward to working with you all. Glad I got to meet you at BP a few weeks ago during my tenure there. Jim Regg and I are sharing some of the UIC workload and Integrity oversight. Regards, Guy From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 9:34 AM To: Schwartz, Guy L (DOA) Subject: FW: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, June 13, 2009 10:01 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 12-07A (PTD #1811750) Manageable OA Pressure All, Well 12-07A (PTD #1811750) is exhibiting manageable OA pressure. The OA pressure was last bleed on 06/10/09 from 350 psi to 0 psi. It has since repressured to 700 psi but appears to be stabilizing. The well has been reclassified as Operable. A TIO plot has been included for reference. «12-07A TIO Plot.doc» Please let us know if the OA pressure becomes unmanageable. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 6/18/2009 OPERABLE: 12-07A (PTD #1750) Manageable OA Pressure • Page 3 of 3 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, June Ol, 2009 12:27 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 12-07A (PTD #1811750) High OA Pressure - OA cemented to surface All, Well 12-07A (PTD #1811750) recently received a rig sidetrack during which the OA was cemented to surface. When the well was put on production the Operator bled the OA several times due what was believed to be thermal expansion. However, the OA continues to build pressure and further diagnostics are to be done. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: Bleed OAP -DONE, repressures to -1100 psi overnight 2. D: Obtain IA and OA gas samples -DONE, waiting on results 3. D: Hold open bleed in an attempt to exhaust the gas source A TIO plot and wellbore schematic have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/18/2009 • 12-07A TIO Plot 4,~0 3,~U 2,000 1,D00 ~1 -~- T6g --f- IA -t- OA OOA + OOOA ~- On 03121109 03/28109 04104109 04111109 04/18109 04/25109 05102109 05109109 05116109 C5123l09 05130109 Ofi,~06109 06113109 TREE = CNV DATE REV BY COMMENTS DATE REV BY COMMENTS 12/30/81 ROW 176 ORIG COMPL (12-07A SDTRK) 5/19/09 KJB/TLH INffIAL PERFS 04/28/97 LAST WORKOVER 05/04109 D-14 RWO 05/04/09 PJC DRLG CORRECTIONS 05/12/09 BSE/TLH GLV C/O 05/15/09 JPK/TLH GLV CORRECTIONS . . PRUDHOE BAY UNIT WELL: 12-07A PERMIT No: 181-1750 API No: 50-029-20409-01 SEC 18, T10N, R15E 459' FSL & 10' FEL BP Exploration (Alaska) os/os/os SCb~~~l'I~~1~ f~ ~ ~ `,~ ~, NO. 5271 Alaska Data & Consulting Services {~~ ~ ~ ~~U~ Company: State of Alaska 2525 Gambell Street, Suite 400 ~1 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~:C1Bi3Slt3Ct 333 West 7th Ave, Suite 100 r9~c3S ~I! ASS LAS Anchorage, AK 99501 ~4flt7f~~G Well Job # Log Description Date BL Color CD 11-30 B2NJ-00002 MCNL - 04/16/09 1 1 12-07A AYOO-00026 _ RST 05/17/09 1 1 ~_ G . 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 ~ Ihh ((``J~ ., osioa/os -~ S~b~e~ge Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~ ~ 05/15/09 1 1 06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESSIT P 05/11/09 1 1 A-44 AWL8-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOQ-00027 PPROF/RST - 05!19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK , 05/06/09 1 1 15-456 ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ / a 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP i r 05/18/09 1 1 X-30A 62WY-00005 E MEM PROD PROFILE 05/10/09 1 1 12-23 AYKP-00021 USIT 4 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-146 AZCM-00022 PROD PROFILE/JEWELRY LOG ~ ~~- 05/20/09 1 1 Li-21 62NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT (~ - Q {~ L 05/22/09 1 1 H-196' B2WY-00004 MEM PROD PROFILE L 05/07/09 1 1 G-16 AYKP-00022 SCMT j / 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ L/~ / 04/21/09 1 1 11-04A AYOO-00028 USIT j L/ ~ 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE >(./ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - ~ 1 05/11/09 1 1 3-37/L-35 AWL9-00035 PRODlINJECTION PROFILE m 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL {,} /~}/5 04/26/09 1 1 PLEASE AGKNUWLEDGE REGt1P I t3Y SIGNING ANU RE I URNIN(i UNE GUPY EACH I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~:y~~,~~ ~~u UNDER EVALUATION: 12-07A (PTD #1811750) High OA Pressure - OA cemented to ... Page 1 of 1 • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, June 01, 2009 12:27 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, EOC Specialists; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Cooper, Katrina N Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 12-07A (PTD #1811750) High OA Pressure - OA cemented to surface Attachments: 12-07 TIO Plot.doc; 12-07A.pdf All, Well 12-07A (PTD #1811750) recently received a rig sidetrack during which the OA was cemented to surface. When the well was put on production the Operator bled the OA several times due what was believed to be thermal expansion. However, the OA continues to build pressure and further diagnostics are to be done. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: Bleed OAP -DONE, repressures to 1100 psi overnight 2. D: Obtain IA and OA gas samples -DONE, waiting on results 3. D: Hold open bleed in an attempt to exhaust the gas source A TIO plot and wellbore schematic have been included for reference «12-07 TIO Plot.doc» «12-07A.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Weil Integrity Coordinator ~~,~,~ ~`„ ~„? i s.~ ~4 ~ ~ '' ~ C' Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/10/2009 • 12-07 TIO Plot 3.000 I -~ Tbg ^ IA 2,000 ~- ~` ~ OOA OOOA ~ ~ On ,~1 J oane~ anaroe os~tsroe osnwoe oTno~ oenoroe osrmroe toiztroe nrnroe tvzzroe mrzvos ouluos o3rt~os aasro9 ovzsros STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION d-.3 09 ~r1AY ~ 7 ~ -; ; := REPORT OF SUNDRY WELL OPERATION 4~ ~~~ ~~ ~~,,~ ~,,,,_, , ~mr~~~~{~~ ~,.,, , . , 1. Operations Performed: ^ Abandon ®Repair Well _ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing„ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drifl Number: BP Exploration (Alaska) Inc. .~ ®Development ^ Exploratory 181-175- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20409-01-00' 7. KB Elevation (ft): 80, , 9. Well Name and Number: PBU 12-07A 8. Property Designation: 10. Field /Pool(s): ADL 028330 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 10570'- feet true vertical 9092' - feet Plugs (measured) None Effective depth: measured 10420' feet Junk (measured) Yes, See Diagram true vertical 8959' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 73' 73' 1530 520 Surface 2711' 13-3/8" 2711' 2711' 4930 2670 Intermediate 9271' 9-5/8" 9271' 7962' 6870 4760 Production Liner 1597' 7" 8966' - 10565' 7716' - 9087' 8160 7020 Scab Liner 1791' 4-1/2" 8430 7500 8709' - 10500' 7510' - 903 0' JJ~tl(({yy~,, 1 *y ryf'(~!lh }l '! Perforation Depth MD (ft): 10230' - 10373' Perforation Depth TVD (ft): 8792' - 8918' 4-1/2", 12.6# 13Cr80 8733' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer 8611' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ... ~,,, JAN ~ ~ tp09 Treatment description including volumes used and final pressure: Cut and pull tubing from 8747'. Cut and pull 9-5/8" casing from 2100'. Run 9-5/8", 47#, L-80 tieback to 2103', cement w/ 160.8 Bbls Class 'G' (Yield 1.17). Run 4-1l2", 12.6#, 13Cr80 Scab liner and cement w/ 73 Bbls Class 'G' (Yield 1.17). Run new Chrome tubing. Add Perfs / Re-Pert post rig. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram - ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 309-125 Printed Name Terrie Hubble Title Drilling Technologist Prepared By NameMumber 27 Signature Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~ ~,,,,% ~ F -.; ~ ~'•~ ~ ~ ~ Submit Original Only 12-07A, Well History (Pre Rig Workover) Date Summary 04/11/09 T/I/0=810/850/165, Temp= S/I, CMIT-TxIA PASSED to 3500 psi on 3rd test. MIT-OA PASSED to 2000 psi, Pressured up IA and tubing with 15 bbls of neat meth to reach 3500 psi. CMIT-TxIA on 3rd test lost 20/20 psi in 1st 15 minutes and 0/0 psi in 2nd 15 minutes for a total of 20/20 psi in a 30 minute test. Bled down IA and tubing psi. Rig off IA and Rig up to OA. Pressured up OA with 1 bbls of neat meth to reach 2000 psi. MIT-OA lost 100 psi in 1st 15 minutes and 20 psi in 2nd 15 minutes for a total of 120 psi in a 30 minute test. Bled down OA psi. FWHP's = 980/970/160. SV, WV, SSV =Closed, MV, IAV, OAV =Open. 04/13/09 WELL SHUT-IN ON ARRIVAL, SSV = C, SWAB = C, MASTER =0 INITIAL T/I/O = 1000/1000/100. CUT 4.5" TUBING AT 8747' AT THE BOTTOM OF THE FIRST FULL JOINT ABOVE THE PACKER. ALL CASING GUAGES OPEN TO TREE. SSV, SWAB, WING LEFT CLOSED. MASTER OPEN. WELL LEFT SHUTIN FINAL T/IA/OA = 750/760/100. JOB COMPLETED. 04/15/09 T/I/O=SSV/800/150, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS, 1 LDS tight but functioned, left backed out (flagged). All the rest moved freely (1 "), Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 04/15/09 T/I/0=900/800/160 Circ out, CMIT Tx IA PASSED to 1000 psi (Pre RWO) Pumped 5 bbls neat meth followed by 915 bbls seawater down Tbg up IA taking returns to the flowline on well #8. Pumped 131 bbls diesel down Tbg. U-Tubed Tx IA for freeze protect. Pumped 2 bbls diesel down Tbg to pressure up Tx IA to 1000 psi for CMIT TxIA. T/IA lost 30/20 psi in the 1st 15 mins and 10/10 psi in the 2nd 15 mins for a total pressure loss of 40/30 psi in 30 mins. Bled WHP's. Wing closed, SSV closed, Swab closed, Master-open, IA and OA open to gauges. Operator notified. FWHP's = 0/0/0. 04/16/09 T/I/O=0/0/0 Rig down post Circ-out &CMIT TxIA (Pre RWO) Bled WHP's, RDMO. Final WHP's = 0/0/0. Page 1 of 1 BP EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLI NG INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: ~ Date From - To Hours Task 'Code Phase Description of Operations NPT 4/16/2009 03:00 - 04:00 1.00 RIGD P PRE -Blow down rig floor. -Finish cleaning pits. 04:00 - 06:00 2.00 RIGD P PRE Skid rig floor to moving position. 06:00 - 08:00 2.00 MOB P PRE Move rig off well 04-40. 08:00 - 09:00 1.00 MOB P PRE Wait on Security 09:00 - 12:00 3.00 MOB P PRE Move rig f/ DS 4 to East Security check point. 12:00 - 14:00 2.00 MOB P PRE Move rig f/ East Security check point to DS 12. 14:00 - 00:00 10.00 CONS P PRE Wait on flow line removal f/ well 12-07A and pad preparation. 4/17/2009 00:00 - 12:00 12.00 CONS P PRE Cont. waiting on flow line removal and pad preparation. -Spread herculite and LD rig mats. 12:00 - 15:00 3.00 MOB P PRE Position rig over well 12-07A. -Shim rig. 15:00 - 16:00 1.00 RIGU P PRE Skid rig floor to drilling position. 16:00 - 17:30 1.50 RIGU P PRE Spot and berm rock washer. 17:30 - 18:30 1.00 RIGU P 18:30 - 19:30 1.00 RIGU P 19:30-21:30 I 2.001 WHSURIP Accept ri C~ 17:30 4-17-09 DECOMP Install auger in rock washer. DECOMP -Pin beaver slide -Hook up lines under rig floor. -Take on seawater in pits. DECOMP -Mobilize DSM lubricator and RU same on tree. -Test lubricator to 500 psi x 5 min on chart. -RD lubricator from tree and keep on rig floor to install back "K" plug after displacing out freeze protect. 21:30 - 00:00 I 2.501 WHSUR I P 4/18/2009 ~ 00:00 - 02:30 ~ 2.50 ~ WHSUR P 02:30 - 04:00 I 1.501 WHSUR I P 04:00 - 09:00 I 5.001 WHSUR I P -SIMOPS: Hard line crew RU hard line and choke manifold to tiger tank. DECOMP -Remove blind flange and install pump in flange on wing. -Install secondary valve in IA and install pump in flange. -RU lines to tubing (wing) and IA to displace out freeze protect to tiger tank. -Check hard line w/ air. Steam hard line. -Pressure test hard line w/ water to 3500 psi. Good test. -Bleed down pressure and blow down hard line. DECOMP Displace out freeze protect (diesel): -Pump 50 bbls seawater down IA, taking returns out tubing to tiger tank. 276 gpm @ 1300 psi. -Shut down pumps. Swap lines. Pump 170 bbls seawater down tubing, taking returns out IA to tiger tank. 296 gpm C~ 1250 psi. -Shut down pumps. Allow diesel to migrate x 30 min. -Pump 30 bbls seawater down tubing, taking returns out IA to tiger tank. 296 gpm Ci3 1250 psi. -Shut down pumps. Verify well static. -C/O lines to take returns f/ IA to pits. DECOMP CBU w/ seawater. 215 gpm C~3 700 psi. -Verify well static. DECOMP -Blow down lines. -RU DSM lubricator on tree. RD lubricator Test BPV f/ below to 1000 psi x 10 min on chart. Printed: 5/11/2009 10:33:20 AM l BP EXPLORATION Page 2 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date. From - To Hours Task 'Code NPT 4/18/2009 04:00 - 09:00 5.00 WHSUR P ', 09:00 - 10:30 1.50 WHSUR P 10:30 - 15:30 I 5.001 BOPSUR P Spud Date: 12/12/1981 Start: 4/14/2009 End: Rig Release: 5/4/2009 Rig Number: Phase, Description of Operations DECOMP -Cameron Rep. dry rod in test dart -Tighten flange on tree (leak) -Grease stem on master valve (leak) -Test from above to 3500 psi x 10 min on chart - OK_ DECOMP ND adapter flange & tree -Remove both from cellar Barriers in place: XXN plug C~3 8796' and "K" plug (BPV) in tubing hanger. DECOMP Install 3' spacer spool -Remove 13 5/8" x 11 "spool from BOP -NU BOPE, choke line hose -Shorten riser to fit flowline :30 - 17:00 17:00 - 23:30 50 6.50 PSU BOPSU P P COMP DECOMP 13-5/8" 5M BOP stack configuration: - Annular preventer - 3-1/2" x 6" VBR (top rams) - Blind Rams - Mud cross - 2-7/8" x 5" VBR (bottom rams) -SIMOPS -Test gas alarms RU to test BOPE Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test upper & lower rams w/ 4" & 4 1/2" test jts. Test witnessed by WSL and Tourpusher. Jeff Jones, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3025 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained C~3 34 sec. 4. Full pressure attained C~ 2 min 42 sec. 5. Nitrogen: 4 bottles x 2150 psi avg. -Tested 29 components 1. 13-5/8" annular. 2. 3-1/2" x 6" VBR (upper rams). 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams). 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 4" Inside BOP, 4" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). 23:30 - 00:00 0.50 BOPSU P DECOMP RD testing equipment. 4/19/2009 00:00 - 01:00 1.00 WHSUR P DECOMP Cameron Re ulled test dart w/ d rod. 01:00 - 02:30 1.50 WHSUR P DECOMP -Install Dutch System extension. RILD and close bag. -RU DSM lubricator on Dutch System extension. Printed: 5/11/2009 10:33:20 AM • . BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours I Task III Code NPT Phase Description of Operations 4/19/2009 01:00 - 02:30 1.50 WHSUR P DECOMP -Attempt to test assy. O-ring on middle connection in Dutch System extension failed. RD assy and change O-ring. -RU assy again. Test to 500 psi x 5 min on chart. Good test. 02:30 - 05:00 2.50 PULL P DECOMP -Mobilize Baker tools to rig floor. -MU spear assy. to 4" DP jt. -RIH and engage tubing hanger -BOLDS -Pull tubing hanger to rig floor. Tubing hanger pulled free w/ 225k. PUW 145k after tubin han er free. blocks wei ht 501 05:00 - 07:00 2.00 PULL P DECOMP -Break circulation. -Pump Safe Surf O pill -Circulate S/S. 378 gpm ~ 1300 psi. 07:00 - 10:00 3.00 PULL P DECOMP -RU tubing handling equipment and control line spooling unit. -Disengage spear. LD spear assy and 4" DP jt. -LD tubing hanger w/ XO and pup jt. -Pull and LD 4-1/2" 12.6# 13Cr FOX tubin to SSSV. -Recover dual control lines. Recover 56 SS bands. 10:00 - 10:30 0.50 PULL P DECOMP RD control line spooling unit. 10:30 - 18:00 7.50 PULL P DECOMP Cont. LD 4-1/2" 12.6# 13Cr FOX tubing and completion equipment. -Total LD: 218 jts (includes 35 ft jt described as pup jt in original running order) + 4 GLMs assy +SSSV assy + 35.72' cutoff jt. (cut was made in first full jt above packer). 18:00 - 19:00 1.00 PULL P DECOMP -RD and clean tubing handling equipment. -Clear rig floor. 19:00 - 19:30 0.50 CLEAN P DECOMP Mobilize BHA tools for scraper run to rig floor. 19:30 - 20:30 1.00 WHSUR P DECOMP Install wear bushing. 20:30 - 22:00 1.50 CLEAN P DECOMP MU BHA w/ 8-1/2" bit & 9-5/8" casing scraper. -PU 12 jts 6-1/4" DCs 1x1 to 373'. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH w/ BHA on 4" DP 1x1 to 2743'. 4/20/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Cont. RIH on 4" DP 1x1 to 3120'. 00:30 - 01:00 0.50 CLEAN P DECOMP CBU. 390 gpm 540 psi. 01:00 - 02:30 1.50 CLEAN P DECOMP Cut and slip drilling line (59.5'). Inspect and service top drive and crown. 02:30 - 03:30 1.00 CLEAN P DECOMP POOH f/ 3120' to 373' (BHA) 03:30 - 04:30 1.00 CLEAN P DECOMP -Rack back 4 stands 6-1/4" DCs. -LD casing scraper, bit sub and XOs. Clear rig floor 04:30 - 05:30 1.00 EVAL P DECOMP PJSM- RU Schlumberger a-line equipment. 05:30 - 08:30 3.00 EVAL P DECOMP RIH w/ USIT log to 3100' -Log up to surface in cement /corrosion mode (repeat pass on bottom 500') 08:30 - 09:30 1.00 EVAL P DECOMP RD SWS 09:30 - 11:30 2.00 DHB P DECOMP PJSM -MU RBP per HES Rep. -RIH on 4" DP -Screw in T.D. Obtain parameters -PUW 80k -SOW 85k _ -Spot RBP at 2289' (C.O.E.) -Set RBP per HES Rep. 11:30 - 12:30 1.00 DHB N DFAL DECOMP LD 1 joint DP -RU test lines Printed: 5/11/2009 10:33:20 AM BP EXPLORATION Page 4 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/20/2009 11:30 - 12:30 1.00 DHB N DFAL DECOMP -Pressure to 3500 psi -Took 8.8 bbls to presure up (at 2289' calculated 2.2 bbls) -Bleed pressure - PU 1 jt DP -Slack off to tag RBP -Taking weight high -Attem t to reset RBP at different de the w/ no success 12:30 - 13:30 1.00 DHB N DFAL DECOMP POH w/ RBP -Inspect same - No visible cause as to problem -LD RBP 13:30 - 15:00 1.50 DHB N DFAL DECOMP PU new RBP -RIH to 2294' 15:00 - 15:30 0.50 DHB N DFAL DECOMP PU single DP -Screw in T.D. -Obtain parameters -PUW 80k -SOW 85k -Spot RBP at 2318' (C.O.E.) - 2313' (Top) - et per ep. -LD single 15:30 - 16:00 0.50 DHB P DECOMP RU test equip. -Test RBP to 3500 psi f/ 10 min. on chart -Good test 16:00 - 17:00 ~ 1.00 CLEAN ~ P 17:00 - 19:30 I 2.501 DHB I P 19:30 - 20:00 0.50 DHB P 20:00 - 20:30 0.50 WHSUR P 20:30 - 22:00 1.50 BOPSU P 22:00 - 00:00 2.00 BOPSU P 4/21/2009 00:00 - 01:30 1.50 BOPSU P 01:30 - 03:30 2.00 BOPSU P 03:30 - 04:00 0.50 WHSUR P 04:00 - 04:30 0.50 PULL P -2.8 bbls to achieve pressure DECOMP PJSM -Displace above RBP w/ 9.8 ppg brine -10 bpm, 420 psi DECOMP -Dum 2200# 20-40 mesh river sand down DP on to of RBP. -Pump 1/2 DP string volume. 140 gpm ~ 30 psi. -Wait 30 min. for sand to settle. -RIH and to to of sand ~ 22 2' DECOMP POOH w/ RBP running tool. LD same. DECOMP Pull wear bushing. DECOMP -ND flow line, riser and choke line. -ND BOP and stand back. -Remove 3' spacer spool. Reason f/ ND BOP: C/O 3' spacer spool x shorter one to allow space to PU BOP, cut and hang 9-5/8" casing (after 9-5/8" casing w/ casing patch is run later in this RWO). 3' spacer had been used to allow space for initial test on lower rams while using "K" plug -test dart in tubing hanger and 2' long XO to screw test jt in tubing hanger during BOP test. Barriers in place to ND BOP: XXN plug ~ 8796' and RBP Q 2318'. DECOMP -Install 18" spacer spool. -NU BOP, choke line, riser and flow line. DECOMP Continue to NU BOP, choke line, riser and flow line. DECOMP -Install test jt and test plug. -RU to test. -Test breaks in BOP and choke hose. -Test to 250 psi low - 3500 psi ig x 5 min each on chart - Pass. -RD testing equipment. Pull test plug and test jt. DECOMP -Install wear bushing. -Blow down choke and kill lines. DECOMP -Mobilize BHA components to rig floor. Printed: 5/11/2009 10:33:20 AM BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: 1 2-07A Common W ell Name: 1 2-07A Spud Date: 12/12/1981 Event Nam e: WORKO VER Start : 4/14/2009 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date ,From - To ~' Hours Task Code NPT Phase ' Description of Operations 4/21/2009 04:00 - 04:30 0.50 PULL P DECOMP -MU BHA w/ multistring cutter, string stabilizer & pump out sub. 04:30 - 05:30 1.00 PULL P DECOMP RIH on 4" DP to 2,031' md. -Screw in Top Drive. -Obtain parameters -PUW 80k -SOW 80k. 05:30 - 06:30 1.00 PULL P DECOMP Break circulation w/ 105 gpm / 150 psi. -Tag casing collar at 2,119' md. -PU and spot knives at 2,100' md. -Begin rotating w/ 40 rpm / 2k tq. -Bring on pumps and stage up to 252 gpm / 780 psi. -Observe torque increase. -After 10 min. rota stalled. Attem t to rotate w/ no success. -PU to 150k (70k over) attempt to work free. -PU to 225k (145k over) and cutter pulled free. -PU 10' & Set back down tagging 3' high. -Appears casing shifted when cut out. 06:30 - 07:30 1.00 PULL P DECOMP PJSM w/ Hot Oil and rig crew. -Close annular & line up to pump down DP taking returns out IA. -Pressure to 500 psi - No circulation. -Stage up to 2000 psi w/ no success. 07:30 - 08:00 0.50 PULL P DECOMP Inspect derrick and Top Drive. 08:00 - 09:00 1.00 PULL P DECOMP POH. -LD cutter and inspect same. -Good wear pattern on knives. -No visible damage on cutter. 09:00 - 09:30 0.50 PULL P DECOMP Pull wear ring. 09:30 - 10:00 0.50 PULL P DECOMP PU spear & packoff f/ 9 5/8" casing. -BOLDS. 10:00 - 12:00 2.00 PULL P DECOMP -Engage hanger at wellhead. -Pull hanger free w/ 100k (50k oven. -Pull to 225k to free casing. -Pull to rig floor w/ 175k. -Attempt to circulate -Pressure to 800 psi. -Work pipe w/ 40' strokes and attempt to circulate. -Work pipe w/ 70' strokes, pressure up to 1000 psi. -Pressure bleedin ,off on up stroke but no circulation. 12:00 - 13:30 1.50 PULL P DECOMP Continue to work pipe in 70' strokes X5. -Attempt to Circulate. No success. -PUW 175k, SOW 99k. 13:30 - 15:00 1.50 PULL P DECOMP Release Spear. LD Spear & DP. -Break off & LD 9 5/8" Csg Hanger. 15:00 - 16:30 1.50 PULL P DECOMP POH w/ 9 5/8" Csg. LD 3 Jts of 9 5/8" Cs to 1 980' md. -Attem t to circulate w/ no success. 16:30 - 00:00 7.50 PULL P DECOMP PJSM on LD Csg. -POH LD 9 5/8" Csg from 1,980' to 400' md. 4/22/2009 00:00 - 03:00 3.00 PULL P DECOMP Continue to LD 9 5/8" to surface. -Recovered: 1 Csg Hanger, 53 full Jts, 1 cut Jt C~? 18.05'. -Cut Jt end was ratty & mushroomed out to 11.125" max OD. -Recovered 4 Bow spring centralizers. 03:00 - 04:00 1.00 PULL P DECOMP Clear Rig floor of unnecessary Tools & equipment. -Clean Drip pan & area of Arctic pac. 04:00 - 05:00 1.00 CLEAN P TIEB1 MOB Dress off BHA to Rig floor. 05:00 - 07:00 2.00 CLEAN P TIEB1 PU & MU Dress off BHA: Printed: 5/11/2009 10:33:20 AM L~ BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ~, Code NPT Phase Description of Operations 4/22/2009 05:00 - 07:00 2.00 CLEAN P TIEB1 -12 1/8" Dress off shoe, Washpipe ext., Dress off Mill. -Boot Basket, XO, 13 3/8" Csg Scraper, Bit sub & Float. -LBS, Oil Jar, POS, XO, (12) 6 1/4" D.C's. -XO's to 411' and 07:00 - 08:00 1.00 CLEAN P TIEB1 RIH to 2 050' md. Ta Cs stub @ 2 100' MD. -Break circulation every 10 stands. 08:00 - 12:00 4.00 CLEAN P TIE61 Close annular, open OA to slop tank. -Pump 100 bbls hot diesel (140 degree) down DP. -Taking returns at slop tank. 84 GPM / 400psi. -Pump 25 bbls Safe-Surf-O Pill. 210 GPM / 340 psi. -Let diesel soak for 2 hours. 12:00 - 14:00 2.00 CLEAN P TIEB1 Pump 80 bbl HV Sweep. -Chase w/ 9.8 ppg down DP w/ returns out OA to slop tank. 14:00 - 14:30 0.50 CLEAN P TIE61 Take clean returns to Pits. -Circulate hole clean. 298 gpm / 280 psi. 14:30 - 15:30 1.00 CLEAN P TIEB1 Dress off Top of Csg stub to 2,100.5' md. -PUW 100k, SOW 100k, ROT wt 100k. -RPM 20 / Tq 1 k. 210 gpm / 110 psi. -Wash over stub to 2 106.5' md. -PU above Csg stub. 15:30 - 16:30 1.00 CLEAN P TIEB1 Pump HV Sweep. -Circulate hole clean. 421 gpm / 410 psi. 16:30 - 17:30 1.00 CLEAN P TIEB1 Slack off over Csg stub w/ no pump or rotary -Clean. -POH w/4" DP to 411' md. 17:30 - 19:30 2.00 CLEAN P TIEB1 Stand back D.C's. -Break off & LD Oil jars, Bumper sub, Scraper, XO's. -Boot basket & Wash pipe. 19:30 - 20:30 1.00 CASE P TIEB1 Clear Rig floor of unnecessary Tools. 20:30 - 21:00 0.50 CASE P TIEB1 MOB Csg & Cement equipment to the Rig floor. 21:00 - 22:00 1.00 CASE P TIE61 RU to run 9 5/8" Cs w/ Torque turn. -PJSM on running Csg. 22:00 - 23:00 1.00 CASE P TIE61 MU: Csg Patch, ES cementer & XO Jt. -Baker Lok all connections below ES cementer. -ES cementer pinned w/ 6 pins to 2700 psi. 23:00 - 00:00 1.00 CASE P TIEB1 Run 9 5/8", 47#, L-80, Hydril 563 to 576' md. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum make torque 15,800 ft / lbs. -9 5/8" Csg is condition "B". 4/23/2009 00:00 - 05:30 5.50 CASE P TIEB1 Continue to run 9 5/8", 47#, L-80, Hydril 563. -Run Cs from 576' to 2,060' md. -Utilize "Jet Lube Sea! Guard" thread compound. -Optimum make up torque 15,800 ft / lbs. 05:30 - 07:00 1.50 CASE P TIE61 Obtain parameters: PUW 135k, SOW 138k. -En age stub with Gra ple on Csg patch. -Pull test to 250k. -Install long Bales and Cmt head. -PU on Csg 100k over. 07:00 - 08:00 1.00 CASE P TIEB1 Test Csg to 1000 psi / 10 minutes -Pass. -Increase to 1400 psi to inflate ECP. -Continue to pressure up to 2000 si / 10 minutes - OK. -Pressure u too en ES Cementer - o en @ 3100 si. 08:00 - 09:00 1.00 CEMT P TIEB1 Pump Soap pill & circulate Brine around until returns temp Q 85 F. Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: 12-07A Common W ell Name: 1 2-07A Spud Date: 12/12/1981 Event Nam e: WORKO VER Start : 4/14/2009 End: Contractor Name: DOYON DRILLI NG INC . Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task 'Code NPT .Phase Description of Operations 4/23/2009 08:00 - 09:00 1.00 CEMT P TIEB1 -Initial pump brought additional Arctic Pac back across shakers. -At bottoms up Arctic Pac cleared up & clean returns noted. 09:00 - 10:30 1.50 CEMT P TIE61 PJSM on cementing. -Pump: 5 bbls H2O & test lines to 3000 psi. -160 bbls of 15.8 ppg class "G" cement, yield 1.17ft3/sk -Kick out Plug with 5 bbls of H2O. -Displace with 145 bbls of 9.8 ppg NaCI brine. -240 gpm / 230 psi ICP. 750 psi FCP. -Slow pumps to 126 gpm / 650 psi for last 15 bbls. -Bump Pluo then oressure uo to 1570 psi to close ES cementer. -Check floats - OK. -32 bbls of cement returns noted. -CIP C~ 10:10 hrs. 10:30 - 11:00 0.50 CEMT P TIEB1 Remove cement head. -Flush Stack and drain. 11:00 - 12:00 1.00 BOPSU P TIE61 Blow down Stack. -ND Stack. Maintain 220k pull on Csg. 12:00 - 13:30 1.50 BOPSU P TIEB1 Suck out Csg to below cut point. -Remove Choke hose. Split Stack below Tbg Spool. 13:30 - 16:00 2.50 BOPSU P TIEB1 Set "E" sli s w/ 100k overpull. -Cut 9 5/8" Csg. LD cut Jt. Cut Jt = 32.32'. -Pull Riser. Stand back Stack. Dress off cut. -Install 9 5/8" Packoff. 