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Home My WebLink About193-033MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-08 PRUDHOE BAY UNIT AGI-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/11/2024 AGI-08 50-029-22348-00-00 193-033-0 G SPT 7920 1930330 1980 3438 3438 3439 3440 24 60 61 62 4YRTST P Kam StJohn 3/1/2024 4 Year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT AGI-08 Inspection Date: Tubing OA Packer Depth 9 2283 2260 2256IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240301110808 BBL Pumped:5.8 BBL Returned:3.3 Thursday, April 11, 2024 Page 1 of 1         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y Samantha Carlisle at 2:05 pm, Dec 27, 2021 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN '650*5'(& ; SVL '/% JLC 1/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.04 14:45:04 -09'00' RBDMS HEW 1/5/2022 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU AGI-08 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-033 50-029-22348-00-00 11648 Conductor Surface Intermediate Production Liner 8464 80 3901 10901 889 11624 20" 13-3/8" 9-5/8" 7" 8449 37 - 117 36 - 3937 34 - 10935 10757 - 11646 37 - 117 36 - 3486 34 - 8025 7916 - 8462 none 470 1950 4760 7020 none 1490 3450 6870 8160 11222 - 11548 7-5/8" 39# x 7" 26# x 5-1/2" 17# T95 x NT80 x L80 33 - 10760 8201 - 8402 Structural 7" HES TNT , 5-1/2" FB1 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028301, 0034628 7" CA A-1 valve 33 - 7918 7797 , 7868 / 2146 0 0 0 0 0 0 0 0 0 0 321-640 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 7797 , 7868 10565 , 10680 10565 , 10680 / 2206 By Meredith Guhl at 10:08 am, Jan 21, 2022 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2022.01.21 09:51:02 -09'00' Bo York ACTIVITYDATE SUMMARY 1/15/2022 T/I/O=3300/50/30 LRS Unit # 72 (TUBING WASH/PICKLE) Pumped 10 BBL's of 60/40 followed by 50 BBL's of 120* DSL. UR frozen unable to pump/Call WSS. Stand- by for vac truck. ***JOB CONTINUED ON 16-JAN-2021*** 1/16/2022 ***Job continued from 1-15-22 WSR*** Pumped 50 bbls 120* DSL followed by 479 bbls 120* FW w/ surfactant down TBG. Let soak for 2 hrs. Pumped 105 bbls 120* FW w/surfactant followed by 15 bbls 60/40. Notify DSO to POI well. WSL notified Valve posiitons=SV closed WV open SSV open CVs OTG LP pilot defeated Accumulater blocked (per DSO) FWHP=400/75/83 Daily Report of Well Operations PBU AGI-08 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗'/ͲϬϴ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϯϰϴͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶ ϭϵƚŚ͕ϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĐǀ͛Ě͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽ ƌŝůůEƵŵďĞƌ͗ϭϵϯͲϬϯϯ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ΕϯϮϲ͕ϬϬϬ DƐĐĨͬĂǇ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϰϱϱ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ;ƐƚŝŵĂƚĞͿ͗ϯϮϱϬ ƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ '/ͲϬϴ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚǇ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞ ϮϬϭϮ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚǇĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďǇ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ '/% ϯϮϱϬ ƉƐŝ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ '/% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 9, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. AGI -08 PRUDHOE BAY UNIT AGI -08 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT AGI -08 API Well Number 50-029-22348-00-00 Inspector Name: Guy cook IDsp Num: mitGDC200306110822 Permit Number: 193-033-0 Inspection Date: 3/62020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI -08 Type Inj G TVD I 7920 Tubing 3375 1 3376 3371 3374' PTD 1930330 "Type Test SPT Test psi 1980 IA 1 302 4140 4089 4083 BBL Pumped: 4.3 - IBBL Returned: 4s OA 224 711 674 655 Interval MALL/ P L/ Notes: This is an initiTesting was done with a Little Red Services pump truck and calibrated gauges. Thursday, April 9, 2020 Page 1 01 1 MEMORANDUM State of Alaska Permit Number: 193-033-0 Inspection Date: 3/6/2020 ' Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, March 10, 2020 � �P.I. Supervisor 4`�4 3l6Z21Z0 SUBJECT: Mechanical Integrity Tests 2 BP Exploration (Alaska) Inc. AGI -08 AGI -08 FROM: Guy Cook PRUDHOE BAY UNIT AGI -08 Petroleum Inspector Tubing 3375 See: Inspector 3371 Reviewed By: P.I. Suprv�- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI -08 API Well Number 50-029-22348-00-00 Inspector Name: Guy Cook Permit Number: 193-033-0 Inspection Date: 3/6/2020 ' Insp Num: mitGDC200306110822 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI -08 Type Inj G TVD 7871 Tubing 3375 3376 - 3371 3374 - PTD 1930330 Type Test SPT Test psi 1968 IA 302 4140 - 4089 _ 4083 - BBL Pumped: 43 BBL Returned: 4.3 _ OA 224 711 674 655 - Interval MITAL I IP/F P Notes: This is an initial post rig MITAA. Testing was done with a Little Red Services pump truck and calibrated gauges. GO.n.Lbuuthrst 7I —x-& 4 --it djue �I1� o,.eG( S; 31zo14 Tuesday, March 10, 2020 Page I of 1 Regg, James B (CED) ptb (830330 From: Regg, James B (CED) !!JJ�' Sent: Wednesday, February 26, 2020 2:33 PM ) V 7 � uG(2( o To: AK, GWO Well Integrity Engineer cC Cc: Daniel, Ryan; Rixse, Melvin G (CED) Subject: RE: BPXA January 2020 MIT Forms Andrew—Thank you for clarifying the status of the well. Since the well has not yet been placed on injection, and based on my commitment to accept the non -witnessed MIT -T, AOGCC will not take any enforcement action regarding BPXA's failure to notify for witness of the 1/19/2019 MIT -T. PBU AGI -08 (PTD 1930330) can be placed on injection at BPXA's convenience. Jim Regg Supervisor, Inspections AOGCC 333 W.71h 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 iim.reeeCdalaska.sov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, February 24, 2020 2:22 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: BPXA January 2020 MIT Forms Mr. Regg, Thank you for accepting the non -witnessed MIT -T. I wanted to clarify that this well has not been on initial injection and it is the intent of BP to maintain full compliance with AOGCC requirements. It would be our preference to obtain a State witnessed MIT -T in lieu of being non-compliant with AOGCC regulations. Please advise if obtaining a State witnessed MIT -T will be required to maintain compliance. Andrew Ogg Well Integrity Engineer BP Global Wells Organization — Alaska Office: 907-659-8110 From: Regg, James B (CED) <jim.regg@alaska.eov> Sent: Monday, February 24, 2020 11:59 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Subject: RE: BPXA January 2020 MIT Forms 1/b Non -witness test will be accepted. We are reviewing the failure to notify for possible enforcement action. JFK Jim Regg Supervisor, Inspections AOGCC 333 W.7'h 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 iim.reg¢@alaska.¢ov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, February 22, 2020 9:25 AM To: Regg, lames B (CED) <lim.regg@alaska.gov> Cc: AK, GWO SUPT Well Integrity <AKDCWeIIlntegritvCoordinator@bp.com>; AK, GWO Projects Well Integrity <AKDCProiectsWelllntegrityEngineer@bp.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Allely, Josh <Josh.Allely@bp.com>; Aivano, Mike (Udelhoven) <mike.aivano@bp.com> Subject: RE: BPXA January 2020 MIT Forms Mr. Regg, I am following up to the email below. AGI -08 is operationally ready for injection. Can you please advise if the non - witnessed MIT -T will suffice or if you are requiring a state witnessed MIT -T prior to injection. Either way, a state witnessed MIT -IA will be performed once the well is on injection. Thanks, Andrew Ogg Well Integrity Engineer BP Global Wells Organization—Alaska Office: 907-659-8110 From: AK, GWO Projects Well Integrity<AKDCProiectsWelllntegrityEngineer bp.com> Sent: Saturday, February 8, 2020 8:27 AM To: Regg, James B (CED) <iim.regg@alaska.gov> Cc: AK, GWO SUPT Well Integrity <AKDCWeIIlntegritvCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee bp.com> Subject: RE: BPXA January 2020 MIT Forms Hello Mr. Regg, We apologize for not requesting a witness on the pre-injection AGI -08 MIT -T. We did complete a non -witnessed MIT -T prior to the MIT -IA, post packer setting. Please see the attached test report. Please advise if this test will suffice or if a witnessed MIT -T will be required. Thank you, Ryan Hayes (Alt. Josh Prowant) Well Operations Specialist - Integrity BP Exploration (Alaska) Inc. P BOC — A212 Office: (907) 659-5297 / 5766 Cell: (206) 999-6347 Harmony -- 2468 YwoanI atwn From: Regg, James B (CED) <iim.regg@alaska.gov> Sent: Friday, February 7, 2020 10:34 AM To: AK, GWO Projects Well Integrity <AKDCProiectsWelllnteerityEnaineer@bp.com> Subject: RE: BPXA January 2020 MIT Forms AGI -08 required both Tubing and IA MITs. Looks like we only have a copy of the pre-injection MITIA. Jim Regg Supervisor, Inspections AOGCC 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 iim.reze@alaska.¢ov. From: AK, GWO Projects Well Integrity <AKDCProiectsWelllnteerityEngineer@bp.com> Sent: Sunday, February 2, 2020 6:56 AM To: Regg, James B (CED) <iim.reggCo@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Brooks, Phoebe L (CED) <phoebe brooks@alaska.gov> Cc: AK, GWO SUPT Well Integrity<AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWelISiteEnginee@bp.com>; AK, GWO Projects Well Integrity<AKDCProiectsWeIIIntegritvEnginee r@bp.com> Subject: BPXA January 2020 MIT Forms All - Attached are the completed AOGCC MIT forms for tests performed by BP in January of 2020. Well: PTD: 03-36 2070200 14-25 1831020 14-35 1831420 AGI -08 1930330 1-09C 2191480 L-105 2020580 M -29A 2000990 PWDW1-2A 1901180 S -22B 1970510 S-34 1921360 Notes: CMIT-TxIA on cement plug for reservoir abandonment 4 year test AA 4E.021 requires 2 year test Initial test post tubing swap MIT -T & CMIT-TxIA past RWO and IA cement squeeze AA 246.005 requires 2 year test 4 year test 4 year test Initial test post RWO 4 year test 3A W-24 1880700 W-223 2110060 X -20A 2071130 t7ge4 10-owaire BP Well Integrity Office: 907 -6S9 -S297 Harmony- 2468 Abet nate: RNeui Haves GGWGlobal Wells V Orcanizatior AA 38.001 requires 2 year test 4 year test 4 year test 4/4 Submit to: iim. re0o®alaska.aov: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOQCO Insnectors0alaska.00v: Phoebe brooks(RaWska. 90V BP Exploration IAlaska), Ptutlhce / GPB /AGI Chris II k ov Form 10426 (Revised 01)2017) MIT PBV PGI -N MIT -T 01-11,W20 AGI Pressures: Prelesi Initial 15 Min. 30 Min. 45 Min. 60 Min. P=*her(eralt Test Well -08 W=Water 4152 � 4066 � d043' 4024 Variance V= RectAnno -1Other TypeTestP PTD 1930330 Type Inj N Tubing I = IMYAnaI Wirtewalef N= Not Inleding Interval 0 Packer ND 7797 BBL Pump 10.4 IA 8 0' 0 O 0 0 0 0 RP Test psi 4150 BBL Retum 4.2 OA 10,565'MD. No Wtl."rovueste0, test done prior to Wmessed pre-in)ec9on MIT -IA and ranked right into MIT -T alter packer seeing. Notes: PeMar ND reBeCs npackenet et ac er antl test Bled back 4.2 We ambient 0...I to 1480Inst. Suntl 319-492. BNs umPed is pumped inclusive of volume use se Pressures: Pretest Initial 15 Min, 30 Min. 45 Min, 60 Min. Well Typo Test PTD Type Inj Tubing Interval Pecker ND BBL Pump A Result Result Test psi BBL ReturnOA Notes: Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Type Test PTD Type Inj Tubing Interval PackerND BBL Pump IA Result Test psi BBL ReturnOA Notes: Pressures: Pretest Initial 15 Min. WMin. 45 Min. 60 Min. Well Type Test PTDInterval Typa Inj Tubing Packer ND BBL Pump A Result Result Test psi BBL Return OA New.: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Type Test PTD Type IN Tubing nterval Packer ND BBL Pump I IA Result Test psi BBL Retu I OA Nobs: Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. Well Type TO t PTD Type lnj Tubing Interval Packer TV BBL Pump A Result Test psi BBL Return OA Nates: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Type Test Type Int Tubing 9 PTD n�erval Packer ND BBL Pump A Result Test Inst BBL Ret in OA Nates: Pressures: Prelesi Initial 15 Min. 30 Min. 45 Min. 60 Min. Wail Type Test PTD Type Inj Tubing Interval Packer ND BBL Pump A Result Test psi BBL Return OA ores: Form 10426 (Revised 01)2017) MIT PBV PGI -N MIT -T 01-11,W20 INTERVAL Cocea Res."Cade. TTPE.I., Im ea TYPETESTCWaa F=Paso P=*her(eralt Test 1=Intel Tetl W=Water O=ghat (aeWtl[e In NMc) 4=Pom Teae Cyde F=Fail G=Goa Variance V= RectAnno -1Other 1=lnconduaNe s =sunn• o= omen (aealme in noted I = IMYAnaI Wirtewalef N= Not Inleding Form 10426 (Revised 01)2017) MIT PBV PGI -N MIT -T 01-11,W20 STATE OF ALASKA RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 0 2020 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ChangeJyq�pCGIGIC ❑ Plug for Reddil ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ��J ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 1 5. Permit to Drill Number: 193-033 3. Address: P.O. Box 196612 Anchorage, 1 6. 50-029-22348-00.00 AK 99519-6612 Stratigrephic ❑ Service 0 API Number: Property Designation (Lease Number): ADL 028301 8 034628 8. Well Name and Number: PBU AGI -08 7 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 11646 feet Plugs measured None feet true vertical 8464 feet Junk measured None feet Effective Depth: measured 11625 feet Packer measured 10565,10680 feet true vertical 8449 feet Packer true vertical 7797.7868 feet Casing: Length: Size: MD'. TVD: Burst: Collapse: Structural Conductor 80 20" 37-117 37-117 1490 470 Surface 3901 13-3/8" 36-3937 36-3486 3450 / 5020 1950 / 2270 Intermediate 10901 9-5/8" 34-10935 34-8025 6870 4760 Production Liner 889 7" 10757 - 11646 7916-8462 8160 7020 Perforation Depth: Measured depth. 11222 - 11546 feel True vertical depth: 8201 -8402 feet Tubing (size, grade, measured and true vertical depth) 7-5/8" 39# T-95 x 7" 26# NT -80 x 5-1/2" 17# L-80 33-10760 33-7918 7" HES TNT Packer 10565 7797 Packers and SSSV (type, measured and 5-1/2" Baker FB -1 Packer 10680 7868 true vertical depth) 7" Carrico Bal -O SSSV 2206 2146 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. Shut -In Subsequent to operation: Not on Infection 14. Attachments: trcyund ae120 nnc 25070.25.071. s 252831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Lags and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP ❑ SPLUG ❑ Sundry Number or N/A if C.O. Exempt: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 319492 Authorized Name: Lastufka, Joseph N Contact Name: Reese, J. Kyle Authorized Title: Specialis Contact Email: lohn.meseCbp.wm Dale: M6 9,0 Contact Phone: +1 9075644629 Authorized Signature: Fon, 1104134 Revised 04/2017 401111101"W -24:9 RBDMSO FtD 02010 Submit Original Only 12/13/2019 12/15/2019 T/I/O=SSV/100/50, Temp=Sl. PPPOT-T (PASS), verify primary seal will hold to 3500 psi. PPPOT-T: Stung into test void (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Stung into TBG hanger monitor port above test void (0 psi). Pressured test void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 75 psi in second 15 min. No pressure increase in TBG hanger monitor void. Installed heater in well house. Torqued LDS to 500 Ib/ft after wellhead warmed up to prevent over torque. Pressured test void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi, T/I/0= 180/125/110 Temp= SI (LRS Unit 42: Assist E -Line -Tubing Cut) Rigged up to Kill Line. ***WSR Continued on 12/16/2019*** ***WELL SHUT IN ON ARRIVAL***(hes eline - tubing cut) RU ELINE AND WELLTEC TO CUT 7" TUBING. 12/15/2019 ***CONT ON 12/16/19 WSR*** 1000 psi and maintained 900 to 1000 psi on TBG monitoring IA pressures with a total of .94 bbis diesel. E -line in control of well upon departure. IA OA= OTG. Final WHP's= 367/153/115 12/16/2019 ***CONT FROM 12/15119 WSR***(tubing cut) CUT 7" TUBING AT 10630' MD WITH WELLTEC MECHANICAL CUTTER. CORRELATED TO TUBING TALLY DATED 5 -MAY -93. 12/16/2019 ***JOB COMPLETE. WELL SHUT IN ON DEPARTURE*** T/I/0= 704/3091119 Temp= SI Circ -Out (Pre RWO) GMIT TxIA P� 4197 psi Max applied 4250, target 4000. Pumped 12.4 bbls down TBG to reach test psi. 1 st 15 min lost 21x21 TxIA, 2nd 15 min lost 17x17 TxIA. Pumped 5 bbls 60/40 to FP surface lines and ensure surface flow path. Pumped 5 bbis 60/40 meth spear down TBG followed by 290 bbls Freshwater w/return to OTT. Pumped 730 bbls 9.8 ppg NaCl brine to circ out TxIA. Pumped 32 bbls DSL down TBG for 1 hour U-tube FP. Pumped 4 bbls 60/40 to FP surface 12/22/2019 lines. Bleed psi's, Hang tags and AFE sign. FWHP's =103/107/588. Well shut in upon TC #401 through tree. Tagged @135". PT'd top side of T/1/0=00 Set 6" CIW "J"W /0/ 300/low..3500/high 5 min. each. see "Field Charted Tests" LRS to perform PT's on bottom 12/24/2019 of TWC. FWP's TWC/010. I M10= 010120 Temp= SI LRS unit 72 Pressure test TWC ( PRE RWO) Pressure test PASSED @ 2987 PSI. pumped 6 bbls DSL to reach max applied psi of 3000 with a target psi of 2800. In a 5 min test IA lost 8 psi. Bled back 6 bbls DSL. Valve positions= SV, WV= 12/24/2019 closed. IAC, OAC= OTG. SSV, MV= Open. FWHP= 0/16/16 T/I/O=TWC/0/0 R/D production tree, R/U Dryhole tree Temp #110. Torqued to API specs. PT'd through tree cap against TWC 300/low..5000/high.. pass. see "Field Charted Tests". Evacuated fluid above Master valve. Removed IA and OA blinds, installed piggyback valves, with integrals, Temp #102 and #104. Torqued to API specs. PT'd through integral flanges on each, 300/low..3500/high.. pass. see "Field Charted Tests" Verified VR plug in non working 12131/2019 OA, installed bleeder plug. Torqued to specs. PT'd 300/low..3500/high.. pass. Job complete, North America -ALASKA - BP Page 1 of 4 Operation Summary Report Common Well Name: AGI -08 Event Type: WORKOVER(WO) Start Date: End Date: 1/12/2020 Project: PBUSAT Site: AGI Rig Name/No.: PARKER 272 Spud DateTme: 2/24/1993 12:00:OOAM Rig Release: 1/12/2020 Rig Contractor: PARKER DRILLING CO. Active datum: KB @60.65usft (above Mean Sea Level) BPUOI: USA00001834 Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ _(hr) _.. (usft). 11`/12020 00:00 - 02:00 2.00 RIGD P PRE SKID FLOOR AND LOWER MAST 02:00 - 12:00 10.00 RIGD N PRE WAITON WEATHER - RIG ON EXCEPTION MOVE RATE -CHANGE OUT RAMS - RECIEVE APPROVAL TO MOVE RIG WHILE TEMPERATURES ARE OVER -35 - HOLE PRE -SPUD WITH BEN HERBERT'S CREW 12:00 - 13:30 1.50 RIGD P PRE SPLIT MODULES AND MOVE RIG DOWN S -PAD ACCESS ROAD - NOTIFIED THAT TEMPERATURE DECLINED TO -40 -STAGE MODULES AT ENTRANCE TO S -PAD_ 13:30 - 22:00 8.50 RIGD N PRE WAIT ON WEATHER - RIG ON EXCEPTION MOVE RATE - RECIEVE APPROVAL TO MOVE RIG WHILE TEMPERATURES ARE OVER -35 22:00 - 00:00 2.00 RIGD P PRE MOVE RIG TO SPINE ROAD 1/8/2020 00:00 - 14:30 14.50 MOB P PRE MOVE RIG TO AGI 1430 - 1630 2.00 MOB P PRE SPOT DRILLMOD OVERAGI-08 - MARRY MUD MOD AND UTILITY MOD TO DRILL MOD 16:30 - 1800 1.50 RIGU P PRE HOOK UP INTERCONNECTS 18:00 - 22:30 4.50 RIGU P PRE GENERALRIG UP OPERATIONS ONAGI-08 - RAISE DERRICKAND SKID FLOOR - PERFORM CHECKLIST FOR EACH TASK - MAX WEIGHT OFF HEADACHE RACK= 535 KLBS - RIG UP RIG FLOOR EQUIPMENT - COMPLETE ALLTASKS ON ACCEPTANCE CHECKLIST "'ACCEPT RIG AT 22:30"* 22:30 - 23:00 0.50 RIGU _ P PRE PERFORM PRESPUDAND EVAC DRILL WITH RUSSEL WOODS'CREW 23:00 - 00:00 1.00 RIGU P PRE NIPPLE DOWN TREE - FMC ON LOCATION TO BLEED ADAPTER VOID AND CONTROL LINES SIMOPS: BRIDLE _DOWN 1/9/2020 00:00 - 03:00 3.00 WHSUR P PRE CONTINUE TO NIPPLE DOWN TREE - TERMINATE CONTROL LINES - CLEAN AND INSPECT THE HANGER THREADS - TEST FIT THE CROSSOVER (8 TURNS TO MAKEUP)__ 03:00 - 05:00 2.00 BOPSUR P PRE NIPPLE UP THE BOP STACK -4-1/2" X 7" VBR IN THE UPPER RAMS - 7-5/8" FIXED RAMS IN THE LOWER RAMS 05:00 - 05:30 0.50 BOPSUR _ P PRE RIG UP TO TEST BOPE - INSTALL TEST JOINT -FILL STACK ANO BLEED AIR FROM SYSTEM Printed 2/412020 10:4256AM **All dephts reported in Drillers Depths'* Printed 2/4/2020 10:42:56AM **All dephts reported in Drillers Depths" North America - ALASKA - SP Page 2 of 4 Operation Summary Report Common Well Name: AGI-08 Event Type: WORKOVER (WO) Start Date: End Date. 1/12/2020 Project: PBUSAT Site: AGI Rig Name/No.: PARKER 272 Spud Date/rime: 2/24/1993 12:00:OOAM Rig Release: 1/1212020 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001834 Active datum: KB @60.65usft (above Mean Sea Level) Date From -To Him Task Code NPT Total Depth Phase Description of Operations 0530 - 1200 6.50 BOPSUR P PRE PRESSURE TEST BOPE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MIN EACH - TEST ANNULAR TO 3500 PSI ON HIGH SIDE - TEST WITH 5-1/2", 7", AND 7-5/8" TEST JOINTS -TESTALARMS, PVFAND FLOW SHOW - TEST WITNESS WAIVED BYAOGCC REP AUSTIN MCLEOD 12:00 - 12:30 0.50 BOPSUR P PRE RIG DOWN TESTING EQUIPMENT - BLOW DOWN SURFACE LINES 1230 - 16:00 3.50 BOPSUR P DECOMP PULLTWC - RIG UP DUTCH RISER AND LUBRICATOR - PRESSURE TEST LUBRICATOR TO 3500 PSI FOR 5 MIN (PASS) - PULL TWC WITH LUBRICATOR - RIG DOWN LUBRICATOR AND DUTCH RISER i 1600 - 1730 1.50 BOPSUR P DECOMP ROCKOUTDIESEL FREEZE PROTECT __ -S BPM, 1055 PSI _ 17:30 - 19:00 1 1.50 PULL _ P DECOMP MAKE UP LANDING JOINTAND PULL HANGER TO RIG FLOOR - FMC ON LOCATION TO BACK OUT LOCK ,DOWN SCREWS - HANGER PULLED FREE AT 220 KLBS, NO .ISSUES UNSEATING HANGER -7" PU WEIGHT 247 KLBS 19:00 - 20:30 1 1.50 1 PULL P DECOMP CIRCULATE SOAP PILL SURFACE TO SURFACE - 10 BPM, 650 PSI - MONITOR WELL FOR 10 MIN (STATIC) SIMOPS: - RIG UP CASING TOOL 2030 - 21:30 1.00 PULL P DECOMP RIG UP TO LAY DOWN 7" TUBING RIG UP CONTROL LINE SPOOLER 21:30 - 00:00 2.50 PULL P 10,644.00 DECOMP PULL 7", 26#, L-80, NSCC TUBING FROM CUT AT 10844' MD TO 9512' MD 1/10/2020 00:00 - 11:00 11.00 PULL P 10,643.00 DECOMP PULL 7", 261 L-80, NSCC TUBING FROM 9512' MD TO SURFACE' MD -TOTAL OF 268 FULL JOINTS, 1 SVLN, 1-5- PUP, AND 1-3.35' CUT JOINT - RECOVER 31 SS BANDS - STRAP OUT OF THE HOLE, TOTAL LENGTH WITH P272 RKB ADDED (42.70') = 10643' MD 11:00 - 11:30 0.50 PULL P 10,643.00 DECOMP RIG DOWN CASING TOOLS - CLEAN AND CLEAR RIG FLOOR Printed 2/4/2020 10:42:56AM **All dephts reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 3 of 4 Common Well Name. AGI -08 Event Type: WORKOVER (WO) Start Date: Eno Date: 1/12/2020 Project: PBUSAT Site: AGI Rig Name/No.: PARKER 272 Spud Date/Time: 2/24/1993 12:00:OOAM Rig Release: 1/12/2020 Rig Contractor: PARKER DRILLING CO. I BPUOI: USA00001834 Active datum: KB @60.65usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) _ 11:30 - 1430 3.00 PULL P 10,643.00 DECOMP CHANGE OUT 9-5/8" PACKOFF - OA HAS BEEN OPEN TO TIGER TANKAND MONITORED FOR 12+ HOURS PRIOR TO PACKOFF CHANGEOUT - DRAIN STACK -ENGAUGE PACKOFF WITH RUNNING TOOL - FMC ON LOCATION TO BACK OUT LOCK DOWNSCREWS - NO CASING GROWTH OBSERVED - PULL RACKOFF, PACKOFF PULLED FREE WITH 55 KLBS OVER BLOCK WEIGHT ,- MAKE UP NEW PACKOFF AND INSTALL IN .WELLHEAD - FMC RUN IN AND TORQUE LOCK DOWN •SCREWS TO SPEC ,- PRESSURE TEST PACKOFF TO 3500 PSI FOR 15 MIN (PASS), TEST APPROVED BY WOS (WSUP DOA) 14.30 - 15:30 1.00 RUNCOM P 10,643.00 RUNCMP LAYOUT 7-5/8" TUBING IN PIPE SHED AND FINALIZE TALLY _ 1530 - 0000 8.50 RUNCOM P 10,643.00 RUNCMP RUN 7-5/8", 391 TSH 563 COMPLETION TUBING TO 5871' MD - USE JET LUBE SEAL GUARD PIPE DOPE - TORQUE TURN CONNECTIONS TO 19000 FT -LBS - PU 204 KLBS, SO 163 KLBS -BRINE WEIGHT =9.8 PPG 1/11/2020 0000 - 07'.00 7.00 RUNCOM P 10,643.00 RUNCMP RUN 7-5/8", 39#, TSH 563 COMPLETION TUBING FROM 5871' MD TO 10643' MD - USE JET LUBE SEAL GUARD PIPE DOPE - TORQUE TURN CONNECTIONS TO 19300 FT -LBS - PU 370 KLBS, SO 225 KLBS - BRINE WEIGHT = 9.8 PPG - TAG THE TOP OF THE TUBING STUB ON PLANNED DEPTH AT 10643' MD 0700 - 1700 10.00 RUNCOM P 10,661.00 RUNCMP WORK PIPEAND ATTEMPT TO ENTER TUBING STUB - WORK PIPE, ORIENT PIPE 1/2 TURN AND WORK PIPE, CONTINUE TO WORK PIPE WHILE WHILE TURNING PIPE IN 1/2 TURN INCREMENTS - EVENTUALLYABLE TO ENTER TUBING STUB - RIH AND TAG CROSSOVER IN ORIGINAL TUBING AND SPACE OUT 18' INSIDE TUBING STUB TO 10661' MD - LAND HANGER AND RUN IN LOCK DOWN SCREWS 17'.00 - 18:30 1.50 RUNCOM P 10,661.00 RUNCMP FREEZE PROTECT TUBING AND IA - PUMP 32 BBL OF 6.8 PPG DIESEL HEATED TO 90° DOWN THE IA -ALLOW DIESELTO U -TUBE TO TUBING FOR 1HOUR 1830 - 21:30 3.00 RUNCOM P 10,661.00 RUNCMP RIG UP DUTCH RISER AND LUBRICATOR AND INSTALL J TYPE TWC - PRESSURE TEST TWC AND TUBING HANGER FROM BELOW TO 3500 PSI FOR 30 MIN (PASS) -TESTAPPROVED BY WSUP - RIG DOWN LUBRICATOR AND DUTCH RISER Printed 2/4/2020 10:42:56AM **All dephts reported in Drillers Depths** Printed 2/4/2020 10:42:56AM **All dephts reported in Drillers Depths" North America - ALASKA - Blo Page 4 of 4 Operation Summary Report Common Well Name: AGI -OB Event Type: WORKOVER (WO) Start Date. End Date'. 1/12/2020 Project: PBUSAT Site: AGI Rig Name/No.: PARKER 272 Spud Date/Time: 2/24/1993 12:00:OOAM Rig Release: 1/12/2020 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00001834 Active datum: KB @60.65usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (usft) __ 21:30 - 2300 _(hr) 1.50 BOPSUR P 10,661.00 RUNCMP NIPPLE DOWN THE BOP STACK AND HIGH PRESSURE RISER 23:00 - 00:00 1.00 BOPSUR P 10,661.00 RUNCMP NIPPLE UP ADAPTER FLANGE AND DRY HOLE TREE -CLEAN AND INSPECT TUBING HANGER_ 1/12/2020 00:00 - 04:00 4.00 BOPSUR P 10,661.00 RUNCMP NIPPLE UPADAPTER FLANGEAND DRY HOLE TREE - INSTALL SEMS SEAL -INSTALL ADAPTER FLANGE AND TREE - TORQUE BOLTS TO SPEC - PRESSURE TEST ADAPTER VOID TO 4500 PSI FOR 15 MIN (PASS) - TEST APPROVED BY WSUP SIMOPS: - BRIDLE UP - GENERAL RIG DOWN OPERATIONS "'RIG RELEASED FROM AGI -08 AT 04:00"' Printed 2/4/2020 10:42:56AM **All dephts reported in Drillers Depths" T/1/0=0/0/0 PULL TWC FOR PARKER. R/U Gray lubricator with 5-5' ext 1-3'& 2- centralizers, & 6" J Plug pulling tool. PT'd lubricator Low 300psi, High 3500 psi. Pulled 6" J 1/9/2020 TWC #401 @ 66". R/D Gray lubricator & ext. RDMO ***Job Complete*** FWHP=0/0/0 1/12/2020 Set 6" TWC #403 @145" with 33' of EXT w/ Lubricator 839. RDMO. ***Job Complete***. T/l/O = TWC/0/0. Torqued THAxMV, MWSSV. PT'd against TWC 350/5000 PSI (Pass) Charted and Retained. Pulled TWC @145". RDMO. ***Job Complete***. FWPs = 0/0/0. 1/12/2020 MV=O, SSV/SV,WV/CWV=C, IA/OA=OTG. T/1/0=0/0/0 POST PARKER. R/D IA piggyback Temp #102 & insatiled tapped blind flange. Torqued IA Blind to 192 ft lbs. R/D OA piggyback Temp #104 & insatlled tapped blind flange. Torqued OA Blind to 192 ft lbs. PT'd IA blind against Gate 2500psi. PT'd IA blind against Gate 2500psi. R/D 6" CIW Temp #110. R/U 6" CIW production tree. ***Job 1/12/2020 Incomplete*** Field Change out With Night Shift. T/1/0=-5/31/4 (Circ out and packer set) Pumped 5 bbls 60/40 down IA w/returns up TBG to OTT's. Pumped 363 bbls 140* 2%KCL followed by 272 bbls 140* Inhibited 2% KCL. Pumped 150 bbls of 100* Diesel for FP. Pumped 5 bbls 60/40 to FP surface lines. U-tube IAxTBG for 1 hour. Drop B&R, Pumped 7.2 bbls diesel down TBG to set S&R and pressure 1/18/2020 up to 4150pR Continued 01-19-20*** ***WELL S/I UPON ARRIVAL*** (rwo expense) R/U SWCP 4516 SLICKLINE UNIT 1/19/2020 ***CONT WSR ON 1/20/20*** ***WSR Continued from 01-18-20*** Temp= SI MIT-T PASSED at 4024 psi, Max Applied Pressure= 4150 psi, Target pressure= 4000 psi MIT-IA PASSED at 4112 psi, Max Applied Pressure= 4150 psi, Target Pressure= 4000 psi (RWO) (AOGCC Test-Wi—tnessed by Adam Earl), MIT-IA PASSED at 4125 psi, Max Applied Pressure= 4150 psi, Target Pressure= 4000 psi MIT-T - 1 st 15 min loss 23 psi and 19 psi in 2nd 15 min loss, Total loss of 42 psi, Bleed TBG pressure, Bled back 4.2 bbls Pre AOGCC MIT-IA- Pumped 6 bbls diesel down IA to reach test pressure, IA lost 22 psi in 1st 15 min and 9 psi in 2nd 15 min, Total loss of 31 psi, Bleed IAP, Bled back 4.5 bbls AOGCC Start witnessed MIT-IA- Pumped 4.5 bbls diesel down IA to reach test pressure- IA lost 15 psi in 1st 15 min and 6 psi in 2nd 15 min for a total loss of 21 psi, Bleed IAP, Bled back -4.6 bbls. Continue to bleed down psi's, bled back 7.8 bbls forjob total. Notify DSO, hang tags and AFE sign. FWHP's= 282/-7/-8. Well 1/19/2020 Ishut in upon departure. TREE = 6-318' CNV WELLHEAD= FMC ACTUATOR= BAKER C OKB. ELEV = 49 BF. ELEV = 15.61' KOP = 1153' Max Angle = 53• @ 11001' Dalian MD = 12181' Dalian TVD= 8800'SS 13-3/8' 3-3/8" CSG, W, K-55, 1=12A15" ) = 19.1024' D = 12.415' 81' 17-5/8- TBG IPC, 398, T-95, HYD 563, - 10 0427 bpf, ID = 6.625' Minimum ID = 4.455" @ 10748' 5-1/2" XN NIPPLE 7 -TBG STUB (12H6M9) 10680' 12• TBG, 17#, L-80 TCO, 10651' 132 bpf, D =4.892' SIZE G 268, Nr -80S NSOC, 10673 . D=6.276' SOZ ITOPOF7"LNR 5-12" TBG, 17#, L -M -PC, NSOC, .0232 bpf , D= 4.892" 8.681" PEFfFORATDN SUMMARY RE= LOG: AWS 05103!93 ANGLEATTOPPEfF: 53• c@ 11222' Note: Refer to Roduct on DB for historical pert data SIZE SPF INTERVAL OprVSgz SHOT SOZ 3-3/8" 6 11222 - 11242 O 6/19193 KR/JMD 33/8" 6 11272 - 11292 O 6119193 3-38" 6 11378 - 11398 O 6/19/93 3-3/8" 6 11460- 11480 O 6/19193 3318" 6 11528 - 11548 O r6mgm 1 .0371 bpf, D = 6.184' SAFETY NOTES: WELL REQUIRES A SSSV ••• LINAGI-OH SCC THREANOT D**** SCR NPPLES"G IS IPC WITH 2206' 7" SLB D85 NIP, D =6.000' 220 7" CAMCO BAL-0 SSSV 9-5/8' MARKER JOINT 75/8 X 5-1a- 15-1 Q- '5-12' HES X NIP. ID = 4.562' HES X NIP, ID = 4.562' MULESHOE, ID = 4.892' - VY XO, D =4.875" ED SEAL ASSY, D = 4.875 X 5-12' BAKER FBA PIR MLLOUr EXTENSION, D = PARKER SWS (9 CR) NP, OTIS XN (9CR1 NP. D = 4. { 10767' —j9-5/8'X7"TEBACKSLV,D=? REV BY 10760' &1/2"WLEG, D=4.892' 10768' EAAD TT LOGGED 06/09/93 10765' 9-5/8' X 7' BKR H PKR RWO 012320 w/ HY-FLO 1 HGR, ID=? DRUG HO CORRECTIONS 17" MARKET JOINT I DATE REV BY COMMENTS DATE REV BY COMMENTS 05/07183 ORIGINAL COMPLETION 01111220 P-272 RWO 012320 JMD DRUG HO CORRECTIONS 012820 KR/JMD FINAL ODEAPPROVAL PRUDHOE BAY UNIT WELL: AGW8 PERMIT No: 1930330 API No: 50-029-22348-00 BP Exploration (Alaska) MEMORANDUM State of Alaska Insp Num: mitAGE200119113727 Alaska Oil and Gas Conservation Commission TO: JimSRegg e `'Z�� DATE: Thursday, January 23, 2020 P.I. upervsor if SUBJECT: Mechanical Inte a Tests � Y BP Exploration (Alaska) Inc. Inj AGI -08 FROM: Adam Earl PRUDHOE BAY UNH` AGI -08 Petroleum Inspector 1889 - 1878 See: Inspector Reviewed By: P.I. Suprv, NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI -08 API Well Number 50-029-22348-00-00 Inspector Name: Adam Earl Permit Number: 193-033-0 Inspection Date: 1/19/2020 - Insp Num: mitAGE200119113727 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min AGI-08 'Type Inj N 'TVD 7871 Tubing 1380 1889 - 1878 1869930330 TypeTest SPT Testpsi 2500 IA 379 4146mped: I 4 5 BBL Returned: 4.6 OA 0 10 10 10 OTHER - PIF P Notes: Witnessed MIT IA tested as per sundry 319-492 wed „ s nce bA trcL 2x14 Thursday, January 23, 2020 Page I of I Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, January 22, 2020 7:45 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; Ak, OPS FS1 Facility PTL; Ak, OPS FS1 Field PTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Brown, Don L.; De la Cruz, Paulina; G GPB FS1 Drillsites; Oestgaard, Finn; Vandergon, Mark A Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Gas Injector AGI -08 (PTD #1930330) passed MIT -T and MIT -IA post RWO All, Gas Injector AGI -08 (PTD # 1930330) was made Not Operable on 03/03/14 for TAA communication. On 01/12/20 a rig workover was completed to change out the production tubing. On 01/19/20 Fullbore performed a passing MIT -T to 4,024 psi and a passing AOGCC witnessed MIT -IA to 4,125 psi. The passing MITs confirm two competent barriers to formation and the well is now classified as OPERABLE. Once the well is on stable injection, an online AOGCC witnessed MIT -IA will be performed. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization—Alaska Office: 907-659-8110 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Bjork Senior Completions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU AGI -08 Permit to Drill Number: 193-033 Sundry Number: 319-492 Dear Mr. Bjork: 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 Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jer rice Chair DATED this 1 day of November, 2019. ;$DMS NOV 0 51019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECD G,i,;V1fND DU T 0 ma Form 10-003 Revised 04/2017 I MS14� Z/NOV 0 5 2019 Il/I 1��1 ORIGINAL Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Oji^r Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 C ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 193-033 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service 0• 6. API Number: 50-029-22348-00-00 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 0 PBU AGI -08 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028301 034628 PRUDHOE BAY. PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(fQ Effective Depth MD: Effective Depth TVD MPBP (psi): Plugs (MD): Junk (MD): 11648 8464 10748 7910 2495 I 10748 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 37-117 37-117 1490 470 Surface 3901 13-3/8" 36-3937 36-3486 3450/5020 1950/2270 Intermediate 10901 9-5/8" 34-10935 34-8025 6870 4760 Production Liner 889 7" 10757 - 11646 7916-8462 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 1 Tubing Grade: Tubing MD (ft): 1 11222 - 11548 i 7" 26#x 5-1/2" 17# NT -80 / L-80 33-10760 Packers and SSSV Type: 5-1/2" Baker FB -1 Packer Packers and SSSV MD (ft) and TVD (ft): 10680/7868 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: January 1, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 " Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Reese, J. Kyle be deviated from without prior written approval. Contact Email: iohn.raese@bp.00m Authorized Name: Bjork, David Contact Phone: +1 9075644629 Authorized Title: Senior Completion Engineer Authorized Signature: "'/r Date: 6, COMMISSION USE ONLY Conditions of approval: Notify Commission so thattaa representative may witness Sundry Number: Plug lnteggnntya ❑ BOP Test Mechanical lntegmy Test El Location Clearance ❑ .L/Y Other. STii�TE C/� e7 � ems) � ssrrry S /�'I 14117--,Z-19 7-d Zs --cc a Post Initial Injection MIT Req'd? Yes 11 No ❑ 'aac /C{l -5--r- -%Spacing Spacing Extion Required? Yes ❑ No [� Subsequent Form Required:/6 tiS/Q y APPROVED BYTHE \1 Approved by: � QCOMMISSIONER COMMISSION 11 Date: 1 Form 10-003 Revised 04/2017 I MS14� Z/NOV 0 5 2019 Il/I 1��1 ORIGINAL Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Sundry Request: Injector Tubing Swap Well: AGI -08 Date: 10/30/2019 Est. BHP at 8800' TVDss: 3375 psi MASP: 2495 psi Well Type: Gas Injector Estimated Start Date: January 1, 2020 History The AGI -08 well was initially drilled, completed and placed on injection in 1993. This injector was on line from 1993 to 2014 with few issues. In 2009, the well developed TAA communication and LDL found leaks at 3754' MD, 3762' MD, the control line and a possible leak at the XO above the packer. Several attempts were made to mitigate this communication with MCX change -outs but MIT -Ts failed. The well was then secured in 2014. Scope of Work Pull 7" tubing from pre -rig tubing cut. Change 9-5/8" casing packoff. Run new 7-5/8" x 5-1/2" tubing. - Pre -Ria Work W PPPOT-T&IC. Function LDS. F CMIT-TxIA to 4000 psi. S Set junk ccatcher. E Jet cut tubing at -10,550' MD. F Circulate wellbore to 9.8 ppg brine with freeze protect cap. CMIT-TxIA to 1000 psi. V Set BPV Proposed RWO Procedure 1. MIRU Parker 272. 2. ND adapter / tree. NU BOPE with the following configuration (top-down): annular, 4-1/2" x 7" VBR, mud cross, 7-5/8" FBR. Test BOPE to 4000 psi (annular to 3500 psi). --L &/ Ak.- 4e14,cn 71•44're� 3. Pull BPV. Circulate out freeze protect. 4. Pull 7" tubing from pre -rig cut at 10,550' MD. 5. Change 9-5/8" casing packoff. 6. Run new 7-5/8" x 5-1/2" tubing to -10,550' MD with stacker packer configuration (packer set post -rig). 7. Circulate freeze protect cap. 8. Set TWC. ND BOPE. NU adapter / tree and test. RDMO. Post -Rig Work Kyle Raese, RWO Engineer 907-564-4629 john.raese@bp.com _._.Ta Zseaps> Tree work. Pull TWC. F Circulate completion fluid and freeze protect. Dropball & rod. Set packer. MIT -T. MIT -IA. S FFV Pull ball & rod. Pull RHC profile. Pull junk catcher. Pull PXN plug. C Contin enc : Cleanout MIT-IA(post-POI) Kyle Raese, RWO Engineer 907-564-4629 john.raese@bp.com _._.Ta Zseaps> TREE= ' 6-3/8*CIW VKLFEAt3� Note: Refer to Reduction DB for historical perf data SIZE ACRATOR� BAKERC Opn/Sgz OK6.8.EV = 49' 3-318" BF. ELEV = 11222- 11242 O KOP= 1153' 1331W CSG, Max Angle = 53" @ 11001' 68#, K-55, Datum MD_ _ .. 12181' D-12.415" Datum TVD= 8800'SS O 20" ODN0IJCTOR, 91.5#, H40, D - 19,1024- 13-318" CSG, 689, L-80, D = 12.415" Minimum ID = 4.466" 0 10748' 6-112" XN NIPPLE /- 7ti3G-IFti, 26#, NT -80S NSCC, .0383 blot , D = 6.276" 5-1/2" TBG, 17#, L-80. PC, NSCC, .0232 but . D= 4.892" CSG, 47#, W -80S NSW, D= PERFORATION SL&WRY REF LOG: AV%G 05/03/93 ANGLE AT TOP PERF: 53* @ 11222' Note: Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT S 0 3-318" 6 11222- 11242 O 6/19/93 3-3/8" 6 11272-11292 O 6119/93 3-38" 6 11378 - 11398 O 6/19/93 3-3/8" 6 11460- 11480 O 6/19193 3-3/6" 6 11528-11548 O 6/19193 .0371 bpf, D SAFETY NOTES: WELL REQUIRES A SSS V "* AGI -08 LINER NOT CEMENTED *** ALL TBG IS IPC WITH NSCC THREAD *** 9CR NIPPLES ®v.� 1 DATE REV BY COMPAENTS DATE REV BY OOMbtBdiS 05/07193 ORK"L COMPI.EIION 11/27/17 RCB/JMD PIAlED PX & PXN PLIICIRF5ET PXN 01!29!01 SlS-MD FINAL 05/22101 F*MK CORRECTIONS 0311&103 AS/TLH ADD PCRHMAD FORTBG 07!22114 JLSOMD PDLL NP REDfFL=SEr PLDG (7/20114) 10/02/15 IVIG--&JMD IVIG--&JSET FIX PLUG (09109/15) SSSV W. X 5-1/2' XO, D=4.875", MED SEAL ASSY, D = 4.875"1 J8" X 5-1/2" BAKER FB -1 PKR , D —=4.1 US" MLLOIIT EXTENSION D= 6.63" 8" X 5-112" XO. D - 4.9a 5-1/2" 5-1/2" OTIS XN(9CR) NP, D=4 57/2" PXN PLOG (11/25/17) 9-5/8" X 7" TIEBACK SLV. D=? 5-1/2" V4LEG, D=4.897 ELMD TT LOGE® 06/09/93 9-58' X 7" BKR H PKR W / HY-FLO II HGR, D = ? D=4.562" PRIAFDE BAY TINT WELL AGI -08 PERMIT No: 1930330 AR No: 50-029-22348-00 Sec. 36. T12N R14E, 2409 FSL & 2536' FEL BP Bcploration (Alaska) TOP OF ROTARY TABLE C/L WELL FWWWX Ill NIPPLE:32' DLA PIPE SFIE NIIDED TO THE Ill OF THE FLOMBOX — _._,..._ , � INNER DN. VIM INMTIHLE RUBBER SEN. WELL 7( T i BOTTOM of ROTARY BCW !L... ___;`_�I� +Lri. I BU 16' DPM LIIPPER. 1B" N LOWER J' CASING HLL WHET (OW OF 2) 13 5/11' W 81 UTE FLANGE 16* KEIIPIER SM -0 -GRIP (1 FA) 5' DA.SN. OUHET D& (1 FA) 2' ON M. OIIRET � MRC I LOCH DORN FLANGE 1 � NNNUVR BOP. 15-5/8' 5M SLANGED TW 13-6/8' SM FLANGED BOROM fffrrr��jjj ( R.W 11'PE BOP: 1J 5/B' 5M NOV DOUBLE BOP 13 5 5m EE, POP CELLAR DECK P1AlFORM i' 13 5/8" SM FLANGED BOTTOM W/ 3-1/2' MANUN EDDK$ W/ flBOOSIEI2 omuRNc cRos �. 13 5/B' 5M SNDOED TW 13 5/8' SM FLANGED BOTTOM 1 }y W (2) 3 1/8" 5N SIDE 0UHE15 1 II�I KILL ZINE I5 I I I III 2-1/16' SN FLEX HDSE a 1 g I i u 2-1/16' W K 3-1/8' SM D.SA 3�1/B' 5M FLANGED MW WL DOE VALW �4C III III I 13_1/8' 514 FLANGED HYDRAWC GALE VALVE iii 11i �i! I III �,. l RAN! TBE A]P: 13 51 W NOY W12 SINGLE BW 13 5/9" W SHIDDW TW 13 5/8' SM FLANGED WTTOM eE - NIPPLE UP. ■ I SPACER SPOOL 13 5/B' 5M FLANGE TOP CHORE ANE: 13 5/8" 511 FLANGED SGI 3-1/5' SM FLANGED MANWE CANE VANE SPACER SPOOL 3-1/8" 5M FLANGED HYDRAUAC GAIE VE Tb' 13 5/8' FLANGE NOP 3-1/8' SM FLFX HOSE WE 13 5/8' 5M NANCED BOAON DOUBLE SNODED ADAPTER 13 5/B' W FLANGED RIP 11' 5N FLANGED BOTTOM COUM AND WELL HFID CONFIGURA1pN ARE FOR REFERENCE ONLY k ARE MING SPOOL ASSEMBLY DEPENDENT W WERATOR'S It' 5M FLANGED TOP REWIREWNIS 11' 5111 FLANGED BOROM CASING HEAD ASSEMBLY 11' W FLANGED TOP 6012 BOP STACK (DRAFT 8.3.17 L. C.) TREE = ' 6-m" CNV WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 49' BF. ELEV= Opn/Sgz KOP = _ 1153' MaX k:= 53'@11001' Dahm MD = 12181' Dahm TVD= 88W SS AGI -08 FLsmj1NER NOT CEMNTED NOTES: WELL RE ALL TBG IS QUIRES A SPC WITH Proposed RWO CC THREAD ***9CR NIPPLES*** 13-3/8" CSG, S1• 68#, K-55, ID= 12.415" 2200' 7"SLB 'DB -6' NIP, ID = 6.000" ID = 19.1024" 1 ne• 113-3/8" CSG. 68#. L-80. D = 12 415" 1 17-518- TBG -PC, 39#, T-95, HW n1563. D= 6.625" 1 I7" TBG -PC, 26#, NT -80S NSCC, 0383 bof. . ID = 6.276' Minimum ID = 4.455" @ 10748' 5-1/2" XN NIPPLE 7" 5-1/2" TBG, 17#, L -80 -FC, NSOC, .0232 bpf , ID = 4.892" FERFORATION SLAW ARY FEF LOG: AWS 05/03/93 ANGLEAT TOP PERF: 53'@11222' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-3/8" 6 11222 - 11242 O 6/19/93 3-3/8" 6 11272 - 11292 O 6/19/93 3-3/8" 6 11378 - 11398 O 6/19193 3-3/8" 6 11460- 11480 O F6119193 3-3/8" 6 11528 -11548 O F6119193 PBTD 11625' .0371 1 � 10680' 9-5/8" X 5-1/2" BAKER FB -1 FKR ID=4.875" / 10,462' S-1/2"HES'X'NP,ID =4.562" 7-518" MLLOLIT IXTENSDN, D = 6.63' 9-5/8"x5-1/2"HES'TNP ID=4.88" / 10,$47' S-i/2"HES'X', ID=4.562" / 10,$64' Sd/2" WLEG / 10674' 7" X 5-1/2" XO, ID = 4.875" 1 � 10680' 9-5/8" X 5-1/2" BAKER FB -1 FKR ID=4.875" 10694' 11/27/17 RMAID FULLED PX 8, F'XN FL=RESEr PXN 7-518" MLLOLIT IXTENSDN, D = 6.63' 05/22/01 RTYKAK IONIS03/18/03 � 10728' S-1/2" PARKER SWS (9 CRI NIP, ID=4.562" •� 10745'--15-1/2'OTIS XN (9CR)NIP, ID=4.4 107$7' 9-5/8" X 7" TEBACK BLV, D=? 10760• 5-1/2" WLEG, ID= 4.692" 10763' ELMD TT LOGGED 06/09/93 OM E?1ITS DATE REV BYgFIRAL DATE REV BY COMMaNITS 05/07/93 L CO"OLET10N 11/27/17 RMAID FULLED PX 8, F'XN FL=RESEr PXN 01/29/01 SIS -MD 05/22/01 RTYKAK IONIS03/18/03 AS/TLH }READFORTBG 07/22/14 JLS/JMD PULL NAP RE /PL(JGdSEF PLUG (7/20/14) 10/02/15 MGS/J SET PX PLUG (09/09/15) 11 1 HY-FLO II HGR ID = ? FRLIO-IOE BAY LINT WELL: AGI -08 R3iMT Nb: 9930330 ARM: 50-029-22348-00 T12N, R14E 2409' FSL & 2536' FEL BP Exploration (Alaska) OF ��`y1��\\ %%%tea, HE STATE 1 a i a - - L._ 11. ,. ._T • B ?, O , �� // —am! , � � in tett 333 Wesi Seventh Avenue '"�ktO.PGOVTRNOR SEANFARNI;LL Anchorage, Alaska 99501-3572 `� -?,a Main: 907.279.1433 �ti . Iv1, . 9(7.. 76 %:42 Javier Farinez SCWED MAY 0 7 2014 -- D3 5 GPB GDE Lead PE " 1 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-08 Sundry Number: 314-210 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �/ K Iriv Daniel T. Seamount, Jr. Commissioner DATED this 1 'day of April, 2014. Encl. RECEIVED • STATE OF ALASKA APR 0 3 2614 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 ' Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ \ 193-033-0 . 3.Address: Stratigraphic ❑ Service Q. 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22348-00-00 , 7.If perforating: 8.Well Name and\umber. 1 What Regulation or Conservation Order governs well spacing in this pool? PBU AGI-08 , Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034628 ' 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): 11648 ' 8464 , 11624 8449 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 36-116 36-116 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate • 10898 9-5/8"47#NT8OS 37-10935 37-8025.11 6870 4760 Production None None None None None None Liner 889 7"29#NT-80 10757-11646 7915.67-8462.38 8160 7020 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 7"MCX SSSV 2285,2216.32' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q ' 14.Estimated Date for 15.Well Status after proposed work: 11 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑✓ ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true andcorrect to the best of my knowledge. Contact Javier Farinez /I Email Javier.Farinez©BP.Com Printed Name Javier jnez Title GPB GDE Lead PE Signature Phone 564-5043 `( r b I tai Date Prepared by Garry Catron 564-4424 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \!--` ^ 2.\0 _ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 1 Location Clearance ❑ 014 RBA Al/ 0 7 2 Other: RBD LU T fete !�/ f�� SS r //171 I T- !A rrcGvIi--d a Ffe-K . -fcc b , 'la`3z-d r`„-2.cc-fie -,. r ,/ Spacing Exception Required? Yes El No L Subsequent Form Required: oa — ga4 i A-',7 APPROVED BY �J? / �JApproved by: / COMMISSIONER THE COMMISSION Date: '�! i // T—' oetRotottlA, SSG-rC'r 441011y �. V 4././y Form 10-403 Revised 10/2012 lid for 12 months from the date of approval. Submit Form and Attachments in Dupl` to VL-i 4if / I .rp/� -o O O 000 O 0 00 co , (o in co , a) o_ O 0 0 0 0 0 0 (i) N CON O L() 00 f� O N p V N CO L() U 0 0 0 0 0 0 0 CO Nr C•1 CC) CO CO 10 M a) v, (6 LO N CO CO CO m N CO 00 CO O V CO 00 CO Cb M p.").. N- Q O CO CO CO N- CO (O co OCOCOMOOMCOCO al co E NN C J co Ln co N- o m (° rn � M7, r- cc) (n O 2 0) O J Q o O M CO C) co co (0 (1) U 0 0 co Lx-) coo , 0o0 0o J Y co = Z H *k *k N Z Co00 C Z O NN N CO CO m O C) CA Ln Ln CA a) CO O 00co co CC) O co Q O c ~ 1 L1J UJ O 0 CC c LL LL Z Z Z LJJ LJJ c m m OI" ZDD » 0 _ Jv) v) 1- 1— Perforation Attachment ADL0034628 Well Date Perf Code MD Top MD Base TVD Top TVD Base AGI-08 6/19/93 PER 11222 11242 8201 8213 AGI-08 6/19/93 PER - 11272 11292 8232 8244 AGI-08 6/19/93 PER 11378 11398 8297 8309 AGI-08 6/19/93 ' PER 11460 1 11480 8348 8360 AGI-08 6/19/93 PER 11528 11548 8390 8402 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 ADL0034628 Well Facility Type _ MD Top Description TVD Top AGI-08 SSSV 2285 7" MCX SSSV • 2216 AGI-08 PACKER 10680 5-1/2" Baker FB-1 Packer 7868 AGI-08 PACKER 10765 7" Baker H Packer • 7921 HcS To: Wireline Ops TL Date: March 28, 2014 Well Services TL From: Bethany Freel AFE: APBINJEC Interventions Engineer Est. IOR: 50 Subject AGI-08: 7" 2 trip tubing patch with SSSV Est. Cost: Nipple WBL Steps 1 S Pull MCX, drift for patch, set nipple reducer and plug, memory acoustic LDL, pull plug 2 E Set bottom section of two piece straddle 3 F Fullbore assist E-line. Pump hot fluid immediately prior to setting bottom section of straddle 4 S Set top piece of 7" straddle, set MCX injection valve in straddle 5 F Fullbore assist Slickline. Pump hot fluid immediately prior to setting Upper section of straddle Well Status Current Status: Not Operable Max Deviation: 49 degrees @ 11001' MD (28° @ SSSV NIP) Minimum ID: 4.455" @ 10748' MD (5-1/2" Otis XN NIP) Last Downhole 1/21/2014 S/L reset MCX with 2 sets of OS pkg and swellfix o-rings Op: Last TD Tag 11/26/2013 Tagged soft bottom @ 11,611 ELM W/ 3.50" cent, TEL, S- BLR (63' of rat hole, schmoo in blr) Objective Identify any tubing leaks above or below the SSSV nipple with an Acoustic and temperature LDL. If no leaks are found, eliminate T x IA by setting a WFD straddle patch with a tubing tail and nipple over the current SSSV nipple. Install MCX injection valve in straddle to facilitate gas injection. Well History AGI-08 was originally completed in May 1993, and despite passing multiple MIT-lAs with fluid, has a prolific history of IA repressurization. The ISSSV has been reset several times, each time with more aggressive packing configurations from 3 sets of standard packing to all oversized 1 • packing with swellfix o-rings. After resetting the ISSSV, IA pressure seems to temporarily hold steady for a short period of time before beginning its upward trend again, leading us to believe that the well's IA pressurization is due to a gas leak past the injection SSSV packing and through the control line into the IA. There has been no LDL performed in this well so it is possible that there are other leaks in the tubing contributing to T x IA communication. Pressure Test History Date Pressure Pass? Type Comments 5000 Y PPPOT -T 10/3/2013 8/8/2013 2500 Y MITIA Witnessed by John Crisp 8/6/2013 2500 Y MITIA 6/7/2012 3500 Y PPPOT -IC, Eval IA x OA 2/7/2012 4200 Y MITIA AOGCC Witness Bob Noble 2/5/2012 3000 Y MITT against TTP @ 10748' MD 2/5/2012 4200 Y MITIA Eval IA repressurization. (with DSSSV in hole) 2/5/2012 N MITIA with SSSV OOH 8/21/2009 2200 Y MITIA AOGCC Witness Jeff Jones 8/17/2009 2400 Y MITIA Passed, pre AOGCC 7/17/2007 3500 Y PPPOT PPPOT-IC 8/23/2005 2180 Y MITIA AOGCC witness John Crisp 5/27/2001 2100 Y MITIA state witnessed 7/6/1997 2000 Y MITIA State witnessed 9/21/1993 2110 Y MITIA State witnessed Procedure Overview Because of the nature of the leak(s) and a history of passing MITs with liquid, it is unlikely that we would see a leak with liquid in the tubing. Therefore, a tubing tail plug will be set and tubing • pressure increased to header pressure with injection gas. Before setting the plug, the well should be put on injection for 24-48 hours to warm up prior to slickline setting the plug and running the LDL in order to log the well at as close to operating conditions as possible. After slickline sets the nipple reducer and plug and pressures up the tubing with injection gas, the IA will be bleed down to induce a pressure differential and activate any leaks from the tubing to the IA. If no leaks are seen with the acoustic LDL, then we will move forward on the assumption that the only source of TxIA is through the ISSSV due to an inability of packing to seal in the nipple profile and a broken control line. E-line will then set the lower section of the straddle with a short tubing tail and nipple profile. Just before E-line sets the lower section of the straddle, fullbore will pump hot fluids down the tubing to avoid cracking the packer elements while they are extruded. After E-line has set the bottom packer, slickline will set the top section of the straddle also with fullbore assist and then will set an injection valve in the nipple profile within the patch. The well will then be put back on injection and monitored. Contacts: Bethany Freel, Interventions Engineer Office: 564-4352 Cell: (907) 379-6493 Javier Farinez, NGI PE Office: 564-5043 Cell: (907) 947-5722 Procedure 2 *If possible, arrange for the well to be POI 1-2 days before slickline gets on the well to warm it up. This will allow us to log the well at as close to operating conditions as possible.* Slickline 1. Shut in well and pull 7" MCX (ser# BP-711) from Camco BAL-O SSSV NIP @ 2285' MD 2. Drift to 2500' MD for 7" ER patch • See schematic attached for dimensions. Max OD = 5.720" 3. Set 5-1/2" x 3-1/2" nipple reducer in XN nipple at 10748' MD 4. Set plug in nipple reducer. • A draw down test is recommended for the nipple reducer and plug. Do NOT test the plug or nipple reducer with fluid. It is essential that the tubing remains as liquid free as possible to facilitate a successful LDL. 5. MU Archer acoustic LDL tool with temperature and run baseline pass from surface to TTP at 10748' MD. 6. Open wing valve and stack tubing pressure out to header pressure (-3300 psi) and bleed IA to slop tank. Hold open bleed on IA while logging. 7. Log up from the tubing tail plug to surface at 30 fpm 8. Ensure that LDL toolstring recorded data as designed, then pull the plug from the nipple reducer at 10748' MD 9. Contact town with any preliminary LDL results. E-line w/ Fullbore assist: Set Bottom Section of Straddle *Only proceed with setting the straddle if NO leaks were found in addition to the leak at the SSSV nipple.* 10. Fullbore: Pump a full transport of hot 1-2% diesel at max rate down the tubing to warm the area where the patch will be set. • It is important that the packer sets in a warm environment to avoid cracking the element while it extrudes as designed. 11. E-line RIH with lower straddle assembly as soon as possible after fullbore has pumped hot fluid to ensure the wellbore doesn't cool down before setting the packer. 12. Set bottom section of 7" Weatherford ER 2 trip patch with the center of the packer element at 2299' MD mid element. • Tie-in to tubing tally • Bottom section of straddle should have a tubing tail with a Camco DB nipple as seen in the drawing attached below. Weatherford has been contacted about preparing this straddle 3 • Please review attached drawing and tubing tally for visual confirmation of setting depth • Ensure that the correct, lower durometer packer element is used in the packer assembly Slickline/ Fullbore assist slickline in warming up the well 13.Fullbore: Pump a full transport of hot 1-2% diesel down the tubing to warm the area where the patch will be set. 14.Slickline: RIH with lower straddle assembly as soon as possible after fullbore has pumped hot fluid to ensure the wellbore doesn't cool down before setting the packer. 15.Set upper section of 7" Weatherford Eclipse 2 trip patch in snap latch seal assembly. This should place the top packer at 2274' MD 16.Install 4-1/2"" MCX in the new nipple in the tail pipe of the straddle. • Use largest bean size possible. 17.RDMO. 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Parker'SWS'Nipple 9 Cr 4.56 6.08 1.33 10727.67 10729.00 , 5.5" 174, L80,NSCC tubing pup joint 4.89 6.09 19.62 10708,05 10727.67 5.5", 174, L80, NSCC tubing pup taint 4.88 6.05 5,63 10702.42 10708.05 XO,5.5-1VSCC,oin X 5 5"FOX box 488 6.05 1.21 10701.21 10702.42 ' 5'44:tieiii;t477; Y*1'.beetr-I-Ttii14.::*;..j..0.4'0.' 41,144tFF', 41&11r;rliO0b4I: Baker Afiliout Extnsn 7-5/8'VAM 190-60 6.63 7.63 6.13 10694.24 10700.37 Baker 7-5,8"VAM box X box 6 8.22 1.04 1069320 10694,24 . Baker 190-60 see Bore Extension 6 7.5 9.28 10683.92 10693.20 Baker 192-60 FB-1 prod. packer 4 88 , 6 3.48 10660.44 10683.92 Baker 'QB}-1-22S'Locator sub 5-1/2' FOX 4.875 6 25 .98 . 10877.85 10678,83 XO,5-112" LT&G box X 5-112'FOX pin 4.875 6.05 3.93 10673.92 10877.85 X0.7*LT&C box X 5-1/2'LT&C pin ,4.875 7.625, .78 10673.14 10673.92 XO 7'NSCC box X 7"LT&C pin 6.276 7.625 2.64 10670.50 10673.14 : 41,4 i-*•',!' -'',.. 6i.216:71i0g: -,,,,,,',..*,11-1.7"W4W-44;66.6.5:,:.::,..kri0,e4O50 7", 264, NT80, NSCC tubing (212 jts) 6.2767,625 8362.06 , 2309.61 10665.67 7", 26#, NT80, NSCC tubing pup joint 6.276 7.625 9.62 2293_99 2303.81 AP t Flow Cauping 6.276 7,67 5.55 2288.44 2293.99 Camco Bal-0 SVLN w. Dummy(41D) 5.937'8.344 3.55 2284.89 2288.44 44i0- tilt.b!$:-Ai q1 •Iit.3.41-44.:;kk8.4.Asi, 7'.26#, NT80, NSCC tubing pup joint 6.276 7.75 9.58 2269,78 2279.34 7', 264, NT80, NSCC tubing (56 Its) 6,276 7.625, 2189.19 80.57 2269.76 80.57 80.57 7',26# NT80,.NSCC pups 6.276 7.625 4.78 75.79 80-57 7t:443400#041466-41i6WItt ti,All t NilgI l'',d:i4i tte40 c ,34,Ow'fii.:f'fitV-gd441;; '::-PV.11.'..t.09 FMC luting pup it&hanger below LDS 6.276 3.19 , 33.00 30.19 Audi 2 KB-LOS 33.00 . 93.00 . i 269 jts T, 26#, N1130S, IPC, NSCC tubing, . . 'Makeup torque = 7000 ft.lbs. . . I • Baker FB-1 production packer: Baker GBH-22S Locator Seal Ass'y. Up weight of tubing string: 280k. Packer TVD-7861'. . Down weight of tbg string: 200k. . Number of control line protectors: 31 . . 17 Liner top @ 10757; Shoe @ 11646'; Landing Collar . • 111@ 11624'. • I .. :Camco Bal-0 SVLN has dummy with 2 sets of packing, ,- ' • and i has a 4.00" ID. Pulling tool to pull 7- dummy requires a SR Walls ----, Camco 7" I- i • 1 PRS pulling tool. Ran 2 control lines (one operating, one •balance) 5 \ , EA_4 1-C cr,' ii.. / c$T TO 5c. cLE ?., Z61ArriON% Q 5s' 1 j :t, iv't$G NW.- ..... IT I 1 5.55' ATI Flow C.0,471i wci Lz8`+.S°1` T 1 Ce,...co�?ia t-o sv�J 26 J E+o E x.55 I 2�.'a„.' t,.i. i I'-t.66APs ?tow Crnrp l f n I s.55' __l_ z t n' 9.6z 4 Z6-0,ttr rtc--7✓µP 'L 2511 ' lixoe-e- CJeerril- 2''x'15 16 l ' 7b 4r NVTS0 NSLG v.It O int 6 WELLHEAD= CM/ ACTLIATQR= BAKER CS- t NOTES:WELL REQUIRES A SSSV "• 'KB. ELEV= 49' AG 1-08 LINER NOT CEMENTED***ALL TBG IS IPC WITH BF ELEV= NSCC THREAD 9CR NIPPLES*** A 110 Max Max Angle= 53°@ 11001' 13-3/8"CSG, H 81' 4-)1( Datum NID= 12181' 68#,K-55, Datum N0= 8800'SS ID=12.415' 1 — 2285' Hi"CAMCO BAL-O SSSV NIP, ID=5.937' 20"CONDUCTOR,91.5#,H-40,ID=19.1024" -- 106' 13-3/8"CSG,68#,L-80,ID=12.415" -� 3937' H , Minimum ID = 4.466" @ 10748' • 10139' H9-5/8"MARKER JOINT 6-1/2" OTIS XN NIP ,- 10674' H 7'x5-1/2"xo,ID=4.875" 7"TBG-IPC,26#,NT-80S NSCC, —j 10673' 10678' H BONDED SEAL ASSY,ID=4.875" 0383 bpf,ID=6.276" 10680' H9-5/8"X 5-1/2'BAKER FB-1 PKR, ID=4 875" _ 10694' I--17-5/8"MLLOUT EXTENSION,ID=6.63" J 10700' j-17-5/9"X 5-1/2"XO, ID=4.94" ' ' 10728' H5-1/2"PARKER SWS(9 CR)NIP,ID=4.562" ' ' 10748' H5-1/2"OTIS XN(9CR) NIP,ID=4.455" TOP OF 7'LNR I— 10757' . 10757' H9-5/8"X 7"TIEBACK SLV,ID=? 5-1/2"TBG, 17#,L-80-IPC,NSCC, —{ 10760' - / 10760' H5-1/2"WLEG, ID=4.892" .0232 bpf,ID=4.897' 10763' H ELMD TT LOGGED 06/09/93 10765' h-9-5/8"X 7"BKR H PKR w/HY-FLO II HGR,ID=? 9-5/8"CSG,47#,NT-805 NSCC,ID=8.681" — 10935' 41 , PERFORATION SUMMARY 11090' H7'MARKER JOINT REF LOG: AWS 05/03/93 ANGLE AT TOP PERF: 53°@ 11222' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11222-11242 0 6!19/93 3-3/8" 6 11272-11292 0 '6/19/93 3-3/8" 6 11378-11398 0 '6/19/93 3-3/8" 6 11460-11480 0 '6/19/93 3-3/8" 6 11528-11548 0 '6/19/93 PBTD 11625' 7"LNR,29#,NT-80S NSCC, .0371 bpf, ID=6.184" H 11646' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION 02/09/12 GJF/JMD SET DSSSV&PXN PLUG(02/05/12) WELL: AGI-08 01/29/01 SIS-ND FINAL 02/14/12 GJF/JMD PULL DSSSV&PXN PLUG(02/12/12) PERMIT No 1930330 05/22/01 RN/KAK CORRECTIONS 02/23/12 PJC DRAWING CORRECTION API No: 50-029-22348-00 03/18/03 AS/TLH ADD IPC/THREAD FOR TBG Sec.36,T12N, R14E,2409'FSL&2536'FEL 04/11/03 JRCJKK CASING CORRECTION 02/11/11 P /JMD ADDED SSSV SAFETY NOTE BP Exploration(Alas ka) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator©bp.com] Sent: Friday, October 25, 2013 1:30 PM To: AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL;AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Farinez, Javier; G GPB FS1 DS; AK, OPS FS1 Operators;Wallace, Chris D(DOA); Regg, James B(DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: AGI-08(PTD#1930330)exhibiting TxIA communication Attachments: AGI-08 Wellbore Schematic.pdf;AGI-08 TIO Inj Plot 10-25-13.docx All, Injector AGI-08(PTD#1930330) has shown indications of tubing by inner annulus communication.The well has experienced thermal events due to gas supply temperature variance during this period,as seen on October 23,2013.An AOGCC witnessed MIT-IA was performed August 08,2013.At this time the well is reclassified as Under Evaluation. Plan Forward: 1. DHD: Bleed and monitor IA BUR 2. Slickline: Pull and Reset SSSV 3. DHD: Monitor well for 14 days Copies of the TIO and Injection plot as well as a wellbore schematic have been included for reference. Please call with any questions. Thank you, S C A R R E D LI 2 O ? Laurie Climer (.:/ternatr-.Jack Disbrori l BP Alaska_- Well Integrity Coordinator °�1' t,a C n lq`s JfCjz: is°x9ii'I WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com 1 • • Injector AGI-08 (PTD #1930330) TIO Plot 10/25/2013 Wee AG102 AWOI r � 1 1.000 -II-IA 2000 00. +000. "". a 077"13 naams WV, ISl7r,J :67173 OST:'f} 090,11 091113 099,19 iw7x'13 iM5'i3 ,M,Jitl 14'41.3 _..._ Injection Plot Welt AG„b 3600 3,500 iID OM 5100 230.005 9,200 Fv\J y 23300 „A.aD 2100 2106 ,+O.rong -PHP 2000 120.0003 -AY tfi _ryy o1sm Imom- _r zm S, -01 '.602 10a9ro =a Yw■ 02020 ,m 00.9a 1.190 ... 1.w9 MOW bo w0, 960 en soar W N.00 00: n 2 OM Ia. m 20 , xo 10 ax 02e1T13 M'A1t3 C3'Yt] L'di.'.RJ 099213 997113 fBVrn? 04JA11 ro^i 13 0322.13 1095,13 10,12113 101415 WELLHEAD= CM/ ACTUATOR= BAKER C SAO NOTES:WELL REQUIRES A SSSV *** KB.ELEV= 49' A • I-U 8 LINER NOT CEMENTED'"*ALL TBG IS IPC WITH BF ELEV= NSCC THREAD 9CR NIPPLES" KOP= 1153' Max Angie= 53°@ 11001' 13-3/8"CSG, 81' Datum MD= 12181' 68#,K-55, Datum TVD'" 8800'SS ID=12.415" - 2285' H7"CAMCO BAL-O SSSV NIP,ID=5.937' 120"CONDUCTOR,91.5#,H-40,ID=19.1024" H 106' 13-3/8"CSG,68#,L-80, ID=12.415" —I 3937' 1A Minimum ID = 4.466" @ 10748' • 10139' ^--j9-5/8"MARKER JOINT 6-1/2" OTIS XN NIP 10674' —[7'X 5-1/2"XO,ID=4.875" 7"TBG-IPC,26#,NT-80S NSCC, — 10673' • 10678' —BONDED SEAL ASSY,ID=4.875"1 .0383 bpf,ID=6.276" 10680' --19-5/8"X 5-1/2"BAKER FB-1 PKR,ID=4.875" J __ 10694' H7-5/8"MLLOUT EXTENSION,IC=6.63" 10700' H 7-5/8"X 5.1/2"XO, ID=4.94" ' ' 10728' —15-1/2'PARKER SWS(9CR NIP,ID=4.562" 1 ' , 10748' H5-1/2"OTIS XN(9CR NIP,ID=4.455" 1 TOP OF 7"LNR —1 10757' 10757' H9-5/8"X 7"TIEBACK SLV,ID=? 5-1/2"TBG,17#,L-80-IPC,NSCC, —1 10760' " " 1 10760' —15-1/2"WLEG,ID=4.892" .0232 bpf,ID=4,892" 1 10763' H ELMO TT LOGGED 06/09/93 10765' —9-5/8"X 7"BKR H PKR w/HY-FLOIIFIGR,ID=? 9-5/8"CSG,47#,NT-80S NSCC,ID=8.681" --1 10935' 1- , PERFORATION SUMMARY • 11090' —7"MARKER JOINT I REF LOG: AWS 05/03/93 ANGLE AT TOP PERF: 53°@ 11222' Note:Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11222-11242 0 r 6/19/93 3-3/8" 6 11272-11292 0 �6/19/93 3-3/8" 6 11378-11398 0 '6/19/93 3-3/8" 6 11460- 11480 0 '6/19/93 3-3/8" 6 11528-11548 0 '6/19/93 PBTD 11625' 1 1 7 LNR,29#,NT-80S NSCC, .0371 bpf,ID=6.184" H 11646' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION 02/09/12 GJF/JMD SET DSSSV&PXN PLUG(02/05/12) WELL: AGI-08 01/29/01 SIS-MD FINAL 02/14/12 GJF/JMD PULL DSSSV&PXN PLUG(02/12/12) PERMIT No: 1930330 05/22/01 RNIKAK CORRECTIONS 02/23/12 PJC DRAWING CORRECTIONS API No: 50-029-22348-00 03/18/03 AS/TLH ADO IPC/THREAD FOR TBG Sec.36,T12N,R14E,2409'FSL&2536'FEL 04/11/03 JRC/KK CASING CORRECTION I] 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) RECEIVED • STATE OF ALASKA KA OIL AND GAS CONSERVATION COMAION JAN 2 3 2013 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations LJ Perforate L Other LJ Water Wash Performed: Alter Casing 0 Pull Tubing0 Stimulate - Frac 0 Waiver 0 Time Extension0 Change Approved Program 0 Operat. Shutdown0 Stimulate - Other 0 Re -enter Suspended Well0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory 0 ,, 193 -033 -0 3. Address: P.O. Box 196612 Stratigraphid Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22348 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 PBU AGI -08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11648 feet Plugs measured None feet true vertical 8463.61 feet Junk measured None feet Effective Depth measured 11624 feet Packer measured See Attachment feet true vertical 8448.8 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H -40 30 - 106 30 - 106 1490 470 Surface 3908 13 -3/8" 68# L -80 29 - 3937 29 - 3486.28 5020 2260 Intermediate None None None None None None Production 10907 9 -5/8" 47# NT8OS 28 - 10935 28 - 8025.11 6870 4760 Liner 889 7" 29# NT8OS 10757 - 11646 7915.67 - 8462.38 8160 7020 Perforation depth Measured depth 11222 - 11242 feet 11272 - 11292 feet 11378 - 11398 feet 11460 - 11480 feet 11528 - 11548 feet True Vertical depth 8200.82 - 8213.16 feet 8231.68 - 8244.02 feet 8297.09 - 8309.44 feet 8347.64 - 8359.96 feet 8389.52 - 8401.84 feet Tubing (size, grade, measured and true vertical depth) 7" 26# NT8OS 26 - 10673 26 - 7863.77 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): SCANNED MAR 0 5 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: v Copies of Logs and Surveys Run Explorator)Q Development 0 Service 0 Stratigraphic 0 Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas 0 WDSPLU GSTOR 0 WINJ 0 WAG 0 GINJ ©-, SUSP 0 SPLUG0 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: 312 -229 Contact Nita Summerhays Email Nita.Summerhays(7bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician � v.v., - Signa - - 4 )r��J��/11// - � � Phone 564 -4035 Date 1/23/2013 RBDMS JAN 2 8 21 v r X734 Form 10-404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0034628 ACTNITYDATE I 10/6/2012 •_ • 1 emp= : was 'ic e so ven rea men ® ° V * * *wsr continued from 10- 06- 12 * * *T7170= 26507560740 Temp =Sl TBG wash/ Pickle (solvent treatment) Pumped into tbg 10 bbl meth spear followed by 204 bbls diesel /xylene 50/50 mix and 245 bbls of fresh water with .02% F -103 surfactant let soak for 2 hrs as per procedure pumped an additional 267 bbls water with surfactant and capped well with 10 bbls meth Final whp's 135/500/46 SV,WV= closed 10/7/2012 SSV,MV,IA,OA =open DSO to PO1 FLUIDS PUMPED BBLS 204 DIESEL/XYLENE 50/50 20 METH 512 FRESH WATER WITH 0.02% F -103 SURFACTANT 736 TOTAL • • Packers and SSV's Attachment ADL0034628 SW Name Type MD TVD Depscription AGI -08 PACKER 10680 7819.09 5 -1/2" Baker FB -1 Packer AGI -08 PACKER 10765 7871.61 7" Baker H Packer �A TUA R = CW • NOTES: WELL REQUIRES A SSSV *** K NCCEL R= BAKER� AGI-08 UNER NOT CEMENTED*** ALL TBG IS IPC WITH BF. ELEV = NSCC THREAD 9CR NIPPLES KOP= 1153' 'Max Angle = 53° Ot 11001' 13 -3/8" CSG, — I 81' Datum ND = _ 12181' 68#, K -55, Datum TVD= 8800' SS ID = 12.415' 2285' H7" CAMCO BAL -O SSSV MP, ID = 5.937' I 120" CONDUCTOR, 91.5#,1.40, ID = 19.1024" H 106' 1 13 -3/8" CSG, 68#, L -80, ID = 12.415" H 3937' , Minimum ID = 4.466" @ 10748' •--1 10139' H9 - 5/8" MARKER JOINT 1 6 -1/2" OTIS XN NIP 10674' HT' X 5-1/7' XO, ID = 4.875" 1 TBG-IPC, S NSCC, — I 1 10673' 10680' H9-5 5-1 BAKER .0383 bpf ID FB-1 Plea = 4.875" I — I 10694 H7 -5/8" MLLOUT EXTENSION, ID = 6.63" I J 1 10700' H7 -5/8" X 5-1/2" XO, D = 4.94" ' 1 10728' H5-1/2" PARKER SWS (9 CR) NP, ID = 4.562" 1 ' ' 1 10748' H5-1/7 OTIS XN (9CR) NW, D = 4.455" ( I TOP OF 7" LMR H 10757' � 10757' H9 -5/8" X T' TIEBACK SLV, 0= ? 