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Home My WebLink About188-0971. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,360 feet NA feet true vertical 10,505 feet ~11,287'feet Effective Depth measured 11,265 feet 9,952 feet true vertical 10,419 feet 9,258 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6# / L-80 / TDS 9,937' 9,245' Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 / TDS 10,067' 9,361' 1,530' MD Packers and SSSV (type, measured and true vertical depth)See Above HXO SSSV 1,530' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: Burst NA Collapse NA 2,260psi 5,090psi 8,530psi 5,020psi 6,870psi 8,150psi 11,220psi 4,760psi Conductor 9,547' 10,505' 10,280' 11,360' 8,828' 2,494'Surface Production Production 20" 9-5/8" 92' 2,456' 8,865' 8,299' ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-68 Plugs Junk measured measured TVD 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-097 50-029-21858-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 255 Gas-Mcf 1000 6449 180010644 287 3413820 326 N/A measured true vertical Packer MD 131' Size 131' 2,494' Length Liner 1,415' 1,337' 13-3/8" 9-5/8" x 3-1/2" SAB NA Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 22018 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:17 pm, Nov 06, 2023 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.11.06 15:24:25 - 09'00' Sara Hannegan (2519) DSR-11/15/23 RBDMS JSB 110823 WCB 12-5-2024 Well Name Rig API Number Well Permit Number Start Date End Date END 2-68 Slickline / Fullbore 50-029-21858-00-00 188-097 10/22/2023 10/25/2023 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: CONT WSR FROM 10/23/2023. SET NS SNAP LATCH W/ 31' SPACER PIPE (35.27' OAL) IN LOWER ANCHOR @ 5,502' MD SET NS SNAP LATCH TEST TOOL IN MIDDLE SECTION OF PATCH @ 5,502' MD T-BIRD PRESSURE TEST MIDDLE SECTION OF PATCH AND LOWER ANCHOR 2500#. SET 45KB PACKER W/ 35' SPACER PIPE & NS SNAPLATCH IN MIDDLE SECTION SPACER PIPE @ 5,462' SLM (Est top of entire patch @ ~5417' MD) MITxIA W/ T-BIRD 2500#. CONT WSR ON 10/25/2023. Fullbore: WSR Continued from 10/23/2023. (TFS unit 4 Assist SL set patch) Pumped 101 bbls of 1% KCL down the TBG followed by a 4 bbl spacer of 60/40, then pumped 23 bbls of DSL for a FP. Further pumped 33 bbls of DSL down TBG/IA to perform a combo TBGxIA pressure test. Pressure Test was deemed a PASS. Pumped 57 bbls of DSL down the IA to attempt MIT-IA. Was not able to achieve a passing test. WSR Contnued on 10/25/2023. ***CONT WSR FROM 10/22/2023*** PULL KB PATCH FROM SSSV @ 1,484'SLM SET 4-1/2" SSCS @ 4,398' SLM PULL 1-1/2" RK-DMY GLV FROM STA #6 @ 4,180' MD CONDUCT MAN DOWN DRILL W/ REP LOAD IA W/ 300BBL's KCL & 80 BBL's DIESEL SET 1-1/2" RK-DMY GLV IN STA #6 @ 4,180' MD PULL 4-1/2" SSCS FROM 4,398' SLM ***CONT WSR ON 10/24/2023*** 10/24/2023 - Tuesday 10/22/2023 - Sunday ***CONT WSR FROM 10/21/2023*** FUNCTION TEST WLV DRIFT TO AND TAG 45KB PATCH @ 5,423' MD W/ 3.80" G.RING PULL 45KB PATCH FROM 5,423' MD (2HRS JARING) AND LEAVE IN SSSV NIP @ 1,530' MD ***CONT WSR ON 10/23/2023*** 10/23/2023 - Monday (Est top of entire patch @ ~5417' MD) SET NS SNAP LATCH W/ 31' SPACER PIPE (35.27' OAL) IN LOWER ANCHOR @ 5,502' MD SET NS SNAP LATCH TEST TOOL IN MIDDLE SECTION OF PATCH @ 5,502' MD T-BIRD PRESSURE TEST MIDDLE SECTION OF PATCH AND LOWER ANCHOR 2500#. SET 45KB PACKER W/ 35' SPACER PIPE & NS SNAPLATCH IN MIDDLE SECTION SPACER PIPE @ 5,462' SLM The tubing patch is shown correctly on the WBS below. -WCB Well Name Rig API Number Well Permit Number Start Date End Date END 2-68 Slickline / Fullbore 50-029-21858-00-00 188-097 10/22/2023 10/25/2023 Hilcorp Alaska, LLC Weekly Operations Summary 10/25/2023 - Wednesday Fullbore: WSR Continued from 10/24/2023. (TFS unit 4 assist SL with MIT-IA) MIT-IA (PASSED) to 2509 psi. Pumped 8 bbls of DSL down the IA to reach max applied pressure of 2500 psi with a target of 2250 psi. 1st 15 min IA lost 29 psi, 2nd 15 min IA lost 4 psi. IA had a total loss of 33 psi in a 30 min test. Haliburton Slick Line in control of Well upon Departure. Slickline: ***CONT WSR FROM 10/24/2023*** T-BIRD PERFORM PASSING MITxIA 2500# (see log for details) SET 4-1/2" SSCS @ 4,415' SLM PULL 1-1/2" RK-DMY GLV FROM STA #6 @ 4,190' MD SET 1-1/2" RK-OGLV IN STA #6 @ 4,190' MD PULL 4-1/2" SSCS FROM 4,415' SLM SET 4-1/2" BBE (ser# HBB4-39 3 set stnd pkg. secondary lockdown instal 60"OAL) IN SSSV NIP @ 1,530' MD ***WELL LEFT S/I ON DEPARTURE, WELL TENDER NOTIFIED ON WELL STATUS*** _____________________________________________________________________________________ Revised By: DH 11/2/2023 Duck Island Unit Well: END 2-68 Last Completed: 10/27/1988 PTD: 188-097 SCHEMATIC TD =11,360’ (MD) / TD =10,505’(TVD) 30” KB Elev.: 55.18’/ BF Elev.: 16.22’ 7” 4 6 9 10 12 13 11 1 9-5/8” 1 2 PBTD =11,265’(MD) / PBTD = 10,419’(TVD) 5 3 Gas Lift Valves- Depth Unknown 13-3/8” 7 14 MIN ID=2.37” TOP @ 5417’ MD – Tubing Patch (set on 10/24/23 3 8 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor N/A / N/A / N/A N/A Surface 131’ 13-3/8” Surface 68/ NT-80/ CYHE 12.415 Surface 2,494’ 9-5/8" Production 47 / NT80S / NA 8.681 Surface 8,865’ 9-5/8" Production 47/ NT95HS/ NSCC 8.681 8,865’ 10,280’ 7" Liner 29/ SM-110/ Btrs 6.184 10,023’ 11,360’ TUBING DETAIL 4-1/2” Tubing 12.6/ L-80/ TDS 3.958 Surface 9,937’ 3-1/2” Tubing 9.2#/ L-80/ N/A 2.992 9,937’ 10,067’ JEWELRY DETAIL No Depth Item 1 1,530’ 4-1/2” OTIS HXO SSSV - Nipple ID=3.813” GLM DETAIL: MGM 4-1/2” RK Latch 24,180’STA 6:Vlv= SO, Dev.= 1, Port= 20, TVD= 4,179’, 06/26/23 3 5,423’ Tubing Patch- Btm @ ~5,502’- MIN ID=2.37” 11/14/18 46,539’STA 5: Vlv= Dmy, Dev.= 36, Port= 0, TVD= 6,383’, 11/09/18 58,305’STA 4: Vlv= Dmy, Dev.= 33, Port= 0, TVD= 7,817’, 7/26/2007 69,359’STA 3: Vlv= Dmy, Dev.= 29, Port= 0, TVD= 8,734’, 1/18/1989 79,624’STA 2: Vlv= Dmy, Dev.=28, Port= 0, TVD= 8,965’, 1/18/1989 89,771’STA 1: Vlv= Dmy, Dev.= 27, Port= 0, TVD= 9,095’, 4/15/1992 9 9,878’ 4-1/2” OTIS SA Sliding Sleeve, ID= 3.813” 10 9,937’ Baker 12’ SBR Tubing Seal Assembly 11 9,952’ 9-5/8” x 3-1/2” Baker SAB Packer 12 9,999’ 3-1/2” X Nipple, ID=2.750 13 10,031’ 3-1/2” XN Nipple, ID=2.635 14 10,067’ 3-1/2” WLEG, ID= 2.992” PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Endicott Oil 10,758’ 10,776’ 9,966’ 9,982’ 18 9/4/90 Sqz 2-1/8” 10,781’ 10,807’ 9,986’ 10,009’ 36 10/27/88 Sqz 2-1/8” 10,816’ 10,828’ 10,017’ 10,028’ 12 10/27/88 Sqz 2-1/8” 10,836’ 10,851’ 10,035’ 10,048’ 15 10/27/88 Sqz 2-1/8” 10,866’ 10,875’ 10,062’ 10,070’ 9 10/27/88 Sqz 2-1/8” 10,890’ 10,910’ 10,083’ 10,101’ 20 9/4/90 Open 2-1/8” 10,910’ 10,934’ 10,101’ 10,122’ 24 5/25/04 Sqz 2-1/8” 10,934’ 10,945’ 10,122’ 10,132’ 11 5/25/04 Open 2-1/8” 10,945’ 10,946’ 10,132’ 10,133’ 1 9/4/90 Sqz 2-1/8” 10,962’ 10,988’ 10,147’ 10,168’ 26 6/24/96 Sqz 2-1/8” 10,996’ 11,024’ 10,177’ 10,202’ 28 8/28/96 Open 2” OPEN HOLE / CEMENT DETAIL 13-3/8” 3,285 cu/ft Permafrost in 17.5” Hole 9-5/8" 575 cu/ft Class ‘G’ in a 12-1/4” Hole 7” 560 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 37 deg. @ 6,945’ Angle at Top Perf = 27 Deg. @ 10,890’ TREE & WELLHEAD Tree 4-1/16” MCEVOY Wellhead MCEVOY GENERAL WELL INFO API: 50-029-21858-00-00 Initial Completion - 10/27/1988 Pulled XXXN Plug – 9/3/2012 Set Patch– 9/27/2012 Set Patch – 10/24/2023 SAFETY NOTE H2S Readings Average 230-260 PPM on A/L & Gas Injectors. Well Requires a SSSV TUBING HANGER NOTE Tubing hanger has a tight restriction. Only able to get a 3.82” broach thru on 5/13/2017. See report. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/19/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231019 Well API # PTD # Log Date Log Company Log Type AOGCC Eset# MPI 2-68 50029218580000 188097 10/15/2023 READ Leak Point Survey Please include current contact information if different from above. T38083 10/20/2023Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 11:16:48 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230920 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPI 2-68 50029218580000 188097 9/11/2023 READ Caliper Survey PBU S-104 50029229880000 200196 9/5/2023 READ IPROF Revision explanation: PBU S-210: Updated LAS files and Final Report added. Please include current contact information if different from above. T38004 T38005 9/21/2023 MPI 2-68 50029218580000 188097 9/11/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.21 09:28:31 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer END 2-68 (PTD# 188-097) IA Exceeded MOASP Date:Thursday, July 14, 2022 10:58:58 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, July 14, 2022 10:00 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Producer END 2-68 (PTD# 188-097) IA Exceeded MOASP Mr. Regg, END 2-68 (PTD# 188-097) was recently shut in for TAR activities at the facility and subsequently exceeded MOASP to 2580 psi. The OGLV was changed out and the well was brought online for a passing warm TIFL. This passing TIFL demonstrates barrier competency. The well is now reclassified as OPERABLE. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Friday, July 1, 2022 1:45 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 2-68 (PTD# 188-097) IA Exceeded MOASP Mr. Regg, Producer END 2-68 (PTD#188-097) was recently shut in for the facility TAR. After being shut in, the inner annulus pressure began to climb and exceeded MOASP to 2580 psi. Currently the well is and will remained shut in until TAR activities are completed. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. C/O OGLV 2. TIFL 3. Engineer to evaluate additional diagnostics as required Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Regg, James B (CED) From: David Gorm <dgorm@hilcorp.com> Sent: Tuesday, April 21, 20204:57 PMj'/ 4I Z I ZtJLtJ l To: Regg, James B (CED) ii Cc: Roby, David 5 (CED) Subject: RE: [EXTERNAL] RE: END 2-68 (PTD: 188-097) Twin Flowline Request Jim, The erosional rates through our production lines have been correlated based on our fluid and gas rates through our facility lines. We calculate our velocity/erosional velocity (v/ve) based on the wells individual well test and we adjust our chokes to target a v/ve near 2.0. We have a subset of wells that we have to choke back reducing the optimization of the well to limit our v/ve through the production lines. We are requesting to add the additional flow line off the tree to increase our overall flow area to reduce our individual flowline v/ve. With the increased flow area we are able to reduce our erosional velocity through our production lines and increase the ultimate recovery of oil from the reservoir. The previous well END 3-31 that we had an additional flowline added off of the tree has proven to reduce our line velocity, reduce the back pressure on the well and increased our recovery of oil. We are now working to build off of that well test and expand the plan to other wells that are currently choked back to limit our v/ve through the production line. After the twinned line is completed some wells may require to have the individual rates tested in our test separator separately due to the increase in volumes we are able to achieve and limitations of our test separator. We currently have END 4-10, END 2-48, END 2-68 submitted to add the additional flowline off of the tree adding another choke and PSL. We are reviewing similar opportunity on End 1-57 and END 1-31 at this time. All the projects are expected to increase ultimate recovery of oil from the reservoir. Let me know if this heled provide more clarity to our requests. Thanks, David Gorm Operations Engineer— Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 From: Regg, James B (CED) [mailto:jim.regg@alaska.gov] Sent: Monday, April 20, 2020 5:10 PM To: David Gorm <dgorm@hilcorp.com> Cc: Roby, David 5 (CED) <dave.roby@alaska.gov> Subject: [EXTERNAL] RE: END 2-68 (PTD: 188-097) Twin Flowline Request Mr. Gorm- I request you provide us an overview of this twin flowline project —scope, objective, and list of wells planned for installation of a twin flowline. 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 lim.regg@alaska.eov. From: David Gorm <dgorm@hilcorp.com> Sent: Monday, April 20, 2020 3:44 PM To: Roby, David S (CED) <dave.robv@alaska.gov>; Regg, James B (CED) <lim.reee@alaska.gov> Subject: END 2-68 (PTD: 188-097) Twin Flowline Request Dave/Jim, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 2-68 (PTD # 188097) in support of a flowline twinning project. Attached request Letter and supporting documents. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer— Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 Regg, James B (CED) From: Roby, David S (CED) n Sent: Monday, April 20, 2020 5:17 PM To: Regg, James 8 (CED); David Gorm Subject: RE: END 2-68 (PTD: 188-097) Twin Flowline Request Mr. Gorm, If this type of operation is something you foresee being used on additional wells in the future it'd might make more sense to amend the pool rules to cover the safety valve and well testing requirements for these types of operations instead of having to approve them on a well by well basis. Regards, Dave Roby 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.¢ov. From: Regg, James 8 (CED) <jim.regg@alaska.gov> Sent: Monday, April 20, 2020 5:10 PM To: David Gorm <dgorm@hilcorp.com> Cc: Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: END 2-68 (PTD: 188-097) Twin Flowline Request Mr. Gorm- I request you provide us an overview of this twin flowline project — scope, objective, and list of wells planned for installation of a twin flowline. 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.reee@alaska.eov. From: David Gorm <dgorm[o@hlIcorp.com> Sent: Monday, April 20, 2020 3:44 PIV Regg, James B (CED) From: David Gorm <dgorm@hilcorp.com> —? U Sent: Monday, April 20, 2020 3:44 PM Hell �I `i u To: Roby, David S (CED); Regg, James B (CED) l Subject: END 2-68 (PTD: 188-097) Twin Flowline Request Attachments: WH Configuration 2-68.pdf; 2-68 -2-70 General Layout.pdf; 2-68-70 P&ID's.pdf; Ltr to AOGCC re 2-68 Flow Line Twinning Request.pdf Dave/Jim, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 2-68 (PTD # 188097) in support of a flowline twinning project. Attached request Letter and supporting documents. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer — Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 THE STATE }ALASKA April 24, 2020 GOVERNOR MIKE DUNLEAVY Mr. David Gorm Operations Engineer Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-030 Well Testing and Safety Valve System Changes MPI 2-68 (PTD 1880970) Duck Island Unit Dear Mr. Gorm: Alaska Oil and Gas Conservation Commission 333 'Nest Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 WWW.00geca10sk0.gov By letter dated April 20, 2020 Hilcorp Alaska, LLC (Hilcorp) requests approval of an alternative well testing methodology and safety valve system changes for Duck Island Unit well MPI 2-68. The well's flow rate is being artificially restricted with a flowing wellhead pressure of approximately 750 psi due to flowline erosion velocity limitations. Hilcorp requests the use of a second flowline attached to MPI 2-68 to enable the well to flow at full rate into the 300 -psi production header. The "twin" flowline has been tied into the existing flowline of long-term shut- in well MPI 2-70 (PTD 1881530) which is adjacent to MPI 2-68, carrying the extra well flow into the production header. The production tree of MPI 2-70 is isolated from its flowline. The MPI 2-68 automatic safety valve system is configured as follows (in the direction of flow): a subsurface safety valve in the tubing, surface safety valve in the vertical run of the production tree, and a low-pressure detection device linked to the existing safety valve control panel. Detection of a low-pressure situation in either of the flowlines closes the surface safety valve, the actuated wing valves on both flowlines, and the subsurface safety valve. Performance testing of the MPI 2-68 safety valve system involves independently actuating the low-pressure switches to verify regulatory compliance. As an alternate method of well testing, Hilcorp proposes the summation of the individual well tests of each of the MPI 2-68 flowlines. Those individual tests will be performed back-to-back to ensure consistent plant conditions and sufficient accuracy for allocation purposes. The Alaska Oil and Gas Conservation Commission APPROVES Hilcorp's request to use the alternate well testing methodology and to install, maintain, operate, and test the twin flowline safety valve system as described in its application, with the following conditions: - The low-pressure detection devices and surface safety valve for the twin flowlines must be uniquely identified and labeled; Docket Number: OTH-20-030 April 24, 2020 Page 2 of 2 - Hilcorp must submit separate test reports for the twin flowline safety salve system tests. Any questions regarding this approval should be directed to Jim Regg at 907-793-1236 (email: jim.rega0)alaska.gov). Si�ncer/ely, v V� 4�— Jeremy M. Price Chair, Commissioner Email: AOGCC Inspectors Carlisle, Samantha J (CED) From: Regg, James B (CED) Sent: Monday, April 20, 2020 4:46 PM To: Colombie, Jody J (CED); Carlisle, Samantha J (CED) Subject: FW: END 2-68 (PTD: 188-097) Twin Flowline Request Attachments: WH Configuration 2-68.pdf; 2-68 -2-70 General Layout.pdf, 2-68-70 P&ID's.pdf; Ltr to AOGCC re 2-68 Flow Line Twinning Request.pdf Need a docket # for this; thank you. 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.rem a@alaska.aov. From: David Gorm <dgorm@hilcorp.com> Sent: Monday, April 20, 2020 3:44 PM To: Roby, David S (CED) <dave.roby@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: END 2-68 (PTD: 188-097) Twin Flowline Request Dave/Jim, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 2-68 (PTD # 188097) in support of a flowline twinning project. Attached request Letter and supporting documents. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer— Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 H Hilcorp Alaska, LLC April 20, 2020 Mr. David Roby Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Re: END 2-68 (PTD # 188097) Request for Approval of Well and SVS Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 2-68 (PTD # 188097) in support of a flowline twinning project. Background END 2-68 is an Endicott natural flow producer completed in the Kekiktuk formation in the upper subzones K3C and K3B. The well has been on steady state production since 2013 and is one of the field's producers with a GOR (`60,000 scf/bbl) and Water Cut (^'94%). Production is currently restricted with a flowing tubing pressure of -750 psi due to flowline erosion velocity limitations. To allow the well to flow at full rate to the —300 psi production header, we would like to connect a 2nd "twin" flowline to the tree to carry a portion of the production from END 2-68 to the flowline of adjacent long term shut-in water injector END 2-70 (PTD#188153). END 2-70 is disconnected and would remain completely isolated from the twinned flowline. Justification Twining END 2-68in this configuration will allow for increased production as well as accurate well testing and allocation within the operating limits of the Endicott MPI test separator. Additional well drawdown is expected to encourage additional K3C and K3B contribution which will help GOR as FTP decreases. Well Testing Methodologv Hilcorp would utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). END 2-68's well tests would be obtained through a summation of individual tests of the original (2-68) and twin (2-6813) flowlines. Currently Endicott wells receive a minimum of monthly tests. With the addition of testing from the twinned (2-686) flowline, a minimum of two tests would be taken to Page 12 ensure one combined 2-68 well test per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain the same utilizing individual tests and flowline On/Off times as determined by the wing valves' open/closed position. Production values for each flowline would then be combined and reported as a single value for END 2-68. This methodology would result in no change or disruption to 2-68's well testing or production reporting. Safety Valve System Low Pressure Switch Configuration Hilcorp would operate and test the SVS systems with the addition of a second low pressure switch to protect against a pressure drop in the twinned (2-68B) flowline. The second low pressure switch would be connected from the twinned (2-686) flowline to END 2-48's safety valve panel. END 2-68's surface and subsurface safety valves would remain unchanged, and the overall safety valve system functionality would be unaffected. When the low pressure switch from either flowline was tripped, both END 2-68's surface and subsurface safety valves would actuate. Additionally, actuated wing valves on either side of the flow cross would close on a low pressure trip. Once installed, this configuration would be function tested and an AOGCC witnessed performance test would be requested. As part of the performance test, each flowline low pressure switch would be tripped independently to verify the correct system actuation pressure for the respective flowline. If you have any additional questions, please contact me at 777-8333 or dgorm@hilcorp.com. Sincerely, Ywl David Gorm Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments END 2-68 Wellhead Twinning Concept Diagram END 2-68 & END 2-68B Redlined P&ID's MPI Wells General Layout END 2-68 Flowline Twinning - Wellhead Arrangement Actuated wings close with trip of either flowline PSL IV New flowline to 2-68B flowline & test/production slot 2-70Im Mor j f Existing flowline to Existing SSV Closes test/production slot 2-68 with trip of either flowline PSL " Ai I i EnEeavvs Islen. 502 591 mmmmmmmmmm ■€ MEN- HEADERSLOTS Endicott Wells status -- MPI & Endeavor Data Current as of Feb 27, 2019 LEGEND aw =aR mmause OE) .AUIVEPEODUCEII /,/iRT ' GASL SHU41JPRODVCER(6j {GASUr -ACFIVE WATER MI£CTORIT2 MPI.2 Entleavnr) 4DD i i9 D SRI 411 WATER INIECFOR14) �ACTVECv1S 0 INJECTOR [3 MPI. 1 EndeavoU SRU,NGASWIEMRD( i OPEN 5113 TINPROO/TESTHEa31FR quo Vim(2)/6N NEADER ROT (21 i .CHOKED FORVNe *v,me3 AJM H3SCDNTENT>=PPm RS) ® WAG WELL(@ j( /.//DISPOSSIWELll51 I H %jJ OFGn OTU/HIXrEGAS B40WOONM Oi Gg5WE111 HEADER (3) A AUTUOROKEOWELLPR D DudexC-SPoolfnrtan.ei nc or,.n:nnrn en 1n11Or t OPERATIONS FORTHE NTFST STAWS OF OROKED FDR VNe �2 WATER INIE(MON HEADER SLO NAT OO NOT ALREADY —•'W PRDERJCTON TIED INTO 714E AMAViV9LE FDR PR CION TIFINSIF THE WL 5 -RESER 15 REWORKED TO ALLOW 10 THE EKGTNG PROD ROWRSNE FLANGE LOUTED3UST ETRE NPERACK Wp'D WALL R SLOTS 2-08 AND 1b1 HAVE UPPED TE-'N5ON 311E WLKRON HEADERS. d.HEAOER AOT 296 MOInjeam VaVv I, Stud. Printed on 319120M IO.43 AT.S B D I s y a , m viEl wa W47��vqq 4 I " i (1M C7_.iZW w WE ------ I C�7uR-a.a..w P= - S D I - N.M , Iw c I END 2-08B P&ID continues next page 8 I A Existing END 2-68 Choke/PSL A! 0 E.PkOYBdyFll 8 1 7 --T-6 ED 3 2 t NQT wmr mo¢aN¢samm � 2 PNL BIPAA'llwtwc to sr ems MMRU FFPI Rb YN AUI[W1kRLLY i R-ILI%I.1m NfN ISEpAE IdNJ61S P9 RWE PALL 4Mpl. x sin IRE"AE ium'taNrn"L (Pi�ARw qII fpq R11ECR Ffl1.S a.lsw ni♦w"era D I S NL P.D pCSMS 9WlE4EC Fp.A WpA $S 0. D6 PtlD VAs [tHIOPN FRW SNE g4GRµ WIRk PMD (PI--£}10D1-DW) I ). PSVN-1118INIPAl6 W WY41C R61Y]MI R CIS SIN 1XE iPpJIT BY ThbgN6 M511 WS �� X�L[A Nll Rp A Ipi p' aneoola w END WELLS PIPING R.smSm De by PIPING•& INSTRUMENTATION DIAGRAM Rsvovrs WELL 2-68 wwe IRc RR.naf�m P1-E2—BP-1000 1 8 4 w"n wt 3 2 1 c 8 A I I mpllta E'�tlIA , m viEl I I I I aneoola w END WELLS PIPING R.smSm De by PIPING•& INSTRUMENTATION DIAGRAM Rsvovrs WELL 2-68 wwe IRc RR.naf�m P1-E2—BP-1000 1 8 4 w"n wt 3 2 1 c 8 A B 1 7 2 _—__--- D F W6YMlY, MES HLLS MYIxp 1. %ttOLLIM SPYh. MfX WXKKXpC Gi B 5 y 4 ---------------------- END 2-68B leg to END 2-70 Production header slot, 2-68B Choke/PSL , , A 8 1 7 3 2 W6YMlY, MES HLLS MYIxp 1. %ttOLLIM SPYh. MfX WXKKXpC m vola w£cirn wnx%, ME pl 1..fM X z c a) MxY VLVF MN TI[PN@WE XFAAt£p s,• ce wnx snv¢ amYE vu. nxx I 52IX YMt£ M (Xdf VAl`h Is Pq6 R�MInM PI RPNK I1fNW�T[flS00. Qi j I WN WXKKXXE 10 WAIFA NSCIXXI SPNff, Itt-114 M5 tlEd VI1Vf D I Z 11AF�F. Vv0.1FS .tlO�N3MylX"i6 .LR � n¢ eNl xEAo xwx 1 FlHEE %mRCOW OF MrylplE 1WF I 6 A�6WY6EO T PXnifO.0 MNWYM M2ttX dNNECIM's MF flNVIXO I �N�MC��4MLLM gEMRI5Wi161Xf R�'kRIEnI1m��IhR W4�(9Mmm'hLL I I s. x�m M� IkxM m Y.LLI£Y 1¢q WAIIX c xrm[mEMmaxzNYam ruo eucnm gym. I I 1. WV CpNA9¢1 m xAIFX x,¢mW, m�AE0.1 Xl®. NYNE4N15 MFi - Wi Mmm�mMCR6 1 fl II¢PlO 1M[Efl¢Vm Flm M[mpMxt ¢M9t Pa9 (N-FI-R-wi�l G m I ION1•]m f mNl@A q 1 1 1 �a ma n n Nz m NmEmNgtl x aumclm zEND WELLS PIPING IurAuxxrr z bp PIPING @ INSTRUMENTATION DIAGRAM WELL 2-70 uN Z—B — PI-E-BPIOUG t B 5NNNo zw 4 E 2 B A THE STATE Alaska Oil and Gas ofAT ACKA Conservation Commission GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-68 Permit to Drill Number: 188-097 Sundry Number: 318-436 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.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. DATED thisV dday of October, 2018. Sincerely, athy P. Foerster Commissioner RBDMS<::�-8CT 0 3 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAC XS 98n 5 SEP '1 8 2018 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q-� Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 • Stratigraphic ❑ Service ❑ 188-097 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21858-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No 0 DUCK IS UNIT MPI 2-68 " 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0034633 ENDICOTT / ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,360' 10,505' 11,265' 10,419' 2,050 11,265' 11,265 & 11,287' Casing Length Size MD TVD Burst Collapse Conductor 92' 20" 131' 131' N/A N/A Surface 2,456 13-3/8" 2,494' 2,494' 5,020psi 2,260psi Production 8,828' 9-5/8" 8,865 8,299' 6,870psi 4,760psi Production 1,415' 9-516' 10,280' 9,547' 8,150psi 5,090psi Liner 1,33T T' 11,360' 10,505' 11,220psi 8,530psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-112" 12.69 / L-80 / TDS 9,93T See Schematic See Schematic 3-1/2" 9.2# I L-80 / TOS 10,067' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 9-5/8" x 3-1/2" SAB and HXO SSSV 9,952MD/ 9,258TVD and 1,530MD/ 1,530TVD 12. Attachments: Proposal Summary 0 Wellbore schematic ❑+ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: 10/14/2018 P OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. pe t /t- ` Authorized Name: Be York Contact Name: Watt Rivard Authorized Title: Operations Manager Contact Email: wrlvard hilcor .corn t� Contact Phone: 777-8547 k, Authorized Signature a.,,, TG! Date: 9/26/2018 COMMISSION USE ONLY Conditions of app". . Notiy Commission so that a representative may witness Sundry Number: n I {✓'1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Y,OCT 0 31010 RBDMS Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No I.yJ Subsequent Form Required: %0 „ L4 04 / APPROVED BY O I Approved by: OMMISSIONER THE COMMISSION Date: �, Form 10-403 Revised 4/2017 z (& ORIGINAL �Q ;3)'5e"b '0'//J Approved application is valid for 12 months from the date of approval. Attachments in Duplicate K Hilmra Alaska, M Tubing Patch Well: 2-68 PTD: 188-097 API: 50-029-21858-00 Well Name: MPI 2-68 API Number: 50-029-21858-00 Current Status: SI Rig: SL & EL Estimated Start Date: Oct 14, 2018 Estimated Duration: 6 days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: N/A Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 188-097 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Current Bottom Hole Pressure: 3,752 psi @ 10,000' TVD (Based on SBH PS taken 8/7/16) MPSP: 2,050 psi (Gas Lift System Pressure) Recent. SI Surface Pressure:—1,450psi (Taken 9/9/17) Min ID: 2.375" at 5,429' Baker KB Patch Tie In Log: SLB Leak Detect Log dated 7/27/07 Brief Well Summary: IA pressurization was recently observed on MPI 2-68 after a plant upset on 9/11/18 suggesting TxIA communication. The well was secured with an IBP set at 10,010' ME on 9/13/18. The well has known tubing leaks at 5,450' and 5,490' MD that were patched with a wireline retrievable patch (70' Element to Element, 77' CAL) in Sept 2012. Going forward, the patch will be pulled and diagnostics performed to confirm there are no new leaks. A patch will then be reset across leaks to restore tubing integrity. Notes Regarding Wellbore Condition: • Well has history of intermittent IAxOA comms through wellhead seals with well SI/cold requiring reenergizing of seals. • Tubing hanger has tight restriction. Maximum OD of recent drift was 3.82" broach on 5/13/17 Objective: Pull suspected leaking patch, confirm leak points and reset patch. Procedure: Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and `2,100 psi high a. Use GL system pressure. 