16:00 - 17:00 1.00 BOPSU P TIEB1 Set Stack on wellhead. -LD Tbg Spool & secondary valve. ', -Stand back Stack. Remove Tbg spool from cellar. 17:00 - 19:30 2.50 BOPSU P TIE61 NU new Tbg Spool. Install double valve. -Cameron test same to 3800 psi / 30 minutes -Pass. 19:30 - 21:00 1.50 BOPSU P TIEB1 NU: Stack, Choke hose, Riser & Flow line. 21:00 - 21:30 0.50 BOPSU P TIEB1 Install Test Plug. i 21:30 - 22:00 0.50 BOPSU P TIEB1 RU to test Stack breaks. 22:00 - 23:30 1.50 BOPSU P TIEB1 Test Stack breaks on: -BOP's, Tbg Spool & Choke hose. -Test to 250 psi low pressure, 3500 psi high pressure. -Test each for 5 charted minutes. 23:30 - 00:00 0.50 BOPSU P TIEB1 Pull test Plug. Install Wear ring. 4/24/2009 00:00 - 00:30 0.50 CLEAN P TIE61 MOB clean out BHA to Rig floor. 00:30 - 02:00 1.50 CLEAN P TIEB1 MU Clean out BHA: -Bit-2 Boot Baskets, Bit sub, LBS, XO, (12)- 6 1/4" D.C's., (2)- XO's. - MU BHA to 390' md. 02:00 - 03:00 1.00 CLEAN P TIEB1 RIH w/ 4" DP out of Derrick to 1,900' md. 03:00 - 04:30 1.50 CLEAN P TIEB1 RU & test Csg to 3500 psi / 30 minutes -Pass. -RD test equipment & Blow down lines. 04:30 - 06:00 1.50 CLEAN P TIEB1 Wash down to top of ES cementer C~ 2,058' md. -Control drill to minimize cuttings size. -Work throu h ES cementer -clear. -PUW 135k, SOW 138k, ROT wt 100k. -315 gpm / 240 psi. WOB 5-10k. RPM 70 / 1 k Tq. 06:00 - 07:30 1.50 CLEAN P TIEB1 Wash down to sand on top of RBP. -Tag top of sand C~3 2,262' md. Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 8 of 18 Operations Summary Report Legal Well Name: 12-07A Common W ell Name: 12-07A Spud Date: 12/12/1981 Event Nam e: WORKO VER Start : 4/14/2009 End: Contractor Name: DOYON DRILLI NG INC . Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date j From - To Hours ~i Task I Code ' NPT ' Phase. Description of Operations 4/24/2009 06:00 - 07:30 1.50 CLEAN P TIEB1 -Dry drill to 2,265' and to break up big pieces form ES Cmtr. -WOB 5-10k. RPM 70 / 1 k Tq. -Pump HV Sweep. 340 gpm / 300 psi. -Sand & small metal shavin sin returns. 07:30 - 08:00 0.50 CLEAN P ~ TIEB1 POH w/ Cleanout BHA on 4" DP to 390' md. 08:00 - 09:30 1.50 CLEAN P TIEB1 Stand back D.C's. Break off Bit. -Break off & clean out Junk Baskets. -2 cups full of small pieces of aluminum & brass. 09:30 - 10:00 0.50 CLEAN P TIEB1 RU to test 9 5/8" Csg. 10:00 - 11:00 1.00 CLEAN P TIE61 Test Cs to 3500 si / 30 minutes -Pass. -RD test equipment. 11:00 - 12:30 1.50 CLEAN P TIE61 PU & MU RCJB BHA: -RCJB, (2) -7" Boot Baskets, 9 5/8" Csg scraper, Bit sub. -6 1/4" LBS, POS, XO, (12) -6 1/4" D.C's & (2) -XO's. -MU to 401' md. 12:30 - 13:00 0.50 CLEAN P TIEB1 RIH w/ RCJB BHA on 4" DP from 401' to 2,011' md. 13:00 - 14:30 1.50 CLEAN P TIEB1 Obtain parameters: -PUW 100k, SOW 100k, ROT wt 100k. -RPM 25 / 1 k Tq. 220 gpm / 580 psi. -Wash down to 2,201' md. Drop ball to open RCJB. -Observe PSI increase. -Wash sand from 2,201' to 2,280' md. -256 gpm / 2430 psi. 14:30 - 15:30 1.00 CLEAN P TIEB1 Drop Dart to open P.O.S. -Observe PSI increase & shear open P.O.S. -Pump HV Sweep. Displace well to 8.5 ppg Seawater. -456 gpm / 250 psi. -Sand & small metal feces in swee . 15:30 - 16:00 0.50 CLEAN P TIE61 POH with RCJB BHA on 4" DP from 2,280' to BHA C~ 401' md. 16:00 - 17:30 1.50 CLEAN P TIEB1 Stand back D.C's. -Break off & clean out RCJB & boot basket. -Recovered 3 lar a feces of aluminum 3-4" in BB_. -LD scraper. 17:30 - 18:30 1.00 CLEAN P TIEB1 MU RCJB, boot basket, jars, XO's & D.C's to 401' md. 18:30 - 19:00 0.50 CLEAN P TIEB1 RIH w/ DP from 397' MD to top of sand C~3 2,197' md. 19:00 - 20:00 1.00 CLEAN P TIEB1 Drop RCJB ball, Observe PSI increase. -Wash sand from 2,197'- 2,303' md. -PUW 100k, SOW 100k, ROT wt 100k. -272 gpm / 2480 psi. RPM 25 / 1 k Tq. 20:00 - 21:00 1.00 CLEAN P TIEB1 Circulate Surface to surface w/ HV sweep. -273 gpm / 2,470 psi. 21:00 - 21:30 0.50 CLEAN P TIEB1 POH from 2,303' to 397' md. 21:30 - 23:00 1.50 CLEAN P TIEB1 Stand back D.C's -Break off & clean out RCJB & boot basket. -Nothing recovered in RCJB. -Hand full of small metal pieces returned in 'unk basket. 23:00 - 00:00 1.00 CLEAN P TIEB1 tear rig floor. 4/25/2009 00:00 - 00:30 0.50 CLEAN P TIEB1 MU RBP retrieval Tool. 00:30 - 01:30 1.00 CLEAN P TIEB1 RIH w/ RBP retrieval Tool on 4" DP to 2,290' md. 01:30 - 02:30 1.00 CLEAN P TIEB1 Wash down to to of RBP @ 2,313' md. -Latch up -pull 10k over to confirm latch up. -CBU X 1.5 ~ 325 gpm / 340 psi to wash away any sand. -Release RBP. Flow check well -static, Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 9 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: i Date j From - To Hours ' Task Code NPT ' Phase Description of Operations 4/25/2009 01:30 - 02:30 1.00 CLEAN P TIEB1 -PUW 78k, SOW 82k. 02:30 - 03:30 1.00 CLEAN P TIEB1 POH w/ RBP on 4" DP. 03:30 - 04:00 0.50 CLEAN P TIEB1 LD RBP & retrieval Tool. 04:00 - 05:00 1.00 CLEAN P TIEB1 RU to test BOP's. 05:00 - 11:00 6.00 CLEAN P TIEB1 Test BOP's: Test BOP's, Choke & associated valves: 29 components. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Hydril to 250 low psi, 3500 high psi. -Test upper & lower Rams w/ 4" & 4 1/2" test jts. -Test 250 low psi & 3,500 psi High psi. -Hold each test for 5 charted minutes. -All tests Pass. Note: 34 secs for 200 psi build up 2 Min & 47 secs for full PSI 4 bottles X 2200 psi. 11:00 - 12:00 I 1.001 FISH I P 12:00 - 12:30 0.50 FISH P 12:30 - 14:00 1.50 FISH P 14:00 - 15:00 1.00 FISH P 15:00 - 20:00 5.00 FISH P 20:00 - 00:00 4.00 FISH P -Test witnessed by T.P. & WSL. -Test witness waived by Lou Grimaldi AOGCC. DECOMP M_OB Packer Milling BHA to Rig floor. -Change out Elevators. DECOMP Lubricate Rig. Inspect Top Drive. DECOMP MU Packer Milling BHA: -Burn Over Shoe, Washpipe, Float sub, Junk Baskets. -Bumper sub, Oil Jars, D.C's & XO's to 450' MD. DECOMP RIH w/ 4" DP out of Derrick from 450' to 3,200' and DECOMP PU 4" DP 1 X 1 from 3,200' to 8,726' md. DECOMP -Obtain parameters & SPR's. -PUW 190k, SOW 160k, ROT wt 175k. -213 gpm / 410 psi. RPM 60 / 4k Tq. -Wash over Tba stub Cry 8.749' md. on racKer rrom u, ibb ro a, i B 10-25k. RPM 40-80 / 5-101 inning to lose partial returns. 4/26/2009 100:00 - 01:00 I 1.001 FISH I P -Daily Seawater losses = 15 bbls. -Total Seawater losses = 15 bbls. DECOMP Continue milling on S-3 Packer from 8,768' to 8,769' md. -Continuing to lose partial returns. -Packer dropped 1' to 8,770' md. Set down 35k. -130 gpm / 180 psi off - 440 psi on. Printed: 5/11/2009 10:33:20 AM BP EXPLORATION Page 10 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: I Date From - To Hours Task '; Code NPT Phase I Description of Operations 4/26/2009 00:00 - 01:00 1.00 FISH P DECOMP -PUW 190k, SOW 160k, ROT wt 175k. -RPM 40 / 5k Tq on & off. 01:00 - 02:00 1.00 FISH P DECOMP Stand back two stands to 8,590' md. -Blow down Top Drive. - Monitor well - Attem t to fill hole never got returns. -Fill hole w/ 15 bbis eve 15 minutes. -C~ 02:00 hrs DHD shot fluid level C~ 650' md. 02:00 - 03:30 1.50 FISH P DECOMP PJSM on cutting Drlg line. -Slip & cut 59.5' of 1 1/4" Drlg line. -Service Top Drive & Blocks. 0 hrs DHD shot fluid level @ 714' md. Release DHD. 03:30 - 07:00 3.50 FISH P DECOMP POH w/ Millin BHA on 4" DP from 8,590' to BHA @ 450' md. -Fill hole with double disolacement plus 15 bbls every 15 minutes. 07:00 - 10:30 3.50 FISH P DECOMP Rack back D.C's. -LD: P.O.S., Jars, Bit sub, Boot baskets, Float sub. -LD: Washover Boot basket, Washpipe & Packer Shoe. -Clear Rig floor of all Tools not needed for upcoming operation. -MOB next BHA to Rig floor. -MU: Spear, XO, Bumper sub, Jar, P.O.S., XO, D.C's., XO. -MU: Intensifier Jars & XO to 405' md. 10:30 - 12:00 1.50 FISH P DECOMP RIH w/ Spear Assy on 4" DP from 405' to 3,725' md. -Adding 20 bbis of 8.5 ppg Seawater every 15 minutes. Seawater losses for Tour = 949 bbis 12:00 - 12:30 0.50 FISH P DECOMP Lubricate Rig. Service Top Drive. 12:30 - 14:00 1.50 FISH P DECOMP Continue to RIH w/ Spear Assy from 3,275' to 8,654' md. -Continue to fill hole w/ 15 bbis of Seawater every 15 minutes. 14:00 - 14:30 0.50 FISH P DECOMP Obtain parameters: -PUW 205k, SOW 150k. Tag Fish C~3 8,755' md. -Work down to Fish. -Run into No-Go. Set down 15k. -Pull S-3 Packer & Tb free @ 95k over ull. 14:30 - 18:00 3.50 FISH P DECOMP POH w/ Fish on 4" DP from 8,755' to the BHA C~ 405' md. -Fill hole w/ 20 bbis of Seawater every 15 minutes. 18:00 - 20:30 2.50 FISH P DECOMP LD Intensifier Jars. Stand back 6 1/4" D.C's. -LD: Oil Jars & Bumper sub. -Pull Fish to Rig floor. Break off cut Jt (4.79'). -Break off & LD Spear w/ cut Jt & XO. -PJSM on punching hole in Tbg. -Punch hole in Pup Jt under S-3 Packer & LD same. -Pull XN nipple above Rig floor. -Punch hole in Pup Jt under XN nipple. -LD: Pups, XN nipple & Unique overshot. 20:30 - 21:00 0.50 FISH P DECOMP MOB Baker Tools to Rig floor. 21:00 - 22:00 1.00 FISH P DECOMP MU: Overshot, Dressoff guide, Bumper sub, Oil Jars, -D.C's, Intensifier Jars & XO's to 405' md. -Overshot dressed w/ 4 1/2" RHW Grapple & Plain control. -Fill hole w/ Seawater 15 bbis every 15 minutes. 22:00 - 00:00 2.00 FISH P DECOMP RIH w/ Fishing Assy on 4" DP from 405' to 6,188' md. Tour Seawater losses = 860 bbis Daily Seawater losses = 1809 bbis Printed: 5/11/2009 10:33:20 AM ~ s BP EXPLORATION Page 11 of 18 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 2-07A 2-07A WORKO DOYON DOYON Hours VER DRILLI 14 Task G INC '~ Code . NPT 4/26/2009 22:00 - 00:00 2.00 FISH P 4/27/2009 00:00 - 00:30 0.50 FISH P 00:30 - 01:30 1.00 FISH P 01:30 - 02:30 1.00 FISH P 02:30 - 05:00 2.50 FISH P 05:00 - 08:00 3.00 FISH P 08:00 - 10:30 2.50 FISH P 10:30 - 12:00 1.50 FISH P 12:00 - 13:30 1.50 FISH P 13:30 - 16:00 2.50 FISH P 16:00 - 17:00 1.00 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 20:30 2.50 FISH P 20:30 - 00:00 3.50 FISH P Spud Date: 12/12/1981 Start: 4/14/2009 End: Rig Release: 5/4/2009 Rig Number: Phase ! Description of Operations DECOMP Total losses to well = 1824 bbls DECOMP Lubricate Rig. Service Top Drive, Drawworks & Blocks. DECOMP Continue to RIH w/ Overshot Assy on 4" DP. -RIH from 6,188' to 8,745' md. -PU 3 Jts of DP from the Pipeshed. -Tagged "K" anchor ~ 8,825' md. DECOMP Fish for "K" anchor. Continue to fill hole 15 bbls every 15 minutes. -Obtain parameters: PUW 210k, SOW 150k, ROT wt 175k. -En a e Anchor PU 275k, allow Jars to fire. -Slack off to 10k under SOW. -PU to 275k allow Jars to fire / PU to 300k. -Slack off to 185k. -Rotate 10 RPM while keeping PUW Cad 185k. -Sto rotatin & PU 70' to confirm "K" anchor release; DECOMP Rack back 1 Std of 4" DP. -Blow down Top Drive. -POH w/ "K" anchor from 8,745' to 405' and -Continue to fill the hole with Seawater. -Fill 20 bbls every 15 minutes. DECOMP LD intensifier Jar. Rack back 6 1/4" D.C's. -LD: Oil Jars & L.B.S.. Service break Baker Tools. -LD Tb Ass /Fish (54'). -MOB Next BHA to Rig floor. -MU: Quick ick Packer Millin Ass ,Boot Baskets, XO's, -Jars, L.B.S. & D.C's. to 424' and DECOMP RIH w/ Quick pick Assy on 4" DP from 424' to 8,859' md. -Continue to fill hole w/ Seawater -15 bbls every 15 minutes DECOMP Obtain parameters: PUW 215k, SOW 150k, ROT wt 175k. -250 gpm / 660 psi. 420 gpm / 1690 psi. -RPM 60 /Free Tq 5k. -Ta ed TIW HBBP Packer @ 8,872' md. -Make several attempts to engage Spear in Packer - No-Go -Attempt to index (1/4 turns) into Packer - No-Go. -0-20k WOB, 0-10 bbls/min. 0-1000 p[si. Seawater losses for tour = 969 bbls. DECOMP Cut & slip 59.5' of 1 1/4" Drlg line. -Service Top Drive. Grease Crown. DECOMP POH w/ Quick Pick Mill from 8,872' to the BHA Q 423' md. ~ -Continue to fill hole w eawater 20 bbls every 15 minutes. DECOMP LD Intensifier Jar. Stand back 6 1/4" D.C's. -Break off & LD Quick Pick Mill Assy. DECOMP MU: Packer Mill, 6 1/4" D,C's & Intensifier Jars to 421' md. DECOMP RIH w/ Mill Assy on 4" DP from 421' to 8,856' md. -Fill hole 15 bbls every 15 minutes. DECOMP Obtain parameters: PUW 212k, SOW 150k, ROT wt 179k. -165 gpm / 100 psi. RPM 60 / 6k Tq. -WOB 10-30k. RPM 50-80. -Ta TIW HBBP Packer ~ 8 879' md. -Mill Packer from 8,879' to 8,882' md. -Push Packer to 8,888' md. Monitor well 10 minutes. Printed: 5/11/2009 10:33:20 AM BP EXPLORATION Page 12 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date ~ From - To ,Hours Task Code NPT Phase ~ Description of Operations 4/27/2009 20:30 - 00:00 3.50 FISH P DECOMP Tour Seawater losses = 1339 bbls Daily Seawater losses = 2308 bbls Total losses to well = 4112 bbls 4/28/2009 00:00 - 00:30 0.50 FISH P DECOMP Continue to push Packer down hole. -PU 2 Jts of 4" DP to 8,953' md. -Continue to fill hole w/ 15 bbls every 15 minutes. -Blow down Top Drive. 00:30 - 03:00 2.50 FISH P DECOMP POH w/ Millin BHA on 4" DP from 8,953' to BHA @ 421' md. 03:00 - 05:00 2.00 FISH P DECOMP Rack back D.C's. -LD Intensifier Jars, Boot Baskets, XO's & Mill. -Clean Boot Baskets of cuttings. -Recovered 1/2 of a 5 gal bucket of metal shavings. -Clear Rig floor of all unneeded Tools. -MOB "C" Dimension Spear Assy to Rig floor. -MU BHA: Bowen "C" Dimension Spear, XO, Oil Jars, Bumper sub, -D.C's, IntensifierJars & XO to 408' md. 05:00 - 06:30 1.50 FISH P DECOMP RIH w/ S ear Ass on 4" DP from 408' to 3,915' md. -Continue to fill hole w/ Seawater, 15 bbls every 15 minutes. 06:30 - 07:00 0.50 FISH P DECOMP Lubricate Rig, Top Drive & Blocks. -Grease Sliding sleeve. 07:00 - 08:00 1.00 FISH P DECOMP RIH w/ Spear Assy on 4" DP from 3,915' to 8,938' md. -Continue to fill hole w/ Seawater, 15 bbls every 15 minutes. 08:00 - 10:00 2.00 FISH P DECOMP PU 1 Jt of 4" DP. -Obtain Parameters: PUW 212k, SOW 150k, ROT wt 179k. -Stage up pumps: 168 gpm / 160 psi ~ 336 gpm / 2030 psi. -Ta~c~ged Fish @ 8,953' md. Attempt to Stab into Packer. -Put in 2 turns to left w/ 5k down. Set 10k down. -Attempt to work into Fish: -10-30k WOB / 42 - 420 gpm / 0-2300 psi. -Attempt to Rock into Packer - No-Go. -Try to rotate in 10-15 RPM - No Go. -Attem t to Bounce in - No-Go. 10:00 - 12:00 2.00 FISH P DECOMP Blow down Top Drive. LD 1 Jt of 4" DP. -POH w/ Spear Assy from 8,938' to 1,924' md. Seawater losses for tour = 967 bbls. 12:00 - 12:30 0.50 FISH P DECOMP Lubricate Rig. Adjust Brakes. Inspect Top Drive. 12:30 - 13:00 0.50 FISH P DECOMP POH w/ Spear Assy from 1,924' to BHA C 408' md. -Continue to fill hole w/ Seawater, 20 bbls every 15 minutes. 13:00 - 14:00 1.00 FISH P DECOMP LD Intensifier Jars. Stand back D.C's. -LD Spear. Tape still in place on Spear. -Paint wore off 1" below Wicker. 14:00 - 15:00 1.00 FISH P DECOMP MU Junk Mill BHA. MU: 3 5/8" Junk Mill, 6 1/4" D.C's & Intensifier Jars to 413' md. 15:00 - 17:30 2.50 FISH P DECOMP RIH w/Junk Mill BHA on 4" DP from 413' to 8,943' md. -Continue to fill hole w/ Seawater, 15 bbls every 15 minutes. 17:30 - 18:30 1.00 FISH P DECOMP Obtain parameters: PUW 212k, SOW 150k, TOT wt 175k. -WOB 5k. RPM 30 / 5k Tq. 127 gpm / 310 psi. -Ta Fish ~ 8,955' md. -Mill Fish to 8,959' and /RPM 50 / 5k Tq. -En a e Fish. 18:30 - 19:00 0.50 FISH P DECOMP POH w/ Fish on 4" DP from 8,959' to 8,469' md. Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: 12-07A Common Wel! Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date ', From - To Hours ~, Task Code NPT Phase Description of Operations 4/28/2009 18:30 - 19:00 0.50 FISH P DECOMP -Continue to fill hole w/ Seawater, 20 bbls every 15 minutes. 19:00 - 20:30 1.50 FISH P DECOMP PJSM on cutting Drlg line. Cut 59.5" of 1 1/4" Drlg line. -Service Top Drive & grease Crown. 20:30 - 23:30 3.00 FISH P DECOMP Continue to POH w/ Fish from 8,469' to 413' md. -Continue to fill hole w/ Seawater, 20 bbls every 15 minutes. 23:30 - 00:00 0.50 FISH P DECOMP LD Intensifier Jars. Stand back 6 1/4" D.C's. -Pull S ear to Floor - No Fish. -Convex Mill well worn. -Bottom two rinds of oraaole are marked from Fish. 4/29/2009 00:00 - 00:30 0.50 FISH P 00:30 - 01:30 1.00 FISH P 01:30 - 03:00 1.50 FISH P 03:00 - 05:30 2.50 FISH P 05:30 - 07:30 2.00 FISH P 07:30 - 10:30 3.00 FISH P 10:30 - 11:30 1.00 FISH P 11:30 - 12:00 0.50 FISH P 12:00 - 12:30 0.50 FISH P 12:30 - 13:30 1.00 FISH P 13:30 - 16:00 2.50 FISH P 16:00 - 17:00 1.00 FISH P Tour Seawater losses = 990 bbls Daily Seawater losses = 1957 bbls Total losses to well = 6069 bbls DECOMP Service Top Drive, Blocks & Drawworks. -Grease sliding sleeve. DECOMP Break Mill & Extension. -Rig team performed a "Man Down" drill. -After the man down in the cellar, we held a Table Top review of drill. DECOMP MU Spear /Mill BHA. MU Mill, D.C's & Intensifier Jars to 408' md. -Change out Elevators. DECOMP RIH w/ Spear Assy on 4" DP from 408' to 8,938' md. -Continue to fill hole 15 bbls every 15 minutes. DECOMP Obtain parameters: -PUW 216k, SOW 151 k, Rot wt 177k. 147 gpm / 830 psi. -Work down. Tagged Fish (~3 8,955' md. -Put 10k down. PU, no overpull. -Put 35k down. PU, no overpull. -Put 35k down. PU, no overpull. -Put 15k down w/ 30 RPM. PU, no overpull. -Put 3 rounds Left (Catch position for Grapple) w/ 15k down. -No overpull noted. -Continue to work Fishin Ass . -Continue to fill hole w/ Seawater, 15 bbls every 15 minutes. DECOMP LD 1 Jt of 4" DP to 8,938' md. Blow down Top Drive. -POH w/ Fishing Assy from 8,938' to the BHA C~3 408' md. DECOMP LD Intesifier Jar. Rack back D.C's. -Break down S ear /Mill. DECOMP MOB Baker Tools to Rig floor. Seawater losses for tour = 710 bbls. DECOMP Lubricate Rig. Inspect Top Drive. DECOMP MU: Junk Mill on Spear. -PU & MU Boot Baskets & XO's. -MU: Bumper sub, Oil Jars, 6 1/4" D.C's & Intensifier Jars to 433' md. -Change out Elevators. DECOMP RIH w/ Fishing BHA on 4" DP from 433' to 8,900' md. -Continue to fill hole w/ Seawater, 15 bbls every 15 minutes. DECOMP Obtain parameters: PUW 213k, SOW 155k, ROT wt 179k. -RPM 40 / 6k Tq. 212 gpm / 820 psi. Printed: 5/11/2009 10:33:20 AM • • BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date ', From - To Hours Task Code I NPT ' Phase Description of Operations 4/29/2009 16:00 - 17:00 1.00 FISH P DECOMP -Tag Fish ~ 8,955' md. -Mill Fish from 8,955' to 8,970' md. RPM 50. WOB 2k. -Engage Fish. 17:00 - 21:30 4.50 FISH P DECOMP POH w/ Fish on 4" DP from 8,970' to the BHA ~ 433' md. -Continue to fill hole w/ Seawater, 20 bbls every 15 minutes. 21:30 - 00:00 2.50 FISH P DECOMP LD Intensifier Jars. Stand back 6 1/4" D.C's. -LD Pump Out Sub & Oil Jars. -Pull up to 1st Tbg Jt below TIW Packer. -Punch holes in Tbg. -LD: Pup Jt (9.69'), TIW Packer & Spear. -Break off & LD XO's, Boot Baskets & Lubricated Bumper sub. -LD 1 Jt of Tbg @ 41.50'. Tour Seawater losses = 1000 bbls Daily Seawater losses = 1710 bbls Total losses to well = 7779 bbls 4/30/2009 100:00 - 01:00 1.00 FISH P 01:00 - 03:00 I 2.001 FISH I P 03:00 - 04:30 1.50 ~ CLEAN ~ P 04:30 - 06:00 1.50 ~ CLEAN ~ P 06:00 - 07:00 I 1.001 CLEAN I P 07:00 - 12:00 I 5.001 CLEAN I P 12:00 - 14:00 ~ 2.00 ~ CLEAN ~ P 14:00 - 15:30 ~ 1.50 ~ CLEAN ~ P DECOMP Continue to punch holes in Tbg tail Assy. -Fish length = 101.33' DECOMP Clear Rig floor of all Tools unneeded for next operation. -Change out Elevators. -MOB Baker Tools for cleanout run to Rig floor. -Change out dies on Iron Roughneck. -Continue filling the hole with Seawater, 15 bbls every 15 minutes. DECOMP MU cleanout BHA: -MU Junk Mill, Bit sub, D.C., String Mill, D.C., Stab, Bumper sub, -Oil Jar, XO, 17 Sts of 4" DP to 1,700' md. -Continue filling the hole with Seawater, 15 bbls every 15 minutes. DECOMP PJSM on cutting Drlg line. -Cut 59.5' of 1 1/4" Drlg line. Service Top Drive & Blocks. -Continue filling the hole with Seawater, 15 bbls every 15 minutes. DECOMP Continue to MU the cleanout BHA: -XO, Double Pin, Csg Scraper, Bit sub, XO, D.C's & XO to 2,080' md. DECOMP RIH w/cleanout BHA on 4" DP from 2,080' to 8,966' md. -Top Drive up. PU 1 Jt of 4" DP to 8,998' md. -Work Mills throu h Liner. -PU 4" DP from 8,998' to 9,475' md. -Work through tight spots 9,475' to 9,516' md. -PUW 222k, SOW 152k, ROT wt 180k. RPM 50 / 6-7k Tq. Seawater losses for tour = 895 bbls. DECOMP PU 4" DP 1 X 1. RIH (~ a controlled rate. Tag up ~ 10,472' md. DECOMP Obtain parameters: PUW 250k, SOW 160k, ROT wt 200k. -RPM 40 / 8k Tq. 212gpm / 330 psi. -Wash & Ream f/ 10,472' to 10,515' md. WOB 10k. RPM 50. -Increase pump rate 335 gpm / 1390 psi. -Established returns. Printed: 5/11/2009 10:33:20 AM • • BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To i I Hours Task ~ 'Code , NPT Phase Description of Operations 4/30/2009 15:30 - 17:30 2.00 CLEAN P DECOMP Pump Hi Vis Sweep surface to surface. -Reci rocate & rotate 60 RPM. -429 gpm / 2020 psi. -Small amounts of sand and metal filings in sweep returns. 17:30 - 21:00 3.50 CLEAN P DECOMP POH w/ Cleanout BHA from 10,515' to the BHA C~ 2,080' md. 21:00 - 23:00 2.00 CLEAN P DECOMP Change out Elevators. PJSM. -LD: XO's, D.C's, Csg scraper & subs to 1,700' md: -Change out elevators. 23:00 - 23:30 0.50 CLEAN P DECOMP Continue to POH w/ 4" DP from 1,700' to 92' md. 23:30 - 00:00 0.50 CLEAN P DECOMP LD Oil Jars & Bumper sub. 5/1/2009 ~ 00:00 - 03:00 ~ 3.00 ~ CASE ~ P 00:30 - 01:00 0.50 CASE P 01:00 - 02:00 1.00 CASE P 02:00 - 03:00 1.00 CASE P 03:00 - 08:00 5.00 CASE P 08:00 - 09:30 1.50 CASE P 09:30 - 12:00 2.50 CASE P 12:00 - 17:00 5.001 CASE P 17:00 - 17:30 0.50 CEMT P 17:30 - 19:00 1.50 CEMT P 19:00 - 21:00 I 2.001 CEMT I P Tour Seawater losses = 1616 bbls Daily Seawater losses = 2511 bbls Total losses to well = 10290 bbls DECOMP Cont. LD BHA -Stab, D.C's, String Mill, Bit sub, and Junk Mill. RUNPRD Clear Rig floor. RUNPRD PU tubing and cementing tools to rig floor. RUNPRD MU 10' pup, XO, TIW, cement head, XO, LS. -Move to pipe shed. RUNPRD PJSM. RIH w/ 4 1/2" 12.6# CR-80 Vam Top tubing. -Float Shoe, Float Collar, Landing Collar,39 jts. -Baker 9 5/8" X 7" hanger & Baker C-2 ZXP Packer. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum torque 4440 ft/Ibs. RUNPRD Rig down Casing equipment: -LD Bales, Elevators, and Compensator. RUNPRD Continue RIH w/tubing on 4" DP. -DP from 1,800' to 3,132' md. -Fill pipe every 1,000' md. Seawater Losses for Tour: 800 bbls. RUNPRD Continue to RIH w/ tubing on 4" DP from 3,132 - 10,425' MD. -Fill pipe every 1,000'. -Make up Top Drive. -Tag fill C~ 10,495' md. RUNPRD Break Circulation Q 16 gpm / 40 psi off / 60 psi on. -Wash fill down to 10,505' md. DECOMP Break out Top Drive, mouse hole top single, blow down Top Drive. -PU & MU cement head off skate. -MU cement hose. -Break Circulation. -Spot Packer in tension w/ Packer @ 8,709'. RUNPRD PJSM on cementing. -Purge lines w/ seawater & test to 4,500 psi. -Purge lines w/ cement. -Pump: 73 bbls, 15.8 ppg class, G cement. -Yield 1.17, 348 sacks. -Drop pump down plug. Latch Liner Wiper Plug @ 92 bbls away. -135 gpm / 360 psi, LW P sheared at 2,240 psi. Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours I Task ~ Code NPT , Phase I, Description of Operations 15/1/2009 119:00 - 21:00 I 2.001 CEMT I P 21:00 - 22:00 I 1.001 CEMT I P 22:00 - 23:30 I 1.50 I CEMT I P 23:30 - 00:00 I 0.501 CEMT I P RUNPRD -Bump LWP ~ 117 bbls away, 84 gpm / 800 psi. -Increase pressure to 4,000 psi, set Hanger. -Set 30k down on Hanger, verify Hanger set. RUNPRD Bleed off pressure. Check Floats -Pass. - RD hoses. -Line up on Top Drive. -Rotate 15 turns to release C-2 Running Tool ~ 120k. -Slow pump to 42 gpm. -Slack off and set packer w/ Dog Sub, 60k down weight. 1 X. -Repeat sequence 2 X w/ rotation to set Liner Top Packer. -PU out of Packer w/ Running Tool, pumping 42 gpm. RUNPRD Pump HV sweep, surface to surface. -546 gpm / 2150 psi. -Noted 22 Bbls. of cement returns. RUNPRD PJSM -LD 2 singles and cement head. -Blow down Top Drive. RU to LD 4" DP, 1 X 1 to pipe shed. 5/2/2009 100:00 - 00:30 I 0.501 CASE I P 00:30 - 09:00 8.50 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 10:00 0.50 BUNCO P 10:00 - 11:00 1.00 BUNCO P 11:00-12:00 1.00 12:00 - 12:30 0.50 12:30 - 17:30 I 5.00 Tour Seawater losses = 336 bbls Daily Seawater losses = 1,136 bbls Total losses to well = 11,426 bbls RUNCMP Service Rig,. -Top Drive blocks, Draw Works, Clean Cement Valves. RUNCMP PJSM on LDDP, LDDP from 8,655' - 7,266' MD. -RIH from 7,266' - 8,529' MD. -LD singles 1 x 1 from 8,529' - 40' MD. RUNCMP Make service breaks & LD Baker Running Tool. RUNCMP Pull Wear Ring. RUNCMP RU to test Casing. -RD Equipment. RUNCMP RU to test BOP's. RUNCMP Continue RU to test BOP's. -Seat Test Plug. RILDS. Pre-Test. RUNCMP Test BOP's: Test BOP's, Choke & associated valves: 29 components. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Hydril to 250 low psi, 3500 high psi. -Test upper & lower Rams w/ 4 1/2" test jts. -Test 250 low psi & 3,500 psi High psi. -Hold each test for 5 charted minutes. - All tests Pass, except TD IBOP failed, it was rebuilt then Printed: 5/11/2009 10:33:20 AM • BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To I'~ Hours Task ~, Code NPT Phase Description of Operations 5/2/2009 12:30 - 17:30 5.00 BUNCO P RUNCMP passed. Note: 30 secs for 200 psi build up 2 Min & 37 secs for full PSI 4 bottles X 2200 psi. -Test witnessed by T. P. & WSL. -Test witness waived by Bob Noble AOGCC. 17:30 - 18:00 0.50 BUNCO RREP RUNCMP RD Test Equipment. -Blow down Choke and Kill lines. 18:00 - 22:30 4.50 BUNCO RREP RUNCMP PJSM, RU to C/O IBOP. -LD Elevator & Bails. -Breakout IBOP. -C/O Actuator to new IBOP. -Install Actuators on Top Drive, Tighten TO rings. -MU Pipe Handler. 22:30 - 23:00 0.50 BUNCO RREP RUNCMP Clear Floor, RU Test Equipment. 23:00 - 23:30 0.50 BUNCO RREP RUNCMP Test IBOP 250 / 3500 psi, 5 min charted. -Pass. 23:30 - 00:00 0.50 BUNCO P RUNCMP RD Test Equipment. -BOLDS. Pull Test Plug. LD Test Joint. 5/3/2009 00:00 - 00:30 0.50 BUNCO P RUNCMP Blow Down Kill Line, Choke Line & Top Drive. 00:30 - 02:00 1.50 BUNCO P RUNCMP PJSM, PU & Install Long Bales and Elevators. -PU Tubing Pup Joints & Tubing Hanger. -PU & RU Torque Turn Equipment. 02:00 - 12:00 I 10.00 RUNCMP -Optimum MU TO 4,440 fUlbs. -Utililzed Jet Lube Seal Guard. -BakerLok all connections below Packer. to 8,400' md. 12:00 - 12:30 0.50 BUNCO P RUNCMP Inspect Rig. Service Top Drive, Blocks & Drawworks. 12:30 - 13:00 0.50 BUNCO RUNCMP Continue running 4 1/2" Tbg. -Run Tbg from 8,400' to 8,739' and - No Go. -PUW 148k, SOW 125k. 13:00 - 14:30 1.50 BUNCO RUNCMP LD 3 Jts of 4 1/2" tubing, -PU four pups: 9.82', 9.82', 7.83', 3.82'. -PU One Jt. of 4 1/2" Tubing (#197). -MU Hanger and TC II Landing Jt. -Land Tbg w/ W LEG C~ 8,733'. 