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Home My WebLink About186-172Nolan 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: 3/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240307 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/9/2024 AK E-LINE GPT-Perf BCU 19RD 50133205790100 219188 1/25/2024 AK E-LINE Perf BCU 13 50133205250000 203138 12/8/2023 AK E-LINE CMT CUT END 2-34 50029216620000 186172 10/29/2023 AK E-LINE PERF KBU 42-6 50133205460000 204209 2/19/2024 AK E-LINE Perf MPU C-13 50029213280000 18567 2/15/2024 AK E-LINE Whipstock Please include current contact information if different from above. T38604 T38604 T38605 T38606 T38607 T38608 END 2-34 50029216620000 186172 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.07 13:13:02 -09'00' 1. 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 11,242 feet NA feet true vertical 10,587 feet Unknown depth feet Effective Depth measured 11,024 feet 10,275, 10,399 feet true vertical 10,385 feet 9,701, 9,813 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 5-1/2" 17#/L-80 9,546' 9,068' 4-1/2" 12.6#/L-80 10,380' 9,796' Tubing (size, grade, measured and true vertical depth)4-1/2", 3-1/2" 12.6"/L80, 9.3#/L80 10,520', 11,024' 9,923', 10,385' 1,511' MD / Packers and SSSV (type, measured and true vertical depth) See Above 5-1/2" HES HRQ SVLN 1,511' 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: 7"x4-1/2" Baker SB3, 7"x4-1/2" Baker S-3 Burst NA Collapse NA 2,670psi 7,020psi 5,380psi 6,870psi 8,160psi 4,760psi Conductor 10,587'11,242' 10,100' 2,483'Surface Production Liner 30" 9-5/8" 131' 2,483' 10,100' 9,546' ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-34 Plugs Junk measured measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-172 50-029-21662-00-00 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) 0 Gas-Mcf 150 21,212 8000 0 2263505 2085 N/A measured true vertical Packer MD 131' Size 131' 2,483' Length 1,415' 13-3/8" 323-505 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 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 PL G 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 4:28 pm, Dec 01, 2023 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.11.30 15:21:11 - 09'00' Sara Hannegan (2519) DSR-12/5/23 RBDMS JSB 120523 WCB 1-21-2025 Well Name Rig API Number Well Permit Number Start Date End Date END 2-34 E-Line 50-029-21662-00-00 186-172 10/29/2023 10/31/2023 Hilcorp Alaska, LLC Weekly Operations Summary Job Continued From 10/30/23. ***WELL SHUT IN ON ARRIVAL***. PT PCE From 200LP - 2150HP RIH with 1 7/16" Cable Head, 1 11/16" GR/CCL, 2" Perforating Guns (Max OD = 2" , Max Lenth = 40') Gun #4 (23' Load) Shooting Depth = 10,904' - 10,927' , CCL Offset = 9.4', CCL Stop Depth = 10,894.6' Rig Down/Move off ***WELL SHUT IN ON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL***. PT PCE 200lp - 2150hp RIH with 1 7/16" Cable Head, 1 11/16" GR/CCL, 2" Perforating Guns (Max OD = 2" , Max Lenth = 40') Gun #2 (31' Load) Shooting Depth = 10,958' - 10,989' , CCL Offset = 7.5' , CCL Stop Depth = 10,950.5' Gun #3 (31' Load) Shooting Depth = 10,927' - 10,958' , CCL Offset = 7.7' , CCL Stop Depth = 10,919.3' ***WELL SHUT IN ON DEPARTURE***. Job continued 10/31/2023. 10/31/2023 - Tuesday 10/29/2023 - Sunday WELL SHUT IN ON ARRIVAL. PT PCE 200lp - 2150hp. RIH with 1 7/16" Cable Head, 1 11/16" GR/CCL, 2" Perforating Guns (Max OD = 2" , Max Lenth = 40') Gun #1 (31' Load) Shooting Depth = 10,989' - 11,020' , CCL Offset = 7.5', CCL Stop Depth = 10,981.5'. WELL SHUT IN ON DEPARTURE. Job Continued on 10/30/2023. 10/30/2023 - Monday Shooting Depth = 10,927' - 10,958' Gun #2 (31' Load) Shooting Depth = 10,958' - 10,989' Shooting Depth = 10,904' - 10,927' Gun #1 (31' Load) Shooting Depth = 10,989' - 11,020' , 2"6 10,904 - 11,020 O 10/31/23 10/31/23 ADD PERFSDH 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,242 UNKNOWN Casing Collapse Conductor NA Surface 2,670psi Production 4,760psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10,399 MD / 9,813 TVD, 1,511 MD / 1,511 TVD NA 11,242 10,100 1,415 See Schematic 907-748-8581 brenden.swensen@hilcorp.com Operations Manager October 5, 2023 3-1/2" Perforation Depth MD (ft): See Schematic 7"x4-1/2" Baker SB3, 7"X4-1/2" Baker S-3, 5-1/2" HES HRQ SVLN 10,275 MD / 9,701 TVD 10,5877" 30" 13-3/8" 131 9-5/8"10,100 2,483 NA 5,380psi 131 2,483 9,546 131 2,483 Hilcorp Alaska, LLC Length Size Proposed Pools: 10,587 11,024 10,385 3,300 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 186-172 C.O. 462.007 DUCK IS UNIT MPI 2-34 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21662-00-00 AOGCC USE ONLY Tubing Grade: 17 # / L-80, Tubing MD (ft): 9,546'Perforation Depth TVD (ft): 9.3 # / L-80 11,024' Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 5-1/2", PRESENT WELL CONDITION SUMMARY TVD Burst ENDICOTT 4-1/2", 4-1/2" 12.6 # / L-80, 12.6 # / L-80 10,380', 10,520' Brenden Swensen Subsequent Form Required: Suspension Expiration Date: 8,160psi MD 6,870psi No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:34 am, Sep 07, 2023 323-505 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.09.07 07:29:27 - 08'00' Sara Hannegan (2519) 10-404 SFD 9/14/2023 DSR-9/11/23MGR19SEP2023*&: 09/19/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.19 11:20:49 -08'00' RBDMS JSB 091923 Page 1 of 7 Add Perf Well: END 2-34 PTD: 186-172 Well Name: END 2-34 API Number: 50-029-21662-00-00 Current Status: Water Injector PTD # 186-172 Estimated Start Date: 10/5/2023 Rig: E-Line Reg.Approval Req’std? Yes Estimated Duration: 2 days Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure: 3,900 psi @ 10,000’ TVD (2-14 SBHPS 7/27/2021) Maximum Expected BHP: 4,300 psi @ 10,000’ TVD (est.) 8.33ppg EMW Max. Anticipated Surface Pressure: 3,300 psi Gas Column Gradient (0.1 psi/ft) History Endicott 2-34 was drilled and completed in 1987. The well was produced until 1989 before being converted to a water injector in 1990. The well was worked over in 1994 and 2007. Slickline stacked up a scab liner in the XN nipple in 2012 followed by coil tubing latching it and running it to TD and cementing it in place. Since then, the well has been an injector in the K2B sand. The well offsets END 2-36 in the K2B, one of the better producers at Endicott. In attempt to minimize 2-36’s water cut as the primary offtake from 2-34 injection, 2-34 has been operating at minimum injection rates. Objective Confirm tag depth of TD. Perforate up to 116’ of the K2M and K2A sands beginning at ±10,904 to TD. Opening injection to the K2M and K2A will allow for the well to operate at higher injection rates and reduce directly flooding 2-36’s production in the K2B. This will improve Endicott’s water injection capacity, increasing production by bringing online wells that are shut in for water handling constraints. Page 2 of 7 Add Perf Well: END 2-34 PTD: 186-172 Procedure (Page 1 of 1) Slickline 1. MIRU. Pressure test PCE low 250psi high 3500psi. 2. Pull SSSV from landing nipple at 1,511’ MD. 3. Drift to TD with sample bailer. Record description of any sample retrieved. a. Eline tagged TD at 11,020’ ELM on 10/22/2012. b. Recommend drifting with 2.70” gage. WSL discretion. i. Min ID 2.80” @ 10,500’ MD, QCLL receptacle. c. Schmoo is a known issue on Endicott injectors. With the smaller tubing size. If drift is difficult, contact OE and discuss options for fullbore assist. 4. Drift with dummy 2-1/8” guns. Eline 5. MIRU. Pressure test PCE low 250psi high 3500psi. 6. Perforate ±116’ from ±10,904’ to ±11,020’ MD. a. Use reference log SLIM CEMENT MAPPING LOG SCMT-CB dated October 21 2012. b. Contact town Geo and OE for final tie in correlation. i. Geo - Brock Rust, brust@hilcorp.com, 907-777-8394 ii. OE - Brenden Swensen, brenden.swensen@hilcorp.com, 907-748-8581 c. Scale has been noted in early history of well. If necessary, scab liner tubing tally is attached to assist with depth control. Slickline 7. MIRU. Pressure test PCE low 250psi high 3500psi. 8. Set SSSV in landing nipple at 1,511’ MD. Page 3 of 7 Add Perf Well: END 2-34 PTD: 186-172 Reference Log Title Page Page 4 of 7 Add Perf Well: END 2-34 PTD: 186-172 Reference Log Gamma Signature Perf Interval: ± 10,904’ to ± 11,020’ Page 5 of 7 Add Perf Well: END 2-34 PTD: 186-172 Add Perf: ± 10,904’ to ± 11,020’ Page 6 of 7 Add Perf Well: END 2-34 PTD: 186-172 Scab Liner Tubing Tally (page 1 of 2) Page 7 of 7 Add Perf Well: END 2-34 PTD: 186-172 Scab Liner Tubing Tally (page 2 of 2) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-34 DUCK IS UNIT MPI 2-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 2-34 50-029-21662-00-00 186-172-0 W SPT 9813 1861720 2453 1775 1779 1788 1783 130 327 319 319 4YRTST P Guy Cook 4/4/2023 Testing was completed with a Thunderbird pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 2-34 Inspection Date: Tubing OA Packer Depth 695 2750 2732 2727IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230403174616 BBL Pumped:3.8 BBL Returned:3.8 Friday, May 19, 2023 Page 1 of 1             MEMORANDUM TO: Jim Regg ��(-C "IIL) Iq P.I. Supervisor `"� FROM: Matt Herrera Petroleum Inspector Well Name DUCK IS UNIT MPI 2-34 IInsp Num: mitMFH190407061230 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 10, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2.34 DUCK IS UNIT MPI 2-34 Src: Inspector Reviewed By: P.I. Supry OPP— NON-CONFIDENTIAL Comm API Well Number 50-029-21662-00-00 Inspector Name: Matt Herrera Permit Number: 186-172-0 Inspection Date: 4/4/2019 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z3a Typelnj W TVD 1 9813 'Tubing �2173 2248 1" ,,13 PTD .. _ _ 11861720 !Type Test SPT Test psi! 2453 IA 706 ; 2654 1639 2633 ' BBL Pumped: 4.5 -BBL Returned: 4.5 OA 170 360 360 360 - Interval 4vRTST— !iP/F P - Notes: MIT -IA to 2650 PSI per Operator ✓ Wednesday, April 10, 2019 Page I of I • I El r== Post Office Box 244027 Anchorage,AK 99524-4027 Hilcorp Alaska,LLCJUL 3 0 2010 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 e® Na- SCO' UC 2 2p1�o Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100i36 - 117 00a Anchorage, AK 99501 � ., Sq. Re: Duck Island Unit Well Renaming Request 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/L21" 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 I • Orig New API_WeliNo PermitNumber WellName WellNumber I 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 2-288/019 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 2-306/ME-01 2-308 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 2-40/522 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/EIDO1 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/017 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 2-665D12 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 5-01/5D7 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/128 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 1150029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C X50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E RECEIVED STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMI ION NOV 2 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L( Repair WU Plug Perforations [] Perforate U Other Performed: Alter Casing ❑ Pull Tubi❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. ShutdoFJ Stimulate - Other ❑ Re -enter Suspended WeIfJ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 186 -172 -0 3. Address: P.O. Box 196612 Stratigraphid Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21662 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034633 EPA 2- 34/P -14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted ENDICOTT, ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 11242 feet Plugs measured None feet true vertical 10586.76 feet Junk measured None feet Effective Depth measured 1493 feet Packer measured See Attachment feet true vertical 1492.98 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 91 30" Conductor 40 - 131 40 - 131 0 0 Surface 2444 13 -3/8" 72# L -80 39 - 2483 39 - 2482.95 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10634 - 10724 feet 10732 - 10760 feet 10795 - 10840 feet 10850 - 10890 feet 10940 - 10980 feet True Vertical depth 10027.51 - 10110.26 feet 10117.59 - 10143.1! feet 10175.17 - 10216.34 feet 10225.49 - 10262.1 feet 10307.9 - 10344.62 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 5 -1/2" MCX SSSV 1511 1510.98 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8 2013 Treatment descriptions including volumes used and final pressure: FEB SCANNED ED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 14087 0 2012 Subsequent to operation: 0 0 20114 0 2185 14. Attachments: 15. Well Class after work: y Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service s Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: .,,, Oil ❑ Gas ❑ WDSF❑ GSTOR ❑ WINJ ig WAG ❑ GINJ ❑ SUSP ❑ SPLU❑ 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 Garry.Catron @BP.Com Printed Name Garry Catron � 1�,,� Title PDC PE Signature / 5114/1- ��GL/ Phone 564 -4424 Date 11/16/2012 V 1 12 1 2 Form 10 -404 Revised 10/2012 Submit Original Only • • Packers and SSV's Attachment ADL0034633 SW Name Type MD TVD Depscription 2- 34/P -14 SSSV 1511 1454.98 5 -1/2" MCX SSSV 2- 34/P -14 PACKER 10275 9645.22 4 -1/2" Baker SB3 Packer 2- 34/P -14 PACKER 10399 9756.9 4 -1/2" Baker S -3 Perm Packer Casing / Tubing Attachment ADL0034633 Casing Length Size MD TVD Burst Collapse CONDUCTOR 91 30" Conductor 40 - 131 40 - 131 LINER 1415 7" 29# L -80 9827 - 11242 9308.06 - 10586.8 8160 7020 LINER 557 3 -1/2" 9.2# L -80 10467 - 11024 9874.63 - 10385.1 10160 10530 PRODUCTION 5328 9 -5/8" 47# NT80S 38 - 5366 38 - 5363.79 6870 4760 PRODUCTION 4745 9 -5/8" 47# NT95HS 5366 - 10111 5363.79 - 9555.66 8150 5080 SURFACE 2444 13 -3/8" 72# L -80 39 - 2483 39 - 2482.95 4930 2670 TUBING 9509 5 -1/2" 17# L -80 37 - 9546 37 - 9067.76 7740 6280 • TUBING 834 4 -1/2" 12.6# L -80 9546 - 10380 9067.76 - 9795.72 8430 7500 TUBING 140 4 -1/2" 12.6# L -80 10380 - 10520 9795.72 - 9923.02 8430 7500 • Daily Report of Well Operations ADL0034633 ACTIVITYDATE I SUMMARY n • 1 - v sca • iner DRIFTED W/ 10' x 2 -1/8" STEM,10' x 2" DUMMY GUN, SAMPLE BAILER, TAGGED HARD BOTTOM @ 11,003' SLM.( no sample) 10/13/2012 ** *JOB COMPLETE, WELL TURNED OVER TO DSO * ** ** *WELL SHUT -IN ON ARRIVAL * ** INITIAL T /I /O = 200/450/50, SSV = CLOSED RAN SCMT FROM LINER TOP AT 10488' - 11020' TD TAGGED • DEPTH CORRECTED TO SLB CBT LOG DATED 12- NOV -86. USED GAMMA RAY TO CORRELATE FROM 10500'- 10670'. GAMMA RAY SIGNATURE WAS SKEWED DUE TO SCALE IN THE PERF ZONES AND DID NOT MATCH THE TIE -IN LOG. FOUND 3.5" LINER TOP AT 10488'. SCAB LINER HAS VERY GOOD CEMENT BOND. PRINT IS UPLOADED TO INTERACT FOR REVIEW BY TOWN ENGINEER BEFORE CONTINUING WITH PERF OPERATIONS LEFT WELL SHUT -IN & SECURE - SSV CLOSED - HAND OVER WITH DSO PRIOR TO DEPARTURE FINAL T /I /O = 200/450/50 10/21/2012 ** *JOB COMPLETE * ** T /I /0= 213/384/0, Temp =S /I, MIT -T PASSED to 2500 psi (Pre -pert, Post - liner) Pressured up tubing with 2 bbls of meth to reach 2535 psi. MIT -T lost 24 psi in 1st 15 minutes and 8 psi in 2nd 15 minutes for a total loss of 32 psi in a 30 minute test. Bled TP (-1 bbls). Well Tender notified of well 10/22/2012 condition upon departure. FWHP's= 200/381/0. ** *WELL SHUT -IN ON ARRIVAL * ** (E -LINE PERF) SSV CLOSED, INITIAL T /I /O = 200/450/50 RAN 2" HSD 6 SPF 60 DEGREE PHASED PJ OMEGA GUNS AND PERFORATED 10795'- 10840' • AND 10850-10890' IN FOUR RUNS. DEPTH CORRECTED TO SLB SCMT LOG DATED 21-OCT- 12. ALL SHOTS FIRED, WHP DROPPED 20 PSI ON FIRST INITIAL GUN, FROM 70 PSI TO 50 PSI, THEN STAYED AT 0 PSI FOR REST OF JOB. TAGGED TD AT 11020'. HAND OVER WITH DSO PRIOR TO DEPARTURE, WELL LEFT SHUT -IN, FINAL T /I /O = 0/450/50. 10/24/2012 ** *JOB COMPLETE * ** ** *WELL SHUT -IN ON ARRIVAL * ** (scab liner) BRUSH SVLN AT 1511' MD W/ 5 -1/2" BRUSH, 4.51" GAUGE RING. SET 5 -1/2" MCX (ser #NM -503) (1.89 bean, 35" OAL, 2nd lock down) AT 1494' SLM/1511' MD 10/27/2012 ** *WELL S/I ON DEPARTURE, WELL TENDER NOTIFIED OF STATUS * ** TREE= 7-1/16" CNN • — At NOTES: 112S READINGS AVERAGE 230 - 260 VVELLHEAD= 11" FMC EN D2-34 PPM ON A/L & GAS INJECTORS. WELL REQUIRES A ACTUATOR= OTIS-BB SSSV. KB. EP = 56.0' IJ BF. ELEV = 16.4' 1511" H 5-1/2" HES HRQ SVLN, ID = 4.562" Max Angle = 33" 6 8022' Datum MD= 10665' ctitiiiiCivo= 10000' SS 30' ( 131' GAS LFT MANDRELS 113-3/8' CSG, 72#, L-80 BTC, 13= 12.347" H 2483' ST MD ND DEV TYPE VLV LATCH PORT DATE • 2 3724 3723 3 MMG 'DMY RK 0 11/09/07 / 1 6026 6018 12 MMG DN1Y IRK 0 09/23/12 19-5/8" CSG, 47#, NT80S XO NT95HS --I 5366' 1 *STA #2= DMY HAS EXTENDED PACKNG Minimum ID = 2.80" @ 10500' ,3-1/2" QCLL RECEPTACLE 5-1/2" 1BG, 17#, L-80 TC11, H 9546' / L 9546' 1 4-1 /2. XO, 113 =3.ig18 .0232 bpf, ID = 4.892' TOP OF 7" LNR H 0827' '9-5/8" CSG, 47#, NT95HS, 13= 8.681" F--F 10110" j- di I • 1 10244' H4-1/2" HES X tsW., ID = 3,813" X XII 1 10275' H X 4-1/2' BKR SB-3 PKR N3= 3.870' 14-1/2" TBG, 12.6#, L-80 TC11, .0152 bpi,13= 3.83 -1 iO380 I • • I 10308' H4-1/2" I-ES X MP, 1) = 3.813" 1 4-1/2" TBG, 12.6#, L-80 TC11, H 10520' r 1 __- 10389' H' X 4-1/2" UNIQUE OVESHOT 1 R ' • .0152 bpf, D = 3.958" 17.1 er, 10399' - Hi" X 4-1/2" BKRS-3 FKR D = 3.833'1 PERFORATION SUMMARY 10426' 1-14-1/2" HES X NI', ID = 3.813" 1 REF LOG: DLL & OR (11/07/86) 1 10467' --1 3.70' DEPLOY SLV, 13 = 3.00' ANGLE AT TOP PERF: 24" t 10795' R , 5 1 10499' -14-1/2" HES XN NP, 0 = 3,725" Note: Refer to Production DB for historical perf data *4 r SUE I SPF ' WTERVAL ! Opri/SqzSHOT SQZ ■• • 4 I t...4 Itr44* riaiii i-- FiTi1/ 71 7CEG6° 3.958"1 5' 4 . 10634 - 10724 S 07/09/87 05/14/11 ele e/ 4 - % le, *4 • 5" 4 10732 - 10760 S 07/09/87 05/14/11 • • • • /70' - ---.4...- \ , 1(),795- 10840 S ..-07109/: 05/14/11 2" 6 1095 1 0 10/24/12 VA: ••7 2" 6 10850 - 10890 0 10/24/12 • • • • •40 f, % • • • 2-1/8' , ::-..1- •..: 0 ' ' ' 05/14/11 P I. 0' f • • N I_ K PER = 2-3/8' 4 10940- 10980 S 02/03/94 05/14/11 'Nile fier 11003 I-1 BAC DOOR FLAP VALVE, 131.00" f I • 0 . ■ % lk i Ni • • * • 11,/,■•041, 11024' - 3-1/2" PORTED TAL FVE ASSEMBLY . 11 1 ‘ 1 Z.N ' ••••• w /BULL NOSE, 13 = 2.992 0 13-1/2" TBG, 9.3#, L-80 STL, .0087 bpf, 1) = 2.972" 1-1 11003' • • ". • • ?? HPOGLM SLP (11/27/06) 1 • . . . . PBTD 11161T %.11..1■11.1.1b. ele S II %Nio.1.14, red.i.e.e■ 17 " LNR, 29#, L-80 SM-110, .0371 bpf, I)' 6.184" 1--1 11247 1■2‘...N.:00k DATE REV BY COMMENTS DATE REV BY COMMENTS 1 ENDICOTT UNIT 07/11187 — ORIGINAL COMPLETION 11/01/12 SE17.AAD REPERFS (10/24/12) , WELL: 2-34/ P-14 11130/94 015 RWO 11/19/12 PJC PERF CORRECTIONS PERMIT No: 1861720 03/31107 016 -RWO API No: 50-029-21662-00 09/26/12 TBD/JMD GLV C/O (09/23/12) SEC 36, T12N, R16E, 1969' SNL & 2256' WEL 10/01/12 ' THH/JMD SCAB LNR (09/25/12) 10/19/12 CJS/PJC .QCLL LNR (10/04/12) BP Exploration (Alaska) ...._ 1 • • t. Al chi t' _ � � � p � SEAN PARNELL, GOVERNOR Q� r it tt L ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Matt Brown Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, 2-34/P-14 Sundry Number: 312 -210 DJUN 2 9 ZU12 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '' . Foerster Chair DATED this /Q-� y of June, 2012. Encl. ' STATE OF ALASKA RECEIVED • ALA OIL AND GAS CONSERVATION COMMON JUN 0 APPLICATION FOR SUNDRY APPROVALS r G-1 2012 1 r i d 20 AAC 25.280 AJ � 1. Type of Request: Abandon Plug for RednII Perforate New Pool Repair Well ❑ Ch n O Program YP q ❑ 9 ❑ p PPS Ell Suspend ❑ Plug Perforations Er & Perforate ill,/ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: SCAB LINER QCLL 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 186 -1720 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21662 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes El No El 2-34/P-14 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 034633 • ENDICOTT Field / ENDICOTT Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11242 . 10587 ' 11160 10511 NONE UNK (11/27/06) Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 30" 40' 131' 40' 131' Surface 2444' 13 -3/8" 72# L -80 39' 2483' 39' 2483' 5380 2670 Production 5328' 9 -5/8" 47# NT -80S 38' 5366' 38' 5364' 6870 4760 Production 4734' 9 -5/8" 47# NT95HS 5366' 10100' 5364' 9546' 8150 5080 Liner 1415' 7" 29# L -80 9827' 11242' 9308' 10587' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 37 9546 - - 4 -1/2" 12.6# L -80 9546 10520 Packers and SSSV Type: 4 -1/2" Baker SB3 Packer Packers and SSSV MD and TVD (ft): 10275 9701 4 -1/2" Baker S -3 Perm Packer 10399 9813 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/15/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name Matt Brown ! Title PE Signatur - e Phone Date '`r\ �d ` �•.:. , 564 -5874 6/1/2012 Prepared byNita Sumemrhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: � ? z,10 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: - f �/� rorm iu 4us n vi ( 2 :;;;t:4_1 �i u .- auo it i uup t'(/ ORIGINA1 2- 34/P -14 186 -172 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2- 34/P -14 7/9/87 PER 10,634. 10,724. 10,027.51 10,110.26 2- 34/P -14 7/9/87 PER 10,732. 10,760. 10,117.59 10,143.19 2- 34/P -14 7/9/87 PER 10,795. 10,840. 10,175.17 10,216.34 2- 34/P -14 1/1/90 STC 10,634. 10,760. 10,027.51 10,143.19 2- 34/P -14 7/13/90 APF 10,850. 10,890. 10,225.49 10,262.11 2- 34/P -14 2/3/94 APF 10,940. 10,980. 10,307.9 10,344.62 2- 34/P -14 3/31/07 STO 10,634. 10,760. 10,027.51 10,143.19 2- 34/P -14 5/15/11 SQZ 10,634. 10,724. 10,027.51 10,110.26 2- 34/P -14 5/15/11 SQZ 10,732. 10,760. 10,117.59 10,143.19 2- 34/P -14 5/15/11 SQZ 10,795. 10,840. 10,175.17 10,216.34 • 2- 34/P -14 5/15/11 SQZ 10,850. 10,890. 10,225.49 10,262.11 2- 34/P -14 5/15/11 SQZ 10,920. 10,980. 10,289.58 10,344.62 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • TREE = 7- 1/16" CM/ • WELLHEAD = 11" FMC • SA NOTES: H2S READINGS AVERAGE 230 - 260 ACTUATOR = OTIS -BB END2-34 PPM ON A/L & GAS INJECTORS. WELL REQUIRES A SSSV. KB. ELEV = 56.0' I I BF. ELEV = 16.4' KOP = 5500' 1511' H5-1/2" HES HRQ SV LN, ID = 4.562" I Max Angle = 33° @ 8022' Datum MD = 10665' Datum TVD = 10000' SS 130" CONDUCTOR H 131' ` GAS LIFT MANDRELS .1) ST MD ND DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2483' 2 3724 3723 3 MMG DMY RK 0 11/09/07 1 6026 6018 12 MMG " "DMY RK 0 03/24/07 9 -5/8" CSG, 47 #, NT8OS XO NT95HS H 5366' 1 \ / "" STATION #1 = DMY HAS EXTENDED PACKING Minimum ID = 3/25" @ 10498' 4 -1/2" HES XN NIPPLE 5 -1/2" TBG, 17 #, L -80 TC11, -4 9546' 1 / 1 954.6' H5 -1/2" X 4 -1/2" XO, ID = 3.958" 1 .0232 bpf, ID = 4.892" TOP OF 7" LNR 1-I 9827' I---^ 19-5/8" CSG, 47 #, NT95HS, ID = 8.681" H 10110' IA ' 10244' —14 -1 /2" HES X NIP, ID = 3.813" I El 0 10275' H7" X 4 -1/2" BKR SB -3 PKR, ID = 3.870" I ( 10308' H4 -1/2" HES X NIP, ID = 3.813" I I4 -1/2" TBG, 12.6 #, L -80 TC11, .0152 bpf, ID = 3,958" I-1 10380' 1- 10389' 1--17" X 4-1/2" UNIQUE OVERSHOT 1 PERFORATION SUMMARY z 10399' H 7" X 4 -1 /2" BKR S -3 PKR, ID = 3.833" REF LOG: DLL & GR (11/07/86) �� ANGLE AT TOP PERF: 23 @ 10634' ' 1 10426' 1-14 -1/2" HES X NIP, ID = 3.813" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 5" 4 10634 - 10724 S 05/14/11 1 ( 10499' H4 -1/2" HES XN NIP, ID = 3.725" I 5" 4 10732 - 10760 S 05/14/11 5" 4 10795 - 10840 S 05/14/11 I I 10520' H4 -1/2" WLEG, ID = 3.958" 1 2 -1/8" 4 10850 - 10890 S 05/14/11 2 -3/8" 4 10940 - 10980 S 05/14/11 4 -1/2" TBG, 12.6#, L -80 TC11, .0152 bpf, ID = 3.958" H 1 10520' ?? J_JFOGLM SLIP(11 /27/06) 1 I PBTD H 11160' � + MI 17 " LNR, 29 #, L -80 SM -110, .0371 bpf, ID = 6,184" 1-1 11242' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 07/11/87 ORIGINAL COMPLETION 11/19/07 DAV /PJC GLV C/O (11/09/07) WELL: 2 -34 / P -14 11/30/94 D15 RWO J 02/24/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 1861720 03/31/07 D16 RWO 05/16/11 RMFUPJC CEMENT SQZ (5/14/11) API No: 50- 029 - 21662 -00 06/23/07 PC/PJC DRLG DRAFT CORRECTIONS 08/15/11 DW /JMD ADDED H2S SAFETY NOTE SEC 36, T12N, R16E, 1969' SNL & 2256' WEL 07/20/07 TEL/PJC GLV C/O (07/08/07) 10/23/07 JLJ /PJC GLV C/O BP Exploration (Alaska) b p • • .�� 4 ow To: C. Olsen/T. Norene J. Bixby /R. Liddelow Date: May 23, 2011 Cc: Jennifer McLeod, Pad Engineer From: Matt Brown, Wells Engineer Subject: END2 -34 QCLL Scab Liner AFE AENINJEC IOR: 400 This procedure includes the following steps: # Type Procedure 1 S Pull MCX/SBHP /Pull DGLv /Run generic GLV design 2 C Underream Liner + ASRC test separator 3 S Drift/Tag /Dummy GLVs /MITIA 4 SP Set QCLL liner- Pending passing MITIA 5 CP Run QCLL liner to bottom /cement liner /cleanout - pending previous steps 6 SP WOC 3 days. D/T with dummy gun- pending previous steps 7 EP SCMT /Rperf - pending previous steps 8 SP Run MCX Current Status SI Injector • Last Inj: 10629 BWPD 490 PSI WHIP Max Deviation 33° at 7986 ft Min ID 3.725" XN @10498' MD Last Tag: 10843' SLM 27- Jul -11 Last Downhole Op: Set MCX 31-Jul-11 Latest H2S value: No data available for well SBHP/T @10,000 SS 3803 psi / 205° ave for Endicott from recent statics SBHP/T: 3758 psi /153° on 01/28/07 most recent for 2- 34/P -14 NOTES: Sundry Needed Endicott is classified as an Elevated Risk pad. 1 Well History Well 2 -34 was drilled and completed in 1987 as a producer in the 3A2 and 2B zones. It produced until 1989, and the well was converted to injection in 1990. As an injector, a straddle over the 3A2 and upper 2B perfs was closed in January 1990, so the well was injecting only in the lower 2B zone. Additional lower 2B perfs were shot in July 1990 and 2A perfs were shot in February 1994. All of these perfs took a share of the injected produced water until a RWO in March 2007 removed the straddle and opened the 3A2 and upper 2B to injection. The production characteristics of the offset 3A2 producers suggested that this zone was getting the majority of the water and an IPROF run in Dec 2009 confirmed 60% into the 3A2 and 40% into the lower 2B. A cement squeeze was pumped on 14- May -2011 with 8 bbls behind pipe to shut off injection into the 3A2 perfs. A sqz pres of 2300 psi was obtained as well as 1:1 returns. After the squeeze, the cemented -off perfs failed a pressure test. An injectivity test established a LLR of 5 bpm at 1700 psi. An IPROF was run on 27 -July -2011 to determine the location of the leaking perfs. The IPROF results showed most of the flow entering the 3A2 zone. f A cemented scab liner is recommended to allow isolation of the 3A2 zone. Prior to running the liner, the wellbore will need underreamed to allow proper placement of the liner. The procedure calls for the QCLL system to deploy a 3 -1/2" scab liner with slick line, then coil will run the liner to TD and cement the liner in place. Eline will reperforate the 3A1 zone. Objectives The goal of this procedure is to run and cement a scab liner using the QCLL system. After the -- liner has been cemented in place, the 3A1 zone will be perforated for waterflood management. cc: w /a: Well Fite Contacts: Matt Brown Jennifer McLeod Carl Diller Bob Harris 564 -5874 (w) 564 -5764 (w) 307 - 258 -6679 907 - 240 -0427 223 -7072 (c) 907 - 529 -4702 (c) 344 -1130 (h) Attachments Wel!bore Schematic SBHP form Lau pumping form QCLL Liner tally QCLL & CTLRT diagrams Rperf form Tie in log cover page Tie in log section Integrity history 2 Job Notes • SOP: Wellwork at Elevated Risk Areas must be followed for Endicott. The SOP is available via the online PE manual in the SOPs — Wells Group folder. • There is some cement/cement stringers left over from the squeeze that need to be underreamed out. The latest tag was 10843' MD and the target depth of the underreaming is 11000. The scab liner will be run to this depth. Note that after the 3/2007 RWO, SL tagged at 11,017' on 9- Jul -07, thus the underreaming will not get as deep as any possible junk from the RWO. • The BHP will not support a column of water. To ensure proper hole cleaning while underreaming, the procedure calls for running LGLVs and using an offset well for AL during the underreaming. The returns will go to ASRC. Output from ASRC should flow to an offset producer instead of tanks in order to minimize the potential of H2S. • Carl Diller /Bob Harris will be on site to run the QCLL system on SL as well as for the CT procedure to deploy the QCLL liner & cement it in place. • Prior to running the QCLL liner with SL, the valves will be dummied off and an MITIA performed. • Cement Specifications are shown below. Note that the Key Parameters are listed; the Key Parameters are the main items to get correct for the cement blend. • BHCT is estimated to be 165 F • BHST for producers averages about 215 F. END2 -34 is an injector and the formation has undergone significant cooling over the years such that BHST is 153 F. However, the wellbore 9 9 9 Y B above the Kekiktuk will be closer to the 215 F BHST of the producers. The cement blend should be designed for BHST of 215 F so that the cement does not set up prematurely in the wellbore during the liner job. • It is recommended to use new coiled tubing for the CTLRT liner running job. A 1- 5/16" ball drift is required and new coil will avoid any potential egging that might cause the ball to hang up. • The QCLL liner volume is only about 2 bbls. If the liner wiper plug bump is not seen, then only 1 additional bbl of cement should be pumped to avoid overdisplacing cement and resulting in a wet shoe. This process will probably leave some cement in the QCLL liner that will need to be milled on the cleanout run. • The volume of cement needed to fill the annular space of the QCLL interval 10499' to 11000' is 12.5 bbls. Approximately 30% excess cement will be pumped for a total of 17 bbls to pump. • The CTLRT will have a 1 -1/8" hard ball seat for 1- 3/16" emergency disconnect (see attached diagram) 3 • • • Key CT Liner Cement -LARC Parameters Ppg: 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110 °F API fluid loss: 7 - 12 cc 1 Thickening Time: 7 hours 2 Compressive Strength: 2000 psi in 24 hrs Thickening Time Calculation 3 hrs — surface shearing /QC /safety meeting 1 hr — displace cement to liner 1 hr — contaminate 2 hrs - safety margin 7 hrs total Cement Ramp for Blend Time Temp Pressure 0:00 90 0 3:00 90 0 3:30 135 3000 4:00 165 4000 5:00 200 3000 5:30 215 3000 8:00 215 3000 Volumes: vol, Tubing top MD bot MD Size ID bbl /ft ft bbls 5 -1/2" tub 0 9546 5 -1/2" 17# _ 4.892 0.0232 9546 221.9 4 -1/2" tub 9546 10520 4 -1/2" 12.6# 3.958 0.0152 974 14.8 236.73 vol, Casing top MD bot MD Size ID bbl /ft ft bbls 7" liner 10520 10634 7" 29# 6.184 0.0371 114 4.2 7" across perfs 10634 10943 7" 29# 6.184 0.0371 309 11.5 Liner total 15.7 Wellbore Total 252.4 CT x Tubing volumes inside outside bbl /ft ft vol 1 -3/4" 5 - 1/2" 17# 0.0203 9546 193.5 1 - 3/4" 4-1/2" 12.6# 0.0122 974 11.9 4 • N,n %� %'" rj...� / %'r:" /',,' .^r:'n;'. ^ /n. ,., %:rd'�;L�w� %�' /i'� i�d' //�.i r�;�r v / 1. MIRU SL. Pull MCX. 2. Perform SBHP per attached form. 3. Pull DGLVs from the top two GLMs. Run generic GLV design 4. RDMO. 4 y ;sn., /;- c l rei ✓n;. ,,�.,,,t r•,�. >mm? Y.. rnr ,47(4 ' &%n / irr �s,W,,i�r / :1 ��..3....�. / /,n �S� . � � , / y ^ .!: % / / r:✓ % l�'�nY � ' ir;: F��• • .,.>, ., v: /� a, /' ,...:. ,ai.: ':: .'.;;r ^"%� /i .rryr ,':v' i n•.F r //F 1. MIRU CT and ASRC. 2. Jumper gas lift from offset producer to END2 -34 with a tee to pump McOH into the AL gas. 3. Line up ASRC output to offset producer. Do not flow to tanks. neat frequently 4. Start gas lift down well, taking returns to ASRC. Pump ea M eOH into IA to inhibit hydrates 5. MU BHA #1: CTC, DCV, Jars, disco, circ sub, 2 -7/8" motor, underreamer for 7" 29# liner 6. RIH performing wt checks as needed 7. Dry tag top of cement (last tag 10843') 8. PUH. Line up to pump geovis down CT. 9. Pump geovis down coil while taking returns to ASRC 10. Before underreaming fill, establish returns rate to see if 1:1 can be achieved 11. Once good returns are established, RIH underreaming 12. Underream to at least 11000'. 13. Drop circ ball. Chase returns to surface with slick KCL at 80% 14. FP coil & well 15. RDMO. • e a' 33$� s ' i tii 3 ,..% sh °'. ` h3 a ,r % y / r,/ / ypi a PAZ '2 jm' !' 1. MIRU SL. Drift and Tag to TD with 3.700" x 5' long drift. Based on tag, the last joint of the QCLL liner will be cut so that we space out and land properly in the XN. 2. Pull live GLVs from stations 1 & 2 3. Run dummy GLVs in stations 1 &2 4. Load well per attached Lau form. MITIA to 3000 psi. 5. If MITIA passes, continue with Slickline- Deploy QCLL / / n . . '� - ' ' % "..'J'�, a "h^ °^�>Ti' -^, 72a^:/'', .� %.x ",: ";� /z °a'" 35k.' "I /n / /.'/1,,�''O/./i'r/ /� � a i' >. :FO,'';' % % /,:: %r ; `+ ✓ „z;' ; '//1.'i% <n.rrr, >/f �.;,; o, •�J � <ZO,a' ;�./`''; /��i %% � �i�../ ' � ;,� 1.. , "�. ; "r •,f ' -' %,� /; .rr . ?rG, .l <, %% ;,rr'orl//,.✓^.,C'r��'s., r' ?g .,;,x. .//7// � r^ �'�. a _�.: d. h:' �, . �;� `,r /�� r.�.s�rr!, , a;,. ' %i�;�r.,.r:'�.�%�' %��1� /is'. �i�� 1. Set releasable X -lock Anchor in the X nipple at 10426'. This anchor requires an extended core to be run with an X -line running tool. The Anchor is delivered so that once set, 1600 #'s over pull at the tool is required to release. Once released, the anchor will lock in the fully open position. Test lock mechanism before setting liner. 2. Ensure all QCLL components have been drifted and are laid out in the proper running order. 3. MU QCLL running tool to shoe joint. Shoe joint will consist of QCLL mandrel, ported nipple, Hydraulic opening stage collar (set at 750 PSI), float collar, float collar, pup,landing collar, joint -20', QCLL mandrel, and running tool. 4. RIH at moderate rate slowing down at all GLM's and jewelry. Get good up and down 5 • . weights about 200' above anchor. RIH at +/- 50 FPM and engage anchor. PU < 200 #'s over previous weight to ensure QCLL Body Lock Ring (BLR) is engaged. Spang down +/- 5-10 times on Anchor to full latch QCLL. PU slowly to open spang and establish free movement from shoe joint. If over pull is noted repeat down spanging. 5. POOH. 6. MU and run remaining QCLL liner joints. These remaining joints differ slightly from the shoe joint as they have the Receptacle box down and the mandrel up. Run as per step 4. See liner tally and diagrams for components attached). 7. RDMO 1. RU CTU 2. Drift coil with 1- 5/16" ball. 3. Launch Pee Wee dart to determine exact coil volume using diesel as displacement fluid. 4. MU CTLRT BHA as per attachment. 5. RIH at moderate rate slowing down at all restrictions 6. Get good up and down weights +/- 200' above liner. RIH at +/- 50 FPM to engage QCLL. Pumping at min rate with diesel while RIH is OK, but not while stabbing onto liner. Prior to stabbing onto liner, reel valve should be open as we have a closed system below. Slack off +/- 5K at surface to engage QCLL. Pick up to neutral and close reel valve. Slowly pressure up to +/- 300 -500 PSI to verify pressure integrity of liner. Pressure up to 750 PSI to open stage collar. Pump —10 bbls down CT without taking returns to ensure that stage collar is open. 7. SD pumps and pull liner weight plus 5k over to release anchor. PUH +/- 50' to elongate anchor and position anchor in the locked open position. 8. RIH such that deployment sleeve is —50' above XN. Get good up /down weights. Slowly RIH and tag no -go on XN. Pick up a few feet above the XN. 9. Line up to pump the following fluids down the backside. Max WHP is 1500 psi. a. 5 bbl 60/40 McOH water spear b. 300 bbls 2% KCI water c. 200 bbls diesel Note: this should leave the well with about 100 psi WHP 10. RIH and land deployment sleeve on No -Go in XN nipple (or set on bottom). Slack off +/- 10K down. 11. Establish circulation by pumping down CT with backside SI, pushing fluids to formation. SD pumps and drop 5/8" release ball and circulate to ball seat as per Baker Oil Tools. Once ball has landed, pressure up CT to 2000 PSI to release CTLRT, continued pressure to 2888 psi will blow ball seat out and establish circulation. 12. SD pumps and PU CT 2 to 3 feet past breakover to verify release from liner. QCLL liner will weigh about 4500 lbs. Considering buoyancy, PU weight should be —3500 Ibs less than with QCLL liner attached. Once it is confirmed that CTLRT is released from liner, slack off and stack —10k down. 13. Batch mix and test 17 bbls pumpable LARC cement. 14. Pump fluids as follows fluids with backside shut in: a. 5 bbls fresh water spacer b. Shut in reel valve c. Displace surface lines until good 15.8 ppg cement is achieved. Open the manifold to the reel and pump the cement into the reel. Pump 17 bbls of cement. Install Pee Wee dart to displace cement and shut in reel valve. d. Displace the surface lines to 1.5# biozan. Open reel valve and chase cement with biozan 6 • • 15. Pump Pee Wee dart at 1 to 2 BPM (at about 3800 psi CT pres). As Pee Wee dart approaches CTLRT, open up backside and take returns. Monitor returns for 1:1. Continue pumping dart until it lands in the Liner Wiper Plug. Do not reduce rate when Pee Wee plugs lands in LWP. 16. Once LWP shears ( +/- 2972 PSI), pump to Landing Collar and bump plugs. a. Note: if LWP does not bump, pump no more than 1 bbl more than expected volume to bump in order to avoid overdisplacing cement and getting a wet shoe. 17. If plug bumps then a. apply 1000 PSI to plugs and hold. Bleed off coil pressure to zero and check for no flow. b. Pressure up coil to 500 PSI and pick up from liner — a pressure drop should be evident when CTLRT seal is out of deployment sleeve. 18. If plug does not bump, then unsting from liner. 19. While taking returns, POOH pumping biozan to replace voidage and contaminate cement at top of liner. Pump at voidage replacement rate plus 0.5 bpm. Monitor returns to ensure return rate is voidage replacement + 0.5 bpm. Pump bio all the way out of the hole. 20. At surface, MU BHA with 2.5" JSN. NOTE: if LWP did not bump, MU BHA with standard 2 -1/8" motor BHA: CTC /DCV /Up Jars /Disco /circ sub /2 -1/8" motor+ 2.70" mill. Wait on cement until it reaches 500 psi compressive strength based on the field blend UCA test. 21. RIH to liner top. Start 1.5# bio down CT. 22. Mill down into liner with bio. Continue milling til TD is reached. Chase returns OOH at 80% 23. FP well on way out of hole 24. RDMO Slicklitte C 1. After waiting for cement to setup for 3 days, RU Slickline and drift to TD for 2" perf guns. 2. RDMO. 1. MIRU E -line. 2. MU SCMT. 3. RIH and log SCMT across QCLL liner (10450' to TD 11000') 4. POOH. 5. MU 28 ft of 2" — 2506 Power Jet Omega guns at 6 spf 6. Shoot 10732' — 10760' MD reference SLB CBT 12- Nov -86 per attached perf form. 7. RDMO EL. z J r i G 'r .',1,,;: V• 1. MIRU. Run MCX. 2. RDMO. 7 • TREE= CIW 7- 1/16" I WELLHEAD = 11" FMC END 2 -34 , SAFETY NOTES: ACTUATOR = 011S-BB KB. ELEV = 56.0' BF. aEV = 16.4' I j KOP= 5500' I 1511' H5-1/2" HES HRQ SVLN. ID =4.562" I Max Angle = 33° @ 8022' Datum MD= 10665' I Datum TVD= 10000' SS 130" CONDUCTOR I 131' ' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG. 72 #, L -80 BTC. ID =12.347" H 2483' 2 3724 3723 3 MMG DMY RK 0 11/09/07 1 6026 6018 12 MMG ""DMY RK 0 03/24/07 19 -5/8" CSG, 47 #, NT80S XO NT95HS H 5366' I--` , *' STATION #1 = DMY HAS EXTENDED PACKING Minimum ID = 3.725" @ 10498' 4-1/2" HES XN NIPPLE 5 -1/2" TBG, 174, L -80 TC11, — I 9546' I / I 9546' H5 -1/2" X4 -1/2" XO. ID= 3.958" I N. .0232 bpf, ID = 4.892" I TOP OF7 "LNR 982T I r • I9 -5/8" CSG, 474. NT95HS, ID = 8.681" H 10110' IA ' 10244 -14-1/2" HES X NIP. ID = 3.813" I pl 14 10275' H7" X 4 -1/2" BKRSB -3 PKR, ID= 3.870" 1 ' I 10308' H4-1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.64, L -80 TC11, .0152 bpf, ID = 3.958" H 10380' 10389' H7" X 4-1/2" UNIQUE OVERSHOT I PERFORATION SUMMARY g 10399' H7" X 4 -1/2" BKR S -3 PKR ID = 3.833" I REF LOG: DLL & GR (11107/86) ANGLE AT TOP PERF: 23 © 10634' ' I 10426' H4-10 HES X NIP, ID = 3.813" Note' Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn;Sgz DATE 5" 4 10634 - 10724 O 07/09/97 , I 10499' 1-14-1/2" HES XN NP. ID = 3.725" I 5" 4 10732 - 10760 0 07/09/87 5" 4 10795 - 10840 0 07/09/87 1 I 10520' H4 -1/2" WLEG, ID = 3.958" I 2 -1 /8" 4 10850 - 10890 0 07/13/90 2 - 3/8" 4 10940 - 10980 0 02/03/94 ' 10522' ELMD Logged 27 Sep - 08 SLB RST (Sigma Pass #3) 14-1/2" TBG, 12.64, L -80 TC11..0152 bpf , ID = 3.958" 1--I 10520' ' ?? H POGLM SLIP (11!27/06) 1 + PBTD —I 11160' 'Al 4 4 1 •"• 4. 17 " L NR, 294, L-80 SM-110, .0371 bpf, ID =6.184" H 11242' ��' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 07/11/87 ORIGINAL COMPLETION 11/19/07 DAV /PJC GLV C/O (11109/07) WELL: 2 -34 / P -14 11/30/94 015 RWO PERMIT No: 1861720 03/31/07 D16 RWO API No: 50- 029 - 21662 -00 06/23/07 PCiPJC DRLG DRAFT CORRECTIONS SEC 36, T12N. R16E 1969' SNL & 2256' WEL 07;20/07 TEL /PJC GLV G/0 (07/08/07) 10/23/07 JLJ /PJC GLV C/O BP Exploration (Alaska) 8 • • STATIC BOTTOM -HOLE PRESSURE SURVEY Ver14, Rev 08/12/2004(JDM) Well: END2 -34 API #: 50- 029 -21662 Date: 5/14/12 Prod Engr Jennifer McLeod Office Ph: 564 -5764 H2S Level: Cost Est: $15,000 Home Ph: no data CC orAFE: AENINJEC Cell/Pager: 529 -4702 WBL Entries Type Work Description Comments S SBHPS :Perform SBHP to deviation. Min 4 day SI. Well Objectives, Logging Notes, and Special Instructions: This SBHP is needed to determine pressure for the upcoming QCLL scab liner job Minimum ID = 3 725" at 10498' Datum: 10,000' TVDss / 10665 I Well Data Procedure: Last Tag 10843' MD (7oDeg) Tag date: 7/27/2011 1. Make 10 min pressure stop in lubricator Max Deviation 33 Degs Depth 7986' MD 2 D &T as deep as possible. Adjust stops accordingly 3. RIH slighly below the first pressure -stop requested. Pull-up to specified depth Min SI Time. 24 h I Logging Data 4. Get stop data at the 4 specified depths 5. POOH and get 10 min pressure in lubricator at 3000psi 6. Check for good data Requested Stops: MD SS Time 7 ROMO 1st 10665' - 10000' 30 min 2nd 10111' -9500' 10 min 3rd 9532' -9000' 10 min 4th 8940' -8500' 10 min 5th NA Summary Dist Well: END2 -34 API #: 50 -029 -21662 PE Town Date: Anch Prod Engr Service Co. New Tag: 'MD P.D. Center Upper Lower Date Time MD SS Gauge Gauge Temperature Test Gauge Pre -Job Lubricator Pressure 10665' - 10000' 10111' -9500' 9532' -9000' 8940' -8500' Post -Job Lubricator Pressure Type of Pressure Tool SITP (Tubing) psig SICP (9- 5/8 "): Shut In Date: . Comments: and Time: Total Shut In Time (hrs) 9 • • Fullbore Pumping Program for Field Well Name END2 -34 Job Scope L&K Well Type PWI AFE AENINJEC Date 5/22/2012 IOR 400 Engineer _ Jennifer McLeod Phone 907 - 564 -5764 H2S Job Objective Load IA in prep for MITIA. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Spear Methanol (60/40) IA 5 I I 5 2000 2 Load inhibited SW I IA 156 ( 5 2000 3 Freeze Protect inhibited 60/40 I IA 110 ( I 5 2000 4 Select Stage I 5 I I I Detailed Pumping Procedure NOTES: It is expected that the IA fluid level will be at the second GLM. Additional Details Recent Tbg Fluid Level (ft) Integrity Issues? Recent IA Fluid Level (ft) Recent OA Fluid Level (ft) 10 • • Liner Tally Tally total 501.17 bot top Bottom to top 11000 10994.00 6. ft 3 -1/2" Tail pipe 10994.00 10992.65 1.35 ft 4 -1/2" Anchor Length of mandrel + 10992.65 10991.04 1.44 ft 3 -1/2" QCLL receptacle receptacle 10991.04 10991.04 1.02 ft 3 -1/2" QCLL Mandrel is 1.61' 10991.04 10990.04 1. ft 3 -1/2" STL ported nipple 10990.04 10970.04 20. ft 3 -1/2" STL shear out sub 10970.04 10968.04 2. ft Baker float collar 10968.04 10966.04 2. ft Baker float collar 10966.04 10965.04 1. ft 3 -1/2" STL Pup joint 10965.04 10964.04 1. ft Baker landing collar Adjust this length based on 10964.04 10961.04 3. ft 3 -1/2" STL Pup joint tag 10961.04 10960.02 1.02 ft 3 -1/2" QCLL Mandrel 10960.02 10928.41 31.61 ft 3 -1/2" QCLL liner section QCLL secl 10928.41 10896.80 31.61 ft 3 -1/2" QCLL liner section QCLL sec2 10896.80 10865.19 31.61 ft 3 -1/2" QCLL liner section QCLL sec3 10865.19 10833.58 31.61 ft 3 -1/2" QCLL liner section QCLL sec4 10833.58 10801.97 31.61 ft 3 -1/2" QCLL liner section QCLL sec5 10801.97 10770.36 31.61 ft 3 -1/2" QCLL liner section QCLL sec6 10770.36 10738.75 31.61 ft 3 -1/2" QCLL liner section QCLL sec? 10738.75 10707.14 31.61 ft 3 -1/2" QCLL liner section QCLL sec8 10707.14 10675.53 31.61 ft 3 -1/2" QCLL liner section QCLL sec9 10675.53 10643.92 31.61 ft 3 -1/2" QCLL liner section QCLL sec10 10643.92 10612.31 31.61 ft 3 -1/2" QCLL liner section QCLL sec11 10612.31 10580.70 31.61 ft 3 -1/2" QCLL liner section QCLL sec12 10580.70 10549.09 31.61 ft 3 -1/2" QCLL liner section QCLL sec13 10549.09 10517.48 31.61 ft 3 -1/2" QCLL liner section QCLL sec14 Adjust this length based on 10517.48 10504.48 13. ft 3 -1/2" STL pup joint tag 10504.48 10503.98 0.5 ft Fluted no -go 3.7" x 3" Deployment 10503.98 10497.98 6. ft sleeve 10499 XN, top liner 11000 TD, after UR 501 total ft 11 • . END2 -34 3 %:" QCLL BHA Detail S tandard Baker CTLRT Run on 1.75" CT 3.700" 6.00' 3.000" Deployment Sleeve 3.700" X 3.00" Pee Wee Plug l 4" "GS" Profile f/15/16" Latch 3.790" 1 .5' Fluted No-Go 3.38" I 4 3,500" --r f * 1.03' Coil Connector i 1,50" 2.25" 5P SA Pup Joint 2.972" 2.00' 31/2" STL 3 .44' X -Over - 1.50" ' 1.38' Swivel 3.700" 1.44' 3'/z" QCLL Receptacle 3.50" 2 3/8" IF B x P 2.960" 1.50" v • * *See Page 2 for QCLL Assembly Detail ** Hydraulic Disconnect 3.63" • 2. 5' 1 5/16" Ball Seat This Box contains S/L 1.25" 2 3/8" IF B x P 2.800" deployed components 1.02' 3' /z" QCLL Mandrel _ 5500 PSI Rupture Disk 3.700" 3.500" - I 20.00' 3 STL Pup Jt 2.972" 3 . 