1 5-1/2" TBG, 171, L-80-PC, NSCC, 10760' 1 / ' 10760' 1--15-12" WLEG, D = 4.892" 1 .0232 bpf , ID = 4.897 1 10763' HELM) TT LOGGED 06/09/93 1 10765' 19-5/8" X 7" BKR H PKR w/ HY -FLO II HGR, ID= ? 1 9-5/8" CSG, 471, NT-80S NSCC, ID = 8.681" H 10935' 1 — A PERFORATION SUMMARY 1 11090' HT' MARKER JOINT 1 REF LOG: AWE 05/03193 ANGLE AT TOP PERF: 53° @ 11222' Note: Refer to Production OB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 11222 -11242 0 6/19/93 3-3/8" 6 11272 - 11292 0 r 6/19/93 3-3/8" 6 11378 - 11398 0 ' 6/19193 3-3/8" 6 11460 -11480 0 ' 6/19/93 3-3/8" 6 11528 - 11548 0 ' 6/19193 PBTD 11625' 1 1 T' LNR, 29#, NT -80S NSCC, .0371 bpf, ID = 6.184" 1-1 11646' 1 , DATE REV BY COMMENTS DATE REV BY COMvENTS PRUDHOE BAY UNff 05/07/93 ORIGINAL COMPLETION 02/09/12 GJF /JM3 SET DSSSV & PXN PLUG (02/05/12) WELL: AGI-08 01/29/01 SIS-MD FINAL 02/14/12 GJF /JMD PULL DSSSV & PXN PLUG (02/12/12) PERM T No: '1930330 05/22/01 RN/KAK CORRECTIONS 02/23/12 PJC DRAWNIG CORRECTIONS API No: 50-029-22348-00 03/18/03 AS/TLH ADO IPC/THREAD FOR TBG Sec. 36, T12N, R14E, 2409' FSL & 2536' FEL 04/11/03 JRC/KK CASING CORRECTION 11 02/11/11 M♦B/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alas ka) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission AUG 7 2012 333 West 7 Avenue Anchorage, Alaska 99501 - © 3 3 Subject: Corrosion Inhibitor Treatments of GPB AGI IC13 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator III • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI-04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 AGI -05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 AGI-06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 AGI -07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 ----.?"A. G1-08 1930330 50029223480000 1.8 NA 1.8 NA 15.3 7/24/2011 AGI-09 1930350 50029223500000 Split conductor NA _ NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA L I % LUi SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Javier Farinez Petroleum Engineer 0 3 3 BP Exploration (Alaska), Inc. ( 3 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -08 Sundry Number: 312 -229 SL /NNEDJUN 2 7 2012 Dear Mr. Farinez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, Cath . Foerster Chair DATED this 44- day of June, 2012. Encl. STATE OF ALASKA cOt tis\ E C E I Y E D A OIL AND GAS CONSERVATION COMMI N 6, JUN 9 ZO1Z APPL FOR SUNDRY APPRO ALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ ChanA G(am ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Water Wash • El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 193 -0330 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service II , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22348 -00 -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 AGI -08 . Spacing Exception Required? Yes El No 0 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL- 034628. PRUDHOE BAY Field / PRUDHOE BAY Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11648 . 8464 • 11624 8449 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H -40 30' 106' 30' 106' 1490 470 Surface 3908' 13 -3/8" 68# L -80 29' 3937' 29' 3486' 4930 2270 Production 10907' 9 -5/8" 47# NT8OS 28' 10935' 28' 8025' 6870 4760 Liner 11619' 7" 29# NT8OS 27' 11646' 27' 8462' 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# NT -80S 26 10673 - - 5 -1/2" 17# L- 80 -IPC 10763 10760 Packers and SSSV Tvoe: 5 -1/2" Baker FB -1 Packer Packers and SSSV MD and TVD (ft): 10680' 7868' 7" Baker H Packer 10765' 7921' 12. Attachments: Description Summary of Proposal Ei 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/2/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ El • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the for g' ing is true and correct to the best of my knowledge. Contact Javier Farinez Printed Name Javi- F. 'ne, Title PE Signature / / Phone Date 564 -5043 6/18/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: �� APPROVED BY Approved by: de1 /9�4 � COMMISSIONER THE COMMISSION Date: b _ 17L "�� JUN 2 Form 10 403 Revis1/2010 O R G N fMS bmi in Duplicate 0 1, o EE E DI D DID'D,DID!cn =,r N r'C)I 17' 07, OIGI O,G) 0'4" GI'* X , o O tn 'o'm1 1 T r r r z 00 00 1 000 co ao w ao 1313 co co 3 rn1C)IC)'.0ir r D Z. 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AIlnlssaoons pasn ueaq aneq sagseM aualix /Iesaia amppefgo gar SZH £1705 - 1795 auo 4d zauu�� aainr✓� aaaulBu3 0£ 21OI Z 1.OZ /ii 1-/9 eiza aa 3JV IO adAj HaM 4uaw ;aaii 4uanlog ado3S qor 80 ewe IIaM pier aoj weiBoad Bu!duand eiogiin j • • • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -8 dimensions mechanical inner capacity outer capacity size lb /ft od id drift id collapse burst bbls /ft ft/bbis bbls /ft ft/bbis 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280.00 7740.00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 8.68 8.53 4760.00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 • 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 40 KCI / CaCI ! NaCI / 20 • .�,♦ ' / o • o / NaBr 0 4. 4 ' O O O -20 ` ♦ ! O O NaCI -40 ` , 1 -�-' CaCI ----. KCI -60 - L■A/ . _ o NaBr 8 .5 9.5 Density, PPG 10.5 11.5 12 .5 • Y WELLHEAD= CMJ ACTUATOR= BAKER C • S/ NOTES: WELL REQUIRES A SSSV "' KB. ELEV = 49' AGI-08 L INE NOT CE E TE D NIPPLES TBG IS IPC WITH BF ELEV = KOP = 1153' Max Angle = 53° (fg 11001' 13 -3/8" CSG, — 81' . d4< Datum MD = 12181' 68 #, K -55, Datum W D= 8800' SS ID = 12.415" 2285' 1--17" CAMCO BAL O SSSV MP, ID = 5.937' I I 120" CONDUCTOR, 91.5 #, H-40, ID = 19.1024" H 106' 13 -3/8" CSG, 68#, L -80, ID = 12.415" H 3937' I , Minimum ID = 4.466" @ 10748' • 10139' H 9 -5/8" MARKER JOINT 6 -1/2" OTIS XN NIP 10674' H 7" X 5-1/2' ' X0, ID = 4 875" 1 7" TBG -IPC, 26#, NT -80S NSCC, —1 10673' 10678' H BODED SEAL ASSY, ID = 4.875"1 .0383 bpf ID = 6.276 10680' 1 9 -5/8" X 5-1/2" BAKER FB-1 PKR ID = 4.875" 1-1 194' — 7 -5/8" AIILLOUT EXTENSION, , I❑ = 6.63" 10700' 1 7 -5/8" X 5-1/2" XO, ID = 4.94" I I 1 10728' — 15 -1/2' PARKER SWS (9 CR) NIP, ID = 4.562" 1 • 10748' 1 OTIS XN (9CR) NIP, ID = 4.455" 'TOP OF 7' LNR H 10757' 10757' H9-5/8" X 7" TIEBACK SLV, ID = ? 1 5-1/2' TBG, 17 #, L -80 -IPC, NSCC, — 10760' 10760' —15-1/2" WLEG, ID = 4.9a2"1 0232 bpf , ID = 4.892" 10763' -1 ELMD TT LOGGED 10765' — 9-5/8" X 7' BKR H PKR 06109/93 w / F{Y -FLO II HGR ID = ? 9 -5/8" CSG, 47 #, NT -80S NSCC, ID = 8.681" — 1 10935' 1 — A , PERFORATION SUMMARY 1 11090' H 7' MARKER JOINT 1 REF LOG' AWS 05/03/93 ANGLE AT TOP PERF: 53° @ 11222' Note. Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3 -3/8" 6 11222 - 11242 0 ' 6/19/93 3 -3/8" 6 11272 - 11292 0 ' 6/19/93 3 -3/8" 6 11378 - 11398 0 ' 6/19/93 3 -3/8" 6 11460 - 11480 0 ' 6/19/93 3 -3/8" 6 11528 - 11548 0 ' 6/19/93 PBTD — 11625' 7" LNR, 29 #, NT -80S NSCC, 0371 bpf, ID = 6.184" H 11646' 1 A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION 02/09/12 GJF /JMO SET DSSSV & PXN PLUG (02/05/12) WELL AGI-08 01/29/01 SIS-MO FINAL 02/14/12 GJF /JMD PULL DSSSV & PXN PLUG (02/12/12) PERMIT No: "1930330 05/22/01 RN/KAK CORRECTIONS 02/23/12 PJC DRAWING CORRECT1ON5 AR No: 50-029-22348-00 03/18/03 AS/TLH ADD IPC/THREAD FOR TBG Sec 36, T12N, R14E, 2409' FSL & 2536' FEL 04/11/03 JRC/KK CASING CORRECTION 11 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) p!- 1g3C 33o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] e(� 2 Sent: Sunday, February 26, 2012 10:28 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert; G GPB FS1 DS; AK, OPS FS1 Operators Cc: Wills, Shane M; King, Whitney; Olson, Andrew; Reynolds, Charles (Alaska) Subject: OPERABLE: Injector AGI -08 (PTD #1930330) IA Repressurization Mitigated After SSSV Change Out Attachments: AGI -08 TIO 02- 26- 2012.doc; MIT PBU AGI -08 2- 7- 12.xls All, The SSSV on gas injector AGI -08 (PTD #1930330) was changed out on 02/12/2012 in order to mitigate TxIA communication. Since the SSSV has been re -set the IA pressure 1 remained stable as seen in the attached TIO plot. The well also passed an MIT -IA on 02/07/2012 confirming two competent barriers. The well is reclassified as Operable at this time, but will remain on the monthly injection report for continued monitoring and evaluation for Administrative Approval. An updated TIO plot, Injection plot, and MIT -IA form are attached for reference: «AGI -08 TIO 02- 26- 2012.doc» «MIT PBU AGI -08 2- 7- 12.xls» Thank you, Mehreen Vazir (4 /IerdnuIL Gerald Nfilrphi ) Well Integrity Coordinator BP Alaska Drilling & Wells 4 t� Well Integrity Office: 907.659.5102�� Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, December 23, 2011 10:21 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chiwis, Robert; G GPB FS1 DS; AK, OPS PCC EOC TL Cc: Wills, Shane M (Northern Solutions); Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael 3 Subject: UNDER EVALUATION: Injector AGI -08 (PTD #1930330) IA Repressurization All, Injector AGI -08 (PTD #1930330) has recently shown a slow increase in IA pressure as seen on the attached TIO plot. The well has been reclassified as Under Evaluation. We plan to keep the well on injection, bleed the IA pressure, and monitor the IA build -up -rate until slickline rigs up to change out the SSSV. The plan forward is as follows: 1. DHD: Bleed and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. DHD: Monitor TIO plot for 10 days 1 • • A wellbore schematic and TIO plot have been included for your reference. « File: Injector AGI -08 (PTD #1930330).doc » « File: AGI -08 (PTD #1930330) wellbore schematic.pdf » Please call if you have questions or concerns. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 • PBU AGI-08 PTD # 1930330 2/26/2012 TIO Pressures Plot We [MIMI Coo 3 000 -4111- 2 OM • --46- OA -0- 000A 1,00D. \ 11/20211 12)03/11 12,013/11 12/17/11 12/24/11 12111/11 ovum 111/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/16/12 020/12 Injection Plot 3.500 240000 3400 - 2371:00 3200 220000 210000 2503 203000 2000 190013 2300 2600 128100 2500 170030 2400 160000 221:0 150000 2,100 140000 tow 100 133000 S gm, 1400 12onxi — 1l0.3/ 100/300 1 1333 9000 1200 MOO 1 100 10133 • 70.102 700 9300 60020 40D60 20.001 403 201 10 100 I//OS//I I//OS//I 12/03/11 12i0/11 12/h/11 12/24/11 12/31/11 01/117/12 01/4/12 01/21/12 01/28/12 02,04/12 - 02/11/12 02/1 02/2 000 5/12 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg2aalaska.gov; doa. aoacc.prudhoe.bav(caalaska.00v; phoebe.brooksOalaska.aov; tom.maunderaalaska.gov OPERATOR: BP Exploration (Alaska), Inc. c; 1 71 Z- I ( v FIELD / UNIT / PAD: Prudhoe Bay / PBU / AGI DATE: 02/07/12 OPERATOR REP: Gerald Murphy AOGCC REP: Bob Noble 1 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI -08 ' Type Inj. N TVD ' 7,868' Tubing 1720 2350 ' 2350 2350 ' Interval 0 P.T.D. 1930330 ' Type test P Test psi ' 1967 Casing 450 4200 ' 4190 4190 P/F P Notes: Under Evaluation injector, 5 bbl to reach test psi. OA 10 30 - 30 30 Tubing tail plug set in well during testing Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Wet Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU AGI - 08 2 - - 12 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday, February 10, 2012 Jim Regg e l Z Z(/ Z P.I. Supervisor % , SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION (ALASKA) INC AGI -08 FROM: Bob Noble PRUDHOE BAY UNIT AGI -08 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J5e-- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT AGI - 08 API Well Number: 50 029 - 22348 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN120207114416 Permit Number: 193 - 033 - Inspection Date: 2/7/2012 Rel Insp Num: p Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI -08, Type Inj. N ' TVD 7868 - IA 450 4200 ' 4190 4190 - P.T.D 1930330 ' TypeTest SPT Test psi 1967 - OA 10 30 30 30 Interval OTHER P/i P - Tubing 1720 2350 2350 2350 - Notes: A tubing tail plug was set in the well. - StAigliEDFEB 2 3 ZUZ Friday, February 10, 2012 Page 1 of 1 • • Regg, James B (DOA) From: Regg, James B (DOA) 2- Sent: Monday, February 06, 2012 4:45 PM q� To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 This is to memorialize my decision regarding reporting requirements for 5 injectors as discussed with you earlier today: PBU NGI -11 (PTD 1770800); PBU AGI -08 (PTD 1930330) Weekly reporting may be discontinued base. on pas ing MITs (1/7/12 for NGI -11; 2/5/12 for AG1-08). Intent as I communicated to Ryan Daniel on 1/20/12 was that weekly reporting was interim step while waiting for diagnostics (suspended due to extreme cold temps); TIO pressures should continue to be reported on monthly injection well integrity report for both wells until decision is made regarding need for Administrative Approval. PBU AGI -05 (PTD 1930020) Weekly reporting (see NGI -11) may be discontinued based on stabilization of annuli pressures that began last week of December 2011. This well can also be dropped from the monthly injection well integrity report at this time. PBU WGI -06 (PTD 190030) Existing Admin Approval (AIO 4E.006) should be canceled based on completion of workover. AOGCC will evaluate the need for a new Admin Approval for the shallow setting depth of packer associated with approved repair. PBU W -44 (PTD 1891000) Well may be removed from the monthly report based on passing MITIA (4/12 -11), no leak found with LDL (6/26/11), and stabilized annuli pressures exhibited during past 90 days while on injection.. Jim Regg AOGCC AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinatorftp .com] Sent: Sunday, February 05, 2012 10:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 Jim, Phoebe, and Guy, Attached is the January 2012 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. 1 «AOGCC Inj Report 02- 12.zip» • • Notes on wells: Added to Report: 11 -38A (PTD #1982160) Added per requirement of AA 4E.040 issued January 9, 2012. Taken off Report: MPC -10 (PTD #1850150) Was being evaluated for TxIA communication. IAP stabilized and well returned to Operable status. Please call with any questions or concerns. Thank you, Meltreen Vazir (Alternate: Gerald ;Ahor /alt} Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 2 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, January 30, 2012 6:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) 1 1( Cc: Daniel, Ryan; Chivvis, Robert 7 1 f Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -11 (PTD #1770800), and AGI -05 (PTD #1930020) Attachments: AGI -08 TIO 01- 30- 12.doc; NGI -11 TIO 01- 30- 12.doc; AGI -05 TIO 01- 30- 12.doc All, Please see attached updated TIO and Injection plots for the three subject wells. AGI -08 (PTD #1930330): No progress has been made at this time on the MCX reset due to wellwork operations being shutdown for weather conditions on the North Slope. As we come back to normal operations, AGI -08 MCX change out will be a top priority job. An IA bleed was performed on 01/21/2012 and the well continues to exhibit slow IA repressurization. «AGI -08 TIO 01- 30- 12.doc» NGI -11 (PTD #1770800): Continue to monitor for thermal stabilization of the IA prior to progressing Leak Detect Log. «NGI -11 TIO 01- 30- 12.doc» AGI -05 (PTD #1930020): IA pressure continues to remain stable at 850 psi. Continue to monitor for IA repressurization. «AGI -05 TIO 01- 30- 12.doc» Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir lien nrrt . Gerald Murphy) ph ) Well Integrity Coordinator ` �! f/ BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coor • tor Sent: Sunday, January 22, 201 :42 PM 1 • • PBU AGI -08 PTD #1930330 1/30/2012 TIO Plot W.kABF.. 1410 3.0W t 1813 0 On 1,000 �^ � +t 3 - � �03 ti' - t - t? • 0 11/05/11 11712/11 11!11 4/11 1122 6111 12/00/!8 12/10/11 12717/11 1224,11 12/3 0147/12 01111 /12 01/21112 01/28/12 Injection Plot Wet Mal 3500 3 240100 3.420 3200 3.200 220000 3,100 3/m 210000 2,800 200400 2400 190 2.1W 100,000 2,600 2503 110400 2300 16.OW 2.300 2200 150600 2203300 140000 _ W1i 1 136100 3 _ SW 1.700 120030 _31 1.70 1,603 110100 1500 1.4J0 100 On .000 � 1.300 90400 1200 '... 1300 00400 1,® 10460 900 60400 ''.... 009 50003 100 600 40 5000 300120 '..... 400 300 20000 '....... 204 10100 iW 11/05 11/12 /11 11/19/11 11/26/11 12103/11 12/10/11 12/12/11 1224/11 12/31/11 01!01 01/11/12 0121/12 012912 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Sunday, January 22, 2012 7:42 PM � !j7_ ; lz- To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Daniel, Ryan; Vazir, Mehreen; Chivvis, Robert Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -11 (PTD #1770800), and AGI -05 (PTD #1930020) Attachments: AGI -08 (PTD #1930330) well bore schematic.pdf; AGI -08 (PTD # 1930330) TIO and Injection Plot.doc; NGI -11 TIO and Injection Data.xls; AGI -05 (PTD # 1930020) TIO and Injection Plot.doc .: 4U Jim and Tom, I wanted to update you on the current status of 3 gas injectors that are either currently classified as Under Evaluation, AGI -08 and NGI -11, or we have been in communication about in the last month, AGI -05. AGI -08 (PTD #1930330) is awaiting the resetting of the MCX SSSV, which has been delayed due to weather conditions on the North Slope. The well is curren7y on injection, and has been showing slow TxIA communication with a rate of about 20 psi /day. The well has not exceed MOASP. The plan forward will be to change out the safety valve and monitor the IA pressure for continued build up. If continued pressure buildup is observed, a Leak Detect Log would be planned. Our plan forward would be to pursue an AA to allow for continued injection is a leak is not identified. -� «AGI -08 (PTD #1930330) well bore schematic.pdf» «AGI -08 (PTD # 1930330) TIO and Injection Plot.doc» NGI -11 (PTD #1770800) passed a witnessed (Matt Herrera) MIT -IA to 4200 psi with the well shut -in on 1/7/2012 but has continued to show erratic IA behavior after it was returned to injection, that appears to be thermally related as it reaches stabilization. An Excel plot is included which plots the last 3 months injection rate and temperature with the TIO plot for your review. An IA bleed performed on 1/16/2012 was recorded as all diesel. The plan forward will be to run a Leak Detect Log, then if nothing is identified, pursue an AA for the well. «NGI -11 TIO and Injection Data.xls» AGI -05 (PTD #1930020) is a well that had operated under an AA (4E.003) until it was cancelled in January, 2011 after not exhibiting IA repressurization for over a year. Shortly after the cancellation, the well began exhibiting intermittent slow IA repressurization. The well is currently not exhibiting IA repressurization since late December, as can be seen in the enclosed TIO and Injection plot. A rig workover is being planned for late 2012 to repair the well. Our plan forward is to pursue an AA since the rig workover is planned for late in 2012 to allow for continued injection until the RWO is completed. «AGI -05 (PTD # 1930020) TIO and Injection Plot.doc» All 3 wells will remain on the monthly injection reports. We are planning to continue to send weekly TIO and Injection plots ✓ to keep you informed on the status of these wells. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 • • PBU AGI -08 PTD # 1930330 1/22/2012 TIO Pressures Plot Wyk A61-00 4,000 3,000 - —�— Tbp OF- IA 2,000 - —A— OA 004 —� 0004 On 1,000 I i 10/22/11 11/05/11 11/19/11 12/03/11 12/17/11 12/31/11 01/14/12 Injection Plot Walk AGI-0(1 240.000 3,200 ✓' � 3.000 200.009 2000 �... �. 1600 180.000 2.400 160A00 2600 140.000 F ° FF' 1,800 120.000 _ G 1,400 100,000 $ - 01h. On 1200 80600 1.000 60,000 800 600 40,000 400 20600 200 10/72/11 10/29/11 11/05/11 11/12/11 11/19/11 11/26711 12/03/11 12/10/11 12/17/11 12/24/11 12/31/11 01/07/12 01114/12 01/21/12 TREE = SAFETY IBS: WELL REQUIRES A SSSV. LINER WELLHEAD= CM/ AGI-08 CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR= BAKER C THREAD. KB. ELEV = ` '49 BF. ELEV = _ KOP _ _. , ".,_ .. 1153' Max Angle = 53 11001' I 2285' 1 CAMCO BALD SSSV MP, ID = 5.937" I Datu MD = @ 12181' I Datum TV D= 8800' SS • 1 13 -3/8" CSG, 68 #, K -55, ID = 12.415" 1--JI 81' I-- 1 13 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3937' HA 17" TBG, 26 #, NT -80 -IPC, NSCC, .0383 bpf , ID = 6.276" — 10673' \ / L 10673' 1-1 7" X 5 -1/2" XO, ID = 4.875" 1 I TOP OF 5 -1/2" TBG — 10673' 10678' I- -1ANCHOR, ID = 4.875" I Minimum ID = 4.455" @ 10748' 10680' I I9 -5/8" x 5 -1/2" BAKER FB -1 PKR, ID = 4.88" I 5 -1/2" OTIS XN NIPPLE 1 ' 1 10728' 1-15-1/2" PARKER SWS NIP, ID = 4.562" I 1 I ( 10748' 115 -1/2" OTIS XN NIP, ID = 4.455" 1 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf , ID = 4.892 "1 —I 10760' I / ' • 10760' 1-15-1/2" WLEG, ID = 4.892" I 10763' H ELMD TT LOGGED 06/09/93 I TOP OF 7" LNR H 10775' I— - 1 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 10935' 1-4 PERFORATION SUMMARY REF LOG: AWS 05/03/93 ANGLE AT TOP PERF: 53 @ 11222' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11222 - 11242 0 6/19/93 3 -3/8" 6 11272 - 11292 0 6/19/93 3 -3/8" 6 11378 - 11398 0 6/19/93 3 -3/8" 6 11460 - 11480 0 6/19/93 3 -3/8" 6 11528 - 11548 0 6/19/93 1 PBTD I—I 11624' 1 17" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" — 11646' j DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION WELL: AGI-08 01/29/01 SIS -MD FINAL PERMIT No: 1930330 05/22/01 RN/KAK CORRECTIONS API No: 50- 029 - 22348 -00 03/18/03 AS/TLH ADD IPC /THREAD FOR TBG Sec. 36, T12N, R14E, 518.76' FEL & 297.59' FNL 04/11/03 JRC/KK CASING CORRECTION 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) P%', ((303so Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] ? f 2i Sent: Friday, December 23, 2011 10:21 AM r( To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert; G GPB FS1 DS; AK, OPS PCC EOC TL Cc: Wills, Shane M (Northern Solutions); Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael J Subject: UNDER EVALUATION: Injector AGI -08 (PTD #1930330) IA Repressurization Attachments: Injector AGI -08 (PTD #1930330).doc; AGI -08 (PTD #1930330) wellbore schematic.pdf All, Injector AGI -08 (PTD #1930330) has recently shown a slow increase in IA pressure as seen on the attached TIO plot. The well has been reclassified as Under Evaluation. We plan to eep ewe on injecti bleed the IA pressure, and monitor the IA build -up -rate until slickline rigs up to change out the SSSV. The plan forward is as follows: 1. DHD: Bleed and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. DHD: Monitor TIO plot for 10 days A wellbore schematic and TIO plot have been included for your reference. «Injector AGI -08 (PTD #1930330).doc» «AGI -08 (PTD #1930330) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 PBU AGI-08 PTD #1930330 12/23/2011 TIO Pressures Plot Wel1 :AGI-08 4.000 90(43 Tbg —I--IA 2,C00 - DOA 000A On 1,000 Abe ileall&M•MMMallkik ....11111•1111•Mm. 09/24/11 10/01/11 10/08/11 10/15/11 10/22/11 10/29/11 11105/11 11/12/11 11/19/11 11/26/11 12/03/11 12/10/11 12/17/11 TREE = • SAFEfES: WELL REQUIRES A SSSV. LINER WELLHEAD= CIW AGI-08 THREAD. TED. ALL TBG IS IPC WITH NSCC ACTUATOR= BAKER C KB. ELEV = - 49' 49' B KOP = 1153' 1 Max Angle = 53 @ 11001' Datum MD = 12181' I I 2285' I-17" CAMCO BAL -O SSSV NIP, ID = 5.937" Datum TN/D= 8800' SS 113 -3/8" CSG, 68 #, K -55, ID = 12.415" I 81' (— 113 -3/8" CSG, 68 #, L -80, ID = 12.415" I—I 3937' 17" TBG, 26 #, NT -80 -IPC, NSCC, .0383 bpf , ID = 6.276" — 10673' \ / l 10673' I -J7" X 5 -1/2" XO, ID = 4.875" I I TOP OF 5 -1/2" TBG — 10673' 10678' H ANCHOR, ID = 4.875" I Minimum ID = 4.455" @ 10748' 10680' I -19 -5/8" X 5 -1/2" BAKER FB -1 PKR, ID = 4.88" I 5 -1/2" OTIS XN NIPPLE ' ' I 10728' 1-15-1/2" PARKER SWS NIP, ID = 4.562" I ' I I 10748' 1-15-1/2" OTIS XN NIP, ID = 4.455" I 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf , ID = 4.892 "I—I 10760' II ' I 10760' 1-15-1/2" WLEG, ID = 4.892" 1 I 10763' H ELMD TT LOGGED 06/09/93 I TOP OF 7" LNR H 10775' I— 1 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" I—I 10935' I PERFORATION SUMMARY REF LOG: AWS 05/03/93 ANGLE AT TOP PERF: 53 @ 11222' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11222 - 11242 0 6/19/93 3 -3/8" 6 11272 - 11292 0 6/19/93 3 -3/8" 6 11378 - 11398 0 6/19/93 3 -3/8" 6 11460 - 11480 0 6/19/93 3 -3/8" 6 11528 - 11548 0 6/19/93 PBTD ( — 11624' I 1 7" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" H 11646' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/07/93 ORIGINAL COMPLETION WELL: AGI-08 01/29/01 SIS -MD FINAL PERMIT No: 1930330 05/22/01 RN/KAK CORRECTIONS API No: 50- 029 - 22348 -00 03/18/03 AS /TLH ADD IPC/THREAD FOR TBG Sec. 36, T12N, R14E, 518.76' FEL & 297.59' FNL 04/11/03 JRC/KK CASING CORRECTION 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) Monthly Injection Report for GPB, GPMA,hstar, Milne Point & Endicott for Oce... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Saturday, November 19, 2011 3:21 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for October 2011 Attachments: AOGCC Inj Report 11- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the October 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 11- 11.zip>> Notes on wells: Added to Report: NGI -03 (PTD #1750610) Under Evaluation for slow IA pressurization Taken off Report: ---4 AGI -08 (PTD #1930330) Was under evaluation for IA pressurization during TAR in July 2011. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator kp;' ' : " ?Litl Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/21/2011 Well AGI -08 Injection Plot Well: AGI -08 0 Pressure vs. Rate o TIO Plot PTD: #1930330 o 0 0 0 ✓ Tbg IA Under Evaluation for IA o 1 • ♦ • • OA r _�� - repressurization in July 2011. O o 0 0 0 r ri To be left on Monthly Injection a • o 0' a o Report for 2 additional months • la: o o 0 0 to facillitate monitoring. N N 0 o O / r O O • • Last 90 days • Last Month �� o , �' 0 0 50,000 100,000 150,000 200,000 250,000 5/12/11 8/2/11 10/23/11 1/13/12 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 11/01/11 206,232 3,345 11/01/11 3,300 950 150 10/31/11 196,738 3,327 10/31/11 3,300 900 100 10/30/11 194,147 3,300 10/30/11 3,300 900 150 10/29/11 190,634 3,300 10/29/11 3,300 950 150 10/28/11 194,945 3,334 10/28/11 3,300 950 250 10/27/11 192,761 3,301 10/27/11 3,300 950 50 10/26/11 194,340 3,280 10/26/11 3,300 875 50 10/25/11 193,409 3,278 10/25/11 3,300 875 50 10/24/11 198,221 3,314 10/24/11 3,300 850 50 10/23/11 175,863 3,168 10/23/11 3,300 850 50 10/22/11 181,144 3,231 10/22/1 3,300 850 100 10/21/11 190,640 3,277 10/21/11 3,300 850 175 10/20/11 186,590 3,274 10/20/11 3,300 850 100 10/19/11 185,121 3,268 10/19/11 3,300 850 100 10/18/11 185,757 3,275 10/18/11 3,300 850 100 10/17/11 184,673 3,257 10/17/11 3,300 800 20 10/16/11 184,537 3,252 10/16/11 3,300 800 20 10/15/11 184,731 3,251 10/15/11 3,300 800 20 10/14/11 185,333 3,253 10/14/11 3,300 800 20 10/13/11 189,043 3,267 10/13/11 3,300 800 20 10/12/11 186,036 3,265 10/12/11 3,300 800 20 10/11/11 184,213 3,266 10/11/11 3,300 800 20 10/10/11 185,303 3,272 10/10/11 3,300 800 20 10/09/11 185,374 3,288 10/09/11 3,300 780 100 10/08/11 186,334 3,300 10/08/11 3,300 780 20 10/07/11 196,857 3,353 10/07/11 3,337 780 20 10/06/11 191,857 3,314 10/06/11 3,337 760 20 10/05/11 195,468 3,342 10/05/11 3,337 760 20 10/04/11 184,837 3,272 10/04/11 3,337 750 25 10/03/11 180,050 3,255 10/03/11 3,337 750 25 10/02/11 190,956 3,306 10/02/11 3,337 700 25 Monthly Injection Report for GP•GPMA, Northstar, Milne Point & Endicoor July 20... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] Sent: Thursday, August 04, 2011 8:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for July 2011 Attachments: AOGCC Inj Report 08- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the July 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 08- 11.zip» Notes on wells: Added to Report: 09 -36C (PTD #1951140): Under Evaluation for IA repressurization. AGI -08 (PTD #1930330): Exhibited IA repressurization. Repressurization mitigated after SSSV change out. To be left on Monthly Injection Report for monitoring for 2 months. NS -27 (PTD #2010270): Under Evaluation for IA repressurization. R -02 (PTD #1781000): Under Evaluation for IA repressurization after a UIC bleed Taken off Report: U -10 (PTD #1851970): Successful AOGCC witnessed MIT -IA after tubing patch repair Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/8/2011 I Well AGI -08 Injection Plot Well: AGI -08 ° TIO Plot o Pressure vs. Rate o PTD: #1930330 0 0 0 v v Tbg IA Under Evaluation for IA 0 1 £ 0 OA - ' repressurization in July 2011. 