14:30 - 15:00 0.50 BUNCO P RUNCMP RU to Reverse Circulate down IA w/ Returns up Tubing. 15:00 - 19:30 4.50 BUNCO RUNCMP PJSM, Pump 650 bbls of 120 Degree Seawater. -Spot Corrosion Inhibitor between 320 & 625 bbls away 19:30 - 21:00 I 1.50 RUNCMP -RU to pump down Tubing. -Pressure up Tubing to 3,500 psi to set packer, 30 min. /Chart - Pass. -Bleed Tubino to 1,500 psi., Pressure IA to 3500 psi. 30 min. / Chart. -Pass. -Bleed off Tubing, Shear DCK Valve C~? 2,500 psi Printed: 5/11/2009 10:33:20 AM • • BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: 12-07A Common Well Name: 12-07A Spud Date: 12/12/1981 Event Name: WORKOVER Start: 4/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 5/3/2009 19:30 - 21:00 1.50 BUNCO P RUNCMP -Confirm Shear: -Pump down Tubing taking returns C~ IA 3 bpm / 170. -Pump down IA taking returns C~? tubing 3 bpm / 350. 21:00 - 21:30 0.50 BUNCO RUNCMP RD Cement Hose, LD Landing Joint. -Remove Head Pin & XO. -Blow down Cement Hose, MU Dry Rod. 21:30 - 00:00 2.50 BUNCO SFAL RUNCMP Test TWC from Below 1,000 psi., 10 min /Chart. -Pass. -Test TWC from Above 3,500 psi., 10 min /Chart. -Fail --Attempt to work Poppet, Attempt to Test -Fail. --Standby for DSM, for lubricator and new TWC. 5/4/2009 00:00 - 00:30 0.50 BUNCO SFAL RUNCMP Cont. Standby on DSM for Lubricator. -Simops, RD -Prep for move. 02:30 - 03:30 1.00 BUNCO P RUNCMP PJSM w/ DSM. RU to test Lubricator. -500 osi. / 5 min -Chart. Pass. 03:30 - 04:30 1.00 BUNCO P RUNCMP -Old TWC removed, Visible damage to rubber seal. Test TWC. -From below 1,000 psi. / 10 min -Charted. Pass. -From above 3,500 psi. / 10 min -Charted. Pass. 04:30 - 05:00 0.50 BUNCO RUNCMP PJSM. LD Lubricator Extension. Suck out Stack. -Blow down Choke line, Kill line, Bleed off line & Hole fill line. 05:00 - 08:00 3.00 BUNCO P RUNCMP PJSM on ND Stack. -Remove: Flow line covers & Flow line. -Remove: Turnbuckles, Riser, Mouse hole & Choke line. -Rack back BOP Stack and secure. 08:00 - 12:00 4.00 BUNCO P RUNCMP Clean Wellhead. NU Adaptor flange & Tree. -Test Adaptor to 5000 psi / 5 minutes -Pass. -SIMOPS Start to Rig down to skid Rig floor. 12:00 - 12:30 0.50 BUNCO P RUNCMP -RU & test Tree to 5000 psi / 5 minutes -Pass. -RD test equipment. 12:30 - 13:00 0.50 BUNCO P RUNCMP Mobilize Lubricator. Install on Tree. -Test to 500 si / 5 minutes on chart. -Pull TWC. 13:00 - 13:30 0.50 BUNCO RUNCMP RD test equipment. -RU to U-Tube diesel for freeze protect. 13:30 - 15:00 1.50 BUNCO RUNCMP PJSM. Pressure test LRS lines to 3500 psi -Pass. -Pump 140 bbls of Diesel. ICP 21 gpm / 40 psi. -C~ 94 bbls away, 84 gpm / 650 psi. -@ 140 bbls away, FCP 84 gpm / 830 psi. 15:00 - 16:30 1.50 BUNCO P RUNCMP Line up & U-Tube for 1.5 hrs. 16:30 - 17:00 0.50 BUNCO P RUNCMP Vacuum & clear lines. -Install Lubricator on Tree. Install BPV. -RD Lubricator. 17:00 - 17:30 0.50 BUNCO P RUNCMP Test BPV from below 1000 si / 10 minutes on Chart -Pass. 17:30 - 18:00 0.50 BUNCO P RUNCMP RD LRS. -RD: Secondary IA valve, Pump in flange. -Install Blank flanges. Install gauges. -Secure well. -----T/I/O = 0/0/0 psi. Printed: 5/11/2009 10:33:20 AM 12-07A, Well History (Post Rig Workover) Date Summary 05/08/09 T/I/O = 0/0/0 Pulled 4-1/16" CIW "H"BPV # 106 thru tree Q 102", 1-2' ext.used. Post rig, no problems. 05/09/09 WELL SHUT IN ON ARRIVAL. PULL BALL AND ROD FROM Q 8696' SLM. ATTEMPT TO PULL STA. 3 C~ 6031' MD / 6028' SLM. RAN 3.78" CENT., 3.75" LIB S/D Q 4739' SLM, PUSHED TO 5100' SLM, APPEARS TO BE OBSTRUCTION IN TUBING. 05/10/09 PULL STA. 3 RK-DGLV 6026' SLM / 6031' MD. PULL STA. 1 RK-DCK 2992' SLM / 3014' MD. SET STA. 1 RK-LGLVQ 2992' SLM / 3014' MD. MAKE MULTIPLE ATTEMPTS TO SET STA. 3 RK-OGLV. 05/11/09 MADE SEVERAL ATTEMPTS TO SET STA. 3 ~ 6026' SLM, (6031' MD). STA #3 EMPTY, RHC PLUG BODY IN HOLE. WELL LEFT SHUT IN, PAD OP NOTIFIED ON DEPARTURE. 05/11/09 WELL SHUT IN ON ARRIVAL. MADE ONE ATTEMPT TO SET RK-OGLV IN STA. 3 C«~ 6012'SLM / 6031' MD. CURRENTLY POOH. 05/12/09 SET RK-OGLV IN STA#3 C«3 6016' SLM. PULLED 4-1/2" RHC-M PLUG BODY FROM 8697' SLM. RAN 2-7/8" DUMMY GUN, SAMPLE BAILER & TAGGED TD C~ 10385' SLM. NO RECOVERY IN SAMPLE BAILER. LEFT WELL S/I,TURNED WELL OVER TO DSO. 05/15/09 T/I/0=310/1950/0+. Temp=Warm. IA FL (for DSO). AL on line, ALP=1950 psi. IA FL Q 6031' sta# 3 S/O (323 bbls). SV =Closed. WV, MV, SSV =Open. IA & OA = OTG. NOVP. 05/16/09 T/I/O = 310/1950/0+. Temp =Warm. TBG FL (EL). Well currently U-tubing. TBG FL C~ 2750' (42 bbls). SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 05/16/09 WELL ON GAS LIFT ON ARRIVAL, CIRCULATING GAS. INITIAL T/I/O = 400/1100/0. SHUT OFF PRIOR TO RIG UP. PUMPED 5 BBL METH AND 2 BBL DIESEL TO ADD TO HYDROSTATIC HEAD PRIOR TO RIH. RIH WITH 2.875" MAX OD GUN, LENGTH = 29'. T/I/O = 1080/1100/0. 05/17/09 PERFORATED INTERVAL = 10343' - 10362'. TIED INTO CNL DATED 1-JAN-1982. RAN RST LOG TO VERIFY TIE IN ON EARLIER PERFORATIONS BY TYING INTO NEUTRON LOG. APPEARS THAT PERFS ARE FROM 10354' - 10373'. THIS IS 11' DEEPER THAN ORIGINALLY PLANNED. RIG DOWN ELINE UNTIL FURTHER REVIEW OF LOGS. FINAL T/I/O = 1100 / 1100 / 0 PSI. WING, AL LEFT SHUT IN. JOB INCOMPLETE. 05/18/09 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 1325/1125/0 PSI. RIG UP E-LINE. RIH WITH 2-7/8" PJ OMEGA 6 SPF 60 DEG PHASING. 05/19/09 PERFORATE WITH 2-7/8" PJ OMEGA 6 SPF, 60 DEG PHASING, EH 0.34", PENE 36", GMS 16. GUN 1:10334'-12354' GUN 2: 10278'-10285' GUN 3: 10230'-10247' PERFORMED STATIC BHP SURVEY. 10330' (8800 TVD): BHP = 3286.7 PSI, BHT = 153.8 DEGF 10217' (8700' TVD): BHP = 3243.1 PSI, BHT = 196.3 DEGF 10103' (8600 TVD): BHP = 3198.8 PSI, BHT = 193.1 DEGF. WELL LEFT SHUT-IN. DSO NOTIFIED. FINAL 1150/1200/0. ***JOB COMPLETE*** Page 1 of 1 TREE = CNV DRLG Dl~AF' 20" CGNDUCTOR 110' I9-5/8" CSG, 47# L-80 Hydril 563. ID = 8.861" I 2,018' 9-5i8" CSG PATCH, 47# L-80 BTC. ID = 8.861" 2103' 13-3/8" CSG, 72#, N-80 BTC ID = 12.347" 2711' Minimum ID = 3.725" @ 8719' 4-1 /2" HES XN NIPPLE TOP OF 4-1 /2" SCAB LNR 4-U2" TBG, 12.0#. 13CR-80 VA(t1 TOP. .0152 bpf, ID = 3.958" TOP OF 7" LNR 9-5/8" X 7" BOT MC LNR TOP PKR I 8966' I 12-07A "'4-112" CHROME TBG 8 SCAB LNR 2, 016' ~ 4-1 /2" HES X NIP, ID = 3.813" 20$8' 9-5/8" HES CEMENTER 2363' 9-5/8" NALCO FOC 2489' 9-5/8" NALCO FOC 2077 9-5!8" ECP PKR GAS LIFT MANDRELS ST MD TVD DEV T`r'FE VLV LATCH PORT DATE 5 3014 3014 5 MMG DOME RK 16 05/12/09 4 4690 4521 43 MMG DMY RK 0 05/03/09 3 6031 5515 44 MMG SO RK 20 05/12/09 2 7412 6537 43 MMG DMY RK 0 05/03/09 1 8501 7348 39 MMG DMY RK 0 05/03/09 y 5$0' 4-1/2" HES X NIP, ID = 3.812" 6,611' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8646' 4-112" HES X NIP, ID = 3.812" 6,719' a-112" HES XN NIP, ID = 3.725" 8,709' 9-5/8" X 7" BKR G2 ZXP LTP w /BKR LNR HGR, ID = 6.30" 8733' S-1/2" WLEG. ID = 4.85" 8739' 7" X 4-1 /2" XO, ID = 3.958" I MILLOUT WINDOW (12-07A) 9271' - 9316' I 19-5/8" CSG, 47#, L-801 S00-95, ID = 8.681" I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 28 @ 10230' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10230 - 10247 O 05!19/09 2-7/8" 6 10278 - 10285 O 05/19/09 2-7/8" 6 10334 - 10354 O 05/19/09 2-7/8" 6 10354 - 10373 O 05/17/09 4-1/2" SCAB LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" I-~ 10500' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10563' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/30/81 ROW 176 ORIG COMPL ~' 2-07A SDTRK) 5/19/09 KJB/TLH INfI-IAL PERFS 04/28/97 LAST WORKOVER 05/04109 D-14 RWO 05/04/09 PJC DRLG CORRECTIONS 05/12/09 BSE/TI_H GI_A/ CIO j _ i 17" MARKERJTS (2 (a7 19.3' & 19.5') 1 LNR) I 10570' I PRUDHOE BAY UNfT WELL: 12-07A PERMff No: 181-1750 API No: 50-029-20409-01 SEC 18, T10N, R15E 459' FSL & 10' FEL BP Exploration (Alaska) oai2sios ~Cb~~b~`~~~I~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh fe x.r~~~,4 ~' r~t,~j N0.5209 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2-34/P-14 12017519 -- ---- RST .,arc o~ ~oior CD 3-03/J-33 AZ4D-00013 - RST 09/27/09 04/05/09 1 1 1 t 15-29A J-09A AXED-00022 AP30-00024 CH EDIT PDC-GR {LDL) _ RST L - 04/18/09 t 3-Ot/N-29 15-29A 12-07A AYKP-00008 AXBD-00022 AY3J RST ()~.~ - MEMORY LDL ~~~ -- ~/ ~ ~ °~~~ " ~ 03/24/09 01/20/09 04/18/09 1 1 1 1 t 1 -00021 USIT .- 04/20/09 1 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGNI Nr oNn wFTi uanurur_ nr.~e rnov GA/~LI TA. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consultin ervices 2525 Gambell Street, Suit 00 Anchorage, AK 903-2 ATTN: Beth I 1 i Received by: ' ~a ~~ • • _ ~~ rF ~ Y ~ "; ~ ~ SARAH PALIN, GOVERNOR P~ ~ ~ d ~' ~~ ~~+ ~t ~ ~+ L~Lt7•-7~A OIIr ~ l7[ti-7 ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA']CIOAT C011I11II55IO1~T ~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 r FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. ~ (~ PO Box 196612 ~'>~~ Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-07A Sundry Number: 309-125 Dear Mr, Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this ~ ~ day of April, 2009 Encl. f •~~ ~ `~~ STATE OF ALASKA ~~~~'~"'-`" / ~~ ALA OIL AND GAS CONSERVATION COMA~ION ~ APR ~ ~Q~~ ~ ~O9 ' <<~ APPLICATION FOR SUNDRY APPROVALL 20 AAC 2s.2so ~Iaska 011 ~ 6a~ Ctrrl~. Cammissiol~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing - ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 181-175 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number; P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20409-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 12-07A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028330 - 80' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10570' - 9092' - 10535' 9061' 8796' Yes, See Diagram in Len th iz M TVD B rst II Structural r 73' 7 ' 7 ' 1 520 rf 2711' 1 - / " 2711' 2711' 4930 2670 Intermedi 9271' 9-5/8" 9271' 7962' 6870 4760 Pr i n Liner 1597' 7" 8 66' - 10 65' 7716' - 9087' 81 0 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10226' - 10490' 8788' - 9021' 4-1/2", 12.6# 13Cr / L-80 9042' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 8762'; 9-5/8" x 4-1/2" TIW 'HBBP' packer 8886' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 20, 2009 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564-5683 Printed Name Da ' Reem Title Engineering Team Leader _ Prepared By Name/Number: Signature Phone 564-5743 Date ~~~ o Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: _~~ Conditions of approval: Notify Commission so that a representative may witness _ \O ~ _~ S ~W~~S 5 ~ -- - ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~© ~~~ ~. ~~~~ I ~ ~Q ~ (p S \ M~ ~i~--~.v ~ ~r~r~~C? <-~~5~ Subsequent Form Required: l...l~~ APPROVED BY ~y A roved B : COMMISSIONER THE COMMISSION Date ' I~ - Form 10-403 Revised 06/006 ~ o y Submit~In upl~icate • • 12-O7a Expense Rig Workover Scope of Work: Repair IA x OA communication to gas. Pull 4-1h" 13Cr-80 completion, cut and pull 9-5/8" casing, run and cement to 9-5/8" surface casing, test 9-5/8" casing, mill and retrieve permanent packers at 8,762' and 8,886'. Cleanout the 7" liner, run and fully cement a 4-1/2" liner and run 4-1/2" 13Cr-80 completion. MASP: 2395psi Well Type: Producer Estimated Start Date: April 20, 2009 Production Engineer: Katrina Cooper Intervention Engineer: David Bjork Pre-Ria Work Reauest: F 1 CMIT-TxIA to 3,500psi through open GLM at 8,567' MD, MIT-OA 1000psi record LLR if necessa E 1 Power Jet cut 4-~/z" 13Cr-80 tubing at 8,755' MD, near the top of the first pup above the acker Reference tubin tall dated 04-27-97 . F 2 CMIT-TxIA to 1,OOOpsi. Circulate well with 8.6ppg seawater and freeze protect to 2000'. W 3 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 4 Set a BPV in the tubin han er. O 5 Verify that the well has a competent cellar. Remove the wellhouse & flow .line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-'/2" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-'h" tubing string to the cut. 3. Run USIT log to determine top of cement in 9-5/a" x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" as the well has two tested barriers (XXN plug at 8,796' and RBP) to the reservoir. 6. Run and fully cement new 9-5/8" casing to surface. Pressure test to 3,500psi 7. Retrieve bridge plug. ~C~~cgnoJ~ Lc~Se~S~~i~'`'~'`~ 8. Continue to de-complete the well/pull the remaining completion string (includes the recovery of 2 packers + 2 tubing-tail assemblies. 9. Make clean-out run to PBTD in the 7" production liner at 10,535' MD (scrape 9-5/8" casing to below planned top new production liner). 10. Run and fully cement a new 4-1/2" chrome scab production liner from the PBTD at --10,535' MD to --8700' MD. Pressure test to 3,500psi. 11. Run 4-1/2" chrome completion (production packer setting depth at 8640' MD). 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. TREE= 5-3/16" GRAY WElLHEA = GRAY ACJUATOR„= ~ AXELSON KB. EL~1/ = 80.0' BF. ELEV = NA KOP - 3300' Max Angie = 46 @ 7700' Datum MD = Datum TV D = 88 • 10330' 00' SS 20" CONDUCTOR 110' 13-3/8" CSG, 72#, L-80, tD = 12.347" I~ 2711' Minimum ID = 3.725" @ 8796' 4-1 /2" HES XN Nipple 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~ 8817' 4-1/2" TBG STUB 8821'dG ~P OF BOT TIEBACK SLEEVE I-~ 8966' 9-5/8" X 7" BOT MC LNR HGR $972' 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-i 9042' 19-5l8" CSG, 47#, L-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 12/24/81 ANGLE AT TOP PERF: 29 @ 10226' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10226 - 10252 C 08104/89 3-3/8" 8 10334 - 10362 C 04/25/82 3-3/8" 4 10374 - 10388 C 09/25/82 3-3/8" 4 10397 - 10406 C 12/13/85 3-3/8" 4 10418 - 10443 C 12/13/85 3-3/8" 4 10453 - 10460 C 12/13/85 3-3/8" 4 10470 - 10490 C 12/13!85 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ® ' 20$1' ~4-1/2" CAMCO BAL-0 SSSVN, ID = 3.812" 2367 9-5l8" FOC 2493' 9-5/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3474 3467 14 TB DOME RA 16 05/01/97 2 3612 3601 16 TB DMY RA 0 04/28/97 3 7089 6300 40 TB DOME RA 16 05/01/97 4 8567 7399 39 TB SO RM 28 08/10/05 8762' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" $796' 4-1/2" HES XN N~, ID = 3.725" $796' 4-1/2" HES XXN PLUG (06/18/07) 8825' 4-1/2" UNIQUEOVERSHOT $$64' 4-1/2" OTIS X NIP, ID = 3.813" 8886' 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 4.00" 9030' ~4-1/2" OTIS XN NIP, ID = 3.725" 9042' 4-1/2" TUBaVG TAIL WLEG 9043' ELMD TT LOGGED 06/27/96 ~_ MILLOUT WINDOW (12-07A) 9271' - 9316' 10285' I-17" MARKER JTS (2 @ 19.3' & 19.5') "FISFf' #1 RUBBER ~BNEM1(f FROM ~P (11113/94). #2 BKR RUBBER COVER (9-2-89). DEPTH UNKNOWN. 10535' I~ ~~ ~ I~ 10570' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/30/81 ORIG COMPL 12-07A sDTRK 6/8/07 AMB/PA 20' CONDUCTORCORR(1981) 04/28/97 LAST WORKOVER 6/18/07 JLJ/PJC SETXXN PLUG @ 8796' 03/07/02 CH/TP CORRECTIONS 09/29/02 BM/TP WANERSAFETY NOTE 10/01/05 EZUPAG WANER SFTY NOTE DELETED 12/14/05 /TLH GLV GO (OS/10/05) PRUDHOE BAY UNff WELL: 12-07A PERMff No: 181-1750 API No: 50-029-20409-01 SEC 18, T10N, R15E 459' FSL & 10' FEL BP Exploration (Alaska) SA Y NOTES: ""* 4-1/2" CHROMETBG RUN TO 88'~ISH ON BTM. "** 'I 2-07A I TREE = Cameron 5K 4" WELLHEA = McEvoy SSH ACTUATOR= KB. ELL~V = 80.0' BF. ELEV = NA KOP = 3300' 20^ CONDUCTOR Max Angle = 46 @ 7700' Datum MD = 10330' DatumTVD= 880' ~S ~ 12-07A •••Proposed 2008 RW O ••• 110' 2,000' 4-1/2" HES X NIP, ID = 3.812" 9-5/8" 47# L-80 Hydril 563 2,140' - 9-5/8" ES Cementer 2,200' - 13-3/8" CSG, 72#, L-80, ID = 12.347" I-~ 2711' _ ._ ;; ~ _ 8, 600' CAA S I IFi MA NI-)RFI C ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 8520 7362 39 MMG DMY 2 7361 6500 43 MMG DMY 3 6010 5500 44 MMG DMY 4 4661 4500 43 MMG DMY 5 3001 3000 5 MMG DCK - 8,590' 4-1/2" HES X NIP, ID = 3.812" 8,600' 9-5/8" X 4-1l2" BKR S-3 PKR, ID = 3.875" 8,634' 4-1/2" HES X NIP, ID = 3.812" M in im u m ID = 3.725" @ xxxx' 4-1/2" HES XN Nipple ~ TOP OF BOT TIEBA CK SLEEVE ~ 9-5/8" X 7" BOT MC LNR HGR I 19-5/8" CSG, 47#, L-80, ID = 8.681" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9271' i PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 29 @ 10226' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" Lowest Per -10,370' MD !0 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 8,694' 4-1/2" HES XN NIP, ID = 3.725" 8,700' 9-5/8" x 7" Liner Top crosse~ over to 4-1/2" scab liner MILLOUT WINDOW (12-07A) 9271' - 9316' - 10285' 7" MARKER JTS (2 @ 19.3' & 19.5') 10,390' 4-1/2" liner PBTD 10,450' 4-112" liner shoe ~ 10535' PBTD ~ TD ~ I 10570' I "FISFI" #1 RUBBER B_BNENT FROM BP (17/13/94). p2 BKR RUBBER COVER (9-2-89). O~rFi UNKNOWN. DATE REV BY COMMENTS DATE REV BY COMMENTS 12/30/81 ORIG COMPL (12-07A SDTRK) 6/8107 AMB/PAG 20' CONDUCTOR CORR (1981) 04!28/97 LAST WORKOVER 6/18/07 JLJ/PJC SETXXN RUG @ 8796' 03/07/02 CH/TP CORRECTIONS 412/09 DRB PLANNED RWO 09/29/02 BM/TP WANER SAFETY NOTE 10/01/05 EZUPAG WANER SFTY NOTE DELETED 12/14/05 /TLH GLV C/O (08/10/05) PRUDHOE BAY UNff WELL: 12-07A PERMfT No: 181-1750 API No: 50-029-20409-01 SEC 18, T10N, R15E 459' FSL & 10' FEL BP Exploration (Alaska) RECEIVED- _ STATE OF ALASKA _ AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 80 KB 8. Property Designation: ADL-028330 11. Present Well Condition Summary: Total Depth measured 10570 true vertical 9091.83 Effective Depth measured 10535 true vertical 9060.92 Casing Conductor Surface Production Liner Length 83 2686 9248 1597 Size 20" 94# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 Perforation depth: Measured depth: 10226 - 10490 True Vertical depth: 8788.41 - 9021.2 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x FEB 0 2 ?n06 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development [;?I Stratigraphic D . . ." '" Ion Stimulate 0 AAI:R9ra¡¡8 Waiver D Time ExtetíšlÒn 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 181-1750 6. API Number: 50-029-20409-01-00 9. Well Name and Number: Exploratory Service 12-07 A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 8780 XXN 10535 feet feet MD 27 - 110 25 - 2711 23 - 9271 8966 - 10563 TVD Burst Collapse 27 - 110 1530 520 25 - 2710.93 4930 2670 23 - 7961.9 6870 4760 7716.22 - 9085.65 8160 7020 Closed Closed &(;fflNED F 4-1/2" 12.6# L-80 21 - 9043 4-1/2" Baker S-3 Perm Packer 4-1/2" TIW HBBP Packer 8762 8886 RBDMS BFL FES 0 6 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory D Development [;?Ii 16. Well Status after proposed work: Oil [;?Ii Gas D WAG Tubing pressure Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Prioted N,m, Sh'm"'''.. V""'" L-. . Signatur~~:I''''¿¡ &t~ Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 1/31/2006 , L Submit Original Only tit e 12-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE .1 .<;.C. SÜMM~.!I~ I 1/2/2006 T/I/O= 1900/1760/1000. Temp= SI. Sleed OA < 300 psi (secure). AIL spool removed & 3" integral installed on IA. Tubing pressure increased 10 psi. lAP increased 10 psi. OAP increased 20 psi. OA FL @ 60' (4 bbls). Sled OAP to slop trailerfrom 1000 psi to 200 psi in 30 minutes (all gas). Monitored for 30 minutes. OAP increased 10 psi. Final WHP's= 1890/1750/210. 1/3/2006 T/I/O= 1900/1760/340. Temp= SI. WHP's post-bleed (secure). lAP increased 10 psi. OAP increased 130 psi. 1/7/2006 ***WELL SHUT IN ON ARRIVAL *** SET XXN TSG. TAIL PLUG @ 8780' SLM & TEST LEFT WELL SHUT IN NOTIFY DSO OF WELL STATUS 1/9/2006 T/I/O=630/630/630. Temp=SI. Sleed WHP's <300 psi (Eval for Secure) Prob Well Day 10. T FL @ 8567' (sta #4, SO) (130 bbls). IA FL @ 8567' (sta #4, SO) (460 bbls). OA FL @ 60' «5 bbls). Sled TP down process from 630 psi to 190 psi in 10 minutes. Sled lAP down process from 630 psi to 190 psi in 2 hours. Sled OAP simultaneous w/lA. **Note** F/L needs re-freeze protected. Final T/I/O=190/190/190. 1/10/2006 T/I/O=200/200/200 Temp= S/I Monitor (Post Sleed) (Eval for secure) T/I/O pressures all increased 10 psi from yesterday. No AIL. Integral flange on IA. 1/11/2006 T/I/O = 190/190/180. Temp = SI. Monitor (post bleed) (eval for secure) PROS WELL Day 11. TSG and lAP decreased 10 psi overnight. OAP decreased 20 psi overnight. FLUIDS PUMPED I BBLS I o TOTAL 12-07A (PTD# 1811750) Classified as Problem Well e e rï. \I~io ~ ',<Aft \ Suhject: 12-07 A (PTnµ. 1811750) Classified as Problcm \Vcll From: "Recves, Donald F" <Rcc\'csDf@bp.com> Date: Tuc, 03 .Ian 2006 05:42:31 -()900 To: "Gcrik, Bob G" <Bob.Gcrik(q}bp.com>.. "GPB, FSUSIP/STP Area Mgr" <GPBFSITL@bp.com>, "GPB, FS I DS Ops Lead" <GPßFS I DSOpsLead@bp.com>, "GPß, FSl DS 12 Operator" <GPBFS IDS 120perator(q}bp.com>, "Rossberg, R Stevcn" <Stevcn.Rossberg@hp.com>, ....~SU, ADW \Vcll Operations Supervisor" <NSUADW\VeIlOpcrationsSupcrvisor(l:i),hp.com>, "GPB, Wclls Opt Eng" <GPßWdlsOptEng@hp.com>. "Kur/, John" <john.kurz(a:bp.com>, "AOGCC Jim Regg (E-mail)" <~imJcgg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <wintol1._.aubcrt@admin.statc.ak.us>, "NSU, AD\V wr. & Completion Supervisor" <.NS lJ ADW\VL&Comp IctionS upervisor@bp.com> cc: "NSU, ADW Well Integrity Engincer" <NSUADWWclUntcgrityEngineer@hp.c.om>, "\Vinslow, Jack L." <Lyonsw@.bp.com>, "MCCOLLUM, CODY 0 (VECO)" <Cody.McCollum@bp.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@bp.com> All, Well 12-07 A (PTD# 1811750) has been found to have sustained casing pressure on the OA The TIO's on 01/02/06 were 1900/1760/1000. The well has known TxlAxOA communication and has been classified a Problem Well. The plan forward for this well is as follows: 1. SL: Set TIP @ 8796' MD 2. DHD: Bleed WHPs < 300 psi A wellbore schematic has been included for reference. Please call if you have any questions. «12-07 Apdf» Thanks, Donald Reeves Well Integrity Engineer - Filling in for Anna Dube 907-659-5102 907-659-5100 Pgr 1154 " , Content-Description: 12-07 A.pdf Content- Type: application/octet-stream Content-Encoding: base64 I of 1 1/5/2006 8:55 AM TREE = 5-3/16" GRAY WELLHEA.D = GRAY ~,""=""''' A CTUA TOR = AXELSON ~^""',......""",.,,-~ KB, ELEV = 80.0' BF. NA KOP'" 3300' Max Angle'" 46 @ 7700' Datum MD '" 1 0330' Datum lVD '" 8800' SS e le-5/8" FOC 19-5/8" FOC 113-3/8" CSG, 72#,L-80, ID= 12.347" Minimum ID = 3.725" @ 8796' 4-1/2" HES XN Nipple 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I TOP OF 4-1/2" TBG STUB 1 TOP OF BOT TIEBACK SLEEVE 19-5/8" X 7" BOT MC LNR HGR I 14-1/2" TBG, 12.6#, l-80, .0152 bpf, 10 = 3,958" I 9042' 1 9-5/8" CSG, 47#, l-80, 10'" 8.681" ÆRFORA TION SUMI'v1ARY REF lOG: BHCS ON 12/24/81 ANGLE AT TOP ÆRF: 29@ 10226' Note: Refer to A'oduction DB for historical perf data SIZE I Opn/Sqz OA TE 3-3/8" 4 10226 - 10252 0 08/04/89 3-3/8" 8 10334 - 10362 0 04/25/82 3-3/8" 4 10374 - 10388 0 09/25/82 3-3/8" 4 10397 - 10406 0 12/13/85 3-3/8" 4 10418 - 10443 0 12/13/85 3-3/8" 4 10453 - 10460 0 12/13/85 3-3/8" 4 10470 - 10490 0 12/13/85 12-07 A DA TE REV BY COMMENTS SAFETY NOTES: ... 4-1/2" CHROM E TBG RUN TO 8817'. FISH ON BTM. *** 2081' -14-1/2" CAMCO BAL-O SSSVN, 10'" 3,812" GAS LIFT MANDRELS ST MD lVD VLV LATCH PORT DATE 1 3474 3467 RA 16 2 3612 3601 16 DMY RA 0 3 7089 6300 40 DOME RA 16 4 8567 7399 39 SO RM 28 08/10/05 8762' -19-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 8796' --14-1/2" HES XN NIP, 10'" 3,725" I 8817' -14-1/2" UNIQUE OVERSHOT ASSY I 8864' --I4-1/2"OTISXNIP,ID=3.813" 8886' -19-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.00" 9030' 9042' 9043' --14-1/2" OTIS XN NIP, ID = 3.72S" I -14-1/2" TUBING TAil WLEG I H ELMD TT LOGGED 06/27/96 I 9-5/8" CSG MILlOUT WINDOW 9271' - 9316' (SECTION MilL) 10285' H7" MARKERJTS (2 @ 19.3' & 19.5') I "FISH" #1 RUBBER ELEMENT FROM IBP (11/13/94). #2 BKR RUBBER COVER (9-2-89). DEPTH UNKNOWN, 10535' ~ 10570' PRUDHOE SA Y UNIT WELL: 12-07A ÆRMIT No: 181-17S0 API No: SO-029-20409-01 SEC 18, T10N, RiSE 459' FSL & 10' FEL BP Exploration (Alaska) 12-07A (PTD# 1811750) Classified as Problem Well ) Subject: 12-07A (PTD# 1811750) Classified as Problem Well . From: "Reeves, Donald F" <ReevesDf@bp.com> '5'í\.. . ~11i>1,,6" Date: Sun, 07 Aug 2005 08:55:00 -0800 \ ~q To: "Gerik, Bob G" <GerikBG@bp.com>, "GPB, FSlISIP/STP Area Mgr" <GPBFSITL@bp.com>, "GPB, FSl DS Ops Lead" <GPBFSIDSOpsLead@bp.com>, "Rossberg, R Steven" <RossbeRS@bp.com>, "NSD, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@bp.com>,"GPB, Wells Opt Eng" <GPBWellsOptEng@bp.com>, "AOGCC Jim Regg(E-maÜ)" <jim_regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@bp.com>,."GPB, FS I.DS 12 Operator" <GPBFSIDS 12Operator@bp.com> cC: "NSU, ADWWell Integrity Engineer" <NSUADWWellIntegrityEngineer@bp.com>,. "Winslow, Jack L." <Lyonsw@bp.com> All, Well 12-07 A (PTO# 1811750) has been found to have sustained casing pressure on the IA. The TIO's on 08/06/05 were 2060/2140/1970. The well is currently waivered for IAxOA communication and failed a TIFL on 08/06/05. The plan forward for this well is as follows: 1. DHO: TIFL - FAILED 2. SL: Change out OGL V 3. DHO: Re- TI FL A wellbore schematic has been included for reference. Please call if you have any questions. «12-07 A. pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-5102 907 -659-5100 #1923 pgr .... ~) f: "OU\'1 i --. .., A~ ~t\"N E ~ t~ (- P (,.'i d L ,. ·~,tpd ,,(J ~. -'" ',.'- ' Content-Description: 12-07 A.pdf 12-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCf ~yP G~~y P :J-A. 2\~ 6'D7ù~ 31. I ~ òl ~ C¿) 4: Z F~b~V~ O~ \q7û~,' ~D~'¡ '3<0 . 6 l-~ +furs k0tal s: ~ 9!q/ðÇ 1 of 1 8/9/2005 8:37 AM ) 1REE= 5-3/16" GRAY WELLHEA 0 = GRA Y "ActtJA to ·Ff= ·········..·þj("ELSOi\i 'kB. ELÐJ"= 80.0; BF. B.. EV ..= .. ..... . ... ·······NA köp·~ . ..m ..···..·..··..··..