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Home My WebLink About194-128Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2026.01.21 14:19:22 - 09'00' Sean McLaughlin (4311) 326-043 By Grace Christianson at 2:50 pm, Jan 21, 2026 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Open hole window milling not to exceed 15'. TS 1/22/26 DSR-1/22/26J.Lau 1/29/26 10-407 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 21, 2026 Re:DIU MPI 1-23 Sundry Request Sundry approval is requested to set a whipstock in the DIU MPI 1-23 wellbore as part of the drilling and completion of the proposed DIU MPI 01-23A CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper and MIT. E-line will set a 4- 1/2"x7-5/8" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window pre-rig, the rig will perform that work. See DIU MPI 1-23A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2"x7-5/8" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling and lands in the Kekiktuk. The lateral will continue in Kekiktuk to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Endicott Oil Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in February 2026) 1. Slickline : Dummy WS drift and Caliper (done) 2. Fullbore : MITxIA to 3,261 psi (done - passed) 3. E-Line : Set 4-1/2"x7-5/8" Whipstock top at 10,343 MD (10,350' MD pinch point) at 0 degrees ROHS 4. Coil : Mill 3.80" Single String window in 7-5/8" (if window not possible, mill with rig). 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: Reference 01-23A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,944 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80 Single String 7-5/8" Window (if not already done pre-rig) 3. Drill build section: 4.25" OH, ~266' (30 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,699' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2 x 3-1/4 x 2-7/8 13Cr solid liner. 6. Pump primary cement job*: 56 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP* (if ran in completion). If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 7. Only if not able to do with service coil extended perf post rig Perforate Liner with 1-1/4" CS Hydril 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig RPM, CBL and perforate (~50) 3. Slickline : Set LTP* (if necessary). Set live GLVs. Set SSSV. 4. Operations : Install Wellhouse & FL 5. Testing : Portable test separator flowback. * Alternate plug placement variance request per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 10,800' Well Date Quick Test Sub to Otis - Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular CL Annular Bottom Annular CL Blind/Shears CL Coiled Tubing Pipe / Slips Kill Line Choke Line CL BHA Pipe / Slip CL Coiled Tubing Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR#-AC BOP Schematic CDR Rig's Drip Pan Fill Line Normally Disconnected HP hose to Micromotion LP hose open ended to Flowline (optional) Hydril 7 1/16" Annular Blind/Shear CT Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross CT Pipe/Slips BHA Pipe / Slips nneeeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' 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 1-23 DUCK IS UNIT MPI 1-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 1-23 50-029-22510-00-00 194-128-0 W SPT 9502 1941280 2376 2277 2275 2260 2281 267 467 465 460 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 1-23 Inspection Date: Tubing OA Packer Depth 742 2750 2721 2714IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230403174825 BBL Pumped:2.3 BBL Returned:2.1 Friday, May 19, 2023 Page 1 of 1            State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Endicott DIU MPI 1-23 Date: 4/22/2019 _ PTD: 1941280 Operator: Hilcorp Type Inspection: MIT Operator Rep: Larry McBride Inspector: Jeff Jones , Position: Lead Operator Op. Phone: (907) 715-6950 Correct by (date): Op. Email: Imcbride@hilcorp.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected Slight crude oil leak @ stem seal on swab valve. Cleaned and serviced swab valve stem seal. Deficiency report was received on 5/3/19. 4/26/2019 Attachments: none Signatures: Robert L Anderson, Dan Wikner Operator Rep A�/Z? 1q_ AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Endicott DIU MPI 1-23 Date: 4/22/2019 ' PTD: 1941280 Operator: Hilcorp Type Inspection: MIT Operator Rep: Larry McBride Inspector: Jeff Jones ' Position: Lead Operator Op. Phone: (907) 715-6950 Correct by (date): Op. Email: Imcbride@hilcoro.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected Slight crude oil leak @ stem seal on swab valve. Attachments: none Signatures: Operator Rep fv ILI? 1�_, AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim Regg 2 /, _ p DATE: Wednesday, May 8, 2019 To P.I. Supervisor ' �a/l1 7I tAq SUBJECT: Mechanical Integrity Tests ( HILCORP ALASKA LLC 1-23 FROM: Jeff Jones DUCK IS UNIT MPI 1-23 Petroleum Inspector Sre: Inspector Reviewed By,: P.I.Supry .J - NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-23 Insp Nam: mitJ1190503123508 Rel Insp Num: API Well Number 50-029-22510-00-00 Permit Number: 194-128-0 Packer Depth Pretest Initial Well j 1-zs -- Type Inj w+'TVD 9502 - g- 2267 - -2255 PTS - 1941280 "Type Test SPT ,Test psti 2376 IA nu BBL Pumped: —1.7 iBBL Returned: 13 OA L 450 600 - Returned: BBL -- - Interval 4YRTST IP/F P �J Notes: I well inspected, slight crude oil leak at s ab valve stem packing. ✓ Inspector Name: Jeff Jones Inspection Date: 4/22/2019 15 Min 30 Min 45 Min 60 Min 210 2263 .691 - 2689 600 600 Wednesday, May 8, 2019 Page I of 1 • • `i Post Office Box 244027 I ! g ` ` Anchorage,AK 99524-4027 Hilcorp Alaska,LLC i U L 3 '3 L.J I J 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission ` / V 333 West 7th Avenue, Suite 100 n 3 Anchorage, AK 99501 SWp;46 AUG 2 9 2416. 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 Orig • New API_WeIINo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/020 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/116 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/115 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg l DATE: Thursday,April 30,2015 P.I.Supervisor �e1c -`(�f!Gr /� SUBJECT: Mechanical Integrity Tests l HILCORP ALASKA LLC 1-23/015 FROM: Bob Noble DUCK IS UNIT MPI 1-23/015 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T� NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-23/015API Well Number 50-029-22510-00-00 Inspector Name: Bob Noble Permit Number: 194-128-0 Inspection Date: 4/28/2015 Insp Num: mitRCN150428141737 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-23/015 ITypelnj W TVD 9502 ,Tubing 2450 2450 2470 2470 PTD 1941280 ' Type Test SPT Test psi 2376 IA 1250 3005. 2980- 2973 Interval '----- --- -- ------- --- -------- ----- --- 4YRTST PAF P ✓ OA 390 560 ' 560 560 Notes: - - -- ------- -- - 'Y SGp�tNED MAY 2 2 2015 Thursday,April 30,2015 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 t-: %r w '1.tYV May 22, 2012 Q DA Mr. Jim Regg 6111-1- r 1 t Alaska Oil and Gas Conservation Commission 4* `�,3 0" �J -- 333 West 7 Avenue l,.NV Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 1 Date: 09/24/2010 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 END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 "7END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 _ NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0 -20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1- 67/T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, May 09, 2011 TO: Jim Regg 1\11 1 7� if P.I. Supervisor l SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1- 23/015 FROM: Lou Grimaldi DUCK IS UNIT MPI 1- 23/015 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JDfa— NON- CONFIDENTIAL Comm Well Name: DUCK IS UNIT MPI 1- 23/015 API Well Number: 50- 029 - 22510 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110506104400 Permit Number: 194 -128 -0 Inspection Date: 5/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1- 23 /015 'I l Type Inj. W TVD 9349 IA 330 T 3000 , 2970 2960 - P.T.D iTypeTest Test psi OA 1941280' SPT 30 135 420 400 400 Interval 4YRTST _ = P/F P Tubing 1945 1945 1945 1945 Notes: 2.8 Bbls pumped. Good test. Some salt evident in conductor flutes. red { 4esi- Z33 -1 11)11 Monday, May 09, 2011 Page 1 of 1 Schlumbep.ger NO. 4459 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth s!G~1h!NEQ OCT 312007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt.,LisburnE WI! J b# L D D B e 0 og escrlptlOn ate L Color CD F-48 11846815 USIT 1'1 k 01 ,(.., 10/12/07 1 G-19A 11890315 USIT 1'1'1- led 09/30/07 1 NGI-13 11890313 USIT 1 )""L(1. I -:::¡..- ....-rAl 09/30/07 1 MPE-30A 11855817 US IT ~O, -Olf 10/01/07 1 F·11B 11649954 MCNL rl ö4 - Ie. £.1 -# 1551-3 03/22/07 1 1 W-12A 11418301 MCNL 1'ì"j(-/7f~ +ç-ç-::¡q 09/10/06 1 1 11-27 11637127 RST i~ £0 - 14"1f tt. I ..:;-S-"":}(.., 06/05/07 1 1 02-22A 11216214 MCNL .Gilt' - h ","0, -It ç ~ -r '+ 10/02/06 1 1 01-16 11630486 RST I Hr-ðO<ir "'", "",<;- ~1r 06/28/07 1 1 01-14 11801086 RST I" 'f"}- f)"+':J. t ~-5 +'-i 07/07/07 1 1 L5-05 11767129 MCNL 1"1f -:} _(")lr.c, *, K;~ D 06/17/07 1 1 D-21 11626119 RST I "x;:) - I"'~'::> <It- "'¡ -S-x ¡ 09/12/07 1 1 14-15 11221550 RST 11r I - ó"7JLI 11 I':').... 'X ~ 03/07/06 1 1 D-18A 11695074 RST :::J{) I - t b'3 'it!- , 5:"! '6 08/28107 1 1 14-05A 11813055 RST ICI¡~ -(1U I ... 11..",~1f ~ 06/11/07 1 1-23/0-15 11846802 RST I) -,. {\ Qt..{ '-1::J")r 'It I-=: :-5" 155 08/11/07 1 S-03 11223120 RST J'$rl - 1&1,"1 'Qt tf)~~t.( 06/13/06 1 1-09A1L-21 11849930 RST o,~ - (,,qq ... IS-~? 5 08/04/07 1 1 P2-19A 11649963 MCNL ~")()+_ (')jd ~ 1~5~d 04/22/07 1 1 OWDW-NW 11211370 RST I J'T(\ 'IV, -VI" j:I. tSS9-1 02/28/06 1 1 K-01 11695073 RST 1~3- /;::)/ 1f' / t>0M 08/27/07 1 1 11-32 11630498 RST D,Lf- 1~1 #-1~S("''1 09/03/07 1 1 3-25B/L-27 11630490 RST ,q¡,Q - f"I~ I .... . .c:-<:7 _ 'V 07/26/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~;~:"~::K 99"~EL Received by: G ,,¡, Date Delivered: 10/23/07 . . 08/30/07 Schlumberger NO. 4396 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 L ATTN: Beth . 'I' \d'" V '1-/2,0,- j¿..l sCANNED SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay E d' tt ~ n ICO Job# Log Description Date BL Color CD \. MPC-08 ) N/A RSTIWFL 08/10/07 1 1VJr;r- 11) 11767136 MEM INJ PROFILE t J-:r<'_ l~ ''9-J/'}-:f- 08/12/07 1 P2-16 11856185 INJECTION PROFILE UTf\" Ie. -:;¡ - l;:)'~ 08/02/07 1 07 -02A 11649983 MEM PROD PROFILE lC:¡r~ - r-6< 7{' 08/07/07 1 R-13 11856186 INJECTION PROFILE ( I "'ï" ,. ,.~ - d/~ 08/02/07 1 D-11A 11649982 MEM PROD PROFILE I q,"\- - 1(~ 07/26/07 1 S-42 11686773 LDL I q ~ - C'\.. ")"(j 08/02/07 1 S-43 11855804 LDL I '1-q- -t"1.C\";:) 08/02/07 1 16-07 11855806 STATIC PRESSURE SURVEY I i( 5""" - !:}o 4 08/04/07 1 16-21 11855805 STATIC PRESSURE SURVEY /1):') -~l~ 08/04/07 1 1-09A1L-21 11849930 SBHP SURVEY Jq":}- - /):Jq 08/04/07 1 2-68/S-17 11630491 LDL l~- rA'+ . 07/27/07 1 1-2310-15 11846802 STATIC PRESSURE SURVEY U:r0_ 1'1¿¡ - J:::J ~ 08/11/07 1 Z-46 11057080 CH EDIT PDC GR (USIT)dD6""-If\1 "It --"~~ 12/14/05 1 -., '(~ A-09A 11216203 MCNL .cl1D-I~U 11 1~{/¡::¡i...1 06/29/06 1 1 L3-11 11801065 RST /1r6"" ;:)~ I --- <; 05/31/07 1 1 PLEASE ACKNOWLEDGE RECEIPl"flY ~<?NING AND RETURNING ONE COPY EACH TO: ''''''~' . ["""'\ ""'" ~ \ If· "'"'~ BP Exploration (Alaska) Inc-~t"'< ill"-~!( :, II"" I~ ': ',i r"'~", Petrotechnical Data Center LR2-1 " ",'~-"'---' ,"-~,-, ,) !1,.-,~ 900 E_ Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 "'''h.''.... AK '''''~ ATTN: Beth Received bY~/. ----..----- -1'"(" L .J /[ Z007 Date Delivered: ¡'\t:~¡OI/~) lVI p ....~ .'<" " "·"·¡,,,\,f,~""1',/J '-''{ (:J~:1n r,;(jrl;~:;, Cr¡nlnW3~,~;~(tf] . . MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'V '-I' I f\\~1 '7 ¡(I ù0 DATE: Wednesday, May 17, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-23/015 DUCK IS UNIT MPI 1-23/015 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,:T&- Comm Well Name: DUCK IS UNIT MPI 1-23/015 API Well Number 50-029-22510-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060513195623 Permit Number: 194-128-0 Inspection Date: 5/13/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 1-23/015 !Type Inj. I W I TVD 9355 i IA ! 1930 i 2600 2590 ! 2590 ! , I , -- P.T. i 1941280 iTypeTest I SPT : Test psi 2338,75 OA ì 300 ---~- I 370 ¡ i , 370 370 I , N"~'" I ---"-- , WRKOVR Tubing! 2480 2480 I 2480 i 2480 I Interval PIF p I I -.. Notes After the 30-minute pressure test the IA was bled down to 600 psi and observed for 2 hours with no pressure increase noted. This verifies tubing x IA integrity. NON-CONFIDENTIAL . --. .\ìj,,"~ '" !t.....\~E\·· " 5\Ji'\J'!'" <1 f)í\\St 1 d 0;...''''' Wednesday, May 17,2006 Page I of 1 Re: 01-08A (#2051950), 17-13A (#2050200), 12-19 (#1821980), N... e e I reviewed the MUs and compared to test reports from Commission Inspector Chuck Scheve. I see 'f\ \..I: ~ I J where he was concerned about high IA pressure - he required pressure to be bled off and monitored // for at least 1 hr in each of the following wells: END 1-23/020 (PTD 1941280) and END 2-22/L14 V (PTD 1890340). Your reports do not acknowledge the additional evaluation of the IA pressure. Question - what is the reason for high pre-test IA pressure in these 2 wells? Inspector's reports indicated there was no pressure build up during the monitoring timeframe; it may be premature to conclude there is no pressure communication. We will probably want to recheck pressures periodically during the next month to verify there is no communication. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MIT forms for 01-18A (#2051950), 17-13A (#2050200), 12-19 (#1821980), NGI-07 (#1760380), Endicott 1-05/0-20 (1861060), 1-23/0-15 (#1941280), and 2-22/L-14 (#1890340) MITs. The AOGCC representative witnessed the majority of the tests. 01-08A Post initial injection - Witnessed by Chuck Scheve 17-13A UIC Compliance - Witnessed by Chuck Scheve 12-19 CMIT- TxlA AA 4C.000 Compliance - not witnessed NGI-07 MIT-T for Sundry #303-132 - not witnessed NGI-07 MIT-OA for Sundry #303-132 - not witnessed Endicott 1-05/0-20 UIC Compliance - Witnessed by Chuck Scheve Endicott 1-23/0-15 MITIA post initial injection - Witnessed by Chuck Scheve Endicott 2-22/L-14 UIC Compliance - Witnessed by Chuck Scheve «MIT PBU 01-08A 05-15-06.xls» «MIT PBU 17-13A 05-15-06.xls» «MIT PBU 12-19 05-12-06.xls» «MIT PBU NGI-07 05-11-06.xls» «MIT PBU NGI-07 05-12-06.xls» «MIT END 1-05,1-23,2-2205-13-06.xls» Please let me know if you have any questions or if there are any errors in the forms. Thank you, .ftnna CDu6e lof2 5/17/2006 1 :35 PM Re: 01-08A (#2051950), 17-I3A (#2050200),12-19 (#1821980), N... e e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 20f2 5/17/20061:35 PM I "\.L.\JL...I V L.U ¡fI¿ /I/;tfl£ STATE OF ALASKA _ ,. ALASKaL AND GAS CONSERVATION CawIv1lSSION MAR 2 4 ¿006 REPORT OF SUNDRY WELL OPERATIONSkaOiJ&GasCons.Commissì, Anchorage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 034633 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 181 Repair Well 181 Pull Tubing 55.85 10800 10412 10712 10328 Length 90' 4203' 10756' o Operation Shutdown o Plug Perforations o Perforate New Pool Re lace Corroded Tubin o Perforate o Stimulate o Waiver 181 Other o Re-Enter Suspended Well o Time Extension 5. 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 99519-6612 194-128 6. API Number: 50-029-2251 0-00-00 9. Well Name and Number: END 1-23/0-15 10. Field / Pool(s): feet feet Plugs (measured) feet Junk (measured) feet Size MD 30" 130' 10-3/4" 4246' 7-5/8" 10796' Endicott Field / Endicott Pool None None TVD Burst Collapse 130' 4180' 5210 2480 10408' 6890 4790 ~(;J11~i)\$f[; ~ .',: 10460' - 10620' 1 0087' - 10240' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl o o 17. 4-1/2", 12.6# Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" Baker SABL-3 HES 'HXO' SVLN Treatment description including volumes used and final pressure: Re resentative Dail Gas-Mcf o o L-80 9959' 13. Prior to well operation: Subsequent to operation: 14. Attachments: 9694' & 9855' 1503' Avera e Production or In'ection Data Water-Bbl Casin Pressure o 300 o 1000 Tubin Pressure 1561 2140 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 0 GINJ 181 WINJ 0 WDSPL correct to the best 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 306-018 o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Sondra Stewman Title Technical Assistant Sig ure Form 10-404 Revised 04/2004 0'3 7..J Prepared By Name/Number: Phone 564-4750 Date - ~-fXp Sondra Stewman, 564-4750 ~'" Submit Original Only R8DMS 8FL MAR 2 8 1006 ~ TREE = 4-1/2" FMC W 5000 PSI leErY NOTES: I WELLHEAD - 13-5/8" 5000 PSI FMC NS e ACTUATOR"" END1-23 KB. ELEV = 55.85' -,,,-,-,-=.-.~----=--- ······_~··_-~·······.._···_~~16:12' BF. ELEV = I 1-14-1/2" HES HXO SSSVN, ID = 3.813" I KOP- 1491' Max Angle - 19 @ 8200' . Datum MD - DatumTVD= ????' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE L 2 3718 3676 17 KGB-2 DMY BK 0 02/23/06 1 6113 5955 19 KGB-2 DMY BK 0 02/20/06 110-3/4" CSG, 45.5#, L-80 BTC, ID = 9.953" I 4245' 1-----J ~ Minimum ID = 3.725" @ 9947' I 9673' 1-14-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIPPLE I 8: ~ 9694' -17-5/8" x 4-1/2" BKR S-3 HYDRO PKR, ID = 3.875" I I I 9717' 1-14-1/2" HES X NIP, ID = 3.813" I 14-1/2" TBG, 12.6#, L-80 ¡BT-M, .0152 bpf, ID = 3.958" I 9780' - l 9793' SLM -1TBG STUB (02/19/06) I 9790' 1-17-5/8" X 4-1/2" OVERSHOT I I I 9834' -14-1/2" HES X NIP, ID = 3.813" I J ì- -1 9854' -1 BKR SEAL ASSY, ID = 3.94" I 9855' -17-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" I 2S. I I 9888' -4-1/2" HES x NIP, ID = 3.813" I I I 9947' -14-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I 9959' I- - 9959' 1-14-1/2" WLEG, ID = 3.95" I 1 9946' I ELMD TT LOGGED ??/??j'y; I FOUND NO ELMD TO THIS l\S OF 03i18íOG PERFORA TION SUMMARY REF LOG: GAMMA RAY/CCL/PERF LOG ON 01/13/95 & 02/29/96 ANGLE AT TOP PERF: 16 @ 10460' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10460 - 10470 0 01/13/95 I 3-3/8" 4 10550 - 10620 0 02/29/96 I PBTD I 10712' 17-5/8" CSG, 29.7#, L-80 NSCC, ID = 6.875" I 10798' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 11/12/94 GAM ORIGINAL COM PLErION WELL: 1-23/0-15 02/24/06 NORDIC2 ~O PERMIT No: '1941280 02/27/06 DRFITLH DRLG DRAFT CORRECTIONS API No: 50-029-22510-00 03/23/06 KSBITLH GL V C/O (02123/06) SEC T N R E BP Exploration (Alaska) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/10/2006 Rig Release: 2/24/2006 Rig Number: Spud Date: 9/27/1994 End: 2/24/2006 2/10/2006 08:30 - 16:15 7.75 MOB P PRE Back rig off of 1Q-04. Begin move to Endicott with KRU Drilling Tool Service escort. Rig stopped at KOC at 1500 hrs to check tires. Continue move. At 1 D pad. Fuel pickups. 16:15 - 20:00 3.75 MOB P PRE Continue move from 1 D pad to MPU turnoff intersection Kup and GPB went to Phz 1 at 1700 hrs, GPB went to Phz 2 at 1945 hrs 20:00 - 20:30 0.50 MOB P PRE WO GPB Security escorts at MPU turnoff 20:30 - 00:00 3.50 MOB P PRE Move east from MPU turnoff to Z Pad 2/11/2006 00:00 - 06:00 6.00 MOB P PRE Continue move to Endicott from Z Pad turnoff and at J Pad for crew change GPB went frorn Phz 2 to Level 1 at 0345 hrs 06:00 - 09:30 3.50 MOB P PRE Continue to move along Spine Road to Deadhorse. Tractors for rig camps on 1 Q Pad location at 0930. Move camps to Milne pt cut off. Security short handed. Security decided to keep camps behind Nabors 7ES move (from Z pad to PM 2). 09:30 - 16:30 7.00 MOB P PRE Continue move along Spine Road. Arrive on DS 17. Park rig. Release security to go and facilitate rig camp move. 16:30 - 23:00 6.50 MOB P PRE Scope down and lay down derrick. Move rig to allow rig camps to pass rig. 23:00 - 00:00 1.00 MOB P PRE Fin wait on security to escort camps around rig 7ES and move to DS 17. Camps AOL at DS 17 at 2345 hrs 2/12/2006 00:00 - 04:00 4.00 MOB C PRE Move rig camps to Endicott. Move misc equipment from area near 1-05 (slickline equipment drifted in). Clear snow from weiland camp location with Endicott loader. Spot camps Resume rig move from DS 17 at 0145 hrs. Rig on Endicott Road at 0315 hrs. 04:00 - 09:30 5.50 MOB C PRE Rig at Endicott ice road. Stand by while Tool Service spots rig mats over main channel. 09:30 - 13:30 4.00 MOB C PRE Continue move across ice road to main island. On location after 51 hours on the road! 13:30 - 16:30 3.00 MOB C PRE Hold PJSM. Scope and raise derrick. 16:30 - 17:30 1.00 MOB P PRE Fin RU 17:30 - 19:30 2.00 MOB P PRE Drywatch rig w/ motorman. Release crews to attend ATP meeting 19:30 - 20:30 1.00 MOB P PRE Move rig closer to well and line up to leave more room on ODS 20:30 - 23:30 3.00 MOB P PRE MIRU VECO 300T crane MIRU Endicott 80T crane and manlift Safety mtg re: changeout stairs ATP mtg re: critical lift Set 13-518" BOP, tree and adaptor flange behind 1-23 Install modified stairs (for Endicott-used every year) on ODS to allow movement over adjacent wellhouse 23:30 - 00:00 0.50 MOB P PRE Move rig for straight shot to well. Start laying rig mats 2/13/2006 00:00 - 02:00 2.00 MOB P PRE Fin lay mats Safety mtg re: move over well Move over 1-23 and set down Accept rig for operations at 0200 hrs 02:00 - 03:15 1.25 MOB P DECOMP Move injector and set to side. RU plywood to enclose cellar and add snow Prespud mtg. Take on rig water 03:15 - 06:30 3.25 BOPSU P DECOMP RU DSM lubricator to pull BPV. Found master frozen shut-wrap and heat for two hrs. Open SSV. Pull BPV Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/10/2006 2/24/2006 Spud Date: 9/27/1994 End: 2/24/2006 2/13/2006 06:30 - 11 :30 5.00 KILL P DECOMP Continue to rig up choke and kill lines and manifold in cellar. Take on 9.6 ppg brine into pits. Pressure test lines to 2000 psi. 11 :30 - 13:30 2.00 KILL P DECOMP Pump30 down tbg to displace IA diesel to tiger tank. Swap to IA. Circulate down 7-5/8" tbg to displace diesel from tbg. Circulate an additional 100 bbls to ensure well is dead. 13:30 - 14:00 0.50 BOPSU DECOMP Install two way check valve (FMC hand, Cameron twc). Pressure test TWC from below to 500 psi. Held solid. 14:00 - 15:15 1.25 BOPSU DECOMP RD circ lines 15:15 - 15:30 0.25 BOPSU DECOMP Hold PJSM to discuss removing tree. Work plan, hazards, assignments were reviewed 15:30 - 17:30 2.00 BOPSU DECOMP Loosen tubing head adapter studs. Prep to lift. Notice small flow from open IA. Install trnasducer and monitor for 10 minutes. Hold PJSMITHA with crane operator. Plan to lift centrifuge off rig, lift control spooler on to rig. Remove centrifuge from pipeshed and install CL spooler on floor w/ 80T crane 17:30 - 20:00 2.50 BOPSU P DECOMP ND tree into 3 pieces and remove from cellar 20:00 - 23:00 3.00 BOPSU P DECOMP Safety mtg re: skid in the stack Move the 13-518" BOPE into the cellar using the skid system 23:00 - 00:00 1.00 BOPSU P DECOMP NU BOPE 2/14/2006 00:00 - 03:30 3.50 BOPSU P DECOMP Finish NU 13-5/8" stack. Install riser and fill wI water 03:30 - 10:30 7.00 BOPSU P DECOMP Initial BOPE test 3500/250. Witness waived by AOGCC. Witnessed by WSL's Sevcik/Goodrich 10:30 - 11 :30 1.00 BOPSU P DECOMP Wait on DSM valve crew to arrive. 11:30-15:15 3.75 BOPSU P DECOMP Rig up lubricator. Pull TWC from tbg hanger after several attempts. DSM didn't have centralizer for 13-5/8" stack, so used 7" lubs to centralize pulling tool Endicott AES pull 1-03 wellhouse Set sills for expected pipe delivery from Fairbanks. . . received one load Lay herculite and sills for used tubing 15:15 - 16:30 1.25 PULL P DECOMP MU 4-1/2 NSTC XO to 3-1/2 DP. Screw into hanger. RUTIW and circ system 16:30 - 17:00 0.50 PULL P DECOMP Pull hanger to floor wI max 148k. After -7', pulling wt dropped to 118k and was steady PVT 289 17:00 - 19:30 2.50 PULL P DECOMP CBU+ w/ both pumps 5.8/290 19:30 - 19:50 0.33 PULL P DECOMP PJSM review UD procedures and hazards. 19:50 - 20:30 0.67 PULL P DECOMP LD DP landing jt and tbg hanger. 20:30 - 23:15 2.75 PULL P DECOMP LD 35jts 4-1/2" tbg and dual SSSV control lines. Recovered all 39 bands. 23:15 - 00:00 0.75 PULL P DECOMP Continue LD 4-1/2" tbg. 20-30% of boxes showing severe corrosion. 2/15/2006 00:00 - 09:00 9.00 PULL P DECOMP Fin LD 234 jts 4-1/2" tubing plus the chemical cut 15.88' stub. Cut looks good 09:00 - 13:00 4.00 PULL P DECOMP Load out used tubing from pipeshed and place over herculite for NORM inspection. Clean up pipeshed, floor and tools of hydrocarbon residue Safety mtg re: lifting Use Endicott 80T crane to remove used HES CL spooler and set two spools for completion Load used 2" e-free reel into reel house Load one row of tubing into pipeshed Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/10/2006 Rig Release: 2/24/2006 Rig Number: Spud Date: 9/27/1994 End: 2/24/2006 2/15/2006 13:00 - 14:15 1.25 EVAL P DECOMP Safety mtg re: WL ops RU SWS slickline wI 0.125 wire NORM check all recovered tubulars 14:15 - 17:30 3.25 EVAL P DECOMP RIH wI 6.6" OD GR/JB run #1 to 9778' SLM. POOH wI 3 gallons of scale, sand, sediment, mung 17:30 - 20:00 2.50 EVAL P DECOMP RIH wI 6.6" OD GRUB run #2 to 9778'. Pulled 15' off bottom and became stuck. 20:00 - 22:15 2.25 FISH P DECOMP Work with spangs and oil jars to 1800# overpull. Called to increase to 1900#. Continue working tools both up and down. Finally worked free. 22:15 - 23:35 1.33 EVAL P DECOMP TOH recv'd 3 gal scale, sand. 23:35 - 00:00 0.42 EVAL P DECOMP Stripped 200' WL and rehead. 2/16/2006 00:00 - 00:30 0.50 EVAL P DECOMP Finsih reheaded. 00:30 - 04:00 3.50 EVAL P DECOMP RIH wI 6.6" OD GR/JB run #3 to 9778'. POOH recv'd 1 gal but tool may have opened during TOH. 04:00 - 07:30 3.50 EVAL P DECOMP Make another run RIH wI GRlJB to 9775' and recovered 3 gallons of sediments 07:30 - 10:00 2.50 EVAL P DECOMP RIH wI 6.6" OD GR/JB run #5 to 9778' and recovered a packed basket of sediment that nearly filled a 5 gal bucket 10:00 - 12:30 2.50 EVAL P DECOMP RIH wI 6.6" OD GR/JB run #6 to 9778' and recovered 2 gallons of packed sediment 12:30 - 14:00 1.50 EVAL P DECOMP RIH wI 6.0" LIB wI 6.25" centralizer and tag at 9778'. POOH and no marks of any kind 14:00 - 16:15 2.25 CLEAN P DECOMP RIH wI 6.6" OD GR/JB run #7 to 9775' and recovered 4 gallons packed sediment 16:15-18:30 2.25 CLEAN P DECOMP RIH wI 6.6" OD JB run #8 to 9778' and recovered 2.5 gallons. 18:30 - 21 :30 3.00 CLEAN P DECOMP RIH wI 2-1/4" JB run #9 to 9778 recv'd 1.1 gallons (full) 21 :30 - 23:45 2.25 CLEAN P DECOMP RIH wI 3" x 10' pump bailer run #10 to 9786' rec'vd 3.5 gallons (full) 23:45 - 00:00 0.25 CLEAN P DECOMP RIH wI 3" bailer run #11 2/17/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP RIH to 9786'. TOH with full bailer. 01 :30 - 03:30 2.00 CLEAN P DECOMP RIH #12. Work bailer at 9783'. TOH with full bailer. Finished loading tubing and jewelry into pipeshéd 03:30 - 05:30 2.00 CLEAN P DECOMP RIH #13. Tag at 9790'. Work bailer. TOH bailer full. Held unannounced pit drill. Both SLB and Nordic driller's responded quickly to the pit gain and sent others to investigate for flow at the shaker. 05:30 - 07:30 2.00 CLEAN P DECOMP RIH #14 with 3" x 10' pump bailer to 9794'. Recovered 2.5 gallons 07:30 - 09:30 2.00 CLEAN P DECOMP RIH #15 wI 3" x 14' pump bailer to 9794'. Recovered 1 gallon of sediment and the rest was fluid 09:30 - 11 :30 2.00 CLEAN P DECOMP RIIH #16 wI 3" x 10' pump bailer to 9793'. Recovered 2+ gallons of packed sediment Rehead rope socket 11 :30 - 14:00 2.50 CLEAN P DECOMP RIH #17 wI 6.6" OD GR/JB to 9787' and recover 3.5 gallons of packed sediment Swapped rams in 7-1/16" BOP to normal 2" configuration in preparation for cleanout run 14:00 - 15:45 1.75 CLEAN P DECOMP RIH #18 wI 3" x 10' pump bailer to 9794' and recover 2+ gallons of sediment 15:45 - 17:00 1 .25 CLEAN P DECOMP RIH #19 wI 3" x 10' pump bailer to 9800' SLM and recover 3+ gallons of sediment 17:00 - 18:20 1.33 CLEAN P DECOMP RIH #20 wI 3" x 10' pump bailer to 9811' then worked it to 9845' Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/10/2006 2/24/2006 Spud Date: 9/27/1994 End: 2/24/2006 2/1712006 17:00 - 18:20 1.33 CLEAN P DECaMP (well inside the 4-1/2" tbg) 18:20 - 21:00 2.67 CLEAN P DECOMP RIH with 6.6" 00 GR/JB tagged at 9794'. TOH bailer empty. 