0 0 0 "' C' To be left on Monthly Injection . a o .m Report for 2 additional months CL CD o- = a 0 0 to facillitate monitoring. N 3 0 O 0 o O • - O • • Last 90 days • Last Month � N 0 50,000 100,000 150,000 200,000 250,000 2/19/11 5/12/11 8/2/11 10/23/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 08/01/11 0 -38 08/01/11 0 600 20 07/31/11 0 -38 07/30/11 0 600 20 07/30/11 0 -37 07/29/11 0 800 560 07/29/11 6,059 468 07/28/11 3,480 800 560 07/28/11 182,196 3,335 07/27/11 3,480 680 160 07/27/11 198,334 3,402 07/26/11 3,480 680 160 07/26/11 199,264 3,412 07/25/11 3,480 680 200 07/25/11 200,437 3,437 07/24/11 3,480 700 180 07/24/11 193,446 3,402 07/23/11 3,480 500 180 07/23/11 192,069 3,402 07/22/11 3,480 220 180 07/22/11 191,240 3,402 07/21/11 3,480 750 400 07/21/11 183,888 3,372 07/20/11 3,480 700 300 • 07/20/11 181,664 3,365 07/19/11 3,480 700 300 07/19/11 188,664 3,401 07/18/11 3,480 660 250 07/18/11 200,000 3,479 07/17/11 3,480 700 300 07/17/11 190,286 3,425 07/16/11 3,480 640 50 07/16/11 161,144 3,443 07/15/11 0 520 20 07/15/11 0 3,416 07/14/11 0 550 20 07/14/11 0 3,425 07/13/11 0 500 20 07/13/11 0 3,412 07/12/11 0 550 20 07/12/11 0 3,330 07/11/11 0 550 20 07/11/11 0 3,399 07/10/11 0 1,300 100 07/10/11 14,046 3,354 07/09/11 3,330 1,300 100 07/09/11 184,541 3,324 07/08/11 3,330 1,300 100 07/08/11 184,597 3,330 07/07/11 3,330 1,300 100 07/07/11 181,247 3,322 07/06/11 3,270 1,300 300 07/06/11 176,903 3,314 07/05/11 3,270 1,200 200 07/05/11 174,274 3,298 07/04/11 3,270 1,100 100 07/04/11 187,197 3,347 07/03/11 3,270 1,100 100 07/03/11 183,046 3,329 07/02/11 3,270 1,100 180 07/02/11 178,386 3,321 07/01/11 3,270 1,100 300 OPERABLE: Injector AGI -08 (PTD #1930330) IA Repressurization Mitigated After SSS... Page 1 of4 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Thursday, July 28, 2011 7:55 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: OPERABLE: Injector AGI -08 (PTD #1930330) IA Repressurization Mitigated After SSSV Changeout Attachments: Injector AGI -08 (PTD #1930330) TIO and Injection Plot.doc All, Injector AGI -08 (PTD #1930330) has shown no signs of IA repressurization during the 10 days of monitoring from 07/18- 28/2011 following the changing of the sub - surface safety valve on 07/10/2011. The well is reclassified as Operable. The well will remain on the AOGCC Monthly Injection Report for 2 additional months to facilitate monitoring. A copy of the TIO and Injection Plot are included for reference. «Injector AGI -08 (PTD #1930330) TIO and Injection Plot.doc» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator , 9 ' /UPI'. Office (907) 659 -5102 ;v..; . Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 om: AK, D &C Well Integrity Coordinator Sent: • • , July 03, 2011 5:26 PM To: 'Maunder, T • E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 • I - or; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, • - •B East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wa - reg (D &C) Subject: UNDER EVALUATION: Injector AGI -08 (PTD #1930330) IA r-. urization All, Injector AGI -08 (PTD #1930330) has recently shown a slow increase in IA pressure as seen o • - attached TIO plot. The well has been reclassified as Under Evaluation. We plan to keep the well on injection, blee. - IA pressure and monitor the IA build -up -rate until slickline rigs up to change out the SSSV. The plan forward is as follows: 7/29/2011 • • Injector AGI -08 (PTD #1930330) TIO Plot 07 -28 -2011 Wet AGI -() 4.000 3000 - • f Tbg t IA 2.000 - -- OA 00A 000A • - On • 1.000 ...... .• . • .• 04/30/1105/07/11 05/14!1105/21/1105 /28/11 06/04/1106/11/1106 /18/ 1106/25/ 1107 /02 /1107/09/1107/16 /1107/23/11 • Injector AGI -08 (PTD #1930330) Injection Plot • W hAGI488 3,600 3,400 - 220,000 • 3,200 • - 200.000 3,000 2,800 - 180,000 2,600 - 160,000 • 2.400 - 2,200 - 140,000 mmz — WHIP 2000 • d SW 1 1800 - 120.000 °� PW 3 MI 600 GI 100,000 OUnn 1,400 On 1,200 : 80,000 1.000 - 60,000 800 - 600 - 40,000 400 - 20,000 • 04/30/11 05/07/11 05/14/11 05/21/11 05/28/11 06/04111 06/11/11 06 /10/11 08/25/11 07/02/11 07/09/11 07/16/11 07/2111 RE: UNDER EVALUATION: Inj or AGI -08 (PTD #1930330) IA repres.zation Page 1ef2 �J Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Tuesday, July 19, 2011 11:03 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector AGl -08 (PTD #1930330) IA repressurization Hi Tom, Injector AGI -08 (PTD #1930330) SSSV has been changed out and the well was placed back on injection on 07/16/2011. We will continue to monitor the TIO over the next 10 days as the well stabilizes and determine if the TxIA communication has been mitigated and provide follow up notification of the well status. As a follow up on your emails with Jerry, we did look at this and the other gas injectors in the recent gas pad review. We are prioritizing injectors and looking proactively to be prepared for rig repairs as much as possible. As you already know, we are I -1 before the end of the year. AGI -08 is definitely one on our radar as a planning to work over MPE -03 and NGI-10 b y y potential p repair if this issue with the SSSV persists and worsens. Please le me know if you have any questions. Thanks, d n. r � 4 4 U JU � I Mehreen "a : $ fi From: , D &C Well Integrity Coordinator Sent: Sund• my 03, 2011 5:26 PM To: 'Maunder, Th. 'gas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 0 AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East We •pt Engr; AK, RES GPB West Wells Opt Engr; Chiwis, Robert Cc: AK, D &C Well Integrity Coordinato ing, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector -08 (PTD #1930330) IA repr-: urization All, Injector AGI -08 (PTD #1930330) has recent shown low increase in IA pressure as seen on the attached TIO plot. The well has been reclassified as Under Eval .tion. We plan , keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline rigs up t. hange out the SSS The plan forward is as follows 1. DHD: Bleed and monito BUR 2. Slickline: Troublesh.. SSSV, control and balance lines 3. DHD: Monitor TI P plot for 10 days A wellbore s ematic and TIO plot have been included for your reference. « File: AGI -08 (PTD #1930330) wellbore schematic.pdf » « File: AGI -08 (PTD #1930330) TIO Plo . *oc» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 7/19/2011 AGI -08 (PTD #1930330) TIO and In'ection Plot Page 1 of 1 i • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, July 03, 2011 8:52 PM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: AGI -08 (PTD #1930330) TIO and Injection Plot Attachments: AGI -08 (PTD #1930330) TIO & Injection Plot.doc Tom, I only included the TIO plot with the notification I sent earlier today for AGI -08. I have included both the TIO and injection plot to show the fact that the pressure rise is not rate related. «AGI -08 (PTD #1930330) TIO & Injection Plot.doc» Regards, w -iti JUL I s 2.n Jerry From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, July 03, 2011 5:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector AGI -08 (PTD #1930330) IA repressurization Attachments: AGI -08 (PTD #1930330) wellbore schematic.pdf; AGI -08 (PTD #1930330) TIO Plot.doc All, Injector AGI -08 (PTD #1930330) has recently shown a slow increase in IA pressure as seen on the attached TIO plot. The well has been reclassified as Under Evaluation. We plan to keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline rigs up to change out the SSSV. The plan forward is as follows: 1. DHD: Bleed and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. DHD: Monitor TIO plot for 10 days A wellbore schematic and TIO plot have been included for your reference. «AGI -08 (PTD #1930330) wellbore schematic.pdf» «AGI -08 (PTD #1930330) TIO Plot.doc» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 7/5/2011 • • AGI -08 (PTD #1930330) TIO Plot 07 -03 -2011 Well AGI -08 4 000 3/00 - Tbg f Y' 2 000 - — OA 00A - -4.— 000A — On 1,000 - 04/09/11 04/16/11 04/23/11 04/93/11 05/07/11 05/14/11 05/21/11 05/28/11 06 /04/11 06/11/11 06 /18/11 06/25/11 07/02/11 AGI -08 (PTD #1930330) Injection Plot Web' AGI -08 3,600 3,400 - 220,000 3200 3,000 - 200.000 2,80. - 180,000 2,600 2,400 - 160 000 2,20. 140,000 - WHIP 200. _ - SW _ py 1,800 - 120.010 ; — �p 1,600 - 100,000 — Oy 1,400 - eneen. 1200 - 80.000 1.000 - 60 &q - 600 - 40 000 400 - 20000 200 - 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 00/21/11 05/28/11 06 /04/11 06/11/11 06/18/11 06/25/11 07/02/11 OPERABLE: Injector AGI -08 (PTD #1930330) IA repressurization mitigated post SSSV ... Page 1 of 2 i Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator ©bp.com] Sent: Tuesday, October 26, 2010 5:49 PM To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; Engel, Harry R; Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: Chiwis, Robert; King, Whitney Subject: OPERABLE: Injector AGI -08 (PTD #1930330) IA repressurization mitigated post SSSV change out Attachments: AGI -08 TIO Plot 10- 26- 10.doc All, Injector AGI -08 (PTD #1930330) had its SSSV changed out on 10/20 due to slow IA repressurization. As seen on the TIO plot, the IA pressure has stabilized -500 psi since the SSSV packing was replaced. The well has been reclassified as Operable and may continue on injection. «AGI -08 TIO Plot 10- 26- 10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, October 14, 2010 3:00 PM To: 'Regg, James B (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; "Schwartz, Guy (DOA'; AK, D &C Well Services Operations Team Lead; Engel, Harry R; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)' Cc: Chiwis, Robert; AK, D &C Well Integrity Coordinator; King, Whitney Subject: UNDER EVALUATION: Injector AGI -08 (PTD #1930330) IA repressurization All, Injector AGI -08 (PTD #1930330) has recently shown an increase in IA pressure as seen on the attached TIO plot. The well has been reclassified as Under Evaluation. We plan to keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline rigs up to change out the SSSV. The plan forward is as follows: 1. DHD: Bleed and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. DHD: Monitor TIO plot for 10 days 7/5/2011 • S 10 -26 -2010 Well: AG1 -08 4 7 3.000 — Tbg —II— 2,000 -- OA OOA --A - -- 000A 1,000 — On !Illt 07/31/10 08 /14 /10 08/28/10 09/11/10 09/25/10 10 /09 /10 10/23/10 OPERABLE: AGI -08 (PTD #1930330) IA repressurization mitigated post SSSV changeout Page 1 of 2 • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Tuesday, November 10, 2009 2:21 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: Sinyangwe, Nathan Subject: OPERABLE: AGI -08 (PTD #1930330) IA repressurization mitigated post SSSV changeout Attachments: AGI- 08.pdf; AGI -08 TIO Plot 11- 10- 09.doc All Well AGI -08 (PTD #1930330) had a SSSV changed out on 10/27/09 after IA repressurization was noticed. The TIO plot attached shows that after a 12 day monitor the TxIA communication has been mitigated. The well has been reclassified as Operable, however, if the well needs to be bled in the future please contact Well Integrity. A wellbore schematic and TIO plot have been included for your reference. «AGI- 08.pdf» «AGI -08 TIO Plot 11- 10- 09.doc» 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: SU, ADW Well Integrity Engineer Sent: Tue .. October 20, 2009 7:31 AM To: 'Regg, James BOA) ; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @ala ..gov >'; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); G• = S1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Har •, NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; ' • angwe, Nathan Subject: UNDER EVALUATION - AGI -08 (P • 1930330) IA repressurizati• All, Well AGI -08 (PTD #1930330) has recent) own an increa : 'n IA pressure. DHD bled the IA pressure from 1720 psi to 400 psi on 10/18/09. A m. or the next day found t' - pressure had increased 110 psi overnight. A successful state witnessed MIT as conducted on 08/21 /09. Th- ell has been reclassified as Under Evaluation. We plan to keep P well on injection and perform further dia. •stics. The plan forward is a ollows: 1. DHD: Monitor BUR 2. Slickline: oubleshoot SSSV, control and balance lines 7/5/2011 0 • AGI -08 TIO Plot (PTD #1930330) 11 -10 -2009 1 1 4.000 - 1 3,000 - I 1 I # Tbg I —F-IA I 2,000 - —+t— OA 00A —4— 000A On 1,000 I Wirikiab 7 08/15/09 08/22/09 08/29/09 09/05/09 09/12/09 09/19/09 09/28/09 10/03/09 10/10/09 10/17/09 10/24/09 10/31/09 11/07/09 ■ I UNDER EVALUATION - AGI~(PTD #1930330) IA repressurization • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 06, 2009 4:00 PM ~~~~ )l~ ~, ~~~ ~ To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION - AGI-08 (PTD #1930330) IA repressurization Page 1 Qf~2' i ~~CIM lL Looks like the IA of this well experienced a significant pressure increase followed by several bleedlrepressure events beginning in mid-September. Notice of the suspect pressure communication/leakage should have occurred much earlier than 10/Z0. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 q. ~. ,~4r~, / t ~~+ I ` "~ ~j ': ~~ ~~Ll"l ~~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, October 20, 2009 7:31 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Sinyangwe, Nathan Subject: UNDER EVALUATION - AGI-08 (PTD #1930330) IA repressurization All, Well AGI-08 (PTD #1930330) has recentlv shown an increase in IA pressure. DHD bled the IA pressure from 1720 psi to 400 psi on 10/18/09. A monitor the next day found the pressure had increased 110 psi overnight. A successful state witnessed MITIA was conducted on 08/21/09. The well has been reclassified as Under Evaluation. We plan to keep the well on injection and perform fj urther diagnostics. ~ ~ ~ ~~~~~' i~~~~s'i~;~,~,~.~ The plan forward is as follows: r 1. DHD: Monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. Fullbore: AOGCC MITIA 4. WIC: Eval for AA A wellbore schematic and Tf0 plot have been included for your reference. «AGI-08.pdf» «AGI-08 TIO Plot.doc» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 11 /6/2009 PBU AGI-08 PTD #1930330 10-20-2009 TIO Plot , ~,II~I~I ~ I ~,ooU ~,0~[- --~ Tbg ~- IA ~- OA oo~ -~- OOOA - On ~ ~ 07l~5109 t18~~a1109 0°~O~r~Q9 08~1510~ 0$~2~l09 0~~~9l09 a91D5~09 09~12~09 0~119~09 09~~fil0~ 10l03l09 10l1010~ 1~!1 ~r~0~ TREE _ W~LHEAD= C ACTUATOR= BAKff2 C KB. ELEV = 49' BF. ELEV = KOP = 1153' Max An le = 53 11001' DatumMD= 12181' DatumND= 8800' SS 13-3l8" CSG, 68t~, K 55, ID= 12.415" I 13-3/8" CSG, 68#, L-80, ID= 12.415" H 3937~ ~ 7" TBG, 26#, NT-80-IPC, NSCC, .0383 bpf , ID=6.276" 10673' TOPOF 5-1/7' TBG 10673~ Minimum ID = 4.455" @ 10748' 5-9/2" OTIS XN NIPPLE 5-1/2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf , ID = 4.892' 10760' TOP OF 7" LNR 10775~ 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" ~--1 10935' PH~FORATION SUNMARY R~ LOG: AWS 05/03/93 ANGLEATTOP PfftF: 53 @ 11222' Note: Refer to Production DB fo r historical rf data SIZE SPF INTERVAL O NS Q4TE 3-3/8" 6 11222 - 1 1242 O 6/19/93 3-3/8" 6 1 1272 - 1 1292 O 6/19/93 3-3/8" 6 11378 - 11398 O 6/19/93 3-3/8" 6 11460 - 11480 O 6/19/93 3-3/8" 6 11528 - 11548 O 6/19/93 ~sT~ 11624' T' LNR, 29#, N-80, .0371 bpf, ID = 6.184" ~--~ 17646' L14TE REV BY CONMENTS Q4TE REV BY CONNIB~ITS 05/07/93 OPoGIf~IAL COMPLETI~N 01/29/01 S15-Nm FIf~lAL OS/22/01 RWKAK CORR~TIONS 03/18/03 AS/TLH ADD IPC/11-IREAD FOR TBG 04/11/03 JRC/KK CASING CORRECTION AG I~O V PC WITH NSCC THREAD. T CEMENTED. ALL TBGIS ~~ 17" CAMCO BAL-O SSSV NIP, ID= 5.937" ~ 10673~ ~-'~7" X 5-1 /2" XO, ID = 4.875" 10678' HANCHOR, ID =4.875" ~ 10680' 9-5/8" X 5-1 /2" BAK9~ FB-1 PKR, ID = 4.88" 10728' 5-1/2" PARK9~ SWS NlP, ID= 4.562" 10748~ - I5-1/2" OTIS XN NP, ID = 4.455" 10760' 5-1/2" WLEG, ID =4.892" 10763' ELND TT LOGGED 06/09/93 PRUDHOE BAY UrIIT W~L: AGI-08 PEFN/lff No: 1930330 API No: 50-029-22348-00 Sec. 36, T12N, R14E, 518.76' FEL & 297.59' FNL BP 6cploration (Alaska) ~ MEMORANDUM To: Jim Regg P.I. Supervisor ~~ ~`/ul~~ FROM: Jeff Jones Petroleum Inspector . State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-08 PRUDHOE BAY UNIT AGI-08 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: PRUDHOE BAY iJNIT AGI-08 API Well Number: 50-029-22348-00-00 Insp Num: mitJJ090906175632 Permit Number: 193-033-0 ~ Rel Insp Num: Inspector Name: JeffJones Inspection Date: g~21/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGt-os Type Inj. G TVD 7868 ~ IA 1 ~oso zzoo ~ 2iao zi~o P.T.D 1930330 TypeTest SPT Test psi I 1967 / ~A 880 ]000 960 ~ 940 Interval 4YRTST P~ P i Tubing 3390 3370 3370 3370 NOteS• 1.4 BBLS diesel pumped. . .~~. "L. ~.,. ,~ L. . - ... fi.t.. tJ ~ ;J .. . t~, ~~fx.n.~ c. Tuesday, September 08, 2009 Page 1 of 1 MEMORANDUM J State of Alaska ) Alaska Oil and Gas Conservation Commission TO: ~i~ S~:;r~iSOr ~tt 1/1 ~ùs DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-08 PRUDHOE BAY UNIT AGI-08 8rc: Inspector j fJ /J:)3 ~1J \J FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. 8uprv ~JB2- Comm Well Name: PRUDHOE BAY UNIT AGI-08 Insp Num: mitJCr050825125949 Rei Insp Num API Well Number 50-029-22348-00-00 Permit Number: 193-033-0 Inspector Name: John Crisp Inspection Date: 8/23/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _~ellJ ACji~Ô8__ ~~pe ì~j. _.l___~l!VD·--]_~ :.~~~-._ .!A·-¡ __.~20'·___..~~:~~80'-=-2ï7o_..J-~~~__~_n__ _~~~~_~~:9JO:;T~y~eTe;~:PTI ~e:t psi i ~: --. !U~~g__ 3~:-±:JI5:~T J~O _J J~:o_-:-=--__m Notes 3 bbls pumped for test. ~:.)Cl~J!\' Nt~~J" n (,/:'\; t .... {'< [r. [II: .Y_ l J .,~ Tuesday, August 30,2005 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~\q~' DATE: May 27, 2001 Commissioner SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPX P.I. Supervisor:J'~ ' AGI Pad AGI-06, 07, 08, 09, 10 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well] AGI-06 I Typelnj.I G I T.V.D. 17880 J Tubing 13500 I 3500 13500 I 3500 J lntervalI 4 P.T.D.I 193-009 ITypetestl P ITestpsil 1970 I CasingI 800 I 2.400 I 2100 I 20901 PIE I P Notes: WellI AGI-07 I Typelnj. I G I T.V.D. 17840 I Tubing I 3400 13400 13400 I~,00 I lntervall 4 P.T.D.I 493-027 ITypetestl P ITestpsil 4960 I Casingl 850 I 2430 I 2130 I 2130 I P/F I P Notes: I^G,-O~ I Typ~,.j.I ~ I T.V.D. I7S~ I Tubi.gl~S00 J~S00 13~00 I~00 I,nterva, I 4 P.T.D.I 193-033 ITypetestl P ITostpsil 1965 ICasingI 890 I 21201 21201 21101 P/F I P Notes: ve,,I I oo P.T.D.I 193-035 TypetestI P ITestpsil 1972 I CasingI 4420I 2100I 21001 2100I P/F I -P Notes: WellI AGI-10 I Typelnj. I G )T.V.D. I 7824 ['l:ubing I 3600 I 3600 I 3600 I 3600 I lntervall 4 P.T.D.I 193-039 Type testI P I Testpsil 1956 I CasingI 700 I 21001 20801 2080 I PIE I -P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, May 27, 2001: I traveled to BPX~s AGI Pad to witness 4 year MITs on gas injection wells AGI-06, 07, 08, 09, and 10. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MIT's. The test data above indicates these wells are suitable for continued injection. Summary.: I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: 0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-06,07,08,09,10 5-27-01 JJ 6/9/01 ON OR BEFORE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate_ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other _X (Prod->H20 Inj Conv) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 65.7 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic~ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1255' SNL, 1549' EWL, SEC. 8, T10N, R15E, UM 01-09A At top of productive interval 9. Permit number / approval number 1779' SNL, 3119' EWL, SEC. 9, T1 ON, R15E, UM 94-33 / 399-114 signed 7/12/1999 At effective depth 10. APl number 50-029-20164-01 At total depth 11. Field / Pool 1953' SNL, 3351' EWL, SEC. 9, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 12701 feet Plugs (measured) Tagged PBTD @ 12275' MD (10/30/99) true vertical 9175 feet Effective depth: measured 12275 feet Junk(measured) ORIGINAL true vertical 8807 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 100' 20" 1790 Sx CS II 100' 100' Surface 2597' 13-3/8" 8100 Sx AS II 2663' 2663' Production 11027' 9-5/8" 1500 Sx G & 125 Sx PF II 10260' 9115' Liner 1778' 7" 322 Sx Class G 12701' 9172' Perforation depth: measured 12164' - 12184'; 12220' - 12228'; (12358' - 12388' & 12559' - 12569' isolated under cement/sand cap). true vertical 8713' - 8730'; 8760' - 8767'; (8878' - 8903' & 9051' - 9059' isolated under cement/sand cap). Tubing (size, grade, and measured depth)4-1/2", 12.64f, 13 CR Tubing @ 11865' MD.RECEIVED Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 11816' MD; Camco TRDP-4A SCSSSV @ 2206' MD. NOV 19 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) A~~! & Gas Cos Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Shut in) - - Subsequent to operation - (Shut in) - 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title AAI Wellwork Design & Optimization Supervisor Date Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01-09A~ DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WATER INJECTION & PERFORATING OPERATIONS Date Event Summary 10/19/1999: 10/20/1999: 10/24/1999: 10/27/1999: 10/29-30/1999: RIH & tagged PBTD @ 12640' ELM. Circulated in 7300 lbs of a gelled 20x40 mesh River Sand slurry to isolate the perforations listed below: 12358' - 12388' MD (Zone 4/3) Reference Log: BHCA 3/17/1994. 12559' - 12569' MD (Zone 2) Final TOS tagged @ 12277' CTM. RIH & tagged TOS @ 12291' ELM. RIH w/dump bailer & dumped on top of the sand cap a total of 31 gallons of Class G Cement f/12304' - 12297' SLM. This further isolated the above mentioned perfs. RIH & tagged TOC @ 12272' ELM. MIRU. PT'd equip. RIH w/perf guns & shot 48' of add perforations f/: 12164' - 12184' MD (Zone 4) Reference Log: BHCA 3/17/1994. 12220' - 12228' MD (Zone 4) Used 3-3/8" carriers and all shots @ 6 SPF, random orientation, 60° phasing, & at balanced press. Tagged PBTD @ 12275' MD. POOH w/guns. ASF. RD. Well is presently shut in, awaiting surface modifications for water injection. It is expected to be injecting produced water by year end. RECEIVED 1 9 1999 F' E R M I T D ~ -'- '~ 93 -033 Di::'R/GR 93 .... 033 DPR/GR 8 3 --' 0 3 3 :3 F:/' C C: L. 93 .... 033 PERF' o.~ ....03 :' SI?.,T/GR/nCL q::,' ...... ~.;- , /._.,,L:~. RI..N 4: :2&5"MD d.~r~. 'RUN 4: 2&5~'TVD ~ R UN i ~ 5" ~z ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 4-17-93 o~- 10-7-93 oa 3-31-93 11/18-3o/92 11-23-92 4-15-93 1-29-93 2-13-93 4-28-93 3-6-93 5-8-93 3-28-93 MWD: DPR/GR DI /AC/C /GR MWD: DPR/GR MWD '~?~-t t-~%0 MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR. MWD: DPR/GR MWD: DPR/GR ~ MWD: DPR/GR Job# 1209 Job#6055 Job# 1202 Job#AI~M~ 11ZS Job#1152 Job# 1168-450 Job# 1172-450 Job# 1181 Job# 1185-450 Job# 1190 Job# 1195-450 Job# 1205-450 Please sign and return the attached copy as receipt of data. RECEIVED BY__~_~ Have A Nice Day! ~sR~O~3~_~..ff Sonya Wallace ATO- 1529 Sperry B~ "/q~-q~5 3q p__~--~ o~0 ltl-II %~-o~-Itol~ ~ q~7z~b-u~elq~ BI~ '75oq--\o0_51 # BOB OCANAS (OH/GCT) # EXXON # BPX # STATE OF ALASKA The correct APl# for 3-18A is 50-029-20421-01. The correct APl# for 9-28A is 50-029-21292-01. The correct API# for AGI-1 is 50-029-22307-00. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~wlvllSSlON WELL COMPLETION OR REOOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E~ Aoex Gas Iniector 2. Name of Operator 7. Permit Number 3. Address . P. O. Box 196612, Anchorace, Alaska 99519-6612 .~~ ! ~ . 4. Location of well at surface~ Oi_!~,,~;:-'L?T!O~,i i Rr~/.~/4/ ....................... , ,-_ .,..,,.,,~,,~_. 9. Unit or Lea§e N~.~ e f ~"O¢~flOl~t Prudhoe Bay U 2410'NSL, 2537' WEL, SEC. 36, T12N, R14E' ~?" ';/ ¢ ; ~IFfED i 10. Well Number At Top Producing Interval ~} -"~'~- -/-~'-~.--~-- ii ' ~= .-. ,..~ ·, .... ~ AGI-8 460' SNL, 3846' EWL, SEC. 31, T12N, R15E ~ ;,".gr. tF,;-u i./~"~ ........ ; 11. Field and Pool At Total Depth ;' .... ' ......... -~ ' Prudhoe Bay Field/Prudhoe Bay Pool 292' SNL, 4340' EWL, SEC. 31, T12N, R15E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 49.5' ADL 34628 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth. if offshore 116. No. of Completions 2/24/93 5/2/93 6/19/93I N/A feet MSLI One 17. TotalDepth(MD+TVD) 18. PlugBackDepth(MD+TVD) 19. Directional Survey 120. DepthwhoreSSSVset 121iThickness of Permafrost 11648'MD/8463' TVD 11624'MD/8449' TVD YES [] NO [] 2285' feet MD 900'(Approx.) 22. Type Electric or Other Logs Run MWD/Gyro 23. CASING, LINER AND CEMENTING RECORD SE'I-TING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 30' 106' 30" 11 ,yds Arcticset 13-3/8" 68# K55/L-80 36' 3937' 16" 2605 cufl "E'Y460 cu ft "G" 9-5/8" 47# NTS80 37' 10935' 12-1/4" 573 cufl Class "G" 7" 29# NTS80 10757' 11646' 8-1/2" Uncemented 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/ Gun Diameter 3-3/8" 6 spf 7" x 5-1/2" 10760' 10680' MD TVD 11222'-11242' 8201'-8213' NT-80/L-80 11272L 11292' 8232'-8244' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11378'- 11398' 8297'-8309' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11460'-11480' 8348'-8360' 11582'-11548' 8423'-8402' 27. PRODUCTION TEST Date Firsl Production Method of Operation (Flowing, gas lift, etc.) 9/20/93 Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED,.~ ©IL-BBL GAS-MCF WATER-BBL :::)IL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED 0CT -- 1 t99~ Alaska 0il & Gas Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ~-..., ,MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10985' 8055' Base Sadlerochit 11582' 8423' 31. LIST OF ATTACHMENTS 32. I hereby cerlify lhat 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 Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (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. R E C'E IV E .'~ Item 28: If no cores taken, indicate "none". Form 10-407 OCT --! 1995 Alaska Oil & Gas Cons. Uummissio': Anchorage BP~iiAAI SHARED SERVICE WELL: AGI-8 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 02/25/93 11:00 SPUD: 02/25/93 10:00 RELEASE: 03/08/93 02:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 02/26/93 ( 1) TD: 328'( 328) 02/27/93 ( 2) TD: 1964' (1636) RIH. MW: 8.7 VIS:195 MOVE RIG. RIG ACCEPTED @ 11:00 HRS, 2/25/93. M/U DIVERTER. P/U BHA %1. SPUD WELL @ 22:00 HRS, 2/25/93. DRLG F/ 116'-328' DRLG. DRLG TO 1964' MW: 9.1 VIS:160 02/28/93 (3) TD: 3950'(1986) 03/01/93 ( 4) TD: 3950' ( 0) 03/02/93 (5) TD: 5380'(1430) 03/03/93 (6) TD: 7023'(1643) 03/04/93 (7) TD: 8340'(1317) CBU. DRLG TO 2151' CIRC. MW: 9.3 VIS:ll5 CBU. POOH. RIH. DRLG F/ 2151'-3950'. N/U BOPE. MW: 9.2 VIS:100 CBU. SHORT TRIP TO 2115'. CIRC. POOH. RIH W/ 13-3/8" CSG. CIRC. PUMP 100 BBLS WATER, 464 BBLS LEAD CMT, 82 BBLS TAIL CMT. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. N/U BOPE. DRLG. MW: 9.0 VIS: 33 N/U BOPE. TEST BOPE. L/D BHA. RIH W/ BHA. TAG FC @ 3859'. CIRC. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. LOT (12.6 PPG EMW) . DRLG F/ 3960'-5055' CIRC. SHORT TRIP TO 3937' DRLG F/ 5055'-5380' POOH. MW: 9.3 VIS: 36 DRLG TO 6180'. CIRC. 15 STDS SHORT TRIP. WASH 90' TO BTM. DRLG TO 7023' CIRC. POOH. DRLG. MW: 9.7 VIS: 40 POOH. CHANGE MTR. RIH. DRLG TO 8340'. 03/05/93 (8) TD: 8830' ( 490) 03/06/93 ( 9) TD:10211' (1381) DRLG. DRLG TO 8770' 8830' MW: 9.7 VIS: 44 CIRC. POOH. CHANGE BIT. RIH. DRLG TO DRLG. DRLG F/ 8830'-10211' MW: 9.9 VIS: 42 Alaska Oil & ~-:~ .............. Ancho:'a'Je WELL : AGI-8 OPERATION: RIG : AUDI 2 PAGE: 2 03/07/93 (10) TD:10942' ( 731) 03/08/93 (11) TD:10942' ( 0) 03/09/93 (12) TD:10942' ( 0) POOH. MW: 9.9 VIS: 44 DRLG. SHORT TRIP. DRLG TO 10942' CIRC. 25 STDS SHORT TRIP. CBU. POOH. TEST PACKOFF. MW: 8.5 VIS: 0 POOH. L/D BHA. RIH W/ 9-5/8" CSG. CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 102 BBLLS (500 SX) CMT. DISP W/ SEAWATER. BUMP PLUGS W/ 2500 PSI. R/D HOWCO. INJECT 275 BBLS MUD DN ANNULUS. INSTALL & TEST PACKOFF. RIG RELEASED. MW: 8.5 VIS: 0 DISP TOP 2000' W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. RIG ACCEPTED @ 14:00 HRS, 3/8/93. SIGNATURE: (drilling superintendent) DATE: Ancl]ora,qe ~7,~7/_~L_J A Baker Hughes company 6324/6116 ¢¢ielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY APEX GAS INJECTION AGI-8 APEX GAS INJECTION PAD Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats' · MWD Survey Listing · Composite 100' MD Interpolated · Composite 100' TVD Interpolated RECEIVED MAR 1 7 !J99;~ Alaska. Oil & Gas Cons. 60mmissi0~ Anchorage Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : : Mar. 7, 1993 : : Paul Smith This survey is correct to the best of my knowledge and is supported by actual field data. .... ./~...~~.....