·····á3Ö"ä Max Angle = 46 @ 7700' ··D:1ïÚiï1·MÖ .;;... ....... ....... ··1"0330' Datum lVO = 8800' SS 12-07A 19-5/8" FOC 1-1 19-5/8" FOC 1-1 2367' 2493' 113-318" CSG, 72#, L-80, 10 = 12.347" I.., 2711' Minimum ID = 3.725" @ 8796' 4-1/2" HES XN Nipple 4-1/2"TBG,12.6#,13-CR,.0152bPf,10=3.958" 1-1 8817' 1 ITOPOF 4-1/2" TBG S1UB I.., 8821'dpm 1 I TOP OF BOT TEBACK SLEEVE 1-1 19-5/8" x 7" BOTMC LNR HGR 1-1 8966' 8972' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" 1-1 9042' 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9271' r-- ÆRFORA 1l0N SLMMA. RY REF LOG: BHCS ON 12/24/81 ANGLE AT TOP PERF: 29 @ 10226' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10226 - 10252 0 08/04/89 3-3/8" 8 10334 - 10362 0 04/25/82 3-3/8" 4 10374 - 10388 0 09/25/82 3-3/8" 4 10397 - 10406 0 12/13/85 3-3/8" 4 10418-10443 0 12/13/85 3-3/8" 4 10453 - 10460 0 12/13/85 3-3/8" 4 10470 -10490 0 12/13/85 r--- 1-- µ :8: :8: J 8 -- L ::g r~ } ) SAFETY NOTES: 4-1/2" CI-ROMETBG RlJII TO 8817'. FISH ON BTM. *** lAx OACOMM. OPERATING PRESSURE OF THE 13-318" ANNULUS MUST NOT EXCEED 2000 PSI (09/22/02 WAIVER) *** 2081' 1-14-1/2" CArvt::O BAL-O SSSVN, [) = 3.812" ~ GAS LIFT MA.NDRB..S ST MD TV 0 DEV 1Y PE V LV LA TCH PORT [)A. TE 1 3474 3467 14 TB RA 2 3612 3601 16 TB RA 3 7089 6300 40 TB RA 4 8567 7399 39 TB RA ~ J I , 8762' 1-19-5/8" X 4-1/2" BKR 5-3 PKR, 10= 3.875" 8796' 1-14-1/2" HESXN NIP, 10= 3.725" 1 8817' 1"'4-1/2" UNQUEOVERSHOT ASSY 1 8864' 1-14-1/2"OTSXNIP,ID=3.813" 1 8886' 1"'9-5/8" X 4-1/2" HN HBBP PKR, 10 = 4.00" 1 9030' 1-14-1/2" OTS XN NIP, 10 = 3.725" 1 9042' 1-14-1/2" TUBING TAIL WLEG 1 9043' I.., ELMO 1T LOGGED 06/27/96 1 9-5/8" CSG MIL LOur WlNOOW 9271'- 9316' (SECllON MLL) 1 10285' 1-- 7"MA.RKERJTS (2@19.3'&19.5') 1 "FISH" #1 RUBBER ELEMENT FROM BP(11/13194). #2 BKR RUBBER COVER (9-2-89). DEPTH UNKNOWN. 1 10535' 1--1 PBm I 17"LNR, 29#, L-80, .0371 bpf, [)=6.184" 1-1 10563' 1 [2£]--1 10570' DATE REV BY COI'vTv'IENTS [)A. TE REV BY COMrvENTS 12/30/81 ORIG COMA.. (12-07 A SDTRK) 4/28/97 LA ST WORKOV ffi 12/12/00 SIS-SLT CO fIN ffiTED TO C'A fIN AS 2/26/01 SIS-MD RNAL 03/07/02 CWTP CORRECTIONS 09/29/02 BrvvTP WAN ER SAFÐY NOTE PRUDHOE BA Y UNIT IJIÆLL: 12-07A PERMIT No: 181-1750 A A No: 50-029-20409-01 SEe 18, T10N, R15E 459' FSL & 10' FB.. BP Explo ratio n (A las ka) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor' FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7, 2001' I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and42 components with 1 failure. The.surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/U~ad: Pmdhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 We~ Permit Separ Set L/P Test Test Test Date oi~ WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 12-01 1790230 12-02 1790320: 12-03 1790410 160 i50 150~ P ' P OIL 12-04A 1811870 160 150 150 P P 12-05 1790550 12-06A 1920540 , 160: 150 150 P i, P .... OIL ~~- 1811750 160 150 140 P P OIL 12'08B 1811670 160 150 140 P P 'OIL 12-09 1800930 160 150 125 P P OIL 12-10A 1920890 ~, 160 'i5'0 150 P P ' oIL ,, :12-11 1810730 i2-12 1810830 160 " i50 90 'P 4 ' 1.2-13B 1960170 ' 160 ' 150 '150 P e ' (~IL , ,, 12-14A 1981460 160 150 150 P P OIL 12-15 ' 1830320! 160 150 150 '.P P 'OIL 12-16A 1931480] .160 150 ~150 P P OIL 12-17 1830040 160 150 150 P P OIL , , 12'18 1822060 160 150 150 P P OIL 12-19 1821980 12-20 1821910 12-21 1840480 12-22 ' 1840600 1'60[ '150 " 125~ P e ' 0IL 12-23 1840580 ~ , , 12-25 1831660 12-26 1840140 ' '160 150 ' 125 e e ' '0IL 12-27A 1990390 ..... 12-28A 1990330 160 ' 150 170 e e ' OIL . 12-29 1840320 , 1'2-30 188'1420 ' ' ' 12-31 1890010 :12-32 1890'110 160 150 150 P P OIL 12-33 1890100 12-34 '1941370 'i60 '150 150 P' P OiL 12-35 1951300 160 ' 150 100 ' 12-36 1951580' 160 150 1~0 P P " OIL ,, RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p_]~C~S Well Number Wells: Permit Number 21 Separ Set L/P Test Date PSI PSI Trip Code Passed Components: 42 Failures: 1 Failure Rate: 2.38% I-190 Day Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS K~ .... STATE OF ALASKA [' ALAS .~IL AND GAS CONSERVATION C~v,,vllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: i--] Operation Shutdown [--I Stimulate [--I Plugging I~l Perforate [--I Pull Tubing [---I Alter Casing I~ Repair Well [--I Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 459' NSL, 10' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 902' SNL, 1341' WEL, SEC. 20, T10N, R15E, UM At effective depth At total depth 924' SNL, 1231' WEL, SEC. 20, T10N, R15E, UM 5. Type of well: [] Development ~] Exploratory r-'] Stratigraphic F-IService 6. Datum Elevation (DF or KB) KBE = 80' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-07A 9. Permit Number / Approval No. 81-175 10. APl Number 50-029-20409-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10570 feet true vertical 9091 feet Effective depth: measured 10535 feet true vertical 9061 feet Plugs (measured) Junk (measured) Casing Length Structural Conductor 73' Surface 2631' Intermediate Production 9236' Liner 1597' Size Cemented 20" 475 sx Arctic Set 13-3/8" 2368 sx F°ndu 9-5/8" 1180 sx Class 'G' 7" 587 sx Class 'G' MD TVD 73' 73' 2711' 2711' 9316' 10563' ORIGINAL 7999' 9086' Perforation depth: measured true vertical 10226'-10252', 10334'-10362', 10374'-10388', 10396'-10405', 10417'-10442', 10452'-10459', 10469'-10489' 8788'-8811', 8884'-8909', 8920'-8932', 8939'-8947', 8958'-8980', 8989'-8995', 9004'-9021' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr, FOX to 8591'; 4-1/2", 12.6#, 13Cr, NSCT 8591' - 8825'; 4-1/2", 12.6#, L-80, NSCT 8830'-9042' Packers and SSSV (type and measured depth) TIW HBBP packer at 8886'; Baker 'S-3' packer at 8762'; Camco BaI-O SVLN at 2081' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl jUL 16 1997 Alaska 0ii l Gas Cons. C0 Prior to well operation: Subsequent to operation: Casing Pressure Tubing Pressure 15. Attachments 116. Status of well classifications as: [--] Copies of Logs and Surveys run I [~ Oil [--I Gas [~ Suspended [~ Daily Report of WellJ~rations I 17. I hereby Certify that~e fo, l~goin~ ~ue~d correct to the best of my knowledge Signed Dan Stoltz/~~r~~ Title Senior Drilling Engineer Forr~ 10'-"404 Rev. 06/15/88 Service Prepared By Name/Number: Date .?'~/~_ Terrie Hubble, 564-4628 Submit In Duplicate Facility Date/Time 25 Apr 97 26 Apr 97 27 Apr 97 28 Apr 97 Progress Report PB DS 12 Well 12-07A Page 1 Rig Doyon 16 Date 16 June 97 07:00-11:00 11:00-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-20:00 20:00-22:00 22:00-23:30 23:30-00:00 00:00-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-09:30 09:30-11:30 11:30-11:45 11:45-18:00 18:00-18:30 18:30-21:00 21:00-00:30 00:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:30 23:30-01:00 01:00-06:00 06:00-06:30 06:30-07:30 07:30-11:00 11:00-13:30 13:30-14:30 14:30-16:30 16:30-17:30 17:30-18:00 Duration 4hr 2hr 1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr lhr 1/2 hr lhr lhr 2hr 1/4 hr 6-1/4 hr 1/2 hr 2-1/2 hr 3-1/2 hr 3hr 1/2 hr lhr lhr 1/2hr 11-1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 1-1/2 hr 5hr 1/2 hr lhr 3-1/2 hr 2-1/2 hr lhr 2hr lhr 1/2 hr Activity Installed Tubing handling equipment Circulated at 0.00 ft Circulated at 0.00 ft Circulated at 0.00 ft Monitor wellbore pressures Circulated at 8834.00 ft Installed Internal BOPs Removed Xmas tree Serviced Casing hanger Rigged up BOP stack Tested BOP stack Tested BOP stack Held safety meeting Rigged up Lubricator Pulled Tubing on retrieval string to 8830.00 ft Circulated at 8025.00 ft Held drill (Kick while tripping) Laid down 6070.00 ft of Tubing Held safety meeting Laid down 2760.00 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 0.00 ft (4-1/2in OD) Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 40.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 7110.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8821.00 ft (4-1/2in OD) Circulated at 8810.00 ft Circulated at 8800.00 ft Installed SCSSSV control line Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Set Permanent packer at 8762.00 ft with 3500.0 psi Rigged down BOP stack Rigged up Adapter spool Rigged up Lubricator Circulated at 2080.00 ft Installed Internal BOPs Rig moved 0.00 % Facility PB DS 12 Progress Report Well 12-07A Page 1 Rig Doyon 16 Date 16 June 97 Date/Time 25 Apr 97 26 Apr 97 27 Apr 97 28 Apr 97 07:00-11:00 11:00-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-20:00 20:00-22:00 22:00-23:30 23:30-00:00 00:00-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-09:30 09:30-11:30 11:30-11:45 11:45-18:00 18:00-18:30 18:30-21:00 21:00-00:30 00:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:30 23:30-01:00 01:00-06:00 06:00-06:30 06:30-07:30 07:30-11:00 11:00-13:30 13:30-14:30 14:30-16:30 16:30-17:30 17:30-18:00 Duration 4hr 2hr 1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr lhr 1/2 hr lhr lhr 2hr 1/4 hr 6-1/4 hr 1/2 hr 2-1/2 hr 3-1/2 hr 3hr 1/2 hr 1 hr lhr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 1-1/2 hr 5hr 1/2 hr lhr 3-1/2 hr 2-1/2 hr lhr 2hr lhr 1/2 hr Activity Installed Tubing handling equipment Circulated at 0.00 ft Circulated at 0.00 ft Circulated at 0.00 ft Monitor wellbore pressures Circulated at 8834.00 ft Installed Internal BOPs Removed Xmas tree Serviced Casing hanger Rigged up BOP stack Tested BOP stack Tested BOP stack Held safety meeting Rigged up Lubricator Pulled Tubing on retrieval string to 8830.00 ft Circulated at 8025.00 ft Held drill (Kick while tripping) Laid down 6070.00 ft of Tubing Held safety meeting Laid down 2760.00 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 0.00 ft (4-1/2in OD) Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 40.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 7110.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8821.00 ft (4-1/2in OD) Circulated at 8810.00 ft Circulated at 8800.00 ft Installed SCSSSV control line Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Set Permanent packer at 8762.00 ft with 3500.0 psi Rigged down BOP stack Rigged up Adapter spool Rigged up Lubricator Circulated at 2080.00 ft Installed Internal BOPs Rig moved 0.00 % ARCO Alaska, Inc. Date: September 20, 1994 P.O. Box 100360,f chorage, AK Transmittal #: 94111 99510,~ ~, Subject: ARCO Static Pressure Survey's From/Location: Karla Zuspan/ATO-1529 /~K/~. ) Telephone: (907) 263-4310 ~ ~~.~ ~'~,/ ~ ~ To/Location: Distribution Number, (M-D-Y) . 04-45i 07-05-94 t Pressure Survey 1 SCH 11-29i ! 07-08-94 i Pressure Survey i 1 SCH 11-36 ~ 06-09-94 i Pressure Survey ! 1 SOH 12-07A i 06-06-941 Pressure Survey 12-10A i 06-07-94 i Pressure Survey 12-12 i 06-08-94i Pressure Survey 12-16A f 07-07-94 i Pressure Surveyi 1 SOil 12-26 i 06-08-94 t Pressure Survey i I SOH 13-31 ! 06-09-94 i Pressure Survm/ i I SCH 13-35 t 06-09-94 ! Pressure Survey { 1 SCH 18-01 i 06-04-94! Pressure Survey 18-08 ! 06-10-94t,, Pressure Survey Number of Records: 13 Karla Zuspan Distribution: Central Files BPX State of Alaska Mobil Please le receipt Phillips Exxon D&M Date: ismi ARCO Alaslu~ Inc. is a SuI~I~IaW of AMcRlchf~ldComlxmy r ALASKA OIL AND GAS CONSERVATION COMM c>iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing X Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 459' NSL, 10' WEL, SEC. 18, TION, R15E At top of productive interval 902' SNL, 1341' WEL, SEC. 20, TION, R15E At effective depth At total depth 924' SNL, 1231' WEL, SEC. 20, TION, R15E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development X Exploratory Sb-a~Jgraphic 10570 feet Plugs (measured) 9091 feet 6. Datum elevation (DF or KB) KBE-- 80' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-7A 9. Permit number/approval number 81~175~Conservation order #258 10. APl number 50- 029-20409-01 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured true vertical 10535 feet Junk (measured) 9061 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length true vertical Tubing (size, grade, and measured depth) Size Cemented 4-1/2", L-80 Tubing to 9042' MD Measured depth True vertical depth RECEIVED ~0V - 4 ~994 kt~ska 0ii & 6as Cons. Commission Anch0ra~e Packers and SSSV (type and measured depth) 9-5/8" TIW 'HBBP' Packer @ 8886' MD; 4-1/2" Camco 'TRDP-4A' SSSV @ 2121' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ /"~ ~,~ TitleDrillin~En~ineerSupervisor Form 10-404 R~ 0(~/15~8~} Date SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIO~'~ PAGE: 1 WELL: DS 12-07A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/21/94 03:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 10/21/94 ( 1) TD:10570 PB:10535 10/22/94 (2) TD:10570 PB:10535 10/23/94 (3) TD:10570 PB:10535 TAKE ON SEAH20 IN PITS MW: 0.0 LAY OVER DERRICK, MOVE CAMP, RIG, PITS AND SHOP FROM DS-4 TO DS-12, RAISE DERRICK. SPOT RIG OVER WELL, SPOT PITS, CAMP AND SHOP. HOOK UP LINES, TAKE ON SEAWATER IN PITS. RIG UP ON TREE TO CIRC OUT DIESEL. WORKING ON TIGHT LDS MW: 0.0 TAKE ON SEAWATER IN PITS. R/U HI PRESSURE LUBRICATOR, PULL BPV, R/D LUBRICAOTR, 0-PSI ON TBG. CIRC DOWN TBG, TAKE DIESEL RETURNS FROM ANNULUS UNTIL FLUID CLEANS UP, CIRC DOWN ANNULUS, TAKE DIESEL RETURNS FROM TBG, CBU, WELL STABLE. SET BPV, INSTALL TEST DART, TEST, PULL DART. N/D TREE AND ADAPTER FLANGE. N/U BOPE, HAMMER UP ALL BOP BOLTS, HOOK UP ALL CONTROL LINES TO STACK. TEST BOPE, TEST BLIND RAMS, CHOKE MANIFOLD, HI-LOW PRESSURE. ATTEMOT TO M/U LANDING JT, WILL NOT M/U WITH BPV IN TBG HGR, PULL LANDING JT. N/U BOPE LUBRICATOR AND PULL BPV, LAY DOWN LUBRICATOR, M/U LANDING JT. COMPLETE BOPE TEST, PIPE RAMS AND HYDRILL, HI-LOW PRESSURE TEST. M/U DOUBLE SPEAR TO PULL TBG, BOLDS, VERY TIGHT, WORKING ON LOCK DOWN SCREWS. CIRC BOTTOMS UP MW: 0.0 WORK 6 TIGHT LDS FREE ON TBG SPOOL. RUN SPEAR INTO TBG, PULL TBG HGR FREE, PULL TBG HGR TO RIG FLOOR, RELEASE SPEAR, LAY DOWN SPEAR AND TBG HGR. PULL 4 1/2" TBG WITH C/L TO BVLN, POH AND LAY DOWN SPEAR & TBG HGR. PULL 4 1/2" TBG WITH C/L TO BVLN, POH AND LAY DOWN 286 JTS 4 1/2" TBG. R/D TBG PULLING EQ, CLEAR FLOOR. M/U KELLY, TEST KELLY AND FLOOR VALVES LOW/HI PRESSURE TEST, SET WR. BREAK OUT AND LAY DOWN TNADEM SPEAR ASSEMBLY, M/U OVERSHOT, P/U DRILL PIPE FROM PIPE SHED. TAG UP ON TOP OF FISH @8865', ENGAGE 6' OF FISH AND PULL SEAL ASSEMBLY FREE. CIRC BTTMS UP. NOV - 4 %994 Oil & Gas Cons, Commission Anchorc,..~ WELL : DS 12-07 OPERATION: RIG : NABORS 2ES PAGE: 2 10/24/94 ( 4) TD:10570' (10570) 10/25/94 (5) TD:10570' ( 0) 10/26/94 (6) TD:10570 PB:10535 CHANGE OUT GRAPPLES ON SPEAR MW: 0.0 VIS: 0 CIRC BTTMS UP, MALL GAS SHOW @ BTTMS UP, WELL STABLE. POH, RECOVERED FISH, SEAL ASSEMBLY AND PUP JT, BREAK OUT ANS L/D FISH. CLEAR FLOOR, SERVICE RIG. M/U TYPE 'B' J-LATCH SPEAR, RIH. RIH W/ SPEAR. WORK SPEAR INTO TOP OF FISH @8892', WORK TURNS INTO PBR TO RELEASE 'K' ANCHOR, APPEARS TO BE FREE, POH. CIRC BTTMS UP, WELL STABLE. POH. NO FISH RECOVERED, BREAK OUT ANS LAY DOWN TYPE 'B' SPEAR. M/U TANDEM SPEAR AND GRAPPLE DRESSED TO CATCH 6 1/8" ID, RIH. SLIP AND CUT DRLG LINE. RIH WITH TANDEM SPEAR. WORK SPEAR INTO FISH @8892', ENGAGE SPEAR, ROTATE 6 TURNS, SPEAR SLIPPING, REPEAT PROCEDURE, SPEAR SLIPS, ATTEMPT TO JAR, SPEAR SLIPS, POH. CIRC BTTMS UP, WELL STABLE. POH. NO FISH RECOVERED, GRAPPLES IN OPEN POSITION, CHNAGE OUT GRAPPLES. P/U 6 1/4" GRAPPLES. MILL ON PKR MW: 0.0 VIS: 0 M/U LARGER GRAPPLES ON SPEAR, RIH. ATTEMPT TO RELEASE LATCH FROM PACKER, SPEAR CONTINUES TO SLIP. PUT 10 TURNS INTO PBR, SPEAR SLIPS, APPEARS PBR/LATCH ARE NOT TURNING, JAR PBR/LATCH FREE FROM PACKER. CIRC BOTTOMS UP. WELL STABLE. POH. RECOVERED PBR/LATCH, SLIPS MISSING FROM LATCH, BREAK OUT AND L/D FISH. M/U PRT/PACKER MILL ASSEMBLY. RIH WITH PRT/PACKER MILL. TAG TOP OF FISH @ 8911', PRT WILL ONLY GO INTO TOP OF PACKER 2', APPEARS SLIPS FROM LATCH ARE IN TOP OF PACKER, ROTATE ON SLIPS, TRY TO PUSH SLIPS THRU PACKER BODY, WORK PIPE TO TRY AND MOVE SLIPS, NO GO. POH WITH PRT/PACKER MILL. SLIP AND CUT DRLG LINE. CHANGE OUT PRT/PACKER MILL, M/U PACKER MILLING SHOE. RIH WITH PACKER MILLING SHOE. MILL OVER PACKER @ 8909'. RIH W/ OVERSHOT TO FISH PACKER MW: 0.0 MILL PACKER FREE, PUSH DOWN HOLE TO LINER TOP. CIRC BTTMS UP, SMALL GAS SHOW, WELL STABLE. POH WITH PACKER MILLING SHOE. BREAK OUT AND LAY DOWN MILL AND EMPTY JUNK BASKETS, MILL 50% WEAR. M/U OVERSHOT WITH 6 3/4" GRAPPLE, RIH. TAG TOP OF FISH @8944', WORK OVERSHOT DOWN OVER FISH 2'. CIRC BTTMS UP, WELL STABLE. POH, NO FISH RECOVERED, APPEARS GRAPPLE TO LARGE. CHANGE GRAPPLE IN OVERSHOT, RUN SMALLER ID, 6 5/8". RIH WITH OVERSHOT. SLIP AND CUT DRLG LINE. RIH WITH OVERSHOT. RECEIVED NOV - 4 1994 A~as~ Oil & Gas Cons. Commission Anchorage WELL : DS 12-07 OPERATION: RIG : NABORS 2ES PAGE: 3 10/27/94 ( 7) TD:10570 PB:10535 10/28/94 (8) TD:10570 PB:10535 10/29/94 (9) TD:10570 PB:10535 RIH W/CLEAN OUT ASSY MW: 0.0 RIH WITH OVERSHOT. WASH DOWN OVER PACKER 4' WITH OVERSHOT @ 8944'. CIRC BTMS UP @ 9 BPM 500 PSI, WELL STABLE. POH, 20 K EXCESS DRAG FIRST 4 STDS, LOST FISH. NO FISH RECOVERED, BREAK OUT OVERSHOT & GRAPPLE, FOUND METAL WEDGED INTO GRAPPLE THAT KEPT IT IN OPEN POSITION, REPAIR GRAPPLE. RIH, FOUND PACKER 400-' OFF LINER TOP, WORK PACKER FREE, PUSH DOWN TO TOL. WASH DOWN OVER PACKER 4' WITH OVERSHOT @ 8944'. OBSERVE WELL, HELD SAFETY MEETING WELL CONTROL TRIP DRILL. POH, 15K-25K EXCESS DRAG FIRST 4 STDS, NORMAL DRAG, RIH, FISH IN OVERSHOT. POH, 15K-25K EXCESS DRAG ON TRIP, PULLED TIGHT THRU FO'S @ 2492' & 2366'. RECOVERED FISH, BREAK OUT & LAY DOWN PAKCER & TAIL PIPE, BREAK OUT FISHING TOOLS, RIH WITH 6" DRILL COLLARS, POH LAY DOWN DRILL COLLARS. M/U 5-3/4" SHOE & JUNK BASKETS, RIH, P/U 3-1/2" DRILL PIPE FROM PIPE SHED RIH WITH 4-1/2" DRILL PIPE FROM DERRICK FOR CLEAN OUT TO TOP OF IBP. POH, LAY DOWN DRILL PIPE MW: 0.0 RIH WITH CLEAN OUT ASSEMBLY TO 8954' DPM, TOP OF 7" LINER. REVERSE CIRC BTTMS UP AT LINER TOP. RIH THRU 7" LINER TO TOP OF SAND PLUG, TAG TOP OF SAND @ 10045' DPM. M/U CIRC HEAD PIN, CLOSE HYDRIL, REVERSE CIRC OUT SAND WHILE SLIDING THRU HYDRIL FROM 10045 -- 10087'. REVERSE CIRC BTTMS UP. R/U TO TEST, PRESSURE UP ON 7" X 9 5/8" CSG. HELD TEST FOR 30 MIN. REVERSE CIRC WELL TO CLEAN FILTERED SEAWATER. P/U AND SET 9 5/8" HALLIBURTON STORM PACKER @ 60' BRKBE. N/D BOPE, REMOVE GRAY GEN II PACKOFF, N/D GRAY GEN II TBG SPOOL. N/U RECONDITIONED GRAY GEN II TBG SPOOL AND MANDREL PACKOFF ASSEMBLY. TEST PACKOFF, N/U BOPE, INSTALL TEST PLUG. PERFORM BOPE TEST, LOW/HI PRESSURE TEST, PULL TEST PLUG, SET WR. M/U RETRIEVING TOOL, RIH, LATCH INTO 9 5/8" STORM PACKER, RELEASE PACKER, POH AND LAY DOWN HALLIBURTON PACKER, WELL STABLE. POH, LAY DOWN 4 1/2" DRILL PIPE TO RUN TBG. N/U ADAPTER FLANGE & TREE MW: 0.0 SLIP AND CUT DRLG LINE. POH, LAY DOWN 4 1/2" DRILL PIPE. LAY DOWN 9 5/8" CSG SCRAPER, 3 1/2" DRILL PIPE & DRILL COLLARS, PULL WR. R/U TBG RUNNING EQ, M/U TAIL PIPE ASSEMBLY, 9 5/8" PACKER, RIH WITH 4 1/2" TBG & GLM'S, M/U TRDP-SSSV. M/U C/L TO TRDP-SSSV, TEST. RIH WITH 4 1/2" TBG & C/L, RAN 210 JTS TBG, USED 53 SS C/L BANDS ON TBG. M/U CIRC HEAD PIN, REVERSE CIRC INHIBITED SEAWATER INTO ANNULUS. DROP PACKER SETTING BALL, M/U TBG HGR, HOOK UP C/L & TEST. M/U LANDING JT, LAND TBG IN WELLHEAD. SET BPV, N/D BOPE, SPLIT STACK INTO 3 SECTIONS FOR NEXT WELL. N/U ADAPTER FLANGE & TREE. NOV - 4 1994 Oil & Gas Cons. Commission WELL : DS 12-07 OPERATION: RIG : NABORS 2ES PAGE: 4 10/30/94 (10) TD:10570 PB:10535 RELEASE RIG MW: 0.0 TEST ADAPTER FLANGE & TREE. R/U HI-PRESSURE LUBRICATOR, PULL TWC, R/D LUBRICATOR. PRESSURE UP TO SET PACKER, HOLD, TBG TEST, BLED TBG PRESSURE DOWN, PRESSURE UP ON ANNULUS, HOLD, PRESSURE LOSS OF 150 PSI DURING TEST, BLED OFF TBG PRESSURE TO SHEAR RP VALVE. ATTEMPT TO CIRC, DIESEL LINE FROZE UP, THAW OUT DIESEL LINE W/ STEAM. PUMP 140 BBLS DIESEL DOWN ANNULUS. U-TUBE DIESEL TO TBG. SET BPV, SECURE TREE AND WELLHEAD, EMPTY AND CLEAN PITS. RELEASE RIG @1500 HRS ON 10/29/94. SIGNATURE: (drilling superintendent) DATE: NOV - 4 %994 Oil & Gas Cons. Commission Anchor[.. ,~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 October 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~F]~.j{~ # DESCRIPTION 12-7A 1 CCL/CHEMCUT FINAL BL 1 CCL/CHEMCUT RF SEPIA 4-02A i DLL/GR/CAL FINAL BL 1 BHC/AC/GR FINAL BL 1 CN/GR FINAL BL i BHPF FINAL BL 1 SSVD/SSDS FINAL BL 1 DLL/GR/CAL RF SEPIA 1 BHC/AC/GR RF SEPIA 1 CN/GR FINAL RF SEPIA 1BHPF FINAL RF SEPIA 1 SSVD/SSDS RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 3795.01 6286.00 Please sign and return to: Atlas Wireli~ 5600 B Stj~t Aj~orage, AK 99518_ · /Attn. Rodney D. Paulson '-~/ Or FAXJto (907) 563-7803 Received by: ' ' Date: $00 W. lnlernaflonal Airport Road Anohorage, AK 99518-1199 Al'TN: Sherrle Well NO. 8858 ~)~/,.~ Oompany: Alaska Oil & Gas Cons Comm C~,~,~, 'l Attn: Larry Grant ~/~6,/r~ 3001 Porcupine Drive 'G,;,~.~e~ ,7~/~0o ~'4~ Anchorage, AK 99501 '~:~' ~o,,~, Field: Prudhoe Bay Log Description ~/~6'/o/~ BL RR Sepia RF Sepia Mylar D.S. 5.13A GAMMA RAy. CCL (7-23-94) 1 1 D.$. 5-13A JEWELRY LOG (7-25-94) 1 1 D.S. 12-7A IBP SETTING RECORD (7-25-94) 1 1 D.S. 9-7 IBP SETTING RECORD (-23-94) 1 1 D.S. 16-13 7- IBP SETTING RECORD (-23'94) 1 1 , 8/11/94 SIGNE ___ Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. DATE: ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Transmittal #: 94054 P.O. Box 100360, ~" '~orage, AK 99510,~~, JUL 7 7' · 4~ Oil & ~as Cons..Co~i~ion Ancnor~ . Number (M-D-Y) Scale I 1-05ST( 6-21-94 ProdProf I 1,1"&5" SCH 1-17 ! 6-20-94 I/ Prod Prof ~ 1, 5" SCH 2-20 i 6-18-94 / IBP Settin(.:g Rec 1; 5" SCH 2-28 i 6-28-94 / Leak Detection 1,2" &5" SCH 3-2 1 6-22-94 ~' Leak Detection 1,1"&5" SCH 4-2 ! 6-17-94 / Patch Set Rec 1, 5" SCH 4-30ST I 6-25-94 J / Per[ Rec 1, 5" SCH /15~ i 4-40 f 6-25-94t ./ Perf Rec 1,5" SCH i {.. 4-43 , 6-23-94 I/ CompRec f 1, 5" SCH 4-44 i 6-20-94 - / PerfRec t 1, 5" SCH 4-45 i 6-25-94 -/' Perf Rec I 1, 5" SCH 5-03A f 6-9-94 ' CDN f 1, 2" &5" SCH 5-03A I 6-9-94 i / Slim1 GR I 1, 2"&5" SCH 5-03A ! 6-9-94 ~ CDR 1, 2"&5" SCH 5-13 i 6-17-94 --Leak Detection 1,1" & 5" SCH 5-33 i 6-29-94 -' Per[ Record 1, 5" SCH 6-8 ! 6-15-94 /' TDTP 1, 5" SCH 6-12A .! 6-24-94 I "- Perf Rec 1, 5" SCH 7-6 ! 6-28-94if PerfRec 1,5" SCH 7-26 ! 6-19-94 ],,, Per[ Rec 1, 5" SCH 9-05A I 6-21-94 ~-' Per[Rec 1, 5" SCH 9-05A ! 6-22-94 ,,' Per[ Rec 1, 5" SCH 9-30STi 6-29-94 ," DuaiBurst 1, 5" SCH 11-6 ! 6-22-94 -'"'Prod Prof 1, l"& 5" SCH 11-29iI 6-27-94 ~' PerfRec 1,5" SCH 12-02 ~ 6-28-94 -"' Inj Prof 1, 5" SCH 12-7A i 6-27-94 l-"Leak Detection 1, 5" SCH ~ i 12-19 ! 6-27-94t '~' ,nj Prof 1,5" SCH i 12-23I 16'28'94 /" InjProf 1,5" SCH 12-28 ~ 6-27-94 ~' Prod Prof 1, 5" SCH 13-08 I 6-30-94 / Per[ Prof 1, 5" SCH 14-24! 6-15-94 .-" CNL 1, 5" SCH 14-39 i 6-19-94 "'[.eak Detection 1, 1" &5" SCH 14-39 ~ 6-19-94 /LeakDetection 1, 2" SCH 16-28 I 6-20-94 I / PerfRec 1, 5" SCH * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO A1,,$1s, Inc. I$ a SubMdlary of Al~antlcRIchfleldCompeny ARCO Alaska, Inc. Date: Feb 11, 1994 P.O. Box 100360~:' achorage, AK Transmittal #: 94021 99510,d~ ~ Subject: From/Location: BHP Report John Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Dat~ Tool Type Run, Scale Contractor Number (M-D-Y) , 1-9 12-17-92 BHP ... - ...... { Camco ... 1-14 8-'11,92 BHP - Camco 1-14 8-11-92 BHP - Camco 2-2 1-10'93 BHP - Camco 2-13 2-12'93 BHP - Camco 2-35 5-21-92 BHP - Camco 3-15A 3-20-93 BH P - Camco 3-20 12-18-92 BHP .' .... camco . 4-7ST 5-17.92 ' BHP . 'Camco ' u 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BH P - Camco ~ , 4-42 4-27-92 BHP .... - . .Camco 5-9 2-21-93 BHP Camco 5'16 2-21-93 BHP - Camco 5-25 2-21-93 BHP -.. . .Camco 5'31 2-21-93 ~BHP. Camco 5'33 1'29-93 BHP ' ' - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 2-15-93 BHP - Camco 9'40 1 '25-93 BH P - Camco 9'51 3-20-93 BHP - Camco "12-7A 12-6-92 " I~HP ' - Camco ..'12-7A' 12..10;.92'' ....... BHP .i. ' ".i.' '. .... ..... '.'.... camco' 12-9 12-10-92 BHP - Camco 12~'29 12-14-92 BHP ' - Camco 13-15 7-3-92 BHP - Camco 13'20 7-4-92 BHP - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BHP - CamcO ~4-'11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco ~6-30 9'28-92 BHP - Camco 17-3 12-12-92 BHP .-. Camco 17-10 11-8-92 BHP - ~ar~:~co ..... 1'7-11 "2'8-93 ' B'HP -' Camco 17-20 12-21-92 BHP" - Camco 17-21 12,21-92 BHP - Camco 18-15 6-14-92 BHP - Camco ARCO RECEIVED FEE~ I< 199,~ Alaska Oil & sas Co,s. Corr~is$ion Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska ~9510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ~2-8 4-40 ~2 ~ ~ ll-IA ~1-1A I-13A 1-16ST 1-8-93 InJ Profile R~_m 1, 5" 1-10-93 Gas Entry Run 1, 5' 11-23-92 Prod Profile R~_m 1, 5" 1-9-93 InJ Profile Run 1, 5" 11-24-92 PITS Run 1, 5" 12-4-92 Prod Profile Run 1, 5" 11-19-92 InJ Profile R~_m 1, 5" 11-22-92' Pump-in Profile Run 1, 5" 1-12-93 Coll_~r/Tubing Patch Run 1, 5" 12-3-92 GR/Collar R~_m 1, 5" 12-3-92 Prod Profile Run 1, 5" 12-3-92 GR/Collar R~_m 1, 5" 12-6-92 PITS R~m 1, 5" CCL/Jewelry Run 1, 5" GR/Collar Run 1, 5' .~ ' 2-7A 12- 0-92 ~Z~~14-28 1-8-93 Prod Profile Run 1, 7-1~5 11-22-92 Static TemPerature Run 1, Please sign and return the attached copy u receipt of data. Have A Nice Day! Sonya Wallace ATO- 1529 APPROVED_~~' Trans# 93037 Ca, nco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Cam©o Camco Ca, nco Camco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AIASKA~ RECEIVED The correct API# for 4-14A is 50-029-20310-00. ~aska 0~ & Gas Cons. C0m~l~si0~ Anchorage ARCO ~IAs~A, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-19-92 REFERENCE: ARCO CASED HOLE FINALS ?~-~/~ 1-5ST ?~'-~/ 7-1 ~/- ?° 9-8 ~-~ 9-27 12-17f~23 12-6 12-7A .12-25 13-4 14-25 18-20 5-31-92 Prod Profile Run 5-29-92 Inj Profile Run 6-1-92 Inj Profile Run 6-1-92 Prod Profile Run 5-29-92 Prod Profile Run 5-28-92 Leak Detect .Run 5-29-92 Prod Profile Rim 5-29-92 Inj Profile Run 5-30-92 Prod Profile Run 5-30-92 Inj Profile Run 5-26-92 Prod Profile Run 1, 5tt 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" 1, 5" Calllco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the RECEIVED BY Have A Nice Day? ~ ~ C ~IV E D attached copy as receipt of data. SonyaWallace JUN 2 9 ~992 AT0-1529 Alaska Oil & Gas Cons. Commission Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL APPROVED Trans# 92123 # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO STATE OF ALASKA ,, ALASK/~" 1_ AND GAS CONSERVATION C~,,~ ,MISSION - REPORT SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate X.~ Plugging ,~. Pull tubing Alter casing .....- Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 459' FSL, 10' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 902' FNL, 1341' FEL, Sec. 20, T10N, R15E, UM At effective depth At total depth 924' FNL, 1231' FEL, Sec. 20, T10N, R15E,' UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 80 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-7A 9. Permit number/approval number 81 - 175/9 0-373 10. APl number 50 - 029-20409-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 73' Surface 2631' Production 9236' Liner 1597' 10570 feet Plugs(measured) 9091 feet 10535 feet 9061 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 475 sx AS 73' 73' 13-3/8" 2368 sx Fondu 2711' 2711' 9-5/8" 1180 sx CI 'G' 9316' 7999' 7" 587 sx CI 'G' 10563' 9086' Perforation depth: measured 10226-10252'; 10334-10362'; 10374-10388'; 10396-10405'; 10417-10442'; 10452-10459'; 10469-10489' true vertical 8788-8811'; 8884-8909'; 8920-8932'; 8939-8947'; 8958-8980'; 8989-8995'; 9004-9021' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, PCT tail @ 9006' MD Packers and SSSV (type and measured depth)BeT 3-H packer @ 8930' MD; 4-1/2",~~.,/~~@ 2207' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Representative Paily Average Production or In!action Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1678 1778 2593 -- 272 Subsequent to operation 4424 4231 3855 -- 291 15. Attachments Copies of Logs and Surveys run ... Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 553 DRR c: J. Gruber, ATO-1478 SH DS 12-7A DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG RIVER & ZONE 4 6~5/90: RIH w/Bridge Plug and set plug at 10,410' MD (middle of plug), to isolate lower perforations in the well at: 10417- 10442' MD (Z4) 10452 - 10459' MD (Z4) 10469 - 10489' MD (Z4) POOH. RD. 6/6/90: RIH & tagged top of Bridge Plug at 10,404' MD. Ref. Log: 12/24/81. POOH. RD. 6/13/90: MIRU, and pumped a propped fracture treatment using gelled water and intermediate strength proppant through perforations at: Ref. Log: 12/24/81. 10226 - 10252' MD (Sag) 10334 - 10362' MD (Z4) 10374 - 10388' MD (Z4) 10396 - 10405' MD (Z4) Pumped treatment as follows: a) 200 bbls Pre Pad, @ 45 bpm, followed by b) Shutdown. ISIP @ 2369. Resumed pumping: c) 1500 bbls Cross Linked Water Pad, @ 45 bpm, followed by d) 820 bbls Slurry w/proppant concentrations of 1 to 12 ppg, followed by e) 180 bbls Flush, @ 45 bpm. Placed a total of 178,000 lbs of proppant into formation. Rigged down. 6/1 6/90: RIH & latched Bridge Plug. POOH w/plug. Rigged down. 6/17/90: Replaced DGLV's w/LGLV's. Flowed well. 8/20/90: Performed a proppant fill cleanout to 10510' MD. 8/22/90: Performed a scale inhibition treatment. Flowed well. Returned well to production and obtained a valid production test. STATE OF ALASKA ALASI(r 3IL AND GAS CONSERVATION(~ M_M_IS_SI.O.N.. ~,?, ~ ~ '~' ~ APPLICATION FOR SUNDRY Ar'PFIOVAL Alter casing ~.- Repair well X Change approved program Other 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Suspend -..-- Operation shutdown ~ Plugging ~ Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Re-enter suspended well Time extension Stimulate Perforate 6. Datum of elevation(DF or KB) 80 RKB feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 459' FSL & 10' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 902' FNL & 1341' FEL, Sec. 20, T10N, R15E, UM At effective depth At total depth 924' FNL & 12131' FEL, Sec. 20, T10N, R15E, UM 8. Well number 12-7A 9. Permit number 81-175 10. APl number 50 - 029-20409-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10570 feet Plugs(measured) 9091 feet Effective depth: measured 10535 feet true vertical 9061 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 73' 20" 475 sx AS 73' Sudace 2631' 13-3,8" 2368 sx Fondu ii'5~i~,, ~ C ~ j V ~ i".,2711' Production 9236' 9-5/8" 1180 sx Cl 'G' 9316' Liner 1597' 7" 587 sx Cl 'G' i.~Vi~i!~ ~t~ ~~,~I('~:: 10563' Perforation depth: True vertical depth 73' 2711' 7999' 9086' Anch0raFa measured 10226-10252'; 10334-10362'; 10374-10388'; 10396-10405'; 10417-10442'; 10452-10459'; 10469-10489' true vertical 8788-8811'; 8884-8909'; 8920-8932'; 8939-8947'; 8958-8980'; 8989-8995'; 9004-9021' Tubing (size, grade, and measured depth) 4-1/2", 12.6g, L-80, PCT tail @ 9006' MD. PaCkers and SSSV (type and measured depth) BOT 3-H packer @ 8930' MD; 4-1/2", Camco Bal-0 SSSV @ 2207' MD 13. Attachments Description summary of proposal X_~ 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Detailed operations program 15. Status of well clasSification as: Oil X.~ Gas Suspended BOP sketch X.. Name of approver Date approved Service 17. I hereb~ certify that the~true and correct to the best of my knowledge. Signed ~ --z""---- O Title FOR COMMI.~ION U.~l= oNLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE O. SMITH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 379 DRR cc: J. Gruber, ATO-1478 P1(12-7A)W1-3 Commissioner Returned Date_.~ '-'~ .- 90 SUBMIT IN TRIPLICATE Drill Site 12-7A Sag River / Ivishak Formation Hydraulic Fracture Treatment PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 12-7A as outlined below: . , , . , Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company. Pump propped fracture treatment at 45 BPM using a cross linked water system with approximately 250,000 lbs of 16-20 proppant. The intervals to be fracture stimulated are the Sag River from 10,226 to 10,252' and Zone 4 from 10,334 to 10,489'. The pump schedule is outlined as follows: A. 3000 Bbl cross linked water pad B. 152 Bbl 2 PPG proppant C. 165 Bbl 4 PPG " D. 177 Bbl 6PPG " E. 189 Bbl 8 PPG " F. 202 Bbl 10 PPG " G 214 Bbl 12 PPG " If necessary rig up CTU and cleanout to PBTD. Install gas lift valves. Open well to flow gradually increasing the drawdown to allow proper fracture healing. 6 5 4 2 COILED TUBING UNIT~ BOP E0U ! PHENT 1. 5000 PSI ?" W£LLHF. AD CONNECTOR rLAN0£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 H]RELINE BOP EOUIPHENT iii iii 1. 5000 PSI ?" WELLHEAD CONN£CIOR fLANGE 2. 5000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Inc.FIL~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 5, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-7A, Approval No. 9-566 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/TPA/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-7A) W1-3 RECEtVED 'AnchOrage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-(~ STATE OF ALASKA ALASKA AND GAS CONSERVATION C.O( ]ISSION REPORT OF SUNDRY WELL OP£HATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 459' FSL & 10' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 902' FNL & 1341' FEL, Sec. 20, T10N, R15E, UM At effective depth At total depth 924' FNL & 12131' FEL, Sec. 20, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic X 6. Datum of elevation(DF or KB) 80 RKB ,,, ,,,, 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-7A 9. Permit number/approval number 81-175/9-556 10. APl number 50 - 029-10409-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 73' Sudace 2631' Production 9236' Liner 1597' 10570 feet Plugs(measured) 9091 feet 10535 feet 9061 feet Junk(measured) Size Cemented 20" 475 SX AS 13-3/8" 2368 sx Fondu 9-5/8" 1180 sx CI 'G' 7" 587 sx CI 'G' Measured depth True vertical depth 73' 73' 2711' 2711' 9316' 7999' 10563' 9086' Perforation depth: measured 10226-10252'; 10334-10362'; 10374-10388'; 10396-10405'; 10417-10442'; 10452-10459'; 10469-10489' true vertical 8788-8811'; 8884-8909'; 8920-8932'; 8939-8947'; 8958-8980'; 8989-8995'; 9004-9021' Tubing (size, grade, and measured depth) 4-1/2", 12.6/f, L-80, PCT tail @ 9006' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 8930' MD; Camco Bal-0 SSSV 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 14. Treatment description including volumes used and final pressure Prior to well operation . - Representative Dail_v Average production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 1649 4022 3632 -- 289 Subsequent to operation 2064 4041 3380 -- 282 15. Attachments Copies of Logs and Surveys run. Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 204 T.P. Allen, 263-4837 Title Date Operations Engineering Manager ~~ TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: 1. , 1 , Si 1 Si 9. 10. 11. Drill Site 12-7A Description of Work Performed Sag River Fracture Treatment To Stimulate the Sag River Formation 10226-10252' MD (Ref. BHCS 12/24/81) August 2 to September 4, 1989 Perforated Sag River interval from 10226' to 10252' MD.(referenced to BHCS log dated 12/24/81) Removed gas lift valves and replaced with dummy valves. Fluid packed the 4-1/2" X 9- 5/8" annulus. Pressure tested annulus to 3000 psig. Set inflatable bridge plug at 10308' MD to isolate Ivishak perforations. Placed 6 bbls of calcium carbonate pill on top of bridge plug. MIRU fracturing service company Pressured annulus to 3000 psig. Pumped propped fracture treatment for Sag River zone using gelled water and Carbolite proppant at 20 bpm. a. 99 bbl Formation breakdown and shutdown for ISIP. b. 38 bbl pump-in/ shut-in c. 250 bbl Pad d. 180 bbl Slurry at 2-14 PPG (39,200/1 of proppant was pumped into the well and 34,100/1 was placed into the formation) e. 180 bbl Flush RDMO fracturing service company. MIRU slickline unit and tagged fill at 10092' MD. Cleanout excess proppant and spotted 14 bbls of HCL to dissolve calcium carbonate pill on top of bridge plug. Retrieved bridge plug with coil tubing. Placed well on production and obtained valid well test. ARCO ALASKA, INC. P.O. BOX iO03&O ANCHORAGE, ALASKA 995i0 DATE: 8-it-89 REFERENCE: ARCO CASED HOLE FINALS 7-i 7-29-89 PRODUCTION PROFILE RUN i, 5' ?-t2 7-28-89 PRODUCTION PROFILE RUN t, 5' ?-23 7-30-89 F'RODUCTION PROFILE RUN t, 9-8 ?-26-89 INJECI'ION PROFILE RUN i2-3 8-4-89 PERF RECORD RUN i, t2-7A 8-4-89 PERF RECORD RUN t4-36 7-29-89 INJECTION PROFILE RUN t5-ti 7-3t-89 PRODUCTION PROFILE RUN ~7-8 7-27-89 INJECTION F'ROFILE RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. DISTRIBUTION ~ PHILLIPS CENTRAL FILE£ CHEVRON PB WELL FILES D&M EXTENSION EXF'LORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON . l TEXACO MOBIL CAMCO CAMCO CAMCO CAMCO $CH $CH CAMCO CAMCO CAMCO ARCO Alaska, Inc.(~ Prudhoe Ba~ .~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 21, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-7A Permit No. 81-175 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment CC: T. B. Gray, BP J. Gruber, ATO-1478 PI(DS 12-7A)W1-3 RECEIVED UUN 2 6 B89 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK~" IL AND GAS CONSERVATION 'MISSION APPLICA i'ION FOR SUNDRY AFPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well ~ Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 459' FSL & 10' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 902' FNL & 1341' FEL, Sec. 20, T10N, R15E, UM At effective depth At total depth 924' FNL & 12131' FEL, Sec. 20, TION, R15E, UM 6. Datum of elevation(DF or KB) 80 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-7A 9. Permit number 81-175 10. APl number 50 - 029-20409-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10570 feet Plugs(measured) 9091 feet Effective depth: measured true vertical Casing Length Conductor 73' Sudace 2631' Production 9236' Liner 1597' Perforation depth: 10535 feet 9061 feet Junk(measured) Size Cemented Measured depth 20" 475 SX AS 73' 13-3/8" 2368sxFonduP E( EIVED2711' 9-5/8" 1180 sx CI 'G' 9316' 7" 587 sx C 'G' ;JUN 2 5 t.989 lOSS3' True vertical depth 73' 2711' 7999' 9086' Alaska 0il & Gas Cons. Commission Anchorage measured 10334-10362'; 10374-10388'; 10396-10405'; 10417-10442'; 10452-10459'; 10469-10489' true vertical 8884-8909'; 8920-8932'; 8939-8947'; 8958-8980'; 8989-8995'; 9004-9021' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, PCT tail @ 9006' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 8930' MD; 4-1/2", Camco Bal-0 SSSV @ 2207' MD i3. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation June 1989 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby c..ertify that t_he forgoing is true and correct to the best of my knowledge. Signed ~J~~.x~~ Title 15. Status of well classification as: Gas Suspended Operations Engineering Manager Date FOR COMMISSION U~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /7~/~ ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Commissioner Approval No. ~:~_..~,,~ Approved Copy Returp~ .... Date Form 10-403 Rev 06/15/88 065 R. A. Clausen, 263-4538 SUBMIT IN TRIPLICATE Drill Site 12-7A Sag River Formation Preliminary Hydraulic Fracture Treatment Procedure ARCO Alaska Inc. proposes the following hydraulic fracture procedure: 1. Perforate Sag River interval from 10226' to 10252' MD.(referenced to BHCS log dated 12/24/81) 2. Remove gas lift valves and replace with dummy valves. Load 4 1/2" X 9 5/8" annulus with seawater. 3 Pump fullbore sand slurry to fill casing from PBTD to 10282' MD. 4. MIRU fracturing service company 5. Pressure annulus to 3000 psig. 6. Pump propped fracture treatment for Sag River zone using gelled water and Carbolite proppant at 20 bpm. a. 100 bbl Formation breakdown and shutdown for ISIP. b. 250 bbl Pad c. 180 bbl Slurry at 2-14 PPG d. 180 bbl Flush 7. RDMO fracturing service company. 8. MIRU slickline unit and tag fill. 9, Cleanout excess proppant and sand to PBTD at 10535' MD with CTU. 10. Place well on production. Run spinner log to determine post frac production split between the Ivishak and the Sag River intervals. RECE'iVED 2 619 9 Alaska Oil & Gas Cons. Commission Anchorage 6 5 4 3 2 CO~L£D 'I'UBI. Ni3 UNIT BOP EOIU ! pllENT 1. 5000 PSI ?" WELLHEAD CONNECTOR IrLANGEi 2. 5000 PSi 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYORAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 - / 2 RECEIVED ~LIN 2 6 t9~9 ]aska Oil & Gas Cons. Commission Anchorage NI, REL,INE BOP EOUIPMENI 1. 5000 PSI ?" WELLHEAD CONNECIOR IrLANG[ 2. 5000 PSI WlRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO ALASKA, INC. ( F'·O. BOX t0~360 ANCHORAGE, ALASKA 995t0 DATE' 5-9-89 REFERENCE' ARCO CASED HOLE FINAL£ t-8 4-t6-89 t -24 4-8-89 2-~ '~ 4-23-89 2-i 4 4-i 5-89 2-~ 7 2-~ 7-89 2-23 4-t 3-89 4-7 4-1 6-89 4-25 4-1 8-89 7-'~'~ 4-i C~-89 9-i 4-i 3-89 ~ ~-3 4-24-89 I I -t ~ 4-1 4-89 t1-t6 4-i~ 89 ~ 2-7A 4--~ 9-89- J 2-~ ~ 4-2~-89 ~2-29 4-23-89 J 3-3 4-~ 4-89 ~ 3-8 4-'~'~-89~ ~ 3-23A 4-23-89 ~ 4-2 4-~ 9-89 ~ 4-~ 8 4-6-89 ~ 6-~ ~ 4-24-89 ~ 7-6 4-~ 9-89 J 7-8 4-~ 7-89 ~ 8-3 4-2~-89 ~ 8-7 4-2~-89 INJECTION PROFILE RUN ~, 5' PRODUCTION PROFILE RUN i, 5' TEMP , RUN i, i'&5' PRODUCTION PROFILE RUN S'F'INNER/TEMF'/FLUID DEN$/GR RUN ~, 5' F'RODUCTION PROFILE RUN F'RODUCTION F'ROFILE RUN t, 5' SPINNER/TEMP RUN LEAK DETECTION RUN ~, 2'&5' PRODUCTION PROFILE RUN LEAK DETECTION RUN LEAK DE'fECTION RUN PRODUCTION PROFILE RUN t, 5' PRODUCTION LOGGING $VC$, RUN GAS LIFT SURVEY RUN TEMP RUN LEAK DETECTION RUN PRODUCTION PROFILE RUN i, 5' MI INJECTION PROFILE RUN PRODUCTION PROFILE RUN PITS RUN t, 5' LEAK DETECTION RUN INJECTION PROFILE/TEMP ~(UN MULTI-RAI'E INJECTION PROFILE RUN i, F'RODUCTION LOGGING $VC$. RUN ~, 5' F'RODUC'¥ION LOGGING $VC$. RUN t, 5' F'LEASE S'IGN AND RETURN THE ATTACHED COPY A;~' RECEIPT OF DATA. B Y . __r.. ~_~ ~..xZ' ~ HAVE A NICE DAY~~~ ~?.,~__ /z~r~ -~ ~ ZALLY HOF-F~~':-::~ "' "~':::~F m- . ~ ,~ APPROVED ~.~ ATO- ~ 529 ~.:..:~l~za Od ~.Ga~ Cons. ~mmts~,o,~ TRAN~'~ 89 ~'9'7 . . , , ~,~.~ t B~E~RI BUI'I ON CENTRAL FILES ~ ~ F'HILLIP$ CHEVRON ~ ~ MOBIL EXTENSION EXF'LORATION ~ BF'X EXXON ~ STATE OF MARATHON ~ TEXACO ALA~'KA CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO 0 T ! $ CAMCO CAMCO CAMCO CAM~O CAMCO ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMI;O ATLAS,' A'I'I_AL~ * THE CORRECT AF'I~ FOR 2-t° ~- . ~ IS' 50-r. J29-2e':~'77 ** THE CORRECT AF'I~ FOR t6-ii I$ 5~-J-~29-2(~5i6· ARCO AI_.A..~KA, INC,~ ANCH[.IRA~F', AI...A..~K A DATF: ~-4-~ REFERENCE: ARCO PRE~IIRE DATA 2-29-88 t2-~3 2-29-88 t2-t5 2-t4-88 t2-~6 2-29-88 t-5 2-26-88 t-29 2-27/28-88 BHF'-STATIC GRADTENT BHP-XTATIC ~RADIENT BHP-FI_OWTNG GRADIENT BHP-~TATIC ~RAD~ENT BHF'-~TATIC ~RAD~NT BHP-~TATIC ~RAD~ENT CAMCO CAMCO CAMCO CAMCO PI..F.A,.~E ,~I.[,N AND RETURN THE ATTACHED COPY A,S' RECF..T..F'T [.iF DATA,. RECEIVED BY HAVE A NICE DAY! RE£EIVE ,,;~m,n Oit & G2s Cons. CommissJo, r; PEGGY BENNETI' ~'~'~"'~ ATO-' t 529 Anchorage TRAN,~ ~88t57 APPROVED . DI~TRIDI.JTTflN C[!'NIRAt... FII..E,., CHEVRON E××ON MARATHON Pn m..I... FIt F; R & D ~APC TEXACO ARCO AIaska P.O. Box i Anchorage, Alaska 995t -8 DATE' August' 7, REFERENCE' ARCO Ca_~ed Hole Final P.o_ LLar Log Run .- '~ ~.~-' CCL Perforating Record Run i_:.~-" £pinner FLuid ID ~.'_.. Differentia[ Te~p F'u~pin Run i Co~,~pLetion Record Run Perforating Depth Con~-o[ Run 3 5" Perforating. Depth Control Run Perforating Depth ConTroL Run CompLe$ion Record Run i 5" PerforaTing Record Run t 5' EPLog Run .. sign and return +.he a+.tached copy 8s receipt of data. -. Received By HAVE A NICE DAY! L~nda Hu[ce AT0-!529 . E Alaska Oil & G..~s C~,ns Commission ~ncnnra.0. e D!£TR!B:JTION ~ Central Fi [es -1i- Chevron D &M Extension Exp Lo'tm± i on Exxon Mara thon ~ Mobi L F'r-: '~ ' _ ~-¥eLL F; Las F,' &"D ~ .'--'7. oh i3 .. · ~..$. ~ t e;.-.o ~£.A ta $ i...: a ARCO Alaska, Inc. ,~ .... Bay ( ,eering Prudhoe Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 DS 12-4A DS 12-5 DS 12-7A DS 12-9 DS 12-10 DS 12-14 DS 12-16 DS 12-17 DS 12-21 DS 12-28 Permit No. 79-41 Permit No. 81-187 Permit No. 79-55 Permit No. 81-175 Permit No. 80-93 Permit No. 81-53 Permit No. 81-138 Permit No. 83-11 Permit No. 83-4 Permit No. 84-48 Permit No. 84-31 Enclosed are the "Subsequent" Sundry Notices and Completion reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TAB/vh RECEIVED Alaska Oil & 6as Cons. C0~nm/ssi0n Anchorage Enclosure cc: SOHIO Alaska Petroleum Co. File PI(DS 12-3)Wl-3 P1 (DS 12-4A) Wl-3 Pi(DS 12-5) Wl-3 P1 (DS 12-7A) W1-3 PI(DS 12-9) Wl-3 PI(DS 12-10) Wl-3 P1 (DS 12-14)W1-3 PI(DS 12-16)W1-3 Pi(DS 12L17)W1-3 P1 (DS 12-21)Wl-3 P1 (DS 12-28)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany STATE OF ALASKA~ · · ALASKA d..'.. AND GAS CONSERVATION CO'~" .~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-175 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20409-01 4. Location of well at surface 9. Unit or Lease Name 459' FSL & 10' FEL, Sec.18, TiON, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 902' FNL & 1341' FEL, Sec.20, TION, R15E, UM DS 12-7A At Total Depth 11. Field and Pool 924' FNL & 1231' FEL, Sec.20, TiON, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 80' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/12/81 12/25/81 12/30/81I N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 10570'MD,9091'TVD Z0535'MD,O061'TVD YES ~ NO [] 2206 feet MD 1800' (aoprox.) 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR, DIL/BHCS/GR/SP, CBL/OR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 73' 30" 475 sx AS 13-3/8" 72# L-80 Surface 2711' 17~" 2368 sx Fondu 9-5/8" 47# L-80/ Surface 9316' 12¼" 1180 SX ClaSs "G" S-95 7" 29~ L-80 8966 10563 8~" 587 sx Class "G- 24. Perforations'open to Production (MD+TVD of Top~ and BO{{om and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10334-10362'MD 8803-8828'SS @ 8 spf 4~" 900&' 8935' 10374-10388'MD 8838-8850'SS @ 4 spf '10396-10405 'MD 8858-8866'SS @ 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. *10417-10442 ' MD 8877-8899'SS @ 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *10452-10459 ' MD 8908-8914'SS @ 4 spf 4~." 150 .~ qla~_~ G-kickoff ~!ug *10469-10489'MD 8923-8940'SS @ 4 spf * added on 12-13 & 12-14-85 Ref: BHCS 12/24/81 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 4 / 26/82 F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/28/82 12.5 TEST PERIOD ~ 1328 1075 206 44I 1081 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 723 -- 24~HOUR RATE I1~ 2264 2447 403 23.2 28. CORE DATA Brief description of lith01ogy, porosity, fractures, apparent dips and presence of oil, gas ~,~ ~t~. ~Jl~n~i1~c~d~pips. ElY L b/ Ataska. 0il & Gas Cons, Anti, crags, Form 10-407 ,/~v*-,~ -~..5~-~/7/ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10331' 8881' Base Sadlerochtt .;, I , 31. LIST OF ATTACHMENTS None , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig ned _ ~_ ~z~f~.~~l--~--~ Title Oger.En~r.M~zr. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item .16 and 24: If:.this well is completed for separate production from more than one interval (multiple com~:tetion), so state in item 1.~6, and in item. 24 show the produC'ing 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 (DF, KB, etc.). Item 23: Attached supplemental records for this snell should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ~Ii'L STATE OF ALASKA ALASKA AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELE,~] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-175 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20409-01 4. LocationofWell Surface: 459' FSL, 10' FEL, Sec. 18, T10N, R15E, UM At Top Producing Interval: 902' FNL, 1341' FEL, Sec. 20, T10N, R15E, UM At Total Depth: 924' FNL, 1231' FEL, Sec. 20, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.)80. ~ I 6. LeaseDesignationandSerialNO.ADL 28330 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-7A 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~]X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations 12-13-85. RU perforating unit and pressure tested surface equipment. RIH w/gun #1. Shot 10469-10489, 4 spf. 12-14-85 RIH w/gun #2. Shot 10452-10459, 4 spf. Shot 10396-10405 4 spf. RIH w/gun #3. Shot 10437-10442, 4 spf. Shot 10417-10437 4 spf. Flowed well to clean up. RD 12-14-85. Ran SSSV 12-15-85 Ref: BHCS 12-24-81 RECEIVED JAN 2 4 1986 Alaska 0il & Gas Cons. L;ouunissi0n Anchorage 14. I hereby,certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay~. teering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 6, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 DS 12-4A DS 12-5 DS 12-9A DS 12-9 DS 12-10 DS 12-11 DS 12-14 DS 12-16 DS 12-17 DS 12-21 DS 12-28 Permit No. 79-41 Permit No. 81-187 Permit No. 79-55 Permit No. 81-175 Permit No. 80-93 Permit No. 81-53 Permit No. 81-73 Permit No. 81-138 Permit No. 83-11 Permit No. 83-4 Permit No. 84-48 Permit No. 84-31 Attached are the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:vh Attachment cc: SOHIO Alaska Petrole%~m Co. File Pi(DS 12-3)W1-3 PI(DS 12-4A)Wl-3 Pi(DS 12,5)Wl-3 Pi(DS 12-7A)Wl-3 Pi(DS 12-9)Wl-3 Pi(DS 12-10)Wl-3 PI(DS 12-11) W1-3 Pi(DS 12-14)W1-3 P1 (DS 12-16)Wl-3 PI(DS 12-17)Wl-3 Pl (DS 12-21)W1-3 Pi(DS 12-28)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanllcRIchfleldCompany STATE Of ALASKA { ALASKA Oil AND GAS CONSERVATION COI~I MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL×~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-175 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 459' FSL, 10' FEL, Sec. 18, T10N, R15E, OM At Top Producing Interval: 902' FNL, 1341' FEL, Sec. 20, T10N, R15E, UM At Total Depth: 924' FNL, 1231' FEL, Sec. 20, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 80' RKB I ADL 28330 12. 8. APl Number 50-- 029-20409-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-7A 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate r~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 12-7A at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10396-10405' MD 10417-10442' MD 10452-10459' MD 10469-10489' MD Ref: BHCS 12-24-81 RECEIVED I 11985 Alaska 0il & Gas Cons. CommJssio~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~ ~Z~ Operational Engineering Mgr. Signed , ~ _ Title The space below for Commission use Date Conditions of APproval, if any: Approved by. ORIG,HAL SIGNED BY IIAIliI¥ ~1, I, IGL£1 Approved Copy ~eturned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate . , ( ska Oil & 6as Cons. Commission Anchorage D & M ii!: ::.:: i::' i. ,:::, 'r .:'.-'~ '[' i ,.'::, '.,".., ,:::.' r.'.', 'r' v J '.::: ,:.7.:: .'.:ir iii; x 'i: ,:.:.:, 'n .'i~: i ,'.::, 'n ii!; '.'.:' c. i .,'.','r..'.', 't' i ,:::, ',."'~ Iii: :'4 x c::'n ..,, ~ , i"i .:3 T' .:'."i 'i.' F..: ,'.'3 'f',: M o 1.':,. i I. ARCO Alaska, inc.[ Post Office[ . 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f D.S. 3-22/ · o 3/ D S 3-2 D.S. 4-1/ D.S. 6-4f D.S. 6-7/ D.S. 6-18/ D.S. 6-23~ D.S. 7-20/ D.S. 7-21/ D.S. 7-22 / D.S. 7-24 D.S. 7-25/ D.S. 7-26' 4-9-84 4-9-84 4-9-84 3-17-84 1-25-84 1-25-84 1-15-84 1-15-84 12-27-83 8-11-83 4-18-84 4-29-84 4=20-84 4-20-84 4-20-84 4-21-84 4-22-84 4-28-84 D.S. 12-7A/ 4-14-84 4-14-84 -D.S. 12-15f 4-13-84 4-13-84 D.S. 12-18.~ 4-15-84 4-16-84 D.S. 13-13/ 4-12-84 D.S. 13-15/ 4~ t3-84 D.S. 13-16 / 4-12-84 D.S. 13-33/ 41-5-84 D.S. 18-7 / 3-14-84 Static Static Static Static PBU Common Data Base Report PBU Common Data Base Report Horner Plots w/listing Horner Plots w/listing PBU PBU PBU Common Data Base Report PBU r, Common Data Base Report PBU PBU PBU Common Data Base Report ~BU Common Data Base Report PBU Common Data Base Report Static PBU Pressure Draw-Down Static PBU Common Data Base Report Camco Camco Camco Camco GO GO Sch Sch Camco DA Camco Camco Camco DA Otis Camco Camco DA DA Camco DA DA · 3-14-84 ~/~Please sign and return the attached copy as receipt of data. Kelly McFarland -ATO-1429F Trans. % 187 Have A' Nice Day: ~ D_ISTRIBUTION ...... Drilling Phillips Exp. Services Prudhoe Bay Well File Ext. Exploration R & D Exxon Carolyn Smith Getty Sohio Marathon State of Alaska. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5537 July 26, 1983 Reference: Arco Pressure Data * D.S. 4-8 .... '~ 6-22-83 Pressure Falloff Survey w/Print-out D.S. 6-17~ 6-30-83 Static Survey D.S. 6-19 6-30-83 Pressure Build-up 6-30-83 Pressure Build-up S~rvey Report D.S. 6-22~ 7-3-83 Pressure Build-up 7-2-83 Pressure Build-up Survey Report D.S. 9-1~" 7-9-83 Pressure Build-up 7-8-83 Pressure Build-up Survey Report D.S. 12-7A 7-6-83 Pressure Build-up 7-6-83 Pressure Build-up Survey Report D.S. 18-7 5-18-83 5-18-83 CORRECTED Pressure Buils-up Pressure Build-up Survey Report * Please note t ~down, but is Please sign and here is a typo on this, it is labeled as a in reality a falloff. return the attached copy as receipt of data. Sch Otis Otis Otis Camc¢ Camc¢ DA Kelly McFarland ATO-1429D Trans. 9 445 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phil!ip~__/,~ P rudhoe B a'7""~ ~,~.,-.-.