50 " CTLRT 3.500" 1.50" 4 . 00 ' 2 3/8" IF Box 1.810" 1.00' Baker Landing Collar 2000PS1 Release - 3.500" 1.00' 3' /z" STL Pup Jt c. 2.972" 3.500" 2.00' (2) Baker Float Collar 2.972" Y 3.500" - 1 3' /z" STL Shear Out Sub 2.800" 750 P51 to Sheer 1 1/8" Hard Bali Seat for 3.500" - 1 3116" Emergency Disconnect Ball 1.00' 3' /z" STL Ported Nipple 2.972" �-O _ 3.700" 2.800" 1.02' 3' /z" QCLL Mandrel 5/8" Ball Seat 2888 PSI Release 3.700" 3' /z" QCLL Receptacle -ii Liner Wiper Plug 1.44' `+ 2972 PSI Release I 2.960" The equipment lengths, OD's and ID's on 3.700" - i t this page are for liner tally purposes. 1.35' 4' /z" Anchor Dimensional drawing for Baker BHA is on 2.79" = , I file. The equipment is set up to use the ■ following operational pressures: 1. CTLRT Release 2000psi 3.500" ® 2. Ball Seat shear Out 2888psi ® 6.00' 3 /z Tail Pipe Assembly 3. Shear Liner Wiper Plug 2972psi 2.977' ® i ' To Pull Seal from Dep Sleeve ' To Pull LWP from Dep Sleeve 12 • II END2 -34 3'/" QCLL BHA Detail Standard Joint Run on S/L Additional QCLL Assembly Detail • 3 W' QCLL Mandrel 2.800" 3.700 " — .17' A This Assembly x 15 3.500" 3'/:" STL Tubing 2.972" 30.00' B x P V 11 3.700" — 1.44' 3' /" QCLL Receptacle 2.960" 13 • bp PERFORATING PERFORATING PROCEDURE Well: END2 -34 API #: 50- 029 - 21662 -00 Date: 3/3/2011 Prod Engr Jennifer McLeod Office Ph: 564 -5764 H2S Level: Home Ph: No data Cost: Cell /Pager: 529 -4702 CC or AFE: AENRO2WL34 IOR: 400 WBL Entries IOR Type Work Desciption Priority /Comments 1 400 E Perf 28 2 Well Objectives and Perforating Notes: Attachment: Reference log with proposed perfs annotated, 5 '/100' scale Reference Log Tie in Log Add 0 feet Log: DLL/MSFL CBT to the tie -in log to be on Date: 11/7/1986 11/12/1986 depth with the reference log. Company: SLB SLB Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re /Iperf 10,732' - 10,760' 10,732' - 10,760' 28 6 Random 60° K2 Rperf Requested Gun Size: 3 -3/8" Charge: 3406 PowerJet, HMX Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown /Suggestions to Achieve Drawdown NA Last lnj: 16,500 BWPD 2,100 WHIP Last Tag: 10,943 ft MD on 12/1/2009 Est Res. Pres. @ 10,000 SS is 3758 psi Perforation Summary Summary Dist Well: END2 -34 Town: Date: API #: 50 -029- 21662 -00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf /Reperf O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - ............... O /B /U - O /B /U - O /B /U - 14 W ono 4MWb and rM1 0 r awn n •-• Daa O4MM ca * �1 orI M O 4O•-• M o -4 444444 'Is"0'ti 2•1 r mP'fm n n D7eM r = pp 1' A w -01 MCI's 4N0 2 A 1 more A DO ' O • i w -c • -4 re 8-4 m•4 m w w »°C-/ • 1mr m--ozm *�dmoa DM mm-xi M 2-4 •-a D2M fill 0 •D <X • !'! . 4OC r02 1 -4 - ra D 2 Q•* D* W D rr '+ 1DOt1• 0' 0 -_i• -' *• 2 -r O D 4 • A DO M a • 2 2< C =IIM 0-4 1 X +0 • ■.■n• 0 •M 2 V2 r4 •-• W Ni 0 r@ .. r .. < w -0-0- O 46 • a two q....... V •+P0 M r o0 • ° 0 X X X 1 M D M D 0 i • • • • • W M W . 0 2 044 ••'/ x o 0 0000 D • • 1 '*i ti • G ~ _ � n r '*1 '•i ••1' i W "' � .� 2 '' PI 0 1 OMV • r c o Of 0 011 X -4 M 1 o ro M M M = 2 0 • 'OH r 0 o - MU r- ' c r n r r '•1 o•- --'» o 0 0 W pr . M 1 2 2 • • • 0 0 w 0 • • • (moo r u) • - .. . 1.; -, . ''' 1 . ', L! r * : : ,...„ : .. . ,tc , :', ' 4: :. : i • s • t 1060D r It.i 1 . so 11 r ill 1 * I_ B C 13T - av ! k perf interv . ;. - 1 10732 -10760 MD I, , ,,,,,,..: 1 _ r 4, ,._ , . z.., .. .. : , ‘,.,,,,_... 10700 - . , 7 \ , L . , ,_ ► y . MI {r r , . ....,,..., , t t. ._ , . i . , , ,, . , . • .. , . r . - . j. 1 MEE 1 0$00 !1 . . .. 1 1... 4 ; : : ; .1. [...._ : , e . , ,, I 1 16 • • RWO completed 03/31/07 > 03/01/04: SL set TTP in nip reducer > 03/02/04: CMIT Passed to 3500 psi. > 03/13/04: MITOA Passed to 3360 psi > 03/13/04: LDL ID'ed leaks from 660' -1132' > 03/15/04: TTP pulled > 05/18/04: Operator call -in possible BH leak > 05/27/04: Mailed Sundry 10 -403 to Winton > 06/06/04: No apparent BH leak > 07/20/04: AOGCC denied sundry (06/28/04) > 08/31/04: Request for Admin Approval > 09/16/04: AOGCC approved AA for PWI with TxIA comm > 01/21/05: Operator call -in possible BH leak > 01/22/05: No BH leak apparent > 03/12/05: MITOA Passed to 3360 psi > 11/26/05: MITOA Passed to 3360 psi > 11/27/05: TTP set @ 9600', AOGCC CMIT TxIA Passed to 3360 psi > 11/28/05: Pulled TTP > 12/31/05: TxIA waiver revised > 02/18/06: PPPOT -T Passed to 5000 psi > 03/11/06: TxIA waiver revised > 03/19/06: PPPOT -IC Failed, unable to press up > 04/19/06: Waiver updated for 2500 psi IAP > 06/17/06: DHD finds fluid at 4 to 6 o'clock position on upper bradenhead. Bubbling in cellar at 9 o'clock position. > 08/02/06: MITOA Passed to 3360 psi > 11/15/06: Set TTP @ 9600'; CMIT -TxIA Failed; pulled TTP > 11/16/06: Set TTP @ 9600' > 11/23/06: CMIT -TxIA Failed, LLR =5.5 gpm > 11/27/06: Set TTP @ 9600' > 12/23/06: CMIT -TxIA Passed to 3360 psi > 12/31/06: AOGCC CMIT -TxIA Passed to 3360 psi > 01/08/07: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3000 psi, LDS Functioned > 01/18/07: AA cancellation sent to AOGCC > 01/20/07: Cancelled waiver due to RWO > 01/28/07: Pulled patch, TTP, nipple reducer > 01/28/07: Caliper 67 jts 40 -85% and 1 jt >85% > 02/13/07: Set CIBP © 9607' MD > 02/26/07: MITOA passed to 2000 psi > 03/28/07: Set TTP @ 5608' SLM > 07/08/07: Pulled DSSSV from 1511', Pulled DGLV from STA # 2 > 07/09/07: Pulled RHC, Set TTP @ 10499', CMIT -TxIA Passed to 2500 psi > 10/16/07: PPPOT -IC Passed to 3000 psi; Tbg and IA circed with 2% KCI > 10/17/07: BH weld complete > 10/19/07: MITOA Passed to 1200 psi > 10/23/07: Set DGLV in sta #2 > 10/24/07: Pulled TTP from 10499' 17 • • > 11/04/07: Notified AOGCC of IA repressurization > 11/09/07: Re -set DGLV in sta #2, MITIA Passed to 2500 psi > 11/13/07: AOGCC MITIA Passed to 2700 psi > 05/11/08: MIT -OA w/ N2 Passed to 500 psi > 01/01/09: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3500 psi, LDS OK > 01/13/09: TIFL Passed pre -rig for END2 -30 > 12/01 /09: Re -set SSSV@ 1511' 18 • bp BP Exploration (Alaska) Inc. " ;, Attn: Well Integrity Coordinator, PRB -20 r Post Office Box 196612 Anchorage, Alaska 99519 -6612 '‘h May 22, 2012 5VF SE.I tip l i ►lrr. 0 Mr. Jim Regg �j 1 34\ Alaska Oil and Gas Conservation Commission � 333 West 7 Avenue 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, r / e_ 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 1 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 50029,29980200 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 / 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 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 1'5C•172 za0R6 Moberg" 24 -AUG -2011 Mob� e' g No. 5782 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 • Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 11 -09A BCRC -00086 PPROF WI DEFT & GHOST 16-Jul-11 1 1 MPJ -15 BD88 -00141 IPROF 25-Jul-11 1 1 MPJ -18 BCRC -00108 (PROF 24-Jul-11 1 1 MPI -08 BAUJ -00096 IPROF 26-Jul-11 1 1 3411K -32 BBSK -00082 PPROF WI DEFT & GHOST 26-Jul-11 1 1 M -08 BCRJ-00104 SBHPS 8- Aug -11 1 1 01 -28A BUTT -00001 PPROF W/ DEFT & GHOST 2 -Aug -11 1 1 01 -28A BUTT -00001 CEMENT BOND LOG 3- Aug -11 % 1 1 r.") 2- 34/P -14 Z -12 V-03 BCRC -00109 IPROF 2727-Jul-11 11 1 1 BJGT -00058 IPROF 2- Aug -11 1 1 BG4H -00066 SBHPS 29-Jul-11 1 1 W-34A BINC -00054 PRIMARY DEPTH CONTROL 26-Jul-11 1 1 17.02 AWJI -00151 PPROF WIDEFT 14-Jul-11 1 1 A -11 BSM4 -00018 IPROF 1- Aug -11 1 1 P1 -07A AWJI -00152 XFLOW 8- Aug -11 1 1 F -29A BG4H -00072 SBHPS 10- Aug -11 1 1 11-11 BBSK -00085 PPROF W /DEFT 1-Aug-11 1 1 Z -06 BD88-00146 TEMP SURVEY 3- Aug -11 1 1 Z -20 BBSK -00085 SBHPS 31-Jul-11 1 1 MPF -13 BUTT -00003 (PROF 9- Aug -11 1 1 MPL -15 BUTT -00003 IPROF 5- Aug -11 1 1 MPK -33 BJGT -00056 USIT 30-Jul-11 Z I 1 L2 -18A AWJI -00153 LEAK DETECTION LOG 11- Aug -11 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 - 2525 Gambell Street, Suite 400 It 900 E. Benson Blvd. Anchorage, AK 99503 -2838 .D JUL (,,°' 2 Zd�f STATE OF ALASKA ALASKA APAND GAS CONSERVATION COMMISSIOO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other J Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ Cement Squeeze 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ . 186 -172 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21662 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 034633 _ 2- 34/P -14 10. Field /Pool(s): ENDICOTT Field /ENDICOTT Pool 11. Present Well Condition Summary: Total Depth measured 11242 feet Plugs (measured) None feet true vertical 10587 feet Junk (measured) UNK (11/27/06) feet Effective Depth measured 11160 feet Packer (measured) 10275 10399 feet true vertical 10511 feet (true vertical) 9701 9813 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 30" 40 - 131 40 - 131 Surface 2444' 13 -3/8 ", 72 #, L -80 39 - 2483 39 - 2483 5380 2670 Production 5328' 9 -5/8 ", 47 #, NT -80S 38 - 5366 38 - 5364 6870 4760 Production 4734' 9 -5/8 ", 47 #, NT95HS 5366 - 10100 5364 - 9546 8150 5080 Liner 1415' 7 ", 29 #, L -80 9827 - 11242 9308 - 10587 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - z_ _ i1 True Vertical depth: _ - - JUN c� Z011 Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 37 -9546 37- 9068 4 -1/2" 12.6# L -80 9546 -10520 ` p 9058 -9923 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SB3 Packer 10275 �ct?- 9701 4 -1/2" Baker S -3 Packer Ui s99 9813 RECEIVE 12. Stimulation or cement squeeze summary: Intervals treated (measured): MN r , Treatment descriptions including volumes used and final pressure: y : O ; '`reprbgG 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 11625 1894 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p Service la Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR p WIND In 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: 311 -122 Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature 1, /��U- Phone (907) 564-5674 Date 6/20/2011 RBCMS JUN P 6.z2-1( . Z�� 614, a�I Zgt� It Form 10 -404 Revised 10/2010 Submit Original Only END2- 34/P -14 186 -172 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2- 34/P -14 7/9/87 PER 10,634. 10,724. 10,027.51 10,110.26 2- 34/P -14 7/9/87 PER 10,732. 10,760. 10,117.59 10,143.19 2- 34/P -14 7/9/87 PER 10,795. 10,840. 10,175.17 10,216.34 2- 34/P -14 1/1/90 STC 10,634. 10,760. 10,027.51 10,143.19 2- 34/P -14 7/13/90 APF 10,850. 10,890. 10,225.49 10,262.11 2- 34/P -14 2/3/94 APF 10,940. 10,980. 10,307.9 10,344.62 2- 34/P -14 3/31/07 STO 10,634. 10,760. 10,027.51 10,143.19 2- 34/P -14 5/15/11 SQZ 10,920. 10,980. 10,289.58 10,344.62 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE I • • • END2- 34/P -14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTwITYDATE - N �,. 1 , , 1- 5/6/2011,T/1/0=1500/200/20 SBG treatment Pumped 5 bbls meth followed by 260 bbls SBG mixture down tbg. Pumped 3 bbls meth to flush and FP surface lines. Pumped 198 bbls of fresh water down TBG to displace SBG. FP TBG with 12 bbls ; meth. Let soak 3 hrs. Pad op notified to POI at 13:00 pm FWHP= 1200/160/20 5/10/2011 * ** WELL INJECTING ON ARRIVAL * ** (pre sqz) DRIFTED TO MCX @ 1490' SLM (1511' MD) W/ 4.60" G- RING. PULLED 5 1/2" MCX ON CARRIER (SER #NM -501, 1.89" BEAN) FROM HRQ NIP 1 @ 1511' MD. DRIFTED TBG W/ TEL, 3.50" CENT & S.BAILER, TAG TT @ 10,492' SLM ( +28' = ;10,520' MD), TAG SOFT TD @ 10,915' SLM ( +28' = 10,943' MD). —37' OF FILL ABOVE LOWEST PERF. RECOVERED SCHMOO. * ** LDFN. WELL BACK ON INJECTION * ** 5/11/2011 * ** CONT FROM 5/10/11 WSR, WELL INJECTING ON ARRIVAL * ** RAN PDS 40 ARM CALIPER FROM TD @ 10,890' SLM TO SURFACE, GOOD DATA. * ** JOB COMPLETE. WELL INJECTING ON DEPARTURE * ** 5/13/2011 CTU #8 w/ 1.75" CT (CTV 35.1) Scope: Injector profile modification (cement sqz) Move from 12 -36. MIRU 3 • • 5/14/2011 CTU #8 w/ 1.75" CT (CTV 35.1) Scope: Injector profile modification (cement sqz) Finish RU. Conduct BOPE test w/ no failures. RIH w/ 2.5" assy. Tag soft fill at 10955' , puh flag at 10945'. PUH to 10470'. Load CTBSw/ 2% KCL and followed by 175 bbls diesel. Pump 35 bbls G cement w/ latex and squeeze away -8 bbls,. but could not build whp above 2300 psi. Had 1/1 returns. Dilute cement w/ biozan 5/15/2011 CTU #8 w/ 1.75" CT (CTV 35.1) Scope: Injector profile modification (cement sqz) RIH diluting cement w/ biozan and clean out to 10920' CTM. POH jetting to surface. Had 5 gal diesel spill. FP CT and 200' of wellbore w/ 50/50 McOH. Left 500 psi on well. RDMO to planned maintenance **job complete ** FLUIDS PUMPED BBLS 260 SBG MIXTURE 223 FRESH WATER 26 NEAT METH 397 1% KCL 5 50/50 McOH 35 CEMENT 120 BIOZAN 1066 TOTAL + TREE= 7- 1/16" CM/ I WELLHEAD = 11" FMC END2-34 SAFETY N s: WELL REQUIRES A SS SV. ACTUATOR = OTIS -BB _KB. ELEV = 56.0' I I BF. ELEV = _ " 16.4' KOP = 5500' I 1511' I - 1 5-1/2" HES HRQ SVLN, ID = 4.562" 1 Max Angle = 33° @ 8022' • Datum MD = 10665' Datum ND = 10000' SS 130" CONDUCTOR H 131' , GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" H 2483' 2 3724 3723 3 MMG DMY RK 0 11/09/07 1 6026 6018 12 MMG **DMY RK 0 03/24/07 19-5/8" CSG, 47 #, NT8OS XO NT95HS H 5366' P / ** STATION #1 = DMY HAS EXTENDED PACKING Minimum ID = 3.725" @ 10498' 4 -1/2" HES XN NIPPLE 5 -1/2" TBG, 17 #, L -80 TC11, — 9546' I I 9 H5 -1/2" X 4 -1/2" XO, 0 = 3 . 9 5 8 " 1 .0232 bpf, ID = 4.892" 'TOP OF 7" LNR H 9827' I ;,„ M 19 -5/8" CSG, 47 #, NT95HS, ID = 8.681" 1-1 10110' 1--+I ' 10244' —14 -1/2" HES X NIP, ID = 3.813" 1 z e 10275' 1 - 17" X 4 -1/2" BKR SB -3 PKR, ID = 3.870" 1 10308' 1- -I4 - 1/2" HES X NIP, ID = 3.813" 1 I4 -1/2" TBG, 12.6 #, L -80 TC11, .0152 bpf, ID = 3.958" 1-I 10380' I 10389' 1 - 1 7" X 4 -1/2" UNIQUE OVERSHOT 1 PERFORATION SUMMARY H I 10399' H7" X 4 -1/2" BKR S -3 PKR, ID = 3.833" 1 REF LOG: DLL & GR (11/07/86) ANGLE AT TOP PERF: 23 @ 10634' ' I 10426' H4-1/2" HES X NIP, ID = 3.813" 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 5" 4 10634 - 10724 S 05/14/11 ' I 10499' 1-14-1/2" HES XN NIP, ID = 3.725" 1 5" 4 10732 - 10760 S 05/14/11 5" 4 10795 - 10840 S 05/14/11 i 1 10520' H4 -1/2" WLEG, ID = 3.958" I 2 -1/8" 4 10850 - 10890 S 05/14/11 2 -3/8" 4 10940 - 10980 S 05/14/11 C t'..-- I- 14 -1/2" TBG, 12.6 #, L -80 TC11, .0152 bpf, ID= 3.958" 1-1 10520' < c � ' k5 per I FBTD I-1 11160' �♦��„' v ;a1 ., ?? 1-I POGLM SLIP (11/27/06) 1 I7 "LNR, 29 #, L -80 SM -110, .0371 bpf, ID = 6.184" 1--I 11242' 444 ■4464 DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNfT 07/11/87 ORIGINAL COMPLETION 11/19/07 DAV /PJC GLV C/O (11/09/07) WELL: 2 -34 / P -14 11/30/94 D15 RWO 02/24/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 1861720 03/31/07 D16 RWO 05/16/11 RMH/PJC CEMENT SQZ (5/14/11) API No: 50- 029 - 21662 -00 06/23/07 PC/PJC DRLG DRAFT CORRECTIONS SEC 36, T12N, R16E, 1969' SNL & 2256' WEL 07/20/07 TEL /PJC GLV C/O (07/08/07) 10/23/07 JLJ /PJC GLV C/O BP Exploration (Alaska) April 2011 AOGCC MIT Forms: NGI (1750690), WGI -06 (1900300), ENT .34 (1861720), ... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, May 03, 2011 5:27 PM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: April 2011 AOGCC MIT Forms: NGI -04 (1750690), WGI -06 (1900300), END 2 -34 (1861720), NS17 (2021690), P2 -28 (1950440), S -123 (2041370), V -100 (2010590), V -214 (2051340), W -42 (1880570), W- 44 (1891000), W -212 (2020660), Z -33A (1890050), MPF -92 (1981930) Attachments: April 2011 MIT Forms.zip Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: NGI -04 (PTD #1750690) GI -06 (PTD #1900300 ,/END 2 -34 LEI® #1861720) NS17 (PTD #2021690) P2 -28 (PTD #1950440) S -123 (PTD #2041370) V -100 (PTD #2010590) V -214 (PTD #2051340) W-42 (PTD #1880570) W-44 (PTD #1891000) W -212 (PTD #2020660) P" 1 2.01 Z -33A (PTD #1890050) MPF -92 (PTD #1981930) MPF -95 (PTD #1981790) MPI -09 (PTD #2001030) MPS -07 (PTD #2020720) MPS -13 (PTD #2021140) «April 2011 MIT Forms.zip» Thank you, Mehreen Vazir (Alteraate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 5/9/2011 II • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoci alaska.gov: doa .aoacc.prudhoe.bay(malaska.gov; phoebe.brooksaalaska.gov; tom.maunder(rDalaska.gov OPERATOR: BP Exploration (Alaska), Inc. 'q f l7( it FIELD / UNIT / PAD: Prudhoe Bay / ACT / END2 ( II DATE: 04/07/11 OPERATOR REP: Gerald Murphy AOGCC REP: Declined to witness by Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2- 34/P -14 Type Inj. W TVD 9,701' Tubing 2150 2150 2150 2150 Interval 4 P.T.D. 1861720 ' Type test P Test psi ' 2425 Casing 580 3010' 3010 3010 - P/F P Notes: 4 -year MITIA to 2700 psi - OA 140 380 370 370 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT ACT END2 - 34 04 07 11.xls • • SEAN PARNELL, GOVERNOR TlaffEE (IF ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Matt Brown Petroleum Engineer k (‘) BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, 2-34/P-14 Sundry Number: 311 -122 o mittED App LO Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holid. , or weekend. •' e Co i• e DATED this day of April, 2011. Encl. ,_- RECEIVED' STATE OF ALASKA 411 ALASKA /AND GAS CONSERVATION COMMISS r` 2 ,11 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .K./N•ll \f;ackt 111 'i ;an . COMMISsioi1 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Apprgye&P,rp9ram ❑ Suspend ❑ Plug Perforations ❑ Perforate FE Pull Tubing ❑ Y Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: CEMENT SQUEEZE - IS 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 186 -1720- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service o , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21662- 00 -00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ 2-34/P-14 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 034633- ENDICOTT Field / ENDICOTT Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11242 • 10586.76- 11160 10510.8 NONE UNK(11/27/06) Casing Length Size MD TVD Burst Collapse Structural Conductor 91' 30" 40 131 40 131 Surface 2444' 13 -3/8" 72# L -80 39 2483 39 2483 5380 2670 Production 5328' 9 -5/8" 47# NT -80S 38 5366 38 5364 6870 4760 Production 4734' 9 -8/8" 47# NT95HS 5366 10100 5364 9546 8150 5080 Liner 1415' 7" 29# L -80 9827 11242 9308 10587 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5 -1/2" 17# L -80 37 9546 - 4 -1/2" 12.6# L -80 9546 10380 - - 4 -1/2" 12.6# L -80 10380 10520 Packers and SSSV Tvoe: 5 -1/2" HES HQR SVLN Packers and SSSV MD and TVD (ft): 1511 1511 4 -1/2" BKR SB -3 PKR 10275 9701 4 -1/2" BKR S -3 PKR 10399 9813 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/25/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El- GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name Title PE Matt 9's Signature � / Phone Date 564 -5874 4/11/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ t , - G a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /d. 110 /* APPROVED BY I Approved by: • MISSIONER THE COMMISSION Date: / 7 APR `� C 7"— ? ry. fj, Form 10 -403 Revised T BD S A R R , t I I A L Cr' { ,, Submit in Duplicate 2- 34/P -14 186 -172 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2- 34/P -14 7/9/87 PER 10,634. 10,724. 10,027.51 10,110.26 2- 34/P -14 7/9/87 PER 10,732. 10,760. 10,117.59 10,143.19 2- 34/P -14 7/9/87 PER 10,795. 10,840. 10,175.17 10,216.34 2- 34/P -14 1/1/90 STC 10,634. 10,760. 10,027.51 10,143.19 2- 34/P -14 7/13/90 APF 10,850. 10,890. 10,225.49 10,262.11 2- 34/P -14 2/3/94 APF 10,940. 10,980. 10,307.9 10,344.62 2- 34/P -14 3/31/07 STO 10,634. 10,760. 10,027.51 10,143.19 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE IIII • by tiz` OW 4 10 1 To: C. Olsen/T. Norene J. Bixby /R. Liddelow Date: March 2, 2011 Cc: Jennifer McLeod, Pad Engineer From: Matt Brown, Wells Engineer Subject: END2 -34 CT Cement Squeeze Est. Cost: AFE AENRO2WL34 IOR: 400 This procedure includes the following steps: # Type Procedure 1 F Schmoo Be Gone 2 S Pull MCX. Caliper Liner & Tubing/ Tag 3 C Cement squeeze. 4 S WOC 7 days. D/T with dummy gun 5 F Injectivity test. 6 EP Rperf pending successful injectivity test Current Status On Injection Last Inj: 12369 BWPD1852 PSI WHIP Max Deviation 33° at 7986 ft Min ID 3.725" XN @10498' MD Last Tag: 10943' during MSTP on 1- Dec -09 (37' fill) Last Downhole Op: 1- Dec -09 D/T MSTP Latest H2S value: No data available for well SBHP/T @10,000 SS 3881 psi / 215° ave for Endicott from recent statics SBHP/T: 3758 psi /153° on 01/28/07 most recent for 2- 34/P -14 NOTES: Sundry Required for Squeeze Endicott is classified as an Elevated Risk pad. Well History Well 2 -34 was drilled and completed in 1987 as a producer in the 3A2 and 2B zones. It produced until 1989, and the well was converted to injection in 1990. As an injector, a straddle over the 3A2 and upper 2B perfs was closed in January 1990, so the well was injecting only in the lower 2B zone. Additional lower 2B perfs were shot in July 1990 and 2A perfs were shot in February 1994. • • All of these perfs took a share of the injected produced water until a RWO in March 2007 removed the straddle and opened the 3A2 and upper 2B to injection. The production characteristics of the offset 3A2 producers suggested that this zone was getting the majority of the water and an IPROF run in Dec 2009 confirmed 60% into the 3A2 and 40% into the lower 2B. The purpose of this job is to squeeze the 3A2 to prevent/reduce injection into this zone and increase support into zone 2B. Objectives The goal of the cement squeeze is to shut off the upper perforations in order to achieve the target injection rate into the lower zones. cc: w /a: Well File Contacts: Matt Brown Jennifer McLeod 564 -5874 (w) 564 -5764 (w) 223 -7072 (c) 907- 529 -4702 (c) 344 -1130 (h) --1 concvl y 2 • • Job Notes • SOP: Wellwork at Elevated Risk Areas must be followed for Endicott. The SOP is available via the online PE manual in the SOPs — Wells Group folder. • Please contact Matt Brown (907- 223 -7072 cell) when job is going to begin in order to monitor with InterAct. • Cement Specifications are shown below. Note that the Key Parameters are listed; the Key Parameters are the main items to get correct for the cement blend. • BHCT is estimated to be 165 F • BHST for producers averages about 215 F. END2 -34 is an injector and the formation has undergone significant cooling over the years such that BHST is 153 F. However, the wellbore above the Kekiktuk will be closer to the 215 F BHST of the producers. The cement blend should be designed for BHST of 215 F so that the cement does not set up prematurely in the wellbore during the squeeze Key CT Squeeze Cement -LARC Parameters Ppg: 15.8 ppg. Field blend to be =lab ppg +1- 0.1 ppg Slurry Temperature: between 80° and 110 °F API fluid loss: 50 - 80 cc 1 Thickening Time: 6 -8 hours 2 Filter cake thickness: 0.75" - 1.0" - The ratio of cake thickness to filtrate volume should be consistent with lab results. - The filter cake should be firm and dry. - The slurry should be smooth and homogenous. - There should be no free water or gelation of the slurry. Compressive Strength: 2000 psi in 24 hrs Plastic viscosity: 25 - 45 cp Yield point: 5 — 15 Ibf /100ft2 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 2:00 90 0 2:30 150 4000 3:00 175 7500 3:30 175 6000 4:30 190 6000 6:30 BHST 6000 3 s Volumes: vol, Tubing top MD bot MD Size ID bbl /ft ft bbls 5 -1/2" tub 0 9546 5 -1/2" 17# 4.892 0.0232 9546 221.9 4 -1/2" tub 9546 10520 4 -1/2" 12.6# 3.958 0.0152 974 14.8 236.73 vol, Casing top MD bot MD Size ID bbl /ft ft bbls 7" liner 10520 10634 7" 29# 6.184 0.0371 114 4.2 7" across perfs 10634 10943 7" 29# 6.184 0.0371 309 11.5 Liner total 15.7 Wellbore Total 252.4 s r/ef ry 1. Pum Schmoo B Gone treatment 2. MIRU SL. Pull MCX. ./ 3. Caliper Liner & Tubing. Tag TD. RDMO. 1. MIRU CTU. RU hose to IA and bleed IA to 1000 psi or less. (IA pres has been averaging -500 psi). Perform a BOP test whether or not there has been a recent BOP test (per Wellwork at Elevated Risk Pad SOP) 2. MU 1.75" cementing nozzle. PT as per standard procedures. 3. Begin loading well down backside (CT x Tbg) at max rate with a 60/40 methanol spear followed by 2% KCI and RIH. ( Wellbore v° =252 bbls). Pump 1.5x wellbore volume ( -400 bbls) with 140 deg 2% KCI to ensure full liquid pack of tubing. Monitor IA and OA pressures. Top off with McOH FP. 4. Tag TD. Pick up & get weight back. PUH 10' & flag pipe. Pump diesel down the IP backside as needed to achieve positive WHP (with CT in the well, about 175 bbls diesel should give 100 psi WHP) 5. Batch mix and pump 45 bbls LARC. (Reference - static bottom hole temp at 10,000'SS' is 215 ° F. BH circulating temp will be 175 ° F) Pump schedule down CT is as follows with backside shut in: ➢ 5 bbls fresh water spacer ➢ 45 bbls LARC ➢ CT vol of fresh water spacer ➢ Biozan for contamination 6. After cement passes onsite QC, line up to pump down coil. Start on pump schedule as listed above. Note when LARC begins to exit nozzle. 7. After about 3 bbls cement exits nozzle, PUH laying in cement 1 :1 while taking returns up backside. Once all perfs are covered with cement, (top perf at 10634'), shut in choke. Continue pumping cement with backside Shut in. Walk squeeze pressure up to 500 psi. 8. Once 500 psi squeeze pressure has been obtained, lay in remaining cement 1:1, 4 • • maintaining 500 psi squeeze pres. 9. PUH to safety (8700') laying in cement. POOH such that last bbl of cement exits nozzle as nozzle is at TOC. WCTOC: PBTD: 10943'MD Cement vol: 45 bbls Cement top in well (none behind pipe): 8924' MD Safety: 8700' MD Max volume of cement that can be pumped if well starts to drink cement: 34 bbls 10. Walk squeeze pressure up to 3000 psi in 500 psi increments, holding each ramp up for at least 5 min. If pressure keeps bleeding off or breaking back, go for a final squeeze pressure of 1500 psi. Monitor total number of bbls LARC behind pipe. Hold final squeeze pressure for 1 hr. 11. Drop ball & prepare for cleanout. Slowly bleed WHP to 500 psi. 12. Pump 1.5# biozan down CT at max rate while taking returns up backside & maintaining 500 psi WHP. 13. Once bio is at nozzle, RIH jetting from safety to cleanout depth at 1 bpm. Contaminate cement 2:1 with 3 passes from Safety to cleanout depth (down, up, down). 14. Swap to slick water & chase contaminated cement out of hole at 80 %. Make double passes across jewelry. 15. FP top 100' with Meth /water or diesel (note that 2500' FP isn't necessary at Endicott). Leave 500 psi on well. / ; jf d ,� 4?,2.ft yefrify 1. After waiting for cement to setup for 7 days, RU Slickline and drift to deviation. 2. RDMO. 1. MIRU LRS. 2. Line up to pump 60/40 down well. 3. PT squeeze by gradually pressuring up tubing to 3000 psi. Do not exceed 3000 psi. 4. Monitor WHP. Establish LLR if pressure falls off. '�" �� %� 1! ��'�. a essful In'ectivi Test 1. MIRU E -line. 2. MU 3 -3/8" Power Jet HMX perf guns 3. Shoot 10732' — 10760' MD reference SLB CBT 12- Nov -86 per attached perf form. ✓ 4. RDMO EL. 5 • • bp PERFORATING PROCEDURE Well: END2 -34 API #: 50- 029 - 21662 -00 Date: 3/3/2011 Prod Engr Jennifer McLeod Office Ph: 564-5764 H2S Level: Home Ph: No data Cost: CeII /Pager: 529 -4702 CC or AFE: AENRO2WL34 IOR: 400 WBL Entries IOR Type Work Desciption Priority /Comments 1 400 E Perf 28 2 Well Obiectives and Perforating Notes: Attachment: Reference log with proposed perfs annotated, 5 '/100' scale Reference Log Tie in Log Add 0 feet Log: DLL/MSFL CBT to the tie -in log to be on Date: 11/7/1986 11/12/1986 depth with the reference log. Company: SLB SLB Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad/Re /lperf 10,732' - 10,760' 10,732' - 10,760' 28 6 Random 60° K2 Rperf Requested Gun Size: 3 -3/8" Charge: 3406 PowerJet, HMX (--‘a/c11. Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown /Suggestions to Achieve Drawdown NA Last Ink 16,500 BWPD 2,100 WHIP Last Tag: 10,943 ft MD on 12/1/2009 Est Res. Pres. @ 10,000 SS is 3758 psi Perforation Summary Summary Dist Well: END2 -34 Town: Date: API #: 50- 029 - 21662 -00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf /Reperf 0 /B /U - O /B /U - O /B /U - O /B /U - O /B /U - 0 /B /U - 0 /B /U - 0/B /U - O /B /U - 6 • • •-■ CDT - CEMENT BOND TOOL cu COMPANY! STANDARD ALASKA PRODUCTION COMP. NELL! 2 34/P - 14 MPI FIELD! ENDICOTT BOROUGH! NORTH SLOPE STATE! ALASKA LOCATION! SURFACE LOCATIOMI 1969' FML L 2256' FEL SEC! 36 TIP$ 12N RGE! 16E PERMANENT DATUM! MSL ELEVATIONS - ELEV. OF PERM. DATUM! 0.0 F KIP: 56.0 F LOG MEASURED FROM! KB DF! 55.0 F 56.0 F ABOVE PERM. DATUM GL! 14.5 F DRLG. MEASURED FROM! KB DATE! 18 NOV 86 API SERIAL MO! RUM MO! 1 5002921662 DEPTH - DRILLER! 11160.0 F DEPTH - LOGGER! 11154.0 F DTM. LOG INTERVAL! 11145.0 F TOP LOG INTERVAL! 9500.0 F CASING DRILLER! 10111.0 F 11242.0 F CASING- LOGGER! CASING! 9 5 /8" 7 HEIGHT! 47.0000 LD /F 29.0000 LD /F BIT SIZE! 8.5 wr• *u. 7 l 1 1\-*v..":.- n ' ' �,., �' ‘....."0-.....60t x.+..,.- - ,i......Js f Acri, r s�► -•-••,...-0,, -. i s. a f -..r,n..,, \.t i .........tr,.f�it.r- r^.r+.r�- ,...JJ\ \.ryrc....r.. �Carrt�,...a:- 4.1.,1 .. 4" ♦-✓ -• '• mod.► � IN a a � • OD N (a W G a - - o 0 a N 4 0 a . , ..� - .. i w . • � } f� r ti t "�1 1 . . , v C ril \ . .. . 1 , ill' x o f . . 1 ,. -::. .. .._. ... -c ..,....., ,... . .,,___.: + .✓' V'i 'i'. e4 - '•' I .. .,... . • .re--- ^•• --•.. � -..-. ». _....r • v,_^i i _` /� -- __ _ .. ...-?. ...ems -. ' � ,,, . . dila. _ _. _.. 40 - r✓ - - 'L. 1dlNYiiIi�LYr avao p �� rn �/f I� " + t:,uwu :K ...: r , s /' '�4' J�I� 4 - _ 4 ...,......p * � , F 1 , ! • • TREE= 7- 1/16" CM/ WELLHEAD = 11" FMC END 2 -34 I SAFETY NOTE I ACTUATOR= OTIS -BB KB. ELEV = 56.0' ' - I BF.ELEV= 164' KOP= 5500' I 1511' H5 -1/2" HES HRQ SVLN, ID= 4.562" I Max Angie = 33° @ 8022' Datum MD = 10665' 9 ..... j Datum TV D = 10000' SS 130" CONDUCTOR I 131' IL LIFT MANDRELS ST MD TVD DEV TYPE V LV LATCH PORT DATE 113 -318" CSG. 72 #, L -80 BTC, ID = 12.347" H 2483' 2 3724 3723 3 MMG DMY RK 0 11/09/07 1 6026 6018 12 MMG * *DMY RK 0 03/24/07 19 - 518" CSG, 47 #, NT8OS X0 NT95HS H $366' * * STATION #1 = DMY HAS EXTENDED PACKING Minimum ID = 3.725" @ 10498' 4-1/2" HES XN NIPPLE 5-1/7 TBG, 17 #, L -80 TC11, —I 9546' I I 95.46' H5-1/2" X 4-1/2" XO, ID = 3.958" I .0232 bpf, ID= 4.892" ` imp OF7 "LNR 9827' I • I9 -5/8" CSG, 47 #, NT95HS, ID = 8.681" H 10110' IA ' 10244' -14-1/2" HES X NIP, ID = 3.813" I X - 4 10275' H 7" X 4 - /2" BKR SB - 3 PKR ID = 3.870" I I 10308' I-14 -1 /2" HES X NIP, ID = 3.813" I I 14 -1/2" TBG, 12.6 #, L -80 TC11, .0152 bpf, ID = 3.958"H 10380' 10389' H7" X 4-1/2" UNIQUE OVERSHOT 1 PERFORATION SUMMARY g 10399' H7" X 4 -1/2" BKR S -3 PKR ID = 3.833" 1 REF LOG: DLL & GR (11/07/86) ANGLEAT TOP PERF: 23 @ 10634' I I 10426' H4 -1 /2" HES X NIP, ID = 3.813" I Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL OpnlSgz DATE 5" 4 10634 - 10724 O 07/09/97 , I 10499' H4-1/2" HES XN NIP, ID =3.725" I 5" 4 10732 - 10760 0 07/09/87 5" 4 10795 - 10840 0 07/09/87 i I 10520' H4 -112" WLEG, ID = 3.958" 2 -1/8" 4 10850 - 10890 0 07/13/90 2 4 10940 - 10980 0 02/03/94 I 10522' ELMD Logged 27- Sep -08 SLB RST (Sigma Pass #3) m 14 TBG, 12.64, L -80 TC11, .0152 bpf, ID = 3.958" H 10520' m ?? H POGL SLIP (11127/06) I PBTD 11160' ..,...� • • • 4 4 w 4 v � 4 • 4.4.4.4 17 " LNR, 294, L -80 SM -110, .0371 bpf, ID= 6.184" 11242' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 07/11/87 ORIGINAL COMPLETION 11/19/07 DAV /PJC GLV C/O (11 /09/07) WELL: 2 -341 P -14 11/30/94 D15 RWO PERMIT No: 1861720 03/31/07 D16 RWO API No: 50 -029- 21662 -00 06/23/07 PC/PJC DRLG DRAFT CORRECTIONS SEC 36, T12N, R16E, 1969' SNL & 2256' WEL 07/20/07 TEL/PJC GLV C/O (07/08/07) 10/23/07 JLJ /PJC GLV C/O BP Exploration (Alaska) 9 END2 -34 40,000 _e_e__.e______ 4000 — PW 35,000 SW I 3500 WELLHEAD_PRES 30,000 3000 i 1 , 25,000 ., ' 2500 • a 1 a_ I ' 20,000 1 ; 11 111 i i hili41 ;i til!l• 2000 E m ( 1 // 1!" i 15,000 — 1500 1 i IJVV 1 I 10,000 i I I I III 1000 II i 1 4 1 5,000 500 1 • 0 0 1/90 9/92 6/95 3/98 12/00 9/03 6/06 3/09 0 RWO completed 03/31/07 > 03/01/04: SL set TTP in nip reducer > 03/02/04: CMIT Passed to 3500 psi. > 03/13/04: MITOA Passed to 3360 psi > 03/13/04: LDL ID'ed leaks from 660' -1132' > 03/15/04: TTP pulled > 05/18/04: Operator call -in possible BH leak > 05/27/04: Mailed Sundry 10-403 to Winton > 06/06/04: No apparent BH leak > 07/20/04: AOGCC denied sundry (06/28/04) > 08/31/04: Request for Admin Approval > 09/16/04: AOGCC approved AA for PWI with TxIA comm > 01/21/05: Operator call -in possible BH leak > 01/22/05: No BH leak apparent > 03/12/05: MITOA Passed to 3360 psi > 11/26/05: MITOA Passed to 3360 psi > 11/27/05: TTP set @ 9600', AOGCC CMIT TxIA Passed to 3360 psi > 11/28/05: Pulled TTP > 12/31/05: TxIA waiver revised > 02/18/06: PPPOT -T Passed to 5000 psi > 03/11/06: TxIA waiver revised > 03/19/06: PPPOT -IC Failed, unable to press up > 04/19/06: Waiver updated for 2500 psi IAP > 06/17/06: DHD finds fluid at 4 to 6 o'clock position on upper bradenhead. Bubbling in cellar at 9 o'clock position. > 08/02/06: MITOA Passed to 3360 psi > 11/15/06: Set TTP @ 9600'; CMIT -TxIA Failed; pulled TTP > 11/16/06: Set TTP © 9600' > 11/23/06: CMIT -TxIA Failed, LLR =5.5 gpm > 11/27/06: Set TTP @ 9600' > 12/23/06: CMIT -TxIA Passed to 3360 psi > 12/31/06: AOGCC CMIT -TxIA Passed to 3360 psi > 01/08/07: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3000 psi, LDS Functioned > 01/18/07: AA cancellation sent to AOGCC > 01/20/07: Cancelled waiver due to RWO > 01/28/07: Pulled patch, TTP, nipple reducer > 01/28/07: Caliper 67 jts 40 -85% and 1jt >85% > 02/13/07: Set CIBP @ 9607' MD > 02/26/07: MITOA passed to 2000 psi > 03/28/07: Set TTP @ 5608' SLM > 07/08/07: Pulled DSSSV from 1511', Pulled DGLV from STA # 2 > 07/09/07: Pulled RHC, Set TTP @ 10499', CMIT -TxIA Passed to 2500 psi > 10/16/07: PPPOT -IC Passed to 3000 psi; Tbg and IA circed with 2% KCI > 10/17/07: BH weld complete > 10/19/07: MITOA Passed to 1200 psi > 10/23/07: Set DGLV in sta #2 > 10/24/07: Pulled TTP from 10499' 11 • > 11/04/07: Notified AOGCC of IA repressurization > 11/09/07: Re -set DGLV in sta #2, MITIA Passed to 2500 psi > 11/13/07: AOGCC MITIA Passed to 2700 psi > 05/11/08: MIT -OA w/ N2 Passed to 500 psi > 01/01/09: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3500 psi, LDS OK > 01/13/09: TIFL Passed pre -rig for END2 -30 > 12/01 /09: Re -set SSSV@ 1511' 12 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD i~ Z-08A 8 5 81-0001 5 PRODUCTION PROFILE 3-27/M-33 B8K5-00012 - / PRODUCTION PROFILE 10/25/09 1 1 2-34/P-14 S-213A V-227 AWJh00061 B8K5-00007 B69K-00036 - / MEM INJECTION PROFILE (,~ - GAS LIFT SURVEY - ~ $ USIT (~ Ze ~{ - 11/18/09 12/01/09 10/26/09 1 1 1 1 1 1 06-181 B2NJ-00033 MCNL .11/19109 1 1 L3-11 AP30-00065 0 RST ' 10/12/09 1 1 0-046 H-OSB B2NJ-00036 B2WY-00033 - MCNL - MCNL _ (~ 10/31/09 11/04/09 10/20/09 1 1 1 1 1 ~ PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETitRNINf: nruc rnnv ~wr•u ~rn. nr txploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. >~ ~~.:s FEr~ ~. ~ 2C~~C `-~ Alaska Data & Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 ?~ ~ ~., _ R - _ '.-. `'_ • • chiumber~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~~~ ~~ ~ T'x 7 ~~;,~ Anchorage, AK 99503-2838 w `~!;~~s'~4 ;_.% 'V! ~ i ;•~~ r_ ~ ~ ATTN: Beth N0.5209 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 04/29/09 U • ,~ £ niaana va~a a VUnSUiun eNIG@5 Petrotechnical Data Center LR2-1 2525 Gambell Street, Suit 00 900 E. Benson Blvd. Anchorage, AK 03-2 Anchorage, Alaska 99508 ATTN: Beth . i Date Delivered: Received by: ~~°'°~-- FW: END2-34/P-14 (PTD #1861) Indication of TxIA Communication through IA Repressuri... Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, November 21, 2007 12:18 PM To: Regg, James B (DOA) Subject: RE: END2-34/P-14 (PTD #1861720) Indication of TxIA Communication through IA Repressurization Jim, I must have forgotten the MIT form. test form sent stiil? Thanks, Andrea Hughes ~~ N Q V ~ 2007 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, November 21, 2007 12:10 PM To: NSU, ADW Well Integrity Engineer Subject: RE: END2-34/P-14 (PTD #1861720) Indication of TxIA Communication through IA Repressurization MIT was not attached Jim Regg AOGCC 333 W.7th Rvenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~,`~~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, November li, 2007 7:28 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW WI Tech; Holt, Ryan P (ASRC); Dahlem, Jason E Subject: FW: END2-34/P-14 (PTD #1861720) Indication of TxIA Communication through IA Repressurization Jim, END2-341P-14 passed an MITIA to 2500 psi on 11109!07 after resetting a DGIsV in Gt_M #2. Please see the attached MIT form. The plan forward is: S: Reset DGI_V in GI_M #2 -DONE 2. F: MITIA to 25003 psi - PASSEC3 3. WAV: AOGCC MITIA to 2500 psi post initial injection. The AOGCC witnessed test is scheduled for Monday morning. Please tail with any questions or concerns. The AOGCC witnessed test form was se'ht on 11/16/07. Would you like the pre- ,tA~-i 11 /21 /2007 FW: END2-34/P-14 (PTD #1861 Indication of TxIA Communication through IA Repressuri... Page 2 of 2 Thank you, • Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Sunday, November 04, 2007 8:22 PM To: END, Operations Lead Tech; END, O&M TL; ENDJBAD Area Manager; Rossberg, R Steven; Engel, Harry R; NSU, ADW Wel- Operations Supervisor; 'James Regg'; Tom_Maunder@admin.state.ak.us; Soto, Jose A; NSU, ADW WL & Completion Supervisor; Varble, Doug A Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Lau, John, Jack; Dahlem, Jason E Subject: END2-34/P-14 (PTD #1861720) Indication of TxIA Communication through IA Repressurization Hi all, Well END2-34/P-14 (PTD #1861720) is exhibiting IA repressurization after being put on injection post RWO and post wellhead welding. Wellhead pressures were T/I/O equal to 2320/2350/410 on 11/4/07 when the IA pressure was b{ed to 400 psi and increase 1800 psi during a 30 minute monitor. It is believed a GLV may be out of pocket. The plan for ward is: 1. S: Check /reset DGLV in GLM #2 2. F: MITIA to 2500 psi 3. WAV: AOGCC MITIA post initial injection A wellbore schematic and TIO plot have been included for reference. «END2-34 TIO plot.BMP» Please call with any questions. Thank you, .~(nnat ~z?u6e, {P.~ ell Integrity Coordinator GPB ells Group Phone: (9CI7) 659-5102 Pager: j907) 659-6100 x1154 11 /21 /2007 4,000 3,000 ~y _._ 2,000 j T 1 ,000 0 2.34 TIa Plot i i 715!2007 9/4/2007 1114/2007 1 /312007 3/5/2007 5/5/2007 4(~-~~- 1 g ~ - I -7 Z- + Tbg ~- IA ~ -~- OA OOA i ...,~ -~- OOOA • • MEMORANDUM To~ Jim Regg P.I. Supervisor ~ ~~~ li~~ f~f.~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Cas Conservation Commission DATE: Monday, November 19, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-3AIP ] 4 DUCK IS li1VIT MP[ 2-34/P14 Src: Inspector NON-CONFIDENTIAL ~,~~v t Reviewed By: P.LSuprv -~~~- Co mm Well Name: DUCK IS UNIT MPI 2-34/P14 API Well Number: 50-029-2 t662-00-00 Inspector Name: Lou Grimaldi IRSp Num: mitLG071 l 16091652 Permit Number: 186-172-0 Inspection Date: 1111312007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j ~-s4iPla jTYPe Inj. ~ ~ ~ TVD ~ ~ 97oI ~ I~ 600 ~ zno~---! ~ 2700 ~ 2700 ~ 1530 1530 ~ y ~ P.T. ~ 1861720 ~TypeTBSt I SPT ~ TeSt PSI ~ 2700 ~ OA 350 ~ 560 540 ~ 530 ! 380 ~ 380 I Interval OTHER P~F P _~ Tubing ; 2375 2300 C 2375 I 2325 2325 ~ 2375 i NOteS' Initial test after Braden head weld. Afrer 30 ~ minutes bled IA from 2700 to 1530 and observed for 15 minutes w/ no buildup observed. Good test. Ey ~{{ ~~^'t ~ ¢ ('~ ~~~~ y~GitwM~~VQ' ~ ~ ~U~~! Monday, November 19, 2007 Page 1 of 1 • Page 1 of 1 s Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, November 03, 2007 12:12 PM To: 'Gary Preble (BRIG)' Subject: 2-34/P-14 (186-172) Gary, 1 am reviewing the 404 for the bradenhead weld job. The summary you have included begins on October 16. It appears there was some work being conducted prior to that. Could you please send 'rn that earlier information? Email is fine. ,~~~~~ t ~ ~ ~ 4,~ Also, is there any information on when it the bradenhead leak was determined? Thanks in advance. ~j~ Tom Maunder, PE ~~~" r" 1 AOGCC ~~~~~~ ~ ~~ ~ ~a~~ 11 /3/2007 STATE OF ALASKA ~ ~T 3 ~ 2007 JD~S/~~ ALASKA OIL AND GAS CONSERVATION COM I N REPORT OF SUNDRY WELL O~~p~ons. Commissinrr 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ nc orBgldOtner ~ Bradenhead weld Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Repair Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ' 1s6-1720 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21662-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56 KB 2-34/P-14 - 8. Property Designation: 10. Field/Pool(s): ADLO-034633 ~ En dicott Field/ Endicott Pool 11. Present Well Condition Summary: Total Depth measured 11242 feet Plugs (measured) None true vertical 10586.76 ~ feet Junk (measured) None Effective Depth measured 11160 feet true vertical 10511 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" Surface - 131' Surface - 131' Surface 2483' 13-3/8" 72# L-80 Surface - 2483' Surface - 2483' 5380 2670 Production 10110' 9-5/8" 47# NT95HS Surface - 10110' Surface - 9555' 8150 5080 Liner 11242' 7" 29# L-80 9827' - 11242' 9308' - 10587' 8160 7020 Perforation depth: Measured depth: 10634 - 10724 10732 - 10760 10795 - 10840 10850 - 10890 10940 - 10980 True Vertical depth: 10027.51 - 10110.26 10117.59 - 10143.19 10175.17 - 10216.34 10226 - 10262 10308 - 10345 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 Surface - 9546' 4-1/2" 12.6# L-80 10380' - 10520' 4-1/2" 12.6# L-80 9546' - 10380' Packers and SSSV (type and measured depth) 7"x4-1/2" BKR SB-3 10275' 7"X4-1/2" BKR S-3 10399' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 11363 2250 2216 Subsequent to operation: Shut-in 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~' Developm ent ~' SerVlce Daily Report of Well Operations X 16. Well Status after proposed work: 0iI ~ Gas "'' WAG GINJ !'~' WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble prepared by Gary Preble 564-4944 Printed Name Gary Preble Title Data Manager Signature Phone 564-4944 Date 10/29/2007 Form 10-404 Revis 04/ ~` I Submit Original Only ~ ~ ~ A f ,~ ~ • 11/05/2007 MON 14:15 FAX 9,45857 BPXA AK Tech Support WELL SERVICE REPORT RECEIVED NOV 5 0 20W plASkas ail ~ Cap Conc. Gummisson ~ 002/003 WELL JOB SCOPE END2-34 ANN-COMM UNKNOWN DATE DAILY WORK DAY SUPV 6/17/2006 AC-FLUID LEVEL DUBE COST CODE PLUS KEY PERSON NIGHT SUPV ENR02WL34-I VEC-DOHERTY UNKNOWN MIN ID DEPTH TTL SIZE 0" OFT 0" _DAf LY-SUMMARY.__... .-._... _.-....-....._.__.... .__.__.._.....- ......_....-. _ -. _...........-_._ .. _..__.-- ._.._- ._-.--~--- -- ----- ---_ . .._._...._ ._..... .-_._._...-.. .... ..-... .. ---._.__...._...__.. --...._._.. _.. ------...... --- ................._ - T/I/0=2480/2240%240. Temp=Hat. OA FL (pre MIT-OA}. OA FL Q surface. OA needs Integral installed. Note: Upper Bradenhead has small amount of fresh liquid around the 4 & 6 o'clock position. Bubbleing in the cellar at the 9 o'clock osition. JOB COSTS S_E_RVICE COMPANY -SERVICE ----~._.... _..--- - - _ ----- DAILY COST CUMUL TOTAL --- --------- VEC_0 - ----- ---- _ ~ -.__ WAREHOUSE ._.... ~~ _.__.....~... __._ -- _____......___.-----.______..__.._ T _ ~Y .~__..~..- $0 __ ~ -~~- : LITTLE RED - -- _-~~ $0~ ~ -~~ '' J~`r ~ TOTAL FIELD ESTIMATE: ~~ WELL SERVICE REPORT WELL JOB SCOPE UNIT END2-34 ANN-COMM UNKNOWN DATE DAILY WORK DAY SUPV 7/13/2006 AC-EVAL; AC-MONITOR WINSLOW COST CODE PLUS KEY PERSON NIGHT SUPV ENR02WL34-( VEC-GSCHWIND UNKNOWN MlN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY T/110=2450/2350/300, Temp=HOT. Eval bradenhead leaking (reported by DHD}. Upper Bradenhead shows signs of leaking in the 4, 6, and 7 O'clock positions. Cleaned bradenhead, snooped and monitored for 30 min, no apparent active leak (snoop did not bubble). There is 4.5" of fluid in cellar, cellar is bubbling in the 8:00 position, 4"from conductor, approx 3 to 4 bubbles eve 30 seconds. JOB COSTS SERVICE COMPANY -SERVICE - DAILY COST CUMUL TOTAir - --. -___.____.._____ --__ VECO _____~ _._ ~ -- - WAREHOUSE . ... - . -__~0 -_-._._.-._.-......_..__ ._. - -- _ ~ -_ _ .-._ -.-._._ ........ ..._._.-._.-.___-___....-._.-.__._.-.._._._._.-.__.-._...---._.-._.__.__. LITTLE RED - - .. -._......_.-..... ._ .._....__ ~ TOTAL 1=1ELD ESTIMATE: 1 ~~~ ~~~ . 11/05/2007 MON 14:15 FAX 945857 BPXA AK Tech Support • 1~j003/003 2-34/P-14 AGTlVETYDATE SUMMARX _.:._ 10/5/2007 T!I/0=200/150/0+. Temp=Sf. Prep Cellar (Pre SH weld}. OA FL near :surface. Cleaned SH for wefd job. 10/6/2007T/I/0=200/150/VAC, Temp=S1. Bleed WHP's to 0 psi (Pre BH weld). 'TBG FL @ surface. Bled TBGP from 200 psi to 0 psi in 1 hr. IA FL surface. IAP tracked the TBG during bleed. SI monitored for 30 min. f=inal WHP's=0/VAC/VAC. 10/7/2007 T/I/O = 0/0/0 Installed 2 1 /16 OA valve And pulled VR plug with lubr'scator 10/15/2407 T/I/0= 0/0/0 Circ-out (Bradenhead repair) Pump 10 bbls neat meoh ',spear followed by 300 bbls 2% KCL down Tbg of well End2-34 taking 'returns up IA into flowiine well End2-32, iet fluids swap out for six hrs. (continued on 10/16/07) • END2-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE SUMMARY 10/16/2007; (continued from 10/15/07 Bradenhead Repair Circ-out) (2nd Circ-out) Allowed fluids to swap for 6 hrs. then pumped 3 bbls of neat and 408 bbls of 2% KCL down Tbg taking returns up IA to hardline jumper to well 32 flowline. Bled WHP down. Final '`: W H P= 0!0/240. "*" IA/OA open to gauges and tagged "`** 10/16/2007;T/IA/OA 0/0/180 Temp= SI PPPOT-IC (PASS) (PRE STARTING HEAD WELD) PPPOT-IC RU 2 HP bleed tools onto IC test void, 0 psi on void. Flushed void until clean returns achieved, pressured to 3000 psi for 30 min test, 3000/ 15 min, 3000/ 30 min. Bled void to 0 psi RD test equipment. Did not cycle LDS "ET Style" all were in good visual condition. and cycled during last PO test. 10/16/2007:T/I/O=V ac/Vac/93. Temp=S1. N@ cap & Purge. (Pre BH Weld). Purged N2 `down TBG & took returns from the IA. took 7.42 bbl of returns to bleed trlr. Rigged 1!2" hp hose from TBG to IA and allowed N2 to u-tube from tbg to IA. Bled OAP `:`from 93 psi to 0 psi in 10 minutes. Purged N2 across OA for 5 minutes, low LEL= - 8% & high reading was 39%. TBG FL C~3 78'. IA FL @ 72'. Left N2 pressure on T, ',', I & O as per W IE. Final WHP's=97/115/110. 