~~~ ..... COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco .lient : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION AGI-8 Location : Apex Gas Injection Pad : North Slope, Alaska : Date Mar. 7, 1993 Filename : ll90TAK No Interpolation Plane of Vertical Section : 69.4° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-8 +0° 0' 0'' (T) Eastman Teleco ~lient Well Name Location : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 Date Mar. Filename No Interpolation of 2 7, 1993 : ll90TAK MD ft 0 4OO 598 779 966 CkL INC DIR TVD VS LAT DEP ft deg deg ft ft ft ft 0 0.0 0.0 0 0 0 0 400 0.2 354.6 400 0 1 -0 198 1.8 91.7 598 3 1 3 181 5.1 75.5 779 14 3 14 187 8.8 72.3 964 36 9 35 D'LEG °/100 0.0 0.0 0.9 1.9 2.0 BU I LD °/100 0.0 0.1 0.8 1.8 2.0 TURN °/100 0.0 -1.3 49.0 -9.0 -1.7 1153 1340 1529 1716 1904 187 9.5 73.7 1149 187 11.4 67.4 1333 189 15.7 62.5 1516 187 17.7 62.8 1696 188 21.3 68.8 1873 66 18 64 0.4 0.4 100 29 96 1.2 1.0 144 48 136 2.4 2.3 197 73 183 1.1 1.1 260 99 241 2.2 1.9 0.7 -3.4 -2.6 0.2 3.2 2091 2277 2465 2652 2839 187 26.4 68.1 2044 186 27.9 66.7 2209 188 29.9 68.5 2374 187 32.7 69.5 2534 187 35.0 67.1 2689 335 126 311 2 420 159 389 0 511 194 473 1 608 228 564 1 712 267 661 1 .7 .9 .2 .5 .4 .7 .8 .1 .5 .2 -0.4 -0.8 1.0 0.5 -1.3 3025 3211 3399 3580 3774 186 38.1 68.5 2838 186 41.2 69.5 2981 188 45.3 70.6 3118 181 45.2 70.6 3246 194 48.9 69.5 3378 823 309 763 1 942 351 874 1 1070 395 995 2 1199 438 1116 0 1341 486 1250 2 .7 .7 .2 .1 .0 1 1 2 -0 1 .7 .7 .2 .1 .9 0.8 0.5 0.6 0.0 -0.6 3890 4144 4426 4708 4990 116 51.1 69.5 3453 254 52.0 71.6 3610 282 51.4 70.6 3785 282 50.1 69.2 3964 282 48.2 66.7 4148 1430 517 1333 1629 584 1521 1850 655 1730 2068 730 1935 2281 8-10 2133 .9 .7 .4 .6 .0 1 0 -0 -0 -0 .9 .4 .2 .5 .7 -0.0 0.8 -0.4 -0.5 -0.9 5271 5551 5832 6115 6395 281 47.2 66.4 4337 280 48.3 65.7 4526 281 46.4 67.4 4716 283 48.3 70.6 4908 280 50.4 69.5 5090 2489 893 2323 2696 977 2513 2902 1059 2702 3110 1134 2897 3323 1206 3096 .4 .4 .8 .1 .8 -0 0 -0 0 0 .4 .4 .7 .7 .7 -0.1 -0.2 0.6 1.1 -0.4 6676 6958 7237 7518 7797 281 49.0 68.5 5272 282 50.2 67.8 5455 279 49.9 71.6 5634 281 49.1 72.3 5816 279 49.5 69.9 5998 3537 1283 3296 3752 1363 3496 3966 1437 3696 4179 1504 3899 4390 1572 4099 0.6 0.5 1.0 0.3 0.7 -0 0 -0 -0 0 .5 .4 .1 .3 .1 -0.4 -0.2 1.4 0.2 -0.9 8078 8359 8640 8927 9216 281 49.0 67.8 6182 281 48.8 67.8 6366 281 48.7 68.1 6552 287 48.4 69.5 6742 289 49.3 69.9 6932 4603 1649 4298 0.6 4815 1729 4494 0.1 5026 1808 4690 0.1 5241 1886 4890 0.4 5459 1961 5094 0.3 -0.2 -0.1 -0.0 -0.1 0.3 -0.7 0.0 0.1 0.5 0.1 ,±ient Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : MD CkL INC DIR TVD VS ft ft deg deg ft ft 9494 278 49.7 69.5 7112 5670 9782 288 50.3 70.2 7297 5891 10070 288 50.7 68.5 7481 6113 10338 268 51.4 69.5 7649 6321 10619 281 51.9 69.9 7823 6542 10870 251 52.2 70.6 7978 6740 Page 2 of 2 Date Mar. 7, 1993 Filename : ll90TAK No Interpolation LAT DEP D ' LEG BUILD TURN ft ft °/100 °/100 °/100 2035 5293 0.2 0.1 -0.1 2111 5500 0.3 0.2 0.2 2189 5708 0.5 0.1 -0.6 2264 5902 0.4 0.3 0.4 2340 6109 0.2 0.2 0.1 2407 6295 0.3 0.1 0.3 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6740 ft 69.1° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Jlient : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION AGI-8 Location : Apex Gas Injection Pad : North Slope, Alaska : Date Mar. 7, 1993 Filename : ll90TAK Interpolated 100 ft of MD Plane of Vertical Section : 69.4° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-8 +0 ° 0' 0' ' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 Date Mar. Filename Interpolated of 3 7, 1993 : ll90TAK 100 ft of MD MD ft 0 100 200 3OO 4OO 5OO 6OO 700 8OO 900 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.1 88.7 100 100 0.1 177.3 200 100 0.2 266.0 300 100 0.2 354.6 400 100 1.0 221.8 500 100 1.8 91.5 600 100 3.7 82.6 700 100 5.5 75.1 799 100 7.5 73.4 899 1000 100 8.9 72.6 998 1100 100 9.3 73.3 1097 1200 100 10.0 72.1 1195 1300 100 11.0 68.7 1293 1400 100 12.8 65.8 1391 1500 100 15.0 63.3 1488 1600 100 16.5 62.6 1584 1700 100 17.5 62.8 1680 1800 100 19.3 65.5 1775 1900 100 21.2 68.7 1869 2000 100 23.9 68.4 1961 2100 100 26.5 68.0 2052 2200 100 27.3 67.3 2141 2300 100 28.1 66.9 2229 2400 100 29.2 67.9 2317 2500 100 30.4 68.7 2404 2600 100 31.9 69.2 2489 2700 100 33.3 68.9 2573 2800 100 34.5 67.6 2656 2900 100 36.0 67.6 2738 3000 100 37.7 68.3 2818 3100 100 39.3 68.9 2896 3200 100 41.0 69.4 2973 3300 100 43.1 70.0 3046 3400 100 45.3 70.6 3119 3500 100 45.2 70.6 3189 3600 100 45.6 70.5 3259 3700 100 47.5 69.9 3328 3800 100 49.4 69.5 3395 3900 100 51.1 69.6 3459 VS ft 0 0 0 0 0 2 3 9 16 28 42 58 75 93 114 137 164 193 225 259 299 340 385 431 48O 529 581 635 691 749 LAT ft 0 0 0 1 1 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.0 0.1 88.7 -0 0.1 0.1 88.7 -0 0.2 0.1 88.6 -0 0.2 0.1 88.7 1 1 1.2 1 3 2.6 2 9 1.9 4 16 1.9 7 28 2.0 0.8 -99.0 0.8 -99.0 1.8 -9.0 1.9 -7.4 2.0 -1.7 1142 1214 1287 1361 1438 808 303 749 1.7 1.7 0.8 871 326 808 1.7 1.7 0.6 935 349 867 1.7 1.7 0.5 1003 372 931 2.2 2.1 0.6 1071 3.95 996 2.2 2.2 0.6 113 277 2.7 2.7 -0.2 128 315 2.6 2.6 -0.4 145 357 0.9 0.8 -0.8 163 400 0.9 0.9 -0.4 182 444 1.2 1.1 1.0 200 490 1.3 1.2 0.8 219 539 1.5 1.5 0.5 238 589 1.4 1.4 -0.3 259 640 1.4 1.2 -1.3 281 694 1.5 1.5 -0.0 419 1063 0.1 -0.1 0.0 443 1130 0.3 0.3 -0.1 468 1199 2.0 1.9 -0.6 493 1268 1.9 1.9 -0.4 520 1340 1.7 1.7 0.1 · 46 129 2.4 2.3 -2.6 58 154 1.4 1.4 -0.6 71 179 1.1 1.1 0.2 84 209 2.0 1.8 2.7 98 239 2.2 1.9 3.2 11 40 1.4 1.4 -0.9 16 56 0.4 0.4 0.7 21 72 0.7 0.7 -1.2 27 89 1.2 1.0 -3.4 35 108 1.9 1.8 -2.9 client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 Date Mar. Filename Interpolated of 3 7, 1993 : ll90TAK 100 ft of MD MD ft 4000 4100 4200 4300 4400 45OO 4600 4700 4800 4900 5000 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6000 6100 6200 6300 6400 65OO 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD ft deg deg ft 100 51.5 70.4 3521 100 51.8 71.2 3583 100 51.9 71.4 3645 100 51.7 71.0 3707 100 51.5 70.7 3769 100 51.1 70.2 3832 100 50.6 69.7 3895 100 50.1 69.2 3959 100 49.5 68.4 4024 100 48.8 67.5 4089 100 48.2 66.7 4155 100 47.8 66.6 4222 100 47.5 66.5 4289 100 47.3 66.3 4357 100 47.7 66.1 4424 100 48.1 65.8 4491 100 48.0 66.0 4559 100 47.3 66.6 4626 100 46.6 67.2 4694 100 46.9 68.2 4762 100 47.5 69.3 4830 100 48.2 70.4 4897 100 48.9 70.3 4963 100 49.7 69.9 5028 100 50.4 69.5 5093 100 49.9 69.1 5158 100 49.4 68.8 5223 100 49.1 68.4 5287 100 49.5 68.2 5352 100 50.0 67.9 5417 100 50.2 68.4 5482 100 50.0 69.7 5546 100 49.9 71.1 5610 100 49.7 71.8 5675 100 49.4 72.0 5740 100 49.2 72.3 5805 100 49.2 71.6 5870 100 49.4 70.7 5935 100 49.5 69.9 6000 100 49.3 69.1 6065 VS ft 1516 1594 1673 1751 1829 LAT DEP D'LEG ft ft °/100 546 1414 0.7 572 1488 0.7 598 1562 0.1 623 1636 0.4 649 1711 0.3 1907 675 1784 0.5 1985 702 1856 0.6 2062 728 1929 0.6 2138 756 1999 0.9 2213 7'85 2070 1.0 2289 813 2139 0.9 2363 843 2207 0.4 2437 872 2275 0.4 2510 902 2343 0.2 2584 932 2411 0.4 2658 2732 2805 2879 2952 BUILD TURN o o /100 /100 0.4 0.8 0.4 0.8 0.0 0.2 -0.2 -0.4 -0.2 -0.4 -0.4 -0.5 -0.5 -0.5 -0.5 -0.5 -0.7 -0.9 -0.7 -0.9 -0.6 -0.8 -0.4 -0.1 -0.4 -0.1 -0.1 -0.1 0.4 -0.2 962 2478 0.4 0.4 -0.2 991 2546 0.2 -0.1 0.2 1021 2613 0.8 -0.7 0.6 1050 2681 0.8 -0.7 0.6 1077 2749 0.7 0.2 1.0 3026 1104 2818 1.1 3099 1130 2886 1.1 3175 1156 2957 0.7 3251 1182 3029 0.8 3327 1208 3100 0.8 3403 1235 3171 0.6 3479 1262 3242 0.6 3555 12'90 3313 0.4 3631 1318 3384 0.5 3708 1347 3455 0.5 0.7 1.1 0.7 1.1 0.7 -0.2 0.7 -0.4 0.7 -0.4 3784 3861 3937 4013 4089 -0.5 -0.4 -0.5 -0.4 -0.3 -0.3 0.4 -0.2 0.4 -0.2 1374 3526 0.4 0.2 0.4 1401 3598 1.1 -0.1 1.4 1427 3670 1.0 -0.1 1.4 1452 3742 0.6 -0.2 0.7 1476 3814 0.3 -0.3 0.2 4165 1499 3886 0.3 4241 1524 3958 0.5 4317 1548 4030 0.7 4393 1573 4102 0.7 4468 1600 4172 0.6 -0.3 0.2 0.1 -0.7 0.1 -0.9 0.1 -0.9 -0.2 -0.7 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 3 Date Mar. Filename Interpolated of 3 7, 1993 : ll90TAK 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 49.1 68.4 6131 8100 100 49.0 67.8 6196 8200 100 48.9 67.8 6262 8300 100 48.8 67.8 6328 8400 100 48.8 67.8 6393 8500 100 48.7 68.0 6459 8600 100 48.7 68.1 6525 8700 100 48.6 68.4 6591 8800 100 48.5 68.9 6658 8900 100 48.4 69.4 6724 9000 100 48.6 69.6 6790 9100 100 48.9 69.7 6855 9200 100 49.3 69.9 6921 9300 100 49.4 69.8 6986 9400 100 49.6 69.6 7051 9500 100 49.7 69.5 7116 9600 100 49.9 69.8 7180 9700 100 50.1 70.0 7245 9800 100 50.3 70.1 7309 9900 100 50.5 69.5 7373 10000 100 50.6 68.9 7436 10100 100 50.8 68.6 7500 10200 100 51.0 69.0 7562 10300 100 51.3 69.4 7625 10400 100 51.5 69.6 7688 10500 100 51.7 69.7 7750 10600 100 51.9 69.9 7812 10700 100 52.0 70.1 7873 10800 100 52.1 70.4 7935 10870 70 52.2 70.6 7978 VS LAT DEP D'LEG ft ft ft °/100 4544 1628 4243 0.6 4620 1655 4313 0.5 4695 16'84 4383 0.1 4770 1712 4453 0.1 4846 1740 4523 0.1 4921 4996 5071 5146 5221 5296 5371 5447 5523 5599 BUILD TURN o °/100 /100 -0.2 -0.7 -0.2 -0.6 -0.1 0.0 -0.1 0.0 -0.1 0.0 1769 4592 0.1 -0.0 0.1 1797 4662 0.1 -0.0 0.1 1824 4732 0.3 -0.1 0.3 1852 4802 0.4 -0.1 0.5 1879 4872 0.4 -0.1 0.5 1905 4942 0.3 0.2 0.2 1931 5013 0.3 0.3 0.1 1957 5083 0.3 0.3 0.1 1984 5154 0.2 0.2 -0.1 2010 5226 0.2 0.1 -0.1 5675 2036 5297 0.2 5751 2063 5369 0.3 5828 2089 5441 0.3 5905 2116 5513 0.2 5982 2143 5585 0.5 6059 6136 6214 6292 6370 0.1 -0.1 0.2 0.2 0.2 0.2 0.2 0.1 0.1 -0.6 21'70 5657 0.5 0.1 -0.6 2198 5730 0.3 0.2 -0.3 2225 5802 0.4 0.3 0.4 2253 5875 0.4 0.3 0.4 2281 5948 0.3 0.2 0.2 6448 6527 6606 6685 6740 2308 6022 0.2 0.2 0.1 2335 6095 0.2 0.2 0.1 2362 6169 0.2 0.1 0.3 2389 6243 0.3 0.1 0.3 2407 6295 0.4 0.2 0.5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6740 ft 69.1° TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION AGI-8 Location : Apex Gas Injection Pad : North Slope, Alaska : Date Mar. 7, 1993 Filename : ll90TAK Interpolated 100 ft of TVD Plane of Vertical Section : 69.4° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH D~pth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-8 +0° 0' 0'' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 Date Mar. Filename Interpolated of 3 7, 1993 : ll90TAK 100 ft of TVD MD ft 0 100 200 3OO 400 5OO 6OO 700 801 901 1002 1104 1205 1307 1409 1512 1616 1721 1827 1934 2043 2154 2267 2381 2496 2613 2732 2853 2977 3105 3236 3374 3515 3660 3808 3966 4127 4288 4449 4607 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.1 88.7 100 100 0.1 177.3 200 100 0.2 266.0 300 100 0.2 354.6 400 100 1.0 221.8 500 100 1.8 91.5 600 100 3.7 82.6 700 100 5.5 75.1 800 101 7.5 73.4 900 101 8.9 72.6 1000 101 9.3 73.3 1100 101 10.0 71.9 1200 102 11.1 68.5 1300 102 13.0 65.6 1400 103 15.3 62.9 1500 104 16.6 62.6 1600 104 17.8 63.0 1700 106 19.8 66.3 1800 107 22.1 68.7 1900 109 25.1 68.3 2000 111 26.9 67.6 2100 112 27.8 66.8 2200 114 29.0 67.7 2300 115 30.4 68.7 2400 117 32.1 69.3 2500 119 33.7 68.5 2600 121 35.2 67.2 2700 124 37.3 68.1 2800 128 39.4 68.9 2900 131 41.8 69.6 3000 137 44.7 70.5 3100 141 45.2 70.6 3200 145 46.7 70.1 3300 149 49.6 69.5 3400 158 51.4 70.1 3500 161 51.9 71.5 3600 161 51.7 71.1 3700 161 51.3 70.5 3800 158 50.6 69.7 3900 VS ft 0 0 0 0 0 2 3 9 16 29 LAT ft 0 0 0 1 1 DEP D ' LEG BUILD TURN o o o ft /100 /100 /100 0 0.0 0.0 0.0 -0 0.0 0.0 88.7 -0 0.1 0.0 88.7 -0 0.2 0.1 88.6 -0 0.2 0.1 88.6 1 1 1.2 1 3 2.6 2 9 1.9 4 16 1.9 7 28 2.0 42 11 41 1.4 58 16 56 0.4 75 21 73 0.7 94 27 90 1.2 116 36 110 2.0 0.8 -99.0 0.8 -99.0 1.8 -9.0 1.9 -7.4 2.0 -1.7 140 169 199 234 272 1.4 -0.8 O.4 0.7 0.7 -1.4 1.0 -3.4 1.9 -2.8 47 132 2.4 2.3 -2.6 60 158 1.3 1.3 -0.3 74 185 1.1 1.1 0.3 88 217 2.2 1.9 3.2 103 252 2.3 2.1 2.2 316 119 293 2.7 364 137 338 1.7 416 157 385 0.9 470 178 436 1.1 527 199 488 1.3 2.7 -0.4 1.6 -0.6 0.8 -0.8 1.0 0.8 1.2 0.8 588 2'21 545 1.5 1.5 0.5 653 245 605 1.4 1.3 -0.7 721 270 668 1.4 1.3 -1.0 795 298 737 1.7 1.7 0.8 874 327 811 1.7 1.7 0.6 959 1053 1153 1257 1367 890 1.8 1.8 0.5 979 2.2 2.2 0.6 1073 0.4 0.3 0.1 1171 1.0 1.0 -0.3 1274 1.9 1.9 -0.4 1389 1.2 1508 0.7 1628 0.2 1747 0.4 1862 0.6 1490 1615 1742 1868 1990 357 389 422 458 495 537 579 620 661 704 1.2 0.4 0.4 0.8 -0.2 -0.2 -0.2 -0.4 -0.5 -0.5 Eastman Teleco Client Well Name Location : Prudhoe Bay Drilling Group : APEX GAS INJECTION AGI-8 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 Date Mar. Filename Interpolated of 3 7, 1993 : ll90TAK 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 4764 156 49.7 68.7 4000 4916 153 48.7 67.4 4100 5067 151 47.9 66.6 4200 5216 149 47.4 66.5 4300 5364 149 47.6 66.2 4400 VS ft 2110 2226 2338 2448 2558 LAT ft 746 789 833 877 921 DEP D ' LEG ft °/100 1974 0.7 2081 1.0 2185 0.6 2286 0.4 2386 0.2 BU I LD TURN o o /100 /100 -0.5 -0.6 -0.7 -0.9 -0.5 -0.5 -0.4 -0.1 0.1 -0.2 5513 149 48.2 65.8 4500 5661 148 47.6 66.4 4600 5809 148 46.6 67.3 4700 5956 148 47.2 68.8 4800 6104 148 48.2 70.5 4900 2668 2777 2885 2994 3102 966 1009 1053 1092 1131 2487 0.4 0.4 -0.2 2587 0.5 -0.4 0.4 2687 0.8 -0.7 0.6 2788 0.9 0.5 1.0 2889 1.1 0.7 1.1 6257 153 49.4 70.0 5000 6410 154 50.3 69.4 5100 6565 155 49.6 68.9 5200 6720 155 49.2 68.4 5300 6874 154 49.8 68.0 5400 3218 3334 3452 3570 3688 1171 1211 1253 1296 1339 2998 0.8 3107 0.7 3217 0.6 3327 0.3 3436 0.5 0.7 -0.3 0.6 -0.4 -0.5 -0.4 -0.2 -0.3 0.4 -0.2 7029 155 50.1 68.8 5500 7184 156 50.0 70.9 5600 7339 155 49.6 71.9 5700 7493 154 49.2 72.2 5800 7646 153 49.3 71.2 5900 3806 3925 4043 4160 4276 1382 1423 1461 1498 15'35 3547 0.4 0.2 0.5 3658 1.0 -0.1 1.4 3770 0.5 -0.2 0.6 3881 0.3 -0.3 0.2 3991 0.5 0.1 -0.7 7800 153 49.5 69.9 6000 7953 153 49.2 68.7 6100 8106 153 49.0 67.8 6200 8258 152 48.9 67.8 6300 8410 152 48.8 67.9 6400 4393 4509 4624 4739 4853 1573 1615 1657 1700 1743 4101 0.7 4210 0.6 4317 0.5 4424 0.1 4530 0.1 0.1 -0.9 -0.2 -0.7 -0.2 -0.6 -0.1 0.0 -0.1 0.0 8562 152 48.7 68.0 6500 8713 151 48.6 68.5 6600 8864 151 48.5 69.2 6700 9016 152 48.7 69.6 6800 9168 152 49.1 69.8 6900 4967 5081 5194 5308 5422 1786 1828 1869 1909 1949 4635 0. 1 -0.0 0. 1 4741 0.2 -0.1 0.3 4846 0.4 -0.1 0.5 4953 0.3 0.1 0.3 5060 0.3 0.3 0.1 9321 153 49.5 69.7 7000 9475 154 49.7 69.5 7100 9630 155 50.0 69.8 7200 9786 156 50.3 70.2 7300 9943 157 50.5 69.2 7400 5539 5656 5775 5894 6015 1989 2030 2071 2112 2155 5169 0.2 5279 0.2 5391 0.3 5503 0.3 5616 0.5 0.2 -0.1 0.1 -0.1 0.2 0.2 0.2 0.2 0.1 -0.6 10101 158 50.8 68.6 7500 10260 159 51.2 69.2 7600 10420 160 51.5 69.6 7700 10581 161 51.8 69.8 7800 10743 162 52.0 70.2 7900 6137 6261 6386 6512 6640 2198 2242 2286 2330 2373 5730 0.4 0.2 -0.4 5846 0.4 0.3 0.4 5963 0.3 0.2 0.3 6081 0.2 0.2 0.1 6201 0.2 0.1 0.2 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION AGI-8 Location : Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 3 Date Mar. 7, 1993 Filename : ll90TAK Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 10870 127 52.2 70.6 7978 VS ft 6740 LAT ft 2407 DEP D'LEG BUILD TURN o o o ft /100 /100 /100 6295 0.4 0.2 0.5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 6740 ft 69.1° SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~-j ONTINUOUS J'~ OOL ,Alaska Oil & Gas Cons. Anchorage Company Well Name Field/Location ARCO ALASKAI INC. I AGI-~ (2409' NSL; 2536' IdEL, SEC 36, T12N, R14E) l ?RUDHOE BAY, NORTH SLOPE~ ALASKA Job Reference No. 93265 Loqqed By: CRYER Date 9-~1UN-93 Computed Bv' KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. AGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' 09-JUN-93 ENGINEER' J. CRYER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 69 DEG 26 MIN EAST COMPUTATION DATE' 1-JUL-93 PAGE 1 ARCO ALASKA, INC. AGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 09-JUN-93 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 go0 O0 0 O0 100 O0 200 O0 300 O0 400 O0 499 99 599 98 699 86 799 55 899 O0 -49 O0 51 O0 151 O0 251 O0 351 O0 450 99 550 98 650 86 750 55 850 O0 0 0 N 0 0 E 0 15 N 37 6 E 0 12 N 26 23 E 0 12 N 75 24 E 0 18 N 84 49 E 0 41 N 88 43 E 1 26 N 82 36 E 3 43 N 77 13 E 5 22 N 73 12 E 6 39 N 70 17 E 0 oo 0 21 0 49 0 80 I 21 I 93 3 59 8 14 15 97 26 38 0 oo 0 O0 0 O0 0 O0 0 oo 0 41 1 27 1 48 1 42 2 15 0 oo N 0 12 N 0 46 N 0 64 N 0 70 N 0 73 N 0 89 N 170 N 3 74 N 7 06 N 0 O0 E 0 18 E 0 35 E 0 61 E 1 03 E 1 79 E 3 50 E 806 E 15 66 E 25 53 E 0 O0 N 0 0 E 0 0 0 1 1 3 8 16 26 22 N 55 51E 58 N 36 45 E 89 N 43 26 E 24 N 55 35 E 93 N 67 45 E 61 N 75 47 E 23 N 78 7 E 10 N 76 34 E 49 N 74 33 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 998 08 O0 1096 O0 1195 O0 1293 O0 1391 O0 1488 O0 1584 O0 1680 O0 1776 O0 1870 949 08 93 1047 57 1146 71 1244 40 1342 34 1439 88 1535 90 1631 32 1727 80 1821 8 31 N 71 29 E 93 8 51 N 71 58 E 57 10 19 N 71 54 E 71 11 41 N 68 58 E 40 13 11 N 65 11 E 34 14 53 N 62 23 E 88 15 27 N 62 30 E 90 16 57 N 63 42 E 32 17 50 N 66 27 E 80 21 4 N 68 51E 39 93 54 99 71 40 90 59 111 94 136 31 162 20 189 93 219 77 252 45 0 48 0 48 1 92 1 10 2 51 0 60 1 27 1 33 1 44 5 46 11 51N 16 22 N 52 21 27 N 68 27 70 N 86 35 99 N 106 46 97 N 127 59 06 N 151 71 71N 175 84 37 N 203 96 68 N 233 38 33 E 65 E 55 28 E 71 36 E 90 06 E 112 96 E 136 08 E 162 96 E 190 O7 E 219 36 E 252 4O 02 N 73 17 E 09 N 72 53 E 51 N 72 42 E 70 N 72 13 E O0 N 71 15 E 31 N 69 51E 21 N 68 39 E 01 N 67 50 E 90 N 67 26 E 60 N 67 30 E 2000 O0 1962 26 1913 26 26 13 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2051 O0 2140 O0 2229 O0 2317 O0 2404 O0 2489 O0 2573 O0 2656 O0 -2738 51 2002 81 2091 53 2180 23 2268 09 2355 12 2440 19 2524 72 2607 70 2689 51 26 48 81 26 53 53 28 15 23 29 6 09 30 32 12 32 38 19 32 54 72 34 3 70 35 36 N 68 47 E N 7O 7 E N 70 22 E N 67 8 E N 67 13 E N 69 4 E N 7O 29 E N 7O 45 E N 69 39 E N 69 12 E 292 77 337 86 382 87 429 O0 476 99 526 52 579 14 633 27 688 24 745 50 3 23 1 O1 0 66 1 88 1 11 2 67 0 81 0 65 2 48 1 05 111 25 N 270 96 E 292 91 N 67 41 E 127 142 158 177 196 214 232 250 270 12 N 313 21N 355 82 N 398 66 N 442 13 N 488 22 N 538 09 N 589 68 N 641 94 N 694 16 E 337 57 E 382 61E 429 81E 477 77 E 526 19 E 579 30 E 633 03 E 688 59 E 745 98 N 67 54 E 96 N 68 12 E 08 N 68 17 E 12 N 68 8 E 65 N 68 8 E 25 N 68 18 E 36 N 68 30 E 30 N 68 38 E 56 N 68 41E 3000.00 2819 31 2770 31 37 13 3100.00 2897 3200.00 2974 3300.00 3049 3400.00 3121 3500.O0 3191 3600.O0 3261 3700.O0 3332 3800.00 3399 3900.00 3462 92 2848 57 2925 09 3000 41 3072 68 3142 90 3212 37 3283 46 3350 95 3413 92 39 0 57 40 58 09 42 38 41 44 52 68 45 34 90 45 0 37 45 54 46 49 50 95 50 59 N 69 28 E N 7O 11E 866 N 70 27 E 930 N 71 20 E 997 N 71 16 E 1066 N 70 41E 1137 N 70 55 E 1208 N 70 47 E 1279 N 71 2 E 1353 N 71 22 E 1430 804 68 47 67 33 35 47 64 57 66 88 2 58 2 O8 2 15 2 15 2 47 0 14 0 96 2 56 2 86 0 3O 291 79 N 749 97 E 804 73 N 68 44 E 313 334 356 378 401 425 448 472 497 23 N 807 57 N 868 69 N 931 48 N 996 82 N 1064 26 N 1131 46 N 1198 80 N 1268 65 N 1341 93 E 866 49 E 930 39 E 997 93 E 1066 13 E 1137 36 E 1208 41E 1279 41E 1353 57 E 1430 52 N 68 49 E 71 N 68 56 E 36 n 69 3 E 35 N 69 13 E 47 N 69 19 E 64 N 69 24 E 57 N 69 29 E 67 N 69 33 E 90 N 69 39 E COMPUTATION DATE' 1-JUL-93 PAGE 2 ARCO ALASKA, INC. AGI-8 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' 09-JUN-93 KELLY BUSHING ELEVATION- 49.00 Fl' ENGINEER' d. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000 O0 3525 96 3476 96 51 4 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3588 O0 3649 O0 3711 O0 3772 O0 3835 O0 3898 O0 3963 O0 4027 O0 4093 36 3539 95 3600 O0 3662 73 3723 39 3786 92 3849 06 3914 69 3978 24 4044 36 51 41 95 52 15 O0 52 18 73 51 30 39 50 54 92 50 14 06 50 2 69 49 24 24 48 32 N 71 26 E 1508 49 N 72 18 E 1586 56 N 72 35 E 1665 22 N 71 4 E 1744 36 N 71 22 E 1822 99 N 7O 6 E 1900 89 N 67 24 E 1978.09 N 67 37 E 2054.77 N 66 35 E 2131.03 N 66 23 E 2206.43 0 87 0 81 1 33 0 99 0 7O 3 57 0.48 O. 30 1.64 1 . 44 522 49 N 1415 14 E 1508 51 N 69 44 E 546 570 595 620 645 674 703 733 763 80 N 1489 36 N 1564 29 N 1639 62 N 1714 89 N 1787 36 N 1859 73 N 1930 17 N 2001 55 N 2070 40 E 1586 57 E 1665 75 E 1744 23 E 1823 95 E 1901 72 E 1978 60 E 2054 O0 E 2131 60 N 69 50 E 29 N 69 58 E 46 N 70 3 E 11 N 70 6 E 04 N 70 8 E 21 N 70 4 E 86 n 69 58 E 09 N 69 53 E 14 E 2206.46 N 69 45 E 5000 O0 4159.87 4110 87 48 4 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4226.91 4177 O0 4294.39 4245 O0 4362.28 4313 O0 4429.45 4380 O0 4495.75 4446 O0 4562.58 4513 O0 4629.94 4580 O0 4698.16 4649 O0 4766.84 4717 91 47 43 39 47 24 28 47 10 45 48 30 75 48 10 58 47 56 94 47 17 16 46 38 84 47 5 N 66 44 E 2280.91 N 66 39 E 2355 02 N 66 43 E 2428 N 66 56 E 2502 N 67 9 E 2576 N 67 41E 265O N 67 55 E 2725 N 68 23 E 2799 N 68 42 E 2872 N 69 I E 2944 74 08 09 91 27 16 26 94 0 26 0 32 0 46 0 51 1 08 0 45 0 42 0 77 0 82 2 5O 793 17 N 2138.57 E 2280 92 N 69 39 E 822 851 880 909 938 966 993 1020 1046 49 N 2206.74 E 2355 73 N 2274.49 E 2428 63 N 2341 99 E 2502 53 N 2410 19 E 2576 30 N 2479 31 E 2650 40 N 2548 19 E 2725 93 N 2616 77 E 2799 67 N 2684 82 E 2872 90 N 2752 61 E 2944 03 N 69 34 E 74 N 69 28 E 08 N 69 24 E 10 N 69 20 E 92 N 69 16 E 29 N 69 14 E 18 N 69 12 E 29 N 69 11E 97 N 69 11E 6000 O0 4833 49 4784.49 48 46 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4899 O0 4966 O0 5032 O0 5096 O0 5160 O0 5225 O0 5290 O0 5356 O0 5420 83 4850 83 48 6 60 4917 O1 4983 90 5047 91 5111 46 5176 89 5241 20 5307 96 5371 60 48 33 O1 49 24 90 50 4 91 49 59 46 49 37 89 48 47 20 49 40 96 49 38 7000 O0 5485 30 5436 30 50 13 7100 7200 7300 7400 750O 7600 7700 7800 7900 O0 5549 53 5500 53 49 53 O0 5614 14 5565 14 49 39 O0 5679 19 5630 19 49 8 O0 5744 57 5695 57 49 15 O0 5809 83 5760 83 49 8 O0 5875 36 5826 36 49 9 O0 5940.41 5891.41 49 30 O0 6005.41 5956.41 49 23 O0 6070.49 6021.49 49 32 N 70 2 E 3019 48 N 70 39 E 3094 30 N 69 46 E 3168 73 N 68 59 E 3244 37 N 69 9 E 3320 45 N 67 49 E 3397 27 N 68 14 E 3473 62 N 68 45 E 3549.24 N 68 44 E 3624.95 N 69 2 E 3701.15 N 69 45 E 3777 70 N 70 39 E 3854 33 N 71 6 E 3930 64 N 71 41E 4006 54 N 71 49 E 4082 N 72 10 E 4157 N 71 5 E 4233 N 69 I E 4309 N 69 2O E 4385 N 69 I E 4461 15 84 30 24 23 16 1 O2 0 76 2 35 0 40 1 63 0 95 0 94 1 09 0 63 0 54 0 96 0 36 0 71 0 38 0 43 0 56 3 17 0 32 0 64 0 39 1073 O1 N 2822 43 E 3019 51 N 69 11 E 1098 1123 1149 1177 1205 1233 1261 1288 1316 10 N 2892 04 N 2963 92 N 3033 O6 N 3104 08 N 3176 76 N 3247 54 N 3317 86 N 3388 37 N 3459 93 E 3094 O6 E 3168 77 E 3244 84 E 3320 38 E 3397 16 E 3473 50 E 3549 12 E 3624 19 E 3701 32 n 69 13 E ~ 75 N 69 15 E E 39 N 69 14 E ~ 47 N 69 14 E ~ 30 N 69 13 E ~ 65 N 69 12 E ~ tX 27 N 69 11 E ~ ~ ~ 99 N 69 10 E ~ c~ ho 19 N 69 10 E o ~ 1343 35 N 3530 83 E 3777 74 N 69 10 E ~ ~ "~ · ~ 1369 1394 1418 1442 1465 1488 1515 1542 1569 26 N 3602 29 N 3675 42 N 3747 18 N 3818 58 N 3890 93 N 3962 28 N 4034 36 N 4105 23 N 4176 95 E 3854 06 E 3930 07 E 4006 92 E 4082 98 E 4157 82 E 4233 04 E 4309 04 E 4385 06 E 4461 37 N 69 11E c ~o 66 N 69 13 E 55 N 69 16 E 16 N 69 19 E 84 N 69 22 E 30 N 69 24 E 24 N 69 25 E 23 N 69 24 E 16 N 69 24 E COMPUTATION DATE' 1-JUL-93 PAGE 3 ARCO ALASKA, INC. AGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 09-JUN-g3 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG BIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6135 57 6086 57 49 12 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6201 14 6152 O0 6267 11 6218 O0 6333 O1 6284 O0 6399 O0 6350 O0 6464 65 6415 O0 6530 34 6481 OO 6596 55 6547 O0 6663.48 6614 O0 6730.13 6681 14 48 51 11 48 46 O1 48 44 O0 48 39 65 49 3 34 48 45 55 48 14 48 47 57 13 48 25 N 68 46 E 4537 08 N 68 38 E 4612 N 68 32 E 4687 N 68 30 E 4762 N 68 50 E 4838 N 68 47 E 4913 N 68 58 E 4988 N 69 16 E 5~63 N 69 27 E 5138 N 69 25 E 5212 57 72 92 06 48 87 82 11 67 0 28 0 44 0 26 0 19 0 22 0 31 0 33 1 02 0 34 0 03 1596.57 N 4246 89 E 4537 08 N 69 24 E 1624.01N 4317 1651.48 N 4387 1679.06 N 4457 1706.41N 4527 1733.68 N 4597 1760.86 N 4667 1787.65 N 4737 1813.78 N 4807 1839.98 N 4877 22 E 4612 19 E 4687 15 E 4762 14 E 4838 47 E 4913 79 E 4988 79 E 5063 33 E 5138 14 E 5212 57 N 69 23 E 73 N 69 22 E 92 N 69 21E 06 N 69 21E 49 N 69 20 E 88 N 69 2O E 82 N 69 20 E 12 N 69 20 E 67 N 69 20 E 9000 O0 6796.36 6747 36 48 40 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 6862 22 6813 O0 6927 O0 6992 O0 7058 O0 7122 O0 7187 O0 7251 O0 7315 O0 7379 74 6878 95 6943 05 7009 84 7073 39 7138 62 7202 77 7266 69 7330 22 48 59 74 49 7 95 49 18 05 49 33 84 49 40 39 49 54 62 50 1 77 50 13 69 5O 23 N 69 26 E 5287 58 N 69 27 E 5362 N 69 30 E 5438 n 69 27 E 5514 N 69 21E 5590 N 69 10 E 5666 N 69 8 E 5742 N 69 4 E 5819 N 69 2 E 5896 N 68 52 E 5972 83 .38 19 10 27 64 29 O0 91 0 33 0 45 0 O0 0 86 0 29 0 42 0 38 0 55 0 38 0 38 1866 30 N 4947 28 E 5287 59 N 69 20 E 1892 1919 1945 1972 1999 2026 2053 2081 2108 74 N 5017 24 N 5088 79 N 5159 49 N 5230 43 N 5301 64 N 5373 94 N 5444 35 N 5516 95 N 5588 73 E 5362 47 E 5438 48 E 5514 54 E 5590 79 E 5666 16 E 5742 77 E 5819 42 E 5896 21E 5972 84 N 69 20 E 39 N 69 20 E 20 N 69 20 E 10 N 69 20 E 28 N 69 20 E 65 N 69 20 E 30 N 69 20 E O1 N 69 2O E 92 N 69 19 E 10000 O0 7443 29 7394 29 50 35 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 7506 O0 7569 O0 7632 O0 7694 O0 7756 O0 7818 O0 7880 O0 7942 O0 8003 62 7457 70 7520 32 7583 65 7645 67 7707 57 7769 42 7831 16 7893 60 7954 62 50 45 70 51 5 32 51 19 65 51 37 67 51 44 57 51 47 42 51 48 16 51 59 60 52 7 N 68 47 E 6050 07 N 68 52 E 6127 N 68 57 E 6205 N 69 3 E 6283 N 69 12 E 6361 N 69 19 E 6439 N 69 31E 6518 N 69 41E 6596 N 69 56 E 6675 N 70 9 E 6754 45 O5 O1 21 65 19 77 43 32 0 26 0 37 0 75 0 20 0 23 0 29 0 24 1 56 0 82 0 45 2136 83 N 5660 16 E 6050 08 N 69 19 E 2164 2192 2220 2248 2276 2303 2331 2358 2385 78 N 5732 74 N 5804 69 N 5877 53 N 5950 31N 6023 89 N 6097 28 N 6171 47 N 6244 37 N 6319 32 E 6127 71E 6205 49 E 6283 57 E 6361 93 E 6439 46 E 6518 12 E 6596 94 E 6675 11E 6754 46 N 69 19 E 06 N 69 18 E 03 N 69 18 E 22 N 69 18 E 66 N 69 18 E 20 N 69 18 E 78 N 69 18 E 45 N 69 19 E 34 N 69 19 E 11000.00 8064 63 8015.63 52 36 11100.00 8125 67 8076.67 52 11 11200.00 8187 20 8138.20 51 56 11300.00 8248 90 8199.90 51 54 11400.00 8310 61 8261.61 51 53 11500.00 8372 21 8323.21 51 59 11600.00 8433 91 8384.91 51 53 11648.00 8463 54 8414.54 51 53 N 71 8 E 6833 52 N 71 6 E 6912 70 N 71 17 E 6991 49 N 71 10 E 7070 14 N 71 18 E 7148 79 N 71 17 E 7227 53 N 71 10 E 7306 18 N 71 10 E 7343 93 0 91 0 24 0 O9 0 23 1 12 0 40 0 O0 0 oo 2411.62 N 6393 84 E 6833 53 N 69 20 E 2437.22 N 6468 80 E 6912 70 N 69 21 E 2462.63 N 6543 42 E 6991 49 N 69 23 E 2487.91 N 6617 95 E 7070 14 N 69 24 E 2513.31 N 6692 42 E 7148 79 N 69 25 E 2538.55 N 6767 04 E 7227 53 N 69 26 E 2563.90 N 6841 54 E 7306 18 N 69 27 E 2576.09 N 6877 28 E 7343 93 N 69 28 E COMPUTATION DATE: 1-JUL-93 PAGE 4 ARCO ALASKA, INC. AGI-B PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: O9-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG BIN DEG BIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIBUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 0 O0 1000 2000 3000 4000 5000 6000 700O 8000 9000 0 O0 O0 998 O0 1962 O0 2819 O0 3525 O0 4159 O0 4833 O0 5485 O0 6135 O0 6796 -49.00 0 0 08 949.08 8 31 26 1913.26 26 13 31 2770.31 37 13 96 3476 96 51 4 87 4110 87 48 4 49 4784 49 48 46 30 5436 30 50 13 57 6086 57 49 12 36 6747 36 48 40 N 0 0 E N 71 29 E 39 N 68 47 E 292 N 69 28 E 8O4, N 71 26 E 1508 N 66 44 E 2280 N 70 2 E 3019 N 69 45 E 3777 N 68 46 E 4537 N 69 26 E 5287 0 O0 93 77 68 49 91 48 70 08 58 0 O0 0 48 3 23 2 58 0 87 0 26 1 O2 0 96 0 28 0 33 0 O0 N 11 111 291 522 793 1073 1343 1596 51N 38 25 N 270 79 N 749 49 N 1415 17 N 2138 O1N 2822 35 N 3530 57 N 4246 33 E 40 96 E 292 97 E 804 14 E 1508 57 E 2280 43 E 3019 83 E 3777 89 E 4537 1866.30 N 4947.28 E 5287 0 O0 E 0 O0 N 0 0 E 02 N 73 17 E 91 N 67 41E 73 N 68 44 E 51 N 69 44 E 92 N 69 39 E 51 N 69 11E 74 N 69 10 E 08 N 69 24 E 69 N 69 20 E 10000.00 7443.29 7394.29 50 35 11000.00 8064.63 8015.63 52 36 11648.00 8463.54 8414.54 51 53 N 68 47 E 6050.07 N 71 8 E 6833.52 N 71 10 E 7343.93 0.26 0.91 0. O0 2136.83 N 5660.16 E 6050.08 N 69 19 E 2411.62 N 6393.84 E 6833.53 N 69 20 E 2576.09 N 6877.28 E 7343.93 N 69 28 E -Alaska Oil & Gas Cons. C0mrnissi0~, Anchorage COMPUTATION DATE' 1-JUL-93 PAGE 5 ARCO ALASKA, INC. AGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 09-JUN-93 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 OI 649 05 749 26 849 69 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49 O0 0 O0 100 O0 2OO O0 300 O0 400 O0 5OO O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 8 N 52 23 E 0 13 N 23 28 E 0 10 N 57 49 E 0 14 N 82 17 E 0 24 N 88 37 E 0 57 N 85 4 E 2 39 N 80 53 E 4 29 N 75 1E 5 58 N 71 17 E 0 O0 0 O7 0 37 0 62 0 98 1 48 2 58 5 29 11 62 20 88 0 O0 0 32 0 O0 0 21 0 O0 0 48 0 75 2 48 2 O5 I 12 0 O0 N 0 01 N 0 29 N 0 58 N 0 68 N 0 72 N 0 76 N I 13 N 2 54 N 5 24 N 0 O0 E 0 07 E 0 28 E 0 45 E 0 79 E 1 31 E 247 E 522 E 11 46 E 20 34 E 0 O0 N 0 0 E 0 0 0 1 1 2 5 11 21 07 N 85 53 E 41 N 43 37 E 74 N 37 28 E 04 N 49 2O E 50 N 61 12 E 58 N 72 48 E 34 N 77 47 E 74 N 77 30 E O0 N 75 33 E 950 40 1051 1152 1254 1356 1459 1562 1666 1771 1876 949 O0 50 1049 73 1149 39 1249 53 1349 32 1449 81 1549 69 1649 32 1749 69 1849 900 O0 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 7 58 N 70 47 E O0 8 40 N 7I 49 E O0 9 24 N 72 9 E O0 11 10 N 70 22 E O0 12 22 N 67 7 E O0 14 26 n 62 48 E O0 15 9 N 62 23 E O0 16 28 N 63 11E O0 17 35 N 65 29 E O0 19 49 N 68 35 E 32 76 47 63 63 31 81 55 102 34 126 03 152 46 180.41 211.05 244.20 2.53 0.18 1.20 1 . 47 1 70 1 83 0 47 1 72 1 21 5 11 9 20 N 13 18 24 32 42 54 67 8O 93 31 54 E 93 N 45 78 N 60 55 N 77 09 N 97 21N 118 52 N 142 43 N 167 82 N 195 69 N 225 32.86 N 73 45 E 64 E 47.72 N 73 2 e 57 E 63.41 N 72 46 E 89 E 81.67 N 72 30 E 26 E 102.42 N 71 45 E 77 E 126.05 N 70 26 E 38 E 152.47 N 69 3 E 39 E 180.46 N 68 3 E 09 E 211.17 N 67 30 E 67 E 244.35 N 67 27 E 1985 23 1949 O0 1900 O0 25 41 2097 2209 2322 2436 2552 2671 2790 2912 3037 18 2049 18 2149 12 2249 43 2349 54 2449 21 2549 71 2649 70 2749 49 2849 O0 2000 O0 2100 O0 2200 O0 2300 0.0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 26 50 O0 26 56 O0 28 32 O0 29 27 O0 31 57 O0 32 50 O0 33 53 O0 35 44 O0 38 1 3166 31 2949 O0 2900 O0 40 16 3299 3439 3581 3724 3877 4036 4198 4361 4521 87 3049 11 3149 73 3249 11 3349 86 3449 76 3549 44 3649 76 3749 55 3849 O0 3OOO O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 oo 370O O0 3800 O0 42 37 O0 45 25 O0 45 12 O0 46 42 O0 50 56 O0 51 19 O0 52 15 O0 51 46 O0 50 45 N 68 43 E N 70 5 E N 7O 17 E N 66 43 E N 67 5O E N 69 59 E N 7O 50 E N 69 46 E N 69 15 E N 69 33 E 286 28 336 59 387 02 439 48 494 80 553 79 617 65 683 06 752 92 827 57 N 70 46 E N 71 20 E 997 N 70 48 E 1094 N 70 52 E 1195 N 70 44 E 1297 N 71 21E 1413 N 71 45 E 1537 N 72 36 E 1663 N 71 16 E 1793 N 69 11E 1917 908 75 25 05 71 02 69 11 99 O3 60 4 60 1 05 0 84 0 83 1 41 2 29 0 23 2 24 1 08 1 68 2 26 2 15 0 61 1 35 3 81 0 68 1 07 1 28 0 79 3 97 108 90 n 264 90 E 286.41 n 67 39 E 126 143 162 184 205 226 248 273 299 69 N 311 61N 359 91N 408 47 N 459 65 N 514 95 N 574 90 N 636 57 N 701 81N 771 97 E 336.71 N 67 54 E 49 E 387.11 N 68 13 E 27 E 439 57 N 68 15 E 27 E 494 93 N 68 7 E 32 E 553 91 N 68 12 E 54 E 617 75 N 68 27 E 17 E 683 13 N 68 38 E 53 E 752 99 N 68 42 E 41E 827 62 N 68 46 E 327.29 N 847 81 E 908 79 N 68 53 E 356.66 N 931 31 E 997 387.48 N 1023 421 02 N 1119 454 21N 1214 492 15 N 1325 531 53 N 1442 569 99 N 1563 611 O1N 1685 651 70 N 1803 14 E 1094 13 E 1195 89 E 1297 27 E 1413 32 E 1537 40 E 1664 83 E 1793 61E 1917 COMPUTATION DATE' 1-JUL-93 PAGE 6 ARCO ALASKA, INC. AGI-8 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' 09-JUN-93 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER- J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4678 11 3949 O0 3900 O0 50 3 4832 4983 5132 5280 5429 5579 5728 5873 6023 69 4049 73 4149 80 4249 46 4349 54 4449 71 4549 06 4649 90 4749 50 4849 O0 4000 O0 49 13 O0 4100 O0 48 6 O0 4200 O0 47 37 O0 4300 O0 47 9 O0 4400 O0 48 38 O0 4500 O0 48 0 O0 4600 O0 47 7 O0 4700.00 46 37 O0 4800.00 48 39 N 67 35 E 2038 O0 N 66 11E 2155 N 66 42 E 2268 N 66 38 E 2379 N 66 53 E 2487 N 67 16 E 2598 N 67 52 E 2710 N 68 29 E 2819 N 68 54 E 2925 N 70 17 E 3037 77 82 24 77 22 21 74 89 14 0 23 0 8O 0 24 0 26 0 41 0 59 0 37 0 46 1 17 I 03 697 34 N 1915 09 E 2038 10 N 70 0 E 743 788 832 875 918 960 1001 1040 1079 10 N 2023 38 N 2127 10 N 2229 O1N 2328 11N 2430 73 N 2534 50 N 2635 06 N 2734 01N 2839 71E 2155 46 E 2268 O0 E 2379 81E 2487 61E 2598 23 E 2710 92 E 2819 82 E 2925 03 E 3037 83 N 69 50 E 84 N 69 40 E 25 N 69 32 E 77 N 69 24 E 23 N 69 18 E 22 N 69 14 E 77 N 69 12 E 92 N 69 11E 17 N 69 11E 6173 50 4949 O0 4900.00 48 9 6326 6481 6636 6788 6943 7099 7253 7406 7559 10 5049 44 5149 19 5249 87 5349 40 5449 17 5549 72 5649 79 5749 77 5849 O0 5000 O0 49 21 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 50 7 O0 49 15 O0 49 39 O0 49 55 O0 49 53 O0 49 24 O0 49 16 O0 49 0 N 70 18 E 3148 93 N 69 3 E 3264 N 68 8 E 3383 N 68 22 E 3501 N 68 45 E 3616 N 69 17 E 3734 N 7O 39 E 3853 N 71 33 E 3971 N 71 5O E 4087 N 72 11E 4202 18 O5 10 46 28 7O 49 29 94 2 02 0 36 1 65 1 13 0 77 1 11 0 36 0 93 0 43 1 13 1116 26 N 2944 45 E 3148 94 N 69 14 E 1157 1199 1243 1285 1328 1369 1407 1443 1479 01N 3052 76 N 3163 92 N 3272 79 N 3380 16 N 3490 05 N 3602 37 N 3713 79 N 3823 37 N 3933 27 E 3264 18 E 3383 70 E 3501 21E 3616 15 E 3734 36 E 3853 79 E 3971 81E 4087 97 E 4202 20 N 69 14 E 07 N 69 14 E 13 N 69 11E 50 N 69 10 E 32 N 69 10 E 73 N 69 11E 51 N 69 15 E 30 N 69 19 E 94 N 69 23 E 7713 23 5949 O0 5900 O0 49 29 7866 8020 8172 8324 8476 8628 8778 8928 9079 93 6049 54 6149 55 6249 24 6349 11 6449 27 6549 39 6649 44 6749 87. 6849 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 49 26 O0 49 8 O0 48 42 O0 48 45 O0 49 6 O0 48 39 O0 47 54 O0 48 27 O0 48 53 9232 53 6949 O0 6900 O0 49 16 9386 9540 9695 9851 10009 10167 10326 10487 10649 05 7049 46 7149 92 7249 95 7349 OO 7449 09 7549 70 7649 61 7749 17 7849 O0 7000 O0 49 31 O0 7100 O0 49 48 O0 7200 O0 50 1 O0 7300 O0 50 16 O0 7400 O0 50 37 OO 7500 O0 50 58 O0 7600 O0 51 21 O0 7700.00 51 43 O0 7800.00 51 46 N 69 1E 4319 31 N 69 14 E 4436 N 68 43 E 4552 N 68 33 E 4667 N 68 34 E 4781 N 68 47 E 4895 N 68 59 E 5010 N 69 27 E 5122 N 69 26 E 5233 N 69 28 E 5347 02 62 09 14 43 11 O8 94 65 N 69 32 E 5463 O0 N 69 22 E 5579 48 N 69 7 E 5697 14 N 69 4 E 5816 16 N 68 58 E 5935 N 68 46 E 6O57 N 68 54 E 6179 N 69 7 E 63O3 N 69 18 E 6429 N 69 36 E 6556 94 02 47 86 92 82 0 . 