21 :00 - 22:45 1.75 EVAL P DECOMP Run wI 6" LIB. Fairly good impression of 2/3 tbg stub. Nothing to indicate problems. 22:45 - 23:15 0.50 EVAL P DECOMP RD slickliners 23:15 - 23:30 0.25 RUNCO RUNCMP PSJM review procedures, pinch points, overhead loads, and skate operations. 23:30 - 00:00 0.50 RUNCO RUNCMP PU Unique overshot assembly and MU to full tbg jt. 2/18/2006 00:00 - 10:15 10.25 RUNCO RUNCMP Continue running 4-1/2" L80 12.6# IBTM tbg and jewelry. MU torque -1800 ftllbs using Best-O-Life 2000 pipe dope 10:15-14:15 4.00 RUNCO RUNCMP MU HES SSSV assy wI dual control lines. Fin run 232 jts 4-1/2" 12.6# L-80 IBT-M R3 tubing installing stainless steel bands under collars 14:15 - 16:00 1.75 RUNCO RUNCMP 98k up, 90k hanging, 82k dn Tag at 35' in on last joint which is 27'? higher than planned. Did not see shear pins shear. RU to circ. Circ 2.9/120 and 4.9/340. RIH and see no pressure increase with 20k stacked. 16:00 - 18:00 2.00 RUNCO RUNCMP CBU 2.8/120 while WO slickline unit. Slickline AOL 1715 hrs. Spot unit and RU. 18:00 - 18:20 0.33 RUNCO RUNCMP Hold PJSM with crews. 18:20 - 00:00 5.67 RUNCO RUNCMP RIH retreive dummy SSSV ball valve. RIH retrieve RHC plug in #1 GLM (60'/min). 2/19/2006 00:00 - 03:00 3.00 RUNCO RUNCMP RIH wI 3.80 drift. Tagged at 9792' ( top of tbg stub maybe) Held table top H2S, Fire and Spill drills. 03:00 - 06:15 3.25 RUNCO RUNCMP RIH wI 3.75" LIB tagged 9792' TOH slowly to avoid swabbing fluids. Clearly see 1/3 of 24' tubing stub which is probably laying on the low side of hole. Also recovered 1/2" long x 3/8" 00 shear screw imbedded in the LIB from the overshot Weather forecasted 'blow' on the way 06:15 - 08:50 2.58 RUNCO RUNCMP SWS crew change. WO fresh LIB and decentralizer Rig evacuation drill 08:50 - 11 :45 2.92 RUNCO RUNCMP MU 3.75" LIB wI decentralizer and RIH to 9792'. POOH slow due to no fluid bypass on tool. LIB verified that stub is on low side. Also saw shear screw indentation mark at 9 o'clock which is obviously not sheared Kuparuk Phz 1 at 0910 GPB Phz 1 @ 0940, CPF2 Phz 2 @ 0940 11:45 -14:30 RUNCMP MU 1-7/8" tool string wI 1-11116" PDS memory GR/CCL. RIH to tag at 9823'. Could not get past assumed sediment at this point (Fasdril plug is at 9920'). Log up hole to above packer. All indications are that we are on the stub or <2' above it Endicott Phz 1 14:30 - 17:00 2.50 RUNCMP RIH and set RHC plug in lower 'X' nipple. Endicott Phz 2 17:00 - 18:10 1.17 RUNCMP Purge control lines. RIH and re-set DBV in SSSV. Test control lines to 5k. 18:10 - 18:30 0.33 RUNCMP RD slickliners. 18:30 - 19:00 0.50 RUNCMP PU and put tbg in tension 95k. Establish baseline PP at 3bpm 150psi. Holding 3500psi on SSSV control lines. HoldPJSM review plans, hazards, and medigating risks for rotating tbg 1 rd with Eckels while still pumping 3bpm, holding torque with Eckels and moving pipe. Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/10/2006 Rig Release: 2/24/2006 Rig Number: Spud Date: 9/27/1994 End: 2/24/2006 21:10 - 21:25 0.25 RUNCO Re-establish tag point on tbg stub. PU put tbg in tension, set slips, rotate 1-1/4rd (2000ftl1bs) with Eckels. (planned only 1rd but could see GLM's "flopping" the other 1/4rd) PU on tbg and remove slips back-off Eckels. Work tbg back down and tag tbg stub but able to workover it more than about 6". Setdown with 25k but unable to work any further. Thinking this might be fill, PU retag and circulate for 30 min. Not helping any. Rotate tbg another 3/4 turn. Work torque down several times but still stopping 6" below tag. Work several more times "poping" the brake while working down. Finally OS continued over tbg stub. Increase in PP from 150 to 370psi. SSSV control line pressure maintained 3500psi. PU 10' pup jt to bottomout on no-go. See remaining shear pins break. Bottom out on correct depth. PU off tbg stub and RIH again to no-go without problems. RUNCMP LD 10' pup jt. RU to rev circulate. Bleed-off control line pressure and re-pressure check to 5000psi. All okay. Hold PSJM with vac truck drivers and rig crews. Go over fluids to be pumped and in what order. Stress importance of knowing what fluids are being pumped and where returns are going. Rev circulate clean 9.6ppg brine followed by 240bbls of corrosion inhibited 9.6ppg brine at 3bpm/370psi Reverse circulate remaining corrosion inhibited 9.6pp brine. LD 2 full jts. PU 10' pup jt and 1 full jt, tbg hanger. MU XO's back to 3-1/2"IF DP MU control lines to tbg hanger and test to 5000k. Chugger out BOP stack. Used a total of 38 SS Bands RIH and land tbg hanger. No problems going over tbg stub at 9800'. Left tbg in tension with OS swallowing +1- 7' of old tbg. RILDS Drop ball/rod. MU TIW valve and circulating hose. Pressure up to 4000psi to inflate and set packer. Hold for 30min to test tbg. Charted by SLB. Have a leaking Whitey valve replace it. Rearrange Kill line valveing to monitor and later PT IA. Pressure back up to 4000psi. Hold for 30min and lost 300 psi. No returns from IA. Assume surface leak RUNCMP Finish crew change. Track down and fix surface leaks NPT =3 Repressure tubing to 4131 psi wI 2.0 bbls 9.6# brine and lost 48 psi in 30 min w/lA open. Got only expansion fluids back from IA RUNCMP Bleed tubing to 1500 psi. Pressure IA to 3543 psi wI 9.6# brine. Lost 26 psi in 30 min Bleed off IA pressure and see DCK valve shear at -700 psi. Bleed all press to zero LD circ tools and landing joint. Chugger stack. Dry rod TWC and PT from below to 500 psi Safety mtg re: NO and skid out BOPE NO riser and hang off in cellar. NO 13-5/8" BOPE and skid outside. Bring in new tree and adaptor flange NU adaptor flange Prep to pick HES spooler from floor wI Endicott 80T crane. 21 :25 - 00:00 2.58 RUNCO RUNCMP 2/20/2006 00:00 - 00:30 0.50 RUNCO RUNCMP 00:30 - 01 :30 1.00 RUNCO RUNCMP 01 :30 - 03:00 1.50 RUNCO RUNCMP 03:00 - 03:40 0.67 RUNCO RUNCMP 03:40 - 04:10 0.50 RUNCO RUNCMP 04:10 - 06:00 1.83 RUNCO RUNCMP 06:00 - 10:30 4.50 RUNCO 10:30 - 11 :30 1.00 RUNCO 11 :30 - 12:30 1.00 WHSUR P RUNCMP 12:30 - 12:45 0.25 WHSUR P RUNCMP 12:45 - 16:30 3.75 WHSUR P RUNCMP 16:30 - 17:30 1.00 WHSUR P RUNCMP Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: 2/10/2006 Rig Release: 2/24/2006 Rig Number: Spud Date: 9/27/1994 End: 2/24/2006 Shut down ops to give Endicott Fire and Safety a walk thru. Pick spooler and load out 17:30 - 20:40 RUNCMP Fin NU adaptor flange and PT @ 5000k. NU porduction tree and PT to 5000K. 20:40 - 21 :00 0.33 RUNCMP PJSM review pulling off well to PU 7-1/6" BOP stack. 21 :00 - 23:30 2.50 RUNCMP Jackup rig and move off well far enough to place BOP stack in front of cellar. Lift in cellar with blocks. and secure. Install lubricator flange and lower XO spool. Move back over well. 23:30 - 00:00 0.50 RUNCMP NU 7-1/16" BOPE. 2/21/2006 00:00 - 02:15 2.25 POST Finish NU BOPE. 02:15 - 07:30 5.25 POST Function test BOP componets. Shell test stack and choke/kill lines to 3500psi. Fix small leak on GreyLok fitting. Test BOPE 250psi/5min 3500psi/5min. Witnessing wavied by AOGCC rep Lou Grimaldi Kuparuk Phz 2 @ 0600 hrs, GPB phz 2 @ 0700 hrs, Endicott Phz 1 @ 0720 hrs 07:30 - 09:15 1.75 BOPSU POST Blind/shears failed. Repair and retest Kup Phz 3 at 0900 hrs 09:15 - 12:00 2.75 BOPSU POST Blind/shears passed LP test, but failed on HP test. Repair and retest GPBlEndicott went to Phz 3 at 1100 hrs Discuss and assess work. ahead. Decide to finish current repair attempt, then SD ops if leak occurs. . which it did 12:00 - 12:45 0.75 BOPSU POST Discuss and assess pulling TWC wI DSM Dryrod pull TWC. MV 23 turns, SV 17 turns. Secure tree 12:45 - 17:30 4.75 BOPSU POST Safety mtg re: responsiblities while WOW WOW due to Phz 3 high winds and low visibility 17:30 - 18:15 0.75 BOPSU POST Crew change using rig loader 18:15 - 20:00 1.75 BOPSU POST Hold weekly safety meetings with day and night crews. Presented BP's Golden Rules on Safety "Working at Heights" Phase 1 20:00 - 00:00 4.00 BOPSU P POST WOW due to Phase 3 conditions. Tabletop drills: Confined Space Entry, Pinholed Coil, H2S/Rig Evac, SpilllContaiment Drill, FirelRig Evac. 2/22/2006 00:00 - 06:00 6.00 BOPSU POST WOW. Phase 3 thoughtout GPB. 06:00 - 15:00 9.00 BOPSU POST Phz 2/3 Endicott snowblower makes it to Satellite Is by noon At 1500 hrs wind not as intense as earlier and forecasted to subside further 15:00 - 15:30 0.50 BOPSU P POST Safety mtg re: continuing operations Mobilize LRS to dig out their PU. Dig out ours at the same time 15:30 - 17:00 POST I Open BOP doors and remove B/S rams and redress. Reinstall rams and PT. Failed at 3500 psi Meanwhile, thaw out LRS unit At 1700 hrs GPB at Phz 1/3 17:00 - 18:00 1.00 BOPSU POST WO LRS to thaw out unit Crew change/TL 18:00 - 18:20 0.33 BOPSU P POST PT blind rams 250psi low 3500psi high. Held good. 18:20 - 18:30 0.17 WHSUR P POST PJSM with LRS and crews. Dicuss plan forward and hazards/spills potentials. 18:30 - 20:00 1.50 WHSUR P POST FP IA to 2000'. PT LRS lines to 3000psi. Down IA pump 55bbls diesel through sheared DKC valve at XJ()()()( 1.3bpm/450psi Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/10/2006 2/24/2006 Spud Date: 9/27/1994 End: 2/24/2006 2/22/2006 18:30 - 20:00 1.50 WHSUR P POST taking returns to pit#5. 20:00 - 21 :00 1.00 WHSUR P POST RU SLB slickline. With SL stipper/pack-off 21 :00 - 21 :10 0.17 WHSUR P POST PJSM: review plan forward 21:10 - 00:00 2.83 DHEOP P POST RIH retrieve DBV. Set sliplstop at 4050' 2/23/2006 00:00 - 03:30 3.50 DHEOP P POST RIH to retrieve sheared DKC valve at 3717'. Failed 1st attempt. Check and redress tools. RIH retreive DKC. 03:30 - 04:10 0.67 DHEOP P POST RIH and set DGLM 04:10 - 05:00 0.83 DHEOP P POST Presssure test tbg to 3500psi for 10 min. Monitoring IA. Straight line test. PT the IA to 3500psi for 10 min. Straight line test. Blow down kill line. 05:00 - 06:00 1.00 DHEOP P POST Retrieve Slip/Stop at 4050'. 06:00 - 10:30 4.50 RIGD P POST Misrun on pulling ball-on-rod. Pull ball-on-rod. Pull RHC. RD SWS slickline 10:30 - 13:30 3.00 CLEAN P CLEAN Safety mtg re: pull CT to injector Install internal grapple and pull CT to floor. Stab into injector 13:30 - 14:30 1.00 CLEAN P CLEAN Install dart catcher. 14:30 - 16:00 1.50 CLEAN P CLEAN Partially fill coil. Test inner reel valve to 3500psi. Continue to flush coil. Install dart. Pump around. 16:00 - 17:00 1.00 CLEAN P CLEAN MU BTT slip-on CTC wI 2-3/8"Reg pin. Pull test to 30K. PT to 3500psi Install new stripper packing 17:00 - 18:00 1.00 CLEAN P CLEAN PU milling BHA. 18:00 - 20:05 2.08 CLEAN P CLEAN RIH to 500', kick on pumps. Pump pressure 4000 psi at 2.5 bpm with 8.5 ppg KCL and 2" coil. Drop pump rate to 1.5 bpm, and RIH. Add biozan to system at 0.5 ppb to help drop pump pressure. Mix 2# biozan for sweeps in pill pit. 20:05 - 20:45 0.67 CLEAN P CLEAN Computer locked up. Depth slipped about 50' before we could shut down ree. Reboot computer, and make Wt check at approximately 9650' = 31500. Pump 20 bbls of 2 #/bbl biozan pill to fluff up junk below overshot. Pumping at 2.35 bpm, 2700 psi. 20:45 - 20:50 0.08 CLEAN P CLEAN Bio to the mill, RIH. Easy down thru overshot. Free spin is 2450 psi at 2.48 bpm. RIH, tag up at 9858'. Probably on bridge plug due to depth error while RIH. Reset depth to 9920'. Mill ahead. Took about 4 minutes of milling and got thru it. 20:50 - 21 :20 0.50 CLEAN P CLEAN RIH chasing bridge plug. Out rate starting to come up. May be getting a gas bubble from under the bridge plug back to surface. Set down with motor work at 10640'. PU. Definately getting higher out rate back. Getting a gas bubble back to surface. Notify pad operator. 21 :20 - 21 :35 0.25 CLEAN P CLEAN PJSM with rig hands to discuss taking gas returns to tiger tank. Pad operator is ok with taking gas to tiger tank. Winds calm. 21 :35 - 21 :45 0.17 CLEAN P CLEAN Line up the triflo choke. Start taking gas returns to tiger tank. Holding maximum of 150 psi whp on line to tiger tank. PU, RIH again. Hard bottom at 10640'. Note last slickline tag prior to starting workover was at 10645'. 21 :45 - 23:55 2.17 CLEAN P CLEAN Pump remainder of Biozan out mill, and POH pumping at full rate. Gas cleaned up quickly. Now taking returns back to pits. Just a little bubble. 23:55 - 00:00 0.08 CLEAN P CLEAN Tag up at surface. Begin to lay down cleanout BHA. Mill has gauge wear at outside lower edge of mill. About 0.2" of gauge worn off. 2/24/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Finish laying down cleanout BHA. Printed: 2/24/2006 1 :56:03 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-23/0-15 1-23/0-15 WORKOVER NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/10/2006 2/24/2006 Spud Date: 9/27/1994 End: 2/24/2006 2/2412006 00:30 - 03:00 2.50 RIGD P POST No N2 pumper available. It is currently at Nordic 1. Bullhead Ip 10 bbls of methanol down well to FP. Empty and clean pits. 03:00 - 03:20 0.33 RIGD POST PJSM with rig crew, 2 Veco truck drivers, and N2 pumper crew. Discuss hazards of pumping N2, and areas to avoid during operation. Assign duty areas. Discuss mitigations to hazards. 03:20 - 05:00 1.67 RIGD P POST Stab injector. PT hard lines. Pump 3 bbls of methanlol down coil. Pump 1500 CFM of N2 for 20 minutes, taking returns to tiger tank. Shut in pumpers, bleed coil to tiger tank. 05:00 - 06:00 1.00 RIGD P POST Unstab coil and secure to reel. Work on injector to stand back for move. 06:00 - 10:00 4.00 RIGD P POST ND BOPE. Clean pits. Install tree cap and test to 5k. Rig Released at 1000hrs 2-24-2006 Printed: 2/2412006 1 :56:03 PM ~ STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ¡¡m reQQ@admín.state.ak.us aOQCG prudhoe bav@admin.state.ak.us bob f¡eckenstein@admín.state.ak.us Contractor: Nordic Rig No.: 2 DATE: 2/14/2006 Rig Rep.: Sevcik / Goodrich Rig Phone: 659-4393 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4398 Op. Fax: 659-4356 Rep.: Mckeirnan / Dowell Field/Unit & Well No.: END 1-23 RWO PTD # 194-128 Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 2500 / 3500 Annular: 250 / 3000 Valves: 2500 / 3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign p Upper Kelly NT Housekeeping: P Dr!. Rig p Lower Kelly NT PTD On Location NA Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 1 p BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13 5/8 P Quantity Test Result Pipe Rams 1 27/8-5 1/2 P No. Valves 14 P Lower Pipe Rams Manual Chokes 1 P Blind Rams 1 13 5/8 P Hydraulic Chokes 1 P Choke Ln. Valves 1 31/8 P HCR Valves 2 31/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 31/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 22 see P Trip Tank P P Full Pressure Attained 155 see P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4 @ 2150 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: Q Test Time: 6.5 Hours Components tested 25 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ¡¡m reQQ@admin.state.ak.us Remarks: 24 HOUR NOTICE GIVEN YES XXX NO Waived By Jeff Jones Date 02/11/06 Time 12:00 Witness Sevcik / Goodrich Test start 3:30 Finish 10:00 ~ c BOP Test (for rigs) BFL 11/09/04 Nordic 2 BOP 2-14-06.xls Re: Variance for Endicott 1-23 & 3-11 ) I~ 4 ~ I 2. f ) SUbject: Re:Variance far Endico.tt 1-23 & 3-11 From: Winto.nAubert <winto.n_aubert@admin.state.ak.us> Date: Wed, 08 Feb 2006 07:40:30 -0900 To:· ·"Worthington, ArasJu. <Aras.Worthington@bp.co.l1l> CC:.GatherineFfoerster<cathy_foerster@adrnin.state.ak.us>, Admin AOGGC Prudhoe·Say <aogcc ....prudhoe....b~y@adm in.stat~.ak.u$> Aras, Per 20 AAC 25.285 (h), AOGCC hereby appro.ves alternate BOPE far yo.ur pro.po.sed wo.rko.vers o.f Endico.tt well 1-23 (prD 194-128, Sundry No.. 306-018) and Endico.tt well 3-11 (prD 188-087, Sundry No.. 306-042). All ather appro.val stipulatio.ns apply. Winton Aubert AOGCC 793-1231 Wo.rthingto.n, Aras J wro.te: Winton, As per phone conversation regarding Sundry permits for Endicott wells 1-23 (306-018) and Endicott 3-11 (Sundry # not received yet). Nordic 2 plans to move to Endicott for these two tubing workovers towards the end of this week. Currently our 13 5/8" BOP stack includes 3 preventers: one pipe ram, one blind ram, and an annular preventer. BP reqljests a variance from regulation 20 AAC 25.285 which implies that 4 preventers are needed if API 5K equipment is required. Our MASP on End 1-23 is 3200 psi and for End 3-11 it is 3300 psi. It may be possible to rig up (4) 135/8" preventers with this rig but would require significant cost/modified rig equipmentand/or additional rig moves onloff the well for these workovers. The 3 preventer stack will provide sufficient BOPE for these rig-workovers and is consistent with BP internal Policy. Aras Worthington CTD Engineer BP Exploration Alaska Inc. 564-4102 ~t^NNEJ) fEB 0 ~1 2005 1 of 1 2/8/20063:36 PM ) ) FRANK H. MURKOWSKI, GOVERNOR AlASKA OIL AND GAS CONSERVATION CO.KMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Sr. Production Engineers BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott, 1-23/0-15 Sundry Number: 306-018 \ ql\'"' \ yb SC)tð\~~~Ef-~ ,J6~N 1 8 20D5 Dear Mr. McMullen: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/1d.ay of January, 2006 Enc!. Cf4- /., I S"61r w~ Il'"5/ "l.O'O(p ") STATE OF ALASKA 0 rj} 7/6 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JAN 1 2 2006 20 AAC 25.280 AI.'tIfI~b§t&lMJdQßSr~ssio 1. Type of Request: 0 Abandon 0 Suspend /[J Operation Shutdown 0 Perforate a Other o Alter Casing a Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program a Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: D Development D ExPloratory/ D Stratigraphic 181 Service 5. Permit To Drill Number 194-128 / 6. API Number: 50- 029-2251 0-00-00 / 99519-6612 55.85 9. Well Name and Number: END 1-23/0-15 11. Total Depth MD (ft): 10800 10. Field / Pool(s): ADL 034633 Endicott Field / Endicott Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10712 10328 None TVD ~~~ 8. Property Designation: 90' 4203' 30" 10-3/4" 130' 4246' 1301 4180' 5210 2480 10756' 7-5/8" 10796' 104081 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10460' - 106201 / 100871 - 102401 Packers and SSSV Type: 7-5/8" Baker SABL-3 HES 'HXO' SVLN Tubing Size: 4-1/2", 12.6# Tubing Grade: Tubing MD (ft): L-80 9959' Packers and SSSV MD (ft): 98541 / 1503' 12. Attachments: 181 Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: .-' D Exploratory D Development 181 Service 15. Well Status after proposed work: DOi! DGas DWAG DGINJ D Plugged Ii· D Abandoned 181 WINJ D WDSPL I February 1, 2006 Date: nd correct to the best of my knowledge. Title Sr. Production Engineers Contact Phone 564-4711 Commission Use Onl Date Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance Other: f/l r L ~,~ ul ~ d . iso Pi?- 1-0 ~SOO f!t'. RBDMS BFl .IAN 1. ";' 2Ð06 COMMISSIONER APPROVED BY THE COMMISSION 1-- Date ORIGINAL ) ) Endicott 1-23/0-15 Water Iniector f!Qposed Ri" Workover Well Status: Active water injector. TxlA communication. Approved for water // injection under Sundry #302-079. Ria Workover Obiective: Replace corroded 4-1/2" tubing. Return well to water injection. 1. Pre-ria: Set millable plug in tailpipe and CMIT-TxIA to 3500 psi. Chemical cut tubing at -- 9800'. Load tubing and IA with kill weight fluid. Set BPV. 2. MIRU Nordic 2. Pull BPV; set and test TWC in tubing hanger. NO tree and adapter flange. NU BaPE. Test BaPE to 250 psi (low)/3500 psi (high). /" 3. Circulate hole volume with kill weight fluid. 4. Pull 4-1/2" tubing down to the cut. /' 5. Drift well to tubing stub. 6. Run new overshot, 7-5/8" packer, and 4-1/2" tubing. Stab over tubing stub. 7. Set and test packer to 3500 psi. ,;-,-/ 8. NO BaPE. NU and test tree. 9. NU and test coil tubing BOPE. RIH with coil and mill plug set in old tail pipe. Cleanout to TO. 10. ROMO. 11. Return well to water injection. / RT. ELEV = 55.85' ) 1-23 Cu. t2..~oJ'-- BF. ELEV = 16.12' MAX DEV = 19.44° @ 8200' 10-3/4", 45.5#/ft, L- 80, BTC. CSG I 4245' I 4-1/2", 12.6#/ft, NSCT tubing PERFORATION SUMMARY ~ CO SIZE SPF INTERVAL AWS 33/8 4 10460-10470 OPN AWS 33/8 4 10550-10620 PBTD 7-5/8", 29.7#/ft, L-80 NSCC DATE REV. BY 11/12/94 GAM 11/18/94 HT 3/1 196 JTP 2/2/98 DB 10712' I 10798' I ~ COMMENTS INITIAL COMPLETION SBL/Gyro/lnit perfs ADD TT ELMO . TREE: 4-~ '..." ,FMC W 5000 psi WELLHEAD: )8" 5000 psi FMC NS HES 'HXO' SVLN I 1503' (3.813" MIN. 10) W/SSSV MIN 1.0. is 2.0" GAS LIFT MANDRELS (HES) 'KBMG' w. 1" BK' LATCH NO. MD-BKB TVD-SS #1 9765' 9362' #2 3507' 3418' 4-1/2" 'X' NIPPLE (HES) 9834' (3.813" MIN. 10) 7-5/8" PACKER (BAKER "SABL-3") 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2" 'X'NIPPLE (HES) (3.813" 10) 4-1/2" 'XN' NIPPLE (HES) (3.725" 10) 9854' 9888' 9947 ' 4-1/2" WLE G New Style 9959' T. T. ELMO 9946' ENDICOTT WELL 1-23/0-15 API NO: 50-029-22510 00 COMPLETION DIAGRAM BP EXPLORATION, INC. RT. ELEV '" 55.85' SF. ELEV '" 16.12' MAX DEV = 19.44° @ 8200' 11\IIIIIo> 10-3/4", 45. 5#/ft, L- 80, BTC CSG I 4·1/2" 'X' N!PPLE (HES) (3.813" MIN. 10) 7-5/8" PACKER (BAKER "SASL-3") 4·1/2", 12.6#/ft, L-80 TAILPIPE 4·1/2" 'X' NIPPLE (HES) (3.813"10) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 4-112" WLE G New Style T. T. ELMD PERFORATION SUMMARY INTERVAL 10460-10470 OPN AWS 33/8 4 10550-10620 PBTD 7-5113", 29.7#/ft, L -80 NSCC I 10712' I -þo- 5 API NO: 000 COMPLETION DIAGRAM EXPLORATI _ _ RECEIVED _ STATE OF ALASKA - ALASKA Oil AND GAS CONSERVATION COMMISSION DEC 0 1 2005 REPORT OF SUNDRY WELL OPERATI0N:8OiI&Gas Cons. Commission 1. Operations Performed: Suspend D Operation Shutdown D Perforate D WaiverD Other [X] Abandon D Alter CasingD RepairWellD Plug PerforationsD Stimulate D Time ExtensionO Change Approved Program D Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 Cancel Sundry 2. Operator 4. Current Well Class: 5. Permit tp 9riU,Number: Name: BP Exploration (Alaska), Inc. "JM¡ît_':è ., Development 0 Exploratory D 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceŒ 50-029-22510-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.85 1-23/0-15 8. Property Designation: 10. Field/Pool(s): ADL-034633 Endicott Field / Endicott Oil Pool, Duck Island Unit 11. Present Well Condition Summary: Total Depth measured 10800 feet true vertical 10411.8 feet Plugs (measured) None Effective Depth measured 10712 feet Junk (measured) None true vertical 10328.0 feet Casing Length Size MD TVD Burst Collapse Conductor 90 30" Conductor 40 - 130 40.0 - 130.0 Production 10756 7-5/8" 29.7# L-80 40 - 10796 40.0 - 10408.0 6890 4790 Surface 4203 10-3/4" 45.5# NT-80 43 - 4246 43.0 - 4179.6 5210 2480 Perforation depth: Measured depth: 10460 - 10470, 10550 - 10620 True vertical depth: 10086.79 -10096.39,10173.16 -10240.27 ~ÇANNED DEC 1 6 2005 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 38 - 9946 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer @ 9854 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG 0 GINJD WINJI!! WDSPLD Daily Report of Well Operations _ Prepared by Garry Catron (907) 564-4657. 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 Anna Dube / Joe Anders 302-079 Printed Name Joe Anders, P.E. Title Well Integrity Coordinator Signature 'lr}/J (I A 4A/7 Phone 659-5102 Date 11/24/05 I / ! I ~ iX.:e-lYhS' c~ \Yk~J5' ~. ORiGiNAL Form 10-404 Revised 12/2003 e e ò BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 1 9661 2 Anchorage, Alaska 99519-6612 23 November 2005 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: Endicott 1-23/0-15 (PTD 1941280) Application for Cancellation of Sundry #302-079 Request for Administrative Approval to Continue Water Injection Operations Dear Mr. Norman: BP Exploration (Alaska) Inc. requests approval to continue water injection operations into Endicott well 1-23/0-15. Endicott well 1-23 has rapid tubing by inner annulus communication indicated by rapid IA repressurization. However, two competent barriers have been established and thus it is BP's contention that the well can be safely operated. The barriers have passed pressure tests to 1.2 times the maximum anticipated injection pressure and observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The proposed operating and monitoring plan (attached) includes the following: 1. Daily recording of surface rate and injection pressure 2. Mechanical integrity testing on an increased frequency 3. Increased reporting to the AOGCC through the Monthly Injection Report If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. The proposed operating and monitoring plan is based on sound engineering and operating practices, and is consistent with Area Injection Order 1. In addition, there is no source of underground drinking water; therefore, no USDW is endangered. It is BP's contention that approval of this request will provide safe operating conditions, is in the best interests of the GPB working owners and the State of Alaska. Approval of this administrative request will supersede the current sundry for slow tubing by inner annulus communication. Therefore an Application for Sundry Cancellation form 10-404 to cancel sundry #302-079 is also attached. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. s~ Steve Rossberg Wells Manager e e Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot Report of Sundry Well Operations form 10-404 e e Endicott 1-23/0-15 Technical Justification for Administrative Relief Request November 22,2005 Well History and Status Endicott well 1-23/0-15 (PTD 1941280) has tubing by inner annulus communication. A sundry (# 302-079) for slow tubing by inner annulus communication was issued 08/22/02. An MIT-IA conducted on 02/24/04 demonstrated the LLR has increased to rapid TxlA comm. A CMIT-TxIA passed to 3360 psi on 11/15/05. An MITOA passed to 3000 psi on 11/15/05. These tests indicate competent production and surface casing. Recent Well Events: - 02/24/04: MITIA failed, LLR-IA .35 BPM @ 2780 psi. - 11/14/05: Set TTP at 9860' SLMD. - 11/15/05: CMIT-TxIA passed to 3360 psi (AOGCC declined witness), MITOA passed to 3000 psi. 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 primary well barrier is the production casing. In the event of a leak, the secondary barrier system composed of the surface casing will contain any pressure. The tubing has been pressure tested to 1.2 times the maximum anticipated injection pressure, and the surface casing has been pressure tested to 1.07 times the maximum anticipated injection pressure, but 1.25 times maximum recorded injection pressure to ensure competency. Pressure testing the surface casing to 1.2 times the maximum injection pressure will exceed the rating of the well head. Barrier competency is monitored using wellhead pressure plots (TIO plot), a Pressure/Rate plot and periodic pressure tests to 1.2 times the maximum recorded injection pressure. Primary Well Barrier System: Production casing competency is demonstrated by the passing CMIT-TxIA to 3360 psi on 11/15/05. Competency will be frequently monitored by daily annulus pressure observations, by frequent review of a Pressure-Rate plot to monitor injectivity/pressure trends and by conducting a 2-year CMIT-TxlA. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT-OA to 3000 psi on 11/15/05. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting an annual MITOA. Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut-in. Injection fluid temperatures are warmer than the wellbore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressure. Mechanical condition'e tubing is not considered a comp!ent in the well barrier systems. The production and surface casing are the 2 competent well barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring 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 1.2 x the maximum recorded well pressure. 5. Perform a CMIT-T x IA every 2 years to 1.2 x the maximum anticipated well pressure. 6. If there is any change in the well conditions that suggest one of the two barriers could be compromised, BPXA will shut in the well immediately and notify the AOGCC. RT. ELEV = 55.85' BF. ELEV = 16.12' MAX DEV = 19.44' @ 8200' 10-3/4", 45.5#/11, L- 80, BTC. CSG. 14245' 4-1/2",12.6#/11, NSCT tubing PERFORATION SUMMARY CO AWS AWS SIZE 33/8 33/8 SPF INT 4 10460-10 4 10550-1 PBTD 7 -5/8", 29.7#/11, L-80 NSCC TREE: 4·1/2 , MC W 5000 psi WELLHEAD: 135/8" 5000 psi FMC NS .. ~ . ~ G .... .. - I -- I I .. .