-z '~'~,,;'~" L :-,~. Sohio z ,.,/,.. State of Alaska ,, ARCO Alaska, In'c. ~ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 27, 1983 Hr. C. V. "Chat" Chatterton State of Alaska Division. of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re: DS 7-7A DS 12-6 DS 1 3-2A DS 13-26 DS 13-30 Permit No. 83-1 3 'Permit No. 80-74 Permit No. 81-175 Permit No. 83-21 Permit No. 82-74 Permit No. 82-101 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lw Enclosures cc' Sohio Petroleum Co. ARC() Al~aka. ~', I~ ~ S~,~[J;8~¥ o~ t~':~anttcR~chfte!dCompany RECEIVED JUN 2 91983 Alaska Oil & Gas Cons. Commission Anchorage ALASK AND GAS CONSERVATION , N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I]~]x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ._ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-175 3. Address 8. APl Number P, O. Box 100360, Anchorage, AK 99510 5o 029-20409-01 4. Location of well at surface 9. Unit or Lease Name 459' FSL, 10' FEL, Sec. 18, T10N, R15E, UM (surface) Prudhoe Bay Unit At Top Producing Interval 10. Well Number 902' FNL, 1341' FEL, Sec. 20, T10N, R15E, UM (top producing) U.S. 12-7A At Total Depth 11. Field and Pool 924' FNL, 1231' FEL, Sec. 20, T10N, R15E, UM (TD) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0i 1 Po01 80' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached i4. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 12/1 2/81 12/25/81 12/30/81I N/A feet MSL 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 10570'MD,9091'TVD 10535'MD,9061'TVD YES[~] NO[] 2206' feetMD 1800' (approx) 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR, DIL/BHCS/GR/SP, CBL/GR 23. CASING, LINER AND CEMENTING RECORD ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOT~ HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf (_ 73],) 30" 475 SX AS 13-3'/8" 72# L-80 Surf 27i-1 ' 17-1/2" 2368 sx Fondu 9-5/8" 47# L-80 & Surf 9316' 12 1/4" 1180 sx Class G S00-95 7" 29# L-80 8966' 10563' 8-1/2" 587 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9006' 8935' 10374-10388' MD 4 spf 8918- 8930' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · Ref· BHCS 12/24/81 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9075' 150sx Class G- kick°ff plug Added perforations, , .' , 27. PRODUCTION TEST Date First ProdUction 'l Method of Operation (Flowing, gas lift, etc.) 9/25/82 Flowing, . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 12/18/82. 12.3 TEST PERIOD I~ 933 790 48 2.5I 846 Flov~ Tul~ing Casing Pressure CALCULATED '~ oIL-BBL GAS'MCF ~ WATER-BBL OIL GRAVITY-APl (corr) Press. 787 N/A 24-HOUR RATE ~ 1821 1541' 95 27.5 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECeiVED JUN 2 c) 983 Alaska Oil & Gas. C0ns~ Comrrtlsmnn Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ArlChOlragt~ Submit in duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPIH GOR, and time of each phase. Top Sadlerochit 10331' 8881 ' . . 31. LIST OF ATTACHMENTs · , , . 32. I hereby certify that the foregoing is true and cOrrect to the best of my knowledge Signed ...... - ~ Title En,qi neer Date INSTRUCTIONS General- This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24:,:1f this well is completed for separate production from more than'one interval (multiple completion), so Si.ate in item 16, and in ite~.,24 show the producing intervals¢~Or only the interval reported i'n item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Anchorage, Alaska 99510 Telephone(~'~7 277 5637 December 3, 1982 RE: ARCO Directional Surveys JD.S. 1-21 10-22-82 ~D~.'S. 6-24 10-22-82 f'D.S. 7-15 10-28-82 ~-~D. S. 12-4A 11-15-82 -D.S. 12-7A 11-15-82 ~D.S. 12-8B 11-15-82 ~D.S. 12-14' '11-15-82 -'D.S. 13-14 11-15-82 f'D.S, 13-15 11-22-82 -8.S. 13-16 11-15-82 fD.S. 13-17 11-15-82 ---D,S. 13-18 11-15-82 ~D.S. 13'23 11-15-82 ~q~.S. 13-23A 11-22-82 ~D.S. 13-24 11-15-82 ~'~S. 13-25 11-15-82 ~D.S. 13-26 11-15-82 Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot' S'ingle Shot Single Shot S i ngl e Shot Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot- · ~.S. 13~30 11-15-82 Single Shot ~q).S. ~-32 11-15-82 Single Shot · /'~.~13-34/ 11-15-82 Single Shot _,. lease sign and return the attached copy as receipt of data. E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W E/W BeCky Benedi ct AFA- 4O3 Trans. #638 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON. CHEVRON GETTY AI~s~ 0~1 ~ Gas Co~s. ~ommiss~o~ A~¢ho~ag~ D&M STATE OF ALASKA DALLAS ARCO AlaSka. lnG. is a Sub$idiMy of AtlanticRichfieldCompan¥ ARCO Alaska, Inc. B " ',0 Post OfficeAl~.=°~,,a Anchorage, 99510 Telephone 907 277 5637 October 5, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' / Re- /D.S. ll-3 JD.S. 12-4A ~i~'~'~ 12- 7A ~'D.S. 13-6 Permit No. 81-147 Permit No. 81-187 Permit No. 81-175 Permit No. 81-121 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very T u 1 y~yo~7 ~ F. Scheve Regional Engineer DFS :TKKW :ml c Enclosures cc- Sohio Petroleum Co. ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfiefdCompany ALASK~ IL AND GAS CONSERVATION ~ .~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, [nc. 3. Address P. O. Box 360; Anchorage, Alaska 99510 4. Location of Well 459'FSL, IO'FEL, Sec. 18, TION, R15E, UM (Surf) 902'FNL, 1341'FEL, Sec. 20, TION, R15E, UM (Top Prod) 924'FNL, 1231'FEL, Sec. 20, TION, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 80' RKB ADL 28330 7. Permit No. 81-175 8. APl I~lumber 50- 029-20409-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-7A 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~X] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 9/25/82. Rig up perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10374-10388' (14' ref. CNL 1/1/82) 4 spf, 0:° phasing. Flowed well to the test separator to monitor rate. Shut in well and pulled gun #1 out of hole. All shots fired. Released perforating unit on 9-25-82. 14. I hereby cede foregoing is tru~e/~and correct to the best of my knowledge. Signed ,//~,~-~~ ' Title space be~fo;C°m~is;ion~'--'---- ' use The Conditions (:fi'Approval, if any: Engineer Date Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office Box 360 Anchorage. Alaska .99510 Telephone ( 277 5637 September 21, 1982 Reference: Arco Pressure Data D.S. 2-ZA. 9-3-82 D.S. 2-18 9-1-82 D.S. 3-13 9-8-82 _~~~ 7-3'82 D.S. 12-8B 7-6-82 D.S. 12-10 6-18-82 D.S. 12-11 6-17-82 D.S. 12-13 7-30-82 Pressure Buildup & Buildup Rpt. Pressure Buildup & Buildup Rpt. Static Survey & Static Rpt. Pressure Buildup & Buildup Rpt. Pressure Buildup & Buildup Rpt. Pressure Buildup & Buildup Rpt. Pressure Buildup & Buildup Rpt. Pressure Buildup & Buildup Rpt. Otis Otis Otis Sch DA Sch Sch GO /Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 488 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON DALLAS ARCO Alaska, Inc.(- Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 10, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re- :::,:.,B:~S~ 12~7A,' Permit No. 81-175 D.S. 16-5 - Permit No. 81-37 D.S. 16-6 - Permit No. 81-51 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, . . cheYe Regional Engineer DFS:sk.h Enclosures cc' Sohio Petroleum Company ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany A(~L) STATE Of ALASKA C(U ALaSK Il AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, :[nc. 81-175 3. Address 8. APl Number P. 0. Box 360; Anchorage~ AK 99510 50-029-20409-01 4. Location of Well 459'FSL, IO'FEL, Sec. 18, TION, R15E, UM (Surf) (Approved gyro unavailable for TD location at present) 5. Elevation in feet (indicate KB, DF, etc.) 80' RKB 12. 6, Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 12-7A 11. Field and Pool Prudhoe Bay Fi el d Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] 'Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pert~.ment details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations at 10374-10388' MD (ref: BHCS 12/24/81) within the Sadlerochit Sand for production from the Prudhoe Bay Unit. All wireline work will be done through a 5000 WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the operation. RE£EIVED SEP 1 a i982 A~.ska 0it &. Gas Cons, C0mmJssi0~ a, nch0rage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ........ ~ Title Regional Operation Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by BY L01~NIIE C. Sr~lJ/tCOMMISSIONER ~pproYed Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in DuPlicate A].~J Alaska, Inc. Post Office Box 360 Anchorage, A~-"a 99510 Telephone 90%r 7 5637 August 10, 1982 Reference: Arco Cased Hole Finals D.S. 1-18 6-14-82 Pipe Analysis Log (PAL) Run 1 5" D. $ " ..~?,~2 7A 7-3-82 Eng. Production Log (EPL) Run 1 5 . / /~~~e sign and return the attached copy as receipt of data. Kelly McFarland Trans. 9 365 DISTRIBUTION NORT~ GEOLOGY E&D FEILLIPS ~,L~:L~TEON' ~0~ EXXON MOBIL GETTY .... D&M GEOLOG~~ ST~T~ OF ALASKA Alaska Oil & (}as Guns. Anchora,qe ARCO Alaska. Inc. is a subsidiary of AtlanticRIchfleldCompany Post Office Box 360 Anchorage, A~.~ka 99510 Telephone 9(IL ;'7 5637 August 9, 1982 Reference: Arco Open Hole Finals D.S. 12-7 D.S. 12-7 Listing of Productivity/Day Volan listing (Recomputed) 10707,62710 10707,62710 D.S D.S. 12-7A / D.S. 12-7A.-~ D.S. 12-7A--~ D.S. 12-7A~'~ D.S. 12-7A----' CPL/Producibility 12/81 (5-1-82) IPRLOG 10706,62417 Listing of Productivity/Day 10706,62417 Listing of Productivity/Day 10707,62711 Liquid,Water,Oil,Gas Flow Rate Charts 5-1-82 Volan listing (Recomputed) 10707,62711 D.S. 13-19 D.S. 13-19 D.S. 13-19 D.S. 13-19 D.S. 13-19 CPL/Producibility . 1,14-82 (4-1'82) IPRLOG 10707,62533 Listing of Productivity/Day 10707,62533 Liquid,Water,Oil,Gas Flow Rate Charts 4-2-82 Volan listing (Recomputed) 10707f62533 D.S. 17-10%? D.S. 17-10~ D.S. 17-10 ..- D.S. 17-10-- D.S. 17-10 CPL/Producibility 8-8-81 (4-1-82) IPRLOG 10707,62532 Listing of Productivity/Day 10707,62707 Liquid,Water,Oil,Gas Flow Rate Charts 4-1-82 Volan listing (Recomputed) 10707,62707 /~lease sign and return the attached copy as receipt of data. Kelly McFariand Trans. # 357 D]~STKIBUTION NORTH.. GEOLOGY R&D-- DP~IT.T. TNG FEILEZ?S.' SOEI03 . MARATHON CHEVRON D&M GEOLOGY S~. OF ~S~ ARCO Alaska, Inc. is a subsidiary of AtlantlcRIchfleldComl~arty ARCO Alaska, Inc. Post Office ~ 360 Anchorage, ~,,~ska 99510 Telephone 907 277 5637 July 13, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: D.S. 4-14 D.S. 11-1 D.S. 11-2 D.S. 11-5 D.S.' 12-8B D.S. 12-9 D.S. 12-13 D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit No. 78-36 Permit No. 81-123 Permit No. 81-128 Permit No. 81-155 Permit No. 81-175 Permit No. 81-167 Permit'No. 80-93. Permit No. 81-87 Permit No.~78-64 Permit No. 81-45 Permit No. 81-70 Enclosed are Completion Reports for work done on the above-mentioned wells. Very truly yours, Regional Engineer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-175 3. Address 8. APl Number P.O. Box 360 Anchorage, Alaska 99510 50-029-20409-01 4. Location of well at surface 9. Unit or Lease Name 459' FSL, 10' FEL, Sec 18, T10N, R15E, UM (surface) Prudhoe Bay Unit At Top Producing Interval 10. Well Number 902' FNL, 1341~ FEL, Sec 20, T10N, R15E, UM (top producing) D.S. 12-7A At Total Depth 11. Field and Pool 924' FNL, 1231' FEL, Sec 20, T10N, R15E, UM (TD) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool 80' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12-12-81 12-25'81 12'30-81 NA feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10570'MD 9091'TVD 10535'MD 9061'TVD YE$~ NO[] 2206' feetMDI 1800' (approx) 22. Type Electric or Other Logs Run CB ,/VDL/CCL/OR, D L/B CS/OR/S , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 73' 30" 4755x AS 13-3/8" 72# ' L-80 Surf 27.11 17-1/2" 23685x Fondu 9-5/8" 47# L-80 & Surf 9316' 12-1/4" [180sx Class G S00-95 7" 2~# L-80 8966' 10563' 8-1/2" 5875x Class G 24. Perforations ol~,en tO Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8 shots per foot 4-1/2" 9006' 8935' 10334' - 10362 'MD 8883' - 8908' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . · DEPTH INTERVAL (MD) :AMOUNT& KIND OF MATERIAL USED 9075' ' 150sx Class C -kickoff plug · 27. PRODUCTION TEST Date First Production I Metho~J of Operation (Flowing, gas lift, etc.) 4-26-82I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO 5-28'82 12.5 TEST PERI'OD ~ 1328 1075 206 44 1081 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 723 NA 24-HOUR RATE ~ 2264 2447 403 23.2 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. E£EIVEi) J U L i 9 · A!~.sk~ Oi~ & Gas Cons, Commission Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10331' 8881' , 31. /~$T OF ATTACHMENTS 32. ~ here~¥ certify that the ~°regoing is true amd correct to the best of my know~edge Signed ~~ ~~-~' Title Regional Engineer Date. 7/J'~ /~2.~ INSTRUCTIONS General::..This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. : Item 1' Classification of Service Wells' Gas injectiOn, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for dePth measurements given in other'spaces on this form and in any attachments. Item 16 and 24: If this well is completed, for separate production from more than one interval (multiple.-'~ completion), so state in item 16, and in item 24 show the,.producing intervals for only the ir~erval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ' Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc./~' Post Office ~, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 13, 1982 Mr. C.V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: D.S. 4-14 D.S. 12-8B D.S. 12-9 D. $. 12-13 D.S. 14-5 D.S. 14-19 D.S. 14-20 Permit No. 78-36 Permit No. 81-175 Permit No. 81-167 Permit No. 80-93 Permit No. 81-87 Permit No. 78-64 Permit No. 81-45 Permit No. 81-70 Enclosed are Subsequent Sundry Notices detailing the work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DF S: TKKW Enclosures Distribution: Sohio Petroleum Co. ARCO Alaska. Inc. is a Subsidiary o1 AttanticRichfieldCompany STATE OF ALASKA ALASKA/~IL AND GAS CONSERVATION CpOMMISSION SUNDRY i . TICES AND REPOR'I , ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360 Anchorage, Alaska 99510 4. Location of Well 459' FSL, 10' FEL, Sec 18, T10N, R15E, UM (surface) 902' FNL, 1341' FEL, Sec 20, T10N, R15E, UM (top producing) 924' FNL, 1231' FEL, Sec 20, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 80' RKB I 6 . Lease Designation and Serial No. ADL 2833O 12. 7. Permit No. 81-175 8. APl Number 50-029-20409-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 12-7A 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Bo.x To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I--] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations on 4/25/82. Pressure tested tree and wireline perforating equipment. Perforated 10334' - 10362'_MD with 8 shots per foot. Well was cleaned up to a tank then flowed to the test separator. Ran static pressure sur~ey. Ran, set and tested SSSV. Released well to Production Department on 5/19/82. RECEIVED J U L I 9 1982 Aiaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~f/~'~. ~(/,~ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit :'lntentions" in Triplicate and "Subsequent Reports" in Duplicate Anchorage, Alaska 99510 Telephone 90~.. ~77 5637 ( June 30, 1982 Reference: ARCO. CASED HOLE FINAL LOGS D.S.2-15 / D.S.2-11j D. S. 13-21'/~ D.S.13-24~ D.S. 14-9B / D.S.2-20 ~ D. S'.2-21j D.S.6_2 ~-~' 5/21/82 5/2O/82 5/23/82 5/21/82 4/16/82 4/8/82 4/27/82 4/29/82 4/30/82 4/29/82 CNL Run 2 5" CNL Run 2 5" ACBL/VDL/GR Run 1 5" ACBL/VDL/GR Run 1 5" CBL/VD Run 1 5" CNL/GR/CCL . Run 1 5" CNL Run 1 5" CNL Run 4 5" CNL Run 4 5" CNL Run 4 5" 4/25/82 Perf Record & CCL Run 1 D.S.12-8B-~ 4/3/82 Collar'Log for Perforation D.S.13-21j 4/28/82 · EPL Run 1 5" D.S.14-3~ 5/2/82 CNL Run 4 5" D.S.15-4 ~' 4/26/'82 CNL Run 1 5" DS..15-4~ 4/8/82 4 Arm Caliper Run 1 5" D.S.15-4~' 4/19/82 CNL/GR/CCL Run 1 5" 511 Run 1 Please sign and return the attached copy as.receipt of data. 11 Mary F. Kellis North Engineering Transmittal # 247 DI'STRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO ' MARATHON CHEVRON EXXON .' MOBIL GETTY D&M GEOLOGy ARCO Alaska, Inc. is a subsidiary of AtlantlcRIchfieldCompany Post Oflice box J0O Anchorage, Alaska 99510 Telephone 907[~ '? 5637 May 26, 1982 Reference: ARCO OPEN HOLE FINAL LOGS D.S.12-7 .4/1/82 ., CPL (Producibility) 5" With Printout, & Well rate prediction CPL (Producibility) 5" With Printout, & Well rate predictJ //Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 188 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS sohio' MA!~THON EXXON MOBIL GETTY D&M GEOLOGY A!~ O~t a 5as Co~. Oo~nmission "' Anchorage ARCO Alaska. Inc. is a subsidiary of AtlantlcRichlleldCompany ARCO Alaska, Inc.-- Post Office D~ Anchorage, Alas,,,~ :}9510 ~,~;, 277 Telephone o,,-~ 5637 May 18, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports - Prudhoe Bay Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following drill sites: 14-28 13-17 14-30 13-23A 15-3 14-9B 15-12 Also enclosed are monthly reports for April on these drill sites: 2-19 14-17 2-20 15-4 2-21 15-5 13-18 Eileen #1 13-21 West Sak 24 Surveys for 2-19, 2-20, E~leen #1, and West Sak 24 are being reran; completion reports for these wells will be submitted when the corrected surveys a~.e.received. The reports on Eileen #1 and West Sak 24 are of a confidential nature. We would appreciaLe it if you could store this information in a secure area. Sincerely, P. A. Van Dusen District Drilling Engineer PAV:JG/llm Y 9 Enclosures 6RU /A9 ARCO Al,~:k~, !r,,'.: ,,; .'. s.h~idi;'~v (:f A!!;,nl~cRich~i¢ldComp~ny · ' STATE OF ALASKA · ALASKA L .... ~ .ND GAS CONSERVATION CL ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED.[] . SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Tnc. 81-175 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20409-01 4. Location of well at surface - - 9. Unit or Lease Name 459' FSL, 10' FEL, Sec. 18, T10N, R15E, UH LOCATIONS Prudhoe Bay Unit VERIFIED At Top Producing Interval 10. Well Number 902' FNL, 1341' FEL, Sec. 20, T10N, R15E, UN Surf. E 12-7A B.H. I~ At Total Depth - 'l 11. Field and Pool 924' FNL, 1231' FEL, Sec. 20, T10N, R15E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Prudhoe 0i} Poo} 80' RKBIADL 28330 12. Date.Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions !2/12/81 12/25/81 12/30/81I N/A feetSSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD-FWD) 19. Directional Survey 20. Depth where SSSV set [ 21. Thickness of Permafrost 10570'MD,9091'TVD 10535'MD,9061'TVD YES'ii NOI-] 2206' feetMDI 1800' (approximate) 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR, DIL/BHCS/GR/SP, CBL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD · ,,CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20", 94# H-40 Surf 73' 30. 4755x AS 13-3/8" 72# L-80 Surf 2711' 17-1/2" 23685x Fondu 9-5/8" a.7# L-80 & Surf 9316'. 12~'1/4,, 11805x Class G · : S00-95 · 7" 29# L-80 8966' 10563' 8-1/2" 5875x Class G .- 24. Perforations open tO Production. {MDrkTVD of Top and Bottom and ,25. TUBING RECORD sIZE ' ' 'DEPTH SET (MD) PACKER SET (MD) interval, size and number) N/A. 4-1/2" 9006' R935' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. : · .,, .i.,., '.'"' ';, , ,i.' . : , DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED · 9075' "lsn..~ P. 1-.~.~ N - l~irl~nrf" nl-,,n ,. - .... .~- - -- ,: r ' ,:, : ..... j , , 27. pRoDucTION TEST~' ' ........ Date ,F,,i¥st:Rrod~ction. ,,. {.:Method of Operation (Flowin,g, gas,lift, etc.) · . N/A.I -". , : Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 'I GAs'OIL RATIO' · I , .~ , .t.' : :. . TEST PER OD .. :. ~ .......... .., . . . Flow Tubing . Casing Pressure CALCULATED' ,O!L-BBL . . G.AS'-MCF. WATER-BBL OILGRAVITY]API (corr) Press. ': .,,: · .: ,;. ,. 24-HOURRA~E· , ., , . 28. cORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A. · ,: ' . ,. ', , . ' . · RECEIVED .~ ~,- ; :, ; ., . "~' <'. . . . . ~.... '. , . ': . : · ... · · - ., . A!3.ska Oil ~ Gas Cons. Commission Anchorage · , , submit in duplicate Form 101407 GRU5/A4/5/6 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, · '- MEAS. 'DEPTH TRUE VERT. DEPTH GOR~ and time of .e~::h phase. Top Sadlerochit 10331' 8881' N/A. - · . · 31. LIST OF ATTACHMENTS .Gyr:os¢op±c Survey (2 copies) 32. · I -hereby certify that.the foregoing is true and correct to the best of my ·knowledge Signed . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5- Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and .24: If this well is completed for .separate production from.more than one interval (multiple completion),'i~so state in item !6, and in item 24show 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 (DF, KB, etc.). · Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ,ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection,"Gas Injection, Shut-in, Other-explain. Item. 28.' If no cores taken, indicate "none". Form 10-407 Ancmorage. Alaska ~95~0 · ' · Teie~hone :..-v7( t 5637 April 30, 1982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S.13-17 4/14/82 Gyroscopic Job No. Boss-16004 D.S.13-23A 4/12/82 Gyroscopic Job No. Boss-16003 D.S.14-30 4/7/82 GyroscopiC Job No. 1307 D.S.14-28 3/19/82 Single-Shot Job No. A0382D0302 D.S.11-6 1/30/82 Gyroscopic Job No 5300 ~/ii 1/2/82 Gyroscopic Job No 3291 ~/Please sign and return the. attached copy a.s receipt of data. Mary F. Kellis North Engineering Transmittal # 136 , DISTRIBUTION DRILLING ,~ ~ GEOLOGY ARCO Alaska, Inc. I,~ North Slope bistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 16, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 4-11 Permit No. 78-6 D.S. 4-14 Permit No. 78-36 D.S. 11-1 Permit No. 81-123 D.S. 11-2 Permit No. 81-128 D.S. 11-3 Permit No. 81-147 D.S. 11-5 Permit No. 81-155 D.S. 11-6 Permit No. 81-161 D.S. 12-4A Permit No. 81-187 ~~ -',l~,~rmi t No. 81 - 17 5 D.S. 12-8B Permit No. 81-167 D.S. 12-13 Permit No. 81-87 D.S. 13-5 Permit No. 81-103 D.S. 13-7 Permit No. 81-129 D.S. 13-8 Permit No. 81-148 D.S. 13-9 'Permit No. 81-158 D.S. 13-10 Permit No. 81-165 D.S. 13-12 Permit No. 81'142 D.S. 13-19 Permit No. 81-180 D.S. 14-12 Permit No. 81-109 D.S. 14-13 Permit No. 81-101 D.S. 14-26 Permit No. 81-110 D.S. 12-1.4 Permit No. 81-138 Enclosed are our Sundry Notices detailing the work to be done on the above mentioned well. Very_truly yours, ~'. A. Ro~hon '- JAR:TKKW:mlc Enclosure MAR i 8 !982 Oil & Gas Cons, Commissiort ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ¢'~ ALASK~iOIL AND GAS CONSERVATION C~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-175 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50-029-20409-01 4. Location of Well 459'FSL,10'FEL,Sec 18,T10N,R15E,UM (surface) (approved gyro unavailable for TD location at present time) 5. Elevation in feet (indicate KB, DF, etc.) 8~KB 6. Lease Designation and Serial No. ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 12-7A 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12.' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Du. plicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadierochit Sand for production from the Prudhoe Bay unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi wP BOp/Lubricator, tested to working pressure. The SSSV will be installed at. the conclusion of the perforating and clean-up operatiOn. Work Repo~e~ Approved by 14. I hereby certify that the foregoing is~t~ue and correct to the best of my knowledge. Signed/~ ~,//'~~/~ Title Dist. Opts. En_~ineer The space ICe~w for Commission use Conditions of Approval, if any: Returned By Order of BY !!~"~_~R¥ ~!. KIiGLEil COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Offic~,qox 3¢30 Anchorag[ ,aska 99510 Telephone 507 277 5637 March 2, 1982 Reference: ARCO CASED HOLE FINALS "),: D.S.7-14 --"'12/31/81 D.S.7-14 ~-~1/1/82 D.S.7-14 12/19/81 ~~'~,~''' ~'~':'~' ~'~"" ""' ~?"~"""~" ~ ' 1 / 2 / 8 2 ~ ,,~l~Y~,, / 2 / 82 · , D. S'. 1"2-9 ~i/3/82 " D.S.12-11~/1/82 D.S. 12-14~ 1/21/82 D.S. 12-14/ 1/16/82 D.S.12-14'~ 1/13/82 D.S.12-14 1/12/82 D.s.12-1~ 1/19/82 D.S.13-3~ 1/9/82 D.S.13-3- 1/8/82 D.S.13-3i' 1/6/82 D.S.13-3 j 1/6/82 D.S.15-14 12/20/81 Casing Collar Log Run 1 5" Collar Log-Tubing Cutter/Depth Determ. Run 1 Collar Log for Tubing Puncher Run 1 5" CNL Run 1 2" CCL Tie-In Log For Gyro Run 1 5" CNL Run 1 5" CCL.& Perf Record Run 1 2"/5" Collar Locator Run 1 2" CCL & Perf Record Run 1 5" CCL & Perf Record Run 1 5" CCL & Perf Record Run 1 5" CBL/VD Run 1 5" CBL/VD Run 2 5" CCL Run 1 5" CCL Run 1 5" Pipe Analysis Log Run 1 5" Electromagnetic Thickness Tool Run 1 5" CBL/VD Run 1 5" ase sign and return the attached-copy, as' receipt ,df '.data. 11 Mary F. Kellis North Engineering Transmittal # 995 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska, Inc.l~ Post OfficetL .360 Anchorage. Alaska 99510 Telephone 907 277 5637 February 23, 1982 Reference: ARCO OPEN HOLE FINALS D.S.12-7A !2/25/81 D.S.12-7A 12/25/81 D.S.12-7A 12/24/81 D.S.12-7A 12/24/81 D.S.12-7A 12/25/81 DoSol2-7A 12/25/81 FDC Run 1 5" ~c / CNL DIL/S~L BHCS Run 1 5" Run 1 2" & 5" Run 1 2" & 5" Profile Caliper Run 1 2" Cybe~look Run 1 5" Please sign and return the attached copy as rec-eipt of data. Mary F. Kellis North Engineering Transmitatl # 986 DI STRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON E~,Na~ Ska Oil & o · Ga. Cons. Corn~is.sio.~ MOBIL Anchorago GETTY D&M GEOLOGY STATE OF A~S~ ARCO Alaska, Inc. Post Office B~ 360 Anchorage.f-,~, ,a 99510 Telephone 907 277 5637 February 3, 1982 Reference:.~ARCO CASED HOLE FINALS ,o D.S.3-3-"//...12/i7/81 D.$;9-1 '/12/16/81 D.S.9-4~' 12/14/81 D.s.9-sw/ 12/13/81- D.s;9-6 ,/12/9/81 D.S.9-6u/ 12/11/81 D.S.13-8z 11/4/81 D.S.11-3 / 12/14/81 .s.11-3/12/5/81 D.S.13-10/12/12/81 CNL Run - CNL Run 2 CNL Run 4 CNL. Run 4 Temp Log Run 1 EPL Run 1 CNL Run 1 Collar Locator for Gyro CCL & Perf Record Run 1 CBL/VD Run 1 CBL/VD Run 1 5I! 5" 5" 5" 5" 2" Run 2 5" 5" 5" 2"/5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #929 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. Inc, is a sub~d,ary ol AHanhcRichheldCort~pany ARC(U Alaska, Inc. Post Office B{'~ 50 Anchorage, AlAsKa:" 99510 Telephone 907 277 5637 January. 25, 1982 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Dear Sir' DS 11-5 DS 14-12 DS 11-6 DS 14-26 DS 12-7A DS 15-14 DS 12-8B DS 15-15 DS 13-10 DS lA-12 DS 13-19 DS B-11GI DS B-8 Enclosed please find the Well Completion Reports for the following drill sites' 11-5, 12-7A, 12-8B, 13-10, 14-12, 15-14, as well as an up-dated Completion Report for DS B-8. Also included are the Monthly Drilling Reports for drill sites' 11-6, 13-19, 14-26, 15-15, lA-12 and B-11GI. Sincerely, P. A. VanDusen District Drilling Engineer Enclosures PAV/GA' ss Alaska 0il &. Gas Cons. Co~nmiss~o~ ~chomge ARCO Alaska, Inc. ~s a Subsidiary of AttanticRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~__ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-175 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50- 029-20409-01 4. Location of well at surface 9. Unit or Lease Name 459' FSL 10' FEL Sec 18 T10N R15E UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number To Be Submitted. 