10/17/2007'T/I/0=95/110/40. Temp=S1. N2 Purge. (BH WELD). TP decreased 2 psi ':overnight. IAP decreased 5 psi overnight. OAP decreased 70 psi overnight. TBG ` FL @ 54'. TBG FL rose 24' overnight. IA FL C~ 78'. IA FL dropped 6' overnight. '!Bled OAP to 0 psi & start N2 purge. DHD will mantain fire watch and N2 purge ;during BH weld process. Top weld completed. C/O with night shift to complete welding job. ~......, _...._,. 10/18/2007T/I/O = 98/111/0. SI. N2 Purge (BH Weld). C/O with day shift crew and continue N2 purge on OA and maintain fire watch for completion of BH welding. Maintain 1 hr fire watch after completion of bottom BH weld. Final WHPs = 98/111/0. 10/18/2007 T/I/0=100/110/vac. Temp=S1. Monitor (post BH Weld). No change in TBGP or ,IAP, OA went on a vac. Braden Head is wrapped with heat blanket. Note: the =grating has been removed from well house. 10/19/2007T/I/0=120/80/0 temp=S1 MIT OA PASSED to 1200 psi (Post RWO & BH Weld) First test - OA pressured up to 1200 psi with 1.3 bbls diesel. OA lost 50 psi in first ''15 minutes and 30 psi in second 15 minutes. For a total of 80 psi in 30 minutes. ":Second test - OA pressured up to 1220 psi with .1 bbls diesel. OA lost 50 psi in first 15 minutes and 0 psi in second 15 minutes. For a total of 50 psi in 30 minutes. ':Bled back - 1 bbl. Tagged wing and OA valves with info. Well SI at departure at :wing valve, all other casing valves open to gauges. FWHP's=120/80/0 <<,. -~ i • 10/19/2007~T/I/0= 90/105/0. Temp= SI. Monitor (post-BH weld). Integral installed on IA. '!Tubing pressure decreased 8 psi. IAP decreased 6 psi. Removed heat blankets :from tree. 10/23/2007``"""WELL S/I ON ARRIVAL*'`* (post wh weld) :PULLED P-PRONG FROM 10,499' SLM. ';SET 1.5" DGLV W/ RK LATCH IN STA# 2 @ 3721' SLM. ?""*CONTINUE WSR ON 10-24-07*"" 10/24/2007;'**CONTINUED FROM 10-23-07*"* ``PULLED PXN PLUG BODY FROM 10,501' SLM. I'' SET 5.5" HRO W/ CARRIER W/ 1.89" BEAN MCX @ 1493' SLM. (SN# NM-505, `NO EO-DEVICE, 2 SETS STD PKG, 58" OAL) 'GOOD DRAW DOWN TEST. ` "'`*GIVE WELL BACK TO PAD-OP*'" FLUIDS PUMPED BBLS 15 Meth 708 2% KCL 3 Neat 726 Total END2-34/P-14 (PTD #1861720)~cation of TxIA Communication thro~IA Repressurization Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ t(~~1~ ~ Sent: Sunday, November 04, 2007 8:22 PM To: END, Operations Lead Tech; END, O&M TL; END/BAD Area Manager; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Regg, James B (DOA); Maunder, Thomas E (DOA); Soto, Jose A; NSU, ADW WL & Completion Supervisor; Varble, Doug A Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Lau, John, Jack; Dahlem, Jason E Subject: END2-34/P-14 (PTD #1861720) Indication of TxIA Communication through IA Repressurization Attachments: 2-34.pdf; END2-34 TIO plot.BMP Hi all, Well END2-34/P-14 (PTD #1861720) is exhibiting IA repressurization after being put on injection post RWO and post wellhead welding. Wellhead pressures were T/I/O equal to 2320/2350/410 on 11/4/07 when the IA pressure was bled to ~ 400 psi and increase 1800 psi during a 30 minute monitor. It is believed a GLV may be out of pocket. The plan for ward is: 1. S: Check /reset DGLV in GLM #2 2. F: MITIA to 2500 psi 3. WAV: AOGCC MITIA post initial injection 11/5/2007 a,0oo 3,000 1 2,000 1,000 2~4 TI^ Plot IA MAASP ~ 1~6-~~z 0 11/412006 10312007 3/5/2007 5/502007 715/2007 9/412007 t Tbg -~- IA -t OA OPA OOOA • TREE = 7-1,'16" CNU VJELLHEAD= 11" FMC ACTUATOR =~ dTIS-BB KB. EI_E1/ = 56.0' BF. ELEV.- 16.4' KOP = 5500° AAax Angle = 33° ~ 8022' Datum h1D = 10665' DatumTVD=~ ~~ 10000'SS 30" CdNDUCTd3 131' 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347'" 24$3` 9-5(8" CSG, 47#, NT80S XO NT95HS 53$6° Minimum ID = 3.725" 10498' 4-112" HES XN NIPPLE 5-112" TSG, 17#, L-80 TC11, 9546' .0232 bpf, !D = 4.892" TdP dF 7°' LNR ~--{~-9$27' 9-518" CSG, 47#, NT95HS, ID = 5.681" ~-{ 10110` 4-1l2" HES X NIP, ID = 3.813° 10275' 7" X 4-it2" BKR SB-3 PKR; ID = 3.870" 1030$` - ~4-112" HES X N{P, ID = 3.813" 4-112" TBG, 12.6#, L-80 TC11; .0152 bpf; ID = 3.958" 103$0' 103$9` 7" X 4-112" UNIQUE dVERSHdT PERFORATICIN SUM(44ARY 10399` 7" X 4-1{2" BKR S-3 PKR, ID = 3.833:' REF LdG: DLL & GR (11/07?86j ANGLE AT TOP PERF; 23 @ 10634' 10426' ° 4-112" HES X NIP, ID = 3.813 Nate: Refer Ia Praductian DB far tiistarical perf data SIZE SPF INTERVAL d /S DA E pn qz T 10499' 4-1{2" HES XN IVIP, ID = 3.725" 5" 4 10fi34 - 10724 d 07{09197 5" 4 10732 - 10760 d 47!119?87 5" 4 10795 - 108411 d {17/09187 1Q520' ~-- ~ 4-1,2" Vt1LEG, ID = 3.958" 2-118" 4 10850 - 10890 d 07113!90 2-318" 4 111940 - 10980 d 02103/94 ~4-112" TBG, 12.6#, L-8Ct TC11, .0152 bpf; ID = 3.958" f-~ 1Q520' PBTD 11160' 7 " LNR, 29#„ L-80 5~;1-110, .0371 bpf, ID = 6.184" 11242' PdGLM SLIP {11{27106) NTS DATE REV BY Cd1~fiN1ENTS PLETION 111{30{941 D15 IRO A 1 I 1 07/20107 TEL/PJC GLV C?d ~ 10;'23{07 JLJ1P,fC GLV Ctd ;=~JDICdTT UNrr ti°~ELL:,?-34 ? P-14 i'ERh11T Nc~: 1861720 API Nc~: 54-423-21662-44 SEC 36, T12N, R16E, 1969' SNL & 2256' WEL BP Exploration (Alaska} ~~.~. 1511' I-j 5-1t2" HES HRQ SVLN, ID = 4.562" GA5 LIFT NFANDREL5 ST MD TVD DEV TYPE VLV LATCH PdRT DATta 2 1 3724 6026 3723 6018 3 12 MNEG M[vIG DNiY DMY RK RK 0 0 10f23}07 03124107 5-112" X 4-112" Xd, ID = 3.958" ~ RECE.IVED . STATE OF ALASKA . ~1'P¡' '" ALASKA OIL AND GAS CONSERVATION COM ION MAY 0 2 2007 REPORT OF SUNDRY WELL OPERATIONS:~laska Oil & Gas Cons. Commission A 1. Operations Performed: .~..~. wt/w D Abandon 181 Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well D Alter Casing 181 Pull Tubing D Perforate New Pool D Waiver D Other D Change Approved Program D Operation Shutdown D Perforate D Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. D Development D Exploratory 186-172 ..- 3. Address: D Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21662-00-00 ~ 7. KB Elevation (ft): 56 I 9. Well Name and Number: END 2-34/P-14 ..... 8. Property Designation: 10. Field / Pool(s): ADL 034633 / Endicott Field / Endicott Pool / 11. Present well condition summary Total depth: measured 11242 , feet true vertical 10587 ' feet Plugs (measured) None Effective depth: measured 11160 feet Junk (measured) None true vertical 10511 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2482' 13-3/8" 2482' 2482' 4930 2670 Intermediate Production 10111 ' 9-518" 10111' 9556' 6870 4760 Liner 1413' 7" 9827' - 11240' 9308' - 10585' 8160 7020 SCANNED MAY o 9 2007 Perforation Depth MD (ft): 10634' - 1 0980' Perforation Depth TVD (ft): 10028' - 10345' 5-1/2" X 4-1/2",17# x 12.6# L-801TCII 10520' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" BKR SB-3, 7" x 4-1/2" BKR Premier 10274', 10399' 5-1/2" HES HRQ SSSV Landing Nipple 1511' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft MAYO 8 2007 13. Reoresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations D Exploratory D Development 181 Service 16. Well Status after proposed work: 181 Well Schematic Diagram DOil DGas DWAG DGINJ 181 WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 304-064 Printed Na1Jle Sondra Stewman Title Technical Assistant 5C ~.: 0- Prepared By Name/Number: r 7/_ ~ . Phone 564-4750 Dateff) -Ol-ol Sondra Stewman. 564-4750 SI ature JV" JVc . Fo'm 10-404 Rov;'" 0412000 () R \ G \ N A L A6(% Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 3/11/2007 19:00 - 00:00 5.00 MOB P PRE Moved Off END 2-58 and Move in and Rig Up on END 2-34. 3/12/2007 00:00 - 00:30 0.50 MOB P PRE Spot Rig Over END 2-34 00:30 - 02:00 1.50 MOB P PRE Rig Up Spot Slop Tank, Stairs, Landings Geronimo Line, Rig Up Squeeze Manifold. 02:00 - 03:00 1.00 MOB P PRE RlU DSM to Pull BPV, RID DSM. 03:00 - 04:00 1.00 MOB P PRE Pre-Spud Meeting, Safety Meeting to Discuss Displacement Procedure. 04:00 - 05:00 1.00 P PRE RlU Lines in Cellar, Pressure Tested Surface Lines to 3,500 psi. Good Test. 05:00 - 05:30 0.50 KILL P DECOMP Taking on 8.8 ppg KCL Water Into Pits. 05:30 - 07:30 2.00 KILL P DECOMP Displace Well Bore to 8.8 ppg KCL Water. Taking Returns to Cuttings Tank. 07:30 - 08:30 1.00 KILL P DECOMP Flow Check Well Bore, Close Master Valve, Blow Down All Lines. 08:30 - 09:00 0.50 BOPSU DECOMP RlU and Set TWC Valve. 09:00 - 10:00 1.00 CASE DECOMP Test Well Bore to 1,000 psi Failed Test, Pressure Would Bleed Off to 0 psi In 2 Minutes, Loss Rate 12 To 15 bph. 10:00 - 11 :00 1.00 CASE DECOMP RlU to Fill Casing, 8 bbls To Fill Well Bore. RID Blow Down Lines. 11 :00 - 14:30 3.50 BOPSU DECOMP Set TWC, Rig Up to Test TWC. Attempt to Test TWC flAbove, Tree Leaking Tighten and Retest flAbove to 3,360 psi. Pressured up on Annulus to 1,000 psi flBelow TWC No Leaks at Surface BID and RID Lines 14:30 - 15:30 1.00 BOPSU DECOMP Bleed Down Adapter Flange Void, terminate control lines. 15:30 - 16:30 1.00 BOPSU DECOMP NID Tree and Adapter Flange. Inspect tubing hanger threads. 16:30 - 19:30 3.00 BOPSU DECOMP N/U 13 5/8" X 5000 psi BOPE. 19:30 - 20:00 0.50 BOPSU DECOMP T/U test equipment to test BOPE. 20:00 - 00:00 4.00 BOPSU DECOMP Test BOPE to 250 psi low test and 3360 high test. Test VBRs with 4" & 5 1/2" test joints. Test was witnessed by WSL, Doyon Tool Pusher and Lou Grimaled with the AOGCC. 3/13/2007 00:00 - 03:00 3.00 BOPSU P DECOMP Test BOPE to 250 psi low pressure test and 3360 psi high pressure test. Each tests was held for 5 minutes. Test witnessed by WSL, Doyon Tool Pusher and Lou Grimalde with the AOGCC. Test #1- Annular Preventer with 4" Test Joint, HCR Choke, HCR Kill, and Upper IBOP Test #2- Manual Choke, Manual Kill, and Lower IBOP Test #3- Lower Pipe Rams on 4" Test Joint Test #4- Choke Valves # 1, 12, 13, 14, Upper Pipe Rams on 4" Test Joint, and TIW Valve Test #5- Choke Valves #9, 11, and Dart Valve Test #6- Choke Valves #5, 8, and 10 Test #7- Choke Valves #4, 6, and 7 Test #8- Choke Valve #2 Test #9- Lower Pipe Rams with 5-1/2" Test Joint Test #10- Annular Preventer with 5-1/2" Test Joint Test #11- Retest HCR Kill Test #12- Choke Valve #3 and Blind Rams Accumulater Test- 2,900 psi starting pressure, 1,700 psi after actuation. First 200 psi in 21 seconds. Full pressure in 1 minute and 31 seconds. 5 Nitrogen Bottles at 2,100 psi. 03:00 - 04:00 1.00 BOPSU P DECOMP Rig down BOP testing equipment and blow down lines. Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 3/13/2007 04:00 - 05:00 1.00 PULL P DECOMP RlU to pull 5-1/2" tubing. Screw XO into tubing hanger. BOLDS. Ensure no pressure on annulus. Screw Top Drive in landing joint. 05:00 - 06:00 1.00 PULL P DECOMP Pull hanger free with 160,000 Ibs, tubing movement @ 190,000 Ibs. Pull hanger to the rig floor and RlU to CBU. 06:00 - 08:00 2.00 PULL P DECOMP Circulate Bottorns Up at 8 BPM with 120 psi. 08:00 - 08:30 0.50 PULL P DECOMP Lay down Tubing Hanger and Landing Joint. 08:30 - 11 :30 3.00 PULL P DECOMP PJSM. R/U Schlumberger Dual Control Line spooling unit and POOH to 1527'. Lay down 5-1/2" NSCC L-80 Tubing. RID spooling unit and lay down used control line. Recovered 25 Stainless Steel Bands. 11 :30 - 18:00 6.50 PULL P DECOMP POOH from 1527'. Lay down 335 joints and one 18.64' cut off joint of 5-1/2" NSCC L-80 Tubing. Lay down 3 GLM and 1 SSSV. 5-1/2" TBG badly corroded with holes and worn threads. No Seals corroded off, top of boxes corroded and brittle up to 2" of threads. 18:00 - 19:00 1.00 CLEAN P DECOMP RID Tubing handling equipment and clean rig floor. 19:00 - 19:30 0.50 CLEAN P DECOMP P/U and set wear ring. 19:30 - 21:30 2.00 CLEAN P DECOMP P/U 9-5/8" HES RBP and RIH on (12) 6-1/4" drill collars picked up from pipe shed. Total BHA= 370.52'. 21 :30 - 00:00 2.50 CLEAN P DECOMP Pick up 4" HT-38 drill pipe and RIH to 2560'. 3/14/2007 00:00 - 05:30 5.50 CLEAN P DECOMP Pick up 4" HT-38 drill pipe and RIH with 9-5/8" HES RBP from 2560' to 9486' 05:30 - 06:00 0.50 CLEAN P DECOMP Establish parameters: Up Weight= 190,000 Ibs; Down Weight= 182,000 Ibs; Circulate at 7 BPM with 100 psi. 06:00 - 07:00 1.00 CLEAN P DECOMP Set HES 9-5/8" RBP at 9486'. Release from RBP and confirm set. 07:00 - 08:30 1.50 CLEAN P DECOMP Circulate gas out of hole. Cleaned up at bottoms up. Monitor well for flow. Well dead. 08:30 - 09:00 0.50 CLEAN P DECOMP POOH 3 stand of 4" HT-38 drill pipe. Stand back drill pipe in derrick. 09:00 - 10:00 1.00 CLEAN P DECOMP RU floor and equipment to test 9-5/8" CSG. Pressure up on 9-5/8" Casing. Hold 3350 psi for 30 minutes. Chart good results. Test witnessed by BP WSL. Bleed off pressure. 10:00 - 10:30 0.50 CLEAN P DECOMP M/U HES 9-5/8" Storm PKR and RIH. Set 5' below wellhead and release from Storm PKR. 10:30 - 11 :00 0.50 CLEAN P DECOMP RU floor and equipment to test 9-5/8" Storm PKR. Pressure up on Storm PKR. Hold 1000 psi for 15 minutes. Chart good results. Test witnessed by BP WSL. Bleed off pressure. 11 :00 - 12:00 1.00 CLEAN P DECOMP Pull wear ring and pump out BOP stack. 12:00 - 13:30 1.50 WHSUR P DECOMP Nipple down BOPE and BOLDS. Remove 13-5/8" x 11" adaptor flange, 11" TBG spool, and 9-518" pack off. Stand back and secure BOPE. 13:30 - 14:30 1.00 WHSUR P DECOMP Clean casing stub and clean out pack off bowl in casing head. Change out one each lock down screw on casing head. 14:30 - 16:30 2.00 WHSUR P DECOMP P/U FMC running/pulling tool and engage 13-3/8" x 9-518" pack off. Set Pack off through rig floor. 16:30 - 18:30 2.00 WHSUR P DECOMP Install reconditioned 13-5/8" x 13-5/8" tubing spool. Install BOPE on tubing spool and N/U. Install riser and flow line to BOPE. 18:30 - 19:30 1.00 WHSUR N DECOMP NID reconditioned tubing spool to change out tubing head studs that were not to BP specs. Tubing head studs were not long enough to give required two threads over full nut. Wait on Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/8/2007 3/31/2007 new studs. Installed one each LDS into tubing spool. Wait on studs for tubing spool. Install new tubing spool studs into tubing spool. N/U BOPE and tubing spool. RILDS and touqued to 450 ft-Ibs energizing pack off. Test tubing spool void. Test to 3360 psi and hold for 30. Good test. Test witnessd by BP WSL. RlU BOP testing equipment and test BOP breaks to 250 psi low test and 3360 psi high test. Test witnessed by Doyon Toolpusher and BP WSL. Pull test plug and set wear ring. P/U Storm PKR running tool and RIH. Sting into 9-5/8" Storm PKR. Release and POOH with 9-5/8" Storm PKR that was set 5' below Wellhead. UD Storm PKR. RIH with 4" HT-38 drill pipe from derrick to 9486'. Establish parameters, Up Weight= 190,000 Ibs; Down Weight= 182,000 Ibs; Circulate at 5 BPM with 350 psi. Latch up to HES RBP and work RBP. Relax elements by setting 15,000 Ibs on RBP and 15,000 Ibs overpull. CBU with 1300 psi at 8 BPM. Small amout of gas detected at bottoms up. Continue circulating clean. Monitor well and RlU to POOH. POOH with 9-5/8" HES RBP. Stand back 4" HT-38 Drill Pipe and 4 stands of 6-1/4" Drill Collars in Derrick. Lay down 9-5/8" HES RBP and Running Tool. Pick up fishing BHA #1consisting of 5-1/2" Type "D" Tri-State Spear, (2) X/O, Bumper Sub, Jars, X/O, 4 Stands 6-1/4" Drill Collars, X/O, Accelerator Jars, Pump Out Sub, and X/O. Total Length of BHA #1 = 419.45' DECOMP RIH with BHA #1 on 4" HT-38 Drill Pipe from Derrick. Tagged top of 5-1/2" Tubing Stub at 9545'. DECOMP Establish parameters at 9545', Up Weight= 187,000 Ibs; Down Weight= 182,000 Ibs; Rotating Weight= 189,000 Ibs at 20 RPM and 2500 ft-Ibs Free Torque. Pump Rate at 4.25 BPM with 560 psi. Run Spear into 5-1/2" Tubing with pump pressure increasing to 590 psi. Rotate 2 right hand turns to engage Spear. Pull 20,000 Ibs overpull to open Jars. Set down 5,000 Ibs on 5-1/2" Tubing and Rotate 11 right hand turns to back out K-Anchor. Pick up 10' without overpull. Pump pressure remained at 590 psi. Drop Ball and open Circulating Sub with 1200 psi. CBU with 1140 psi at 8 BPM. Monitor well for flow. Pump Dry Job. Well taking an average of 9 BPH while circulating. POOH with K-Anchor standing back 4" HT-38 drill pipe in derrick. POOH with BHA #1 standing back 4 stands of 6-1/4" Drill Collars. Lay down Spear Assembly. Change over to handle 5-1/2" Tubing. POOH with 5-1/2" and 4-1/2" Tubing. Break out and lay down K-Anchor. Total length of fish= 48.10' A Composit Plug was set in K-Anchor during pre-rig work. Could not see Composit Plug due to fill and debris in K-Anchorl 3/14/2007 18:30 - 19:30 1.00 WHSUR N DECOMP 19:30 - 20:30 1.00 WHSUR N DECOMP 20:30 - 21 :00 0.50 WHSUR N DECOMP 21 :00 - 22:00 1.00 WHSUR P DECOMP 22:00 - 23:00 1.00 WHSUR P DECOMP 23:00 - 23:30 0.50 WHSUR P DECOMP 23:30 - 00:00 0.50 DHEOP P DECOMP 3/15/2007 00:00 - 00:30 0.50 DHEOP P DECOMP 00:30 - 01 :00 0.50 DHEOP P DECOMP 01 :00 - 02:30 1.50 DHEOP P DECOMP 02:30 - 07:30 5.00 DHEOP P DECOMP 07:30 - 09:00 1.50 CLEAN P DECOMP 09:00 - 12:30 3.50 CLEAN P 12:30 - 13:30 1.00 CLEAN P 13:30 - 15:00 1.50 CLEAN P DECOMP 15:00 - 17:30 2.50 CLEAN P DECOMP 17:30 - 18:30 1.00 CLEAN P DECOMP 18:30 - 20:00 1.50 CLEAN P DECOMP Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/15/2007 18:30 - 20:00 1.50 CLEAN P DECOMP Fish. 20:00 - 20:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor 20:30 - 22:00 1.50 CLEAN P DECOMP Pick up PKR Milling Assembly for 9-5/8" SB-3 Baker PKR. BHA #2 consisting of 8-1/2" PKR Mill, (3) Boot Subs, Bit Sub, Bumper Sub, Jars, X/O, (4) stands 6-1/4" Drill Collars, and X/O to 4" HT-38 Drill Pipe. Total Length of BHA #2= 413.01' 22:00 - 00:00 2.00 CLEAN P DECOMP RIH with BHA #2 on 4" HT-38 Drill Pipe from Derrick to 6073'. 3/16/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP RIH with BHA #2 (9-5/8" PKR Milling Assembly with 3-518" Solid Bull Nose) on 4" HT-38 Drill Pipe from Derrick. Tag 9-5/8" Baker SB-3 PKR at 9594'. 01:30 -10:30 9.00 CLEAN P DECOMP Establish Parmeters, Up Weight= 187,000 Ibs; Down Weight= 183,000 Ibs; Rotating Weight= 190,000 Ibs at 70 rpm with 3500 ft-Ibs Free Torque. Pump Pressure on Bottom= 900 psi at 6.8 BPM. Mill PKR from 9594' to 9597' with 15,000 to 30,000 Ibs WOB, 4500 to 12,000 ft-Ibs Torque at 80 RPM, 900 psi at 6.8 BPM. 10:30 - 12:00 1.50 CLEAN P DECOMP Circulate High Viscosity Sweep at 6.5 BPM with 1020 psi without any extra cuttings to surface. 12:00 - 12:30 0.50 CLEAN P DECOMP Monitor well and check for flow. Blow down top drive. 12:30 - 16:00 3.50 CLEAN P DECOMP POOH with PKR Milling Assembly. Stand back 4" HT-38 Drill Pipe in Derrick. 16:00 - 17:00 1.00 CLEAN P DECOMP Handle BHA. Stand back (4) 6-1/4" Drill Collars. Lay down PKR Mill and clean out Boot Subs. Recovered 4 gallons of metal from 3 Boot Subs. 17:00 - 17:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 17:30 - 18:30 1.00 CLEAN P DECOMP Pick up Spear Assembly for 9-5/8" Baker SB-3 PKR consisting of Spear, X/O, Bumper Sub, Jars, X/O, (4) Stands 6-1/4" Drill Collars, X/O, Accelerator Jars, Pump Out Sub, and X/O to 4" HT-38 Drill Pipe. Total Length of BHA #3= 420.22' 18:30 - 21:00 2.50 CLEAN P DECOMP RIH with BHA #3 on 4" HT-38 Drill Pipe from Derrick to 8088'. 21 :00 - 22:00 1.00 CLEAN P DECOMP Slip and Cut 97' of Drill Line 22:00 - 22:30 0.50 CLEAN P DECOMP RIH with BHA #3 on 4" HT-38 Drill Pipe from Derrick. Tag Top of 9-5/8" Baker SB-3 PKR at 9597'. 22:30 - 23:00 0.50 CLEAN P DECOMP M/U Top Drive and Establish Parameters: Up Weight= 195,000 Ibs; Down Weight= 184,000 Ibs; Pump Pressure at 250 psi with 2.8 BPM. Bottomed out No-Go at 9602' while Pump Pressure increased to 280 psi. Pulled 25,000 Ibs overpull to 220,000 Ibs where Jars opened. Continue pulling to 240,000 Ibs (45,000 Ibs overpull) where 9-5/8" Baker SB-3 PKR pulled free with 10,000 Ibs extra weight noticed on Wait Indicator. New Up Weight= 205,000 Ibs. 23:00 - 00:00 1.00 CLEAN P DECOMP Drop Ball to open Pump Out Sub at 4.7 BPM with 500 psi. Sheared Pump Out Sub with 900 psi. CBU with 1000 psi at 8 BPM. 3/17/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP Engage 9-5/8" Baker SB-3 PKR at 9597'. Drop Ball to open Pump Out Sub at 4.7 BPM with 500 psi. Sheared Pump out Sub with 900 psi. CBU at 8 BPM with 1090 psi. Monitor Well and check for flow. Blow down Top Drive. 01 :00 - 05:30 4.50 CLEAN P DECOMP POOH with 9-5/8" Baker SB-3 PKR and 4-1/2" TBG. Stand back 4" HT-38 Drill Pipe in Derrick. 05:30 - 07:30 2.00 CLEAN P DECOMP POOH and lay down (12) 6-1/4" Drill Collars, Subs, Bumper Sub, and Jars. Printed: 412/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/17/2007 07:30 - 08:00 0.50 CLEAN P DECOMP Lay Down Spear and 9-5/8" Baker SB-3 PKR. 08:00 - 09:30 1.50 CLEAN P DECOMP PJSM. RlU and Lay Down (23) full Joints of 4-1/2" TBG, (2) GLM, and (1) 4-1/2" Cut Off Joint of TBG. Cut Off Length= 18.30' TBG cut was flared to 5-7/8" OD and sliced 18". 09:30 - 10:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 10:00 - 11 :30 1.50 CLEAN P DECOMP Change Out Top Drive Saver Sub. 11 :30 - 13:30 2.00 CLEAN P DECOMP Pick up BHA #4 (Dress Off Assembly) to dress off flared TBG cut at 10,590' consisting of Wash Pipe with Burn Shoe, Boot Sub, 4-3/4" Bumper Sub, 4-3/4" Jars, XIO, and (12) 4-3/4" Drill Collars. 13:30 - 17:00 3.50 CLEAN P DECOMP RIH with BHA #4 (Dress Off Assembly) on 4" HT-38 Drill Pipe from Derrick. Picked up another 30 Joints of 4" HT-38 Drill Pipe and RIH to 10,564'. 17:00 - 18:00 1.00 CLEAN P DECOMP Establish Milling Parameters. Up Weight= 190,000 Ibs; Down Weight= 185,000 Ibs; Rotating Weight= 190,000 Ibs at 60 RPM with 3,500 ft-Ibs Free Torque; Pump Pressure= 310 psi at 3.5 BPM. RIH and tag top of TBG Stub at 10,590'. Increased pump rate to 5.5 BPM with 780 psi. Dress off TBG Stub at 60 RPM with 4,000-5,000 ft-Ibs Torque and 1000 to 4000 Ibs WOB. Pump Pressure increased to 870 psi while milling over TBG. Continue milling to 10,599'. Confirm TBG Stub was dressed off by working over 3 times with the 90 psi increase in pump pressure each time. 18:00 - 20:00 2.00 CLEAN P DECOMP Pump 20 bbl high viscosity sweep at 8 BPM and 1380 psi. Sweep brought up a slight increase in cuttings to surface. Monitor well for flow. Blow down Top Drive and Prep to POOH. 20:00 - 23:30 3.50 CLEAN P DECOMP POOH with Dress Off Assembly from 10,564' to 402'. Stand back 4" HT-38 Drill Pipe in Derrick. 23:30 - 00:00 0.50 CLEAN P DECOMP POOH with with BHA #4 (Dress Off Assembly). Stand back 4 Stands of 4-3/4" Drill Collar. Lay down Washpipe and Boot Sub. 3/18/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Pick up BHA #5 (Overshot and Grapple Assembly) to catch top of TBG Stub at 10,590'. BHA #5 consisting of Guide Shoe, Overshots with 4-1/2" Grapple, Overshot Extension, Top Sub, 4-3/4" Bumper Sub, 4-3/4" Jars, Pump Out Sub, XIO, 4 Stands of 4-3/4" Drill Collars, and XIO to HT-38 Drill Pipe. Total Length of BHA #5= 416.98' 00:30 - 04:30 4.00 CLEAN P DECOMP RIH with BHA #5 (Overshot and Grapple Assembly) on 4" HT-38 Drill Pipe from Derrick to 10,580'. 04:30 - 05:30 1.00 CLEAN P DECOMP Establish Fishing Parameters. Up Weight= 190,000 Ibs; Down Weight= 185,000 Ibs; Rotating Weight= 192,000 Ibs at 30 RPM and 3,000 ft-Ibs Free Torque; Pump pressure= 490 psi at 4.5 BPM. RIH and Tag TBG Stub at 10,590'. Wash over 4-1/2" TBG stub to 10,611' and engage Grapples. Rotate 15 right hand turns to attempt to release K-Anchor. Grapples not set, Jar up to set Grapples. Several attempts to free K-Anchor were made. Gradual increases in overpull were made from 35,000 Ibs over to 85,000 Ibs over, K-Anchor pulled free. 05:30 - 07:30 2.00 CLEAN P DECOMP Drop Ball to open Pump Out Sub at 4.5 BPM with 490 psi. Sheared Pump out Sub with 1700 psi. CBU at 7.5 BPM with Printed: 4/212007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/18/2007 05:30 - 07:30 2.00 CLEAN P DECOMP 1210 psi. Small amout of Gas was detected at bottoms up and cleared up shortly after bottoms up. Monitor Well and check for flow. Blow down Top Drive. 07:30 - 12:30 5.00 CLEAN P DECOMP POOH with BHA #5, (Overshot and Grapple Assembly) with 4-1/2" Tubing Stub and Baker 7" SABL-3 K-Anchor from 10,590' to 416'. Stand back 4" HT-38 Drill Pipe in Derrick. 12:30 - 15:00 2.50 CLEAN P DECOMP POOH with with BHA #5 (Overshot and Grapple Assembly). Stand back 4 Stands of 4-3/4" Drill Collar. Lay down Overshot and Grapples. Recover TBG Stub, 7 Blast Joints, and XIO Assembly. Total Length of Fish= 165.86' K-Anchor did not release. PKR pulled apart. Recovered top section of PKR and Mandrel. Total length of PKR- 3'. 15:00 - 15:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 15:30 - 16:30 1.00 CLEAN P DECOMP Pick up BHA #6 (PKR Milling Assembly) to mill up 7" Baker SABL-3 PKR at 10,759'. BHA #6 consisting of 6" OD PKR Mill, (3) Boot Subs, Bit Sub, Bumper Sub, Jars, XIO, and (4) Stands 4-3/4" Drill Collars. Total Length of BHA #6= 406.93' 16:30 - 19:00 2.50 CLEAN P DECOMP RIH with BHA #6 on 4" HT-38 Drill Pipe from derrick to 10,665'. 19:00 - 22:00 3.00 CLEAN P DECOMP Make up Top Drive and Establish Milling Parameters. Up Weight= 193,000 Ibs; Down Weight= 185,000 Ibs; Rotating Weight= 193,000 Ibs at 80 RPM with 4500 ft-Ibs Free Torque; Pump Pressure= 900 psi at 6 BPM. RIH and Tag Top of PKR at 10,759'. Mill on 7" Baker SABL-3 PKR with 5000 to 15,000 Ibs WOB and 90 RPM with 4000 to 7000 ft-Ibs Torque. Pump Rate at 6 BPM and 900 psi off Bottom and 930 psi on Bottom. First Sweep pumped while milling brought up minimal cuttings to surface. Continue Milling to 10,762' where 7" PKR fell free. 22:00 - 00:00 2.00 CLEAN P DECOMP Pushed and Chased PKR and Tail Pipe Assembly to 11,015'. Attempted to push and mill PKR to PBTD of 11,160' with no success. 3/19/2007 00:00 - 02:00 2.00 CLEAN P DECOMP Attempt to push 7" Baker SABL -3 PKR past 11,015' with no success. Pump High Viscosity Sweep. Sweep brought Fine Metal Cuttings and Smooze to surface. 02:00 - 06:00 4.00 CLEAN P DECOMP Blow Down Top Drive and POOH with Milling Assembly standing back 4" HT-38 Drill Pipe in Derrick to 406'. 06:00 - 07:00 1.00 CLEAN P DECOMP POOH with BHA #6 (7" PKR Milling Assembly). Stand back (4) stands 4-3/4" Drill Collars in Derrick. Lay down Mill, and Boot Subs. Boot Subs recovered 2-1/2 Gallons of Metal Cuttings. 07:00 - 08:00 1.00 CLEAN P DECOMP Clear and Clean Rig Floor. 08:00 - 08:30 0.50 CLEAN P DECOMP Make up Stack Washing Sub and run through BOPE to clean out junk. 08:30 - 10:00 1.50 CLEAN P DECOMP Pick up BHA #7 (7" and 9-5/8" Scraper Assembly) to scrape both 7" and 9-518" Casings. BHA consists of 6" Bit, 7" Scraper, (2) 5" Boot Subs, Bit Sub, Bumper Sub, Jars, XIO, (4) stands 4-3/4" Drill Collars, 26 Joints of 4" HT-38 Drill Pipe, 2 XIO, 9-5/8" Scraper, Bit Sub, and XIO to 4" HT-38 Drill Pipe. Total Length of BHA= 1245.04' 10:00 - 13:00 3.00 CLEAN P DECOMP RIH with BHA #71245' to 9524' on 4" HT-38 Drill Pipe from Derrick. Printed: 4/212007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/19/2007 13:00 - 14:00 1.00 CLEAN P DECOMP PJSM. Slip and Cut 83' Driling Line. Inspect Saver Sub, Lubricate Dynamatic Brake Engagement Ring. 14:00 - 14:30 0.50 CLEAN P DECOMP Continue RIH with 4" HT-38 Drill Pipe from Derrick to 10,959'. 14:30 - 16:00 1.50 CLEAN P DECOMP Make up Top Drive and establish Parameters. Up Weight= 200,000 Ibs; Down Weight= 187,000 Ibs; Rotating Weight= 195,000 Ibs at 40 RPM and 4000 ft-Ibs Free Torque; Pump Pressure= 1590 psi at 8.5 BPM. Tag top of 7" PKR at 11,015'. Depth of 7" Scraper 11,012' and depth of 9-5/8" Scraper to 9780'. Pump 20 bbl Sweep at 8.5 BPM with 1610 psi. Sweep brought back returns of Smooze. 16:00 - 16:30 0.50 CLEAN P DECOMP POOH 2 stands and make up Top Drive. Pump at 8.5 BPM with 1590 psi. Rotate and Reciprocate 9-5/8" Scraper from 9538' to 9633'. Expected setting depth of 9-5/8" PKR= -9576'. Rotate and Reciprocate 7" Scraper from 10,775' to 10,870'. Expected setting depth of 7" PKR= -10,400 16:30 - 17:00 0.50 CLEAN P DECOMP Break and blow down Top Drive. POOH standing back 4" HT-38 Drill Pipe in Derrick. 17:00 - 18:00 1.00 CLEAN P DECOMP Perform Man Down Drill with Endicott Emergency Response Team. 18:00 - 21 :00 3.00 CLEAN P DECOMP Continue POOH standing back 4" HT-38 Drill Pipe in Derrick. 21 :00 - 23:00 2.00 CLEAN P DECOMP POOH with BHA #7 (7" and 9-5/8" Scraper Assembly). Stand back 4 stands 4-3/4" Drill Collars. Lay down Scrapers, Boot Subs, and XIO Subs. No recovery in Boot Subs. 23:00 - 23:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 23:30 - 00:00 0.50 CLEAN P DECOMP Pull Wear Ring and install Test Plug. Prep to test BOPE. 3/20/2007 00:00 - 07:00 7.00 CLEAN P DECOMP Test BOPE to 250 psi Low Pressure and 3,360 psi High Pressure. Each Test was held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Lower Pipe Rams with 4" Test Joint, Upper IBOP Test #2- Annular Preventer, Manual Choke and Kill Valves, Lower IBOP Test #3- HCR Choke and Kill Valves Test #4- Choke Valves No.1, 12, 13, 14, and TIW Valve Test #5- Choke Valves No.9, 10, and Dart Valve Test #6- Choke Valves No.5, 8, and 10 Test #7- Choke Valves No.4, 6, and 7 Test #8- Choke Valve NO.2 Test #9- Choke Valve No.3 and Blind Rams Test #10- Upper Pipe Rams with 5-1/2" Test Joint Test #11- Lower Pipe Rams with 5-1/2" Test Joint Test #12- Upper Pipe Rams with 4-1/2" Test Joint Accumulater Test- 3,000 psi Starting Pressure. 1,750 psi after actuation. First 200 psi in 17 seconds. Full Pressure in 1 Minute and 27 Second. 5 Nitrogen Bottles at 2,150 psi. RID BOP Testing Equipment and blow down lines. 07:00 - 13:00 6.00 CLEAN P DECOMP Make up HES Champ PKR and RIH to 9814'. Stop at 7" Liner Top. Work throught Liner Top several times to insure no problems. Continue RIH to seting depth of 10,494'. 13:00 - 14:00 1.00 CLEAN P DECOMP Set HES Champ PKR at 10,494' and Test Wellbore Integrity to 3360 psi for 30 Minutes Charting Results-Good Test. Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 3/20/2007 14:00 - 22:00 8.00 CLEAN P DECOMP Release HES Champ PKR and POOH with 4" HT-38 Drill Pipe. Lay down Drill Pipe while POOH. 22:00 - 22:30 0.50 CLEAN P DECOMP Lay down HES Champ PKR. 22:30 - 00:00 1.50 EVAL P DECOMP NID Bell Nipple and N/U Shooting Flange to top of BOPE. 3/21/2007 00:00 - 00:30 0.50 EVAL P DECOMP Nipple up Shooting Flange to top of BOPE. 00:30 - 01 :30 1.00 EVAL P DECOMP PJSM with Schlumberger Wireline Services. RlU SWS Lubricator to Shooting Flange and E-Line Sheeves. SWS rigged up with Wireline BOPE on Lubricator with Pump In Sub and Grease Head/Pack off. 01 :30 - 03:00 1.50 EVAL P DECOMP RIH with SWS USIT Logging Tool to 9800'. 03:00 - 07:30 4.50 EVAL P DECOMP Log with SWS USIT Logging Tool in the Cement and Corrosion Mode to 200'. 07:30 - 09:00 1.50 EVAL P DECOMP Make Repeat Passes over areas of 30% Corrosion. From 5900' - 5500' and 2750' - 2650'. 09:00 - 10:30 1.50 EVAL P DECOMP POOH with E-Line and RID E-Line Sheeves, Lubricator, BOP's, Pump In Sub and Lub Extension. 10:30 - 12:00 1.50 DECOMP NID Shooting Flange and N/U Flow Riser. 12:00 - 13:30 1.50 i RUNCMP Move Completion Jewelry into Pipe Shed. Confirm Measurements and Inspect all Components. Arrange Jewelry in Proper Running Order. 13:30 - 14:00 0.50 RUNCMP Rig Up and Inspect Pipe Handling Equipment, Power Tongs and Torque Turn Equipment. 14:00 - 14:30 0.50 I RUNCMP Pre Job Safety Meeting on Running Completion. Focus on Hand Placement I Safety and Procedures. 14:30 - 00:00 9.50 RUNCMP M/U and Run 4-1/2" TC-II x 5-1/2" Hydril 563, L-80 Completion to 7320'. Jet Lube Seal Guard Dope used on connections. Torque Turn used on all connections, 4-1/2" TC-II to 3850 ft-Ibs and 5-1/2" Hydril 563 to 6700 ft-Ibs. All connections below 7"x4-1/2" Baker Premier PKR were Baker Locked. 3/2212007 00:00 - 01 :30 1.50 RUNCMP Continue Running Completion L-80 5-1/2"x4-1/2" Tbg Completion. 01 :30 - 03:00 1.50 RUNCMP PJSM. P/U HES SCSSV and RlU Dual Control Line Spools. Purge Lines, Tie into Safety Valve, Pressure Test to 5000 psi for 10 Minutes. 03:00 - 07:00 RUNCMP Continue RIH with Completion. Clamp Dual Control Line to 5-1/2" Hydril563 TBG with single Cannon Clamp per Joint on Collar. 35 Cannon Clamps and 2 Stainless Steel Bands were run. 07:00 - 09:00 RUNCMP M/U Hanger to String and M/U Landing Joint. Thread Control Lines Through Hanger. Test Control Lines to 5000 psi for 10 mins each. 09:00 - 09:30 0.50 RUNCMP Land Tbg Hanger. Up weight = 190,000 Ibs; Down Weight = 187,000Ibs. 09:30 - 10:30 1.00 RUNCMP Rig Up to Reverse Circ. Pressure Test Lines to 4400 psi. 10:30 - 14:30 4.00 RUNCMP Reverse Circulate 240 bbls of 140 deg 2% KCL and 440 bbls of 2% KCL wI Corrosion Inhibitor. Pump at 3 bpm and 140 psi. 14:30 - 15:30 1.00 RUNCMP BIO Circulating Head and RlU Test Chart. Drop 1-7/8" Ball and Rod Assembly. RlU Circ Head and Pressure Up Tbg to 4200 psi for 10 mins to set packer. Pressure Not Holding - Lost 400 psi in 10 mins. Bleed back tbg pressure to 3500 psi and hold pressure in attempt to get tbg pressure test. Lost 400 psi in 15 mins. Call Town and Consult. 15:30 - 16:00 0.50 RUNCO DFAL RUNCMP Pressure Up again on tbg to 3500 psi and test for 30 mins on Printed: 4/212007 10:57:22 AM chart. Lost 900 psi in 30 mins; first 10 mins lost 400 psi, second 10 mins lost 250 psi, lost 225 psi in last 10 mins. DFAL RUNCMP Bleed tbg pressure back to 1750 psi and shut in. Pressure Up on Annulus to 3360 psi and test on chart for 30 mins. Annulus lost -175 psi in 30 mins. Tbg Pressure increase steadily gaining 320 psi over the interval. DFAL RUNCMP Consult town again. Bleed Off Pressure on Tbg and Shear DCR Valve. Valve Sheared at 1,200 psi differential. Pump 5 bbls both ways through valve to confirm fully open. Pressure Up Tbg and IA to 3360 psi and test for 30 mins on chart to confirm packer set and casing pressure test holding. Good Test. Back out and UD landing joint. Install TWC and test from above and below to 1,000 psi for 10 minutes on chart. Good Test. NID and standback BOP stack. Prep control lines and tubing hanger for adapter flange. N/U adapter flange and control line ports. RlU and Pressure Test Control Lines to 5000 psi. Hold Test for 20 minutes. Good Test. RlU and Pressure Test Adapter Flange Void to 5000 psi. Hold test for 30 minutes. Good Test. RID Testing Equipment. P/U reconditioned Master Valve and spot on Adapter Flange. P/U and spot 2nd Tree Valve on Master Valve with 7" Otis Union Tree Cap. Nipple Up Tree. R/U and Pressure Test Tree to 5000 psi and hold for 30 minutes. Good Test. RlU DSM Lubricator and Equipment. Pull TWC Valve. RID DSM R/U Little Red and Pressure Test Lines to 1500 psi. Pump 16 bbls diesel down IA and take returns off tbg. Allow Diesel to U-Tube for 30 mins. BID Lines and Hoses. RID Little Red. Move In and Spot Slick Line. PJSM wI Slickline and Crew. Rig up lubricator, BOP's, and Wireline Sheeves. PT Surface Equipment to 2500 psi RIH w/ Slickline and Pull Dummy Sleeve from SSSV at 1502' md. POOH P/U Widdon Catcher and RIH. Set Catcher at 4-1/2" x 5-1/2" XO at 9536' md. POOH RIH and Pull DCR Valve from 5-1/2" x 1-1/2" GLM at 3714' md. POOH. Inspection of Valve showed no markings in packing or other evidence of leaks. P/U Dummy GLV and RIH. Set Dmy Valve in GLM at 3714' md. POOH CIO running tools and RIH and retrieve Widdon Catcher at 9,536' md. POOH CIO tools and P/U SSSV Dummy Sleeve and RIH. Purge control lines and set Dummy sleeve at 1,505' md. POOH RID SWS equipment and standback. RIU test equipment. Pressure test tubing to 3,500 psi for 30 minutes. Pressure bled off 400 psi in 5 minutes with fluid returns from the IA. Discuss options with town. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 16:00 - 17:00 1.00 17:00 - 18:30 18:30 - 20:30 RUNCMP 20:30 - 21 :30 1.00 RUNCMP 21 :30 - 22:30 1.00 RUNCMP 22:30 - 00:00 1.50 RUNCMP 3/23/2007 00:00 - 01 :00 1.00 RUNCMP 01 :00 - 02:00 1.00 RUNCMP 02:00 - 04:00 2.00 RUNCMP 04:00 - 05:30 1.50 RUNCMP 05:30 - 06:30 1.00 RUNCMP 06:30 - 07:30 1.00 RUNCMP 07:30 - 08:00 0.50 RUNCMP 08:00 - 10:30 2.50 RUNCMP 10:30 - 11 :00 0.50 RUNCMP 11 :00 - 12:30 1.50 RUNCMP 12:30 - 15:00 2.50 RUNCMP 15:00 - 16:30 1.50 RUNCMP 16:30 - 17:30 1.00 RUNCMP 17:30 - 19:30 2.00 RUNCMP 19:30 - 22:30 3.00 RUNCMP 22:30 - 23:30 1.00 RUNCMP 23:30 - 00:00 0.50 RUNCMP Start: Rig Release: Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/8/2007 3/31/2007 Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 RID Test Equipment and M/U Slickline Lubricator to Tree Cap. RIH wI Slickline and Pull Dummy Sleeve from SSSV at 1502' md. POOH 01 :00 - 03:00 2.00 RUNCMP P/U Widdon Catcher and RIH. Set Catcher at 4-1/2" x 5-1/2" XO at 9536' md. POOH 03:00 - 04:00 1.00 RUNCMP RIH and Pull DGLV from 5-1/2" x 1-1/2" GLM #1 at 6027' md. POOH. Inspection of Valve showed no markings in packing or other evidence of leaks. 04:00 - 05:30 1.50 RUNCMP P/U DGLV and RIH. Set DGLV in 5-1/2" x 1-1/2" GLM #1 at 6027' md. POOH 05:03 - 07:00 1.95 RUNCMP CIO running tools. RIH and retrieve Widdon Catcher at 9,536' md. POOH 07:00 - 08:00 1.00 RUNCMP CIO tools and P/U SSSV Dummy Sleeve and RIH. Purge control lines and set Dummy sleeve at 1,505' md. POOH 08:00 - 08:30 0.50 RUNCMP RID SWS equipment and standback. RlU test equipment. 08:00 - 10:00 2.00 RUNCMP Pressure test tubing to 3,500 psi for 30 minutes. Pressure bled off 500 psi in 15 minutes with fluid returns from the IA. 10:00 - 11 :00 1.00 RUNCMP RID Test Equipment and M/U Slickline Lubricator to Tree Cap. RIH wI Slickline and Pull Dummy Sleeve from SSSV at 1502' md. POOH 11 :00 - 14:00 3.00 RUNCMP Wait on 4-1/2" Junk Catcher Sub from SWS. 14:00 - 16:00 2.00 RUNCMP P/U Junk Catcher Sub and RIH. Set Catcher at 4-1/2" "x" Nipple below PKR at 10,433' md. POOH 16:00 - 18:00 2.00 RUNCMP RID SWS Slickline Equipment and Tools. 18:00 - 21 :30 3.50 RUNCMP MIRU SWS E-Line Unit. P/U Tools and BOPE Equipment. RlU E-Line Lubricator Extensions to Tree Cap with Double set of BOPE and Pump in Sub. Pressure Test SWS Lubricator. 21 :30 - 22:30 1.00 RUNCMP PJSM with SWS and Rig Crew. RlU and Arm SWS Chemical CutterTool for cutting 4-1/2" 12.6#, L-80 TBG. 22:30 - 00:00 1.50 RUNCMP Open Well and RIH with SWS Chemical Cutter to 8000'. 3/25/2007 00:00 - 00:30 0.50 RUNCMP Continue RIH with SWS Chemical Cutter from 8000' to 10,380' and cut TBG. 00:30 - 03:00 2.50 RUNCMP POOH with SWS Chemical Cutter. Positive indication of Firing Head of Cutter. UD Cutting Tool and RID SWS Tools and Equipment. 03:00 - 03:30 0.50 RUNCMP RlU Circulating Lines to Tree and Pressure Test to 2500 psi. 03:30 - 06:30 3.00 RUNCMP PJSM. Displace Well with 8.5 ppg 2% KCI Brine at 6 BPM with 470 psi. Dispose of old PKR fluid with Corrosion Inhibitor. 06:30 - 08:00 1.50 RUNCMP Wait on DSM. 08:00 - 10:30 2.50 RUNCMP RlU Drill Site Maintance Lubricator. Set TWC and Test to 1,000 psi from below. Hold pressure for 10 minutes, good test. Attempt to test to 3,360 psi from above. Test Failed. RlU DSM Lubricator. 10:30 - 13:00 RUNCMP P/U new TWC and set. Test TWC Valve to 1,000 psi from below. Hold test for 10 minutes, good test. Test to 3,360 psi from above and hold for 10 minutes, good test. All tests charted. RID DSM. 13:00 - 14:00 1.00 RUNCMP NID Tree and remove Control Lines from Wellhead. Prep Hanger to POOH. 14:00 - 15:30 1.50 RUNCMP N/U BOPE. RlU hoses and lines, fill BOP Stack. 15:30 - 16:00 0.50 RUNCMP RlU BOP Testing Equipment. 16:00 - 21 :00 5.00 RUNCMP Test BOPE to 250 psi Low Pressure and 3,360 High Pressure. Each Test was held for 5 Minutes. AOGCC Witness of Test Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 21 :00 - 21 :30 21 :30 - 22:30 0.50 RUNCO 1.00 RUNCO was Waived by Chuck Scheve. Test was Witnessed by the Doyon Toolpusher andBP WSL Test #1- Annular Preventer with 4" Test Joint, HCR Choke, HCR Kill, and Upper IBOP Test #2- Manual Choke, Manual Kill, and Lower IBOP Test #3- 3-1/2" x 6" VBR (Lower) Pipe Rams with 4" Test Joint Test #4- 4-1/2" x 7" VBR (Upper) Pipe Rams with 4-1/2" Test Joint Test #5- Choke Valves No.1, 12, 13, 14, TIW Valve, and 4-1/2" x 7" VBR Pipe Rams with 5-1/2" Test Joint Test #6- Choke Valves No.9, 11, and Dart Valve Test #7- Choke Valves No.5, 8, and 10 Test #8- Choke Valves No.4, 6, and 7 Test #9- Choke Valve NO.2 Test #10- 3-1/2' x 6" VBR (Lower) Pipe Rams with 5-1/2" Test Joint Test #11-Choke Valve No.3 and Blind Rams Accumulater Test- 2900 psi Strarting Pressure. After First Actuation- 1700 psi. First 200 psi in 19 seconds. Full Pressure in 1 minute and 27 seconds. 5 Nitrogen Bottles at 2150 psi. RUNCMP RlU DSM Lubricator and Extention. Pull TWC. RID DSM. RUNCMP P/U Landing Joint and Sting into HGR. BOLDS. Pull HGR to Rig Floor. HGR Pulled Free at 185,000 Ibs, 5-1/2" x 4-1/2" TBG Pulled Free at 190,000 Ibs. Terminate Control Lines from TBG HGR. RlU Circulating Lines and CBU at 8.5 BPM with 680 psi. RlU HES Control Line Retrieving Spools. Continue CBU at 8.5 BPM with 680 psi. RlU Doyon TBG Handling Equipment with Compensator and Double Stacked Tongs. RlU HES Control Line Retrieving Spools. Continue R/U Doyon TBG Handling Equipment with Compensator and Double Stacked Tongs. RlU Long Bails on Top Drive. UD 5-1/2",17.0#, Hydril562, L-80 TBG to SSSV. RID and UD HES Control Line Spools and Equipment. Continue UD while POOH with 5-1/2" Hydril TBG to 844'. RID 5-1/2" TBG Handling Equipment and RlU 4-1/2" TBG Handling Equipment. Continue UD while POOH with 4-1/2", 12.6#, L-80 Completion. Recoved 35 Cannon Clamps and 2 Stainless Steel bands, SSSV, 2 GLM, 5-1/2" x 4-1/2 X/O, and "x" Nipple. TBG Cut was at 0.95' on 3rd 4-1/2" Pup Joint below "x" Nipple. Inspection of Cut showed a goodlclean cut with no flare. TBG Stub= 9' RUNCMP Consult with town, decision make to RIH with Completion without Dress Off Run. Gather all personnel necessary to run Completion. Sort new and used Completion Jewelry and finalize Running Order. PJSM with Rig and Completion Personnel. RUNCMP P/U and RIH with 4-1/2" Completion BHA consisting of 7" x 4-1/2" Unique Overshot, "x" Nipple with RHC Plug, 7" x 4-1/2" Baker S-3 PKR, "x" Nipple with D-16 Plug installed, (17) Joints 22:30 - 00:00 1.50 RUNCMP 3/26/2007 00:00 - 00:30 0.50 RUNCO RUNCMP 00:30 - 01 :30 RUNCMP 01 :30 - 05:00 3.50 RUNCMP 05:00 - 06:00 1.00 RUNCMP 06:00 - 18:00 12.00 RUNCMP 18:00 - 22:00 4.00 RUNCO 22:00 - 00:00 2.00 RUNCO Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 Start: Rig Release: Rig Number: 3/27/2007 00:00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 06:00 06:00 - 08:30 08:30 - 12:30 12:30 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 17:30 17:30 - 21:30 21 :30 - 22:00 22:00 - 00:00 3/28/2007 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 04:30 of 4-1/2", 12.6#, L-80, TC-II TBG and Pups, and 4-1/2" x 5-1/2" X/O. 4-1/2" TC-II connections torqued to 3850 ft-Ibs. All connections below Baker S-3 PKR were Baker-Locked. All normal precautions for running L-80 premium thread were used with Compensator, Stabbing Guide, and Torque Turn Equipment. Jet Lube Seal Guard Dope was used on Threads. 2.50 1.50 1.00 RUNCMP Continue RIH with 4-1/2" x 5-1/2" Completion. 5-1/2" Hydril 563 connections torqued to 6700 ft-Ibs. RUNCMP M/U Circ head to Joint #70 and RlU to pressure test tubing against D16 plug. Pressure Test Tbg to 3000 psi for 10 mins. Good Test. RUNCMP Continue to RIH wI Tbg. RUNCMP M/U Circ head to Joint #104 and R/U to pressure test tubing against D16 plug. Pressure Test Tbg to 3000 psi for 10 mins. RUNCMP Continue to RIH wI Tbg. RUNCMP M/U Circ head to Joint #158 and RIU to pressure test tubing against D16 plug. Pressure Test Tbg to 3500 psi for 10 mins. Pressure Leaking Off. Made Multiple Attempts at Pressure Test. Reverse Circ 20 bbls at 1.7 bpm and 40 psi to flush D16 plug. Pressure Up again on Tbg and Attempt to Pressure Test Tbg to 3500 psi. Monitor Pressure Drop and Fluid gain on back side. Final Pressure showed 350 psi pressure loss in tubing in 80 mins and fluid in the back side was - 2.0 gals in 35 mins. RUNCMP RID Pressure Test Equipment and Clrc Head. RlU to Lay Down Tubing to find leak. RUNCMP POOH and UD Tbg in Pipe Shed. POOH from Joint #158 to GLM #1. RUNCMP Rig Up Pressure Test Equipment and Test Pump. M/U Circ Head Up to GLM #1. Pressure Test Tubing to 3500 psi. Monitor Annulus for fluid movement. Good Test, no fluid movement in annulus. RUNCMP RID Pressure Test Gear and Rig Up to RIH. RUNCMP RIH wI 5-1/2" Hyd 563 Tbg. Increase M/U Torque Values to 8000 ft-Ibs. RlU and Tested Tubing at Jt # 120 To 3,500 psi Good Test. Tested at Jt # 135, Pressure Drop of 125 psi in 15 minutes. RUNCMP RlU and Reverse Circulated to Wash D-16 Profile, at 1.5 bpm wI 40 Psi for 20 bbls. RUNCMP RID Circulating Equipment, RlU to Test Equipment and Test Tubing at Jt # 135 No Test, Attempt Testing again Successful Test. RUNCMP RIH w/5.5" Hydril563 from 5,728' Jt 135 to 6,360' Jt 150. RUNCMP RlU to Test Tubing to 3,500 psi. Tubing Bled Off 300 psi in 15 minutes. Reconfirmed Test with Same Results. RUNCMP RlU to Reverse Circulate, at 2 bpm and 50 psi. RUNCMP RlU and Test Tubing to 3,500 psi, Bleed Off 300 psi in 15 minutes. RUNCMP UD Joints 150 to Jt 146, 6,360' to 6,150'. RUNCMP RlU and Test Tubing to 3,500 psi, Bleed Off 150 psi in 10 minutes. RUNCMP UD Jt #145 to #140,6,150' to 5,728' 1.00 2.50 4.00 0.50 0.50 3.00 1.00 0.50 4.00 2.00 0.50 1.00 0.50 1.00 0.50 0.50 0.50 Printed: 4/212007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05:00 - 09:30 09:30 - 10:00 10:00 - 12:30 12:30 - 18:00 18:00 - 19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 3/29/2007 00:00 - 05:30 05:30 - 07:00 07:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 00:00 3/30/2007 00:00 - 01 :00 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 0.50 2.50 1.00 2.00 1.50 1.50 0.50 0.50 1.00 0.50 1.00 1.00 1.00 0.50 0.50 Start: 3/8/2007 Rig Release: 3/31/2007 Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 RlU to Test Tubing to 3,500 psi. Pressure Bleed Off 75 psi. No Sign of Annular Flow, Test Results Same as Previous Tests, Indicating Leak May Be In Tubing Between Jt 136 and Jt 140 RUNCMP Pressure Test Tubing, to 3,500 psi on Jts #140,139,138, 137, & 136. Connection of each joint in view above Floor. All test have approximatel equivalent leak off rates. 