-- :8: I: :g .- ( I ( I ERVAL 470 OPN 0620 I ~ ... 10712' 10798' 1-" HES 'HXO' SVLN I 1503' (3.813" MIN. ID) W/SSSV MIN 1.0. is 2.0" AS LIFT MANDRELS (HES) KBM G' w. 1" BK' LATCH NO. MD-BKB TVD-SS #1 9765' 9362' #2 3507' 3418' 4-1/2" 'X' NIPPLE (HES) (3.813" MIN.ID) 7-5/8" PACKER BAKER "SABL-3") 9834' 9854' 4-1/2", 12.6#/11, L-80 TAILPIPE 4-1/2" 'X' NIPPLE HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 9888' 9947 ' 4-1/2" WLE G New Slyle 9959' 9946' T. T. ELMD DATE REV. BY COMMENTS EN DICOTT WE LL 1-23/0-15 11/12/94 GAM INITIAL COMPLETION API NO: 50-029-2251000 11/18/94 HT SB LIG yroll nil perfs COMPLETION DIAGRAM 3/1/96 JTP ADD 2/2/98 DB TT ELMD BP EXPLORATION, INC. ~ t \. '" 1..23 TIO Plot 4,000 3,000 2,000 1,000 o 11/18/2004 9/18/2005 11/18/2005 1/18/2005 3/18/2005 5/18/2005 7/18/2005 ..- Tbg fA OA OOA OOOA ENDl-23/0-15 (PTD 1941280) Status e e. 1l\I'bloS' Subject: END 1-23/0-15 (PTD 1941280) Status 14ft From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntcgrityEngincer@BP.com> Date: Thu, 17 No\' 2005 21 :54:38 -0900 To: jim_ rcgg@admin.statc.ak.us, winton_aubcrt@admin.state.ak.us CC: "Rossberg, R Steven" <RossbeRS@BP.com>, "McMullen, John C" <McMuIIJC@BP.com>, END/BAD Area Managcr <ENDBADArcaManager@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWcIlOpcrationsSupcrvisor@BP.com>, "NSU, ADW Well Integrity Engincer" <NSlJADWWelllntcgrityEngineer@BP.com>, "Mielke, Robert L." <robcrt.mic1ke@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "Luckett, Ely Z. (VECO)" <luckez@BP.com>, "Engel, Harry R" <EngeJHR@BP.com> Hello Winton and Jim. Endicott well 1-23/0-15 (PTO 1941280) is in the process of being evaluated for an AA to continue injection with TxlA communication. The well is currently injecting under Sundry #302-079 for slow TxlA communication. The leak rate has increased and purpose of this work is to update the Sundry to an AA for TxlA communication. Recent well history: > 08/22/02: AOGCC approved Sundry #302-079 for slow TxlA communication > 04/10/04: Set TIP, CMIT-TxIA Passed to 3360 psi. Plug stuck in hole. > 04/29/04: CT fished TTP, pumped SSG > 05/30/04: OA Own sqz with 15.7 ppg Arctic Set 1 cement (1/4 #/sac cello flake) > 06/04/04: MIT-OA Passed to 3360 psi > 06/18/04: Sent 10-404 & new 10-403 to AOGCC - Lost in the mail > 07/27/04: Re-mailed the Sundry packet > 11/14/05: Set TIP > 11/15/05: CMIT TxlA Passed to 3360 psi (AOGCC declined witness), MITOA passed to 3000 psi Current plans are pull the TIP, re-establish injection and submit a request for an AA. Attached is a wellbore schematic and TIO plot. Please call if you have any questions. «1-23.pdf» «EN01-23 TIO Plot 11-17-05.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~ANNEG DEC 1 G 2005 Content-Description: 1-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: ENDI-23 no Plot 11-17-05.jpg ENDl-23 TIO Plot 11-17-05.jpg Content-Type: image/jpeg j...6fL f'~ Z-b~1t- 11/18/2005 9:23 AM t............ - RT. ELEV = 55.85' BF. ELEV = 16.12' MAX DEV = 19.44" @ 8200' TREE: 4-112" ,FMC W 5000 psi WELLHEAD: 135/8" 5000 psi FMC N S 10-3/4",45.5#/ft. L- 80, BTC. CSG 14245' .. . HES 'HXO' SVLN I 1503' (3.813" MIN. 10) W/SSSV MIN 1.0. is 2.0" 4-112", 12.6#/ft, NSCT tubing GAS LIFT MANDRELS (HES) 'KBMG' w. 1" BK' LATCH NO. MD-BKB TVD-SS #1 9765' 9362' #2 3507' 3418' I 4-112" 'X' NIPPLE (HES) (3.813" MIN. 10) 7-5/8" PACKER (BAKER "SABL-3") 9834' 9854' 4-112", 12.6#/ft, L-80 TAILPIPE 4-112" 'X' NIPPLE (HES) (3.813" 10) 4-112" 'XN' NIPPLE (HES) (3.725" 10) 9888' I I I I 9947 ' PERFORATION SUMMARY 4-1/2" WLE G New Style 9959' CO AWS AWS SIZE 33/8 33/8 SPF INTERVAL 4 10460-10470 OPN 4 10550-10620 T.T. ELMO 9946' PBTD 7-518",29.7#/ft, L-80 NSCC 10712' I I --þo. 10798' .." DATE REV. BY COMMENTS ENDICOTT WELL 1-23/0-15 11/12/94 GAM INITIAL COMPLETION API NO: 50-029-2251000 11/18/94 HT SBLlGyrollnit perfs COMPLETION DIAGRAM 3/1/96 JTP ADD 2/2/98 DB TT ELMO BP EXPLORATION, INC. e e STATE OF ALASKA / ALASKA OIL AND GAS CONSERVATION COMMISSION . \\lvIO~ Mechanical Integrity Test ~~ q II f:maiUQ:__WiotQo_Aubert@admin.state.ak.us;Bob""Fleckenstein@admin .state.ak.us; -Jim:;;Regg@admin.state,ak,us~m.::.Maunder@admin.state,aICUs OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Endicott 1 END 1 MPI 11/15/05 Joe Anders ¡v\~ \q '"f Packer Depth Pretest Initial 15 Min. 30 Min. Well1-23/0-15 I Type Inj. I N TVD 9,503' Tubing 1,420 3,360 3,380 3,380 IntervaJ 0 P.T.D.1941280 Type test P Test psil 2376 Casing 1,300 3,360 3,340 3,330 P/F P Notes: CMIT-TxlA to 3360 psi for AA OA VAC VAC VAC VAC AOGCC declined to witness Weill I Type Inj. TVD I Tubingl I I Interval P.T.D.I Type test I Test psil Casing I I P/F Notes: OA I I Weill I Type Inj. TVD Tubing I I Interval/ P.T.D.I I Type test I Test psil Casing I P/FI Notes: I OAI I I Weill I Type Inj.1 I TVD I Tubing Interval/ P.T.D. I Type test! I Test psi I Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval P.T.D. Type test I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 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) '..-' 'À í\\;,\f.: : 1 t,: f: ~i ~V~~J~.i" ,,,........,;...; .,.. MIT END1·23 11·15 -05.xls " . 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 00 Pluq PerforationsD Pull TubingO Perforate New Pool 0 Operation Shutdown 0 Perforate 0 Stimulate D OtherD WaiverD Time ExtensionO Re-enter Suspended Well 0 4. Current Well Class: Development 0 2. Operator SP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 8. Property Designation: ADL-034633 11. Present Well Condition Summary: 5. Permit to Drill Number: 194-1280 6. API Number 50-029-22510-00-00 Exploratory D Stratigraphic 0 9. Well Name and Number: 1-23/0-15 10. Field/Pool(s): Endicott Field 1 Endicott Oil Pool, Duck Island Unit Service ŒJ Total Depth measured 10800 feet true vertical 10411.8 feet Effective Depth measured 10712 feet true vertical 10328.0 feet Casing Conductor Production Surface Length 90 10756 4203 Perforation depth: Plugs (measured) Junk (measured) None None Size 30" Conductor 7-5/8" 29.7# L-80 10-3/4" 45.5# NT -80 TVD Collapse MD Burst 40 40 43 130 40.0 - 10796 40.0 - 4246 43.0 130.0 - 10408.0 - 4179.6 6890 5210 4790 2480 Measured depth: 10460 -10470,10550 -10620 ~(;J\N~~ED SEP 2: 5 2004 RECEIVED SEP 2 1 2004 Ala$ka Oil & Gas Cons. Commission Anchorage True ve rtical depth: 10086.79 - 10096.39, 10173.16 - 10240.27 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 38 9946 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer @ 9854 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ,f1 ClA[ C~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Signature Form 10-404 Revised 4/2004 Oil-Bbl o o 15 Bbls 15.7 ppg Arctic Set 1 Cement w/1/4# per sack celloflake @ 1170 psig; 5 Bbls Neet Cement @ 1160 psig Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure o -16161 2400 o -17855 2300 Tubing Pressure 2331 2309 ~ 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD WAG D GINJD WINJI!) WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-079 Development D Service ŒJ Title Production Technical Assistant Phone 564-4657 Date 9/20/04 OQ' G.' ",1\, - . \ ,n~li 3~libl-0 <' "2.~::.:'" ) ) . ' 1-23/0-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/15/04 PRESSURE OA TO 2000 PSI, OA FL@ 2700', BLED OA TO ZERO, OA DOWNSQUEEZE DIAGNOSTICS. OS/25/04 TI0=2300/2400/320 ---PUMP OA INJECTIVITY TEST PRE-CEMENT DOWN SQZ--- PUMPED 164 BBLS DIESEL TOT AL---OA CAUGHT PRESSURE @ 80 BBLS PUMPED--- ESTABLISHED INJECTION RATES OF 3 BPM @ 1940 PSI AND 4 BPM @ 2050 PSI---OA BLEED TO 1600 PSI NATURALLY THEN HELD---FINAL WHP'S= 2300/2400/300 05/30/04 T/I/O = 1550/2120/0. OA DOWNSQUEEZE. MIRU DS. HOLD PJSM. PT LINES TO 3500 PSI. PUMPED 10 BBLS OF METHANOL AND 50 BBLS OF CRUDE TO ESTABLISH INJECTIVITY. FOLLOWED UP WITH 5 BBLS OF FRESHWATER,20 BBLS OF DS CW101 SURFACTANT, 200 BBLS OF FRESHWATER,15 BBLS OF CW101 SURFACTANT, 15 BBLS OF 15.7 # PPG ARCTIC SET 1 CEMENT CONTAINING 1/4# PER SAC CELLOFLAKE, AND 5 BBLS OF NEET CEMENT. DISPLACED CEMENT WITH 5 BBLS OF FRESHWATER AND 134 BBLS OF CRUDE. SD, RD, MOL. MONITORED OAP FOR 30 MIN. OAP INCREASED TO 1050 PSI DUE TO THERMAL. BLED OA TO 250 PSI. FINAL WHP'S = 1450/1950/250. FLUIDS PUMPED BBLS 164 Diesel 210 Fresh Water 184 Crude 35 DS CW1 01 Surfactant 10 Methonal 15 15.7 ppg Arctic Set 1 cement wi 1/4# per sack of celloflake 5 Neet Cement 623 TOTAL Page 1 ) , BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 18, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 RE E JUN 2 3 2004 Subject: Endicott well 1-23/0-15 (PTO 1941280) Application for Cancellation of Sundry #304-079 Application for Sundry Approval for Water injection with Rapid T x IA Communication Dear Mr. Aubert: Attached is both an Application for Sundry Cancellation form 10-404 to cancel sundry #304-079 and an Application for Sundry Approval form 10-403 for Endicott well 1-23/0-15 (PTO 1941280). The purpose of this request is to continue water injection into Endicott well 1-23/0-15 (PTO 1941280) and to clarify the required compliance testing. If you require any additional information or clarification, please contact Anna Oube or Joe Anders at (907) 659-5102. c ~~tLk Anna Oube Well Integrity Coordinator Attachments Report of Sundry Well Operations form 10-404 Application for Sundry Approval form 10-403 Description Summary of Proposal Wellbore Schematic c' fr' ,^ ¡/i..~ \;>"~iF ~;, ~I ~ n çj f2 '[('I DL) t;))v¿r\:.ß\J5'\'j~¡;"" ,.1 L I,. (ìQ\h'~' ~.' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ) ) 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D Repair WellD Pull Tubing D Operation Shutdown D Plug PerforationsO Perforate New PoolO 4. Current Well Class: Perforate D WaiverD Stimulate D Time Extension 0 Re-enter Suspended WellD Other IX) Cancel Sundry Name: BP Exploration (Alaska), Inc. 5. Permit to Drill Number: 194-1280 Development 0 ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 8. Property Designation: ADL-034633 11. Present Well Condition Summary: StratigraphicO 9. Well Name and Number: 1-23/0-15 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit Service ŒJ 6. API Number 50-029-22510-00-00 Total Depth measured 10800 feet true vertical 10411.8 feet Effective Depth measured 10712 feet true vertical 10328.0 feet Plugs (measured) Junk (measured) None None Casing Conductor Production Surface Length 90 10756 4203 Size 30" Conductor 7 -5/8" 29.7# L-80 10-3/4" 45.5# NT-80 MD TVD 40 - 130 40.0 - 130.0 40 - 10796 40.0 - 10408.0 43 - 4246 43.0 - 4179.6 Burst Collapse 6890 5210 4790 2480 Perforation depth: Measured depth: 10460 -10470, 10550 -10620 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 38 9946 f~E: E, JUN 2 3 2004 True vertical depth: 10086.79 -10096.39,10173.16 -10240.27 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer @ 9854 ^h~~ka em 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~CA\N!NEt\1 J!UL f¡~ Œ» 20Dl1 13 Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run_ 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG D GINJO WINJŒ] WDSPLO Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: .-3Owi .()'73 3 (!)~ --tD?1 ~ c".¿.. Title Well Integrity Coordinator Daily Report of Well Operations _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Anna Dube I Joe Anders Printed Name A~a ~be / Signature J-X Â A..tAÚI -" J J .l t-O OR\G\NAL Phone 659-5102 Date 6/18/04 RBDMS Bfl jUN 2, 4 70n~ Form 10-404 Revised 12/2003 --',) } R, " E... ('" r""'," ~ '\" I' ~:,:,,:::~r"'\ STATE OF ALASKA "~"" "',/ ~':::, ~ ~I ~i,'N... b-' ALASKA OIL AND GAS CONSERVATION COMMISSION N ''þ 3 2004 APPLICATION FOR SUNDRY APPROVAL JU /JCt ,,, 20 AAC 25.280 Ma~:I\Œ m~ 1. Type of Request: Abandon D D D Suspend D Repair Well D Pull Tubing D o D D PerforateD WaiverŒ] StimulateD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 194-1280 StratigraphicO Service Œ] 9. Well Name and Number: 1-23/0-15 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 10411.8 10712 10272.1 Length Size MD TVD Operation Shutdown Plug Perforations Perforate New Pool Alter Casing Change Approved Program 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Development 0 Exploratory 0 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 KB 8. Property Designation: ADL-034633 :3. Address: I 11. Total Depth MD (ft): 10800 Casing Conductor 90 Production 10756 Surlace 4203 Perforation Depth MD (ft): 10460 - 10470 10550 - 10620 Packers and SSSV Type: 4-1/2" Baker SABL-3 Packer 12. Attachments: Description Summary of Proposal D top 40 40 43 bottom top 130 40.0 10796 40.0 4246 43.0 Tubing Size: 4.5 " 12.6 # bottom 130.0 10408.0 4179.6 Tubing Grade: L-80 30" Conductor 7-5/8" 29.7# L-80 10-3/4" 45.5# NT-80 Perforation Depth TVD (ft): 10087 10096.4 10173 10240.3 Packers and SSSV MD (ft): 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D ExploratoryD 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. July 2, 2004 15. Well Status after proposed work: Oil D GasD WAG D GINJD Date: Contact Printed Name Signature An~ Dube (J n _ ~.I\). A.. Á(O - .A.A JI A9-- Title Phone Well Integrity Coordinator 659-5102 6/18/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechanciallntegrity Test D Location Clearance D Other: Subsequent Form Required: Annular Disposal D OtherD 6. API Number 50-029-22510-00-00 Plugs (md): None Burst Junk (md): None Collapse 6890 5210 Tubing MD (ft): 38 4790 2480 9946 9854 DevelopmentD ServiceŒ] Plugged D WINJI!) Abandoned D WDSPLD Prepared by Garry Catron 564-4657. Anna Dube I Joe Anders Sundry Number: Approved by: BY ORDER OF THE COMMISSION Date: (,Ç:Ch.~~[¡\~Jt;;'h " " '" r)[' [ \2)\\;7nU~O~i.k.lL;' ,JUiL (¡ t~ {_' J.,M Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE ) ) Endicott 1-23/0-15 Description Summary of Proposal 06/18/04 Problem: Injector with Rapid T x IA Communication Well History and Status Endicott well 1-23/0-15 (PTD 1941280) is a water injector with rapid T x IA communication. A MITIA failed with a leak rate of 0.35 bpm @ 1000 psi differential pressure. Summary of recent events: > 02/24/04: LLR-IA .35 bpm @ 2780 psi, 1000 psi differential. > 04/10/04: CMIT-TxIA Passed to 3360 psi. This sundry request is to allow for continued water injection. The following supports the request: - A CMIT-T x IA Passed to 3360 psi on 04/10/04, demonstrating competent production casing. - Pressures, temperature, and injection rate are monitored and recorded daily. Proposed Action Plan 1. Allow well to continue water injection. 2. Record wellhead pressures, temperature, and injection rate daily. 3. Submit a monthly report of daily pressures, temperatures, and injection rates. 4. Perform a CMIT-T x IA once every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. (SCt~~~lh~Et J~n (! (~ 2DD!J ) ) RT. ELEV = 55.85' BF, ELEV = 16.12' MAX DEV = 19.44° @ 8200' TREE: 4-1/2" ,FMC W 5000 psi WELLHEAD: 135/8" 5000 psi FMCNS 10-3/4", 45,5#/ft, L- 80, BTC. CSG. 14245' I ..... A . HES 'HXO' SVLN I 1503' ----- (3.813" MIN. ID) .. W/SSSV MIN I.D. is 2.0" 4-1/2", 12.6#/ft, NSCT tubing ..... GAS LIFT MANDRELS (HES) 'KBMG' w.1" BK' LATCH ----- NO. MD-BKB TVD-SS #1 9765' 9362' #2 3507' 3418' PERFORATION SUMMARY ~ ~: ~,î 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" PACKER (BAKER "SABL-3") 9834' 9854' 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 9888' 9947 ' 4-1/2" WLE G New Style 9959' 9946' CO AWS AWS SIZE SPF 3 3/8 4 3 3/8 4 INTERVAL 10460-10470 OPN 10550-10620 T. T. ELMD [ PBTD 7-5/8", 29.7#Ift, L-80 NSCC 1 0712' I I~J ~ 10798 ' DATE REV. BY COMMENTS 11/12/94 GAM INITIAL COMPLETION 11/18/94 HT SBLlGyrollnit perfs 3/1/96 JTP ADD 2/2/98 DB TT ELM D ENDICOTT WELL 1-23/0-15 API NO: 50-029-22510 00 COMPLETION DIAGRAM BP EXPLORATION, INC. SCANNEL Jut 0 ~ 20D¿~ "'- ,.. ,.¡(.' ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 \Nc,4 ~ {iCf ¡zoot.¡ Ov:s 3/¡C¡/1-- 1. Type of Request: D D Abandon Suspend Alter CasinQ D Repair Well ŒI Change Approved Program D Pull Tubing D Operation Shutdown Pluq Perforations Perforate New Pool o D D PerforateD WaiverD Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 194-1280 / 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Development 0 Exploratory 0 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 KB 8. Property Designation: ADL-034633 11. Total Depth MD (ft): 10800 Casing Stratigraphic 0 Service Œ] 9. Well Name and Number: 1-23/0-15 / 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 10411.8 10712 10272.1 Length Size MD TVD 6. API Number ,/ 50-029-22510-00-00 3. Address: Plugs (md): None Burst Junk (md): None Collapse Surface Perforation Depth MD (ft): 10460 - 10470 10550 - 10620 Packers and SSSV Type: 4-112" Baker SABL-3 Packer 90 10756 4203 top bottom top bottom 30" Conductor 40 130 40.0 130.0 7-5/8" 29.7# L-80 40 10796 40.0 10408.0 6890 4790 10-3/4" 45.5# NT-80 43 4246 43.0 4179.6 5210 2480 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10087 10096.4 4.5 " 12.6 # L-80 38 9946 10173 10240.3 Conductor Production Packers and SSSV MD (ft): 9854 12. Attachments: Description Summary of Proposal D Detailed Operations Program Œ] BOP Sketch D 13. Well Class after proposed work: Exploratory D DevelopmentD Service Œ] 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. April 2, 2004 15. Well Status after proposed work: Oil D GasD WAG D GINJD Plugged D Abandoned D WINJI!) WDSPLD Prepared by Garry Catron 564-4657. Date: Contact John McMullen Plug Integrity D Other: \¡Jt:t.' Title Sr Production Engineer Phone 564-4711 3/18/04 Printed Name Sundry Number: .3¡;tj- 071 Mechanciallntegrity Test g1 Location Clearance D ~o ~-l,'Y'--tirlU-{ (,V C\.-t e.v ; 1'«-t:Ù.~ . . Dtf SCA!MNE['1 M,f-\V f,' } ZOD'<I \1AR 1 8 200 RØ)tJ\S BfL Date: a(t If WI??' - Approved y: O~IGtN^L BY ORDER OF THE COMMISSION ~. r Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE , '"f ~ ) ~) To: J. Smart I D. Cismoski Well Operations Team Leader Date: March 15, 2004 From: Kristin Carpenter, Design Engineer Subject: END1-23 OA Cement DownsQueeze Est. Cost: $22 ENR01WL23-N /' lOR: ann comm Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step 1 2 3 Type S o o P roced u re Set TIP. CMIT-TxIA to(-f3~ Pull TIP if CMIT passes. 1I.':-o~~,';,(I"""'" OA cement downsqueeze MIT OA cement downsqueeze after WOC END1-23 is a water injector that is currently waivered for TxlA communication. On 2/24/04 a LLR on the IA was performed yielding a rate of 0.35 bpm at 2780 psi. The MITOA performed 2/24/04 failed with a rate of 1 bpm @ 1760 psi. / Note: Last CMIT TxlA passed to 2500 psi. LLR of 0.1-0.2 bpm @ 2500 psi established on 2/24/02. The objective of this procedure is to establish another barrier for continued water ../ injection under waiver for TxlA communication. This will involve ensuring that the IA has integrity and performing the OA downsqueeze. Please make any changes to the OA downsqueeze procedure in compliance with the new downsqueeze job design work being done by Jeff Rea, et al. The procedure includes the following major steps: 1. DHD Shoot fluid levels and record WHP's. 2. S Set TTP. CMIT-TxIA to 3360 psi. Pull TTP if CMIT passes. If CMIT fails, establish LLR for additional diagnostics. ~ 3. DHD Depress OA FL with gas lift gas. 4. DHD Bleed the T, lA, and OA to +1- 200 psi and fluid pack with crude as required. 5. 0 OA Downsqueeze (may need revision if step #3 shows that leak is not at sh oe). 6. 0 MIT OA to 3360 psi after waiting on cement. If you have any questions or comments regarding this procedure, please call Kristin Carpenter at x5850, or 229-2772 (C), or Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Julian J. McMullen K. Carpenter w/o: S. Rossberg SCÞJ:~~~E[) Mf-\)í n 1 2,DO~ ) ') OA Downsqueeze JOB PLANNING DETAILS: Note: Contact WDE for job redesign if FL is not at shoe after depressing OA FL with gas lift. Current OA leak rate- 2/24/04: LLRT: LLR of 1 BPM at 1760 psi. Well is currently waivered for TxlA communication. OA= 10-3/4" 45.5# L-80 IA= 7-5/8" 29.7# L-80 Shoe at 4245' OAxlA Annular Capacity=.0397 bbls/ft Volume to shoe=169 bbls 500' of cement=20 bbls Displacement= 169 -5 (H20 spacer) - 20 (cement) - 5 (H?O flush) = 139 bbls Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: .1.Q bbls Crude Displacement: 138 bbls at 30-60 degree F Crude: (volume needed to load OA) DS CW1 01: 35 bbls Arctic Set 1 Cement (15.7 ppg) with %# per sack celloflake: 20 bbls pumpable (design the pumping time for 2 3/4+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Shoot FLs and record WHPs. 2. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 3. Fluid Pack the OA with crude. ,~r,nl CEMENTING OPERATIONS: '!\ ~ f"I\~ ( _ ,_-\'"' ï" I' \,,\\~t. ,~C..:" \, FB Pumping 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 2. Flood lines with warm fresh water and pressure test lines. 3. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 3000 psi. Note injectivity at pertinent times during the displacement. Current OA leak rate-LLR of 1 BPM at 1670 psi. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity · i._ ~ J, ) ') b. 20 bbls of OS CW1 01 surfactant c. ....250 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 15 bbls of OS CW 1 01 su rfactant e. 5 bbls of fresh water spacer f. 20 barrels of 15.7 ppg Arctic Set 1 cement containing %# per sack of / celloflake. g. 5 bbls of fresh water flush h. 139 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 129 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 4. Shut down pumps and leave the well SI. Please DO NOT try to achieve a sQueeze or to build SQueeze pressure. The intent of this job is to place cement " near the OA shoe, not to achieve a squeeze past the shoe. Record final /' pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 5. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post SQueeze: FB: 1. MIT-OA to 3360 psi. (1.2 times max operating pressure. Endicott injection /' pressure approx. 2800 psi.) Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. SC¡~N~~Ee MAJf n 1 2004 ~ " RT. ELEV = 55.85' ) BF. ELEV =16.12' MAX DEV = 19.44° @8200' ","" 't.".. .' 10-3/4", 45.5#/ft, L-80,BTC.CSG. I 4245' I 4:-1/2",t2.6#/ft, NSCTtubing PERFORATION SUMMARY .... CO SIZE SPF INTERVAL AWS 33/8 4 10460-10470 OPN AWS 33/8 4 10550-10620 PBTD 7 -5/8". 29.7#/ft, L-80 NSCC DATE REV. BY 11/12/94 GAM 11/18/94 HT 3/1 /96 JTP 2/2/98 DB 10712' I I-Þ-" 1 0798' J~ ~ ~ A . ..... COMMENTS INITIAL COMPLETION SBUGyro/lnit perfs ADD TT ELMD TR~E: 4-1',",.IIFMC W 5000 psi WELLHEAD: )"5000 psi FMC NS ~ HES'HXQ'SVLN 11503' (3.813"·. tvI.IN .··1 D) ~ W/SSSVMIN1D. ¡s2.0" GAS LIFT MANDRELS (HES) 'KBMG' w. 1" BK' LATCH -41-N()·~P-E31:<13 TVD-SS 9362' 3418' 4-1/2"'X'NIPPLE(HES) I 9834' (3.813"MIN.ID) 7-5/8" PACKER (BAKER "SABL-3") 4~1/2", 12.6#/ft, Lë80 TAILPIPE 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2"'XN' NIPPLE (HES) (3.725"ID) 9854' 9888' 9947' 4-1/2" WLE G New Style T. T. ELMD 9959' 9946' [ SCANNEC MA~f 0 1 2004 ~ ENDICOTT WELL 1-23/0-15 API NO: 50-029-22510 00 COMPLETION DIAGRAM BP EXPLORATION, INC. ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission ~ I 1.-" [2/ lqL4 TO: JimRegg P.I. Supervisor 'l<e:1 ~I 11-104 DATE: February 24,2004 r SUBJECT: Mechanìcallntegrity Test BPX Duck Island Unit MPI1-23/0-15 & 1-37/P-24 Endicott FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Well 1-23/0-15 Type Inj. S TV.D. 9503 Tubing 1600 P.TD. 1941280 Type test P Test psi N/A Casing 1700 Notes: Well was taken off injection to perform Liquid Leak Rate test. Well 1-37/P-24 Type Inj. S T.V.D. 9428 Tubing 1500 P.T.D. 1870900 Type test P Test psi N/A Casing 1600 Notes: Well was taken off injection to perform Liquid Leak Rate test. Well Type Inj. T.V.D. Tubing P.T.D. Type test Test psi Casing 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 Initial 1650 2800 Interval V P/F .E v 15 Min. 30 Min. 1700 1850 Interval V P/F .E Interval P/F Interval P/F Interval P/F / Type Inj. Type test T.V.D. Test psi Tubing Casing Type Inj. Type test TV.D. Test psi Tubing Casing 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 Well 1-23/0-15's LLR .35 bb1 minute @ 2800 psi. The last LLR test performed was .1 to .2 bb1 minute @ 2500 psi differential. OA pressure test attempted to 2000 psi, 17 bbl's pumped into OA @ 1 bb1 minute w/ 1880 psi. Welll-37/P- 24 LLR 1.3 bb1 minute 1850 psi. The last LLR test performed was .1 bb1 minute @ 2500 psi differential. Wellhouse sign indicated open surface casing shoe. 18 bbl's pumped away in OA @ 1 bpm 900 psi. The max. pressure seen on 1- 37's OA was 2100 psi. These tests showed huge LLR increases & failed tests to continue inj. M.I.T.'s performed: ~ Attachments: Number of Failures: ~ Total Time during tests: 6 hrs. cc: SC!~NNED MJ\R 1 72004- MIT report form 5/12/00 L.G. MIT DIU Endicott 02-24-04 JC.xls 3/12/2004 ) State of A'laska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich RPft DATE: February 22,2003 Commissioner ùt 2!4/o ~ dY\J, SUBJECT: Mechanical Integrity Test THRU: Tom Maunder xid:" I VI BPX P.I. Supervisor ¡n::v." ....O~ MPI Id~ 5-01& t-23 FROM: Chuck Scheve DIU Petroleum Inspector Endicott NON· CONFIDENTIAL ) MEMORANDUM ~ Well 5-01/SD7 Type Inj. P.T.D. 180-120 Type test Notes: Well 1-23/015 Type Inj. N T.V.D. 9503 Tubing 950 950 950 950 Interval P.1.D. 194-128 Type test Test psi 2376 Casing 2800 2800 2800 P/F Notes: Leak Rate test.2 bbl per minute ~~,,~~..\ ~~\"V\..~ \-((~\ ~<;.'-\,~~ ~'1 ~~~~'{ Well Type Inj. 1.V.D. Tubing , Inte~al P.1.D. Type test Test psi Casing P/F Notes: Well P.T.D. Notes: Well P.1.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING G P Packer 1.V.D. Test psi Depth 8940 2235 Tubing Casing Pretest 3600 900 Initial 3600 2400 15 Min. 30 Min. 3600 3600 2400 2400 Interval P/F v f v Type Inj. Type test T.V.D. Test psi Tubing Casing Interval P/F Type Inj. Type test T.V.D. Test psi Tubing Casing Interval P/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 I traveled to BPXs DIU MPI and witnessed the six month MIT on well 5-01 and the annual leak rate test on welll-23 as required by variance. Well 5-01 passed the standard annulus pressure test and could possibly be returned to the normal 4-year test schedule. Well 1-23 has a severe tubing by inner annulus leak. The initial pressures were equal at 2450 psi. The water injection was shut down and the tubing pressure slowly decreased to 950 psi with the annulus tracking slightly behind. The pump truck was rigged up on the annulus and an injection rate of .2 bbl per minute at 2800 psi was established. M.I.T.ls performed: ~ Attachments: Number of Failures: º Total Time during tests: 4 hour cc: SCANNED MAR 0 7 2003 MIT report form 5/12/00 L.G. MIT DIU 2-22-03 CS1.xls 2/27/2003 ") ) I C¡C¡-/d-c{ J BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 1 , 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 1-23/0-15 (Approval No. 302-079) Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of October 2002 from 1-23/0-15 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, A'Î{)~A Ilflvti~W~? Madelyn A. ~illholland Data Manager MAM Enclosure cc: File: 76.13 Re€EfVED OCT 0 3 2002 Alaska Oi~& Gas gems. Gomm\ssior, Anchorage ') ~¡ ) ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 1-23/0-15 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak at approx 2000'. 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 IIA (9-5/8) psi OA (13-3/8) psi 9/1/2002 2350 400 9/2/2002 2350 400 9/3/2002 2350 200 9/4/2002 2350 200 9/5/2002 2300 300 9/6/2002 2200 200 9/7/2002 2400 200 9/8/2002 2200 200 9/9/2002 2200 200 9/10/2002 2200 200 9/11/2002 2400 200 9/12/2002 2200 200 9/13/2002 2350 150 9/14/2002 2350 200 9/15/2002 2350 200 9/16/2002 2350 350 9/17/2002 2200 100 9/18/2002 2200 100 9/19/2002 2100 500 9/20/2002 2200 500 9/21/2002 2350 1 00 9/22/2002 2300 400 9/23/2002 2250 500 9/24/2002 2300 500 9/25/2002 2300 500 9/26/2002 2300 100 9/27/2002 2300 100 9/28/2002 2300 100 9/29/2002 2300 100 9/30/2002 2300 500 WHP (psi) 2383 2364 2387 2388 2353 2328 2426 2385 2401 2378 2348 2361 2354 2375 2392 2362 2219 2207 2101 2164 2344 2343 2303 2322 2320 2342 2300 2322 2281 2266 Ilnjection Rate (MBD)I 20386 20365 20382 20154 19142 18589 20678 19798 20439 20159 19194 19519 17028 19407 19974 19145 15914 15498 13411 15020 18710 18758 1 8001 18244 18190 18414 17801 18462 17888 17426 WHT (F) 167 167 164 165 166 163 165 166 164 162 165 158 169 166 165 156 159 172 167 164 160 170 169 170 169 165 168 168 170 170 Note NOTES: (use this section to recorde significant events such as loss of SW etc) ) ') 194-/~ì BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 1 , 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 1-23/0-15 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of August 2002 from 1-23/0-15 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, ( ltt~ (\. /lUJJL~(~d Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 ) . ') ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL1-23/0-15 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak at approx 2000'. 