12-7A At Total Depth 11. Field and Pool To Be Submitted. Frudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. ~u(]]loe 0iZ :Pool 80' KBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., SuMp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12/12/81 12/25/81 12/30/81 feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set ] 21. Thickness of Permafrost 10570'MD 10535'MD YES ~__ NO [] 2206' feet MDI 1800' (Approx.) 22. Type Electric or Other Logs Run CBL/VDL/CCL/GR DIL/BHCS/GR/SP CBL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD . CASING SIZE WT. PER FT. GRADE TOP - BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED ZO" '94~ H-40 Surf. 73' 30" 475sx Arctic Set c~lt. 13-3/8" 72# N-80 Surf. 2711 ' 17~." 2368sx Fondu · 9-5/8" 47# L-80/ Surf.' · 9,316' 12,1t~ ~ !lS0sx Class "G" S-95 7" 29# L-80 8966' 10563' 8z 587sx Class "G" 2 24. Perforations oPen to Production (MD+TVD of Top .and Bottom and 25., TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4TM 9006 ' 2 8935' TO BE SUBM I TTED. ~ -- . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' ~' ': ' ':' ~ '.~'~t'75' 150sx Class "G"-kickoff pi ~ DEPTH I~TER-VAL(MD) AMOUNT& KIND OF MATERIAL USED · ; , . 27, pR'oDUCTION TEsT ' Date First Production.. , ,... Method of Operation (~lowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF: WATER-BBL CHOKESIZE IGAS-OILRATI© · . " .. ;, : · TEST PERIOD ~- ',, i ' ' ' I Flow Tubng. Casing Pressure CALCULATED: j~ OIL~EEL,. GA'S-MCF , WATER-EEL OIL GRAVITY-APl (corr) Press. - ,. .... ' 2~4.HOUR RATE". 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, i~il ~:,: , · ~ . ug Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS ;-: ~.~ '" .~ :,, -; :i :~:,";': Include interval tested, pressure data, all fluids recovered and gravitY, GOR, and time Of each phase. ' - of my knowledge NAME · MEAS. DEPTH TRUE VERT. DEPTH TO BE SUBMI ~ TED. ,.. . . . , ,, 31. LIST OF ATTACHMENTS . 32... ' I hereby certify that the foregoing is to the best Title Sr. Drlg. Fmgr,. INSTRUCTIONS " General': This fOrm is designed.for submitting a complete and correct well completion.report and log on all typesof lands and leases in Alask.a. 'Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given, in other spaces on this form and in any attachments. Item 16 and-24: If this..well is completed for. separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the prodUcing intervals for only 'the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supPlemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DS 12-7A (Sidetrack) Drilling History Production perforations squeezed w/4OOsx Class "G" cmt. RIH w/tubing cutter and CCL - cut tubing @ 9757'. Accepted @ 0900 hrs, 12/12/81. Set BPV. ND tree. NU BOPE and tesiced to 5000 psi - ok. Pull BPV. Pulled 231 its 5-1/2" tubing. Ran CBL/VDL/CCL/GR. RIH and mill 9-5/8" casing from 9271' - 9316'. Set cement plug w/150sx Class "G" cement - tagged cement @ 9075'. Cleaned out cement to 9261' RIH and Dyna Drill fr/9261' - 9382'. Continued drilling 8-1/2" hole to ~0,570' Ran DIL/BHCS/GR/SP and FDC/CNL/Cal. Ran 39 its 7" 29# L-80 liner' fr/8966' to'10,563'. Cemented 7" liner w/587sx Class "G" cement. Drilled cement to 10,535'PBTD. Test liner lap to 2000 psi - ok. Displaced · well to NaC1/brine. Ran CBL/GR. Ran 4-1/2" competion assembly w/tail 0 9006' and packer @ 8935'. Tested tu6ing hanger and packoff to 5000 psi - ok. Set BPV and ND BOPE. NU tree and test to 5000 psi - ok. Pull BPV. Displaced well to diesel. Dropped ball and set packer. Tested tubing to 200 psi and annulus to 750 psi - ok. Tested tubing to 3000 psi and annulus to 200 psi - ok. Secured well and released rig @ 1800 hrs, 12/30/81. Eastman Whipstock A PETROLANE COHPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. , , COMPANY DS 12.r Well Number: 7A WELL. NAME Prudhoe Bay, North Slope, Alaska LOCATI ON JOB NUMBER TYPE OF SURVEY Directional Single Shot DATE ~E£EIVED ]982 Alaska Oil & Gas Cons. Anchorag~ SURVEY BY American Directional Drilling OFFICE (G. Thibodeaux) ~OiqM ~"302 R2 ARCO AI_ASKA., INE:. D'.::: 12, WELL NO: 7A DSS (AMERIrZ_:AN DIRECTIONAL DRILLII~IG) PRUDHOE BAY NORTH .=.LJFE ALASKA L'I¢'¢'.=,.=. , ¢~27 1 - 104'?0 MEI, l' I E- I N PCI I NT I c. ....... AT 92F~r~ bl[I '.::;I_IRVEY F'ROVIDED BY AMERICAN DIREC:TIONAL DRILLING. REL. LRD OF .'::l IRVFY RAEIII_I:3 OF I]:LIRVATLIRE ME I'HOL'I ARC:O AL. AS:K(./., I NC:, ;, -!" '1'-''? DS 12 WELL NL,, '7A E.:..:, F:°RLIDHOE BAY., NORI'H c'/FIPF ........... ALASKA (AMERICAN DIRECTIONAL DRII_LING) COMPI_ITAT I ON PAGE '~ NO. :!. · T I ME DA']-E ,,.; )"" 55 TRUE MEA.:,I_RED DRIFI' DRIFI' r":C,_IR.'::;E VERTIC:AL VERTIF:AL '.:;IIB".::EA R E C T A I',! C.i II L A R r': 1_ 0 c. i.i R E [,,:::,':i~l._E.r.i~ DEF'TH AN6L_E El I REF:I' I FIN LENGTH DEPTH SECT I ON TVD C 0 0 R D I N A 'F E S D I'"".::,TANI-'_.E- [I I I:;t[!i:l]::l' I FIN... ::31i:iVER I '1-'," FEET D M D I'1 FEET FEET FEET FEET FEET FEET D M !',3 / 10,.'-~F'T '.-.7200. 36 0 S 73 0 E 'F~271, 36 0 '..E: 7:3 0 94.31. 3:3 0 S :31 0 E 'iP604. :::1 0 S 88 0 E 9781. 2E: 0 S 82 0 E 0 7'.~0:3 ?,'7 ':' /- "::' ~i 1° 7827 'F.'7 1'-"'-'~ 64 ¢' .... :,.,,:.~ 3:384 11 E "" ":"=' .... .:,6._~._, Pi'-? S 6 ::: :3.4. I:E · -'t ct-., ~,",:qb'~ :'::4 71 79/_-,1 41 .:,=.6~ ..... 41 1 0 :_--:,1 ':' ,,=,,_ ..... , 3424-.02 E :::677 20 '::' 6.'_:: :::7 E: ~ 60 '-" '-'-' :3757 ~.-- '=' ' 17 2/_-. 1361 ':' ':'s ':' o<~?._-, ,__,'-:'/- '-"'-' ,:,0 1 .:,'-' 12 24 E 37/_-,/_-, 7'~ L-,:q 4'::)E im · ...' .m · ., 17 3 "~"-" ':' ':) '-/' ._', ,-. 4 6 °F/7 1 0 7 6 ? ~, ,., ..._,., ~.~ F", '-":"' '-J ,_-, 16o. '-T~&. 3/:.'F~, g".-~ ¢' '-'/ ' '-' .... · _, .:., :,0o,, 4.:z: F ."{; 1 1 E{ · · ............. *ml'..I.m *.- & 177 ,-,.-,e .Z ?.:,Z. 14 18 O0 1377 ="" ,=..:, .': 4-. 00 '- '- '-'"" ':' ..... -, . . .-,,-, ........ S :::Aq','A ":.,:.. .... 1 E :,.':.:,,=,..'c"'-'"':" '?,"-,_ L:; ,:.S'~:: :2:2 E (), 00 0. O0 ":' :':; 2.4:3 1 OF'. "'3.. 26 45 '='._, ,:,.-,'-":' () E 10~:. 26 0 'S 74 0 E 0.51 (). ?() FINAL C:LC .:,_IRE nlRECTION: DI" ...... . ,. , _ .... · =,FANL. E" 4.??,'--'' 66 FEEl' S 70 DEGS l-O" .=,E_.~, E ,;.. M I NS; .::','" '"' F'~' ..; .............................................................. ~ ............................................... ; .................................. ~ ...... ~ ,. .._~ '. ~ .................................. ~ .......... ~ ...................... ~ ........... . -~ .... [ .......................... - i '? ~u'~ -~ ~) ....... ~ ...... ................................... ~..~ .... ~ :F ~; ............................ , ............ ............ ~ ...... _ ......................... , ............... ~ ................... ~ , ~ ~ --- ........... - .................................... ~ "l-'l ............ ~ ..... ~ ............................ SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage, Alaska 99502 · 907/349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED January 2, 1982 Job #3291 North Slope Drilling- Enclosed please find our Gyro Survey on DS 12-7A along with our Horizontal and Vertical View mapS, Film, and Field paperwork. If any other information is needed please call 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely Manager A!~C~.~ ALASI,'~,/~ Il,IL, (,Y',,:c)SC(JI~IC SLJI.',VEY I:~AU ILlS C ()h ~ P L ~ 1? I!'. D t, iEiI't-luL~ '(}F COi',-iPUl' Al' l ON l:.'t.1 L, I i,~D,'5I';Y b Aoo.':' 12-'fA it() F't · $LJI.qVt:,Y UAl't: 022 JAN. JOt¢ N() 32':)1, RECOt,<D OF 5UPVFY /4EAS. DRIFT D~PTH AHGLc,,., D 0 0 0 2 (.) 00 0 0 250O 0 30 300O 4 30 3100 6 0 320O 8 30 330(.) 10 15 3400 12 0 3500 11,/.I. 0 · 360(') 1,~ 0 3700 18 30 3800 20 0 3900 23 15 4000 ~5 30 410C) 28 30 4200 32 0 4300 35 0 4400 247 .3(} 4500 40 30 4(300 42 15 4700 43 25 48 O0 44 0 4900 44 0 5000 4,3 3(} 5100 43 4.5 TRUE VERT I CAL D E P T k.I (') · 00 2499.99 299'9.41 3098.99 3198 · 18 3296.84 3394, .96 3492*39 3538.9~ 3684,47 3778~8 3871,8B ~962,91 4052,00 4221,75 4302,39 4380,09 4455, 13 4528.~5 4600,73 G672~67 4744,90 4817,29 StJB DR I F 'r S E A D I R E C DEG. '"' 8 (). O0 1920 · O0 z41~.99 2919.41 ~018.99 3118.18 3216.84 3314, 3412,39 3508 3604.47 3698 ~791,8~ 3882,9 40~8,37 41g~l ,75 4222,~9 4300 · 09 4375. 4520.73 ~592,67 S O.OOE 558.61E S22.33E 568 · 03E S81.28E $73.04E S67,86E 580.3 ~,~E; 579.13E S75 · 94~ S73.69E 572,49E S72,84E' 869,88B S69.'44. E 868.89E S66.99~ $63 · 31E S65.2~E 564.11E 565.21~ SOB. 68E S65,79E 4,,93E 5,53E 4.664,90 56 4737,29 56 T 0 'r i::~ L C () 0 R D 1 N A T E S C L O S U D I $ T A i',~ C E 36,53 S 93,55 E 42.11 S 118,81 E 49,8.q S 14'7,43 E 59,47 S 178,97 70,4.5 $ 214,14 E 8~.6~+ S 25~.24 E 99.42 S 295.81 117,~3 S ~42,88 E 12~8.06 S 394,03 E loz,90 S 447.67 190.22 S 504.3~ E 218.50 5 504.09 E 247.60 S 625,54 E 277.41 S 687,89 307,05 S 750~71 335,88 S 813,~6 E 364,79 S 876,20 E O.O0 S 0 0,00 S 0 2,14 5 40 23.37 5 44 31,61 S 53 43.42 S 59 59,50 5 62 78.47 S 65 100,43 S 68 1Z6,0f~ $ 70 155.64 S 71 188.59 S 71 225,44 S 71 200,70 5 71 312.07 S 71 362.40 S 71 41.7.51 S 70 476.39 S 70 672,76 $ 68 741.72 S 68 811,07 $ 67 880,17 S 67 949,11 S 67 RES A f,4 G L E D DOG LEG GEV'-"" ,:-,I TY DEG/I()OFT 0 · ~,) 0 (.) O.oOO O. 0.802 1.507 1 · 768 1.832 2 . 001 2.015 2.510 1,50't 3.250 2,310 3,002 3.503 3,064 2.848 3,107 1 . 822 1'289 0,933 1.456 0,645 0,381 SECT ION i STAi,~CE 0,00 0.0() 1.84 20,92 42,57 58,86 78,09 100.33 155,6-. 188,59 225.42 200,59 3i2.06 302.40 4'16.29 538.75 604,42 671,97 740.60 809,62 878,41 947,03 Al.:Ct-1 iSS 12-7A (:~YI:,:¢,IbC()t¢ ! C bLJI<VI: Y 5Ui.{VbYLL) U.:'. JA,,I, ~,:'. I,',ECORI.~ eoF: ,".,llt<Vk Y ME:AS. DRIFT DE[:'TH ANGLL: D M 5200 43 45 53(.)(7) 40 5400 37 45 5500 38 45 560O 40 0 57O0 41 45 5800 41 30 59OO 6000 ~,4 30 6100 42 6200 42~ 30 63o0 43 30 ¢.aO0 43 r) 6500 43 15 6600 41 15 6700 41 15 68O0 4b 0 6900 41 15 70O0 4() 15 7100 40 15 7200 43 30 7300 43 30 74O0 42 45 75O0 45 30 7600 44 4.5 77O0 /+5 30 7800 t~O a5 7900 8000 T R l,J F. \/Lj F4 T ICAL D [] t.-' T H 4889.53 4963 5041.25 5119.78 5197.08 5272 · 69 5347./45 5421,02 5492,80 5565.19 5637.57 5709. 57S2,34 5855,33 5929,35 6004 · 53 6080,43 6156~B2 6232,08 6308.40 6382.85 6455~39 6528,38 6600 · 15 6670,7]. 6741,26 6814.23 6889,99 6965 · 46 S U t3 SEA 4809,53 4tl83,68 496]..25 5039.7b' 5117,08 5192.69 534 ].. 02 5412,80 5485,19 5557.57 5629 · 50 5702,34 5775.33 5849.35 5924 · 53 O00(), 43 6076,32 6152~.08 6228.40 6302,85 6375,39 64&8 ~ 38 6520.15 0590 · 71 66~1 . 26 6734.23 8809,99 6885,46 DR IFl' DIREC DEG. S64 · 0SE S67.61E ,ST0 o 48E S70,185 S69,81E S67,99E S07.9OE S6 5 · 86E S67 · 11 g S66.50~ S66.18E S06,29E S07,71E S66,8~E S66,39E S66.29E S67,68E S66,21E S66,91E $64,61E $6B,75E S63,81E S62,63E 663 · 43E S66,89E S72,93E S74,50E 575.00E TOI'AL COOi,~DINATES CLOSURES D I STAdCE ANGLE D M 394,23 S 938.78 E 1018.19 S 67 13 14 421.67 S 999.96 g 1085.23 S 67 8 8 E 44.4..23 S 1058,88 E 1148.Z9 S 67 14 25 g 465,07 S 1117.17 486.77 S 1176,78 E 1273.49 S 67 510.33 S 1237,83 E 561 .~ o 1361,70 589, ~77 %~..~.~..~ 1425 ¢~. 53 ~- ~.': ~ ;'h~ ~W n ~ ,~ . ~ · · Y.S,-78.tfE(-,.II.:-,lU18,57 S 67 23 19 725,61 S 1741.83 E 1886,93 S 67 2~ 4 E 752.30 S 1803,52~ E 1954,15 5 67 21 28 E 778,76 S 1863,93 E 2020,08 8O4.86 S 1923,58 E 2o85,18 5 67 17 ~0 E 8~0,2/+ S 1983,54 85D.80 S 204~,60 E ~215,~6 S 67 16 881,50 S ~.102,88 E 2280,17 S 67 908,90 S 2163,7~ E 2~46,88 938,88 S 2225,70 E 241.5.52 S 67 7 41 E 969,08 S 2287,02 000,45 S 2349,17 E 2553,33 S 66 ()62,D5 S 2476,63 E 2694,86 085.82 S 2540,78 E 2763.07 104,1Z S 2603,43 g 2827,89 121.38 S 2666,75 E 2892,91 S 67 11 34 E DOG LEG SEVL~< I 'FY D E G / 10 o I: l' £.00~ 3.575 2.953 1 · 007 1,927 0,250 2 . q. 6~+ 0.969 1,772 1.75'? 1,001 0,82~ 0.483 Z,O09 0,060 1'252 1,30i 1,17~ 0,452 3,4.28 0.592 0.751 2,815 0 · 84U 1,913 5 · 402 0,545 b t.:,. C T I 0 ?'4 015 TAN CI;~ 1015,75 1082 · 52 1145,56 1207,46 1270,89 1330.27 1402,59 1539.50 1608,29 1677,03 1740 · 24 1814.57 1882 · 77 2015.4 2080.B7 2210,40 2274,80 2541.24 2409,56 2477,35 2010.44 2086,90 2755,19 Z~ZO,40 288b,88 ",I:tC(:, I)S 12-/'A t.~1:, GYROSCL}F'iC SUtJ, V[:JY JC~i3 N() 3;:91 .fiL,II-qVEYI.:[.~ (.;2 JA~,~,, 1'! E C (J F, D () F S I, ~1~ V i.. Y BiO,.') 41 15 704(.!.6,4 0900.64 S74.9"JL 8200 aO 30 7116.25 7C)36,2b S74.23E ~3bO 460 0 7192.58 7112.58 874.28E 8~00 ~0 15 7269.04. 7189.0~ S74,98E 8500 38 ~C) 7346.34 7266,34 8600:3° 0 7424,33 ~700 38 30 7502.31 7422.31 57B..36E ~800 36 0 7581.91 7501.91 S73.24E ~900 36 0 7662.81 7582.81 S73.14E 9000 36 45 774-3.33 7663.33 S72 glO0 36 45 7823.~5 774.3.45 S72.75E 0200 36 0 7903.97 7823.97 S72.86E 9300 35 0 7985.38 7905.38 883.13E 9400 32 10 8068.67 79~.~,67 i~i86.83E · 9500 3I 45 8153.52 8073.52 N87.82E 9600 31 15 8238.79 8158.78 N87.48E 970U 30 15 8324.72 82~4..72 I',18C.63E 9800 29 0 8411.~5 8331.65: S89.73E 9900 27 15 8499.83 8419.83 S88.68E lO000 27 BO 8588.6z~ 8508.64 587.47E 10100 28 0 8677.13 8597.13 S83,17E 10200 28 30 8765.22 8685.22 S79.30E 10300 28 15 8853.21 8773.21 $78,30E 10400 28 0 892~1,40 8861,40 678.85E lo5o0 28 o 9029.69 8949.69 578.95E FXTI~APOLATEL', TO TD. 10570 28 0 9091.50 9011..50 $78.95E 1 0 I' t\ L C ( ,¢)I -i [,) 1 'N A '[ E .5 C L. (.; S U Ij, E..b b ! ,b T A I',i C [.:. A r,,l G L L 1138.48 ::, 2730.41 i 29bb,,,i:b 1155.U8 S 2'}'93.49 E 3023.19 117.3.41 $ 2855.68 E 3087.36 1190.49 S 2917,8Z E 3151.34 1206.77 S 2'979.13 E 13214.,2'/' 122:5.'72 S 3039.38 E 3276,48 i24i.~7 s ~o9~3.~5 E 333~ ~2 s i57. z F_ iO 1342,48 S 3496.04 E 37~.94 1340.01 S 3548.92 E 3'793.47 1337.87 S '.3601.12 E 38~1.61 1336.13 S 3652.22 [5: 388B.96 133~.06 S 3701.05 E 393~.25 1336,31 S 374~,,78 E 1337.~ S 379/-+.74 E 1341,66 S 3B41.13 E 1348,87 $ 3U87,90 E 1358,10 S 3934.52 E 1367.~3 S 3980,72 E 1376.q7 S 4026.79 E 1382.77 S 4059.05 E 428d.i2 S 71 11 16 E L) (3 ('i L L o SEVLI< I '1Y I.) L, G / 1 G (? F 1' 0.04~ 0.8O0 0.500 0.38 D 1 °754 0.927 2.500 0.059 0,054 0,751 3.524 4.014 C.b'02 0.508 1 .U42 1 ,:~08 1,764 0.359 1.07g 1.013 0,278 0,000 3017,00 3081,52 3209,13 3334.18 3394'.66 3453.4'0 3512,08 3572,49 3~31.77 3089.36 3'742.19 3'791.4~ 3840.1~ 3887,98 3934.62' 39'/9.44 4023.44 4068,58 4115.18 4162'2~ 4255.55 %2U8.12 n. OTTO,~,.: HOLE CLOSURE 4288.12 FEET AT S 71 !1 16 E APCQ f'),5 12-78 ,l:';,ID c. Yi::~(~SC(~I,:,'IC SUI'::VEY jOt~ I'-40 32");]. IhlTFI~P(.)LATI::,[) I'I.:L~I; V[:I'.!I'~CAL DEPTFIS~ CU[)I4',L~It.~AI'[{.% A¢'<D CL(..)~:,UI<ES F¢)I~ GIvEr4 DEPTt.tS CODE ME ASURI~I) VERTICAL I',tAME DEPTH DEPI'H TOTAL COORD I NATES CLOSURE D I STANCE ANGLE D M S ,SURVEYED 02. JAN, 8Z ,SUB SEA TOP SAD 10331 8880,53 PI3TD 10535 9060.60 TD 10570 9091,50 1361.14 S 1379.89 S 1382.7'7 S 3948,85 E 4042,87 E 4059,05 E 4176,86 S 70 58 52 E 8800,53 4271.87 S 71 9 15 E 8980.60 428U,12 $ 71 il 16 E 9011.50 ARCO [')S 12-TA.RD F~,t':A51.11.!t,;[:~ DI:P¥t..] ANI~ F (.) i.~ i~;V L,, R Y t= I,.L I' (')t:: .%lJt5 --=St'.A I,)1:, [-~ T PI, 5UNVEYt!'D U;! JAN. D E P 1' H 1' RUE V 1: i.~, T ! F.: A L ,% t.,J f~, D I]:: P r t-i s [,!~ A H D- T VD D I I::' Fk le, L,N C VKF',T I CAL C¢)R I','. E C T I ON TOTAL CO0t~P !NATgS laO 180. 280 2~0o 38O 380, 480 480. 580 58U · 680 580, 7RO 780. 880 880. 980 980, 1080 1080. 1180 1180. 1280 1280. 1380 1380. 1480 1480 · 1580 1580, 1680 1680. ], 78 0 17 80 · 1880 IUSO. 1980 19iJO'. 2(350 2080 · 2180 2180. 2280 2280. 2380 2380, 24.80 24.80, 2580 2580. 268 0 2680 · 2730 2780. 2 a8 0 2H 80. 298 1 2980 · 3081 30[30. 3182 3180. 3283 3280, ~385 3380. 34P, 7 3880, 3591 100 200 300 4O0 600 700 800 90O 1000 11 (30 1200 1300 1400 1 5 u (,;, 1 1700 1800 19 C) 0 2000 21 O0 2200 230 0 2400 25 CO 2500 27(i0 2800 /' 2900 3000 3100 ~200 ~300 3~.~00 :JSOO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 ? 10 U.O0 O.OU U.O0 U.O0 U.OO U.OO ~.OO U. OO U.UU O.OU O.OO O. UU O.UO 0.03 0,59 1,50 2.66 4.93 8,07 11.81 15.85 18.66 21.lB 26.24 32,!1 36.04 41,70 1 '2 '6 9 0.00 W 0.00 W 0,00 W O.UO W 0.00 W O.OU W 0,00 W 0.00 W 0.00 W 0.00 W O.UO W 0.00 W O.UO U.OO 0.00 W O.O0 W 0.00 W 0,00 W O.U4 E 0,22 E 0,50 E 0.~7 E 1.,29 E' 1,88 E 3,32 E 5,88 E 9.78 E 5.17 E 3.33 E 5,O0 0,07 E 8,27 E 0.47 E 6,28 E A P. C 0 b S ~' ~ i£ A ,S I JR L !3 12-7A. F',D DLPl't"t AND o'[:l-tL:,i~ I) A T A (':i Y Iq 0 S C 0 P I C FOR L\/LkY SURVEY LVI::N It') FL[if ()1-' 5[.3f~ 5L'^ [)LPI'H. SUf,~VEYED 02 Ji~N,, OZ t-f E A S U iR t:.{ D [)PIP TH 'I R U E VERT I CAL D L P T SUP. SLA HD-TVO D IF'FERENCE VF'RT ICAL C 0 R R ~. C T [ 0 i"-~ TOTAL COORD INATE5 3~0 :l 401g 4~49 4372 4500 4771 4010 504B 51B7 5321 5449 5578 571C, 5982 5259 639 7 6534 6667 6799 6931 7063 7196 7334 7471 7613 7754 7887 8019 8152 3680 · 37,a0. 3880. 3~80. 4.180, 4280 · a38o. 4480 . 4580 · 4680. 4780. 4. B 80 · 4980. 5080 · 5180. 5280. 54B0 · 5680, 5780, 5880. 5980. 6180, 6280. 6380. 6480. 6F80. 6780, 5880. 6980. 3600 370O 380O 390(') 4000 4100 4200 4300 450(3 /-+600 4.700 4 8 0 0 490 0 5000 5 ]. 00 5200 5300 5 4 t,) 0 5500 5600 5700 5800 5900 6000 6100 6 200 63('30 6400 6500 6600 6700 680O 6900 7 (7)0 1-5 21 28 38 52 69 91 119 153 191 23O 268 307 341 369 397 43O 463 5¢)2 540 579 617 654 687 719 751 783 816 854 891 974 1007 1039 1072 49 59 71 86 105 12'7 155 190 228 309 350 Ilt~: ~<~ 0 b 46 505 622 601 698 734 770 804 87~ 908 949 991 1036 1076 1102 · 83 S 145,81 · 58 S 179,29 ,55 S 217.49 · 60 S 260.96 · 03 $ 310,30 .47 S 367,37 .96 ,5 4~2.26 · 45 S 504 · 16 ,41 5 584.56 · 85 5 669,68 .99 5 75'7,00 · 20 5 843.35 · 57 S 930,41 · N9 5 1012,47 · Sb 5 1087,22 · 20 5 1163.27 · 87 S 1243.8~ · gb b 1326.42 .14 S 1413,71 · 28 ~ 1501.39 · 21 S 15~9.83 · 89 S 1676,53 · 93 5 1762.78 · 26 5 1843.90 · 9~ 5 1922,82 · 25 S 2002.28 · 30 S 2080,66 · 51 S 2160,90 .43 S 2246,41 · 64 S 2BB0,62 · 72 $ 24~0,~0 · 72 $ 2511.48 · 51 S 2594,93 · 64 $ 2678,82 ,89 6 2763,23 (.; V I.i i) .% C ()I..~ I ¢: I.,A'I/~ t o1,:. LVLI.iY 5UI~,VLY LVi.I.I lot, 0t' ,bUI3 ;iL^ DLt~/'t't, ~'iLJl'i V t;~ Y E D 02 d f, lli: ASUlt t',: I) t. ~ { ( t,' l" I 1 l'l'~LJl,, Vl(I-i'l' ! CAL I) i._J I.:' '1 I SL.A L) lt'"FLI.:LNCI,:. '1 d/AL C OU I:< L) 1NA l'h ,5 8414 854.3 86'11 8798 8921 904.6 9170 9293 9413 9531 9648 9764 9878 9990 0103 0217 0330 0444 0.557 71 ~l 0 7380 '1480 75~0 768 0 7780 7880 7980 8080 8180 8280 8380 8480 8580 8680 71~1o 7 2 C) 0 7300 7z, O0 7500 7600 7700 7800 7900 UO00 6100 .3200 U300 d/+O0 ~::500 8700 5900 9000 11o3 11'34 1163 1191 1218 1241 1266 1290 1313 13B3 1351 1368 1384 1398 1410 1423 1437 1450 1464 1477 1170,6! 119Z.9'! 1213.91 1236,73 125J.95 1279.69 1301 · 87 132~,97 1340.65 1342, O1 1339,16 1336.68 i'~38.08 1350,41 13 61 · 05 1371,70 1D82.03 284,5.¢)8 2926 · 49 3004~ · 99 3081 . 95 315~5.89 3225.40 3296.34 3S67 , 04 3436 · 73 3509 · 94 3565.17 3625 , 87 3683,94 3738,47 3790 · 11. ~842,53 3895 * 76 ~948.39 4000,80 4052,95 12-7A-RI> ,ll,i'l'[:i'<t'ut.A'f[.I) VAL. tJt:.& t T ;-~ LI /.,1t:: A 5 U I< I~ b V [.: i?, T ! C I.) E PTt t [) L.i 1-' T L, V 1:. L AL 1-1 1 (3 o 0 10 t~ o. 9 20(7)0 20()0. 19 3(.)00 299,.,¢. 29 4000 3962 · 38 5000 6000 7000 62~2. 6i 8000 696~. 68 9000 77l*3. 76 10000 8588. ¢:iY~()SCOPIr~ SUHVLY jOL~ NO 3291 lOOk) I'LL'I k~t ilui\,bUi4LL.) DL'i'Iil. ~: t/t~, .%LA TOTAL LUuRD i t,~^'ru s 20. O.Ou S 0.00 W 20. ,3. L)O S O.uu 19. 16.64 $ 16.40 82, 84.2.2 S 253,04' E 64, 336.82 S 813,12 E 12, 590,11 S 1425,30 E 52, 856.26 S 2043,.%0 E 85. 1121,65 S 2666..65 E 63, 1293.89 S 3.270.1.5 E 08, 1338.3~ S 3794.72 E %.,*~:~,~,,,¢",¢¢' ....... .... g, Ui'4VEYLD 02 JAn. ............... - ............ ------------------'---- HORiZONTAL.. _ VIEW. ....... : ........ .: . ,ARCO ALASKA~ INC.~ ......... WELL:- DS 12'~7A---'RD .......... -:' ............... : "~' -'- RADIUS-OF-CURVATURE : GYROSCOPIC . SURVE~_-"__:-_i ........................... _z ................ : ............... . ....... : uAr~t, ~.~ I~.~_ i c~..~.. _'.,,, _,~,_,_<,_,___... --- _.-~ ,- . .................... ....... ...... t -. :--.~ ............ _ _ : ...... ............... __ :-,- ................. ..... : ........... : ....'- ......... ' ....... i ........................ i ........................ + ...... -: ..... + .......... ~ ............... :- .... ----!-~ ....................... : .... 'F: - - ': ........ ,, .......... : .--*, .... -r ..... :'- ............ ..---T- ........ --T--.--T---:-~-.+_----~----T--7.. .......................... : ...................... ~ ~iiii:.:~~:: .... -'. : --. --- .......... ": - : .... :--::' ............................. '. -' · :-7--:- ........ ~! .... T--': ........ · '-" TVD= 9092,~ ' TMD= i0~570' ' ?. SURFACE LOCATION IS ..... 459' NSL~ I0' WEL~ SEC. 18 T. I0 N~R. 15 E.~ U.M. '-' , _ . VERTICAL SECTION ................ ARCO ALASKA : WE CC-- DS"-12,-:.7A-- R - * i : ' RADIUS OF CURVATURE -i .:'_ '*_"__~' i ..... *.'.- * i- ~.~. i : _____GYROSCOPIC...___ --SURVEY '- -~CALI~: ..... ' *' ....... ' ..... " MARCH . : : .... '. ................. ~ ..... ~. . - .......... ~ ......... = ........... .......... ~' .......... ; ...... - ...... : ........ · '. ....... ALL DEPTHS SHOWN .... ' -ARE .... TVD ; : -. ~. ... - .................. : 5200 7600 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: /- ~ Date Required Date Received Ccm~pletion Re~ort Yes .... / Well History Yes / , . Mud L~ Core ~scription ~ ~' e ~ Registered Su~ey Plat Inclination Su~ey Drill St~ Tes~ Pr~u~ion Test Re~rts .~a' ~~ -- ......... " Digitiz~ ~ta ARCO Oil and Gas Company North Alaska~':' '~trict Post Office ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochcn District Operations Engineer ,.January 19,'1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.11-5~/ 12/20/81 D.S. 12-7A~ 1/1/82' Tape f/62405 Tape f/62450 D.S'.3-18~ 11/7/81 ]~.S.15-15~J 1/8/82 Tape ~/62330 Tape f~62470 se sign and return the attached copy as receipt of data. Mary F.' Kellis North Engineering Transmittal f! 894 · DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY CHEVRON A_as~ Oil & Gas Cons. AnChorag~ Corm~l~$1o~l ARCO Oil and G~s Company ~s a.Divi$~on ol AllanhcRichhelclCompany - ARCO. Oil and Gas Company North Alaskaf' 'rict Post Oltice BX~, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operahons Engineer January 18, 1982 , Reference: ARCO -~ASED HOLE FINALS D.S.6-6 12/17/81 D.S.ll-5 1/1/82 D.S.12-7A 12/28/81 D.S.11-5 12/19/81 D.S.11-5 12/29/81 D.S.4-10 12/3/81 D.S.16-9 1/7/82 Gamma Ray Collar Log Collar Log ACBL/¥DL Collar Log Gamma Ray Collar Log Perforation & Collar Log Spinner Survey Run 1 5" Run 1 2"/5" Run 1 5" Run 1 2"/5" Run 1 2"/5" Run 1 5" Run 1 5" se sign and retrun the attached copy as receipt of data° Mary F~ Kellis North Engineering Transmittal # 888 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL PHILLIP! MARATHON Alaska Oil & ~as Cons. CommiSsion CHEVRON Anchorago ARCO OII and Gas Company is a Division ol AtlanhcR~chfieldCompany · ARCO Oil and Gas~'~mpany North Alask~ ~istrict Post Oil;ce 6ox 3~0 Anchorage, Alaska 99510 Telephcne 907 277 5637 Jerry A. Rochon District Operations Engineer January 11, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.12-7A~ 12/24/81 Tape #62424 D.S.11-5~ 12/23/81 Tape #62421 D.S.14-12w~ 2/23/81 Tape #62425 D.S.12-8B~ 12/19/81 Tape #61416 D.S.15-14~'~ 12/17/81 Tape #62376 D.S.9-5~ 12/13/81 Tape #62365 D.S.i~-13 ~' 11/23/81 Tape #62326 D.S.15-12L/ 12/22/81 Tape #62426 and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #871 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PH]LL~PS '£EIV=D CHEVRON Naska Oil & Gas Cons. Commission ~ch0rage ARCO Oil and Gas Company is a Division ol AtlanlicRichtieldComDany £ATE OF ALAS~\ ALASKA OIL & -CAS GONSERVATIO;' CCM~ISSION B.O.P.E. Inspoction Report. Date erator ~o ,cation: Sec T R il ling Contractor .~_D~3 ~ ~ M Rig #gl Representative Permit # Casing Set Representative .cation, Genera] ~ ii sign neral Housekeeping serve pit ~)~ Stack Test ~es~ ~ : Pul ACCUMULATOR SYSTEM 1 Charge Pres sure ~ssure After Closure psig , psig ~incr. clos. pres. 200 psig [! Charge Pressure Attained: ~\l[Contgls: b~ster psig '~;[ Remote' Blinds switch cover Kelly and Floor Safety Valves · nular Preventer-- pe Rams ind Rams eke Line Valves.~ C.R.' Valve 11 Line Valves- , eck Valve Upper Kelly Lower Kelly Ball Type Irs ide BOP Choke Manifold No. Valves__ Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure No. flanges ._ ~dj ustable Chokes_ .Hydrauically operated choke min sec. min sec. st Results: Failures Test Tim~ , hrs. _ pair or Replacement of failed equipment to be made within .... days and spector/Ccmmi~ion office notified. ~arks: stribution ig. - AO&GSC - Operator - Supervisor Inspector BLOWO Y" T pR EV ENTE ..,TEST. ANNUl. AR WORKING PR[S. ~-ooo .-.. CHOK~ NiANtFOL~ RAM-SIZE' · , ~/,~c~ · d '. s,z ' RAM SIZE~. ,~ -' .. ~ ~ '1 , . * i ~ - WORKING PR~.' ~ 0 0 0 . . ,.,Ca~ ~o~' ' w~' U' sI~ ~' ~'"' .. I ... .... WORKING: PR'r.~. ~T'O0. o RAM $.lZ,~. . ' . o , ~o ..,~,, i i i i i i' i I ii iji iiii, J ~ . ¢ , i i i i i ~ i _ i i ii ii i illl ' / _ . ii .... T~ ~ _ .~.~ .6 ~ D. o.~ ¢... , , ii i i . i i i iii i, ii i ii i i ii iii i ] i . ii ill i i i i i i .... ' ......... 2D.o ~,.~;, i i . ii , u i i i , L ~__ ~ .,,,, . .... ... .... .- _.~ . .. ,. ,, .. ,~.~..~.~,. . ~.., December 1, 1981 Mr.. Charles E. Ross Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re~ Prudhoe Bay Unit DS 12-7A ARCO Alaska Inc. Permit No. 81-175 Sur. Loc.~ 459'FSL, 10'FEL, Sec 18, T10~, R15E, UM. 'Bo~to~hole L~c.m 1024'FNL, 1279'FEL, Sec 20, T10N, R15E, Dear Mr. Ross Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud Icg are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be s%~bmitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 1~.50. 870 and the regulations promulgated thereunder (Title 5, Alas.ka Administrative Code). Prior to commencing operatio~ you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title i8, Alaska Administrative Code, .Chapter 70) and by the Federal 'Water Pollution Control Act, as amended. Prior to Hr. Charles E. Ross Prudhoe Bay Unit DS 12-7A -2- December 1, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hoy H. Hamilton Chairman of BY ORDER OF TH~ CONi~A~$$~ON Alas~ka Oil & Gas Conservation Commission Enclosure c'c= Department of Fish & Game, Habitat Se~ion w/o enul. Department of Environme.ntal Conservation w/o/eno1. ARCO Alaska, Inc./~ Post Office~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1981 Mr. Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 12-7 Sundry Notice to Plug and Abandon Dear Sir: Enclosed please find our applicatiOn for Permit to Drill DS 12-7A (Sidetrack) and the required $100 filing fee. Attachments to the application include a plan view of the proposed wellbore and description of the BOP equipment and testing procedure, including anticipated pressures. Inasmuch as this well will be sidetracked from the DS 12-7 wellbore, which previously produced from the Sadlerochit formation, our Sundry Notice is also attached describing the Notice of Intention to Abandon that wellbore. We anticipate~beginni.ng operations on this well on or about ~December 11, 1981. Your early review of this application is appreciated. ou rs, C. E. Ross Sr. Dri 11 i ng Eng i neer CER:SLB:ltc Attachment ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL ~ DEVELOPMENT OIL r~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 459'FSL, 10'FEL, Sec 18, T10N, R15E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 1000'FNL, 1386'FEL, Sec 20, T10N, R15-E, UM DS 12-7A At total depth 11. Field and pool 1024'FNL, 1279'FEL, Sec 20~ T10N, R15E, UM Prudhoe 0il Pool 5. Elevation in feet (indicate KB, DF etc.) ~ 6. Lease designation and serial no. .Prudhoe Bay Fi el d 80' KB~ ADL 28330 12. Bond information (see ~0 AAC 25.025) Type Statewide surety and/or number Fed. Ins. Co '#8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property Or lease line 15. Distance to nearest drilling or completed ENE Deadhorse, AK 5 miles 1386 feet we. 2535 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10,357'MD 8912'TVD feet 2560 December 11 ~ 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3714 psig@ .. Surface KICK OFF POINT9300feet. MAXIMUM HOLE ANGLE 28 oI (see 20 AAC 25.035 (c) (2)4382.psig@ 891 2 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight I Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8~ 7 29# L-80 Butt 1357 9000 I 7740 10 357~1:9111 400 sx Class "G" I ~ I I ~ I 22. Describe proposed program: Operator plans to section mill a +_40' window at 9300' and sidetrack to a new bottom hole location +150' northeast at 10,357' MD (8912'TVD). Logs will be run in the open hole. A 13-5/~" 5000 psi RSRRA B0P stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and~operationally tested each trip. A string of 4½" 12 6# L-80 tubi~ng, packer, and subsurface safety equipment will be set. A separate Sundry Notice will be submitted when the well is to be perforated. NOV ~. 5 1961 ' 23. I hereby certify that the foregoing issue and correct to the best of my knowledge '"J~$~k~t-~'" 0[[ ~ (~EIS ~0115,- t~u,-,, SIGNED TITLE Sr. Drilling Engineer DATE The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~NO []YES [~J~JO .~YES []NO[ 50-- O ~ ~'- Permit number Approval date ~ {-/~7~' SEE COVER LETTER FOR OTHER REQUIREMENTS 12/01/ APPROVED BY_~, ,COMMISSIONER DATE D~d~m~r 1. 19~1 by order of the Commission Form 10~,01 Submit in triplicate Rev. 7-1-80 I ANNULAR PREVENTER BLIND RAMS PIPE RAMS LLING SPOOL PIPE RAMS RECIEIVEi) NOV 2 5 198! ;Alaska Oil & Gas Cons. Commissio~ Anchorag~ 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3. minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- ~ure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. · 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to ze~o. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. '12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and.-all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/13/81 8000.:. · 8500' t RUDH · ~ . ..9500-...:. toOoo i, 10500 ill[ PROPOSED" KOP" TVD='~986 ! : i , ! : ; · : '"1500 ' I SFIOi. $: 72C ~199 ;RT I~ON - ~. ~.~.: "~ [:' A .' '-:3 . ... ,. . ,' .'--i, t .,',' '~.. :. '~'~'3" -."-.~ ' · ' ~ ' '. ' ~..,I. , ' c:.-/,,.¥ .' '~ ' · "i'" ', ~-.., f.~ · , "~.&.; .-,., , . ;:. -: ...... /,, !;.t :'.' ,¢" .".';-,~ ./'~ 1,,,,,, - - - · - .,./ .//,:~..~, ,~',~,,,.:,,; .. '~ ~ '. NO. 4.,'i~'-$ * &.,'.~ ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- · '- .,BU. ILT SURVEY MADE BY ME, AND ', · THAT ALL DIMENSIONS AND OTHER "~/¢~ DETAILS .A~[ C~RRECT-, $ -- LJE._W WE. LL bO(.,~TIOId · -- E::"/,.i~'-~'T', WF--LL D.G. 12 WELLG 5, 6,'7, t 8 'x...._ AtlanticRichfieldCompany.. ~' IDATE' NORTH--AMERICAN PRODUCING DIVISION ALASKA DISTRICT-'-PRUDHOE BAY i i i. i i i #5 Y = 5,931,029.18 x = 697,575.79 LAT = 70°1 2~ 56.618'" LONG = 148°24~ 22.472" #6 #7 Y = 5,930,909.77 x : 697,587.70 LAT = 70"~Z '55.440" LONG = .148~24z22.217'' Y = 5,930,790.35 X = 697,599.61 LAT = 70°1 2i54.263'' LONG = 148°24~21.962" #8 Y .., ~ LAT LONG LOCA, TIONG I = 5,930,670.93 = 697,611.52 = 70°] 2~53.086'' = 148"24~21.707" AG-BUILT II DRAWING No' .1~ - ' 90i0 ~5'0o~!. "1 ~0000 - i .:..,: ........ 1.ooO : ~0o CHECK LiST FOR NEW WELL PERMITS Company ,, ('~y*L o Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (3) Admin ' th ru (4) Casg ~2 thru 20) (5) BOPE~ 7/",7'~- 2~'/ --~(21 thru 24) 1. Is the permit fee attached ................................ 2. Is well to be located in a defined pool ........... 1. { ii'' ' ' !i i i! 3. Is well located proper distance from property line [ 4. Is well located proper distance from other wells .. ~° ~° ~ o~ 5. Is sufficient undedicated acreage available in this pool ......... 6. Is well to be deviated and is well bore plat included ............ 7. Is operator the only affected party .............................. 8. Can permit be approved before ten-day wait ....................... o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force ............................... Is a conservation order needed ................................... Is administrative approval needed ................................ Is conductor string provided ..................................... Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate~ or production strings Will cement cover all known productive horizons ........... , ...... Will surface casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore-. ......... Is old wellbore abandonment procedure included on 10-403 ......... Is adequate well bore separation proposed ........................ YES NO / · d qi d Is a iverter system re u re ...................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~.~Ooo psig . Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: RF~MARKS ~rc~ / z--.7 l! Geology: Enginge~ring: .cs JAL .~gx~.~- rev: 03/10/81 INITIAL [ GEO.. UNIT ON/OFF POOL CLASS STATUSI AREA NO. SHORE. ,, . ?fo · Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is .accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~ SCHlUmbERGER ~ ~ISTING OF PRO~UCTI¥ITY / DAY COMPANY ~ ARCO WELL ~ D.$, 12-?A FIELD ~ PRUDHOE BAY COUNTRY ~ USA REFERENCE RECEIVED Oil & Gas Cons. ~"-,,~'~'ttJssJon Anchorage COMPANY ~ ARCO WBb~ : D,S, 12'7A PAGE NOTE: FbOW RATE UNITS ENGliSH * BB/D - BARREbS PER DAY * KF3D - THOUSAND CU. FT. PER DAY * METRIC * M3/D - CU. METERS PER DAY * KM3D - THOUSAND CU, METERS PER DAY (ZONED PARAMETERS) ZONE INDEX ZINDEX (VAbUE) ._ :.I.000000 10490 0 - 10470. 999.2500 10470:0 10463. 2.000000 10463 0 10454 -999.2500 10454i0 I0446i 3.000000 10446 0 10420 -999.2500 10420'0 4,000000 10406,0 10372. 2500 I0372,0 10363, '99 ~0000 1 63,0 10351, 80000 10350,0 10340. COMPANY ~ ARCO WELL ~ D,S, 12-7A PAGE 2 ZONE SAND FACE 3915,0 3905,0 3895.0 3885.0 3875,0 DRAW DOWN PRES -34 DOWN HOLE S U R F SOL OIL GAS WATER OIL GAS BB/D KF3D BB/D BB/D KF3D -5 -4 -2 -19 -14 -8 -38 -6 -16 -48 -19 -36 -20 -116 -107 -86 -50 A C E FREE GAS KF3D TOTAL -209 -119 0.0 .6 -8.8 :2 .2 TOTAL 21 1 15 14 10 6 -21 5 -26 -3 -19 -11 -36 -12 -26 -i5 -91 -76 -67 -39 -103 -59 30.0 26,1 1~,6 ,2 '7,1 '14,2 46 i 34 19 47 35 19 13 13 9 6 -13 -10 -23 -5 -17 -i0 -66 -44 -49 -28 TOTAL 3 1 40,0 72 1 53 3O 36.1 80 59 33 25.6 47 22 35 20 ,2 -1 4 -1 12.9 -11 2 -8 -5 -4.2 -40 -13 -30 -17 TOTAL 108 61 50.0 21.2 12,9 5.8 97 2 72 40 112 83 46 81 30 60 34 12 7 9 -5 I 9 I 1 -15 18 -11 -6 WATER BB/D -4 -19 -105 -133 · l 5 -3 -12 -74 -83 1 13 -5 -34 1 22 4 2 '13 16 2 3O 7 9 18 COMPANY ARCO WESL, : D,S, 12=7A ZONE SAND FACE PRES 3865,0 3855,0 _ 3845,0 .. 3835.0 - 3825.0 -- DRAW DOWN PRES DOWN H 0 b E OIL GAS WATER BB/D KF3D BB/D BB/D TOTAL 21 60.0 56.1 45,6 31.2 R F A C SOL, FREE GAS GAS KF3D KF3D 120 mm m mm emi mm mmmm mm m mm mm mm mm emi m i22 2 91 51 145 108 60 115 39 85 48 24 10 18 10 13 16 t0 6 10 49 7 5 mmm mll mmmmmmmmmmmmmmm#mlmmmmmmmmmm#mmmmmmmmmmmm#mmmmmmmmmmm 148 3 109 61 178 132 73 149 47 110 62 36 13 27 15 26 23 19 11 35 81 26 16 24 70,~ 55,~ 32~9 25.8 TOTAL 4 173 3 128 71 210 156 87 183 56 135 48 17 36 20 38 3O 28 16 60 112 45 27 528 8O 65.6 5[, 42,~ 198 3 147 82 243 180 100 216 64 !60 91 61 20 45 25 50 37 37 2i 85 143 63 38 90,0 86.1 75,6 61. 52,~ 45'8 TOTAL 633 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 223 4 1~5 92 275 204 114 250 73 185 105 73 23 ~54 31 lO0,? 96. 85.6 7! .2 239 298 358 WATER BB/D 65 2 38 10 16 49 115 3 47 13 22 79 164 3 55 16 29 110 214 3 63 36 141 263 4 72 23 COMPANY I ARCO WEb6 ; D,$. 12'7A 'SAND FACE 3725.0 3625.0 3525,0 3425,0 3325,0 DRAW DOWN PRES PSI 62,9 55,8 TOTAL DOWN HOLE OIL GAS WATER BB/D KF3D BB/D BB/D 62 44 110 174 200.0 470 7 196.1 595 185.6 582 158 171.2 194 55 162.9 182 1~3 155,8 356 4 7 TOTAL I 300.0 712 ~1 296 I 908 285:6 907 244 271.2 311 88 262.9 299 182 255'8 596 799 400.0 948 15 396,1 1213 385.6 1224 329 371,2 427 120 362.9 414 252 355,8 831 1112 TOTAL 3 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 500,0 496,1 485 6 455.8 TOTAL 1179 18 1510 1533 414 1 539 152 525 321 1059 1424 4 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#m 600,0 1403 22 I R F A C E SOL FREE GAS GAS KF3D KF3D 46 26 82 49 737 416 WATER 43 172 313 349 195 441 246 432 243 144 81 135 77 264 156 765 mmmmmmmmmmmmm 999 7 156 54 . 808 528 295 673 375 673 379 231 130 222 127 442 2bl . 77O mmmmmmmmmmmmm 1568 703 392 90O 501 908 512 316 178 307 175 616 363 750 2124 11 240 86 179 787 1304 14 324 1095 1799 874 487 120 624 137 641 400 225 390 223 786 463 707 mmmmmmmmmmmmm I 1 2666 18 408 150 316 1402 2294 041 580 21 COMPANY i ARCO : D.$. 12'7A PAGE 5 ZONE SAND FACE PRES PSlG 3225.0 3125,0 3025,0 2925.0 DRAW DOWN PRES PSI 596.1 585.6 571.2 56 ,9 555.8 TOTAL DOW BB/D N H 0 b E S U R F SOb GAS WATER OIL GAS KF3D BB/D BB/D KF3D A C g FREE GAS KF3D 1800 1336 744 1835 499 1361 767 1 648 185 481 271 634 390 470 269 1283 1737 952 561 1 5641 3196 1622 25 1203 671 2083 1545 861 129 585 1579 890 2755 217 560 316 740 460 549 314 1500 2049 1113 657 TOTAL 6550 700.0 671,~2 662,9 655,8 1 1 i 3712 800,0 796.1 785.6 i55,8 .9 1835 29 1361 759 2359 1750 975 2415 670 1791 1010 859 249 637 359 844 529 626 358 1712 2361 1270 750 TOTAL 7436 4215 mmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmmmmm#mmmmmmmmmmmmm#mmmm 2042 33 1515 845 2627 1948 1085 2693 755 1998 1126 960 281 712 -402 944 598 700 401 1919 2673 1423 841 TOTAL 8298 4704 900,0 896.1 885,6 871.2 862.9 855.8 1000,0 85, 971 2 962~9 955,8 TOTAL 2244 36 1665 928 2887 2142 }~93 1 2964 840 2199 ..40 2 1059 314 785 443 1 1042 668 773 442 2119 2985 1572 929 1 9136 5180 WATER 492 182 384 1710 2789 .. 25 576 213 453 2017 3284 29 660 245 521 2325 3779 32 744 277 589 2632 4274 36 828 309 657 2939 4769 COMPANY ARCO Wgbb ; D,$, 12-7A PAGE ZONE SAND 1925,0 925,0 DRAW DOWN PRES PSI DOWN H 0 6 E S U R F A C SOb FREE 016 GAS WATER 016 GAS GAS BB/D KF3D BB/D BB/D KF3D KF3D 2000.0 [996.1 1985.6 1971.2 196~,9 195 '8 3943 73 2925 1631 5084 3772 2101 5249 1693 3894 2199 !890 637 1402 792 1868 1360 t386 796 3815 6104 2830 1687 TOTA6 16209 mmmmmmmmmmmmmmmmmmmmmmm~mm~mmmmmmmmmmmmmmmmmmmm 3000.0 2996.1 2985.6 2971,~ 2962, 2955.8 5068 109 3759 2096 6539 4851 2702 6765 2546 5018 2841 2442 960 1812 1026 2419 2053 1794 I036 4946 9217 3669 2210 TOTAb 20903 3925°0 39 $880~8 5596 142 4151 2315 7224 5359 2985 7482 3334 5550 3152 2706 1258 2007 1140 2682 2693 1990 1157 5488 12093 4071 2487 [ 1 2 t 2 9214 11922 TOTAb 23129 WATER BB/D 71 1667 627 1339 6010 9715 107 2507 945 2021. 9075 14656 140 3283 1239 13247 19221 "V' COHPANY I ARCO NELL ~ D,$, 12-7A FIELD I PRUDHOE BAY COUNTRY ~ USA REFERENCE ~ 10707,62711 SCHLUMBERGER LISTI~G OF PRODUCTIVITY / DAY COMPANY WELL FIELD COUNTRY REFERENCE ARCO DRILL SITE 12-7A P~UDHOE BAY UNIIED STATES 10706,624:17 g£££1V£D AU¢ i i ]982 Oil & Gas Cons. Anchorage C°mm/SSion COMPA~,iY ; ARCO PAGE * NOTE: PLOW RATE UNITS * , * , * BB/D - BAR}~ELS PER DAY * KF3D - THOUSANb CU. FT. PER DAY , * ~iMTR1C * , * M3/D - CU. METERS PER DAY * * KM3D - THOUSAND CU. METERS PER DAY , * **************************************** CZONED PARAMETERS) ZO~g I~O~X ZINDEX (VALUE) i 000000 -9!9 2500 2 o6oooo (LIMITS) 10365.0 - 10351. 10351.0 i0350. 10350.0 10340. DRILL SiTE 12-7A Z 0 N E SA~D DRAW 0 0 W FACE DOWN PRES PRES OIL PSIC PSi BB/D 3915,0 10,0 -5 5,7 -27 3905,0 3895,0 3875,0 3865,0 3855,0 3845.0 HOLE $ U R F A C ,SOL FREE G;~S WATER OIL GAS GAS KF3D BB/D BB/D KF3D KF3D -4 -2 -20 -1! 20,0 2]. I I5 9 15,7 i7 13 7 TOTAL 28 16 mmmmmmemmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmemmmmmmmmmmmmm 30,0 ~6 t 34 19 25.7 6O 45 25 TOTAL 79 44 40.0 72 t 53 30 35,7 104 77 43 TOTAL 130 73 mmmmmm~mm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmm~m~mm 50,0 97 2 72 40 45,7 147 109 61 TOTAL ~81 101 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmm~mmmmmmmmmm~mmmmmmmmmmm 60.0 122 2 9i 51 55,7 190 141 79 TOTAL 232 70.0 148 3 109 61 65,7 233 173 96 TOTAL 282 80,0 173 3 128 71 75,7 276 205 114 TOTAL 333 129 157 186 W~Lb : DRILL SITE 12-7A PAGE SAND FACE PRES PSIG 3835.0 3825.0 3725.0 3625.0 3525.0 3~25.0 3325.0 ~225.0 DRAW D 0 W N H 0 £, E DOWN PRES OIL GAS WATER PSI BS/D FF3D BB/D 90.0 19~ 3 85.7 319 TOTAL ImmmmMmmmm~mmmmmmmmmm~mmMmMImmmmmmmmmmmmm~mmm A C E PREE GAS KF3D S U R F SOL OIL GAS BB/D KF3D 147 82 237 132 383 214 is ~i im ,mi m,~ i Im ~I~ I mm II m III 100.0 223 4 165 95.7 362 268 TOTAL 434 92 149 242 200.0 470 7 349 195 195.7 764 582 324 TOTAL 931 519 300.0 295.7 712 1~ 528 295 196 887 494 TOTAL 1416 7~9 400.0 948 15 703 392 395.7 1599 1186 661 TOTAL 1890 ~mI~m~mi~I~m~mmmm~~m~~~mmmm~mli~~ 1053 500.0 ~179 18 874 487 495.7 1992 1478 823 TOTAL 2352 1311 600.0 1~03 22 1041 580 595.7 2375 1762 981 TOTAL 2803 1562 700.0 1622 25 1203 671 695.7 274E 2039 11~6 TOTAL 3242 1807 WATER BB/D 11 11 14 14 18 18 21 21 25 25 DRILL SITE i2-7A PAGE SA~D DRAW P 0 W FACE DOWN PRES PRES OIL PSIG PSi BB/F 3125.0 ~00.0 ~835 795,7 3112 3025.0 2925.0 1925.0 925.0 N HOLE S U R F ;% C SOb FREE GAS NATE~ OiL GAS GAS EF3D BB/D BB/D KF3D KF3D 29 1361 759 2308 1286 TOTAL 3669 900.0 20~2 33 1515 845 895,7 3465 2571 1432 1 TOTAL 4086 2277 1000,0 224~ 36 1665 928 995,7 3809 2826 ~574 TOTAL 4490 2503 2000.0 3943 7~ 2925 t631 1995.7 6709 4977 2772 '"TAL 7902 4405 3000.0 5068 109 3759 2096 2995.7 8629 640i 3566 TOTAL I0~61 5664 3925.0 5596 ~.42 4151 2315 3920,7 9533 7072 39~9 TOTAL 11224 1 2045 6257 WATER BB/D 29 29 32 32 36 36 71 72 107 107 140 140 LISTING OF P~ODU~TIVITY~ / DAY COUNTRY ARCO DRILL SITE 12=7A PRUDHOE BAY UNITED STATES REFERENCE : 10706,62417 -IPPLOG DRILl: PAG~ -',. ,. ]"..' i SPEC., ~iP.h?ZW~,T, 2ROD.GAS- VOLA'iil,h, OiL ~PT BORa.~. C'7,E D: i A.~'I.ETER TOT'AL PiSSULVMD SObIDS St : 10&.O~ 0 : 0 1.0~000. : : 1.00000 : i : 3.,oaooo : .892000 .6..50C00 [4.70G0 :,. 75,.6.0G0 700.000 FT FT DFHF DEG. F F3/F :'_-g99.,250 · ---''8' FT ,,. ~.4 ~9.00 ,_ '5' 0 r. g; u go -- .'..o99.250 : .125000 YM2 : .lO'~O0:O~ !6 FAC. ,. OIL FAC., WATS CC:" ~.~ ~.:]S ~i LfTY, GAS_ T'E ~" F? CVALUK) : 1.80..,0000 DEG~ :. I79.132'~: DE'G? 3925.000 PSiG 1,.70000 PSis? :- 4250.000 PSi~ .0.0435.29 V/V 1.3480,00 V/V - !.015370 .9~9415% V/V ]- DRILL sIT5 I PAGE_ SP-'T.C. :.'h~-".-:'!':-:y ,?REE GAS' S 9 EC, ~_.- ~-'. ~. Vi V'~', r~SS~._ . GAS A&E. ~ r,O, ..... -~ ',:. :.'~ ,'¢, ,-' ' ., ,.'6 ~...,,-: .... A5 OIL ~F~FG Z I..?', 0 ~.X ,~ . - ._ .56C-0000 ,73E6167 ..02C,~179 CP .7982000 CP .310COOO CP ..7'55~17~ G/C~ .9~8629 G/CZ 556..9966 F3/F 18 ..63'8~56. ; ,0014370 ; 3.,9'3924,7 : 7.0'7229.1 ,00C.2766 -999.2.500 ;--999.2500 -99g.2.500 _- FT N?3A ~/~. DRILL S!?E CU? .. . _ : D~ILL SiTE 12-7 · 19..J 15.7 ~ .'2 5 4 9 GAS OIL- TUT- p fl - DgI6L SITE 12-7A FO? .':., ~-"©'5-0'>i£ ?'ACT.OR $ GAS '- . ' ~ "'" UA'rE' .' .... ~ '~ ~'o ~ GAS: ~ ~.~.' ~ ~ ~-. . · · ,;'%. ,h .,~ 0 · ~,.'~:~AL WATER ~:V Z~C'. Ii-,= S'G.!-':. ,.~ ~' I ~ ~ ~ m 'I TSRES' ZT-i~'D, EX ' (.VALUE) : -99.c-.~500 :-ggg.a~O0,~,.,. : 14.7{)000 -99~.2500 -999,25~0 -.999.2500 -999.2500 -9'99.25'00 -999.2500 -999.2500- ::-999.2.500 :--999.,2500 : -999..2500 _ -- -- : '999.2500 : : -99g.2500 ; -995.2500 '. c9~ ~500 ~ ' ,. .. · : -999.2~00 --999.2500 DEGF -'V/V -V/.~ V/V V/V CP CP CP G/CS G/C3 F3'/~ £3/? M F 3 ~ MF30 fi`E/'" FT .- PAGE CI.L oU TOT 'CUT- DRILL F? ~PP.~ES. ZPR ~G Zg~. S. $Cii. C-:;..3-O!L RATIO SOL. ;:~,,.,:~-~!At'"E:{ RA: .~.FF FG (VatUE) lfi0.000u OEG~ 179.0'580 DEGF 3925.000 PS'~xo !4.70000 PSis; 4-25'~.000 .0,0%3521 -V/V _ i..3,~Sd0O-V/V : !.015343 V/V : .9493486 .5660000 .738.6096 : 020.~' 8 :- .7982000 CP : .31o0000 CP -- :-' .75:52250 G/C3' .~':- .9848887 G/C, 3 : -'557.0672 F3/9 : .00!026= 2.315175 ~F3D :. 4.:151317 --999.2500 FT ~:-9,99.2500 ~F3~. -999.250'0 B~/A 2.0000.00 ,' ~ C2.:.'~ . 16"' ' 5. 163,::3 10340.5 F I~.O" R A :? E · .I PU OiL ' T'OY' 9U PU ~7 69 . 7 t 7-1 '/3 7'3 7.5 7'5 77 77 7~ 7'~ ~5 90 90 97 97 9S 99 100 _CUT ' FIRC, O PRUDHOE Of'iT ! 2-7FI 'lOl.-: '3.9580 IN o RPERF- ·12500 IN2 6RVSIE=-999.25 POB1ND= · r,.._) · LLI ,----, C,O c7') -"%,~'~-l~'-"-.t r--. m ..... -v ............................. . .................. :' . .... -.. ........ ": ..... ,., ......... - .......... %., ,11~';.I'u'''' ..... "'--': ..... I I ""';";'-'1 ..... I ':-, - ....... - ..... T -- -" '-'-': I U. UO 20. [JO t[f.J. UD [ti1. UO ;',U. (/!J ittU. O0 120. 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PERF BENS= 2 FT-1 Fk'- PERF DENS= Il FT-I X PEBF BEllS= O FT-1 '5 PERF DENS= 12 FT-I X PERF BENS= 16 FT-I (~ IPR CURVE 0 C) ,~0~_c~ J' 180.00 210.00 2EO.O0 BB/D 0-_ c; ' \ \ · \ %. OD -30. OD Go. OD 9o. OD :t 20. OD ~. 5o. po ldPI] LI1 I--:LoIN MH'I'Iz. ~IU- · 5-1qPR-O20LI: LIcJ: 50 HH~U lOI= 3.9580'IN_ CD RPERF= .12500 IN2]~ CD CD ~UU~L OH.I ' COI=-999.85 IN ' GRVSIZ=-999.25!' SCROE-999,25:it.N"" · PGRIND= 7 ~ PERF DENS=: 2 FT-1 · ?EBF OENS=; ~ FT'I X PEBF DENS=~ 8 FT-I ~ PERF DENS=: 12 FT-I ~ PERF DENS=, 18 FTc1 O IPR CURVE ~ ~ TI PNH~ 800.00 PSi 0 CD I -20.00 0.00 · l' - . . ,. I 20. O0 U,O. O0 I~ 80. O0 80. O0 L I gU I O FLON RRTrE ~ 1 0a .I 100,00 1.20,00 '.i, 1L~O,O0 BB/O 1-HRT-82 08:3g:32 . I ARCO ' RPERF 2500 J, N2.. ' O0 :' 20.00 PRUOHOE BAY "' , DRILL SITE 1;~-7R , [DJ=-999.25 2]~ $£ROE-999.25 i,]N ;' RVSIZ=-999. 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GR ** FILE TRAILER FILE NAME :SERVIC,001 SERVICE NAME VERSION ~ DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME EOF 5.320 999 250 52,438 ** TAPE TRAILER SERVICE NAME :SERVIC DATE :81112/31 ORIGIN :1070 TAPE NAME :62424 CONTINUATION ~ NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE :81/12/31 ORIGIN : REEL NAME ~REEL ID CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :REEL COMMENTS EOF EOF 015 TAPE VERIFICATION GiSTING ~VP 009.HO5 V~jR1FiCATiON LISTING ~ TAPE HEADER DATE ;82/01/ 7 ORiGi~ :1070 TAPE ~A~E :624b0 PReViOUS TAPE ,, FiLE i~AM~: :SgRVIC,001 SERVICE NAM~ VER~iO~ # : DATE : MAXiMUi~ 5~NGTH : 102~ FILE TYPE CN ' WN F~,~ RAi~G: STA® CTR~: AT~ANTIC RICHFIELD COMPANY DRI~5SITE'I2-TA' PRUD~OE BAY' NORTH SLOPE A~ASKA USA CNLOO6F RECORD ~iYPE 0~7 ** UNIT TYPE CATE SIZE CODE 000 UO0 026 u6b 000 000 01~ 000 000 012 000 000 003 065 O00 000 003 065 000 000 OOZ 000 000 012 000 000 006 O6b O00 000 004 065 UNIT ~"~Pg CATE SIZE CODE 000 000 007 LVP oOg. 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NA = 8.5 IN. ** uAT~ F[)RMAT ~ECO~D ** ENTKY BbOCK~ T~PE SIZ~ REPR CODE ENTH~ 4 i 66 i d 4 73 60 9 ~ 65 .lin O 1 66 0 DA'.rU~,~ GPECiP'ICATION BLOCKS MNE~ SE~VIC~ 8ERViCE ONIT APl API API API FILE SIZE PROCE6S SAMPLg REPR ID O~OE~ ~ bOG TYPE CLASS MOD NO. bEVEL CODE DEP~' '- Fr 0 0 0 0 0 4 0 1 u8 NPHi Chh PO 42 6~ 2 0 0 4 0 i ~8 NRAT CNL 42 42 1 0 0 4 0 i ~8 VERIFICATION LiSTI~G 34 31 68 ~2 3~ 31 92 93 2 1 92 32 ~8 ~8 ~8 DEPT lOb~6.bO0 NPHI FC~b -'-999.250 GR NCnb !528.000 FCN~ DEP~ 10900,000 N~[ FC~ ~53,500 G~ NCnb i052.000 FCN~ FC~D ~62,000 GR D~PT 10300.000 NPHi FC~ '1953,000 Ga DEPT 10200.000 NPHi FCi~ ~41,~7~ G~ NC~ 992,500 FCNi~ DEPT 10i00.000 NP~i FC~D 25i,750 GR NCN~ -M99,250 FCNb DEP~ 1OOOO.O00 NPHi FCNb ~2~.37b G~ NCNb -W99'250 FCNb DEPT 9~00,000 NPhI FC~b 214,'150 G~ NCi~ -999,250 FCNb DEPT 9806,000 NPH% FC~ Z72'500 GR NCnb -M99,250 FCNb DEPT 9700,000 NPH£ FC~L 282.750 GR NC~b '999,2~0 FC~h DEP~ 9000,000 N~I FC~b 359.000 G~ -99 -99 2 5O ~2 4 ~91 4 5 23 0 -99 5 -99 -gw 18 -99 12 '99 3 8 9.250 9.250- 9.OOO 1,344 5.500 9.531 9.469 5.500 ~.OOO 6'813 3,000 1,113 6.7i9 3.500 2,871 0.93~ 9.250 6.680 9.719 9,250 5.947 1.250 9.250 6.973 6,625 9.250 8,965 4,063 9,250 2.~13 ~,625 NRAT NPHI G~ bRAY GR bRAT bRAT NPHI GR ~FHI bRAT NPHi NPHi GR bRAT ~PHi NPHI GR NPHI ~PHi -W99.250 '26.465 21.813 2.939 25.342 ~3.V81 2.694 23,389 16.i09 1.507 7.~78 45.750 ~.052 45.312 60.063 4,i60 -999,250 '~99,~50 4.395 -999,250 -99~,250 4.351 -999,250 -999.250 4.415 -999,250 -999,250 3.W18 -~99.250 '~99,250 3,539 -999.250 NCNb NRAT NCNb NCNb NRAT NCNb NCNb N~AT NCNb NRA~ NCnb bRAT NRAT NCNb NCNb -W99.250 3.113 1472.000 3.045 1~81.000 2984,000 1.b49 967.900 ~' 4.244 i032,000 -999.25U ~51.b00 -999.250 970.b00 -999.~50 1133.000 I183,000 -999.250 1176.000 -999.250 LVP O09,HU5 VERIFICATION LISTING PAGE 4 NC~b -~99.25U FCN~ -999.250 DEP93 9b0O. 000 NPMI FC~gb J25.750 GR NC;~ -999.250 FCNL 36,621 NRAT 11~.125 NPHI -999.250 GR FC~'~o 278.Z50 GR NCSb -999.Z50 FCNG ~0,b25 NRAT 135.125 NPHi -999.250 GR D~PT 9~00.uOO NP~{I FC~b 390.000 G~ NC{~ -999,250 FCNb 28,857 NRAT 42.219 NPMI -999.250 GR 9200,000 NPMI -M99.250 FCNG 40,088 NRAT 30.078 NPHI -999.250 GR D~P'I 9100.000 NPHi FC~o 242, ~Tb GR NC~., -999, Z5O FCNL 48.193 NNAT 30.406 NPHI -999.250 GR OEP%' 9000.000 NPHi ~C~O 253,87b GR NCi~ -~9~,250 FCNh 47.119 NRAT l~.01b NPMI -999.250 GR DEPT 8900,00U NPHI FC~gb 242.~79 GR NC~b -999.250 FCNU 59.131 NRAT 23,375 NPHI -999.250 GR D~PT 8UO0.O0O NPHi FCD~ 223.12~ GR NCnb -999,250 FCN~ 50,439 33,594 -999,250 NRAT NPM£ NRA'f NPHI GR NRAT NPMi GR DEPT ~700.000 NPHI FC~L 200.37~ GR NCN~ -999.250 FCN~ 47.998 35.96~ -999,250 DEPT ~o7o. OOO NPM£ FC~b 184,~7b G~ NC;~L -999.250 FCNL 51,807 ~1,750 -999.250 Flbr~ i'~ AMC :SERViC.O01 SERVICE NAME DATE ; MAXi~:,L:~4 L~GT~ : 1024 FI L,~; TYPE t~EXJ,] ~'IbE i~4~;q~ -999,250 3,772 -999,250 -999,250 ~.021 -999,250 -999,250 3,295 -999,250 -999,250 3.990 -999.250 -999,250 4,485 -999,250 -999,250 4.424 -999'250 -999,250 5,163 -999,250 -999,250 4,626 -999.250 -999,250 - 4,476 -999,250 -999,250 ~.710 -999,250 -999,250 NCNb NCNb NRAT NCNb NRAT NCNb NRAT NCnb NRAT NCNb NRAT NCNb NRAT NCNb NRAT NCNb NRAT NCNb NRAT 1173.000 -999.250 1067.o00 -999.250 1240,000 -999.250 1107.000 -999,250 117,000 999,250 142 000 1306 000 -999:250 925 500 ~43,000 -999.250 B30,o00 -999.250 LVP 0C-9.H05 VLRIFiCATIO~ 6ISi~I~G PAGW 5 TAP~ ~AME C~TI~!JATION ~ CO~NE~TS :TAPL COAMgNTM ORiGi~ : COi~Tii~UAT%[)~ ~ COM~iENT5 :Rggb R~EEIVED JUN -. 8 i982 Oil & Gas Cons. CornrniSsio,,.~ Ane.~orag9 TU ~T Ti CU~V~ FL TPRG vOLO'I~ BDIA~ { ~,50000 IN (MATRIX PAPAPgT~RL} FT-i CZONKD PA~AMETMR8) FU?~ATION Pi<F~SUR{< FORM. VDLU~E ~"AC~DP~ FOR~AYION VOL.FAC,, OIL FO~ATION VOL,FAC,, WAT~: COMPR~SLIBIDI~Y, GA~ FP BPPR~BolP~ : ZGA~.iPR it0.O000 D~GF' ,~ {79,B2~7 DEGF 3925.000 P$iG li-?O000 PSl~ 4250.000 P~IA .0043b0b V/V 1,3480n0 V/V l,OlSh?O V/V .950052b V/V -, F C¥~&C.~p~ 7.386808 .02o8102 CP - 79~2uOO C'P ,3100000 CF, : !2-7A PAGE : 12-7~ FT ~0~90.0 10}87.5 ..... .!.048o,~ I048~,~ i0484.5 BB/D ,i9 ,7 6,4 ~U CONlPlgUTIDN WA~E~ f~lL TOT ClOT PU PO PU B6 89 9O 9o 90 10480,,5 5.4 ,3¸ 72 10475.~ 10472,5 10~?0,5 2'~3 1.7 7.3 ,7 4 4 i i 77 70 ~ AL~E) ~ H OO ~ -g99.2500 G/C~ ~OI,,.GAS-WAT~ R.ATIn ~O~.!Pi;{ ~ =099.250u F3/B ' ' ,, ~ ,v ~ ~ . ,. ~, ~ .- PoT, t~E, GAS AFP~6 ~¥ TOTAL GAS ; -099.2500 PU P~ PU PU 10~69.0 10468.o 10467,0 10466,0 10465,0 10464,.0 tl I1 I1 il Ii 11 i! 11 B~ ,~'~B~:~,. FLOW POTPj~,~'I~'IAL OIL O. ~AGg ~ ~t K~3D ~B/D B~tD PO PU PU PU 10462", 5 3,3 10461.0 10460°0 10457.0 i0455,0 10454.0 · ..'i I~ 12 ] .1 1_~ 13 7 13 13 b2 1.5 4., 4 ol 5,0 WATER VISCOSITY SOL.GAS-WAT~P PATIO Il-999,,~500 P3/[~ I -999,~$00 MPtD ZONE; INDEX ZINDK:X ?, F L o ~ k A 'I ii: ~ I L FLOk/ CONTR 1045~,0 i0452,0 10451.0 10~50.0 10449,0 10448.~ PU 17 17 15 FO~,~:~ ~I VOl, OI b i~aO0 ,~'755 i, 754 .2:3 25 10436.,0 ,~ .1 20 20 1043.1..0 t,4 ,4 ~1 ~1 I0427.:0 22 22 90 10424,:0 23 23 1042:).0 24 24 ,7 2,6 ,'2 IF :D 0 t~~ R A T B -999,2500 V/V -999.2500 V/¥ -999,~500 -099,2500 CP '099 1'04 10409 o 0 t0407,0 I0406,0 .,3 .2 25 25 WE, Lb PA~ lb fZONED . ( V A L U)'~ ) rL .P. f~HT 180.0000 DEGF GVI$C, IP~ { ,0208160 CP ~:~ HOD : ,:755,~002 G/C, 3 SOL.GA,: WA'i~ RAT;tO AB~, ~bOW POT, F~E,. CAS 10400,0 2.~ .9 29 29 25 7 29 2! 3 3 o 10394.0 ~3 35 71 10393 I039~ 10391.~ 10390 103B9.0 lO~8.O 103B7.5 103B7.0 103~6 1038&.0 ~ 0385 10385.~ 1038~,0 I0382,-5 P~ PY PU PO 10377 10376.5 3.O 1.6 4~ 4~ 22 1.7 ~6 46 24 10374.5, 10171.5 4.~ SGWA,IP~, : -999.2500 F3/b FLOW PUTfNTIAL OIL AFPOIh TOTAL GAS ~gS'EF~Vt:C~ '}'G~,S : -999.2500 ZONE INOgX ZINDEX : .'.q99.2500 ~A~E 2O 1037'1.5 ~0 5O 10371 ,o 5o 50 lo~::?o,~ so 50 10370,0 50 50 10369,0 50 50 10367.0 5u 50 10366,0 50 50 10]65.~0 50 '50 BOTTO~ HOLE T~P. AbANDOqMEHT PNESSURE AP FO~q~A~ION VOL,FAC,, r~I~ ~ tBO,iPR :f !1,348000 V/V TOTAL ~A$ Ri 10 0 1036 10357.0 10~55,0 10354,0 ~03~..0 10351.0 7~ 7~ 77 77 PAG~ . . .~, DF, N~I:~:Y OF 016 ~H:O0 : '-g99,:~00 G/C3 ZON~ XND:~X Z,I~ D~:X: '999.~,2500 7~ 78 ~y (VALUF) : 3925.o00 P$1o : I~.70000 P,.q l G v/v 9493486 v/¥ W~ is¢ ,iP;~ t00000 ~t()O : .7552250 C;/C~ SOL.GAS-WATeR HATZQ FLOW POTENTIAL OIL ~ [,0~. CONT~I~IJTIO~{ 10349.0 I0~48,0 I O,~4b. 0 10 .{ 4 4 ,, 0 .l