34 O. 78 0.44 0 35 0 24 0 18 0 19 0 17 0 20 0 53 0 78 0 35 0 3O 0 56 0 29 0 39 0 41 0 32 0 26 0 69 1518 88 N 4043 44 E 4319.31 N 69 25 E 1560 27 N 4152 57 E 4436.02 N 69 24 E 1602 20 N 4261 37 E 4552.62 N 69 24 E 1643 93 N 4367 98 E 4667.09 N 69 23 E 1685 72 N 4474 11E 478114 N 69 21E 1727 15 N 4580 64 E 4895.44 N 69 20 E 1768 49 N 4687 62 E 5010.12 N 69 20 E 1808 15 N 4792 32 E 5122.08 N 69 20 E 1847 45 N 4897 06 E 5233 95 N 69 20 E 1887 41N 5003 51E 5347.66 N 69 20 E 1927 86 N 5111 54 E 5463 O1 N 69 20 E 1968 2010 2052 2095 2139 2183 2228 2272 2317 75 N 5220 43 N 5330 82 N 5441 66 N 5553 35 N 5666 54 N 5780 13 N 5896 87 N 6014 38 N 6133 61E 5579 64 E 5697 85 E 5816 71E 5935 64 E 6057 84 E 6179 97 E 6303 83 E 6429 66 E 6556 49 N 69 20 E ~ ~ 15 N 69 20 E : 17 N 69 20 E ~ 95 N 69 20 E ¢ 03 N 69 19 E ~' 48 N 69 18 E ~ 88 N 69 18 E 94 N 69 18 E 83 N 69 18 E COMPUTATION DATE: I-JUL-93 PAGE 7 ArCO ALASKA, INC. AGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 09-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIM DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 10811.12 7949 O0 7900 O0 52 4 10974.28 8049 O0 8000 O0 52 34 11137.99 8149 O0 8100 O0 52 3 11300.16 8249 O0 8200 O0 51 54 11462.30 8349 O0 8300 O0 52 0 11624.45 8449 O0 8400 O0 51 53 11648.00 8463 54 8414 54 51 53 N 69 59 E 6684 19 N 70 57 E 6813 10 N 71 10 E 6942 66 N 71 10 E 7070 27 N 71 17 E 7197 83 N 71 10 E 7325 41 N 71 10 E 7343 93 0 SS I 36 0 44 0 23 0 39 0 O0 0 O0 2361 47 N 6253.16 E 6684 21 N 69 19 E 2404 98 N 6374.53 E 6813 11 N 69 20 E 2446 92 N 6497.17 E 6942 66 N 69 22 E 2487 95 N 6618.07 E 7070 27 N 69 24 E 2529 02 N 6738.91 E 7197 83 N 69 26 E 2570 11 N 6859.75 E 7325 41 N 69 28 E 2576 09 N 6877.28 E 7343 93 N 69 28 E qiask,~ U/i 6 G;~,s 0o~?$. C'orl!.,iT~ission An'Jhora.oe ARCO ALASKA, INC. aoI-8 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER GCT LAST READING TD COMPUTATION DATE' 1-JUL-93 INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE 8 DATE OF SURVEY: 09-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER SURFACE LOCATION = 2409' NSL & 2536' WEL, SEC36 712 R14 E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11571.40 8416.25 8367.25 2556.64 N 6820.24 E 11648.00 8463.54 8414.$4 2576.09 N 6877.28 E REEE V D ,~ i~G 2 G 1993 Alaska Oil ~ Gas ~' . ,-, ,.,OHS. Commissior, Anchorage ArCO ALASKA, INC. AGI-8 PRUDHOE BaY NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 1-JUL-93 PAGE 9 DATE OF SURVEY: 09-JUN-93 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: J. CRYER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2409' NSL & 2536' WEL, SEC36 T12 R14 E MEASURED DEPTH '"I-VD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11648.00 8463.$4 8414.$4 2576.09 N 6877.28 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11648.00 8463.54 8414.54 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 7343.93 N 69 28 E _ Aiask.?. Oil & Gas Cons. Commission Anchorage DIRECTIONAL SURVEY COMPANY ARCO ALASKA INCORPORATED FIELD PRUDHOE BAY WELL AGI-8 COUNTRY USA RUN ONE DATE LOGGED 09 - JUN - 93 DEPTH UNIT FEET REFERENCE 93265 AJI Interpretations are opinions based on Inferences from electrical or other measurements and we cannot, and do not ............ I guarantee the accuracy or correctness of any Interl~retaflons. and we shall no~. except in'the case of gn:)IS or wllfull r negligence on our part. be liable or responsible for any loss. costs, damages or expenses incurred or sustained by anyone resulting from any Interpretation made by any of our officers, agsnt~ or employees. These Interpretations ere alSo subject to our General Terml and Conditions as set out in our cun'ent price Schedule. . bELL: AGT-8 (2409' NSL, 2536' IpJEL, SEC 36, T12N, R14E) HORZZONTAL PROdECTZON SCALE= 1/ 2000 i,:4 ¥--i**-~ *~.-[--i~--ii-ii-i;i[.*i.i--4; -i~i-.~-.-i'~;-;.~.-.~.i-i.~.,;i~;- ii;: : .......... i .... : : i "-i :'"!'~ "'i ! :'~ i i'!"~' i i"i"i i '!'i'i'i''i'i'i i ! i'i'"i'"~T'i";'~' i ' i .... ;..~ .... ~..~...~...~. i ..... ~.~ ....................................................... ii:i::ii.::i:i:i::.;.':!::.!.:ii:i.i:.i .............................. i.:.:.::i:i i : ~ i i i I : : i i . . ~ : :: :.:. : .. ::.. :.: :::: :::: ;::: :::: :::: :::: : ;'-: i ~ -'i;~-i ....i:-!-! -.:.i.i-i.--ii--i.-i ,---i--iii ..... il--i-'.!-.,i--i-.i--!., i..i-.i..!-.! .... i'i ..... !-i! i-, ! : : : ........... :i:.: i...;.::...::;i ::..i.i...L:~i':.i..i~i..i. ii;Li:;: .::i:. i:.i.:.i.~;:.;.::;~;:,; ,.:. ,:: : :..: :. .:: .::. :::: ::.: .-.. .::: : .. 6000 !.:::..~.i.i~.. :...! - ::.. · : :::- -::: ::: :::. .::: :.': :.:' : · ;::; .:.:j: ;.:: :ii;.;.;i:..~:.:.~iL: i:i~ ii:~.ii-ii :.i?i :i:: ::.: :::. ::: ::: ~:i i .i..;.i.~ .;.: ;..i.. ~ ~ ;.i ..i.i.ii. i.;..i.i .!..;.i; ;iil..;..;.;; .; i.i.; .;..il.i i ~ ........ . . . : : . : · . : . : · : - . __ ................... ~: .................... :':: ::: i :i ':': :::' ::: :!:: :::: ~::: i!i i: . :::: :.;: :.:.: :::: ;:::.::;: :::: :~.:: ::;: ;::: .... :: : . :: : . .: : ..- ::.. ..: : :. -... ......... : . : : : .~ ;;;,. :; ~ ; .:,, ,,,: :~., ,,,,.,,:, ,:: ..... · . ~ i i ...... i.Li.. : ........... ~ i ;..L .i i.i.:. !.i.i : ........ i ; i i i.L.; ~ .: i i ; ....... 4000 · ::: : :' ..i~ .!i .... i.:. : :: .... ~ . . . ............................. ~ ; ~ ; i-; ; i : ~ ; : -: ~.~ .i .................. ' ' : · · ~ ; ~ i i ; :.! ! ~ : : i ~ ~ i i -iI I ~ .: :-i i .i i i i -i ~ : ; :.i ~ i i ~ ~ i i .i i ~ i .: i : : : ~ : ...... : ooo · i ..~ .... !.i -i. : ~ ~--+! ..... i--i .... i--!-~OOi-- i~-ii ...... i : i..i--i!..-~---i.-i--. :. ii..! ..................... · o ' :'!'!"i ': -: .... ..... i ; ; ; .-i.-i--i...i ....... ............ i., ,...i .... ~-, ....... :. --i ..... i--.i...,.i--i..~ ...... ~..,.i4... i ................. ~.-i ..... I .................. : . , i }..; i i-: ; : : .; : ;.; ;..i..i i ..} i i i .i i i i i.i i i i : ~ i i i.~ i i i : ; .: : . ; .... . .:.: ::.. ,::. .:: : .... :: , -: : ~ t::! !'~: ................................ : · . . . , : .. [ i.:~.: ~ ...... ::.~il.. .:i..:..:..i.}.}:..:ii.::i:~ .:::.i : ..... .... :: .:; .... ::. : .: .:;: : , ; i i.i...i ; ......... i i ,.~ .;.; .i ;.i ;-i- i...i.i-i. ~ ; i ; ..... ; ;.; ;. i...i i , , ; , : : . . . · :! :. · .. __ ............. ~ ~ ~ ~ : .... · ,i!~-~---i--i~}.--i---i---!i--i--! .... !--:-! ..... !---ii~--! .... !.!---i---~ .... !---~.!~i ...... !i-!--i---i-.!.-!~-! ..... i-',-i-!i .... · ................ . , 1~3 . . : : i i.--i-i-i ..... i : : ~ :-:-.i-:- : : .-! : i - i i ..; : i : :.. : i ........ ': ... ::::,: :. :. : :::: :::: :::: :::: -:::~::. ;;il i..;~ : '; :~ .;~ ~ ; ;.;il :.;...i..; i...;i ; i : ; ii.i-.; .....;~ : i.; ......... sou~-6000 ~ : : · : : ' ' ' -4000 -2000 0 2000 4000 6000 8000 10000 12000 WEST EAST k'ELL: AGI-8 (2~109' NSL, 2536' IIEL, SEC 36, T12N, R14E) VERTICAL PROJECTION 249.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 · ~ : ~ : *; ..... ~ .... i*--h;---!-.-~ ~.:-!- i-[ ! ~- i ! !.~ ~.i-!'~---~ ......... ~.i-~ } .... i } ! ~.. i-; ! ! ..... ~.! ~ ! i ~ .! ! ~ i !-i i-i- i*i-i*i -!-i~i i i.i :.i- i i i i. i i.~ ~ ~.i i i i i i i.. i.i ~.~ ; ~ i : : i ~ : : : : : i ~ :. ! ! ~ ~ : !,' : : ~ ~..~ : i Li i : i i .~ i i : ~ i ! i i i ! i. i : i : i ! i ! ! ! ! i . i ......................... - . . . ~,i~:~ .;.~ ~.~i~ :~i !~:! ~.,~eooo !!ii !~!'i !!!'VERT[(:A£iSi:CTIOIi : ! :-i ! ! ~ i i : : i . ; : - ..... ' ' . ! '-' .... :.: i--'i.-:-!.'., i-i i .... i '" .... :¢ii'" !ii i'i'~':!I'! i'::"! ::i! !i'!'i"ii-'i:ii":i'!'"i':~':i:iiii' ;[ i]i ...... ' .... .............~ _~ 8o_00. ~_, : ~:L_ ' i : L_~ :! -_×i_a~O~c ........................................ ..:. :.:~ :~: .:~:..~.~ ~:: :~;~ :~ ~,.~ ~:~ ~ .... :;~,,.,: ..: ......... : i : : · : · . . · . . . i : .... ..ii : ........ ii_ii.. :: :-'i .... ii. i .... i.i i ~ . i~ i ..~i i ..i. li.~ ..... i .................... . . ..... · ....... : ........ iii: , -:il.iii:.:i.~., ~.~i ~,.~ -,i..i*.i :~.-i ~::ii~.~ i.,:~., .... ~ .... ~ ............... . .:: ........ · : : i ~ : i : i : ~_~100~): i . . : ' : . ' ' · : . . . ~ .... ........ ! :. _i : i.i ........ i ..i i..i.i. :.:.: i ...... : .:. i i ..i i i .. i i.i i i i : ...... : .......... · . :: :.:: . .- :. . .:.: · . . . i : i.. :.. : ~...!.~..~..: .... : ..... i .... : : i : ~..: : .... : i :.~ .... i ~.. i i.! i :.: ............ : : :: : . : '':* * ::. ::': .':' ':: : : ::: ,:,i ~ i~.~I .... i.i.i.! .i.~:.L2~(.iil; ~::, ~,:;.. --~.: .,~.~ . ............. .i,..i..i ............ i..i...i..i .: : : ................ i ...... ! i !...i ..i..: : i...! i i : .................................... . . : ..... :i:i. .~ ..i...~i.!..: .... ~:~.. :!:i ~i:..i :.:!~ :.:i! i:: ...... : .... : :: .::: : .: · , ::: .... !. ~':;~ .... Y?"!'"] ~;'~'!!"?~ :;''~,~'!':'::': ': ......... .::. ::.i:...i..i.~.i..:.:.:.i:.~:i:::: :::: ' : :il.i :::: i:.. :: , :;~i. ;!.il...i...ii ..;.ii.;.i i!h.i::i, i.: ~ ~.i. ~..;.i AU.G,2i~.i)9~i .. : .... i :.~.i.l.i ...... i..il...i., i i i i..i i.! i ~ i.i.i ! !.i i .-i-i-+i i.i i.i...!.~ ! !.1 ........ ~ ~ : ........ . . .::. :.:. :::: :,:: ::: :::: ::::- :: : ::-:: .:.: : ...... ,; ; i'i i i ii:iii'ii?i:i i.i: iii'l":i:iiiiii!/?iii"!:.i i'ii!'?;ii:i:: 'ii"i! !i'Anchorag~i}'il ':;'; iii ' :. 69.00 0 PROJECTION ON VERTICAL PLANE 249.00 69,00 ~gCALED IN VERTICAL DEPTHS HtO~IIZ SCALE = I / 2000 IN/FT ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Please sign and return the attached copy as RECEIVED BY_~~ Have A Nice Day! Sonya Wallace ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL Job#AKEI30010 Sperry Job#1209 BHI Ana Ana Job#AKEI30016 Sperry Job#AKMW30020 Sperry Job//1188 Teleco Job#AKlc-I30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Aha Ana Ana Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Teleco Job#AKMM911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job#1168 Teleco Job# 1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job# 1190 Teleco Job # 1195-450 Teleco Job#1205 BHI receipt of data. ,%.' o/ Trane# 930~9 '~ ~ PB ~LL F~ES ~ BPX ~ ST. OF ~. (2 COP~) i LUC~LE JO~STON INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-033 DPR/GR 93-033 DPR/GR 93-033 GR/CCL 93-033 PERF 93-033 SBT/GR/CCL 93-033 407 93-033 93-033 Are well tests required? Was well cored? Yes No... DAILY WELL OP SURVEY Yes No RUN 4, 2&5"MD RUN 4, 2&5"TVD RUN 1, 5" RUN1, 5" RUN 1, 2&5" COMP DATE:06/19/93 02/26/93-03/09/93 SS DIRECTIONAL If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL 08/30/1993 PAGE · 1 COMMENTS: ARCO/~IAs~rA, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO OPEN HOLE FINAI~ 3-18A ~> ~/~4/-10-17/93 MWD: DPR/GR R--S 1-3. 2"&5'3rid 3-18A/ 4/10-17/93 MWD: DPR/GR R-ns 1-3, 2"&~'rVD · ~-°'.~~%~Ai 6- z3-93 LW~: CnN ~m Z. ~'~' · 5-3A ~ 6-13-93 LWD: CDR Run 1, 2'&5" · 5-3A / 6-13-93 LWD: CDN N/F Run 1, 2"&5" · 5-3A 6-13-93 LWD: CDN N/F OverlayRun 1, 2"&5" 5- 6-13-93 LWD: CDN Run 1, 2"&5"IVD 5-3A ~6-13-93 LWD: CDR Run 1, 2"&5"rVD · * AGI-5-~ /t~' ~4.1~O_9933 DLL/GR/SP Run 1, 2"&~' ~ ** AGI-5~ 4-20-93 BH Profile Run 1, · * AGI-6"~ ~ 4-25-93 DLL/GR/SP Run 1, 2~'&ff' · * AGI-6/ ~o~ 4-25-93 BHCA/GR Run 1, 2"&fi' 4-25-93 BH Profile Run 1, · * AGI-6 ~ ~'~ AGI-6 ] .2/11-13/93 DPR/GR Runs 6&7, :~'&5'!MD AG~-~ ~f{ ~/~1-13/93 ~.~P./a.~ ~uns 6a7, AG~-7 C ~-~ ~/1.~4/28/93 D~/C~ AGI.7~ Runs 6&7, 2'&5'~MD t -~ 2/15-4/28/93 DPR/GR Rlm_s 6&7, 2"&5"I'VD A~-S~4~ 3/~6/93 -~a/C~ ~un 4, Z'~'~ AG~-8~ _ ~{ 3/5-6/93 -D~/GR Run 4, A~-9~ ~'~ 3/~/7/93 V~/C~ ~uns 4~, ~'~'~ AGI-9' 3/9-5/7/93 DPR/GR R~m~ 4&5, 2"&~'rVD AGI-~O~ ~ 3/24-28/93 I)Pa/C~ ~,,~- 3~4, ~'&~'~ AGI-10., 3/~A--~8/93 DPR/GR Rmm ~8t4, ~'&~'TVD Please sign and return ~~tached~~ as receipt of data~ ATO-1520 Tr~$# 93070 JUL ~ 0 199~ # CHEVRON Alaska 0it & ~as C~Pi~'~LI, FILES # D & M Anch°r~CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # TEXACO # MOBIL BHI BHI Sch Sch Sch Sch Sch Sch Atlas Atlas Atlas Atlas Atlas Atlas Teleco Te!eco BHI BHI BHI BHI BHI BHI BHI BHI * The correct name for this well is 5-3A, and the logs are finals. -?_*~._- These logs are revised final prints, please replace previous logs. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINAI~ * 1_1B~ I~ °~6.20.93 1-16 ~'~;~ 6-25-93 1-22 ~ ~,t 6-29-93 1-30 ~;~' ~ ~o 6-29-93 3-25A ~'~ 6-27-93 3-ao 6- 3-9 3-31 ~~6-23-93 3-33 ~/-I/~ 6-29-93 3-36 ~-l~ 6-28-93 4-37 ~/~7 6-20-93 4-40 ~ I~ I~ 6-20-93 5-3A ~f 6-18-93 5-26 ~q~ ~ 6-25-93 ~!~AGI-6 ~ ~-~ 4-25-93 AGI-8 ~~6-19-93 6-4 ?~- ~z~6-26-93 6-13 ~ -3~ 6-25-93 9-49 ~ ~-~ 6-22-93 9-50 {~-H~ 6-26-93 12-26e~ 6-22-93 13-17 ¥~ 6-27-93 13-14 ?~-~ 6-28-93 13-20 ~ ~? 6-19-93 16-1-2 ~l~ 6-21-93 17-20 ~-~6-26-93 · *' AGI- 104t ~$~ 6-18-93 · ** AGI-10-~6-18-93 Prod Profile Perf Record Production Log Leak Detect Perf Record Leak Detect Bridge Plug Setting Completion Record Perf Record Dual Burst TDTP (Borax) Completion Record s r/cd /cc TDTP (Borax) Production Log Perf Record Production Log -Production Log CNL Le~k Detect Leak Detect Plug Depth Record Prod Profile Production Log ;~.AC~ oustic CBT ~' Perf Record Perf Record R~_m 1, 5" Sch Rim 1, 5" Sch R~_m 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 2"&5" Sch R.n 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch R-n 1, 5" Sch R-n 1, 5" Sch R._~ 1, 5" Arias Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 1"&5" Sch Run 1, 2"&5" Sch Run 1, 5" Sch Rim 1, 2" Sch Run 1, 2" Sch R!!n 1, 5" Sch Run 1, 1"&5" Sch Run 1, 5" Sch Run 1, 5" Arias Run 1, 5" Sch R~m 1, 5" Sch R-~ 1, 5" Sch Please sign and return the attached .c~op~ as receipt of data. EC ,VE , Have A Nice Day~// · / Sonya Wallace APPROVED_ ATO-1529 Trans# 93074 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct nnme for this log is 1-1B. This ts a revised log, please discard previous copy receivecL The correct APl# for AGI-10 is 504)29-22353-00. RECEIVED # 'dUL 0 199~ # CLINT CHAPMAN ## ~x'"XONs~o~m Naska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'~'? y 6-18-93 3-25A ~'~3 6-17-93 3-31 }V-~z 6-16-93 3-32 e ~/-/~ 6-15-93 3-33 ~ ¥~ ~'o 6-16-93 4-8 ?i-~ 6-11-93 5-14 ??-}~ 6-12-93 6-22A ~ ~.f~6-6-93 6-22A - 6-10-93 7-25 ~-y ~. 6-6-93 9-44 ~ ~ ~ za6.6_93 11-18 f~-1~6-7-93 14-6 ~- ~6-8-93 14-8 ?~-/,~ 6-10-93 14-13 ~]~'ld 16-13-93 14-15 fl~ 6-8-93 16-4A tz-t¢~6-9-93 16-17~- zz~6-14-93 16-31 ~ ~-~ { 6-7-93 17-4 ~~ 6-14-93 AGI-5 5~-~-6-13-93 AGI-6 ~-d~ 6-14-93 AGI-7 _6-8-93 AGI-7 ~ ~-t6-15-93 AGI-7 6-17-93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Le~l~ Detect Leak Detect Perf Record Perf Record Production Log PITS/Leak Detect Leak Detect I. nj Profile Completion 'Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record Rllrl R!!n alln Rl~n R~ln R11_n R11_ri R11T1 Run Run Run Run Ru_n Run Rnn Rim Rl11'1 Run R~n Run Run Rll_n Rl11'1 R~n ! 1, 1, 1, 1, 1, 1, 1 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 1, 5" 5" 5" 5" 5" 5" 2" 5' 5" 5" 5" 5" 2"&5" 5" 5" 1"&5" 2"&5" 5" 5" 5" 5" 5" 5" 5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch AGI-8 ~? '$ 3/6-9-93 GR/CCL Rnn 1, 5" Sch AGI-9~ a ~,,'~' 6-9-93 GR/CCL Rl~n 1, 5" Sch AGI-9/-~ ~ 6-17-93 Pe~ Record R,m 1, 5" Sch ~e.e s. ~d ret~~~che~~ ~ceipt ~~- - .... Sonya W~ac,' / APPROVED ~e W.~ <~/, ~ ~ON ~ ~ ~ MOB~ ~/~ #BPX # STATE OF ALASKA * The correct AFl# for 3-32 is 50-029-21141-00. The correct well name for this log is 6-22A. ARCO ,~1~.~r~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: 6-9-93 5-6-93 Static Pressure Run 1, t~' Sch 5-8-93 Prod Profile l~m 1, 5" Sch 5-10-93 Production Run 1,1~' Sch 5-11-93 CBT/New TfKI/J~~ Run 1, 5~' Sch 5-10-93 Leak Detect/Spin/Temp/Press Run 1, 2" & 5" Sch 5-4-93 USIT (Cement & Corrosion) (Color) Run 1, 5" Sch 5-3-93 InJ Proflle/Spin/Temp/Press Run 1, IE' Sch 5-2-93 Inj Profile/PITS Run 1, 5" Sch 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" Sch 5-7-93 Dual Burst/TDT-P (Borax) Run 1,/~' Sch 5-6-93 Vertilog Run 1, 5" Atlas 5-8-93 GR/Collar Run 1, 5~' Atlas 5-6-93 Perf Record Run 1, 5" Sch 5-7-93 GR/CCL l~m L 5~' Sch 5-10-93 CNL Run 1, 5" Sch 5-11-93 Leak Detect Run 1, 2'' & [~' Sch 5-7-93 Perf Record Run 1,/~' Sch 5-9-93 TDT-P (Borax) Run 1, 5" Sch 5-3-93 Leak Detect/Spin/Temp/Press Run 1, 5" Sch 5-3-93 Perf Record Run 1, ~' Sch 5-4-93 Production Run 1, ~' Sch 5-5-93 CCL/Perf Record l~m 1, [~' Atlas 5-8-93 SHT/GR/CCL Run 1, I~' Atlas l~m 1, ~' Sch Run 1, 5" Sch Run 1, ~' Sch l~m 1. 2'' & 5" Atlas ~... ]~ ~_AGI-4~ 5-7-93 GR/CCL (Color) '~"~. 0~...AGI- 5 5-10-93 GR/CCL (Color) ~_~.GI4 5-10-98 GR/CCL {Color) q~ff,~~~I-8 5-3-93 SBT/GR/CCL Please sign and return the attached copy as receipt of data. RECEIVED BY__~~-~ Have A Nice Day! 9306~ # CENTRAL FI~~'~..~-~X # PHILLIPS . # CHE~ON ~ c.'~.~.. PB WELL FILES # CLINT CHAPMAN '~4. # BPX # EXXON ~ # STATE OF ALASKA # MOBIL MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W Johnston date: Chairman,-"~,~ file: thru: Blair E Wondzell ~ subject: Petr Insp Supervisor from: '~ o~bby Foster Petr Inspector May 10, 1993 050193-1.doc BOP Test - AUDI AAI- PBU-AGI #8 PTD~ Prudhoe Bay Field Saturday, May 1, 1993: I traveled this date to AUDI rig 2 and witnessed the BOP test which began at 5:30am and was completed at 7:30am. There was one failure; the lower Kelly valve leaked. This is to be changed out, tested, and I am robe notified. Summary: I witnessed the BOP test on AUDI rig 2 on AAI's AGI well #8; test time two hours, one failure. attachments STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Rig No. Set@ ./~ ~' ~ .~ Weekly Other ~ PTD # (~.~- ._,-~ Rig Ph.~ ~ ~ - ~ P~ -- Rep.: ~"~ ~ ~;~ ~ Rig Rep.: ~~". [~/~ Location: Sec._ ~ T. /~ ' ~ / q ~ Me,dian ~ Test Well sign Drl. Rig MISC. INSPECTIONS: Location Gen.: J Housekeeping: ~ (Gen) Reserve Pit'S, Test BOP STACK: Quan. Pressure Annular Preventer / Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Une Valves / Check Valve P/F FLOOR SAFETY VALVES: Quan. Pressure ~/F Lower Kelly / IBOP ! Ball Type ! Inside BOP MUD SYSTEM: Visual Alarm Trip Tank Pit Level Indicators Flow Indicator Gas Detectors Test CHOKE MANIFOLD: Pressure P~ No. Flanges Manual Chokes ~ Hydraulic Chokes ACCUMULATOR SYSTEM: System Pressure ~ o '0 J Pressure After Closure J ~ D 0 I 200 psi Attained After Closure ---, minutes ~ sec. System Pressure Attained , .~ minutes ~ o sec. Blind Switch Covers: Master: ~ RemOte: ~ Uitgn. Btl's: ~ ~ / ~ ~r~,' Psig. Number of Failures / Test Time' ~, Hours Number of valves tested / ~ . Repair or Replacement of Failed Equipment will be made within / days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Distribution: odg-Well File c - OperJRig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES ~ NO 24 HOUR,NOTICE GIVEN YES // NO Waived By: VV'rmessed By: FI-021L (Rev. 2/93) Boptst3 STATE OF ALASKA ' ,~/._. AL,-,,SKA OIL AND GAS CONSERVATION COMMIS~.ON REPORT OF SUNDRY WELL OPERATIONS X Stimulate Plugging Perforate 1. Operations performed: Operation shutdown Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2409'NSL, 2536' WEL, SEC. 36, T12N, R14E At top of productive interval N/A At effective depth N/A At total depth 443' SNL, 1466' WEL, SEC. 31, T12N, R15E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 50' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number AGI-8 9. Permit number/approval number 93-33 10. APl number 50- 029-22348 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10942 feet 8022' feet N/A feet N/A feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 76' 20" Surface 3896' 13-3/8" Intermediate Production 10897' 9-5/8" Liner Perforation depth: measured None Cemented Measured depth 281 cu ft Arcticset 2605 cuft "F"/460 cu ft "G" 573 cuft Class "G" 106' 3937' 10935' True vertical depth 106' 3482' 8018' true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil ~ Ga~ ~,u,,~ ....... Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae Production or Injection 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 Apex Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~]ned ¢/~'~ .-.~.-,...,, / Title Drillin~TEn~lineerSupervisor Form 10-404 Rev 06/15/~,8" .~/ ' SUBMIT IN DUPLICATE BP~/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI-8 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 02/25/93 11:00 SPUD: 02/25/93 10:00 RELEASE: 03/08/93 02:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 02/26/93 ( 1) TD: 328' ( 328) 02/27/93 (2) TD: 1964' (1636) RIH. MW: 8.7 VIS:195 MOVE RIG. RIG ACCEPTED @ 11:00 HRS, 2/25/93. M/U DIVERTER. P/U BHA %1. SPUD WELL @ 22:00 HRS, 2/25/93. DRLG F/ 116'-328' DRLG. DRLG TO 1964'. MW: 9.1 VIS:160 02/28/93 (3) TD: 3950'(1986) 03/01/93 (4) TD: 3950' ( 0) 03/02/93 (5) TD: 5380' (1430) 03/03/93 (6) TD: 7023' (1643) 03/04/93 (7) TD: 8340' (1317) CBU. MW: 9.3 VIS:ll5 DRLG TO 2151' CBU. POOH. RIH. DRLG F/ 2151'-3950' CIRC. N/U BOPE. MW: 9.2 VIS:100 CBU. SHORT TRIP TO 2115'. CIRC. POOH. RIH W/ 13-3/8" CSG. CIRC. PUMP 100 BBLS WATER, 464 BBLS LEAD CMT, 82 BBLS TAIL CMT. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. N/D DIVERTER. N/U BOPE. DRLG. MW: 9.0 VIS: 33 N/U BOPE. TEST BOPE. L/D BHA. RIH W/ BHA. TAG FC @ 3859'. CIRC. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. LOT (12.6 PPG EMW) . DRLG F/ 3960'-5055'. CIRC. SHORT TRIP TO 3937' DRLG F/ 5055'-5380'. POOH. MW: 9.3 VIS: 36 DRLG TO 6180'. CIRC. 15 STDS SHORT TRIP. WASH 90' TO BTM. DRLG TO 7023'~ CIRC. POOH. DRLG. MW: 9.7 VIS: 40 POOH. CHANGE MTR. RIH. DRLG TO 8340' 03/05/93 (8) TD: 8830' ( 490) 03/06/93 (9) TD:10211' (1381) DRLG. DRLG TO 8770' 8830' MW: 9.7 VIS: 44 CIRC. POOH. CHANGE BIT. RIH. DRLG TO DRLG. DRLG F/ 8830'-10211' MW: 9.9 VIS: 42 RE' E VE MAR t99 Oil & Gas Oons. Commission Ar~chorag~ WF.~LL : AGI - 8 OPERATION: RIG : AUDI 2 PAGE: 2 03/07/93 (10) TD:10942' ( 731) 03/08/93 (11) TD:10942' ( 0) 03/09/93 (12) TD:10942' ( 0) POOH. DRLG. SHORT TRIP. DRLG TO 10942' TRIP. CBU. POOH. MW: 9.9 VIS: 44 CIRC. 25 STDS SHORT TEST PACKOFF. MW: 8.5 VIS: 0 POOH. L/D BHA. RIH W/ 9-5/8" CSG. CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 102 BBLLS (500 SX) CMT. DISP W/ SEAWATER. BUMP PLUGS W/ 2500 PSI. R/D HOWCO. INJECT 275 BBLS MUD DN ANNULUS. INSTALL & TEST PACKOFF. RIG RELEASED. MW: 8.5 VIS: 0 DISP TOP 2000' W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. RIG ACCEPTED @ 14:00 HRS, 3/8/93. SIGNATURE: (drilling superintendent) DATE: --, MAR t~7 799;~ .OJJ.& Gas Cons, Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 February 23, 1993 Michael Zanghi Drilling Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit AGI-8 BP Exploration Permit No: 93-33 Sur. Loc. 2409'NSL, 2536'WEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 339'SNL, 653'WEL, Sec. 31, T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 0~ l[)rinle(ll on recycled [)al)ur STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 fla. Type of work Drill [] Redrill CIIlb. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) ~10. Field and Pool ARCO Alaska, Inc. KBE = 36'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 34628 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.o25) 2409' NSL, 2536' WEL, SEC. 36, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 430' SNL, 900' WEL, SEC. 31, T12N, R15E AGI-8 U-630610 At total depth 9. Approximate spud date Amount 339' SNL, 653' WEL, SEC. 31, T12N, R15E 2/28/93 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 4939' feet AGI-4-478'@ 500'MD feet 2560 11546' MD/8464' TVDieet 16. To be completed for deviated wells 17. Anticipated pressure (s~e 20 AAC 25.035 (.,)(2)) Kickoff depth 5oofeet Maximum hole unpile49.22° Maximum surface 3330psig At total depth (TVD) ~l~l~)O'/4390pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5~ H-40 Weld 76' 30' 30' 106' 106' 11 yds Arcticset 16" 13-3/8" 68~ L-80 B TC 3917' 29' 29' 3946' 3500' 1102 sx "E"/400 sx "G"/250 sx "C" 12-1/4" 9-5/8" 47# L-80 NSCC 10898' 28' 28' 10926' 8059' 500 sx Class "G" 8-1/2" 7" 26# L-80 NSCC 770' 10776' 7965' 11546' 8464' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIV~D Conductor Surface Intermediate F'~_ B Production Liner Alaska Oil & Gas Cons. Co[~rniss~ot~ Perforation depth: measured Anch0rag(~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certify t~at t,t,t~e fo/egoing is true and correct to the/o/~/l~st of my knowledge Date~ Si.qnedy[- '~,,~._ Title "t~r~" lling Engineer Supervisor Commission Use Only Permit Number IAPI number IAppr_oval date ISee cover letter i50- .z?- ~z.~' 5/~' J ~:~.--~..-~'~'~ Jfor other requirements Conditions of approval Samples requ, ir. ed [] Yes ~]'NO Mud Icg required []Yes .[~ No ,Hydrogen sulfide measures [] Yes ~ No Directional survey requ~reo ~ Yes [] No Required working pressure for BOPE []2M; I-'i3M; ,[~5M; I-I10M; l"]15M; Other: Original S~'Oned BY by order of Approved by [}avid W. johnston Commissioner me commission Date~:;,', Form 10-401 Rev. 12-1-85 Submit in triplicate ',,.'Ceil: Field: Engineer: Work Sheet: Bate: ~,/.. C. emen! 'Volume LTalc4¢lalion.~ Casing Type Casing Size Casing LenCh Hole Diameter Cement-Yield Cemer,,t - Cubic It cement Cubic ¢' Cement- Sacks Cement-View Cement- Cubic it Ceme~.,'¢.- Cubic tt Cement-Sacks -Inches -Feei ~il ~2 ~I2 ~2 ~3 Cement - Yield ~3 Cement- Cubic it~3 Cement- Cubic It:i:i3 Cement-Cubic It /Vol Cement- Fill Factor Conductor 20.000 7o. uuO 30.000 0.000 0.000 0.000 297.000 0.0'00 0.000 0.000 O. uuO 297.000 i.433 S~face 13.375 3,917.000 1G.000 1,102.000 2.'170 2,39! .340 2,391.340 400.000 l.lGO 4G4.000 4G4.000 0.000 0.000 0.000 0.000 2,855.340 1.733 0.000 O. O00 0.000 0.000 0.000 0.000 O. OOO O. 000 0.000 0.000 0.000 0.001.! ~DIV/0! Casing Type Casing Size -Inches Casing Depth- Feet Hole Diarnete~ -inches Cement-Sa,.,ks Cement-Yield Cement- Cubic ft '.41 Cement-Cubic f( Cement- Sacks ~2 CamarO. - Yiefd~2 Cement. - Cubic ,,'{ ~2 Cement Cubic ...ement- Yacks Cement-Yield :I:13 Cement- Cubic fi. ~3 Cement- Cubic ft ,._.~¢m" .... - Cubic fi / Vol Cement- inte;vai ft Top of Cement- Feet Intermediab ~! 0.000 0.000 O000 0.OO 0.00 0.00 0.00 0.00 0.00 O. O0 0.00 O. O0 0.00 0.00 0.00 U. LIU ~DiV/0! Intermediate ~I2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. iXi ~IDIV/O! ~.D!V/O! Pm¢.~ction 9.825 10,926.000 '! 2. 250 500.00 '! .05 525.00 F.. 9F. ' ,.,_u.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 525.0[} ! ,.G76.34 WELL PLAN Well: APEX GAS INJECTOR #8 (AGI #8) LOCATION: Surface: Target: T.D,: 2409' FSL, 2536' FEL, Sec. 36, T12N, R14E 430 ' FNL, 900' FEL, Sec. 31, T12N, R15E 339 ' FNL, 653 FEL, Sec. 31, T12N, R15E ESTIMATED START: 28FEB93 OPR. DAYS TO COMPLETE: 20 (16 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUlLD/MAX DEP: 49.22°/N69.43°W/500'/1.5° per 100' MD/7Z04' Estimated Ground level elevation is 1 Item 3' AMSL. KB to ground level elevation is 36'. TVD(_BKB) MD(BKB) mud Wt. 20" CONDUCTOR 106 106 8.5 13-3/8" SHOE 3500 3946 9.0 9-5/8" SHOE 8059 10926 9.2-10.0 TOP SADLEROCHIT 8064 10934 9.2-10.0 7" SHOE 8464 11546 9.2-10.0 TARGET 8239 11202 9.2-10.0 TOTAL DEPTH 8464 11546 9.2-10.0 CASING PROGRAM: Hole Cs_o Wt Grade Conn Length Top 30" 20" 91.5# H-40 WELD 76 30 16" 13-3/8" 68# L-80 BTC 3917 29 12-1/4" 9-5/8" 47# L-80 NSCC 10898 28 8-1/2" 7" 26# L-80 NSCC 770 10776 Btm 106 3946 10926 11546 COMPLETION: Tubing: 7" GLMs: None Packer: LOGGING PROGRAm: 26# 1-80 NSCC 10699 27 10726 9-5/8" x 5-1/2" PERMANENT PACKER set at 10726 MD or +/- 50' above Top of liner Open Hole 12-1/4" hole: 8-1/2" hole GR/RESISTIVITY WHILE DRILLING TO PICK CASING POINT. GR/RESISTIVITY WHILE DRILLING ACROSS SADLEROCHIT Cased Hole SBT IN 9-5/8" before running tubing (GR to be run up to 13-3/8") RECEIVED kJaska Oil & Gas Cons. Anchorag~ , PEX GAS INJECTOR #8 (AGI DRILLING DISCUSSION AGI #8 is the eighth of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the additional gas injection requirements associated with the GHX-2 project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the Ivishak sand injection interval (target interval) comprised of Zones 1, 2, 3, and partially truncated Zone 4. Ivishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2" tailpipe will be the completion assembly. ANNULAR INJECTION The 13-3/8" x 9-5/8" annulus of AGI #2, AGI #3, AGI #4, AGI #5, AGI #6, and AGI #7 may be available for injection purposes. Ensure any annulus has been properly permitted before commencing injection. The 13-3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. ADEC has informed Prudhoe Bay Drilling that only associated fluids from drilling operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. SHUTDOWN OF WELL OPERATIONS Shutdown of well operations once 9-5/8" casing has been set and cemented is planned for wells AGI #3 thru AGI #9. Wells AGI #3- AGI #9 will be drilled to 12-1/4" hole TD, 9-5/8" casing run and cemented. At this time operations will be shutdown and the rig will move to the next well and repeat the process. AGI #10 will be drilled to 8-1/2" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/2" hole, running 7" liner and completing all the wells in which operations were shutdown. As per conversation with AOGCC (B. Wondzell) on 30DEC92 shutdown and resumption of well operations approval will be included as part of the permit approval-as long as the process is outlined in the PROPOSED DRILLING AND COMPLETION PROGRAM associated with this package-and therefore no application for sundry approval will be necessary for shutdown/resumption of operations. The decision to drill AGI #3- AGI #10 as described above is based solely on economics and therefore dictated by prudence alone. There are no known hydrocarbon bearing sands between surface and 9-5/8" casing point in any of the AGI wells. All 9-5/8" casing points are estimated to be above the top of the Sadlerochit sands. Operations on AGI #8 are expected to resume on or about 14MAY93. All ten wells are estimated to be drilled and completed by 19MAY93. If there are any questions or if further information is required please contact J. E. Robertson at 564- 5510. FREEZE PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES WELLNAME SLOT DISTANCE DEPTH (' TVD) AGI #3 AGI #3 599' AGI #4 AGI #4 478' AGI #5 AGI #5 360' AGI #6 AGI #6 240' AGI #7 AGI #7 120' LGI #10 LGI #10 523' 500' TVD 500' TVD SURFACE SURFACE SURFACE Anchorage PROPOSED DRILLING AND COMPLETION PROGRAM AGI #8 Procedure · MIRU drilling rig. Notify AOGCC of upcoming diverter function test. N/U diverter and function test same· . . Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 2500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. seawater Bump cementing plug with . RIH to 2000' MD and displace to diesel. ND 8OPE. NU dryhole tree and test to 5000 psi. SHUTDOWN OPERATIONS. Release rig. Move off. · RESUME OPERATIONS. MIRU. Notify AOGCC of upcoming BOPE TEST. ND dryhole tree and NU BOPE. Test BOPE. . 10. 