3. RIH and set catcher sub. 4. Pull GLV from station at 4,180'MD 5. Set DMY GLV valve in station at 4,180' 6. Attempt to MIT -T to "'1000 psi. a. Do not exceed pressuring up to 1,000 psi against IBP set at 10,010' Contingency: If MIT -T passes, notify OE to discuss proceeding directly to IBP pull. 7. RIH and pull catcher sub. 8. Pull upper section of 4.5" Baker KB patch (77' OAL) a. Upper section is —40' OAL. b. Snap latch at bottom of upper section is pinned to 5,520# 9. RIH and pull lower section of patch a. Lower section is —37' OAL 10. RIH and pull GLV from station at 6539' MD Tubing Patch Well: 2-68 PTD: 188-097 Hikarn Alaska, LL API: 50-029-21858-00 11. Set DMY GLV in station at 6,539' MD 12. Brush proposed patch set interval from ^'5,400-5,550'MD 13. RIH with D&D hole finder to — 5,500' MD (Below hole at 5,490' MD) 14. CMIT-TxIA to 1,000 psi a. If CMIT-TxIA fails, move D&D downhole until passing test achieved. 15. Reset D&D hole finder uphole to —±5,430' MD (Above hole at 5,450' MD) 16. MIT -T to 1,000 psi. a. If MIT -T fails, move D&D uphole until passing test achieved. 17. RDMO. E -Line 1. MIRU EL unit. 2. Pressure test to 300psi low and—2,100psi high. 3. Set packer and lower patch section at ±5,498' Mid Element Set Depth or just below depth of passing CMIT-TxIA if additional leak points found with D&D holefinder. a. Tie into SLB Leak Detect Log dated 7/27/07 b. Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to set for final approval of tie in. 4. RDMO Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and—2,100psi high. 3. Sting into lower patch section with upper patch and snap latch assembly. 4. Set upper patch section packer. 5. MIT -IA to 2,100 psi a. Monitor for IAxTBG communication. Do not let tubing exceed 1000 psi against IBP. 6. Following passing MIT -IA, RIH and pull IBP at 10,010' MD. ✓ 7. Pull DMY GLV from station at 4,180' MD 8. Set screened orifice GLV in station at 4,180' M 9. Set 4-1/2" BBE SSV at 1,530' MD. 10. RDMO. Attachments: 1. As -built Schematic 2. Proposed Schematic K cora Alaska. LU: KEtBcv.: 56.19/ EFEII 16.22 011 13318' MINID-2375 @5,43D- 7lhingNch 95'8- 3 Cas Lift Valve Depth [kia 7" m SCHEMATIC Duck Island Unit Well: END 2-68 Last Completed: 10/27/1988 PTD: 188-097 SAFETY NOTE TUBING HANGER NOTE H2S Readings Average 230-260 PPM on A/L & Gas Injectors. Tubing hanger has a tight restriction. Only able to get a Well Requires a SSSV 3.82" broach thru on 5/13/2017. See report. TREE & WELLHEAD Tree 4-1/16" MCEVOY Wellhead MCEVOY OPEN HOLE / CEMENT DETAIL 13-3/8" 3,285 cu/ft Permafrost in 17.S" Hale 9-5/8" 575 cu/ft Class 'G' in a 12-1/4" Hole 7" 560 cu/ft Class "G" in 8-1/2" Hole WELL INCLINATION DETAIL Max Hole Angle = 37 deg. @ 6,945' Angle at Top Perf = 27 Deg. @ 10,89d CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor N/A/N/A/N/A N/A Surface 131' 13-3/8" Surface 68/ NT -80/ CYHE 12.415 Surface 2,494' 9-5/8" Production 47/NT80S/NA 8.681 Surface 8,865' 9-5/8" Production 47/NT95H5/NSCC 8.681 8,865' 10,280' 7" Liner 29/ SM -110/ Btrs 6.184 10,023' 11,360' TUBING DETAIL 4-1/2" Tubing 12.6/ L-80/ TDS 3.958 Surface 9,937' 3-1/2" Tubing 9.2#/L-80/N/A 2.992 9,937' 1 10,067' JEWELRY DETAIL No Depth Item 1 1,530' 4-1/2"OTIS HXOSSSV-Nipple ID=3.813" Date Status GLM DETAIL: MGM 4-1/2" RK Latch 2 4,180' STA 6: VIv= Dome, Dev =1, Port= 16, TVD= 4,179', 9/4/2012 3 5,4301 Tubing Patch- Btm @ 5,500'- MIN ID=2.375" 4 6,539' STA 5: VIv= SO, Dev= 36, Port= 24, ND= 6,383', 9/4/2012 5 8,305' STA4:VIv=Dmy,Dev=33, Port= 0, TVD= 7,817', 7/26/2007 6 9,359' STA 3: VIv= Dmy, Dev= 29, Port= 0, TVD= 8,734', 1/18/1989 7 9,624' STA 2: VIv= Dmy, Dev=28, Port= 0, TVD= 8,965', 1/18/1989 8 9,771' STA 1: VIv= Dmy, Dev= 27, Port= 0, TVD= 9,095', 4/15/1992 9 9,878' 4-1/2" OTIS SA Sliding Sleeve, ID= 3.813' 10 9,937' Baker 12' SBR Tubing Seal Assembly 11 9,952' 9-5/8" x 3-1/2" Baker SAB Packer 129,999' 10,048' X Nipple, ID=2.750 13 10,003' 2-1/8" Baker IBP on 9/13/18: OAL=11.04' / 1.375" Fishing Neck 14 10,031' 3-1/2" XN Nipple, ID=2.635 15 10,067' 3-1/2" WLEG, ID= 1992" PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size 10,758' 10,776' 9,966' 9,982' 18 9/4/90 Sqz 2-1/8" 10,781' 10,807' 9,986' 10,009' 36 10/27/88 Sqz 2-1/8" 10,816' 10,828' 10,017 10,028' 12 10/27/88 Sqz 2-1/8" 10,836' 10,851' 10,035' 10,048' 15 10/27/88 Sqz 2-1/8" 10,866' 10,875' 10,062' 10,070' 9 10/27/88 Sqz 2-1/8" Endicott Oil 10,890' 10,910' 10,083' 10,101' 20 9/4/90 Sqz 2-1/8- 10,910' 10,934' 10,101' 10,122' 24 5/25/04 Open 2-1/8" 10,934' 10,945' 10,122' 10,132' 11 5/25/04 Open 2-1/8" 10,945' 10,946' 10,132' 10,133' 1 9/4/90 Sqz 2-1/8" 10,962' 1 10,988' 1 10,147' 1 10,168' 1 26 6/24/96 Sqz 2-1/8" 10,996' 1 11,024' 1 10,177' 1 10,202' 1 28 8/28/96 Open 1 2" TD=11,36U (M0/TD=10,5050 Wj GENERAL WELL INFO FEUD=11,266' (MD)/ PBID=1Q419(IWj API: 50-029-21858-00-00 Initial Completion - 10/27/1988 Pulled XXXN Plug -9/3/2012 Set Patch -9/27/2012 Revised By: TDF 9/27/2018 nilcoru Alaeke, LLC KB Eley.: 55.18'/ BF Eley.: 16.22' 30' t 13-3/8' 2 MN ID=2.375 @5,431' - Tubing Patch-: 3 a Proposed Duck Island Unit Well: END 2-68 Last Completed: 10/27/1988 PTD: 188-097 SAFETY NOTE TUBING HANGER NOTE H25 Readings Average 230-260 PPM on A/L & Gas Injectors. Tubing hanger has a tight restriction. Only able to get a Well Requires a SSSV 3.82" broach thru on 5/13/2017. See report. TREE & WELLHEAD Tree 4-1/16" MCEVOY Wellhead li MCEVOY OPEN HOLE/ CEMENT DETAIL 13-3/8" 1,285 cu/ft Permafrost in 17.5" Hale 9-5/8" 575 cu/ft Class 'G' in a 12-1/4" Hole 7" 1 560 cu/ft Class "G" in 8-1/2" Hole WELL INCLINATION DETAIL Max Hole Angle = 37 deg. @ 6,945' Angle at Top Perf = 27 Deg. @ 10,890' CASING DETAIL Size Type Wt/Grade/Conn Drift I Top Btm 20" Conductor N/A/N/A/N/A N/A Surface 131' 13-3/8" Surface 68/ NT -80/ CYHE 12.415 Surface 2,494' 9-5/8" Production 47/NT80S/NA 8.681 Surface 8,865' 9-5/8" Production 47/ NT95HS/ NSCC 8.681 8,865' 10,280' 7" Liner 29/ SM -110/ Btrs 6.184 10,023' 11,360' s TUBING DETAIL 4-1/2" Tubing 12.6/ L-80/ TDS 3.958 1 Surface 1 9,937' 3-1/2" Tubing 9.2#/L-80/N/A 2.992 9,937' 10,067' 7 JEWELRY DETAIL 3 Cas Lift Valves Depth Unkrwnn 7. L No Depth Item 1 1,530( 4-1/2" OTIS HXO SSSV - Nipple ID=3.813" Date Status GLM DETAIL: MGM 4-1/2" RK Latch 2 4,180( STA 6: VIv=SO, Dev=l, Port= 24, TVD- 4,179', 3 "5,431' Tubing Patch- Btm @ `5,498'- MIN ID=2.375" 4 6,539' STA 5: VIv= Dory, Dev= 36, Port= 0, ND= 6,383', 5 8,305' STA 4: VIv= Dmy, Dev = 33, Port= 0, TVD= 7,817', 7/26/2007 6 9,359' STA 3: VIv= Dmy, Dev. 29, Port= 0, TVD= 8,734', 1/18/1989 7 9,624' STA 2: VIv= Davy, Dev=28, Port= 0, TVD= 8,965', 1/18/1989 8 9,771' STA 1: VIv= Dmy, Dev.= 27, Port= 0, ND= 9,095', 4/15/1992 9 9,878' 4-1/2" OTIS SA Sliding Sleeve, ID= 3.813' 10 9,937' Baker 12'SBR Tubing Seal Assembly 11 9,952' 9-5/8" x 3-1/2" Baker SAB Packer 12 9,999' 3-1/2"X Nipple, ID=2.750 13 10,003' 2-1/8" Baker IBP on 9/13/18: OAL= 11.04'/ 1.375" Fishing Neck 14 10,031' 3-1/2" XN Nipple, ID=2.635 15 10,067' 3-1/2" WLEG, ID= 2.992" PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (ND) FT Date Status Size 10,758' 10,776' 9,966' 9,982' 18 9/4/90 Sqz 2-1/8" 10,781' 10,807' 9,986' 10,009' 36 10/27/88 Sqz 2-1/8" 10,816' 10,828' 10,017' 10,028' 12 10/27/88 Sqz 2-1/8" 10,836' 10,851' 10,035' 10,048' 15 10/27/88 Sqz 2-1/8" 10,866' 10,875' 10,062' 10,070' 9 10/27/88 Sqz 2-1/8" Endicott Oil 10,890' 10,910' 10,083' 10,101' 20 9/4/90 Sqz 2-1/8" 10,910' 10,934' 10,101' 10,122' 24 5/25/04 Open 2-1/8" 10,934' 10,945' 10,122' 10,132' 11 5/25/04 Open 2-1/8" 10,945' 10,946' 10,132' 10,133' 1 9/4/90 Sqz 2-1/8- 10,962' 10,988' 10,147' 10,168' 26 6/24/96 Sqz 2-1/8" 10,996' 11,024' 10,177' 10,202' 28 8/28/96 Open 2" TD=11,360' (MD) / TD=10,505'(TVD) GENERAL W ELL INFO PBTD=11,265' (MD) / PBTD=10,419'(TVD) API: 50-029-21858-00-00 Initial Completion -10/27/1988 Pulled XXXN Plug -9/3/2012 Set Patch -9/27/2012 Revised BY: TDF 9/27/2018 • • RECEIVEDPost Office Box 244027 JUL0 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U3 2015 3800 Centerpoint Drive Suite 100 AOGCC Anchorage,AK 99503 (Rs�1 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100joCts7 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request SCANNED AUG 2 9 2016. Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/121" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig New I API_WellNo I PermitNumber' WellName WellNumber I WeIlNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (do.e) '~ Two-Sided RESCAN Color items: Grayscale items: Poor Quality Originals: DIGITAL DATA [] Diskettes, No. Other, No/Type D Other: TOTAL PAGES: NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL Project Proofing DATE; OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other Is~ [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl SCANNED BY~ BEVERLY BREN VINCENT SHERYL~OWELL DATE~[ i(~ ( ~~'"' /S/ RESCANNEDBY:~BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ( 'l'i? (Yt r FILE # I Pd /J2~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ;333 W. 7th Ave., Ste. 100 ~ Anchorage, Alaska 99501 Voice (907) 279-1433 ¡Fax (907) 276-7542 RECEIVED 1 STATE OF ALASKA • KA OIL AND GAS CONSERVATION COMMISSION OCT 17 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other ICJ *a b i M ,4� Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ c) Change Approved Program ❑ Operat. Shutdownf Stimulate - Other ❑ Re -enter Suspended Went] 2. Operator 4. -Well Class Before Work: 5. Permit to Drill Number. Name: BP Exploration (Alaska), Inc ` Development 0 Exploratory ❑ 188 -097 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21858 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0034633 EPA 2- 68/S -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): f _ To Be Submitted ENDICOTT, ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 11378 feet Plugs measured None feet true vertical 10520.55 feet Junk measured See Attachment feet Effective Depth measured 11265 feet Packer measured See Attachment feet true vertical 10418.57 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 92 20" 94# H-40 39 - 131 39 - 131 1530 520 Surface 2456 13 -3/8" 68# NT8OCYHE 38 - 2494 38 - 2493.94 5020 2270 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 f3 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 18 15 5915 1869 402 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El . j Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _ El Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Gar .Catron 0 BP.Com Printed Name Garry Catron Title PDC PE Signature 9.1aA J Cf..-^L.> Phone 564 -4424 Date 10/16/2012 FiFrr,IVIS OCT 1 9 201 /0 . 4 .1./ 1---- Form 10-404 Revised 10/2012 Submit Original Only 2- 68/S -17 188 -097 -0 Junk Attachment SW Name MD Date Description 2- 68/S -17 11265 3/11/92 Two Gas Lift Valves 2- 68/S -17 11287 3/6/92 Dummy Gas Lift Valve • • Packers and SSV's Attachment ADL0034633 SW Name Type MD TVD Depscription 2- 68/S -17 PACKER 5429 5360.62 2 -7/8" Baker KB Packer 2- 68/S -17 PACKER 5468 5397.38 2 -7/8" Baker KB Packer 2- 68/S -17 PACKER 9952 9202.45 3 -1/2" Baker SAB Packer Casing / Tubing Attachment ADL0034633 Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 20" 94# H-40 39 - 131 39 - 131 1530 520 LINER 39 2 -7/8" 6.16# L -80 5429 - 5468 5415.82 - 5452.58 13450 13890 LINER 1337 7" 29# SM -110 10023 - 11360 9321.37 - 10504.3 11220 8510 PRODUCTION 8828 9 -5/8" 47# NT8OS 37 - 8865 37 - 8298.74 6870 4760 PRODUCTION 1415 9 -5/8" 47# NT95HS 8865 - 10280 8298.74 - 9546.67 8150 5080 SURFACE 2456 13 -3/8" 68# NT8OCYHE 38 - 2494 38 - 2493.94 5020 2270 TUBING 9901 4 -1/2" 12.6# L -80 36 - 9937 36 - 9244.15 8430 7500 • TUBING 130 3 -1/2" 9.2# L -80 9937 - 10067 9244.15 - 9360.35 10160 10530 • Perforation Attachment ADL0034633 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 2- 68/S -17 3/7/1992 SQZ 10758 10776 9965.58 9981.59 2- 68/S -17 3/7/1992 SQZ 10781 10807 9986.03 10009.16 2- 68/S -17 3/7/1992 SQZ 10816 10828 10017.16 10027.84 2- 68/8-17 3/7/1992 SQZ 10836 10851 10034.96 10048.3 2- 68/S -17 6/19/1996 SQZ 10866 10875 10061.64 10069.64 2- 68/8-17 5/25/2004 RPF 10890 10910 10082.98 10100.76 2- 68/S -17 5/25/2004 SQZ 10910 10934 10100.76 10122.1 • 2- 68/S -17 5/24/2004 RPF 10934 10945 10122.1 10131.89 2- 68/S -17 5/24/2004 SQZ 10945 10946 10131.89 10132.78 2- 68/S -17 8/27/1996 SQF 10962 10986 10147.01 10168.37 2- 68/S -17 8/28/1996 RPF 10996 11024 10177.27 10202.2 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • 1 • Daily Report of Well Operations ADL0034633 • SUMMARY *,_.. �_ '® S -x `11- r - : 11 r •5` Pumped 5 bbls Neat Methanol followed by 25 bbls am Diesel down TBG. * * *WSR continued to 9 -12. 9/11/2012 12 * ** ** *WELL SHUT IN UPON ARRIVAL * ** (E -LINE: II3P /PACKER) INITIAL T /I /O = 1400/300/0 PSI INITIAL VALVE POSITIONS: SWAB /SSV/WING = CLOSED, MASTERNALVES TO CASING = OPEN SET BAKER 2 -1/8" IBP @ 10,010'.ME (TOP @ 10003') (OAL = 11.05' / 1.375" FN / 2 -6" ELEMENT W/ 1" STIFFENER RING) • CORRELATED TO 4.5" TUBING SUMMARY DATED 13 -SEPT -1988. LRS CURRENTLY IN PROCESS OF PERFORMING MIT ON IBP ** *CONTINUED ON 12 -SEP- 2012 * ** 9/11/2012 * * *WSR continud from 9- 11 -12 * ** Assist E -Line with CMIT TxIA ** *PASS * ** ( Repair TxIA comm with tbg patch) Pumped an additional 1.47 bbls down TBG to achieve 3000 psi CMIT TxIA test pressure. TBG lost 10 psi in the first 15 minutes and 8 psi in the second 15 minutes for a total loss of 18 psi over the 30 minute test. IA lost 10 psi in the first 15 minutes and 6 psi in the second 15 minutes for a total loss of 16 psi over the 30 minute test. E -Line in control of well pad op notified upon departure. FWHP = 1116/1006/0 S/W /SSV /M = E -Line 9/12/2012 IA/OA = OTG ** *JOB IN PROGRESS FROM 11 -SEP- 2012 * ** E -LINE: LOWER PACKER SET ZING LRS PERFORMED PASSING CMIT Tx IA TO 3000# SET BAKER 4 -1/2" LOWER PKR @ 5500' M.E. (TOP SET @ 5468') (OAL= 36.56" / MIN ID = • 2.45 ) i- CORRELATED TO SLB LEAK DETECT LOG DATED 27 -JUL -2007 FINAL VALVE POSITIONS: SWAB / SSV/WING = CLOSED, MASTERNALVES TO CASING = OPEN FINAL T /I /O = 1100/1000/0 PSI . ., WELL LEFT SHUT IN - NOTIFIED PAD OP OF WELL STATUS 9/12/2012 ** *JOB COMPLETE * ** ** *WELL SHUT IN ON ARRIVAL * ** (patch tubing /liner) DRIFT DOWN TO LOWER PATCH ANCHOR W/ 3.805" G.RING TO 5440' SLM 9/26/2012 * ** CONT WSR ON 9/28/12 * ** Daily Report of Well Operations ADL0034633 CONT WSR FROM 9/26/12 xV 51 " t4` SET BAKER KB -45 PATCH IN LOWER ANCHOR AT 5440' SLM(oal=40.67', min ID= 2.375") MIT -T TO 3000# ...PASS(see data tab) PULL 2 -1/8" IBP FROM 9980' SLM /10003' MD(all elements and stiffener ring recovered) 1 BRUSH SVLN AT 1496' SLM /1530' MD NOTE: UNABLE TO PASS THROUGH TREE WITH 4 -1/2" BBE OR 3.84" NOGO CENT 9/27/2012 ***CONT WSR ON 9/28/12 * ** ***CONT WSR FROM 9/26/12 * ** • SET 41' OF BAKER KB -45 PATCH IN LOWER ANCHOR AT 5440' SLM 9/27/2012 MIT -T TO 3000 #....PASS(see data tab) • TREE= 4 -1/16" MCEVOY • SA NOTES: MS READINGS A CT LHEAD= MCEVOY END 2 - ACTUATOR PPM ON All & GAS NJEC ORS WELL REQUIRES = KB. EFEV = 55.18' - ' SSSV .« BF. ELEV = 16.22 KCB= O 1530' — - 112" OTIS SSSN NIPPLE, D = 3.813" Max Angle 37° @ 6945' Datum MD = 10859' Datum1VD= 10000'SS 5429' --145 BKR KB PATCH, 13 = 2.375" (09/27/12) 13 -3/8" CSG, 68#, NT80 -CY HE, H 2494' ID = 12.415 " 2 5468' — 4 -1/2" BKR LOWER STRADDLE PKR FOR PATCH, (OAL 36.56 "), D = 2.45" GAS LFT MANDRELS 1 ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 4180 4179 1 MGM DOME RK 16 09/04/12 5 6539 6383 36 MGM SO RK 24 09/04/12 9-5/8" CSG, 47 #, NT80S — 8865' >< 4 8305 7817 33 MGM DMY RK 0 07/26/07 3 9359 8734 29 MGM DMY RK 0 01/18/89 2 9624 8965 28 MGM DMY RK 0 01/18/89 Minimum ID = 2.375" @ 5429' 1 9771 9095 27 MGM DMY RK 0 04/15/92 45 BKR KB PATCH I I I 9878' ---I OTIS XA SLIDING SLEEVE, D = 3.813" I I4 -1/2" TBG, 12.6#, L -80, .0152 bpf, 13= 3.958" — 9936' 9937' H BAKER 12' SBR, D = ? 9952' — I9 - 5/8" BKR "SAB" PKR , D = ? 9964' H4/1/2" X 3-1/2" XO, ID = 2.992" I I I F — 9999n -3 - 112" OTIS X NIPPLE, 13 = 2.750' ( 3 -1/2" TBG, 9.2# L -80, .0087 bpf, 13 = 2.992" H 10066' I I 10031' --1 3-1/2" OTIS XN NIPPLE, D = 2.635" 9 -5/8" CSG, 47 #, NS95HS, — 10280' \/ \ 10067' 3-1/2" WLEG, D = 2.992" .0733 bpf ID = 8.681" PERFORATION SUMMARY REF LOG: DLL -GR (09/09/88) ANGLE AT TOP PERF: 27° @ 10890' Note: Refer to Production DB for historical perf data SIZE SPF( INTERVAL Opn/Sqz DATE 2 -1/8" 4 10758 - 10776 S 03/08/92 2 -1/8" 4 ",`,` 10781 - 10807 S 03/08/92 2-1/8" 4 "`. 10816 - 10828 S 03/08/92 2 -1/8" 4 10836 - 10851 S 03/08/92 2 -1/8" 4 10866 - 10875 S 08/23/96 2 -1/8" 4 10890 - 10946 S 08/23/96 2 -1/2" 4 g 10890- 10910 C 05/25/04 2 -1/2" 4 10934 - 10945 C 05/25/04 2-1/8" 4 j 10962 - 10986 S 08/23/96 2 -1/8" 5 10996 - 11024 S 08/23/96 I ? ?? H FISH- 1 EE GAS LFT VALV ES ( ? ? ? ?) 2 4 € , 10996 - 11024 C 08/27/96 I 11265' — TOP OF CEMENT (3 /11/92) I MID --I 1128T .�.�.�.�.�.�.�.�. 4 7" LNR, 29#, SM BTRS - TKC, D = 6.184" I I 11360' 444444 4 DATE REV BY COMMENTS DATE REV BY COMMENTS E DICO T UNIT 08/01/98 COMPLETION 09 /08/12 PJC DRAWING CORRECTIONS WELL: 2 -68 / S-17 12/04/08 SWCIPJC XXN PLUG (11/15/08) 09/13/12 JCMJM) SET EIP & LWR PKR (09/11 - 12/12) PERMIT No: 1880970 02/17 /11 M3/JMJ SSSV SAI-f_IY NOTE 10/01/12 THWJMD PULL IBP& SET45 KB PATCH (09/27/1 AR No: 50- 029 - 21858 -00 08/15 /11 DW /JM) H2S SAFETY NOTE SEC 36, T12N, R16E, 2137' SNL & 2366' WE _ 09/06 /12 CJWJM? PULLED XXN PLUG (09/03/12) 09/18/12 CJW PJC GLV C/O (09/04/12) ] BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 SFLANtiFJ) SET? k '4.131;f. Mr. Jim Regg Q Alaska Oil and Gas Conservation Commission , 8' 0 1 - 1 N 333 West 7 Avenue I $ 1 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 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, 1;1 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Endicott Row 2 Date: 03/28/2012 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 ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2-08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0 -16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0 -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S-13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S-14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 1 0-12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 ,�- j END2 -68 / S-17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 08/30/07 Schlumberger NO. 4396 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 . L ATTN: Beth ~ \d~ ))'1-ec,· ~l sCANNED SEP 1 8 Z007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay E d' U /~ n ICO Job# Loa Description Date BL Color CD \.. MPC-08 / N/A RSTIWFL 08/10107 1 I.......· I " 11767136 MEM INJ PROFILE U::r:~ le- G;¡ - J^-:f 08/12/07 1 P2-16 11856185 INJECTION PROFILE ()'Tt' Ie. ~ - L~~ 08/02/07 1 07 -02A 11649983 MEM PROD PROFILE I q (. - îY1 s< 08/07/07 1 R-13 11856186 INJECTION PROFILE tiT 11 ,. 3 - t'N~ 08/02/07 1 D-11A 11649982 MEM PROD PROFILE I C1,",,- - 1'1<'7. 07/26/07 1 S-42 11686773 LDL I q {¿¡ - {'ü"(/ 08/02/07 1 S-43 11855804 LDL Jq4-t'ì~:J 08/02/07 1 16-07 11855806 STATIC PRESSURE SURVEY /~S--r:¡o4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY J 1\f\ -:i./ ~ 08/04/07 1 1-09A1L-21 11849930 SBHP SURVEY J ~ ~ - t'J::Jq 08/04/07 1 2-68/S-17 11630491 LDL l~- rA'+ . 07/27/07 1 1-2310-15 11846802 STATIC PRESSURE SURVEY U:r:(I_ lC}q - J~ ~ 08/11/07 1 Z-46 11057080 CH EDIT PDC GR (USIT)~Dt)-J~ï 'It r~<'¡~ 12/14/05 1 A-09A 11216203 MCNL .c(''jD- I~U 'II 1S'{/,Q'-( 06129/06 1 1 L3-11 11801065 RST i '75D ;)~ I .... '" 05/31/07 1 1 PLEASE ACKNOWLEDGE RECEIP~,~r "§!S?~J,~~.AND R~!.!:'",RNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. !."¡"!{.' ,w...j.....'" F.. .'" ..'.i", r:.i ~...f ~...", ,t; 'I:,\~' <\ l' b I" "~þ m Petrotechnical Data Center LR2-1 . .. ~" '''. ,,-..... ,¡.' i'-..,_ 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ""''''''''''' AI< ""~ A TTN: Beth Received byt,. -_....~ C.' I" r' .:, 1::'1") 4 Z007 Date Delivered: /1'1 ¡d ··'·...1'1" I" ( " " -<;·y,,(',/i. {\~ <:1:"'):;' .,,{lr¡;:~, t ,(Hnn1m~¡~t}rn . . Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description Date BL H-01A \ q ~- - \ \ 1..) 10687663 LDL 01/04/04 1 J-24A .1~ý -1\~ 10563218 SBHP SURVEY 09/28/03 1 E-05A ¡CjQ-030 10703984 SBHP SURVEY 04/10/04 1 A-13 I g ¡ - i S-t.I 10621770 PPROF WIDEFT/GHOST 03/22/04 1 C-17A \ q ~- (5 ;""J 10672332 LDL 10/27/03 1 F-46A :) C/-f - (, t "'( 10715389 MCNL 03/18/08 1 2-68/S-17 J 8 ;j .. 0 9 '1 10866550 PPROF W/DEFT 07/07/04 1 1-45/Q-26 189 ~ ¡ :1. &f 10568473 PPROF WIDEFT/GHOST 07/11103 1 B-17 /7Q--C')...t} 10679034 PSP INJECTION PROFILE 11/27103 1 S-30 I c¡ (, -. t ~ G, 10560328 SBHP SURVEY 01/02/04 1 S-42 \ q L~ è t;; '-f 10877777 SBHP SURVEY 08/22/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 :'sC/-\NNEC SEP u 8 2005 1 ) f ~^J....'\~ ¡;\¡') ,~"'t-\. Dale Delivered' 07/20/05 NO. 3438 \ Cf/6 .J()'17 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD '- '13 J/-t J --- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995031838 , ! J I A TTN: Beth /1 ¡ / r'~j I :1 1 . II I I I ' Received by: iYf1fiN't!(' l..l :(,~ MICROFILMED 10/12/00 DO NOT PLACE · ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging,, Pull tubing Alter casing Repair well __ Perforate. X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272'SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398'SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number/approval number 88-97/Not required 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11360 feet 10504 BKB feet 11287 feet 10440 BKB feet Plugs (measured) Junk (measured) Top of squeeze cement at 11265 Casing Length Structural Conductor 92' S u rface 2455' Intermediate 10241' Production Liner 1337' Perforation depth: Tubing (size, grade, and measured depth) Size 30" 13 3/8" 9 5/8" Cemented Measured depth True vertical depth BKB BKB Driven 131' 131' 3285 c.f. Permafrost 2494' 2494' 575 c.f. Class G 10280' 9530' 7" 560 c.f. Class G 10023' - 11360' 9321' - 10504' measured 10758'- 10776'; 10781'- 10807'; 10816'- 10828'; 10836'- 10851'; 10866'- 10875'; 10890'- 10946'; 10962' - 10986' (all squeezed) 10996'- 11024' (open) true vertical (Subsea) 9910- 9926~ 9931'- 9954'; 9962'- 9973'; 9980'- 9993'; 10006'- 10014'; 10028'- 10077'; 10092' - 10113' (all squeezed) 10122'- 10147' (open) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951~ 4 1/2" SSSV at 1530' 13. Stimulation or cement squeeze summary Water/Gas Shut off, Squeeze (all peris - 8/26/96) Reperiorat~,(~l~;~6l-~.l ;10;]~4'~' L) 8/27/96) Intervals treated (measured) 10758'- 10776' ;10781'- 10807'; 10816'- 10828'; 10836'- 10851'; 10866' 01~'7~ ~8~-~ 10946'; 10962'- 10986'; 10996'- 11024', 10996'- 11024' Treatment description including volumes used and final pressure See attachments Alaska 0il & {3as Cons. Commission Anchor~g~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 172 391 4118 0 20 157 4042 0 Tubing Pressure 384 353 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ..X Gas __ Suspended Service 17. I hereb~.c~rtify that the~f~e~going is tru,e a,~d correct to the best of my knowledge. Signed( ........... ~~~,, '~;~7'/ ~,'{~..-~L.,, -~/ Title Senior Technical Assistant IV Form 10;40~/Flev 06/15/88 Date 10/18/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department ....... POST SQUEEZE PERFORATIONS DATE: 8~27~96 WELL N-°: 2-68/S-1 7 BP EXPLORATION REP: SERVICE COMPANY: POWERS AWS (BRUNNER) DATE/TIME OPERATIONS SUMMARY I 15:00 MIRU ATLAS SIP=1150 lAP=300 OAP=50 16:20 RIH WITH 28' 2-1/8" PREDATOR GUN, GR, CCL. ,,, 17:21 OUT OF TUBING. TIE-IN TO DLL DATED 9/9/88 17:40 _ ADD 17'. LOG INTO POSITION. WELL SHOULD BE UNDERBALANCEDi SIWHP = 965 PSIG. ,,, 17:45 SHOTGUN FROM 10996'-11024' ELMD. LOG OFF. POOH. 18:20 OOH. CONFIRM ALL SHOTS FIRED 18:45 RDMO ATLAS. POP WELL WITH LIFT GAS., SIWHP=1150 PSIG PERFORATION SUMMARY: SUBZONE DEPTH INTERVAL 3B1 10996' MD - 11024' MD 28' ALL PERFORATIONS WERE SHOT USING 2-1/8 PREDATOR, 6 SPF, 0 DEGREE PHASING & 0 DEGREE ORIENTATION. BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE FROM: D. Varble/ J. Powers WELL: 2-68/S-17 OPERATION: WSO Cement Squeeze Initial Well LOCATION: ENDICOTT Status (psi) (psi) , (psi) (psi) (psi) (o F) II 4350 I1125 I 0 I 2oo0 I 25o I TIMEI OPERATION I 8:00 RU NC 4906. MU BHA 9:48 PT to 4000 psi- OK. 1005 Bleed down to 1500 psi. open swab SIP = 1350 psi RATE IWHP J STG · i vo..· RETN. I REMARKS 1005 SURF 0 1300 1350 RIH 1050 4390 1.5 1350 1200 1 pump down coil & test injectivity 1104 6025 1.37 3500 1550 26 open ck. to circ. kill well 1109 6600 1.8 3650 1325 35 taking gas returns down flowline. 11:40 10000 1.8 3700 1400 90 15K up wt 1150 11000 .2 1200 1400 110 close ck. & reduce pump rate to tag td. 1200 11216 .2 1200 1400 112 ta~l hard btm. @ 11216' softfrom 11115'on 1204 11074 2.0 3750 1300 124 continue circ kiil takin~l returns down flowline, flag line 1254 11074 1.8 3625 1300 210 - Hydrate chemicals 1315 11074 1.8 3600 1290 257 cooling pass to10500 batch cmt. 16.5K up wt. 1356 11074 1.8 3620 1250 320 back @ cooling 1410 11074 0 1350 1300 332/0 switch to BJ to pump acid 1414 11074 1.5 3000 1300 5 acid in coil. 5 min f.I. test = 43.1 mis 1424 11035 1.5 2650 1300 20/14 acid away. switch to seawater 1429 11035 1.5 2500 1300 10 acid off surface. 