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 IIA (9-5/8) psi OA (13-3/8) psi 8/1/2002 2000 100 8/2/2002 2350 100 8/3/2002 2200 100 8/4/2002 2300 100 8/5/2002 2300 100 8/6/2002 2300 100 8/7/2002 2300 100 8/8/2002 2300 100 8/9/2002 2300 100 8/10/2002 2300 350 8/11/2002 2300 350 8/12/2002 2300 0 8/13/2002 2400 0 8/14/2002 2300 100 8/15/2002 2350 150 8/16/2002 2400 150 8/17/2002 2400 200 8/18/2002 2400 200 8/19/2002 2400 250 8/20/2002 2400 300 8/21/2002 2400 300 8/22/2002 2350 250 8/23/2002 2400 500 8/24/2002 2350 500 8/25/2002 2350 300 8/26/2002 2350 300 8/27/2002 2350 400 8/28/2002 2350 400 8/29/2002 2350 400 8/30/2002 2350 400 8/31/2002 2350 400 WHP (psi) 2194 2308 2304 2286 2331 2324 2306 2361 2367 2367 2366 2382 2394 2355 2359 2371 2387 2401 2398 2393 2392 2393 2395 2378 2354 2345 2351 2365 2394 2339 2387 Ilnjection Rate (MBD)I 16578 19015 18896 18581 19682 19220 18836 19588 19719 20089 20313 19965 20076 19110 19164 19203 19378 19512 19683 19532 19529 19817 20271 20424 20146 20186 20460 19914 20463 19303 20114 W HT (F) 147 149 157 154 148 152 154 165 164 168 166 164 166 165 164 164 166 167 166 167 166 167 172 170 168 169 170 168 168 163 162 Note NOTES: (use this section to recorde significant events such as loss of SW etc) ') ') ~ BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson Blvd Anchorage, Alaska 99519-6612 February 26, 2002 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Endicott Well 1-23/0-15 Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for Endicott water injection well 1-23/0-15 (PTD 1941280). This request is for approval to continue water injection only with known tubing by inner annulus communication. A summary proposal and wellbore schematic is attached. If you require any additional information or clarification, please contact Dan Robertson at 564-5546 or Kevin Yeager/ Joe Anders at (907) 659-5102. Sincerely, ~~ Dan Robertson, P.E. Sr. Petroleum Engineer SCANNED OCT 0 4: 7007 Attachments ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) þ'ì(O Of) 1/2 L.. " 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program _ Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _ Stratigraphie _ Service_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2020' FNL,2087IFEL,Sec.36, T12N, R16E,UM At top of productive interval 5196' FNL, 8921 FEL, SEC 25, T12N, R16E, UM At effective depth 5194' FNL, 8091 FEL, Sec. 25, T12N,R16E,UM At total depth 5171' FNL, 7921 FEL, Sec 25 T12N, R16E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 259118, 5982392) (asp's 260378, 5984456) (asp's 260463, 5984456) (asp's 260479, 5984478) 1 0800 feet 10412 feet Plugs (measured) Effective depth: measured true vertical Casing Length Conductor 91' Surface 4207' Intermediate Liner 10757' 10712 feet 1 0328 feet Junk (measured) Size 30" Cemented Driven 784 sx PF 'E', 375 sx 'GI 10-3/4" 7-5/8" 403 sx Class 'G' Perforation depth: measured Open Perfs 10460' - 10470', 10550' - 10620' true vertical Open Perfs 10087' - 10096', 10173' - 10240' Re-enter suspended well _ Time extension Stimulate _ Variance _X Perforate 6. Datum elevation (DF or KB feet) RKB 56.0 feet 7. Unit or Property name Other _ Duck Island Unit! Endicott 8. Well number 1-23/0-15 9. Permit number / approval number 194-1280 10. API number 50-029-22510-00 11. Field / Pool Endicott Field / Endicott Pool Measured Depth 130' 4246' True vertical Depth 1301 41801 10796RECEI\~~D FEB 2 7 zmv Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth 4-1/2",12.6 ppf, NSCT Tubing to 9854' w/4-1/2", 12.6 ppf, L-80 Tubing Tail to 99461. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker ISABL-3' Packer @ 98541. 4-1/2" HES HXO SVLN @ 1503' 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation March 04, 2002 16. If proposal was verbally approved Tom Maunder 2/26/2002 Name of approver Date approved Service Water Iniector 17. I hereby (\;/Y that the ~regtg is =d correct to the best of m: knowledge. Signed è:Jû..-v- l ~ Title: Endicott Sr. Petroleum Engineer Dan Robertson Detailed operations program _ 15. Status of well classification as: Oil BOP sketch Gas Suspended _ Questions? Call Dan Robertson @ 564-5546. Date 02/27/2002 Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval ng.. ~ a' Plug integrity _ BOP Test Location clearance ~ I 019 ~ :\ ~ J Mechanical Integrity Test $... c.\--\ \ \" L..\ ~ \Subsequent torm required 10- ~~ ", ~v\- C)~ ~~", ~~ ~\»~~o~,.(. ~~ ,,\.)~ \ \...\:.~\ '0,\ ~~ðngQI~ned By '\ Cammy Oechsli T aylot' Approved by order of the Commission commis~oljl?él ^ 4: 20ffiàte Sl,;ANNEu U 0 - ORIGI~'AL ~ ~/o')-- Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE )) Water Injection WeIl1-23/0-1:S Summary Proposal 2/26/02 Problem: Water injection well with slow tubing by inner annulus communication Well History and Status Endicott water injection well 1-23/0-15 inner annulus pressure was noted to be increasing during routine daily monitoring on 2/7/02. A subsequent mechanical integrity test of the inner annulus was unsuccessful. A leak rate of 4-8 gpm @ 2200 psi was established. Recent events: > 2/7/02: Increasing inner annulus pressure noted. Inner annulus pressure bled and monitored. > 2/10/02: MITIA Failed, 500 psi/ 7 min pressure bleed off rate. Tubing hanger seals tested good. > 2/14-18/02: Plug installed in nipple below packer. Tubing leak determined to be in the interval 1700-1800'. > 2/24/02: Combined tubing and casing mechanical integrity test successful, 2540 psi / 30 min. AOGCC witnessed test. Leak rate confirmed to be 4-8 gpm at 2200 psi differential pressure (pump pressure was stable at 4 gpm, but increasing slowly at 8 gpm) , , This sundry request is to allow for continued injection of water. The following supports the request: - The successful combined tubing and casing pressure test with the tailpipe plug installed indicates competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annuallA leak rate test will be conducted to monitor the leak severity. - A combined tubing and casing pressure test against a tailpipe plug will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressure, annuli pressures, and injection rates daily. 3. Perform an annuallA leak rate test. 4. Perform combination MIT Tubing x IA against a tailpipe plug every 4 years. 5. Submit a monthly report of daily pressures and injection rate. SCANNED OCT 0 4 2002 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. RT. ELEV = 55.85' ) BF. ELEV = 16.12' ' MAX DEV = 19.44° @ 8200' TREE: 4·· '''','' ,FMC W 5000 psi WELLHEAD: )8" 5000 psi FMC NS 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 4245' I .... A . ~ . HES 'HXO' SVLN I 1503' (3.813" MIN. ID) W/SSSV MIN I.D. is 2.0" 4-1/2", 12.6#/ft, NSCT tubing ...... GAS LIFT MANDRELS (HES) 'KBMG' w. 1" BK' LATCH ------ NO. MD-BKB TVD-SS #1 9765' 9362' #2 3507' 3418' PERFORATION SUMMARY ;~ --"" f t~ 4-1/2" 'X' NIPPLE (HES) I 9834' (3.813" MIN. ID) 7-5/8" PACKER (BAKER "SABL-3") 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 9854' 9888' 9947' 4-1/2" WLE G New Style T. T. ELMD 9959' CO SIZE SPF INTERVAL AWS 33/8 4 10460-10470 OPN AWS 33/8 4 10550-10620 9946' [ PBTD 10712' I 7-5/8", 29.7#/ft, I-þo-j ~ L-80 NSCC 10798' DATE REV. BY COMMENTS ENDICOTT WELL 1-23/0-15 11/12/94 GAM INITIAL COMPLETION API NO: 50-029-22510 00 11/18/94 HT SBUGyro/lnit perfs COMPLETION DIAGRAM 3/1/96 JTP ADD 2/2/98 DB TT ELMD BP EXPLORATION, INC. ("<oJ CJ CJ '" ~ o I- o a Q W Z Z <C Ü íJ) UNDE~JROUND INJECTION CONTROL PR\"'~kM ALASKA OIL AND GAS CONSERVATION COMMISSION Authorization to Inject with an Integrity Loss Sundry application ~~-\J~" for well ':>\\.) \-àS I a - \S- approved to allow the well to remain in injection service. PTD \~~-\). )Sis This approval is subject to the following conditions. Confirmed T x IA communication, rate not quantifiable. 4 ~ ffi,~ Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITIAlLLRT 4 year CMIT T x IA Confirmed T x IA communication, > 10 gpm. 3 Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. 2 year CMIT T x IA (tubing leak) or MIT T (packer leak) Production Casing Leak 2 Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA IA x OA Communication 1 Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA Alarm wI injection shutdown on OA. Set point minimum 1000 psi < minimum burst strength of outside casing. This approval is specific for the identified integrity loss. Should pressure/rate monitoring indicate a change in the well conditions, the following applies: Type 4 changes to Type 3, notify Commission on next business day and secure permission to continue operations. If well already has Type 4 or 3 integrity loss and monitoring indicates Type 2 or 1 may have developed, secure well immediately and notify the Commission on the next business day. By Order of the Commission (~r~~n02 RE: FW: Endicott 1-23/0-15 TeSLn¡ection)equ est (PTD 1941280) ') Subject: RE: FW: Endicott 1-23/0-15 Test Results, Return to Injection Requ est (PTD 1941280) Date: Tue, 26 Feb 2002 19:36:56 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> CC: "NSU, ADW Well Operations Supervisor" <NSUADWWeIlOperationsSupervisor@BP.com>, "Robertson, Daniel B" <RobertDB@BP.com>, "END, Production Coordinator" <ENDProductionCoordinator@BP.com> Hi Tom. The Endicott Production Coordinator will add it the report they are currently submitting for the existing 3 variances. Thanks and let me know if you have any questions. Joe -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, February 26, 2002 3:42 PM'- To: NSU, ADW Well Integrity Engineer Subject: Re: FW: Endicott 1-23/0-15 Test Results, Return to Injection Request (PTD 1941280) Joe, Returning the well to water service is appropriate, please forward the sundry. Will you be adding the well to "your" list or will others at Endicott be sending the information? Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > We are requesting verbal approval to return Endicott well 1-2310-15 (PTD > 1941280) to water only injection. On 2fl102, attempts to bleed the IA were > unsuccessful. A TTP was set and a CMIT TxlA passed on 2124102. Using a > Slickline hole finder, the leak was located between 1700'-1800', The well is > currently SI with a TTP set. Listing of recent events: > > > 02/07102: lAP = 2300 psi, unable to bleed below 1300 psi. > > 02/09/02: Verbally notify Chuck Scheve of status. > > 02/18102: Set TTP, D&D test tool found leak between 1700'-1800'. > > 02/24102: CMIT TxlA Passed. Leak rate of 0.1-0.2 bpm at 2500 psi > established. > > The passing CMIT TxlA demonstrates competent casing. We will monitor > wellhead pressures and injection rates for any indication of the leak > severity increasing. A Sundry 10-403 requesting a variance to continue water > only injection is being prepared. > > Please call if you have any questions. Thanks for the help! > > Joe > > Joe Anders, P.E. 1 Kevin Yeager > Well Integrity Engineer > BP Exploration, (Alaska) Inc. > (907) 659-5102 > email: NSUADWWelllntegrityEngineer@bp.com > > -----Original Message----- > From: Spearman, Jim W > Sent: Monday, February 11,20022:08 PM SCANNED OCT 0 4 2002 1 of 2 8/22/2002 10:56 AM RE: FW: Endicott 1-23/0-15 Test...njectionRequ est (PTD 1941280) ) ) > To: 'Tom Maunder'; Spearman, Jim W " > Cc: Robertson, Daniel B; AOGCC North Slope Office; Bob Fleckenstein > Subject: RE: Endicott 1-23 IA pressure observation > > Tom, > > Should have the work scope outlined below done by the end of this week. The > information gain will allow us to better forecast our timing. I'll keep you > posted as we progress. > > Thanks > Jim > > -----Original Message----- > From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] > Sent: Monday, February 11,20029:33 AM > To: Spearman, Jim W > Cc: Robertson, Daniel B; AOGCC North Slope Office; Bob Fleckenstein > Subject: Re: Endicott 1-231A pressure observation > > Jim, > Thanks for the notice. Your plan is acceptable. Please keep us informed. >00 > you expect to have this resolved by the end of the month?? > > Bob, would you please enter this information into the database. Thanks. > > Tom Maunder > > "Spearman, Jim W" wrote: > > > Tom, » > > On Saturday 2/9/02, the inner annulus pressure for Endicott water > injection > > well 1-23 was notice above normal operating range. The IA pressure was > bled > > down. Once the IA was shut in, pressure built at a rate of 80 psi/min. I > > contacted Chuck Scheve and reported the information. As discussed with > > Chuck, the well will be left on injection during the diagnostic work. The > > work plan is to: » »* »* »* > Set > > tail pipe plug and perform a combination MITlA. > > * The findings from the steps above will determine the next sequence > > of events. » > > Thanks > > Jim Spearman > > 659-6546 Perform an MITIA (failed on 2/10/02) Pull Shear valve. If sheared - replace and bleed IA. If not sheared - Determine inner annulus leak rate. S/I well. SCANNED OCT 0 4 2002 2of2 8/22/2002 10:56 AM Enhanced Monitoring Requirements· Annual MITIA/LLR T 4 year CMIT T x IA 2 year CMIT T x IA (tubing leak) 2 year MIT T (packer leak) Annual CMIT IA x OA Production casing leak MIT Tubing - 2 yrs IAxOA communication Annual MITT 1 I Annual CMIT IA x OA IIn addition to Monthly Report of Daily Operating Parameters; Annulus Pressure Monitoring Well Name: \)\~ \-')"3>H)-\S PTD: \ " '-\ - \ d <¿s- Operator: Sundry #: Item Y/N 1. Standard MIT test provided? N '< "'{ '< '('{ i ~ 2. Notified of pressure communication or leakage? 3. Diagnostics planned/run? Method? 4. Form 10-403 submitted requesting waiver? 5. Alternate MIT passed? Method? AOGCC witnessed? 6. MIT Part II veritìed? How? 7. Area or Review examined? Integrity Category Condition # Barriers Affected ø TxIA communication (tubing leak; packer leak not quantifiable) TxIA communication (tubing leak; packer leak quantifiable) 3 2 UIC Check List R? ~CJ;)·-a '"1 c:; New Well Date: ~\. ")C ~ d \ rlC()~ ~ Conversion Order(s): P\1:0 - ~ Comments ;)/e;-O"d \- ~ ~\ "'~~:~\ \ ~ \ \.J ~ \ '- '- \t.:\ ol~~-Od ~/~~-ad- ""\, ß£\t\.) Co t¿, ~-~ç ~(,¿.\\ '''~~'f'..~O~ ~ <::'\. ~\....,\S"c C\.\\'( ~~rC \t.Cè) ..'00'(, \C\~G\\~"Q)èk ~ e::. ~(;L \'-,,::> ~\~\ ~ \I'-\. ""'" \<t. Waiver Assessment (if necessary) Definition of Terms T Tubing IA Inner Annulus (tbg x csg) OA Outer Annulus (csg x csg) MIT Mechanical Integrity Test CMIT Combined test of annular spaces LLRT Leak Loss Rate Test ( Operational Restrictions Water only Water only f SCANNED OCT 0 4 2002 Water only Water only, Alarm wI injection shutdown on OA. Set point minimum 1000 psi < minimum burst strength of outside casing. Reviewing Engineer: t-2tyy¿~~ ~'ð';>~~ Recommended Action: ~ ~~~~ ~<::i\~ Integrity Category: '-\ Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis 2. Production casing designed for shut-in tubing pressure 3. USDW exemption or tìnding of no aquifer waiver_chkIst.doc:8112/2002 ® ) ) I 0;'-/- /d?f BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 1, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 1-23/0-15 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2002 from 1-23/0-15 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely (1~~ t". ~~lc(Q-C¿Qc~ Madelyn A. ~illholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED JUL 2 2002 Alaska Oil & Gas Cons. Commission Anchorage SCANNED JUL 1 0 2002 ) ) ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL1-23/0-15 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak at approx 2000'. Well can remain on injection under the above variance. WHP to remain below 2500psi and Annular pressures to remain below 500psi. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IIA (9-5/8) psi þA (13-3/8) psi 6/1/2002 2250 350 6/2/2002 2400 300 6/3/2002 2400 250 6/4/2002 2400 250 6/5/2002 2400 250 6/6/2002 2400 250 60/2002 2400 250 6/8/2002 2300 500 6/9/2002 2300 500 6/10/2002 2600 500 6/11/2002 2600 500 6/12/2002 2400 400 6/13/2002 2400 400 6/14/2002 2400 400 6/15/2002 2400 500 6/16/2002 2400 500 6/17/2002 2400 500 6/18/2002 2400 500 6/19/2002 2300 250 6/20/2002 2400 400 6/21/2002 2400 400 6/22/2002 2300 300 6/23/2002 2400 200 6/24/2002 2400 300 6/25/2002 2400 400 6/26/2002 2400 200 6/27/2002 2400 0 6/28/2002 2400 100 6/29/2002 2400 100 6/30/2002 2300 350 WHP (psi) 2397 2413 2400 2392 2399 2383 2351 2369 2358 2383 2382 2356 2354 2404 2417 ·2367 2241 2417 2371 2392 2394 2387 2405 2414 2355 2367 2414 2416 2421 2357 I Injection Rate (MBD)I 19405 19395 19354 19497 19895 19575 19617 19694 19990 20586 20417 19961 19361 20426 20715 19833 16219 19666 18908 19431 19715 19299 19300 19870 19200 19335 19745 19866 20154 19507 WHT (F) 169 170 169 169 170 171 175 173 175 173 172 173 174 172 175 173 160 172 170 171 172 168 167 171 172 169 165 166 167 170 Note ,:,~;:':. NOTES: (use this section to recorde significant events such as loss of SW etc) SCANNED JUll () 2002 " ® ) ) I 9 LJ ~ / d. '6 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 3, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 1-23/0-15 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2002 from 1-23/0-15 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, ()\Q~~ À .. Î\uL~I[a:&tCtJ \ Madelyn A. M)lholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED \.]UN 0 4 2002 Alaska Oil & Gas Cons. Comm¡ss¡ol Anchorage Sf'.iHIoI wru.NED JUN 24 2002 ) ') ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 1-23/0-15 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak at approx 20001. Well can remain on injection under the above vari WHP to remain below 2500psi and Annular pressures to remain below 500psi. 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) Note 5/1/2002 2400 100 2463 20719 166 5/2/2002 2450 100 2464 20628 164 5/3/2002 2450 100 2487 20938 163 5/4/2002 2450 150 2479 20958 166 5/5/2002 2450 150 2473 20773 165 5/6/2002 2400 350 2438 20350 168 5n /2002 2450 100 2414 20162 170 5/8/2002 2450 100 2406 20270 170 5/9/2002 2450 100 2407 20560 168 5/10/2002 2450 100 2440 21179 171 5/11/2002 2450 100 2427 21449 171 5/12/2002 2400 350 2403 20169 171 5/13/2002 2450 500 2404 19734 172 5/14/2002 2400 350 2435 20611 170 5/15/2002 2450 300 2444 21172 170 5/16/2002 2450 300 2429 20961 169 5/17/2002 2450 300 2401 20154 168 5/18/2002 2300 150 2407 20338 168 5/19/2002 2300 150 2408 20362 167 5/20/2002 2400 150 2426 20345 166 5/21/2002 2400 150 2426 20345 166 5/22/2002 2400 200 2417 19989 169 5/23/2002 2400 500 2414 20214 173 5/24/2002 2400 150 2400 19422 174 5/25/2002 2400 400 2424 19490 169 5/26/2002 2400 100 2437 19221 164 5/27/2002 2400 100 2425 18961 165 5/28/2002 2400 300 2437 18986 168 5/29/2002 2400 250 2412 18806 170 5/30/2002 2400 350 2422 19436 170 5/31/2002 2400 350 2416 19760 171 NOTES: (use this section to recorde significant events such as loss of SW etc) SCANNEDJUN 2'4 2002 .. . \. ~i!J~~f:~~;~:~' " '~f:-:f "I: .' :,":.:':~<~ ',:.~~"': '.,' BP EXPLORATION ) May 1 , 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 1-23/0-15 Dear Mr. Maunder: ) /G¡~'/~c¡( 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Attached in duplicate is the daily inner and outer annular pressure data for the month of May 2002 from 1-23/0-15 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, \~iV,--(~~G( Madelyn A. MiII~lIand Data Manager MAM Enclosure cc: File: 76.13 RECEI\/ED [/,JY 0 <; 'Jon? . I... v I... ,,(.. Alaska DB & Gas Cons, l.;t,Hliliìl::ìSH,: Anchoraoe SCANNED JUll 9 2002 · ) ) ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL1-23/0-15 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak at approx 20001. Well can remain on injection under the above vari WHP to remain below 2500psi and Annular pressures to remain below 500psi. 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) Note 4/1/2002 2400 750 2522 22136 168 4/2/2002 2400 750 2534 22139 169 4/3/2002 2450 300 2536 22121 167 4/4/2002 2450 250 2540 21934 164 4/5/2002 2500 450 2535 21800 168 4/6/2002 2500 250 2565 21238 162 4/7/2002 2450 300 2539 21033 166 4/8/2002 2450 350 2529 22015 166 4/9/2002 2500 250 2544 22068 164 4/1 0/2002 2500 250 2522 21534 162 4/11/2002 2500 100 2557 21990 160 4/12/2002 2400 400 2523 21326 162 4/13/2002 1700 500 1755 8742 171 4/14/2002 1800 500 1720 8921 175 4/15/2002 1900 400 1929 11914 168 4/16/2002 2400 400 2126 14963 159 4/17/2002 2400 400 2498 21302 159 4/18/2002 2400 400 2464 20637 161 4/19/2002 2400 100 2494 21052 161 4/20/2002 2400 100 2498 21173 161 4/21/2002 2400 300 2485 20888 162 4/22/2002 2400 300 2484 20909 160 4/23/2002 2400 300 2500 21206 160 4/24/2002 2450 250 2480 21003 165 4/25/2002 2400 230 2463 20952 169 4/26/2002 2400 550 2404 20132 171 4/27/2002 2400 600 2409 20057 171 4/28/2002 2450 100 2462 20875 166 4/29/2002 2450 100 2467 20734 165 4/30/2002 2450 100 2458 20525 168 NOTES: (use this section to recorde significant events such as loss of SW etc; SCANNED JUll 9 2002 ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor cei DATE: February 24, 2002 Chair _ A ,\ ~UBJECT: Mechanical Integrity Tests THRU: Tom Maunder øtJ1W~~ BPXA P.I. Superviso~ \\. ~ MPI & Endeavor Is. ,\-\o..( " 5-01/SD7, 1-23/015 FROM: John H. Spaulding Duck Island Unit Petroleum Inspector Endicott Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 5-01/SD7 Type Inj. G T.V.D. 8940 Tubing 4500 4500 4500 4500 Interval V P.T.D. 180-127 Type test P T est psi 2235 Casing 1100 2500 2400 2375 P/F ~ Notes: Well 1-23/015 Type Inj. N T.V.D. 9501 Tubing 950 1350 1325 1300 Interval V P.T.D. 194-128 Type test P T est psi 2375 Casing 1600 2540 2560 2560 P/F ~ Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test T est psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. T~pe test T est psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ, M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4=" Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variar,ce N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Type the test details in here. Expand or cotract the row height as needed. The sheet is protected so you will need to un protect first, there is no password. M.I.T's performed: ;::¿ Attachments: Number of Failures: ø Total Time during tests: cc: SCANNED JUN·~ 1 ~fìn1 M IT report form 5/12/00 L.G. mit diu 2-24-02 js.xls 3/8/02 Re: Endicott 1-231A pressure observation ) ) \ <;. L\ - \ d-- ~ Subject: Re: Endicott 1-23 IA pressure observation Date: Mon, 11 Feb 2002 09:33:20 ..0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Spearman, Jim W" <SpearmJ@BP.com> CC: "Robertson, Daniel B" <RobertDB@BP.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Jim, Thanks for the notice. Your plan is acceptable. Please keep us informed. Do you expect to have this resolved by the end of the month?? Bob, would you please enter this information into the database. Thanks. Tom Maunder "Spearman, Jim W" wrote: > Tom, > > On Saturday 2/9/02, the inner annulus pressure for Endicott water injection > we1/1..23 was notice above normal operating range. The IA pressure was bled > down. Once the IA was shut in, pressure built at a rate of 80 psi/min. 1 > contacted Chuck Scheve and reported the information. As discussed with > Chuck, the well will be left on injection during the diagnostic work. The > work plan is to: > > * Perform an MITfA (failed on 2/10/02) > * Pull Shear valve. If sheared.. replace and bleed IA. > * If not sheared.. Determine inner annulus leak rate. S/I well. Set > taU pipe plug and perform a combination MITIA. > * The findings from the steps above will determine the next sequence > of events. > > Thanks > Jim Spearman > 659..6546 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1of2 2/11/029:34 AM ., .It¡ . ~~ared . . . ervices . . rilling Alaska II -.- '''''' , -( ~, 900 East Benson Boulevard, NIB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December .14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Annular Disposal Information Request RECEIVED DEC 14 1998 Dear Ms. Mahan: Alaska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with our records and are able to prQvide you with the following data: · Individual Annular Disposal LQgs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. TheSSD records ar~ provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-01, L-16, 1-19, L-25, F-30, L-21, K-38, NMP #1 &#2, K-05, K-02, H-07, K-25, K-37, E-17, F-21,K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F -49i, K-18 · PBU Wells £-38,18-34,15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were reqllired by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ., hnnular Disposal Letter 12/14/98 - " t ~ l¡ . ) :1...8 q4~ I -4- z- I ) · Endicott wells 1-23/0-15, 1-61/Q-20, 2-40/S-22 · Exploration well sourdo~h #3 ;; ~-bso 008"'4 Iz.-b 9"'-01. - CJ8 .,Ç·II / -, - · Milne Point wells F-06, -05, H-06, J-13, L-24 - 9$- Of 0 95"· q, 's-<oq.... ( C).$:- '~'3 ,9$· ,-1:,. 3 · PBU wells-18-30, 18-31, 14-44,,.£-43, E-34, E-36, G-04A, and S-33~ ~2' 102- 93- - oS 1.. ':)'3 . ,o'¡" . c¡ oS" . 0'=7 3 · Individual logs are provided to yOU fot these logs as well. ~..¡·,sz.. I . Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. . Sincerely, 1-{? - ~ ~0.!· Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIV'ED DEC #'~ 4 1998 Alaska Oil & Gas Cons. Comm\ss\OO Anchorage ¡ ¡ f\I1l.Ç, Qgs,9rt¡ ¡ Intermltari t-na/ &ür::e............... . ¡ CorItarri1ated...................¡ Rig.w.........æh...... ...! ("~............... FamaIKx1.' Fræze Fræze..... ... ... .rklill... . .. I Dated' . . .. , . . .... ..., "^,,,,'.~ I . .'. . . .' . ...; ..,...., WeI ! Irjecbl DtJM.d I Fü:iS i Fü:iS Fü:5 PJœdbn Prdeâion TdaI f~·53ïCF20·--···fri72·2194 .h..hh-·1220· .._..._hh_.h__.__ -..--.----.h.-.-.hh---·l-····---···-------·---·-r·---- . -. --"-'-'--' ..._._.__._________.____._____.hh_____hh____._ ·2~m---h..-.--.-.-- . 1-53/Q-20 111/23/94 1216 f! 216 1-53/Q-20 i11/24/94 1271 , 271 , I . 1-53/Q-20 111/25/94 1205 I ¡ 205 1-53/Q-20 ¡ 11/26/941173 I 173 I _ I . 1-53/Q-20 111/27/94 ---195- ¡-- ------------ -gg---- 1-53/0=20--11/28/94 ---219---·--·...·--------- -------------- --.--..-- ·21g---·---hh 1=537Ö=20""--11/29/94' ..... 201' ....---.-... _ m_ _ m__m_ ..h'_'_"'_'_'_"_ --. -.-.-..-.--. .-.- mhh.__h... ¿bi'--"-"- ---- ..,.__._.._...._........... ._...~ __.. .__._..._.. .. ._..__ .... ... __ .... _..·.....h·...._n._. _...._.. ..__ . .... . _ _ _ _.... _____ . _h' __.. __.m- _.__ ____ ~Q-20 111/30/94 500 500 1-~;~-li~~~:: =¡~:~--=:::::--=-=:===--==-=-:=~-=--==-===== -~::===~~--:::: 1-53/Q-20 112/03/94 1207 207 1-53/Q-20 ' 12/04/94 185 185 1-53/Q-20 12/05/94 -568--- 568 1-53/Q-20 12/06/94 359 -- ----- 359 1-53/Q-20 ¡ 12/08/94 212 212 ; 1-53/Q-20 /12/09/94 118 118 1-53/Q-20 12/12/94 130 130 1-53/Q-20 - 12/14794- 365 --- ---.--- 365 1-53/0-20 12/15/94 606 606 1=53/0=20--1211-6/94----·402---·-----------------hh-- -.-- ....--.--.-------- ----- __m_.__.__ 402 ------ 1=53ïõ=2Ö·--·····i2l07ï94-mn.--. 950··..---h------.-.-.- h._.__.._.____.h_________·_·_·__·_..· ..__·._...·.__.__h.......... _._hh_.___.h._.___.. -·-··------..·-··-950..--·-··....--· '1=5310=20h-"- "12nO/94..···h-··15r--"--· ..-- _h.h... __h__..________·__.._____·_·_·___·___ -..--..-.--. --------. h______..________.. .--------.--.--- '151'---'-----'" 2=4078=22-·h-...h·,0 1/6-4795..·· --.-. 98'---'-'"-''''''''' h.... -. . ... _.0._' h.o.. ._....._____ ._. 1995 SUMMARY _.-- ..-.--.-------.... ____.... .__..______h_.________ ___ ___"______"..__.._....._._h ----------- ._____._______________ .------------------------..--______00______-----------_______ ---------- _____ +__-0-__0- __________________________ --_.__._0._____0._____----------- o ._..m___.'___"_'_',,___.o._~_ O".._m__m__' ....__m...._.._ ----..------..-.... ----_.-.--- ~.._._._.. ____.._m______ _.._._.___. .____..h_ u .__ ._m..._...._.__..___m ___________..______.__ ______.___o_.__u________.._____.._____..____.._o_____ ____.._.._______________________ ____________O_~___·_ Qmm1:;Car~"S f994SUtiifMÄRY"'-'-'" AmiJs Status Pressure Rate Daily Data i~aska Oil ~~ lia8 COJi'>. c:um~il¡G(·; ", Am,'horago *STOP INJECTING* ...........120........ ... ............................. .............................. Rig Completion Well Total Mud/Ctg Wash Fluids ....... .~2.ºß.4........ ...... ..30..6.º:4. ....... ..:.......1..1.6Jt ;....... . ..;...... .20Q........... , Dr.e 1 .:l 199B *Permit Expires in 30 Days or Less* Fotrnatiõri Ihtermittanl Finai Fluids Freeze Freeze Cumulative Data p .,~ L~ \...~ II- ~ )[ ~ . ;0-" .,"'.. " ,. u. ¡ ,.../ ............................... ............................... Permit End ......J.2I.~.1/.f1:4....... Permit Start .........Jl.1/.f1:4......... As set .Endjs;QU...... ........... .................... Rig Name D.Q)lQtl..1.5.................................. Inj Well Name 1::2~/.Q:J5.................................. Sur Csg Dep 42.49................. òo ANNULAR INJECTION ~ DATA ENTRY SCREEN \ ~ -::r- CJ ............................... ............................... 'Ef\'l. 20°7.'EE' SEr' 3.6 112N B 16E................................. Research lITEn TQ /1Q~rY" Legal Desc 20.20._ -...- M -- -- '-- - ...-, - .. -- - - L_ - - - .................._____........ C.QB.BEC.IEQ.CQ.P..¥..SUElM. _. ....... ._r.¡. _"'''M.___.:::::::: ................................................. ........... ......... ................... 2:.29.: 9.7................. .... ............................................................... ~-"Vf\:)-~~ V IIV;Jf::1;J ::1/;J 717 613 666 636 644 396 616 688 415 464 372 173 - ------------- 186 215 255 ------------- 2-40/8-22 i 01/25/95 188 188 2-40/8= 22-"'-101/25/95"-'·-'·- 999 ........-....-.-- ----..-...--..-..- _.._m.__._....·____· ....---..---...-. ..............___.._._00 00-.-.....-........---999-00-_-.........-. 2=40/8-~j01/26i95 :.~~~_=~.~~.~=t·..-..······---==r-..·=~~=~~--- -------·6<j""·-------····34¿-·---··.. 1-03/P-16 109/30/95 786 200 986 1-03/P-16 110/01/95 21 21 1-03/P-16 110/02/95 477 200 677 1-03/P-16 10/02/95 342 200 542 1-03/P-16 10/03/95 542 200 742 1-03/P-16 10/04/95 806 806 1-03/P-16 10/05/95 700 700 1-03/P-16 10/06/95 1,000 1,000 1-03/P-16 110/07/95 - 387 387 1-03/P-16 110/08/95 -0 323 .---~ --- 323 ~P-16 110/09/95 535 535 , . ~~=!~-..~.J~..?~~.?!~~ ~~~.... 00 _''''_''_'''00'__.'' ._mm..._..m _._....._........m.._.._......._m........_........mm._.._.__._.___._....._......__._....__.~~~...::...m___.._... ----- 1-03/P-16 110/11/95 491! I 491 1-03/P-16 -ITôï1219s----- 302''''·· ..-.-.......-~---....-....--..----- ....m..__...___.._._.!__..__.__.__ ......-.--...-....--- ....m..-mm·....-·..·....·SÕ2 -.......---. 1-03/P- f6-"-T1(5ï14/95--·-·--·1~i9..·m..-..-..---- ..-..-....-...-.--- --..--.-...---. _...._._._..__.m ----.------. ··-..·-·-·-..---·149 ---....--. 1-03/P-16 i 1 0/15/95 i 165 260 425 1-03/P-16 /10/16/95 . 553 553 1-03/P-16 110/17/95 207 207 1-03/P-16 110/18/95 421 421 ! 1-03/P-16 110/19/95 293 293 1-03/P-16 10/20/95 424 424 1-03/P-16'--'--iõ72119S--- 186- .d_.__.._._ .......__n_.. ---- .....U ...-...--- ._._____________.____m_u -.-.- _m·-186m... 1-03/P-16 -¡ 1 0/22/95 i677-·---- ----..------- ---..-- ---.-----.... 671'-''''-- 1-03/p-16"--T1 0/23/95 ..1464-..-----..--..·- !-._~ 464 __ ~ L___. ;~;~:~~J~~~;:~:~m=_~::_- .-.:::::: ... - .....--:::=.-::::..:.:..:. ~.----==-- ;~.-....--=- 2-40/8-22 01/06/95 717 2-40/8-22 01/07/95 613 2-40/8-22-01/08/95 666 2-40/8-22 01/09/95 636 2-40/8-22 01/10/95 644 2-40/8-22 01/11/95 396 . 2-40/8-22 01/12/95 616 2-40/8-22 01/14/95 688 2-40/8-22 ¡01/16/95 415 2-40/8-22 01/17/95 464 2-40/8-22 01/18/95 372 2-40/8-22 01/19/95 173 2-40/8-22·m- 01120/95 ---·:f8S------..----·---..-·---------- ~8-22 -.J01/21/95 _~~__ ~ J01/22/9~__ 25~_____._________.___..__..._.__ -- -------------- ------------. --..-.--.----.-..----.-.---.--.----------------..------.---------.----."-"--- -----..._-._-- ..-.-....---.-...-----.----...-..-.-.---....--.-.-.....-.-.-----.-.-------. .-- _______ .._h....___._·...·__·__···_··_·_·_·_·_····_____·_·____._______.______________ '. . ",['f. --, ¡. ." ~--- ~., . ,. It ,.. n '" '...-- \.~. . '1'" I'· . . '.J nft~j '~9~ N8s~a UII ~;.. \,;;a~; Gv~.). cy_¡:·~~~~~~:.·._~'..mm_____. . t.lr,hQ(ag(~ ---.----_.-.__.- - ----- --- ,,__,___~___,,__,_..._.___.,,_.._.. _..__.__.._____u____ --..--.------.-----.---------.---------- ------.-------..- ---------.---------..--..---.-------------.-.---.--------.-------- _..____.._._ _.__._n__._ _____. _____._.__.._....._m...._.._u..___._h_u.._..·____u....h__._.._..____ _.'" ..._...._.__________ mn___ _._. _..___...._..n__ - u ......_.._u__________.__ ____.__.__m____·__·__m_._ . . .. n __._____n____ 1000 psi @ 3 bpm 1000 psi @ 3 bpm 1000 psi @ 3 bpm 1000 psi @ 3 bpm 1000 psi @ 3 bpm 1000 psi @ 3 bpm -'-"1000 psi @3 bpm 900 psi @ 3 bpm _._-------_._---_.._------_._--_._._------_._---_._~ 750 psi @ 3 bpm -----.------.- 750··psr@-·:=n)'pm-----··-·--..-..--··--·..·---------- -----.-<--.----.-----..-.------ 750 psi @ 3 bpm u__.__· _......... ......_ .. .......... 750 psi @ 3 bpm . ...__nn .m._'......n_._...__nh.....u.. _.......... .....__ 750 psi @ 3 bpm ... u____.._ ...____ .. ,.__... . ...._ _._. u. ..._m 750 psi @ 3 bpm --.-............ Ohm. -Y50.psr@'3bpmm ... ....... . ._._....m..._.._ 110 bbJ of water was cement rinsate 600 psi @ 3 bpm 600 psi @ 3 bpm 650 psi @ 3 bpm 650 psi @ 3 bpm 700 psi @ 3 bpm -- --- ---.-------.- -----. - -- 700 psi @ 3 bpm --.------..-- ...---------- 7öõ-iisr-@¡-'3h'bpm"-' -- .-. -- .------------- --.--.----. "7ÕOpsi @ 3IJpm------..·----·------ --------------.. 700 f)Sr@-3-bpm----···-..···..·---·-·---------- .---.....--.. .......... ................ .--..... 700 psi @ 3 bpm --- I-V.;)I r- 10 \ 1"11 C.Uf ò3iJ c.vu 1-03/P-16 110/27/95 165 165 1-03/P-16 ITo/28/95 508 508 1-03/P-16~10/29/95 412 412 1-03/P-16 10/30/95 712 200 912 ------- 1-03/P-16 1 0/31/95 382 382 1-03/P-1S------- -11}Õ179s"------..·160 --~------_.-----_. --------- ---~--..---_.------ -------------- -- .-._---- -----··-------16"0·---------------- 1-03/P-1"S--t--11/02!95 -----279 ---------- ----------- -------------279 _n_...____ _._______._ .._.m _¡~~_~.~____m______~m_. ~_______~__m_~__.~_~ ..____..______ __~.~_~_..___._~_~_._~__~_ _...._.__m_~__..___m._.___. ___m.____.~___ ._~__~____._._~ __~~___m.._m.._ 1-03/P-16 11/03/95 850 850 1-03/P-16 ¡ 11/05/95 100 200 60 360 1-03/P- t 6 111/04/95 ----ì----- 102125197-- =200---- ~___m__ 102125/97 -308 I ¡ I I -'--·--r~----l==-~-t----------- ; ---------. m"_"_,,, _..~ ~.~..m_.. ~ ~~ .....m__.... ¡ ~_m_._._..._~m____·_ .... ~..J~-.-.. .. ~ _~ m_~m_·_~__~~·_...._m ì _____~_~_m~_..__~_ m_¡~..~_.__..__ m ..m_m.~~_____... -------- -----~-------_.__. ----~--- -------------- -200 -308 I --i------------ I ! i r i ~ -------- _ moo ·u.._______.____.__.__ ____no._____ ...unnn..'___. nn_ ____ .d_"__ .....____..__ _....______...______.____n___ .__......__.,__..________m.. _ ._ ._____. ____...__. _.____m___.________..._. ._______.__._._________ .__0_._·0_-_··----·- ___.__________.__.___0_____. ____··______.____.0__00____·_ _ _______0 . - _..___...__.___.m___ ._. ___ _m__.___O___ --·_-0____·----··-- _______________ __._______._________.0_ _______.__ ___._.___.____ ______________._____ ___._._..___.________ ___._.____0___________·_· .____.___.__ _____n_ _._. __._. ______.______~_._______.__ _____________ ___~_________ ____.__._____ __________. _______~___.__o __ ______0__. ___ . n_. ___ ___ ._. ._.__0__ .____ _..n_n __0' - 0-- __ ___.__...___ __ ___.___ 0__' ___ __ __._. _ _0__·.·________._.·___·___· . I i I ¡ ¡ , i __--==1~--==-~L=:··=::~=t= = 1__~~~=-=-:=~~===_==:_-==:::=_~==~=:=- 500 psi @ 3 bpm 700 psi @ 3 bpm 700 psi @ 3 bpm 700 psi @ 3 bpm .----.-----.. ·80õ-jJSï-~@--3bpmn-. _......__~..__._.n..,. 70Õ..pšr.@..3...bpm'.... ··7ocfjJš¡m@'3·bpm·-·n . ..~ 700 j)šr@- 3bpmm'H" ------ ----------------------- ._ .--.----·--__--0--·- '--'_0- _...._.______m_ ···_.-__000___----- Open ___0__..__.-.--------- ___ 0___' ._._ _________ ____ _._____~. ____.___ - ~ - .________.. _____ ____ _________________.._'____ ____ ___0__- Volume Corrected from Rock Washer Volume Corrected from Rock Washer _____m_________.__.. ___._____________.___________..____.__.___________n__m_._____________ -~-----------_._---~._-_.- -------------------- ---------------------------.-.-----.--.------------- --------- ---..----.---.--------.-----.-------...-...-.------ ------------ . _n __.____._.._ ___no_on --------_._------ --------..--.--.-..----.- .. _..___._h_._ .___._._ _.._..._.____ ___.... .__....._.._.______m_______ .-.------... -.---------- - ....-...-. -- ---------..-..--...-..--------....---- -.. - ~.._--_.._.._., --.------ --- .. .....--....--...-. -............... ._.. .n.__..___....... _ ... ....--....-----.- ~ Jt r~~ '~tl¡ d =i ~,' - i .r¡ f·_If'" e·~-· .- . . ' ~- I I ~ ,'..,..... ¡ ..... J j a.j · -.' - ,. ' I . ~e" - ..... . " " .,' " ""':, ' " ,", .. .:. "'. ,..... ... . . 6'» " ". 'M ' :.t -__. rv CBS r~11 ¡ n g. ._ y u _ _ _ . ... - TO: FROM: DATE: SUBJECT: API # Blair Wondzell Chris West October 27, 1995 MPB-24 Well Suspension 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form., This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/811 x 711 annulus available for the injection of liquid wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 .._~. . -' ~.' t'V' t-- \ .~ t,·; -. ~=-~ r~~ ' t-~ ç '\:.,"- '-ß -_ t)£e 1 4 199a .. ..,.-... _. . :~::::. ~.:,,_; ~~..., :,. :'J '11-:: L) -.. .~:.t""\IIII:I"':I!"~ '"-r' ""....c.\œ 0\\ & Ga5 COf¡~· t;C¡iÎ~~~'"'''''''''' 1'\00.;. ,. .....,.....on.., -\I'II"IIIJ' g~"" ~ " ~ . '...... \ - ... ... , Shared Se~ice Drilling Anndfar Injection Volumes July 25, 1995 until December 1998 Cumulative Report IniWell Surface Casing Depth Legal Dese Rig Endicott Doyon 15 1-19/1-18 5000 Sec. 36, T12N, R16E Doyon 15 1-23/0-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E Doyon 15 1-33/M-23 5013 3217'NSL, 2114'WEL, See 36,T12N, A16E - --- --.. - ------. -------- -_.._----------- - - -- -------------------------- Doyon 15 1-61/0-20 4236 3075'NSL, 2207'WEL, See 13,T12N, R16E Doyon 15 2-40/S-22 4531 2020'FNL, 2289'FEL, See 36,T12N, R16E -.-- --_._~---------- ----------- EOA Cum Mud Cum Total & Ctgs 4" Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Wash Fluids Fluids Freeze Freeze Start çnd 8,960 7,848 32,084 30,604 9,879 9,729 ._-------~ 25,228 21,379 31,195 29,952 1,063 ._____ _____.u boyon 14 15-47 3515 3648'NSL, 4956'WEL, See 22,T11N, R14E - .~-_._----- - -----~~~--------------- Doyon 14 OS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11N, -~---- -- -- ----._---------.--- -". --------- ------ -~--- Doyon 14 OS 15-48 3548 Sec. 22, TUN, R14E -q----- - ...------ ---. -- -- ---------------"--- - - - ----- -~-- --- ------ Doyon 14 OS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, Doyon 9 18-30 3930 1499'SNL, 26'WEL, See 24,T11N, R14E ----- -- ----- ----.---. ----. -.. .-----------. ------- - Joyon 9 18-31 3680 3719'NSL, 64'WEL, See 24,T11N, R14E ---<--_-----0-_._- _~_________ _______ _____ Joyon 9 18-32 3830 3632'NSL, 41WEL, See 24,T11N, R14E --~-----------~-- Joyon 9 18-33 4140 3690'NSL, 56'WEL, See 24,T11N, R14E --~--- -------------~-_. ------~-- ~---~- >Jabors 18E 12-35 3543 348'NSL, 705WEL, See 18,T10N, R14E ~abors 18E 12-36 3452 63'FSL, 899'FEL, See 18,T10N, R15E --'-~--------- -----.----------- -- ----- Jabors 18E 13·36 3431 1585'NSL, 5187WEL, See 13,T10N, R14E labors 18E 14-44 3288 2829'NSL, 1617'WEL, See 9,T10N, R14E :xploration '001 4 Sourdough #3 4236 IiIne 2245'FSL, 5067' FEL, Sec. 29, T9N, R24E '27E 3508 3648'NSL,2100'WEL, Sec.03, T12NR 11 E 1038 NSL, 2404 WEL, See 10,T13N, 1143'FNL, 2436'FWL, See 10,T13N, RtoE 1086 NSL, 2419 WEL, See 10,T13N, See 10,T13N, R10E MPK-17 ------------------ abors 22E MPC-23 4941 -- abors 22E MPC-25 8595 abors 22E MPC-26 4704 abors 22E MPC-28 5405 ---------- ------------ 3,002 1,882 3,385 4,669 --- 1,559 2,266 936 6,086 2,250 3,311 1,861 5,215 2,050 3,723 3,436 4,002 1,961 ~~-- 4,137 3,523 3,974 5,786 19,608 2,060 1,905 5,228 425 Page 1 Annulus Statl!S 12/5/96 Open 12/31/95 Open 992 1,160 200 150 2,613 1,176 120 12/5/95 120 9/30/95 8/31/95 60 12/5/95 -- --_._---~--- 120 60 7/25/95 903 ----------------- 2,009 134 820 2,283 -~-~-- ---- 1,141 1,904 1,697 216 380 1,100 200 3,035 137 50 464 2,319 4,630 1,156 18,538 285 1,800 130 1 ,465 300 4,483 555 350 ------ 800 2,565 1,100 10 1,871 1,535 685 r~I~':" Ct:i \fED DEe 1 4 1998 ~!aSK~ utI & \:,85 Cons. Ccmmjse:JrJ Anchorage ---------------- 12/31/95 12/5/96 Broached Open ---- - - . ------ - -- --~-- -- -------- 12/31/95 Open ----------- -._--- ------- 90 11m95 12131/95 Open 51 4/4/96 4/4/97 Broached 66 12/21/95 12121/96 Open 65 2121/96 2121/97 Open 150 7/25/95 12/31/95 Open 171 7/26/95 12/31/95 Open 150 8/24/95 12131/95 Open 120 9/28/95 12131/95 Open 150 9/1/95 12131/95 Open 120 10/13/95 12131/95 Open 150 10/26/95 12/31/95 Open 120 8/17/95 12131/95 . Open 1/26/96 1/26/97 Closed 100 4/18/96 4/18/97 Open 130 1/25/96 1/25/97 Open 140 1/5/96 1/5/97 Open 190 12119/95 12119/96 Open 75 2/15/96 2/15/97 Open ~ ~ Sha~d S~ice Dtilling Annular Injection Volumes July 25, 1995 until December 1998 Cumulative Report Rig Nabors 22E Nabors 22E Nabors 22E Nabors 22E ------ ----- InjWell MPF·06 MPF-14 MPF-70 MPH·05 -- -_._---------. Nabors 22E MPH-06 Nabors 22E MPI-07 Nabors 22E MPJ-13 Nabors 22Ë MPJ-16 Nabors 27E 8-24 Nabors 27E MPF-22 Nabors 27E MPF-25 Nabors 27E MPF-37 ------- Nabors 27E MPF·38 -- .------------- Nabors 27E MPF-45 Nabors 27E MPF-53 -- -----------.- - -------- --- Nabors 27E MPF-61 Surface Casing Depth 8766 6690 7919 5335 7304 2680 4080 --- Cum Total 1,927 18,717 19,775 8,283 8,515 1,680 -.----- - - 14,127 8841 See 06,T13N, A10E UM 6,536 ___ _0-____---- ______.__________ 3405 1857'NSL, 2696'WEL, See 6,T13N, R10E ·9,897 6621 1931'NSL, 2643'WEL, See 6,T13N, A10E 7,032 ------ 8561 1994'NSL, 2731'WEL, See 6,T13N, A10E 9,232 .-- ------- - ------------------ 6678 1979'NSL, 2608'WEL, See 6,T13N, A10E 17,562 6750 2028'NSL, 2572'WEL, See 6,T13N, A10E 2077'NSL, 526'WEL, See 31,T14N, A10E 2141'NSL, 2627'WEL, See 6,T13N, A10E 2125'NSL, 2502'WEL, See 6,T13N, A10E 2237'NSL, 2555'WEL, See 6,T13N, A10E 3654'NSL, 5180'WEL, See 8,T13N, A10E ..--------- -- 6585 Nabors 27E Nabors 27E ------_.__._-_._~---- 6059 5772 MPF-62 MPF-69 ~-------_._----- Nabors 27E Nabors 27E MPF-78 MPL-24 7085 6515 ---_.__._-----_._---~ ----- WOA 18E 18E Joyon 9 Joyon 9 Joyon 9 -Jabors 18E F-33 ---- F-36 3570 3691 3332'NSL, 2174'WEL, See 2,T11N, A13E 2642'NSL, 2878'WEL, See 2, T11 N, A 13E -----_._-."-------------- ------ 0-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11 N, 0-31 3215 SEC. 26, T11N, A13E ---.---------- 0-33 3222 2965' NSL, 1067' WEL, SEC. 23, T11 N, S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,A12E 6,051 5,732 386 9,740 8,476 6,790 Cum Mud & Ctgs 1,731. 17,107 18,794 7,711 8,335 1,280 13,292 -~._---- 6,466 9,357 6,887 9,157 17,381 5,671 5,657 316 9,665 7,456 4,900 1 ,468 183 6,963 1,998 5,261 2,811 150 4,661 2,425 5,943 2,636 Page 2 -------- -- - -------- --------.. Cum Rig Wash 1,270· 735 382 40 1,320 660 1,359 1,275 2,106 1,716 Cum Campi Cum Form Cum Interm·· Cum Final Fluids Fluids Freeze Freeze 196 190 Disposal Period Start End. 1/25/96 1/25/97 Annulus Status Open Open Open Open 340· 6/3/96 56 6/17/96 190 8/19/95 180 8/5/95 6/3/97 6/17/97 12/31/95 12/31/95 Open ----- - ----------- - ---------..- ---- -~------_.---~-~-- ------ 12/31/95 250 70 165 75 60 . - l~aC Cons. Con1!!ÙS~~.:n pjattli.1 0\\ tit ~ ~ 0'" AncbOt8"", - --- - -- ----- -- -- 250 645 ----- 80 70 9/21/95 12/31/95 Open ----------------- -- -.-----.--- --------+-+------------ ---- 60 130 10/17/95 Open Open ~' Legal Desc See 06,T13N, A10E Sec06,T13N, A10E UM 2189'NSL, 2591'WEL, Sec 6,T13N, A10E 2882'NSL, 4028'WEL, See 34,T13N, R10E ----- 282~'~~L, 40~4'WE~,~ec ~,T13N,-.~.1~.__ 2339'NSL, 3906'WEL, See 33,T13N, A10E - - - - .-- - -------- - 2835 2319'NSL, 3179'WEL, See 28,T13N, A10E - .._~_.----- --- .-.- ----~----------- ----------- 3112 2317'NSL, 3336'WEL, See 28,T13N, A10E 985 915 -.---------.- - - ~ -... - -~------------------- --- See 18,T13N, A11E UM 1,468 1,396 -----------~~- 70 11/12/95 12/31/95 -------- - -- ------------------- Open 72 775 65 165 335 465 3,471 1,035 1,511 f~t:Ct\vED DEt 1 4 1998 ----- ---._---- ----- -------- 1/25/96 1/25/97 70 12/12/95 12/12/96 Open -------- _._--~ 225 65 12/26/95 12/26/96 Open 75 7/25/95 12/31/95 Open 75 12/6/95 12/31/95 Open 181 80 75 70 75 140 70 7/31/95 12/31/95 Open 8/19/95 12/31/95 Open 8/31/95 12/31/95 Open 10/13/95 12/31/95 Open 8/31/95 12/31/95 Open 9/12/95 12/31/95 Open 11/27/95 12/31/95 Open 160 2/21/96 2/21/97 Open 135 12/18/95 12/18/96 Open W ------ 140 1/31/96 1/31/97 Open 150 4/20/96 4/10/97 Open 130 2/21/96 2/21/97 Open 80 5fl/97 5m98 OPEN Shared, ~êt1tice D~illing AnntJiàr Injection Volumes July 25, 199~ until December 1998 Cumulative Report Surface Casing Rig fnjWell Depth Nabors 28E 8-33 3504' Nabors 28E E-34 3664 Nabors 28E E-36 3648 Nabors 28E E-37 3810 --+---.--- ---<-.-- Nabors 28E E-39 3638 Nabors 28E G-04A 3509 Nabors 28E G-21 3509 Nabors 28E S-24 2750 Nabors 28E S-33 2958 --------- Nabors 28E S-41 3331 Nabors 28E S-42 3077 ------------- Cum Mud & Ctgs 2,842 7,228 4,417 4,241 928 Cum Rig Wash 857 1 ,420 1,293 374 220 Cum Campi Cum Form Cum Interm Ruids Fluids Freeze 195 858 -- ---------- 3,096 1,022 ------"--. 1,798 3,956 11,773 -------- - - -- ---------.----- 6,613 8,062 4,159 168 100 4,860 3,725 1,452 857 - _.----------- Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21 ,T11 N, R13E - -~------------------------ Nabors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E --------.-. - ---------- -----------.------ Page 3 1,824 .--- ._~---- 3,072 2,177 2,431 2,034 ._-- 555 100 2,315 - -- ---~-~._--- 4,270 5,751 8,392 70 275 - ---------.- 270 --------- ----- 68 3/13/96 1,754 480 410 Cum Final Freeze 80 Disposal Period Start Enç1 5/1/96 12/31/96 "62 285 308 115 Annulus Status Broached Open Open Open Open ---- -- -._--- Open 9/8/95 12/31/95 Open ---------+--- ----- .- - -----------.-- ------ 12/9/95 12/1/95 2/8/96 Legal Desc Cum Total 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 ---- --.. -. - ---- ------- 1706'SNL, 822'WEL, Sec 6, T11 N, A 14E 9,271 3391'NSL, 881'WEL, Sec 6,T11N, A14E 4,695 "-"--.-...---.----.----.-----.---.---.- --.----- 3358'NSL, 501 'WEL, Sec 6,T11 N, A14E 2,250 - - --, - -- - -- -------------- 2917'NSL, 1974'WEL, Sec 12,T11N, A13E 5,937 -.- - .-- - -------- -----------.-- 2911'NSL. 2368'WEL, Sec 12,T11N, A14E 11,430 ---------------. -- 1633'SNL, 4228'WEL, Sec 35,T12N, A12E 20,261 -- -----. --------- ---------- 1639'SNL, 1487'WEL, Sec 35,T12N,R12E 18,014 4152' NSL, 4504' WEL, Sec 35,T12N, -------- ..._-~-------------- Sec 35, T12N, A 12E 40 110 8/23/95 12/31/95 -- - - .---- ------- - ~ 365 100 7/25/95 12/31/95 80 9/16/95 12/31/95 .------------.------- 80 8/28/95 12/31/95 10/20/95 12/31/95 ------ ----~-_._- ----- 20 80 10/26/95 85 10/26/95 ~:ü=Gt':Ù¡EO DEe 1 4 1998 -" ~~~~"'~~r'-"r . " ..: ~on5.lIOtœmw,-....;.' ";uï;;i',¡; .J'¡ () ~d.... \\nchoT8'JÐ -- 12/9/96 12/1/96 2/8/97 3/13/97 12/31/95 12/31/95 Open ~ Open Open Open Open Open .~ ~ s. Q) Q ~ ~G) g.= ~§' (i)~ ~ :::l 3 fj õ' =' . .-oS c.D ALASKA OIL .AND GAS CONSERVATION COMMISSION MECHANICAL INTEGRITY TEST Date: 11/18/98 Company: . WELL *s; *I TYPE OF PKR *p: ANNULUS TVD *M; *N FLUID I-iD 1-23/0-15 P 9502 I BRINE ~ 9855 CASING SIZEr.'1T ¡GRADE 7-5/8- /29.7# L-BO NSCC BP Exp1oration TBG REQ PRETES~ SIZE TEST <rEG PRESS eSG PRESS 2200 : 4.51J 2378 50 co~s: Test not witnessed by AOGCC Rep. Waived by C. Scheve :z o -< ~. n C COMMENTS: n - <: rr U'COMMENTS: --- (,0 <.0 00 COMMENTS: Tli13!N.G I.NJ.ECT~ON Fl.UID: P = PRODUCED WATER INJ S = SALT l'jATER INC" M = MISCIBLE INJECTION I = INJEC':'ING N = NOT INJECTING ANNULAR FLuID DIESEL GLYCOL SALT ¡'jATER DRILLING MUD OTHER OTEER GRADIENT: rœLL TEST: Initial Explain Field: Endicott I DUr I MPI S~ART 15 rfJN 30 MIN START T3G TBG TBG TIME CSG CSG CSG PRESS PRESS P.3.ESS 2225 2225 2225 2525 2525 2525 : 1549 4-year _x ~1)'orkover N/A AOGCC WITNESS SIGNA-TORE Doug Varble COMPAiW REP SIGNATURE p F p~ I--i t=1 :--- :z 0 c ......... \..0 \..0 ~' co co Ul '1) ()'I I~ :z a o 'I~ 0 ~<.N & --0 ~ . [\\~ ,~ ID: NOV 19'98 8:57 No.003 P.03 ) ) - 1\",,,.- BPX , "'".....,.~- ð Endicott Production Engineering , Departlll:~nt ... . ".....,.. MJI_Test On .IA DATE: 11/18/98 WELL Nit: 1-23/0-15 BP EXPLORATION REP: D. Williams SERVICE COMPANY: HB&R , '. '\ DATElTIMI: 1532 .. ....!II OPERATìÖNS SU~MARY ... .-- . .,,- .........- .- MIRU HB&R to IA and PIT hard-line to 3500 psi. FWHP=2200 psi ......... IA.=50 psi O,~:;=º_,psi. _. ..... Sta~~d pumping 60/40 ME.TH. down IA. _, Pumped a'total of 5 bbls of METH. Started 30' min. test. TP=2'225 psi fA: 252? psi QA= 280 psi,_. TÞ= 2~25..p_~¡'IA=2525 psi O~~2a.º-ps. TP=.?~~5.p~i IA=2525 psi Oð;;280.psl. . ........_ T~=:=2225 psi fA=2525 p~l...OA=280 psi. stop test. ~I~~~_IÄ-back to 5º.Q p~.i.~ J~DMÖ. . '.')) 1536 1539 1549 1559 . .. '.." .. 1609 1615 SUMMARY: * Pumped a total of 5 bbls of 60/40 METH. · Held 2525 psi on IA for 30 mlns. Good Test. * TP~2225 psi IA=2525 psi OA=280 psi "",,/// Hot Oil Service , Flhet Unite ) NOV 19'98 ___. -.-, _, .J.J.Y\,,' '. Pouch # 340083 ) Prudhoe ely. AK 98734 8:57 No.003 P.04 Prudhoe B&, (907) 6&9-3182 PIge, (107) &59..3618 Cøllular (1071 6&9·0223 ID: - , .1 Job Type.~.. /I!~':I._ ... Location I~ 2. ? . ..., £?4(~ i)"hh. Date /~ //3 ._.... .. Operator ~(f¡~. -r ~ .lPdir--.- . Unit No._,.~ ...]17 Initial WHP. . PSi IA_ ..... ._ psi OA ... P;~ssure . "BBls" Pe~ MInute ..psi 10tal BBLs Final WHP psi fA_ ...,,,, psi OA ..p~ Time rype of Fluid ....... . . ~ .. . 3i3\1.~ 1'PI~.ð"·· tf?«_"3~~ 4J:.J6 .~~~ J?~_ '.../~l)..... :1:1. 7 I ,l()() ..L e. .3.'.~5 . -~. r:+ú-.. .-. Temp. Comments 2.ï~·'!f.At!</ t.. _ ,1",,- . _ ~~~~~. ,1Þ1d~ . ff¿~i1~:t-._- --. . :.._.. .. -£-h-,,:I-&!QJr-- .. .7'</';'""" ~/l/Jc....~ +1<7. :2" 0 0 .. oA. ~'O ~... ~-_..s Ä,P... )/¡;jJ '¡;/~4 t&~~. .... ~1'-? ""-.2r ~ - ~-:4éIr> . . I-~ -:? / ~ (..{ .. .... (\.A;. - 7./Q (") -.. - -fi,.J ~ ~~~.:- - ."!!, ~ ~¡;() --I)... . .: :>, :.....,.J . - .,,\ J. )~-,. .,.. ....., I - ., A..S _~ __. .,,- .h-#:;j' 1#0<1 '1/ I~'- '2~~- ..s-O 0 .12o~~.. f<~-!-.. -"':4¡:-..<.ur oÆ-~ --,J(~J....~~ r~ Hsn FoITII 430 "'16196 ~,~;P,',"III. OIœllGO- PEF.:~IIIT D/\Tt\ ) , ,) t\ () G C~; C I n d ",' v 'j' d U I:~I I,AI el ï Ci e 01 0 q'¡' c al Mat e r' :, ,~::¡ ï ~::; I n v E; I'^\ tor V ,,,, iD c80' ' T DATA_PLUS,Ø (c7/~ P a ':~ '::~ ~ 'j IJate ~ 'j °1/20/96 F: IJ N D /\ T E ..._..F.: E C \/ D ~~... ......... ~~,. ........ ....... ........ "'.... ,..... ",. ""~ 'Yo" ....,. ....'.. ....., ...... ......,. ",.., ......... ,..... ........ ....,- '..... ·'w ".. ,",.. ,..... v.,' ......,. .....,. ....... ......,. .,,',' ......' ..". ""'" ....,. '..... ....... ....,... ....,.. ....... ........ ......" ....... ..,.,.. ....... ....... '""" ,....., ",. ...... '.'.',' 'ow w. ....... .",. _'" ....... '" 9how'128 94 "" 'j 28 94""'j2~3 9LJ.·w128 94'-' '128 9l¡,""j28 94 "" 'j2~3 s~ Li- .,..... '1 :? l1 94",128 94~"128 9h ",. '120 9h""128 94,,,,128 6 3: 3 'j ßHP DIFL/Gf;:/SP F~1T GR/CCL/PERF ~,, E L PFC/CiR/'CL I:)L~; .~ IN,,,I P L ~:: ,/ r' I 'oJ A L .. J N J S8T,/GR/CCL. SPIr,! L()(¡ :3 S TVD ZDL/CNL/GR/C¡.\L "... ....... ,'"' '100''' '...... ~'oo'''' '10768 'j'I/22//94 Y9800- 'I 0749 'II / 'I ,t, / 9 l r7 200"" '1 0779 11/ 'll¡·,/9h X 7?¡6:2""7726 '1 'I / '1 4 ,/ 9 l¡. VS E F' I A ( ~ :3 "t 8.... lorY ¡> ~¡t~,.d1 0 6~· 4 0:3,/:20/98 0::::/ '17,/95 y ,] 0400'- '1 0666 X'SEPIA lo}1""0'" 1.'c,lð 0'1,/23/'95 03/20/9(3 ¡",,( 'I 0 /.¡, 0 0,- 'j 0 6 2 !S 0L¡./20/9~) X 9692" '10688 1.1.t)~ L :a..8"- 'I 0 6 lJ. 4 '12/02,/94 03/17,/9S, ~9 BOD 'w "1 0 '7 7 9 11,11 D -r:-7:200~ '107/,¡,9 '11 / '1 l¡. / 9 l¡. '1'1/ '¡h/ 9/'¡, ve:5 <~ A-nd '"'ee,e1i ved? Are dry ditch samples required? Was the well cored? \/.~:~~ no ve s ~Ä niSI 'I '''I' S ",' s &. des c r' " p t ·ï 0 n I" e c e " v 0 d '? V0;::; no A r' E~ V,,I e 1'1 t e :~)t~; I'" e q ul' r' e d ? V e s ~ R e c e i v e d ? lIIel1 'is ï n compliance ~_ I 1"1 ",' t :¡, 031 CCJMi\1 ENT:3 '~"-...........' ~"~_~.N- I ~ . ~!J_____,__. ". .:Pt~\':1 ~ Y-'J. . .' \ì:~S U\¥.\C.~......, O~ý .hu1\I) 'Y e-s--f) 0 k . .. , . JI1Ji. ~$~..... __ .. 3/(ÝL!;=_.__ ~ ._. IO/'-'lftl,- /(1 ð '/ft-----..____o_____;¿LL'i_.L.fL..o_ . (\ ", ¡(, 7..- £t> b ~ .R. t'l ~ ~W"¡ J t ..'0___0_"____ .JI' vjj!lt:::._,o___ ~ >- b 7 _16 tJ ~q ß. n ~~ r: II J / ).ê) /fJ..r I STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ORIGINAL Perforate ..JL Other _ 6. Datum elevation (DF or KB) KBE = 55.85 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-23/0-15 9. Permit number/approval number 94-128/96-036 10. API number 50- 029-22510 11. Field/Pool Endicott Field/Endicott Pool 1. Operations performed: Operation shutdown _ Stimulate _ Plugging_ Pull tubing _ Alter casing _ Repair well _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service -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 3259' NSL, 2087' WEL, Sec. 36, T12N, R16E At top of productive interval 83' NSL, 893' WEL, Sec. 25, T12N, R16E At effective depth 85' NSL, 809' WEL, Sec. 25, T12N, R16E At total depth 101' NSL, 769' WEL, Sec. 25, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 10800 feet 10466 BKB feet Plugs (measured) Effective depth: measured true vertical 10712 feet 10767 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 91' Size Measured depth BKB True vertical depth BKB Cemented 30" Driven 130' 130' 4207' 103/4" 784 sx PF "E"/375 sx "G" 4246' 4179' 1 0757' 7 5/8" 403 sx Class "G" measured 10460' - 10470', 10550' - 10620' 10796 10407' true vertical (Subsea) 10031' - 10041', 10117' - 10184' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/ft, NSCT tubing set at 9959' Packers and SSSV (type and measured depth) 75/8" Packer set at 9855'; 4 1/2' SSSV set at 1503' 13. Stimulation or cement squeeze summary Intervals treated (measured) it: ('~ ~.~: ~ 't~, { ;'" lkw ~r.~ m.ow w ~l ~~: ÔFJR ') r' 'tg'''''''' I! ¡, ¿ \') I'.. ,.I.:~ -. . ,J v Treatment description including volumes used and final pressure Af¿~~Û:a í)iJ 8r GD:3 Con~;. Cc;n;-,11ss¡œl ,f:,;j{. r¡~; ".1 !J ¡} 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations -.X.. Oil_ Gas_ Suspended_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C:)¿.I{,./z,/1.--<"-- c;;(" 1;(¿:''l¿'t~~1'''' Title Senior Technical Assistant /I Form 1 O.:1f64 Rev 06/15/88 V Prior to well operation Subsequent to operation 17382 16982 1701 1618 Service Water Injector Date <¡;65~/qt;? SUBMIT IN DUPUCATE ~ \' ,~': ~, !E3PJ( i!i Endicott Production Engineering Department Additional Perforations DA TE: 2/29/96 WELL N°: 1-23/0-15 BP EXPLORATION REP: POWERS SERVICE CO: ATLAS' (BARKER) II DATE/TIME 0945 1045 1135 1200 1310 1350 1360 1215 1230 OPERATIONS SUMMARY MIRU. FWHP = 0 PSI; lAP = 250 PSI; OAP = 0 PSI SI WELL TO LOWER WHP. INSTALL SSV FUSIBLE CAP. SIP= PRESSURE TEST LUBRICATOR TO WELLHEAD PRESSURE. RIH WITH GUN #1 (10 FEET). TIE IN TO DIL DATED HANG GUN #1 AT 104581. SHOOT GUN #1 FROM 10460' TO 10470. LOG OOF AND POOH. CONFIRM ALL SHOTS FIRED. RD. MOVE OVER TO 1-27. POI ~ PERFORATION SUMMARY: GUN 1 DIL DEPTH 10460' -10470' FEET 10' SUBZONE 2A ALL INTERVALS WERE SHOT USING 3-3/8" ALPHAJET GUNS AT 4SPF, RANDOM PHASING AND 60-120° ORIENTATION. r,'...... , \~. l'·· IC ~ '\ l 'í.:,:",q). I' ,I,." ~ ~ ~ V ¡I ¡~ ~\\;~ \),t.\I.' \~...... ;;\.r.mI '..-,:, I 1"\ ,..... ·~'(\0G t. \J I.:J.J þ:.~,~,~3t:a 8, G~~; GO~~,",Güm:;:',~5S\Dn J),nd-;t1;t;¡H\" ' \ ( LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date,: 5 March 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL .JI. DESCRIPTION ECC No. 1r S7- ~ 1-27/P-20 1 PLS FINAL BL+RF Run # 1 4731.04 q tf~ ( ;t~1-23/0-15 1 PFC/PERF FINAL BL+RF Run # 1 6296.05 ~ ~ 1'~-23/0-15 1 PLS FINAL BL+RF Run # 1 6296.06 9'~¡~1" ,I. ,,'..,'....,,<:,,),,,,.,, ,'. Iq," , ' Please sign and return to: Received by: ~ Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 r< ~::{:~: .::: J t: 1.) ') O,,"'~(þ;: :_ \.,J..... \,) Date: A!eska Oil f:.t ,3a5 Cens. C-o:m¡¡issicn ~ ~,~:1r;f1C~ ( ( mi BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 13, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. B. Wondzell q ~/__ \ 'L í Dear Mr. Wondzell, Attached, please find an Application for Sundry Approval for Endicott MPI water injection well 1-23/0-15. BP requests that additional perforations be approved for the well to better manage voidage replacement in the MPI uppermost Subzone 2A. Please feel free to contact myself at 564-4613 if you require further information or discussion regarding the proposed course of action. Sincerely, /J$4~ Bo~~r Endicott Development attachments rrm ec: Haas, J. Suttles, D. Wood, D. Endicott Production Coordinator Endicott PE Supervisor cc: File 06.10 1-23Well File RECt::rvED FEB 1 5 1996 Alaska Oil & Gas Cons. Commission Anchorage <.E (" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSIU¡\I 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 -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 3259' NSL, 2087' WEL, Sec. 36, T12N, R 16E At top of productive interval 83' NSL, 893' WEL, Sec. 25, T12N, R16E At effective depth 85' NSL, 809' WEL, Sec. 25, T12N, R16E At total depth 101' NSL, 769' WEL, Sec. 25, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development _ Exploratory _ Stratigraphic _ SeNice --X...- ORIGINAL 10800 feet 10466 BKB feet Plugs (measured) Effective depth: measured true vertical 10712 feet 10767 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 91' 4207' 10757' 7518" measured 10550' - 10620' Size 10314" Cemented 30" Driven 784 sx PF "E"1375 sx "G" 403 sx Class "G" true vertical (Subsea) 10117' - 10184' Tubing (size, grade, and measured depth) 4 112" 12.6#lft, NSCT tubing set at 9959' 6. Datum elevation (DF or KB) KBE = 55.85 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-23/0-15 9. Permit number 94-128 10. API number 50- 029-2251 0 11. Field/Pool Endicott FieldlEndicott Pool Measured 1rR~ True vertical depth BKB 130' 130' 4246' 4179' 10796 10407' RECi::IV1::D FEB 1 5 1996 .Alaska on & Gas Cons. COmm\sslon Packers and SSSV (type and measured depth) 7518" Packer set at 9855'; 4 112' SSSV set at 1503' Anchorage 13. Attachments Description summary of proposal -X- Detailed operations program _ BOP sketch 14. Estimated date for commencing operation February 21, 1996 16. If proposal was verbally approved 15. Status of well classification as: Oil Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Name of approver Date approved Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ d. ~ Title~1, -rÙJ._ ~"C ¿;/ . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- '-lo¥ Gas Suspended _ Ir Date-2} '3/91, Approval No.' <11o' 06lp Approved GJµy f!.etlJ~ed 2124./9Co _ Commissioner Date ?/ 7..oh~ SUBMIT IN TRIPLICATE ~ ( f SUNDRY APPLICATION FOR ADDITIONAL PERFORATIONS ENDICOTT POOL WATER INJECTION WELL 1-23/0-15 February 13, 1996 Background Well 1-23/0-15 was drilled as an MPllower subzone water injection well to provide pressure support via voidage replacement in November, 1994. At that time, the well was completed with perforations placed below the regionally correlative "0" shale, primarily to support offtake at wells 2-04/M-19 and 1-25/N-22. To date the well has a cumulative injection of 4.1 mm barrels of water. Injection averages approximately 17 m barrels 1 day. MPI Upper 2A Reservoir Management A review of upper Subzone 2A reservoir performance has shown a need to increase water injection. The increase in water injection is anticipated to provide relief for recent rising gas production at well 2-14/0-16 and decrease the ratio of gas:water injection in the MPI 2A overall. Well 1-23/0-15 is best positioned within the reservoir to achieve these results. Recommendation BP requests that additional perforations be approved for the uppermost 2A sands at well 1-23/0-15 across the interval 10455 - 10480· md (25l A minimum targeted injection rate of approximately 3000 barrels of water 1 day is required to balance current voidage. An injection profile will be acquired following the additional perforations to ensure the desired results have be ach ieved. rrm encl. (1) RECEIV1::D FEB 1 5 1996 Maske OU & Gas Cons, Commissioo Anchorage SPINNER SPINNER SPINNER SPINNER 4/7/95 1.00 10117 10184 TOP TVD BOT TVD -s _V) , co -s -..... K1 S1C -s - ~ \i.B0S=: -s - ...... I.ØØØ= - -s U') -U') -s ...... -s s -U') -s ..... XPh 88-92 lOG: 08 t-tdt/-tr 5Ø~29-2251ØØØ ',1-23/0-15 ( 70 10620 10550 H TOP M.D. BOT M.D. ENDICOTT WELL 1-23/0-15 API NO: 50-029-22510 00 COMPLETION DIAGRAM BP . EXPLORATION, INC. 2A ZONE SBL 11/17/95 LOGJDA TE COMMENTS INITIAL COMPLETION SBl.JGyroIInIt perfs Depth COIT8CtIoo8 J J"" , , , " , , ~ \. ,',',',',',',' J~ """", 1<2A. S3A.3 "M" I ¡ ""-'$ I S3A2 I ....1fl" WlE G New StM ,~ 9959' ....1fl" 'X' NIPPLE (HES) 1 9834' ~ (3.813' MIN. ID) ~ ~ . 7-518" PACKER 111854' .2S. ---- (BAKER "SABL-3? ~ ....1fl". 12.8I1ft, L-80 TAILPIPE .... ~ 4-1fl" 'X' NIPPLE I (HES) (3.813" 10) 9888' 4-1fl" 'XN' NIPPLE I ~ (HES) (3.725·ID) 0947' "3A 0362' 3418' .1 8765' 12 350T BHRZ _ GAS UFT MANDRELS (HES) 'KBMa' w. 1· BK' LATCH ~ NO.,MD-8K8 TVD-SS . HES 'HXO' SVlN I 1503' ~ (3.813" MIN.ID) WISSSV MIN LD. Is 2.0" TREE: ....1fl",FMC W 6000 psi WEI.LHEAD: 13 5N' 6000 psi FMC NS ~ ~ Interval 10550-106200ør\ ~ --1 a o L 1-23/0-15 WELL NAME REV. BY QAM HT JlH DATE 11/12/94 11/18194 2113196 10712' 10798' PBTD 7.{S18".2Ð.7./ft, L-eo NSCC SPF .. Size 3a/8 ~. AWS PERPORA~ONSUMMARV 4-112". 12.8I1ft, NSCT tWIng 1Q.3I4·.45.5I1f1. L·eo. BTC. CSG. ~ AT. ELEV . 55.85' BF. ELEV . 18.12' MAX DEV . 048.9- 0 4298' ~.. ( MPI WELL 1-23/0-15 , ~. .. .~ I~ . { ( . . ~~~\"I~~~~~'-'~~~~~::~~~~~r::~~3;~:~-~: Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) March 16, 1995 TO: BP Exploration (Alaska) Inc. Marian Sloan, MB12-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The-following Anadrill data for well 1-'3/0-15, was sent to: BP Exploration (Alaska) Inc. Marian Sloan, MB12-1 900 E. Benson Blvd. Anchorage, Alaska 99519~6612 Arco Alaska Inc. Attn: Dede Schwartz, ATO-1336 Anchorage, Alaska 99510-0360 .------- State of Alaska .----- Alaska Oil ~~rvation Comm Attn:~a1TY Grant 'Ó1 Porcupine Drive Ancllo "§-B-r Alaska 99501 Exxon Company, USA Alaska Interest Organization Attn: Susan Nisbet 800 Bell St., EB3083 Houston, Texas 77002-7420 UNOCAL Attn: Debra Childers 909 W. 9th Ave. Anchorage, Alaska 99519-0247 Amoco Production Company Attn: Shirley A. Kuhr 18506 Osprey Circle Anchorage, Alaska 99516 RECEIVED MAR 1 7 1995 Alaska Oil & Gas Cons. Commission Anchorage 1 Diskette (MWD - Final) 2 Blueline each MEL & Spin Log 1 Mylar each MEL & Spin Log 4 Survey Programs 1 Survey Program 1 Diskette (MWD - Final) 1 RRolled Sepia each of the MEL & Spin Log 1 Blueline & 1 Rfolded Sepl the MEL & Spin Log --------.~,." 1 Blueline & 1 Rfolded Sepia each of the MEL & Spin Log Sent Certified Mail P 905 127 791 1 Blueline & 1 Rfolded Sepia each of the MEL & Spin Log 1 Blueline & 1 Rfolded Sepia each of the MEL & Spin Log Sent Certified Mail P 905 127 794 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER. MB3-3 900 EAST BENso1\J BLVD. ANCHORAGE, ALASKA 99519-6612 Schlutl1berger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Received By: ( 'I' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well OIL ŒI GAS 0 Classification of Service Well SUSPENDED 0 SERVICE 0 ABANDONED 0 2. Name of Operator ~ toCA11OIIIi~ BP Exploration : , ¥!fJf~ l 3. Address Ç"""'IJI/\ ~ P. O. Box 196612, Anchorage, Alaska 99519-6612 &'~Lf.~h" ¡ 4'3~~;~i~~:: ;~~;,t ~~:,c~EC. 36, T12N, f'f¡¡~¡;;~iq R E € E I V li It §.ff)~ At Top Producing Interval : ~~ ~ 85'NSL,893'WEL,SEC.25, T12N,R11~~1 MAR 141995 At Total Depth t..:-.._t:~l<a 011 & GaS Cons. CommissIon 101' NSL, 769' WEL, SEC. 25, T12N, R16E 7. Permit Number 94-128 8. API Number 50- 029-22510 9. Unit or Lease Name Duck Island Unit/Endicott 10. Well Number 1-23/0-15 11. Field and Pool Endicott Field/Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) IS. LeCelD~H~'~A~ KBE = 55.85' AD~4!~ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 10/23/94 11/6/94 1/13/95 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10800' MD/10411' TVD 10712' MD/10326' TVD YES ŒJ f\D 0 22. Type Electric or Other Logs Run DIFUCDC/CNUGR, FMT 23. 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Gun Diameter 3-3/8" 4 spf MD TVD 10598~10620' 10217~10238' 10574'-10598' 10194'-10217' 10550~10574' 10171~10194' CASING SIZE 30" 10-3/4" 7-5/8" wr. PER FT. Struct 45.5# 29.7# 27. Date First Production 2/5/95 Date of Test Hours Tested Flow Tubing Casing Pressure Press. 115. Water Depth, if offshore 116. No. of Completions 6-12' MSL feet MSL One 120. Depth where SSSV set 121. Thickness of Permafros t 1503' feet MD 1465' (Approx.) GRADE Drive NT-80 L-80 CASING, LINER AND CEMENTING RECORD SEITING DEPTH MD TOP BOTIOM 40' 130' 43' 4246' 40' 10796' AMOUNT PULLED HOLE SIZE 30" 13-1/2" 9-7/8" CEMENTING RECORD Drive 784 sx PF "E''/375 sx "G" 403 sx Class "G" 25. TUBING RECORD DEPTH SET (MD) 9959' PACKER SET (MD) 9855' SIZE 4-1/2", L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL TEST PERIOD .. CALCULATED OIL-BBL GAS-MCF WATER-BBL 24-HOUR RATE. CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY-API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~ GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH Subsea HRZ 9732' 9328' K38 9990' 9576' Kekiktuk 9990' 9576' 30. ( FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. REGEIVED MAR 1 4 1995 Alaska 011 & Gas Cons. Commission Anchora . '" 31. LIST OF ATfACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed if dl1t1;Jt;. ¡;..r ~Ti tie Drilling Engineer Supervisor Date 3/;3/C¡¡- 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 rlP/AAI SHARED SERVICE 'I ( (r DAILY OPERATIONS ( PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: MPI 1-23/0-15 NORTH SLOPE ENDICOTT ENDICOTT 50- ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: WO/C RIG: 10/23/94 06:00 DOYON 15 10/24/94 ( 1) TD : 1 0 34' ( 0 ) POOH T/REPLACE MWD MW : O. 0 VI S : 0 ACCEPT THE RIG @06:00 HRS & RU. FUNCTION TEST DIRVERTOR & ACCUMULATOR SYSTEMS. TEST WITNESSED BY DOUG AMOS W/AOGCC. PRE SPUD MTG HELD W/STOP WALKTHROUGH, SPUD THE WELL. DRILL T/472. MWD QUIT. EXCEPT AT INTERMITTENT INTERVALS. GYRO NOT WORKING AT FIRST. SURV W/GYRO. DRILLED T/563. TAKE GYRO. DRILLED T/6555. TAKE GYRO. DRILLED T/1034. MWD QUIT WORKING. SENT F/NEW ONE F/WAREHOUSE. POOH T/REPLACE. 10/25/94 ( 2) TD : 34 97' ( 2 4 63 ) DRILLING MW: O. 0 VI S : 0 POOH & CHANGE OUT THE MWD. TOOL WASHED OUT @ COVER PLATE. RIH WINO PROB'S. DRLG F/I034 T/1983. TAKE GYRO SURV. DRILG T/2263. CBU & OBSERVE THE WELL. SHORT TRIP BACK T/HWDP. OK. CHANGE OUT AWS UNIT DURING SHORT TRIP. DRLG T/2641. TAKE GYRO SURVEY. DRILL T/3497. 10/26/94 ( 3) TD : 4 2 55' ( 7 5 8 ) RUN 10-3/4" CSG MW: O. 0 VI S : 0 DRLG F/3497 T/4255. ROP SLOWED @4175. CIRC HI-VIS SWEEP AROUND, HOLE UNLOADED FAIR AMT OF GRAVEL & SAND. OBSERVE WELL, 20 STND SHORT TRIP. WORK PIPE THRU SEVERAL TIGHT SPOTS. CIRC HOLE CLEAN, SIGNIFICANT RETURNS. POOH. HOLE CLEANED UP - GOOD DRAG & HOLE FILL TRENDS. HOLE BEGAN TAKING MORE FLD T/FILL UP DURING TRIP OUT. LD BHA & BREAK STAB SLEEVES. RU & RUN 10.75" CASG. AFTER RUNNING 95 JTS, THE RETURNS WERE GOOD BUT THE AMT OF DISPLACEMENT IS IN QUESTION. RECEIVED MAR 1 4 1995 M(ìska Oil & Gas Cons. Commission Anchora ,'; WELL MPI 1-23 OPERATION: RIG DOYON 15 10/27/94 ( 4) TD : 42 55' ( 0 ) 10/28/94 ( 5) TD: 5322' ( 1067) 10/29/94 ( 6) TD : 6 933' ( 1 611 ) 10/30/94 ( 7) TD : 7 51 8' ( 5 8 5 ) (' ( PAGE: 2 PU BHA MW : O. 0 VI S : 0 RUN 10.75" CASG. DISPLACEMENT WAS UNDER CALCUATED VOL. RAN PIPE SLOW. CIRC & RECIP. 800PSI @ 70 SPM INITIALLY. 750PSI @ 90SPM BEFORE CMT. SUBSTANTIAL GRAVEL RETURNS OVER SHAKERS INITIALLY. CMT CASG. RECIP. UNTIL STRING TIGHTENED @ 330 BBLS DISPLACEMENT. PUMP 100 BBLS H20, 374 SX E PERMFRST,375 SX PREM, USED 2 PLUGS. BUMP PLUG & HELD PRESS @2500, BLED PRESS-WOULDN'T BLEED BELOW 500. SHUT IN CMT HEAD. GOT CMT BACK T/SURF. WT RECORDED WAS 11.2 PPG. 10 BBLS BEFORE THE PLUG WAS BUMPED & BEFORE DIVERING INTO CELLAR. RU T/CHK F/CMT @ SURF. RAN INTO FIRM CMT 10' BELOW LNDG RING. RD TBG. BACK OUT LNDG JT & LD. CLEAR FLOOR OF CASG TOOLS. ND DIVERTER, NU SPLIT SPEED HEAD & TEST T/1000. NU BOP, TEST. WITNESSED BY LOU FERRIGNO W/AOGCC. INSTALL BOWL PROTECTOR, BEGIN MU BHA. DRILLING MW: O. 0 VI S : 0 PU & ORIENT BHA, RIH T/600 & TEST MWD. SERVICE THE TOP DRIVE. CUT DL. RIH T/3963 & TAG TOC (200' HIGH) TEST CASG T/3000/30 MIN USING HALIBURTON, PRESS UP @ 1/4 BPM. DRLG CMT, SHOE TRACK & 10' NEW HOLE T/4265. CBU. RAN LOT W/HLBRTN @ 1/4 BPM [1000PSI W/9.3 MW @ 4185 TVD = 13.9 PPG.] DRILLED 10' & CIRC F/15 MIN. DID LOT W/RIG PUMPS @ 1. BPM. GAVE 13.9 PPG LOT. DRILLING F/4275 T/5322. PREPARING A SHORT TRIP AFTER CLEANING UP SHAKERS. DRILLING MW: 0.0 VIS: 0 CBU F/SHORT TRIP. TAKE SHORT TRIP T/ CASG SHOE, 40K O'PULL ON STDS 9, 10 & 11. WIPED OUT OK. PERFORM SERIES OF JUG TESTS. RESULTS WERE FAXED IN, GENERALLY GOOD. PUT 700 PSI (12.5PPG EMW) ON SYSTEM. BLED T/650 IN 5 MIN. INCREASED PRESS IN 100PSI INCREMENTS (0.5PPG EMW) UP T/1200PSI. (14.8 PPG) PRESS BLED T/1100 IN 5 MIN. RIH T/5322. NO PROBLEMS, PROPER DISPLACEMENT WHILE RIH. DRLG F/5322 T/6271. PLENTY OF CLAY ON RETURNS AFTER SHORT TRIP. CBU POOH T/SHOE. WORKED OUT OF HOLE F/1ST 2-3 STNDS. GOOD HOLE FILL AFTER WORKING PIPE AND NO DRAG THRU PREVIOUSLY TRIPPED THRU SECTION. RIH WINO PROBLEMS. DRLG F/6271 T/6933. PLENTY OF CLAY ON RETURNS. MASSIVE SAND SECTIONS BEGAN @ +/- 6300'. HAVING PROBLEMS W/SAND BLINDING THE SHAKERS & LOSING MUD. DRILLING MW: O. 0 VI S : 0 DRILL & SURVEY F/7195. CBU. DROP BAKER HUGHES SURVEY. OBSERVE WELL, POOH F/BIT. FLOW CHECKS @ SHOE & BHA. CHANGE OUT MWD, MOTOR, BIT & PU SHOCK SUB. & ORIENT. RIH T/1500. TEST MWD & FILL PIPE. RIH DRILL & SURVEY F/7195 T/7518. RE(EIVED MAR 1 4 1995 A.laska Oil & Gas Cons. Commission Anchora WELL MPI 1-23 OPERATION: RIG DOYON 15 10/31/94 ( 8) TD : 84 65' ( 94 7 ) 11/01/94 ( 9) TD : 94 0 8' ( 94 3 ) 11/02/94 ( 10) TD : 97 6 8' ( 3 6 0 ) 11/03/94 ( 11) TD : 1 0 4 3 6' ( 6 6 8 ) 11/04/94 ( 12) TD : 1 0 64 5' ( 2 0 9 ) 11/05/94 ( 13) TD : 1 0 8 0 0' ( 15 5 ) 11/06/94 ( 14) TD : 1 0 8 0 0' ( 0 ) (' ( PAGE: 3 DRILLING MW: 0.0 VIS: 0 DRILLING T/7920. CBU & POOH CONDUCT FLOW CHECK @ BTTM, SHOE & BRA. SERVICE THE RIG. RIH W/8DC BIT T/4589. TEST MWD. RIH DRILL & SURV. 7921 T/8465. I DRILLING MW: O. 0 VI S : 0 DRILLING T/9028. CBU OBSERVE WELL. SHORT TRIP T/LAST BIT RUN ( 12 STNDS). DRILLING F/9028 T/9408. DRLG IN TUFFS FORMATION MW: O. 0 VI S : 0 CBU & OBSERVE WELL. POOH T/8400, PUMP DRY SLUG. FLOW CHECK @ BTTM SHOE & BHA. LD STAB, BUMPER SUB, XO & MUD MOTOR. SERVICE THE RIG. PU BHA & RIH T/500. CUT DRILL LINE. RIH T/ 4487. TEST MWD. RIH. WASH & REAM F/9382 T/9422. DRILL & SURVEY F/9422 T/9768. DRILLING MW : O. 0 VI S : 0 DRILLING & SURVEYING T/10061. CBU. OBSERVE WELL. SHORT TRIP T/9213. WORK TIGHT SPOTS F/9787 T/9401. DRILLING & SURVEYING F/10075 T/10436. CBU. DRLG AHEAD W/NEW BIT MW: 0.0 VIS: 0 CBU CHK F/FLOW. SHORT TRIP F/10423 T/9005. WORK OUT THREE MINOR TIGHT SPOTS. DRILL & SURVEY T/10645. CBU CHK F/FLOW. PULL 10 STNDS, OBSERVE WELL. CONDUCT AN H2S DRILL. PUMP DRY SLUG. POOH. LD STAB & MWD. CHANGE OUT BIT. SERVICE THE RIG. RIH & FILL PIPE EVERU 40 STNDS. WASH T/BTTM 80'. DRILLING F/10645 T/10650. RIH FOR WIPER TRIP MW: 0.0 VIS: 0 DRL TO 10800' MD. CIRC. MONITOR WELL, PUMP DRY SLUG. SHORT TRIP 10800-8911' (20 STDS). RIH. CIRC HIGH VIS SWEEP. DROP SVY, PUMP DRY SLUG. POH (SLM). R/U ATLAS WIRE LINE, RIH W/(GR,CN,ZDL, DIFL) LOGS, PULL TIGHT 7500-8990', WORK FREE POH. SERVICE RIG. M/U BHA, RIH FOR WIPER TRIP. OPEN HOLE LOGGING MW: 0.0 VIS: 0 CUT DRILL LINE. RIH FOR WIPER TRIP TO 10800' TD, (NO PROBLEMS ON TRIP IN). CIRC GEL SWEEP TO SLICK UP HOLE FOR LOGGING. POH (FLOW CHECKS @ BTM, SHOE & BHA). CLEAR FLOOR, R/U ATLAS WIRE LINE. LOG #1, (DIFI/ZDC, CN, GR) PULLED 5K OVERPULL 8400-8800' WLM). LOG #2, (FMT-GR). RECEIVED MAR 1 4 1995 A\aska Oil & Gas Cons. CommlssiQn Anchora'·' WELL MPI 1-23 OPERATION: RIG DOYON 15 11/07/94 ( 15) TD : 1 0 8 0 0' ( 0 ) 11/08/94 ( 16) TD : 1 0 8 0 0' ( 0 ) 11/09/94 ( 17) TD : 1 0 8 0 0' ( 0 ) SIGNATURE: { ( PAGE: 4 RIH W/ 7-5/8" CSG MW: 0.0 VIS: 0 R/D ATLAS WIRE LINE. M/U BHA, RIH TO 10800' TD. CIRC HOLE CLEAN W/VIS SWEEP. POH (CHECK FOR FLOW @ BTM, SHOE, SHOE & IN THE BOP STACK). PULL WEAR RING, CHANGE RAMS TO 7-5/8". R/U & RIH W/7-5/8" CSG TO 10-3/4" SHOE. BREAK CIRC @ SHOE (CIRC VOLUME OF PIPE) RIH W/7-5/8" CSG. N/D BOP MW: 0.0 VIS: 0 RIH W/261 JTS 7-5/8" CSG, p/U LANDING JT & LAND CSG @ 10977'. CIRC @ 14 BPM. R/U HALLIBURTON, PUMP 10 BBLS WATER, TEST LINES TO 3000 PSI, PUMP 10 BBLS WATER, PUMP 82.5 BBLS 15.8 PPG CMT @ 6 BPM 500 PSI, FLASH LINES W/SEAWATER, DROP PLUG, DISPLACE W/492 BBLS SEAWATER W/RIG PUMP @ 1600 PSI, 14 BPM, BUMP PLUG @ 4000 PSI. FLOATS HELD. R/D CSG TOOLS, CHANGE RAMS TO 5". M/U & SET 7-5/8" PACKOFF, TEST TO 3000 PSI. RIH W/231 JTS 4-1/2" NSCT L-80 TBG, BAKER PACKER, 2/GLM'S. P/U SSSV & CONTROL LINES, TEST TO 5000 PSI. RIH 2/4-1/2" TBG = TOTAL OF 336 JTS. P/U TBG HANGER & CONNECT CONTROL LINES, TEST TO 5000 PSI. LAND TBG. N/D BOP. RIG RELEASED MW: 0.0 VIS: 0 N/D BOP, RISER, ADAPTER FLANGE, M/U & TEST CONTROL LINE, ADAPTER FLANGE, TO 5000 PSI. M/U TREE & TEST TO 5000 PSI R/U LURICATOR, PULL TWC. PRESSURE DOWN TBG TO 4000 PSI, SET PACKER & TEST TBG. TEST ANNULUS TO 3500 PSI. PUMP DOWN TBG ANNULUS, UNABLE TO OPEN RP VALVE IN UPPER GLM W/3500 PSI. WAIT ON SLICK LINE UNIT. R/U SLICK LINE UNIT, RETRIEVE RP VALVE, R/D SLICKLINE. R/U & FREEZE PROTECT & U-TUBE W/DIESEL TO 1500'. INSTALL BP VALVE, SECURE TREE. (drilling superintendent) DATE: REGEIVED MAR 1 4 1995 Alaska Oil & Gas Cons. Commission Anchora'"\ q4· 01'2..8 ANNULAR INJECTION DATA ENTRY SCREEN Ass e t .ElldlcaU.................................. Rig Name~9ayall..15............................... Inj Well Namlr_~....................... Permit Sur Csg Dep .42116.............. Start .......1.L.4.l.9.5...... Leg a I Desc 2.020:E.NL,..2Q81:EEL....s.EC...36....T.12~...B.16.E.................... Res ear c h .......................................................................................................................COBBEC1E.D..COP.Y..SUBMlTIED.IO.AOGC.c............. 2;.2.6.:.9.1..................................................................................... Permit End ....1.21.3..1.1.9.5... ............................... ............................... ....1..1.1221.9.11... ....1.21.1.61.9.4... *Permit Expires in 30 Days or Less· Formation ........ Intérmittant Fina.l Fluids Freeze Freeze Cumulative Data Rig Cpmpletion Well Total Mud/Ctg Wash Fluids .......32.0.811..... .......3.0..6.0:4..... .......J....l.6.0...,... ......;...2.00.......... .u·...................u.... ..;...;..;..120......". ·STOP INJECTING* Daily Data "'I'J.j ('i'r 1~lÏor ! Ifll,= {Iii; II j(lr' F;,~, ii :.: ul< '7 C'jl~ 1)1 (,)ílljrlI111JI';lj 1~lj\"/,J·.r, ("'.'lïl~II':III.'I·' F·.lrril,JII,:,rl '=rI:'ÞO;'~~ FI':,;:,:- ''''II; I: 111.1.-' [Irl'j r.~1.1I1 f IIJ"]: f IIJIIJ: ¡: IIJI11 ~ F"l,lt'( 11·.ln J:'I(II':- I. r 11.'1' [. ¡II J ï '",I.jl ~(II·II..II} :. R,.2J..;- f't:"::IJI,:" :.I~IIJ~I (,:lIïiÏl':III.:(\'lï':lll,J[II:'-I'; W-II --- 1:2:?L9--=--~QL1JL?_glJH_ g~_~_ 1-53/0-20! 11/23/94 216 I 1-53/0-20111/24/94 271 i --~~---I----- I 1-53/0-20! 11 /25/94 205 ¡ 1-53/0-2°111/26/94 173 ¡ 1-53/0-2°111/27/94 95 1-53/0-2°111/28/94 219 1-53/0-2°111/29/94 201 1-53/0-20111/30/94 500 1-53/0-201 2/01/94 219 1-53/0-20i 12/02/94 184 1-53/0-20112/03/94 207 1-53/0-20112/04/94 185 1-53/0-20! 12/05/94 568 1-53/0-20!12/06/94 359 1-53/0-20112/08/94 212 1-53/0-2011.li09/94 118 1-53/0-20112/12/94 130 1-53/0-20! 12/14/94 365 1-53/0-20! 12/15/94 606 1-53/0-2°112/16/94 402 1-53/0-20112/07/94 950 1-53/0-20112/10/94 151 -I 2-40/8-22!01/04/95 98 2-40/8-221° 1 /05/95 975 2-40/8-22101/06/95 717 2-40/8-22101/07/95 613 2-40/8-22101/08/95 666 2-40/8-22101/09/95 636 2-40/8-22101/10/95- 644 2-40/8-22101/11/95 396 2-40/8-22¡01/12/95 616 2-40/8-22¡0 1 /14/95 688 2-40/8-22!01/16/95 415 2-40/8-22101/17/95 464 2-40/8-22!0 1 /18/95 372 2-40/S-22jO 1 /19/95 173 2-40/8-22101/20/95 186 2-40/8-22101/21/95 215 --' J£?i>__i 1216 . 1271 I !205 ! 173 !95 1219 1201 I~~h ! 184 i !~~~ I i568 I 1359 !212 1118 1130 1365 1606 I~~~ ¡ 151 ¡ 198 1975 ¡ 1717 1613 ¡666 --L~ª§_ !644 1396 1616 ¡688 1415 1464 !372 i 173 1186 1215 -~~ _______.1 1994_~UMMABL I I ! ----------------- ~-~, ,1995 8UMMARY ----- 11000 psi @~J?~ i 1000 psi @ 3 bpm ! 1000 psi @ 3 bpm ! 1000 psi @ 3 bpm ! 1 OOº~si @ --ª--ºp~___ 11000 psi @ 3 bpm ¡ 1000 psi @ 3 bpm !900 psi @ 3 bpm 1750 psi @ 3 bpm 1750 psi @ 3 bpm !750 psi @ 3 bpm 1750 psi @ 3 bpm !750 psi @ 3 bpm 1750 psi @ 3 bpm 1750 psi @ 3 bpm i 110 bbl of water was cement rinsate ¡ 60~si @ 3 bpm i 600 psi @ 3 bpm 1650 psi @ 3 bpm ! 650 psi @ 3 bpm 1100 psi @ 3 bpm ¡700 psi @ 3 bpm ¡ 700 psi @ 3 bpm !700 psi @ 3 bpm 1700 psi @ 3 bpm 1700 psi @ 3 bpm : 700 psi @ 3 bpm ¡ 500 psi @ 3 bpm _____llºº_Q~~_~l!I______________..________ !700 psi @ 3 bpm ! 700 psi @ 3 bpm j 800 psi @ 3 bpm ! 700 Q&~ bpm ¡700 psi @ 3 bpm !700 psi @ 3 bpm ! i 2-40/8-22101/22/95 ~55 1255 2-40/8-22101/25/95 188 ! 188 2-40/8-22101/25/95 999 ; !999 2-40/8-22!0 1 /26/95 282 i ! 60 1342 1-03/P-16!09/30/95 786 1200 -------i,-- 1986 1-03/P-16¡10/01/95 21 I !21 1-03/P-16110/02/95 477 1200 :677 1-03/P-16!10/02/95 342 !200 1542 1-03/p-J..§i.1Q!.º_;3j~542 1200 ·742 . 1-03/P-16¡10/04/95806 _.1.18700-06-1 1-03/P-16!10/05/95 700 1-03/P-16i10/06/95 1,000 !1,OOO 1-03/P-16110/07/95 387 1387 1-03/P-16¡10/08/95 323 1323 1-03/P-16!10/09/95 535 1535 1-03/P-16i10/10/95 254 1254 1 - 0 3/ P - 1 6 1 0/ 1 tL~ ~ 91 ! 491 I 1-03/P-1610/12/95 302 1302 1-03/P-16¡10/14/95 149 ' 1149 1-03/P-16¡10/15/95 165 1260 1425 1-03/P-16:10/16/95 553_1 _¡,.!_____~...:- 1553 . 1'=03/P-16!1 0/17/95 207 120~1 1-03/P-1610/18/95 421 I 1421 ! 1-03/P-1610/19/95 293 -I 1293 I 1-03/P-16J 0/20!J!.2.... 424 I 42'L-__! 1-03/P-16j 10/21/95 186 '---I ! 186 ! 1-03/P-1610/22/95 677 1677 1-03/P-16¡10/23/95 464 ¡ 1464 1-03/P-16!10/24/~ 197 1197 1-03/P-16!10/25/95 180 1180 1-03/P-16i10/26/95 208 1208 1-03/P-16!10/27/95 165 ,. .! 1165. 1:_º-;uE:jJ~IJJ>J:gªŒ.2.... -~ºª---j---¡-----~----i---~----- 50ª--__i 1-03/P-16!10/29/95 412 ! i ! ! 412! 1-03/P-16110/30/95 712 1200 J ! 1 ¡ 912! 1-03/P-16110/31/95 382 i ¡ ! i 382 I 1-03/P-16!11/01/95 160 ! i 160! 1-03/P-16!11/02/95 279 ! 1 279 1-03/P-16j11/03/95 850 i : 850 1-03/P-1611/05/95 100 .1"",,'200 /60 360 1-03/P-16111/04/95 -. Open 102/25/97 ¡02/25/97 -308 1-200 I I ¡ I----i -200 -308 ---I ! i I , , \--- I ! ! ! I j I ,-- I -------- -~~, ~.-- i Volume Corrected from Rock Washer Log I Volume Cooected trom Rock Washer Log ( ( C~G·--- PAGE r~O. 1 H¡t*****H· ¡~!H**H'***'~****** *un *:(··);*****************j~******t~ i~H"H**** *********ï.. ***FHiBB~ ANADRILL ********** ¡BH(,****** SCHLUMÐE~~GER ********iH¡ ********* ********** **************'***1t***t("~¡;:'*¡I,)t*********,m****~,************** ~~* *******~~*** SUI\'VE'l PROGPf\t1 *********** COITPA!~Y PRUDHOE BAY DRILLING WEI~ NAME 1-23/0-15 LOCATION 1 MPI~ ENDIC011 LOCA1'IO~1 2 NSB t ALASKA MAGNETIC DECLINATION 29.89 DATE; 26-0Ci-94 WELL 'NUMBER 0 WELL HEI~ID LOCATION~. LAT(Nf-B) 0.00 DEF'Œ/-W) O.Ü'CJ AZIMUTH PROM ROTARY TABLE TO TARGET IS 30.81 TIE IN PDINTtTIP) ~ MEASURED DEPTH 567.00 TRUE VERT DEPTH 567.00 INCLINATION 0.80 AZIMUTH 316.70 LATITUDE (Ní-S) 0.00 DEPARTURE(E/-W) -1.00 MICROfILMED Dare- 13, 0/ : '~~ RECE'VED MAR 20 1995 Ä\aska OU & Gas Cons. CommissIon Anchora:ge '11 ( í . dGE !~O. 'j i-diD-iS L. ************* f,¡-JJ~Dr<ILL ***BaEH·:a:!f**** SUf.:VEï CALCULATIONS ******k*~**** CIRCULAR ARC METHOD******** MEASURED INTERVAL VERTICAL TARGET STATIm,1 AZIMUTH LATITUDE DEPFIF\TUF:E DISFLACEMENT ;.t ;IZIMUTH DLS DEPTH DEPTH SECTION INCLN. Nl-S E/-I.a) deq/ ft ft ft ft deg d~ ft ft ft aea 100ft 567-00 0.0 567.00 0.86 0.80 316.70 0.00 -1.00 1.00 ').00 0.00 687.56 120.6 687.53 0.52 1.64 328.53 2.09' -2.48 3.24 310 .l).~ 0.73 783.01 '15~4 782,87 2.38 3.78 323 7 ~5-8 5.78 -5.06 7.,fIB 318.32 2.25 8ì6+4.~ 93.5 875.99 6.09 5.7/:. 333.38 12.45 -8.99 1 r.- ,., t 324.1ì 2.28 ...J..~.~ '7'73.78 97.3 'i72 . 80 11.52 6.11 333 . ~32 21.46 -13.49 25.34 327 t 84 0.37' 1069.53 95.ì 1068.08 16.58 5.01 334.23 29.79 -17;58 34.59 329t45 1.15 11.65.66 96+1 1163.97 20.04 3.1.1 326+,i4 35.7b -20.83 41.38 32'1'.7ß 2~O4 1257.01. 91.3 1255.24 21.20 1.70 303.49 38.59 -23.32 45.08 32B.ßb of ,... l .L . ì:Jc1 1351.32 9413 1349.53 20.93 0.69 264."40 39.30 -25.04 46.60 327;50 1132 1447.98 96.7 11146.1'1 20.04 0.66 21~" 38 38.82 -25. 'i? 46.71 326.21 0.53 1544.33 %.3 15112.52 18.89 0.73 224.)44 37 . '15 -26.76 46.43 324.32 0.09 1637.52 93.2 1635.71 17.53 0.% 210.99 36.85 -27,.5ì 46.03 323720 0.32 1733.73 96.2 1731.91 1".46 0.B9 280.31 36.29 -28.72 46.29 321"64 1.09 18'7'2.00 158.3 lß90.17 . 16.85 0.60 20.90 37.29 -29.63 47.63 ~'2L53 0.73 2012.67 120.ï 2010.84 18.17 0.b6 28+82 38.49 -29.07 ' 48. 2:~ 322.93 0.09 210.s.20 95.5 2106.J:; 17'.35 0.77 25.12 3S' . 55 -28.54 48. ï7 :;'24.: 19 0.12 2'297.04 188.8 2295.06 25.74 3.35 9.04 46.14 -27.13 53.53 329,55 1.3'1 2390.54 93.5 2388.25 32.59 5.84 6.02 53.58 -26.20 59.64 333.94 2..,8 2563.00 . 172.5 2559.10 54.03 9.70 B.70 76.68 '"23.08 80.08 343 . t~5 2.25 2675.86 112. '1 2669.90 73.98 12+17 10.24 97+78 -19.53 99.71 348 ÿ 71. 2.20 2770.70 ~¡4t8 2..7 62.59 92 ~ 7'1' 12.25 lO.i,5 117.51 -15.89 li8 'r 58 352.30 0.13 2865.92 95.2 2855.39 112. 82 13+64 10.75 138.48 -11.'i3 138.99 355+08 1.46 296:t ,23 95.3 2947.63 135.33 15.46 10 .94 162.00 -7.42 16'. 1.7 357" . 38 1.91 3054.08 92.9 3037.03 158.99 15.88 11.79 186.59 -2.47 186.60 359+24 0.51 3150.50 '16.4 3129.78 183+93 15.87 11·) ß3 212.40 2.93 212.43 O.ì9 0.02 3244.45 93.9 3220.1'7' 208.03 15.68 11. 09 237.44 8.00 237.57 1. + j'3 0.29 3340.00 If 5.) 3312.09 232.88 16.11 1.4db 262.96 13.73 26:3.32 2.99 0.99 3433.88 9.... .;, 3402.20 258.17 16.47 15.16 288.43 20.3'1 289.15 4.04 0.49 .:'It! 3526.88 93.0 3491.16 284.25 17.41 1.5.00 314.60 27.44 315.79 4.99 1.02 3626+47 99.6 35a.~, . 29 312.64 17+03 15.24 343.06 35.13 344.85 5.85 0.39 3717.38 90.'1 3673.15 338.68 17.30 18.74 :3b8.70 42.98 371.20 6.65 1.17 3813.05 91:' ..,. 37,j4.50 366.89 17+38 30.57 394.,49 54.82 398.28 7.91 3.68 .Jtf 3'102.47 89.4 384'1.77 39~~.69 1.7.74 40 ~ ~)5 41b.35 70.48 422.27 ?6:l 3.39 39'16+4'1 94+0 3939..22 421.98 18.16 45.49 437.50 . 90.24 446 .71. 11 .é5 1.68 4091 ,52 SIS.O 4029.5b 450+39 17. '1'9 46. \~8 457.89 H1.53 471.28 13.69 0+52 41&5.30 93.8· 4118.87 477.89 F.54 4t,.77 477.45 132~42 4'15~48 15.50 0.48 4297,97 112.:7 4226. :i4 510.27 17.40 48.4ì 500.25 157.40 524.43 17.47 0.47 43'7'1+7~: 93.8 4315.80 537.22 17.46 45.78 519+36 177.98 549.01 1.8.92 0.':>6 4486.94 'i5.2 4406.60 564+98 17.57 44 . .-:.J.O 539 + 5'1 198.26 t7"48' 20.1ß 0.45 .>/ + 0 4582.83 95.9 4497t99 593.16 17.64 44.54 560.28 218.58 ¿,Olt41 21~31 0.0'1 I'" ( ~~, ¡,AGE ~40. 3 1-23/0-15 ************* ANADRILL ************** ~JRVEY CALCULATIONS ************* CIRCULAR AF:C MRTHOD******** MEf;SURED I!~TEF:\..IAL ~¡ERTICAL TARGET STATIOt4 ,~ZIM!JrH LATITUDE DEPARTURE DISPLACEMENT at AZmUTH DLS DEPTH DEPTH SECTION INCL~ . NI-S E/-W deq! ft ft ft ft de<] deq ft ft ft deq 100ft 4674.62 91.8 4585,49 .520, 15 17,56 44,14 580,13 237 .98 627.05 22.30 0.16 47l/} . 16 'i4,5 4675.60 647,94 17..,4 44.67 60C.56 257.9B 653.62 23.25 0.1'1' 4858. 5,~, 89.4 4760.80 674.18 1ì . 63 45.47 619.68 277 .15 678.84 24.10 0.27 4'7'53 . .~7 9C" ~ 4851.51 701,80 17.38 46,40 639.58 297.71 705.48 24.96 0.39 )+.\. 504'7',2'7' 95.6 4942tï5 729.26 17,41 47.43 659,11 318.59 732. Qt, 25-;80 0.32" 5143.39 '7'4.1 5032.49 756.63 17,63 43.'19 678.88 338.85 758.75 26.53 1.12 5235.23 S'1 . .9 5119.96 7B3,98 17.67 42.21 699,32 357/:;7 785.,;2 27. 11 0.b4 5339.53 104.3 5219.17 815.49 18.10 43.23 722.98 379.82 816.68 27.72 0.38 5434.07 94.5 530'i~02 844. j.9 18.13 43;24 744.39 399.96 845.04 28.25 0.00 5527.86 93.8 5398.08 B72.88 18.44 44.08 765.68 420. -27 873.44 28.76 0.44 5621~18 93.3 548.$,60 901.55 18.43 44.93 786.73 440.95 901.88 29 + 27 0.29 5713.83 92.6 5574.40 930+22 18.83 45.29 807.61 461.92 930+38 29. ì7 0.45 5807~a2 94.0 5663t34 959.88 18.93 41.7B 829.65 482.86 959.93 30.20 1.21 5899 .33 91.5 5749.B7 98'7' + 34 19.08 36.40 852.76 501.63 989.36 30.47 1.92 59'7'4.56 95.2 5839.85 1020.42 19.14 33.89 878.25 519.57 ~020.43 30.61 0.87 6092 .87 98.3 5932.?·S 1052.48 19.00 35.26 '104.70 537.80 1052.48 30.73 0.48 6184.50 91.6 6019.42 1082.18 18.,'2 34.49 929.12 554.83 1082.18 30+84 0.29 628ìf22 102.7 6116.54 1115.50 19.10 37+37 956.21 574.46 1115.50 31.00 0+93 6378.51 . 91.3 6202.83 11.45.13 19.00 36.05 980.09 592 .28 1145..15 31.14 0.49 6476.10 '?7 ~6 6295. 13 1176.72 18.90 34+38 1005 +'10 610.66 1176.75 31.26 . 0.40 65M~. 1'8 92.9 6383,11 1206.48 18;53 3Ü.94 1030.90 626.86 1206.52 31~3tj 1.42 ,,/.162.84 'i3 . '1 6472.13 123.~ ~ 25 18,45 3L39 . 1056.37 642.26 1236.29 31.30 0.17 6755 ~ S'6 93.1 6560.42 1265.81 18.57 30.35 1081.75 657.43 1265.85 31.29 0.38 6.gS0,72 94.8 ~,650 . 25 1295.98 18.57 29.26 1107 +'7'3 6ì2,43 1296.02 31.25 0.37 6944.21 93.5 6738.34 1325.83 18.69 29.40 1133.96 687.06 1325.87 31.21 0.14 7039.71 '1St} .S829 . 33 1356.37 18..s1 30.30 '1160.46 702.26 1356.40 31.18 0.31 712B~35 88.6 6913.38 1384.52 18.42 31.73 1184.58 716.76 1384.54 ~U. 18 0.56 7220.45 '1'2.1 7000.76 1413+61 18.42 29.94 1209.56 731.67 1413.64 31.1.7 0.61 731bt08 95.6 7091.51 1443.79 18.37 . 29.41 1235.78 746.62 1443.81 31.14 0.18 740B.88 '12.8 7179.54 1473.15 18.53 29.38 1261.37 761.03 1473.17 31+10 0.17 7503.91 91': ," 7269.63 1503.37 18.57 30.83 1287.51 776.20 1503.39 31.08 0.48 .Jtv 7596.51 92.6 7357.40 1532.89 18.61 31.22 1312..81 791 .41 1532.90 31.08 0.14 7690.79 94.3 7446.80 1562.79 18.41 33..62 1338.07 807,45 1562.81 31+11 0.84 7781.46 90.7 7532 i M 1591,34 18.32 31.35 1362.16 '822.78 1591.36 31.13 0.79 7881.75 100.3 7628.10 1622.75 18.20 3~: + 23 1338.72 839.57 1622.78 31.16 0..,0 7'i71S .72 '?5~O' 7718.30 1652.46 18/27 30.30 1413~98 855.21 1652.49 31.17 0.97 B072t37 95.'7 7B08. )'3 1683.02 19.01 32.72 11!40 .03 871 . 19 1683.05 31.17 1.12 81.M.06 '1'3 .7 7897.39 1713.88 19,50 34.04 14b5.83 888.19 1713.92 31.21 0.70 8261 + 5<) 95.4 7987+41 1745.56 19.31 32.32 1492.36 '105.54 1745+';1 31+25 0.63 8~~56 . bS '11~) . 1 8077.23 17ì6.n 19.21 ~~3.83 151.8.M 922.67 1776.97 31.28 0.53 ( (' / fAGE NO. 4 1-23/0-15 ****H******* ANADRILL ************** SURVEY CALCULATlrn~ ******;;Jf***** CIRCULAR ARC METHOD******** MEASURED INrrriF:VAL VERTICAL TARGET STATION AZIMUTH LA'rITUDE DEPPIRTls'RE D ISPLACEMEWI at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W deq/ ft ft ft ft deQ de-g ft ft ft deg lOOft 8446.7B 'to.l 8162.37 180b~46 19.12 34.02 1:;-43~21 939.18 180b.53 31.32 0.12 8543+77 97.0 8253+% 1838.27 19.2t. 35.08 1569.47 957 . 2.7 1838.3ï 31.38 0.39 8637 .1î 93.3 8342.18 1868.69 18.89 35.44 1594.38 974.88 1868.31 31.44 0.42 8725.70 88.6 8426.03 1897.16 18.74 36.01 1617.58 991.56 1897.30 31~51 0.27 8822.71 97.0 8517. SIO 1928.29 18.77 3L2,~ 1643.53 1008.82 1928.44 31.54 1.57' 8917.14 94.4 8607.29 1958.ì2 18.85 3~:.47 1669.24 1025.12 19SH.88 31.5b 0.ì6 8947.27 30.1 8635.81 19b8.39 18.b3 32.52 1677.36 1030.39 1968.5!') 31.56 1.25 9014.61 67.3 86\1'S\64 1989.86 18.58 32.98 1695.42 1042.01 1990.04 31~5f1 ., 'J"\ ,I. '-ü 9109.'7'0 95.3 8790.04 2019.98 18.31 33.20 1720.68 105ß~47 2020.17 31.60 0.29 9204.70 94.8 8879.95 2050.00 18.64 32.73 1745.88 1074.82 2050.21 3Lé2 0.39 9299.i9 94.5 8969.6ï 2079.65 17.94 31.8'1 1770.95 1090.67 2079.86 31.63 0.79 9415.08 115.9 9080+12 2114.71 17.29 2'7\ 69 1801.07 1108.63 2114 t 92 31.~,1 O.al 9513.99 '18 ~ '1 9174.66 2143.80 16.92 31.47 1826.11 . 1123.42 2144.01 31.60 0.65 9605.25 91.3 92t.2.06 2170.06 16.53 32.10 1848.44 1137.26 2170.27 31 fl~'O 0.47 ':¡,s97 .51 92.3 '1350.58 219".03 16.18 32.45 1870.40 1151.13 2.196.25 31.61 0.40 9795.92 98.4 9445.20 2223.09 15.76 33.25 1893.l5 1165.81 2223.31. 31.62 0.48 9890.90 95.0 '1'536. ,j8 2248.5'1 15.42 33.71 1914.44 117'1.89 2248.83 31.65 0.38 9$'8..~.15 97.3 9630.47 2274.29 15.27 33.69 1935.85 1194 .17 2274.54 31.1:.7 0.16 l00aO.70 . 92.5 9719.72 2298.72 15. ~~7 32.73 1956.31 1207.5¡S 2298.99 31.69 0.30 10175.55 94.9 9811.13 2324.02 15.59 32.61 1977.62 1221.23 2324.30 31.70 0.22 10271.13 ~5~6 9903.10 2350+04 16.02 32.73 1999.53 1235.28 2350.33 al.71 0.45 10364.17 93.0 9992+48 2375.87 16.24 32.60 . 2021.29 1249+23 2376.17 31+72 0.24 10457.08 92+\? 10081.70 '2401+78 16.17 33.85 2042+'18 1263.44 2402.09 31.73 0.38 10550.21 93.1 10171.11 2427.78 16.31 34.43 2064.53 1278.05 2428.11 ~il.7 b 0.23 THE FINAL SUR\.JEY IS A PI\'O.JECTF.D SURVEY ONLY.. 10644.00 93.8 10261.13 2454.07 16.31 34.43 2086.26 1292.95 2454.42 31.ì9 0.00 ****~'*1f***** ****1HHEH1~*'***** :( (' qvl~1 ).1 PAGE [,40. 1 H****'¡H** ¡~****;H'iHHEH***** ***~*~-:Ht************i~***;~******~~ iŒ******* ********** ******im* ANADRILL ***.~****** ¡(){'HiHH~** SCHLUMBE~~GER ********iB¡ **mHf**** ********** ***H*j('*******'***1H:***':¡¡,('*¡¡'****;(***H~~*~'************1:.***** ~¡* *******~Bf** SUI\'VE'l PROGPI~M *********** COlrPANY PRUDHOE BAY DRILLING WELL NAI~E 1-23/0-15 LOCATION 1 MPI~ ENDIC011 LOCATIO!~ 2 NSB, ALASKA MAGNETIC DECLINATION 29.89 DATE~ 26-0CT-94 WELL 'NUMBER 0 WELL HEt-ID LOCATION: LAT(N/-B) 0.00 DEPŒ/-!.aI) O.Ü(¡ AZIMUTH PROM ~~TARY TABLE TO TARGET IS 30.81 TIE IN POINT(TIP) MEI~SURED DEPTH TRUE VEF:T DEPTH INCLINATION AZIMUTH LATITUDE(~II-S) DEPARTUREŒ/-W) 567.00 567.00 0.80 316.70 0.00 -1.00 . RE~EIVED MAR ,1 4 1995 M I (R 0 I L M1 D:W~~: Comndss~n 0a1& , (ý6/ ,< ~ RE(EIVED (, riGE liO. ') 1:"d/O-15 '- ************* i~I··\¡~DRILL ******H·);nHH MAR 1 4 1995 SURVEY CALCULATIONS I O' ******** ~Ú.** CIRCULAR ARC METHOD**;B~*"HB~ A aska If & Gas Cons. Commission MEASUF:ED INTEF~VAL VERTICAL TARGET STATIm,1 AZIMUTH LATITUDE DEF'AF<TURE DISPLACEMENT at P,ZIMUfHAnCU"¡ DEPTH DEPTH SECTION INCLti. W-S Eí-W de{}/ ft ft -ft ft cteg d8;) ft ft ft deg 100ft 567~OO 0.0 567.00 0.86 0.80 316.70 0.00 -1.00 1.00 (¡+OO 0.00 687 ~ 56 120.6 687.53 0.52 1.64 328.53 2.09' -2.48 3424 310tOB 0.73 733.01 '15'14 782.87 2.38 3.78 323~5'jj 5.78 -5.06 7.t1ß 318.82 2.25 87b.46 93.5 B75.99 6.09 5.76 333.3B 12.45 -8.9'1' 11:' '-,1 324.17 2.2B ..J.·J0 '173.78 97.3 '172.80 11~52 6.11 333. ~52 21.46 -13.49 25.34 327.84 0.37' 1069+53 95.7 1068.08 16.58 5.01 334.23 29.79 -17 ~ :58 34.59 :;29 ~ 45 1.15 11.65. b6 96+1 llb3+,il 20~O4 3.1.1 326+'7'4 35+76 -20.83 41. 33 329.7ß 2~O4 1257~Gl 91.3 1255.24 21.20 1.70 303.49 38.59 -23.32 45.08 328 4 8,~, '" C-l. l...k· 1351.~}2 9443 1349.53 20.93 0.69 264."40 39.30 -25.04 46.60 327,50 1.32 1447~98 9/:..7 1446.1'1 20.04 0.66 21'1'.38 38.82 -25.'7'7 46.71 326.21 0.53 1544.33 '7'6.3 1542.52 18.39 0.73 224.A4 3? . "~5 -26.76 46.43 324.82 0.09 1637.52 93.2 1635.71 17.53 0+96 210.99 3t..BS - 27.57 46+03 3'23 + 20 0.32 1733.73 96.2 1731.'i1 1.~.46 0.89 280.31 36.29 -28.72 46.29 321.M 1.0'7' 18'7'2.00 1.58.3 1890.17 . 16.85 0.60 20.90 37.21' -29.b3 47+b3 32L53 0.73 2012.67 120.7 2010.84 18.17 0.66 28.82 38.49 -29.07 , 48.23 32l~ . 93 0.01Ï' 210.g.20 95.5 2106.35 19.35 0.77 25.12 39.55 -28.54 48. ï7 :;'24.ò 19 o .1i~ 229ì.04 lM.ß 2295.06 25.74 3.35 9.04 46.14 -27.13 53.53 329.55 1 . 3'7' 2390/54 93.5 2388.25 32.59 5.84 6.02 53.58 -26.20 59.64 333.94 2.,,8 2563.00 . :l72.5 2559.10 54.03 9.70 8.70 76.M -23.):)8 80..0ß 343. 'ð 2.25 267S.M 112. '1 2M9 . 90 73.98 12.17 10.24 97.78 "19.53 99.71 34B,,71 2.20 2770.70 94.ß 2762.59 92+79 12.25 1.0+65 117 +51 -15.89 l1B.58 352.30 O.i3 2B65~92 91:i '1 2855.39 112.82. 13+64 10.75 138.48 -lL'i3 138.99 35~) .08 L4b .n£. 296:t .23 95.3 2947+63 135 ¡, :33 15.46 10.'1'4 162.00 -7.42 16'-.1.7 357.38 1.91 3054~O8 92.9 303ì.03 158+99 15.88 11.79 lB¿..S9 -2.47 i86.60 359~24 0.51 3150,50 96.4 3129.78 183~, n 15.87 1Lß3 21.2~40 2.93 212.43 O.ì9 0.02 3244.45 93.9 3220. 1'7' 208.03 15.68 11 .09 . 237.44 8.00 237 t 57 t.; '1'~¡ 0.29 3340.00 'rS.) 3312.09 232.88 16.11 1.4.16 262.96 13.73 263.32 2.99 0.99 3433.88 93.9 3402!.20 258.17 M.47 15.16 288.43 20 + 3'1 289 + 15 4.04 0.49 3526.88 93.0 3491.16 284.25 17.41 15.00 314.60 27.44 3~L5.79 4.99 1.02 3626.47 99.6 3586.29 312.64 17.03 15.24 343.06 35.13 344.85 5.85 0.39 371.7 .38 90.1' 3673.15 338.68 17.30 18.74 :3M.70 42.98 371.20 6.65 1+17 3813.05 91:; ï 37.~4+50 366.89 17.38 30.57 394..49 54.82 398.28 7.91 3.bB .J.I 3902.4ì 89.4 3849.77 393.6'1 17.74 40 ~ ~)5 41~S.35 70.48 422,27 9.bl 3.39 39'7'6.4'1 94.0 3939·.22 421 . '78 18d6 45.49 437.50 . 90.24 446.71. 13..65 1.M 4091. 52 SIS.O 4029.5b 450.39 17.'19 46 . 1;'8 457.8'1 111.5:3 471.28 13.69 0.52 4185.30 93.8· 4118.87 477.89 17+54 4~. 77 477.45 132.42 495~48 15.50 0.48 4297.97 112.7 4226.34 510.27 17,40 48,47 500.25 157.40 524.43 17.47 O~47 4391..73 93.8 4315.80 537.22 17.46 45.78 519.36 177.98 549.0l 1.8.tf2 O~86 4486. '1'4 ~,r: I'j 4406.60 564.98 17.57 44+40 53'1 + 5'1 198.26 5ì 4.86 20.18 0.45 J.!.. 4582.83 95.9 4497 + 9S' 593.16 17~64 44.54 560.28 218.58 601.41 ¡~l .31 0,09 ~, ( RECEIVED AGE t40. 3 1-¿3/0-15 ************* ANADRILL ************** MAR 1 4 1995 $JRVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** Alaska Oil & Gas Cons. Commission MEASURED INTEF:t..'AL ~tERTICAL TARGE'¡' STATIOH ,~ZIMIJrH LATITUDE DEPARTURE DISPLACEMENT at AZII'IUT!Anch~ ' DEPTH DEPTH SECTION INCL~ . N/-S E/-W deç¡/ ft ft ft ft de<] deq ft ft ft deq 100ft 4674.¿.2 91.8 4585.4~' 0520.15 17.56 44.14 580.13 237 .98 627.05 22.30 0.16 4ì69.16 '14.5 4675.60 647.94 17.64 44.67 600.56 257 ~ 'i8 653.62 23.25 0.1'1 485S~56 89.4 4760.80 674.18 17.63 45.47 619.68 277 . 15 678.84 24.10 0.27 4'i53. b7 95.1 4851.51 701.80 17.38 46.40 ¿.39 . 58 297.71 705.48 24.96 0.39 504'i.29 95.6 41'42.75 729.26 17.41 47.43 659.11 318.59 732.0t, 25~aO 0.32' 5143.39 '14.1 5032.49 756.63 17.b3 43.'19 678.88 338.85 758.75 26.53 1.12 5235.23 91.8 5119. ':;6 783.98 17.67 42.21 699.32 357.97 785.,~2 27. 11 0.,,4 5339.53 104.3 5219.17 815.49 18.10 434£~ 722.98 379.82 816.68 27.72 0.38 5434.07 94.5 530'1 I, 02 844.1.9 18.13 43:24 744.39 399.96 845.04 28.25 0.00 5527.86 93.8 5398.08 872.88 18.44 44.08 765.68 420.27 873.44 28.76 0.44 5621~la 93.3 548.$.60 901.55 18.43 44.93 786.73 440.95 901.88 29.2J 0.29 5713.83 92.,~ 5574.40 930.22 18.83 45'129 807.61 461.92 930.38 29. ì7 0+45 5807~ß2 94.0 5663t34 959.88 18.93 41.78 829.65 482.86 959.93 30.20 1.21 5899.33 91.5 5749.87 989.34 19.08 36.40 852.76 501.63 989.36 30.47 1.'n 59'14.56 95.2 5839.85 1020.42 19.14 33.89 878.25 519.57 ~020.43 30.61 0.87 bOn.87 98.3 5932176 1052.48 19.00 35.26 '7'04.70 537.80 1052.48 30.73 0.48 6184+50 91.6 6019.42 1082.18 18.92 34.49 929.12 554.83 1082.18 30.84 0.29 6287.,22 102.7 6116.54 1115.50 19.10 37.37 956.21 574.46 1115.50 31.00 0.93 6378.51 . 91.3 6202.83 11.45.13 1'1.00 3b.05 980.09 592 .28 1145..15 31.14 0.49 6476.10 97.6 6295.13 1176.72 18.90 34+88 1005.'10 610.66 1176.75 31.26 . 0.40 6568. S'8 92.9 6383.11 1206.48 18v53 30.94 1030.90 626.86 1206.52 31.30 1.42 ';662.84 '1'3. 'i 6472.13 123.6,25. 18.45 31.~39 . 1056.37 642.26 1236.29 31.30 0.17 6755~96 93.1 6560.42 1265.81 18.57 30.35 1081.75 657.43 1265.85 31.29 0.38 6850.72 94.8 6650,25 1295.98 18.57 29.26 1107.93 672.43 1296.02 31.25 0.37 6944.21 93.5 6738.84 1325.83 18.69 29.40 1133.96 687.06 1325.87 31.21 0.14 7039.71 95.5 6829.33 1356.37 lS..S1 30 + 30 '1160.46 702.26 1356.40 31.18 0.31 712B~35 8e,.b 6913.38 1384.52 18.42 31.73 1184.58 716.76 1384.54 31.18 0.56 7220.45 'n.l 7000.76 1413.61 18.42 29'194 1209.56 731.67 1413.64 31.17 0.61 7316.08 95.6 7091.51 1443.79 18.37 . 29.41 1.235.78 746.62 1443.81 31.14 O.lô 7408.88 92.8 7179.54 1473.15 18.53 29.38 1261.37 761.03 1473.17 31.10 0.17 7503 + 91 91:' (\ 7269.63 1503.37 18.57 30.B3 1287.51 776.20 1503.39 31.08 0.48 ..i.v 7596.51 92.6 7357.40 1532.8'7' 18.61 31.22 1312..81 791.41 1532.90 31. 08 0.14 7690.ì9 94.3 7446.80 1562.79 18.41 33* 62 1338.07 807.45 1562.81 31.11 0.84 7781.46 90.7 7532~B6 1591.34 18.32 31.35 1362.16 822.78 1591.36 31.13 0.79 7881.75 1.00.3 7628.10 1622.75 18.20 :33 ~ 23 1338.72 839.57 1622.78 31.16 O.bO 7'~7"S . 72 95.0· 7718.30 1652.46 1 B /27 30.30 1413498 855.21 1652.49 31.17 0.97 8072~37 95.'7 780th S'3 1683.02 19.01 32.72 1440.03 871.19 1683.05 31.17 1.12 ß1.M.06 S'347 7897,3'1 1713488 19.50 34.04 14b5.83 888.19 1713.92 31.21 0.70 8261.50 95.4 7987.41 1745.56 19.31 32.32 1492.36 '105.54 1745.~,1 31.25 0.63 K556. .s~} ';15.1 13077 .23 1776.91 19.21 33.83 151.8.66 922.67 1776.97 31.28 0.53 MAR 1 4 1995 A\aska OU & Gas Cons. COmmls.ion Anchors, '" RE~EIVED , ( \\ tiGE NO. 4 1·23/0-15 ***IHH·H***** ANADRILL ************** SURVEY CALCULATIONS ******~~***** CIRCULAR ARC METHOD******** MEASURED INiERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTG~E DISPL~CEMENT at AZIML~H DLS DEPTH DEPTH SECTIm~ INCLN. N/-S E/-I¡J deq/ ft ft ft ft de~ de-g ft ft ft de9 100ft B446.7B '7'0.1 8162.37 180b.46 19.12 34.02 1543.21 93'7' .113 1806.53 31.32 0.12 8543.77 97.0 8253.96 1838.27 19.26 35.0e. 1569.47 ''757 . 2.7 183B.3ï 31.38 0\:3'1 8637.1î '13.3 8342.13 1868.69 18.8'1 35.44 1594.38 974.88 1868.31 31.44 0.42 8725.70 88.6 8426.03 1897.16 18.74 36.01 1617.58 991. 56 18'17 .30 r-.1 r.:;. 0.2ì ..J.L(¡,J"! 8822.71 97.0 851,7. SiO 1928.2'i 18.n 31. 20~ 1643.53 1008.82 1928.44 :31 .54 1.57" 8S'17.14 94.4 8607.2'1 1958.72 18.85 3~:.47 1669.24 1025.12 195H.B8 31.5:'; 0.76 8947.27 30.1 8635.81 19b8.3S' 18.b3 32 . ~52 16ì7t36 1030.39 1968. 5f~ 31.56 1t25 9014.61 67.3 8699.64 1989.86 18.58 32.98 1695.42 1042.01 1990.04 31.¡SEI 0,23 9109.90 95.3 8790.04 2019.98 18.31 33.20 1720.68 t05ß~47 2020.17 31.,:)0 0.29 9204.70 94.8 887'r . 95 2050.00 18.64 32.73 1745.88 1074.82 2050.21 3Lé2 0.39 '1299 . i 9 94.5 8969.67 2079~1:/5 17. '7'4 31.8'1 1770.95 t090.67 2079.86 :31.6:3 o 70 tIJ 9415.08 115.9 90BO.12 2114.71 17 . 2~' 2$' . 69 1801.07 1108.63 2114.92 31.t,l 0.61 9513.99 '1'8 t '1 9174.66 2143i80 16.'n ~U.47 182b.11 . 1123.42 2144.01 31.60 0.65 9605t25 91.3 92b2.06 2170.06 16.53 32.10 1848.44 1137.26 2170.27 314'~O 0.47 '1697.51 'i2.3 9350.58 2196.03 16.18 32.45 1870.40 1151. 13 2.196.25 31.61 0.40 97'1'5.92 98+4 9445.20 2223.09 15.76 33.25 1893.l5 1165+81 2223.31, 31..;2 0.48 9890.90 95.0 '1536. b8 2248.5'1' 15.42 33.71 1,'14.44 117'1.89 2248.83 31.65 0.38 9$'a..~+ 15 97.3 9630.47 2274.29 15.27 33.69 1935.85 1194 ~ 17 227 4.54 31.b7 0.16 100BO.70 '12.5 9719.72 2298.72 15.37 32.73 1956.31 1207.51) 229H.99 31.69 0.30 10175.55 94.9 9811.13 2324.02 15.59 32.61 1977.62 1221.23 2324.30 31.70 0.22 10271.13 95~6 9'?O3.10 2350.04 16.02 32.73 19':"9.53 1235.28 2350.33 31.71 0.45 10364.17 93.0 9992.48 2375.87 16.24 32.60 2021.29 1249.23 2376.17 31.72 0.24 10457.08 'jl2.'·í 10081.70 '2401.78 16.17 33.85 2042.98 1263.44 2402.09 31.73 0.38 10550.21 93.1 10171.11 2427.78 16.31 34. A13 2064.53 1278.05 2428+11 ~~1. 7 h 0,'23 THE FINAL SUR~JEY IS A PROLTECTHD SURVEY ONt Y . 10644.00 93.8 10261.13 2454.07 16.31 34.43 20M.26 1292.95 2454.42 31.79 0.00 ******u***u* ~HH(.·HiBF,(·*iH~·***** .' {!:r.y¡~~~r~;;:¡:~'~·\ jr~,~'''" Date: Received by: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B street suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Please sign and return to: WELL # DESCRIPTION ECC No. g1- ð~ 3-21/L-34 SDI 1 PFC/PERF FINAL BL+RF Run # 1 5765.07 87- 33 3-21/L-34 SDI 1 PLS-STP FINAL BL+RF Run # 1 5765.08 13- 17D 3-43/P-36 (SDI) 1 PLS FINAL BL + RF Run # 1 6192.05 '1V- 1/9 3-19/R-28 SDI 1 PFC/PERF FINAL BL+RF Run # 1 6217.09 9 f -'/)$I'~?;.~ 3 /0-15 1 PFC/PERF FINAL BL+RF Run # 1 6296.03 ...1~I:i': I Enclosed, please find the data as described below: Dear Sir/Madam, Sent by: MAIL LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. RE: Transmittal of Data RECEIVED JAN 2. 3 1995 Alaska on & Gas Cons. commIssion Anchorage Date: "Is January 1995 (' .I~ ( ( ( LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 November 1994 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: ~LL # DESCRIPTION ECC No. ú.... ~/ ')-24/M-12 MPI 1 PFC FINAL BL + RF Run # 1 6114.07 ~.-ó 1L. 4-38/K-34 1 PFC FINAL BL + RF Run # 1 6235.05 q ql{ t' I '¿, ~ - 23/0-15 1 SBT/GR FINAL BL + RF Run # 1 6296.02 <6~t'1 va-07/N-28 1 PDK FINAL BL + RF Run # 1 6305.00 P!eaRP ciyu Atl~R Wireline Services ~ 5600 B ~ . t/?-'201 An'ého e, AK 'i / ~ //'Attn. Rodne . Paulson ç.:> / /lOr TAX to (907) '-:-7803 ~ Z// Dat~~ 7 . ë. - ---, - ~~ ~~ ~. '- C1 % ~. en ~. ~ ~ ~~ ~~ ~ ¿ ~~ ii :~ ~ . _. '-"-"-""'''''--_.'-'-~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP 1-23/0-15 ENDICOTT NORTH SLOPE, AK Tapes/Diskettes: 1 LDWG TAPE & LISTER I( Date: 10 November 1994 RE: Transmittal of Data ECC #: 6296.00 Sent by: COURIER Data: LDWG Please sign and return to: Ai!!I~.... Wir~'{n~ ~Q~v{:1c.... , 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson or;t:¡ to (907) 563-7803 Received by: ~ ~ ~<'~ DaLe; If¡ ~r/ tì( '1 / A ll,; } -Ä ~ ,5 Enclosed, please find the data as described below: L) ~'( . Run # ~~)) \ ~ 1'..... ~ ~ <~ ~a. V,t.. ~ ~Q?()J ~ ~ 1'¿ ~~ ('~A, ' ~Cb .æ V ~~ ~ ~~~ ~ ~ ~ ( ( LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION Date: 10 November 1994 3001 PORCUPINE DRIVE ( ANCHORAGE AK, 99501. Dear Sir/Madam, \ 'V '\ -fJ. 6 ~ / ~~23/o-15:æ ~ ~ END I COTT ':6 ~ 5? ¿:.. ~Q ..A NORTH SLOPE, ~\ ~ 'f ~ ~.~ .v ~ Enclosed, please find the data as describe~~elow: ~. ~ ~ RE: Transmittal of Data ECC #: 6296.00 Sent by: U.S. MAIL Data: LDWG Reference: Prints/Films: Prints/Films: 1 1 1 1 1 1 1 1 DIFL/GR FINAL BL DIFL/GR RF SEPIA ZDL/CN/GR FINAL BL ZDL/CN/GR RF SEPIA BORE PROF FINAL BL BORE PROF RF SEPIA SSTVD FINAL BL SSTVD RF SEPIA S-e p~~ J-~\ ()-tr~~ Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 fZVlA-rj6 (1- R'ea9Q c4gn 3nd ~~LULll Lo; ALla~ w1reline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~ O~ M (907) 563-7803 Received bY:~ ~~(íl?--~ Date: '-"'~'-.,.... f MEMORANDUM TO: David Johnst- / Chairma~ ~ Blair Wondzell, IL( P. I. Supervisor C Lou Grimaldi,~~ Petroleum Inspector THRU: FROM: ;1 ~ State of Alaska Alaska Oil an~fil:.-~tion ~ommiSSion DATE: ~ FILE NO: AKHJJ1 BD.DOC SUBJECT: BOP Test Doyon rig #15 BPX well # 1-23/0-15 Endicott field DIU PTD # 94-128 Wednesday, October 26, 1994: I traveled this evening to Doyon rig #15 to witness the initial BOP test on their rig which is presently drilling BPX well # 1-23/0-15 in the MPI of the Endicott field. The rig was not ready when I arrived, I made a preliminary inspection and stood by on the rig for approximately 3 hours until they were ready early the following morning. Thursdav, October 27, 1994: The test was started at 0100 hrs. and lasted approximately 4 hrs. All components functioned properly and held their pressure test although there was a slight leak from the bonnet flange on the center isolator valve of the gas buster leg on the choke manifold. This flange was tightened and retested "OK". A closure test of the accumulator showed 1200 psi, although meeting the minimum 200 psi above precharge of the bottles this seemed low for this BOP setup. I required the check of pressures on the bottles and found most of them to be low with some being very low (500 psi), the precharge was brought up to 1000 on 14 of the 16 bottles when the motorman ran out of nitrogen. We retested the accumulator and the closure test left 1320 psi remaining on the system. I felt more comfortable with this and allowed them to drill with the requirement that by the next BOP test all bottles would be retested and repaired if necessary. Summary: I witnessed the initial BOP test on Doyon rig #15. Test time 4 hours. One failure. Attachment: AKHJJ1 BD.XLS ,t' (' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: DOYON Operator: BPX Well Name: 1-2310-15 Casing Size: 10 314 Test: Initial X Set@ Weekly Rig No. 15 PTD # 94-128 Rep.: Rig Rep.: 4,245 Location: Sec. 36 T. Other DATE: 10/27/94 Rig Ph.# 659-6510 STEVE WALLS MIKE DRODDY 12N R. 16E Meridian UM TEST DATA Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly IIBOP 1 30015000 P Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly IIBOP 1 30015000 P Reserve Pit NIA Ball Type 1 30015000 P Inside BOP 1 30015000 P Test BOP STACK: Quan. Pressure P/F Test Annular Preventer 1 30013000 P CHOKE MANIFOLD: Pressure P/F Pipe Rams 1 30015000 P No. Valves 18 30015000 P Pipe Rams 1 30015000 P No. Flanges 40 30015000 F Blind Rams 1 30015000 P Manual Chokes 2 Functioned P Choke Ln. Valves 5 30015000 P Hydraulic Chokes 1 Functioned P HCR Valves 2 30015000 P Kill Line Valves 1 30015000 P ACCUMULATOR SYSTEM: Check Valve NIA NIA NIA System Pressure 3,000 P Pressure After Closure 1,320 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 38 sec. Trip Tank OK NIA System Pressure Attained 3 minutes 16 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. BU's: (4) Bottles Gas Detectors OK OK 2400 (Ave.) Psig. H2S Detectors None None , TEST R~SUL T8 Number of Failures: 1 ,Test Time: 4.0 Hours. Number of valves tested 28 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Accumulator at minimum (1200 psi), recharged bottles and tested "OK" @ 1320 psi Center vlv on gas buster line (choke manifold) had bonnet leak, tightened & retested "OK" Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c - Inspector FI-021 L (Rev. 7/93) STATE WITNESS REQUIRED? YES X NO Waived By: Witnessed By: Louis R Grimaldi 24 HOUR NOTICE GIVEN YES X NO AKHJJ1 BD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David JOh¿ Chai~ Blair Wondzell, d3,-12.oJ:- P. I. Supervisor (0/'2.7 Doug Amos, T)~ ~ Petroleum Inspector DATE: O~tober 23, 1994 THRU: FILE NO: ekhhjwbd.doc FROM: SUBJECT: Diverter Function Test Doyon 15 BPX DIU MPI1-23/0-15 Endicott Field PTD No. 94-128 Sunday, October 23,1994: I traveled to BPX DIU MPI1-23/0-15 well to inspect and witness the Diverter function test on Doyon Rig No. 15. As the attached AOGCC Diverter Systems Inspection Report form indicates, the divertersystem was in compliance. The long runs of 12" vent line were necessary to clear all well houses and still leave ample room for additional auxiliary equipment if need. The location and rig were in good conditio~ and the drilling crew seem knowledgeable about their equipment and it purpose. SUMMARY: I witnessed the Diverter Function Test and inspected the Diverter System on Doyon Rig No. 15 at BPX DIU MPI well 1-23/0-15. Attachment: EKHHJWBD.XLS ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Operator: Well Name: Location: Sec. Doyon Drilting BPX Endicott DIU / MPI/123/0-15 36 T. 12N MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: NiA Flare Pit: N/A . DIVERTER SYSTEM INSPECTION: Diverter Size: 20 in. Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes/No Vent Line(s) Size: 12 in. Vent Line(s) Length: . 280 ft. Line(s) Bifurcated: Yes Line(s) Down Wind: Yes Line(s) Anchored: Yes Turns Targeted / Long Radius: N/A R. Operation: Rig No. Oper. Rep.: Rig Rep.: 16E Date: 1 0/23/94 X Exploratory: 94-128 Rig Ph. # 659-6510/11 Jim Gaffney Mike Droddy Development 15 PTD # Merdian Umiat TEST DATA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3000 1500 min. 2 min. 6 @ 1900 psig psig 22 sec. 9 sec. psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: .oK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK DIVE,RTERSCHEMA TIC, ....100' of 12" Vent Line . NORTH I \ " " . ..,¿Ç ~ Production Flow Lines \ i: 1"2:: ~~~~~I"~n"i;e"~ Z . . " " " . . · . ~ ~,: ~~~t' ~i~~ . . " " , . . . - ~ - - ~~~;~~d" ;I~~;i~~' - " 1 ~." ~~I~~... ,".,.. __~ .~: .... ...... .1.8~: __. .. __,'" _..... _..... __ ~a.n"w~~~.~. ~ \ -~ -- -==- -- ~.~ Production Flow Lines ~~.~ , Ö~ /~ WELLHOUSEJ, , 1 ~#1 WlNDDIRECTION '~ / . ------ 20" MSP 2K Diverter / RIG MOTORS & PITS --- 12" Hyd. Operated, Full Opening Knife Valve WELL HOUSE ROW #2 Non Compliance Items 0 Repair Items Within N/A Day (s) And contact the Inspector @ 659-3607 Remarks: The 12" Manual Vent Line Valve running North was chained and locked in the open position. Distribution orig. - Well File c ~ Oper/Rep c - Database c .. Trip Rpt File c - Inspector AOGCC REP.: Doug Amos OPERATOR REP.: EKHHJWBDXLS DVTRINSP.XL T (REV. 1/94) ~~m9E d~ ~J I ~&£ X,~ ( ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 27, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 1-23/0-15 BP Exploration (Alaska), Inc. Permit No. 94-128 Sur. Loc 3259'NSL, 2087'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 162'NSL, 738'WEL, Sec. 25, T12N, R16E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. @ priPled on recycled p;:wc~ h V (>D ,( J' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work Drill IX! RedrillO 1b. Type of well. ExploratoryD Stratigraphic Test 0 Development Oil 0 Re-Entry 0 Deepen 0 Service GJ Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB.=S5.85 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage,Alaska 99519-6612 ADL 34633 4. Location of well at surface 7. Unit or property Name 3259' NSL, 2087' WEL, SEC. 36, T12N, R16E Duck Island UnitÆndicott At top of productive interval 8. Well number Number 66' NSL, 795' WEL, SEC. 25, T12N, R16E 1-23/0-15 25100302630-277 At total depth 9. Approximate spud date Amount 162' NSL, 738' WEL, SEC. 25, T12N, R16E 9/27/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 1.4. Number of acres in property 15. Proposed depth (MD and lVD) property line ADL 312828-738 feet 1-2111<-25-7.3' @ 676' MD feet 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 19.22> 18. Casing program size Hole ,Casing 30" 13-1/2" 10-3/4" 9-7/8" 7-5/8" 11. Type Bond(see 20 AAC 25.025) Specifications Weight Grade Coupling Length Struct. Drive Weld 90' 45.5# NT80 BTC 4063' 29.7# NT95HS NSCC 10836' 2560 10873' MD/10456' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3900 pslg At total depth (TVD) 10000'/4890 pslg Setting Depth Top Bottom MD TVD MD TVD 40' 40' 130' 130' 37' 37' 4100' 4041' 37' 37' 10873' 10456' 403 sx Class "G" Quantity of cement (include stage data) Drive 784 sx "£"/375 sx "G"/150 sx roe 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 Casi ng Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth REGEIVED SEP 2 1 1994 measured true vertical 20. Attachments Filing fee[Kj Property plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program ŒJ Drilling fluid program ŒJ Time vs dePt,h plot ~ Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0, 21. I .hereb~ certify that'4~ I Ü9}>-'?7~ true: nd correct to the best 'of my knowledge f'! . Signed )J/¥-~ /, ~!(. Tit Ie Drilling Engineer Supervisor Date q;J. / q f I Commission Use Only Permit Numþer API number ,.r-- / Appro)<al date Çj ~I See cover letter 7'1-/ ¿ <T 50- 02...'9 - 2-2...J /0 "1 - ;?1·/ I C¡ for other requirements Conditions of approval Samples required 0 Yes .lRJ No Mud log required ·0 Yes .RI No Hydrogen sulfide measures 0 Yes )8l No Directional survey reqUIred :m Yes 0 No Required working p-r~s,sure fpr BQP-.E 02M; 03M; JS5M; 010M; 015M; Other:. Ongmal SIgned 13y Approved by David W. Johnston Form 10-401 Rev. 12-1-85 Alaska Oil & Gas Cons. Commission Anchoré:.8e Commissioner by order of me commIssion Date 7/1".7/" y Submit in trip(i~ate ( ( I Well Name: 11-23/0-15i Well Plan Summary Type of Well (producer or injector): WATER INJEcrOR Surface Location: Target Location: Bottom Hole Location: 3259' FSL, 2087' FEL, SEC 36, T12N, R16E 66' FSL, 795' FEL, SEC 25, T12N, R16E 162' FSL, 738' FEL,SEC 25, T12N, R16E AFE Number: 717493 I Estimated Start Date: 1 9/27/94 I MD: 110,873' Rig: DOYON #15 I Operating days to complete: 121 1 TVD: 110,456· 1 KBE: 155.85' I Well Design (conventional, slimhole, etc.): 1 SLIMHOLE / 4-1/2" Tbg Completion Formation Markers: Formation Tops MD Permafrost 1473' Surface Csg Pt 4100' TUFFS 9237' HRZ 9719' PUT RIVER 13,723' KEKIKTUK 10,010' TARGET 10,534' 1D 10,873' TVD (BKB) 1471' 4041' 8911' 9366' 9815' 9641' 10,136' 10,456' REG[\VEU SFP L \ \994 On & Qne Cons- commission 1\\as\<.a Anchor~ Casin~/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDrrVD Driven 30" Struct. WLD GL Preset 13-1/2" 10-3/4" 45.5# NT-80 BTC 4063' 37' MD 4100'/4041' 9-7/8" 7-5/8" 29.7# NT -95HS NSCC 10,836' 37' MD 10873/10456' TBG 4-1/2 " 12.6# L-80 NScr 9963' 37' MD 10,000' MD Well Plan Summary 1-23/0-15 Page 1 (' Logging Pro~ram: I Open Hole Logs: . SURFACE INTERMEDIA TE PRODUCTION I Cased Hole Logs: ( DIRECTIONAL (MWD & GYRO) MWD Directional; ElLine logs - DIFL/ZDC/CN/GR & 5-10 FMT's GRlSBT/CBL f/ TD to end of tubing after rig release Mud Program: I Special design considerations I Fresh water lightly dispersed mud to TD Surface Mud Properties: Density Marsh (PPG) Viscosity 8.7 300 csg pt. 9.2 100 Yield Point 40-60 20-40 Intermediate Mud Properties: Density Marsh Yield (PPG) Viscosity Point 9.2-9.8 50 15-25 Production Mud Properties: Density Marsh Yield (PPG) Viscosity Point 9.8-10.2 50-60 20-30 I SPUD 10 see gel 30-60 15-20 10 min gel 60-80 20- 30 pH 9-10 9-10 Fluid Loss 15-25 15-25 Fluid Loss <12 Fluid Loss 5-8 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. I Fresh / lightly dispersed 10 see 10 min pH ~el ~el 12-15 25-30 9.5-10 I Fresh/lightly dispersed 10 see 10 min pH gel ~el 12-15 25-30 9.5-10 Directional: I KOP: J KOP @ 500' departure = 2566' @ TD I Maximum Hole Angle: 19.22 DEG; 30.82 DEG Azimuth Close Approach Well: 1-21jK-25 @ 676' in 1-23/0-15. 7.3' Separation Well Plan Summary R EGEIVED SEP 2 1 1994 1-23/0-15 Alaska Oil & Gas Cons. Commission Anchora..;Of;$ P 2 age f CEMENT PROGRAM -HALLIBURTON 10-3/4" SURFACE CASING CASING SIZF: 10-3/4", 45.5# CIRC. TFMP: 40°F I FAD CFMENT TYPF: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 784 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 375 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX.SACKS: 1 50 MIX WATER: 11.63 gps SPACFR: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME 1. Lead slurry + 375 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 1 50 sx. 7 5/8" PRODUCTION CASING CASING SIZE: 7 5/8", 29.7# ° CIRC. TEMP 1 35 F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1. 15 ft3/sx MIX WATER: 5.0 gps SACKS: 403 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACFRS: Pump 20 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Batch mix tail slurry. Displace at 14-1 5 bpm with rig pumps. RECEIVED SEP 2 1 1994 CEMENT VOLUME k OiJ & Ga C . . 1. Tail Slurry to 500' above top of Kekiktuk wi 50% excess + 80 ft. shJ'd~s a, ,s ens,. CommisSion Anchor~~e 1-23/0-15 September 21, 1994 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Production Casing Depth: Production Casing Size Production Casing Weight: Proposed Top of Cement(MD) Bit Diameter: Excess Factor(T AI L): ( f 1-23/0-15 Cement Volumes Surface String 4100 1 0 3/4 45.5 13.5 1.4 10873 7 5/8 29.7 9500 9 7/8 0.5 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 784 (1701 Cu. Ft.) TAIL (Premium) Yield 1 . 1 5 Density 15.8 # sacks 3 75 (431 Cu. Ft.) TOP JOB (TYPE "E" PERMAFROST) # sacks 1 50 (325.5 Cu. Ft.) 2.17 cuft/sx 12.0 ppg Production String LEAD (Premium) Yield Density # 'sacks # bbls TAIL (Premium) Yield Density # sacks # bbls 3.24 11 o (0 Cu. Ft.) o 1 .15 15.8 403 (463 Cu. Ft.) 82 REGEIVED SEP 2 1 1994 Alaska Oil & Gas Cons. Commission Anchora,ß ( ~' ~, WEll 1-23/0-15(MPI) PROPOSED DRilliNG AND COMPLETION PROGRAM Objective Well 1-23/0-15 will be drilled from the Endicott MPI to inject water in Subzone 2A of the Kekiktuk formation. The well may be pre-produced before conversion to an injector. The well will be completed with a 4-1/2" carbon tubing completion. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to proposed depth. Run and cement 10-3/4" 45.5#/ft NT- 80 buttress casing to surface. Pressure test casing. Install SOPt::. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 9-7/8" hole with a 9.0 - 10.2 ppg mud system through the Kekiktuk formation. E/Line logs will be run at this point. The long string will be 7-5/8" 29.7#/ft., NT95HS, NSCCcasing. No abnormal pressures are expected in the 9-7/8" hole section. Pressure test casing. Run the 4-1/2" L-80 completion with a single permanent packer and nipple up and test the tree and release Rig. Run SST/GR/CCU in the 7-5/8" casing. after the rig is released A subsurface safety valve will be installed below base of permafrost. Fluids incidental to the drilling of the well will be pumped down an approved annulus of a near-by well. The 1 0-3/4" x 7-5/8" annulus will be freeze protected with a non-freezing fluid down to 1500 feet after the 7-5/8" casing is run. DKC 9/21/94 RE<ZEIVED SEP 2 1 1994 Alaska Oil & Gas Cons. Commission Anchora~ß PRUDHOi ~ðrK~r Identification A) KB B} KOP SuILD 1.5/100 C} END 1.5/jOO SUlLO OJ STAAT 1/100 DROP E) END OF 1/100 DROP f) BUILD 2/100 G) END OF 2/100 BUILD H} SjA~T 2/100 CURVE#1 II END OF 2/100 CURVEi1 J) STAR1 2/100 CURvEG2 K) END OF 2/100 CURVE#2 LJ START 2/100 CURVE;3 MJ END OF 2/100 CURVE~3 N) --- TARGET --- 0) TO 2600 MD o 500 850 1000 1525 2300 3200 3520 4072 5983 6j63 7570 7S42 1053-4 10ß73 2400 2200-- 2000- 1800 1500-'" -..." ., ...... .......... ., .. i4oo--··· .. -.. ~.- ". .. . 1200 1000- . . 800 600 400 'I'\, 200 I ' - ,:¡: c: ê 0 = ,~ :5 I..? N/S o o 13 24 43 43 361 279 ~24 842 885 1250 1259 2087 2183 . '-i- I BAY ; .........' ~¡ ,I~.l I 'Í-Í-[ ~~ ¡. ,-1_) DR I LL I NG( GROUP 1-23/0-15 (P14) PLAN VIEW ElII' o o !O 18 32 32 9 7 83 509 545 791 803 1291 1348 . I¡on ~'~ : .' ..- 'H ~G 4~ .:, 200 I , 200 0 200 ~- wEST: EAST ->. ÍH1ðC!l'Úl /(:Jg3 'Z3Cj5j4 81.52 ::':4$ ~ jl . I. .' ," . ,... '. ,i I 400 I 600 800 ~ooo 1200 CLOSURE.....: 2566 feet at Azimuttl 31.71 DECLINATIOI~.: 30.000 E SCALE.......: 1 Jncn:;: 400 feet DRAWN.......: 07/1.4/94 Anadrj)] ~chJumberger I ¡ '1 ; 0 .. --.-., ... . . .. . '-'1 ,.... .......- I, .., .......... RE(?~JVED . '- SEP 2 ~ 1994 'Alaska Of! & Ga~ Cons .j:, .....-: . A h ,. \JomI.1ISslon nc orave. I I , t 2~OO 2600 I I 1400 2000 1600 1800 2200 I.. : ,: . £~øorjJJ i.cJ!'3 J230.1524 8LSo? 1: 43 PN :1) ---~ 7800 7200 I 6600 6000 5400 . ! ....,;:v..-.r.~r. - - ... - - - ~ - - - - - - - ... - - _ - -\- - - . - - - 1 - - - - - - - - - _ .1 - _ gOOO~wf.f.3_, .B91,. .. . '..__ -- ¡ . . I J I -T¡)¡~-1;JQb" - - - I - - - - - - - - - - - - - - - - - - - - - ~ - - - - . - - - - - - - - - . I I I, 9500 '-i!~~S'Jir.o(~';¡&6~T - ~ - - - - - - - - - - - ,- ;.' - - ~ - - - - - - - - - - - - - - - - -i.. - - - - ,")?j::I'1oo~ ~ - "91ëö"" - -: - - - - - - - - - - - ~- - - - - - - - - - ':' - - - - - - - - - - _1- - - - - . "':IZi;:¡:::?~~""" - À~-- - ..:. - - - - - - - - - - - ,- - - - - - - - - - - - - - - - - - - - - - - - ... - - , -ES1 I:ð¡;::" ~l6"'c;r.::~ - i - - - . - - - - - - -:- - - - - - - - - - - j - - - - - - - - - - - - - - - - . ~.. -.¡:;¡,:: ~- ~...c - ~ - - - - - - - - ... - -'- - - - - ~- - - - - - - - - - - - - - - - - - - - - :> ~~w- f · ~!]tr" CII ", - .. · · · · · - - - ".-= · · . . · ... · · ~ ::r: ::E 11: a - . . · . . -I - . = = tc - iO_DO ...~_~ ~... - - - ...-=._ .o_-=-_ - - - - - _ _ ~ _";' - - - - t _ ;:0_ _ -';; _ _ _ _ _1_ _ _ ;.: _ _.; .... ~,r; -~~'= : : 1 : : = = = = = = : = = = : = : : ~ - ~ : : : ~ : : : : : = : : : : :¡: : = = = : : 10800 . l 'I I I -' ! o 600 1200 1800 2400 3000 3600 4200 4800 Section Departure ,- :SEP 2 1 1994·" Alaska ¡Oil & Gas Cons. Co~mission AncflOré:.:)J1 .. I I -\ I J ¡ .L_. 8400 REGEIVEP 7800 7200 6600----.· ->...---- JK\ 6000 .--.... ,-- 5400 Section at: 30.82 TVD Sc a) e .: 1 inch = j200 feet Oep Scale.: 1 inch = 1200 feet Drawn.....: 07/1A/9.4 - -. . Anadri}} SchJumberger Marker Identjfication MD 8KB sECTt~ INCLN A) K6 0 0 0 0.00 B) KOP BUILD 1.5/100 500 500 0 0.00 ¡ C) END 1.5/100 BUILD 850 850 6 5.25 ..!._.... 0) START 1/100 DROP 1000 999 11 5.25 E) END Or 1/100 DROP 1525 1523 20 0.00 F) BUILD 2/100 2300 2298 20 0.00 G) END OF 2/100 BUILD 3200 3183 151 18.00 H) START 2/100 CURVE#1 .3520 3488 2¿3 18.00 I) END OF 2/100 'CUAVE#~ . 4072 4014 406 18.21 J) START 2/100 CURVEi2 5983 5829 984 18.21 K) END OF 2/100 CURVE#2 6163 6000 j039 18.21 l) START 2/100 CURVE#3 7570 7337 1478 18'.21 M) END OF 2/100 CU~VE#3 76~2 7405 1501 19.22 N) --- TARGET --- 10534 10136 245~ 19.22 0) TO 10873 10456 2565 19.22 ....-..- --- - ..-........ U Ii· 4800 4200 B K 3600 B I I I 3000- -,-·-1,-,-", G 2¡jOO .. F - -~ I 1800----·········· I - .-.- . I (' BAY DRILLING GROUP 1-23/0-15 (P1.4) VERTICAL SECTION VIEW <K6> 0 A 500 B- CT 0-- 1200 . I I E...... I PRUDHLt: WELL PERMIT CHECKLIST COMPANY SfJ /-~7 ,O/u WELL NAME FIELD & POOL :7 .2-.0/6 ð IN IT CLASS GEOL AREA lr?l'"1 ADMINISTRATION ~My ENGINEERING ;:jr 42¿ -- GEOLOGY ïL ~~y 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. n Permit fee attached. . . . . . . . Y Lease number appropriate. . . . Y Unique well name and number. . . Y Well located in a defined pool. . . . . . . . . . . . . .Y Well located proper distance from drlg unit boundary. . .Y Well located proper distance from other wells. . Y Sufficient acreage available in drilling unit. . . Y If deviated, is wellbore plat included . . . . . . Y Operator only affected party. . . . . . . . .Y Operator has appropriate bond in force. . . . . . . . . ,Y Permit can be issued without conservation order. . . . . Y Permit can be issued without administrative approval. . .Y Can permit be approved before 15-day wait. . . . . . . .~ N N N N N N N N N N N N N 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided . . . . . . . . . . . . . . . ~ N Surface casing protects all known USDWs . . . . . . . . ~ N 0 CMT vol adequate to circulate on conductor & surf csg:f\ ~ N ~Ce.- ~~ HR ('5 CMT vol adequate to tie-in long string to surf csg . . . Y (]Þ CMT will cover all known productive horizons. . . . . . iN Casing designs adequate for C, T, B & permafrost. . . . N Adequate tankage or reserve pit. . . . . . . . . . . .. N If a re-drill, has a 10-403 for abndnmnt been approved. .~ Adequate wellbore separation proposed. . . . . . . . . .1 N If diverter required, is it adequate. . . . . . . . . . Y N ~ Drilling fluid program schematic & equip list adequate . Y N J)~ I ~ BOPEs adequate . . . . . . . , . . . . ~ . . . . . .. N (J BOPE press rating adequate; test to ;::> ~¿:;o psig.(}þ N Choke manifold complies w/API RP-53 (May 84).. .. . ~ Nit Work will occur without operation shutdown. . CX) ~ Is presence of H2S gas probable. . . . . . . .. . .Y ~ 30. 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures. . Data presented on potential overpressure zones . Seismic analysis 9f shallow gas zones. Seabed condition survey (if off-shore) . Contact name/phone for weekly progress reports . [exploratory only] .YY N : ~ N M . N .,/.'y N / 19, GEOLOGY: RP#f'. ENGINEERING: COMMISSION: Comments/Instructions: BEWÆq,.vJ- 91"t: 1'.... JDH~ DW~~ RAD 1> , "2-, _.......f>~.. TAB . y-tJ> HOWljo - A:\FORMS\cheklist rev 03J94 /-¿3/ð -~~ PROGRAM: exp 0 UNIT# ,/0 SI ~ d REMARKS c1 v-.- 0 b..r-- dev 0 redrll 0 ser~ ON/OFF SHORE <::::3,u '. t:ï o z: o H ¿; t::d H H t::tj H z: H ::r:: H Cf.) Cf.) ~ Þ> (") t::tj ( ( 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. -1 ~LII\V(p fì¡7 \ ~ ~ I'-A PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. BARITE PRESENT IN MUD SYSTEM (3.3%) CAN EFFECT RESPONSE OF PE CURVE. UPPER WEST SAK SECTION LOGGED AT CUSTOMER'S REQUEST. PULLED 2000# OVER COMING OFF TD ON MAIN PASS. DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 1415, 05-NOV-94. LOGS WITNESSED BY: D. BOYER, P. BARKER, & C. BALLARD. # REMARKS: 4246.0 10800.0 9.875 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 10.750 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) RUN 1 RUN 2 RUN 3 JOB NUMBER: 6296.00 LOGGING ENGINEER: JOHN DAHL OPERATOR WITNESS: SEE REMARKS # SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: FSL: 3259 FEL: 2087 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 55.85 DERRICK FLOOR: 55.85 GROUND LEVEL: 14.50 # WELL CASING RECORD 1 - 23/0 - 15 500292251000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 10-NOV-94 TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Tape Subfile 2 is type: LIS $ THE DEPTH SHIFTED RT & DI CURVES ARE INCLUDED IN A TRAILING FILE AFTER RAW DATA PER CLIENT'S REQUEST. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: EDITED OPEN HOLE MAIN All tool strings; hole data. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ 1 PASS depth shifted and clipped curves; all runs merged; no case .5000 START DEPTH 4240.0 7200.0 7200.0 7200.0 STOP DEPTH 10713.0 10768.0 10737.0 10720.0 # BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ---,..----- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH LL8 ILD NPHI RHOB 7204.0 7204.0 7231.5 7232.0 7235.0 7234.5 7244.0 7244.0 7251.5 7252.0 7254.0 7253.5 7284.5 7284.0 7290.5 7290.5 7293.0 7293.5 7301.5 7301.5 7301.5 7302.5 7302.5 7302.0 7311.5 7311.5 7312.5 7313.0 7313.0 7313.5 7329.0 7329.0 7351.0 7351.0 7352.5 7353.0 7358.5 7359.0 7358.0 7372.0 7372.0 7376.5 7376.5 7377.0 7376.5 7376.0 7404.5 7405.0 7405.0 7406.0 7408.0 7408.0 7423.5 7424.0 7423.0 7426.0 7426.0 7450.5 7450.5 7453.0 7454.0 7453.5 7456.0 7456.5 7456.5 7457.0 7499.0 7499.5 7510.5 7510.5 7512.5 7512.0 7515.0 7515.0 7516.0 7515.5 7542.5 7543.5 7543.0 7543.5 7544.0 7549.0 7549.0 7551.0 7551.0 7551.0 7551.0 7551.5 7551.5 7577.5 7577.5 7661.0 7661.5 7662.5 7663.0 7665.0 7666.0 7663.5 7677.5 7677.0 7693.0 7691.5 7699.0 7699.0 7698.5 7700.0 7699.5 7699.0 7705.0 7705.0 7708.0 7708.5 7736.5 7737.0 7736.5 7737.0 7737.0 7739.5 7739.5 7739.0 7750.5 7750.5 7750.5 7762.5 7762.5 7763.0 7763.0 7765.0 7766.0 7768.0 7767.5 7787.0 7786.5 7787.0 7787.0 7791.5 7791.5 7792.0 7791.5 7794.5 7794.0 7796.0 7795.5 7796.5 7796.0 7806.5 7806.0 7807.0 7807.0 7811.0 7811.0 7814.5 7814.5 7815.0 7815.0 7821.5 7821.5 7822.0 7822.5 7824.5 7826.0 7828.5 7830.0 7842.5 7843.0 9652.0 9652.0 9655.5 9655.5 9655.5 9665.5 9665.0 9679.0 9679.0 9712.0 9712.5 9724.5 9724.5 9724.5 9820.0 9820.0 9820.5 9820.5 9819.5 9838.0 9837.0 9840.5 9840.0 9850.5 9849.5 9849.5 9863.0 9862.5 9863.5 9863.0 9891.5 9891.0 9897.5 9898.0 9898.0 9907.5 9906.0 9907.5 9908.5 9906.5 9909.0 9907.0 9910.0 9909.5 9914.0 9914.0 9914.5 9914.5 9914.5 9918.0 9917.5 9920.0 9920.0 9931.5 9931.0 9931.5 9931.0 9947.0 9946.5 9948.0 9947.0 9947.0 9948.5 9947.5 9949.0 9948.5 9955.0 9954.5 9960.5 9959.5 9963.5 9963.5 9963.5 9966.0 9966.0 9972.0 9971.5 9979.0 9980.0 9985.0 9985.0 9991.0 9991.5 9992.0 9992.0 9992.0 9996.0 9995.5 9995.5 9997.5 9997.5 :'0004.0 10003.5 10004.0 :'0010.5 10010.5 :'0011.0 10010.5 :'0013.0 10013.0 :'0013.5 10015.0 10013.0 :'0016.5 10018.0 10017.5 10016.5 :'0017.0 10017.0 :'0020.0 10021.5 :'0020.5 10022.5 :'0021.0 10023.0 :'0023.0 10023.5 10022.0 :'0024.5 10025.5 :'0025.0 10026.5 :"'0026.0 10027.5 :"'0029.0 10029.5 :"'0033.0 10032.0 10034.0 10033.0 10034.0 10034.5 10034.0 10035.0 10034.5 10039.0 10038.5 10039.5 10039.5 10039.5 10041.5 10041.5 10045.0 10044.5 10044.0 10047.0 10047.0 10049.5 10049.0 10049.5 10049.5 10053.0 10053.0 10052.5 10057.5 10057.0 10058.0 10057.5 10058.5 10057.0 10059.5 10059.0 10060.0 10060.0 10060.5 10060.0 10060.5 10059.5 10063.0 10063.0 10065.0 10064.0 10070.0 10069.5 10077.5 10077.5 10084.5 10083.0 10085.5 10085.0 10086.5 10086.0 10087.0 10086.5 10090.5 10089.5 10090.0 10089.0 10091.0 10090.0 10096.5 10096.5 10096.5 10097.0 10096.0 10099.5 10098.5 10103.5 10103.5 10104.0 10104.0 110104.5 10104.5 10109.5 10108.0 10110.0 10108.5 10110.5 10109.5 10111.0 10110.5 10115.5 10116.0 10114.5 10116.0 10115.5 10116.5 10116.5 10120.0 10120.0 10122.0 10122.0 10123.0 10122.5 10130.5 10130.5 10130.5 10130.0 10138.0 10138.0 10141.0 10141.5 10140.5 10141.5 10141.0 10150.5 10150.5 10151.5 10151.0 10152.0 10152.0 10154.5 10155.0 10155.0 10155.5 10155.5 10162.0 10161.5 10162.5 10162.5 10163.5 10163.5 10165.5 10165.5 10165.5 10165.0 10166.0 10166.5 10168.0 10167.0 10172.0 10171.0 10172.5 10173.0 10175.5 10176.0 10176.5 10176.5 10179.0 10179.0 10179.0 10179.5 10179.5 10181.0 10181.0 10181.5 10182.0 10182.0 10183.0 10182.5 10183.5 10184.5 10183.0 10189.0 10188.5 10187.5 10189.5 10189.5 10194.5 10194.5 10195.0 10195.0 10194.5 10197.0 10196.5 10197.5 10197.0 10197.0 10199.5 10199.5 10200.5 10200.5 10201.0 10201.0 10200.0 10201.5 10201.0 10202.5 10201.5 10204.5 10203.5 10231.5 10231.0 10231.5 10233.0 10232.5 10237.0 10236.5 10235.5 10240.0 10239.5 10240.0 10243.0 10243.0 10248.0 10247.5 10248.5 10257.0 10257.0 10262.0 10261.5 10263.0 10263.0 10264.5 10264.0 10265.0 10265.0 10267.0 10267.5 10268.0 10268.0 10270.5 10270.5 10270.5 10271.5 10272.0 10274.0 10274.0 10274.5 10275.0 10275.0 10276.0 10283.0 10285.0 10302.5 10302.0 10303.0 10303.0 10303.5 10303.5 10304.5 10304.0 10305.5 10305.0 10306.0 10306.0 10307.5 10307.5 10308.0 10308.5 10312.0 10312.5 10322.5 10320.5 10325.0 10323.0 10325.5 10323.5 10326.0 10324.0 10327.5 10327.0 10327.5 10326.0 10333.0 10333.0 10338.0 10338.0 10338.0 10338.5 10337.5 10340.5 10339.5 10341.0 10340.5 10341.0 10344.0 10344.0 10344.5 10344.0 10348.5 10348.5 10349.5 10349.0 10351.5 10349.5 10352.0 10350.5 10361.0 10361.0 10363.0 10364.0 10363.5 10362.5 10365.0 10364.0 10365.5 10365.0 10366.0 10365.5 10379.5 10379.0 10379.0 10382.0 10382.0 10386.5 10387.0 10387.0 10387.5 10388.0 10388.0 10391.0 10391.0 10390.5 10392.0 10391.5 10393.0 10393.0 10392.5 10393.5 10393.5 10394.0 10394.0 10398.0 10398.5 10398.5 10400.0 10400.5 10405.0 10405.5 10405.0 10405.5 10405.5 10408.0 10408.0 10407.5 10409.5 10410.5 10410.5 10410.5 10416.5 10416.5 10417.0 10417.0 10419.5 10419.5 10420.0 10420.0 10419.5 10420.5 10420.5 10421.5 10421.0 10422.0 10420.5 10422.5 10422.5 10425.5 10425.5 10424.5 10426.0 10426.0 10431.0 10430.5 10440.0 10440.0 10441.0 10441.0 10443.5 10443.0 10443.0 10447.0 10446.5 10448.5 10447.0 10446.5 10448.5 10448.5 10449.0 10449.5 10449.5 10450.0 10450.5 10449.5 10452.0 10452.0 10453.5 10452.5 10453.0 10452.0 10454.0 10455.5 10454.5 10454.5 10455.0 10455.0 10461.0 10460.0 10463.5 10463.0 10463.5 10470.0 10470.0 10470.0 10470.5 10470.0 10472.5 10473.0 10477.5 10477.5 10479.5 10480.5 10479.5 10481.0 10481.5 10480.0 10481.5 10481.0 10482.0 10482.0 10482.5 10483.5 10490.5 10490.5 10492.5 10493.0 10493.5 10493.5 10494.5 10494.5 10495.5 10495.0 10504.0 10504.0 10509.0 10509.0 10509.0 10508.5 10510.0 10509.5 10510.5 10510.5 10519.5 10519.0 10519.5 10518.0 10525.5 10525.0 10525.0 10526.0 10525.5 10526.0 10531.0 10530.0 10530.5 10534.0 10533.5 10534.5 10534.0 10535.5 10534.5 10534.5 10535.5 10535.0 10537.5 10536.5 10537.0 10539.0 10538.5 10539.0 10539.5 10539.0 10542.5 10542.0 10545.5 10546.0 10546.0 10546.5 10574.0 10573.0 10577.0 10577.0 10576.5 10595.0 10594.5 10602.0 10602.5 10625.5 10625.0 10626.0 10626.5 10626.5 10627.5 10628.5 10629.0 10628.5 10631.0 10631.0 10632.0 10633.0 10632.5 10632.5 10635.5 10636.0 BP EXPLORATION (ALASKA) 1-23/0-15 ENDICOTT NORTH SLOPE ALASKA /??MATCH1.0UT /??MATCH2.0UT /??MATCH3.0UT /??MATCH4.0UT $ MERGED MAIN PASS. NOTE: THERE IS A GAP IN THE DATA BETWEEN ROUGHLY 7825 - 9790'. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM WAS SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, CALI, & PEF WERE SHIFTED WITH RHOB. 10636.5 10636.0 10637.5 10645.5 10651.5 10652.0 10654.5 10654.5 10654.0 10662.0 10664.0 10663.5 10671.5 10671.5 10670.5 10677.5 10676.5 10684.0 10686.0 10690.0 10691.0 10694.0 10694.0 10694.0 10700.0 10707.0 10708.0 10709.5 10710.5 10713.5 10744.5 10758.5 SOURCE CODE RUN NO. PASS NO. MERGE TOP MERGE BASE 1 5 4240.0 9789.0 1 4 9789.0 10713.0 1 5 7200.0 7848.0 1 5 9648.0 9790.0 1 4 9790.0 10768.0 1 5 7200.0 7834.0 1 4 9790.0 10737.0 1 5 7200.0 7816.0 1 4 9790.0 10720.0 CN WN FN COUN STAT # # REMARKS: # MERGED DATA PBU TOOL GR GR DIL DIL DIL SDN SDN 2435 2435 $ 10636.0 10636.5 10646.0 10650.5 10651.5 10654.0 10654.5 10662.0 10664.5 10671.0 10677.0 10685.0 10690.0 10691.5 10694.0 10694.5 10699.5 10705.5 10706.0 10708.5 10710.5 10714.0 10744.0 10757.5 $ * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: API API API API Log Crv Crv Name Tool Code Samples units size Length Typ Typ CIs Mod 1 GR DIL 68 1 GAP I 4 4 55 965 57 0 2 LL8 DIL 68 1 OHMM 4 4 50 746 76 1 3 ILM DIL 68 1 OHMM 4 4 50 746 76 1 4 ILD DIL 68 1 OHMM 4 4 50 746 76 1 5 SP DIL 68 1 MV 4 4 50 746 76 1 6 MTEM DIL 68 1 DEGF 4 4 50 746 76 1 7 TEND DIL 68 1 LB 4 4 50 746 76 1 8 TENS DIL 68 1 LB 4 4 50 746 76 1 9 RHOB SDN 68 1 G/C3 4 4 22 779 91 0 10 DRHO SDN 68 1 G/C3 4 4 22 779 91 0 11 PEF SDN 68 1 BN/E 4 4 22 779 91 0 12 CALl SDN 68 1 IN 4 4 22 779 91 0 13 NPHI 2435 68 1 PU-S 4 4 98 211 23 1 14 FUCT 2435 68 1 CPS 4 4 98 211 23 1 15 NUCT 2435 68 1 CPS 4 4 98 211 23 1 ------- 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 881 Tape File Start Depth = 10805.000000 Tape File End Depth = 4202.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 2 211313 datums 1363 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE GR DIFL ZDL 2435 $ START DEPTH 9790.0 9790.0 9790.0 9790.0 STOP DEPTH 10739.5 10795.0 10763.0 10746.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO VENDOR TOOL CODE CHT MIS MODL GR CN ZDL TEMP PCM DIFL $ # BOTTOM) TOOL TYPE CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE{IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 05-NOV-94 FSYS REV. J001 VER. 1.1 1415 05-NOV-94 2025 05-NOV-94 10800.0 10782.0 7200.0 10768.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3506XA 1503XA 9.875 4246.0 4240.0 LSND 10.10 59.0 9.0 5.0 172.0 MUD AT MEASURED TEMPERATURE ( MT) : 1.920 70.0 MUD AT BOTTOM HOLE TEMPERATURE ( BHT) : .825 172.0 MUD FILTRATE AT MT: 2.120 68.0 MUD FILTRATE AT BHT: .000 .0 MUD CAKE AT MT: 2.250 68.0 MUD CAKE AT BHT: .000 .0 # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): .000 # TOOL STANDOFF (IN) : 1.5 # REMARKS: MAIN PASS. $ # CN BP EXPLORATION (ALASKA) WN 1-23/0-15 FN ENDICOTT COUN NORTH SLOPE STAT ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 4 67 456 14 5 2 RFOC DIFL 68 1 OHMM 4 4 27 515 24 6 3 RILM DIFL 68 1 OHMM 4 4 06 213 78 0 4 RILD DIFL 68 1 OHMM 4 4 04 903 06 0 5 VILD DIFL 68 1 MV 4 4 04 522 10 6 6 RT DIFL 68 1 OHMM 4 4 04 903 06 0 7 DI DIFL 68 1 IN 4 4 06 213 78 0 8 SP DIFL 68 1 MV 4 4 53 419 67 0 9 TEMP DIFL 68 1 DEGF 4 4 40 467 34 0 10 CHT DIFL 68 1 LB 4 4 78 867 34 0 11 TTEN DIFL 68 1 LB 4 4 78 867 34 0 12 SPD DIFL 68 1 F/MN 4 4 13 331 34 0 13 ZDEN ZDL 68 1 G/C3 4 4 52 443 33 1 14 ZCOR ZDL 68 1 G/C3 4 4 09 884 61 1 15 PE ZDL 68 1 BN/E 4 4 76 731 33 1 16 CAL ZDL 68 1 IN 4 4 24 115 90 6 17 CNC 2435 68 1 PU-S 4 4 98 211 23 1 18 CNCF 2435 68 1 PU-S 4 4 98 211 23 1 19 CN 2435 68 1 PU-L 4 4 52 326 75 5 20 LSN 2435 68 1 CPS 4 4 84 023 70 1 21 SSN 2435 68 1 CPS 4 4 83 368 34 1 --.-.---- 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 370 Tape File start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = 10805.000000 9789.000000 0.250000 = = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 89431 datums Tape Subfile: 3 450 records. . . Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 5 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE GR DIFL ZDL 2435 $ START DEPTH 4200.0 7200.0 7200.0 7200.0 STOP DEPTH 9792.0 7849.0 7849.0 7849.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO VENDOR TOOL CODE CHT MIS MODL GR CN ZDL TEMP PCM DIFL $ BOTTOM) TOOL TYPE CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 05-NOV-94 FSYS REV. J001 VER. 1.1 1415 05-NOV-94 2103 05-NOV-94 10800.0 10782.0 7200.0 10768.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3506XA 1503XA 9.875 4246.0 4240.0 LSND 10.10 59.0 9.0 5.0 172.0 MUD AT MEASURED TEMPERATURE (MT): 1.920 70.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): .825 172.0 MUD FILTRATE AT MT: 2.120 68.0 MUD FILTRATE AT BHT: .000 .0 MUD CAKE AT MT: 2.250 68.0 MUD CAKE AT BHT: .000 .0 # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): .000 # TOOL STANDOFF (IN): 1.5 # REMARKS: UPPER MAIN PASS. $ # CN : BP EXPLORATION (ALASKA) WN : 1-23/0-15 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: API API API API Log Crv Cry Name Tool Code Samples units Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 4 67 456 14 5 2 RFOC DIFL 68 1 OHMM 4 4 27 515 24 6 3 RILM DIFL 68 1 OHMM 4 4 06 213 78 0 4 RILD DIFL 68 1 OHMM 4 4 04 903 06 0 5 VILD DIFL 68 1 MV 4 4 04 522 10 6 6 RT DIFL 68 1 OHMM 4 4 04 903 06 0 7 DI DIFL 68 1 IN 4 4 06 213 78 0 8 SP DIFL 68 1 MV 4 4 53 419 67 0 9 TEMP DIFL 68 1 DEGF 4 4 40 467 34 0 10 CHT DIFL 68 1 LB 4 4 78 867 34 0 11 TTEN DIFL 68 1 LB 4 4 78 867 34 0 12 SPD DIFL 68 1 F/MN 4 4 13 331 34 0 13 ZDEN ZDL 68 1 G/C3 4 4 52 443 33 1 14 ZCOR ZDL 68 1 G/C3 4 4 09 884 61 1 15 PE ZDL 68 1 BN/E 4 4 76 731 33 1 16 CAL ZDL 68 1 IN 4 4 24 115 90 6 17 CNC 2435 68 1 PU-S 4 4 98 211 23 1 18 CNCF 2435 68 1 PU-S 4 4 98 211 23 1 19 CN 2435 68 1 PU-L 4 4 52 326 75 5 20 LSN 2435 68 1 CPS 4 4 84 023 70 1 21 SSN 2435 68 1 CPS 4 4 83 368 34 1 -....----- 84 Total Data Records: (TYPE# 0) 974 BYTES * * DATA RECORD Tape File start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth units **** FILE TRAILER **** 2057 = 9858.000000 4202.000000 0.250000 = = Feet LIS representation code decoding summary: Rep Code: 68 709064 datums Tape Subfile: 4 2137 records. . . Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: RAW OPEN HOLE Curves and files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR DIFL ZDL 2435 $ 4 REPEAT PASSES log header data for each pass, tool string, and run in separate 1 1 3 .2500 START DEPTH 9961.0 9961.0 9955.0 9955.0 STOP DEPTH 10745.5 10801.0 10769.0 10747.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO VENDOR TOOL CODE CHT MIS MODL GR CN ZDL TEMP PCM DIFL $ BOTTOM) TOOL TYPE CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): 05-NOV-94 FSYS REV. J001 VER. 1.1 1415 05-NOV-94 1947 05-NOV-94 10800.0 10782.0 7200.0 10768.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3506XA 1503XA 9.875 4246.0 4240.0 LSND 10.10 59.0 9.0 5.0 172.0 1.920 .825 70.0 172.0 MUD FILTRATE AT MT: 2.120 68.0 MUD FILTRATE AT BHT: .000 .0 MUD CAKE AT MT: 2.250 68.0 MUD CAKE AT BHT: .000 .0 # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): .000 # TOOL STANDOFF (IN): 1.5 # REMARKS: REPEAT PASS. $ # CN BP EXPLORATION (ALASKA) WN 1-23/0-15 FN ENDICOTT COUN NORTH SLOPE STAT ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: API API API API Log Crv Crv Name Tool Code Samples units Size Length Typ Typ CIs Mod 1 GR DIFL 68 1 GAPI 4 4 67 456 14 5 2 RFOC DIFL 68 1 OHMM 4 4 27 515 24 6 3 RILM DIFL 68 1 OHMM 4 4 06 213 78 0 4 RILD DIFL 68 1 OHMM 4 4 04 903 06 0 5 VILD DIFL 68 1 MV 4 4 04 522 10 6 6 RT DIFL 68 1 OHMM 4 4 04 903 06 0 7 DI DIFL 68 1 IN 4 4 06 213 78 0 8 SP DIFL 68 1 MV 4 4 53 419 67 0 9 TEMP DIFL 68 1 DEGF 4 4 40 467 34 0 10 CHT DIFL 68 1 LB 4 4 78 867 34 0 11 TTEN DIFL 68 1 LB 4 4 78 867 34 0 12 SPD DIFL 68 1 F/MN 4 4 13 331 34 0 13 ZDEN ZDL 68 1 G/C3 4 4 52 443 33 1 14 ZCOR ZDL 68 1 G/C3 4 4 09 884 61 1 15 PE ZDL 68 1 BN/E 4 4 76 731 33 1 16 CAL ZDL 68 1 IN 4 4 24 115 90 6 17 CNC 2435 68 1 PU-S 4 4 98 211 23 1 18 CNCF 2435 68 1 PU-S 4 4 98 211 23 1 19 CN 2435 68 1 PU-L 4 4 52 326 75 5 20 LSN 2435 68 1 CPS 4 4 84 023 70 1 21 SSN 2435 68 1 CPS 4 4 83 368 34 1 ------- 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 312 Tape File start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth units = 10811.000000 9955.000000 0.250000 = = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 164782 datums Tape Subfile: 5 390 records. . . Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 6 is type: LIS THE CURVES RT & DI HAVE BEEN DEPTH SHIFTED. THE SAME SHIFTS WERE APPLIED AS THOSE USED FOR ILD & ILM CURVES IN THE EDITED MAIN PASS FILE. THIS FILE IS INCLUDED IN THIS FORMAT PER BP EXPLORATION REQUEST. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units API API API API Log Crv Cry Size Length Typ Typ CIs Mod 1 2 RT DI DIL DIL 68 68 1 1 OHMM IN 4 4 4 50 746 76 4 50 746 76 1 1 ------- 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 86 Tape File start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth units = 10805.000000 7200.000000 0.500000 = = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 6 730698 datums 91 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 94/11/ 9 01 **** REEL TRAILER **** 94/11/10 01 Tape Subfile: 7 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes End of execution: Thu 10 NOV 94 5:04p Elapsed execution time = 47.35 seconds. SYSTEM RETURN CODE = 0