11. RIH. Displace diesel cap w/seawater. Drill to 9-5/8" shoe. Displace wellbore w/"drill in" mud. Continue drill/LOG 8-1/2" hole through reservoir to TD. IVlU 7" liner on 5" DP. RIH to TD. Displace wellbore w/completion fluid. Set liner hanger and liner top packer. POOH. Run 7", L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. 12. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: 3850 psi @ 8800' TVD SS 2970 psi 8.6 PPG SEAWATER Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. No potential productive zones are anticipated above 9-5/8" casing shoe. d. No potential hazardous levels of H2S are anticipated in this well. E.C'EJVED Alaska Oil & Gas Con, s. Commission Anchorage MUD PROGRAM: Well AGI #8 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~3 O0 < 100 YP lbs/100ft2 40- 60 20- 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 rain Gel lbs/100ft2 60- 80 20- 30 pH - 9.0 - 10 9.0 - 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 rain Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 min 6-8 pH - 8.5 - 10.0 Hardness mg/I <200 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point Ibs/lO0ft2 20- 30 10 sec Gel lbs/100ft2 18 - 22 10 rain Gel lbs/100ft2 20 - 24 APl Fluid loss mi/30 min 6.0 - 8.0 pH - 9.5 - 10.0 Hardness mg/I <200 The mud salinity should be compatible with the Reservoir logging program. The mud will be run at _+40,000 ppm chlorides. RUN LOW SHEAR RATE VISCOSITY AT 40,000+ Centipoise on mud system. AGI #8 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 1-80 5020 2260 PBYS (#) 1069000 1556000 TJYS (#) 1300000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SI PRESSURE 14 3500 2198 Burst S.F. 1.57 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S.F. 1,31 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 3946 PBYS Tension S.F. 4.66 Mud Wt. 9.5 ppg TJYS 5.67 String Wt. (#) 229367 AGI #8 Casing Design Production Casing 9-5/8", 47#,L-80, NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3850 Burst S.F. 1.78 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/fi) Collapse press 10.2 8059 0.1 3469 Collapse S,F. 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 10926 PBYS Tension S.F. 2.51 Mud Wt. 10.2 TJYS 2.68 String Wt. (#) 433464 i,,.. OtJ- Oil & Gas Co,.~.' '",~ Cor.,-H-oissior~ AGI #8 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3942 3850 Burst S.F. 1,84 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (F-r) (psi/ft) Collapse Press 10.2 8464 0.1 3643 Collapse S.F. 1.49 Tension Calculation Based on full string weight in mud Casg Wt. (#irt) MD (FT) 26 770 Mud Wt. String Wt. (#) 10.2 16899 Tension S.F. PBYS TJYS 35.74 39.47 i~i~cho!'a,rj~ CEMEN ,' PROGRAM - HALLIBURTON SERVICES 13 3/8" SURFACE CASING CASING SIZE: '13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a j- WEIGHT: 12.0 ppg ~' YIELD:2.17 ft3/sx APPROX #SACKS: 1102 PUMP TIME: 4:30 hfs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride J WEIGHT: 15.8 ppg YIELD: 1.1 ~ ft3/sx APPROX #SACKS: 400 ~'~ PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TypE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx APPROX #SACKS: 250 PUMP TIME: 2:30 hrs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. From top of tail to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F TAIL CEMENT TYPE: CLASS G 9 5/8" INTERMEDIATE CASING ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5,00 gps FW APPROX #SACKS: 500 PUMP TIME: 4 hrs Mix water temp: 70-80 F SPACERS: Pump 20 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix tail slurry. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show. 2. Tail Slurry to 1000' MD above shoe w/30% excess. Prudhoe Prudhoe AGI-08 VERTICAL SCALE 1 0 0 0 REFERENCE: 500q Bay Bay Drilling VIEW ?±, / R,K,B, DIVISION 0.00° ~ 0 MD R,K,B. ELEVAFIBN 49' ABOVE SEA LEVEL TRUE 3o.15 doO. E,,~t ~,~.~o~ ] 49.82' ~ 3946 MD 13-3/8' CSG. PT. 0.00° 8 500 MD KICK-OFF POINT/BUILD !,5/]00 3.00' 9 700 MD 6.00° 8 900 MD 9.00' ~ I100 H~ la,O0' 8 1300 MD 15.00' ~ 1500 MD 18.00' ~ 1700 MD 21 O0' ~ 1900 MD 24.00' e 2100 MD 27.00' ~ 2300 MD 3O,OO' ~ 2500 MD 33.00' ~ 8700 MD 36.00' 8 2900 MD 39.00' 8 3100 ND 48.00' ~ 3300 MD 45.00' ~ 3500 MD 1325 49.28' @ 3781 MD END OF BUILD 1450 [ ' HDRIZFINTAL SCALE 5 O0 REFERENCE: 00 VIEW ?t, ,/ D!V!S!UN WELL HEAD , 500 1000 1500 2000 8500 3000 3500 4000 4500 5000 5500 6000 6500 7000 3000 '~8500 ---8000 --1500 --1 000 '--500 0 503 C~ITI£AL POINT DAT~ il MD JnC Azl TVD Nor~ Eos R.K,B. ELEVATION 49' 0,00 0.00 0 KDP / 1.5/100 500 0,00 0,00 500 O END OF BUILD 3781 49,2269,433392 465 1240 13-3/8' CSG. PT,3946 49,2269,433500 509 135~ 9-5/8' CSG. PT,10926 49.2269.438059 23~6 6306 TOS 10934 TARGET 11202 BASE SAD/KAVIK 11470 49.2~ 69,43 8414 2511 6691 TOTAL DEPTH 11546 BHL DATA J TVD 8464.00J ~r~h 11546.1~ VS 7804,5~ 2531.2~ Eost 6745,2~ SURFACE LOCAT[BN 2409' FSL~ 2536' FEL SEC. 36~ TISNj RI4E ASP,Y = 5980046.82 X : 688733.98 TARGET LOCATION 430' FNL~ 900' FEL SE6. 31; TISN; R15E ASP, Y = 5982652.07 X = 695170.~1 ~OffOHHOLE LOCATION ASP~ Y= 5988750.05 X = 695411.96 6735 674t 6944 7147 7804 1000 2000 3000 4000 5000 6000 7000 8000 49.82' 8 10926 MD 9-5/8' CSG. PT, 49.22' 8 t0934 MD TOS "x~ 49.88' 8 11202 MD TARGET 49.22' @ 11470 HD BASE SAD/KAVIK 49.22' 8 11546 MD TOTAL DEPTH VERTICAL SECTION PLANE: 69,43° Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 69.43 deg. Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.21.00.81 N - Long. 148.28.03.29 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (feet): 59800!6.82 N 688733.98 E Vertical Section Reference: WELL~ ! EAD Closure Reference: WELLHEAD North Aligned To: TRUE NORTH Page 1 Date: 1/29/93 Wellpath ID: AGI-08WP Last Revision: 1/29/93 Prudhoe Bay Drilling Prudhoe Bay AGI AGI-08 AGI-08WP2 Measured Incl Drift TVD Subsea Depth Dir. Depth (ft) (deg.) (deg.) (ft) (ft) R. ICB. ELEVATION 49' ABOVE SEA LEVEL 0.00 0.00 0.00 0.00 -49.00 100.00 0.00 0.00 100.00 51.00 200.00 0.00 0.00 200.00 151.00 300.00 0.00 0.00 300.00 251.00 400.00 0.00 0.00 400.00 351.00 KOP/BUILD 1.5/100 500.00 0.00 0.00 500.00 451.00 600.00 1.50 69.43 599.99 550.99 700.00 3.00 69.43 699.71 650.91 800.00 4.50 69.43 799.69 750.~9 900.00 6.00 69.43 899.27 850.27 1000.00 7.50 69.43 998.57 949.57 1100.00 9.00 69.43 1097.54 1048.54 1200.00 10.50 69.43 1196.09 1147.09 1300.00 12.00 69.43 1294.16 1245.16 1400.00 13.50 69.43 1391.70 1342.70 1500.00 15.00 69.43 1488.62 1439.62 1600.00 16.50 69.43 1584.86 1535.86 1700.00 18.00 69.43 1680.36 1631.36 TOTAL Rectangular Offsets (ft) (rt) 0.00N 0.00 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 0.00N 0.00 0.00 N 0.00 0.46 N 1.23 1.84N 4.90 4.14N 11.02 7.35 N 19.59 11.48N 30.59 16.¢2 N 44.03 22.47 N 59.88 29.33 N 78.15 37.08N 98.81 45.73N 121.86 55.26N 147.27 65.68 N 175.03 Geographic Coordinates Latitude / Longitude E 70.21.00.8063N 148.28.03.2853W E 70.21.00.8063N 148.28.03.2853~ E 70.21.00.8063N 148.28.03.285JW E 70.21.00.8063N 148.28.03.2853W E 70.21.00.8063N 148.28.03.2853W E 70.21.(hL8063N148.28.03.2853W E 70.21.00.8103N 148.28.03.2495W E 70.21.00.8244N 148.28.03.1421W E 70.21.00.8470N 148.28.02.9631W E 70.21.00,8786N1,l~ 28.02.7127W E 70.21A~0,9192N 148.28.02.3911W E 7~.21.00.9688N 148.28.01.9985W E 70.21.01.0273N148.28.01.5352W E '70.21.01,0947N148.28.01.0014W E 70.21.01.1710N 148.28.00.3975W E 70.21.01.2560N148.27.59.7240W E 70.21.01.3498N148.27.58.9813W E 70.21.01.4523N148.27.58.1699W GRID Coordinates Closure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5980046.83 688733.98 0.00~ 0.00 5980046.83 688733.98 0.00~ 0.00 5980046.83 688733.98 0.00~ 0.00 5980046.83 688733.98 0.00~ 0.00 5980046.83 688733.98 0.00~ 0.00 5980046.83 688733.98 0.00~ 0.00 5980047.32 688735.19 1.31~ 69.43 5980048.79 688738.83 5.23(~ 69.43 5980051.24 688744.90 11.77~ 69.43 5980054.67 688753.38 20.92~ 69.43 5980059.08 688764.28 32.68~ 69.43 5980064.45 688777.58 47.03~ 69.43 5980070.80 688793.28 63.96~ 69.43 5980078.11 688811.36 83.47~ 69.43 5980086.38 688831.82 105.54~ 69.43 5980095.61 688854.64 130.15~ 69.43 5980105.78 688879.81 157.30~ 69.43 5980116.90 688907.30 186.95(~ 69.43 Ve~ical Section (n) 0.00 0.00 0.00 0.00 0.00 0.00 1.31 5.23 11.77 20.92 32.68 47.03 63.96 83.47 105.54 130.15 157.30 186.95 DLS (dg/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 Smith International, Inc. Measured Incl Drift TVD Subsea Depth Dir. Depth (f0 (deg.) (deg.) (ft) (ft) Proposal Report Page 2 Date: 1/29/93 Wellpath ID: AGI-08WP TOTAL Rectangular Offsets (ft) (ft) Geographic Coordinates Latitude / Longitude GRID Coordinates Northing Easting (ft) (ft) Closure Dist. Dir. (ft) deg. Vertical Section (ft) DLS (dg/100ft) 1800.00 19.50 69.43 1775.05 1726.05 1900.00 21.00 69.43 1868.86 1819.86 2000.00 22.50 69.43 1961.74 1912.74 76.98N 205.13 E 89.14N 237.53 E 102.15N 272.22 E 70.21.01.5634N 148.27.57.2904W 70.21.01.6830N 148.27.56.3433W 70.21.01.8110N 148.27.55.3294W 5980128.94 688937.10 5980141.92 688969.18 5980155.81 689003.53 219.09~ 69.43 253.706 69.43 290.76~ 69.43 219.09 253.70 290.76 1.50 1.50 1.50 2100.00 24.00 69.43 2053.62 2004.62 2200.00 25.50 69.43 2144.43 2095.43 2300.00 27.00 69,43 2234.~2 2185.12 116.02N 309.18 E 130.73N 348.38 E 146.27N 389.78 E 70.21.01.9474N148.27.54.24)3W 70.21.02.0921N 148.27.53.1038W 70.21.02.2449N 148.27.51.8936W 5980170.60 689040.13 5980186.29 689078.94 5980202.87 689119.94 330.236 69.43 372.106 69.43 416.326 69.43 330.23 372.10 416.32 1.50 1.50 1.50 2400.00 28.50 69.43 2322.61 2273.61 2500.00 30.00 69.43 2409.86 2360.86 2600.00 31.50 69.43 2495.80 2446.80 2700.00 33.00 69.43 2580.37 2531.37 2800.00 34.50 69.43 2663.51 2614.51 2900.00 36.00 69.43 2745.17 2696.17 162.63N 433.38 E 179.79N 479.12 E 197.76N 526.99 E 216.50N 576.95 E 236.02N 628.96 E 256.30N 683.00 E 70.21.02.4058N 148.27.50.6196W 70.21.02.5746N 148.27.49.2826W 70.21.02.7513N 148.27.47.8836W 70.21.02.9357N 148.27.46.4235W 70.21.03.1276N 148.27.44.9033W 70.21.03.3270N 148.27.43.3241W 5980220.33 689163.11 5980238.64 689208.40 5980257.81 689255.80 5980277.8i 689305.27 5980298.63 689356.77 5980320.27 689410.27 462.88~ 69.43 511.756 69.43 562.876 69.43 616.23~ 69.43 671.79~ 69.43 729.50~ 69.43 462.88 511.75 562.87 616.23 671.79 729.50 1.50 1.50 1.50 1.50 1.50 1.50 3000.00 37.50 69.43 2825.30 2776.30 3100.00 39.00 69.43 2903.83 2854.83 3200.00 40.50 69.43 2980.71 2931.71 3300.00 42.00 69.43 3055.89 3006.89 3400.00 43.50 69.43 3129.32 3080.32 3500.00 45.00 69.43 3200.95 3151.95 277.32N 739.01E 299.07N 796.97 E 321.54N 856.84 E 344.70N 918.57 E 368.55N 982.12 E 393.06N 1047.45 E 70.21.03.5338N 148.27.41.6869W 70.21.03.7477N 148.27.39.9929W 70.21.03.9686N 148.27.38.2433W 70.21.04.1965N 148.27.36.4391W 70.21.04.4310N148.27.34.5817W 70.21.04.6721N 148.27.32.6724W 5980342.70 689465.74 5980365.91 689523.13 5980389.88 689582.41 5980414.60 689643.53 5980440.05 689706.45 5980466.21 689771.14 789.33~ 69.43 851.24~ 69.43 915.186 69.43 981.116 69.43 1048.99~ 69.43 1118.776 69.43 789.33 851.24 915.18 981.11 1048.99 1118.77 1.50 1.50 1.50 1.50 1.50 1.50 3600.00 46.50 69.43 3270.73 3221.73 418.23N 1114.51E 3700.00 48.00 69.43 3338.60 3289.60 444.03N 1183.26 E END OF BUILD 3781.34 49.22 69.43 3392.38 3343.38 465.47N 1240.39 E 70.21.04.9196 N 148.27.30.7123W 70.21.05.1734N 148.27.28.7030W 70.21.05.3842N 148.27.27.0332W 5980493.06 689837.54 5980520.59 689905.61 5980543.47 689962.18 1190.40~ 69.43 1263.83~ 69.43 1324.85~ 69.43 1190.40 1263.83 1324.85 1.50 1.50 1.50 3881.34 49.22 69.43 3457.70 ~408.70 ,192.07N 13-3~" CSG. PT. 3946.10 49.22 69.43 3500.00 3451.00 509.30N 3981.34 49.22 69.43 3523.01 3474.01 518..6§N 1311.29 E 70.21.05.6459N148.27.24.9611W 1357.20E 70.21.05.8153N148.27.23.6192W 1382.18 E 70.21.05.9075N 14g.27.22.8890W 5980571.87 690032.38 5980590.25 690077.84 5980600.26 6901~2.57 1400.576 69.43 1449.616 69.43 1476.30~ 69.43 1400.57 1449.61 1476.30 0.00 0.00 0.00 4081.34 49.22 69.43 3588.33 3539.33 545.28N 4181.34 49.22 69.43 3653.65 3604.65 571.88N 4281.34 49.22 69.43 3718.96 3669.96 598.49N , 4381.34 49.22 69.43 3784.28 3735.28 625.09N 4481.34 49.22 69.43 3849.59 3800.59 651.70N 4581.34 49.22 69.43 3914.91 3865.91 .678.30N 1453.08 E '/0.21.06.1692N148.27.20.8169W 1523.97 E 70.21.06.4308N148.27.18.7448W 1594.87E 70.21.06.6925N148.27.16.6727W 1665.76 E 70.21.Ot,.9542N148.27.14.6006W 1736.66 E 70.21.07.2158N148.27.12.5285W 1807.55 E 70.21.07.4775N148.27.10.4564W 5980628.65 690172.77 5980657.05 690242.96 5980685.44 690313.16 5980713.84 690383.35 5980742.23 690453.55 5980770.63 690523.74 1552.02~ 69.43 1627.74~ 69.43 1703.466 69.43 1779.19~ 69.43 1854.916 69.43 1930.63~ 69.43 1552.02 1627.74 1703.~6 1779.19 1854.91 1930.63 0.00 0.00 0.00 0.00 0.00 0.00 Smith International, Inc. Proposal Report Measured Incl Drift TVD Subsea Depth Dir. Depth (fl) (deg.) (deg.) (ft) TOTAL Rectangular Offsets (ft) (rt) 4681.34 49.22 69.43 3980.22 3931.22 704.90N 1878.45 E 4781.34 49.22 69.43 4045.54 3996.54 731.51N 1949.34 E 4881.34 49.22 69.43 4110.85 406!.85 751LIIN 2020,24 E 4981.34 49.22 69.43 4176.17 4127.17 784.72N 2091.13 E 5081.34 49.22 69.43 424t.49 4192.49 811.32N 2162.03 E 5181.34 49.22 69.43 4306.80 4257.80 837.92N 2232.92 E 5281.34 49.22 69.43 4372.12 4323.12 864.53N 231}3.82 E 5381.34 49.22 69.43 4437.43 4388.43 891.13N 2374.71E 5481.34 49.22 69.43 4502.75 4453.75 917.74N 2445.61E 5581.34 49.22 69.43 4568.06 5681.34 49.22 69.43 4633.38 5781.34 49.22 69.43 4698.69 5881.34 49.22 69.43 4764.01 5981.34 49.22 69.43 4829.32 6081.34 49.22 69.43 4894.64 6181.34 49.22 69.43 4959.96 6281.34 49.22 69.43 5025.27 6381.34 49.22 69.43 5090.59 6481.34 49.22 69.43 5155.90 6581.34 49.22 69.43 5221.22 6681.34 49.22 69.43 5286.53 6781.34 49.22 69.43 5351.85 6881.34 49.22 69.43 5417.16 6981.34 49.22 69.43 5.!82.48 7081.34 49.22 69.43 5547.80 7181.34 49.22 69.43 5613.11 7281.34 49.22 69.43 5678.43 7381.34 49.22 69.43 5743.74 7481.34 49.22 69.43 5809.06 7581.34 49.22 69.43 5874.37 7681.34 49.22 69.43 5939.69 7781.34 49.22 69.43 6005.00 4519.06 944.34N 2516.50 E 4584.38 970.94N 2587.40 E 4649.69 997.55N 2658.29 E 4715.01 11}24.15N 2729,19 E 4780.32 11}50.76N 2800.08 E 4845.64 1077.36N 28711.98 E 4910.96 111}3.96N 2941.87 E 4976.27 1130.57N 3012.77 E 5041.59 1157.17N 3{}83.66 E 5106.90 1183.78N 3154.56 E 5172.22 1210.38N 3225.45 E 5237.53 1236.98 N 3296.35 E 5302.85 1263.59 N 3367.24 E 5368.16 1290.19N 3438.14 E 5433.48 1316.80N 3509.03 E 5498,80 1343.40N 3579.93 E 5564.11 1370.00N 3650.82 E 5629.43 1396.61N 3721.72 E 5694.74 1423.21N 3792.61E 5760.06 1449.82N 3863.51E 5825.37 1476.42N 3934.40 E 5890.69 15{13.02N 4005.30 E 5956.00 1529.63N 4076.19 E Geographic Coordinates Latitude / Longitude 70.21.07.7391N 148.27.08.3843W 70.21.08.0008N148.27.06.3121W 70.21.08.2624N148.27.04.2400W 70.21.08.5241 N 148.2 ,',02.1678W 70.21.08.7857 N 148.27.00.0956W 71}.21.09.0474 N 148.26.58.0235W 70,21.09.3090 N 148.26.55.9513W 70.21.09.5707 N 148.26.53.8791W 70.21.1}9.8323 N 148.26.51.8069W 70.21.10.0940N148.26.49.7347W 70.21.10.3557N 148.26.47.6625W 70.21.10.6173NI48.26.45.5903W 70.21.10.8791} N 1.48.26.43.5181W 70.21.11.14116 ?'i I ~8.26.41.445~7W 7t}.21.11.4{123 N 148.26.39.3736W 70.21.11.6639 N 148.26.37.3014W 71}.21.11.9256 N 148.26.35.2291W 70.21.12.1872N 148.26.33.1569W 70.21.12.4489 N 148.26.31.0846W 70.21.12.7105N 148.26.29.0123W 70.21.12.9722 N 148.26.26.9400W 70.21.13.2338 N 148.26.24.8678W 71}.21.13.4955 N 148.26.22.7955W 70.21.13.7571N 148.26.20.7232W 70.21.14.0188NI48.26.18.6509W 70.21.14.2805N 148.26.16.5785W 70.21.14.5421N 14~:.26.14.5062W 70.21.14.8038N 148.26.12.4339W 70.21.15.0654 N 148.26.10.361~V 70.21.15.3271N 148.26.08.2892W 70.21.15.5887 N 148.26.06.2168W 711.21.15.850,! N ! 48.26.04.1445W ..,, GRID Coord~ates Closu~ ~odhiag Easting Dbt. Dir, (f0 (f0 fit) Vertical Section (ft) 5980799.03 690593.93 2006.35~ 69.43 2t)06.35 5980827.42 690664.13 2082.08(~ 69.43 2082.08 5980855.82 690734.32 2157.80~ 69.43 2157.80 5980884.22 690804.51 2233.52~ 69.43 2233.52 5980912.62 690874.71 2309.24~ 69.43 2309.24 5980941.02 690944.90 2384.96~ 69.43 2384.96 5980969.43 691015.09 2460.69~ 69.43 2460.69 5980997.83 691085.28 2536.41~ 69.43 2536.41 5981026.23 691155.47 2612.13~ 69.43 2612.13 5981054.63 691225.67 2687.85(~ 69.43 2687.85 5981083.04 691295.86 2763.58~ 69.43 2763.58 5981111.44 691366.05 2839.30~ 69.43 2839.30 5981139.85 691436.24 2915.02~ 69.43 2915.02 5981168.25 691506.43 2990.74~ 69.43 2990.74 5981196.66 691576.62 3066.47~ 69.43 3066.47 5981225.07 691646.81 3142.19~ 69.43 3142.19 5981253.48 691717.00 3217.91~ 69.43 3217.91 5981281.89 691787.19 3293.63~ 69.43 3293.63 5981310.29 691857.38 3369.36~ 69.43 3369.36 5981338.70 691927.57 3445.08~ 69.43 3445.08 5981367.12 691997.75 3520.80~ 69.43 3520.80 5981395.53 692067.94 3596.52~ 69.43 3596.52 5981423.94 692138.13 3672.25~ 69.43 3672.25 5981452.35 692208.32 3747.97~ 69.43 3747.97 5981480.77 692278.50 3823.69~ 69.43 3823.69 5981509.18 692348.69 3899.41~ 69.43 3899.41 5981537.59 692418.88 3975.14~ 69.43 3975.14 5981566.01 692489.07 4050.86(~ 69.43 4050.86 5981594.43 692559.25 4126.58~ 69.43 4126.58 5981622.84 692629.44 4202.30~ 69.43 4202.30 5981651.26 692699.62 4278.03~ 69.43 4278.03 5981679.68 692769.81 4353.75~ 69.43 4353.75 Page 3 Date: 1/29/93 Wellpath ID: AGI-08WP DLS (dg/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Smith International, Inc. Measured lncl Drift TVD Subsea Depth Dir. (ft) (deg.) (deg.) (ft) Proposal Report T O T A L Geographic Coordinates Rectangular Offsets Latitude / Longitude (ft) (ft) .... .,-, ", C: 4~ ,: ' ' GRID Coordinates Closu~ Northing Easting Dist. Din (u) (r0 (rt) deg. Vertical Section (ft) Page 4 Date: 1/29/93 Wellpath ID: AGI-08WP DLS (dg/lOOft) 7881.34 49.22 69.43 61}70.32 7981.34 49.22 69.43 6135.63 8081.34 49.22 69.43 6200.95 6021.32 1556,23N 4147.09E 70.21.16.1120NI48.26.02.0721W 5981708.10 692839.99 4429.47~ 69.43 4429.47 6"~',,,:~.c,,:~, l~S2,84N 4217.9gE 70.21.16.3737NI48.25.59.9997W 5981736.52 692910.18 4505.19~ 69.43 4505.19 61:~,~,'~:'', 1609.44N 4288.88E 70.21.16.6353NI48.25.57.9274W 5981764.94 692980.36 4580.921~ 69.43 4580.92 0.00 0.00 0.00 8181.34 49.22 69.43 6266.27 8281.34 49.22 69.43 6331.5~ 8381.34 49.22 69.43 6396.90 6~17.27 1636.04N 4359.78 E 70.21.16.8970N148.25.55.8550W 5981793.36 693050.55 4656.64~ 69.43 4656.64 6282.58 1662.65N 4430.67 E 70.21.17.1586NI48.25.53.7826W 5981821.78 693120.73 4732.36~ 69.43 4732.36 6347.90 1689.25N 4501.57 E 70.21.17.4203NI48.25.51.7102W 5981850.20 693190.92 4808.081~ 69.43 4808.08 8481.34 49.22 69.43 6462.21 6413.21 17!5.86N 4572.46 E 70.21,17.6820N148.25.49.6378W 5981878.62 693261.10 4883.81~ 69.43 4883.81 8581.34 49.22 69.43 6527.53 6478.53 1742.46N 4643.36 E 70.21.17.9436N148.25.47,5653W 5981907.05 693331.28 4959.531~ 69.43 4959.53 8681.34 49.22 69.43 6592.84 6~3.84 1769.06N 4714.25 E 70,21.18.2053NI48.25.45.4929W 5981935.47 693401.47 5035.25~ 69.43 5035.25 0.00 0.00 0.00 0.00 0.00 0.00 8781.34 49.22 69.43 6658.16 6609.16 1795.67N 4785.15 E 70.21.18.4669N 148.25.43.4205W 5981963.90 693471.65 5110.97~ 69.43 5110.97 8881.34 49.22 69.43 6723.47 6674.47 1822.27N 4856.04 E 70.21.18.7286N148.25.41.3480W 5981992.32 693541.83 5186.69~ 69.43 5186.69 8981.34 49.22 69.43 6788.79 6739.79 1848.88N 4926.94 E 70.21.18.9902NI48.25.39,2756W 5982020.75 693612.01 5262.42~ 69.43 5262.42 0.00 0.00 0.00 9081.34 49.22 69.43 6854.10 68115.10 1875.48N 4997.83 E 711.21.19.2519NI48.25.37.2031W 5982049.17 693682.20 5338.14~ 69.43 5338.14 9181.34 49.22 69.43 6919.42 68711.42 1902.08 N 5{}68.73 E 7t}.21.19.5135N 148.25.35.1307W 5982077.60 693752.38 5413.86~ 69.43 5413.86 9281.34 49.22 69.43 6984.74 6935.74 1928.69N 5139.62 E 711.21.19.7752N 148.25.33,0582W 5982106.03 693822.56 5489.58~ 69.43 5489.58 0.00 0.00 0.00 9381.34 49.22 69.43 7050.05 7001.05 1955.29 N 5210.52 E 70.21.20.0368N 148.25.30.9857W 5982134.46 693892.74 5565.31~ 69.43 5565.31 9481.34 49.22 69.43 7115.37 7066.37 1981.90N 5281.~I E 711.21.20.2985N 148.25.28.9132W 5982162.89 693962.92 5641.03~ 69.43 5641.03 9581.34 49.22 69.43 7180.68 7131.68 211118.511N 5352.31 E 711.21.20.5601N148.25.26.8407W 5982191.32 694033.10 5716.751~ 69.43 5716.75 0.00 0.00 0.00 9681.34 49.22 69.43 7246.00 7197.00 2035.10N 5423.20 E 70.21.20.8218N 148.25.24.7682W 5982219.75 694103.28 5792.47~ 69.43 5792.47 9781.34 49.22 69.43 7311.31 7262.31 2061.711N 5494.10 E 7{}.21.21.0835N 148.25.22.6957W 5982248.18 694173.46 5868.20(~ 69.43 5868.20 9881.34 49.22 69.43 7376.63 7327.63 2{}88.31 N 5564.99 E 70.21.21.3451 N 148.25.20.6232W 5982276.61 694243.64 5943.92~ 69.43 5943.92 0.00 0.00 0.00 9981.34 49.22 69.43 7441.94 7392.94 2114.92N 5635.89 E 70.21.21.6068N148.25.1K5507W 5982305.05 694313.82 6019.64~ 69.43 6019.64 10081.34 49.22 69.43 7507.26 7458.26 2141.52 N 5706.78 E 70.21.21.8684N148.25.16.4782W 5982333.48 694384.00 6095.36~ 69.43 6095.36 10181.34 49.22 69.43 7572.58 7523.58 2168.12N 5777.6~ 2 70.21.22.1301N148.25.14.4056W 5982361.91 694454.18 6171.09~ 69.43 6171.09 0.00 0.00 0.00 10281.34 49.22 69.43 7637.89 7588.89 2194.73 N 5848.57 E 70.21.22.3917 N 148.25.12,3331W 5982390.35 694524.36 6246.81~ 69.43 6246.81 10381.34 49.22 69.43 7703.21 7654.21 2221.33N 5919.,17 E 70.21.22.653,1N148.25.10.2605W 5982418.78 694594.54 6322.53~ 69.43 6322.53 10481.34 49.22 69.43 776~.~2 7719.52 2247.93N 5990.36 E 70.21.22.9150N148.25.08.1880W 5982447.22 694664.72 6398.25~ 69.43 6398.25 0.00 0.00 0.00 10581.34 49.22 69.43 7833.84 7784.84 2274.54N 6061.26 E 70.21.23,1767N148.25.06.1154W 5982475.66 694734.89 6473.98~ 69.43 6473.98 10681.34 49.22 69.43 7899.15 't850.15 23111.14N 6132.15 E 70.21.23.4383N148.25.04,0428W 5982504.09 694805.07 6549.70~ 69.43 6549.70 10781.34 49.22 69.43 7964.47 7915.47 2327.75N 6203.05 E 70.21.23.7000N148.25.01.9702W 5982532.53 694875.25 6625.42~ 69.43 6625.42 0.00 0.00 0.00 10881.3 !~ 49.22 69.43 8029.78 7980.78 2354.35N 6273.9,1 E 70.21.23.9616N 148.24.59.8976W 5982560.97 694945.43 6701.14~ 69.43 6701.14 9-5/8" CSG.PT. Smith International, Inc. Proposal Report Page 5 Date: 1/29/93 Wellpath ID: AGI-08WP Measured Incl Drift TVD Subsea T O T A L Depth Dir. Depth Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) Geographic Coordinates Latitude / Longitude GRID Coordinates Closure Vertical DLS Northing Easting Dist. Dir. Section (ft) (ft) (f0 deg. (ft) (dg/100ft) 10926.07 49.22 69.43 8059.00 8010.I)0 2366.25N 6305.66 E 70.21.24.0787NI48.24.58.9705W 5982573.69 694976.82 6735.02~ 69.43 6735.02 TOS 10933.73 49.22 69.43 8064.00 8015.00 2368.29N 6311.08E 70.21.24.0987NI48.24.58.8119W 5982575.87 694982.19 6740.816 69.43 6740.81 10981.34 49.22 69.43 8095.10 80.46.10 2380.95N 6344.84E 70.21.24.2233Nl,18.24.57.8250W 5982589.41 695015.60 6776.876 69.43 6776.87 0.00 0.00 11081.34 49.22 69.43 8160.41 8111.41 2407.56N 6415.73 E 70.21.24.4849N148.24.55.7524W 5982617.85 695085.78 6852.59~ 69.43 6852.59 11181.34 49.22 69.43 8225.73 8176.73 2434.16N 6486.63E 70.21.24.7466NI48.24.53.6798W 5982646.29 695155.96 6928.316 69.43 6928.31 TARGET 11201.66 49.22 69.43 8239.00 8191}.00 2439.57N 6501.t}3 E 70.21.24.7998NI48.24.53.2587W 5982652.07 695170.21 6943.70~ 69.43 6943.70 0.00 0.00 0.00 1131}1.66 49.22 69.43 8304.32 8255.32 2466.17N 6571.93E 70.21.25.0614N148.24.51.1861W 5982680.51 695240.39 7019.42~ 69.43 7019.42 11401.66 49.22 69.43 8369.63 8320.63 2492.78N 6642.82 E 70.21.25.3231N148.24.49.1135W 5982708.95 695310.57 7095.14~ 69.43 7095.14 KAVIK/B. SAD 11469.59 49.22 69.43 8414.00 8365.00 2510.85N 6690.98 E 71}.21.25.5008N148.24.47.7056W 5982728.27 695358.24 7146.586 69.43 7146.58 0.00 0.00 TOTAL DEPTH 11546.14 49.22 69.43 8464.00 8415.00 2531.21N 6745.25E 70.21.25.7011N148.24.46.1189W 5982750.05 695411.96 7204.55~ 69.43 7204.55 0.00 HFNIZONTAL VIEW SCALE 500 £e, / DIVISI[]N REFERENCE: WELL HEAD :: , . . ~Di s-I;on ce W~lttx~±h SIo't AGIO! ~D AE;]-OL::'M~ D AG]-O,:3 ~]-~WD A~-~ ~-~WD A~-~ ~-~VP A~-~ ~-~P~ A~-07 L~-~ L~-~ L~-~ L~-~ L~-~ L~-~ L~-~ L~-~ L~-IO L~-iO L~-12 L~-12 ~3~-0t n~t~ NP~-~ ~-~ NPBs~-03 WB-O4~D TVD: 0 - 8%1S ~W, In Wemvet, %0 £W, ALt Dimeciions Ret ~o Tmue No~Wh ~,~ ~ 6g.g~ N'u 0.00 0.~ i ~ 240.~ ~69.~ 0.00 0.~ ~ ~.0l ~69.94 0.00 0.~ ~ ~ ,: ¢, ... ,; ..... ,, ', ,, ,~ ';% N/A N/A N/A N/A N/A N/A N/A N/A NVA N/A N/A N/A N/A N/A N/A N/A 583.47 87.4~ 9~.5J.6! 6g00.00 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A I'e'A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A iN/A N/A N/A N/A N/A N/A N/A N/A N/'A N/A N/A N/A N/A N/A N/A smith International, Inc Travelling Cylinder Report Computed by the Sii Win-CADDS Systen Least Distance Method Page 1 Date: 1/28/93 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG] AGI-08 AGI-OSWP2 TVD, N/S and E/W are measured from the WELLHEAD Wel[path Stol Distance AGIO1M~ AGI-~I 838.96 AGI-O2MWD AGI-02 720.02 AGI-O3M~E) AGI-03 598.83 AGI-O4M~/D AGI-04 478.08 AGI-O5M~I~ AGI-05 360.00 AGI-O6WP AGI-06 240.00 AGI-7~/P2 AGI-07 120.01 Closest Points Direction Ref MD Ref TVD 169.95 550.00 550.00 169.94 0.00 0.00 169.91 500.00 500.00 170.95 500.00 500.00 169.94 0.00 0.00 169.94 0.00 0.00 169.94 0.00 0.00 Smith International, Inc. ,, Travelling Cylinder Report ¢omputed by the Sii Win-CADDS Sy~ter; Page 1 Date: 1/28/93 Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AGI AGI-08 AGI-O8WP2 TVD, N/S and E/W are measured from the WELLHEAD We[lpath Slot Distance [101 L1-01' 5515.10 [102 L1-02 5493.04 [109 L1-09 5275.55 [110 L1-10 5253.93 [114 L1-14 5017.78 [115 L1-15 5096.14 [121 L1-21 4916.87 [127 L1-27 4526.08 [128 L1-28 4576.98 [130 L1-30 4328.85 Closest Points Direction Ref MD Ref TVD 183.02 50.00 50.00 181.18 100.00 100.00 182.93 300.00 300.00 181.02 200.00 200.00 174.22 2783.63 2650.00 182.85 0.00 0.00 182.78 0.00 0.00 216.32 4481.96 3850.00 170.18 2546.52 2450.00 167.79 3498.66 3200.00 Pr, udhoe Bo, b,' P~ udhoe ]~o,y A61-08 A6I-O8WPt avel ing ,e Cylindem - kees~ Disfl~ence £epence R/eL~- AOI-O8WP TVD: 0 - 85~8 OW, InlepveL, 50 ~I, AL/ DimecWions AeL io lmue NomWh ET0c ,--. 6oo ,,~ 550 30° / i i ~ !' / / / '. i , i t '. ' , ': . ~ ',. ",.. ", , / / / i ,' f ii : ' '"-. '. " .' ,' / ,, ,' I ,~t , ,...,, '. 'N..~ ~.. i ~ " "' ' " ' " '" ~ ""x " ," ! / ! .. / ' ,; ~ '~ ... ,. -.. ,. -...~._.~ _~__..----" ..' . ~, - , ,.' . . ,' ~ ,, x,, ., , .... ~. .../ ..." ..'"' , ., ," .,"' /., , '. . ',, '.. x~. ~ / /' .' / / / / ~ ' -~ ,, , -. -.. -~ //- ' .,, ,. ,. ~ ; .." ~ ', ~ "x ".. '--.. . ' ,. / ,,' -.. ,/ ' , '-.. ~_ / / , '~ . .. .. -~..._ ~ ." . ., / / z ~, ",,, .~.. ,,,, ',.,.. '~. "-,,... ~~ ~' ,,,,' /., / / /' ,., · ' ..... '"x ' / ".,.... '.. -. "'"-.,.. '- j ~.q-~ L~-02 L~ LGN06 L~-C~ LGi-~0 L~-~2 CLOSEST F~NTS Sio~ LG-02 LG]-EN LG}-OS LG]-08 LG]-IO LG]-I2 'fig:once D, rec-tion Ref ND Ref N/A N/A N/A N/A N/A t~A N/A N/A l'-,V A N/A N/A N/A Nit-. N/A N/A N/A 5_>3.47 87.41 c)~5J.61 N/A N/A N/A N/A ?nudhoe Pr~udhoe iBoy D~, .n9 I._]SMITH I t~i-O4M'UD CLOSEST ~NTS $1o± AG]-O AG] AG] -03 AG]-C)4 AG] AG]-07 Bs±ance D,~ec±ic~ Re£ MD Ref IVD KL/A N/A N/A N/A N/A 'h[/A N/A ~A 5~.83 ] 69.9 ~ 500.~ ~.~ 478.~ ~ 70.~ 500.~ ~.~ 350.09 ] 69.94 0.00 0.~ 840.~ ] 6g.g4 O.OO 0.~ ] ~-O~ ] 69,94 0.00 0.~ Smith International, Inc. Travelling Cylinder Report ,. Computed by the Sii Win-OADDS Syst¢ Least Distance Method Page 1 Date: 1/28/93 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG! AGI-08 AGI-OSWP2 TVD, N/S arcJ E/W ere measured from the WELLHEAD Wetlpath Stot Distance [G!-02 LGI-~2 3784.41 LGI-04 LGI-04 3822.52 LG!-06 LGI-06 1949.73 LG!-08 LG~-08 886.22 LGI-IO LGI-IO 523.47 LGI-!~ LG~-12 2579.07 Closest Points Direction Ref MD Ref TVD 182.85 4788.17 4050.00 166.43 100.00 100.00 145.71 11601.26 8500.00 191.13 11601.26 8500.00 87.41 9151.61 6900.00 218.41 8539.20 6500.00 .. , P~udhoe Say P~ ud½oe Boy Dp,. ,n9 SHITHI 330° --~ 55O 50O 45O 4OO 35O 60o Vellpo-I:h I LGI-05 I LG]-Ce / LG]-~O I LG]-~ CLOSEST POINTS Slot LG]-08 LD -04 LG]-O6 LG]-08 LG]-IO LG]- 180o Ds~cance Di~ec±ion ReF MD Re£ TVD N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 5~3.47 87.4J 915~..6] 6900.00 N/A N/A N/A N/A/I Smith International, Travelling Cylinder Report Computed by the Sii Win-CADDS Syste, Least Distance Method Date: Page 1 1/28/93 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AGI A61-08 AGI-OSWP2 TVD, N/S and E/W are measured from the WELLHEAD Wettpath Slot Distance ngil NGI'~I 8755.25 ngi2 NGI-02 8644.42 ngi3 NGI-03 8534.34 ngi4 NGI-04 7660.32 ngi5 NGI-05 8110.21 ngi6 NGI-06 8204.82 ngi7 NGI-07 8095.42 ngi8 NGI-08 7986.83 ngi9 NGI-09 7877.51 ngilO NGI-IO 7009.42 ngi11 NGI-11 7176.38 ngi12 NGI-12 7553.73 ngi13 NGI-13 7446.49 ngi14 NGI-14 6750.89 Closest Points Direction Ref MD Ref TVD 190.50 50.00 50.00 190.80 200.00 200.00 191.12 50.00 50.00 182.10 7237.82 5650.00 190.34 3359.78 3100.00 192.11 0.00 0.00 192.46 0.00 0.00 192.81 500.00 500.00 193.17 50.00 50.00 209.63 3498.66 3200.00 218.83 2783.63 2650.00 194.34 300.00 300.00 194.75 50.00 50.00 197.31 3570.01 3250.00 ud¼oe ]gay AG]' AGI-08 mo~ ~T~vettin9 Cylinde~ - Leas~c AG'[-uowr-6Re-f'emence Se~L- AGI-O8WP TV~: 0 - 851S {~, In~emvat, att Sipec~ions Ret to Tpue 50 Non th 330° 55O 5OO 45O 35O E70o 150o 180° CL[]SEST POINTS Do~ Dstance Direc-t:ion ReF MD R~F TVD k[3]-OI N/A N/A N/A N/A NG]-C~ KL/A N/A N/A N/A NO]-03 N/A N/A N/A N/A hl5]-04 N/A N/A N/A N/A NG]-05 N/A N/A N/A N/A NG]-06 N/A N/A N/A N/A NG]-O7 N/A N/A N/A N/A NG]-08 N/A N/A N/A N/A NG]-09 N/A N/A N/A N/A NG]-IO N/A N/A N/A N/A NG]-I! N/A N/A N/A N/A NG]-~ N/A N/A N/A N/A NG]-J3 N../A N/A N/A N/A Ix,F~-~4 Nt/A N/A N/A N/A Smith International, Inc Travelling Cylinder Report Computed by the $ii Win-CADDS Systel. Page 1 Date: 1/28/93 Least Distance Method REFERENCE WELL: Prudhoe Bay DriLling Prudhoe Bay AGI AGI-08 AGI-O8WP2 TVO, N/S and E/W are measured from the WELLHEAD WeLLpath SLot Distance NPBst-01 NPBS~-01 11930.88 npbst02 NPBst-02 8061.46 NP-O3WP NPBst-03 3092.71 wbeach01 WBCH01 1963.09 wbeachla WBCH01 1963.09 wbeach02 ~BCH02 3101.03 wbch03 ~BCH03 3011.28 wbchO3a WBCH03 3011.28 wbchO3b ~BCH03 3009.84 WB-O4M~9 WBCH04 3080.52 Closest Points Direction Ref MD Ref TVD 324.10 0.00 0.00 315.69 500.00 500.00 341.93 0.00 0.00 299.24 8232.99 6300.00 299.24 8232.99 6300.00 341.41 0.00 0.00 338.59 2206.17 2150.00 338.59 2206.17 2150.00 338.58 2206.17 2150.00 341.25 1615.80 1600.00 P?udhoe ]Boy A61-08 evelting CytindeP - Lees~ Distance AGI-OSWP e£e~ence We~/- AGI-O8WP TVD: 0 - 85:~ £~, In~ePvet~ 50 £t, AL~ Directions Re~ ~o Tpue Nopth H 60O ~o CL,.~ES'T POIN]S [;stance ginection Re£ MD P, eC TVD l~Bs%-03 WBt'H33 ~BCH33 N/A N/A NfA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A IX~/A NIA N/A N./A N/A N/A NtA t-,VA NtA N/A N/A N/A N/A N/A N/A NIA N/A N/A f,~,'A N/A N/A N/A N/A/] Smith International, Inc. Travelling Cylinder Report ....... · Computed by the $ii Win-CADDS Syste¢,, Page 1 Date: 1/28/93 Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG! AG!-08 AGI-OSPP2 TVD, N/S and F/W are measurud from the VELLHEAD ~e[tpath Slot Distance wgil gGI-~l 8874.58 wgi2 gGI-02 8969.12 wgi3 ~GI-03 8454.35 wgi4 ~GI-04 8378.96 wgi5 ~GI-05 9546.81 wgi6 gGI-06 9255.84 wgi7 ~GI-07 9352.61 wgi8 ~GI-08 9449.91 Closest Points Direction Ref MD Ref TVD 206.41 0.00 O.OC 205.93 0.00 0.00 216.22 3498.66 3200.00 202.55 3159.80 2950.00 203.27 100.00 100.00 204.56 0.00 0.00 204.12 0.00 0.00 203.69 0.00 0.00 P udhoe iBoy AGI-08 ~maveiLin9 Cytindem - Leas~c Dis~cence AGI-OSWP~e{'epence R/ell- AGI-O8WP TV]l: 0- 851~ £t, In~cemva/, 50 ~'c, A[~ DiPec~ions J~e[ ~co Tpue No~h 27? 