9-5/8" by tubing annulus monitored. A small indication of a leak visable. RUNCMP Set Joint #136 in the slips and BIO Circulating I PRessure Testing Head. Rig Up for Slickline. RUNCMP Rig Up Slickline Pump In Sub, BOP, and Lubricator to 7" Otis to 4-1/2" IF XO. Rig Up Slickline Sheeves and Line. M/U Slickline X-Equilizing spear and GS Pulling Tool. RUNCMP RIH and Pull D-16 Plug from X Nipple #2 at 5611' SLM (5616'MD) and POOH. M/U PXX Plug Body and RIH and Set Plug Body in the same X-Nipple. POOH. M/U Prong for Plug and RIH. Set Prong at 5608' md. POOH RUNCMP Stand Back Slickline Lubricator and BOP's. RlU Pressure Test Equipment. Pressure Test Tbg to 3500 psi for 15 mins. - Good Test! Bleed Off and Rig Down Pressure Test Equipment. RUNCMP Stand Down and Wait on END Ops. Gas Release from END 2-06. ESD Slickline Units and Move Crews to Dog House with Rig Crew. RUNCMP RID SWS Tool, and Pressure Control Equipment. RUNCMP RlU 5.5" Handling Equipment. RIH to Jt #140 RlU Pressure Testing Equipment and Test to 3,500 psi for 15 minutes. Good Test, RID Test Equipment. RUNCMP Continue to RIH From jt # 140 to Jt #145, RlU and Test GOOD Test. Continue to RIH and Test on Jts 150,160,185, All Tests held 3,500 psi for 15 minutes. PIU SSSV. HMAN RUNCMP Wait on Control Lines Spooler to arrive from Deadhorse. RUNCMP RlU Control Line Spooler. RlU Control Lines and M/U to SSSV. Pressure Test Control Lines to 5000 psi for 15 mins. RUNCMP M/U Joint 210 above SSSV and RIH. RUNCMP Rig Up Pressure Test Equipment and Pressure Test String to 3500 psi for 15 mins. Pressure Test Failed. Leaking Off 350 psi in 15 mins. RUNCMP POOH wI Jt #210, SSSV, 209, 208,207, & 206. RUNCMP Rig Up Pressure Test Equipment and PT Tbg to 3500 psi. Good Pressure Test from Jt #205 and Below. RUNCMP M/U Jt #206 & 207 and RIH. RUNCMP Pressusre Test Tbg String to 3500 psi - Good Test from Jt 207 and below. RUNCMP M/U Jt #208 & 209 and RIH. RUNCMP Pressure Test Tbg String to 3500 psi - Good Test from Jt # 209 and below. RUNCMP M/U SSSV to String. Rig Up Pressure Test Equipment and PT to 3500 psi. Visible Leak in NSCC Connection on the Top of the SSSV. SFAL RUNCMP RID Pressure Test Equipment. BIO SSSV and UD. Send SSSV back to HES to be repaired. BIO Hydril 563 x 5-1/2" BUTT XO to send back with SSSV. SFAL RUNCMP Contiue to Wait on SSSV to be Repaired at HES. Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 10/18/1986 End: 3/31/2007 3/8/2007 3/31/2007 P/U SSSV, RlU and Test 1/3,500 psi for 15 Minutes,Good Test, RID Circulating Equipment. Tie In Control Lines to SSSV and Test to 5,000 psi for 10 minutes. RIH w/5.5", L-80, 17#, Hydril563 Tubing to Jt# 220. Pressure Test Tubing to 3,500 psi for 15 minutes, Good Test. RIH w/5.5", L-80, 17#, Hydril 563 Tubing to Jt# 230. Pressure Test Tubing to 3,500 psi for 15 minutes, Good Test. RIH w/5.5", L-80, 17#, Hydril 563 Tubing to Jt# 242. Pressure Test Tubing to 3,500 psi for 15 minutes, Good Test. M/U and RIH wI Joints #243 - 245. Watch Shear Pins Shear wI 10,000 Ibs at 18' in on Joint Number #245. Continue in hole and Stack Out at 22.25' in on Joint #245. Repeat two times to confirm Stack Out in Correct Spot. POOH and UD Joint #245-243. Make Up Hydril 563 x TC-II XO, 4 Space Out Pups, 1 Joint of TC-II and Hanger Assembly. Up Weight = 190,000 Ibs, Down Weight = 182,000 Ibs. M/U Control Lines through Hanger. Pressure Test Pack Off to Control Lines to 5000 psi for 10 mins. Reconnect Control Lines to Spool and Pressure Up Control Lines. RIH wI Hanger on Landing Joint. Land Hanger and RILDS. 35 Cannon Clamps 2 Stainless Steel Bands Used on Control Line. Pressure Test Tbg to 3,500 psi for 30m ins. Test include all tubing from Plug in X Nipple to Hanger and Landing Joint. Good Test. UD Landing Joint. Pump Out Stack. Set Lubricator Extension. Rig Down COntrol Line Spooler and Tubing Handling Equipment. MIRU Slickline. RlU Slickline Lubricator, BOP's, Sheaves, and Lines. Pull Dummy Sleeve from SSSV. RIH to Pull Equilizing Prong f/PXX Plug. RIH to Pull PXX Plug. Drift Ball and Rod Through Dummy Sleeve. Had to Break Tools Down to Drift. After Being Asked to Drift Sleeve Off Line. RIH and Set Dummy Sleeve at 1,514'. RID SWS Pressure Control Equipment. RlU Circulating Lines to Displace Well, Pressure Test Lines to 3,500 psi. Reverse Circulate 235 bbls of 140 deg 8.5ppg Sea Water. Followed by 445 bbls of 140 deg 8.5 ppg Sea Water with Corrosion Inhibitor at 3 bpm w/250 psi. Drop Ball & Rod. Allow to Fall on Seat. Pressure Up on Tubing to 4200 psi and Set Packer as per Baker. Pressure Test Tubing for 30 mins at 4200 psi - Good Test. Bleed Down Tbg Pressure to 1600 psi and Pressure Up on IA to 3360 psi. Pressure Test IA to 3360 psi for 30 mins - Good Test. Bleed Down Tubing Quickly and Shear DCR Valve at 2600 psi differential. RUNCMP Pull Landing Joint. P/U and Set 6" J- Style TWC. Install Landing Joint. Pressure Test TWC from below to 1000 psi for 10 mins and Pressure Test TWC from above to 3360 psi for 10 02:00 - 02:30 0.50 RUNCMP 02:30 - 03:30 1.00 RUNCO RUNCMP 03:30 - 04:00 0.50 RUNCO RUNCMP 04:00 - 05:00 1.00 RUNCO RUNCMP 05:00 - 05:30 0.50 RUNCO RUNCMP 05:30 - 06:30 1.00 RUNCO I RUNCMP 06:30 - 07:00 0.50 RUNCO RUNCMP 07:00 - 07:30 0.50 RUNCO , RUNCMP 07:30 - 09:00 RUNCMP 09:00 - 10:00 1.00 RUNCMP 10:00 - 11 :00 1.00 RUNCMP 11 :00 - 11 :30 RUNCMP 11 :30 - 12:30 RUNCMP 12:30 - 16:00 3.50 RUNCMP 16:00 - 17:00 1.00 RUNCMP 17:00 - 18:30 1.50 RUNCMP 18:30 - 21:30 3.00 RUNCMP 21 :30 - 22:00 0.50 RUNCMP 22:00 - 23:00 1.00 RUNCMP 23:00 - 00:00 1.00 RUNCMP 3/31/2007 00:00 - 01 :00 1.00 RUNCMP 01 :00 - 05:30 4.50 RUNCMP 05:30 - 07:00 RUNCMP 07:00 - 08:30 1.50 RUNCO P Printed: 4/2/2007 10:57:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-34/P-14 2-34/P-14 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 3/8/2007 3/31/2007 Spud Date: 10/18/1986 End: 3/31/2007 09:00 - 10:00 RUNCMP 10:00 - 11 :00 I RUNCMP 11 :00 - 13:00 2.00 WHSUR P RUNCMP 13:00 - 14:30 1.50 WHSUR P RUNCMP 14:30 - 15:00 0.50 WHSUR P RUNCMP 15:00 - 16:00 1.00 WHSUR P RUNCMP 16:00 - 18:30 2.50 WHSUR N SFAL RUNCMP mins. UD Landing Joint and Rig Down Pressure Test Equipment. Blow Down Lines and Hoses. Drain Stack. Nipple Down BOP Stack Cut Control Lines to Length and Insert through Tubing Spool Outlets. Make Valves to End of Control Lines. Pressure Test Control Lines to 5000 psi for 15 mins. N/U Adapter and Dry Hole Tree. End Well Tender verify correct position of tree. Pressure Test Adapter Flange to 5000 psi for 30 mins. Fill Tree with Diesel and Pressure Test Tree to 5000 psi for 30 mins. End Well Tender witness tree test. Rig Down Test Equipment and lines. P/U DSM Lubricator and Pull TWC. MIRU Little Red. RlU to Reverse Circ. Pressure Test Lines to 3000 psi. Pump 18 bbls of Diesel down IA. Allow Diesel to U-Tube for 30 mins. Set BPV with DSM Lubricator and Test to 1000 psi below. Plug Leaking. Attempt to Set 2 times - Plug Leaking by with Minimal Pressure. Pump Out Tree Visually inspect, No Sign of Obstruction. Attempt to Set 3 rd Time, No Test, Upon Pulling BPV it Pulled Tight. Some Scaring on Body of BPV. Change out Internal Mechanism From BPV and Assembled into the TWC, Making it a BPV, Ran BPV Set and Tested to 1,200 psi for 15 minutes. RD DSM Lubricator. Blow Down Rig Down Little Reds Lines. Nipple Down Double Annulus Valve and Secure Well. Rig Released at 21 :00 hrs on 3/31/07 18:30 - 19:30 1.00 WHSUR P RUNCMP 19:30 - 20:30 1.00 RIGD P RUNCMP 20:30 - 21 :00 0.50 RIGD P RUNCMP Printed: 4/2/2007 10:57:22 AM TREE =, . WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 7-1/16" ciw FMC 56.0' 16.4' 5500' 33 @ 8000' 10665' 10000' SS 13-3/8" CSG, 72#, L-80 BTC, ID=12.415" -i 2483' 9-5/8" CSG, 47#, NT80S XO NT95HS, ID = 8.681" 15-1/2" TBG, 17#, L-80, .0232 bpf, ID =' 4.892" Minimum ID = XN Nipple 10498' 14-1/2" TBG, 12.6#, L-80, .0152 bpf. 10- 3958"1 9-5/8" CSG, 47#, NT95HS. 10 "8.681" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10" 3958'" ÆRFORA TION SUMMARY REF LOG: DLL&GR(11/07/86) ANGLEATTOPÆRF: 23 @ 10634' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 5" 4 10634 - 10724 C 07/09/97 5" 4 10732 - 10760 C 07/09/87 5" 4 10795 - 10840 0 07/09/87 2-1/8" 4 10850 - 10890 0 07/13/90 2-3/8" 4 10940 - 10960 0 02/13/94 2-5/8" 4 10940 - 10980 0 07/13/94 2-3/8" 4 10960 - 10980 0 02/13/94 PBTD I 17" LNR, 29#, L-80 BTS, .0371 bpf, ID = 6.276" DATE 11/30/93 02/03/94 07/28/98 06/18/99 10/16/04 03/16/06 REV BY MD JHL DAV TP KDClTLH RPHITI-IL COMMENTS RWO COM PLETION SET TBG PATCH SET NIP REDUCER WAIVER SAFETY NOTE REV WAIVER sm NOTE 10380' 11160' DATE 04/19/06 11/17/06 12/10/06 04/01/07 ST MD TVD 2 3724 1 6026 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE MMG DCR RKP MMG Dummy RP 9546' -i 5-112" X 4-1/2" XO, ID =3813 I -f4-1/2" HES X NIP. ID - 3.813" I -i 7" X 4-1/2" BKR S-3 PKR, 10 = 3.87" -14-1/2" HES X NIP, ID - 3.813" I I'" 7" X 4-1/2" 9Cr Unique Overshot 10399' -17"X4-1/2" BKR PREMIERPKR,ID-3833'" 1 0426' -14-112" HES X NIP, ID = 3.813" I 10498' -14-1/2" HES XN NIP, ID - 3 725" 10519' 1-14-1/2" WLEG REV BY COMMENTS COM'PJC WAIVER SAFETY NOTE CJNJPJC SET XX TTP@ 9600' JCM'JC CONVERT TO NEW FORMATE D-16/MJA RWO ENDICOTT UNIT WELL: 2-34/ P-14 ÆRMIT No: 1861720 API No: 50-029-21662-00 SEC T N R E BP Exploration (Alaska) C/'·, '" E..·-·~' l1 \1, ie,',.,"'.' _ ,~...f1C~ ~ ~::I' tb Schlumbel'ger (' ", ~ l1;~- tV;¡ d l),- APR 2 0 Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ;'\i{)$ka Oil 8., (3as Com~. CO\'f!m¡~ Ancll~~ ~ Well Job# Log Description Date DS 04-01 11637323 SCMT 03/13/07 2-34/P-14 11638622 USIT 03/20/07 N-22B I 11594483 SCMT 03/06/07 N-22B N/A US IT (CORROSION) 02/13/07 N-22B ' N/A USIT (CEMENT BOND) 02/13/07 P2-50B 11626472 SCMT 03/17/07 09-11 " 11638619 USIT (CEMENT EVALUATION) 03/16/07 09-11 . 11638619 USIT (CORROSION) 03/16/07 09-11 . 11638621 CEMENT BOND LOG 03/19/07 L2-32 11221617 RST 10/13/06 A-24 11221856 RST 03/23/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 SCANNED APR 2 5 2007 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: '~ 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color 1 1 1 1 1 1 1 1 1 CD 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: Re: END 2-34 (186-172) RWO addition ofpa. completion . Subject: Re: END 2-34 (186-172) RWO addition of packer to completion From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 09 Mar 2007 13 :40:56 -0900 T().: "Chan,.Paul(PRA)" <PauLChan@bp.com> Thank you. You may proceed as planned. Good luck with the work. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 3/9/2007 1 :36 PM: Tom The rated casing burst tòr both the 9-5/8" and 7" casing will not be exceeded by the calculated pressure increase. Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) ~~ED MAR Q it 2007 From: Thomas Maunder fmailto:tom maunder@admin.state.ak.us] Sent: Friday, March 09, 2007 1:29 PM To: Chan, Paul (PRA) Subject: Re: END 2-34 RWO addition of packer to completion Are there any casing burst concerns? Chan, Paul (PRA) wrote, On 3/912007 1 :22 PM: Tom Our calculations, with anticipated temperature and volume changes, shows a potential pressure increase of less than 2000 psi. This calculated pressure increase is less than the collapse ofthe tubing string and will not exceed the parameters on the packers. Sincerely, Paul Chan workover Engineer BP Alaska/wells Group (907) 564- 52 54 10f2 3/9/2007 1 :41 PM Re: END 2-34 (186-172) RWO addition ofpa.o completion . (907) 440-0183 (cell) (907) 564-5510 (fax) From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, March 01, 2007 9:47 AM To: Chan, Paul (PRA) Subject: Re: END 2-34 RWO addition of packer to completion Paul, I don't remember all the details about this well. Placing the 9-5/8" packer as you describe should help isolate the liner top. Will the fluid between the two packers be isolated or is there the "ability" for it to leak off? The concern I have is the potential burst and collapse forces that a temperature increase could generate. Look forward to your reply. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 311120079:37 AM: Tom Ref Sundry 307-064 BP would like to change the completion on this well by adding a 9-5/8" packer set at -9576' MD. The 7" liner does not have a liner top packer and the addition of the 9-5/8" packer would isolate the 7" liner top from MIT-IA pressure testing. «END2-34 Proposed.pdf» Please let me know if the AOGCC is ok with the proposed change. Sincerely Paul Chan workover Engineer BP Alaska/wells Group (907) 564- 52 54 (907) 440-0183 (cell) (907) 564-5510 (fax) 20f2 3/9/2007 1 :41 PM TREE = WELLHEAD = ACtUA TOR = KB. ELEV = BF. ELEV = KOP'" Max Angle = Datum MD = bâtum l'JÖ",u -34 Proposed Co 7-1/16" ciw FMC 56.0' 16.4' 5500' 33 @ 8000' 10665' Ù)060' 55 13-3/8" CSG, 72#, L-80 BTC, 10=12.415" 9-5/8" CSG, 47#, NT80S XO NT95HS, 10 = 8.681" 15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" I TOP OF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958"1 19-5/8" CSG, 47#, NT95HS, 10 = 8,681" I ~ORATONSUMMARY REF LOG: DLL & GR (11/07/86) ANGLE AT TOP PERF: 23 @ 10634' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 5" 4 10634 - 10724 C 07/09/97 5" 4 10732 - 10760 C 07/09/87 5" 4 10795 - 10840 0 07/09/87 2-1/8" 4 10850 - 10890 0 07/13/90 2-3/8" 4 10940 - 10960 0 02/13/94 2-5/8" 4 10940 - 10980 0 07/13/94 2-3/8" 4 10960 - 10980 0 02/13/94 IPBml 11160' 17" LNR, 29#, L-80 BTS, .0371 bpf, 10 = 6.276" letion ß!:\ "" --i5-1/2" HES SSSV LANDING NIP, 10 = 4.562" I GAS LIFT MANDRELS TVD DEV TY VLV LATCH PORT DATE ST MD 2 1 5-1/2" X 4-1/2" XO, 10= -i4-1/2" HES X NIP, 10 = 3.813" -9576 -i9-5/8" X 4-112" 6KR PREMIER PKR, 10 = -10400 --i7" X 4-1/2" BKR PRE1v1IER A<R, ID -" 4-1/2" HES X NIP, 10 = 3.813" 1-i4-1/2" WLEG, 10 =" DATE 11/30/93 02103/94 07/28/98 06/18/99 10/16/04 03/16/06 REV BY MD JHL DAV TP KDClTLH RPH/THL DATE 04/19/06 11/17/06 12/10/06 REV BY COMMENTS COM/PJC WM/ER SAFETY NOTE CJNlPJC SET XX TIP@ 9600' JCM/JC CONVERT TO NEW FORMATE ENDICOTT UNIT WB.L: 2-34/ P-14 PERMIT No: 1861720 API No: 50-029-21662-00 SEe T N R E COMMENTS RWO COM PLETION SET TBG PATCH SET NIP REDUCER WArvER SAFETY NOTE REV WArvER SFTY NOTE BP Exploration (Alas ka) . . SARAH PALIN, GOVERNOR A I"IA~1iA. OIL A..5D GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ., .,.',.... .. .-.........-.'.. \... \\~ \Có~ Re: Endicott Field, Endicott Oil Pool, END 2-34jP-14 Sundry Number: 307-064 Dear Mr. Reem: ~f{"I,¡,~~'~b~'¡ FEB 2 6 2007 ~\.:1lJ'\.ò\\'i!Ð~-V Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this14- day of February, 2007 Encl. 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension Anchorage o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development o Exploratory 186-172 J 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21662-00-00 I 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: END 2-34/P-14 ¡ Spacing Exception Required? DYes ONo 9. Property Designation:AN 17.. dg.- ., 110. KB Elevation (ft): 11. Field / Pool(s): ADL 0~4633 - 't:Â'¡S,Þ 56 Endicott Field / Endicott Pool / 12. .. PRESENTWELLCONDITION·SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 11242 r 10587 11160 10511 None None Casinn Lenath Size MD TVD Burst CollaDse Structural Conductor 131' 30" 131' 131' Surface 2482' 13-3/8" 2482' 2482' 4930 2670 Intermediate Production 10111 ' 9-518" 10111 ' 9556' 6870 4760 Liner 1413' 7" 9827' - 11240' 9308' - 10585' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 0634' - 1 0980' . 1 0028' - 10345' 5-112" X 4-1/2", 17# x 12.6# L-80 10793' Packers and SSSV Type: 9-5/8" x 4-1/2" BKR SB-3, 7" x 4-1/2" BKR S-3 I Packers and SSSV MD (ft): 9616',10781' 5-1/2" Otis SSSV Landing Nipple 1508' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal o BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: February 28,2007 181 Oil o Gas o Plugged o Abandoned 17. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Nam&,d Room Title Drilling Engineer Prepared By Name/Number: Signature ~ Phone S, c¡ f7l{J Date Z. -1'1-07 Sondra Stewman, 564-4750 Commission Use Onlv I Sundry Number: Zi)7 - () I, ;(þ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: ~a~ .\c~\- ~()\- \0 ~"l-C-~ CJ .? ~~ 0 ~~, Subsequent Fonn Requ;rM LtÇ) y{¡f¡¡, Date 1-"'U -O:r- ADDroved Bv; I j ),'Ø COMMISSIONER APPROVED BY THE COMMISSION Fonn 10-403 Rev;sed 06l2Ö RIG I Ñ A Y '-- ;;;t~DMS BFt Submit In Duplicate OTS U21/7 (n1 c)p.lí)1 é2#- ECEIVED " STATEOFK[A~ ~-/.s"'''7 R ALASKA OIL AND GAS CONSERVATION COMMISSION /,.;;-' FEB 1 4 ZOOI APPLICATION FOR SUNDRY APPROVAL It"- 20 MC 25.280 Alaska Oil & Gas Cons. Commission -- . . bp Endicott 2-34/P-14 Rig Workover Scope of Work: Pull 5-W completion, mill and retrieve Baker 9_%" SB-3, mill and push to bottom Baker 7" SABL-3 packer, run USIT log, and run 5-W x 4-W' L-80 completion. MASP: 3247 psi Well Type: Injector Estimated Start Date: February 28, 2007 Pre-ri S 2 E 3 S 4 E 5 F 6 o 7 o 8 o 9 re work: Retrieve AVA DWP patch at 6645' MD. Retrieve plug and reducer bushing in X nipple at 9600' MD. Drift 5-W' and 4-Y2" tubing for plug and tubing cutter. Caliper survey 4-W and 5-Y2" tubing. Obtain one hour SBHP at 10000' TVDss/10667' MD in addition to the regular stops (please check with John McMullen if an hin different is needed. DONE 1/28/07 String shot and tubing punch in preparation for chem cut. Chemical cut 4-Y2" tubing @ 10614' MD (in the middle of the first full joint above the blast joints at 10634' MD). Depths referenced to Tubing Summary dated 11/28/1993. Tubing punch the 4-W' tubing at 9631' MD and circulate out/bullhead awa an tra ed as below the 9-5/8" acker at 9616' MD. Set lu 1 ron in X ni Ie at 9600' MD. Jet cut 5-W tubing @ 9569' MD (in the middle of the first full joint above the Baker SB-3 packer at 9616' MD. De ths referenced to Tubin Summa dated 11/28/1993. Circulate well with -8.6 ppg NaCI brine and cap with diesel thru the cut. Adjust brine weight as needed depending on amount of diesel freeze protect and reservoir pressure from SBHP survey. MITOA to 2000 psi. CMIT T x IA to 3360 psi prior to the rig arriving. Bleed WHPs to 0 si. Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. DONE 1/8/07 Set a BPV in the tubin han er. Remove the well house & flow line. Level the ad as needed for the ri . ProDosed Procedure 1. MIRU. NO tree. NU and test BOPE to 3360 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-W tubing string to the cut. 3. Mill and retrieve the Baker SAB packer. 4. Run US IT log from surface to 10656' MD. 5. Mill and push to bottom the Baker 7" SABL-3 packer. 6. Run 5-W x 4-W L-80 completion with Baker S-3 packer. Set packer at -10400' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3360 psi. Freeze protect to 200' MD. 9. Set BPV. NO BOPE. NU and test tree. RDMO. Note: Doyon 16 will be using a 4 preventer "drilling" stack configuration (reference PBU Well V-212, PTD: 205150) . TREE = . WELLHEAD = ACTUA TOR - KB. EL BF. EL KOP= Max A Datum Datum 7-1/16" ciw FMC END.-34 Proposed Co.letion N S - EV= 56.0' EV= 16.4' -1500 H5-1/2" HES SSSV LANDING NIP, ID = 4.562" I 5500' . ngle = 33 @ 8000' MD= 10665' TVD= 10000' SS ) . GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80 BTC, 2483' r ST MD TVD DEV TYÆ VLV LA TCH PORT DATE ID = 12.415" l 2 1 19-5/8" CSG, 47#, NT80S XO NT95HS, 5366' ~ / ID = 8.681" BG. 17#. L-80, .0232 bpf, ID = 4.892" I I I -15-1/2" X 4-112" XO, ID = I TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"1 TOPOF7" LNR I 9827' ~ :8 19-5/8" CSG, 47#, NT95HS, ID = 8.681" I 10110' -µ ~ ÆRFORA TION SUMMARY I · 1-14-1/2" HES X NIP, ID = 3.813" I REF LOG: DLL & GR (11/07/86) ~ r, -10400 1-17" X 4-1/2" BKR S-3 PKR. ID =" I ANGLEATTOPÆRF: 23 @ 10634' .... I · 1-14-1/2" HES X NIP, ID = 3.813" I ote: Refer to Production DB for historical perf data IZE SPF INTERV AL Opn/Sqz DATE I H4-1/2" HES XN NIP, ID = 3.725" I 5" 4 10634 - 10724 C 07109/97 · 5" 4 10732 - 10760 C 07/09/87 I H4-1/2"WLEG,ID=" , 5" 4 1 0795 - 1 0840 0 07/09/87 I -118" 4 10850 - 10890 0 07/13/90 -3/8" 4 10940 - 10960 0 02/13/94 -5/8" 4 10940 - 10980 0 07/13/94 -3/8" 4 10960 - 10980 0 02/13/94 I ~ PBTD' 11160' I .29#. L-80 BTS, .0371 bpf. ID = 6.276" I 11242' ~ ~ 15-1/2" T 14-1/2" 2 2 2 2 17" LNR DATE 11/30/93 02103/94 07/28/98 06118/99 10/16/04 03/16/06 REV BY MD JHL DAV TP KDClTLH RPH/THL COMMENTS DATE 04/19/06 11/17106 12/10106 REV BY COMMENTS corvvPJC WAr-fER SAFETY NOTE CJNlPJC SET XX TTP @ 9600' JcrvvJC CONVERT TO NEW FORMATE ENDICOTT UNrT WELL: 2-34 I P-14 ÆRMrT No: 1861720 API No: 50-029-21662-00 SECTNRE RWO COM PLETION SET TBG PATCH SET NIP REDUCER WAIVER SAFETY NOTE REV WAIVER SFTY NOTE BP Exploration (Alaska) "TREE = .. WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = . END2-34 7-1/16" ciw FMC 56.0' 16.4' 5500' 33 @ 8000' 10665' 10000' SS 13-3/8" CSG. 72#, L-80 BTC, ID= 12.415" 9-5/8" CSG. 47#. NT80S XO NT95HS, ID = 8.681" Minimum ID = 2.313" @ 9600' REDUCING NIP 19-5/8" CSG. 47#. NT95HS. ID = 8.681" I NOTE: COMPLETION EQUIPMENT DEPTHS ARE E-LlNE MEASUREMEMTS. THE DIFFERENCE BETWEEN DLRS & EL DEPTHS IS 7.7' 1 TOP OF 7" LNR I 9827' ÆRFORA TION SUMMARY REF LOG: DLL & GR (11/07/86) ANGLEAT TOP ÆRF: 23 @ 10634' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 5" 4 10634 - 10724 C 07/09/97 5" 4 10732 - 10760 C 07/09/87 5" 4 10795 - 10840 0 07/09/87 2-1/8" 4 10850 - 10890 0 07/13/90 2-3/8" 4 10940 - 10960 0 02/13/94 2-5/8" 4 10940 - 10980 0 07/13/94 2-3/8" 4 10960 - 10980 0 02/13/94 14-1/2" TBG. 12.6#. L-80. .0152 bpf,ID= 3.99" I IPBTD I 11160' 17" LNR, 29#, L-80 BTS, .0371 bpf. ID = 6.276" . ST MD lVD 5 3400 3400 4 6228 6214 3 9530 9054 2 9677 9179 1 9786 9273 . 1508' -15-1/2" OTIS SSSV LANDiNG NIP, ID = 4.562" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 3 OTIS DMY RA 0 11/28/93 16 OTIS DMY RA 0 11/28/93 32 OTIS DMY RA 0 04/24/98 31 OTIS DMY RA 0 04/24/98 30 OTiS DMY RA 0 04/24/98 9600' -15-1/2" X 4-1/2" XO, ID = 3.99" I 4-1/2" X NIP, ID = 3.813 W/ 2-7/8" REDUCING NIP, ID = 2.313" (07/06/98) 9616' -19-5/8" X4-1/2" BKR SB-3 A<R. ID = 4.75" I 10634' - 10773' -1 BLAST JOINTS, ID = 3.958" I 10775' -14-1/2" SWS X NIP, ID = 3.813" I 10781' -i 7" X 4-1/2" BKR S-3 A<R, ID = 3.870" 10788' -14-1/2" SWNXN NIP, ID = 3.725" 10793' H4-1/2" WLEG. ID = 3.99"1 COMMENTS DATE 04/19/06 11/17/06 12/10/06 REV BY COMMENTS COIWPJC WAIVER SAFETY NOTE CJNlPJC SETXXTTP@9600' JCIWJC CONVERT TO NEW FORMATE DATE 11/30/93 02/03/94 07/28/98 06/18/99 10/16/04 03/16/06 REV BY MD JHL DAV TP KDClTLH RPH/THL RWO COM PLETION SET TBG PATCH SET NIP REDUCER WAIVER SAFETY NOTE REV WAIVER SFTY NOTE ENDiCOTT UNrr WELL: 2-34/ P-14 ÆRMrrNo: 1861720 API No: 50-029-21662-00 SEC T N R E BP Exploration (Alaska) RE: Endicott 2-54/Q-12 . . Tom \ '6~-t7&- The reason for the 3360 psi test pressure is that the casing head has a 3M bottom flange that has been uprated to a maximum of 3360 psi. The BOPE test pressure is then limited to the 3360 psi limit. I have also included a sketch of the 3 ram stack currently on the rig. Thanks Paul Chan Workover Engineer BP Alaska/Wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) -----Original Message----- From: Thomas Maunder Ito:tom maunder@admin. Sent: Monday, February 12, 2007 9:04 AM To: Chan, Paul (PRA) Cc: Reem, David C Subject: Endicott 2-54/Q-12 Paul and Dave, I am reviewing the sundry to workover the subject well. A couple of questions. 1. On the BOP test pressure, why the specificity of 3360 psi? Based on prior work/operations, it would seem that the appropriate pressure would be 3500 psi. 2. Having a 4 preventer stack is appropriate according to the BOP regulations (MASP > 3000 psi). Could you please send a copy of the stack drawing so I can attach it to the application? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: Doyon 16 BOP Sketch.pdf Doyon 16 BOP Sketch.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 2/19/2007 10:06 AM ·~ Alaska Department of Natural Resources Land Administration System Page 1 of2 . . rch State Cabins Natural Resources C= Alaska DNR Case Summary File Type: I~I:)~ File Number: L~q~~«i33 ~. print:lþleÇa~efi le$lJmlT1ªry See Township, Range, Section and Acreage? (i Yes No I"ASMeny GªseAÞstrªct I Case Detail I Land Abstra_ct http://www.dm.state.ak.us/las/Case _Summary .cfm ?File Type= ADL&FileNumber=34633&... 2/15/2007 . Alaska Department of Natural Resources Land Administration System . . CONTAINING 2,560 ACRES, MORE OR LESS. ********************************************************************** 91 * *PARTICIPATING AREA LEGAL DESCRIPTION** End of Case Summary Page 2 of2 Last updated on 02/15/2007. Not sure who to contact? Have a question about DNR? Visit the PLJP¡içInfQrrni3tiQn Center. Report technical problems with this page to the WeÞmª$ter. Site optimized for Netscape 7, IE 6 or above. This site also requires that all COOKIES must be accepted. State Of Alaska Natural. Resources LAS Home Copyright Privacy System. $tatus http://www.dm.state.ak.us/las/Case _Summary .cfm ?File Type= ADL&FileNumber=34633&... 2/15/2007 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ..,...D1 ''RêfL rV Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Endicott / END / Row 2 12/31/06 Jack Winslow L...\1'd- ,l'6'0 Packer Depth Pretest Initial 15Min. 30 Min. We1l12·34/P14 Type Inj. N TVD I 9,127' Tubing 150 3,360 3,320 3,300 Interval I V P.T.D.11861720 I Type test I P Test psi! 2282 Casing 150 3,360 3,320 3,300 P/FI P Notes: CMIT TxlA to 3360 psi for Variance OA 0 0 0 0 Weill I Type Inj. I I TVD I Tubing Interval p.T.D.1 I Type test I I Test psi Casing I P/F Notes: OA I Weill I Type Inj.J I TVD I Tubing Interval P.T.D.I I Type test I I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing I I Interval P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SCANNED JAN 0 8 2007 2006-1231_MIT _DIU_2-34.xls . STATE OF ALASKA ..A NOV 24 tOU] ALAS OIL AND GAS CONSERVATION COMNPW'0N REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56 KB 8. Property Designation: ADLO-034633 11. Present Well Condition Summary: Total Depth measured 11242 feet true vertical 10586.76 feet Effective Depth measured 11160 feet true vertical 10511 feet Casing Length Size MD Conductor 71 30" Conductor 40 - 111 Production 5328 9-5/8" 47# NT80S 38 5366 Production 4745 9-5/8" 47# NT95HS 5366 - 10111 Perforation depth: Measured depth: 10634' - 10980' True Vertical depth: 10027.51 - 10289' - Tubing: (size, grade, and measured depth) 5-1/2" 17# I 'L.VL.I V L-LJ StimulateD Other 0 WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 186-1720 d Repair Exploratory Service w 6. API Number: 50-029-21662-00-00 9. Well Name and Number: 2-34/P-14 10. Field/Pool(s): Endicott Field Field/ Endicott Oil Pool Pool Plugs (measured) None Junk (measured) None TVD 40 - 111 38 - 5363.79 5363.79 - 9555.66 Burst Collapse 6870 8150 4760 5080 "" S'.O \ -:' ~) L-80 surface - 9590' 3-1/2" AVA DWP Patch Packer 3-1/2" AVA DWP Patch Packer 4-1/2" Baker SB3 Packer 4-1/2" Baker SABL-3 Packer Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 17595 0 o Shut in 0 15. Well Class after Droposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble 6643 6668 9616 10781 Tubing pressure 2384 o Service w WINJ W WDSPL Title Data Engineer Date 11/22/2006 Signature Phone 564-4944 ì 8 200lÈubmit Original Only . . 2-34/P-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/4/2006iT/I/O=2500/2500/400. Temp=Hot. Eval braden head leak. The top section of the bradenhead is leaking oil, the leak is comming from the 4 O'clock to 9 O'clock position on the bradenhead. 11/11/2006i***WELL SII ON ARRIVAL*** DRIFTED WI 4.5" GAUGE RING TO 1517' SLM. PULLED 5 1/2" MCX SSSV, (SER# NM-03 1.885" BEAN) @ 1517' SLM. RIH WI 2.80" CENT, 5' STEM, 27/8" BL, BRUSH, 2.25" CENT, S. BAILER. *** JOB CONTINUED ON 11-12-06 WSR *** ·.-,.···'wwNum==_'~uu_,~·<__v ,""",mmmu-< 11/12/2006 *** JOB CONTINUED FROM 11-11-06 WSR *** (set Up I pull sta#2) DRIFTED TUBING WI 2.80" CENT, 5' 1 1/2" WB, 2 7/8" BL BRUSH, 2.25" CENT, 1 1/2" S. BAILER. SET 2 7/8" TTP WI 14" FILL EXT @ 9,572' SLM. ATTEMPTED TO SET WHIDDON CATCHER SUB @ 6,611' SLM. ATTEMPT TO WORK THROUGH OBSTRUCTION @ 2,600' SLM. *** JOB CONTINUED ON 11-13-06 WSR *** 11/13/2006 ***CONTINUED FROM 11-12-06 WSR***(set Up/pull sta 2) MADE SEVERAL BAILER RUNS TO CLEAR THROUGH SHMOO BRIDGE @ 2590' SLM. DRIFTED TUBING WI 2.5" CENT TO TOP OF PLUG @ 9572' SLM. RAN EQ DVC TO TT PLUG, SAT DOWN AT 9572'SLM. RAN GS TO PLUG, UNABLE TO LATCH PLUG, POOH SHEARED (MAY HAVE SHEARED RIH). RIH W/2-7/8" GR. ***CONT ON 11-14-2006*** 11/13/2006 Assist S-Line Brush & Flush spot EQ job in progress Weld, WC) Load meth rd to location Assist S-Line brush & Flush (Brainhead Weld, WC)Transfer fluid from 62 to 46 RD to COTU load diesel RD to location MIRU job in progress 11-13-06 and in)(Brainhead weld,WC)Pumped down TBG 5bbls of 5* methanol followed by 123bbls of 180* diesel Fwp"s=2000/170010 *****MASTER VALVE AND TBG HANGER AND SSV NOT FULL NUT****** .. . . . 11/14/2006 *** JOB CONTINUED FROM 11-14-06 *** (set Up) PULLED 2 7/8" XX-PLUG @ 9572' SLM. LRS PUMPED 123 BBLS HOT DIESEL DOWN TUBING FOR B&F BRUSH TUBING WI 5.5" BL BRUSH & 3.850" GAUGE RING SD @ 6607' SLM (PATCH) DRIFTED TO PATCH WI 4.5" GAUGE RING SD @ 6607' SLM, DRIFTED WI 2-7/8" B. LINE BRUSH & 2.0" GAUGE RING SD @ 7080' SLM UNABLE TO WORK PAST (5-1/2" TBG BLW PATCH. RAN 2.25" PUMP BAILER 7080' SLM-RETURNED WI SCHMOO PERFORMED WEEKLY WLV TEST, STANDBY FOR PUMP TRUCK *** JOB CONTINUED ON 11-15-06 WSR *** 250/1400NAC Assist S-line with CMIIT-TBGxIA to 3360 PSI (FAILED) (Shut in)(Brainhead Weld,WC) Pumped 150 bbls 180* diesel down while slick line brushes. CMIT TxlA Pumped 48 bbls of diesel. Unable to reach test pressure. Tubing and IA tracking. Tubing reached 3300 psi IA 3100 psi @ 1 bpm, shut pump down both TxlA dropped to 2500 psi within 10 min. Final Whp's = 2125/228010 ****Master VLV&TBG hanger&SSV not full nut**** ,'..................,'.... -.-------------------- ------------------------------------------------------,..--. - -.' """""""... . ............... ... '_A_A_~ 11/15/2006 *** JOB CONTINUED FROM 11-14-06 WSR *** BRUSH & FLUSH TBG DOWN TO NIPPLE REDUCER @ 9572' SLM, SET 2.313" XX PLUG @ 9572' SLM, CMIT FAILED AFTER SEVERAL-X, RIG DOWN FOR SAFETY STAND DOWN DUE TO CRANE ISSUES. PULL 2.313 XX PLUG @ 9572' SLM. ***CONT ON 11/16/06 WSR*** 11/16/2006 ***CONT FROM 1 SET 2.313 XX PLUG IN REDUCER NIPPLE @ 9572' SLM. PERFORMED SUCCESSFUL DRAW DOWN TEST BEGINING PRESSURES T/IA=1525/1600, TEST ENDING PRESSURES T/IA=1050/1150, SET 5.5" WHIDDON C-SUB @ 6611' SLM, PULLED DGL V FROM ST A#2 (RA latch) @ 5509' MD(pocket left open), PULLED 5.5" C-SUB FROM 6611' SLM ***WELL LEFT S/I*** .~"""., ,__·,vu·, 11/19/2006 T/I/O= 870/1030Nac. Temp.= SI. T & IA FL's. (pre-CMITTx IA). TBG FL near surface. IA FL is @ 400' (18 bbls.) no 3" integral on IA. Top bradenhead threads leaking 360* around wellhead. Cleaned bradenhead and pup joint for further eval. FLUIDS PUMPED BBLS I 198 DIESEL 198 TOTAL MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, November 30, 2005 SUBJECT: Me~hani~alJntegrity Tests. BP EXPLORATION (ALASKA) INC 2-34/PI4 DUCK IS UNIT MPI 2-34/P14 ./\ 1~ \1610 u . TO: ~~~8~::r~isOI"Kc?~l· ~hID~ 8rc: Inspector Reviewed By: P.I.8uprv--.JBf2-- Comm Well Name: DUCK IS UNIT MPI 2-34/PI4 API Well Number 50-029-21662-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS051127151100 Permit Number: 186-172-0 Inspection Date: 11/27/2005 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 2-34/PI4 ¡Type Inj. ! N I TVD I c;¡¡ 'Z1 ì IA i 560 I 3300 ¡ 3300 I 3300 i I I P.T. I 1861720 ITypeTest I SPT i Test psi I 2..Zßi. 751 OA I 90 ! 400 400 400 I I Tubing I 560 ! 3360 I 3360 3360 i I Interval REQVAR P/F P ! Notes Well has known tubing leak, CMIT perfonned to verifY production casing integrity. NON-CONFIDENTIAL Ff; ~ Wednesday, November 30, 2005 Page 1 of 1 ~ @1ffli\lfrErmrç; (ð\ ~ ~\ ~ WI l~ æ) U 1rU U Lb UJJ If Jt\ LL Lid QJ) l}~ Lft:ü AI,ASIiA OIL AlQ) GAS CONSERVATI ON COMMISSION / / í ! / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 September 16, 2004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage,AJ( 99519-6612 RE: Endicott 2-34/P14 (pTD 186-172) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 001.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on En- dicott 2-34/P14. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures conducted during first quarter, 2004, Endicott 2-34/P14 exhibits two competent barriers to release of well pressure. Accordingly, the Commis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Endicott 2-34/P14 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform a yearly MIT-OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform a CMIT T x IA every two years to 1.2 times the maximum anticipated well pressure; Mr. Steve Rossberg September 16, 2004 Page 2 of 2 5. BPXA shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and 6. after well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. bp August 31,2004 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: RECEIVED Endicott 2-34/P-14 (PTD 1861720) SEP - 32004 Request for Administrative Approval to Continue Water lJ}ÏfiiiA11 & Gas Cons. Cormisaion Operations Anchorage Dear Mr. Norman: BP Exploration (Alaska) Inc. (BPXA) hereby requests approval to continue water injection operations into the subject well. The subject well has tubing by inner annulus communication. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The risks associated with continued water injection were evaluated under BPXA internal well integrity policy. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressures, and the tubing/casing annulus operating pressure does not exceed 45% of the casing's rated burst pressure. The proposed corrective action plan (attached) includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests, and increased reporting to the AOGCC. BPXA asserts that corrective actions can include a combination of several activities to demonstrate and ensure a well is safe to operate. They can include physical well interventions and actions to confirm competent barriers and follow-up mechanical integrity tests to ensure continued safe operations. Considering the proposed limited well operation and the presence of 2 competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in and physical corrective action options will be evaluated. This request is consistent with Area Injection Order 1, in that sound engineering practices have established 2 competent barriers and a corrective action plan has been developed to ensure continued safe operations. There is no underground source of drinking water and thus no USDW is endangered. Please contact me at 564-5637 or Harry Engel at 564-4194 if you have any questions. Steve Rossberg Wells Manager Attachments Technical Justification for Administrative Relief Request Wellbore Schematic Endicott 2-34/P-14 Technical Justification for Administrative Approval To Continue Water Injection 08/31/04 Well History and Status Endicott injection weIl2-34/P-14 (PTD 1861720) has rapid T x IA communication. An MIT-IA failed on 02/05/04, leak rate is .6 BPM @ 2750 psi. Recent Events: ~ 02/04/04: Attempt to bleed lA, did not bleed < 2100 psi ~ 02/05/04: MIT-IA Failed, LLR = .6 BPM @ 2750 psi ~ 03/01/04: SL set TIP in nipple reducer ~ 03/02/04: CMIT-TxIA passed to 3500 psi ~ 03/13/04: MIT-OA passed to 3360 psi ~ 03/13/04: LDL identified tubing leaks from 660' to 1132' ~ 03/15/04: TIP pulled Barrier and Hazard Evaluation The well has 2 competent well barrier systems to prevent the atmospheric release of fluids and safely operate the well. The production casing composes the primary well barrier system. In the event of a leak, the secondary well barrier system, composed of the surface casing, will contain any pressure. Both these systems have been pressure tested to at least 1.2 times the maximum allowable injection pressure to ensure competency. Barrier competency is monitored using Tubing, Inner Annulus, Outer Annulus (TIO) and Pressure/Rate plots and periodic pressure tests to 1.2 x the maximum allowable operating pressure. - Primary Well Barrier: Competency is demonstrated by the passing CMIT-TxIA to 3500 psi on 03/02/04. Competency will be frequently monitored using a Pressure-Rate plot and by conducting a 2-year CMIT-TxIA. - Secondary Well Barrier: Competency is demonstrated by the passing MIT-OA to 3360 psi on 03/13/04. Competency will be frequently monitored using a TIO plot and by conducting an annual MITOA. - Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. Thermal effects are managed by operational procedures requiring operators remain on location during well start until thermal equilibrium is achieved, bleeding as necessary to maintain outer annulus pressures below 1,000 psi. In the event of a shallow production casing leak, the Operators conducting daily well inspections would observe an OA pressure increase and the well would be shut-in. When a well is shut in, the well temperatures decrease and the lower thermal effect thereby reduces annular pressure. Endicott 2-34/P-14 Technical Justification for Administrative Approval Mechanical Condition: The tubing is not a component in the well barrier systems. However it does contain the flow of injection fluids, thereby protecting the casing from potential degradation that may be associated with injection operations. The production and surface casing are the 2 well barrier systems and have been confirmed as competent barrier systems. The well will be shut-in at any indication of barrier competency loss. Considering the presence of 2 competent well barrier systems allows for the safe operation of the well, physical correction actions are not necessary. Proposed Corrective Action Plan 1. Continue water injection. 2. Record wellhead pressures and injection rate daily. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a MIT-OA every year to 1.2x the maximum anticipated well pressure. 5. Perform a CMIT-T x IA every 2 years to 1.2x the maximum anticipated well pressure. 6. Notify the AOGCC if there is any indication of change in well mechanical conditions. Endicott 2-34/P-14 Technical Justification for Administrative Approval , RT ELEV. = 56.0' BF ELEV = 16.4' MAX. DEV. = 32:52 8000' MD 13-3/8", 72#/f\, L-80, B1rs Csg I 2483' I >~ 9-518", 47#/f\ NT8OS XO to NT95HS I 5366' I >- 30' AVA DWP Tbg Patch 2.992" min. 10 /6645' I BAD PIN @ 9,627' TOP OF 7" LlN ER I 9,827' :> 9-518", 47#/ft, NT95HS, NSCC I 10,111' I :> PERFORATING SUMMARY Ref. Log: DLL-GR (11A:J7/86) r.n r..IIN ~PI BAKER 'S' 4 BAKER 'S" 4 BAKER 'S' 4 SOS 2-1/8" 4 AWS 2-518" 4 10,634' -10,724' 10,732' -10,760' 10,79'S - 10,840' ~g,~~: ~g,~~: PBTD I 11,160' I I 11,242' I 7", 29#/ft, L-80, BTRS Date By Comments 11/30/93 MD RWO 2/3/94 ~H COMPLETION 7/28/98 I DÞ,V S~t Tho. Patch, 6/18/99 I TP I nipple reducer TREE: 7-1116"/5000 psi I CIW 10TIS 10TIS WELLHEAD: 13-5/8" X 11" 15000 psi I FMC .~ 5< :8 SSSV LANDING NIPPLE OTIS (4.5621 @ 1,508' . 8 cg - ...... ~ 5-112", 17#1ft, L-80, NSCC GLM's (OTIS), 1-1/2" RA Latch NO. MD-BKB lVD-S 3 3,400' 3,344' 2 6,228' 6,158' 1 9,530' 8,998' .- " NOTE: COMPLETION EQUIPMENT DEPTHS ARE ELECTRIC LINE MEASUREMENTS. THE DIFFERENCE BETWEEN DLRS AND E.L DEPTHS IS -7.7' -- 5-1/2" BY 4-112" CROSSOVER - - 4~~:>~' NIPPLE (3.813") @9,600' v ~ ~ = wi1h 2718" reducing nipple (716198) 6 ð"- 9-518" BAKER "58-3" PACKER @ 9,616' - LEAKING GLM @ 9,669' 4-1/2" OTIS GLM'S @ 9,677' (1-112" RALATCH) @ 9,781' ~ I rx I' I ~ ~ """- ,. ^ r ,. - XXX~ ,. - .J' - ~ , .. 4-1/2", 12.6#1ft L-80, TAILPIPE, TDS BLAST JOINTS OD = 5.25", ID= 3.958" 10,634' - 10,773' i....oJ'_~1/2""X" NIPPLE(3.8131 @10,775' ~7' BAKER SBL-3 PKR @10,781' 4-1/2" "XN" NIPPLE (3.725')@ 10,788' 4-1/2" WLEG @10,792' ENDICOTT WELL: 2-341P-14 API NO. 50-029-21662 COMPLETION DIAGRAM B.P. EXPLORATION (ALASKA) INC. ( ( BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 0.:".' bp , I ,', . May 27, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: Endicott 2-34/P-14 (prO 1861720) Application for Sundry Approval for PWI with rapid r x IA communication. Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well Endicott 2-34/P-14 requesting approval to continue injection into a water injection well with rapid r x IA communication. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, )fIf ~ Joe Anders, P.E. Well Integrity Coordinator Attachments Application for Sundry Approval form 10-403 Description Summary of Proposal Well bore Schematic ECEJVE,[) JUN 022004 Aias!Œ Oï' gf¡ (;omrnì5S!On OR\G\NAL 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Suspend 0 Repair Well D Pull Tubing D Operation Shutdown D Plug Perforations 0 Perforate New Pool D 4. Current Well Class: PerforateD WaiverŒ] Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 186-1720 3. Address: BP Exploration (Alaska), Inc. Development D StratigraphicD 9. Well Name and Nu 2-34~14 10. Field/Pool(s): Endicott Fïpfd / Endicott Jil Pool, Duck Island Unit PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): IEffective Depth MD (ft): ~Effe ive Depth TVD (ft): ' 10586.8 11160 10454.8 Length Size MD TVD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-034633 11. Total Depth MD (ft): 11242 Casing Conductor 71 Liner 1415 Production 5328 Production 4745 Surlace 2444 Perforation Depth MD (ft): 10795 . 10840 10850 - 10890 10940 . 10980 Packers and SSSV Type: 3-1/2" AVA DWP Patch Packer 3-1/2" AVA DWP Patch Packer 4-1/2" Baker SABL-3 Packer 4-1/2" Baker SB3 Packer 12. Attachments: 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Printed Name Signature to V bottom top bottom 40 . 111 40.0 - 111.0 9827 . 11242 9308.1 . 10586.8 3 . 5366 38.0 - 5363.8 5 6 . 10111 5363.8 . 9555.7 " 9 - 2483 39.0 . 2483.0 TUbi:;ng Size: Tubing Grade: .5 " 9.3 # L-80 4.5 " 12.6 # L-80 5.5 " 17 # L-80 , \ U 7 " 26 # L.80 1/ \. .. . \ ~ Packers and S$SV MD (ft): \' I 6643 '. \ \ I 16;768~ W' ,ð. 9616 sa \). . t $t) W~ Class after proposed work: P,Skelch ::J 11 '\ ExploratoryD DevelopmentD r,ll 1 2004' \g 15~ Well Status after proposed work: '\ Oil D GasD PluggedD AbandonedD ate: V \ WAG D GINJD WINJrx1 WDSPLD ~repared by Garry Catron 564-4657. Contact 6. API Number 50-029-21662-00-00 Plugs (md): Junk (md): None None Burst Collapse 8160 6870 8150 4930 Tubing MD (ft): 6643 9621 42 37 7020 4760 5080 2670 6672 10793 9621 42 ServiceŒ) Joe Anders/Anna Cube Title Phone Well Integrity Coordinator 659-5102 5/27/04 Plug Integrity D BOP TestD Conditions of approval: Nð,1:ifl Commission so that a representative may witness Commission Use Only Other: Subsequent Form Required: Approved by: c_aFl MechanciallntegrityTest D REæ~[~JP rD291OO\ JUN 022004 I SUndryN~4~:~o'1 \.; 0 R \ \ N Alaska Oi\ & ea);' ß.,RDER'C\~ . (5 AL '.~È'86.1.",'ütrj'I\~l1ìS~;¡(m MU1JirJ. .. MMISSION D I ...".IIUI d~B ale: SUBMIT IN DUPLICATE Form 10-403 Revised 12/2003 \ ( Endicott 2-34/P-14 Description Summary of Proposal OS/27/04 Problem: Produced Water Injector with rapid T x IA communication Well History and Status: Endicott weIl2-34/P-14 (PTD 1861720) has rapid T x IA communication. An MIT-IA failed on 02/05/04. Mechanical integrity testš indicate competent production and surface casings. Recent Well Events: > 02/04/04: Attempt to bleed lA, did not bleed < 2100 psi > 02/05/04: MIT-IA Failed, LLR = .6 BPM @ 2750 psi > 03/01/04: SL set TTP in nipple reducer > 03/02/04: CMIT-T x IA passed to 3500 psi > 03/13/04: MIT-OA passed to 3360 psi > 03/14/04: LDL found 5 leaks. TTP pulled This Sundry request is to allow for continued water injection in this well. The following supports the request: . A CMIT-T x IA passed to 3500 psi on 03/02/04, indicating the production casing is capable of withstanding injection pressure. . A MIT -OA passed to 3360 psi on 03/13/04, indicating the surface casing is capable of withstanding injection pressure. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a tubing or surface casing leak. Proposed action plan: 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Perform 2-year CMIT-T x IA. 4. Stop injection and notify the AOGCC if there is a loss of production casing integrity. RT ELEV. = 56.0' SF ELEV = 16.4' MAX. DEV. = 32:52 8000' MD { 13-3/8", 72#/ft, L-80, Btrs Csg >Â 2483' I 9-5/8", 4 7#/ft NT80S XO to NT95HS I 5366' , > 30' AVA DWP Tbg Patch 2.992" min. ID 1 6645' 1 BAD PIN @ 9,627' TOP OF 7" LINER , 9,827' > 9-5/8", 47#/ft, NT95HS, NSCC I 10,111' I > PERFORATING SUMMARY Ref. Log: DLL-GR (11/07/86) CO. GUN SPF INTFRVAL BAKER 5" 4 10,634' - 10,724' BAKER 5" 4 10,732' - 10,760' BAKER 5" 4 10,795' -10,840' SOS 2-1/8" 4 10,850' - 10,890' AWS 2-5/8" 4 10.940' - 10.980' PBTD , 11 ,160,1 , 11 ,242' , 7", 29#/ft, L-80, BTRS Date 11/30/93 By Comments MD RWO ~LH COMPLETION DAV Set Tbg. Patch TP nipple reducer 2/3/94 7/28/98 6/18/99 . g X .. X 8:l ~ 2 A TREE: 7-1/16" 15000,: 'CIW I OTIS I OTIS WELLHEAD: 13-5/8"~, . I 5000 psi I FMC ~ /'ðÐl 8~ SSSV LANDING NIPPLE OTIS (4.562") @ 1,508' ~ ~ 5-112", 17#/ft, L-80, NSCC GLM's (OTIS), 1-1/2" RA Latch NO. MD-BKB TVD-S 3 3,400' 3,344' 2 6,228' 6,158' 1 9,530' 8,998' ~ z NOTE: COMPLETION EQUIPMENT DEPTHS ARE ELECTRIC LINE MEASUREMENTS. THE DIFFERENCE BETWEEN DLRS AND E.L. DEPTHS IS -7.7' ----- 5-1/2" BY 4-1/2" CROSSOVER @9 590' J - 4:f/2" "X" NIPPLE (3.813") @9,600' ~.4.. with 2 7/8" reducing nipple (7/6/98) ~ 9-518" BAKER "SB-3" PACKER - @ 9,616' -..... LEAKING GLM @ 9,669' ...c:: 4-1/2" OTIS GLM'S @ 9,677' , (1-1/2" RA LATCH) @ 9,781' 4-1/2", 12.6#/ft L-80, TAILPIPE, TDS ~ BLAST JOINTS OD = 5.25", ID= 3.958" 10,634' -10,773' & I 4-1/2" "X" NIPPLE (3.813") @10,775' K4E-7" BAKER SBL-3 PKR @10,781' 4-1/2" "XN" NIPPLE (3.725")@ 10,788' 4-112" WLEG @10,792' I \ ~ ~ :)I;^^^" >xxx)< ENDICOTT WELL: 2-34/P-14 API NO. 50-029-21662 COMPLETION DIAGRAM B.P. EXPLORATION (ALASKA) INC. ( NSU, ADW Well Integrity Engineer subject: NSU, ADW Well Integrity Engineer Thursday, May 27, 2004 2:28 PM AOGGG - Winton Aubert (E-mail) Reeves, Donald F; NSU, ADW Well Operations Supervisor; Engel, Harry R; Francis, Michael J; McMullen, John G; Patterson, Teresa J. (VEGO); Dube, Anna T Sundries in the Mail From: Sent: To: Cc: Hi Winton. We just put 3 sundry requests in the mail, addressed to you: END2-34: A 10-403 for rapid TxlA comm. END2-54: The well has gone from slow to rapid TxlA comm. There's a 10-404 to cancel the exiting slow TxlA comm sundry and a 10-403 for a new rapid TxlA comm sundry. NS27: A 10-404 to cancel the existing sundry. The RWO fixed the TxlA communication. Thanks for the help, let me know if you have any questions when you get the sundries. Joe (907) 659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 RECEI\lF:' JUN 027004 Alaska OH 8~ 1 Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ?eA{ 4114'\C'4-" P.I. Supervisor t SUBJECT: Mechanical Integrity Tests BPXA Row 2 Endicott 2-34 Duck Island Unit Endicott Field NON- CONFIDENTIAL DATE: February 5, 2004 From: John Spaulidng Petroleum Inspector 0 F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details The outer annulus when checked by the operator showed higher than nonnal pressures. I was contacted and offered the opportunity to witness the testing to ascertain tubing x casing integrity. The annulus was pressured up to 3000 psi and immediately bled to injection pressure, this was done 3 times with the same results each time MITIA failed! M.I.T.'s performed: 1 Attachments: Number of Failures: 1 Total Time during tests: 30 minutes cc: MIT report form 5/12/00 loG. 2004-0205_MIT _Endicott_2-34-.is.xls 4/14/2004 ... MEM ORAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~s~:~oJt11 "\I3IM FROM: John Spaulding Petroleum Inspector DATE: Tuesday, April 13, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-34/P14 DUCK IS UNIT MPI 2-34/P14 Src: Inspector Reviewed B7".r IJ /..A,I,~D4' P.I. Suprv ._J~ Comm NON-CONFIDENTIAL API Well Number: 50-029-21662-00-00 Insp No: mitlS0404I31 14317 Inspection Date: 2/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 2-34/PI4 Type Inj. U TVD 9127 IA 2550 3000 2550 2550 P.T. 1861720 TypeTest SPT Test psi 2281.75 OA Interval Other (describe in notes) P/F Failure Tubing 2600 2600 2600 2600 Notes: The tubing and IA began tracking each other. This test was to be a test to establish some type ofIeak rate and confirm tracking. The IA was pressured up 3 times and immediately bled to the injection pressure. Thus the failure. BPXA is going to follow up with further diagnostics. Tuesday, April 13, 2004 Page I of I 99-01 2-34 AOGCC IA-OA .xls ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-34/P-14 REPORT PER AOGCC VARIANCE Note: Well can remain on injection under the above variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Injection Rate (MBD) WHT (F) 1/1/99 2000 0 2164 19872 155.2 1/2/99 2300 100 2177 18992 159.86 1/3/99 2150 50 2199 20868 161.4 1/4/99 2000 0 2202 21350 162.04 1/5/99 2200 100 2202 20744 162.86 1/6/99 2000 100 2206 20533 161.35 1/7/99 2200 200 2186 19675 164.31 1/8/99 2150 250 2212 20795 165.21 1/9/99 2100 250 2191 19111 162.87 1/10/99 2200 250 2173 19444 157.43 1/11/99 1900 0 2177 19721 159.7 1/12/99 2100 0 2179 20169 159.78 1/13/99 2100 0 2158 17912 160.85 1/14/99 2000 0 2191 18259 161.53 1/15/99 2100 100 2212 19762 162.95 1/16/99 2100 150 2229 21048 163.4 1/17/99 2100 0 2233 20632 163.5 1/18/99 2050 100 2136 18139 162.5 1/19/99 1200 100 2335 4773 134.9 1/20/99 1800 100 2171 17196 163.8 1/21/99 1850 0 2215 19279 158.7 1/22/99 2050 0 2216 19814 158.3 1/23/99 2050 0 2192 18520 154.4 1/24/99 2000 0 2216 18356 153.4 1/25/99 2350 50 2257 19741 157.32 1/26/99 2150 0 2241 20014 160.595 1/27/99 2250 100 2242 23649 161.8 1/28/99 2100 200 2212 22477 164.2 1/29/99 2000 100 2207 22245 161.23 1/30/99 2000 100 2155 20034 154.159 1/31/99 1350 200 2193 22179 152.34 Note NOTE E-mail this report monthly to Madelyn Millholland, Scott McEntyre and Emerson Milenski in Anchorage. They will forward to Blair Wondzell a NOTES: (use this section to recorde significant events such as loss of SW etc) 1/19/99 off line part of day for rig move 5CANNED DEC :l. 9 2002 Page 1 99-02 2-34 AOGCC IA-OA .xls ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-34/P-14 REPORT PER AOGCC VARIANCE Note: Well can remain on injection under the above variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Injection Rate (MBD) WHT (F) 2/1/99 2100 0 2236 22396 160 2/2/99 2050 100 2252 21332 158 2/3/99 2100 100 2217 17578 158 2/4/99 2200 0 2226 17472 157 2/5/99 2200 0 2196 18175 157 2/6/99 2000 0 2110 15309 159 2/7/99 2200 200 2156 16303 157 2/8/99 1200 0 2101 17027 150 2/9/99 1200 0 2074 16127 156 2/10/99 1200 0 2002 14266 141 2/11/99 800 0 1751 10894 123 2/12/99 2700 0 2109 16341 157 2/13/99 2000 0 2093 16103 156 2/14/99 2000 0 2076 15692 152 2/15/99 2000 0 2110 15853 157 2/16/99 2000 0 2123 16366 160 2/17/99 2050 100 2163 19093 166 2/18/99 2000 50 2163 18358 163 2/19/99 2050 0 2163 19469 161 2/20/99 2100 100 2195 20285 165 2/21/99 2000 0 2221 20751 165 2/22/99 2000 150 2215 20432 166 2/23/99 2100 250 2002 19467 141 2/24/99 1750 0 2 t 40 17780 160 2/25/99 1900 200 2'153 17351 161 2/26/99 2100 250 2164 19858 169 2/27~99 2100 300 2169 19947 168 2/28/99 2050 300 2167 18108 168 Note SCANNED DEC ! 9 2002 Page 1 99-04 2-34 AOGCC IA-OA .xls ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-34/P-14 REPORT PER AOGCC VARIANCE Note: Well can remain on injection under the above variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inje~ion Rate (MBD) WHT (F) Note 4/1/99 1500 0 1708 8498 145 P-1907 down 4/2/99 1550 0 1996 17716 140 4/3/99 1500 0 1887 14326 133 4~/99 1400 0 1871 13281 133 4/5/99 1900 0 1972 17813 127 4~/99 2000 0 1967 16400 131 4/7/99 1800 0 1986 15547 128 4/8/99 1850 0 2005 15813 126 4/9/99 2050 0 2012 16248 126 4/10/99 1850 0 1984 14889 127 4/11/99 1250 0 2066 14314 156 4/12/99 1250 0 2107 16000 163 4/13/99 1250 0 2061 13334 164 4/14/99 1750 0 2014 14155 162 4/15/99 2100 0 2087 13122 164 4/16/99 2250 0 2064 12703 163 4/17/99 1100 0 2014 12966 142 4/18/99 2000 0 2041 12701 150 4/19/99 2000 0 1851 8418 157 4~0/99 2100 0 1787 7761 170 4/21/99 1500 0 1868 9816 154 P-1907 down 4/22/99 1900 0 1863 9393 159 P-1907 down 4~23~99 1900 100 1894 10003 167 P-1907 Started 4/24/99 1700 100 1933 13114 147 P-1907 down 4/25/99 2000 0 1804 8888 159 4~6/99 1900 100 1794 8487 167 4~7/99 1550 0 1860 10372 157 P-1907 Started 4/28/99 1050 0 2188 19704 125.58 4/29/99 1950 0 2166 20391 132 4/30/99 2050 0 2175 19202 E-mail this report monthly to Madelyn Millholland, Scott McEntyre and Emerson Milenski in Anchorage. They will forward to Blair Wondzell a NOTES: (use this section to recorde significant events such as loss of SW etc) Page I BP EXPLORATION BP Exploration (Alaska)Inc. /t~ / 900 East Benson Boulevard .,~ RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 20, 1990 Blair Wonzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Blair, Per your request we have investigated Endicott well records for Mechanical Integrity Tests (MIT) on injection wells. Our records indicate that for the period from October 1, 1989 to October 1, 1990 one MIT was performed. This was done on January 4, 1990 on well 2-34/P-14, a sea water injector. If we can be of further assistance, please contact us. Sincerely, R. S. Allan Endicott PE Supervisor REcrclV D Alaska Oil & Gas Cons. Arc,borage SCANNED DEC ALA~ -' OIL AND GAS CONSERVATION COMMIS' N REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well__ PeRorate__ 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 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development ~ Exploratory ~ Stratigraphic ~ Service .. 6. Datum elevation (DF or KB) PT= 56.0 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2- 34/P- 14 MPI feet At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 86-172/398-285 10. APl number 50- O29-21662 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner PeRoration depth: 11242 feet Plugs (measured) true vertical 10587 BKB feet measured 11160 feet Junk (measured) true vertical 10511 BKB feet Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' '3 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SD-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' - ....... --,~..'~-~ ;i '~. :L.:.., '~ -:.¢' :;- .:..'; "-';-'¢' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MIT8/16/O0 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 6631 14349 Tubing Pressure 1716 2132 15. Attachments MIT 8/16/00 Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service W~t~.r In?ntnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '-!,% ~'%C("~' ~4~x~-J Title Senior Technical Assistant IV f564-52a4~ Date 9/7/00 Form 10-404 Rev 06/15/8.,8,~,... SUBMIT IN DUPLICATE BPX Endicott Production Engineering OPERATIONS REPORT DATE: 8-16-00 WELL N°: 2-34 / P-14 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: MIT LAWSON APC 1620 SAFETY MEETING OPERATIONS SUMMARY 1625 PRESSURE TEST LINE FLOW RATE: 1950 IA: 2000 OA: 200 1630 1633 START PUMPING DIESEL DOWN IA. PUMPED I BBLS OF DIESEL. PRESSURE UP TO 2550. WATCH FOR 30 MIN~.- GOOD TEST WITH STATE WITNESS. RD. BLEED DOWN IA TO 300 psi. IA: 300 OA.' 0 - SUMMARY: MIT IA WITH STATE WITNESS. GOOD TEST. RD. SSSV: IN MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abanaon Suspend Operation Shutdown __ Re-an[er suspended well __ Alter casing__ Repair well __ Plugging ~ '13me extension Stimulate Change approved program __ Pull tubing Variance Perforate O[her 2. Name of Operator -_ BP Exploration (Alaska) Inc. 3. Address P. O. Box 198612, Ancftorarle, Alaska 99519-6612 4. Location of well at surface 1989' SNL, 225~' WEL, Sec. 36, TI2N, R16E At top of productive interval 222' SNL, 3776' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 38, T12N, R16E At total depth 24~ SNL, 3838' WEL, Sec. 36, '1'1£N, R16E 5. Type of Well: Development Exploratory .... Stratigraphic ~ Service z 6. Datum elevation (DF or KB) RT= 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-34/P- 14 MPI 9. Permit number 86.172/398-285 10. APl number 50-029-21662 11. Reid/Pool Endicot~ Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11242 feet Plugs (measured). 10587 BKB feet 11160 feet Junk (measured) 10511 BKB feet 0 R I L Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured c~ True vertical depth BKB 71' 30~ Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 95/8' 575c, f. Class G 10111' 9556' 1413' 7~ 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'. 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'. 10055', 10062'- 10088', 10119'- 70161'; 10160'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) $ I/2~ 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth)9 5/8" Baker SB-3 Packer at 9616', 7 "'Baker SABL-3 Packer at 10781', 8SSV at 1508' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation I 15. Status of well classification as: October 2000 (rec/uest for time extension of ap~rova1398-285) 16. if proposal was verbally approved Oil__ Gas __ Name ~)f approver Date approved Service Water Injector 17. I hereby certify that the foregoin§ is true and correct to the best of my knowledge. .... FOR COMMISSION USE ONLY ions of approval: Notify Commission so representative may witness integrity BOP Test __ Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15/88 /_./9' d Date 9/29/99 Suspended ..... dA3CI iiODIQH3 Xd8 Nd~q:E:O 86, 61~ Approval No._~,. Location clearance ~ Subsequent form required 10- ~..o~\'~,~,,~r~ r,~,~.~\~,,~,~t,.~\a ~-~ :ONiGINAL SIGNED'BY oommiss?er Date Ro~A N. Ghdstenson SUBMIT IN TRIPLICATE BP EXPLORATION September 28, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn; Mx-. Blair Wondzell Re: Endicott water injection well 2-34/P-14 Dear Mr. Wondzell, Please find the attached Application for Sundry Approvals for Endicott water injection well 2-34/P-14. This application requests an extension to a variance currently in effect for this well. AS previously reported in detail in the original request of October 1998, this well has a slow leak from the tubing to the inner annulus. It is believed to be caused by the inability of a tubing patch to completely effect a seal over a section of corroded tubing. Consequently, the inner annulus pressure will build up slowly to wellhead pressure. Our daily annulus pressure monitoring shows that there is no conununicaUon to the outer annulus. As you know, Endicott is currently engaged in an extensive study aimed at optimizing injection strategy, which may alter our injection well set. This work is expected to continue well into 2000, Meanwhile, well 2-34 provides essential water injection support in the field's major producing horizon, Zone Given the benign nature of the pressure communication and the importance of the well in maintaining offtake, we wish to keep it on water injection service. ConsequeatIy, BP Exploratior~ requests an extension of the current vm'iance through October 2000. We would continue to supply daily injection data, incorporating water rate plus wellhead and annulus pressures, to the AOGCC on a monthly basis. A mechanical integrity test will also continue to be performed every six months. Please contact me at 564-5853 if you require additional information, Sincerely, _ ._.. ~ Graham Stewart Endicott Subsurface Team attachment: Form 10-403, Application for Sundry Approvals cc: ENS Subsurface Manager (w/o attaclnnent) File: 76.13 ORIGINAL STATE OF ALASKA ALA?'--~ OIL AND GAS CONSERVATION COMMI,c~ -~N REPORT SUNDRY WELL OP,.RATIONS 1. Operations performed: Operation shutdown_ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exl~loration (Alaska) Inc. Development __ RT= 56.0 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchora_qe, Alaska 99519-6612 Service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 2-34/P- 14 MPI 9. Permit number/approval number 86-172/398-154 10. APl number 50- 029-21662 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: 11242 feet 10587 BKB feet 11160 feet 10511 BKB feet Plugs (measured) Junk (measured) ORIGINAL Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' '..; ~' ¢'~ ;."-.,,, i ~;~ .,., "i'.' '~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure (/MIT 8/30/99 L~nr~hc~fRfl::~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 6631 14349 Tubing Pressure 1716 2132 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service W~tp.r Ini.¢ctnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~¢~ .¢~,.~ Title Senior Technical Assi.~tant IV L5~4-5234) Form 10-404 Rev 06/15/8~ Date 9/17/99 SUBMIT IN DUPLICATE'~ Endicott Production Engineering .... Departme,nt , , , BPX MIT With AOGCC Witness DATE: 8-30-99 WELL N°-: 5-01,5-02, 2-16, 2-16, 1-64, 2-06, 2-34. BP EXPLORATION REP: Peruzzi, Williams SERVICE COMPANY: APC pump truck with Beardsley, Neuman and Linberg Summary: On 8/28 and 8/29 all seven wells were fluid packed and pre-MIT'ed to 2500. All passed. On 8/30 a.m. all wells were witnessed by Chuck Scheve who filled out the data sheets attached. All passed. Attachments: State form Pump sheet for official MIT .- Well Pre-MIT diesel MIT diesei pumped Notes ' ' ' ~ p.umpe, d, BBLS , BBLS 5-01 9 3 5-02 5 7 2-34 1 8 2-06 6 4 used 66/40 for pre-MIT 2-16 54 15 pumped 1'20 barrels of 60'/z~O p'rior t(~ . , pumping diesel · 1-64 6 6 · . _ 2-64 4 4 Summary: Pumped a total of 132 bbls of Diesel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Hecha nical ! nt~grity Test OPERATOR: ~ FIELD I UNIT t PAD; Endio:::~, ,/D!U / MP! DATE: .... 8j,'3,0J99 Diesel 9.354 4,400 4,.400 4,400. 4,400 2.06 G P I~ne .122.38 9 5/~. "./ 4.7.#_/ NT-80 7,' 23,38.5 1,100 2,600 2,550.. 2,550.. 11:20 P COMMENTS; PTC~ 87'-18 Semi Annual 2-16 S P Brine '10.191 J 95fS"I4?#/NT-80__ 4._1.tZ'J2342.75J--500' J 2,soo 2,500 I, 2,5o0 _j 10:.50 P C'0UUE~S: PTD~ 88-134 4Year .....I 1 "l ....... [ .... , ,.o.,I- ........ COMMENTS: PTI)~ 86-172 Semi Ahnual 2..-64 S P B.rine 8984 9 5t8" ! 47# / NT-80 4...~/2" 1759 - 400'/ ..... 2525- J 2500 J --'2500 J 1_2145. ~oi~u~s: " 1-69 ._8..._ P Brine J 11217 J95tS"I47#INT-95HS 4 /2" 2312,251 0 J _2..500 J 2450_--j-124.50 J 13.'0.5. ~O~MENTS: PTi~ 90-29 4Year .. ...... ~ . . , , ~ , i . - . TBG. tNJ. FLUID CODES = FRESH WATER INJ. =GAS INJ. = SALT WATER 1NJ. = NOT INJECTING TEST TYPE; U = ANNULUS MONITORING P = STD AN NULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEHPERATURE ANOHALY TEST D "- DIFFERENTIAL TEHPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL · ~ALT WATER DRILLING MUD OTHER P.P.S. Grad. WELL TEST: 0.00 tni~al 0.00 4 - Year X O.O0 Workover 0.00 Oliver ofig - Well File c - Opeca~ c - Trip RiX FlJe c- Insce~or OPERATOR REP 81GNATURE: Tave Pemzzi jkgkh4gt'.xl$ , AOGCC REP SIGNATURE: Chuck Scheve (Rev 9t17/96) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: BPX FIELD I UNIT f PAD; EndicoU; / DIM / HPt DATE: 8/30/99 Diesel 8,94~4 4~100 4,100 ¢,100 4,400 . 5-01 G . __p_ ..... _Bri~ne . !.0,.842..,.. 9 5/9" f47#~L-80 7" 2236 1,650 2,500 2,400 ___2_,4.00.- 9:25 COMMENTS: PTI:~ 80-120 Semi Annual 502 S P Brine I 11,2~'7' 9 5/9" 147#/HI-05 COMMENTS: PTD~ 8"t-118 Semi ,Annual COI~IMENTS:- - COU~a~NTS: - COMMENTS: .... TBG. INJ. FLUID CODES FRESH WATER tNJ. GAS INJ. N = NOT '"~I, ECTINO TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = iNTERNAL PAD. TRACER SURVEY A = TEMPERATURE ANOHALY TEs'r O = D/FFEREN~L TEHPERATURE TEST ~ - Well Fl~e c - Opermor c - D~.abase c -Im, pe,ctor OPERATOR REP 81G NATURE: Tave Peruzzl JkgkMgf. x~ ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD , OTHER P.P.G. Grad. 0.00 · 0.O0 0.00 O.O0- O.OO , ADC-CC REP SIGNATURE: __ _ WtELL TEST: h'rdal 4 - Year Workover Oth~ X (R~v 9t17/96) STATE OF ALASKA ALAS: - OIL AND GAS CONSERVATION COMMIS,C.' ~ REPORT GF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing M Repair well __ Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development __ RT = 56.0 feet Exploratory __ 3. Address Stratigraphic M 7. Unit or Property name P. O. Box 196612, Anchoraqe, Alaska 99519-6612 Service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 2-34/P- 14 MPI 9. Permit number/approval number 86-172/398-154 10. APl number 50- 029-21662 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical 11242 feet 10587 BKB feet Plugs (measured) Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11160 feet 10511 BKB feet Junk (measured) Length Size Cemented Measured depth~:; ;i,,_; True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 16015 14889 Tubing Pressure 2009 1990 15. Attachments MIT4-1-99 Copies of Logs and Surveys run __ Daily Report of Well Operations x 16. Status of well classification as: Oil__ Gas Suspended__ Service W~fp.r Ini._~.ntor 17. I hereby,certify that the foregoing is true and correct to the best of my knowledge. Signed ~~-~' ~%~'~%¢~'~Lk~ TitleseniorTechnicalAs~istantlV[SF;4-523zl) Date4-12-99 ~ Form 10-404 Rev 06/~1,5,~88 SUBMIT IN DUPLICATE",,,%[,~ BPX Endicott Production Engineering Department MIT with AOGCC Witness DATE: 4-1-99 WELL N°: 2-341P-14 BP EXPLORATION REP: Lovelace SERVICE COMPANY: APC DATE/TIME OPERATIONS SUMMARY 4/1/99 WHP= 1700 IA = 2000 OA = 0 Bled down the IA to 1500 ps~ State AOGCC witness monitored the IA for 30 minutes IA bled down from 1500 psi to 800 psi in 30 minutes Did not pass MIT according to State witness WHP=1700 IA= 800 OA= 0 Summary: MIT with the state AOGCC witness Lou Grimaldi. The IA had 2000 psi from the pre-test that was performed earlier and not bled down afterwards, it was decided by the State witness to bleed the IA from 2000 psi to 1500 psi. and then monitored. This was done and was monitored by the State witness for 30 minutes. The pressure fell 1500 psi to 800 psi. However at the same time the well was taken off produce water (because of compressor problems in facility) and put on sea water injection, which runs at a cooler injection temperature. This was relayed to the State witness. Pump Summary: BBLS FLUID STATE OF ALASKA AL/' .... OIL AND GAS CONSERVATION COMMI"'-' -- I REPORT SUNDRY WELL OF . HATIONS 1. Operations performed: Operation shutdown ~ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well__ Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development __ RT = 56.0 feet Exploratory __ 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchora.qe, Alaska 99519-6612 Service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R 16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 2-34/P- 14 MPI 9. Permit number/approval number 86-172/398-154 10. APl number 50- 029-21662 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth' measured Effective depth: Casing Structural Conductor Surface Intermediate ProdUction Liner Perforation depth: true vertical measured true vertical Length 11242 feet Plugs (measured) 10587 BKB feet 11160 feet Junk (measured) 10511 BKB feet Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SD-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 16088 10144 Tubing Pressure 2003 1617 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations x 16. Status of well classification as: Oil__ Gas.__ Suspended Service W~t~.r Ini. p.c. tnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed t'"'"iL~~4A"vu [~ ~',~,,-~'-('~-~---~-4~ Title Senior Technical A.¢.¢istant IV [564-.5234) Form 10-404 Rev 06/[lj5/88 Date 10/02/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 9/12/98 WELL N°: 2-34/P-14 BP EXPLORATION REP: D. Williams SERVICE COMPANY: APC MIT TEST IA DATE/TIME OPERATIONS SUMMARY 1630 1645 ' 1715 1730 Rig up Tri-plex and PT lines to 3000 psi. Pump methanol down IA and pressure up to 2500 ps~. Monitor for 30 minutes, Pressure held test good. Rig down Tri-plex. IA bled down to 350 ps~. SUMMARy:-- ...... ;~-~mped a total of 3--~3~s-~)~6'0/40~meth. * Test witness by AOGCC REP. ~*--Test-good., STATE OF ALASKA AL/~ OIL AND GAS CONSERVATION COMMIF "N APPLICA' -,'ON FOR SUNDRY APr-ROVALS 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 X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) RT- 56.0 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-34/P- 14 MPI At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 9. Permit number 86-172/398-177 10. APl number 50- 029-21662 11. Field/Pool Endicott Off Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11242 feet Plugs (measured) 10587 BKB feet 11160 feet Junk (measured) 10511 BKB feet ORIGINAL Casing Structural Conductor Surface Intermediate ProdUction Liner Perforation depth: Length Size Cemented Measured d~ True vertical depth BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for. commencing operation October 1999 (reQuest for time extension of approval 398-177) 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~_/~/~_.~-~,~. ,~~ Title FOR COMMISSION USE ONLY Date I O/26/98 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 [ Approve, No~..,~ "c~ ¢,~ Subsequent form required 'PO-- t~o,,~-J-J,l,/ /~~ - ¢~ ~] ~ David W, Johnston ,-o?" ' ,¢o~'~~ommissioner Date /¢ ~, ~2~ SUBMIT IN TRIPLICATE SUNDRY APPLICATION FOR VARIA~', CE ENDICOTT POOL WELL 2-34/P-14 October 23, 1998 ORIGINAL Background Originally completed as a zone 3A/2B producer, well 2-34/P-14 was initially put on production in April, 1988. After producing 3.36 million stock tank barrels, the well was converted to a water injector in January, 1990. In November, 1993, a rig work over was completed on well 2-34/P-14 to replace a failed production packer. Since the 1993 work over, the well has been very necessary to maintain zone 2B reservoir pressure via water injection. Tubing to inner annulus communication was first suspected in mid April, 1998 with a injection profile log and confirmed with a leak detection log (5/11/98) and Kinley Caliper Survey (5/12/98). The location of a leak was identified to be in the middle of a joint of tubing at approximately 6,655' md. The identified leak is evidenced to be an isolated hole in a single joint of tubing. On July 28, 1998, a mechanical tubing patch was set across the identified hole. Following the - setting of the patch, the well passed the initial Mechanical Integrity Test (IA pressured to 2500 psi, lost 50 psi over 30 minutes). A MIT was performed on August 28, 1998 in which the inner annulus was pressurized to 2600 psi and lost 75 psi over 30 minutes. On September 12, 1998 the well passed an AOGCC witnessed MIT. Although the criteria for a successful test was met, there remains a very small, unidentifiable leak. Consequently, BP Exploration is requesting a waiver to permit continued injection, until such time as any leak becomes significant enough for its source to be identified and fixed. Remedial Actions From discovery of the leak until setting of the mechanical patch, the well had discontinued water injection. The small volumes and flowrates associated with the remaining leak verify that continuation of water injection into the existing well completion poses no significant risk to further decrease the integrity of the well bore. No problems were encountered when setting the mechanical patch, so it is our belief that there is nothing to be gained from attempting to pull and re-set the patch. Recommendation We request well 2-34/P-14 be allowed to continue with water injection service until the extent of communication between the Inner annulus and tubing becomes more severe. During the interim, the inner and outer annulus pressures will be monitored on a daily basis presented to the Commission in monthly reports. The Commission will also be informed of the results of semi- annual Mechanical Integrity Tests performed on the well while continuing to inject. BP believes the well can remain in service in its current state without compromising safety or the environment, until identification of the small remaining leak. Your concurrence is requested. BP EXPLORATION October 23, 1998 ORIGINAL Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. B. Wondzell Dear Mr. Wondzell, Please find the enclosed Application for Sundry Approval to obtain a waiver for Endicott MPI water injection well 2-34/P- 14. Tubing to inner annulus communication was noted, and the tubing leak was identified in the well in June, 1998. In July, 1998, a mechanical tubing patch was set to eliminate the communication. The mechanical patch reduced the extent of tubing to inner annulus communication, but did not completely eliminate it, as observed during the most recent MIT. BP Exploration requests permission to continue water injection into this well until October 1, 1999. Well 2-34/P-14 is the single provider of water injection support for many high production Zone 2 Kekiktuk wells. Water injection at the location of well 2-34/P-14 is necessary for effective resource development. There are currently no options to replace the function of this well. The well's annular pressures, injection pressure, and injection volumes will be recorded on a daily basis and reported to the Commission at monthly intervals. Additionally, the results of semiannual Mechanical Integrity Tests will also be reported to the Commission. This reporting will continue until the source of the tubing to annulus communication is identified and fixed. Please do not hesitate to contact me at 564-5952 or Graham Stewart at 564-5853 if you require additional information regarding the proposed course of action on well 2-34/P-14. Sincerely, Scott R. McEntyre ~' Endicott Development Group MPI Production Engineer attachments (2) srm cc: 2-34/P-14 Well File / AOGCC File 06.10 ec: Stewart, G. Endicott Wells Team Leader STATE OF ALASKA AL' -"fA OIL AND GAS CONSERVATION COMM'- -:ON REPORT SUNDRY WELL OF .RATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well X Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory __ Stratigraphic Service .. At top of productive interval 9. 6. Datum elevation (DF or KB) RT=56.0 feet Unit or Property name Duck Island Unit/Endicott Well number 2-34/P- 14 MPI Permit number/approval number 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 86-172/398-154 10. APl number 50- 029-21662 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11242 feet 10587 BKB feet 11160 feet 10511 BKB feet Plugs (measured) ./ : - Junk (measured) Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6# L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Tubing Patch (7/28/98); MIT after tubing patch (8/5/98); MIT IA (8/28/98) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 22002 Tubing Pressure 0 2007 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations × 16. Status of well classification as: Oil__ Gas__ Suspended__ Service w..qf~.r Ini.~.ntnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~-~'~:~(-.~__ A, ~~~ Title.q~nior Technical Assi.~tan! IV Form 10-404 Rev 06/16/88 Date 09/02/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 8~28~98 WELL N°: 2-34/P-14 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT IA Lovelace Tri-plex TIME i OPERATIONS SUMMARY 0900 0915 0945 0950 0955 RIG UP Tri-plex AND P-TEST LINES TO 3000 PSIG SIWHP = 1250 IA = 2100 OA = 350 PUMP METHANOL DOWN IA AND PRESSURE UP TO 2600 PSI MONITOR FOR 30 MINUTE, PRESSURE DROPPED OFF 75 PSI IN 30 MINUTES TEST GOOD SIP=12501A=300 OA=350 RIG DOWN Tri-plex. IA BLED DOWN TO 300 PSIG. Summary: Pumped methanol down IA and held 2600 psi for 30 min. bled down to 2525 psi, lost 75 psi in 30 minutes. BPX Endicott Production Engineering Department MIT DATE: 8~5~98 WELL N°: 2-34/P-14 BP EXPLORATION REP: SERVICE COMPANY: BARBA Triplex , TIME , OPERATIONS SUMMARY 1330 MIRU Triplex. 1000 1343 1357 1415 1445 IAP300PSI, WHP1000 PSI. PUMP DIESEL DOWN INNER ANNULUS UNTIL PRESSURE IS 2500 PSI. Close casing valve IA PRESSURE DOWN TO 2460 PSI. IA PRESSURE DROPPED TO 2380 PSI. lAP 2300 PSI. PASSED MIT. BLEED lAP TO 300 PSI. RDMO. PASSED MIT. Spoke to JOHN SPAULDING, AOGCC REPRESENTATIVE and he said this would be good and just fax the AOGCC MIT form to Wendy Mahan in town. BPX Endicott Production Engineering Department SET TUBING PATCH DATE: 7~28~98 WELL N°: 2-34/P-14 BP EXPLORATION REP: VARBLE SERVICE COMPANY: SWS (C. Vetromile) DHS (L. Savage) 7/29 DATE/TIME OPERATIONS SUMMARY MIRU SWS SIP = 400 lAP = 100 OAP = 300 1000 1030 1300 1350 1605 1617 1640 1655 1715 1733 1737 1743 1845 2030 1100 1145 1155 1205 1215 1230 Make up lubricator Arm Baker 20 setting tool using SAFE. RIH with cci / Baker 20 setting tool / 25' AVA retrievable patch. OAL = 43' (new line on unit, season wire while running in hole) At 6850 md. Log tie ~n pass up. Not getting good collars Adjust gain & log again, fie into Leak Detection Log dated 5/11/98. Take out 7'. Log confirmation pass. Add 1'. Log again. On depth. Log into place & hang CCL @ 6629.7'. (15.3' from CCL to top element. Puts top element @ 6645'md) Shoot setting tool. (hanging weight = 2530 #) Weight dropped off to 1800 #. Setting tool released. Looks like a good set. Log off. POOH OOH. Shear p~n ~n wireline adapter sheared. RDMO. SIP=400 IAP=100 OAP=300 MIRU triplex pump. Pump 4 bbls diesel & pressure test IA to 2500 psL lAP = 2500 WHP = 350 OAP = 300 lAP = 2500 WHP = 350 OAP = 300 lAP = 2475 WHP = 350 OAP = 300 lAP = 2450 WHP = 3500 OAP = 300 Passed MIT Rig down pump and bleed lAP down to 250 psi. Put well on injection at 100% SUMMARY: Set 25' AVA tubing retrievable patch @ 6645' md. (top element @ 6645', btm element @ 6670') Overall length of patch is 29,6'. Saw good weight loss & tool release when set. Shear pin in wireline adapter sheared. Performed MIT to 2500 psi on IA, Lost 50 psi over 30 min, Passed MIT. Put well on injection at 100% choke, Bled lAP down to 250 psi, STATE OF ALASKA ALAS' OIL AND GAS CONSERVATION COMMIS REPORT (.,¢' SUNDRY WELL OPERATIONS 1. Oberatibns performed: Operation shutdown_ Stimulate__ Plugging__ Perforate__ Pull tubing__ Alter casing __ Repair well X Other__ 2. Name of Operator 5. Type of Well: BP E,~ploration (Alaska) Inc. Development Exploratory __ 3. Address Stratigraphic 7. P. O. Box 196612, Anchora.cle, Alaska 99519-6612 Service X 4. Location of well at surface 8. 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 9. 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 10. 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 11. 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 6. Datum elevation (DF or KB) RT = 56.0 feet Unit or Property name Duck Island Unit/Endicott Well number 2-34/P- 14 MPI Permit number/approval number 86-172/398-154 APl number 50- 029-21662 Field/Pool Endicott 0il 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11242 feet Plugs (measured) true vertical 10587 BKB feet measured 11160 feet Junk (measured) true vertical 10511 BKB feet Length Size Cemented Measured depth BKB 71' 30" Driven 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 10071' 95/8" 575c. f. Class G 10111' True vedical depth BKB 111' 2482' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17t/L-80 tubing to 9590' MD; 4 1/2" 12.61/L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SD-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MIT prior to tubing patch (7/7/98); MIT after tubing patch (7/28/98) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 22002 Tubing Pressure 0 2007 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended Service W~f_~.r Ini. p.~.fnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~k. ~,o~~ Title,9~niorT¢chnicMA.~.~i.~tantlV Form 10-404 Rev 01~15/88 Date 7/30/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 7~7~98 WELL N°: 2-34/P-14 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT PLUG AND REDUCING NIPPLE Lovelace Tri-plex TIME OPERATIONS SUMMARY ' 1315 1317 1331 1350 1355 RIG UP Tri-plex AND P-TEST LINES TO 3000 PSIG SIWHP = 2000 IA = 2000 OA: 0 (HAD OPEN WING AND INJECTED AGAINST PLUG AND BROUGHT TUBING AND IA UP TO 2000 PSI) BEGIN PUMPING METHANOL DOWN TUBING UNTIL THE TUBING AND IA PRESSURE UP TQ 2550 PSI MONITOR FOR 30 MINUTE, PRESSURE HELD SIP=20501A=2050 OA=0. GOOD TEST. IA BLED DOWN TO 1000 PSIG. RIG DOWN Tri-plex. Summary: Pumped methanol into the tubing and held 2550 psi for 30 min. on the tubing and inner annulus. The tubing and the IA have a communication problem. Bled tubing and inner annulus back to 1000 psi BPX Endicott Production Engineering Department SET TUBING PATCH DATE: 7~28~98 WELL N°: 2-34/P-14 BP EXPLORATION REP: VARBLE SERVICE COMPANY: SWS (C. Vetromile) DHS (L. Savage) DATE/TIME 1000 1030 1300 1350 1605 1617 1640 1655 1715 1733 1737 1743 1845 OPERATIONS SUMMARY MIRU SWS SIP = 400 lAP = 100 OAP = 300 Make up lubricator Arm Baker 20 setting tool using SAFE. RIH with cci / Baker 20 setting tool / 25' AVA retrievable patch. OAL = 43' (new line on unit, season wire while running in hole) At 6850 md. Log tie ~n pass up. Not getting good collars Adjust gain & log again. Fie into Leak Detection Log dated 5/11/98. Take out 7'. Log confirmation pass. Add 1'. Log again. On depth. Log into place & hang CCL @ 6629.7'. (15.3' from CCL to top element. Puts top element @ 6645'md) Shoot setting tool. (hanging weight - 2530 #) Weight dropped off to 1800 #. Setting tool released. Looks like a good set. Log off. POOH OOH. Shear p~n m w~relJne adapter sheared. 2O3O 7/29 1100 1145 1155 1205 1215 1230 RDMO. SIP=400 IAP=100 OAP=300 MIRU triplex pump. Pump 4 bbls diesel & pressure test IA to 2500 psL IAP=2500 ' WHP=350 OAP=300 lAP = 2500 WHP = 350 OAP = 300 lAP = 2475 WHP = 350 OAP = 300 lAP = 2450 'WHP = 3500 OAP = 300 Passed MIT Rig down pump and bleed lAP down to 250 psi. Put well on injection at 100% SUMMARY: Set 25' AVA tubing retrievable patch @ 6645' md. (top element @ 6645', btm element @ 6670') Overall length of patch is 29.6'. Saw good weight loss & tool release when set. Shear pin in wireline adapter sheared. Performed MIT to 2500 psi on IA. Lost 50 psi over 30 min. Passed MIT. Put well on injection at 100% choke. Bled lAP down to 250 psi. ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 August 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ~.. _ . --~-,.. . --~.- _,.... _.-.~.~,~: .....~. ............ _ ........ _. : _~ ~. --...=- ...... ~.u=_. ..... ........ xf-u~.~ ....... _ .-. _ . - ..... :.- ...... .- _; ....~..=.. ~-~.-..~ ~ ....... ..:: ..~ ........ r-.-~x~.=.~~~~~. 7 '-:'-~ ._~i.T-:.-~{r~ ....~-~L~i-?1-29/M-25 '~~;.~Li .... 7c-L- I PLS FIN~ BL+~ .T'~>vu?~Z Run '. .... -~.-. ,1~ ...... . ........ '-. ~--'~----'~ ..-- ...... ~!~ .--.- ........... '~-- -_-'.u~-. .................... - . ...... - ................. .. ..... r~.- ; - ,~.~ -.- ._ ._~ . . _~__~_~-:---_:_---..._ ..___~.~-~- ..... .... .... .. -.. . . ..... : .... ..-~~~i k.. ---'-~--'L~,. ~ 1-~~2-34/P-14 '._:' ~]~"-:~_ ':=~-'-' ?-_1 PDK FIN~ BL+~ -' ....~.Run ~ 1 ~/'.. 76092.03.j~...~~ ~.~. . "P~ % / -' ~-" ' - .... - ...... ~'1-39 P-17 ' ~ - -" ~ 1 PDK FIN~ BL+~ - Run ~ i '. 6146 01 ......... ~-=~x.~ ~ - ~.-%. ~ ~ - _. ........ . ..... -.~=~_-~.~ X "...-~ 3~ ~_ .-/'. ~ .'. .~._. . ;_ ' _ ' .. -_. . ~ · . _ ........ - - ' - - ---' ~--~'--3'-; - ' '---. ..... · '71 -' ---c:'--'.. ' -..' ~' ..- - Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 RECEIVED Anchorage, Received by :~~ ~te: DEDE SCHWARTZ Attn. RECORDS PROCESSOR ARCO ALASKA INC. 700 G STREET ATO 1336 ANCHORAGE AK, 99510-0360. USA Date: 8 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION ECC No. Run ~ 1 6092.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 :~~~/f Or FAX to (907) 563-7803 .. Received by RECEIVED SEP 1 4 199.5 '-~.laska Oil, & Gas C~ns... C_~tm~i'or~ Date: ~ ' ~ ........ ~,hora.q~ 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 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 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development Exploratory .. StratJgraphic Service X 6. Datum elevation (DF or KB) RT= 56.0 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-34/P- 14 MPI 9. Permit number/approval number 86-172~Not required 10. APl number 50- 029-21662 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 5O' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E Gas Cons. Commission Anch0ra~e 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11242 feet 10587 BKB feet 11160 feet 10511 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve._rti.c~l depth BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. C/ass G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6~ L-80 tubing to 10793' MD Packers and SSSV (type and m easu red depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781 ', SSS V at 1508' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classification as: Oil Gas. Suspended Service Water Injector 17. I hereby certify that the foregoing is true,and correct to the best of my knowledge. Si~ned (~~~"~¢,.~ ~ /~/'-~"~---'/' Title Senior TechnicalAssistant II D at e ~)~.,//~ SUBMIT IN DOPL(CATE Form 10-~ Rev 06/15/88 i1_ ii Endicott Production Engineering Department DATE: 7/9/94 WELL N°. 2-34 /P-14 BP EXPLORATION REP' SERVICE COMPANY' MIT KIMMET LITTLE RED (MURRAY) TIME OPERA, TIONS ,,SUMMARY ,, , 0950 MIRU I~I-I-rLE'RED. 1000 lAP 1450 PSI, WHP 1860 PSI. PUMP DIESEL DOWN INNER ANNULUS UNTIL PRESSURE IS 2500 PSI. 1021 IA PRESSURE DOWN TO 2475 PSI. BUMP UP T© 2500 PSI. 1032 IA PRESSURE DROPPED TO 2450 PSI. BUMP UP TO 2500 PSI. 11 00 lAP 2400 PSI. pAS~ED MIT. 1111 BLEED lAP TO 1450 PSI. RDMO. PASSED MIT. WITNESSED BY. JOHN SPAULDING, AOGCC REPRESENTATIVE. 0il & 6as Cons. 6omrnis¢on ^nchoraga STATE OF ALASKA A,_ASKA OIL AND GAS CONSERVATION COMM,,.,oION REPORT OF SUNDRY WELL OPERATIONS rf x 1. Operations performed: Operation shutdown Stimulate Plugging Pe orate ~, _,~) Pull tubing Alter casing Repair well . Other 5. Type of Well: 6. Datum elevation (DF or KB~".,~-,-¢ RT= 56~.OY~t 2. Name of Operator BP Exploration (Alaska) Inc. Development Exploratory 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 ser~ce x Duck/s/and Unit/Endicott 4. Location of well at surface 8. Well number 2-34/P- 14 MPI 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E .~ E C E I V E D 9. Permit number/approval number At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823'WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E Anchorage 86-172INet required 10. APl number 50- 029-21662 11, Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 11242 feet 10587 BKB feet Plugs (measured) Effective depth: measured true vertical 11160 feet 10511 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve...rti.c,.al depth BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' 9308'- 10585' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890', 10940'- 10980' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206', 10252'- 10289' Tubing (size, grade, and measured depth) 5 1/2" 17# L-80 tubing to 9590' MD; 4 1/2" 12.6¢/L-80 tubing to 10793' MD Packers and SSSV (type and measured depth) 9 5/8" Baker SB-3 Packer at 9616', 7 "Baker SABL-3 Packer at 10781', SSSV at 1508' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 10418 . 1757 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended. Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knoWledge. Signed ~--'/,¢'/~,~~ , Title Senior Technical Assistant II Form 10-~ev 06/15/88 SUBMIT IN DU~LICJ~TE' Endicott Production Engineering Department DATE: 2/3/94 WELL N°: 2-34/P-14 BP EXPLORATION REP: SERVICE COMPANY: Additional P?rforations KIMMET RECEIVED ATLAS [[ DATE/TIME OPERATIONS SUMMARY 2/2 1700 MI ATLAS. 2/3 0700 RU ATLAS. 0800 Install SSV fusible cap. FWHP = 1500 psig. WHT = 125 deg F. lAP = 450 psig. OAP: 0 psig. FCV: 40%~ Rate = 5400 bpd. 0810 Pressure test lubricator to wellhead pre,?sure. 0815 SI well. RIH with Gun #1 (20 feet). SIWHP = 500 psig. 0940 Tie in to DLL/MSFL dated 11/7/86 logging up. SIWHP: 320 psig. Flag line at 11050'. 0942 Hang GR at 10957.5' and top shot at 10960'. 0945 Shoot gun #1 from 10960-10980 MDBKB. 0950 Log off while POOH. 1055 OOH. Confirmed shots fired. SIWHP = 220 psig. 1140 RIH with Gun #2 (,20 feet). SIWHP = 175 psig. 1240 Tie in to DLL logging up. Hang GR at 10937.5' and top shot at 10940'. 1252 Shoot gun # 2 from 10940-10960' MDBKB. SIWHP = 268 psig. 1253 Log off while POOH. 1350 OOH. Confirmed shots fired. SIWHP = 0 psig. 1530 RDMO. POP. PERFORATION SUMMARY' GUN D LL/M $ FL FEET SUBZONE 1 10960-10980 20 2A 2 10940-10960 20 2A All intervals were shot using 2-3/8" guns at 4 spf, 180 degree phasing and random orientation. STATE OF ALASKA ALAS,.,~ OIL AND GAS CONSERVATION COMMISSI,_.. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing x Alter casing Repair well Other . 5. Type of Well: 6. Datum elevation (DF or KB) RT= 56.0 feet" 2. Name of Operator BP Exploration (Alaska) Inc. Development Exploratory 3. Address Stratigraphic 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 Service ~; 4. Location of well at surface 8. 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E . 10. 11. Unit or Property name Duck Island Unit/Endicott Well number 2-34/P-14 MPI Permit number/approval number 86-172/90-3 78 APl number 50- 029-21662 Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 11242 feet 10587 BKB feet Plugs (measured) Effective depth: measured true vertical 11160 feet 10511 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True veBr~l depth BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' · 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890' 9308'-10585' true vertical (Subsea) 9972'- 10055; 10062'- 10088; 10119'- 10161'; 10169'- 10206' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 tubing to 9590'MD; 4-1/2", 12.6#, L-80 tubing to 10793'MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9-5/8", Baker SB-3 packer @ 9616' MD;7" Baker SABL-3 packer @ 10781' MD RECEIVED 14. Intervals treated (measured) DEC ;5 0 199,5 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Representative Daily Average Production or Injection Data ¢,i~c~oi,~yu Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5000 1400 5000 1250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foreg~~.,~is true and c~___.~re~ to the best of my knowledge. Signed #,~/-~ -~,~ Title Drilling En.qineerSupervisor Form 10-40~ Rev ~36/15/88 ' /(,./ / SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 2-34/P-14 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/20/93 04:00 SPUD: RELEASE: 11/30/93 09:30 OPERATION: DRLG RIG: WO/C RIG: DOYON 15 11/21/93 ( 1) TD:11242 PB:lll60 N/U BOPE. MW: 8.5 Seawater MOVE RIG. RIG ACCEPTED @ 16:00 HRS, 11/20/93. REPAIR TOP DRIVE. N/D TREE. N/U BOPE. 11/22/93 (2) TD:11242 PB:lll60 RIH. MW: 9.4 NaCl N/U BOPE. TEST BOPE. PULL TBG HGR. CIRC 9.4 PPG BRINE. POOH, L/D TBG. RIH. 11/23/93 (3) TD:11242 PB:lll60 11/24/93 ( 4) TD:11242 PB:ll160 11/25/93 ( 5) TD:11242 PB:lll60 11/26/93 (6) TD:11242 PB:lll60 POOH. MW: 9.4 NaC1 RIH TO 9563' CIRC. SET RTTS @ 52'. N/D BOPE. CHANGE PACKOFF. N/6 BOPE. TEST BOPE. L/D RTTS. RIH TO 9765'. WASH OVER PKR. CIRC. POOH. RIH W/ SPEAR. MW: 9.3 NaC1 L/D WASHPIPE. RIH W/ OVERSHOT. LATCH SBR. POOH W/ SBR. RIH W/ OVERSHOT. LATCH K-ANCHOR. POOH. L/D K-ANCHOR. RIH W/ SPEAR. POOH. MW: 9.3 NaC1 RIH. LATCH & RELEASE HBBP PKR. CBU. POOH W/ PKR. L/D PKR. RIH W/ MILL TO 10584'. DRESS TOP OF PKR. RELASE K-ANCHOR. WORK FISH FREE. POOH. M/U BHA. MW: 9.3 NaCl POOH. L/D K-ANCHOR. RIH W/ PKR MILL TO 10771'. MILL PKR. POOH. M/U BHA. 11/27/93 (7) TD:11242 PB:lll60 11/28/93 (8) TD:11242 PB:lll60 11/29/93 (9) TD:11242 PB:lll60 CIRC. MW: 9.3 NaC1 RIH W/ MILL TO 10771' MILL ?KR TO 10773' POOH. RIH W/ MILL SHOE. MILL PKR. PUSH PKR TO 11130' REAM TO 11143' CIRC. RIH W/ CSG SCRAPERS. MW: 9.3 NaC1 POOH. L/D MILL'SHOE. RIH W/ TEST PKR TO 2486'. TEST CSG. OK. RIH TO 9800' TEST CSG. OK. POOH. L/D PKR. RIH W/ CSG SCRAPERS. RUN 5-1/2" TBG. MW: 9.2 NaC1 POOH. L/D BHA. RIH W/ 5-1/2" X 4-1/2" COMP ASS'Y. DEC 3 0 19g;5 Oit & Gas Cons. Commissior, Anchorage WELL : 2-34/P-1 OPERATION: RIG : DOYON 15 PAGE: 2 11/30/93 (10) TD:11242 PB:lll60 12/01/93 (11) TD:11242 PB:lll60 SET & TEST PKRS; MW: 9.2 NaC1 RIH W/ 5-1/2" X 4-1/2" TBG. R/U ATLAS. RUN GR/CCL. R/D ATLAS. SPACE OUT TBG. M/U TBG HGR. TEST SAME. OK. LAND TBG. N/D BOPE. N/U TREE. TEST LINES. OK. TEST TREE. OK. REV CIRC. DROP BALL. SET BAKER 7" & 9-5/8" PKRS W/ 4000 PSI. TEST PKR. RIG RELEASED. MW: 9.2 NaC1 F/P WELL W/ 129 BBLS DIESEL. SET BPV. SECURE TREE. RIG RELEASED @ 09:30 HRS, 11/30/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED Aiaska 0~t & 6as Cons. Commissar,, Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LAPdqY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 6092.02 Data: PL Dear Sir/Madam, Reference: BP 2-34/P-14 ENDICOTT Enclosed, please find the data as described below: Prints/Films: Sent by U.S. MAIL PLS INJ. FINAL BL PFC/SCL FINAL BL PLSCIN~RF SEPIA PFC/COL RF SEPIA Run # 1 Run # 1 Run # 1 ~IP--/\ ~C~ ._~' Run ~ 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date · ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE . AK, 99501. USA Date: 16 December 1993 RE: Transmittal of Data ECC #: 6092.01 Data: NONE Dear Sir/Madam, Reference: BP 2-34/P-14 ~¢_. [7L ENDICOTT NORTH SLOPE, AK Enclosed, please ·find the data as described below: Prints/Films: 1 1 Sent by U.S. MAlL GR/CCL FINAL BL Run # 1 GR/CCL FINAL RF Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA - Date: 24 November 1993 RE: Transmittal of Data ECC #: 6092.00 D at a: NONE Dear sir/Madam, Reference: BP 2-34/P-14 NORTH SLOPE, AK Enclosed~ please find the data as described below: Prints/Films: Sent by U.S. MAIL COLLAR LOG RF. SEPIA COLLAR LOG FNL. BLUE Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK.99518 Attn. Rodney D. Paulson Received by: Date: RECEIVED NOV 2 6 19.9.3 Alaska Oil & ~s ~ STATE OF ALASKA ,2,~"~'f ? ; .-' ~ Al_A,., ,A OIL AND GAS CONSERVATION COMMISL .,I ~ ,,.~ J i t~ · , . ) ' (, ?,./'/, APPLICATION FOR SUNDRY 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 x Vadance Perforate Other 2. Name of Operator I 5. Type of Well: 6. Datum elevation (DF or KB) · Development RT 56 0 feet BP Exploration (Alaska) Inc. I ~ . . - = · .... I ~-xplora[ory ~. Aaoress I Stratigraphic - /. un~ or r'roperty name P. 0. Box 196612, Anchorage, Alaska 99519-6612 I service; Duck Island Unit/Endicott 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 8. Well number 2-34/P- 14 MPI 9. Permit number 86-172 10. APl number 50 - O29 -21662 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: 11242 feet Plugs (measured) 10587 BKB feet 11160 feet Junk (measured) 10511 BKB feet Length Size Cemented RECEIVED f"~OV 1 $ 199~ Alaska 0il & 6as 6ons. 0ommission Anckoraae , Measured cl~ T[u/~/~/~rtica, depth 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827'- 11240' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890' 9308'-10585' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9757', 3 1/2" 9.2# L-80 tubing with 2 718" tailpipe to 10779' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9757', 7 "HB-BP Packer at 10765', SSSV at 1602' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch __ 14. Estimated date for commencing operation 11/18/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Iniector Suspended,__ 17. I hereby certify that the foregoing/is true and correct to the best of my knowledge. Signed,~~ ~.~?,,~¢¢~,."/~' Title Drillin.q Engineer Supervisor ' ~ .~ FOR COMMISSION USE ONLY Conditions of approval: Notify Co~hmission so representative may witness Plug integrity BOP Test__ Location clearance__ Mechanical Integrity Test ,'X'. Subsequent form required 10- ,yon Original Signed By Approved by order of the Commission David W. Johnston I Approval No. Approved Copy Returned Com',hissluner Date f/'//f'~'// SU BM IT tN TRIPLICATE Form 10-403 Rev 06/15/88 ENDICOTT SDI 2-34/P-1 WORKOVER PLAN OBJECTIVE: A rig workover is required on well 2-34/P-14 to replace a failed 9-5/8" Retrievable packer. The scope of the work will be to pull the 4-1/2" tubing, mill and recover the 9-5/8" packer, recover the straddle assembly, mill and recover the 7" packer, clean out to PBTD, and run a new 5-1/2" x 4-1/2" carbon steel straddle assembly. Due to the well being a water injector, carbon steel will be used instead of 13-Cr. Since barite was spotted on the packer in an attempt to seal the leak, extra fishing time is included to wash over the SBR. TIMING: 3rd Quarter 1993 13 days plus island to island with rig Doyon 15 PRE-RIG OPERATIONS . . RECEIVED RU slick line. dummy off gas lift mandrels. Pull the WL SSS~''''~*~ "" ~' 6as Cons. Commission · Anchorage RUE line. RIH and cut the 3-1/2" tubing below failed 9-5/8" packer in the first full joint of tubing above the ported nipple (10,604' MD). Attempt to circulate the IA with 9.4 ppg brine. The well may not circulate due to the barite plug. Check that the well is dead. . RIH and cut the 4-1/2" tubing +/- 70' above the the TIW SBR. Check that the well is dead. If the well would not circulate in step #2, circulate the well with 9.4 ppg brine. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If rig move is delayed to more than three days after the well kill, a deeper freeze protect will need to be done. . Dig out the cellar and level the pad. Inspect the wellhead and tree. Test the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS I . Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. . Pull the BPV with DSM lubricator· Check that the well is dead. Set the BPV. 3. ND the tree and NU the BOPE. Test the BOPE. (1/2 day) . Screw in the landing joint. Pull and LD the tubing to cut point above the 9-5/8" packer. (1/2 day) . PU wash pipe assembly and DP and RIH. Wash over tubing and SBR to to top of packer. (1 day) JLH Page 1 November 12, 1993 . , . . 10. 11. 12. 13. 14. ENDICOTT SDI 2-34/P-14 ~WORKOVER PLAH P/U overshot and recover the tubing stub and SBR. Fish the slick stick and latch. (1 - 1/2 days) P/U retrieving tool for 9-5/8" HBBP-R. Recover failed 9-5/8" HBBP-R packer. (2 days) GIH w/overshot to recover 3-1/2", blast joint assembly, and 7" packer latch. (1 day) GIH with 7" packer mill and mill up TIW 7" HBBP packer. Push packer to PBD. (1 day) Run an 6" mill and tandem casing scrapers (7" & 9-5/8") to top of milled packer in rathole. The 9-5/8" scraper should be spaced out above the 7" liner top. Displace the well with clean sea water. (1/2 day) P/U and GIH 9-5/8" test packer. Set packer at +/- 2500' MD to ensure packer is operating correctly. TIH to just above 7" liner top at 9827' MD. Test casing to 3500 psi for 30 minutes. POH w/packer. (1/2 day) RIH w/7" x 4-1/2" packer, 4-1/2" L-80 blast joint assembly, 9-5/8" x 5-1/2" packer and 5-1/2" L-80 tubing to expected setting depth. (2-1/2 days) R/U E-line. Tie in and position packers on depth with WLM. Set the 7" and 9-5/8" packers. Test the tubing to 3500 psi Test the packer and IA to 3500 psi. (1/2 day) ' Set the BPV. ND the BOPE and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day) 16. Turn the well over to Production. RECEIVED ~.ov 1 ~ A!~ska Oil & ~as Cons. Commission Anchorage JLH Page 2 November 12, 1993 Bluelines to the State BLUELINE AND SEPIA INFORMATION ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS ,~?-~ 1-27/P-20 -'"' 5/1/92 ~,~--,~o" 2-28/P-19 f-'/'¢<' 2-30/0-09 ¢... I?Z. 2-34/P-14 LOG NAME RUN NO 10350'-10850' Production Profile Survey One COMPANY NAME Camco ~(~--Z,? 2-46/Q-15 ~ e "'77 2-64/U- 10 ~'~.--! ~"' 3-01/N-29 ~ ~-'{~ 3-33/K-37 ~ ~-.7,7.. I4-02/Q-28 4-02/Q-28 J~--~¢ 4-50/K-41 ,' 4-40/P-43 ~/' 5/2/92 · '" 5~20/92 -'/ 5/16/92 · / 5~3~92 "" 5~22/92 ,/' 5~4~92 '/' 5/21/92 ,,/ 5/1 1/92 .,/ 5~24/92 · / 6/7~92 ./' 5/14/92 5/14/92 5/14/92 5/14/92 5/18/92 5/18/92 4~40/P-43 -~' ~[~.,,[,3, 4-40/P-43 '~' 4-40/P-43 ,./" 4-40/P-43 '/' 4-40/P-43 --' 9900',10300' 11100'-13250' 100'-10700' 10500'-11100' 8800'-9600' 12150'-12700' 12640'-12945' 11800'-13000' 10600'-13008' 13300'-13890' 13100'-13801' 13031.6'-13624' 13100'-13806' 9650'-13806' 12580'-13688' 12580'-13652' Production Profile Survey Production Log Leak Detection Survey Production Profile Survey TDT-P/Borax Survey/Water FLow Log Production Profile Survey Production Log Flowmeter Temperature Log Injection Profile Survey Production Logging Services Dual Laterolog Micro-SFL Repeat Formation Tester Subsea TVD Log Compensated Neutron-Litho-Density Ultrasonic Imager (USI)' Cement Bond Log One One One One One One One One One One One One One One One One Camco Schlumberger Camco Camco Schlumberger Camco Schlumberger Camco Camco Atlas Wireline Services Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Page 1 AL~,.,,,,A OIL AND GAS CONSERVATION COMMIS~ .... ~1 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Alter casing __ Change approved program__ 2. Name of Operator BP Exploration (Alaska) Inc. Suspend __ OperalJon Shutdown __ Re-enter suspended well __ Repair well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Vadance x Perforate __ Other __ 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 12. Present well condition summary 6. Datum elevation (DF or KB) RT-- 56. O 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-34/P- 14 MPI 9. Permit number 86-172 10. APl number 50- 029-21662 11. Field/Pool Endicott Oil Pool RECEIVED Total depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical measured true vertical Length 11242 feet Plugs (measured) 10587 BKB feet 11160 feet Junk (measured) 10511 BKB feet Size Cemented APR 1 3 1992 Alaska 0il & Gas Cons. O0mm~ss~On Measured de~,B Arlch[~r~Bev/~ical depth 71' 30" Driven 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 10071' 9 5/8" 575 c.f. Class G 10111' feet 111' 2482' 9556' 9308'- 10585' Date '" ~' ,/'"~"' >":,Z ?, SUBMIT IN TRIPLICATE~::~~"- 1413' 7" 447c. f. Class G 9827'- 11240' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9757', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10779' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9757', 7 "HB-BP Packer at 10765', SSS V at 1602' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended __ 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~.~?~ q~. ~'FOR COMMISSIoNTitle SeniorTechnicalAssistantllusE ONLY Date Conditi~s of approval: Notify Commission so representative may witness I Approval No. ,~. Plug integrity_ BOP Test__ Location clearance I Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission OR,~:~INAL 8IuNED BY L~:"'~ C SMITH Form 10-403 Rev 06/15/88 Commissioner ~ ~ o ? '~' ..,-, - C:.' '"':; <''':_ , ?.. :' ~.~.. ~:'j,:~'..'~'" ~: ' "~ . SUNDRY APPLICATION FOR VARIANCE Well 2-34/P-14 4/6/92 Background Well 2-34/P-14 is a former 3A/2B producer converted to 2B only water injection. The well produced from both subzones between field startup and 4th quarter 1989, when it was converted to full-time water injection and the straddled 3A perforations were isolated with a blanking sleeve. Currently the well is shut-in due to communication between the straddled perforations and the inner annulus. A noise and temperature survey taken 3/3/91 indicates that the 9-5/8" packer is allowing formation fluids from the straddled perforations to communicate into the inner annulus. Remedial actions Non-rig remedial actions to deal with the situation have been exhausted. In June '91, 130 feet of barite fill was circulated onto the 9-5/8" packer in an attempt to "sand back" the leak. The operation restricted leak rate but has not eliminated communication. Currently, the well is freeze protected and shut-in with a stabilized inner annulus pressure of 1600 psi. A rig workover to return the well to injection is not required from a reservoir management perspective for at least three years. The target water injection sequence (MPI 2B) is repressured due to gas injection. Reservoir simulation indicates that water injection will not be required in this well for the next four to eight years. Recommendation Our recommendation is to leave the well shut-in until water injection is again required for reservoir management. At that time a rig workover to repair the leaking straddle packer will be completed. In the interim, a plug will be set in the straddle assembly to isolate the water injection perforations and the well will be isolated from the injection facility. The inner annulus will be monitored daily and maintained below 2000 psi. Your approval is sought for this course of action. RECEIVED APR 1 1992, Alaska Oil & Gas Cons. 6ommissior~ Anchorage 'MPI WELL '-34/P-14 ) ~Q;;O' MD MORRT NOTF~ COMPtETION EQUIPM'E~ DEPTHS ARE IDRILLER'~ DEPTHS. PERFORATING DEP'r'Hs ARE WIRE.UNE MF_A~IR EMF~E,_ 4 lf2" SS,S~ WTI"H M3N Ln O F 3 1113"; 4-I~3-, 12.Sar'FT. L.a~ BTR~ TualNa OA~ MFT MANDflEI.~ 41~' (1750' MIN LD.) -- 3-I/2', 9.2~, L-lO, 3"D~ 11.1~N<3 g ~ c~3 SHOE (M~N ID 10.634' TO I~,724' 10.732' TO 10,~22' TO 10~7~0' 10,7~'* 3' - 2-7/~' PUP JOINT ~.-?/r 'x" NIPPLE (/..313' I1~ 2-7/~' ~ MPf:H,.E (2.313' 1D) 10,77~' PERFORATIONS: BAKER OPC - 5- (~ 4 SPF fiEF: OLL-.GR(11/7/8~) 10.~..<o' TO 1 SCHI.UMBERGE.R - 2 1/'r 4~ 4 SPF PBT'D 11,160' BP EXPLORATION,INC. (;OMPLETION DIAGRAM APl NO: 50-,0Z:~.; ~ WELL NAME 2-341P-14 LOG/DATE DIL/SFL 11/7/86 23DNE TOP M.D. BOT M.D. 3A3/3A2 10634 10724 3A2 10732 10750 2B3 10795 10840 2B1 10850 10890 H TOP 'I'VD BOT TVD SPINNER SPINNER 2/9/88 5/1 3/89 90 9972 1 0055 0.27 0.29 28 10062 10088 0.27 0.00 45 10119 10161 0.46 0.71 40 10169 10206 SPINNER SPINNER 8/1/90 0.19 0.81 WELL 1-55/R-25 RADIOACTIVE TRACER SURVEY 12950'-13550' SCHLUMBERGER STATIC PRESSURE SURVEY 12950'-13550' SCHLUMBERGER 8/12/90 RUN ONE 8/12/90 RUN ONE WELL 1-57/R-2~ CTEMPERATURE SURVEY 11486'-11972' HALLIBURTON LOGGING SERVICES 8/14/9O RUN ONE WELL 1-63/T-22 STATIC PRESSURE SURVEY 12436'-12436' SCHLUMBERGER RADIOACTIVE TRACER SURVEY 12300'-13082' SCHLUMBERGER 8/13/90 RUN ONE 8/13/90 RUN ONE WELL 1-67/'['-2~) ,/TEMPERATURE SURVEY 111 20'- 11650' HALLIBURTON LOGGING SERVICES 8/12/9O RUN ONE WELL 2-26/N-14 STATIC TEMPERATURE SURVEY 11500'-12000' CAMCO .. WELL 2-28/P-1 ~) v" PERFORATION RECORD 10070'-10436' SCHLUMBERGER 8/12/90 RUN ONE 8/22/90 RUN ONE WELL 2-34/P-14 INJECTION PROFILE WARM BACK 10770'-10990' CAMCO 8/1/90 RUN ONE John Boyle Alaska Oil and Gas Conservation Commission Page Two WELL 2-34/P-14 LEAK DETECTION 9100'-10900' 3/3/91 RUNONE WELL 2-44/R-12 INJ 11900'-12340' 3/2/91 RUN ONE WELL 3-11/M-30 SURF-1495' 3/28/91 RUNONE WELL 3-23/N-32 PROD-F 11200'-11660' WELL 3-29/J-32 HRS 11950'-12700' SPINNER WELL 4-08/P-27 PROD-F 13000'-13710' 3/27/91 RUNONE 3/22/91 RUNONE 3/26/91 RUN ONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~JN 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 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RT= 56.0 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-34/P- 14 MPI 9. Permit number/approval number 86-172/90-378 10. APl number 5O- 029-21662 11. Field/Pool Endicott Off 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: 11242feet 10587 BKB feet 11160 feet 10511 BKBfeet Plugs (measured) Junk (measured) Length Size Cemented Measured depth True vertical depth BKB BKB 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 95/8" 575c. f. Class G 10111' 9556' 1413' 7" 447c. f. Class G 9827' - 11240' measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 10890' 9308'- 10585' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161'; 10169'- 10206' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9757', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10779' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9757', 7 "HB-BP Packer at 10765', SSSV at 1602' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Produ~ion orln!ection Data~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 5000 1400 5OOO 1250 '~'TUb~ng;Prossure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas__ Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ."/"'~ 2 ,/"_~~..~-")'7~7'% Title Reservoir Development Coordinator Form 10-404 Rev 06/15/88 Date ~//2.¢//¢' D SUBMIT IN ECUPI~ICATE Endicott Production Engineerin g --' I I I J JI · -' ----I_IZ~- ' m ...... ~ ..... ...... , ..... --'11I I . DPERATIONS~FIEpORT DATE: 7/1 319 0 WELL N~: 2.34/P-14 TYPE OF OPERATION: ADDITIONAL PERFORATIONS BP EXPLORATION REP: SERVICE COMPANY: SOHLUMBERGER- ,gARBER DATE/TIME OPERATIONS SUMMARY __ ......... t ,,. i JL I - i~ ~U ~11 I ' .......... i~' · --1-''. ........ :' .-'~.._."i , 0700 ,..~3S. .. :,,0 ~ ;'1 5 ' A.RM GUN #1 'AND PULL I'~0 RISE-R. P;.TEST, LUBRIC_.ATOh ~_._l_'r'H WHP'~' ,, L 0840 _ WHI.P__-150.O_'P$!,_..!_A..P.,600 PSIi O_~.~-=0 PSI, SI W, ELL AND..RIN. . O 9 5 0 PUT WELL ON INJECTION AT 8000 BPD, WHIP,--1580 PSI, TIE IN TO CBT(11/l~J86). SHOOT 20 FT INTERVAL FROM 10870-10890 FT, SI · WEL.L AND PON. 1 1 00 ...... ,GUN #1 A, Ti~URFA0tE, AL['S~-O.T.~ FIRED.' ARM G'UN,~2 AND RIN. ' ....... ' 1 2'00'-- PUT WELL ON INJECTION AT 8000 BPD, WHIP-1600 PS1, TIE IN TO _ AND SHOOT 20 FT INTERVAL FROM 1085_0-1.0870 FT, SI WELL AND POH. i 1,31 ~ GUN #2 AT .SURFACE, ALL'SHOTS.FIReD. '" _ . il _ , ,-, : ---.- .. . Il !.~ .30 ' PEIRFORATi0N',.RUM~RY?~tE~'' ~'OLEOWING iNTERVAL WAS SHOT U$1N(3 ,~K~HLUMBEG~R 2.1/8 IN(;H HYPERDOME CARRIER GUNS AT 4 SPF, 0 DEG PHASING AND ORIENTED TO THE LOW SIDE OF THE LINER. DEFrI'NS ARE I~EF: C8T(11/12/86). · . ...... 1,0850-.! .08g:..O ,.F..T'... MDSKB .......... Page 1 WELL 2-28/P-19 7/14/90 *DUAL BURST TDT LOG (TDT-P) 9650' - 10445' Run No. 1 Schlumberger WELL 2-:~4/P-14 7/1 :~/90 *PERFORATION RECORD 10650' - 11113' Run No. 1 Schlumberger WELL 2-58/S-09 *DGR/EWR/CNO/SFD 9928' - 10796' Sperry-Sun 5/28/9O Run No. 1 *DGR/CNO/SFD 12496' - 15350' Sperry-Sun Run No. 1 *EWR/DGR 12496' - 15350' Sperry-Sun Run No. 1 *CEMENT BOND LOG / ~¢¢'¢, .__1_8e40~_ 15156' Schlumberger 6/1/90 Run No. 1 · CEMENT EVALUATION LOG 10304' - 15174' Run No. 1 Schlumberger *GAMMA RAY-CCL 13874' - 14340' Schlumberger 6/4/90 Run No. 1 *COMPLETION RECORD 6/5/90 13800' - 14360' Run No. 1 Schlumberger *GR/CCL TCP CORRELATION LOG 13566' - 13950' Run No. 1 Schlumberger WELL3-05/C)-29 6/18/90 *PERFORATING RECORD 12100' - i 2550' Schlumberger Run No. 1 6/1/90 6/7/90 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 16, 1990 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Endicott Field Well 2-34/P-14 Additional Perforations Dear Mr. Chatterton: 232JLH Enclosed in triplicate is Form 10-403, Application for Sundry Approvals, for the above named well. We are planning to perforate additional intervals in this well. Please contact Gary Adamson at 564-4624 if any additional information is required. Sincerely, H. L. Hellman Reservoir Development Coordinator HLH/~ .~~slk Enclosures xc: Working Interest Owners J. F. Oldenburg T. N. Tyler W. R. Blosser--z¢_ ~ G. R. Adamsoff~ J. L. Haas K. A. Greenes A. R. O. Wood Well File File 76.10 :MAY 2 '.! 1199r" ,'~.i.:4st~.0jl & Gas Cons~ Comrr;issior~ ..... , .....?,. ~nchora~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,ob,,.~N 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. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development__ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) RT= 56.0 feet 7. Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 8. 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 9. Well number 2-34/P- 14 MPI Permit number 86-172 10. APl number 50- 029-21662 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 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: 11242 feet 10587 BKB feet 11160 feet 10511 BKB feet Plugs (measured) Junk (measured) Length Size Cemented ~,V'lf:~¥' 2 'l 1.9F!-' :;¢ska Oil & Gas Cons, 6ommiSst'ori Measured d/~Bh ....... %" ~i~[~;'~alBKB depth 71' 30" Driven 111' 111' 2442' 13 3/8" 2542 c.f. Permafrost 2482' 2482' 10071' 9 5/8" 575 c.f. Class G 10111' 9556' 1413' 7" 447c. f. Class G measured 10634'- 10724', 10732'- 10760', 10795'- 10840' 9827'- 11240' 9308'- 10585' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9757', 3 1/2" 9.2# L-80 tubing with 2 7/8" tailpipe to 10779' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9757', 7 " HB-BP Packer at 10765', SSSV at 1602' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 25, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'// '2 ~~ Title ReservoirDevelopmentCoordinator 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 Subsequent form required 10-'-- I Approval No. ~'~ (...,) _,~ 7 ~ Approved Copy Returne~l Commissioner SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY BP Exploration Endicott Field Well 2-34/P- 14 Additional Perforating Proposal In order to obtain injection in the 2B1 sequence we propose to perforate the following interval. 10850'-10890' (Ref. DIL/SFL 11/7/86) 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. BASIC SYSTEM MAKEUP FLOWLINE 'VALVE ._~~,,'"' BOWEN PACKOFF' ~ ¢, '1 //.~,--~SE SE*~ ' ~LOWLINE ~I ~t I~GREASE LINE -~ 0 _ GR~SE ~-i i~ -~~ . RISB ~REA'SE RESERVO. BOP WELL 1-43/P-26 *TEMPERATURE SURVEY 12900' - 14290' Run No. 1 CAMCO WELL 1-05/O-20 *COLLAR LOG 10312' - 10670' Run No. 1 ATLAS WIRLELINE SERVICES WELL 2-34/P-14 MPI *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 WELL 3-35/L-36 SDI *PRODUCTION PROFILE 12000' - 12350' CAMCO Run No. 1 WELL, ~-84/P-14 MPI *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 LMS cc: File 06.10 BP EXPLORATION October 11, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. 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, GND/Ims ~" /Ai~.ska Oil & Gas Cons. Commissio~a V Anchorage BP EXPLORATION October 10, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 RE: Notice of Commencement of Injection Operations for Well 2-34/P-14 Dear Mr. Chatterton' Endicott well 2-34/P-14 will be converted from oil production service to water injection service during October 1989 as part of the full field waterflood. Per field regulation 25.420, this letter fulfills the requirement of notification (not application). Arrangements have been made to have an AOGCC representative available for the pressure test of the casing immediately exterior to the injection tubing string as required by 25.412c and 25.412e. If there is a need for any additional information, please contact me at 564-4757. Sincerely, i /~eservoir and Production Engineering "~ JFO/JLH/Ims: Attachment cc: Working Interest Owners 1167/JLH BP EXPLORATION October 1 O, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RE: Notice of Commencement of Injection Operations for Well 2-34/P-14 Dear Mr. Chatterton' Endicott well 2-34/P-14 will be converted from oil production service to water injection service during October 1989 as part of the full field waterflood. Per field regulation 25.420, this letter fulfills the requirement of notification (not application). Arrangements have been made to have an AOGCC representative available for the pressure test of the casing immediately exterior to the injection tubing string as required by 25.412c and 25.412e. if there is a need for any additional information, please contact me at 564-4757. Sincerely, I eservoir and Production Engineering JFO/JLH/Ims: Attachment Working Interest Owners 1167/JLH Attachment 1 BP Exploration Endicott Field Well 2-34/P-14 Notice of Commencement of Injection Operations Endicott 2-34/P-14 will be converted from oil production service to water injection service during October 1989 as part of the full field waterflood. Notes' 1. This notice was originally supplied to the AOGCC as a letter dated · September 21, 1989. Since, under the field regulations (25.420), notification (not application) is all that is required to begin injection, the original notice fulfills compliance and this is a redundant second issue. 2. A pressure test of the casing immediately exterior to the injection tubing string will be conducted as required (25.412c). An AOGCC representative has been contacted for witnessing the test - (25.412e). 1167/JLH RECEIVED CCI' I 1 l§g~ Alaska. 0il .& Gas Cons. Commission ,,.. Anchorage Attachment 1 BP Exploration Endicott Field Well 2-34/P-14 Notice of Commencement of Injection Operations Endicott 2~34/P-14 will be converted from oil production service to water injection service during October 1989 as part of the full field waterflood. Notes: , , This notice was originally supplied to the AOGCC as a letter dated September 21, 1989. Since, under the field regulations (25.420), notification (not application) is all that is required to begin injection, the original notice fulfills compliance and this is a redundant second issue. A pressure test of the casing immediately exterior to the injection tubing string will be conducted as required (25.412c). An AOGCC representative has been contacted for witnessing the test - (25.412e). 1167/JLH OCT 1 1 1§~;'-" aJaska .0ii ,& Gas Cons. ,. Anchorage BP EXPLORATION September 21, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Change of Service on Well 2-34/P-14 Dear Mr. Chatterton: Enclosed in triplicate is Form 10-403, Application for Sundry Approvals, for Endicott Well 2-34/P-14. The well is currently a producer in subzones 3A and 2B and will be converted to a 2B water injector. A pressure test on the annulus will be submitted in the near future. If there is a need for any additional information, please contact Bill Blosser at 564-4401. Sincerely, na.ger Reservoir a,nd Production Engineering jV'O/WRB~h Enclosures cc: Working Interest Owners Drilling Well File 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 X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic__ Service 6. Datum elevation (DF or KB) 7. Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 9. 8. Well number 2-34/P- 14 MPI Permit number 86-172 10. APl number 50- 029-21662 222' SNL, 3716' WEL, SEC. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E At total depth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 11. Field/Pool Endicott Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 11242 feet 10587 BKB feet 11160 feet 10511 BKB feet Plugs (measured) Junk (measured) Size Cemented Measured d/~/~Bh 30" Driven 111' 13 3/8" 2542 c.f. Permafrost 2482' 9 5/8" 575 c.f. Class G 10111' 71' 2442' 1OO71' 1413' 7" 447c. f. Class G measured 10634'- 10724', 10732'- 10760', 10795'- 10840' RECF VED ,'-~!asl(~. 0il & Gas Cons, True BKB 111' 2482' 9556' 9827'- 11240' 9308'-10585' true vertical (Subsea) 9972'- 10055', 10062'- 10088', 10119'- 10161' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 tubing to 9757', 3 1/2" 9.2t/L-80 tubing with 2 7/8" tailpipe to 10779' Packers and SSSV (type and measured depth) 9 5/8" HB-BPR Packer at 9757', 7 " HB-BP Packer at 10765', SSSV at 1602' 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 15, 1989 16. If proposal was verbally approved Oil X Gas __ Suspended __ Name of approver Date approved Service 17. I herebC'~eCrfy that th/e"rjz~r, ed~ing~ true and correct to the best of my knowledge. f ,l l ' ,,,~,~ l/l i ll I Signed ~//'~~ Title Manager, Reservoir & Production Engineering C //' "o/~(di~tion/~ '-'- f FOR COMMISSION USE ONLY of approval: Notify Commission so representative may witness Plug integrity BO~.Test Location clearance Mechanical Integrity Test ~xx, Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL 2-42/P-1 :~ *PRODUCTION PROFILE 11300'- 11900' CAMCO WELL 2-08/K-16 *PRODUCTION PROFILE 11700'-12200' CAMCO WELL 1-2~)/M-25 *PRODUCTION PROFILE 13300'-13900' CAMCO WELL 2-34/P-14 *PRODUCTION PROFILE 10450'-10900' CAMCO WELL 2-14/O-16 *PRODUCTION PROFILE 10350'-10750' CAMCO WELL 3-45/M-39 *INJECTION PROFILE 12200' - 12690' CAMCO ' WELL 4-08/P-27 *PRODUCTION PROFILE 13000' - 13500' CAMCO WELL 1-43/P-26 *INJECTION PROFILE 13600' - 14279' CAMCO 1027/GD Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 2 REVISED WELL C :PLETION REPORT 11-23-88 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WI:LL COMPLETION OR RI:COMPLETION REPORT AND LOG" -- - 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 86-172 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21662 4. Location of well at surface 9. Unit or Lease Name 1969' SNL, 2256' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 2-34/P- 14 MPI 222' SNL, 3716' WEL, SEC. 36, T12N, R16E 11. Field and Pool At Total Depth Endicott Field/Endicott Oil Pool 24' SNL, 3838' WEL, SEC. 36, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. 56'= KBE I ADL 24633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10-18-86 11-08-86 07-11-87I 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 of Permalrost 11242'MD 10587'TVD 11160'MD 10477'TVD YES [] NO []I 1682 feet MD I 1466' 22. Type Electric or Other Logs Run DLL/MSFL, Array Sonic, NGT/SPEC, MEST RAW DATA, CNL/LDT 23. CASING, LINER AND CEMENTING RECORD SETnNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMB',rl'ING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 131' Drive 13-3/8" 72# L-80 Surface 2482' 17-1/2" 2542 cuft Permafrost 9-5/8" 47# NT80S Surface 5366' 12-1/4" 9-5/8" 47# NT95HS 5366' 10111' 12-1/4" 575 cuft C/ass G o. 12% HR, o. 75% CFR-2 7" 29# L-80 9827' 11240' 8-1/2" 44 7 cuft Class G .15% LWL & .05% Halad 344 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) Schlumberger 5"@ 5 spf 4-1/2" 12. 6~ 9757' 9-5/8" ~ 9773' MD TVDss L-80 7" HP-BP ~ 10764' 10634'- 10724' 9971 '- 10054' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10732'-10760' 10061'-10087' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10795'-10840' 10119'-10160' 9-5/8"x 13-3/8" Annulus Down Squeeze with 345 SX Permafrost followed by 115 BBL Dry Crude. _>7. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) July 7, 1987 IF/owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, lractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED DE,., ? Alaska 0il & Gas Cons, Commission Anchorage ~'"..L--.', :_ _1..~1:~ Form 10-407 Submit in duplicate Rev. 7-1-80 C, Ch'~INUED ON REVERSE SIDE 1' ; i' ' 29. ~,/ · 3o. :, GEOLOGIC MARKERS '- FO~ATION TESTS NAME Include interval tested, pressure data, all tluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP HRZ 9832' 9257' LCU 10152' 9518' TOP KEKIK7-UK 10291' 9660' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.(~ /~L~,"I "' Endicott Drilling Engineering Signed ~~'''' v, v,~,-, ,-,.~ Title SuD@rvi¢¢r Date //-- ~"~c'~ '-'~'~ INSTRUCT~NS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the 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 [i:~,L, '.,,': ( WELL NAME: · ' APl NO.: ,,r.,, ~,'-~; SERVICE CO.: --~ DESCRIBED BY: LAB ANALYSIS: STANDARD OIL PRODUCTION CO. SIDEWALL CORE,., DESCRIPTION DATE : ~ou,1)lq~ ~. RUN NO.: / GUN TYPE: GUN NO.' BULLET TYPE: ~/Y~ /'/ CHARGE ' c[~ -~ S-o~ LOG RUN W/GUN ®1~ .~-~'~ -~-:.~,' ~. CORRELATION LOG TYPE: ':'%F. +i~ ~'-,~ SAMPLE CUTS ~/ DRY ~ WET . ,. . DEPTH REC COND LITHOLOGY SAMPLE POROSITY _ STAIN FLUORESCENCE CUT ~UT FLU ' (SIZE) LIST-TYPE, COLOR, HARDNESS, GRAIN SIZE, ANGULARITY, LOC. ODOR DIST~ I:~JANT.~/''~ INTE~/ SORTING AND ACCESSORIES ~ .~...-'~OLOR DIST. INT. COLOR '/~-~..CO.LOR / COLC ' ~,~ ~"~ z:~ ~:~ f> ~,: ~ '~/0% ~~ " " " :~'~ .... ., .. / ~J.~.'. ...... ;, -I _ . ,,F ..... , , , i , , ,, , ,i ECOV RY GRAIN SIZE SAMPLE LOCATION OIL STAIN (Distr.) OIL STAIN (Color) ' .CUT (Color) FLUORESCENCE ] = Lost Bullet B= Broken Bullet ~,: Empty Bullet ~F: Misfire OND1.1' IONS/S IZE [inches) Intact qroJ<en attered M =Mud )~.~=Thin-section N = Nome L ~_ Light ~ ~Lt.ar S : Silt' X-ray Diffraction E = Even M N~lium . .~.~.Straw Distr. Intensity VF : Very Fine * : SEM M = Mottled Dz Dark 2 Straw E : Even B: Bright F : Fine ~: G~chemical Sam. la SP = Spar,r ~ Dare Straw 5 : Streaked D Dull M = Medium BiostrotiQrophic Sample BO ~ee~ng Oil CUT .SPEEDJColor Co~ Ligh~ Amber SP: Spo~y P: Pale C : Coarse P= Preserv.~ Sample BG .,..a,ng Gas ~': 51,'~ m, 5 Amber M Mottled Special Anelysis ~lt~ 'ng ' 6 Very DarEBro. n PP: Permanently Preserved FST= FaSt streaming 7 Dar~ Brown Orange [ =' I~'~tentaneous ODOR N : None FT : Faint F : Fair Color Y : Yellow W: White/Blu, G = Gold GR= Green WELL NAME: ~' APl NO.: SERVICE CO.: DESCRIBED BY: LAB ANALYSIS: STANDARD OIL PRODUCTION CO. SIDEWALL CORE ,DESCRIPTION DATE RUN NO.: LOG RUN W/GUN CORRELATION LOG TY~PE- C-.-~ SAMPLE CUTS // DRY GUN NO.' CHARGE ECOVERY GRAIN SIZE SAMPLE LOCATION ~= Lost Bullet M =Mud TS= Thin.,ection B: Broken Bullet S : Silt XR X-ray Diffraction B: Empty Bullet VF = Very Fine * = SEM ~F Misfire F = Fine CC= Geochemical Sample ONDITIONS/SIZE M = Medium B Biostrati~iraphic Sample '(-~T~es) ' ' C = Coarse P Preserved' Sample Special Analysis Intact ODOR PP Permanently Preserved ~ro[en N = None "~tered FT = Faint F : Fair OIL STAIN [piltr,} OIL STAIN (Color) ' .CUT (Color) FLUORESCENCE N = '~l.o~.e L = Light 0 Clear Distr. Intensity E ,.,,.,, M': /~idium 1 Pale Straw M = Mottled D= Dark 2 Straw E = Even B = Bright SP = Spotty 43 Dark Straw S = Streaked D Dull BO Bleeding Oil CUT SPEED(Color Col,) Light Amber SP = Spotty P = Pale BG Bl..ding Gas ,~L='SI~w 5 Amber M Mottl.d ST': streaming 6 Very Dark Brown FST= 'Fast streaming 7 Dark Brown Orange ! :' In'$tantoneous Color Y = Yellow W = White/Blue G = Gold GR: Green STAIN FLUORESCENCE CU1~ CUT FLU COND L ITHOLOGY ISAMPLE POROSITY '~lST~.//~ [~.JANT.....~'''~ ,NTE~.......~ NO. DEPTH R~. (SIZE) LIST-TYPE, COLOR, HARDNESS, GRAIN SIZE, ANGULARITY, LOC. ODOR SalTING AND ACCESSO"IES. ~ ~OLOR DIST. INT. COLOR ~OLOR /. COLC _ ~ ~, ~. . ~*S J ~ , , , ............................................... ,,: l ~. .... i · , , l. , ....... ......... II u ........ GUN TYPE: BULLET TYPE: ~LI · WET '~-:- WELL NAME: 'v ~'¥".~ """:~' ...... &APl NO.: ~:..~^,~:! :,:,~ SERVICE CO.: DESCRIBED BY: STANDARD OIL PRODUCTION' CO. ... SIDEWALL CORE,:, DESCRIPTION DATE : ~ou, "J) ~q~'~P RUN NO.: ~ LAB ANALYSIS: GUN TYPE: GUN NO.' BULLET TYPE :.:i"~;" ~'"' CHARGE ' LOG RUN W/GUN ~- ~'~-'~ CORRELATION LOG TYPE: C-'t~- ~'< SAMPLE CUTS ~"~' DRY WET SAMPLE LOCATION TX~= Thin- section , X-roy Diffraction SEM GCB~ Geochemical Sample Biostratiaraphic Sample P ~- Preservec/ Sample Special Analysis PP -- Permanently Preserved OIL STAIN (Distr.) OIL STAIN (Color) .CUT (Color) FLUORESCENCE N : ~JvO:~e L= I. igl).t (~ Clear Distr. Intensity E M= Medi:um Pale Straw M = Mottled Dz Dark 2 Straw E = Even B = Bright SP = Spotty 43 'Dark Straw S = Streaked D Dull BO = ~B!eec~mg Oil CUT .S~EED (Color CoL) Light Amber SP = S~otty P: Pale BG ~,.eaing Gas ,~L= ~IeW 5 Amber M Mottl.d ST =Stteeming 6 Very Dark Brown FST= Felt streaming 7 Dark Brown Orange ! :' I~Itantaneous Color Y "Yellow W = White/Blue G : Gold GR: Green ECOVERY GRAIN SIZE B= Lost Bullet M = Mud B= Broken Bullet S = Silt B = Empty Bullet VF : Very Fine iF Misfire F Fine M = Medium ONDITIONS/SIZE C = Coarse (inches) Intact ODOR Rroken N : None ntlered FT = Faint F : Fair ,,,. ,,,. STAIN FLUORESCENCE CUT CUT FLU ~ , CONI~ L ITHOLOGY S,~/I, PLE POROSITY ODOR DISTR././"' QgANT,~/ NO. DEPTH REC. :(SIZE) LIST-TYPE, COLOR, HARDNESS, GRAIN SIZE, ANGULARITY, LOC. SORTING AND ACCESSORIES , ~ . ,~"IZOLOR DIST. INT. COLOR ,,~.~OLOl~ ..' /oq;:.:,....' Lo t - ........ -- ~ ", .... / .... ,, .... . ........ ,,,,,, ~..., ,.,,., , ., 1-41/0-23 January 29, 1988 SPINNER 1-35/0-25 Run 1 February 8, 1988 * PRODUCTION PROFILE 2-34/P-14 Run 1 February 9, 1988 * FLOWMETER/TEMPERATURE 1-27/P-20 Run 1 February 3, 1988 ~ * PRODUCTION PROFILE 2-62/Q-17 Run 1 January 31, 1988 ~* CONTINUOUS FLOW SURVEY ,~,* DIFFERENTIAL TEMPERATURE * PRODUCTION PROFILE (2-5-88) 2-52/S-14 Run 1 February 4, 1988 * PRODUCTION PROFILE Received by Laura Fuj ik. awa-~ Da t e r ...... ,~ae~ Standard Ala~a Production Coml:mny 900 East Benson Boul~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 25, 1988 STANDARD ALASKA PRODUCTION John Boyle A~ 3001 Porcupine Drive Anchorage, AK 99501 Mr Boyle: Enclosed are sidewall core descriptions from wells M-33.1, P-14, Q-21, . Q-35, and R-25. Please advise me if you will need any further information on these wells. Sincerely, G GC~han GG:CZ:gh Anchorage A unit of the original Standard C~I Company Founded in Cle,,eland Ohio in 1870. Standard Alaska ._ Production Com[ 900 East Benson ~ ,.,,. d P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 OCT 13, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: P-14 Run 2 September 29, 1987 * HP Log Sincerely, ...-q ,,x).M../-' - ~,,~ ~ '/ .l-" / '.~ ,/x. ' ~ [ ;' //~--~BrU~e St. Pierre Received by~.~ Date A unit of the original Standard C~I Company Founded in Cleveland Ohio in 1870 Standard Alask ~- ' Production Corn, 900 East Benson Bau. .,rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907i 561-5111 SEP 25, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: P-14 Run 1 August 30, 1987 * Temperature Log ~/~~ 0il & Gas Cons, C0mm_J~J0l~ Anchorage Sincerely, Bruce St. Pierre A unit of the or,g~r'ol Stondord Oil Compony Founded in Cie~eJor~d Ohio m 1870. Standard Alaska ~' Production Comp 900 East Benson L d P.O. Box 196612 Anchorage, Alaska 99,519-6612 (907) 561-5111 JUL 28, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: P-14 Run 2 July !0, 1987 * GR Positioning Log Received Date Sincerely, Bruce St. Pierre A unit of the or,glr, oi Standard Oil Compopy Fou,~ded in Cle, e!ond Ohio in 1870. STATE OF ALASKA ALA ....,,-, OIL AND GAS CONSERVATION COl, ...... SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~ Pull tubing Alter Casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of wellatsurface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E Attop of productiveinterval 222' SNL, 3716' WEL, Sec. 36, T12N, R16E Ateffective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E Attotaldepth 24' SNL, 3838' WEL, Sec. 36, T12N, R16E 5. Datum elevation (DF or KB) KBE = ..56 Feet 6. Unit or Property name Duck Island Unit/Endicot 7. Well number 2-34/P-14 HPI 8. Approvalnumber ?-368 9. APInumber 50-- 029-21662 10. Pool Endicott 0il Pool 11. Present well condition summary Total depth: measured true vertical 11242 ' feet 10587 ' BKB feet Plugs (measured) Effective depth: measured 11160 ' feet true vertical 10477 ' BKB feet Junk (measured) Casing Length Structural Conductor 111 ' Surface 2482' Intermediate 10110' Production Liner 1413 ' Perforation depth: measured Size 30" 13-3/8" 9-5/8" 10634' - 10724' true vertical 9971' - 10054' Tubing (size, grade and measured depth) Cemented Measured depth Driven 2542 cu.ft. Permafrost 575 cu.ft. Class G w/.12% HR, 0.75% CFR-2 111' 2482' 10110' ~ue Verticaldepth 111' 2482' 9555' 7" 447 c.f. Class G 9827'-11240' w~15% LWL & .05% Halad 344 10732' - 10760' 10795' - 10840' 10061' - 10087' 10119' - 10160' 4-1/2" 12.6#/ft L-80 BTRS Non-IPC @ 9757'. Packers and SSSV(type and measured depth) Q-K/R" UR-RP9 P~c~e~ @ 9773'' 7" TTW H_~-_~P P=_cker @ !07§~_'' ~c~7 a ~ng, 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RE-£EIVE ) Representative Daily Average Production or Injectior:A~l~3 0ii & 13. 9330' -10584 Oil-Bbl Gas-Mcf Water-Bbl An ch_,_0 r. age Casing Pressure ~uD~ng Pressure Prior to well operation Subsequent to operation Not on production 14. Attachments Initial Perforatin§ Summary Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15.1hereby certify that the foregoing is true and correct to the best of my knowledge ~;~)~ ~-~)J '~7 ~. Si~ned ~orm 10-404 Rev. 12-1-85 3LI-{/1949D Title Division Drilling Engineer Submit infDuplicate ~ ENDICOTT WELL 2-34/P-14 MPI INITIAL PERFORATING SUMMARY The following intervals for initial oil production were perforated July 9, 1987 using Schlumberger 5" tubing conveyed perforating guns at 5 s.p.f. 10634' - 10724' MD (Ref. DIL/SFL 11/7/86) 10732' - 10760' MD (Ref. DI1/SFL 11/7/86) 10795' - 10840' MD (Ref. DIL/SFL 11/7/86) A tubing and packer completion followed immediately thereafter. A lubricator was installed and tested to 3500 psi and a SSSV was set and tested in the ball valve nipple at 1602' on July 13, 1987 after the well was completed. Anchorage ~H/kb/195 0D STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COM,. _.SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ,.%' Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension Q Change approved program ~ Plugging [] Stimulate ..~ Pull tubing ~ Amend order [] Perforate~' Other?C,. 2. Name of Operator Standard Alaska Produc.~_{nn Comr)~nv 3. Address P. O. Box 196612, Anchoraqe, Alaska 4. Location of well at surface 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E At top of productive interval 222' SNL, 3716' WEL, Sec. 36, T12N, R16E At effective depth 50' SNL, 3823' WEL, Sec. 36, T12N, R16E t total depth A24' SNL, 3838' WEL, Sec. 36, T12N, R16E fee I(.~ 99519-6612 5. Datum elevation (DF or KB) 6. Unit or Property name Duck Island Unit/Endicott 7. Well number 2-34/P-14 MPI 8. Permit number 86-172 9. APl number 50_029-21662 11. Present well condition summary Total depth: measured true vertical 11242' feet 10587' BKB feet Plugs (measured) Effective depth: measured 11160' feet true vertical 10477' BKB feet Junk (measured) Casing Length Size Structural Conductor 111' 30" Surface 2482 ' 13-3/8" 10110 ' 9-5/8" Intermediate Production Liner 1413 ' 7" Perforation depth: measured true vertical Cemented 10. Pool Ez~dicott Oil Pool Measured depth 111' 2482' 10110' Driven 2542 cu.ft. Permafrost 575 c.f. Class G w/.12% HR, 0.75% CFR-2 ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 447 c.f. Class G 9827'-11240' w/.15% LWL & .05% Halad 344 ~ue Verticaldepth BKB 111' 2482' 9555' 9330'-10584' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June 15, 1987 that the foregoing is true and correct to the best of my knowledge Title Division Drillinq Enqineer Commission Use Only 14. If proposal was verbally approved f!1 Name of approver Date approved 1~. I_g¢;eby certify Notify commission so representative may witness Approval No. [] Plug integrity [] BOP Test [] Location clearance Conditions of approva Approved by by order of the commission Date .Submit in triplicate Form 10-403 Rev 12-1-85 Endicott Well 2-34/P-14 MPI Initial Perforation Proposal We propose to perforate the following intervals for initial oil production using drillpipe conveyed perforating guns at 4 s.p.f, in June. 1987. 10690' - 10710' 10732' - 10760' 10790' - 10820' (Ref. DIL/SFL 11/7/86) (Ref. DIL/SFL 11/7/86) (Ref. DIL/SFL 11/7/86) After perforating, the guns will be removed and the well will be shut-in. We will then run a tubing and packer completion. A lubricator will be installed and tested to 3500 psi and a SSSV will be set and tested in the ball valve nipple after the well is put on production. ,~, 785D cx,o~ple$ puck- Standard AIc~ska Production Company 900 Eost Benson Boule¥ord P.©. Box 196612 Anchoroge, AIo~ko 99§19-6612 (907) 561-5111 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells Dear Mr. Smith, April 3, STANDARD We are requesting that the AOGCC adopt dual designation for all future well names in the Duck Island/Endicott Unit for operational and safety reasons. Dual designation lists the numeric surface location followed by an alpha-numeric bottom hole location. This will be indicated in future wells on Form 10-401 in Item Number 8. We also ask that wells drilled to date be referenced by this dual designation. For your use is a llst of wells drilled to date. WELL NA~4E PERMIT NUMBER API NUMBER 1-5/0-20 (MPI) 1-27/P-20 (MPI) 1-29/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 ($DI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/L-36 ($DI) 3-47/Q-35 (SDI) 4-8/P-27 (SDI) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) . ~ounded in CleYelond, OMo, in 1870. 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 We thank you for your assistance and should you have any questions, give me a call at 564-5007. Yours very truly, R. S. Allan. Division Drilling Engineer RSA/MAW/pm/1664D cc: R H. Reiley_ B L. J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development Standard Alaska Production Company 900 Eo$! Benson Boulevo,o P-O. BoA 196612 Anchoroge. AIo.,ko 99,519.66 (907) ,564-511 I INDEXED DALLAS ARCO CHE ON STANDARD EXXON TEXACO Date: 01/06/87 ?o: MOUIL TI: 77644 PHILLIPS STATE OF ALASKA GEOSCIENCES ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A.-16- Injection Profile/Flowmeter/Temp A-23 Temp. 10/24/86 #1 A-23 BoreholeAudio Tracer 10/24/86 A-23 Borehole Audio Tracer 11/06/86 A-23 DFT 11/06/86 #1 B-9 Borehol~ Audio Tracer 11/16/86 D-17 CCL/Perf. 11/23/86 #1 D-18 CCL/Perf. 11/23/86 #1 D-26 Spinner 12/07/86 #1 D-27 CCL/Perf. 11/19/86 #1 D~28 CCL/Perf.. 11/20/86 #1-3 E-7 EPL 07/23/86 #1 E-9 CCL/Perf. 11/16/86 #1 E-9 Cont. Flow Survey 11/29/86 #1 E-9 Temp. 11/29/86 #1 G-3i CCL/Perf. 11/10/86 #1 ~-15 Collar 12/07/86 #1 H-20 CCL/Perf. 10/25/86 #1-2 M-17 Temp. 11/29/86 #1 M-22 CCL 10/30/86 #1 P-14 GR/Correlation 11/07/86 #1 T-1. Injection Profile 11/22-23/86 #1 U-3 Injecion Profile 11/29-30/86 #1 11/26-27/86 #1 9900-11182 Camco 2700-10100 GO 2"/5"/1" #1 1000-10600 GO 2" #1 500-10600 GO 1" 3950-10600 GO 5" #1 1900-3200 GO 5" 8850-10346 GO 5" 10700-11260 GO 5" 10500-10870 Camco 5" 8650-9690 GO 5" 9500-11110 GO 5" 8350-9457 Sch 5" 10600-10980 GO 5" 10500-10905 GO 5" 10500-10905 GO 5" 6980-9228 GO 5" 0-2500 CAMCO 5" 9050-10200 GO 5" 11000-11758 GO 5" 9500-10550 GO 5" 10790-11000 GO 5" 10400-10923 CAMCO 5" 9000-9530 CAMCO 5" Victoria Aidridge ~NFOR~I~ON CONYROL We~ Records tR2-~ 11 Standard Alaska ~'- Pr~duction C~mFm 900 East Benson Bc, .,rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 19, 1986 STANDARD ALASKA PROi UCTION William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: P-14 Run 1 November 12,1986 ~ CBT Si/~cerely,_~ ,- , Laura Fuj ikaw~ A unit of the odginol Standard O~1 Company Founded in Cleveland, Ohio. in 1870. Standard Ala~ Production Con 900 East Benson Boullevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-51 ! 1 November 14, 1986 S'TANDARD. ALASKA PRODUCTION William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: P-14 Run 1 November 7,1986 ~'* DLL/MSFL '"~* ARRAY SONIC ~.~.~, NGT/SPEC MEST-RAW DATA ~ CNL/LDT 1 Magnetic tape and listing for: Run 1 ~'~~'* DLL/LDT/CNL/NGT/SDT/GR Laura Fuj A unit of the original Standard Oil Company Founded in Cleveland. Ohio, in 1870. Completion Deferred until mid-1987 - STATE OF ALASKA P-14 MPI ALASKA - AND GAS CONSERVATION C( MISSION Row 2, Slot 34 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 86-172 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21662 4. Location of well at surface ......... 9. Unit or Lease Name 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 222' SNL, 3716' WEL, Sec. 36, T12N, R16E ~Surf'-'"---~-t P-14 MPI At Total Depth ~iB. H. ----~ 11. Field and Pool 24?' SNL, 3838' WEL, Sec. 36, T12N, R16E 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Endicott Field 56' = KBEI ADL 24633 Endicott Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10-18-86 11-8-86 11-10-86 I / feet M L deferred until , N_A S ~ . 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thicken'ss Ot'l-'-efmafrost 11242' MD 10587' T~TD 11160'MD 10477' YES [] NO [] 22. Type Electric or Other.,Logs Run TVD DLL/MS~L, Array ~'onic, NGT,~_EC, MEST RAW DATA, CNL/LDT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Stru¢'.tural Dr:_ve Pipe Surface IDrive 13-3/8" 72# L-80 Surface 2482' 17-1/2" 12542 cu. ft. Permafr(~st 9-5/8" 47~ NTBOS Surface 5366' 12-1/4" 9-5/8" 47# NT95HS 5366" 10111' 12/1-4" 575 cu. ft. Class G 0 12%HR,0.75% SFR-2 7" 29~ . L-80 9827' 11240' 8-1/2" 1447 cu.ft. Class G .].5%LWL & .05% Hale 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD 344 interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9-5/8" x 13-3/8" Annulus downsqueeze with 345 ex. Permafrost followed by 115 bbl dry crude. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ 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. . !,. · · , ,,.,, ~i! ,'. :.': :' "' Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. Top HRZ LCU NAME Top Kekiktuk GEOLOGIC MARKERS MEAS. DEPTH 9832' 10132' 10291' TRUE VERT_ DEPTH 9257' 9518' 9660' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division Drilling Signed [~' (~' Title Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple 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 Rig: Doyon #15 Well: P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT October 17, 1986 at 0600 hours AFE # 71 7519 0600 Depth: ' Day: -1 24-Hour Ftg' ' Current Operation: Rig repair. Move rig to P-14. Rig repairs. MUD TYPE- WT.' VIS: PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H' SAPC Daily Drilling Report -- ENDICOTT October 18, 1986 at 0600 hours Rig' Doyon #15 Well- P-14 (2-34) AFE # 71 7519 API 50-029-21662 0600 Depth' 670' Day' -2 24-Hour Fto' 670' Current F)peration- Drilling. Accepted rig at 1200 hrs. on 10-17-86. spud well at O001 hrs. on 10-18-86. Drill and survey 17-1/2" hole to 670 ft. MUD TYPE-Spud Mud WT'8.7 VIS'300 PV' YP- FL' SOLIDS' TEMP'38 OF SURVEY MD ANGLE DIRECTION TVD SECTION COF)RD I NATES DLS 131 2H · Rig: Doyon #15 Well: P-14 {2-34) SAPC Daily Drilling Report -- EI!DICOTT October 19, 1985 at 0600 hours AFE # 71 7519 API 50-029-21662 0600 Depth: 3500' Day: 1 24-Hour Ftm: 1830' Current Operation: Run 13-3/8" casing. P, rilI and survey 17-1/2" Hole to 1503 ft. Trip bit. Drill to 2500 ft. POH. Run 13-3/8" casing. MUD TYPE-Spud Mud WT:9.9 VIS:185 PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COP, RD I ~ATF_S DLS 1312H' Rig- Doyon #15 Well- P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT October 20, 1986 at 0600 hours AFE # 717519 API 50-0~9-21662 0600 Depth' 2500' Day' ~ 24-Hour Ftg' ' Current Operation' Test F~OP's. Run 13-3/8" casing - shoe at 2483 ft. Mix and pump cement. N/U BOPE. Test BOPE. MUD TYPE-Gel Benex WT'9.2 VIS'44 PV'7 YP-IO FL'4 SOLIDS' TEMP' SURVEY MD ANGLE DIRECTIOH TVD SECTION COORDINATES DLS 1312H. SAPC Daily Drilling Report -- ENDICOTT October 21, 1986 at 0600 hours Rig: Doyon #15 Well: P-14 ~2-34) AFE # 717519 API 50-029-21 662 0600 Depth: 4260' Day: 3 24-Hour Ftg: 1760' Current Operation: Drilling. RIH. Tag cement at 2440 ft. Test casing to 3000 psi. Drill float equip and l0 ft. new hole. Conduct F.I.T. EMW = ll~9 ppg. Drill 12-1/4" hole to 4195 ft. Trip bit. Drill 12-1/4" hole to ~260 ft. MUD TYPE-Seawater/Ligno WT:9.4 VIS:40 PV:IO YP:4 FL:22 SOLIDS:5 TEMP:58 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H: Rig: Doyon #15 Well: P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT October 22, 1986 at 0600 hours AFE # 717519 API 50-029-21662 0600 Depth: 551 9' Day: 4 24-Hour Ftg: 1259' Current Operation: Drilling. Drill 12-1/4" hole to 5450 ft. POH. surveys every 500 ft. from 2.600 ft. 551 9 ft. P/U Dynadrill. R]H taking Dynadrill 12-1/4" hole to MUD TYPE-Sea Ligno WT:9.6 VIS:37 PV:IO YP:7 FL:18.5 SOLIDS:6 TEMP:62 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H: SAPC Daily Drilling Report -- E~-!DICOTT October 23, 1986 at 0600 hours Rig: Doyon #15 Well: P-14 (2-34) API AFE # 717519 50-029-21662 Current Operation: Tripping. Dynadri 11 new BHA. 0600 Depth: 6268' Day: 5 24-Hour Ftg: 749' 12-1/4" hole to 6268 ft. POH. L/D Dynadril 1. N/U MUD TYPE-Sea Ligno WT:9,5 VIS:37 PV:IO YP:7 FL:8 SOLIDS:7 TEHP :85 °F SURVEY MD A[~GLE DIRECTION TVD SECTION COORDINATES DLS 5454 2.2 t,149E 5735 7.9 N31W 6018 12.5 N37W 6209 1 5.4 !~.48W 5451 5731 6010 61 95 1 5.95 N66 E108 O. 3 3.94 k!88 E1 06 3.0 45.98 N131 E7895 1.8 92.67 N166 E4718 1 ]9 1312H' SAPC Daily Drilling Report-- ENDICOTT October 24. 1986 at 0600 hours Rig: Doyon #15 Well: P-14 (2-34) AFE # 717519 API 50-029-21662 0600 Depth: 6968' Day: 6 24-Hour Ftg: 700' Current Operation: Drilling. RIH. Ream to bottom. Dynadrill to 6766 ft. POH for BHA change. RIH. Drill 12-1/4" hole to 6968 ft. MUD TYPE-Sea Ligno WT:9.6 VIS:38 PV:IO YP:8 FL:6 SOLIDS:8 TEMP:85 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 6329 18.1 NS1W 6309 127 N188 ~- 20~89 2~4 6426 21.4 N48W 6401 159 ~O 209 W 4, 04 3.7 6522 23.9 N47W 6490 196 I~ 234 N 31,30 25 6 6614 26.4 N45W 6573 235 aJ 261 W 59543 2~9 1312H: SAPC Daily Drilling Report -- ENDICOTT October 25, 1986 at 0600 hours Rig: Doyon #15 Well: P-14 /2-34) AFE # 717519 API 50-029-21662 0600 Depth: 7536' Day: 7 24-Hour Ftg' 568' Current Operation: Drilling. Drill and survey 12-1/4" hole to 7394 ft. Trip bit. Drill and survey to 7536 ft. MUD TYPE-Sea Ligno WT:9~7 VIS:39 PV:8 YP:7 FL:5.5 SOLIDS:8 TEMP:88 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 6896 30.9 N44W 681 9 372 hJ 363 ~ 152 1 ~ 4 7086 31.4 N40W 6982 471 I~ 436 ~ 218 1 ~ 1 7181 31.5 N42W 7063 521 ~/ 474 v~ 250 1 ~2 7284 31 . 5 N43W 71 51 574 I~/514 W 286 O. 5 1312H: Rig: Doyon #15 Well: P-14 12-34) SAPC Daily Drilling Report -- ENDICOTT October 26, 1986 at 0600 hours AF£ # 717519 API 50-029-21662 0600 Depth: 8300' Day: 8 24-Hour Ftg: 764' Current Operation: Drilling. Drill and survey 12-1/4" hole to 8300 ft. MUD TYPE-Sea Ligno WT:9.8 VIS:39 PV:8 YP:7 FL:5.5 SOLIDS:8 TEMP:88 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 7459 31.4 N43W 7300 666 tV580 vd349 7648 32.3 N42W 7460 765 ~ 654 W416 7842 32.6 N43W 7624 869 ~ 731 v~487 8034 32.8 N43W 7786 973 ~ 806 v~557 1312H: DLS OL1 0~6 0~2 Oil Rig: Doyon #15 Well: P-14 /2-34) SAPC Daily Drilling Report -- ENDICOTT October 27, 1986 at 0600 ~ours AFE # 71 7519 API .q0-029-21662 0600 Depth: 8760' Day: 9 24-Hour Ftg: 460' Current Operation: Tripping. Drill and survey 12-1/~" hole to 8760 ft. MUD TYPE-Sea Ligno WT:9.8 VIS:39 PV:9 YP:7 FL:5.5 POH. Test BOPs, RIH~ SOLIDS:9 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION 8223 32.5 N42W 7945 1075 8411 31.9 N41W 8104 1175 8592 31 . 5 N45W 8258 1P_71 COORDI NATES 882 957 1026 626 692 757 1312H: DLS Oj2 Oj4 Oj9 J _ _ Rig: Doyon #15 Well: P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT ~lctober 28, 1986 at 0600 hours AF£ # 717519 API 50-029-21662 0600 Depth: 8925' Day: 10 24-Hour Ftg: 165' Current Operation: ~rilling. RIH. Drill and survey 12-1/4" hole to 8925 ft. MUD TYPE-Sea Ligno WT:9.8 VIS:38 PV:9 YP:8 FL:5.5 SOLIDS:9 TEMP:89 °F SURVEY MD ANGLE DIRECTION TVD SECTION 8781 31.5 N45W 8419 1369 COORDINATES ~1096 ~8~7 1312H.' DLS 0.0 SAPC Daily Drilling Report -- E~DIC~TT October 29, 1986 at 0600 hours Rig: Do.yon #15 Well: P-14 AFE # 71 7519 API 50- or~ 0L.-21662 0600 Depth: 9~°36' Day: 11 24-Hour Ftg' 311' Current Operation: Drillin9. Drill and survey 12-1/4" hole to 9236 ft. MUD TYPE-Sea Ligno WT:9.8 VIS:39 PV:IO YP:8 FL:5.5 SOLIDS:9 TEMP:90 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 38 8968 31 . 6. N43t! 8579 1467 ~/1166 W/895 O. 2 1312H: Rig: Doyon #15 Well' P-14 /2-34) SAPC Daily Drilling Report -- ENDICOTT October 30, 1986 at 0600 hours AFE # 717519 API 50-029-21662 0600 Depth: 9431' Day: 12 24-Hour Ftg: 195' Current Operation: RIH. Drill and survey 12-1/4" hole to 9431 ft. Trip bit. MUD TYPE-SW Ligno WT:IO.O VIS:40 PV:13 YP:9 FL:5.8 SOLIDS:9 TEMP:88 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 39 9162 32.5 N41W 8743 1570 N1242 w964 40 9347 32.7 N40W 8899 1770 fq 1318 v~/1028 1312H: DLS 0.6 0.2 Rig' Doyon #15 Well- P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT October 31, 1986 at 0600 Ilours API AFE # 71 7519 50-029-21662 0600 Depth- 9814' Day: 1 3 24-Hour Ftg' 383' Current Operation' Drilling. Ream from 9144 to 9431'. Drilling. MUD TYPE-SW Ligno WT'IO.O VIS'38 PV-16 YP'8 Repair pumps. Drilling. FL '5.6 SOLIDS:lO TEMP'96 OF SURVEY MD ANGLE DIRECTIOn! TVD 41 9545 32.3 N41W 9065 42 9731 30.8 N36W 9224 SECTIO~~ COORDINATES 1776 N1399 W1097 1873 N1475 Wl158 1312H' DLS 0.3 1.2 Rig: Doyon #15 Well: P-14 (2-34) SAPC Daily Drilling Report -- ENDICOTT November l, 1986 at 0600 hours AFE # 717519 API 50-029-21662 0600 Depth: 10126' Day: 14 24-Hour Ftg: 312' Current Operation: Rig up to run 9-5/8" casing. Drill and survey 12-1/4" hole to 10126 ft. POH. Rig up to run 9-5/8" casing. MUD TYPE-SW Ligno WT:IO.2 VIS:42 PV:17 YP:ll FL:5.8 Short trip. CF~U. SOLIDS:Il TEMP:IO0 °F SURVEY MD ANGLE DIRECTION TVD SECTION 43 9974 29.2 N32W 9434 1994 44 10050 28.8 N35W 9501 2033 COORDINATES DLS N 1576 IA/1226 1.4 ~1607 ~ 1246 2.4 1312H: SAPC Daily Drilling Report -- ENDICOTT ~ovember 2, 1986 at 0600 hours Rig- Doyon #15 Well-P-14 (2-34) AFE # 71 7519 API 50-029-21662 0600 Depth' 10126' Day' 1 5 24-Hour Ftc' O' Current Operation- L/D 12-1/4" BHA. Run 9-5/8" casing. Shoe at lOlll ft. Mix and pump cement. Install and test pack-off to 3000 psi. Install tubing spool and test BOPE. MUD TYPE-SW Ligno %,1T:9.7 VIS'40 PV-12 YP'8 FL'8.6 SOLIDS'8 TEMP' SURVEY MD ANGLE D IRF. CTIO~.! TVD SECTION COORDINATES DLS 1312H' SAPC Daily Drilling Report -- ENDICOTT November 3, 1986 at 0600 hours Rig' Doyon #15 Well' P-14 {2-34) AFE # 717519 API 50-029-21662 0600 Depth' 10264' Day' 16 24-Hour Ftg' 138' Current Operation' Drilling. L/D 12-1/4" BHA. P/U 8-1/2" BHA and RIH. Pressure test casing to 3000 psi. Drill FC and 50 ft. cement.. Pressure test casing to 3000 psi. Drill shoe and lO ft. new hole. Perform LOT to 13.5 ppg. Drill 8-1/2" hole to 10264 ft. MUD TYPE-SW Ligno WT'9.7 VIS'38 PV'IO YP:8 FL-6.8 SOLIDS'8 TEMP'82 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H' - / , SAPC Daily Drilling Report -- ENDICOTT November 4, 1986 at 0600 hours Rig' Doyon #15 Well' P-14 /2-34~ AFE # 717519 API 50-029-?1662 0600 Depth' 10536' Day' 17 24-Hour Ftg' 272' Current Operation- Drilling. Drill 8-1/2" hole to 10536 ft. MUD TYPE-S.W. Lig WT'9.7 VIS'38 PV'13 YP'9 FL'6.4 SOLIDS'8 TEMP'96 OF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H' Rig: Doyon #15 Well: P-14 (2-34) SAPC Daily Drilling R. eport -- ENDICOTT November 5, 1986 at 0600 hours AFE # 717519 API 50-029-21662 0600 Depth: 10932' Day: 18 24-Hour Ftg: 396' Current Operation: Drilling. Drill 8-1/2" hole to 10,912 ft. Trip bit. Drill to 10,932 ft. MUD TYPE-SW Lig WT:9.7 VIS:38 PV:13 YP:8 FL:6.6 SOLIDS:8 TE~IP:96 °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H:~ SAPC Daily Drilling Report -- ENDICOTT November 6, 1986 at 0600 hours Rig' Doyon #15 Well' P-14 (2-34) AFE # 717519 API 50-029-2166_~ 0600 Depth' 11,242' Day: 19 24-Hour Ftg' 310' Current Operation' Logging. Drill 8-1/2" hole to 11,242 ft. Short trip. CBU. POH. Run open hole logs. MUD TYPE-Lig SW WT-9.7 VIS:38 PV-12 YP'7 FL'6.5 SOLIDS'8 TEMP' °F SLIRVEY MD ANGLE DIRECTION TVD SECTION COORDINATES ,,, 1312H' SAPC Oaily [~rilling Report -- E~$DICflTT November 7, 1986 at 0600 hours Rig' Doyon #15 Well' P-14 (2-34,) AFE # 71 7519 API 50-029-21662 0600 Depth' 11,242' Day' 20 24-Hour Ftg: ' Current Operation' Snort trip. Run open hole logs. RIH for wiper trip. Ream through tight spots to bottom. CBU. Short trip. MUD TYPE-SW Ligno WT'9.7 VIS'38 PV-12 YP-9 FL'5 SOLIDS'9 TEMP' SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H' Rig: Doyon #15 Well: P-14 12-34) SAPC Daily Drillin§ Report -- ENDICOTT November 8, 1986 at 0600 hours AFE # 717519 API 50-029-21662 0600 Depth: 11,242' Day' 21 24-Hour Ftg: ' Current Opera ti on.' Run liner. CBU. POH. Run sidewall cores. Clean out trip. Run 7" liner. MUD TYPE-SW Ligno WT:9.7 VIS:39 PV:12 YP:9 FL:5 SOLIDS:9 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1312H: DLS SAPC Daily Drilling Report -- ENDICOTT November 9, 1986 at 0600 hours Rig: Doyon #15 Well: P-14 (2-34) AFE # 717519 API 50-029-21662 0600 Depth: 11,242' Day: 22 24-Hour Ftg: ' Current Operation: RIH. Run liner shoe at 11,242 ft. Mix and pump cement. PON tools. RIH and tag cement at 9358 ft. Drill cement to top of liner. POH. P/U 6" bit and BHA. MUD TYPE-SW Ligno WT:9.7 VIS:36 PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1312H: SAPC Daily Drilling Report -- ENDICOTT November 10, 1986 at 0600 hours Rig: Doyon #15 Well: P-14 (2-34) AFE # 717519 API 50-029-21662 0600 Depth: 11,242' Day: 23 24-Hour Fta: ' Current Operation: ~-.~/U tree. RIH. Drill cement to 9827 ft. Test liner lap to 3000 psi. RIH. Tag cement at 11,057 ft. Drill cement, landing collar and cement. Displace well to 9.6 ppg brine. Test liner to 3000 psi. POH. Install 1 joint tubing below hanger. N/D BOP's and install master valve. MUD TYPE-Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION Tvb SECTION COORDINATES DLS 1312H: SAPC Daily Drilling Report -- ENDICOTT November l l, 1986 at 0600 hours Rig' Doyon #15 Well' P-14 (2-34) AF£ # 717519 API 50-029-21662 0600 Depth ll,2 o, Day' 24 24-Hour Ftg' ' Current Operation' Clean mud pits. Clean pits. Released rig at 0900 hrs. on 11/10/86. MUD TYPE- NaC1 WT'9.6 VIS: PV- YP- FL' SOLIDS: TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDInaTES DLS · , , 1312H' GREAT LAND DIRECTIONAl. DRILLING INC. REF'ORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMF'ANY C O f'~ P A i'-! Y P-PAD WEL. t. NO. 14 ENDICOTT .................................................................................................. J..:., .;,' ........................................................................ AL1088DJ7 MWO ~ SINGLE SHOT 11-0J-86 .............................................................................................................................................................................................. J 0 E', N U M ~, E'. F?. T Y f:' E ~:; U F~'. V E Y D ' BRIAN WEST DIRECTIONAL SUPERUISOR I-!~, i .... 'l' I'" ~ ..... . .... 570 FT 1012~ FT [) E F' "f' H t N "~' E R V A L. F' R 0 10--21-86 11-01-86 t~ A T E S U R U E Y '1' A ~-., Iz. N I:: R 0 THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FIL. ES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRI'CTEST CONFIDENCE. GREAT LAND DIRECTIONAL_ DR (:;1lent .............. : STANDARD AL_AoKA PRODUCTION COMPANY Well - P-14 Closure Direction...- N 39.11 W Mctgnettc Decl~n~tfon- 31 deg 30 rain E Data file name - B-P14.DAT RECORD OF SURVEY IWell assumed vertical to Computation - Survey date- Me t hod - FtKB Height.- 507.0 } RADIUS OF CURVATURE 11-3-86 MWD & SS B6.0 ft MEAS DR I Fl' TRUVER'[ SUBSFA SECI' I ON D I RECT I ON DEP'FH DG MN DEPTH DEPTH DIST ANGLE 507 0 30 506.99 ~G0.~9 --2.20 S 44.30 E ~3 0 15 ~92.98 936.~8 --2.6~ N S8.00 W 1500 0 35 1499.97 1443.97 0.14 N 40.70 E ~050 0 30 ~0S9.94 ~003.94 -1.B8 S 85.60 E 2480 0 30 2479.93 2423.93 -4.09 S 71.10 E FtEL. AT I VE COORDINAI'ES FROM WEt_L--HEAD 1.58 S :t.55 E 3.28 S O. 18 E 0.07 S 0.31 W 1.93 N 4.40 E :1.22 N 7.98 F CLOSURE DISTANCE DG MN S 2.2:/ S 44 17 dO E 3.28 S 3 B 32 E 0.32 S 77 42 S W 4.80 N 66 21 12 E 8.07 N 81 19 13 IE DOG LEI de, ','10 0. 0.05 0 . 0.01! 0.00 3005 2 24 3004.74 2948.74 -9.84 N 47.00 E 3525 3 0 3524.16 3468.16 --8.39 N 48.00 E 4005 2 36 4003.S8 3947.58 -9.2d N 58.00 E 450[5 2 18 4503.12 4447.12 -11.90 N 58.00 E 5005 2 30 5002.69 4946.69 --14.68 N S9.00 E 3.86 N 20.35 E 20.41 N 38_41 E 34.S0 N 5'7.11 E 45.83 N 75.24 E 5~.77 N 93.09 E 20.71 N 79 15 47 E 43.49 N 62 1 5 E 66.72 N S8 51 52 E 88.10 N 58 39 17 E 109_03 N 58 37 30 E 0.36; 0.Ili 0. 081 0.06~ 0.04, 5400 2 24 5397.32 5341.32 --1d.03 N 52.00 E 5454 2 12 S4S1.28 S395.28 --16.02 N 47.00 E 5548 3 0 5545.18 5489_18 --14_52 N 11.00 E 5643 5 42 5639.90 5583_90 -8.76 N 17.00 W 5735 7 54 S731.25 5675.25 1.73 N 31.00 W 66.32 N :107.00 Ei 67.70 N :108.67 E 71.33 N 110.7d E! 78.45 N 110.39 E 88.38 N i05.97 E 125.89 N 58:12 23 E 128.03 N 58 4 35 E 131.74 N 57 13 10 E 135.43 N 54 35 57 E 137.99 N 50 10 20 E O. 02, 0 . 37, ~.85' o 40' t.... · S833 ? 42 S828.09 S772.09 16.51 N 28.00 W S924 11 6 5917.59 5861.59 32_76 N 34.00 W 6018 12 30 6009.60 5953.60 51.95 N 37.00 W 6114 14 24 d102.97 8046.97 74.28 N 43.00 W 6209 lB 24 6194.77 6138.77 98.S3 N 48.00 W 101.43 N 98.59 E l lS.S0 N .90.13 E 131. lB N 78.97 E 148.24 N 64.63 E ldS.3d N 47.21 E 141.45 N 44 11 iS E 146.51 N 37 S8 2 E 153.09 N 31 3 16 E 161.72 N 23 33 1S E 171.97 N 1S SS 60 E 1 _ 83! 1. SSi 1 2.01' 6329 18 6 6309.67 6253.67 132_54 N Si. O0 W 6426 21 24 6400.95 6344.95 164.77 N 48.00 W 6S22 23. 54 ~489.54 6433.S4 201.34 N 47.00 W 6614 26 24 6572.81 6516.81 240.15 N 45.00 W 6713 29 6 6660.42 6604.42 286.1S N 40.00 W 187.81N 20.92 E 209.10 N 4.00 W 234.07 N 31.26 W 261.23 N S9.38 W 295.20 N 90.S1 W 188.98 N 6 21 16 E 209.14 N 1 S 48 W 236.15 N 7 36 22 W 267.89 N 12 48 22 W 308.78 N 17 2 44 W 2.26: 3.42' 2_61' 2.7.5: 2.97' P- 14 11-3-86 MEAS DEPTH 7086 7181 7284 7648 7842 8034 8223 841'1 8592 8781 8968 9'162 9347 9545 9731 9974 10050 10126 DR I F'F T RUVERI' SUBSEA SEECT I ON DG MN DEP'r H DEPTH DIST 30 54 6818.87 6762.89 377.51 3~ 2~ 6981.50 6925.50 475.65 31 30 7062.54 7006.54 525.19 31 30 7150.36 7094.36 578.91 31 24 7299.66 7243.66 670.01 32 18 7440.20 7404.20 769.51 32 36 7623.91 7567.91 873.36 32 48 7785.~8 7729.48 976.85 32 30 7~44.61 7888.61 1078.64 31 54 8103.69 8047.69 1178.73 31 30 8257.69 8201.69 1273.60 31 30 8418.84 8362.84 1371.83 31 36 8578.20 8522.20 1469.32 32 30 8742.63 8686.63 1572.13 32 42 8898.48 8842.~8 1671.77 32 18 9065.~7 9009.47 1778.12 30 48 9223.97 9167.97 1875.41 29 12 9434.41 9378.41 1~96.39 28 ~8 9500.88 944~.88 2033.06 28 24 9567_6~ 9511.61 2069.32 RECORD OF SURVE:Y D I REC T I ON ANGLE N 44.00 W N z~0.00 W N 42. O0 W N 43. O0 W N 43_ 00 W RELATIVE COORDINATES FROM WELL-HEAD 363.18 N 151.72 W 436.20 N 217.47 W 473.61 N 249.99 W 513.29 N 286.34 W 580.07 N 348.62 W N 43.00 W 653.01N 416.63 W N 43.00 W 729.14 N 487.63 W N 43.00 W 805.00 N 558.37 W N 42.00 W 880.17 N 627.25 W N 41.00 W 955.20 N 693.63 W N 45. O0 W N 45.00 W N 43.00 W N 41.00 W N 40.00 W 1024.75 N 1094.58 N 114~. 96 N :1241.46 N 1317.25 N 758.49 W 828.31W 896.28 W 965.16 W ~029.89 W N 41.00 W N 36.00 W N 32.00 W N 35.00 W N 34.00 W 1398.14 N 1474.28 N 1574.99 N 1605.71 N 1635.69 N 1098.98 W 1159.55 W 1227.47 W 1247.81W 1268.41W CLOSURE DISTANCE DG MN S 393.60 N 22 40 22 W ~87.41 N 26 29 55 W 535.54 N 27 49 35 W 587.?6 N 29 9 20 W 676.76 N 31 0 20 W 774.60 N 32 32 20 W 877.16 N 33 46 24 W 979.69 N 34 44 46 W 1080.81 N 35 28 32 W 1180.48 N 35 59 9 W 1274.91 N 36 30 28 W 1372.66 N 37 6 59 W 1449.84 N 37 34 25 W 1572.50 N 37 51 47 W 1672.07 N 38 i 12 W 1778_36 N 38 10 6 W 1875.65 N 38 11 8 W 1996.82 N 37 SS 52 W 2033.55 N 37 51 4 W 2069.87 N 37 47 32 W DOG LE deg/lO 1.14 .62 58 .26 O.OS 0 O.1S 0.10 0.22 0.35 0.64 0.00 0.29 0.55 0.19 07 0.74 1.05 0.60 P - :14 1 1 -- 3 - 8 ~ DATA INTEEP, POLATED FOR EVEN 100 FEET OF SUBSEA DEPTH MEAS. O E P T H 356 4S6 TRU VERT SUB SE:A MD--'[VD VER'rlCAL lIE P-I' H DE P T H D I FF. CORRECT S6 0 0 0 :15 6 10 0 0 0 2[58 200 0 0 3S6 300 0 0 45 6 400 0 0 556 556 500 0 0 656 656 600 0 0 756 756 700 0 0 856 856 ilO0 0 0 956 956 900 0 0 1056 1156 1256 1356 1456 1556 1656 1756 1856 1.956 2056 °156 2256 2356 2456 25S6. 2656. 2756 2856 2956 10S6 1000 0 0 1156 1100 0 0 1256 :1200 0 0 13S6 1300 0 0 1456 :1400 0 0 1556 1500 0 0 :1656 1600 0 0 1756 1700 0 0 18S6 1800 0 0 1956 1900 0 0 2056 2000 0 0 2156 ~ °100 0 0 2256 2200 0 0 2356 2300 0 0 2456 2400 0 0 2556 2500 0 0 .2656 2600 0 0 2756 2700 0 0 2856 2800 0 0 2956 2900 0 0 RELATIVE COORDINATES FROM WELL-HEAD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I. 84 S 1.88 E 1.98 S 2.63 E 1.88 S 3.27 E 1.08 S 3.55 0.45 S 3.42 E 3.15 S 0.09 W 3.04 S 0.64 W 3.11 S 1.30 W 3.41 S 2.01 W 3 94 S o 67 W 0.38 N 0.04 E 1.23 N O.SS [--. 2.13 N 0.89 E 3.05 N 1.08 E 3.P7 N 1.10 E 4.85 N 0.97 E 1..90 N 5.23 E 1.93 N 6.11 E 2.02 N 6.97 E 2.16 N 7.84 E 1.01 N 8.80 E 0.85 N 10.46 E 1.00 N 12.73 E 1.65 N 15.53 E 2.95 N 18.71 E DATA · INTERF~()L-ATED FOR EVFN :tO0 FEET OF SUBSE:A DEPTt4 MEAS. DE P T H 3056 3156 32S7 335? 3557 3657 3757 3857 3957 ~057 4158 ~258 4358 4~,58 ~558 ~658 ~+758 4858 5058 5158 5259 535~ 5459 56SP 5760 5881 TRU VERT DEPTt4 3056 3156 3256 3356 3456 3556 3656 3756 3856 3956 4056 4156 4256 ~356 4556 4656 4756 4856 4956 5056 5156 S256 5356 5456 SSS6 5656. S756 S856 5956 SUB ,:~EA MD-TVD VER'r ICAL DEEPT H D I FF. CORRECT 3000 0 0 3100 0 0 3200 3300 1 0 3400 I 0 3500 1 0 3600 1 0 3700 i 0 3800 1 0 3900 1 0 ,qO00 :1 0 4'100 2 ~200 2 0 · ~l. 3 00 2 0 4z~O0 2 0 4500 h600 4700 z~800 4900 5000 5100 5200 5300 5400 SSO0 5~00 5700 5800 5900 2 2 2 3 3 3 3 3 S 7' ;. 0 0 0 0 ~ · 0 RELATIVE COORDINATES F:ROM WELL_-HEAD .. 5.34 N 21.9~, E 8.35 N 25.15 E lit.Sit N 28.4~ E 14.82 N 31.97 8.28 N 35.58 E: 21.53 N 39.64 E 25.06 N 43.34 E 28.63 N 46.80 E 32.22 N SO.O~ E 35.82 N 53.04 E 35.75 N 59.12 E 38.10 N 62.88 E 40.40 N 66.55 E 42.6q N 70.13 E 44.82 N 73.62 E 46_96 N 77.05 E 49_14 N 80.51 E 51.37 N 84_02 E 53.64 N 87.58 E 55.97 N 91.19 E 57.98 N 95.07 E 60.32 N 98.70 E 62.75 N 102.22 E 65.26 N 105.62 E ~7.83 N 108.81 E 71.92 N 110.86 E 80.03 N 109.87 E 91.40 N 104.13 E 105.70 N 96.22 E 121.88 N 85.73 E DATA :[N'FEIr~PC)LA'FE[D F-'OR EVEN 100 FEEl' OF SUBSEA DEP'rH MEAS. DEPTtt 6066 6:169 6273 6378 6595 6708 6823 6939 7056 'rRM VE=R'F DEPI'tt 6056 6156 6256 6356 64 S6 6556 6656 6756 6856 6956 SUB SEA MD-TVD DEP'Ftt DIFF. 6000 ~0 6100 13 6200 17 6300 22 6400 30 VERTICAL CORRECT 6500 39 9 6600 52 13 6700 67 ~5 6800 83 16 6900 200 17 7173 7056 7000 117 7292 7156 7100 235 7408 7256 7200 152 7moF 7356 7300 269 7643 7456 7400 187 7762 7556 7500 206 7880 7656 7600 224 7999 7756 7700 243 8128 7856 7800 262 8236 7956 7900 280 8355 8056 8000 299 8472 8156 8100 316 8590 8256 8200 334 8707 8356 8300 351 8825 8456 8400 369 8942 8556. 8500 386 9060 8656 8'600 404 9178 8756 8700 422 9297 8856 8800 442 9415 8956 8900 459 :17 18 17 17 i[8 19 18 19 19 18 RELATIVE COORDINATE~3 FROM WELL-HEAD 139.53 N 72.31E 158.18 N 54.88 E 177.05 N 33.85 E 197.70 N 8.37 E 224.07 N 20.82 W 254.83 N 54.15 W 290.79 N 91.50 W 336.27 N 126.47 W 379.10 N 167.34 W 421.00 N 210.94 W 470.63 N 247.3~1 515.81 N 288.70 560.56 N 330.42 605.46 N 372.29 651.08 N 414.83 697.48 N 458.11W 744.17 N 501.65 W 791.13 N 545.43 W 838.00 N 589.38 W 885.54 N 632.09 W 19 932_14 N 674.62 W ~7 979.42 N 715.19 W 18 1024.01N 757.75 W 17 1067.35 N 801.08 W 18 1110.63 N 844.S0 W 17 18 18 1153.21N 888.74 W 1200.07 N 929.57 W 1247.89 N 970.76 W 1295.83 N 1013.04 W 1345.35 N 1053.62 W P -- ~1 h ii. il - 3 - 86 DATA INTERPOLATED FOR EVEN 100 F:EET OF SUBSEA DEP'rH MEAS. OEP'rH ~883 I'RU VERT SUB SEA MD-TVD VERTICAL DE"- P T It DEP-F H D I FF. CORRECT ~'0S6 ~000 ~+78 9256 9300 hgS RELATIVE COORDINATES FROM WELL-HEAD 2393.63 N 2~39.5A N 2~89_q9 N 2535.S0 N 1S85.12 N 109S.OS 1136.82 1170.72 1206.20 1233.93 10113 ~5.56 9500 557 lz~ 1830.23 N 1265.2z+ W P- 141 ~l - 3 - 86 DA'FA IN'FERPOLATED FOR EVEN 1000 FEE'[' Of: MEASURED DEPTtt MEAS. TRU VERT SUB SEA DE P Ttt DE.'_., P Ttt DE P T H 1000 1000 9q4 2000 2000 :194q 3000 3000 2~44 4000 3999 39~3 5000 4998 ~942 6000 5992 5936 7000 6908 6852 8000 7757 7701 9000 8605 8549 10000 9457 9401 REt_A'rIVE COORDINATES FROM WELL-ItEAD 3.26 S 0.15 E 4.36 N 1.06 E 3.76 N 20.18 E 37.35 N 54.24 E 56.96 N 92.71 128. OS N 401.03 N 791.53 N 1177.21 N 1585.66 N 81.27 E 189.69 W S4S.81W 907.77 W 1234.28 W 750 1500 3000 3750 4500 5250 ,~EC ~.~ ON VERTICAL ~anke? I~ntiflcatlon N~ T~ DEPRT ~ TD i0126 9568 2069 6000 6750 7500 8250 gO00 9750 10500 12000 12750 13500 -750 750 ifioc, i'_':EO z:too 3750 4500 Jepa, ~ 8250 -'l ' ~ ~ DE~RT 2070 ft 3000 r 2riO0 : ~000 ~- ' - ~500 ..... ~50 ........ 7~0 ............ 1:50 SUB-SURFACE DIRECTIONAL SURVEY ~UIDANCE [~ONTINUOUS ~]OOL COmpany STANDARD ALASKA PRODUCTION COMPANY Well Name 2-34/P-14 MPI(1969' SNL,,~2256' WEL~SEC 367T12N,R16E) Field/Location ENDICOTT~ NORTH SLOPE~ ALASKA, Job Reference No. 72065 Loaaed Et,/: WARNER Date 12-NOV-86 Computed By: CUDNEY GOT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. METHODS OF COMPUTATION Z-3~/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA SURVEY DATE: 12-NOV-86 ENGINEER: WARNER TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 41 DEG 30 MIN WEST COMPUTATION DATE: 1T-NOV-86 PAG~ STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE ME~SUREO VERTICAL DEPTH DEPTH DATE' DF SURVEY: 12-NOV-86 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 399.99 500.00 499.99 600.00 599.99 700.00 699.98 800.00 799.98 900.00 899.98 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: WARNER EVEN 100 FEET OF MEASURED DEPTH 1000.00 999.98 1100.00 1099.98 1200.00 1199.98 1300.00 1299.98 1400.00 1399.98 1500.00 1499.98 1600.00 1599.97 1700.00 1699.97 1800.00 1799.96 1900.00 1899.96 SUB-SEA COURSE VER'TICAL VERTICAL DEVIATION AZIMUTH SECTION DEPTH OEG MIN DEG.MIN FEET 0 0 N 0 0 E 0 11 S 51 33 E 0 16 S 39 11 E 0 17 S 32 29 E 0 29 S 26 48 E 0 31 S 17 27 E 0 23 S 6 45 E 0 7 S 3 30 E 0 3 S 35 14 E 0 12 S 38 10 W 2000.00 1999.95 ZlO0.O0 2099.95 2200.00 2199.95 2300.00 2299.95 2400.00 2399.95 2500.00 2499.95 2600.00 2599.95 2700.00 2699.94 2800.00 2799.94 2900.00 2899.92 -56.00 44.00 144.00 244.00 343.99 443.99 543.99 643.98 743.98 843.98 0 15 S 67 44 W 0 11 N 75 51 W 0 4 N 0 39 E 0 2 N 16 12 E 0 13 N 10 17 W 0 35 N 13 56 E 0 42 N 32 52 E 0 29 N 47 12 E 0 30 N 40 8 E 0 33 N 63 21 E 3000.00 2999.89 3100.00 3099.85 3200.00 3199.79 3300.00 3299.71 3400.00 3399.58 3500.00 3499.44 3600.00 3599.30 3700.00 3699.18 3800.00 3799.08 3900.00 3898.98 0 23 N 78 5 E 0 16 N $5 46 E 0 6 N 80 8 E 0 9 N 58 23 E 0 16 N 64 27 E 0 8 N 44 23 ~ 0 19 N 47 10 ~ 0 27 N 44 17 E 0 59 N 42 46 E 1 17 N 51 7 E 943.98 1043.98 1143.98 1243.98 1343.98 1443.98 1543.97 1643.97 1743,96 1843.96 1943.95 2043.95 2143.95 2243.95 2343.95 2443.95 2543.95 2643.94 2743.94 2843.92 2943.89 1 28 N 50 15 E 3043.85 1 48 N 50 7 E 3143.79 2 5 N 53 52 E 3243.71 2 39 N 53 35 E 3343.58 3 0 N 52 47 E 3443.44 3 5 N 51 36 ~ 3543.30 2 55 N 52 56 E 3643.18 2 38 N 55 2 E 3743.08 2 32 N 56 5 E 3842.98 2 32 N 57 13 E DOGLEG RECTANGULAR SEVERITY NOR'TH/SOUTH DEG/IO0 FEET COORDINATES HORIZ. DEPARTUR: EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 0.00 -0.38 -0.83 -1.31 -2.01 -2.87 -3.61 -3.99 -4.10 -4.22 0.00 0.00 N 0.87 0.31 S 0.08 0.60 S 0.25 0.99 S 0.17 1.61 S 0.10 2.46 S 0.28 3.28 S O. 13 3.76 S 0.14 3.86 S 0.21 4.07 S . O. O. O. 1. 1. 1. 1. 1. 1. O0 E 0.00 22 E 0.38 57 E 0.83 86 E 1.31 21 E 2.02 55 E 2.91 74 E 3.71 77 E 4.16 82 E 4.27 77 E 4.44 N 0 0 E S 34 35 E S 43 46 E S 40 42 E S 36 55 E S 32 12 E S 27 57 E S 25 14 E S 25 15 E S 23 31 E -4.18 -3.95 -3.71 -3.70 -.3.53 -3.05 -2.55 -2.44 -2.34 -2.39 0.22 4.34 S 0.13 4.37 S 0.29 4.22 S O. 14 4.16 S 0.31 3.98 S 0.42 3.27 S 0.42 2.16 S O. 12 1.42 S 0.20 0.81 S 0.18 0.21 S . 1. O. O. O. O. 1. Z. 2. 3. 4i E 4.56 03 E 4.49 83 E ~. 30 88 E 4.26 83 E 4.07 91 E 3.40 40 E 2.58 07 E 2.51 61 E 2.74 36 E 3.37 S 18 4 E S 13 14 E S 11 6 E S 11 55 E S 11 50 E S 15 29 E S 32 55 E S 55 35 E S 72 47 E S 86 24 E -2.70 0.09 0.07 N -3.03 0.18 0.15 N -3.22 0.10 0.17 N -3.28 0.25 0.26 N -3.37 0.17 0.44 N -3.49 0.64 0.70 N -3.52 0.31 0.98 N -3.47 0.24 1.53 N -3.37 0.33 2.38 N -3.35 0.09 3.71 N . 4. 5. 5. 5. 6. 6. 6. 7. 9. 16 E 4.16 74 E 4.74 O~ E 5.05 24 E 5.24 59 E 5.61 05 E 6.09 42 E 6.50 96 E 7.13 78 E 8.14 25 E 9.9? N 89 0 E N 88 8 E N 88 6 E N 87 12 ~ N 85 29 E N 83 26 E N 81 17 E N 77 37 E N 72 59 E N 68 10 E -3.44 0.34 5.21 N -3.49 0.13 7.06 N -3.71 0.22 9.16 N -4.09 1.39 11.50 N -4.50 0.31 14.53 N -4.81 0.09 17.84 N -5.15 0.29 21.08 N -5.63 0.20 23.91 N -6.17 0.15 26.49 N -6.79 0.29 28.96 N 11. 13. 15. 19. 23. 27. 31. 35. 39. 42. 08 E 12.24 25 E 15.01 95 E 18.39 17 E 22.36 21 E 27.38 43 E 32.72 60 E 37.99 52 E 42.82 25 E 47.35 97 E 51.82 N 64 48 E N 61 57 E N 60 8 E N 59 25 N 57 56 E N 56 57 E N 56 17 E N 55 3 E N 55 59 E N 56 1E COMPUTATION DATE: 1T-NOV-86 PAGE 2 STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 100 FEE'T MEASUR DEPT TRUE SUB-SE ED VERTICAL VERTIC H DEPTH DEPT A COURSE AL DEVIATION AZIMUTH H DEG MIN DEG MIN 4O 41 42 43 44 45 46 47 49 00. 00. 00. 00. 00. 00. 00. 00. 00. 00. O0 3998.88 3942. O0 4098.79 4042. 00 4198.70 4142. O0 4298.60 4242. O0 4398.52 4342. O0 4498,44 4442. O0 4598.36 4542. O0 4698.29 4642. O0 4798.23 4742. O0 4898.16 4842. 88 2 27 N 59 53 E 79 2 28 N 61 53 E 70 2 27 N 67 57 E 60 2 26 N 68 24 E 52 2 20 N 68 30 E 44 2 18 N 67 50 E 36 2 10 N 66 16 E 29 2 6 N 65 9 E 23 2 4 N 64 48 E 16 2 9 N 65 0 E 5000. 5100. 5200. 5300. 5400. 5500. 5600. 5700. 5800. 5900· O0 4998.08 4942. O0 5098.01 5042. O0 5197.93 5141. 00 5297.85 5241. 00 5397.76 5341. O0 5497.67 5441. O0 5597.56 5541. O0 5697.18 5641. O0 5796.28 5740. O0 5894.89 5838. 08 Z 14 N 66 58 E O1 2 15 N 66 29 E 93 2 17 N 64 55 E 85 2 19 N 63 47 E 76 2 28 N 62 46 E 67 2 15 N 43 37 E 56 3 38 N Z 3 W 18 6 19 N 20 38 W 28 8 38 N 28 53 W 89 10 24 N 32 14 W 6O 61 62 63 64 65 66 67 68 69 00. 00. 00. 00. 00. 00. 00. 00. 00. 00. O0 5992.98 5936. O0 6090·48 5034. O0 6187.27 6131. O0 6283.44 6227. O0 6378.33 6322. O0 6471.21 6415. O0 6562.i8 6506. O0 5651.23 6595. O0 6738.08 6682. O0 6823.85 6767. 98 11 59 N 36 27 W 48 13 44 N 40 50 W 27 15 7 N 45 51 W 44 16 59 N 49 4 W 33 20 2 N 49 4 W 21 23 9 N 48 8 W 18 25 50 N 46 44 W 23 28 23 N 45 41 W 05 30 35 N 44 54 W 85 31 I N 45 6 W 7000· 7100· 7200. 7300· 7400. 7500· 7600· 7700· 7800. 7900. O0 6909.45 6853.45 O0 6994.89 6938.89 O0 7080.20 7024.20 O0 7165,56 7109.56 O0 7251.01 7195.01 O0 7336.34 7280.34 O0 7421.26 7365.26 O0 7505.89 7449.89 O0 7590.35 7534.35 O0 7674.57 7618.57 31 14 N 45 10 W 31 21 N 45 4 W 31 24 N 44 5,5 W 31 13 N 44 42 W 31 28 N 44 8 W 31 37 N 44 7 W 32 3 N 44 43 W 32 17 N 45 22 W 32 28 N 45 15 W 32 38 N 45 4 W VERTICAL DOGL SECTION SEVE FEET DEG/ -7.55 0 -8.48 0 -9.75 0 -ll. ZO 0 -12.65 0 -13.99 0 -15.26 0 -16.34 0 -17.34 0 -18.41 0 DATE OF SURVEY: 1Z-NOV-86 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: WARNER OF MEASURED DEPTH EG RECTANGULAR COO RITY NORTH/SOUTH EAS 100 FEET FE .19 31 · 22 N 46 · 29 33.33 N 50 .11 35.05 N 54 .16 36.62 N 58 · 34 38.16 N 62 · 13 39.67 N 65 .49 41.19 N 69 · 19 42.74 N 72 .,28 44.29 N 76 · 22 45.83 N 79 -1'9.58 0.20 47.44 N 83 -20.82 0.20 48.95 N 86 -22.01 0.24 50.56 N 90 -23.11 0.21 52.31 N 94 -24.19 0.19 54.20 N 97 -24.88 1.10 56.37 N 101 -22.75 3.44 60.53 N 102 -15.08 3.20 68.91 N 100 -2.30 1.10 80.83 N 94 13.98 1.90 95.07 N 86 33.30 1 55.47 2 80.53 1 107.77 2 138.98 3 175.72 2 216.99 2 262.32 2 311.76 1 363.08 0 414.68 466.54 518.61 570,61 622.48 674.58 727·33 780.48 833.90 887.71 RDIN4TES HORIZ. DEPARTURE T/WEST DIST. AZIMUTH ET FEET OEG MIN .84 111.12 N 75 ,15 128.44 N 61 .61 146.67 N 44 .60 165.07 N 23 .58 185.58 N 0 .71 210.13 N 27 .67 238.13 N 58 · 83 269.67 N 91 · 21 304.57 N 126 ,40 340.93 N 162 .69 E 56.17 .47 E 60.49 .32 E 64.65 .30 E 68.85 .22 E 72.99 .95 E 76.96 .59 E 80.87 .97 E 84.57 .22 E 88.16 · 59 E 91·85 N 56 13 .~ N 56 33 E N 57 10 E N 57 51 E N 58 28 E N 5B 58 E N 59 22 E N 59 38 E N 59 50 E N 60 3 E .17 E 95.75 .'74 E 99.60 .36 E 103·55 .01 E 107.58 .77 E 111·79 · 27 E 115.90 .74 E 119.24 · 66 E 121.99 .84 E 124.61 .36 E 128.44 N 60 17 E N 60 33 E N 60 46 E N 60 54 E N 60 59 E N 60 53 E N 59 29 E N 55 36 E N 49 33 E N 42 15 E 0.06 377.40 N 199 0.59 414.06 N 236 0.41 450.94 N 272 0.82 487.87 N 309 0.37 524.96 N 346 0.75 562.45 N 382 0.45 600.19 N 419 0.54 637.83 N 456 0.79 675.43 N 495 0.35 713.43 N 533 .34 E 134.25 .46 E 142.39 .24 E 153.19 .94 E 166.80 .01 E 185.58 .68 W 211.94 .3i W 245.17 · 08 W 284.64 .25 W 329.70 .60 W 377.72 N 34 8 N 25 34 N 16 47 N ~ 15 N 0 0 N 7 30 N 13 45 N 18 39 N 22 30 N 25 29 · 24 W 426.77 .07 W 476.63 · 97 W 527.13 · 70 W 577.87 · 06 W 628.76 .31 w 680.08 .27 W 732.13 .94 W 784.6i .04 W 837.43 .31 W 890.73 N 27 ~9 W N 29 41 W N 31 11 W N 32 24 W N 33 23 W N 34 12 W N 34 56 N N 35 37 W N 36 14 w N 36 46 w COMPUTATION DATE: 17-NOV-86 PAGE 3 STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICDTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 100 TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH GEPTH DEG MIN DEG MIN 8000.00 7758.66 8100.00 7842.66 8ZO0.O0 7926.76 8300.00 8011.i3 8400.00 8095.83 8500.00 8180.79 8600.00 8265.86 8700.00 8351.16 8800.00 8436.45 8900.00 8521.64 7702.66 32 52 N 45 7 W 7786.66 32 50 N 45 3 W 7870.76 32 39 N 45 15 W ?955.13 32 19 N 45 25 W 8039.83 31 57 N 45 28 W 8124.79 31 44 N 45 48 W 8209.86 31 38 N 46 4 W 8295.16 31 20 N 46 9 N 8380.45 31 33 N 45 51 W 8465.64 31 36 N 45 16 W 9000.00 8606.76 9100.00 8691.64 9200.00 8776.15 9300.00 8860.31 9400.00 8944.47 9500.00 9028.80 9600.00 9113,43 9700.00 9198.69 9800.00 9284.61 9900.00 9371.26 8550.76 31 43 N 44 22 W 8635.64 32 6 N 43 37 W 8720.15 32 29 N 43 10 W 8804.31 32 47 N 42 40 W 8888.47 32 34 N 42 11 W 8972.80 32 25 N 41 55 W 9057.43 31 54 N 41 35 W 9142.69 31 7 N 40 58 W 9228.61 30 16 N 40 0 W 9315.26 29 43 N 38 45 W 10000.00 9458.27 10100.00 9545.89 10200.00 9634.18 10300.00 9723.54 10400.00 9813.70 10500.00 9904.63 10600.00 9996.19 10700.00 10088.15 10800.00 10179.63 10900.00 10271.16 9402.27 29 8 N 37 22 W 9489.89 28 29 N 36 8 W 9578.18 27 23 N 35 9 W 9667.54 26 3 N 34 49 W 9757.70 25 10 N 34 24 W 9848.63 24 0 N 34 20 W 9940.19 23 33 N 33 53 W 10032.15 23 13 N 33 26 W 10123.63 23 55 N 32 32 W' 10215.16 23 43 N 31 38 W 11000.00 10362.91 11100.00 10455.15 11200.00 10547.74 11242.00 10586.65 10306.91 23 1 N 30 51 W 10399.15 22 23 N 29 39 W 10491.74 22 7 N 29 55 W 10530.65 22 7 N 29 55 W FEET OF VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 941.72 0.24 995.87 0.41 1049.86 0.23 1103.42 0.35 1156.45 0.32 1209.07 0.23 1261.46 0.50 1313.48 0.27 1365.52 0.25 141'7.75 0.53 DATE OF SURVEY: 1Z-NOV-86 KELLY BUSHING ELEVATION: ENGINEER: WARNER MEASURED RECTANG NORTH/S FEET 751.6 789.9 828.0 865.7 903.0 939.9 976.4 1012.6 1048.8 1085.5 1470.15 0.61 1122.7 1522.97 0.37 1160.7 1576.40 0.49 1199.6 1630.41 0.56 1239.1 1684.39 0,25 1279.0 1738.14 0.43 1319.0 1791.41 0.87 !358.6 1843.68 0.73 1398.0 1894.82 1.25 1436.8 1944.72 1.16 1475.4 1993.92 1.12 1514.2 2041.94 1.03 1552.8 2088.52 1.41 1591.0 2133.21 0.71 1627.8 2176.18 1.06 1663.4 2217.45 0.89 1697.7 2257.34 0.74 1731.0 2295.24 1.40 1763.7 2336.20 1.06 1797.5 2375.39 0.39 1831.7 2415.07 0.56 1865.7 2452.96 2.10 1899.0 2489.97 0.00 1931.7 2505.47 0.00 1945.4 DEPTH 56. O0 FT ULAR COORDINATES HORIZ. DEPARTURE OUTH EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 3 N 571.65 W 944.31 8 N 610.03 W 998.10 6 N 648.45 W 1051.75 6 N 686.68 W 1105.02 4 N 724.57 W 1157.79 2 N 762.29 W 1210.18 8 N 800.03 W 1262.36 4 N 837.67 W 1314.21 8 N 875.24 W 1366.09 0 N 912.68 W 1418.20 2 N 949.69 W 1470.51 8 N 986.38 W 1523.27 6 N 1023.08 W 1576.67 8 N 1059.92 W 1630.64 7 N 1096.30 W 1684.60 0 N 1132.28 W 1738.34 9 N 1167.82 W 1791.60 1 N 1202.24 W 1843.86 8 N 1235.50 W 1895.01 2 N 1267.23 W 1944.93 5 N 1297.60 W 1994.17 7 N 1326.42 W 2042.25 3 N 1353.73 W 2089.01 2 N 1379.45 W 2133.70 1 N 1404,06 W 2176.76 7 N 1427.50 W 2218.15 0 N 1450.1~ W 2258.16 6 N 1471.82 W 2297.20 5 N 1493.93 W 2337.32 1 N 1515.23 W 2377.20 N 3'7 15 W N 37 40 N N 38 3 W N 38 25 W N 38 44 W N 39 2 W N 39 19 W N 39 35 N N 3'9 50 W N 40 3 W N 40 13 W N 40 21 W N 40 27 W N 40 32 W N 40 36 ~ N 40 38 W N 40 40 W N 40 41 W N 40 41 w N 40 39 W N 40 35 W N 40 30 W N 40 23 N N 40 16 W N 40 10 W N 40 3 W N 39 57 W N 39 50 W N 39 43 N N 39 35 W 1 N 1535.93 W 2416.60 N 39 27 W 1 N 1555.47 W 2454.73 N 39 19 W 7 N 1574.30 W 2492.02 N 39 10 W 8 N 1562.20 W 2507.64 N 39 7 W COMPUTATION DATE: 1T-NOV-S6 PAGE 4 STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 1000 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN VERTICAL SECTION FEET DOGLEG SEVERITY DEG/IO0 0.00 0.00 -56.00 1000.00 999.98 943.98 2000.00 1999.95 1943.9.5 3000.00 2999,89 2943.89 4000.00 3998.88 3942.88 5000.00 4998.08 4942.08 6000.00 5992.98 5936.98 7000.00 6909.45 6853.45 8000.00 7758.66 7702.66 9000.00 8606.76 8550.76 10000.00 9458.27 9402.27 11000.00 10362.91 10306.91 11242.00 10586.65 10530.65 0 0 N 0 0 0 15 S 67 44 0 23 N 78 5 1 28 N 50 15 2 27 N 59 53 2 14 N 66 58 11 59 N 36 27 31 14 N 45 10 32 52 N 45 7 31 43 N 44 22 29 8 N 37 22 23 1 N 30 51 22 7 N 29 55 0.00 -4.18 -2.70 -3.44 -7,55 -19.5'~ 33.30 414.6~, 941.72 1470.15 1993.92 2415.07 2505.47 0.00 0.22 0.09 0.34 0.19 0.20 1.84 0.05 0.24 0.61 1.1Z 0.56 0.00 DATE OF SURVEY: 1Z-NOV-86 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: WARNER MEASURE RECTANG NORTH/S FEET 0.0 4.3 0.0 5.2 31.2 47.4 111.1 377.4 751.6 1122.7 D DEPT ULAR COORDINATES HORIZ. DEPARTURE OUTH EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 0 N 0.00 E 0.00 N 0 0 E 4 S 1.41 E 4.56 S 18 4 ~ 7 N 4.16 E 4.16 N 89 0 E 1 N 11.08 E 12.24 N 64 48 E 2 N 46.69 E 56.17 N 56 13 E 4 N 83.17 E 95.75 N 60 17 E 2 N 75.34 E 134.25 N 34 8 E 0 N 19~.24 W 426.77 N 27 49 W 3 N 571.65 W 944,31 N 37 15 W 2 N 949.69 W 1470.51 N 40 13 ~ 1514.25 N 1297.60 W 1994.17 N 40 35 W 1865.71 N 1535.93 W 2416.60 N 39 27 W 1'945.48 N 1582.20 W 2507.64 N 39 7 W COMPUTATION DATE: STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA TR ME4SURED VERT DEPTH DE INTERPOLATED VALUES FOR EVEN 100 UE 'SUB-SEA COURSE VERTICAL ICAL VERTICAL DEVIATION AZIMUTH SECTION PTH DEPTH DEG MIN DEG MIN FEET 0.00 0.00 -56.00 56.00 56.00 0.00 156.00 156.00 100.00 256.00 256.00 200.00 356.00 356.00 300.00 456.01 456.00 400.00 556.01 556.00 500.00 656.02 656.00 600.00 756.02 756.00 700.00 856.02 856.00 800.00 956.02 956.00 1056.02 1056.00 1156.02 1156.00 1256.02 1256.00 1356.02 1356.00 1456.02 1456.00 1556.03 1556.00 1656.03 1656.00 1756.04 1756.00 1856.04 1856.00 1956.04 1956.00 2056.05 .2056.00 2156.05 2156.00 2256.05 2256.00 2356.05 2356.00 2456.05 2456.00 2556.05 2556.00 2656.05 2656.00 2756.06 2756.00 2856.07 2856.00 2956.10 2956.00 3056.13 3056.00 3156.19 3156.00 3256.25 3256.00 3356.36 3356.00 3456.50 3456.00 3556.64 3556.00 3656.77 3656.00 3756.88 3756.00 3856.98 3856.00 0 0 N 0 0 E 0.00 0 27 S 34 4 E -0.07 0 17 S 49 38 E -0.62 0 16 S 34 43 E -1.10 0 25 S 29 22 E -1.65 0 32 S 21 5 E -2.50 0 28 S 13 10 E -3.32 0 16 S 2 43 E -3.87 0 3 S 41 17 E -4.06 0 7 S 13 1 W -4.17 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 l?O0.O0 1800.00 0 16 S 54 2 W -4.23 0 12 S 88 37 W -4.07 0 8 N 49 18 W -3.79 0 2 N 65 29 E -3.70 0 6 N 18 52 N -3.65 0 26 N 6 33 E -3.29 0 44 N 25 8 E -2.73 0 33 N 45 10 E -2.45 0 26 N 39 29 E -2.40 0 34 N 52 21 E -2.'31 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 0 29 N 71 25 E -2.55 0 20 N 83 32 E -2.89 0 8 N 89 9 E -3.16 0 7 N 64 23 E -3.26 0 14 N 63 27 E -3.32 0 23 N 59 47 E -3.45 0 16 N 54 36 E -3.51 0 28 N 43 50 E -3.50 0 41 N 44 41 E -3.44 1 8 N 48 53 E -3.32 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 1 20 N 50 11 E -3.40 1 37 N 49 15 E -3.46 1 59 N 52 38 E -3.58 2 16 N 54 11 E -3.92 2 55 N 53 2 E -4.32 3 4 N 51 34 E -4.69 3 0 N 52 21 E -4.99 2 45 N 54 26 E -5.41 2 36 N 55 21 E -5.93 2 33 N 56 16 E -6.51 17-NOV'-86 PAGE DATE OF SURVEY: 1Z-NOV-86 KELLY BUSHING ELEVATION: ENGINEER: WARNER FEET OF SUB-SEA DEPTH DOGLEG RECTANGULAR .SEVERITY NORTH/SOUTH DEG/iO0 FEET 0.00 0.00 N 0.57 0.05 S O. 19 0.45 S 0.06 0.81 S 0.30 1.29 S 0.09 2.08 S 0.39 2.95 S 0.20 3.61 S 0.09 3.83 S O. 16 3.95 S 0.13 4.23 S 0.12 4.39 S 0.26 4.29 S 0.07 4.18 S 0.24 4.10 S 0.46 3.66 S 0.25 2.65 S 0.34 1.69 S 0.11 1.09 S O. 26 0 · 44 S 0.34 0.01 S O. 05 0.13 N 0.12 0.16 N 0.04 0.20 N 0.15 0.35 N 0.27 0.59 N 0.18 0.84 N 0.09 1.27 N 1.37 1.89 N 0.46 3.10 N 0.18 4.53 N 0.53 6.19 N 0.59 8.22 N 0.73 10.40 N 0.22 13.18 N 0.23 16.38 N 0.16 19.72 N 0.29 22.74 N O. 11 25.40 N O. 18 27.90 N 5 56. O0 FT COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET OEG MIN 0.00 E 0.00 0.05 E 0.07 0.43 E 0.52 0.74 E 1.10 1.04 E 1.66 1.42 E 2.52 1.68 E 3.39 1.76 E 4.01 1-79 E 4.23 1.83 E 4.35 1.60 E 4.52 1.19 E 4.54 0.87 E 4.38 0.86 E 4.27 0.87 E 4.19 0.83 E 3.75 1.13 E 2.88 1.78 E 2.46 2.39 E 2.63 3.00 E 3.03 3.84 E 3.84 4.51 E 4.51 4.95 E 4.95 5.15 E 5.15 5.41 E 5.42 5.87 E 5.90 6.25 E 6.30 6.71 E 5.83 7.32 E 7.56 8.52 E 9.07 10.26 E 11.21 12.23 E 13.71 14.70 E 16.84 17.57 E 20.50 21.41 E 25.14 25.59 E 30.38 29.83 E 35.76 33.86 E 40.79 37.66 E 45.42 41.37 E 49.90 N 0 0 E S 49 48 E S 43 49 E S 42 6 E S 38 41 E S 34 15 E S 29 42 ~ S 26 1 E S 25 45 S 24 52 E S 20 38 E S 15 9 E S 11 29 E S 11 39 E S 11 56 E S 12 48 E S 23 2 E S 46 27 E S 65 26 E S 81 41 E S 89 49 E N 88 21 E N 38 8 E N 87 45 E N 36 15 E N 84 17 E N 82 21 E N 79 17 E N 75 33 E N 69 58 E N 66 9 E N 53 8 E N 60 47 E N 59 31 E N 58 23 E N 57 22 E N 56 31 E N 55 7 E N 56 OF: N 56 0 E COMPUTATION DATE: 17-NOV-86 PAGE 6 STANDARD ALASKA PRODUCTION CO. 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTH 3957.08 3956.00 4057.17 4056.00 4157.26 4156.00 4257.35 4256.00 4357.44 4356.00 4457.52 4456.00 4557.60 4556.00 4657.68 4656.00 4757.75 4756.00 4857.81 4856.00 4957.89 4956.00 5057.96 5056.00 5158.04 5156.00 5258.12 5256.00 5358.21 5356.00 5458.29 5456.00 5558.38 5556.00 5658.62 5656.00 5759.28 5756.00 5860.49 5856.00 INTERPOLATED VALUES FOR EVEN 100 SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH SECTION DEPTH DEG MIN DEG MIN FEET 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 2 29 N 58 44 E -7.20 2 29 N 60 52 E -8.07 2 25 N 67 25 E -9.14 2 27 N 68 41 E -10.58 2 24 N 68 40 E -12.04 2 17 N 68 1 E -13.43 2 15 N 66 47 E -14.76 2 8 N 64 58 E -15.89 Z 3 N 6.~ 16 E -16.92 Z 7 N 65 30 E -17.96 2 16 N 65 45 E '-19.06 2 12 N 67 14 E -20.31 2 16 N 65 53 E -21.52 2 i8 N 64 17 E -22.66 2 25 N 63 8 E -23.7~+ 2 21 N 60 40 E -24.77 2 30 N 16 51 E -24.25 5 11 N 15 30 W -18.89 7 54 N 26 58 W -8.06 9 44 N 3I T W 7.17 5962.24 5956.00 6064.56 6056.00 6167.63 6156.00 6271.36 6256.00 6376.33 6356.00 6483.48 6456.00 6593.13 6556.00 6705.45 6656.00 6820.85 6756.00 6937.52 6856.00 7054.48 6956.00 7171.65 7056.00 7288.82 7156.00 7405.85 7256.00 7523.11 T356.00 7641.03 7456.00 7759.34 7556.00 7877.97 7656.00 7996.84 7756.00 8115.88 7856.00 5900.00 6O00.OO 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.OO 7400.00 7500.OO 7500.00 7700.00 7800.00 11 24 N 34 54 W 25.69 13 6 N 39 21 W 47.27 14 45 N 44 14 W 72.19 16 18 N 48 26 W 99.65 19 14 N 49 18 W 131.19 22 42 N 48 11 W 169.31 25 39 N 46 50 W 213.99 28 32 N 45 38 W 264.95 30 49 N 44 53 W 322.40 31 5 N 45 7 W 382.37 31 20 N 45 7 W 442.92 31 26 N 44 58 W 503.86 31 15 N 44 45 W 564.83 31 28 N 44 7 W 625.53 31 46 N 44 13 W 686.71 32 10 N 44 57 W 749.11 32 22 N 45 20 W B12.18 32 38 N 45 6 W 875.87 32 52 N 45 7 W 940.00 32 48 N 45 10 W 1004.47 FEET OF DOGLEG SEVERITY DEG/IO0 0.18 0.10 0.30 0.44 0.17 0.13 0.38 0.16 0.17 0.19 0.28 0.22 0.14 0.40 0.26 1.16 3.30 2.96 2.83 1.66 1.69 1.94 1.89 2.30 3.29 2.87 2.70 2.80 0.76 0.44 0.51 0.34 0.81 0.35 0.64 0.45 0.26 0.42 0.23 0.45 DATE OE SURVEY: 1Z-NOV-86 KELLY BUSHING ELEVATION: 56.00 ENGINEER: WARNER SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ. OEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 30.28 N 45.10 E 54..32 N 567 E 32.44 N 48.84 E 58.63 N 56 24 E 34.36 N 52.64 E 62.87 N 56 51 E 35.96 N 56.60 E 67.06 N 57 34 E 37.51 N 60.56 E 71.24 N 58 13 E 39.02 N 64.37 E 75.27 N 58 46 E 40.53 N 68.08 E 79.23 N 59 13 E 42.08 N 71.54 E 83.00 N 59 32 E 43.64 N 74.86 E 86.65 N 59 45 ~ 45.17 N 78.16 E 90.27 N 59 58 E 46.77 N 81.63 E 94.08 N 60 11 E 48.31 N 85.24 E 97.98 N 60 27 E 49.87 N 88.34 E 101.88 N 60 41 E 51.56 N 92.48 E 105.88 N 60 51 E 53.39 N 96.17 E 109.99 N 50 57 E 55.38 N 99.97 E 114.28 N 61 0 E 58.33 N 102.54 E 117.97 N 60 21 E 64.99 N 101.96 E 120.91 N 57 29 E 75.61 N 97.62 E 123.48 N 52 14 E 89.17 N 89.96 E 126.67 N 45 15 E 104.90 N 79.80 E 131.80 N 37 15 ~ 122.16 N 66.74 E 139.20 N 28 39 E 140.79 N 50.18 E 149.46 N 19 37 E 159.69 N 30.11 E 162.50 N 10 40 E 180.44 N 5.97 E 180.54 N 1 53 ~ 205.83 N 22.87 W 207.10 N 6 20 W 236.06 N 56.12 W 242.64 N 13 22 W 271.51 N 92.96 W 285.99 N 13 54 W 312.12 N 133.77 W 339.58 N 23 11 W 354.57 N 176.30 W 395.98 N 26 26 N 397.36 N 213.31 W 453.86 N 28 53 W 440.49 N 262.53 W 512.79 N 30 47 W 483.75 N 305.63 W 372.21 N 32 17 W 527.15 N 348.18 W 631.76 N 33 26 N 571.17 N 390.77 W 692.05 N 3~ 22 W 615.66 N 434.65 W 753.63 N 35 13 N 660.12 N 479.59 W 815.94 N 35 59 W 705.04 N 524.92 W 878.99 N 36 40 N 750.41 N 570.43 W 942.61 N 37 14 W 796.05 N 616.13 W 1006.64 N 37 44 W COMPUTATION DATE: 1T-NOV-B6 PAGE 7 STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: I2-NOV'-86 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WARNER 56.00 FT INTERPOL4TED VALUES FOR EVEN 100 FEET OF SUB-SE& DEPTH T MEASURED VER DEPTH D RUE SUB-SEA TICAL VERTICAL EPTH DEPTH COURSE VERTICAL DOGLEG RECTANGULfiR DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH DEG MIN DEG MIN FEET DEG/IO0 FEET COORDINATES HORIZ. DEPARTURE EAST/WEST DIST. .AZIMUTH FEET FEET DEG MIN 8234.71 79 8353.06 80 8470.85 81 8588.42 82 8705.67 83 8822.94 84 8940.35 85 9057.95 86 9176.13 87 9294.87 88 56.00 7900.00 56.00 8000.00 56.00 8100.00 56.00 8200.00 56.00 8300.00 56.00 8400.00 56.00 8500.00 56.00 8500.00 56.00 8700.00 56.00 8800.00 32 31 N 45 24 W 1068.53 0.65 841.22 N 32 4 N 45 30 W 1131.66 0.71 885.61 N 31 47 N 45 43 W 1193.78 0.40 929.22 N 31 39 N 46 2' W 1255.40 0.41 972.27 N 31 21 N 46 8 W 1316.42 0.31 1014.69 N 31 34 N 45 46 W 1377.49 0.21 1057.25 N 31 39 N 44 54 W 1438.86 0.47 1100.43 N 31 57 N 43 53 W 1500.68 0.52 1144.66 N 32 25 N 43 13 W 1563.60 0.22 1190.33 N 32 47 N 42 43 W 1627.64' 0.59 1237.13 N 661 · 706. 751. 795. 839. 883. 927. 97'0 · 101~. 1058. 75 W 1070.31 N 38 11 W 86 W 1133.11 N 38 35 W 30 W 1194.95 N 38 57 N 65 W 1256.33 N 39 17 W 79 W 1317.13 N 39 36 W 85 W 1378.03 N 39 53 W 66 W 1439.27 N 40 7 ~ 97 W 1501.01 N 40 18 W 30 W 1563.87 N 40 26 W 04 W 1627.87 N 40 32 W 9413.67 9532.21 9650.05 9766.80 9882.42 9997.40 10111.51 10224.55 10336.10 10446.65 8956.00 8900.00 9056.00 9000.00 9156.00 9100.00 9256.00 9200.00 9356.00 9300.00 9456.00 9400.00 9556.00 9500.00 9656.00 9600.00 9756.00 9700.00 9856.00 9800.00 32 33 N 42 6 W 1691.75 0.42 1284.52 32 16 N 41 54 W 1755.39 0.67 1331.86 31 30 N 41 10 W 1817.73 0.96 1378.44 30 40 N 40 20 W 1877.99 0.88 1424.02 29 46 N 39 4 W 1936.00 0.82 1468.63 29 10 N 37 24 W 1992.65 1.13 1513.24 28 23 N 36 0 W 2047.42 1.12 1557.30 27 2 N 35 2 W 2099.80 1.51 1600.23 25 46 N 34 44 W 2148.89 '0.89 1640.77 24 36 N 34 17 W 2195.70 1.43 1679.66 N 1101. N 1143. N 1185. N 1224. N 1261. N 1296. N 1329. N 1360. N 1388. N 1415. 24 W 1691.96 N 40 36 W 78 W 1755.58 N 40 39 W 20 W 1817.91 N 40 41 W 63 W 1878.18 N 40 41 W 75 W 1936.20 N 40 40 W $2 W 1992.90 N 40 35 W 67 W 2047.73 N 40 29 W 20 N 2100.21 N 40 21 W 46 W 214'9.41 N 40 14 W 15 W 2196.34 N 40 6 W 10556.12 99 10665.08 100 10774.13 101 10883.43 102 10992.49 103 11100.92 104 11208.91 105 11242.00 105 56.00 9900.00 23 39 56.00 10000.00 23 0 56.00 10100.00 23 59 56.00 10200.00 23 43 56.00 10300.00 23 5 56.00 10400.00 22 24 56.00 10500.00 22 7 86.65 10530.65 22 7 N 34 13 W 2239.88 0.49 1716.43 N'33 25 W 2282.74 1.07 1752.39 N 32 56 W '2325.80 1.33 1788.71 N 31 43 W 2369.33 0.31 1826.05 N 30 56 W 2412.18 0.76 1863.19 N 29 38 W 2453.30 1.91 1899.32 N 29 55 W 2493.25 0.00 1934.68 N 29 55 W 2505.47 0.00 1945.48 N 1440. N 1464. N 1488. N 1511. N 1534. N 1555. N 1575. N 1582. 26 W 2240.65 N 40 0 W 31 W 2283.65 N 39 52 W 23 W 2326.87 N 39 45 W 73 W 2370.61 N 39 37 W 42 W 2413.69 N 39 28 W 64 W 2455.08 N 39 19 W 98 W 2495.33 N 39 9 W gO W 2507.64 N 39 7 W COMPUTATION OATE: l?-NOV-86 PAGE 8 STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 1Z-NOV-B6 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WARNER 55.00 FT INTERPOLATED VALUEG FOR CHOSEN HORIZONS MARKER MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1969 SNL, 2256 WEL, SEC 36, T1ZN, R16E TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST TD (DRILLER) 11242.00 10586.65 10530.65 1945.48 N 1582.20 W COMPUTATIDN DATE: 1?-NOV-86 PAGE STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 12-NOV-B6 2-34/P-14 MPI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WARNER 56.00 FT MARKER MEASURED 9EPTH BELOW KB SURFACE LOCATION AT ORIGIN: 1969 SNL, 2256 WEL, SEC 36, TI2N, R16E TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TD CDRILLER) 112~2.00 10586.65 10530.65 1945.48 N 1582.20 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET 3EG MIN 11242.00 105B6.65 10530.65 2507.64 N 39 7 W SCHLUMBERGER O I AEC T I ONAL SUR V E Y COMPANY STANDARD ALASKA PRODUCTION WELL 2-34/P- i 4 MP I FIELD END I COTT COUNTRY USA RUN DATE LOOOED REFERENCE 0000?2065 WELL' 2-34/P-14 MP] (1969' SNL, 2256' WEb, SEC 36, T12N, R16E) IORIZONTAL PROJECTION NORTH 9000 REF 0000720SS 2S0~ 2OO0 1500 1000 SOO -SO0 SOOTH - 1000 NEST I J, OL. HLI"- l/bUD IN/FT I-!..-i---i--iyN+~.-i-..i---;-.~...f...;...i...:..~...I...~...~.4...i...'..L~..~...:. ~:~ i~ ~, T,,~ .............. 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T-'?'t'"~ ..... t'"~'?' ~ .... t-'~ ~-.- ~ 4 i ~ ~..:...:_:... '"~'r't'-~-*]--~---~---~.*; ....... i...~...~ ..... ~..i.. ! · +++..~.4...~.4...~.4_~...~4_~ ..... ~.~..~'-~ ..... FT'T"F'[~'"F'F'-; ...... ~"f"~'"~ ....... ~'"f+~ ..... ~-'+++-r--~'-~ ~--.~ ..... ~-.-~--.;---; ...... L~...L.~ ....... ~;;'~-,-~-'['"r"r--r"~t~--~-~ -~-.+-.~.--~ ...... ~--4.~¢-.4 ...... t-4..4 ..... ~.4-.4--4 ...... ~.4 ~ [ ~ ~ ~ ~ ~ ~ .... t"~--T'f ...... v.r--t---, ..... r-t-.-~.--~ .... ~---;--~.--~--J---~-.~---L.~.- ..4.4 ~ ~ ~ i ~ ; ~ ; ~ ~ ~ '";"F'~'~ ~"F"T'-."' .... .... ..... ...... ::::::::::::::::::::: ,2S00 -2000 _~hn ,n~ ' ~ ............ ~ ~ ~, ~ ~ ~ ~ ~ ~ '"r ?'l'~'T'"r';' - 30 -500 0 SO0 ! 000 ! SO0 EAST WELL' 2-34/P-14 MPI (1969' SNL, 2256' WEL, SEC 36, T12N, R16E) RTICAL PROJECTION -SO0 0 0 SO0 100 3500 318. PROJECTION ON VERTICAL PLANE 318. - 158. SCALED IN VERTICAL DEPTHS HORIZ SCALE = I/SO0 IN/FT October 9, 1986 Telecopy: (907) 276-7542 · ~ R. S Allan ~Ir. · Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 A~nchorage, Alaska 99519-6612 Re: Duck Island Unit P-14 MPi Standard Alaska Production Company Peri. it No. 86-172 Sur. Loc. 1969'SNL, 2256'~,~L, Sec. 36, T12N, R16E, UM. Btmhole Loc. 5'NSL, 3883'WEL, Sec. 25, T!2N, R16E, UM. Dear Mr. Allan: 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 governmental agencies~pri°r 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. I~nere 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. Ve~M-~tru~ly .2z~qr_s, ~ /' il'~ // i .~ / ~ ~' . - - ~ V. Cha~e-~on' Chai~an of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI.~!ISSIO~ dlf. Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowez~Y -' STATE OF ALASKA P-14 MPI ALASKA i, lL AND GAS CONSERVATION C_.vlMISSION PERMIT TO DRILL ,. 20 AAC 25.005 la. Type of work Drill ~ Redrill ©1 lb. Type of well. Exploratory [] Stratigraphic Test Re-Entry ~ Deepen ©1 Service .~ DevelopementGas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company BKB = 56' feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612~ Anchorage~ AK 99519-6612 ADT; 34633 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1969' SNL, 2256' WEL, Sec. 36, T12N, R16E Duck Island gnit/Endico:t At top of productive interval 8. Well nu .tuber Number 245' SNL, 3785' WEL, Sec. 36, T12N, R16E P-14 MPI K00683449.-G-14 At total depth 9. Approximate spud date Amount 5~ iNSL, 3883' WEL, Sec. 25, T12N, R16E October 17, 1986 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 11,153 'MD ADL 312828 1495 feet 90·7 feet 2560 10,496' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) l0 ~ 000 ' TVDss Kickoff depth 5450 feet Maximum hole angle 300 Maximum surface 3900 psig At total depth fi'VD) 4900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Str']ctur~l Dr~v~_ ~i~ 75'Surface 131'- 131' Drive 17-1/2" 13-3/8" 72% L-80 Butt. 2444'Surface 2500' 2500' 2700 cu. ft. Permafros- 12-1/4" 9-5/8" 47~ NTSOS NSCC 5444' Surface 5500' 5500' 320 cu. ft. Permafrost 12-1/4" 9-5/8" 47'~ NT95H~ NSCC 4522' 5500' 5500 10022 9516' 575 cu. ft. Class G 8-1/2" 7" 29% SM-113 Butt. 1381' 9772' 9300 11153 10496' 400 cu. ft, 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 k ~ ~ E i¥' ~' Intermediate Production ,...:'~i 0 , ~ ' Liner Perforation depth' measured .::J~.sk~,Oii & Gas Cons. Anchorage true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch '.~ DiverterSketch Drilling fluid program ~ Timevs depth plot [] Refraction analysis ~ Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the for. egoing is true and correct to the best of my knowledge · h - --.,.. '" .' Commission Use Only IA'PI number I Appr~8~? I See cover letter Permit Number?,; ,-~ _ . 86 for other requirements ~ - [ '? '? 50-- t. t, ¥" -- '~'-< ~ C,, C Conditions of approval Samples required ~ Yes ~.No Mud Icg required ~ Yes [~' No Hydrogen sulfide measures C Y,e.2,.~ No Directional survey required ~ Yes Q No Required wo~7~P~~.' 5M; [] 10M; ~ 15M Other: by order of Approved byk f./', k ~¢~ Commissioner the commission Date Form 10-401 Rev. 124-85 Sub/. triplicate PROPOSED DRILLING AND COMPLETION PROGRAM NELL P-14 (MPI) Drill 17-1/2" hole to 2500', run, and cement 13-3/8", 72#/ft., L-80 Buttress casing to surface. Install BOPE. Maximum BHP is 4900 psi at 10000' TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Directionally drill 12-1/4" hole to the intermediate casing point above the Kekiktuk formation. Run and cement---9-5/8", 47#/ft., NT80S and NT95HS, NSCC casing. No fresh water sands are anticipated below the surface casing shoe. No abnormal pressure intervals are expected in the 12-1/4" hole section. The programmed 9-5/8" casing cement will provide over 500 ft. of annular fill-up above all significant hydrocarbon zones. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a nonfreezing fluid'. Pressure test the 9-5/8" casing to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commission may witness the test. Drill 8-1/2" hole to TD. Log and run and cement 7", 29#/ft., SM-110 Buttress liner to TD with approximately 250' of lap in the 9-5/8" casing. Clean out to float equipment. Test casing and lap to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commission may witness the test. Change over to NaCl packer fluid. Move off ri g. Move rig on in 1987. Perforate well utilizing drill pipe conveyed guns. Kill well. Run and set 7" and 9-5/8" packers. Run 4-1/2", 12.6#/ft., L-80, TDS tubing with a sliding sleeve and GLM's. A subsurface safety valve will be placed 50' below base of permafrost. Install and test tree. Shut in well. Rig up to flow well. Flow tubing volume to tanks. Shut in well. JGV/pm/1199D D, PZL L Z/VG PfTO~/:7A M P, POPO,_PE-z~ W~'L L ,PO/::]~z- z~Z,d ~,PA M t/EL L P-_f 4 (MP_I) T VD BKB b~D BKB d3d' 13d' ~000' ~00' ~00' ~00' 3000' 3000' ~500 ' 5500 RIG' DOYON IS BKS.' 56' AMS£ 30" Structural P.~De Baae Permafrost SSSY Top o£ Downsqueeze Cement 43-3/8" 68 ~/f t L -80 B TC Bottom of Oownsqueeze Cement 9-5/8' d7 ~/ft NTBO$ N$£C to Surface d-d/R" 1£.6 $/ft TDS Tb9. W/3-~/R' TPSGL~S 9£57' 97£P' 9300' 977~' 9-5/8~ TirOl Packer w/SBR Liner Hanger 9-5/8' 47 ~/f t NT95HS NSC£ 7" TIkt Packer 7" TIH Packer dO. 496' IL t53' 7" B9 O/ft S~-ddO BTC B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ANNULAR PREVENTER 2 IN. KILL LINE CHECK HAND N GATE GATE PIPE RAMS Oil & Gas Cons. L~L'i~nissic :; Anchorage I 1 I BLIND RAMS I 1 DRILLING SPOOL 1 I PIPE RAMS 4 IN. CHOKE LINE GATE GATE .... ,~ ...... -- r, I I I I, I _ _ II1_ I DRW NO. IIg- 85 SHEET 1 Qf I0 REV. 0 i i i · i _ i_ PLAT OF PROPOSED I/ELL LOCATIONS MPi ~lls Leceted In Se¢.$&,T.I:ZI~,R. IGE.,Um~t M. SDI Wdll Lece~ed I, ~. t,T.II#.,R.I?E.,Um'~et M. · PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPAR EO BY F.R. BELL & ASSOC. PRUDHOE BAY OFFICE PRUOHOE BAY, ALASKA i NOV. I:S, ICALE: I''1 MILE ~§Ii. AWN 11' : RG.T. CHECKED BY' i.E. i iL · 36 CERTIFICATE OF SURVEYOR I kearby certify that I ~ properly registered and licensed to I)roctice land surveying IR the State o~ Alaska end that this plat represents an propolad IDeation for the Well numbers shown above. Ail surveying was eons by me or under m~, supervision, and that ell dimensions end details ere correct. DRW. 116-85 SHEET Z of i0 REV. 0 NO TE$' 36 Indicates well I~dicates Celc[,leted Section Cer~er I~ositmn Indicates Per~ndiculer Off~t Dietetics I~dicetes ~diculer Off~t Distance )erpendicular ~istonc es tar PLAT ~ MPi PROPOSED WELL LOCATIONS L~CATED IN BEC.~&, T.I~ N.,R. IS [. UMIAT M. I~EPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED BY F.R. BELL & ASSOC. ' PRUDHOE BAY OFFICE PRUDHOE BAY, ALASKA DATE ' IlOV- I$, SCALE~ I". 60' DRAWN IY CHECKED BY" I.E:. IL -- 2 Y- 5982~79,88 N- 780~].~2 70~21'10.t8~4" 147°57'24,~2~7" 1135.43 ~- 259041.49 E- 464094.4~ 4 jY-5,,257,.69' N-7805,50.99 X- 2,90,5.76 E- 464092.74 70~21'~0'8~1' * 147'- 57 ' 24' 7856' j184''80' 2174'41- X- 259169.27 E- 4641~.95 i Y- 598256~.~0 N- 7805~48.47 70~21'10.8;68' ~47~57'24.9454' IB~2.17' 2179.g8 X- 2~9030,02 E- 464091.04 7 Y- 59824~7.B0 N- 78053~6.94 70~21'09.8200' 147~57'20.94~5' 19~.~2 2~916~.~4 E- 464152.24 J X" 2~9024.29 E~ 464089.33 9 Y- ~9B2449,&I N- 7B0~314.41 70021'09.7376" 147°~7'21.1g~4" ~9&1.19 204B.~3 X- 2~91~7.10 E- 464130.53 10 Y- 59B2~47.11 N- 7B0~343.42 70o21'10.6~21' 147c~7'2~.2&~1' lI~B.91 2190.B3 X- 2~901~.~5 E- 464~87.62 11 Y- ~9B2441.42 N= 7~05311.B9 70~21'09.6~53" 147°~7'21.26~3' ~970.26 20~4.00 X- 2~9152.07 E~ 464128.83 12 Y- ~9B2~38.92 N- 780~340.90 70c21'10.~697" 147°~7'2~.42~0" 1877.21 2196.30 X- 2~9012.~2 E- 46408~.92 1~ Y- ~982433.23 N- 780~309.36 70~21'09.57~0' 147°~7'21.42~1' 1978.63~ 20~9.47 X- 259~46.33 E- 464127.[2 14 Y- ~9B2530.73 Nm 7BO~33B.37 70~21'10.4874' 147°~7'2~.~B49' IBB~.&6 2201.77 " X- 2~9007,08 E' 4~4084.2t 1~ Y- 598242~.03 N- 780~306.B4 70c21'09.4906' 147c57'21.~B~0' 1987.00 2064.94 X- 259140.&0 E" 464125.42 ~6 Y" ~982~22.54 N' 780~33~.B5 70°21'~0.40~1" 347°57'2~.7447" ~194.03 2207.24 X" 259001.35 E" 464082.50 17 Y' ~982416.B4 N" 7B0~304.31 70°21'09.4083' ~47°57'21.7449" 1995.3B 2070.41 Zm 2~9134.16 E" 464123.71 1~ Y' 5982~14.3~ N' 7B0~333.32 70°21'10.3227" 147°57'25.904&" ~902.40 22~2.71 X' 2~8995.61 E' 464080.B0 19 Y' ~982408.65 N' 7B05301.79 70c21'09.3260" ~ 147°57'21.9047" 200~.7~ 2075.19 X" 2~9129.13 E~ 464122.00 20 Y' ~982~06.16 N' 7BO~3~O.gO 70c21'10.2404" 147~7'26.0644" 1910.77 221B. IB X' 2~8989.ff7 E~ 464079.09 21 Y' 5982400.46 N' 7B0~299.27 70°21'09.24~6" ~ 147o57'22.0&4&" 2012.12 20~1.36 X' 2~9123.39 E' 464120.30I~ . MPI PRO~SED WELL L~ATION LIST ~C ~ AL;~l- LOCATED IN SEC. 5e,T. IZN.,R.16E. UNIAT M. g''~~~~. ~ SOHIO ALASKA PETROLEUM CO. fa~. t ~194 '~ DRW. NO. 116-85 PREPARED aY DATE'NOV. 13, 1985 ~a~-~.~~ F.R BELL & ASSOC qh_~C~c .... ~t ~ ~ SHE ET 3 of IO ' · SCALE · N/A ~%~~ P RU DHOE BAY OFFICE oR~w~ BY' REV. 0 PRUDHOE BAY, ALASKA CHECKED m m .... , m ~ m PL, 7- BHI L~'PARTURE 255B' X=257, 325 Y=~ 984, 423 dd.f53' MD (d049~' TVD) SE£. 2~, Td~N, R,+6E TARGET DEPARTURE £3B7' X=257, 740 Y=5. 984, 245 d069.~' tdD (~0096' TVD) Td£N. Rd6E SURt--A£E LOC, AT. TON SLOT 2-34 Y=~. 98~. 449 Seaech Radius= 31'-'~ 7 DEGREE LEAD LINE Foe peoposed mell. P-14 [21-3&-12-1&] Location = W-E S-N TVD(SBS) Top 258750. O0 5982449. O0 -56. O0 Bottom 257291. 17 5984015. 29 9961. 06 Note' All depths in feet Below Kellg Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART A029-2023300 MI-SD3 10017. I 2281.4 ~249.0 7~. 0 A029-~024500 MI-SD4 10017. I 2281.4 10884.2 5653,2 A029-2028000 SI-DI1 6091.3 91.6 9276.8 3737,3 A029-2028001 SI-DI2 5500.0 0.5 6205.4 3041. 1 A02~-2051000 SI-DI3 426.0 0.0 400.0 1.6 A029-2051800 MI-SD7 2807.2 0.0 2799.? 14.6 A02~-~063900 MI-SD~ 1707.5 0.0 1700.0 3.3 MISDIO 4850.4 0.0 484~.~ 1063.4 A02~-2156800 MI-P18 3756.0 0.0 3756.0 0.0 SI-~35 3100.1 0.0 30~.5 25.4 A02~-2158500 MI-MI~ 2601.1 0.0 2600.0 7.4 A0~9-2158600 SI-M33 58~7. I 44.0 8756.0 4236. 1 A029-2160500 MI-n20 2900.5 0.0 2899.8 12.3 A02~-2162400 SI-02~ 6899.1 482.0 10149.4 5643.6 A02~-2162500 MI-G21 0.9 0.0 0.0 0.0 A02~-2163~00 MI-O16 ~900.5 44.8 5~02.5 19.3 A029-~164500 SI-N32 6186.7 121.6 9414.8 3636.~ CLOSEST DISTANCE 7166.8 1788.3 15334.1 I7112.8 23193.1 1579.2 1629.3 1~15.~ 158.7 16200.6 1~0.0 14283.7 208.3 11922.9 197.8 14145.2 SUMMARY The well which comes closest to the proposed well is:~Ui O/ ~,~OU ~ -F ~ ~', / ~ ,:Ja,d~a Oil & ~ Anchorage Closest approach distance = ~'~),'/ ~eet KICK OFF ~oe this run = 5450. 0 Feet ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND NELL P-14 (MPI) Interval Mud Neight Viscosity Fluid Loss (ppg) (sec/qt) (ml/3Omin) 0-2500 8.8-9.8 100-200 20-15 9.0-9.5 Mud Type/ Components Generic Mud //5 Seawater Fresh Nater Soda Ash Set 13-3/8" Casing 2,500 - 10,022 9.2-10.2 40-45 lO-12 10.0-10.5 Generic Mud //7 Seawater Fresh Mater Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Set 9-5/8" Casing 10,022 - 11,153 9.6-10.2 40-45 6-8 10.0-10.5 Generic Mud //7 Seawater Gel Caustic Soda Soda Ash Barite Li gnosu 1 fonate Dri spac Lignite Hang 7" Liner JGV/pm/l199D DOYON DR!LLiNG~ !NC. RIG NO. ~5 MUD AND SOLIDS CONTROL EQUIPMENT Equ i pmen t Manufacturer Nominal Model Capaci t~ Shaker Desander Hudcleaners Centrifuge Brandt Dual Double Demco 2-12" cones Tri Flow Double 8 each - 4' cones 1000 SPin 700 9pm ( each ) 40 0 gpm (each) Pioneer Mark II, 150 9pm Decant i n g Degasser Dril¢o Agi tarots Brandt Geo so u r ce Uacuum 1000 gpm 8 each - 25 h.p. Hoppers Dual Sidewinders ~000 9Pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drilling recorder system that contains visuaI and audio warnin9 devices located in the driIier's consoIe. 12 - 0 ~ -o' 16:c' · , IZ .c ' ,,t.(., iz : (,-' /D ' &' f[~..g. / li'~ ' O: it :S ' I1 '.,0 ' il7 -0 I I- 1 I i :._ ..~ Oil & Gas Cons. 6ommissic: ~ ~chorag.e _ I I J I . 1 I ~9 '-o ~LA~J V/£W- Z~ VEL Z TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4½" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG. 7) 1.) Make up the 13-1/8" x 4%" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the ~est plug through the B.O.P. stack until it lands on the lower load shoulder of the. split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG TFII$ E/VD UP L FMC P.N. 48-261-082 REQ'D PART NO. DESCRIPTION 1 48-261-268 Test Plug 1 48-261-083 Body 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing 1 51-092-001 2" Ball Check Figure #7 (Part number 48-261-082 continued on next page) FMC P.N. 48-261-082 continued REQ'D. PART NO. DEscRIpTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug .. 1 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 WP 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13½" X 4½" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13%" x 4½" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG FMC P.N. 48-261-068 REQ'D PART NO. DESCRIPTION 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check -- 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring . . 2 48-180-027 Pipe Plug HIS END UP Figure #19 ILLUSTRATION# 13 B.O.P. STACK ......... ~]'13-5/8" 5000 WP 13-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4½" IF test plug (combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown acres which have been run in. 6.) Remove the test plug. .-Jaska Oil & Gas Cons. Commlssir: Anchorage 10" CO_~4BINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING 'FOOL THIS END UP FMC PART NO. 48-261-503 REQ'D. PART NO. DESCRIPTION 1 48-261-504 BODY 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. 1 48-180-025 PLUG, 1¼ L.P. 4 t 48-180-015 PLUG, ½ L.P. ,. 1 48-010-009 WRENCH , (Figure #22A) ~ B.O.P. STACK 1" 5000 WP 13-5/8" 3000 STACK - 11" 5000 WP ~_ 11" 5000 WP 13-5/8" 3000 WP ITEM APPROVE DATE (1) Fee y~'~'~ ! ~-7 -~ k 1. (2) Loc ~t~-~ t~-]-fk hruS) . 3. 4. 5. 6. 7. 8. (3) AdnRn ~-- ! a-p-~L 9. (9 thru 13) 10. ~(10 and 12{)z 12. 13. (4) Casg ~,¢~.~/, /a-F-~g (14 thru 22) (23 thru 28) (6) 01~ /~/, ~o. (29 31) Geology: WV^ JAL~ · Company~/~b~ C YES Is the pemit fee attached .......................................... ~ Is well to be located in a defined pool ............................. ~ Is well located proper distance from property line ....... Is well located proper distance from other w~lls .. . Is sufficient undedicated acreage available in this'~i' Is well to be deviated, and is wellbore plat included .... . Is operator the only affected party ................................. ~ Can permit be approved before fifteen, day wait ...................... ~ rev: 07/18/86 6.011 Lease & Well No.~ · , 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 ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of ~~ B~PE attached. Does BOPE have sufficient pressure rating - Test to ~°°~Z~oom psig .. Does the choke manifold comply w/API RP-53 (May 84)... f'. ............. Is the presence of H2S gas probable ................................. 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- 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/O~% POOL CLASS STATUS AREA NO. SHORE Additional 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. LIS TAPE VERIFICATION LISTING .VP 010.H02 VERIFICATION LISTING PAGE ~: REEL HEADER $$ ~ERVICE NAME :EDIT DATE :86/11/11 ]RIGIN : REEL N~ME :T20~3 CONTINUATION ~ PREVIOUS REEL : COMMENTS :LIS TAPE, STANDARD ENDICOTT P-i4 MPI, API 50-029-21662 ~ TAPE HE~DER ¢~ SERVICE NAME :EDIT DATE :86/11/11 ORIGIN :T204 TAPE NAME : CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :LIS T~PE, STANDARD ENDICGTT P-I~ MPI, API 50-029-21662 ~ FILE HEADER ~ FILE NAME :EDIT .001 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS UNIT TYPE CATE SIZE CODE CN : STANDARD ALASKA PRODUCTION CO. 000 000 030 065 WN : 2-34/P'-14 MPI OOO 000 014 065 FN : ENDICOTT 000 000 008 065 RANG: 16E 000 000 004 065 TOWN.: 12N 000 000 004 065 SECT: 36 000 000 002 065 COUN:: NORTH SLOPE 000 O00 O~Z 065 STAT: ALASKA 000 000 006 065 CTRY: USA 000 000 004 065 MNEM CONTENTS PRES: E UNIT TYPE CATE SI ZE CODE Ifil fill II,I! IItI 000 '0.00 001 065 .VP OlO.HO2 VERIFICATION LISTING PAGE ~ SCHLUMB E R GE R .,,~. ) ALASKA COMPUTING CENTER ~. :OMPANY = STANDARD AL.ASKA PRODUCTION CO ~ELL = 2-34/P-14 MPI :IELD = EN2ICOTT COUNTY = NORTH SLOPE .BOROUGH ~TATE = ~LASKA JOB NUMBER AT ACC: T2043 ~UN ~1, DATE LOSGEO: O? NOV 86 .DP: RICK KRUWELL SASING ~YPE FLUID ]ENSITY ¢ISCOSITY ~H mLUID LOSS mATRIX SANDSTONE : 9.625" @ 10111' - BIT SIZE : 8.5" TO 11242' : SEAW.&TER = 9.7 'LB/G RM = .5t5 @ 76 DF = 38 S RMF = .402 @ 76 DF : 10.5 RMC : °685 @ 76 DF : 6-6 C3 RM AT 8HT : .217 @ 190 DF ~DTE: PgRTIONS OF REPEAT FiLE HAVE BEEN SPLICED INTO LOG FILE DUE TO DLL,LDT/CNL,NGT TOOL STRING STICKING. =ILE EDIT.O01 CONTAINS DAT.& SAMPLED @ .5' S~MPLE RATE _VP OlO.H02 VERIFICATION LISTING PAGE 3 :ILE :DIT.O02 CONTAINS DATA SAMPLED @ .167° SAMPLE RATE :IL~ EDIT.O03 CONTAINS DATA SAMPLED @ .0416' SAMPLE RATE ,- ........ ,- THIS DATA HAS BEEN DEPTH SHIFTED TO DUAL LATEROLOG ~¢.-;~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE': DUAL LATERLOG (DLL) DATA AVAILABLE: 11238' TO 10102' ARRAY SONIC LOG (SOT) DATA AVAILABLE: 11237' T~ 10102' LITHO DENSITY COMPENSATED LOG CLOT) COMPENSATED NEUTRON LOG (LDT) DATA AVAILABLE: 11207' TO 10102, NATURAL GAMMA TOOL (NGT) DATA AVAILABLE: 11177' TO 10102' GAMMA RAY IN CASING (GRoCSG) DATA AVAILABLE: 10102' TO 9590' .VP OlO.H02 VERIFICATION LISTING PAGE ~: DATA FORMAT RECORD ENTRY BLOCKS TYPE 2 4 16 0 DATUM MNEM DEPT LLD LLS SP CALS $I0 SVO DIO DVO DVl MRES MTEM SGR TENS TENS SGR CALI CGR LU LL LS LI TH SSI SS2 LS HV SSHV QSS QLS PEF RHOB DRHD DPHI RNRA DC NL NC NL SPECIFICATION SERVICE SERVICE ID ORDER # OLL DLL OLL DLL DLL DLL DLL DLL DLL DLL DLL DLL DLL LOT LOT LOT LOT LOT LDT LOT LOT LOT LOT LOT LOT LDT LOT 'LOT LOT L D'T :L D' T LOT LOT :L D T BLOCKS UNIT FT OHMM OHMM MV' IN MV UA MV MV OHMM DEGF GAPI LB GAPI IN' G,~P I CPS CPS CPS CPS CPS CPS V V G/C 3 G/C3 PU' C PS CPS PI OG O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 SIZE 1 1 4 4 1 1 REPR CODE 66 66 73 65 66 66 API API API FIL TYPE CLASS MOD NO 000 O0 0 0 220 10 0 0 220 Og 0 0 010 O1 0 0 000 O0 0 0 000 O0 0 0 000 00 0 0 000 O0 0 0 000 O0 0 0 000 O0 0 0 823 50 0 0 660 50 0 0 310 O1 0 0 635 21 0 0 635 21 0 0 310 O1 0 0 28O O1 0 0 '310 O1 0 0 354 O1 0 0 354 01 0 0 354 O1 0 0 354 O1 ,0 0 000 O0 0 0 000 O0 0 0 0 O0 O0 0 0 000 O0 0 0 000 O0 0 0 000 O0 0 0 3:58 O1 0 O 350 02 0 0 .356 01 0 0 890 O0 0 0 000 O0 0 0 330 30 0 0 330 31 0 0 ENTRY 0 1 6O .lin 1 0 SIZE SPL 4 1 4 1 4 1 4 1 4 4 1 4 t 4 1 4 1 4 1 4 1 4 4 1 4 4 1 4 1 4 ! 4 1 4 1 4 1 4 4 1 4 1 4 4 1 4 t 4 1 4 1 4 1 4 4 1 4 1 4 4 1 4 1 REPR PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 000000~00000000 68 00000000000000 68 00000:000000000 68 00000000000000' 68 O00000000OO000 68 00000000000000 68 00000000000000 68 00000000000000 68 0000000000'000~0 68 0000000000000'0 68 00000000000000 68 00000000000000 68 000'00000'000000 68 00000000000000 68 00000000000000 68 0000000000000'0 68 00000000,000000 68 0000~00,00000000 68 0000000'0000000 68 000'00000000000 68 00000000000000 68 '00000000000000 68 00000000000000 68 000:0000'0000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 _VP OlO.H02 VERIFICATION LISTING PAGE 5 qRAT LDT O0 qPHI LDT PU O0 MRES LDT OHMM O0 ~TEM LDT gEGF O0 TENS NGT LB O0 ~SNG NGT CPS O0 ~4NG NGT CPS O0 ~3NG NGT CPS O0 ~2NG NGT CPS O0 dING NGT CPS O0 JRAN NGT PPM O0 THOR NGT PPM O0 ,~OTA NGT PU 00 POT~ VOL PU O0 MRES NGT OHMM O0 MTEM NGT DEGF O0 SGR NGT GAPI O0 CGR NGT GAPI O0 CS NGT F/HR O0 DT SOT US/F O0 DTCO SOT US/F O0 LSDT CDT gS/F O0 LDTL SOT US/F O0 DTL SDT US/F O0 DTST SDT US O0 DTSM SOT US/F O0 GR CDT GAPI O0 TENS CDT LB O0 MRES SDT OHMM O0 MTEM SDT DEGF O0 GR CSG GAPI O0 TENS CSG LB O0 42 89 82 66 63 31 31 31 31 31 79 79 71 71 82 31 31 63 52 O0 52 52 52 O0 53 31 82 66 31 63 OAT 4 ~:~ DEPT 11262.0000 LLD CALS -9'99.2500 SlO DVO -999.2500 OVl SGR 0.0000 TENS CALl -999.2500 CGR LS -999.2500 LITH LSHV -999.2500 SSMV ~EF -999,2500 RHOB RNRA -999.2500 FCNL qPHI -999.2500 MRES ~SNG 4.5242 WANG ~ING 263.6406 URAN ~OTA 0..0000 MRES CGR 0.0000 CS ~.SDT 102.902'3 LDTL ]TSM O.OOOO GR ~iTEM -999,2500 GR -999. -999. -999. -999. 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EXT T~PE NAME : 9MMENTS :LIS TAPE, STANDARD ENDICOTT P-14 MPI, .API 50-029-21662 ~: REEL TRAILER ~ ~ERVICE NAME :EDIT )ATE :86/11/11 ]RIGIN : ~EEL NAME :72043 :ONTINUATIQN # :OI ~EXT REEL NAME : :OMMENTS :LIS TAPE, STANDARD ENDICOTT P-14 MPI.~ API 50-02g-21562 :Tape Subfile 2 is type: LIS 7~APE H~ER E?~DICOTT UNIT CASED :0LE WIRELINE LOGS :.~OGGING COMPANY: ~APE CREATION DATE: JOB Nt~4BER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 2 - 34/P - 14 500292166200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 05-SEP-95 6092.03 D. BARBA J. POWERS 36 12N 16E 1969 2256 56.00 55.OO 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10111.0 47.00 7.000 11242.0 29.00 5.500 9590.0 17.00 4.500 10792.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 07-NOV- 86 UNKNOWN BASELINE DEPTH 10393.0 10398.5 10402.5 10405.0 10410.5 10414.0 10422.5 10445.5 10447.5 10451.5 10459.5 10463.0 10468.5 GRCH 10393.0 10398.5 10402.5 10405.5 10411.0 10414.5 10423.0 10445.0 10448.0 10451.5 10459.0 10463.0 10468.5 EQUIVALENT UNSHIFTED DEPTH 10476.0 10480.0 10486.0 104~9.0 10 i ~:-1.0 -- ~ .~3.0 - ~7.5 ~.-;5- ~; ~,0.0 ~ C;~07.5 10514.5 10519.5 ~.u~31.5 10534.0 10539.0 10547.0 10554.0 10557.5 10565.5 10601.5 10604.0 10606.5 10609.5 10611.5 10613.5 10617.5 10632.0 10642.5 10658.0 10664.5 10684.0 10699.5 10714.0 10725.5 10729.5 10755.5 10761.5 10764.0 10767.0 10782.5 10786.0 10788.5 10844.5 10846.5 10896.0 10898.5 10906.0 10910.5 10916.0 10920.0 10929.5 10939.5 10998.5 11005.5 11011.0 11014.0 11028.0 11030.0 11035.5 11051.0 11054.0 10475.0 10479.5 10486.0 10489.0 10491.5 10493.0 10497.0 10499.5 10507.0 10513.5 10519.5 10531.0 10533.5 10538.5 10546.5 10553.5 10557.0 10564.5 10600.0 10603.0 10605.0 10608.0 10611.0 10612.5 10616.5 10631.0 10640.5 10656.0 10663.0 10681.5 10696.5 10711.0 10724.5 10728.5 10754.0 10759.5 10763.0 10766.0 10782.5 10785.5 10788.0 10843.0 10845.5 10896.0 10899.0 10906.0 10910.0 10916.0 10920.0 10929.5 10939.5 11000.0 11007.0 11012.5 11016.0 11029.5 11031.5 11037.0 11052.5 11056.0 11056.5 11062.5 11065.0 11071.0 1~ '~6.0 - :-09.0 11058.5 110'64.5 11067.0 11073.0 11077.5 11109.5 PDK-100/GR. TIED INTO CBT DATED 12-NOV-86. WELL SHUT-IN WHILE LOGGING. LOGGING SUITE ORGANIZATION: 1) 3 SHUT-IN PASSES. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL THREE PASSES. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 0.0 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL THREE PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ? ?MATCH1A. OUT $ FILE HEADER ~ ~LE NUMBER: 1 ¥ ~>iTED CURVES ~ ~.~th shifted and clipped curves for each pass in separate files. ?~ ~ · ~UMBER: 1 ~ INCREMENT: .5000 .i~i.~ SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10388.0 10400.0 BASELINE DEPTH SGMA 10402.5 10402.5 10405.0 10405.5 10410.5 10411.0 10414.0 10414.5 10422.5 10423.0 10445.5 10445.0 10447.5 10448.0 10451.5 10451.5 10459.5 10459.0 10463.0 10463.0 10468.5 10469.0 10476.0 10475.0 10480.0 10479.5 10486.0 10486.0 10489.0 10489.0 10491.0 10491.5 10497.5 10497.0 10500.0 10499.5 10507.5 10507.0 10510.5 10509.0 10514.5 10513.5 10519.5 10519.5 10531.5 10531.0 10534.0 10533.5 10539.0 10538.5 10547.0 10546.5 10554.0 10553.5 10557.5 10557.0 10565.5 10564.5 10592.5 10592.5 10596.5 10596.5 10601.5 10600.0 10604.0 10603.0 10606.5 10605.0 10609.5 10608.0 10611.5 10611.0 10613.5 10613.0 10617.5 10616.5 10631.5 10630.0 STOP DEPTH 11112.0 11124.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... 10642.5 10658.0 10664.5 10684.0 10~99.5 ~7714.0 ~725.5 10729.5 10755.5 10761.5 10764.0 10767.0 10782.5 10786.0 10788.5 10830.5 10844.5 10846.5 10896.0 10898.5 10906.0 10910.5 10916.0 10920.0 10929.5 10939.5 10998.5 11006.0 11011.0 11014.0 11028.0 11030.0 11035.5 11051.0 11054.0 11056.5 11062.5 11065.0 11071.0 11076.0 11080.5 11082.0 11109.0 11114.5 $ 10640.5 10656.0 10663.0 10681.5 10696.5 10711.0 10724.5 10728.5 10754.0 10759.5 10763.0 10766.0 10782.5 10785.5 10788.0 10830.0 10843.0 10845.5 10896.0 10899.0 10905.5 10910.0 10916.0 10920.0 10928.5 10939.5 11000.0 11008.0 11012.5 11016.0 11029.5 11031.5 11036.0 11052.5 11056.0 11058.5 11064.5 11067.0 11073.0 11077.5 11082.5 11084.5 11109.5 11116.0 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH1B. OUT $ : BP EXPLORATION : 2 - 34/P - 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ~;E DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 $ MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 111 Tape File Start Depth = 11140.000000 Tape File End Depth = 10366.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26334 datums Tape Subfile: 2 384 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS ~ZLE H~DER FiLE ~ ~BER: 2 EDI~ CURVES ~.~%h shifted and clipped curves for each pass ~'sS ~.~3]~BER: 2 i.:i£PTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10388.0 10400.0 STOP DEPTH 11112.0 11124.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 10383.0 10383.0 10392.5 10392.5 10393.0 10395.0 10397.5 10399.5 10398.0 10400.5 10402.0 10404.5 10403.0 10405.0 10405.0 10404.5 10407.0 10411.0 10413.5 10411.5 10414.5 10424.5 10427.5 10425.0 10427.5 10425.5 10428.0 10430.5 10433.0 10435.0 10437.0 10444.5 10446.0 10446.5 10445.5 10447.0 10448.0 10450.5 10452.5 10455.0 10453.5 10455.5 10458.0 10460.0 10461.5 10463.5 10463.5 10466.0 10468.0 10470.5 10471.5 10473.5 10472.5 10474.0 10476.0 10477.5 10478.0 10479.5 10479.5 10481.5 10480.5 10482.0 10483.0 10485.0 10483.5 10486.0 10484.0 10486.0 10485.5 10487.5 10489.0 10491.0 10490.5 10492.5 10491.5 10494.0 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 10493.0 10494.0 10497.5 10504.0 ~'~i05.0 - ~07.5 i...~-508.5 i~510.5 10511.5 10514.0 10514.5 10516.5 10517.5 10518.0 10521.5 10522.0 10522.5 10523.5 10537.5 10538.0 10540.0 10541.0 10552.5 10558.5 10560.5 10565.0 10566.5 10571.5 10575.5 10583.0 10584.5 10585.5 10587.5 10588.0 10589.5 10595.5 10596.5 10599.5 10600.0 10601.5 10605.0 10606.0 10608.5 10609.0 10610.5 10611.0 10622.5 10623.5 10635.5 10636.5 10637.0 10664.0 10664.5 10665.0 10667.5 10670.0 10673.0 10675.0 10686.0 10687.5 10495.5 10499.0 10512.0 10512.5 10517.5 10539.0 10540.0 10542.0 10542.5 10560.0 10585.0 10585.5 10587.5 10588.5 10600.0 10601.0 10606.0 10606.5 10611.0 10612.0 10638.0 10664.5 10668.0 10673.0 10674.5 10686.0 10687.0 10496.0 10506.0 10506.5 10509.0 10509.5 10515.0 10516.0 10519.0 10520.0 10523.5 10524.5 10525.0 10525.5 10554.5 10562.0 10566.0 10567.5 10573.0 10577.0 10585.5 10592.0 10598.0 10598.5 10602.5 10609.5 10610.5 10624.0 10624.5 10636.5 10637.0 10665.0 10666.0 10671.0 10693.0 10697.5 10710.5 107!1.0 10"~15.0 ?~ 16.5 ~ 20.5 10734.0 10742.0 10745.0 10747.0 10747.5 10748.0 10752.5 10753.0 10754.5 10759.5 10761.0 10763.5 10766.5 10769.0 10770.0 10776.0 10778.0 10779.5 10783.5 10784.0 10785.0 10786.0 10791.0 10792.0 10793.0 10797.0 10800.0 10807.0 10824.0 10830.0 10833.0 10834.5 10836.5 10845.5 10846.5 10847.5 10848.0 10848.5 10850.0 10852.5 10853.0 10857.5 10864.5 10875.5 10876.0 10877.0 10890.0 10890.5 10893.5 10897.5 10898.0 10898.5 10692.5 10696.5 10710.0 10724.5 10743.0 10745.5 10748.0 10748.5 10762.0 10764.5 10768.0 10770.5 10777.5 10780.0 10785.0 10787.5 10798.5 10801.0 10831.0 10835.0 10846.0 10851.5 10866.0 10877.5 10878.0 10878.5 10892.0 10895.0 10900.0 10710.0 10710.5 10715.0 10716.5 10722.0 10735.5 10748.5 10753.5 10754.5 10756.0 10760.5 10771.0 10782.0 10786.5 10787.0 10793.0 10793.5 10794.5 10808.0 10826.0 10835.0 10837.5 10847.5 10848.0 10848.5 10849.5 10853.5 10854.5 10859.0 10892.5 10900.0 10900.5 10907.5 10908.5 10913.0 10913.5 !C- 24 · 5 ~ 25.5 ~i 534.0 i~. ~36.0 10940.5 10946.0 10949.0 10954.5 10971.0 10973.0 10976.0 10986.5 10988.5 10998.5 11006.0 11011.0 11029.0 11029.5 11034.0 11041.5 11051.5 11056.5 11062.5 11067.0 11070.0 11072.0 11076.0 11082.0 11096.0 11106.5 11107.5 11115.0 $ REMARKS: 10909.5 10910.0 10914.5 10915.5 10926.5 10927.0 10935.5 10938.5 10942.5 10948.5 10951.5 10957.5 10974.0 10975.5 10978.5 10989.0 10992.0 11002.0 11010.0 11014.5 11032.5 11033.0 11037.0 11044.5 11055.0 11060.5 11066.5 11070.5 11074.0 11075.5 11079.0 11086.0 11099.5 11109.5 11111.0 11118.5 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ? ?MATCH2 B. OUT $ CN : BP EXPLORATION WN : 2 - 34/P - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ~ GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 i 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 111 Tape File Start Depth = 11140.000000 Tape File End Depth = 10366.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26334 datums Tape Subfile: 3 338 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS ~iLE ~-EADER FILE ~BER: 3 ED!- ~ CURVES ~,~_~sh shifted and clipped curves for each pass ~.$5 ~; 'J~BER: 3 ~EPTH iNCREMENT: .5000 FILE Sb74MARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10388.0 10400.0 STOP DEPTH 11112.0 11124.0 (MEASURED DEPTH) BASELINE DEPTH 10392.5 10394.0 10395.5 10396,0 10402.5 10405.5 10406.0 10411.0 10411.5 10424.5 10425.0 10425.5 10430,5 10435.0 10444.5 10447.5 10448.0 10450.0 10452.0 10452.5 10453.5 10458.0 10463.0 10463.5 10468.0 10468,5 10472.0 10474.5 10476.0 10478.0 10479.0 10479.5 10483.0 10483.5 10485.0 10487.0 10489.0 GRCH 10392.5 10396.0 10397.5 10398.5 10408.0 10409.0 10428.0 10449.0 10452.5 10454.5 10465.5 10470.5 10474.0 10476.0 10480.5 10487.5 10489.5 10491.5 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 10405.0 10413.5 10414.5 10427.5 10428.0 10433.0 10437.0 10446.5 10450.5 10455.0 10455.5 10460.0 10466.0 10470.5 10477.5 10479.5 10481.5 10485,0 10486.0 10491.0 10491.5 10492.5 10494.0 1C~!97.0 ~ 00.0 ~ i~O1.5 ~ ~ ~ © 4.0 ~05.0 10505.5 10507.5 10508.5 10514.0 10514.5 10516.0 10517.5 10518.0 10518.5 10519.5 10520.0 10523.5 10534.0 10543.5 10550.0 10550.5 10552.5 10554.0 10560.5 10565.0 10566.5 10568.5 10571.5 10575.5 10583.0 10586.5 10587.0 10587.5 10588.5 10595.5 10596.5 10601.5 10608.5 10609.0 10610.0 10615.5 10617.0 10620.0 10622.5 10623.5 10632.5 10635.5 10636.5 10637.0 10664.5 10665.0 10669.5 10670.0 10697.0 10703.0 10710.5 10493.5 10495.5 10499.0 10501.5 10503.5 10507.5 10509.0 10517.5 10519.5 10520.5 10522.0 10535.5 10545.5 10551.5 10552.0 10555.5 10569.5 10587.5 10588.5 10589.0 10589.5 10611.0 10617.0 10618.5 10621.5 10633.5 10638.0 10670.5 10696.5 10702.5 10494.0 10496.0 10506.0 10506.5 10509.0 10509.5 10515.0 10516.0 10519.0 10520.0 10525.5 10554.5 10562.0 10566.0 10567.5 10573.0 10577.0 10585.5 10598.0 10598.5 10602.5 10609.5 10610.5 10624.0 10624.5 10636.5 10637.0 10665.0 10666.0 10671.0 10710.0 10711.0 10714.0 10715.0 10716.0 ~ ....16.5 ~17.5 719.5 i~ 720.5 .~ --726.0 10734.0 10736.0 X©737.0 10747.0 10747.5 10749.5 10752.5 10753.0 10754.5 10759.5 10761.0 10766.0 10766.5 10770.0 10779.5 10784.0 10785.0 10789.5 10790.5 10791.0 10793.0 10807.0 10822.0 10823.0 10824.0 10833.0 10836.5 10842.0 10842.5 10843.0 10846.0 10846.5 10848.5 10850.0 10852.5 10853.0 10857.5 10874.0 10874.5 10890.0 10893.5 10896.5 10897.5 10898.5 10901.5 10902.0 10906.0 10907.0 10915.5 10916.0 10924.5 10713.5 10716.0 10718.0 10720.0 10727.5 10737.5 10738.0 10748.0 10750.0 10762.5 10767.5 10768.5 10791.5 10792.0 10823.5 10824.0 10843.0 10843.5 10844.0 10847.0 10851.5 10875.5 10876.5 10895.5 10899.0 10904.0 10909.0 10917.5 10918.5 10710.5 10715.0 10716.5 10722.0 10735.5 10748.5 10753.5 10754.5 10756.0 10760.5 10771.0 10782.0 10786.5 10787.0 10793.0 10794.5 10808.0 10826.0 10835.0 10837.5 10847.5 10849.5 10853.5 10854.5 10859.0 10892.5 10900.0 10900.5 10904.5 10908.0 10926.5 10925.5 10934.0 10936.0 10937.5 !0a46.0 ~' 50.0 '51.0 10989.0 10989.5 10992.0 10993.5 10994.0 10998.5 11006.0 11011.0 11027.5 11029.0 11029.5 11034.0 11037.0 11041.5 11051.0 11051.5 11054.0 11056.5 11062.5 11067.5 11076.5 11082.0 11096.0 11102.0 11103.0 11104.5 11106.5 11107.5 11114.5 $ REMARKS: 10927.0 10936.5 10935.5 10938.5 10938.5 10939.5 10948.5 10953.0 10954.0 10957.5 10974.0 10992.5 10993.0 10995.0 10996.5 10997.5 11002.5 11010.0 11015.0 11031.0 11032.5 11033.0 11037.0 11040.5 11044.5 11055.0 11055.5 11057.5 11060.5 11060.5 11066.5 11066.5 11071.0 11080.5 11086.5 11099.5 11105.5 11106.0 11107.5 11109.5 11111.0 11118.0 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH3A. OUT /??MATCH3B.OUT $ CN : BP EXPLORATION WN : 2 - 34/P - 14 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves:, Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod '~ GRCH PDK 68 1 GAPI 4 ~ BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 mmm~m~m 64 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 111 Tape File Start Depth = 11140.000000 Tape File End Depth = 10366.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52668 datums Tape Subfile: 4 340 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FiLE >~-~IADER FiLE uMBER: 4 AVE'- i~ED CURVES '~ensated Neutron: Arithmetic average of edited passes for all curves. ?-~.-~sed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; a~:ithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: CN WN ~FN COUN STAT 1 1, 2, 3 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ : BP EXPLORATION : 2 - 34/P - 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 SS PNAV 68 1 CPS 4 8 MSD PNAV 68 1 CU 4 9 RATO PNAV 68 1 4 10 RBOR PNAV 68 1 4 11 RICS PNAV 68 1 4 12 RIN PNAV 68 1 4 13 SGMA PNAV 68 1 CU 4 14 SGMB PNAV 68 1 CU 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 111 ~ape File Start Depth = 11140.000000 Yape File End Depth = 10366.000000 ape File Level Spacing = 0.500000 ~?ape File Depth Units = Feet **~* FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52668 datums Tape Subfile: 5 133 records... Minimum record length: 62 bytes Maximum record length: 958 bytes T~pe Subfile 6 is type: LIS '~[LE ¥-'-: ~DER i~:. r~LE i :~4BER: 5 ~: ~- ~- ~{VES ~ .~::-ves and log header data for each pass in separate files; raw background >~;.::~:_~: in last file. :..!: ~ NU/IBER: 1 i. ;_PTH INCREMENT.' .2500 FiLE SUMMARY VENDOR TOOL CODE START DEPTH GR 10382.0 PDK 10394.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11124.5 11136.5 22-AUG-95 FSYS REV. J001 VER. 1.1 1112 22-AUG-95 11160.0 11132.0 10400.0 11124.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 11242.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT),: .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 8000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 STANDOFF (IN): .0 RE~S: PASS 1. NEAR COUNT RATE HIGH SCALE (CPS) = 120,000 $ CN WN FN COUN STAT : BP EXPLORATION : 2- 34/P- 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 G1 PDK 68 1 CPS 4 10 G2 PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 51 310 01 4 51 391 51 4 51 390 51 4 51 995 99 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 01 4 51 995 02 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 636 99 4 51 635 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 308 ~pe File Start Depth = 10372.000000 ~pe File End Depth = 11140.000000 ~ape File Level Spacing = 0.250000 ~iape File Depth Units = Feet ~*** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 129494 datums Tape Subfile: 6 384 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE V?JMBER: 6 RA~ .J¥~VES ~rves and log header data for each pass in separate files; raw background ~,~= in last file ~ASS NUMBER: 2 i~EPTH INCREMENT: ·2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10384.0 PDK 10396.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11126.5 11138.5 22-AUG-95 FSYS REV. J001 VER. 1.1 1212 22-AUG-95 11160.0 11132.0 10400.0 11124.0 900.0 YES TOOL NUMBER 3913NA 2725XA .0O0 11242.0 .0 PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .OO0 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 8000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REd.ARKS: PASS 2. NEAR COUNT RATE HIGH SCALE (CPS) = 120,000 $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 34/P - 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 G1 PDK 68 1 CPS 4 10 G2 PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 51 310 01 4 51 391 51 4 51 390 51 4 51 995 99 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 01 4 51 995 02 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 636 99 4 51 635 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 311 ~ape File Start Depth = 10366.000000 ape File End Depth = 11142.000000 '?ape File Level Spacing = 0.250000 ?ape File Depth Units = Feet ~*** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 130294 datums Tape Subfile: 7 387 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE ~JMBER: 7 RA~ ~RVES ., i~ves and log header data for each pass in separate files; raw background ~.~s in last file. ~As~ N~MBER: 3 3EPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10383.0 PDK 10395.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11126.5 11138.5 22-AUG-95 FSYS REV. J001 VER. 1.1 1312 22-AUG-95 11160.0 11132.0 10400.0 11124.0 900.0 YES TOOL NUMBER 3913NA 2725XA .OO0 11242.0 .0 PRODUCED FLUIDS .00 .0 .0 0 .0 .0O0 .OO0 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT) : .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 8000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 ~-~OOL STANDOFF (IN): .0 REMARKS: PASS 3. NEAR COUNT RATE HIGH SCALE (CPS) = 120,000 $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 34/P- 14 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 G1 PDK 68 1 CPS 4 10 G2 PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 51 310 01 1 4 51 391 51 1 4 51 390 51 1 4 51 995 99 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 390 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 636 99 1 4 51 635 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 311 ?ape File Start Depth = 10366.000000 ?ape File End Depth = 11142.000000 ?ape File Level Spacing = 0.250000 ~?ape File Depth Units = Feet ~*** FILE TRAILER **** LiS representation code decoding summary: Rep Code: 68 207120 datums Tape Subfile: $ 387 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 9 is type: LIS 95/ 9/05 01 **** REEL TRAILER **** 95/ 9/ 5 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 5 SEP 95 5:15p Elapsed execution time = 5.21 seconds. SYSTEM RETURN CODE = 0