15 f.I. test = 45.2 mis 1436 11035 1.5 2600 1330 19 acid @ nzl. 1438 10986 .5 2600 1300 20 close ck. good break - reciprocate pipe 1442 11035 1 2275 1600 35 increase rate 1451 11035 1 2300 1600 38 acid out nzl. Over displace acid with FSW 14:58 11074 1 2612 1800 40/0 SWto EF 15:03 " 1/1.5 2400 1300 6.5 crack chokes and increase rate 15:09 " 10/0 SW to cmnt 15:19 " 1.46 3500 900 16.5/0 SW to EF 15:25 " 1.9 3440 920 10/0 SW to FSW 7 8 15:31 9 Cement at nozzle, PUH at 10 FPM 10 11 12 13 14 '"15:36 11000 1 600 900 15 Increase pressure to 1500 psig, 35 FPM 16 15:38 10920 1385 1500 17 18 19 15:42 10820 1750 1500 20 Start live cell 21 22 23 24 ,,, 15:46 10624 2200 1500 25 PLF 26 15:49 10400 1 2330 1500 28 0 At safety, start gauging returns 15:50 2350 1500 29 1 Increase pressure. 15:52 1750 30 2 15:52 2000 31 2.5 15:53 2500 32 3.0 15:54 -33 4.0 15:56 1/.5 2500 ~ 34 4.5 15:58 35 5.5 Increase pressure 16:00 3200 36 5.75 16:03 3500 37 6.0 16:06 - 38 6.5 39 7 'i6:08 40 8 .... 16:10 , , 3500 41 8.5 SD and trap pressure ,, 16:15 2950 Bump Pressure back,up. .,16." 18 3550 42 Still leaking 16:25 2540 bleed pressure to 2000 psig. 16:33 1857 Bump pressure back to 2000 psig 1641 10400 1.6 0 1600 0 start reverse out live cell = 33 mis. ,, , 1647 10645 1.6 0 2100 31 30 top of cmt. 1711 10750 1.4 10 2270 52 reduce rate. top of perfs 1806 11030 1.4 0 ,, 2255 136 thru perfs 18:21 11085 1.4 2270 148 Wait for bottoms up. C/O depth 11780' 1845 11080 1.6 0 2000 185 181 Btms. up switch over for jet pass 1848 11080 1.5 3160 1500 0 jet pass up 1851 10970 1.75 ' 3750 1500 7 above sqz. perf. increase rate 1902 10500 1.7,5, 3720 150'0 27 ' Jet pass down 1915 10980 1.5 3325 1500 46 Jet across perfs. Reduce rate 1917 11080 1.5 3325 1500 51 On btm. Pooh 1920 10800 1.6 0 2100 0 Reverse out. 1933 11085 1.6 0 2145 18 20 On btm. 1955 11085 1.66 0 2000 54 56 Btms up. Pooh 1958 10980 0 1940 1975 '59 60 Press. test .... 2008 10980 0 1940 1973 Good test. 2010 10980 0 2000 2035 Lift gas press, on tbg. Pooh 2110 2000 0.5 2180 2025 Out of fluid, pump down coil. 2120 sur. 0 2000 2030 5 Ooh 2127 sur 2 ,,3500 2030 4 Freeze protect coil with MEOH.' Status (psi) (psi) (psi) II 8/23/96 I 2030 I 2030 I 0 GLP J FLT (psi) (° F) I SUMMARY Circulate kill well due to poor injectivity. (1 bpm @ 2300psi) Tag TD @ 11216' CTM. Cool sump. Wash perfs with 14 bbls. HCL/XYLENE. Good break (approx. 500 psi) Lay in 16 bbls cement from 11074' @ 900 psi. Perfs covered, ramp up to 1500 psi. Ramp up to final sqz. pressure of 3500 psi. Leaking off. (found out late~r it was leaking thru G/L jumper line) LRO to 11085'. Jet cemented interval & RO to 11085'. Press. test to 2000 psi. Jug tight. Apply 2000 psi. lift gas press. to tbg. Pooh. Fluid level left @ 1600'. Under balance for inflow test will be1050 - 1100 psi, Left 2000 psi on tbg. 800psi overbalanced. FLUIDS PUMPED B BLS. DESCRIPTION 746 FSW 14 15% HCL/XYLENE 20 EW 16.5 CEMENT 4 MEOH , BOTTOM-HOLE ASSEMBLY #1 "To01 Strin~1 Descriptions I O.D. I I.D. I Length I Comments TC I 2.45 1' CNZI 2.5 .5' TOTAL 1.5' CEMENT DETAILS BJ SERVICES 15.8 PPG Class G Cement containing: 0.1% CD-32 0.32% R-11 0.58.% FL-33 1.0 gal/100 sx FP-6L Thickening Time = 8 HRS. + 1 HR. Surface time Lab APl Fluid Loss = 48.4 Field APl Fluid Loss = 46.1 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK,~ 99501. Date: 7 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ,~ # DESCRIPTION ~--~o~-o~ ~ q%'O~'q~ ~.~ ~ ~.+~ 2-16/M-16 ~/~ 1 PLS FINAL BL+RF ECC No. Run ~ 1 5639.01 Run ~ 1 6001.16 Run # 1 6148.05 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street g, FAX to (907) 563-7803 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. operations performed: Operation shutdown Stimulate Plugging .. Perforate × Pull tubing Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI At top of productive interval 4272'SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410'SNL, 4351' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 88-97iNet required 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11360 feet 10504 BKB feet 11287 feet 10440 BKB feet Plugs (measured) Junk (measured) Top of squeeze cement at 11265 3gasliftvalvesat11265'O R I G I NA Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 92' 30" Driven 131' 131' Surface 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' Intermediate 10241' 9 5/8" 575 c.f. Class G 10280' 9530' Production Liner 1337' 7" 560 c.f. Class G 10023'- 11360' 9321'- 10504' Perforation depth: measured 10758'- 10776'; 10781'- 10807'; 10816'- 10828'; 10836'- 10851'; 10866'- 10875'; 10946'; 10962' - 10986' (all squeezed) 10996'- 11024' (open) true vertical (Subsea) 9910-9926'; 9931'- 9954'; 9962'- 9973'; 9980'- 9993'; 10006' '[J~)~[74~;'F.:', '<. " 10077'; 10092'- 10113~ (aflsqueezed) 10122'- 10147' ~'o~)en) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951~ 4 1/2" SSSV at 1530' 13. Stimulation or cement squeeze summary Water/Gas Shut off, Squeeze (all perfs - 6/19/96) Reperforate (10996'- 11024'- 6/24/96) Intervals treated (measured) 10758'- 10776';10781'- 10807'; 10816'- 10828'; 10836'- 10851'; 10866'- 10875'; 10890'- 10946'; 10962'- 10986'; 10996'- 11024', 10996'- 11024' Treatment description including volumes used and final pressure See attachments 14. Representative Daily Average Production or Injection Deta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 106 1520 3419 0 830 216 1042 3441 0 360 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed :':: ~,~/~-{.,<' ; ~): ~"(. '<"/ Title Senior Technical Assistant IV Form 10-404~¢1~0v 06/15/88 Date 8/20/96 SUBMIT IN DUPLICATE L Endicott Production Engineering Department RE- PERF DATE: 6-24-96 WELL N-°: 2-68/S-17 BP EXPLORATION REP: SERVICE COMPANY: VARBLE AWS (BARKER) 'DATE/TIME OPERATIONS SUMMARY 1000 MIRU ATLAS · 1045 ARM GUN 1150 RIH WITH PFC/28' GUN 1230 OUT T.T. - OPEN GLT & POP @ 60 BEANS. FWHP--'350 PSI ' ' 1240 LOG TIE IN PASS FROM 11040'- 10795' MD. ADD 40' 1250 LOG REPEATPASS UP TO 10600' MD. (VERY HIGH G.R. COUNTS THROUGH PERFORATED INTERVALS. NOTHING TO CORRELATE TO) , 1400 TAKE OUT 2'. LOG REPEAT PASS. 1428 ON DEPTH. LOG INTO PLACE @ 10991' MD (5' FROM TOP SHOT TO PFC) & SHOOT GUN FROM 10996' - 11024' MD. GOOD CAP BREAK, NO WEIGHT CHANGE 143'5 LOG OFF. 1443 SHUT IN WELL & POOH. 1515 OOH 1519 ALL SHOTS FIRED. 1600 RDMO , .... , PERFORATION SUMMARY' SUBZONE DEPTH INTERVAL 3B2 10996' - 11024' MD 28' ALL PERFORATIONS WERE SHOT USING 2" ALPHA JETS, 4 SPF, 90 DEGREE PHASING & RANDOM ORIENTATION. To: Wood / Metzger From: Collins Operation: 2-68/S-17 Cement Squeeze Location: Anchorage Date'6/19/96 I Initial Well Status I FWHP I lAP I 0AP (psi) (psi) (psi) I 1650 I 1275 I SIGLP (psi) (psi). (°F) 0 I 600 I na ITIME I OPERATION I06:30 I MIRU 4906 07:10 1 Pressure test to 4000 psi. 07:20 1 Open swab and start bullhead kill. TIME DEPTH RATE CTP WHP STAGE OUT RETURN REMARKS , ,(ft) (bpm) (psi) (psi) bbls nozzle bbls CTV 33 bbls ..... 07:20 17 , i 5.0 1650 1650 0 Openswab. 07:45 " 5.0 2100 2100 11 4 WHP starting to increase. Shut down and start in hole. 09:00 7300" 1.5 2400 ' 1500 114/0 Start circulation kill. 09:45 11050 2.5 3700 1250 75 Park and continue kill/cooldown. 11 '00 " .... 600 280 Well fluid packed and cooled. Hold safety meeting. I 1 · 10 " 1.5 1 900 600 285 / 0 Start acid. Take returns up backside. , I 1 '24 .... 1500 600 21/0 Start seawater displacement. 11 · 32 10776 ...... 1 2 0 Acid at nozzle. Close chokes. Pump 5 bbls at depth of leaking perf. 11'35 .... 2000 1200 I 7 5 Pump the rest While moving down over perfs. 11"45 11020 " 2250 1250 33 21 Shut down for soak. No~cid action obvious. Cement to weight. '12:00 11050 " 2300 1 200 Displace acid out of sump and from above perfs. 12:25 10500 " 2500 1200 15 min fluid loss 45 cc/30 min. Test second sample. Circulate to cool. 12: 55 11033 '1600 850 Second sample the same. 13:02 11050 1.5 2150 850 86/0 Start freshwater spacer. --- STATE OF ALASKA .~ --- A ,,A, OIL AND GAS CONSERVATION COMMI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging Pull tubing Alter casing Repair well .... Perforate__ Other_Z_ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development .. Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI At top of productive interval 4272'SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410'SNL, 4351' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 88-97/Not required 10. APl number 5O- 029-21858 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 11360 feet 10504 BKB feet Plugs (measured) Top of squeeze cement at 11265 Effective depth:, measured 11287 feet true vertical 10440 BKB feet Junk (measured) 3 gas lift valves at 11265' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve.j'tic__~l depth BKB 92' 30" Driven 131' 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 9530' 1337' 7" 560 c.f. C/ass G 10023'- 11360' 9321'- 10504' measured 10758'- 10776'sqzd;' 10781'- 10807'sqzd; 10816'- 10828'sqzd; 10836'- 10851'sqzd; 10866'- 10875'; 10890'- 10946'; 10962'- 10986'; 10996'- 11024 true vertical (Subsea) 9910 - 9926'sqzd; 9931'- 9954'sqzd; 9962'- 9973'sqzd; 9980'- 9993sqzd'; 10006'- 10014'; 10028'- 10077'; 10092'- 10113'; 10122'- 10147' Tubing (size, grade, and measured depth) 4 1/2" 12.6~ L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSS V at 1530' MA v ,, 13. Stimulation orcementsqueezesummary Scale inhibitortreatment (4/12/95) Ai.~,,~_ '"-~ ~ ~ ~ ~^A ..... oil Intervals treated (measured) 10866'-10875';10890'-10946';10962'-10986'; 10996'-11024~ueraa~vr/;~"~/15~'ff~'C°r~lleSi$/~~te ..... itor mix; --, . 70 Bbls diesel/mutual solvent, 73 B__ . Treatment description including volumes used ano Tlnal pressure 315 Bbls seawater/2% surfactant 175 Bbls. seawater tubing volume and 3 Bbls diesel FSWHP = 1425 psig 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 112 927 685 0 306 Subsequent to operation 175 1076 2330 0 753 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil × Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'__~,,/-~'~,~, ~, ~-'--¢~..,./.~-.,~--/'~ Title senior TechnicatAsslstantll Form 10~4 Rev 06/1 Date ~-'~_~/~.~'--- SUBMIT IN DOPLICATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 31, 1992 Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Cancellation of Sundry_ Intent Dear Mr. Smith' The following is a list of approved Applications for Sundry Approvals for jobs that have been cancelled. If there is need for any additional information, please contact Jeanne Haas at 564-5225. ~l~ H~I 2-68/S-17 92-188 7/17/92 Add Perfs Sincerely, /~anne Haas ~Zl'echnical Assistant II jlh cc' Working Interest Owners Drilling Well File RECEIVED s E P - 2 1997. Alaska 0ii & Gas Cons. Commis$io[t Anchorage AL ....~ OIL AND GAS CONSERVATION COMMIS~,,,JN . APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing ~ Variance~ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 55.18 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number 88-97 10. APl number 50 - 029-21858 11. Field/Pool Endicott Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11360 feet 10504 BKB feet 11287 feet 10440 BKB feet Plugs (measured) Top of squeeze cement at 11265 Junk (measured) 3gas lift valves at 11265' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured de~ TrueBv~ical depth 92' 30" Driven 131' 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 9530' 1337' 7" 560c. f. ClassG 10023'- 11360' 9321'- 10504' measured 10758'- 10776'sqzd;' 10781'- 10807'sqzd; 10816'- 10828'sqzd; 10836'- 10851'sqzd; 10866'- 10875'; 10890'- 10946'; 10962'- 10986'; 10996'- 11024 true vertical (Subsea) 9910 - 9926'sqzd; 9931'- 9954'sqzd; 9962'- 9973'sqzd; 9980'- 9993sqzd'; 10006'- 10014'; 10028'- 10077'; 10092'- 10113'; 10122'- 10147' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSSV at 1530' 13. Attachments Desc'ription summary of proposal X Detailed operations program BOP sketch 4. Estimated date for commencing operation October, 1992 61' If proposal was verbally approved 15. Status of well classification as: Oil X Gas__ Suspended__ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~-~.~ ,~./_~¢"~?j-?j2~ ~. //~"~'.-~- Title Senior TechnicalAssistant// ~ FOR COMMISSION USE ONLY Date ~' -,~.'~ Condit.~s of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ¢.~,/ Original Signed By Approved by order of the Commission David W. Johnston p oval Approv ,,Ad ~'c~ y Retained p~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ENDICOTT FIELD Well 2-68/S-17 Change of Program Well 2-68/S-17 is a MPI area 3B/3C oil producer. It was approved by the State on July 17, 1992 (Approval #92-188) to add perforations to the well. Rather than add perfs It is now our intention to set a Schlumberger PosiSet plug between the 3C1 and 3B3 to shut off the 3B3 water and allow the 3C1 to flow on it's own. The well was recently squeezed to shut-off 3C4 gas production. Since the squeeze, gas production has been eliminated; unfortunately, water cut has increased from 60%, before the squeeze, to 95% after the squeeze. Oil production has decreased from 1500 BOPD to 50 BOPD. The latest production logs show that currently the 3C1 and 3B3 are flowing with the 3B3 contributing the majority of the water. Although the logs indicate the 3C1 is also flowing mostly water, it is not clear if oil production in the 3C1 is being masked by the dominance of the 3B3 water flow. In order to shut off the 3B3 water and allow the 3C1 to flow on it's own, we request that a Schlumberger PosiSet plug be set between the 3C1 and 3B3. A more detailed program for setting the plug is attached. 2-68/S-17 Schlumberqer PosiSet Pluq Installation Proqram RU slickline unit. Pull SSSV and make a 2.2-inch drift run through tailpipe. RDMO slickline unit. Block SSV with fusible cap and shut-in well at choke and wing valve. Note wellhead and annulus pressures. Pump ~20 bbls diesel to freeze protect tubing. RU SWS. RIH with plug assembly and E-line setting tool. A Schlumberger, 2-1/8 inch OD PosiSet element should be used. Locate and set center of element at 11752 feet md, referenced to the DLL Gamma Ray, dated 1/20/89. Note' The spacing between the 3C1 and 3B3 perforations is 19' md. After setting, tag element to ensure proper depth location prior to spotting cement. POH. Prepare Class G cement with proper additives for pumpability. Estimated reservoir temperature at 11752 feet md is 215 °F. RIH with SWS slickline/dump bailer. Spot 16 gallons Class G cement on top of plug (three runs with 40' long, 2-inch OD bailer). POH. Allow 12-18 hours setting time. The 16 gallon volume will provide a 7-foot cement plug on top of the bridge plug, with allowances for hole deviation and spillage into the 3C1 perforations. This plug size should be adequate to support a pressure differential of 3000 psi across the plug assembly. Top of cement should reach 11745 feet md, assuming the specified location of the element. RIH with E-Line to tag cement top. POH. RDMO SWS. RU slickline unit. RIH to replace SSSV. POH. RDMO slickline unit. Put well on production at maximum attainable rate. After well has stabilized, obtain a well test. 2656/ABC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing ~ Repair well ~ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate ~ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At t°tal depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development x .. Exploratory __ Stratigraphic __ Service RECEIVED d U L I 1992 Alaska Oil & Gas Cons. CommisSiOn Anchorage 6. Datum elevation (DF or KB) KBE -- 55.18 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number 88-97 10. APl number 50-029-21858 11. Field/Pool Endicott Oil Pool 11360 feet 10504 BKB feet Plugs (measured) Top of squeeze cement at 11265 feet Effective depth: measured 11287 feet true vertical 10440 BKB feet Junk (measured) 3gas lift valves at 11265' Casing Length Size Cemented Measured d~;;)~B TrueBvAg~ical depth Structural Conductor 92' 30" Driven 131' 131' Surface 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' Intermediate 10241' 9 5/8" 575 c.f. C/ass G 10280' 9530' Production Liner 1337' 7" 560c. f. C/ass G 10023'- 11360' 9321'- 10504' Perforation depth: measured 10758'- 10776'sqzd;' 10781'- 10807'sqzd; 10816'- 10828'sqzd; 10836'- 10851'sqzd; 10866'- 10875'; 10890'- 10946'; 10962'- 10986'; 10996'- 11024 true vertical (Subsea) 9910 - 9926'sqzd; 9931'- 9954'sqzd; 9962'- 9973°sqzd; 9980'- 9993sqzd'; 10006'- 10014'; 10028' 10077;' 10092'- 10113'; 10122'- 10147' TUbing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSSV at 1530' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch × 14. Estimated date for commencing operation July, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed<~.~~ c~. ~ Title SoniorTechnica/AssistantlI D~~ ,,,/~ FOR COMMISSION USE ONLY Conditi~ffs of approval: Notify Commission so representative' may witness I Approval No~~- J Plug integrity ~ BOP Test~ Location clearance ~ &pproved Co~h;, Mechanical Integrity Test__ Subsequent form required 10- ~/'0~ Returned ~ Original Signed By - ~j' Approved by orderofthe Commission Da,:id W, Johnston Commissioner Form 10-403 Rev 06/15/88 Date r-/. I"'/' ~ 2 SUBMIT IN TRIPLICATE ENDICOTI' FIELD Well 2-68/S-17 Well 2-68/S-17 is a MPI area 3B/3C oil producer. The well was recently squeezed to shut-off 3C4 gas production. Since the squeeze, gas production has been reduced; unfortunately, water cut has increased from 60%, before the squeeze, to 95% after the squeeze. Oil production has decreased from 2000 BOPD to 100 BOPD. The latest production logs show that currently the 3C1, 3B3 and 3B2 are flowing with the 3B3 contributing the majority of the water. BHFP is sufficiently low (2800 psi) to produce flow from all the perforated sequences. Therefore, the increase in water cut must result from loss of oil and condensate production from sequences 3C3 and 3C4. Production logs prior to the cement squeeze showed gas production from the 3C4 and upper 3C3. However, gas production from the 3C3 resulted from communication with the 3C4 through a channel. The gas channel to the 3C4 should have been closed during the recent cement squeeze. In order to increase oil production, we recommend perforating the 3C3. The 3C4 should remain shut-in in order to avoid gas production. We plan to add the following 38' of perfs at 4 spf, 0 degree phasing on the low side of the pipe with the well flowing through a fully opened choke. 10781'-10807' BKB (Ref. CET, 9/14/88) 10816'-10828' BKB (Ref. CET, 9/14/88) A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforations are added. RECEIVED d U L 1,5 ~992 Alaska Oil & Qas Cons. Commission Anchorage il BASIC SYSTEM MAKEUP 8OWEN PACKOFF' HAND .PUMP ~SE SEAL 'FLO~BE · F'LOWLINE GREASE LINE FLOWLINE V. ALVE GREASE - I MANIFOLD · · . GREASE PUMP: .. RISER GREASE RESERVO. BOP RECEIVED Alaska Oil and Gas Conservation Commission May 15, 1992 Page Three WELL 4-02/Q-28 1570-13005' PRODUCTION SCHLUMBERGER WELL 2-44/R-12 ~" ??~ 10850-12000' ~ GAMMA RAY/CCL JEWELRY 11850-12000' ~ INJECTION PROFILE SURVEY WELL 2-68/S-17 1 055-11220~-'~ GAS lIFT J WELL 4-18/S-30 11100-11600' PRODUCTION PROFILE SCHWMBERGER Sincerely, ,L. Haas JLH/clt Enclosures 5/8/92 RUN I 3/1 9/92 RUN 1 3/1 9/92 RUN 1 4/6/92 RUN 1 4/30/92 RUN 1 R E EIVED MAY 2 0 1992 Alaska 0ii & Gas Cons. Commission Anchorage xc: File 6.10 J. L. Haas 2596/JLH/clt STATE OF ALASKA ALAor,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate .. Plugging Perforate x. Pull tubing ... Alter casing Repair well X Other 2. Name of Operator BP Exploration (Alaska) lnc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 8. Well number 2-68/S- 17 MPI . 9. Permit number/approval number 88-97/92-O43 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2"SSSVat 1530' Length Size Cemented Measu~/~Bdepth True ve~)~ depth 92' 30" Driven 131' 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' 10241' 95/8" 575c. f. Class G 10280' 9530' 11360feet 10504 BKBfeet 11287feet 10440 BKBfeet Plugs (measured) Junk (measured) 3 GL V's at bottom of hole measured 1337' 7" 560 c.f. Class G 10023'- 11360' 9321'- 10504' 10758'- 10776'sqzd;' 10781'- 10807'sqzd; 10816'- 10828'sqzd; 10836'- 10851'sqzd; 10866'- 10875'; 10890'- 10946'; 10962'- 10986'; 10996'- 11024 true vertical (Subsea) 9910 - 9926'sqzd; 9931'- 9954'sqzd; 9962'- 9973'sqzd; 9980'- 9993sqzd? 10006'- 10014'; 10028'- 10077'; 10092'- 10113'; 10122'- 10147' 13. Stimulation or cement squeeze summary Please see attachments Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2077 9424 3388 0 35 ~.~ ' 57 ~ 3458 ,- 0 Tubing Pressure 729 332 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X ...... Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~c.-~-~ c-~.. _//_-¢'L.~ Title senior Technical Form 10~404"~ev~ 06/15/88 SUBMIT IN DI. JPLI(~ATE 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272'SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott i i i i iii ii i i i ii ii i i i[ii iii i i i i iiiiiiiii i Endicott ProduCtion Engineering Department ,, CTUWO OPERATIONAL SUMMARY REPORT TO: HORNBROOK FROM' BARTEL/CAMPBELL/LOVELAN D LOCATION: ANCHORAGE DATE: 3/5/92 OPERATION' ENDICOTT 2-68/S-17 SQZ #1 AFE: 176213 SUMMARY BULLHEADED WELL W/485 BBLS FILTERED SW (W/SURFACTANT) @ 5.6 BPM/800 PSI. TAGGED AND CORRECTED TO 11271'. COOLED SUMP TAKING RETURNS W/50 WHP. LAID IN 28 BBLS CLASS G CEMENT FROM TD WITH INITIAL SQUEEZE PRESS OF 1000 PSI OVERBALANCE. RAMPED TO FINAL SQUEEZE PRESS OF 3000 PSI O/B OVER 6 MINS AND HELD FOR 20 MINS. PRESS TEST @ 3000 PSI: DROPPED 50 PSI IN 5 MINS. OVER 3 HRS LEFT ON THICKENING TIME SO WENT DIRECTLY TO LIVE REVERSE OUT. REVERSED OUT TO FLAG @ 11260' CTD. PRESS TEST TO 2000 PSlG: DROPPED BY 800 PSI IN 5 MINS. PERFORMED STEP RATE TEST TO 0.75 BPM @ 2500 PSlG. JETTED TO WCTOC AND BACK TO FLAG. REVERSED OUT JET~ED VOL AND F/P TOP OF TBG W/MEOH. WILL LOG TO LOCATE LEAK IN MORNING. NOTE: APPROX 6 BBLS CMT NOT ACCOUNTED FOR (DOES NOT APPEAR TO BE BEHIND PIPE) 3/5/92 06:30 RU DS#9947 (CTV VOL=33 BBLS) SIWHP=1700 PSlG, lAP=500 PSIG, OAP=0 PSIG, GLP=2100 PSIG, G/L OFF, FLP=200 PSI, FLT=70 F ,,, 7:45 FUNCTION TEST BOPS. LEAKING VALVE IN MANIFOLD. W.O. REPAIR 8 '1 9 P/T CT/BOPS/LUB TO 4000 PSIG. PRESS BLED BACK TO 2000 PSlG. CLOSE MASTER VALVE. NO PRESS ON CT SO BOPS HOLDING. REPRESS ,,, , 8:55 RECOVER MEOH. REPAIR LEAKING VALVE ON WATER PUMP. _ ,,,, ,, 9...;40 BULLHEAD DOWN CT AND TBG W/68°F SW AND SURFACTANT. RIH W/2.25" SWIRL NZL. oZZL'EI RATE WHP BBLS COMMENTS I DE,,,PTH I(B P M , PUMP~,D NOZZLE ETURN , 10'14 3800 ..5.6 850 620 178 SW %~b PERFS. 10:35 6700 1050 820 300 SD SURFACTANT 10:59 9500 430 WT CK, 17K#. ISlP = 800. 11'16 11100 4.0 650 500 480 WTCK, 21K#. 'OPERATION. Page 2 IDEPTHI(BPM PUMPED NOZZLE RETURN 11:21 11260 .3 200 1 40 485 TAGGED DOWN. CORRECTED TO 11271 WL TAG. FLAGGED CT @ 11260. COOL SUMP. START MIXING CMT. 11:30 2.3 3800 50 500 WTR RETURNS. 12:21 5 0 600 ~COOLSUMP 12:30 627 SAMPLE TO LAB , 13' 14~ 0 11 0 726 / 0 S/D PUMP SW TO F/P SURF LINES & PUMP. RECIPROCATE CT 13:20 1 1 / 0 SW TO PUMP DWN CT W/HOWCO 13:23 11260 1.5 1800 10 0 START FW _13:27 5 / 0 START CMT 13'30 2640 60 3 30 MIN FL=52 CC 13'47 1.5 2900 60 28/0 SWTO FW 13:49 1.0 1430 4 RED RATE , ! 3: 50 1100 5 / 0 0 SW TO SW. CMT TO NZL 13:51 950 50 1 1 13'51~ 850 2 2 IAP=471 PSIG 13:52 700 3 3 PUll , 13:53 11242 600 40 4 4 UP WT26000 LBo 1_3:5,4 11225 450 5 5 13:55 11206 425 6 6 13'56~ 11188 7 7 13 '.'=:;,7 11169 50 8 8 13:58 11146 9 9 13:59 11100 70 10 10 14:00 11120 11 11 14'01 11047 80 12 12 14'02 11020 13 ,,13 14:03 1i0.02 14 14 14:04 10980 15 15 14:05 10956 440 100 16 16 ]4'06 10937 180 17 17 14'07 10912 400 18 18 14:08 10882 620 19 19 14:09 10844 770 20 20 ,, 14'10 1 0800 11 50 1 000 21 21 CT PRESS lNCREASE. STGAUGE RTNS ~)PERATION: Page 3 ! .. IDE~THI(BPM PUMPED NOZZLE RETURN 14'111 10775 1350 22 22 0.5 14'12~ 10732 .1400, , 23 23 1.0 14 13 10704 1550 1050 24 24 2.0 · .~ ~"'~ ~,, ...... 14'14 10659 1650 25 25 3.0 14'15 10620 1750 26 26 3 9 1~'16 10580 18~,0 , 27 .2~ 4.8 14'17 10530 1900 28 28 5 7 C~AWAY - 14'18 10480 1990 29 6.5 14'19 10433 2050 30 7.5 RED~TE 14:20 10360 0.5 1500 31 8.0 , ,, ,, 14:22 10350 32 9.0 , , 14:24 33 10.0 RAMP TO 2000 PSIG ,, ,, , 14:26 1900 1560 34 10.8 ,, 14:28 2400 2000 35 11.0 ,. 14:30 36 12.0 RAMP TO 3000 PSIG 14:32 3200 2800 37 12.3 , 14:34 3350 3000 38 13.2 14:36 3400 39 14.0 , ...... 14:38 3010 3000 40/0 15.0 ~DHOWCO. PRESSTEST 14:43; 3030 2950 PRESS DROPPED 50 PS= IN S MINS 14'53i 1.5 110 1700 ST UVE REV OUT. RIH ,, 15'14 10525 1.3 80 1960 32 WHPLIMITED-REDRATE ,, 15'48 10740 1.1 2120 73 PARK CT. REV BTMS UP 16 '08 1.3 8 0 1 800 9 8 CO~ RIH LIVE REV OUT 18'05 1!260 1.2 2060 244 ~~~. 18'43 1470 1470 304/0 CL~NRTNS. PRE~TEST .... , 18:49 PRESS FELL 800 PSI IN 5 MINS. SW TO PUMP DWN CT FOR INJECTIVI~ TEST 19'00 0.75 3050 2500 STEP RATE TEST. ISIP=2550PSIG 19'02 2.0 3760 580 0 ~H ~RJ~P~ 19'17 10450 3710 610 31 RIH JE~ING 19:33 11261 2.0 180 1970 62/0 SW TO REV BTMS UP 20:25 180 2070 81/0 SWTOPUMPMEOH 20:36 0.3 680 520 1 5 NO ADDITI~AL CMT RECO~RED. SW TO PUMP DWN CT. P~H , , 21:52 SURF 650 650 62 CLOSE WELL IN. RDMO. ,,, 'OPERATION: Page 4 SUMMARY BULLHEADED WELL W/485 BBLS FILTERED SW (W/SURFACTANT) @ 5.6 BPM/800 PSI. TAGGED AND CORRECTED TO 11271'. COOLED SUMP TAKING RETURNS W/50 WHP. LAID IN 28 BBLS CLASS G CEMENT FROM TD WITH INITIAL SQUEEZE PRESS OF 1000 PSI OVERBALANCE. RAMPED TO FINAL SQUEEZE PRESS OF 3000 PSI O/B OVER 6 MINS AND HELD FOR 20 MINS. PRESS TEST @ 3000 PSI: DROPPED 50 PSI IN 5 MINS. OVER 3 HRS LEFT ON THICKENING TIME SO WENT DIRECTLY TO LIVE REVERSE OUT. REVERSED OUT TO FLAG @ 11260' CTD. PRESS TEST TO 2000 PSIG: DROPPED BY 800 PSI IN 5 MINS. PERFORMED STEP RATE TEST TO 0.75 BPM @ 2500 PSlG. JE~-FED TO WCTOC AND BACK TO FLAG. REVERSED OUT JETTED VOL AND F/P TOP OF TBG W/MEOH. WILL LOG TO LOCATE LEAK IN MORNING. NOTE: APPROX 6 BBLS CMT NOT ACCOUNTED FOR (DOES NOT APPEAR TO BE BEHIND PIPE) FLUIDS 4 8 5 BBLS SW TO LOAD WELL 2 4 1 BBLS SW TO COOL SUMP 1 1 BBLS MEOH (FREEZE PROTECTION SURFACE LINES) 5 BBLS FW (PREFLUSH) 2 8 BBLS CEMENT 5 BBLS FW (SPACER) 4 0 BBLS SW (DISPLACEMENT) 3 0 4 BBLS SW (LIVE REVERSE OUT) 6 2 BBLS SW (JET PASS) 8 1 BBLS SW (FINAL REVERSE OUT) 4 7 BBLS MEOH (FREEZE PROTECTION CT) 1 5 BBLS MEOH (FREEZE PROTECTION WELL) 732 22+ WELL CLEANED OUT TO 11260' BBLS LOAD FLUID BEHIND PIPE (CUMULATIVE APPROXIMATE TOTAL LOAD FLUID BEHIND PIPE IS 732 BBLS) BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) CEMENT (,.HALLIBURTON) 15.5 PPG CLASS G CEMENT CONTAINING 0.3 % CFR-3 0.15% LWL O.35% HR-12 0.17 GAL/SK HALAD-344 L THICK TIME = 6 HRS 40 MIN (*) INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. = 40 ML @ 165°F (REQUESTED RANGE 35 TO 50 ML) FIELD APl F.L. = 52 ML * TT BASED ON SCHEDULE 2 (RAPID INC TO 212°F). TT BASED ON SCHEDULE 1 (GRADUAL INCREASE) = 9:34 HRS. i Endicott Production Engineering Department CTUWO OPERATIONAL SUMMARY REPORT TO- HORNBROOK FROM' BARTEL/CAMPBELL/LOVELAND LOCATION' ANCHORAGE DATE: 3/7/92 OPERATION- ENDICOTT 2-68/S-17 SQZ #2 AFE- 176213 .~UMMARY TAGGED DOWN @ 12261 AND CORRECTED TO 11265 WL TAG. COOLED SUMP W/305 BBLS 66°F SWTR. INJECTIVITY WAS 1 BPM/2000 PSI. BULLHEADED 4 BBLS 12% HCL W/CTN @ 10765'. NOTED IMMEDIATE DROP IN WHP OF 1900 PSI; INJECTIVITY INCREASED TO 3.2 BPM @ 1100 PSIG. CIRC TO COOL SUMP. LAID IN 28 BBLS CLASS G CMT WITH CHOKES CLOSED. HELD INITIAL SQZ PRESS OF 1000 PSI OVERBALANCE FOR 15 MINS. RAMPED QUICKLY TO 3000 PSI OVERBALANCE. HELD FINAL SQZ PRESS FOR 30 MINS. PRESS TEST: HELD TIGHT. CONTAMINATED WITH DUAL POLYMER AND REVERSED OUT TO 11262'. FINAL PT TO 2000 JGT. JETTED UP TO WCCTOC, MAKING 2 PASSES ACROSS JEWELRY. RAN BACK TO DO'Fl'OM WHILE REVERSING. NO ADDITIONAL CMT RECOVERED. REVERSED IN LIFT GAS TO APPROX 4300'. WILL INFLOW LATER IN DAY. 3/7!.92 8:00 RU DS#9947 (CTV VOL=33 BBLS). SIWHP=0 PSIG, lAP=500 PSIG, OAP=0 PSIG, GLP=2100 PSIG, _ FLP=200 PSIG~ FLT=66°F ,,, 9:00 P/T TO 4000 PSIG. RECOVER MEOH FROM CT. RIH W/2.25" SWIRL CTN PUMPING 1 BPM, HOLDING 200 WHP. · ,, , TllVIEjNOZ'ZEEI RATEJI OO" "TS I IDEPTHI(B'PM UMPED NOZZLE RETURN 10:38 8500 !.0 1500 200 80 WT CK, 16K# 11:04 11000 110 WT CF, 20K# 11 '14 1 1 261 1 2 0 TAGGED DOWN. CORRECTED TO 11265 WL TAG. FLAGGED CT @ 11255'. START FRICTION REDUCER. COOL SUMP. 12'16! 11255 3.5 3100 100 310 12:44 41 0 INJECTIVITY TEST: 1 BPM/2000 PSI. , -- 12:57 1.5 1250 100 425/0 PUH. START FW. 'OPERATION: 2-68/S-17 SQZ #2 Page 2 I IDEPTHI(BPM PUMPED NOZZLE RETURN COMMENTS 13:01 11100 1350 5/0 STARTACID 13:04 10930 1500 4/0 START FW 13:08 10765 1700 100 5/0 START S~.'TR ..... , , , 13'19 1.0 2570 1990 20 CLOSEC~~ ,, 13:25 690 9 0 2 4 ACID @ CTN. SUDDEN BREAK IN PRESS 13:28 3.0 2 8 SW TO DISPLACE DWN BACKSIDE & CT. 13:35 1020 890 45 STTO MIX CMT ,, , 13:37 1 090 950 52 RIH ,, ,, 13:45 3.2 1250 1110 76 STABLEINJ RATE ,, 13:47 11258 3.2 3340 21 0 82/0 SWTOCIRCTO~LSUMP ,, ,, .... , ,,, 14:38 3.3 3440 21 0 1 60 SAMPLE TO LAB ........ , 15:11 269/0 15 MIN FL=57 CC. F/P PUMP & B/S LINE 15:21 11255 1.5 1150 130 10/0 CLOSECHKS. STARTFW ,,, ~ ,, 15:24 1700 490 5/0 START CMT ,., 15:30 3320 680 7 30 MIN FL=54 CC .., 15:44 3250 660 28/0 SWTO FW ,,, ,,, ,, 15:47 1.0 1260 640 5/0 0 SW TO SW. CMT T© NZL 15:48 850 580 1 1 .. 15:49 800 560 2 2 IAP=581 PSIG. PUH ,, , ,,, ,, , 15:50 11230 600 520 3 3 ,, ..... , !:L 15:52 11193 5 5 .... 15:53 11176 400 510 6 6 15:54 11152 520 7 7 15:55 11132 ,,, 500 ,, 8 8 15: 56 1111 3 490 9 9 CALC SUMP ~VERED 15:57 11092 600 1 0 1 0 WHP PRESS INCR~SING I 15:58 11071 800 11 11 ,,, ~ , ,, 15:59 11045 1000 12 12 16:00 11028 1 3 1 3 ~UGE~S .... 16:01~ 11009 14 14 0.8 ..... . 16:02 10987 15 15 1.5 ,, 16:03 1 0965 1 6 1 6 2.0 CTP INCR~SE. LIQ CAUGHT UP 16:04 10940 800 17 17 2.8 , 16:04 10925 1000 18 18 3.0 ..... 'OPERATION- 2-68/$-17 SQZ #2 Psge 3 IT', M E'JNOZZ£EJ I IDEPTHI( B P,M PUMPED OUT BBLS NOZZLE RETURN COMMENTS ,, 16'09 10732 1525 23 23 7.8 16'12 10610 1750 26 26 10.3 16'13 10563 1850 27 27 11.3 ,,,, 16:14 10522 1950 28 28 12.0 C~AWAY ,. 16:15 10480 0.5 2000 29 13.0 RAMPTQ2000PSIG. REDRATE ,, 16:17 10409 1850 1500 30 13.5 16'18 10350 2450 2000 31 13.5 RAMP TO 3000 PSI ,, , ,. 16'21 3200 2870 32 .] 6'22j 3450 3000 33 14.5 16 '241 3450 3 4 / 0 15.5 CLUE CHKS. ~ HOWCO. SW TO DS .] 6'2~ 0.5 3350 SW TO DUAL ~LYMER 16'43 0 3000 3000 9 PRE. TEST ., . 16'50 3000 3000 ~Y~TE~ 16:56 2.3 3440 500 BLEED WHP TO 500 PSIG. CONT TO CIRC GEL TO NZL 17'04 2.2 3410 500 26 RIH 17'07 10447 1.0 31 PARKCT 17:08 1 970 500 33 RIH J~ING TO CONTAMINATE .,, 17:17 10833 2060 500 42/0 SWTOSW 17:27 11267 0.5 1 660 500 1 2 TAG TD. RED ~TE. P~H JE~ING 18'10 8305 !.5 0 1960 32/0 SWTOREVOUT. RIH 19:33 10060 1.4 2000 118 20:42 10563 !.2 .,,0 1910 206 HUNGUP~PA~EDTHRO~H 21:41 11000 1'2 0 1960 277 I'MAGITTINGOLDI 22:17 11262 2000 321 22 '4 ~ 1 800 356 / 0 R~URNS C~. PRESSURE TEST TO 2000 JGT. ,,, 22'53i 1.5 2400 500 JET UP. JET JEWELRY. 3:42 2.0 8 9/0 RIH REVERSING. 3/8/92 10'21 [11260I 1.5 J 0 ! 18001 6O/O I NO CMT RETURNED. (~PERATION- 2-68/S-17 SQZ #2 Page 4 I! IDEPTH I( B P M PUMPED NOZZLE RETURN COMMENTS , ,,, 0:37 1800 1800 BEGIN REVERSE INLIFTGAS 1 '01 0 21 00 3 5 CLOSE CHOKES. POOH 2 '14 0 21 60 OOH. CLOSE IN WELL. F/P CT. 2:36 3 5 RD INJECTOR HEAD OPERATION: 2-68/S-17 SQZ #2 Page 5 ~UMMARY TAGGED DOWN @ 12261 AND CORRECTED TO 11265 WL TAG. COOLED SUMP W/305 BBLS 66°F SWTR. INJECTIVITY WAS 1 BPM/2000 PSI. BULLHEADED 4 BBLS 12% HCL W/CTN @ 10765'. NOTED IMMEDIATE DROP IN WHP OF 1900 PSI. INJECTIVITY INCREASED TO 3.2 BPM @ 1100 PSIG. CIRC TO COOL SUMP. LAID IN 28 BBLS CLASS G CMT WITH CHOKES CLOSED. HELD INITIAL SQZ PRESS OF 1000 PSI OVERi~ALANCE FOR 15 MINS. RAMPED QUICKLY TO 3000 PSI OVERBALANCE. HELD FINAL SQZ PRESS FOR 30 MINS. PRESS TEST: HELD TIGHT. CONTAMINATED WITH DUAL POLYMER AND REVERSED OUT TO 11262'. FINAL PT TO 2000 JGT. JETTED UP TO WCCTOC, MAKING 2 PASSES ACROSS JEWELRY. RAN BACK TO BOTTOM WHILE REVERSING. NO ADDITIONAL CMT RECOVERED. REVERSED IN LIFT GAS TO APPROX 4300'. WILL INFLOW LATER IN DAY. ESTIMATE 3 BBLS CMT BEHIND PIPE. FLUIDS 4 25 BBLS SW TO LOAD WELL 5 BBLS FW 4 BBLS ACID 5 BBLS FW 8 2 BBLS SW (DISPLACEMENT) 2 69 BBLS SW (COOL SUMP) 5 BBLS FW 2 8 BBLS CEMENT 5 BBLS EW (SPACER) 3 4 BBLS SW 4 2 BBLS DUO POLYMER (CONTAMINANT) 3 2 BBLS SW (DISPLACEMENT) 3 5 6 BBLS SW (REVERSE OUT) 8 9 BBLS SW (JET PASS) 6 0 BBLS SW (FINAL REVERSE OUT) 3 5 BBLS RECOVERED (LIFT GAS DISPLACEMENT) 3 5 BBLS MEOH (FREF_~E PROTECTION CT) 100 25+ WELL CLEANED OUT TO 11262' BBLS LOAD FLUID BEHIND PIPE (CUMULATIVE APPROXIMATE ~ LOAD FLUID BEHIND PIPE IS 832 BBLS) BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) ACID (HALLIBURTON) 12% HCL 0.4% LOSURF-300 0.4% HAl-85 45PPT FERCHEK-A CEMENT ,(HALLIBURTON) 15.5 PPG CLASS G CEMENT CONTAINING 0.2 % CFR-3 0.3% HR-12 0.18 GAL/SK HALAD-344 L THICK TIME = 7 HRS 16 MIN INCLUDING 1 HOUR SURFACE TIME LAB APl F.L. = 61 ML @ 165°F (REQUESTED RANGE 40 TO 60 ML) FIELD APl F.L. = 54 ML PV=93, YP=44 Endicott Production Engineering Department DATE: 3/14-15/92 WELL N°: 2-68/S-17 BP EXPLORATION REP: SERVICE COMPANY: Post-Saueeze Perforations Luedke-Chan AWS(Brunner) DATE.TIME ~ oPERATIONS SUMMARY 0800 RU. Post radio silence signs at the entrance to island and next to well site. 0815 Install SSV fusible cap. . SIWHP - 1200 psig. IAP = 750 psig. .,,.OAP = 0 Psi#. Choke = 0 Beans. _ 0825 t'r,essure test lubricator to wellhead pressure. 0830 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security), 0830 Make sure well is in high flow test separator. Bleed WHP to 250 psi. 0945 RIH with Gun #1 (20,f~et). SIWHP = 250 psi#. 1100 Open wing valve and set production choke to 30beans. 1130 Tie in to CBT dated 09-14-88. All of the depths listed below are from the open hole reference log. Flag line for next run. FWHP = 25(I psi#. 1140 Hang gun #1 Top Shot at 11004' MDBKB. 1145 Shoot gun #1 from 11004'-11024' MDBKB and flow for 40 min. No liquid in separator. FWHP = 250 psi#. 1225 SI well and POH. 1315 RIH with Gun #2 (8' + 4' -select fire). S1WHP = 250 psi#. 1355 Open choke to 104 beans. FWHP = 250 psi#. 1400 Tie in to CBT logging up. Shoot gun #2a (8 fi) from 10996'-11004' M DBKB. FWHP = 250 psig. PUH and shoot gun #2b (4 ft) from 10982'-10986' MDBKB. FWItP = 250 psi#. Flow well. 1410 SI well and POH. Flow well w/ 1.7 MMSCFPD GL until fluid to surface (1/2 hour). SI Well. 1630 RIH with Gun #3 (20 feet). SIWHP = 450 psi#. 1800 Open chokc to 104 beans. FWHP = 275 psi#. 1820 Tie in to CBT logging up. Shoot gun # 3 from 10962'-10982' M DBKB. FWHP = 275 psi#. Flow well on GL for 20 minutes. 1840 SI well and POH. 1950 RIH with Gun #4 (20 feet). SIWHP = 500 psi#. 2030 Open choke to 104 beans. FWHP = 275 psi#. 2045 Tie in to CBT logging up. Shoot gun # 4 from 10926'-10946' M DBKB. YWHP = 275 psig and flow well for 1 hour on gas lift. 2140 SI well and POH. 180 bbl fluid in separator. No gas. 2250 RIH with Gun #5.. Short. POOH. RIH with Gun #5. Short. POOH. 0210 Rill wilh Gun #5 (20 feet). SIWHP = 800 psi#. 0250 Open choke to 10,* ~cans . FWHP = 400 psi#. 0310 Tie in to CBT loggia# up. Shoot gun # 5 from 10906'-10926' M DBKB. FWHP = 350 psig. Flow well for 20 minutes on gas lift. 0330 Sl well and POH. 0420 RIH with Gun #6 (16'). SIWt~p = 100{~'"Psig. 0510 Open choke to 104 beans. FWHP = 300 psi#. 0520 Tie in to CBT logging up. Shoot gun # 6 from 10890'-10906' MDBKB. FWHP = 300 psig. Flow well for 10 minutes on gas lift. 0530 SI well and POH. 0640 RIH with Gun #7 (9'). SIWHP = 900 psi#. DATE: 3/15/92 WELL N°: 2-68/S- 17 TYPE OF OPERATION: Post-Squeeze Perforations 0700 Open ckoke to 104 beans. FWHP = 300 psig. 0710 Tie in to CBT logging up. Shoot gun #7 (9') from 10866'-10875' MDBKB. FWHP = 300 psig. Flow well for 10 minutes on /zas lift. 0750" SI well and POH. SIWHP = 950 psig. Confirm all shots fired. 0800 End radio silence. 0815 RD. POP ~ 104 beans. 1.7 MMSCFPD. PERFORATION SUMMARY: GUN INTERVAL(DLL) .(J~_la_I)_F..,~T_~ FEET ~ 7 10866-10875 10866-10875 1 0 3C2 4-7 10890-10946 10890-10946 56 3C1 2-3 10962-10986 10962-10986 24 3B3 1-2 10996-11024 10996-11024 28 3B2 All intervals were shot using 2 1/8" Jumbo Jet guns at 4 spf, 0 degree phasing oriented to the low side of the hole. As of 4 pm Sunday 3/15/92, the well was making 5800 BFPD with 3.0 MMSCFPD Gas Lift - fluid level at the screened oriface at 6539' MDBKB. Well will be tested later. Alaska Oil and Gas Conservation Commission April 14, 1992 Page Two ,, I ~/o .....-W'ELL 2-30/0-09 ~ 12900-13669' STATIC TEMPERATURE LOG /./1~551-12848' ~ MWD DUAL GAMMA RAY / / iiERRY'SUN · ' ..1--2848-13024' .,~ J MWD DUAL GAMMA RAY ~ SPERRY-SUN ~,~W024-13781' D DUAL GAMMA RAY SPERRY-SUN 3/9/92 RUN 1 1/2/92 RUN1 1/4/92 RUN'3..- 1/5/92 RUN 3 ~r~ ...,WELL 2-68/S-17 PFC/GAMMA RAY ATLAS WIRELINE SERVICES 3/14/92 RUN 1 .-11219' IN TEMPERATURE AND JEWELERY SURVEY 1150' N TEMPERATURE SURVEY 1 2/1 9/91 RUN 1 12/21/91 RUN I 650-11150' ION PROFILE SURVEY RECEIVED APR 1 f 1992 3/6/92 RUN 1 Alaska 0ii & Gas Cons. Commission Anchorage 2533/JLH/clt APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well X Plugging __ Time extension ~ Stimulate __ Change approved program __ Pull tubing ~ Variance__ Perforate x Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 12. present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED MAR 11 t992 Alaska 0il & Gas Cons. Commission Anchorage 11360 feet 10504 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.18 7. Unit or Property name Duck Is/and Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number 88-97 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 11287 feet 10440 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~;)~ TrueB~ical depth 92' 30" Driven 131' 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 9530' 1337' 7" 560 c.f. Class G 10023'- 11360' 9321'- 10504' measured 10758'- 10776'; 10781'- 10807? 10816'- 10828'; 10836'- 10851'; 10866'- 10875'; 10890'- 10946'; 10962'- 10986°; 10996'- 11024 true vertical (Subsea) 9910 - 9926'; 9931'- 9954'; 9962'- 9973~ 9980'- 9993'; 10006'- 10014? 10028'- 10077'; 10092'- 10113'; 10122'- 10147' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSSV at 1530' feet 13. Attachments Description summary of proposal '14. Estimated date for commen(~ing operation March 5, 1992 16. If proposal was verbally approved Name of approver Russ Doug/as 3/5/92 Date approved Detailed operations program X BOP sketch X 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~/~/~//~ Title Endicott Lead Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ~o ~ ORIGINAL SIGNED B'¢ Approved by order of the Commission LONNIE O. SM{TH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE . R. Al'lan/J:. Goldina ' 2-68/S-17 CTU Ce,nent 2-68/S-17 W/O PITS 1) RU slickline unit. Pull all live GLVS and run dummys. Squeeze , i::CEIVE. D CTU,, Cement S0ueeze ,,program 1 1 1992 ~taska 0il & Gas Cons. fJomrcjss~ot~ Anc. horag.e Pull SSSV and make a 2.5-inch drift run through ta~lpipe. RDMO slickline unit. 2) Block SSV with fusible cap and shut-in well at choke and wing valve. Note wellhead and annulus pressures. Leave well shut-in at least 12 hours. 3) RIH with E-line temperature tool and CCL. Tag TD and note depth (11287' MD PBTD). Obtain baseline temp/CCL pass, up to TP. Note TP depth. Pump 300 bbis filtered sea water (approximately two tubing volumes) at maximum rate below frac gradient into the well to establish cement design temperature and to evaluate injectivity. Note exact volume pumped and pump rate. Target cool-down temperature is 165-190° F. 4) Stop pumping and record temperature passes once per hour from 11100' MD to 10650' MD for 6 hours. 5) Monitor WHP to determine if the well is inflowing during the warm-back period. Pre-S~.~eeze Preparation 1) Prepare class G cement for a 40 cc/30 min fluid loss and 5-7 hour thickening time. Results from WOPITS will determine design temperature. 2) Have the following on site to be pumped: - 300 bbls filtered seawater (kill well, cool wellbore) - 20 bbls filtered seawater (buffer cement, test pumps) - 14.5 bbls cement (cover perfs and perf tunnels, assuming a small gas channel between 3C4 and 3C3 ) - 22 bbls effluent water (displace coil and squeeze; .D.[.OJ.DJZD volume) - 18 bbls Biozan 2-Polymer system (retard cement in liner) - 200 bbls filtered seawater (reverse out and jet liner) - Nitrogen (for underbalance perforating and freeze protection while WOC) Squeeze Program 1) RU CTU with 1 3/4" coil. Tie in TD from WOPITS, and flag coiled tubing. Locate coil at .,, 10740' MD, above uppermost perforation. 2) Perform fluid loss test on cement. If fluid loss is satisfactory, proceed with squeeze program. 3) Set the hot water bath temperature at SIBHT (refer to WOPITS baseline). Place two samples into bath, one 100% cement and one mixed 50/50 with polymer. These samples should remain on location in the squeeze lab until the cleanout is complete. Note the time the samples are placed in the bath. ' R. Allan / J~ Golding ~ ' 2-68/S-17 CTU Ce~rnent Squeeze 4) Pump filtered seawater down the production tubing to kill the well. The same volume and rate as pumped for the WOPITS should be used (~300 bbls). Objective temperature shculd be 165-190 o F, based on WOPITS. Achieving this cooling will be critical in assuring that cement does not set prematurely in liner. With a hyrdrostatic head of 4350 psi and sequence reservoir pressures ranging from 4000 to 4300 psi, minimal pump head pressure will be required to maintain kill conditions. 5) Once kill volume is away, continue in hole with coil. Begin pumping the 20 bbls filtered seawater stage through coil at approximately 1 BPM as the coil reaches the base of the 3B2 perforations. R E 6 E I V LE D 6) Begin pumping the following stages at the surface at 1 BPM. -14.5 bbls cement MAR 7 1 ~992 -22 bbls effluent water Alaska 0/1 & 6as Cons. Commission -18 bbis biozan polymer /~nchorage 7) Locate CT at 11029' MD, five feet below bottom of 3B2 perforations as cement hits CT nozzle. 8) To prevent cement from stringing out in the liner, keep the CT nozzle ~50' below the cement top as the coil is brought uphole across the perforations (i.e. leave CTN stationary until ~2 bbis cement are displaced, then move coil at ~27 ft per minute @ 1 BPM pump rate). Ensure nozzle is located at the cement top as the water hits the nozzle, then move nozzle at least 50 feet above cement top. Target cement top should be 10700' MD-BKB (50' or 2 BBLS above top of 3C4 perforations). 9) Continue injecting water down coil, maintaining initial squeeze pressure of approximately 1200 psi across the pedorations (--1200 psi WHP). Hold initial squeeze for .-10 minutes without leakoff, such that volume injected into coil equals the volume returned to the gauge tanks. 10)Slowly (over 30-40 minutes) increase squeeze pressure by reducing returns up annulus until a 3000 psi differential across the perforations is reached (~3000 psi WHP). A step-wise increase of approximately 600 psi per step is suggested, with approximately 5-10 minutes per step spent to monitor returns to ensure no leakoff. Total squeeze time should be 40-50 minutes. 11)If bbl/bbl returns are not achieved or if drop in WHP occurs, begin a hesitation squeeze. 12)After holding 3000 psi for --5 minutes without leakoff, slowly reduce WHP to maintain 1500 psi differential across the perforations and prepare for cleanout operations. 13)Jet through cement with polymer from WCTOC to ~50' below bottom of perfs and back to WCCTOC. One down pass and one up pass should be made through the cement as polymer is pumped at 0.5 to 1.0 bpm (see schedule). ' . .R,. Allan / J. Golding ..... ' 2-68/S-17 CTU Ce,,aent Squeeze 14)sWitch to reverse circulation, taking returns up the coil ensuring that WHP remains _below 2000 psi to prevent CT collapse. Continue reverse out until returns clean up, as coil is moved down to 50' below base of cement. 15)Switch to Pumping produced water and jet liner from base of cement to worst case cement top and back down. At base of cement again switch to reverse circulation and continue until returns clean up. 16)Freeze protect with nitrogen head to approximately 5000 ft in order to provide sufficient underbalance (~1500 psi) for inflow testing and subsequent reperforation. Leave a positive 2500 psi WHP on the well once the 5000 ft gas/liquid interface is attainged. Shoot F.L. on tubing to confirm gas/liquid interface. 17)Allow cement to set approximately 24 hours, or as indicated by surface testing the cement. Check cement sample in hot water bath for setting prior to proceeding. 18) Bleed WHP to zero and monitor WHP for inflow from squeezed perforations. If no inflow is apparent, proceed with reperforation. If evidence of inflow is noted, a PITS should be performed in an attempt to locate the offending perforation(s). If the inflow is confirmed to be only from an interval to be reperforated (3C2, 3C1, 3B3 or 3B2), proceed with reperforation, if the inflow is from either 3C4 or 3C3 interval, the well should be resqueezed. Contact Anchorage engineering to discuss resqueeze design. ,Reperfor, oting 1) Once a positive squeeze of the 3C intervals is confirmed, proceed with restoration of the following intervals to the well (depths referenced to the CBT GR dated 9/14/88): Subz,~ne Interval (MDBRT) Feet 3C2 10866 - 10875 10 3Cl 10890- 10946 56 3B3 10962- 10986 24 3B2 10996 - 11024 28 Use a 2 1/8" enerjet strip gun at 4 spf, 0° phasing on the Iow side of the pipe. Ensure sufficient gas head remains on the well to provide a minimum 1000 psi underbalance. Reduce surface pressure (if any) (shoot F.L. to confirm gas/liquid interface) to achieve maximum underbalance prior to perforating the first interval (upper 3C1, 10890-10910' MD). Perforate and continue to flow until liquids are heard at the choke. Perform subsequent perforations at maximum underbalance. Utilize gas lift as required to assure sufficient underbalance is achieved. 2) POP. After well has stabilized, obtain a production test. Sustained gas lift will likely be necessary to bring the well back to production given the w,.~lls h_igh watercut (60%). IVED 3) Production logs will be requested separately. MAR l l t992 Alaska Oil & Gas Cons. Commission Anchorage 2-68/S-17 SQUEEZE SCHEDULE Cum Time Sqz time Stage fluid minutes minutes Bbls on surface O on CMT 15 15 end CMT 32 on EW 33 34 37 22 end EW 38 on Poly 39 41 43 45 0 46 1 47 2 49 4 53 8 57 12 59 14 61 16 18 end POLY 63 18 on EW 65 20 67 22 69 24 73 28 77 32 81 36 10 end EW 83 38 on SW 85 40 ' 89 44 " 91 " 93 ' ~ . 95 97 99 101 103 104 105 108 110 112 Barrel BBIs fluid Pump Counts outnzl atnzl BPM 0 1 14.5/0 1 17.5 0 CMT 1 18.5 1 CMT 1 19.5 2 CMT 1 22/0 4.5 CMT 1 1 5.5 CMT 1 2 6.5 CMT 1 4 8.5 CMT 1 6 10.5 CMT 1 8 12.5 CMT 1 9 13.5 CMT 1 10 14.5 CMT 1 12 2 EW 1 14 4 EW 0.5 16 6 EW 0,5 17 7 EW 0.5 18/0 8 EW 0.5 1 9 EW 0.5 2 10 EW 0.5 3 11 EW 0.5 4 12 EW 0,5 6 14 EW 0.5 8 16 EW 0.5 10/o 18 EW 0.5 1 19 EW 0.5 2 2O EW 0.5 4 22 EW O.5 6 0 POLY 1 8 2 POLY 1' 10 4 POLY 1 12 6 POLY 1 14 8 POLY 1 16 10 POLY 1 18 12 POLY 1 19 13 POLY 1 20 14 POLY 1 21 15 POLY 1 22 16 POLY 0.5 23 17 POLY 0.5 24 18 POLY 0.5 CTD TOC _ 11029 11029 11029 11O29 11029 11002 11029 10975 10962 10908 10935 10881 10908 10854 10854 10800 10800 10746 10746 10692 10692 10665 10638 10638 10530 10638 10588 1O638 1O633 10752 10579 10866 1O525 10980 10471 11094 10417 11094 10364 10914 10310 10824 10283 10734 10256 10644 10229 10464 10202 10284 10175 10148 10148 COIL Return EEM WHP Bbls 0 0 0+ 0 0 -27 -27 -27 -27 -27 -27 -54 -54 1200 -54 " 0 " 0 " 1800 2400 # · 3000 · 0 " 57 1500 57 ' 57 " 57 ' 0 ' -90 -90 -90 ' -90 -90 -90 ' -68 0 ABC/1 1/23/91 comments Circulate sump while pumping cement switch to EW; ~H to 11029 (5' below perfs) Cement at nozzle; chokes dosed Open chokes when WHP rises to 1000 = perfs covered POOH bbl for bbl or 27 fpm switch to Poly Bbl for bbl Perfs covered/SQZ begins. SPEED UP coil to 54 fpm EW at nozzle; cross out of cement with nozzle SAFETY; park coil; reduce rate to 1/2 Start gauging returns Reduce returns; increase WHP ',-600psi Switch to EW: Reduce returns; increase WHP 600psi Reduce returns; increase WHP 600 psi SD pump; final bbl count; release WHP to 1500; sw/to PW Stop coil 50' below base of cement(11099') reduce rate and POOH Continue POOH to 50' above WCCTOC(10152') Trap 1500 WHP; switch to reverse circulation and RIH Total bbls oum~_d 0 14.5 32 33 34 36.5 37.5 38,5 40.5 42.5 44.5 45.5 46.5 48.5 50.5 52.5 53.5 54.5 55.5 56.5 57.5 58.5 60.5 62.5 64.5 65.5 66.5 68.5 70.5 72.5 74.5 76,5 78.5 80.5 82.5 83.5 84.5 85.5 86.5 87.5 88.5 L00 OA?R FRO~t PX~:Oq-gOB QB/~g/gO 2-88/8-17 50029-2185800 L 0800 .logoo 1ST LOC,: CBT 14-3EP-;~8 2FT 2 IN NELL .'{0 GRID3 - SINGLE NELL PANEL . '" H~O _~T' i'0 ' '~000"~.GS81JL~ 0N6TY ___~ ~ · ~-~ , ELE~ - DEV.. 37:14 7000' ~ HTSO.C'i~E. BTRS. ,, ~..5,,.r. 47#/it. fiEF: LO~ DLL~R iNqg:: Rv,ki. ~0758' - %0776' 107~1'* rOBOT I~1b"- 108~ * IO~1' Io~6z. Io9~6,- 10996' - 1 t024' WELL NAME LOG/DATE 2-68/S-17 DLL 9/9/88 TREE 4. t~r I ~x~ ~ / ~EvoY WELLHEAd. 1~*1 ~X~ ~/ OTI~ t3.81:~ ~N. W~ ~ I.D. ~ ~1~. I~. L~, ~(~) 3-1~. o~ L~ ~ ~7~ 3-1~ EN01COTr WELL 2-68 / S-17 APl NO; 50-029-21~158. COMpLE'nON DIAGRAM BP EXPLORATION, INC. l [n._~ ~ T.T~O. I 2-88/5- ! 7 I '~DRNP ~(NDI LD~ ~ J ~[O LRT LDI~ RECEIVEI ,Alaska OiJ & Gas Cons, CommiSSiOn Anchorage TOP M.D. BOTM.D, H TOP TVD BOT TVD SPINNER 6/1 1/89 3C4 10758 10776 15 9910 3C3 10781 10807 26 993; 3C3 10816 10828 12 9962 3C2 10836 10851 15 9980 3C2 10866 10875 9 10006 3C1 10890 10946 55 10028 383 10962 10986 20 10092 382 10996 11024 30 10122 9926 9954 0 9973 100% 9993 0 10014 0 10O77 10113 10147 SPINNER 9/6/89 100% 0 0 0 SI~NNER 9/1 6/90 0.00 0.00 0.00 0.00 0.00 0.47 0.53 0.00 SPINNER 5/19/91 0.38 0.18 0.05 0 0.01 0.22 0.11 0.05 ~ C.. 2. ; . .1 . RECEIVED MAR Oil & Ga~ Cons. Anchorage C,U SQUEEZE PROCEDURE ATTACHMENT A BP CEMENT DESIGN FORM Date: We11:2,68/S-17 Submitted By: Service Company: Thickening Time' Fluid Loss Target: Acceptable Range: 40 40-50 hrs (includes 1 hr surface plus 4-6 hrs pump time) cc/30 min at j 165 ,°F cc/30 min ...TEMPERATURE/PRESSURE 0-60 90°F @ Atmospheric Pressure 60-90 Increase pressure to 4000 psi. Increase temperature to 150° (120°/hr). 90-120 From 90 to 120 minutes, gradually increase pressure to 7500 psi and temperature to 165°F. 120-130 Hold Temp & Press @ 165°F & 7500 psi for remaining 20 min. 130-150 Maintain temperature at 165°F. Decrease pressure to 6000 psi and hold 6000 through- out the remainder of the test. 150-End of Test Increase temp by 15°/hr to a BHST of__ (if reached) until End of Test. oF Results' Please submit results to Anchorage Petroleum Engineering. Date of Test' Lab Fluid Loss: Service Co. Engineer: Thickening Time: RECEIVED PLH/11/20/91 AJaska Oil & Gas Cons. Commission Anchorage ***** C,U SQUEEZE PROCEDURE .Calculations Tubular O.D. (in), Tubing 4.5 Tailpipe 3.5 Liner 7 Weight I.D. Capacity Top- Bottom (#/ft) (in) .. (bbl/ft) (ft MD BKB) 12.6 3.958 .0152 38.9-9937 9.2 2.635 .0087 9951-10067 29 6.276 .0371 10023-11287 Volume 151 Cement- Liner Volume-- (11029-10700)*(.0371 ) Safety factor Total 12.2 1.20 14.5 BBLS Worst case top of cement-- 11029 -14.5/0.0371 Polymer 14.5 '1.25 10638' 18 BBLS Liner volume above WCTOC (10638-10067)* 0.0371 .... 21.2 Tailpipe volume 1.0 Contaminated cmt vol. in tubing 18 - ( 21.2+ 1.0 ) Will not reach tubing WC top of contaminated cmt: 10638 - (18 / 0.0371) 10152' RECEIVED MAR 992 Alaska Oil & Gas Cons. Commission Anchorage' PLH/1 1/22/91 ***** C,d SQUEEZE PROCEDURE ATTACHMENT B CTU .NRWO .. CEMENT .,,~QUEEZE SUMMARY Any questions please contact Bryce Cunningham @ extension 4980 or Bill Blosser @4401. Last TD: .............. 11 287' Tubing size' 4 1/2" Liner size' 7" Minimum restriction:, 2.635" @10031' Pre Squeeze WO/P!TS 300 bbls seawater Cement Saueeze and Reverse Out Bottom Hole Static Temperature 220 F Bottom Hole Static Pressure .............. 4200 psi Cement Volume ............................... 14.5 bbls WCTOC 10638' WCCTOC 10152' Polymer .................................. 18 BBLS Design TemD F.L. cc/30min Thickening time(bO Initial Sqz. 165 °F. 40 5-7 Squeeze Pressure: 1200 psi for 10 min increasing to 3000 psi over the remaining 40-50 mins of squeeze. Jet polymer to cement prior to reverse out. Reverse cement out immediately and spot N2 to allow 1500 psi underbalance during perf operations and adjust WHP to allow 1000 psi overbalnce at perfs while WOC. Post Cement Squeeze Operations Inflow Test Perforate with 2 1/8" guns at 4 SPF 10866'-11024' Ref. CBT 9/14/88 PLH/11/22/91 / ECEIVED MAR t i ~"q" ,'~Jaska 0il & Gas Cons. Commission Anchorage · BASIC SYSTEM MAKEUP ' 8OWEN PACKOFF' F~ ,,,~ ,i 1-*- HAND .PUMP - FLO.WTUeE. ,. F'LOWLIN I i GREASE LINE FLOWLINE · VALVE.... ~ '_ . GREASE. : .. t..:MANIFOLD '-'~ ~~~GREASE · -~ .~ PUMP RISER GREASE RESERVO. )~t -'~ ~ ~o~ ,~nChorage June 13, 1991 Alaska Oil and Gas Conservation Commission Page 3 WELL 2-58/S-09,,~0" ~ '2, TEMPERA'FURE COLLAR LOG v/ 13000'-14335' TEMPERATURE LOG 9900'-10806' HRS · PRODUCTION PROFILE 105·00'-11100' WELL 2-70/U-15V/.~ "153 TEMPERATURE LOG 11308'-12175' HRS WELL 3-01/N-29 V' PERFORATING RECORD 11650'-12750' SCHLUMBERGER WELL 3-05/O-29 / X - Y CAUPER SURVEY 11440'-12550' TEMPERATURE SURVEY 11600'-12565' 12100'-12430' ATLAS WIRELJNE 5/25/91 RUN ONE 6/4/91 RUNONE 5/1 9/91 RUN ONE 5/19/91 RUN ONE 5/13/91 RUNONE 5/7/91 RUNONE 5/24/91 RUN ONE 6/6/91 RUNONE 2013/JLH/cit COLLAR 10140'-10261' ATLAS WIRELINE WELL 2-68/S-17 STATIC 10650'-111 00' HRS CAPACITANCE 10295'-10895' HRS WELL 3-17/J-30 PROD-R 13300'-14000' HRS WELL 3-21/L-34 DUAL STATIC 12625.5'-12632' SCHLUMBERGER WELL 3-33/K-37 DUAL STATIC 12944.5'-12957' SCHLUMBERGER WELL 3-39/J-39 PROD-R 14000'-14425' SCHLUMBERGER WELL 4-20/M-35 PROD-R 11535'-11850' HRS Sincerely, b~-iaas JLH/Ims cc: File 06.10 11/4/9O RUN ONE 10/1/90 RUN ONE 10/1/90 RUN ONE 1 0/7/90 RUN ONE 1 1/1 0/90 RUN ONE 10/21/90 RUN ONE 11/3/90 RUN ONE 10/3/90 RUN ONE RECEIVED NOV 2 8 1990 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 20, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 1-27/P~20 PERF 9688'-10690' SCHLUMBERGER WELL, ,,1-27/P-20 PROD-F 10350'-10942' WELL 1.63/T-22 PROD-F 12200'-13098' WELL 2-28/P-19 PROD-F 9900'-10443' WF~LL 2.36/O-14 TUBING CUTTER 10140'-10270' SCHLUMBERGER 8/22/90 RUN ONE 10/20/90 RUN ONE 10/19/90 RUN ONE 10/26/90 RUN ONE 1 1/1 3/90 R~E RECEIVED NOV 2 8 1990 Alaska Oil & (~as Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 17, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells' WELL 1-01/J-! ~) /PRODUCTION PROFILE 11800'-12240' CAMCO 9/8-9/90 RUN TWO WELL 1-27/P-20 9/1 2/90 PRODUCTION PROFILE RUN ONE 10350'-10946' CAMCO ...iWELL 1-47/Q-2.1 10700'-11200' PRODUCTION LOG (MULTIRATE) SCHLUMBERGER 10/2/90 RUNONE RECEIVED · ~~' ' WELL 1-55/R-25 12900' - 14250' PRODUCTION LOG SCHLUMBERGER 1 0/1 1/9O RUNONE pRE L L 2-18/L-16 ODUCTION PROFILE 10700'-11346' CAMCO 9/13-14/90 RUNONE WELL 2-68/S-17 i ~TATIC, TEMP SURVEY O650 -1110O' H~%-iTANCE 10295'-10895' '"<~RS 10/1/90 RUNONE RUNONE PRODUCTION LOG 154' - 11125' SCHLUMBERGER /,~/pRE L L 3-47/Q-35 ODUCTION PROFILE 10000'-11263' CAMCO 9/17/90 RUNONE WELL 4-48/K-43 /~RODUCTION PROFILE 15870'-16230' CAMCO Sincerely, 9/10/90 RUNONE ~2'.~ !~: Haas JLH/Ims cc: File 06.10 9/10-1 1/90 RUNONE % RECEIVED 0C T .2~ 1990 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALA~SKA OIL AND GAS CONSERVATION COMMISSJuN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate.. Plugging Pull tubing .. Alter casing Repair well Perforate x Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410'SNL, 4351' WEL, Sec. 36, T12N, R16E 12. Present well cc~ndition summary' " Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service Effective depth' measured true vertical 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number/approval number 88-97/90-505 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool 11360 feet 10504 BKB feet 11287feet 10440 BKBfeet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 9530' measured 1337' 7" 560 c.£ Class G 10023'- 11360' 9321'- 10504' 10760'- 10775'; 10781'- 10807'; 10816'- 10828'; 10836'- 10851'; 10866'- 10875'; 10890'- 10945'; 10966'- 10986'; 10995'- 11025' true vertical (Subsea) 9912'- 9926'; 9931'- 9954'; 9962'- 9973'; 9980'- 9993'; 10006'- 10014'; 10028'- 10077'; 10095'- 10113'; 10121'- 10148' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) 9 518" Packer at 9951'; 4 1/2" SSSV at 1530' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3311 2564 50 0 2147 1276 293 0 Tubing Pressure 733 1205 15. Attachments Copies of Logs and Surveys run ,,, Daily Report of Well Operations . X 16. Status of well classification as: Oil X Gas__ Suspended,., Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~// '~, ~'~ TitleReservoirDeve'oprnentCoordin,tor Form 10-4~34 Rev 06/15/88 Date ~.,~/,7..~.//? O ~ SUBMIT IN DOPL1CATE .SEP-- T--90 FRI JUN-01-'00 17:13 BP EXPLOR TEL HO: .... P. 1 1 Production Engineering ,., Department. ..... DATE: ] Sept 1990 WELL N": 2-68/$-17 BP EXPLORATION REP: SERVICE COMPANY: Ad__d_!_t!.onal .....Perforations Lumdke. Chan AWS(Harper) 9/1/90-0700 RU AWS. Post radio silence signs at the entrance'to'the island-and ._adjacent to tho well site, 0730 ' Install SSV fusibl~, c..ap. '~'~-~S.~'..is O_ut, '-" .......0_8_00 ...... Pressure test lubrieator..t° wellhead pressure. 0800 ., I~TA.B~ISH RADIO SILENCE AND__A_R_M___ O.U_N$_iNotifv rig, security). SI Well, Make sure well is in test s~paratRr_,: .... 0900 Valves found to bo leaking, Wait on grease truck, Or~ase trUck ..operator could not fix Ixoblcm...,.,_. ,W,,a. it for he.l%_f_rom _PB,. 1130 Rig d_o.W__n,__No materials on .han,,d~t~Lflx_.s.w..ab valve, 9/3/90-0700 RU AW$, Post radio silence signs at the entrance to the island and .adia~_.~.n..t to thc well site, 07'30 Install SSV fusible cap. The S$$V"ls In' Out, WHP -- l~i) psis, WHT_" ?3__d_ezF, IAP = 0 I)SIll, nIP ,1. 0 psllt. . ......... 0800 Pressure test lu_b. ricator, to wellhead...pr_o.s_s.u_m 0730 .... ESTABLISH, RADI0,,S,,[J~_N~N_C_E_A. ND.._AR.,M__0U?'~_'i(N-0_tii~y. riz. se,urity). 0800 SI Well, Mck9 su~....wg!!/_s_ in. ~est separator, 0820-' Rill wRh Ogn #1 ( 20 feat). ..... $1WHP..,.~I31_0_ I~il~ 1300 Log CCL from 11100'-980ff M~DBKBY-~e into CBT dated 14.sep-88. AII~ of the depths listed below are from the open hole reference log. Fiat, line . for...._~next_ r_o.n,~,, .... 1~20 Oven vroducti.~p..,~e,hoke to 2!._b~ans, __F_W?P = 1193 134o Hang and shoot gun #1 from 11004'-110:14' MDBKB and flow Well for 10-15 minutes. FWHP =_._:!~28 osi~., ... ....... !~0___ SI well and POI-I, 1437 ........ Rill wi~h Ou~ #2. ( 12 f~i):_'$1WHP ?.'.iid. i--i~lg. ' .. -' 1515 Oven eh0k, to 20 beans, FWI. Ip - I110 psis. ' 1530 TI, in to CBT logging up. Shoot gun # 23 from "ib996~~11004' MDIIKB, Shoot gun # 2b from 10981'.10986' MBIIKB. .FWHP ~ 1171 --.. I700 Open choke t.o 20 beans FWHP =. fi?0 D~illb. 1745 Tic in to CBT logging ~p. Sho~i'"~n # 3 from 10962-10~8;l' MDB_KB, ,I*WHP = ii~.{,,.]~!~. 1752 ~!l._..w, ell and POI,I, G.U,n,_. ,dll not fir, · .,faul~ cap. 183_0__.. RIH wlth__Oun__~...( 20...fee~t)._ SIWItP = 1204 1937 ,., SI well ,nd POId...R~_._eh*ld--b,~-~'~e---o-~'"~;'-'jh- eabl~ heM, "- .... ot,.5 . ma cu. #3 ( fe..o, s WaP. _psis:' i ..... ~1.0.0, Open choke tg~g0 bean,. FW, HP. - 1094 2115 Tie {n to CBT loggin~ up. tlh°ot 8~un # 3 from 1'0962.10}82, .......... ~_,_}BKB. FWRP-- 10}4 2130 Sl well and POR, "O'~n didn,t fire - {"~akinli firjn~ h~.d' - '" - " " - - - ---':' ' - .............. -~.~-~ ...... '1 ~'-"'~' .... 2]$0 RIB with 0~n.._~.~ 20 feet),_,__' {{~HP = ll2~-"-O~ig.~. ........... 2200. Open ohoke to 20 buau.s .... .F. WHP _- 1060 p~{g, '"' 2230 Ti, in to CBT logging up. Shoot gUn # 3 from I09~2-10~8~' MI)BKll.._F. WHP = 114~ Imsli~ ..... .... z 0d' ._sl_ w¢{l..,%nd PO-., ' ................ , , _.. __,. . .... . ,.. DATE; 4 Sept 1990 WELL N~: 2-68/g-17 TYPE OF OPERATION; ^ddliional Perforations .... ;~/~/~__0' ~0.~0.., ~ wRh (]un .84 ( 20 fe~t}, _~IWHP = 95§ ps_ii .... 0100 0pe_n ch-0k_~ to_20 beans, FWHP --- 1060 pale, ,, ~_ '0115' ' Tie in to CBT logging up. ~oot gun # 4 from 10926-10P4~' .............................. MP.~KB., .FWHP:~_ ?~_0.. psis.. ~ .............. - ___0!30 .... 8I well and P0,H. ,, ...... 0'{~d ..... Tie in m ~T logging up. ~h~l gun MDBKB~, FW~P = 968..~m1{. , ..... 0308 . ~I wull ~d POH. ........... 04]~ ........ RIH wia O,~ ~ ( 16 feet}. ~SI~HP. ~ ~'.l~'~'--osig. 0450 D~-' ~hoke to 20 b~.an~. FWHP = 1~80 psig.., ' 0500 Tic in ~ CBT lo8~{ng up. ~ho°~ ~n ~P~KB. FWHP = 1040 psis, ..... , ........ 0600 } RIH, wi~ On. ~7 (,,.!,8 f~t)..,SIWHP = 1720 pmlg. .. ,, 0640 Oo!o choke to ~0 be,~O,S~ F~P = .!65~_ o!il ........... 0650 Tiu in lo CBT logging up. Sh~t g~ MDB~B. FWHP = 1670 pall ............... '~" '- 0700 ...... ~I w~il'~and.,,~H,, S~aJP = l,~2~osi~."-~onfi~ ali shots fife4. ........ 0800 -.-. ~ End .radio.., siJ~nqe,,. . ......... - ........... 090~., RD. POP, ~_~ ~ .... , PERFORATION SUMMARY: INTERVALtDLL) ~R{,~[~F.,I~[{ 10758-10776 10758-10776 10890-10946 10990-10946 10962-10986 10962-10986 10996.11024 10996.1102~ I 8 3C4 .g 6 3C1 24 3B3 28 3B2 = 126 All intervals were shot using AWS 2 1/8" hollow carrier guns at 4 spf, 6 1/2 grams charge and0 d¢grco phasing on tho low side of the hole. The tie-in .log was on depth with th~ open hole reference log. SUMMARY: BEIaO~ <gJN AF'I~R EVvU-IP__ _~ ~ Y"Wne 1194 1310 1 1284 1228 1220 1284 2 1210 1172 1060 1122 3 956 1140 702 956 4 1230 760 978 1230 .5 1452 968 1580 1452 6 1720 1040 1650 1720 7 1325 1670 Note: Asphaltines began appearing in the lubricator after the second gun and the pressure sensors/gauges probably became partially gummed up, , ! . . '2", ,. . · . · . . BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 26, 1990 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Field Additional Perforations Dear Mr. Chatterton' Enclosed in triplicate is Form 10.403, Application for Sundry Approvals, for wells 1-01/J-19, 1-47/Q-21,2-46/Q-15 and 2-68/S-17. We are planning to perforate additional intervals in these wells. Please contact Quinn Meads at 564-5880 if any additional information is required. Sincerely, H. L. Hellman Reservoir Development CoOrdinator HLH/RQM/Ims Enclosures STATE OF ALASKA ~,_,~SKA OIL AND GAS CONSERVATION COMMI~olON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate x Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351'WEL, Sec. 36, T12N, R16E 12. present well condition summary Total depth: measured 11360 feet true vertical 10504 BKB feet 5. Type of Well: Development. x Exploratory __ Stratigraphic__ Service Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number 88-97 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool Effective depth: measured 11287 feet true vertical 10440 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~/~Bh 92' 30" Driven 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 10241' 9 5/8" 575 c.f. C/ass G 10280' 1337' 7" 560 c.f. Class G 10023'- 11360' measured 10781-10807? 10816-10828'; 10836-10851'; 10866-10875' true vertical (Subsea) 9931-9954'; 9962-9973'; 9980-9993'; 10006-10014' True vertical depth BKB 131' 2494' 9530' 9321'-10504' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951~ 4 1/2"SSSVat 1530' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/?~,ZO ~ Title ReservoirOevelopmentCoordinator FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Location clearance IApprOval N°' Subsequent form required 10-~-~ ~' LONNIE C. SMITH ~ Date ~ '~-- 22 SUBMIT IN TRIPLICATE BP Exploration Endicott Field Well 2-68/S-17 Additional Perforating Proposal In order to better drain the oil in subzones 3B and 3C, we propose to perforate the following additional intervals. 10760' -10775' MD 10890' -10945' MD 10966' -10986' MD 10995' -11025' MD (Ref. DLL 9/14/88) A lubricator will be installed and tested to 3000 psi for all well work. will be reinstalled and tested after the perforations are added. The SSSV BASIC SYSTEM MAKEUP 8OWEN PACKOFF' '~1-*-'" HAND .PUMP SEAL ' E:LOW'TUB E FLOWLINE GREASE LINE FLOWLINE V. ALVE ? 8oP GREASE .,,_.GREASE RESERVO. BP EXPLORATION October 11, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott well: WELL 2-34/P-14 *TEMPERATURE LOG (PITS) Logged 10/1/89 Run No. 1 *TDT-P (PULSED NEUTRON-BORAX LOG) Logged 10/1/89 Run No. 1 WELL 2-68/S-17 *PRODUCTION LOG Logged 9/8/89 Run No. 1 WELL 4-04/T-26 *CEMENT EVALUATION LOG (CET) Logged 9/18/89 Run No. 1 *CEMENT BOND LOG (CBT) Logged 9/18/89 Run No. 1 Logged by Schlumberger. Sincerely, G~llard~ GND/Ims EE ED /Alaska 0il & 6as Cons. C0mmissi01~ V Anchorage BP EXPLORATION Ofl!GIN t BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 10, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Mud Acid Treatment on Well 2-68/S-17 Dear Mr. Chatterton: Enclosed in duplicate is Form 10-404, Report of Sundry Well Operations, for Endicott Well 2-68/S-17. The well was treated with mud acid on September 3-4, 1989. If there is a need for any additional information, please contact Bill Blosser at 564-4401. Sincerely, j/rReserxToir and Production Engineering jFO/WRB/lms Enclosures CC: Working Interest Owners Drilling Well File RECEIVED OCT 1 1 1989 Alaska 0/i & Gas Cons. C0mmlsS[01t Anchorage 1152/JLH STATE OF ALASKA ALA,...A OIL AND GAS CONSERVATION COMMISS,,... ~ ~~,.~ RI:PORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development X Exploratory Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-68/S- 17 MPI 9. Permit number/approval number 88-97/?- 10. APl number 50- 029-21858 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11360 feet 10504 BKB feet 11287feet 10440 BKBfeet Plugs (measured) Junk (measured) Length Size Cemented Measured depth BKB 92' 30" Driven 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 1337' 7" 560 c.f. Class G 10023'- 11360' measured 10781-108077 10816-10828'; 10836-10851'; 10866-10875' True vertical depth BKB 131' 2494' 9530' 9321' - 10504' true vertical (Subsea) 9931-9954'; 9962-9973'; 9980-9993'; 10006-10014' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSS V at 1530' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1 1 ]989 Alaska Oil & Gas Cons. Commisslol~ 14. Prior to well operation Subsequent to operation Representative ~)aily Average Production or hljection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 270 .... 0 3451 285O -- 0 Anchorage Tubing Pressure 322 74O 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of~ X Oil X Gas . Suspended .. Service 17. I~b--~-/~1, ,a~,~/?/i~i~t~ue and correct to the best of my knowledge. Signed ~ ,~///__//__//__//__//_~¢~'~ Title Manager, Reservoir& Production Engineering Date//~"//'~' Form 10-404,Re¢, 06/15/88 I SUBMIT IN DUPLICATE Attachment 1 WELL 2-68/S-17 MUD ACID TREATMENT OPERATIONS SUMMARY 1 ) R.U.D.S. and A.C.T. Have vac truck on standby 2) Flange D.S. to wellhead. Have A.C.T. prepared to enter well as soon as D.S. moves off well. 3) Safety meeting and job overview. 4) Pressure piping, wellhead connections and BOPE to 5000 PSIG. SIWHP = 890 PSIG IAP = 380 PSIG OAP = 2000 PSIG 5) Hook up chart recorder to monitor treatment 6) Open gas lift flow control valve and increase IAP to 1900 PSI. NOTE: Monitor and bleed IAP and OAP as required during treatment. Set pump trips to a 4900 PSI surface pressure limit. All treatment fluids should be heated to a minimum temperature of 120° F. Obtain 1 liter representative samples of all treatment fluids for analysis by Chemlink. 7) Stage 1 treatment fluid: 12 BBL (500 GAL) 7-1/2% HCL W/l% A166 +20#/MGAL A153 + 0.2% F75N +0.5% W35 +20#/MGAL L58. 8) Begin pumping Stage 1 acid pre-flush at 5 BPM, 4350 PSI. 9) 10) 1152/JLH Stage 2 treatment fluid: 19 BBL (800 GAL) 9%-3% HF W/l% A166 +20#/MGAL A153 +0.2% F75N +0.5% W35 +20#/MGAL L58. RECEIVED Begin pumping Stage 2 mud acid at 5 BPM, 4200 PSI. OCT 1 1 1989 AJaska Oil & Gas Cons. Commission Anchorage 1 1) Stage 3 treatment fluid: 150 BBL 3% Ammonium Chloride 12) Begin pumping Stage 3 overflush at 5 BPM, 4100 PSI. 13) Bleed IAP from 2500 to 2000 PSI. 14) Stage 4 treatment fluid: 30 BBL 3% Ammonium Chloride. Begin pumping Stage 4 at 1/2 BPM and 2800 PSI. End stage at 11:42. Pressure declined steadily from 2800 to 120 PSI. 1 6) Stage 5 treatment fluid: 448 BBL 3% Ammonium Chloride. Increase pump rate to 8 BPM at 3000 PSI. Begin dropping 1.2 SG ball sealers at 3 balls/BBL at the start of Stage 5. Total of 45 balls injected. Pressure oscillated from 3000 to 3600 PSI. 18) Balls hit perfs. Immediate increase in pressure from 3300 to 3800 PSI. Continued to flow at 8 BPM, 3800 PSI. 19) Drop additional 45 balls. 2o) Balls hit perfs. Immediate increase in pressure from 3800 to 4200 PSI. Pumped total of 628 BBL of NH4CL. 2 1 ) Called out additional acid and overflush. 22) Fluids on location, pressure test lines to 5000 PSI 23) Safety meeting and job overview 24) Stage 6 treatment fluid: 34 BBL (1420 GA1.) 7-1/2% HCL W/l% A166 + 20#/MGAL A153 + 0.2% F75N + 0.5% W35 + 20#/MGAL L58. 25) Begin pumping Stage 6 acid pre-flush at 8 BPM, 3550 PSI. Begin dropping 1.2 SG ball sealers at 3 balls/BBL at the start of Stage 1. Total of 100 balls injected. RECEIVED 1152/J LH OCT 1 1 1989 Alaska Oil & Gas Cons~, Commission , Anchorage 26) Stage 7 treatment fluid: 69 BBL (2890 GAL) 9%-3% HF W/l% A166 + 20#/MGAL A153 + 0.2% F75N + 0.5% W35 + 20#/MGAL L58. 27) Begin pumping Stage 7 mud acid at 8 BPM, 3650 PSI. Stage 8 treatment fluid: 430 BBL 3% Ammonium Chloride. 28) Begin pumping stage 8 overflush at 8 BPM, 3600. 29) Ball hit perfs. Pressure increases from 3600 PSI to 3800 PSI. 3o) Lower rate to 5 BPM, 2600 PSI (Slower rate will increase contact time). Mud acid is in formation. Pressure decreased from 2600 PSI to 2000 PSI at 5 BPM. Increase rate to 8 BPM for overflush. 32) Shut down. 3 3) Bleed down annulus. 34) R.D D.S Use vac truck to suck lines dry. 35) Flange up A.C.T. 36) Pressure test lines and well connections to 4500 PSI. 37) Open wing valve and choke. 38) Notify production supervisor of potential presence of unspent acid entering the flow stream and to increase the emulsion breaker as needed. 39) RIH with coiled tubing. 40) Start N2 injection at 400 SCF/MIN. 41 ) New pump truck called out to location. 42) Back on line at 400 SCFM. 1152/JLH 43) 44) Well is flowing naturally to plant at roughly 3500 BPD and a wellhead pressure of 680 PSI. R.D.D.S. and A.C.T. 1152/J LH . BP EXPLORATION enson Boulevar~ RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 15, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Well 2-68/S-17 Mud Acid Stimulation Dear Sirs: Enclosed, in triplicate, is form 10-403, application for Sundry approvals, for Endicott Well 2-68/S-17. We are planning to perform a mud acid stimulation on this well in August 1989. If there are any questions regarding this data please contact Dave MacDonald at 564-4697. Sincerely, F~/iOmi~e fibu rg i cc: Working Interest Owners Well file T. N. Tyler W. R. Blosser H. L. Hellman File 06.10 1075/JLH STATE OF ALASKA AL~oKA OIL AND GAS CONSERVATION COMMISu,,.,N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well__ Plugging __ Time extension__ Stimulate x Change approved program __ Pull tubing __ Variance __ Perforate__ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development x KBE = 55.18 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E At top of productive interval 4272' SNL, 4091' WEL, Sec. 36, T12N, R16E At effective depth 4398' SNL, 4324' WEL, Sec. 36, T12N, R16E At total depth 4410' SNL, 4351' WEL, Sec. 36, T12N, R 16E 12. Present well condition summary Total depth: 2-68/S- 17 MPI 9. Permit number 88-97 10. APl number 50- O29-21858 11. Field/Pool Endicott Oil Pool measured true vertical 11360 feet 10504 BKB feet Plugs (measured) Effective depth: measured true vertical 11287 feet 10440 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~,~Bh 92' 30" Driven 131' 2455' 13 3/8" 3285 c.f. Permafrost 2494' 10241' 9 5/8" 575 c.f. Class G 10280' 1337' 7" 560 c.f. Class G 10023' - 11360' measured 10781'- 10807'; 10836'- 10851'; 10816'- 10828'; 10866'- 10875' True vertical depth BKB 131' 2494' 953O' 9321'-1O5O4' true vertical (Subsea) 9931'- 9954'; 9980'- 9993'; 9962'- 9973'; 10006'- 10014' Tubing (size, grade, and measured depth) 4 1/2" 12.6#L-80 tubing with 3 1/2" tailpipe to 10067' Packers and SSSV (type and measured depth) 9 5/8" Packer at 9951'; 4 1/2" SSSV at 1530' 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: August 17, 1989 16. If proposal was verbally approved Oil X Gas ~ Suspended ~ Name of approver Date approved Service 17. I hereby,~ce~ th~~'~'~g i/~true and correct to the best of my knowledge. / .~/. ../// / //.,/,//~ // Signed ~,,~¢/~/ ~~/¢,f~~~', Title Manager, Reservoir & Production Engineering Date(~'/,,r'. ~ /"- /- "- / FOR COMMISSION USE ONLY Condi¢ons//of approval: Notify Commission so representative may witness I Approval No. ( ,/Plug integrity BOP Test Location clearance I ~ Me~'hani~al in~y Test ~-ubsequent form required i~-- ~'0~,/ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By r~ .... :.~ ~" jo~. ..... · 'dvlu ¥¥~, III I~'l, UI I ~pproved C,~o P¥ Ret~n%~ Co m__mJss~'~'-~ Date SUBMIT IN TRIPLICATE Attachment I DESCRIPTION SUMMARY OF PROPOSAL ENDICOTT WELL 2-68/S-17 S-17 was intended to be a test of the ability of Iow porosity (<10%) sands to produce. Four intervals, which are normally considered non-pay, were shot with wireline-conveyed perforation guns. Three intervals showed negligible pressure response during perforation, however the interval from 9962' to 9973' TVD showed a strong response. Flowmeters indicate that 100% of the flow is coming from a 4' sand located in this interval. Analysis of the PBU used this interval as the only pressure contributor. Horner and derivative analyses were in good agreement producing a transmissibility value of 2251 mDarcy-feet/cpoise. This resulted in a permeability of 450 mD, which is significantly higher than the 150-200 mD expected in zone 3C. It is likely that pseudo-steady state flow had not been reached, although the derivative analysis does indicate a flattening of slope. A skin value of +95 due to formation damage was calculated. It has been suggested that one possible cause of the abnormally high skin may be a relative permeability reduction due solution gas breakout in the near wellbore region. An r-z model of the area was history matched to the limited production data. It was not possible to reduce the effective oil permeability by gas breakout. When a skin factor of 85 was applied to the producing well, however, pressure drops similar to those observed were obtained. A mud acid stimulation is recommended to both reduce the skin damage in the one flowing interval and break-down the non-productive intervals. Attachment II is a more detailed procedure for the proposed 2-68/S-17 stimulation. Attachment II WELL 2-68/S-17 MUD ACID TREATMENT JOB OBJECTIVES To remove high skin damage and to attempt to stimulate initial productivity from Iow porositY sands in zone 3. Targeted perfs for the acid treatment are from 10781 to 10875 MD. The interval from 10816 to 10828 MD is currently the only flowing interval. PRE-TREATMENT 1) 2) 3) 4) 5) 6) Obtain an accurate and reliable well test with GOR Verify that there is no communication history between the tubing and the inner annulus Pull SSSV. Make a drift run for expected CTU nozzle diameter. Hot diesel wash to cleanup tubing as necessary. Flowback the well for 12 hours to remove paraffin in solution Make contact with Chemlink (Buck Houchin @ 659- 8367) to perform a flowback analyses on wellhead samples. Be prepared to provide them with produced fluids, samples of treatment fluids, and flowback samples as requested by them. INJECTIVITY TEST 1) Shut in choke, wing valve and injection gas 2) Pressure test lines to 5000 psi 3) Begin injection of deisel to measure the ability of the formation to accept fluids. Filter deisel on the fly to 3 microns 4) Increase pump rate to 8-10 BPM or maximum wellhead pressure of 4800 psi 5) Test should be concluded when ability to maintain injection of 8-10 BPM is confirmed, or when wellhead pressure of 4800 psi is reached 6) Notify Anchorage Reservoir Engineering before proceeding with pre- acid pickling PRE-ACID 2) 3) 4) 5) PICKLING Pressure test lines to 5000 psi Pump 2000 gal 7-1/2% HCL w/1% A166 + 20#/Mgal A153 Displace to top perforation with dead crude or diesel Put well on gas lift to flow back fluids Fluid pack the well with diesel TREATMENT 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) Shut-in the well at the wing valve, production choke and gas lift flow control valve Shoot fluid level on the inner annulus to confirm gas-liquid interface at the S/O GLV Pressure test lines to 5000 psi Maintain pump rate of 8-10 BPM or maximum wellhead pressure of 4800 psi. Filter all treatment liquids to 3 microns, on the fly Pump 750 gal 7-1/2% HCL w/1% A166 + 20#/Mgal A153 + additives Pump 1450 gal 9%-3% HF w/1% A166 + 20#/Mgal A153 + additives Pump 1420 gal 7-1/2% HCL w/1% A166 + 20#/Mgal A153 + additives While pumping the HCL, begin dropping ball sealers at 11 BalIs/BBI If bailout occurs, surge balls 3 times and attempt to finish displacement Pump 2890 gal 9%-3% HF w/1% A166 + 20#/Mgal A153 + additives Over displace with 250 BBIs 3% Ammonium Chloride water Displace to top perforation with dead crude or diesel Do not place in formation Rig down DS Flow well back. Method used either flow to tiger tanks, plant or disposal to be determined by NS operations. If flow is to plant, Production Supervisor should be notified of the potential presence of 14) unspent acid in the flow stream and of the need to increase the emulsion breaker accordingly Sample as requested by Chemlink POST 2) 3) TREATMENT Have Chemlink analyze flowback samples Obtain an accurate well test with GOR Obtain a PBU and flowmeter using A Schlumberger's down hole shut-in tool basket flowmeter and BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 24, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: ~"~VELL 1-63/T-22 APl No 50 029 21905 Run No. 2 *PRODUCTION PROFILE 12000'-12660' 6/7/89 5 inch log scale cased hole well _ logged by Camco WELL 3-41/K-39 *COLLAR LOG 13300'- 13638' 5 inch log scale APl No 50 029 21878 Run No.1 WELL 3-01/N-29 APl '50 029 21678 Run No.1 *SPINNER HP PRESSURE TEMPERATURE LOG 12280'- 12730' 4/23/89 5 inch log scale cased hole well logged by Halliburton WELL 2-70/U-15 APl 50 029 21899 Run No.2 *PERFORATING RECORD 11190'-12050' 6/19/89 5 inch log scale cased hole well logged by Schlumberger 6/12/89 cased hole well logged by Atlas Wireline Services ~WELL 2-68/S-17 APl 50 029 21858 Run No.1 ~---....~*PRESSURE BUILD UP SURVEY 10023'-11200' 3/24/89 no log scale cased hole well "~ PRODUCTION LOG 10600' -11000' 6/11/89 5 inch log scale cased hole well logged by Schlumberger WELL 1-27/P-20 APl 50 029 21693 Run No.1 "~*PRODUCTION PROFILE LOG 990o'-10850' 6/27/89 5 inch log scale cased hole well logged by Camco WELL 2-22/L-14 APl 50 029 21931 """~*INJECTION PROFILE LOG 11748'-12100' 6/14/89 5 inch log scale cased hole well logged by Camco Run No. 1 W~ 2-04/M-19 APl 50 029 21586 Run No.1 TEMPERATURE LOG 10100'-10660' 6/13/89 5 inch log scale cased hole well logged by Camco WE~2-08/K-16 APl 50 029 21676 Run No.1 PRODUCTION PROFILE LOG 11700'- 12200' 6/9/89 5 inch log scale cased hole well logged by Camco WELL 3-17/J-30 APl 50 029 21946 Run No.1 '"'--,*CEMENT EVALUATION LOG 13040'-14004' 7/3/89 5 inch log scale cased CEMENT BOND LOG 103040'- 14004' 7/3/89 5 inch log scale cased GAMMA RAY- CCL 13100'- 13700' 7/5/89 5 inch log scale cased logged by Schlumberger hole well hole well hole well Alasla 0~I & ~as Cons. ~mm~0~ Anchorage WELL 4-50/K-41 APl 50 029 21940 Run No.1 & 2 '"'"~PERFORATING RECORD 13553'-13564' 6/22/89 Run 1 ~...~. 5 inch Icg scale cased hole well *PERFORATING RECORD 13260' - 13820' 7/8/89 Run 2 5 inch log scale cased hole well logged by Schlumberger WELL 2-46/Q-15 APl 50 029 21921 Run No.1 '"'-J'PRODUCTION PROFILE 10600'-11000' 6/21/89 2 & 5 inch Icg scale cased hole well '"'"'*TEMPERATURE SURVEY 10600' - 11100' 6/24 & 25/89 2 inch Icg scale logged by Otis WELL 3-17/J-30 APl 50 029 21946 Run No.1 ~ *DUAL LATEROLOG MICROSPHERICALLY FOCUSED LOG 13382'- 14102' 3/8/89 ~ 2 & 5 inch Icg scale open hole well *COMPENSATED SONIC LOG 13382' - 14080' 6/29/89 2 & 5 inch icg scale open h01e well ~*DUAL INDUCTION LATEROLOG 13382' - 14105' .6/29/89 2 & 5 inch Icg scale open hole well ~ *SPECTRAL DENSITY DUAL SPACED NEUTRON LOG 13382' - 14103' 6/29/89 2 & 5 inch Icg scale open hole well *FORMATION TEST LOG no depths 6/29/89 no Icg scale open hole well logged by Halliburton Sincerely, Greg Dil a~(:~ GD/Ims cc: File 06.10 BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 5, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 .Endicott Field - B0tt0m-HCe Pressure RepQrts Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1-09/J-18 (Lower) 1-09/J-18 (Upper) 1-09/J-18 (Flowing Gradient) 06-07-89 O6-O7-89 06-07-89 1-63/T-22 06-07-89 2-04/M- 19 06-13-89 2-14/O-16 (Lower) 2-14/O-16 (Upper) 05-13-89 05-13-89 2-68/S- 17 06-12-89 3-27/M-33 05-23-89 3-41/K-39 05-25-89 if there are any questions regarding this data, please contact Dave MacDonald at 564-4697. Sincerely, V ' JUL 1 " BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 3, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ..Endicott Field - B0tt0m-H01e Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 2-16/M-16 2-10-89 2-26/N- 14 2-21-89 2-42/P- 13 2-09-89 2-68/S- 17 2-16-89 3-27/M-33 2-16-89 4-26/0-34 ' 2-21-89 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. Sincerely, JLH/Ims Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-661 (907) `561-.5111 STANDARD ALASKA PRODUCTION October 7, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one L.I.S. (data format) tape and computer read-out sheet for the open hole run in the following Endicott wells: 2-16/M-16 3-11/M-30 2-68/S-17 1-43/P-26 4-28/N-37 4-14/R-34 1-49/P-21 4-26/0-34 1-57/R-23 50 029 21885 50 029 2~48 50 029 21858 50 029 21864 50 029 21870 50 029 21863 50 029 21841 50 029 21835 50 029 21873 Received Date illard A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. HOUSTON ARCO CHEVRON E."LXO N TE}b\CO TO: MO B I L PHILLIPS STATE OF ALASKA GEOSC IENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS INOEX[~ Da*e: 10-31-88 r~: 79484 The following material Is being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning It to'this office: H- 16 LDT/CNL ay 10-29-88 #1 9350-10468 ATLAS 5" 10-12-88 #1 9400-9558 ATLAS 5" 10-26-88 #I 10600-11000 ATLAS 5" Shirley R. McCurry I NFOR~T I ON Wel I Records LR2-I Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION September 16, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one bludline print for the cased hole well logs mn in the following Endicott well: Endicott Well 2-68/S- 17 *Dual Laterolog MSFL Run Date: 9-9-88 Run No. 1 10272-11376 Company: Gearhart *Spectral Litho-Density Compensated Neutron Log Run Date: 9-9-88 Run No. 1 10272-11372 Company: Gearhart *Formation Tester Run Date: 9-9-88 Run No. 1 Company: Gearhart GND:gr Received by: Date Sincerely, Gre o}SPN~. A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company f~'~'~ 900 East Be~son tBoulevard PO. Box 196612 Anchorage, Alaska 995t9-66 (907) 561-511 i STANDARD ALASKA PRODUCTION September 21, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: EnclOsed please find one sepia and one blueline print for the cased hole well logs mn in the following Endicott well: WELL 3-45/M-39 *Collar and Perforating Log 12200'-12520' Gearhart WELL 2-68/S- 17SDI *Cement Bond LOg 10000'-11270' Schumberger *Cement Evaluation Log 10000'- 11290' Schumberger Sincerely, Greg~. Dillard Received By Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870, ALAS:'.. ',. AND GAS CONSERVATION' ._ /liSSION WELL COMPLETIOI i OR RECOMPLETION HEPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-97 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-21858 4. Location of well at surface 9. Unit or Lease Name 2137' SNL, 2366' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 'i 'I'(~A~iONSVERIFIED ~' 10.2_68/S. 17Well Number 4272' SNL, 4091' WEL, SEC. 36, T12N, R16E MPI . .Sur~ J},~/~ 111. Field and Pool At Total Depth Endicott Fie/d/Endicott Pool 4410' SNL, 4351' WEL, SEC. 36, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designalion and Serial No. KB = 55.18 IADL 34633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 08-22-88 09-10-88 10-27-88I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey 120. Depth where SSSV set 121. Thickness ol Permafrost 11360'MD 10504' TVD 11287'MD 10440'TVD YES [] NO []I 1530 feet MD I 1467 22. Type Electric or Other Logs Run CBT CRT, DLL/MSFL, SLD/CNL, FM Tester 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 131' Drive 13-3/8" 68# NT-80 Surface 2494' 17-1/2" 3285 cu ft Permafrost 9-5/8" 47# NT-80S Surface 8865' 12-1/4" 9-5/8" 47# NT-95H 8865' 10280' 12-1/4" 575 cu ft Class G 7" 29# SM110 10023' 11360' 8-1/2" 560 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD} 2-1/8" Silverjet @ 4 spf 4-1/2"12.6#TDS 10067'MD 9952'MD MD BKB TVDss w/3-1/2" tailpipe 10781'- 10807' 9931'-9954' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10816'-10828' 9962'-9973' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10836'-10851' 9980'-9993' 13-3/8"X 9-5/8" Down squeeze 13-3/8"x 9-5/8" 10866'-10875' 10006'-10014' annulus with 345 sks permafrost cement followed by 115 bbls dry crude. 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) October 27, 1988 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL 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 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS h JRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH GOR, and time of each phase. TOP HRZ 9980' 9283' ITKIL YARIAK 10288' 9554' TOP KEKIKTUK 10 703' 9917' 31. LIST OF ATTACHMEN'~'S .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ? '- Endicott Signed . .. Title Drillina Fnr]/neerin~7 Supervisor Date . 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. Item 28: If no cores taken, indicate "none". Form 10-407 STANDARD ALASKA PRODUCTION Rig: Doyon #15 Well: 2-68/S- 17 (MPI) Daily Drilling Report -- ENDICOTT August 18, 1988 at 0600 hrs AFE # 717554 APl: AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Current Operation: Moving rig. Move rig from Well 2-28/P-19. Mud Type: SURVEY. WT: VIS: PV: YP: ANOLE DIRECTION SECTION Solids: Temp: °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 19, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: -1 Current Operation: Annual rig maintenance. Exception rig move. Begin annual rig maintenance. Mud Type: SURVEY WT: VIS: PV: YP: FL: ANGLE DIRECTION ,TVD SECTION Solids: Temp: °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 22, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 API: 50-029-2158 AFE Amount: Current Amount: 0600 Depth: 350' Day: 1 72- Hour Ftg: 350' Current Operation: Drilling 17-1/2" hole. Complete annual rig maintenance. Except rig on 2-68/S-17 on 8-22-88 @ 0001 hrs. Spud well 2-68/S-17 on 8-22-88 @ 0230 hrs. Drill 17-1/2" hole to 350'. Mud Type: Spud SURVEY MD. WT: 8.9 VIS:250 PV: YP: FL: Solids: Temp: °F ANGLE ,DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: Doyon #15 Well' 2-68/S-17 (MPI) Daily Drilling Report -- ENDICOTT August 23, 1988 at 0600 hfs AFE # 717554 APE 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 2450' Day: 2 24- Hour Ftg: 2100' Current Operation: Drilling 17-1/2" hole. Drill & survey I7-1/2" hole to 2450'. Mud Type: Spud SURVEY i..lYrD_ WT:9.3 VIS: 105 PV: 14 ANGLE DIRECTION TVD YP: 26 FL: SECTION Solids: Temp: 46 °F COORDINATES DL$ STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 24, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 APl: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 2510' Day: 3 24- Hour Ftg: 60' Current Operation: Nipple up on 13-3/8" casing. Drill & survey 17-1/2" hole to 2510'. CBU. Trip for & cement 13-3/8" casing. Mud Type: SURV~., Y WT: VIS: PV: YP: FL: ANGLE DIRECTION TVD ~ Solids: Temp: ~F COORDINATES DLS. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 25, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 3350' Day: 4 24- Hour Ftg: 840' Current Operation: Drilling 12-1/4" hole. Nipple up B©PE & test to 3000 psi. RIH. Test casing to 3000 psi. Drill out cement & perform LOT. Drill 12-1/4" hole to 3350'. Mud Type: Ligno SURVEY ~ WT: 9 VIS- 36 PV: 6 YP: 6 FL: 22.5 Solids: 4 Temp' 50 °F ANGLE DIRECTION .TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 26, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 4800' Day: 5 24- Hour Ftg: 1450' Current Operation: Tripping. Dr/Il & survey 12-1/4" hole to 4800'. Trip for motor. Mud Type: Ligno .,SURVEy MD WT: 9.6 VIS: 37 PV: 9 YP: 11 FL: 18 ANGLE D1RE~FION TVD SECTION Solids: 8 Temp: 74 °F COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: Doyon #15 Well: 2-68/S- 17 (MPI) Daily Drilling Report -- ENDICOTT August 29, 1988 at 0600 hrs AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 7568' Day: 8 72- Hour Ftg: 2768' Current Operation: Tripping. Kick well off @ 4800'. Drill & survey 12-1/4" hole to 7568'. Mud Type: Ligno WT: 9.9 VIS: 37 PV: 10 YP: 7 FL:6.8 SURVEY MD ANGLE DIRECTION ~TVD SECTION 17 5162 11.7 $26W 5159 -16 19 5505 20.5 S35W 5488 18 22 6099 33.3 S32W 6020 337 26 6878 37 S34W 6654 785 27 7076 37.2 S32W 6812 903 29 7449 36.4 S36W 7110 1126 Solids: 8 Temp: 90 °F COORDINATES S5 W30 S89 W17 S313 W152 S692 W400 S790 W468 S973 W597 DLS 3.1 2.8 2.8 0 0.2 0.4 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT August 30, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 8218' Day: 9 24- Hour Ftg: 650' Current Operation: Tripping. Drill & survey 12-1/4" hole to 8218'. POH for motor. Mud Type: Ligno SURVEY MD 32 8021 WT: 9.8 ANGLE 33.8 VIS: 36 PV: 11 DmECTION S35W TVD 7579 YP: 9 FL: 6.4 SECTION 1452 Solids: 9 Temp: °F COORDINATES DLS S 1242 W784 0.4 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT August 31, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 8400' Day: 10 24- Hour Ftg: 182' Current Operation: Drilling 12-1/4" hole. Drill & survey with motor. POH for BHA. Drilling to 8400'. Mud Type: Ligno SURVEY MD 33 8291 WT: 9.9 VIS: 38 PV: 12 YP:9 FL: 6.4 ANGLE DIRECTION TVD SECTION 32.8 S40W 7804 1600 Solids: 9 Temp: 96 °F COORDINATES .DL,S, S1360 W875 1.1 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 1, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 9021' Day: 11 24- Hour Ftg: 621' Current Operation: Tripping. Drill & survey 12-1/4" hole to 9021'. Mud Type: Ligno WT: 9.9 SURVEY ~ ANGLE 36 8864 28~4 VIS: 37 PV: 12 DIRECTION S45w' TVD 8297 YP: 8 FL: 6.0 SECTION 1892 Solids: 9 Tcmp: ~96 °F COORDINATES DLS S1571 W1077 0.9 STANDARD ALASKA PRODUCTION Rig: Doyon #15 Well: 2-68/S-17 (MPI) Daily Drilling Report,-- ENDICOTT September 2, 1988 at 0600 hrs AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: Current Operation: 0600 Depth: 9300' Day: 12 24- HourFtg: 279' Drilling 12-1/4" hole. POH. Test BOPE. RIH. Drilled to 9300'. Mud Type: Ligno. SURVEY ]MD WT: 10.0 VIS:38 PV: 15 ANGLE DIRECTION TVD YP: 10 FL: 5.3 SECTION Solids: 10 Temp: 96 °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 6, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 10,480' Day: 16 96- Hour Ftg: 1180' Current Operation: Drilling 8-1/2" hole. Drill 12-1/4" hole to TD @ 10,295'. Run & cement 9-5/8" casing; shoe @ 10,279'. RIH with 8-1/2" BHA. Drill out cement & test casing to 3000 psi - OK. Drill 8-I/2" hole to 10,480'. Mud Type: Ligno SURVEY 39 41 43 ,MD 9421 9801 10295 WT: 9.7 VIS: 37 PV: 10 YP: 7 FL: 6.0 Solids: 9 Temp: 102 *F ANGLE DIRECTION ..TVD SECTION COORDINATES DLS 29.6. S47W 8786 2157 S1755 W1268 0.5 26.6 S53W 9121 2334 S1873 W1403 1.5 29.6 S61W 9559 2553 S1996 W1596 1.1 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 7, 1988 at 0600 hrs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 10,670' Day: 17 24- Hour Ftg: 190' Current Operation: Drilling 8-1/2" hole. Drill to 10,662'. Circulate & condition mud. Drill to 10,670'. Mud Type: Ligno. S, UR, ,~,Y MD WT: 9.7+ VIS: 36 PV: 10 ANGLE DIRECTION TVD. YP: 8 FL: 6.4 SECTION Solids: 9 Temp: 104 °F COORDINATES DIS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 8, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: I 1,090' Day: 18 24- Hour Ftg: 420' Cun'ent Operation: Drilling 8-1/2" hole. Drill 8-1/2" hole to 11,090'. Mud Type: Ligno SURVEY MD . WT: 9.8+ VIS: 35 ANGLE DIRECTION PV: 10 YP: 9 FL: 5.6 TVD SECTION Solids: 9 Temp: 108 °F COORDINATES DLS ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT September 9, 1988 at 0600 hrs Rig: Doyon #15 Welt: 2-68/S-17 (MPI) AFE # 717554 Al'I: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 11,360' Day: 19 24- HourFtg: 270' Current Operation: Running open hole logs. Drill to 8-1/2" hole TD @ 11,360'. Circulate & condition hole. POH. Run DLL/MSFL/SP/GR & SLD/CNT/GR. Mud Type: FW/Lignoo SURVEY' MID WT:9.8+ VIS:37 PV: 10 YP:9 FL:5.4 ANGLE D1RECTIQN TVD .SECTION Solids: 9 Temp' 110 °F COORDINATE~ DL$ STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICO'FT September 12, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-68/S-17 (MPI) AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 11,360' Day: 22 72 - Hour Ftg: Current Operation: Repairing leak in 9-5/8" casing coupling. Run open hole logs: SLD/CNT/GR, ML/GR (Mis-run), SFT/GR, SWC/GR (Tool failed). Circulate & condition hole for liner. Run & cement 7" liner; shoe @ 11,360'. POH. Clean out cement to top of liner. Attempt to test 7" liner lap - No test; teak in 9-5/8" casing coupling near surface. Mud Type: Ligno SURVEY MD _ . WT:9.6 VIS:42 PV: YP: FL: ANGLE DIRECTION TVD SECTION Solids: Temp: °F COORDINATES .DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 13, 1988 at 0600 hfs Rig: Doyon #15 Well: 2-68/S- 17 (MPI) AFE # 717554 APl: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 11,360' Day: 23 24- Hour Ftg: Current Operation: Retrieve packer & storm valve. Set storm valve & RTYS packer. Pull packoff & mandrel hanger. Back out parted pup joint. Make up new joint of 9-5/8". Set emergency slips. Test packoff & casing to 3000 psi. POH with packer & storm valve. Mud Type: Ligno. SURVEY MD. WT: 9.6 VIS: 42 PV: YP: FL: Solids: Temp: cF ANOL~ I)!R~Cri0N ..... TV~ SECnON_ COOm)~AT~S ~)LS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 14, 1988 at 0600 hfs Rig: Doyon t115 Well: 2-68/S- 17 (MPI) AFE tt 717554 API: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: 11,360' Day: -24 24- Hour Ftg: T.D. Current Operation: Rig up to mn cased hole logs. POH with storm packer. RIH & test liner lap-OK. Tag cement @ 11,161'. Clean out to FC @ 11,287'. Displace well to NaCI brine. Test liner - OK. POH & R/U to run cased hole logs. Mud Type: NaCI Brine SURVEY MD WT: 9.2 VIS: PV: YP: ANGLE DIRECTION TVD FL: Solids: Tcmp: CF sECTIoN COORDINATES DLS Rig: Doyon #I5 Well: 2-6g/S- 17 (MPI) STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT September 15, 1988 at 0600 hfs AFE # 717554 API: 50-029-21858 AFE Amount: Current Amount: Current Operation: 0600 Depth: 11,360' Day: '25 24- Hour Ftg: T.D. RIH with gauge ring. Run cased hole logs. Run 4-1/2" tubing. N/U & test tree. Attempt to set a plug in XN nipple. Miss run. Make gauge ring run. Mud Type: Brine SURVEY tVID WT: 9.2 VIS: PV: YP: FL: Solids: Temp: cF ~ANGL~ DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Rig' Doyon #15 Well: 2-68/S- 17 (MPI) Daily Drilling Report -- ENDICOTT September 16, 1988 at 0600 hfs AFE It 717554 APl: 50-029-21858 AFE Amount: Current Amount: 0600 Depth: I 1,360' Day: '26 24- Hour Ftg: Current Operation: Rig released. Set packer. Displace tubing to diesel. Secure tree '& release rig @ 1600 hours on 9/15/88 for move to 1-43/P-26. Mud Type: SURVEY WT: VIS: PV: YP: ANGLE ,DIRECTION - TVD FL: Solids: Temp: °F SECTION COORDINATES .DLS $UB.~URFACE DIRECTIONAL ~URVEY ~]UIDANCE F~ONTINUOUS ~-~"~ OOL Company STANDARD ALASKA PRODUCTION COMPANY Well Name 2-68/S-17 MPI (2137' SNL~2.3.66' WEL,SEC 36,T12NrR16E) Field/Location ENDICOTT~ NORTH SLOPE, ALASKA Job Reference No. 72933 SALAZAR Oat....~e 14-5EP-88 Com. puted By; KRUWELL GCT DIRECTIONAL SURVEY CUSTO~E~ L ] ST [~4,.% ST~NgARD ALASKA PRODUCTION 2-68/S-17 MPI ENDICOTT NORTH SLgPE,~L&SKA SURVEY D~TE: 14-SEP-8~ ENGINEER: S. SALAZAR METHOOS OF COM~IJT~TION TOtaL L]CAT~ON: TA~'IGENTIAL- AVER&GED DEvI&TION ~ND ~ZIMUTH V:PTIC~L SECTION: HORIZ. DTST. P~OJECTED ONTO ~ T~RGFT ~IMUTH OF SOUTH 40 DEG 41 MIN WEST C~MPUTAT!qN DATE: 18-SEP-B8 STANDARD ALRSKA PPOgUCTION 2-68/S--17 MPI ENDICOTT NORTH SLOPE,~LASK~ CO. INTERPOLATED VALUES FOR EVEN 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEV DEPTH DEPTH DEPTH OEG COURSE VERTICAL DOGLEG IATION AZTMUTH SECrI3N SEVERITY MIN DEG MIN FEET 9EG/IO0 0.00 0.00 -54.50 100.00 100.00 45.50 200.00 200o00 145.50 300.00 300.00 245.50 400.00 400.00 .345.50 '500.00 500.00 44S.50 600.00 600.00 545.50 700.00 700.00 545.50 800.00 800.09 745.50 900.00 900.00 845.50 0 N 0 0 5 0.00 0.00 7 S 61 15 E -0.05 0.04 6 S 65 36 E -0.09 0.0~ ~ S 1'7 6 ~ -0.07 0.1~ 3 S 12 35 E 0.09 0.24 16 S '74 4~ ~ -0.03 0.23 12 S 25 30 c -0.05 0.35 B N ~ - . .. 14 S 38 6 E -0.19 0.47 B N ,~5 24 E -0.18 0.23 1000.00 999.99 945.49 0 14 1100.00 1099.99 1045.49 0 10 1200.00 1199.99 1145.49 0 14 1300.00 1299.99 1245.49 0 11 1400.00 1399.99 1345.49 0 1500.00 1499.99 1445.49 0 26 1600.00 1599.99 1545.49 0 20 1700.00 1699.98 1645.48 0 1800.00 1799.98 1745.48 0 18 1900.00 1899.98 1845.48 0 24 S 29 15 E -0.28 0.29 S 86 46 E -0.23 0.25 S 17 43 E -0.21 0.21 S 79 36 E -0.19 0.29 S 22 43 E -0.13 0.17 S 54 50 E -0.18 0.9~ S 73 45 .E -0.16 0.70 S 70 51 E -0.58 0.23 N 65 25 E -0.93 0.21 S ~7 13 E -1.42 0.11 2000.00 1999.9~ 2100.00 2099.98 2045.48 2200.00 2199.97 2145.47 2300.00 2299.97 224~.47 2400.00 2399.9r 2345.~,5 2500.00 2499.94 2445.~4 2600.00 2599.93 2545.43 2700.00 Z699.gz 2645.42 2~00.00 27'99.91 274S.-%1 2900.00 2899.99 2845.39 0 15 0 24 0 27 0 4q 0 58 0 47 0 50 0 53 0 57 1 9 N 87 57 E -1.82 0.61 N 59 55 E -Z.42 0.3'7 N 80 0 E -.3.17 0.30 N ~7 22 :. -3.95 0.54 N ~5 43 E -4.95 0.22 N 58 32 E -6.08 0.63 N 58 30 E -7.35 0.28 N 68 51 E -8.64 0.43 N 70 30 E -10.01 0.48 S 87 9 E -11.41 0.39 3000.00 2999.87 2945.37 3100.00 3099.85 3045.35 3200.00 3199.81 3145.31 3300.00 3299.75 3245.25 3400.00 3399.65 334~.15 3500.00 3499.55 34.45.05 3600.00 3599.45 ~¢4~. 95 3700.00 3699.40 ~644. }0 3800.00 3799.37 3744. 37 3900.00 3899.3'5 3~44. 35 20 44 23 33 40 '9 37 S 82 8 E -11.51 0.14 S 86 39 E -13.68 0.76 N .~1 27 E -15.62 0.64 N ~q 43 ~ -18.52 0.55 N 65 24 E -22.43 0.3~ N 53 47 m -26.64 0.90 N 66 ;3 2: -30.60 0.75 W 72 9 ~ -33.41 0.48 ~ q3 11 E -35.43 0.58 S 38 51 E -36.84 0.51 KELLY D~TE OF SURVEY: BUSHING ELEVATION: ENGINEER: PAGE 1 14-SEP-88 54.50 FT S. S ALAZ~R MEASURED DSPTH RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FEET ~EET 0.00 N 0.00 E 0.01 S 0.08 E 0.10 S 0.26 E 0.25 S 0.39 E 0.45 S 0.38 E 0.52 S 0.65 E o.n4 S 1.05 E 0.96 S 1.1,~ E 1.09 S 1.55 E 1.20 S 1.67 E 1.38 S 2.03 E 1.56 S 2.17 E 1.85 S 2.47 E 2.00 S 2.62 E 2.37 S 2.97 E 2.67 S 3.39 E 3.10 S 3.85 E 3.21 S 4.61 E 3.25 S 5.21 E 3.17 S 5.87 E 3.21 S 6.53 E 2.91 S 7.10 E 2.55 S 7.83 E 2.46 S 8.77 E 2.3'9 S 10.37 E 2.16 S 11.83 E 1.62 S 13.16 E 1.07 S 14.51 E 0.54 S 15.99 E 0.~7 S 17.93 E 0.59 S 19.88 E 0.86 S 21.98 E 0.67 S 24.73 E 0.23 N 28.14 E 1.92 N 32.17 E 3.90 N 36.33 E 5.75 N 40.24 E 6.88 N 43.24 E 7.48 N 45.65 E 7.5~ N 47.68 5 HORIZ.:DEPARTtJRE 91 ES,~,.,. AZIMUTH FE ,)~:, DEG MIN 0.00 "N"~"~ 0 0 E 0.08 S 86 25 E 0.28 S.~68 24 E 0.46 $~57 35 E O.59 $ 4O 18 E O.83 S 51 31 E 1.34 S 51 16 E 1.52 S 5O 48 E 1.~9 S 54 55 E 2.06 S 54 11 E 2.46 S 55 48 E 2.67 S 54 16 E 3.09 S 53 9 E 3.30 $ 52 40 E 3.80 S 51 19 E 4.31 S 51 45 E 4.95 S 51 7 E 5.62 S 55 12 E 6.14 S 58 I E 6.67 S 61 '35 E 7.28 S 63 %9 E 7.67 S 67 ~3 E 8.23 S 71 56 E 9.11 S ?4 20 E 10.64 S 77 1 E 12.03 S 79 39 E 13.26 S 82 58 E 14.55 S 85 45 E 16.00 S 88 3 E 17.9~ S 88 48 ~ 19.89 S 88 17 E 22.00 S 87 46 E 24.74 S 88 27 E 28.14 N 89 32 E 32.22 N 86 34 E 36.54 N 83 52 E 40.65 N 81 51 E 43.78 N 80 57 E 46.25 N 80 41 E 48.28 N 80 57 E STAND~RO ALASKA PPODUCTIDN 2-68/S- 17 MPI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 18-SED-B8 DATE OF SURVEY: KELLY BUSHING ELEVRTION: ENGINEER: PAGE Z 14-SEP-88 54.50 FT S. SALAZAR INTERPOLATED TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH OEPTH 4000.00 3999 3TM . 4100.00 4099.31 4200.00 4199.30 4300.00 q299.28 4400.00 ~399.27 4500.00 4499.27 4600.00 4599.25 4700.00 4699.2.5 4800.00 6799.2.5 4900.00 4899.29 5000.00 4998.80 SlO0.O0 5097.70 5200.00 5195.7.2 5300.00 5292.68 5400.00 5388.33 5500.00 5482.59 5600.00 5575.81 5700.00 5657.91 5800.00 5758.77 5900.00 5848.16 6000.00 5935.65 6100.00 6020.79 6200.00 6103.82 6300.00 5186.23 6400.00 6258.53 6500.00 5350.53 6600.00 5431.92 6700.00 6512 .cO 6900.00 6592.41 6900.00 6672.28 7000.00 5751.89 7100.00 6831.60 7200.00 6911.3~ 7300.00 6991 7400.00 7071.76 7500.00 7152.32 7600.00 7233.34 7700.00 7315.01 7800.00 7396.99 7900.00 7479.44 394 ~. 83 4044.?1 4144.80 4244.78 4344.77 4444.77 4544.76 4~44.76 4744.76 4344.70 V~LUES FOR EVEN 100 FEET OF ME&SUR:~ DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG ~IN VERTICAL SECTION FEET DOGLEG REC TA!qG',JLAR SEVERITY N,gR'TH/S gU TH DEG/10g r-EET CgORD!N~TES HORIZ. E~ST/WEST gIST. FEET FEET -38.0] -39.10 -39.95 -40.77 -41 0.44 7.49 N 1.OR 7.29 fi 0.24 7.0t ~ 0.27 6.71 N 0.43 6.53 N 49.5~ E 50.15 51.50 E 52.02 53.13 E 53.59 54.73 E 55.14 55.99 E 56.37 DEPARTUR~ AZIMUTH 'DEG MIN N 81 24 E N 81 5'7 E N 82 28 E N 83 0 E N,83 20 E 4944.30 5043.20 5141.22 5239.18 5333.~3 5428.09 5~21.31 5613,~1 5704.27 5793.6~ 6 40 S 37 24 10 i S 32 0 12 41 S 22 41 15 34 S 23 40 lB 16 S 30 13 20 26 S 33 35 22 0 S 28 32 23 47 S 29 6 ~5 38 S ~9 49 27 39 S 30 48 5881.16 30 20 5'966,29 32 54 6049,32 34 26 6131.73 34 33 6214.03 34 41 6296.05 35 !5 6377.42 35 49 6~5~.00 3~ 47 6537.91 37 0 6617.78 ~7 4 6697.39 37 14 6777.10 37 5 6356.38 36 52 6336.95 36 48 7017.2,6 36 27 7097.~2 36 2 717q.84 35 40 7260.51 35 4 7342.49 34 41 7424.94 34 !l S 31 39 S 32 Z S 32 3 S ~1 43 S 31 31 S 32 9 S 32 4r, S 3332 S 33 4! S 34 D S 34 26 S 34 32 S ~4 40 S 34 24 S ~4 lZ S 34 15 S 33 37 S 33 36 S 3334 S 33 22 -42.16 -42.82 -43.41 -43.89 -41.74 W -32.89 W -18.28 W 0.89 W 24.04 W 52.33 W 85.40 W 120.99 W 159.09 w 200.04 W 244.12 291.85 P143.69 398.79 454.76 510.95 567.37 $24.91 683,60 743.27 803..01 863.14 923.18 983.13 1042.69 1101.91 1160.79 1218.99 1276.24 1333.09 1389.22 0.34 6.45 Pi 0.68 6.4~ N 0.39 6.63 N 0.46 6.88 N 4.03 5.69 N 4,33 0.85 S 2,99 12,95 S 2,82 30.52 S 2.64 53.11 S 3,26 79,12 S 2,54 107.05 S 1.84 138.19 S 1.62 172.39 S 2,11 20~.75 S 2',46 247.41 S 2.71 238.74 S 2.22 333.31 S 0.32 380.53 S 0.31 428.61 S 0.16 477.00 S 0.96 525.64 S 0.80 574.66 S 0.81 624.24 S 0.29 674.27 S 0.49 724.27 S 0.82 774.29 S 0.83 824.05 S 0.42 873.66 S 0.26 922.99 S 0.36 972.23 S 1.05 1021.15 S 1.40 1069.81 S 0.25 1117.91 S 0.34 1165,59 S 0.62 1212.82 S 57.15 58.13 58.87 59,72 57.41 51,43 63,10 34,12 24.89 11.75 6.49 24.8.5 43,5Z 64.04 ~6.69 111.84 139.51 169.12 199.05 228.80 258.92 290.17 322.52 355.86 389.35 423.39 457.61 491,86 525.84 559,40 592.84 6Z5,51 657,38 689,12 720.28 50 ::~ N 38 E 59.24 ~N 83 34 E 59.71 N 83 ;~3 E 57.69 N 84 20 E 51,44 S 89 3 E 45,00 S 73 16 E 45,78 S 48 11 E 58,65 S 25 6 E 79.99 S 8 26 E 107.25 S 3 28 W 140,41 S 10 11 W 177.80 S 14 I0 W 218.35 S 17 3 W 262.15 S 19 18 W 309.64 S 21 10 W 361.33 S 22 42 W 416,42 S 23 57 W 472.57 S 24 54 W 529.03 S 25 37 W 585.95 S 26 13 W 643.76 S 26 47 W 702.63 S 27 19 W 762.41 S 27 49 W 822,28 S 28 15 W 882.49 S 28 40 W 942.58 S 29 2 W 1002.60 S 29 22 W 1062.27 S 29 40 W 1121.6g S 29 54 W 1180.76 S 30 8 W 1239.26 S 30 18 W 1296.87 S 30 27 W 1354.06 S 30 35 W 1410,58 S 30 42 W STANDARD ALASKA PRODUCTION CO. 2-68/S-17 MPI ENDICOTT NORTH SLOPE,ALASK ~, COMPUTATION D~TE~ 18-SEP-88 PAGE 3 D~,TE OF SURVEY: 14-SEP-88 KELLY EUSHING ELEVATION: 54.50 FT ENGINEER: S. SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG' M!N DEG MIN 8000.00 7562.35 7507.85 33!48 8100.00 7645.56 7591.06 33 35 8200.00 7729.02 7574.52 33 17 8300.00 7812-84 7758.34 32 44 8400.00 7897.33 784~.83 31 59 8500.00 7981.47 7927.~7 31 17 8600.00 8068.20 8913.70 30 37 8700.00 8154.57 8100.07 29 53 8800.00 8241.64 8197.14 29 1 8900.00 8329.39 8274.39 28 20 9000.00 8417.70 8363.20 27 42 9100.00 8506.18 8451.68 28 1 9200.00 8594.29 8539.79 28 22 9300.00 8682.15 8627.65 28 46 ,9400.00 8769.50 8715.00 29 29 9500.00 8856.56 8902.06 29 lO 9600.00 8944.21 8889.71 28 21 9700.00 9032.45 8977.96 27 47 9800.00 9121.26 9066.76 26 50 9900.00 9210.80 9156.30 26 17 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ'.:DEPARTURE SECTION SEVERITY NORTH/SOUTH ERST/WEST OISTo : AZIMUTH FEET OEG/IO0 =EET FEET FEET:: ~;,DEG MIN S 33 19 W !444.67 S 33 7 W 1499.64 S 33 22 W 1554.26 S 38 29 W 1608.52 S 43 41 W 1661.98 S '~3 40 W 1714.35 S 43 46 W 1765.76 S 43 57 W 1816.07 S 44 21 W 1865.17 S 44 20 W 1913.01 S 43 41 W 1959.88 S 43 51 W 2006.41 S 44 40 W 2053.60 S 45 44 W 2101.22 S 46 25 W 2149.67 S 47 7 W 2198.58 S 48 9 W 214&.37 S 49 ~ W 21;92.97 S 51 45 W 2338.28 S 53 49 W 2381.82 0.50 0.44 1.04 3.61 l .Iff 0.66 0.75 0.91 0.9 Z 0.55 0.49 0.65 0 .~3 0.79 0.73 0.55 0.99 1.05 1.88 1.23 1259.53 S 751.01 W 1466'43:: $::~30 48 W 1305.90 S 781.48 W 1521.83 $ 30 53 W 1352.08 S 811.46 W 1576.89~ ~$ 30 58 W 1396.55 S 842.97 W 1631,25 S 3I 6 W I436.52 S B78.49 W 1683.8~" 26 W 1474.34 S 914.83 W 17~5 ~I S ~1 49 W 1511.56 S 950.39 W 1785~5~ S~32 9 W ~54~.87 S 985.33 W 1834'8~.:' S3Z 28 W 1583.20 S I019.54 W ~883.08 S ~2 46 W 16IT.4Z 5 1053.14 w 1930.06 S ~3 4 W 10000.00 9300.69 9246.19 26 18 10100.00 9389.2! 9334.77 28 38 10200.00 9476.75 9422.25 29 10300.00 9563.96 9'509.46 29 39 10400.00 9650.90 9596.40 29 10500.00 9738.02 9683.62 29 1 10600.00 9825.72 9771.22 28 24 10700.00 9913.99 9'359.49 27 41 10800.00 10002.81 9949.~.1 27 Il 10900.00 10091.7~ 10037.24 27 14 S 55 31 W 2424.29 S 57 1,t W 2468.90 S 58 18 W 2515.28 S 59 52 W 2561.68 S 60 44 W 2608.18 S 61 16 W 2654.22 S 61 54 d 2699.11 S 62 30 W 2742.85 S 52 36 W 2785.49 S 52 30 W 2827.91 2.29 1.9~3 0.79 0.82 O. 5'7 0.77 0.82 0.73 O.O.q 0.16 llO00.O0 10180.69 10126.19 27 6 11100.00 10269.99 10215.49 26 19 llZO0.O0 10359.76 10305.26 25 37 11300.00 10450.00 10395.50 25 31 11360.00 10504.15 10449.65 25 31 S 62 Z W 2870.38 S 61 50 W 2912.37 S 61 31 W 2953.48 S 61 29 W 2993.75 S 51 29 W 3017.91 0.62 0.7~ I .77 0.00 0.00 1651.18 S 1085.76 W 1976.17 S 33 19 W 1684.89 S 1117.92 W 2022.02 S 33 33 W 1718.76 S 1150.90 W 2068.50 S 33 48 W 1752.43 S 1184.79 W 2115.36 S 34 3 W 1786.15 S 1219.89 W 2162.97 S 34 19 W 1819.84 S 1255.73 W 2211.03 S 34 36 W 1852.33 S 1291.24 W 2257.97 S 34 52 W 1883.45 S 1326.53 W 2303.71 S 35 9 W :1912.80 S 1361.88 W 2348.09 S 35 27 W 1939.70 S 1397.38 W 2390.63 S 35 46 W 1964.93 S 1433.19 W 2432.07 S 36 6 W 1990.45 S 1471.92 W 2475.57 S 36 28 W 2016.44 S 1512.84 W 2520.85 S 36 52 W 2041.55 S 1554.80 W 2566.19 S 37 17 W 2065.92 S 1597.78 W 2611.69 S 37 43 W 2089.76 S 1640.69 W 2656.86 S 38 8 W 2112.60 S 1682.97 W 2701.01 S 38 32 W 2134.54 S 1724.54 W 2744.14 S 38 56 W 2155.69 S 1765.34 W 2786.29 S 39 18 W 2176.76 S 1805.91 W 2828.35 S 39 40 W 2197.95 S 1846.40 W Z870.57 S 40 1 W 2219.21 S 1886.08 W 2912.42 S 40 21 W 2240.08 S 1924.85 W 2953.48 S 40 40 W 2260.64 S 1962.71 W 2993.7~ S 40 57 W 2272.98 S 1985.43 W 3018.01 S 4l 8 W STANDARD ~L~SKA PRODUCTTON 2-68/S--17 MPI ENDICOTT NORTH SLOPE,ALASKA CO. COMPUTATIgN DATE: 18-SEP-88 D~TE OF SURVEY.' KELLY BUSHING ELEVATION: ENGINEER: PAGE 4 !4-SEP-88 54.50 FT s. TR MEASURED VSRT DEPTH DE INTERPOLATED VALUES FOR UE SUB-SEA TCAL VERTIC&L PTH OEPTH O.O0 0 1000.00 999 ZO00.O0 1999 3000.00 2999 4000.00 )999 5000.00 4998 6000.00 5935 7000.00 5751 8000.00 7552 9000.00 8417 10000.00 9300 11000.00 101 80 11360.00 10504 COURSE DEVIATION AZIMUTH DEG MIN DEG .Oq -54.50 .99 945.49 .98 1945.48 .97 2945.37 .33 3944.93 .80 4344.30 .66 5~t.16 .89 6697.39 .3~ 7507.~ .70 8363.20 0 0 N 0 0 E 014 S 29 lS c 0 15 N 87 57 E I 8 S 32 '~ E 1 6 S 95 14 E 6 40 S 37 24 W 30 20 S ~1 39 W 37 14 S 34 26. W 33 48 S 33 Ic} W 27 42 S 43 41 W .69 9~46.19 .69 10126.19 .15 10449.55 26 lg S 55 39 W 27 6 S 62 ~ W 25 31 S 61 29 W EVEN 1000 FE VERTICAL DOG SECTION SEV FEET DEG -12. -38. -32. 291. 863. 1444. 1959. 2424. 2870. 3017. O0 82 O1 14 57 B8 29 38 91 E'T OF MEASURED DE°TH LEG R~CT~NGUL~R COORDINATES H ERITY NORTH/SSUTH EAST/WEST /100 ¢:EET FEET FE 0.00 C.O0 N 0.00 E 0 0.29 1.38 S 2.03 E 2 0 61 3 21 S 6 c3 E 7 0.14 0.59 S 19.89 E 19 0.44 7.49 N 49.59 E 50 4.33 0.85 S 51.43 _: 51 2.71 288.?4 S 111.84 W 309 0.~2 774.29 S 423.39 W 8B2 0.50 1259.53 S 751.01 W 1466 0.48 !651.18 S 1095.76 W 1976 2.29 1954.93 S 1433.19 W 2432 0.62 2197.95 S !846.40 W 2870 0.00 2272.98 S 1985.43 W 3018 ORIZ. DEPARTURE ST. AZIMUTH ET OEG MIN .07 S 36 6 W .57 S 40 I W .01 S 41 8 W STANDARD ALASKA PRODUCTION 2-68/S-17 MoI ENDICOTT NORTH S/OPE,ALASK~ CO. COMPUTATIDN D&TE: 18-SEP-88 KELLY DATE 5USHING OF SURVEY: ELEVATION: ENGINEER: PAGE 5 14-SEP-88 54.50 FT s. s ALJ~ZAi~ :' TNTERPOLATED VALUES FOR TRUE SUB-SEn COURSE qEASURED VERTICAL VEPT!C&L DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 0.00 O.OO -54.50 0 0 N 0 0 54.50 54.50 O.O0 0 7 N 34 154.50 154.50 100.00 0 7 S 254.50 254.59 200.00 0 6 S 3P 0 354.50 354.50 300.00 0 7 S 7 20 454.50 454.5') 400.00 0 10 S 554.50 554.50 'SOO.Q0 0 19 S 47 7 654.50 554.59 SOO.Q0 0 5 S ~4 754.50 754 . 50 TO0. OF) 0 16 S 75 F354.50 854.50 8.00.00 0 3 S 28 32 954.50 954.50 900.00 0 17 S 57 47 1054.51 1054.50 1300.90 0 6 S 27 55 1154.51 1154.50 1100.00 0 ~7 S .~9 39 1254.51 1254.50 1200.00 0 5 S 77 44 1354.51 1354.50 l~OO.O0 0 21 S 35 49 1454.51 1454.59 1400..90 0 17 S 65 21 1554.51 1554.50 1500.00 0 21 S 41 48 1654.51 1654.50 1~00.00 0 28 S 99 !8 1754.52 1754.50 170,9.90 0 18 S ~5 4~+ 1854.52 1854.50 l~OO.O0 0 25 N 8B 5~ 1954.52 1954.50 1300.00 0 24 S 97 24 2054.52 2054.50 2000.00 0 23 N A.O 20 2154.53 Z154.50 2100.00 0 30 N 51 11 2254.53 2254.50 2209.90 0 30 N ~3 2354.54 2354.50 2300.00 0 56 N 2454.55 2454.51] 240:3.00 0 48 N ~! 2 2554.56 2554.50 2500.00 0 59 N ~ 20 2654.57 2654.50 2600.00 0 2754.58 2754.59 2709.00 0 52 N 71 2854.60 2854.50 2'300. O0 1 2954.62 2954.50 2900.00 I 7 S 93 3054.64 3054.59 3000.00 1 11 S 82 0 3154.67 3154.50 3tOO.O0 1 39 N 84 24 3254.72 3254.50 3200.00 1 cq N 75 28 3354.80 3354.50 3300.00 2 32 N 66 46 3454.91 3454.50 ?4OD.g0 2 40 N 64 31 3555.01 3554.59 3~00.00 2 28 N 64 37 3655.08 3654.50 3500.90 ] ~5 N 70 19 3755.12 3754.50 3700.30 1 23 N 76 10 3855.14 3854.50 3900.90 ! 9 N 87 EVEN 100 VERTICAL SECTION FeET 0.00 -0.01 -0.07 -0.10 0.03 ,~.96 -0.09 0.00 -0.15 -0.12 -0.30 -0.18 -0.29 -0.13 -0.24 -0.11 -0.14 -0.39 -0.73 -1.!3 -1.66 -2.12 -2.83 -!.49 -4.44 -5.57 -6.78 -8.05 -9.38 -19.81 -12.03 -13.ll -14.63 -17.02 -20.62 -2,~ .70 -28.94 -32.26 -34.63 -3~.25 FEET OF SU~-SEA DEPTH DOGLEG RECTaNGULaR COORDINATES SEVERITY NORTH/SgUTH E~ST/WEST DEG/IO0 FEET FEET 0.00 0.00 N 0.00 0.89 0.01 N 0.00 0 0~ 0 06 S 0 13 . J . 0.07 0.17 S 0.34 0.16 0.3~ S 0.40 0.2~ 0.49 S 0.47 0.31 0.65 S 0.91 0.30 0.95 S 1.10 0.53 0.97 S 1.36 0.67 1.22 $ 1.60 0.62 1.22 S 1.88 1.01 1.55 S 2.0~ 0.32 1.~,6 S 2.37 0.37 1.99 S 2.51 0.4q 2.13 S 2.85 0.11 ~.55 S 3.13 0.3Z 2.95 S 3.65 0.30 3.13 S 4.23 0.8e 3.~2 S 4.98 0.~4 3.1~ s 5.54 0.33 3.19 S 6.25 E 0.26 3.06 S 6.82 E 0.19 2.69 S 7.47 0.52 2.50 S 8.25 E 0.14 2.43 S 9.63 0.29 2-30 S ll.22 E 0.20 1.86 S 12.56 E 0.29 1.33 S 13.89 E 0.55 0.79 S 15.31 0.21 0.36 $ 17.00 0.25 0.4~ S 19.00 E 0.43 0.75 S 20.9.q E 0.49 0.82 S 23.40 E 1.02 0.32 S 26.48 : 0.63 1.10 N 30.34 ~' 0.46 2.98 N 34.43 E 0.36 4.99 N 38.59 E 0.44 6.45 N ~1.97 E 0.53 7.29 N 44.65 E 0.28 7.58 N 46.80 E HORIZ. DEPARTURE DIST. AZIMUTH FEET DEG MIN 0.00 N 0 0 E 0.01' N 21 2 E 0.19 S 70 52 E 0.38 S 64 13 E 0.55 S 46 15 E 0.67 S 44 2 E 1.12 S 54 3 E 1.45 $ 49 7 E 1.67 S 54 37 E 2.01 S 52 ~7 E 2.24 S 56 53 E 2.60 S 53 15 E 2.89 S 55 0 E 3.20 S 51 37 E 3.56 S 53 9 E 4.04 S 50 53 E 4.70 S 51 2 E 5.26 S 53 3! E 5.99 S 55 18 E 6.38 S 60 23 E 7.02 S 62 57 E 7.47 S 65 48 E 7.93 S 70 11 E 8.6Z S 73 9 E 9.93 S 75 50 E 11.46 S 78 24 E 12.69 S 81 35 E 13.95 S 84 32 E 15.33 S 87 3 E 17.01 S 88 46 E 19.01 S 88 33 E 20.99 S 87 56 E 23.42 S 87 59 E 26.48 S 89 18 E 30.36 N 87 54 E 34.56 N 85 3 E 38.91 N 82 38 E 42.46 N 81 15 E 45.24 N 80 43 E 47.41 N 80 48 E STANDARD ALASKA P~O~UCTIoN 2-68/S--17 MPI ENDICOTT NORTH SLOPE,ALASK~ CO. COMPUTATION D~TE: 18-55P-88 KELLY PAGE 6 D~TE OF SURVEY: 14-SEP-88 RUSHING ELFVATION: 54.50 FT ENGINEER: S. SALAZA~ T MEASURED VER DEPTH D 3955.16 39 4055.18 40 4155.20 41 4255.21 42 4355.22 63 4455.23 ~4 4555.24 45 4655.24 46 4?55.24 ~7 4855.24 48 4955.46 4.9 5056.21 50 5157.84 51 5260.47 52 5364. ~,7 53 5470.06 54 5577.06 55 5685.38 56 5795.27 57 5901.18 58 6021.91 59 6140.37 60 6261.49 51 6382.94 62 6504.84 63 6527.89 54 6752.54 65 6877.?3 56 7003.27 67 7128.77 58 7253.82 59 7378.52 70 7502.69 71 7625.99 72 7748.25 73 7869.82 74 7990.56 75 8110.72 76 P, 230.46 77 8349.~,2 78 T .,..N, ERPOLATEO VALUES FOR RUE SU~-SE~ TICAL VERTICAL FPTH :O~PTH 54.50 3900.00 54.50 4000.00 54.50 41,00.00 54.50 4200.00 54.50 4300.00 54.50 4400.00 54.50 4'500.00 54....'~O 4609. O0 54.50 4700.00 54.50 4~00.00 54.50 4900.00 54.50 5000.00 54.50 5100.00 54.50 5200.90 54.50 5300.00 54.50 5400.00 54.50 ~, 500.00 54.50 5600.00 54.50 5709.00 54 -50 5809.00 54.50 5 90 O. O0 54.50 6000.00 54.50 6100.00 54.50 6200.90 54.50 6300.00 54.50 6400.00 54.50 6~00.00 54.50 6500. O0 54.50 6700.00 54.50 St'JO0. O0 5~.59 6900.00 54.50 7900.00 54.50 7100.00 54.50 7200.90 54.50 7300.30 54.50 7400.00 54.5C 7500.00 54.50 7500.J0 54 .50 7700.90 54.50 7803.00 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 1 3 S 86 13 E 1 5 S .9326 0 56 S 79 48 1 0 S 79 3~ 045 S ~5 27 E 0 40 S 85 40 0 3Z N 37 25 0 26 N 77 42 0 16 N 61. 50 122 S 58 5I W 5 16 S 41 35 W 8 39 S 34 3! W 11 37 S 26 25 W 14 26 S 22 21 W 17 22 S 27 46 W 19 57 S 34 3 W 21 39 S 29 12 W 23 32 S 28 59 W 25 32 S 29 46 W 27 49 S 30 5] W 30 94 S 31 43 W 33 44 S 32 5 ~ 34 2'9 S 31 52 W 34 39 S 31 31 W 35 17 S ~2 12 W 36 ~ S 32 5~ W 36 5~ S 33 41 W 37 0 S 33 5 4 W 37 ]4 S 34 2,,6 W 37 6 S ~4 34 W 36 46 36 27 36 1 35 25 34 58 34 21 33 5! 33 3] 33 9 32 1,9 S 34 33 ~ S 34 12 W S 34 1~ W S 33 32 w S 33 39 W S-~3 22 w S 33 19 W S 33 .5 W S 3& 17 W S 41 33 W EVEN 100 VERTICAL SECTION FEET -37.49 -38.62 -39.58 -41.1.8 -41.34 -42.52 -43.16 -43.~9 -4 3.63 -37.46 -25.35 -7.60 14.30 41.69 75.11 112.68 153.37 198.04 247.44 302.91 365.65 433.20 501.27 570.13 541.11 714.94 789.T0 865.10 940.50 1015.16 1089.Zl 1162.36 1233.96 1303.76 1372.36 1439.46 1505.52 1570.83 1635.99 ~EET O= SUS-SE~ OEPTH OOGL SEVE OEG/ EG RECTAqGULAR Cr]Oq 'RITY NORTH/SOUTH EAST 100 mEET FEE 0.59 7'.54 N 48. 0.34 7.39 N 50. 0.3t 7.13 N 52. 0.27 6.85 N 54. O.gl 6.6~ N 55. 0.07 6.48 N 56. 0.57 6.45 ,,l 57. 0.29 6.55 ,q 58. 0.13 6.77 q 59. 5.66 6.75 M 59. .05 2.70 N 54. .51 6.99 S 47. .41 22.46 S 37. .23 ~,3.69 S 28. .38 69.62 S 17. .23 98.53 S O. .04 130.75 S 20. .67 167.28 S ~0. .09 206.98 S 63. .45 250.30 S 88. DINATES HORIZ. DEPARTURE /WEST DIST- AZIMUTH T FEET BEG MIN 74 E 49.32 N 81 12 E 65 ~ 51.18 N 81 42 E 41 ~ 52.89 N 82 14 E 05 E 54.48 N 82 46 E 46 E 55.86 N 83 11 E 64 E 57.01 N 83 28 E 72 E 58.08 H 83 37 E 57 E 58.94 N 83 37 E 15 E 59.54 N 83 28 E 05 E 59.44 N 83 28 E 32 E 54.38 N 87 9 E 02 E 47.53 S 8I 32 E 78 E 43.95 S 59 15 E 8~J E 52.37 S 33 27 E 02 E 71.67 S 13 44 E 61 W 98.53 S 0 21 W 77 W 132.39 S 9 1 W 69 W 172.15 S 13 40 W 04 W 216.37 S 16 56 W 42 W 265.46 S 19 27 W 2.47 298.26 S 117.73 1.87 352.12 S 151.32 0.42 410.05 S 187.55 0.19 468.73 S 223.73 0.95 528.00 S 260.41 0.97 588.41 S 299.02 0.08 650.5'1 S 340.03 0.32 713.14 S 381.85 0.81 775.91 S 424.51 0.77 838.39 S 467.49 0.55 900.15 S 510. 0.35 961.66 S 552. 1.01 1022.45 S 593. 1.05 1082.3~ S 633. 0.69 1140.99 S 672. 0.46 1198.63 S 710. 0.50 1255.14 S 748. 0.43 1310.86 S 7~4. 2.41 1366.00 S ~20. 3.2~ !416.83 S 8~0. W 320.66 S 21 32 W W 383.26 S 23 15 W W 450.91 S 24 34 W W 519.38 S 25 30 W W 588.72 S 26 15 W W 660.03 S 26 56 W W 734.02 S 27 35 W W 808.95 S 28 10 W W 8~4.45 S 28 41 W W 959.92 S 29 8 W l~l W 1034.68 S 29 32 W 24 W 110~.94 S 29 52 W 7Z W 1182.34 S 30 8 W 84 W 1254.31 S 30 21 W 75 W 1324.55 S 30 31 W 93 W 1393.60 S 30 40 W 12 W 1461.19 S 30 47 W 64 W 1527.75 S 30 54 W 69 W 1593.57 S 30 59 W 13 W 1657.48 S 31 15 W COM~UTATIgN STANDARD ~LASKA PRDDUCTZON 2-68/S-17 MPI ENDICOTT NORTH SLOPE,ALASK~ CO. I~TERPOLATEO VALUES FOR T MEASURED VER DEPTH O RUE SUB-SEA TICAL VERTICAL EPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG 8467.24 ?954.50 7900.00 8584.06 8054.50 8000.90 8699.92 8154.50 8100.00 8814.70 R254.50 8200.00 8928.51 835&.50 8300.00 9041.55 8454.59 ~400.90 9154.79 ~554.50 8509.00 9268.48 8654.50 9600.00 9382.77 8754.50 8700.00 9497.54 ~854.50 8RO0.O0 31 31 S 43 47 W 30 44 S 43 44 W 29 54 S 43 57 W 28 53 S 44 25 W 28 B S 44 10 W 27 42 S 43 36 W 28 14 S 44 17 W 28 36 S 45 22 W 29 22 S 46 19 W 29 11 S 47 6 W 9611.68 ~9 9724.90 90 9837.17' 91 9948.61 92 10060.49 93 10174.55 .94 10289.13 95 10404.15 96 10518.B2 97 I0632.68 98 ~4.50 ~ ~00. gO 54.50 9000.00 54.50 9'100. O0 54.50 9100.00 54.50 9300.90 54.50 9,400.00 54.50 9500.00 54.59 9600.90 54.50 9700.,90 54.50 9300.00 2B 16 S 48 16 W 27 35 S 49 3B W 26 30 S 52 37 W 25 48 S 54 54 W 2P 6 S 56 49 W 29 3 S 57 48 W 29 2~ S 59 42 W 29 37 S 60 45 W Z~ 54 S 61 2~+ W 2B 9 S 62 4 W 10745.58 99 10858.11 100 109'70.56 101 11082.72 102 11194.16 103 11360.00 105 54.50 9900.00 27 22 S 62 37 W 54.50 lOOOO.O0 2.7 1Z S 62 32 W 54.50 lnlO0.O0 27 9 S 62 17 W 54.50 10200.00 26 25 S 61 50 W 54.50 1030D.00 25 43 S 61 33 W 04.15 10449.65 25 ll S 61 29 W gATE: 18-SEP-88 EVEN 100 FEET VERTIC SECTI FEE AL DOGLEG SEVERITY T OEG/IO0 31 0.83 63 0. 04 0.91 27 0.74 49 0.91 12 0.56 21 0.4~ 13 0.7 ) 22 O.~S 44 0.49 1697. 1757. lq16. 1~72. 1926. 1979. 2032. 2086. 2141. 2197. 2251. 2304. 2354. 2402. 2450. 2503. 2556. 2510. 2662. 2713. 86 0.85 43 I. 4! 60 O.4O 51 1.74 90 ,2.31 48 1.06 62 O. 8.3 11 0.63 74 0.71 54 0'. 7'9 2762. 2.910. 2857. 2905. 2951. 3017. 44 0.75 12 0.19 87 0.31 22 0.95 12 2.33 91 O.OO DATE OF SURVEY: KELLY BUSHING ELEVATION: SUD- SE.~ DEPTH ENGINEER: .. P~GE 7 14-SEP-88 54.50 FT S. SALAZ&R !144.25 S 1743.30 W 2763.49 S 39 6 W 2167.91 S 1738.91. W 2810.70 S 39 31 W 2101.67 S 1834.51 W 2858.12 S 39 55 W 2215.59 S 1879.32 W 2905.29 S 40 18 W 2238.8~ S 1922.64 W 2951.12 S 40 39 W 2272.98 S 1985.43 W 3018.01 S 41 8 W 18~6.0! S 1295.37 W 2253.35 S 34 54 W 1891.00 S 1335.32 W 2314.94 S 35 13 W 1922.99 S 1375.06 W 2364.04 S 35 34 W 1952.14 S 1414,66 W 2410.83 S 35 55 W 19~0.26 S 1456.16 W 245B.01 S )6 19 W ?009.90 S 1502.34 W 2509.33 S 36 46 W 2038.85 S 1550.1B W 2561.25 S 37 14 W 2066.93 S 1599.57 W 2613.59 S 37 44 W 2094.11 S 1648.69 W 2665.23 S 38 12 W 2119.87 S 1696.64 W 2715.22 S 38 40 W RECTANGULAR COORDINATES HORIZ. DEPARTURE NSRTHISDUTH EAST/WEST OIST. AZIMUTH FEET CEET FEET DEG MIN 1462.00 S 993.04 W 1718.41 $ ~1 42 W '1505.6~ S 944.76 W 1777.54 $ 32 6 W 1547.~5 S 9:~5.70 W 1834.84 S 32 28 W 15~8.29 S 1024.52 W 1890.05 $ B2 49 W 16!7.0~ S 1052.56 W 1943.31 S 33 8 W 1665.13 S 1099.05 W 1995.14 $ 33 25 W 1703.46 S 113F.89 W Z047.45 S 33 41W 17~1.83 S 1173.97 W 2100.52 S 33 5B W 17~0.29 S 12!3.74 W 2154.67 S 34 IT W 1819.06 S 1254.89 W 2209.91 S 34 36 W STANDARD ALASKA PRODUCTION CO. 2-6B/S-17 MPI ENDICOTT NORTH SLOPE,ALASK~ MARKER DRILLERS OEPTH COMPUTATION DATE: 18-SEP-88 · . PAGE 8 DaTE OF SURVEY: 14-SEP-BB KELLY BUSHING ELEV&TION: 54.50 FT ENGINEER: S. SAL AZ~'R INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASUREO DEPTH BELOW KB FROM KB 10504.15 11360.00 SURFACE LOCATION AT ' ; ORIGIN: 2137 SNL, Z366 WEL, SEC 36 TVD SUB-SEA 10449.65 , R16E RECTANGULAR :NATES NORTH/SOUTH :,AS~YWE ST 2z,z.,o s w · COMPUTATION DATE: STANDARD ~LASKA PDODUC~TION CO. 2-68/S-17 MPI ENDICOTT NORTH SLOPE,ALASKA ~*~*~*~*~* STR~TIGRAPHIC 18-SE~-88 SUMM~RY KELLY MARKER DRILLERS 'gE PTH FINAL WELL L~C.~TION AT TO: T~IJ~ SUB-SEA MEASUREO VFPTICAL VERTICAL DEPTH D~'PTH DEPTH MEASUREO 9EmTH ~ELOW KB 113~0.00 11350.00 10504.15 113449.65 FROM KB 1050~.'1.5 8R[GIN: 2137 SNL, TVD SUS-SE-A HgR'[ZONTAL D=PARTU~F 9IST~NCE ~ZIMUTH FEET DEG 3018.91 S 41 flg DATE OF SURVEY: ~USHTNG ELEVATION: ENGINEER: PAGE 9 I4-SEP-88 5~.50 FT S. SAL~ZA~ SURF&CE LOCATION 2366 W6L, SEC 36~ TlZN, R16E RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2272.98 S 1985.43 W SCHLUMBERGER O ~ RECT I ONAL SURVEY COMPANY STANDARD ALASKA PRODUCTION WELL 2-68 S-iT MP! 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H.-:.-i..-. -..HH:...L..-.~...HH! ...... ~..+--H:...HHHH: ....... :...:...~...:..4-.:...~..~-~......H:..4...~...~-H~.4...H..4.4..4...~......H~.4.4 ...... ~.4.4.4..:...~...~...~...~...;...~.4-..~.4..~.4...L.:.4 ....... i.4..4...i ....... i....:...L.i .... · 'H":-"~ ....... t":'"H ...... :'":'":"H't't":'"t:":'-'::"~nht-'t-':-'t-'-'H'-%-'"t-H"-: ....... H.H-t't-H,-: ...... H--H-'ffH--H ....... ~...H...:...t.l~...f..t..: ....... H'"H'",'"H"f-': .... 221. II PROJECTION ON VERTICRL PLRNE 221. - 41. SCALEO IN VERTICAL DEPTHS HORIZ SCRLE = 1/1000 IN/FT GREAT LAND DIRECTIONAl. DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY C: 0 f"l !::' A N Y AI..888-D29 SINGLE SHOT & ~IWD SURVEYS 9/12/88 ,l(IP, NLII'ql;:',FR TYi::'F S[.iF;.:VF:;Y DA"I'I!:' DIRECTIONAL ~O~ P..RIAN WEST SUPERVISOR ................ o .......... , .............. o .......................... . ........................ . ............................ . ................................................ ~., hi A i~'1 liil "f' I 'T' !.,. t::~ '.:...R 'r. (~ N A '1" LI t;.'. E 490 FT 10295 FT D E F' T I..I ] N T F R U A I.. F R (.~1~i T 8-21-88 ?-04-88 r) A'I" F: .'..~ I.J !:;: V I:: Y T/'''':'' F' R El t'l ...... .~,',,.:. N T C) THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELl,. WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALI. COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALt.. SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING,INC Client .............. : STANDARD ALASKA PRODUCTION CO. Well ................ : ENDICOTT MPI N 2-88/S-17 Closure Direction...: S 40.98 W Mognettc De¢ltnotion- 31 deg 5 mtn E Doto file nome ...... : B:MS17D.DAT RECORD OF SURVEY IWel] ossumed verti¢o] to 9/12/88 Computotton: RADIUS OF CURVATURE Survey dote: 8/23/88 Method ..... : SINGLE SHOT & MWD RKB Height.: 54.S ft 0.0! MEAS DRIFT TRUVERT SUBSEA SECTION ( )EPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 0 490 950 1479 1953 0 0 0.00 -54.50 0 0 490.00 435.50 0 0 950.00 895.50 0 25 1479.00 1424.S0 0 30 1~52.~U 18~U.48 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E -1.41 N 84.00 E .... 4.P7 N 80.00 E 2489 2745 3042 3318 3515 0 45 2488.95 2434.45 0 42 2744.93 2890.43 0 $4 3041.90 2987.40 2 42 33]7.75 32~3.25 a 42 3514.53 3480.03 -9.44 N 56.00 E -12.34 N 77.00 E -15.42 N 89.00 E -22.87 N 57.00 E -31.57 N 58.00 E 3704 3990 4170 4381 4551 1 36 3703.40 3648.90 1 12 3989.31 3934.81 0 48 4189.28 411~.78 0 48 4380.2~ 4305.7~ 0 24 4550.25 4495.75 -38.1;+ N 88.00 E -44.87 N 0.00 E -47.15 S 85.00 E -49.34 N 78.00 E -51.12 N 58.00 E 4775 0 18 4774.25 4719.75 4984 S 38 4982.93 4908.43 S18a 11 42 5158.59 5104.09 5353 17 0 S343.S~ 5289.08 SSOS 20 30 S487.47 S432.97 -52.24 N 28.00 -47.51 S 40.00 -18.11 S 28.00 27.71 S 27.00 75.78 S 35.00 5743 24 42 5707.15 5652.65 5933 28 36 5878.93 S822.43 8099 33 18 8019.25 598~.75 8310 34 30 8194.38 8139.88 8504 35 38 ~353.20 8298.70 186.06 S 29.00 249.71 S 31.00 333.89 S 32.00 450.28 S 33.00 S80.81 S 33.00 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.20 N 1.91E 0.73 N G.67 E 2.90 N 11.05 E 4.19 N 14.00 E 4.69 N 18.1] E 7.19 N 2..6.29 E 12.18 N 34.1Fd E 15.39 N 40.43 E 20.85 N 44.11E 22.74 N 48.17 E 22.95 N 48.82 E 23.72 N 50.64 E 24.92 N 50.96 E 25.79 N 42.76 E 0.89 N 26.59 E 41.46 S 5.48 E 83.30 S 19.86 W 180.81S 68.10 W 234.80 S 110.70 W 307.37 S 155.29 W 406.62 S 218.52 W 500.06 S 279.20 W CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 0.00 N 0 0 0 E 0.00 N 0 0 0 E 1.92 N 84 0 0 E 5.71 N 8ie hO 221 E 11.42 N 75 18 43 E 14.82 N 73 21 4 E 18.71 N 75 28 34 E 27.26 N 74 41 S7 E 36.23 N 70 21 19 E 43.28 N 89 9 17 E 48.79 N 64 41 S3 E S1.47 N 63 46 42 E 53.94 N 64 49 19 E 55.92 N 64 53 57 E 58.73 N 63 56 19 E 49.93 N 58 54 31E 26.61 N 88 S 32 E 41.82 S 7 31 25 E 85.59 S 13 16 53 W 174.84 S 22 57 2 W 259.41 S 25 1S 39 W 344.37 S 26 48 1S W 461.82 S 28 15 14 W 572.72 S a9 10 34 W DOG LEG deg/lO0 0.000 0.000 0.000 0.079 0.018 0.047 0.020 0.067 0.653 0.001 O. 582 O. 140 O. 222 O. 002 0.211 0.045 2. 860 3. 094 2. 775 2. 391 1.819 ~. 067 2. 837 O. 589 O. 567 ENDICOTT MPI ~ 2-68/S-17 9/12188 RECORD OF SURVEY NEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG NN DEPTH DEPTH DIST 669h 37 0 650~.32 6451.82 672.13 S 34.00 W S93.85 S 6878 37 0 6653.27 6E'98.77 782.05 S 3~.00 W 685.66 S 7076 37 12 6811.19 6756.69 900.72 S 35.00 W 784.08 S 7260 36 54 6958.04 6903.54 1010.98 S 35.00 W 874.90 S 7449 36 24 7109.68 7055.18 1123.28 S 36.00 W 966.74 S DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 341.28 W 403.20 W 470.85 W S34.44 W S99.95 W 7635 35 24 7260.34 7205.84 1231.74 S 34.00 W 1056.08 S 7830 34 30 7420.17 7365.67 1342.73 S 35.00 W 1148.14 S 8021 33 48 7578.24 7523.74 1449.37 S 35.00 W 1235.97 S 8291 32 S4 7803.78 7749.28 1597.48 S 40.00 W 1353.69 S 8479 31 24 7962.94 7908.44 1697.48 S 44.00 W 1428.02 S 662.51W 725.78 W 787.28 W 877.61W 944.53 W 8676 30 0 8132.33 8077.83 1797.87 S 45.00 W 1499.75 S 1015.02 W 8864 28 24 8296.43 8241.93 1889.36 S 45.00 W 1564.60 S 1079.88 W 9044 27 54 8455.14 8400.64 1974.07 S 45.00 W 1624.65 S 1139.92 W 9232 28 36 8620.75 8566.25 2062.71 S 47.00 W 1~86.46 S 1203.93 W 9421 29 36 8785.89 8731.39 2154.12 S 47.00 W 1749.15 S 1271.15 W 9610 28 12 8951.35 8896.85 2244.86 S 48.00 W 1810.85 S 1338.49 W 9801 26 36 9120.91 9066.41 2331.52 S 53.00 W 1866.74 S 1406.29 W 9987 26 48 9287.08 9232.58 2412.59 S 57.00 W 1914.67 S 1474.74 W 10295 29 36 9558.50 9504.00 2550.95 S 61.00 W 1989.61 S 1599.46 W CLOSURE DISTANCE DG MN S 684.93 S 29 53 8 W 7~b.h2 S 30 27 28 W 914.60 S 30 59 7 W 1025.22 S 31 25 9 W 1137.78 S 31 49 24 W 1246.68 S 32 6 4 W 1358.30 S 32 17 S4 W 1613.28 S 32 57 20 W 1712.12 S 33 28 54 W 1810.95 S 34 S 24 W 1901.08 S 34 36 47 W 1984.67 S 35 3 18 W 2072.]0 S 35 31 20 W 2162.26 S 36 0 25 W 2251.83 S 36 28 12 W 2337.18 S 36 S9 32 W 2416.78 S 37 36 17 W 2552.81 S 38 47 46 W DOG LFG deg/lO0 0.761 0.000 0.210 0.163 0.324 O. 647 0.490 O. 366 O. 640 O. 985 O. 722 0.851 O. 278 0 O. 529 0.750 O. 989 0.450 O. 963 ENDICOTT MPI ~ 2-68/S-17 DATA INTERPOLATED FOR EVEN lO0 FEET OF SUBSEA DEPTH P/12t88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT SS SS 0 0 0 1SS 1SS lO0 0 0 255 255 200 0 0 355 355 300 0 0 455 455 400 0 0 SSS SSS SOO 0 0 6SS 855 600 0 0 755 755 700 0 0 855 855 800 0 0 955 955 900 0 0 10SS 10SS 1000 0 0 llSS llSS 1100 0 0 1255 1255 1200 0 0 1355 1355 1300 0 0 1455 1455 1400 0 0 1SSS 1SSS 1SO0 0 0 16SS 1855 1600 0 0 17SS i?SS 1700 0 0 1855 1855 1800 0 0 1955 1955 1900 0 0 2055 2055 2000 0 0 2155 2155 2100 0 0 2255 2255 2200 0 0 2355 2355 2300 0 0 2455 2455 2400 0 0 2555 2555 2500 0 0 2655 2655 2600 0 0 2755 2755 2700 0 0 2855 2855 2800 0 0 2955 2955 2900 0 0 RELATIVE COORDINATES FROM WELL-HEAD 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0~00 F 0.00 N 0.00 E 0.00 N 0.00 W 0.07 N 0.02 W 0.24 N 0.1S W 0.42 N 0.48 W 0.49 N 1.01 W 0.30 N 1.72 W 0.26 N 2.47 E 0.36 N 3.23 E 0.47 N 4.02 E 0.59 N 4.83 E 0.73 N 5.88 E 0.93 N 8.57 E 1.21 N 7.53 E 1.59 N 8.53 E 2.08 N 9.58 E 2.87 N 10.67 E 3.41 N 11.73 E 4.28 N 12.85 E 4.21 N 14.12 E 4.56 N 15.36 E S.O~ N 16.69 E ENDICOTT MPI ~ 2-68/S-17 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH .g/12/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3055 3055 3000 0 0 3155 3155 3100 0 0 3255 3255 3200 0 0 3355 3355 3300 0 0 3455 3455 3400 0 0 3SSS 3SSS 3500 0 0 3855 3655 3500 0 0 3755 3755 3700 0 0 3855 3855 3800 0 0 3955 3955 3900 0 0 4055 4055 4000 0 0 4155 4155 4]00 0 0 4255 4255 4200 0 0 4355 4355 4300 0 0 4455 4455 4400 0 0 4555 4555 4500 4655 4655 4600 4755 4755 4700 4855 4855 4800 4956 4955 4900 5057 SOSS SO00 2 1 5158 S1SS SlO0 3 1 S261 5255 S200 6 3 5365 5355 5300 10 4 5470 5455 5400 1S S 5578 SSSS SSO0 23 8 5686 5655 5600 31 8 5796 5755 5700 41 5908 5855 5800 53 12 6023 5955 5900 RELATIVE COORDINATES FROM WELL-HEAD 4.70 N 'i8.32 E S.02 N 20.58 E 8.05 N 23.82 E 8.14 N 27.75 E 10.74 N 31.68 E 13.16 N 35.63 E ]R.4S N 38.67 E 16.05 N 41.66 E 17.B~ N 43.40 E 20.09 N 44.11 E 22.06 N 43.74 E 22.78 N 42.28 E 22.73 N 47.36 E 22.93 N 48.74 E 23.31N 49.91E 23.74 N 50.67 E 24.25 N 51.06 E 24.83 N 51.02 E 26.13 N 49.44 E 26.06 N 43.37 E 16.71 N 35.99 E 1.62 N 26.98 E 19.29 S 16.86 E 44.50 S 3.95 E 75.16 S 5~.47 W 104.99 S 34.34 W 140.55 S 56.44 W 180.63 S 78.96 W 225.44 S 102.65 W 273.34 S 133.73 W ENDICOIT MPI ff 2-68/S-17 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH P/12/88 MEAS. DEPTH 6141 6262 6383 6506 6630 6754 6880 7005 7130 7256 7380 7504 7628 7750 7871 7992 8112 8232 8351 8~69 8585 8701 8816 8930 9043 9157 9271 9385 9499 9614 TRU VERT DEPTH 6055 6155 6255 6355 6455 6SSS 6655 6755 6855 6955 70GS 7155 7255 7355 7455 7555 7655 7755 7855 7955 8055 8155 8255 8355 8455 8SSS 8655 8755 8855 8955 SU[] SEA M[)-TVD VERTICAL DEPTH DIFF. CORRECT 6000 86 18 6100 107 21 6200 128 21 6300 151 23 6400 175 24 6500 199 24 6600 225 26 6700 250 25 6800 275 25 6900 301 26 7000 325 7100 349 24 7200 373 24 7300 395 22 7400 416 21 7500 437 21 7600 457 20 7700 477 20 7800 496 19 7900 S14 18 8000 S30 16 8100 S46 16 8200 S61 1S 8300 575 14 8400 S88 13 8500 602 14 8600 616 14 8700 630 14 8800 644 14 8900 659 15 RELATIVE COORDINATES FROM WELL-HEAD 327.23 S 384.49 S 441.69 S 500.85 S S62.35 S 167.65 W 202.76 W 241.30 W 279.71 W 319.14 W 623.95 S 749.31 S 810.93 S 872.71 S 361.58 403.72 445.62 532.91 934.04 S 993.31S 1052.61S 1111.08 S 1167.35 S 575.36 W 619. OS W 660.17 W 699.19 W 739.23 W 1222.88 S 1277.83 S 1333.44 S 1378.69 S 1428.30 S 778.11W 815.67 W 850.69 W 898.11W 936.12 W 1467.67 S 1508.70 S 1548.34 S 1586.69 S 1624.41S 982.47 1023.97 1063.61 1101.96 1139.68 1662.62 S 1699.11S 1737.08 S 1775.41S 1811.98 S 1177.11W 1217.S0 W 1258.21W 1299.12 W 1339.74 W ENDICOTT MPI ~ 2-68/S-17 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 9/12/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 9726 10177 102~0 9055 9000 671 12 91S5 9100 68~ 13 925S 9200 696 12 93SS 9300 70~ 13 ~SS 9~00 722 13 9555 ~SO0 735 13 RELATIVE COORDINATES FROM WELL-HEAD 18~8.06 S 1876. ~8 S 1908.63 S 1933.94 S 196~+. 29 S 1377.67 W 1~19.68 W lq58.75 W 1503.85 W 15q7.6~ W 1996.78 S 1592.1~ W ENDICOTT MPI ~ 2-68/S-17 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 9/12/88 MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 1000 1000 945 0.02 N 0.00 W 2000 2000 1945 0.81 N 6.08 E 3000 3000 2945 5.28 N 17.32 E ~000 3999 394~ 21.06 N ~A.IO E SO00 4999 ~9~ 22.78 N 40.35 E 6000 5935 S880 262.98 S 127.62 W 7000 6751 6696 7q6.83 S ~43.99 W 8000 7561 7506 1226.39 S 780.57 W 9000 8~16 8361 1610.06 S 1125.3~ W 10000 g299 92~ 1917.88 S 1~79.66 W ~488 V VERTICAL SE~'~ION STANDARD ALASKA PRODUCTTON CO, ENDICOTT NPI # 2-68/S-t7 SECTION AT S 40.98 14 TVD SCALE: I inch = t200 feet OEP SCALE: ~ 1rich = t200 feet: I.DRANN : 9/52188 F -SOO Departure 5460 6000 B600 ~ DEPRT 0 0 9558 2551 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION ENDICOTT MPI # 2-88/S-t7 iCLOSURE: 2553 ft S 38.8 N DECLINATION: 3~.08 ~eg E SCALE: t i~ch: 580 feet iDRAWN: 9/t2/88 o iOoO 2080 2000 2'150 WEI',L LOG INVENTORY NAME : PAGE LOG CDM (mudlog) LOG COUNT DATE REC DIL/SFL (dual induction log) CNFD (compensated neutron density) (comp-sated neutron formation/ litho-density) : CFD (compensated formation density) BHC/SL (borehole compensated sonic) of RUN# LSS (long spaced sonic) SSS (short spaced sonic) CYB (cyberlook) ML (microlog) RFT (repeat formation tester) GCT (groscopic survey), SNP (sidewall neutron porosity) NAME: Well LeK Inventory PAGE of LOG SC (sidewall core) PR (perf record) FMS (formation test) LOG COUNT DATE REC RUN# · SHDT (high res dipmeter) CBL (cement bond log) _. OTHER~-O!i'~,~/' 1(/~ ,,, OT HER i?r "' OTHER J COMMENT S: , August 17, 1~88 J G Vidrine Endicott Drlg Eng Supv Standard Alaska Production Company P O Box 196612 Anchorage, AK 99519-6612 Telecopy No. (907) 276-7542 Re.. Duck Island Unit/Endicott 2-68/S-17 MPI Standard Alaska Production Company Permit # 88-97 Surf Loc 2137'SNL, 2366'WEL, Sec 36, T12N, R16E, UM Btmhole Loc 4513'SNL, 4444'WEL, Sec 36, T12N, R16E, UM Dear Mr Vidrine~ Enclosed is the approved application fOr permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chai~an Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMblISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of EnVironmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-!11b. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-!I Service [] Development Gas [] SingleZone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^^c 25.o25) 2137' SNL, 2366' WEL, Sec. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 4330' SNL, 4275' WEL, Sec. 36, T12N, R16E 2-68/S- 17 MPI KOO683449-G- 14 At total depth 9. Approximate spud date Amount 4513' SNL, 4444' WEL, Sec. 36, T12N, R16E August21, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandmVD) property line ADL34636 1005 feet 2-62/Q-17 30 feet 2560 11352'MD 10476'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (se., 20 ^AC 25.035 (e)(2)) Kickott depth 4800 feet Maximum hole angle 32.20 Maximum surface 3600 psig At total depth (TVD)9855 4600 ps~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coup!lng Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75 Surface 131' 131' Drive 17-1/2" 13-3/8" 68# NT-80 Butt 2444 Surface 2500' 2500' 2700 cu fl Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 8961 Surface 9017' 8500' 320 cu fl Permafrost 12-1/4" 9-5/8" 47# NT95H NSCC 1254 9017' 8500' 10271' 9561' 575 cu fl Class G 8-1/2" 7" 29# SM110 Butt 1331 10021' 9349' 11352' 10476' 433 cu fl Class G 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 Conductor Surface RECEIVED Intermediate Production Liner J~UG ]- ]~ ].988 Perforation depth: measured true vertical Alaska 0il & Gas Cons. C0mmissi0~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Dl~¥~"'~ketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify..j.th.,aJ)th9 forgoing is true and correct to the best of my knowledge Signed X'£ ' o &,,¢/~¢' ~///~ Title Endicott Drilling Engineering Supervisor Date Commission Use Only Permit Numbe¢' IAPI number IApproval date See cover letter ~'~- ~'7 150-0.2. '~--- Z / ~'.5"'~IO8/'1 7/88 for other requirements Conditions of approval Samples required [] Yes ,E]rNo Mud Icg required BYes .,~ No Hydrogen sulfide measures [] Yes J~ No Directional. survey required J~ Yes [] No Required workin/~~,~_~ I-I1 OM; I-I15M; e~,~ Other: by order of Approved by ~._ ~ ,.~,', ~//.~. ~,,'~,,,~31~ Commissioner me commission Dat .......... ,_ _ __ _,',' - -/_ -/ - Form 10-401 Rev. 12- Submit in td)licate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-68/S-17 (MPI) Objective Well 2-68/S-17 will be drilled as an oil production well from zone 3C. The completion will be run at the time of drilling and will consist of a simple assembly. Ooeration - Execute a rig move to slot 2-68 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4600 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3600 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 4800 ft., then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run logs. Run and cement 7" 29#/ft, SM-Il0 buttress liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Run CET/CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Change over to NaC1 packer fluid. Perforate well under balance utilizing drill pipe conveyed guns. Run a simple completion assembly and install and test tree. Release rig. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. REC[IVED AUG 1 1 1988 Alaska Oil & Gas Cons. Con]mission Anchorage ENDICOTT PROPOSED DIAGRAM WELL 2-68/S-17 NON-FREEZING FLUID TVD {BKB) MD (BKBI 30" DRIVE PIPE 131 FT 131 F-F B~E PERMAFROST 1467 FT 1467 FT SSSV 1550 FT 1550 FT TOP OF DOWN SQUFFZF CEMENT (ESTIMATED) 2000 FT 13-3/8" 68#/FT NT-80CYHE BTC 2500 FT 2500 FT BOTTOM OF DOWN SQLIEEZE CEMENT (ESTIMATED) 3000 FT 4-1/2". 12.6#/FT L-80 TDS TUBING W/ 3-1/2" TA_PIPE __ KOP~DIR:S40.8°w: ANGLE: 32.2DEG ~ 4800 FT TOP OF 9-518" CEMENT 9-5/8" 47#/FT NT80S NSCC (ESTIMATED 8471 FT 8500 FT 9017 FT 4-112" SLIDING SLEEVE 9-5/8" PACKER 9307 PT 9971 FT 7"LINERTOP 9349 :T 10021 FT 9-5/8" 47#/FT k!T95HS NSCC 9561FT 10271FT PLUG BACKTD 7" 29#/FT SM-110 BUI-ELINER 11272 FT 10476 FT 11352 FT KRL/7-12-88 B.O.P. STACK CONFIGURATION 1;5-5/8 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER .I I RECEIVED I I I I PIPE RAMS I I I 2 IN. KILL LINE L, I 4 IN. CHOKE LINE I-Fl f-T-1 I-T-1 I-l-I_J DRILLING I I PIPE RAMS ~ ...... ,, ! I,, i AUG 1 1 1988 Oil & Gas Cons. Commission Anchorage _ Iii IJ _ ~ :56 -- 31 3?. " 3.3 .... iMotn Producttot Island (HPI) Nd,, ~ T.I~ M. . I 5 4 T.I I N. htelllt4 ClviNi.:I I~lnd(iOl) '~'~ '" o ~-~,~;.:,.:::.-~-, ."-.:::'.;:'.::; :~5 .:::-,.-,~ ~ ~ ~-~:-:".~ ~/~!i'~' :v:-:---- , '/ ". ~ :':'" ' ~~ :-.' .:. .' ~ c- Gas Cons. Commission Anchorago PLAT OF I PROPOSED W E L _L L._OCA T_I_O N s !"" ~ _'-'.'_ _~-' U'~' "- SOl WdlsLK~sd ~a S~c.. B,T.IIN.,RI I ......,?_,_o. o,. ,o. ,,~-., I '"'"":' ,, _ "":"-°2'-'"" SH I I F.R BELL & A$$OC · _~_~,., o !,... ,~. ,,o~. ~,c.~,: ,-.,.,~, ..... I PRUDHO[ BAY OFFICE ~IA~N $6 24 -- I ~b© ?0 ~ ~)0 ~ 0 ~? ~ 0 ~1 0 ~ 0 z?z~© z9 0 © ~ 530© 6~) 0 $56~ 0 ~eo00 RECEIVED uu~ 1 1 1981t _,~chorag~, N 0 TES ' 36 CERTIFICATE OF SURVEYOR o I kearby certify thatl em properly registered end licensed to practice land surve),ing In t#e State M Alaska end that this plat represents an propoled lecation for the Well numbers eho~en abowe. All surveying was dane by me or under my supervision, and that ell dimens(ons end details ere correct. SHEET Z ef I0 REV. Indicates well Indicates Celcblated Section Cer~er I~sltieA Ind;cates Perpendicular Offset Distance I,dicetes ~4;cuter Off~ Distance erpend;cular a,ston ~r,es for PLAT OF MPi PROPOSED WELL LOCATIONS LOCATED IN SEC. SG, T. IZ ii., R. 16 E. UMIAT M. II~E PARE D FOR SOHIO ALASKA P£TROLEUM CO. PI~EPAN ED BY F.R. BELL & ASSOC. ' PRUDHOE BAY OFFICE PRUOHOE BAY, ALASKA i I iii DATE ' IK)V. IS, leis SCALE, I', 60' CHECKED BY' I.E. I Y- ~tl2412.'37 N- 7105324.5~ 7~2l'i0.0670' 14~17'Ze.4~' 1921.4l 2 Y- ~982~79.88 N- 78~.~2 70~22'20.9gZ~'' ~47~57'24.62~7' 113~.4~ X- 2~9~4~.49 E- 464094.4~ ~ 3 Y- 5~82474.18 ~N-'7805321.98 ~ 70-21 '0~.~4~' 147~ 57'20.6258' 1-'~36.7~? ~032'-.'1i Ix" 2'90'"76JE" 4640'2'7' 5 tY- 5982465.99 { N= 7B05~19.46 70~21 '09.~O~-a 14~57'20.785'7~'-'--t~45/[5 i X- 259169.27 E= 464Z~.95 & Y= 598256~.50 N= 7805~48.47 70~i'tO.S16B" 147~57'24.9454" IB52.17i 2~79.~8 X- 2~90~0.02 E= 464091.04 7 Y=' 5982457.80 N= 7805~26.94 70c22'09.8200' 147~57'20.9455' 195~.52' 204~.06 X= 259163.54 E- 464132.24 ,, , , 8 Y" 5982555.30 N= 7805~45.94 70c21'~0.7"~44" i47°57'25.1053* 1860.54 2185.35 X= 259024.29 E= 464089.33 , , 9 Y- 5982449.61 N= 78053~4.41 70~1'09. 7376" 147°57'21.1~54" 19&1.19 204B.53 X= 259~57.10 E= 4641~0.~ ~0 ~'Y=' 5982547.~ N='7805343.42 70o21'10.6521" 147c57'25~2&51* '" liis.tl 21tO.l~ X= 259018.55 E= 464.087.62 ..... 11 Y= 5982441.42 N= 7805311.89 70~ 21' 09. 6553* 147o57'21.2653* 1970.26 2054.00 X= 259152.07 E= 464128.83 12 Y- 59B2538.92 N- 7805340.90 70c 21'10. 5697* 147°57'25.4250* 1877.21 219~.30 X= 2590~2.82 E= 464085.92 13 Y="'~9824~.2~ N- 780'5~09.~6 70C21'09.57~0" 1'470 57 ' 21~"42~i* 1978.&3~ 2059'.47 X= 259146.33 E= 464127.12 14 Y= 5982530.73 N= 7805338.37 70~21'10.4'B74* 147°57'25.584'9* IB85.66~ 2201.77 X= 259007,08 ~= 4640~4.2~ . 15 Y= 5982425.03 N= 7805306.84 70c21'09.4906' 147c57'21.5850* 1987.00 2064.94 X= 259140.60 E= 464125.42 16 Y" 5982522,54 N= 78053~5,85 70°2'1'10,4051' 147°57'25,7447' 1194,03 2207,24 X" 259001,35 E" 464082,~0 17 Y= 598241&,B4 N" 7805304,31 70°2'1'09,4083" J'47~57'21,'7449" 1~5,3B 2070,41 X- 25~134,16 E" 464123,71 lB Y- 5982514,35 N= 7805333.32 70°21'10.3227" 247°57'25,'~04&" l~02,40 22~2,71 X- 258995,61 E' 464080,~0 19 Y= 5982408,65 N= 7805301.79 70c21'0~.3260" ~ 147°57'21.~047" 2003.75 2075,19 X= 259Z29,13 E- 464122,00 20 Y- 5982506,16 N= 7805330,80 70c21'10.2404" ~ 147~57'26.0&44" 1910:77 221B,]8 X= 25~909.B7 E= 464079.09I 21 Y= 5982400,46 N= 7805299,27 70~21'09,2436' I 147c57'22,0~4&' 2012,12i 2001.36 X- 259123 39 E= 464120 30 t ~ iii i i i ii i i i i g.~--.~ .j ,, ~ch0rag SOHIO ALASKA PETROLEUM CO. f,~ ~19~ .'~ ~ ORW. NO. 116-8S -PREPARED 'IY DAT['NOV. 13, f~85 ~j~'~-~~ F.R BELL ~k~CFESS~~ SHEET ~ ef IO ' ' C&LE' N/4 -~~~ PRUDHOE BAYOFFICE PO~WN BY: ~G.~ nEV. O PRUDHOE BAY, ALASKA CHECKEO a~, I.E. i i i i i i i i ii mi II ....... " '--. i -r iiiiii ii - 22 .... Y" 11't2497.t7 II- 780552i.27 7'~2i,10,[sllV~ ~47ol7'2&.224~· I1'19.1"S' '~225.&~ l- 2si914.14 [- 464077.$1 23 Y- $9e23~,2.27 ~N- 780~29&.74 70o~1'09.1[~111~' ~ 147~S7":22.2244· 2020,4t 20i4,.'13 X- 2~S9~17.&5 E- ~4 !Y- ~,982'~89.77 , N,. 71~0~2~.7~ "70c~'22'I°.0757' 247~-57.:26,3~42· ' I727.~:~ ? ~:~29.1~ · . ~ Y= ~G~4~.~G N- 7~0~.~ 70' ~2 0~.9~4 ~ . ~ . · X- 2~7~. 67 27 ~Y= 59B2375.~9~N= 7e052~Z.6~ 70':2Z'0e.~6" Z47~'57'22.51~2' ~ 20~7.24 2097:-7'7 2e Y= 59B2'473.39 i, 7e05'320.70 ~'70c'2~'0~:t~1" ~17~57'21.703~' 154~.27 2240.07' x= 2~e~,~ E= ~6~072,27 , 2~ Y= 59B2~67.70 X- 259~00.~.5 E- 41411~.47 ~ . 30 Y= 59a2~5.20 3~ Y- 59,2359.50 ~- 71052BI.~5 T'70~2z'oa'.1320" t47c57'22.1&3t" 2053.~1~2~°1.72 32 Y-'5982~57.0] i," 3~ Y'='59B2~51.3i' i='7eo52B~.~2 ~70~21'0B':749~" ~7c57.2~.0237· 2062.35 ~2zl~.~ X= 259088.98 E- 4641t0.06 ~4 Y'-'5982448.82 N- 7805~1~.1~ ~70c~1'09.&641' 1470~7'27.11~4' ~ tg&9.38I 2256.49- ' ~ Y- ~982~18,55 N- 7805274 02 70°2t 08 4'20~' t47o~7'2~.~i~2' ' 2095.14 21~6,07 X- 259066.0~ E- 46410~.2~ 36 Y- ~98'2416,0~ H- 7805~03'03 70°2l 09 ]347" t47c57'27,1229" 2002.17 2278.37 X- 258926.78 37 Y- 59823t0.36 N-'7805271 50 ~ 70°2~08.3379" t47o57'23.B230" 2t04.2~ 214~.55 X- 259060.30 E- 464101:~]I , , 38 Y- ~982407.B6 N- 780~300.~1 70o21'09.2524· 147o'57'27.~127" 2011.24 2283.B4 x- 2~892~.0s E- ~' '3~ y. S9~2302.17 N- 7,0~268.98 7~2~'0~.2~3~' ~47~7'23.~2~" 2112.~ 2~7'.02 X- 2390~4.~6 E- 46~099. 40 'Y' '~982399.&7 Nl'TB05297.98 ~70o21'09.1700" 147o57'28.~42&'" 2019.&2 2289.31 x- 2~89z~.3z E- 46~0~6.9Z~ _, , 41 Y- 5982293.97 N- 7~05~'~6.4~ 70°21'08.1733' 1'47C57'24.~427" 2120.~ 21~2.49 X- 25904B.B3 E- 4~4098. ii ii iii ii mil , Ill II III I R : CE VED ~P, PR~SED WEL~ L~ATION LIST ~ ~ ..~ - SOHIO ALASKA PETROLEUM CO. DRW. NO. 116-85 PREPARED BY DATE'~OV.I~, 1985 " ~' F.R. BELL & ASSOC ~ '~~V '" -' PRUDHOE BAY O~CE '~' ..... DRAW -',. eEV. O PRUDHOE BAY, ~AS~ CHECKED IY: I.E i .................... ii i ii i i ii iii ii i ii iii I I II ~ II I ..... I I ~lll~ I WELL AlP 10lK I UTh .ONe & LATITU~£ L~, .run lilt Jilt x- 2~9043.09 E- 464096:41 44 Y- ~982383.29 N- 780~292~3 ~ 70'2~'09.00~4". 147°~7'28.4&2~' 20~&.3& 2300.26 ........ X- 2~8903'84, E- 4640~3'~0 + 4~ ~Y- ~qS2277.~V~ d'-'780~24{ 40' 70-2i'~OdlOOS~~ {47~-5i"~2'42~' 2{37.70 2{63.43 { X- 2~9037.36 E- 464094.70 X- 259031.62 E' 464092.99~ : 48 Y" ~982366.9{ W' 7805287.89 ~:70c2~'08.8407' {47~7'28.7B20; - 20~3.{0{ 23{~.20 X- 2~8892,37 E- 4640~0.08. 49 Y- ~982242.2l N- 780S2~6.3~ 70~2{'07.8439" 147°~7'24.7122" 2{~4.44 } 2{74.38 X- 2~902~,89 E- 464091.29 50 Y- 598235B.7l ~- 7~0~28~.36 70o2{'08.7~84· 147°~7'2W.94{~" 20et.47T 23l~,47 / X- 2~8886.63 E- 464048.38 ~X Y- ~9822~3,02 ~- 780~2~3.83 70~21'07.76~6· 147o~7'24.9420· 2l~2.1l ~ 2179.~6 X- 2~9020, l~ E- 46e089.~8 , 52 Y- ~9823~0.52 W- 7BO5282.B4 70c2~'08.6740" 147°57'29,1017' 2069,~ 2322,~4 X- 2~8880.90 E- 464046,67 5982244~B3 N- 78052~1.3~ 70o21'07.6793" ~ 147o~7'2~.1019' 2~71,19 218S,33 y- X- 2590~4,4l E- 464087,88 ~4 Y- ~982342.33 N- 7805280,3l 70o2~'08.~937· l~7o~7'29,24%~" 2078,22 2327,42 X- 258875.16 E- 464044.96 ~5 ]Y- 5982236.64 N- 780~24B.78 7002~'07,~969· 147o~7'2~,2~17" 2179,~6 2190,~0 l X- 2~9008,68 E- 464086.17 ~6 Y- 5982334,14 N- 780~277,79 70~2l'08,~3" 147o57'29,42{4· 2086,~9{ 2333.09 X- 2~8869,43 E- 46e043,26 ~7 Y- 5982228,44 N- 780~246.26 70o2l'07,~1~6· 147o~7'2~.42l~" 2%~7,93 2%96.27 X- 2~9002,94 E- 464084,~6 ~8 Y- 598232~,95 M- 780~27~,27 70o2{'08.4~90· 1470 ~7 ' 29, 5112" 2094.96 2338,~6 X- 2~8863,&9 E- 464041,~ ~9 Y- ~982220,2~ N- 780~243,73 7002l'07.4323· 147°~7'2~,~114" 2~9&,30 2201.74 ~- 238997,2l E- 464082,76 60 Y- 5982317,76 W- 780~272.74 70o2~'08,3467· 147°S7'2t,74ll" 2103,33 2344,03 X- 2~8857,96 E- 464039.85 6~ Y- 59822%2,06 M- 7B0~24~.2l 70c2~'07,3499· 147o57'25,7413" 2204,&7 2207.2l ~- 2~8991,47 E- 46408~,05 62 Y- 5982309,~7. W- 780~270.22 70c2~'08,2643· 147o~7'29,9009" 2lll. Tt X- 2~88~2.22 E-- e64038.14 , 63 Y- ~9B2203,~7 W- 780~238.69 70o2~'07.2676' 147o~7'2~,90~l" 22~3,05 2212.&9 X- 2~898~. 74 E- 464079.34 i n .T~--~''~- " 2' r C E {Y [ D MP' PRO~S E D WELL L~TION LIST ~_~_~.~.~ ~ LOC&TED IN ~C. 3&,T. IZN.,R. - ~% '' · ~ DRW. NO. 116- 85 PREPARED IY DATE:NOV.13 '~¢~r~s¢~%~ SHEEr 5~f ~0 F.R. IELL · 4~0C. ~C4L[' ~/4 -~%~~ .... PRUDHOE BAY OFFICE i i i I~LL ZONE LiT ! TJ/tE LO. . &4 f- ~912301.3! #- 7105267.&9 7~:'21'Ol, ll20' 147°S7'$0,06GI' ll]~.t~ Z354.97 X' 2~114&.41 E' 46403&.4~ &5 Y' $982195.68 #' 7805256.26 70°21'07.2852' 147o57 26.0620' 2222.4~ 2211. I& X" 258980.00 E" 464077,64 66 Y= 5982293.18 N' 7805265,17 70'21'08.0997' 147'57 30.2206' 2128.45 2360.45 X- 2~8840.7~ E- 464 67 y.--~-982187.49' N- 780S 68 Y- 5982284,99 N' 7805 034.73 233.64 07§.93! 262.64 ' 70:21'08.0173" 147s57 70-21 07. 1029" - 1-47 30.3805' 2136.82'2365.92 26.3807' 2231.17 2229.10 ~0,5403' 2145.!9 2571.39 X' 258835.01 E' 464035.02 69 Y: 5982179150 i N: 7805251111 70c21'07.0206' ! 147157, X 258968 53 ~ E 464074 23 70 Y' 598227&.10 #' 7~05260.12 70021'07.9350' : 147~57 X' 258829.28 E' 464031,31 RECEIVED Anchorage ii i i ORW. NO. 116-85 SHEET G of IO REV. O i · MPI PROPOSED WELL LOCATION LIST LOCAT ED IN SEC. 3,6,T. 12 N.~ R. 16 E. UMIAT M. SOHIO PRE PARED FOR ALASKA PETROLEUM CO. PREPARED IY F.R. BELL & ASSOC. PRUDHOE BAY OFFICE PRUDHOE BAY, ALASKA ii i DATE: NOV. 13, I ti .',','I SCAt.. E: N/A DRAWN BY: R.G.T. CHECKED ii ENDICOTT DEVELOPMENT WELL 2-68/S-17 (MPI) TRUE NORTH GRID SLOT 2-68 SURFACE LOCATION X = 258,835 FT ; Y = 5,982,285 FT 2137 FT SNL; 2366 FT WEL SEC 36, T12N, R16E DEPARTURE TO TARGET: 2909 FT 10886 FT MD 10081 FT TVD BKB S 40° 50' W DEPARTURE TO BHL: 3158 FT 11352 FT MD 10476 FT TVD BKB RECEIVED Anchorage NOTE: THE NEAREST WELL TO 2-86/S-17 IS 2-62/Q-17 LOCATED 30 FT NORTHEAST AT SLOT 2-62. KRL/8-5-88 Search Radius= 200 COURSE LINE For proposed well: 2-68/S17 [14-36-12-16] Location = W-E S-N TVD(SBS) Top 258835.00 5982285.00 -56.00 Bottom 256687.87 5979969.61 10420.00 Note: All depths in feet Below Kelly Bushing (BKB) --- Closest Approach Analysis --- Date: 5-AUG-88 Time: 14:07:46 Closest Approach WELL IDENT /PROPOSED\ /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000056 MI-36 NO COORDINATE A000-0000119 MI-69 NO COORDINATE A000-0000120 MI-70 NO COORDINATE A029-2064000 MISD10 NO COORDINATE POINTS WITHIN A029-2162500 MI-Q2X 5539.7 123.2 5536 A029-2164800 MI-Q17 2900.9 0.0 2900 A029-2166200 MI-P14 1100.0 0.0 1100 A029-2174800 MI-P24 1699.8 ,0.0 1699 A029-2175000 MI-S14 5214.7 38.1 5226 A029-2176700 MI-R12 700.9 0.0 700 A029-2178800 MI-R25 1.0 0.0 0 A029-2181500 ~I-N14 2600.9 0.0 2600 S UM.~JkR Y POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW SPECIFIED SEARCH WINDOW 252 4 49 41 34 4 57 2 19 00 2.0 169 .7 24 .5 196.9 201 .3 75.3 119.4 180 .5 238.8 The well which comes closest to the proposed well is: A029-2164800 MI-Q17 Closest approach distance = 24.5 feet KICK OFF for this run = 4800.0 feet CD VertiCal /PROPOSED\ TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 6184.1 455.0 8220.3 484.2 2037.1 Se&rch Radius= 200 7 DEGREE LEAD LINE For proposed well: 2-68/S17 [14-36-12-16] Location = W-E S-N TVD(SBS) Top 258835.00 5982285.00 -56.00 Bottom 256986.05 5979725.20 10420.00 Note: All depths in feet Below Kelly Bushing (BKB) --- Closest Approach Analysis --- Date: 5-AUG-88 Time: 14:09:43 WELL IDENT Closest Approach /PROPOSED% /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000086 MI-36 NO COORDINATE A000-0000119 MI-69 NO COORDINATE A000-0000120 MI-70 NO COORDINATE A029-2064000 MISD10 NO COORDINATE A029-2162500 MI,-Q21 5597.0 A029-2164800 MI-Q17 2900.9 A029-2166200 MI-P14 1100.0 A029-2174800 MI-P24 1699.8 A029-2175000 MI-S14 5198.0 A029-2176700 MI-R12 700.9 A029~2178800 MI-R25 1.0 A029-'2181500 MI-N14 2600.9 POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW SUP[MARY 14'3 0 0 0 0 0 34 8 0 0 0.0 0.0 The well which comes closest to the A029-2164800 MI-Q17 proposed well is: Closest approach distance = 24.5 feet 3 5592.6 255.2 153.1 0 2900.0 4.9 24.5 1100.0 4.1 196.9 1699.3 34.4 201.3 5210.0 52.4 77.1 700.0 1.9 119.4 0.0 0.0 180.5 2600.0 2.0 238 ...2..~ ~.. KICK OFF for this run = 4800.0 feet Vertical /PROPOSED~ TVD DEPART Intersection /NEARBYN TVD DEPART VERTICAL DISTANCE 5605.7 146.7 7285.7 176.1 1680.9 Interval ENDICOTT MUD PROGRAM MAIN PRODUCTION I,~LAND WELL , 2-68/S-17 Mud Weight Viscosity Fluid Loss (sec/qt) (ml/30min) .oH Mud Type/ Components 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 Generic Mud #5 2,500- 10,271 Set 13-3/8" casing 9.2-10.2 40-45 15-16 9.0-10.5 Set 9-5/8" casing 9.6-10.2 40-45 6-8 9.0-11.0 Hang' 7" Liner 10,271- 11.,352 Seawater Fresh water Gel Soda Ash Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill DOYON DR!LLING~ !NC. RI G NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equ i pmen t IHanuf acturer Model Nominal Capacity Shaker Desander Brandt Demco Dual Double 2-12" cones 1000 9Pm 700 9pm (each) Hudcleaner s Tri Flow Double B each - 4" 'cones 400 9pm (each) Cen tr i fuge Pioneer Mark I I , Decant i n 9 150 9pm De.gasser Agitators Hoppers Drilco Brandt Geosource Macuurt3 B each - 2.5 h.p. Dual Sidewinders 1000 9Pm 1000 9pm The trip tank and mUd tank-sections~haue one vertical pit level float indicator which are connected to the drillin9 recorder sVstem that contains visual and audio warnin9 devices iocated in the driIIer's consoIe. ECEIVF b G~s Con:;. Cc, ~ ~.~ Anchorage .... I ii I_ I III III I II I IF I~ DOUBT - - - AS. KII _ _ I Iii__ J , 12 - 0 ' ¢ LO ' fl- IZ 'C ' [ ] i I UTr..-' I.~ Y O~ it :,~ ' J U:O ' IP '-0 ' J tp : ' I 1.9 t' · 13-5/8" APl-SO00, 13-5/8"' API-3000, t J CONTROL LINE WELLHEAD ASSEMBLY,'ENDICOTT 5KSI 13-3/8"x 9-%/B"x 4-1/2" SOHIO ALASKA PETROLEUM COMPANY lC, lIRE I (3) 13-3/8" 9-5/8" CONTROL LINE 4-l/2y ri. 3. 9-5/8" CASING AND WELLHEAD EQUIPHENT 3.1 TESTING B.O.P. STACK 1. After B.O.P.'s are nippled up to split speedhead, make up 13" x 4-I/2 Internal Flush B.O.P. test plug, Accessories Item 7, Part No. 538116. 2. Lower plug into head (it will land on lower step). Tighten 4 lockscrews 90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plug. CAUTION: It is very important not to have the lockscrews protruding into the bore of the head while either running or pulling the B.O.P. test plug. Always check them if in doubt. (29) --SPLIT SPEEDHEAD TEST PLUG (30) CASING II II ACCESSORIES ITEH 7 t'-8 i I 210 · - "E.-T PL;'3 FOF,, LDWERBOWL (19) II. 4. 4-1/2 TUBING AND WELLHEAD EQUIPMENT 4. 1 TESTING B.O.P.'s 1. After 9-5/8" has been set and tested, run in B.O.P. test plug, Accessory Item 6, Part Number 538117, which lands in upper bowl of the split speedhead. Run in 4 lockscrews lightly, 90° apart to keep plug from moving. 2. After test, retract lockscrews and pull plug. 3. Run in short bowl protector, Accessory Item 8, Part Number 538114, using the same running tool, Accessory Item 5, Part Number 538115, that was used for the long protector. 4. After bowl protector is in place, run in 4 lockscrews lightly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. (43) I --TEST PLUG --PACKING PORT TEST .PORT --LOCKSCREW CASING HANGER SPLIT SPEEOHEAO I 3 - 3/8 o,. . ACCESSORTES I'TEH 6 iI 13t,.7 t,,-1/2 IF FE~,~LE THO Il II II II .i 'r-L ~2 C~PSCF,'EWS 21 0 BOP TEST PLL,G gO~ UPPER BOWL (5381:71 _. ITEM APPROVE DATE ( 1 ) F e e /~ ~//S/~"F (2) Loc (2 thru 8) (8) (9 thru 13) (10 and 13) (4) Casg (14 thru 22) (5) BOPE ~,~ (23 thru 28) (6) OTHER /~,~ (29 thru 31) (6) Add: Geology: Eng~inearing: rev: 08/11/88 6.011 1. Is the permit fee attached .......................................... YES 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 and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day.wait ...................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. NO REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and 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 and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ........................ Will all casing give adequate safety in collapse, tension and burst.. Is this 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 ....................................... -~c Is the drilling fluid program schematic and list of equipment adequate/~KL. Are necessary diagrams and descriptions of diverter and BOPE attached.,4¢¢ Does BOPE have sufficient pressure rating - Test to3Ooo/o-oo~ psig Does the choke manifold comply w/API RP-53 (May 84) .................. ~ Is the presence of H2S gas probable ................................. ~y exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: o ~z ~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. DIRECT DIGITAL LOGGING COPIPUTER PROCESSED ANALYSIS Compan.v STANDARD ALASKA PRODUCTION CO, Well 2-68/S-'17 MPI API HUM: 50-029-21858 Field ENDICOTT DATE LOGGED: 09-09-88 Countp NORTH SLOPE St~t.~ ALA.~KA Countr~ USA CLIENT FORMAT DATA T.AP E LOG INFORMATION STANDARD FORMAT ( L , I , S , Hame: 2-68/:.-,-1 ? ~IP I Field: ENDICOTT AP[ NUM: 50-02~-218.58 DATE LOGGED: 03-09-88 S, TAPE RECOEDS REEL HEADER Servic~ name: &GSFO1 Pr~viouz, r~et: HEADER Date: 88709/I? Origin: Comm~ntz: RECORD'~,~. Reel name: 392277 Page Continuation ~: 01 **** TAPE~ HEADER **** *********************** S~rvice name: &GSF01 Previous.tape: Date: 88709/17 Origin: Commen-tz; Tape name: 392277 Continuation #: Ol *** EOF *** FILE HEADER **** ************************* Fil~ n~m¢: ,0'01 Maximum length: 1:024 HEADER RECORDS S~rvice name_: ¥~rzion #: File .typm: LO Previous ?ile: Date: CN WN FN COUN STAT CTRY APtN LAT! LONG SECT TOWN RANG EKB EDF PD LMF RUN TIME DATE LCC *OH LUH 'FL LUL ENGi WITH DL TLI BLI TC$ TLAB BHT MRT MT MSS MVIS RM RMF MFST HFSS RHC HCST MC$S CS BS INFORMA CONTENTS STANDARD ALASKA PRODUCTION CO .......... 2-687S-i? HPI API HUM: ENDICOTT DATE LOGGED: 09-09-88 ......... NORTH SLOPE ALASKA .................... USA ..................... 0 Dig· :0 Min. O. 0 Sec. N ..... ~0 Dig, 0 Min. O. 0 Sec, W ..... 16, , ....... 54 '. 500 ..... '0; :000 ...... 14,500 ..... Mi 'KB O, 000 ...... 30 NORTH SLOPE NORTH SLOPE Z~RNDT ...... 11360,000, . i 1378, :000.. i0272,~00.. tI376,000,. 20 ·"3'0:0 ...... 5. 450 ....... i88. 000 ..... 188,000 ..... LIaNOSULF, . C IRCUL~TED . 37. 000 ...... 2,150 ....... 1 , 000 ....... 7J .000 ...... 72.0 O0 ....... 9,625 ........ 8.500 ........ TION RECORDS itiim ii,il ii,mm Imlml ~mmlI ii/ii mImII ImmI· imwli ima~m 4.,mi mImml Imm·· ii mm i mi mi · mm I ii mm m I UNIT TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 2.0 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 J 65 FT 0 3 4 68 FT' 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 ,3 2 65 0 3 2 65 0 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 1 0 65 0 0 20 ~,5 0 0 2 0 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 ;3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 1 4 68 0 2 20 65 0 2 20 65 CP 0 2 4 68 OHMM 0 2 4 68 OHMM 0 2 4 ~8 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 1'2 '=' 0 3 4 68 0 3 4 68 Page GF- ~¢11 Location Comment 1: Well Location Comment 2:. Welt Location Comment 3: ~ell Location Comment 4: :COM:MENT RECORDS 2137' FNL & 2366~ FEL COMMENT RECORDS LIS.tape wri~tten by: ANCHORAGE COMPUTING CENTER All curv~ and .tool mn~_monicz used ara those which mozt clozel~ match · Gearhart curv~ and tool mnemonicz, GEARHART TO SCHLUMBERGE R TOP MNEM SERVICE UHIT MNEM SERVICE UNIT DEPTH DEPTH FEET DEPT FEET 10200.0'0 GEl SLDCNS API GE SLDCNS AP! 10272.00 RHOB1 SLDCHS G?C3 RHOB SLDCNS G?C3 10272,00 PEF~ SLDCNS B/EL PEF SLDCHS B/EL 10272.00 NPHII SLDCNS LSPU NPHI SLDCHS LsPu 10272.00 ET ULTRA OHMM RT ULTRA OHMM 10272.00 RXO ULTRA OHMfl RXO ULTRA OHMM 10272,00 RBTH ULTRA ~/C3 RBTH ULTRA G/C3 10272,00 CVSD ULTRA ~ CVSD ULTRA ~ 10272.0'0 CNTH ULTRA LSPU CNTH ULTRA LSPU 10272.00 CVLI ULTRA ~ CVLI ULTRA ~ 10272.00 RXTH ULTRA OHMM RXTH ULTRA OHMM 10272.08 CVMA ULTRA ~ CV~A ULTRA Z 10272.00 RTTH ULTRA OH~M RTTH ULTRA OHHM 10272,00 GRTH ULTRA API GRTH ULTRA AP! 10272.00 CVCL ULTRA % CVCL ULTRA Z 10272,00 PETH ULTRA G/EL PETH ULTRA B/EL 10272,00 RHOM ULTRA G/C3 RHOM ULTRA G/C3 10272,00 BOTTOM DEPTH 11394,00 11360,00 11360,00 11360,00 11360.00 11360,00 11360,00 11360.00 11360.00 11360 O0 11360 O0 11360 O0 11360 O0 11360 O0 11360 O0 11360 O0 11360 O0 11360 O0 Page SXOT St~T PHSW PHSX PHI T COAL FLBH ULTRA ULTRA ULTRA ULTRA ULTRA ULTRA ULTRA FLAG FLAG SXOT SWT PHSW PHSX PHIT COAL FLBH ULTRA ULTRA ULTRA ULTRA ULTRA ULTRA ULTRA FL~G FLAQ 1;0272.'00 '1'0272.00 10272.00 10272.00 i0272.'0'0 ~0272,00 10272.00 't 1360.'00 11360. O0 11360. O0 11360,00 1 1360..00 11360, O0 11360, O0 DATA :ENTRY : :+~.~** EN,TRY 'BLOCK :LEGEND TYPE DESCRIPTION 0 Terminator ( no more entriez > F 0 R M A T SPEC I TYPE SIZE CODE 0 '1 66 F I CAT IONS Pag~ D A'T A FORMA **** DATUH SPECIFICATION BLOCKS SERVICE SERVICE API API MNEM ID ORDER # UNIT LOG TYPE API API CLASS MOD DEPT 2277 FEET '0 GR SLDCNS 227,7 RPI 94 RHOG SLDCNS 2277 G/C3 94 350 PEF SLDCNS 2277 B/EL 94 0 NPHI SLDCNS 2277 LSPU 94 890 RT ULTRA 2277 OHNM iO 0 RXO ULTRA 2277 OHMH 0 0 RBTH ULTRA 2277 G?.C3 0 CVSD ULTRA 227? ~ '0 0 CNTH ULTRA 22.77 LSPU '0 0 CVLI ULTRA 2277 ~ 0 0 RXTH ULTRA 2277 OHMM CVHA ULTRA 22.77 ~ 0 0 RTTH UL~TRA 2277 OHMM GRTH ULTRA '2277 APl 0 .0 CVCL ULTRA 2277 ~ 0 0 PETH ULTRA 2277 B?EL 0 RHOH ULTRA 2277 G?C3 0 0 SXOT ULTRA 2277 Z SWT ULTRA '2277 ~ 0 ~0 PHSW ULTRA 2277 ~ 0 PHSX ULTRA 2277 ~ 0 '0 PHIT ULTRA 2277 ~ :'0 0 COAL ULTRA 2277 FLAG · 0 FLBH ULTRA 2277 FLAG 0 0 .0 0 1 0 i O 0 0 i 0 0 0 O 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 T SPEC I F I CA T IONS FILE PRC # # SIZE LVL SHPL RC 0 0 0 0 0 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 0 4 0 1 4 0 1 4 0 I 4 0 i 4 0 1 4 0 i 4 0 1 4 0 1 4 0 '1 4 0 4 0 4 0 i 4 0 4 0 i 4 0 4 0 4 0 1 4 0 1 4 0 1 4 0 I 4 0 1 4 0 1 4 0 1 4 0 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 PROCESS INDICATORS 000000 000000 000000 000000 0'00000 000000 O000OO O'O000O 000000 000000 000000 000000 000000 000000 000000 000000 00'0000 000000 000000 000000 000000 000000 O0000O 000000 000000 .000000 000000 000000 0:00000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 00000'0 000000 000000 'OOO000 000000 OOO000 000000 000000 000000:000000 000000 000000 00:0000 000000 000000 000'000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Page DA TA RECORDS DEPT ~R RHO8 PEF NPH I RT RXO RB TH CVSD CN TH CVL I RXTH CVHA RT TH .~RTH C VCL :PEYH RHOH 'SXOT SWT PHSW PHSX PHi T COAL FLBH Page ii360o000 0,000 2.384 i .740 -999.250 3.970 15.i60 2.372 ,994 0,:000 ,994 i5,160 1, OOi 3,970 i4,752 1 ,.00i 2.082 '2.664 .766 .766 . i34 .i J4 . i74 O. 000 ~O, O O0 260. '000 30. 600.' 2. 342 1. 660 20. 043 i8. 323 38.160 2. 341 .85,9 2;0. 047 .858 38. 160 .858 18. 323 30. 522 1. 000 t. 899 2.645 .428 .336 .063 .080 . i86 O. 000 ~, '0 O0 :iiJ60.O00 78.80:0 2.604 2.270 13.325 8.933 32.957 2.604 .447 13.325 .447 32.957 .452 8.933 78.799 1.000 2.270 2.673 1.OOO 1..000 .030 .~030 .030 0.000 O.O00 11 060,000 1:06,000 2,655 2. Ol 0 15. 792 11 .320 15,465 2. 670 · 296 t7.i49 ,296 15.465 ,296 I1.320 96.804 1.OOO 2.. 1 ?O 2. 645 i. O00 i. OOO O. 000 O. OOO O.O.O0 O. 000 O. '000 1 0960.0 00 92,800 2,654 2,38 0 16,99 0 15,943 13. 679 2. 654 .320 16.990 .320 I 3. 679 .32E{ 15.943 92. 806 1 . OOO 2. 380 2..705 i . O0:O i . OOO . O15 . OJ5 .015 O. OOO O. OOO 10860,000 109,100 2,598 2,6?0 30.875 7.010 6.083 2,641 · S72 30.570 .i72 6.083 .187 7.010 107.966 1.000 2.601 2.896 1.000 1,000 .042 .042 .042 0,000 t.O00 1 0760.~000 22.200 2.434 2. i60 18. 095 75.4<)8 42. 194 2.434 .932 iS. 09~. .932 42. 194 .940 75.498 22.200 1 , 000 2.1 60 2.6~8 . 575 . 234 · 031 . 076 . 13i O. OOO O. 000 DATA RECORDS DEPT GR RHOB PEF NPHI RT RXO RBTH CYSD CNTH CVLI RXTH CVMA RTTH GRTH CVCL PETH RHOM S×OT SWT PHSW PHSX PHIT COAL FLBH Page 10 I0660,000 60,800 ;2,679 3. 450 1.3,26.4. 19,907 21 . 048 2,678 ,.'097 ! 3,243 .544 21 ,048 .54,4. 19,907 60.920 1. 00:0 3,502 . 2,699 i.O00 1.00.0 ~008 .008 .008 0.000 O,OOO 0560. 000 48. !00 2,660 5,670 1 O, 638. 79. 903 87. 864 2,690 .005 10,630 ,634 87,864 ,634 79,903 47.518 1. 000 4,046 2.71 0 1 , 0.00 1 , 000 ,005 .005 .005 O. OOO O. 000 10460,'000 4;0,200 2,646 3.270 15,300 13,944 5.633 2,633 ,i69 15.101 .704 5,633 .704 i3,944 40.g77 1.00i 3,746 2,697 l,OOO 1,:OOO ,037 ,037 .037 0.000 0.,:00'0 I036.0,000 54.000 2,619 3,240 li.16i 12.546 '16.566 2,619 ,254 Ii,160 ,616 i6,566 ,6i6 i2.546 54.00~0 i.00.0 3,240 2,685 1,000 '1,000 ,028 .028 .028 0.000 i,O00 10272.000 65.900 2,399 9,820 34.295 2.i92 3.580 2,546 .089 34.123 ,500 3.,580 .500 2.1.92 64,991 1.OOO 3.404 2.710 1,000 1,000 ,089 .009 .089 0.000 O..O00 File nama: &~5F01.00! Maximum length: "1024 TRAILER RECORDS S.ervi c~ name V~rzion #: File typm: LO Next ~ile: Date: Page EOF ~* Next tmpe: Date: 88/'09/17 Comm~ntz: TRAILER Origin: RECORDS Tap~ name: 392277 Page Continuation #: 0t 12 REEL TRAILER Servicm namm: &GSF01 Next Date: 887.09/17 Comments: Origin: Reel name: 392277 Continuation #: 01 GF_4R/,,J,a. RT