6OO ': ~ : ~ ~ · , , , ,, 'S '~' ,,.. , ,., . . t ~ ~ ~ ', ,, 'x, , t , , ~ ~. , ~,. '-x ~ .. · . 'x,x,' ~ .~ 'x ~ /- .,, · , " · '~ i ./- , ' " "N N~ , ,, "' 'x N'~ i / " '., -... ~/ ~/// /// /' / "\ 150° 127 AG! #8 KOP: 500 MD MAX. ANGLE: 49.22° TD Departure · 7204' . WELLHEAD' FMC JER FEB93 20" Conductor MD BKB 106' MD -~ 13-3/8", 684f, L-80, BTC ~. 13-3/8" Shoe 3946'MD 9-5/8", 47#, L-80, NSCC 7" Baker Hngr and Liner Top Packer 9- 5/8" Shoe 10776'MD 10926'MD 7", 264f, L-80, NSCC Liner PB TD 7" Shoe 8-1/2" hole TD ___11506'M D 11546'MD 11545'MD SUF. Ok'-, OL-- DIVERTER SYSTEM ...... "' Two lines venling go deg. aped in direclions that ensure sale down wind venling, and ex- lending to a poinl at least 100' Irom an)' potential source ol ignilion. _~_10' Full Opening Valves 35' or ~s required Dresser 5u~ ANSi 1. Ail pipe connections 1 '~" Ringes or weld~ conne-~bns ----' 2~-c*~Jr~ to prev-rff, m,~avemer. L Manure! 10' lull opening v~lves me-_h~nicsliy conned~: la ensure one v~Jve is Isil-s~ie open ~t ~1~ I0' Di,,'ener ~ne tums ~.re aO deg. t~r-geled. ~.,I valve w/Hyd~ulic iC- Full opening k-1 A~u~tor Gella~r 20- Diveder Spool w/ 10' Side Oullel. k'; E M 1 ~"3,'~ 0 I~( f I^,;JirO.L D ---c:::::) ro ~'~r T ~,,I ( l.- l~[a~cilt .Dual Tandem ,Sl~a].e Sl~aker 1.- [L~m 6-12" Cone Shale [~sanda~ ].- l~,~ 41611 w/16 runes ~ (].) l~r~ 1 - [')[il~ hb~sphe~Lc I.lud [~gasse~ ~0 ].- 200 gpm OperatJ. ng Capacity. Centrifuge 15 - l[~:andt t-l.h5 Hud l-tLx hcj].taLors 1- 150 b})]., Trip Tank ].- I~e~rcl[~g drilling ~].uid pLt level ].~]d.i. caLor vL[th }~tI~ v].s~l and audio war~l, ng.devices at d[lller's mnsole 10 J .... rx~, II'"'' [.-Dr~l.n~ ~lu[d ~lu.,~ sensor v/itl~ readout aL drill~.',s console AUDI #2 5/8" 5,000 psi Stack ,~' 2.00 4.12 I 12.72 I 4.5O 3.01 i3.01 i 1 .$3 3.01 t 2.52 I ¥ 1.5 RKB 1 I DRIP PAN GROUND LEVEL RIG FLOOR HYDR1L PIp~, _ RAM 17.88 22.38 BLIND RAM MUD CROSS PIPE RAM MUD CROSS ~X~ASE FLG/ 25.3,~ I o~ P3 o4.z3 35.75 AUDI #2 .5/8" 5,000 psi Stack 12.72 4.50 3.01 3.01 1 I .$3 3.0I i 2.52 1.5 2.00 RKB RIG FLOOR 4.12 DRIP PAN HYDRIL 17.88 PI, ~ RAM BLIND RAM MUD CROSS PIPE RAM i MUD CROSS 22.33 25.3P I 30.23 GROUND LEVEL '~AS~ FLG/ 35.75 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Comnfission TO: THRU: FROM: / David Johnston,'''~ Commissioner DATE: ~~ FILE NO: Blair Wondzell, '¢~"d' P. I. Supervisor SUBJECT: Jerry Herring, J(/~ Petroleum Inspector February 9, 1993 jh- rep 10.doc , Wellbore Plug AAI, PBU, Pad 9-4 Original PTD 76-040 Redrill PTD 93-033 .Sunday, February 7, 1993: I witnessed a wellbore plug on ARCO's PBU drill pad 9, well 4. A coil tubing rig was utilized for the plugging operation. The existing bottom hole location was being plugged and abandoned and the well is to be redrilled at a later date for a new bottom hole location. I arrived on location at 10:00 a.m. and witnessed the rigging up of the coil tubing rig and pressure testing of the BOP stack. The well was flushed with seawater to cool the 190°F bottom hole temperature to a desired temperature of 170°F for cement setting purposes. The cement crew arrived on location at 1:00 p.m. and began mixing the 57 barrels of cement required for the job. A quality check of the cement was completed and witnessed by the ARCO engineer and myself. Upon completion of the flushing operation, the cement was laid down hole with the coil tubing rig. Squeeze pressure of 1000 psig was held for one hour. Flushing operation was then completed and the coil tubing rig released from the location at 9:00 p.m. Due to change-out, I was not able to witness the final tagging and pressure test of the cement plug which was to be completed Monday afternoon. There was 157 feet of cement designed from the top of the perforations at 9600' to the bottom of the tubing tail at 9453' providing a 57 foot margin beyond the 100 foot minimum requirement above the perforations. ARCO's P/A plan for this well was exceptional. This type of P/A operation using a coil tubing rig in preparation for a redrill is becoming very popular at Prudhoe Bay. I spoke to Doug Amos about the inspection form currently being used which is not quit applicable. Doug is developing a new form on the computer specific for redrill type P/A work. Summary: The wellbore plug on PBU well 9-4 was laid in preparation for a redrill of the bottom hole location. Final tagging and pressure testing of the plug was not witnessed due to change-out. Attachment STATE ()F ALASKA ; ~KA OIL & GAS CONSERVATION COM," qION Plug & Abandonment Report Operator Company Repr. ~/I£ ~D~lO~cJ Lease No. ~OC ~2_TWell No. Total Depth q~.~ /Elevation Date Drilling Permit ~ ~/-b sec. T-R ~ al Mud Wt. Casing: Drive Pipe Conductor Int~mediate Plugging Data: "O.D. Set at "O.D. "O.D. Ft. w/ Pene. Ft. Surface ~ ~' "O.D. @../.dlZ3~ Ft. Ft. Production ~k[ "O.D. @ 1. Open hole plugs: 2. Open hole isolation plug: 6. Surface plug: Casing removal: REMARKS: 3. Perforation plugs (if any) 4. ~nulus plugs (if any): 5. Casing st~ plugs: ~ .- "casing cut at "casing cut at "casing cut at General Purpose Worksheet !Subtec~ Page No. File ~ ttz2~O c, mT" T'~P ,L ,,,., Well 9-4 Spud Date: 04-21-76 Original RKBE: 54' Top of Sadlerochit: 9597' A~,., Alaska Inc. - Prudhoe Bay Field APl#: 50-029-20212-00 Well Type: Producer Completion Date: 05-06-87 New [] Workover [] Hanger Type: FMC Genl Hanger: 28" Maximum Hole Angle: 39-0 Angle Through Sad. ' 35° Annulus Fluid: Diesel/9.0# NaCI Reference Log: BHCS 05-13-76 ANN COMMUNICATION: WAIVERED WELL - 9-5/8'" X 13-3/8" COMM TO A/L GAS. All Depths are RKB Drilling MD to Top of Equipment except where noted. Jewelry 1 1 2255' 2 2998' FO @ 2333' 3 8662' 4 9330' FO @ 2456' 5 9350' 6 9361' 2 7 9463' k9 8 9496' 13 10112' 7" Otis RPB SSSV Nipple: ID = 5.96" 7" x 5-1/2" Crossover Teledyne Tbg Patch ID=3.75" BOT PBR Assembly Baker SAB Packer 5-1/2" x 4-1/2" Crossover (Hole in Tbg 01-14-93)** Otis X Nipple: ID = 3.813" 4-1/2" Tubing Tail ELM Tubing Tail (Logged 06-10-87 GR/CCL) Fish: 17'x 4 -1/2" Tubing Tail - Tagged 05-09-87 Fish: Kinley Caliper/Feelers/Trippers 01-21-90 Fish: IBP Neck (01-17-93) Minimum ID: Teledyne Tbg Patch ID=3.75" @ 8662' 3 4 5 6 (Hole in Tbg) 9 10 Casing and Tubing Size Weia~ ht Grade ToD Bottorrl 13-3/8" 72# MN-80 0' 2701' 9-5/8" 47# MN-80 0' 10233' 7" 29# L-80 0' 2998' 5-1/2' 17# L-80 2998' 9362' 4-1/2' 12.6# N-80 9362' 9496' Description Casing Casing PC Tubing PC Tubing NPC Tubing Tail ::::::::::::::::::::::::::::::::::::::::::::::::::: 7 I I I Cement Plug @ 982g 12 Gas Lift Information (Valve Change Date: 07-17-92) Depth MD TVD Stn. Mandrel ~/Iv TYpe Latch 3012' (3011') 1 TE-TGPD CA R-20 RK 5146' (5029') 2 TE-TGPD CA R-20 R K 5773' (5524') 3 TE-TGPD TE D-14R TG 6363' (5990') 4 TE-TGPD TE D-14R TG 6755' (6302') 5 TE-TGPD CA R-20 R K 7145' (6616') 6 TE-TGPD TE D-14R TG 7456' (6871') 7 TE-TGPD TE D-14R TG 7730' (7096') 8 TE-TGPD CA RDO-20 R K 8043" (7356') 9 TE-TGPD TE D-14R TG 8355' (7613") 10 TE-TGPD TE D-14R TG 8668' (7868') 11 TE-TGPD TE D-14R TG 8941' (8091') 12 TE-TGPD TE D-14R TG 9254' (8347') 13 TE-TGPD TE ED-15R TGE Covered by Teledyne Tubing Patch @ 8662'- 8683' port Sz. TRO Date 1/4' 1709 07-17-92 1/4" 1750 07-17-92 5/16" 1833 07-17-92 3/8' ORIF 07-17-92 Perforation Data (ELM Depths) Interval Zone FT SPF Date ¢:omment~ 960D-9640 4 40 0 05-23-91 WSO Sqz 9640-9692 4 52 0 07-12-92 WSO Sqz 9692-9714 4 22 0 05-23-91 WSO Sqz 9768-9778 4 10 0 05-23-91 WSO Sqz 9786-9811 3 25 4 08-03-92 Reperf 9814-9846 3 35 -0 07-12-92 WSO Sqz 9846-98E~ 3 14 0 05-23.91 W$O Sqz 9896-9941 2 45 0 05-23.91 WSO Sqz 9954-9958 2 4 0 05-23-91 WSO Sqz 9969-9973 2 4 0 05-23.91 WSO Sqz 9985-9995 2 10 0 05-23-91 WSO Sqz 1CEk%-1C064 lB 28 0 05-23-91 WSO Sqz 10072-10110 lB 38 0 05-23-91 WSO Sqz PBTD= 10147' TD = 102501 Datum 8700' SS = 9754' MD 8800' SS = 9878' MD Revision Date: 01-15-93/by PTB Reason: Hole in Tbg/Fish Previous Revision: 09-07-92 Well 9-4 -~e .~ueese Wellwork RU 'slickllne. PT lubricator. RIH with 8,5' tool string w/ tubing tall locator. Locate the tubing tail and tag l~ll. Tie into tbg. t~!! at 9453' ELM. RD sllcldtne. Note: The last tag was at 9820' ELM on 9/4/92. Cem_.en P & A lh _edure 1. Notify AOC, CC Inspector 24 hrs prior to co_m___m__en~ng o~rations. Note: State approval for this work has not yet been received {2/4/93}, contact Shannon Latchem/Krlsti Wysocki at 265-4821 for the Sundry Notice Approval # and date: Inspector Phone Numbers: 659-3607_ pager 659'3870 truck 279-1433 office Note: This ~U '~ a hole m'~e tub~ ~ 5-1/2' x 4-1/2' XO at 9~1' {11' ~bw ~e p~ ~ 1/14/~ ~ ~ffion log. 2. ~d 9-5/8" ~~ ~ ~~t~ ~d ~~ ~~t flu~. ~ed. u~n 9-5/8' ~as vroblems ~nco~ntered. d~n~__~e 3~_15~ ~~e~d to p~~pp~~~ 2 ~sme ~umes of fl~d ~ 9-5/8" ~ flu~ out ~ much 9f ~ it ~ ~t ~sm ~, ~T p~ ~ ~ don= ~ ~v~ ~L~s. ~e up a ~pl~ ~mp W ~e 9-5/8" d~g ~e~ ~d m~~n ~siflve press~e ~ ~m~~ ~~s ~e ~mplete. ~ 1.75' ~ ~ com~~on ~,~ ~men~Je~g n~e. ~ cod, t l~OPs, and hardltnes to 4500 psi. Fluid pack/displace the wellbore with 160°F heated mw~t~r with 50 ppm soale h~hm_itor Or 1% KC.A, w~ter. NOTE: Seawater/KCL water is required because there is a chance that " the P&A plug will be drilled up during the RWO and the current BI-IL produced, l~.~mp 400 bbls down the backside at 5+ BPM if possible then reduce the rate to 22 .bpm or positive WHP. During fluid pack operation establish end document inJeetlvity rate and pressure. The State Representative may request thc data for comparison with the post squeeze pressure test, Tag bottom with nozzle. Correct b~ck w slickJine tag depth. Pull up 10' and flag pipe. Pull uphole above wi! peris at i9550' while mixing cement. w.H. 2/4/93 ~ & A~ure Project AFE '#4J8002 F~F~5 . 0E~5 4. Batch ml~ ~ of cement (p,,mp 57 bbls} to yield the following: Ci~_~s "G" Cement Filter Cake >>> >0.75" ~ cake in Lab TMckenlnf 'Time >>> 5-7 hours at 190 ? SBHT FluYt Loss Target >>> 40-150 cc/30-minutes at 170~F BHCT Mix Wat~' >>> 1% KCL w/> 0.2% bwow Surfactant ~ A~nt >>> Perfect SealTM expanded aggregate Load at 20~/bbl in :~0 bbls Mix up 62 bbls cmt in two podS, b.rmg cmt up to weight, roll together. shear thoroughly. Catch a sample of ce_-,~ent fdr QC testing. The on-site workover engineer will conduct QC tests on the field blend to ensure that it is acceptable. Once the blend is approved, add aggregate to one 50 bbl pod, line up cementers to the coil. 5~ While engineer is testing cement, check to see if the well goes on a bep to vacuum. If it does. repared load the tbg. with sufficient methanol/ water to achieyea positive WI-1P before going downhole with cement. 6. Line out cementers to the CT. Pump the following down the coil: 10 bbls 1% KCL water spacer 7 bbls of Class "G" cement without aggregate 50 bbla Class "G" cement with aggregate loaded at 20#/bbl Coil voh:me of 1% KCL water displacement Coil vol,,me of 1.5# biozan gel for Jetting out NOI'E: OBJF, C'I'IVE OF P&A IS TO ENSURE THAT FINAL CEMENT TOP PLACEMENT IS BETWEEN ~50' ~)- 0500'; however the desired final _cement top is at the tubing taft at 2/4/93 D,O, fO4 ~ & A Proeedu.,'e ProJ~t ~ ~,4J~O0~ 7~ * Continue to pump water down the backside at 2 BPM. · RIH with coil to flag depth as cement reaches nozzle. , Stop backside injecUon and take returns at mtntm~l WHP aider 2 bbls cement exits the nozzle. · Allow the c__~.ent top in the casing to rise 50' above the nozzle .... (i4 bbls out nor~fle in 9-[i/8' e~using) before pulling coil uphole. · Lay in cement at 1:1 pulling uphole until cement top is at 9,[S40' (CT nozzle at 9,590'. * SI backside and squeeze well to a targeted pre~sure of 1000 poi, y0- y, coil from 9590'- 9620' while waiting for squeeze. *****' DO NOT p~mp more than 80 bbb cement behind pipe.****** The cement top shc,_d__r!_ be at the tubing mil at 9453' ELM tf 30 bbls Cement is placed behind pipe. When WHP=1000 pll or 80 bbp. take returns to maintain WHP and lay in the rem_~_lrflng cement in coil at 1:1 raUo in weir, ore. & · Speed up to position coil at cement top as last bbl of cement reaches nozzle, pull uphole at max speed to safety and park coil. · Once all cement is Out coil the WHP can be lowered to WtiP=500 psi or lower. It is not necessary to hold WHP for one hour before starting clean out * With coil at safety prepare to jet out cement Break out cementers and switch to CTU pumping 1-1/2# biozan down the coil. · Launch ball. · Chase ball to nozzle with 1.5# biozan gel · With ball seated in nozzle, IIIH at 1:1 jetting at 4000 psi injection down to 9453' ELM. Note: Do not_Jet out cement be4__ew 94_s~_'~ Make 3 down-passes and 2 up-passes (~ 80% running speed) with 1.5~ bi0zan gel. Do not Jet out cement below 9453'. · Take a barrel count to ei;~ure 1:1 r~. - ...... · Freeze protect top 2500' of vel]bore. * RD CTU leaving well secured with :bi00 psi left on the h'ee. · ~ to semmter on last pass. Ensure t/mt all Jewel~/glv's. etc. · Jet uphole at 80% running speed and -4000 psi injection pressure. 2/4/93 7 ":* CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1) Fe'e ~ ~/~-~ (2) Loc [ 2 thru [9 thru 13] [10 & 13] (4) Cascj ~:~Z't~,,~'k:'/ ~e.].~., .~/.~ [:14 thru 22] (5) BOPE [23 thru 28] Company //---~) , YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... ~ 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is well bore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. Lease & Well NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... . . Is lease nLrnber appropriate .......................................... ~ ... Does well have a unique name & number ................................ ~ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface S intermediate or production strings ...... Will cement cover all known productive horizons ..................... ,, Will all casing give adequate safety in collapse, tension, and burst. ~,~' Is well to be kicked off from an existing wellbore ................... , , Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~OOopsig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other /,/~, ~ 29 thr~'~'l :7) Contact~ ~32] geo ]ogy' DWd~ RP~~ 29. 30. 31. 32. 33. rev 12/92 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , ? o // _Co Additional remarks' UM.X MERIDIAN' SM Exp/Dev Inj)( TYPE' Redrill' Rev~' 0 -cZ ~0 Well HistorY File APPENDIX Information of detailed nature that is not particulady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simp!ify 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. US VERIFICATION USTING FOR: ARCO ALASKA, INC. AGI-8 PRUDHOE BAY MICROFILt i) ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE US TAPE GENERATED FOR ARCO ALASKA INC. AGI-8 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB mmho/m mmho/m MWD-API deg deg mins ohm-m ohm-m ft/hr ft/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Tue 5 OCT 93 1:39p != = ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESOAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode US Comment records: 0=OFF, I=ON 4 INFORECS = I , ! Decode US Information records: 0--NO, I=YES 5 MSTMETHOD = 0 , ! Usting Method: 0=depth units 1=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 MSTMAX = 0 , ! Usting Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=MS ... thru 35=Array Accoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0=NO, I=YES 12 SPMTLlS = I , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to Interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , USTMETHOD = 0 , USTFREQ = 50, LISTMAX = 0 , STATS = 0, FORCETYP = 0 , WRITEASCll = 0 , WRITETAP = 1 , SPUTMS = 1 , SUBFILES = /0/, INTERPOLATE = 'YES' END -! PROCESSING INTERVAL FROM 0.000 TO 0.000 -- I- CONSTANT PARAMETERS AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 IISTFREQ= 50.0000 USTMAX = O.O00000E+O0 USTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPUTUS= 1.00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1,00000 dpcte = 1.00000 '-- ddength= O.O00000E+O0 listwave= O.O00000E+O0 maxrecin= O,O00000E+O0 minrecln= O.O00000E+O0 nsamptes= O,O00000E+O0 numcurvs= O.O00000E+O0 numdatar= O.O00000E+O0 numrecfl= O.O00000E+O0 tfendep = O.O00000E+O0 tflevsp = O.O00000E+O0 tfstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcdevsp= O.O00000E+O0 wcrtop = O.O00000E+O0 ARRAY PARAMETERS SUBFILES(1) = O.O00000E+O0 SUBFILES(2) = -99cJ9.00 SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999,00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9cJ99.00 SUBFILES(9) = -9999.00 SUBFILES(10) = -9999.00 SUBFILES(11) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(20) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -.9999.00 SUBFILES(36) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(41) = -9999,00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) -- -9999.00 SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES(80) = -9999.00 SUBFILES(81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) -- -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 ~--. SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 ,~,, SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) SUBFILES(104) SUBFILES(106) SUBFILES(108) SUBFILES(110) SUBFILES(112) SUBFILES(114) SUBFILES(116) SUBFILES(118) SUBFILES(120) SUBFILES(122) SUBFILES(124) SUBFILES(126) SUBFILES(128) : -9999.00 : -99(:J9.00 : -9999.00 : -9999.00 -- -9999.00 = -9999.00 : -9999.00 : -9999.00 -- -9999.00 - -9999.00 -- -9999.00 = -9999.00 : -9999.00 = -9999.00 STRING PARAMETERS INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1190\1190.TAP (Output Tape-Image file will be created) Usting Method ("USTMETH") = 0, Depth Unit oriented listing. Usting Frequency ("MSTFREQ") is every ( 50) units of Depth. Usting output limiting (MSTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE--1 to enable this feature) US comment record decoding (COMMENTS= 1) has been enabled by user input. US information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD 93/10/5 1190 01 **** TAPE HEADER **** MWD 93/10/5 1190 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS LIS COMMENT RECORD(s): 12345678,901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: AGI-8 APl NUMBER: 50-029-22348 OPERATOR: Arco Alaska Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 05 OCT 93 JOB DATA BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: 1190 LOGGING ENGINEER: S. BURKHARDT OPERATOR WITNESS: J. GAFFANEY SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 14E FNL: FSL: 2409 FEL: 2536 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 49.00 GROUND LEVEL: 13.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 106.0 2ND STRING 16.000 13.375 3937.0 3RD STRING 12.250 PRODUCTION STRING REMARKS: $ **** FILE HEADER **** MWD .001 1024 LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8723.0 10943.0 $ BASEMNE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ~ EQUIVALENT UNSHIFTED DEPTH ~- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD $ REMARKS: $ CN WN FN COUN STAT 4 8723.0 10943.0 : Arco Alaska Inc. : AGI-8 : Prudhoe Bay : North Slope :Alaska LIS COMMENT RECORD(s): 123456789012345678901234567890123456789012345678,90123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered' 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0 0 0 0 0 00 1 00 0 1 Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a IF ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I GR MWD 68 1 GAPI 4 4 98 660 71 6 2 RA MWD 68 1 OHMM 4 4 98 660 71 6 3 ROP MWD 68 1 FPHR 4 4 98 660 71 6 4 RP MWD 68 1 OHMM 4 4 98 660 71 6 16 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 89 Tape File Start Depth = 8723.000000 Tape File End Depth = 10943.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4982 datums Tape Subtile: 2 158 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subtile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 US COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8723.0 10943.0 $ LOG HEADER DATA DATE LOGGED: 06 MAR 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M 1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT)' 0.0 TOP LOG INTERVAL (FT): 8723.0 BOTTOM LOG INTERVAL (FT): 10943.0 BIT ROTATING SPEED (RPM): 0 HOLE INCUNATION (DEG) MINIMUM ANGLE: 48.7 MAXIMUM ANGLE: 52.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: LT DISPERSE MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 42.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 2207-45 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.050 MUD FILTRATE AT MT: 1.250 138.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 0.0 144.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 10889' TO 10943' MD (7989 TO 8022' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT 9 5/8 INCH CASING POINT. $ CN :Arco Alaska Inc. WN : AGI-8 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678,9012345678901234567890123456789012345678,90 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 4RR. * FORMAT RECORD O'YPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0001 00000001 0001 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod I ATOM MWD 68 2 ATDC MWD 68 3 CADE MWD 68 4 CPDE MWD 68 5 DOOM MWD 68 6 GRAM MWD 68 7 PDOM MWD 68 8 PDDO MWD 68 9 PDEM MWD 68 10 RACM MWD 68 11 RADE MWD 68 12 ROPA MWD 68 13 ROPSMWD 68 14 RPCMMWD 68 15 RPDE MWD 68 16 TCDMMWD 68 -dB -dB MMHO MMHO 1 1 1 1 1 1 GAPI I DEG 1 DEG I MINS 1 OHMM 1 OHMM I FPHR 1 FPHR 1 OHMM 1 OHMM 1 DEGF 4 4 98660 71 6 4 498660 71 6 4 498660 71 6 4 4 9866O 71 6 4 4 9866O 71 6 4 49866O 71 6 4 4 98660 71 6 4 4 9866O 71 6 4 4 9866O 71 6 4 4 9866O 71 6 4 4 9866O 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 9866O 71 6 4 4 98 660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 635 Tape File Start Depth = 8723.000000 Tape File End Depth = 10943.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** US representation code decoding summary: Rep Code: 68 19778 datums Tape Subtile: 3 701 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 9311015 1190 01 **** REEL TRAILER **** MWD 93/10/5 1190 01 Tape Subtile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes -- End of execution: Tue 5 OCT 93 1:40p Elapsed execution time = 42.01 seconds. , __..~ SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR ROP RP 8723.0000 -999.2500 -999.2500 -999.2500 -999.2500 8723.5000 -999.2500 -999.2500 -999.2500 -999.2500 8750.0000 65.9649 4.9254 -999.2500 4.2776 8800.0000 88.3213 8.1345 69.3000 6.4757 8850.0000 69.1946 3.7979 118.1382 3.4524 8900.0000 82.5714 8.3493 96.3713 6.8561 8950.0000 91.1025 11.8361 140.7394 8.0845 9000.0000 101.2531 7.3849 141.6400 6.0537 9050.0000 95.3999 8.9393 76.9783 7.5095 9100.0000 89.4578 8.1309 118.1326 6.7534 9150.0000 101.3540 7.2775 110.8856 6.3296 9200.0000 104.2867 6.8230 130.7896 6.0296 9250.0000 100.4195 7.2276 69.0964 6.1814 9300.0000 93.9958 8.4843 88.5971 7.3386 9350.0000 98.4061 10.6183 78.7530 8.5961 9400.0000 101.1328 10.7597 102.1712 8.4284 9450.0000 94.6611 11.6064 85.6415 9.0629 9500.0000 95.5306 10.6877 87.1931 8.4409 9550.0000 91.1395 10.0966 79.6111 8.3571 9600.0000 96.9884 9.7431 54.6153 8.1475 9650.0000 83.7271 9.8282 48.7897 8.2446 9700.0000 98.3913 9.2816 84.3782 7.1127 9750.0000 106.0296 6.9226 104.2319 5.6444 9800.0000 90.9915 7.3136 118.1295 6.0788 9850.0000 103.6840 7.0123 114.5556 5.7770 9900.0000 98.0810 7.8917 91.5527 5.9173 9950.0000 97.5231 7.5166 122.2029 6.1187 10000.0000 95.7897 7.6376 59.0647 5.9428 10050.0000 104.3224 7.8065 114.3188 6.3689 10100.0000 105.8418 5.8347 75.4018 4.5707 10150.0000 90.5004 5.4280 87.91 48 4.6229 10200.0000 84.9136 5.2859 85.9167 4.5901 10250.0000 161.1526 3.2755 78.7530 3.0114 10300.0000 188.1969 2.6743 73.4985 2.1417 10350.0000 156.2574 4.5477 73.2422 4.3342 10400.0000 152.0404 4.4124 67.8168 4.0677 10450.0000 166.2667 6.7500 70.8777 5.7765 10500.0000 141.8339 8.5659 57.0943 6.5663 10550.0000 127.0908 11.5410 62.0696 8.0900 10600.0000 135.3231 7.1526 95.7806 6.0052 10650.0000 96.6869 8.2327 90.8688 7,5999 10700.0000 158.4375 9.4382 64.2475 7.7206 10750.0000 152.3795 8.2142 73.8309 6.2292 10800.0000 196.6396 7.2672 75.4018 5.8235 10650.0000 210.0261 6.0224 64.2475 5.3519 10900.0000 -999.2500 -999.2500 90.1489 -999.2500 10943.0000 -999.2500 -999.2500 88.5971 -999.2500 Tape File Start Depth = 8723.000000 Tape File End Depth = 10943.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8723.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8723.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8750.0000 0.7374 0.7984 203.0276 233.7774 112.8973 65.9649 11.5349 11.2561 -999.2500 5.3859 4.9254 -999.2500 -999.2500 4.1155 4.2776 -999.2500 8800.0000 0.4402 0.5034 122.9330 154.4234 93.2423 88.3213 8.8546 8.5977 44.5833 9.3499 8.1345 73.3875 69.3000 6.1949 6.4757 118.2875 8850.0000 0.9407 1.0003 263.3054 289.6531 124.7678 69.1946 13.1636 12.8738 38.7667 4.0812 3.7979 123.4046 118.1382 3.3303 3.4524 119.3562 8900.0000 0.4288 0.4910 119.7709 145.8553 90.8518 82.5714 8.5312 8.2759 36.4667 9.6046 8.3493 94.3079 96.3713 6.5516 6.8561 120.6500 8950.0000 0.2815 0.3484 84.4870 123.6938 84.2708 91.1025 7.6455 7.4018 46.8500 14.5776 11.8361 135.5407 140.7394 7.7097 8.0845 121.7750 9000.0000 0.4692 0.5517 135.4117 165.1893 96.1716 101.2531 9.2519 8.9906 42.1167 8.3826 7.3849 125.4405 141.6400 5.7962 6.0537 122.1125 9050.0000 0.3982 0.4598 111.8C:)59 133.1641 87.1460 95.3999 8.0315 7.7832 46.7667 10.3543 8.9393 84.2506 76.9783 7.1687 7.5095 123.9125 9100.0000 0.4416 0.5036 122.9869 148.0739 91.4675 89.4578 8.6145 8.3601 31.2833 9.3187 8.1309 118.1314 118.1326 6.4568 6.7534 125.0375 DEPTH DCCM RACM RPDE ATCM GRAM RADE TCDM ATDC PDCM ROPA CADE PDDC ROPS CPDE PDEM RPCM 9IS0.0000 94.2240 8.2179 6.3296 0.4985 101.3540 7.2775 126.6875 0.5594 8.9877 110.9184 137.4107 8.7292 110.8856 157.9877 54.9500 6.0568 9200.0000 96.3451 7.6506 6.0296 0.5336 104.2867 6.8230 126.0500 0.5941 9.2755 123.2734 146.5631 9.0143 130.7896 165.8494 38.4826 5.7738 9250.0000 95.2491 8.1652 6.1814 0.5016 100.4195 7.2276 128.3000 0.5630 9.1271 75.8827 138.3583 8.8674 69.0964 161.7750 89.9995 5.9175 9300.0000 88.0678 9.7475 7.3386 0.4226 93.9958 8.4843 126.9500 0.4835 8.1560 93.4901 117.8646 7.9048 88.5971 136.2662 37.6328 7.0073 9350.0000 81.9511 12.6351 8.5961 9400.0000 82.6846 12.8666 8.4284 0.3261 98.4061 10.6163 129.4250 0.3201 101.1328 10.7597 130.5500 0.3883 7.3356 82.6891 0.3833 7.4336 99.5410 94.1772 7.0957 78.7530 92.9396 7.1925 102.1712 116.3325 49.3161 8.1921 118.6461 36.5500 8.0348 9450.0000 80.0248 14.0570 9.0629 9500.0000 82.6291 12.7578 8.4409 0.2923 94.6611 11.6064 132.2375 0.3229 95.5306 10.6877 133.4750 0.3553 7.0788 83.3801 0.3858 7.4262 84.6992 86.1591 6.8410 85,6415 93.5656 7.1852 87.1931 110.3405 58.8500 8.6281 118.4702 43.0833 8.0465 9550.0000 83.0078 11.9006 8.3571 9600.0000 83.9665 11.41 92 8.1475 0.3465 91.1395 10.0966 135.2750 0.3612 96.9884 9.7431 135.8375 0.4082 7.4768 80.6629 0.4227 7.6051 54.2703 99,0428 7.2347 79.6111 102.6368 7.3619 54.6153 119.6584 68.1833 7.9669 122.7377 71.1167 7.7705 9650.0000 83.5271 11.5300 8.2446 0.3577 83.7271 9.8282 137.4125 0.4191 7.5463 51.2585 101.7482 7.3023 48.7897 121.2916 92.8333 7.6596 DEPTH DCCM RACM RPDE ATOM GRAM RADE TODM ATDC PDCM ROPA CADE PDDC ROPS CPDE PDEM RPCM 9700.0000 89.3208 10.8802 7.1127 0.3791 98.3913 9.2816 138.0875 0.4433 8.3249 87.0416 107.7400 8.0734 84.3782 1 40.5935 88.6167 6.7965 9750.0000 99.3047 7.8100 5.6~ 0.5233 106.0296 6.9226 133.7844 0.5861 9.6782 106.8080 144.4541 9.4136 104.2319 177.1668 37.5833 5.4109 9800.0000 95.9941 8.2853 6.0788 0.4946 90.9915 7.3136 136.4562 0.5568 9.2277 118.1295 136.7321 8.9659 118.1295 164.5070 82.4000 5.8192 9850.0000 98.2598 7.9151 5.7770 0.5167 103.6840 7.0123 137.8625 0.5792 9.5356 113.0367 142.6061 9.2719 114.5558 173,1016 90.5167 5.5350 9900.0000 97.1785 9.0754 5.9173 9950.0000 95.6967 8.5514 6.1187 0.4531 98.0810 7.8917 135.0125 0.4799 97.5231 7.5166 135.7250 0.5182 9.3886 89.3360 0.5426 9.1873 117.8729 126.7155 9.1266 91.5527 133.0389 8.9272 122.2029 168.9951 66.8500 5.6680 163.4343 55.0167 5.8582 10000.0000 96.9862 8.7293 5.9428 10050.0000 93.9641 8.9167 6.3689 0.4705 95.7897 7.6376 138.8750 0.4609 104.3224 7.8065 138.3125 0.5345 9.3624 56.5184 0.5235 8.9523 109.5962 130.9311 9.1007 59.0647 128.0983 8.6932 114.3188 1 68.2704 98.1833 5.6922 157.0139 60.2667 6.0929 10100.0000 109.4805 6.4948 4.5707 10150.0000 108.9161 5.9824 4.6229 0.6219 105.6418 5.8347 140.0000 0.6705 90.5004 5.4280 138.9875 0.6860 11.0669 76.3451 0.7322 10.9897 88.1706 171.3872 10.7912 75.4018 184.2306 10.7130 87.9148 218.7870 66.9000 4.3934 216.3140 41.6567 4.4420 10200.0000 109.2665 5.8090 4.5901 0.6887 84.9136 5.2859 141.4625 0.7498 11.0376 79.9147 189.1815 10.7619 85.9167 217.8582 173.5500 4.4117 DEPTH DCCM RACM RPDE ATOM GRAM RADE TODM ATDC PDCM ROPA CADE PDDC ROPS CPDE PDEM RPCM 10250.0000 133.0163 3.4929 3.0114 1.0736 161,1526 3.2755 140.7875 1.1328 14.2971 77.8083 305.3010 14.0018 78.7530 332.0724 60.5833 2.9100 10300.0000 156,1948 2.8384 2.1417 1.2744 188.1969 2.6743 139.6625 1.3373 17.4826 71.3479 373.9274 17.1761 73.4985 466.9163 71.6000 2.0783 10350.0000 112.2240 4.9288 4.3342 0,7979 156.2574 4.5477 140.3375 0.8564 11.4425 69.5077 219.8,906 11.1626 73.2422 230.7234 50.4333 4.1681 10400.0000 115.5685 4.7786 4.0677 0.8200 152.0404 4.4124 140.7875 0.8793 11.9009 69.5071 226.6353 11.6198 67.8168 245.8395 69.1333 3.9162 10450.0000 98.2623 7.5750 5.7765 10500.0000 92.6596 9.9620 6.5663 0.5387 166.26~7 6.7500 140.5625 0.4136 141.8339 8.5659 142.0250 0.6001 9.5359 70.2097 0.4780 8.7756 57.4822 148.1481 9.2722 70.8777 116.4705 8.5182 57.0943 173.1142 70.8824 5.5347 152.2925 65.9825 6.2791 10550.0000 64.2438 14.1065 8.0900 10600.0000 96.5293 8.0806 6.0052 0.2912 127.0908 11.541 0 142.4750 0.5066 135.3231 7.1526 142.7000 0.3573 7.6418 60.9428 0.5685 9.3004 91.0741 86.6479 7.3981 62.0696 139.8083 9.0382 95.7806 123.6095 60.2328 7.7151 166.5230 33.3828 5.7502 10650.0000 86.6720 9.3843 7.5999 10700.0000 86.0529 11.0306 7.7206 0.4386 96.6869 8.2327 143.7125 0.3739 158.4375 9.4382 142.8125 0.4977 7.9676 87.3106 0.4361 7.8844 66.1915 121.4666 7.7200 90.8688 105.9527 7.6378 64.2475 131.5803 60.5833 7.2539 129.5243 44.3000 7.3675 10750.0000 94.9012 9.4873 6.2292 0.4339 152.3795 8.2142 143.4875 0.4986 9.0794 98.4691 121.7411 8.8202 73.8309 160.5342 66.3667 5.9642 DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10800.0000 0.4968 0.5600 137.6042 171.7171 97.9071 196.6396 9.4857 9.2211 48.6833 8.2457 7.2672 74.0322 75.4018 5.5779 5.8235 143.6000 10850.0000 0.6059 0.6663 166.0473 186.8490 101.7762 210.0261 10.0125 9.7451 57.4833 6.6781 6.0224 67.5989 64.2475 5.1335 5.3519 144.5000 10900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 92.4823 90.1489 -999.2500 -999.2500 1 44.2750 10943.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 88.5971 88.5971 -999.2500 -999.2500 144.9500 Tape File Start Depth = 8723.000000 Tape File End Depth = 10943.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS