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HomeMy WebLinkAbout191-122CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable: Endicott 2-54 (PTD# 191-122) Passing MIT-IA Date:Tuesday, May 16, 2023 12:29:08 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, May 16, 2023 11:55 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Operable: Endicott 2-54 (PTD# 191-122) Passing MIT-IA Mr. Wallace, On 4/28/2023 Produced Water Injector END 2-54 (PTD# 191-122) had an internal MIT-IA to 2750 psi with a pressure gauge stung into the tubing void, re-pressurization of the tubing void occurred during this test. On 5/8/2023 the LDS on the tubing hanger were re-torqued to spec. On 5/15/2023 the well passed an AOGCC witnessed MIT-IA to 2826 psi. WHP’s have been stable during the under evaluation period. The well will now be reclassified as OPERABLE. Thanks, Ryan Thompson Milne/Islands Well Integrity Engineer 907-301-1240 From: Ryan Thompson Sent: Tuesday, April 25, 2023 1:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: Under Evaluation: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Mr. Wallace, Produced Water Injector END 2-54 (PTD# 191-122) failed a witnessed MIT-IA on 4/4/2023. On 4/8/2023 both a PPPOT-T & PPPOT-IC passed. On 4/24/23 an Internal MIT-IA passed to 2643 psi with the well shut in. Per our conversation Hilcorp will now bring this well online for a 28 day under evaluation period. Plan Forward: 1. Perform MIT-IA while on injection. 2. Monitor for pressure communication. 3. Additional diagnostics as needed. Thanks, Ryan Thompson Milne Pt / Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Wednesday, April 5, 2023 9:26 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Mr. Wallace, Produced Water Injector END 2-54 (PTD# 191-122) failed a witnessed MIT-IA on 4/4/2023. Inspector Guy Cook was on location during the test. The well is now classified as NOT OPERABLE and will remain shut in until diagnostics and repairs have been completed. Plan Forward 1. PPPOT-T and PPPOT-IC 2. Engineer to evaluate additional diagnostics Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-54 DUCK IS UNIT MPI 2-54 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 2-54 50-029-22218-00-00 191-122-0 W SPT 9899 1911220 2475 2177 2188 2194 2169 272 545 540 534 4YRTST P Brian Bixby 5/15/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 2-54 Inspection Date: Tubing OA Packer Depth 338 2897 2847 2826IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230515162714 BBL Pumped:5.5 BBL Returned:5.5 Friday, June 16, 2023 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Under Evaluation: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Date:Tuesday, April 25, 2023 2:09:42 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, April 25, 2023 1:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: Under Evaluation: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Mr. Wallace, Produced Water Injector END 2-54 (PTD# 191-122) failed a witnessed MIT-IA on 4/4/2023. On 4/8/2023 both a PPPOT-T & PPPOT-IC passed. On 4/24/23 an Internal MIT-IA passed to 2643 psi with the well shut in. Per our conversation Hilcorp will now bring this well online for a 28 day under evaluation period. Plan Forward: 1. Perform MIT-IA while on injection. 2. Monitor for pressure communication. 3. Additional diagnostics as needed. Thanks, Ryan Thompson Milne Pt / Islands Well Integrity Engineer 907-301-1240 From: Jerimiah Galloway Sent: Wednesday, April 5, 2023 9:26 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Mr. Wallace, Produced Water Injector END 2-54 (PTD# 191-122) failed a witnessed MIT-IA on 4/4/2023. Inspector Guy Cook was on location during the test. The well is now classified as NOT OPERABLE and will remain shut in until diagnostics and repairs have been completed. Plan Forward 1. PPPOT-T and PPPOT-IC 2. Engineer to evaluate additional diagnostics Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Date:Wednesday, April 5, 2023 10:10:33 AM Attachments:END2-54_TIO_Schematic.docx From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, April 5, 2023 9:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Endicott 2-54 (PTD# 191-122) Failed MIT-IA Mr. Wallace, Produced Water Injector END 2-54 (PTD# 191-122) failed a witnessed MIT-IA on 4/4/2023. Inspector Guy Cook was on location during the test. The well is now classified as NOT OPERABLE and will remain shut in until diagnostics and repairs have been completed. Plan Forward 1. PPPOT-T and PPPOT-IC 2. Engineer to evaluate additional diagnostics Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-54 DUCK IS UNIT MPI 2-54 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/10/2023 2-54 50-029-22218-00-00 191-122-0 W SPT 9899 1911220 2475 2188 2202 2195 2196 147 367 365 363 4YRTST F Guy Cook 4/4/2023 Testing was completed with a Thunderbird pump truck and calibrated gauges. Well consistently lost between 26 to 29 psi every 15 minute test interval showing no stabilizing trend. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 2-54 Inspection Date: Tubing OA Packer Depth 391 2748 2719 2692IA 2193 360 45 Min 2664 2202 357 60 Min 2636 Rel Insp Num: Insp Num:mitGDC230403174955 MITOP000009713 BBL Pumped:4.6 BBL Returned:4.2 Monday, July 10, 2023 Page 1 of 1 9 9 9 9 9 9 99 999 9 9 9 9 9 F Well consistently lost between 26 to 29 psi every 15 minute test interval showing no stabilizing trend. James B. Regg Digitally signed by James B. Regg Date: 2023.07.10 11:22:33 -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 2-54 DUCK IS UNIT MPI 2-54 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ 2-54 50-029-22218-00-00 191-122-0 W SPT 9899 1911220 2475 2188 2202 2195 2196 147 367 365 363 4YRTST F Guy Cook 4/4/2023 Testing was completed with a Thunderbird pump truck and calibrated gauges. Well consistently lost between 26 to 29 psi every 15 minute test interval showing no stabilizing trend. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 2-54 Inspection Date: Tubing OA Packer Depth 391 2748 2719 2692IA 2193 360 45 Min 2664 2202 357 60 Min 2636 Rel Insp Num: Insp Num:mitGDC230403174955 BBL Pumped:4.6 BBL Returned:4.2 Friday, May 19, 2023 Page 1 of 1           Pressure loss during 30-minute test intervals exceeds 2% criteria applied to MITs with low total pressure loss; jbr 5/19/2023 MEMORANDUM State of Alaska 15 Min 30 Min Alaska Oil and Gas Conservation Commission Tn13i11 I'll DATE: Wednesday, May 8, 2019 7'O: Jim Re 2 / 5 tel SUBJECT: Mechanical Integrity Tests P.I. Supervisor ` �1 1914 400 - 2897 - 400 - HILCORP ALASKA LLC 2883 " aoo 2-54 FROM: Jeff Jones DUCK IS UNIT MPI 2-54 Petroleum Inspector --- Src: Inspector Reviewed By: PA. Supry NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-54 Insp Num: mitJJ190503130810 Rel Insp Num: API Well Number 50-029-22218-00-00 Inspector Name: Jeff Jones Permit Number: 191-122-0 Inspection Date: 4/22/2019 Packer Depth Well E ... 2-54 Type Inj w' ,TVD 9 99 PTD 1911220 "Type Test SPT Test psi 2475 BBL Pumped 4.6 ' BBL Returned: 5.' - Interval 4YRTST Notes' I well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min Tn13i11 I'll P_LG 11-," 2190 2]'2 IA 543 OA 180 1914 400 - 2897 - 400 - 2888 aoo 2883 " aoo --- Wednesday, May 8, 2019 Page I of 1 • • � ffi r F _ ' s E Post Office Box 244027 ,JULAnchorage,AK 99524-4027 Hilcorp Alaska,LLCU201,1 3800 Centerpoint Drive Suite 100 AOGC ` Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 SCM4t EO AUG 2 3 ZG"16; Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 n2� Anchorage, AK 99501 Cf 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 11/ Orig .II New API_WelINo l PermitNumberl WellName IWeIlNumber WeIlNum ber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-306/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-466 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/5D7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/1(33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-176 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 07,2015 TO: Jim Regg p� ciO/IS P.I.Supervisor " SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-54/Q12 FROM: Johnnie Hill DUCK IS UNIT MPI 2-54/Q12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 5S62— NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI2-54/Q12 API Well Number 50-029-22218-00-00 Inspector Name: Johnnie Hill Permit Number: 191-122-0 Inspection Date: 4/28/2015 Insp Num: mitJWH150505110846 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type Inj � 2-54/Q12 W TVD--_- 9899 - Tubing ----__ 2275 " 2275 2275 - 2275 ---- PTD 1911220 -Type Test SPT Test psi 2475 - IA 1490 2860 - 2847 - 2841 Interval 4YRTST P/F P ✓ OA 310 460 460 - 460 Notes: %— --- — - --- - N n15 Thursday,May 07,2015 Page 1 of 1 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg 2 �, Alaska Oil and Gas Conservation Commission I — 1 L-1 ( 333 West 7 Avenue Anchorage, Alaska 99501 9- Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Gerald Murphy, at 659 -5102. Sincerely, / If -. Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na pal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 -,END2 -54 / Q-12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 ENO2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD-12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, May 09, 2011 TO: Jim Regg P.I. Supervisor P/ �� 51 (/l II SUBJECT: Mechanical Integrity Tests (� BP EXPLORATION (ALASKA) INC 2- 54/Q12 FROM: Lou Grimaldi DUCK IS UNIT MPI 2- 54/Q12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry v NON - CONFIDENTIAL Comm Well Name: DUCK IS UNIT MPI 2- 54/Q12 API Well Number: 50- 029 - 22218 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110507160920 Permit Number: 191 -122 -0 Inspection Date: 5/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weill 2- 54/Q12 (Type Inj. W ' TVD 9899 ' I IA 500 3000 2990 2985 P.T.Di 1911220 1TypeTest SPT Test psi I 3000 ' OA 40 280 1 275 275 Interval 4YRTST p/F P - Tubing 184o 1840 1840 1850 Notes: 5.1 Bbl's Meoh pumped. Well fluid packed. Good test. 1 A, ray 74r" A MAY 1S ZU1I Monday, May 09, 2011 Page 1 of 1 ~I. PROACTIVE DIAgNO571C SERVICES INC_ • T/4ASlTT~4L To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 (~ ~~ / 4j ~ - ~~~ l ~ ~~ 1) Injection Profile 21-Jan-1 O 2-54 / ~-12 BL / EOE 2) Signed Print Name: ,~j J ` I Date 50-029-22215-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL : =- __~' i`:'. ~ e.= WEBSITE : ~ -'- --- -- _ -- C',Dociunznts and Szttings~Dianz W'flliams:Desktoo~Transmit_L32 docx 01 /08/09 •~ ~chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0. 5029 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 K-O5C AWJB-00016 MEM PROD PROFILE : ~; C .__ ':~ .~y ~~;' " vase 1y29/Og DL 1 ~oior cu 1 2-54/0-12 11968974 SBHP SURVEY ; ; :: ~. 1` ' `.~ '!- C. -_? 11/23/08 1 1 V-223 AXBD-0001 MEM INJECTION PROFILE +~ ~.~9 """ „~- _ -, ~ %"" ~-~~~ " 12/29/08 1 i 18-24B 12066555 MCNL ~~'~_,-,%~!- '= 1 ' j ~ ' "% 10/18/08 1 1 J-18 12103680 RST ' -;' ~-, - t'~` i ' - <'= ' ..1 r' 09/25/08 1 1 1-45/0-26 12086686 RST ~ ' ~ ' ~` '~"' 12r °~1 -1 , )' ,' " ~-r - 1 <-,~ ~ 09/22/08 1 1 V-219 40018249 OH MWD/LWD EDIT =~~;:~, -~ ~ ~_" _Z `-` ~.:(;-~'-~, 11/17/08 2 1 PLEASF_ OCKNAWI FIIr:F ClC r`CIDT QV CI!_4 n A~/~ ALII'1 ~CTI1~\II\I/~ A.~r ~Anv ~. ~.. rw BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 j'I Anchorage, AK 99503-2838 f / ATTN: Beth j J ~ r Received by: ~ i !~______---~ ''~ C~ • P.. • ~ ~~ ~- 4 Regg, James B (DOA) From: END, Production Coordinator [ENDProductionCoordinator@BP.com] Sent: Thursday, November 27, 2008 6:51 AM To: Regg, James B (DOA); Jones, Jeffery B (DOA) ~ ~~ ~ - ~ ZZ Subject: Endicott 2-54 Water Injector ~~~~ Gentlemen, Perforating operations were completed on well 2-54 on 11/25 and the MCX was installed on 11/26. Thank you for working with us on this one. Hal Tucker a~;`w,~~~~~% '~i!-~ ~ ~` '~. ~Q~~i x6529 Melody, It is my understanding that you were unable to fiinish your planned well work in the 14 day time frame due to a BPXA instituted "safety shutdown" triggered by a recent series of injuries on the North Slope. Be that as it may, I have discussed your situation with the AOGCC inspection Supervisar Mr. Jim Regg, and you have approval to finish your planned well work and then replace the SSSV. Please be aware that this approval is not totally open ended and new AOGCC regulations are in the process of finalization that will have additional wellhead safety valve system requirements that apply to this type of situation. _ Nv~-2 ,- ASS ~ '~ ~`tU~ uc Thank you, _ Jeff Jones ~~c ~-ri~~~~~~ AOGCC t, From: END, Production Coordinator [mailto:ENDProductionCoordinator@BP.com] Sent: Tuesday, November 18, 2008 10:32 AM To: Jones, Jeffery B (DOA) Subject: Endicott 2-54 Water Injector Jeff: The SSSV on Endicott Water Injection well 2-54 was removed on 11 /5 for wellwork. The well was entered into our safety defeat log, and has been on injection since 11/6. Normally that would start a 14 day clock, during which time we would complete the wellwork and replace the SSSV, or shut the well in. The last stages of the desired wellwork have been delayed for a variety of reasons, and will not be completed before the end of the 14 day window. It is my understanding from our phone conversations, that on this well, at this moment in time, the 14 day rule does not apply. With your approval, we will continue injecting water into this well until we can finish our planned wellwork, at which point we will replace the SSSV. Your attention to this is most appreciated! Melody Grover Production Coordinator ACT--Endicott/ Northstar 11/28/2008 .~ _ ~ STATE OF ALASKA ~~ !1' ~ '~~~F~` ALA OIL AND GAS CONSERVATION COM~11ls510N REPORT OF SUNDRY WELL OPERATIONS ,~,?- -os 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Other` Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time ExtensiorrQ `° Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Renter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~~ Exploratory 191-1220 3. Address: P.O. Box 196612 Stratigraphic Service . ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22218-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 55.1 KB ~ 2-54/0-12 8. Property Designation: 10. Field/Pool(s): ADLO-034633 ~ Endicott Field/ Endicott Pool 11. Present Well Condition Summary: Total Depth measured 12175' feet Plugs (measured) None true vertical 10601.79 - feet Junk (measured) None Effective Depth measured 12134 feet true vertical 10564 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" Surface - 131' Surface - 131' Surface 2736' 13-3/8" 68# NT80 Surface - 2736' Surface - 2735' 5020 2270 Production 9483' 9-5/8" 47# NT80S Surface - 10926' Surface - 9498' 6870 4760 Liner 1519' 7" 29# L-80 10656' - 12175' 9269' - 10602' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 35' - 10584' 4-1/2" 12.6# L-80 10582' - 11511' Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR -- 11392' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: _ Intervals treated (measured): ,„.~r,,~'~~~~~J~~t ~~ ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 27335 2390 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: copies of togs and surveys Run Exploratory ~ Development ~"` Service hr`~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG GINJ ~ WINJ - WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~~' Phone 564-4944 Date 11/26/2008 '~ ' ~f '?'~ ~~ ~~ ~ (I~i /~ ~.~ . Submit Original Only Form 10-404 Revised 04/2006 ' 'cA l~~ 2-54/Q-12 191-1220 PFRF ~TTOrHMFNT C~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2-54/Q-12 12/7/91 PER 11,788. 11,881. 10,251.33 10,335.11 2-54/Q-12 12/7/91 PER 11,894. 11,940. 10,346.82 10,388.36 2-54/Q-12 12/7/91 PER 11,952. 12,062. 10,399.2 10,498.55 2-54/Q-12 5/5/96 SPS 11,941. 12,062. 10,389.26 10,498.55 2-54/Q-12 4/27/07 BPP 11,941. 12,062. 10,389.26 10,498.55 2-54/Q-12 11/24/08 PER 11,900. 11,920. 10,352.24 10,370.29 2-54/Q-12 11/24/08 PER 11,920. 11,940. 10,370.29 10,388.36 2-54/Q-12 11/24/08 PER 11,960. 11,980. 10,406.42 10,424.49 2-54/Q-12 11/25/08 PER 11,562. 11,582. 10,049.68 10,067.42 2-54/Q-12 11/25/08 PER 11,604. 11,624. 10,086.94 10,104.7 2-54/Q-12 11/25/08 PER 11,683. 11,703. 10,157.21 10,175.06 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 2-54/Q-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/23/2008 T/t/0= 300/180/0 Temp=S1 Freeze Protect Tbg (pre adperf). Pumped 35 bbls 60/40 meth down Tbg to freeze protect. Final WHPs 600/180/0 ~ ; IA/OA casing valves open to gauges, swab shut needle valve open to gauge at j 'time of departure 11/24/2008 ***JOB CONTINUED FROM 23-NOVEMBER-2008*** ~~~ RIH WITH HEAD/2-1.69 IN WEIGHT BARS/ PBMS/ PGMC. JEWELRY LOG, #BEGIN STATION LOGS. PICKUP DEPTH AT 11998 FT. PERFORATED INTERVALS 11900-11940 FT, AND 11960-11980 FT. SURFACE AND VISUAL CONFIRMATION OF GUNS FIRING. ***JOB CONTINUES 25-NOVEMBER-2008*** _ _ 11/25/2008 ""*JOB CONTINUED FROM 24-NOVEMBER-2008.*** PERFORATED INTERVALS 11683'-11703', 11604'-11624' AND 11562'-11582' WITH 3.38" HSD 6SPF 60 DEGREE PHASED PJ3406 GUNS..DEPTH CORRECTED TO SLB CBL LOG DATED 6-DEC-91. ALL SHOTS FIRED, DSO HAD FACE TO FACE TURN OVER OF WELL BACK TO PRODUCTION CONTROL. FINAL T/1/O = 275/400/0 **"JOB COMPLETE*** E _ ~ ~._._... ~. _ _ _.__ ~ _ __._.__ . ~ ~__..__ ~ _.__ .._._.. FLUIDS PUMPED BBLS 1 diesel 1 METH 2 Total 03/15/2007 Schlumberger NO. 4184 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth UJ:C-1C ¡ -IQd Company: State of Alaska Alaska Oil & Gas Cons (:omm AUn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay WI b# L B CI CD el Jo OJ! Description Date L o or Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-06B N/A MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02/19/07 1 03-02 . 11626072 USIT CORROSION EVALUATION 02/22/07 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24· 11549359 RST 12/26/06 1 1 U-06BPB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWD/LWD 05/08/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ') 2007 Petrotechnical Data Center LR2-1 ~,.......M,..,...r;n APR () tJ 900 E. Benson Blvd. \iJUIU~ Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '\ Received by: Ü ¿ Date Delivered: IIIJAP ~ ..~!, '(fI(rl ILl . . ~ RECEIVED . STATE OF ALASKA ~..."",u-~1 ALA OIL AND GAS CONSERVATION COM~ION MAR 2 2 2007 REPORT OF SUNDRY WELL OPERATIONSAlaska 0·' & G C . . , as ons. Commtsslon . . 1. Operations Performed: -g D Abandon ~ Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well D Alter Casing ~ Pull Tubing D Perforate New Pool D Waiver D Other D Change Approved Program D Operation Shutdown D Perforate D Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. D Development D Exploratory 191-122 / 3. Address: D Stratigraphic ~ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22218-00-00 - 7. KB Elevation (ft): 55.10 / 9. Well Name and Number: END 2-54/Q-12 ' 8. Property Designation: 10. Field / Pool(s): ADL 034633 {' Endicott Field / Endicott Pool - 11. Present well condition summary Total depth: measured 12175/ feet true vertical 10602 £ feet Plugs (measured) None Effective depth: measured 12134 feet Junk (measured) 11648' true vertical 10564 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 131' 30" 131' 131' Surface 2736' 13-318" 2736' 2735' 5020 2270 Intermediate 9483' 9-518" 9483' 8292' 6870 4760 Production 1443' 9-518" 9483' - 10926' 8292' -9498' 8150 5080 Liner 1519' 7" 10656' - 12175' 9269' - 10602' 8160 7020 Perforation Depth MD (ft): 11788' - 11940' titGANNED MAR 2 e 2007 Perforation Depth TVD (ft): 10251' - 10388' 5-1/2" x 4-1/2", 17# x 12.6# L-80 11510' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 11392' 5-1/2" HES HRQ SSSV 1560' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations D Exploratory D Development ~ Service 16. Well Status after proposed work: J ~ Well Schematic Diagram DOil DGas DWAG DGINJ ~WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact PaulChan, 564-5254 307-058 Printed Name Sondra Stewman Title Technical Assistant J~- ---' Prepared By Name/Number: Sig ature V;;'" L7J.If\. ~3>- Phone 564-4750 Datefh- 2-1 -D-¡Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 - .. MAR :2 82007 Submit Original Only ORIGIN.~L IRSDMS ~ (~""""\ ,TREE = , WELLHEAD = ACTUA TOR = RT. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 6" CfI/V 13-5/8" MCEVOY AXELSON 55.10' 16.20' . END 2-54 FROM DRlG ~ DRAFT . 43 @ 6300' 11S68' 10000'SS . 1 1476' I"""iS-1/2" HES HRO SSSV LANDING NIP, ID = 4.S62" ~ 2736' GAS LIFT MANDRELS ST MO TVD OEV TYÆ VLV LATCH PORT DATE L 2 1 NlA S I 9483' ~ / 2" I 10661' I HS-1/2" x 4-1/2" CROSSOVER I 1 0584' NR I 10656' 2S .958'1 6811 10926' "}---..4 I I 11332' - HES XD DURO SLIDING SLEEVE I I - 4-1/2" X NIP, 10 = 3.813" I . 11363' X ~ - 11396' -iT' X 4-1/2" S-3 PKR, ID = 3.910 I .... I 11426' -i4-1/2" X NIP, 10 = 3.813" 1 MMARY I 11499' - 4-1/2" XN NIP, 10 = 3.72S" I ?? -14-1/2" WLEG, 10 = 3.9581 "- - 11510' 26° @ 11788' or historical perf data t---i 11648' HRA TAG I Opn/Sqz DATE ~ 0 12/10/91 0 12/10/91 S 04/06/96 I] II PBTD I 12134' 6.184" I 12175' I 113-3/8" CSG, 68#, NTBOCYHE, ID = 12.4 19-5/8" CSG, 47#, NT80S XO TO NT95H IS-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.89 TOPOF 7" L 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3 19-5/8" CSG, 47#, NT9SHS, NSCC, 10 = 8. ÆRFORA TION SU REF LOG: ? ANGLE AT TOP ÆRF: Note: Refer to Production DB f SIZE SPF INTERVAL 4-1/2" S 11788-11881 4-1/2" S 11894 - 11940 4-1/2" S 11952 - 12062 17" LNR, 29#, L-80,BTRS- TKC, .0371 bpf, 10 = DATE 01/20/92 OS/OS/96 06/13/00 12/31/0S 11/23/06 12/11/06 REV BY JLH JTP MAS EZLlPJC CJNlPJC 'II PJC COMMENTS DATE COMPLETION 03/11/07 SANDBACKI CMT TBG PATCH REVISED WAVIER SFTY NOTE SET XX PLUG @ 106S0 CONVERT NEW FORMA T ENDICOTT UNrr WELL; 2-54/0-12 ÆRMrrNo: 1911220 API No; 50-029-22218-00 SEC. 36, T12N,R16E, 2328'FEL,2078'FNL REV BY COMMENTS /PAG ORLG DRAFT CORRECTIONS BP Exploration (Alaska) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/16/2007 21 :00 - 00:00 3.00 MOB P PRE 2/17/2007 00:00 - 02:30 02:30 - 05:30 2.50 MOB 3.00 MOB P P PRE PRE 05:30 - 09:30 4.00 MOB P PRE 09:30 - 11 :00 1.50 MOB P PRE 11 :00 - 12:30 1.50 MOB P PRE 12:30 - 16:00 3.50 MOB P PRE 16:00 - 20:00 4.00 MOB P PRE 20:00 - 00:00 4.00 MOB P PRE 2/18/2007 00:00 - 01 :00 1.00 MOB PRE 01 :00 - 01 :30 0.50 KILL OECOMP 01 :30 - 03:30 2.00 KILL OECOMP 03:30 - 06:00 2.50 KILL OECOMP 06:00 - 08:30 2.50 KILL OECOMP 08:30 - 13:30 5.00 KILL OECOMP 13:30 - 15:00 1.50 KILL DECOMP 15:00 - 18:30 3.50 KILL DECOMP 18:30 - 22:00 3.50 KILL DECOMP ROMO. Move off well 4-18/S-30. RID top drive. Bridle up to lay down derrick. Prep to move rig. Move off 4-18. Lower pipe shed chute. RID and unhook from top drive. Move rig to open area of pad. Install lifting yoke on BOPE. Remove BOPE from cellar and set on skid. Prepare all lines and personnel to break derrick over. Hole PJSM on lowering the derrick. Lay derrick over and secure for rig move. Install rear boosters and test. Move rig from SOl to MPI. Set rig down and remove rear boosters. Pick up BOPE and set back on pedestal in cellar. Postion rig to raise derrick. Hold PJSM on raising derrick with all crew personnel. Raise derrick and secure. Raise pipe shed chute and RlU floor. Install derrick touque tube. Install mud manifold. Bridle down and store. Layout Herculite over well site and set rig mats. PJSM. Move and spot rig over well slot 2-54. Shim and set down rig. Load pits with 400 bbls of 2% KCI brine. Install equipment needed in cellar. RlU high pressure circulating hoses. Position slop tank under mud pits conveyor. Spot #2 mud pump module and make connections. Spot and RlU #4 generator module. RlU double annulus valves on wellhead. RlU circulating manifold and circulating lines in cellar. Pressure test circulating lines to 3500 psi. Valve not holding. Install communication line from rig to camp. RlU DSM lubricator and pull BPV. RID OSM. Change out bad valve on circulating pump manifold in cellar. RlU circulating line and pressure test circulating lines to 3500 psi (good test). PJSM. Check for pressures on tubing and annulus. No pressure. Displace diesel freeze protection and wellbore fluids with 120 deg F 2% KCI brine. Pump a high viscocity spacer before brine. Pump at 6 BPM with 390 psi. Take all returns to slop tank. Hook up OA line to flow tank to vent OA. RlU and set TWC valve. Test TWC to 1000 psi from below and 3360 psi from above (good tests). Hold both test for 10 and chart results. RID testing equipment. Nipple down production tree and adaptor flange. Break down tree to facilitate removal from cellar. Inspect and function test wellhead and hanger equipment by functioning lock down screws and inspect hanger threads. Clean up tools and equipment from cellar. N/U BOPE. Install kill and choke lines. M/U hydraulic connections to BOPE. RlU BOP testing equipment. Test BOPE to 250 psi low pressure and 3,360 psi high pressure. Each test was held for 5 minutes. AOGCC witness of test was waived by Lou Grimaldi. Test was witnessed by the Doyon Toolpusher and BP WSL. Test #1- Choke Valves 1, 12, 13, 14, Annular Preventer on 4" test joint, Upper IBOP, and Kill Une HCR Test #2- Choke Valves 9, 11, Lower IBOP, Manual Kill, Upper Pipe Rams on 4" test joint Printed: 3/1212007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/18/2007 18:30 - 22:00 3.50 KILL DECaMP Test #3- Choke Valves 5, 8, and 10 22:00 - 00:00 2.00 KILL OECOMP BOP Flange between mud cross and lower pipe rams leaking. RID Testing equipment and blow down choke and kill lines. Suck out BOP stack. Break BOP stack between mud cross and lower pipe rams. 2/19/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Break BOP flanges between mud cross and lower pipe rams. 00:30 - 03:00 2.50 CLEAN P DECaMP Inspect API ring groove for damage. No damage. Replace BX-160 API seal ring and N/U BOPE. 03:00 - 05:30 2.50 CLEAN P DECOMP Test BOPE to 250 psi low pressure and 3,360 psi high pressure. Each test was held for 5 minutes. AOGCC witnessed of test was waived by Lou Grimaldi. Test was witnessed by Doyon Toolpusher and BP WSL. Test #4- Choke Valves 4, 6, 7, Top Pipe Rams, and Dart Valve Test #5- Choke Valve 2, and TIW Valve Test #6- Choke HCR Test #7- Manual Choke 05:30 - 09:00 3.50 CLEAN P DECaMP Inspect and change out manual choke valve on BOP mud cross. 09:00 - 09:30 0.50 CLEAN P OECOMP Test BOPE to 250 psi low pressure and 3,360 psi high pressure Each test was held for 5 minutes. Test was witnessed by Doyon Toolpusher and BP WSL. Test #7- Choke Valve 3 and Blind Rams Test #8- Bottom Pipe Rams w/5-1/2" test joint Test #9- Top Pipe Rams w/5-1/2" test joint, Manual Choke Accumulator Test- 3000 psi starting pressure, 1,700 psi after actuation. First 200 psi in 19 seconds, full pressure in 1minute and 35 seconds. 5 Nitrogen bottles at 2,200 psi. 09:30 - 10:00 0.50 CLEAN P DECaMP RID BOPE tesing equipment and blow down choke and kill lines. 10:00 - 11 :30 1.50 CLEAN P DECaMP RlU OSM and DSM lubricator. Pull TWC valve and RID lubricator and OSM. 11 :30 - 12:00 0.50 CLEAN P OECOMP RlU rig floor to pull 5-1/2" tubing. 12:00 - 12:30 0.50 CLEAN P OECOMP M/U landing joint with xIo to hanger. Screw into hanger and back out lock down screws. Pull hanger free at 130,000 Ibs. Pull tubing and hanger to rig floor with 210,000 Ibs. 12:30 - 13:00 0.50 CLEAN P OECOMP RID and terminate control lines from hanger and rig control line pulling unit. Back out landing joint from hanger and lay down hanger. 13:00 - 15:00 2.00 CLEAN P OECOMP RlU circulating lines and equipment. Circulate bottoms up at 15 BPM with 1720 psi. Bottoms up returns were clean. Blow down and RID circulating equipment. 15:00 - 17:30 2.50 CLEAN P DECOMP POOH with 5 1/2" NSCC tubing and recover GLM, SSSV, and control line. Recovered all 20 clamp and 4 stainless steel band used for control line in well. POOH from 10,537'. Major corrosion with holes noted in tubing starting at joint 122. 17:30 - 19:00 1.50 CLEAN N DECaMP Worn spot noticed in cable for pipe shed door operating system. Change out cable. 19:00 - 00:00 5.00 CLEAN P DECaMP Continue POOH with 51/2" NSCC tubing to 4612'. Corrosion noted in tubing joint 122 out of the hole. 2/20/2007 00:00 - 04:00 4.00 CLEAN P OECOMP POOH with 5-1/2" NSCC tubing from 4612'. Recovered second GLM. Corrosion noted in tubing from joint #122. Nose seal on pin ends corroded thought out string. Tubing cut was Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/2012007 00:00 - 04:00 4.00 CLEAN P OECOMP clean and slightly beveled. Cut was 1.5' down on first pup joint below 2nd GLM at 10,537'. 04:00 - 05:00 1.00 CLEAN P OECOMP RID 5-1/2" tubing running equipment and clean rig floor. 05:00 - 07:00 2.00 CLEAN P OECOMP Pick up BHA #1 consisting of Tri State Spear, xlo, circulating sub, bumper sub, jars, xlo, 9- 6.24" drill collars, xlo, and accelerator jars. Total Length = 330ft. P/U 3 Jts of OP. 07:00 - 08:30 1.50 WHSUR P DECOMP M/U RTTS and Set at 33' below KB. Test RTTS to 1000 psi from above and below to 1000 psi for 10 mins. 08:30 - 10:00 1.50 WHSUR P DECOMP Blow Down Top Drive and Kill Line. Drain Stack. Pull 4-1/2" x 7" VBR's and install 2-718" x 5" VBR's in Lower Rams. 10:00 - 10:30 0.50 WHSUR P DECOMP RlU 4" Test Joint and Test Lower Rams to 250 psi Low Pressure I 3360 psi High Pressure for 5 mins each. Charted results. 10:30 - 11 :30 1.00 WHSUR P OECOMP UD Test Joint and M/U 9-5/8" Pack Off Pulling Tool. RIH and J into Mandrel Pack Off. Pull free wI 15,000 Ibs. UO Pack Off and Pulling Tool. 11 :30 - 12:30 1.00 WHSUR P OECOMP NID BOP's to inspect Spools and LOS. 12:30 - 16:00 3.50 WHSUR P OECOMP Clean I Inspect Tubing & Csg Spools, LDS. Replace two LOS in Tubing Spool. M/U New 9-5/8" Pack Off to Running Tool and Install. Test Pack Off to 3360 psi for 30 mins. 16:00 - 18:00 2.00 WHSUR P OECOMP N/U BOP Stack and Flow Riser. 18:00 - 19:00 1.00 WHSUR P OECOMP RlU BOP Testing Equipment and test Spool breaks to 250 Low Pressure I 3360 High Pressure test. Chart results. RID BOP Testing Equipment and blow down lines. 19:00 - 19:30 0.50 WHSUR P OECOMP Install Wear Ring with 9.24" 10. P/U RTTS Running Tool and RIH. Sting into RTTS and release PKR. POOH and UD RTTS. 19:30 - 00:00 4.50 CLEAN P DECOMP P/U 4" HT·38 Drill Pipe and RIH with Tri-State Spear on BHA #1 to 4800'. 2/21/2007 00:00 - 04:30 4.50 CLEAN P OECOMP P/U 4" HT-38 Drill Pipe and RIH with Tri-State Spear on BHA #1 04:30 - 05:30 1.00 CLEAN P DECOMP Establish fishing parameters of 195,000 Ibs up weight, 170,000 Ibs down weight, 180,000 Ibs rotating weight with 20 RPM and 4,000 ftIlbs torque. Pump rate at 10 BPM with 3550 psi. Engage tubing stub at 10,509'. Stack out at 10,514' and latch to K-Anchor. Rotate out anchor with 16 right hand turns. 05:30 . 07:00 1 .50 CLEAN P OECOMP CBU at 10 BPM and 3510 psi. 07:00 - 12:00 5.00 CLEAN P DECOMP POOH. Stand Back 4" OP and 6-1/4" DC's. 12:00 - 12:30 0.50 CLEAN P DECOMP UO Spear and K-Anchor Fish Assembly. Length of Fish = 32.69 ft. 12:30 - 13:00 0.50 CLEAN P OECOMP Clean and Clear Rig Floor. 13:00 - 14:00 1.00 CLEAN P OECOMP MlU BHA #2. PRT and 8.5" Packer Mill, 3 Boot Baskets, Circ Sub, Bumper Sub, Jars, 9 - 6-1/4" DC's, Accelerator. Total Length of BHA = 346.53 ft. 14:00 - 17:30 3.50 CLEAN P DECOMP RIH wI BHA #2 on 4" OP from Derrick. 17:30 - 21 :30 4.00 CLEAN P OECOMP Establish Milling Parameters; Up Wt = 200,000 Ibs, Down Wt = 175,000 Ibs, Rotating Wt = 180,000 at 90 RPM and 6500 ft-Ibs Torque. Pumping at 8 BPM with 1700 psi. RIH and tag PKR at 10,538'. Mill through PKR with 10,000 Ibs WOB, 90 RPM with 8500 ft-Ibs Torque. Pump at 11 BPM with 2700 psi. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Establish PKR was free. Drop Dart to open Circulating Sub. Circ Sub did not shear, unable to circulate. Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/21/2007 21 :30 - 00:00 2.50 CLEAN P DECOMP POOH 10 stands from 10,538'. Attempt to open Circulating Sub. Circ Sub would not shear. Continue POOH wet to 8,106'. 2/22/2007 00:00 - 04:00 4.00 CLEAN P DECOMP POOH wet from 8,106' to 346'. Stand back HT -38 Drill Pipe in Derrick. 04:00 - 07:30 3.50 CLEAN P DECOMP POOH with BHA #2 UO Jars and Subs. Stand back Drill Collars in Derrick. Attempt to lay down BHA. Fish hung up in Wellhead. Work Pipe, able to get top of packer through rotary table. 07:30 - 12:00 4.50 CLEAN P DECaMP Work fish up hole. Circulate through fish, rotate and recipricate as well. Work fish fully clear of wellhead into BOP stack. Found that bottom section of fish was held by junk in the hole from milling on packer. Recovered all of fish which consisted of remains of Baker SAB packer, 5-1/2" tbg, Otis X Nipple & XN Nipple, and TIW LG-6 Seal Nipple. 12:00 - 15:00 3.00 CLEAN P OECOMP Break Out Fishing Tools from fish. Break Out 5-1/2" BUTT XO from Circ Head. Pull and Inspect Wear Ring, RIH with same. Move Pipe in Derrick to make room for E-line Sheaves. 15:00 - 17:00 2.00 CLEAN P DECaMP Rig Up to Pressure Test Casing. Pressure Test Casing to 3360 psi. Pressure Test Leaking Off. Bleed Off and Check all Valves and Connections. Pressure Test again, still leaking off. Leak off 2345 psi in 25 mins. 17:00 - 17:30 0.50 CLEAN P DECaMP RO Pressure Test Equipment. Wait on Orders. 17:30 - 19:00 1.50 EVAL P OECOMP PJSM. RlU SWS E-Line Tools and Equipment. 19:00 - 00:00 5.00 EV AL P DECaMP RIH with 8.52" Gauge Ring and Junk Basket on E-Line Gauge Ring stacked out 4530'. POOH and empty Junk Basket, no recovery. Rerun Gauge Ring and Junk Basket. Stack out at 4700'. POOH and install 8.37" Gauge Ring and Junk Basket. RIH 2/23/2007 00:00 - 02:30 2.50 EVAL P OECOMP Continue RIH with 8.37" Gauge Ring and Junk Basket. Tagged the Top of the 7" Liner at 10,645' WLM. POOH with Gauge Ring and Junk Basket. No recovery in Junk Basket. RID Gauge Ring and Junk Basket. 02:30 - 04:30 2.00 EVAL P OECOMP RlU SWS USIT Logging Tool and RIH to 10,650' WLM. 04:30 - 11 :00 6.50 EVAL P OECOMP Log up with USIT Logging Tool in Low Resolution/Corrosion Mode at 50 FPH. Log from 10,645' to surface. 11 :00 - 12:00 1.00 EVAL P OECOMP Pull to surface and RID USIT Logging Tool. RID E-Line and Equipment. 12:00 - 15:00 3.00 CLEAN P DECaMP M/U BHA#3. 6"Bit, 7"Casing Scraper, (3)- 4-3/4"Boot Baskets, Bumper Sub, Jars, (9)- 4-3/4" DC's, 6 Stands 4" OP, 9-5/8" Casing Scraper, (3)- 7" Boot Baskets, (9)- 6-1/4" DC's. Total Length = 1199.09 ft. 15:00 - 20:30 5.50 CLEAN P DECaMP RIH to 10,584' with BHA#3 and 4" DP from Derrick. 20:30 - 21 :30 1.00 CLEAN P DECaMP Slip and Cut 83' of 1-1/4" Drill Line. 21 :30 - 00:00 2.50 CLEAN P DECaMP Continue RIH to Top of Liner at 10,636'. Stack out on Junk. M/U to Top Drive. Establish Parameters, Up Wt = 209,000 Ibs, Down Wt = 174,000 Ibs, Rotating Wt = 190,000 Ibs at 30 RPM and 5000 ft-Ibs Torque. Pump at 5 BPM with 650 psi. Work and Wash Bit and Scraper through Top of Liner. Continue washing to 10,872' at 70 RPM and 5000-15,000 ft-Ibs Torque. Pump Pressure = 1300 psi at 7 BPM. 2/24/2007 00:00 - 02:00 2.00 CLEAN P DECaMP Establish Parameters at Top of Liner, Up Wt = 209,000 Ibs, Down Wt = 174,000 Ibs, Rotating Wt = 190,000 Ibs at 30 RPM and 5000 ft-Ibs Torque. Pump Pressure = 650 psi at 5 BPM. Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/2412007 00:00 - 02:00 2.00 CLEAN P DECOMP Continue washing from 10,872' to 11,449' at 70 RPM and 5000-15,000 ft-Ibs Torque. Pump Pressure = 1300 psi at 7 BPM. Worked Scrapers thought Production Packer set depths of 11,400' and 10,500'. 02:00 - 03:30 1.50 CLEAN P OECOMP Rotate and Reciprocate Drill Pipe at 11,449'. Pump 40 bbl High Viscosity Sweep at 12 BPM with 3100 psi. Up Wt = 207,000 Ibs, Down Wt = 187,000 Ibs, Rotating Wt = 195,000 Ibs at 10 RPM with 2,000 ft-Ibs Torque 03:30 - 07:30 4.00 CLEAN P OECOMP POOH with BHA #3 to 1,199'. Stand back 4" HT-38 Drill Pipe in Derrick. 07:30 - 11 :30 4.00 CLEAN P DECOMP B/O and UO 9-5/8" Casing Scraper, 6-1/4" Drill Collars, 7" Boot Subs. Clean out Boot Subs. Boot Subs recovered 4-1/2 Gallons worth of Schmoo, Scale, and pieces of milled PKR. Stand back 6 stands of 4" HT-38 Drill Pipe in Derrick. Stand back 3 stands of 4-3/4" Drill Collars. B/O (3) 4-3/4" Boot Subs and 6" Bit. Recovered 2-1/2 gallons of the same. 11 :30 - 12:30 1.00 CLEAN P DECaMP Clear and Clean Rig Floor. 12:30 - 13:00 0.50 CLEAN P DECaMP Pick up BHA #4,6" x 3-1/2" PKR Mill, (3) 4-3/4" Boot Subs, XlO, Bumber Sub, Jars, Circ Sub, XlO, and (9) 4-3/4" Drill Collars. Total Length of BHA #4 = 315.02' 13:00 - 17:00 4.00 CLEAN P DECaMP RIH with BHA #4 on 4" Drill Pipe from Derrick and 16 Singles to tag Top Of PKR at 11,722'. 17:00 - 17:30 0.50 CLEAN P DECaMP Establish Milling Parameters, Up Wt = 200,000 Ibs, Down Wt = 178,000 Ibs, Rotating Wt = 191,000 Ibs at 60 RPM with 5500 ft-Ibs Torque, Pump Pressure = 1640 psi at 8 BPM. 17:30 - 20:30 3.00 CLEAN N OECOMP Circulate and pump High Viscosity Sweeps with SafeSurf at 12 BPM with 3320 psi while waiting on Vac Truck with Brine. Veco Dispatch "Forgot" about additional Brine Water ordered. 20:30 - 22:00 1.50 CLEAN P OECOMP Milled 7" PKR at 80 RPM with 5000-15,000 ft-Ibs Torque, Pump at 10 BPM with 2200 psi, WOB = 5000-15,000 Ibs. Push PKR to 11,745'. After milling PKR loose, fluid losses at 5-9 BPM while pumping at 10 BPM. 22:00 - 00:00 2.00 CLEAN P OECOMP Shut down pumps and monitor well. Well flowing. CBU at 9.5 BPM with 2010 psi and monitor losses at 26 BPH while pumping. Bottoms up returns looked clean with no contamination. Shut down pumps and monitor well. Well flowing at 4.5 BPM and decreased to 1 BPM. Circulate at 9.5 BPM with 2050 psi and monitor losses at 1 BPM while circuating. 2/25/2007 00:00 - 03:00 3.00 CLEAN P OECOMP Continue to circulate at 9 BPM with 2100 psi. Slow pump rate to 5 BPM with 540 psi, 8 BPH gain. Increase pump rate to 6.5 BPM with 1040 psi, 10 BPH losses. Weight up Brine from 8.5 to 8.7 ppg. Shut down pumps and monitor well losses at 8 BPH Static. 03:00 - 05:00 2.00 CLEAN P OECOMP P/U Singles and RIH pushing PKR and Tail Pipe Assembly to 11,786'. End of Tail Pipe at 11798'. 05:00 - 06:30 1.50 CLEAN P DECOMP CBU at 7.5 BPM with 1390 psi. Avg Losses at 26 BPH while circulating. 06:30 - 10:30 4.00 CLEAN P OECOMP POOH and Stand Back DP. 8-10 BPH Lose Rate while POOH. 10:30 - 12:00 1.50 CLEAN P DECaMP Stand Back 4-3/4" DC's. U 0 4-3/4" Boot Baskets and 6" Packer Mill. Collected - 1.5 gals of metal cuttings from Boot Baskets. P/U ITCO Spear BHA. 3-1/2" ITCO Spear wI 4.010" Grapple. Bumper Sub, Jars, Circ Sub, (9) 4-3/4" DC's. Total Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/25/2007 10:30 - 12:00 1.50 CLEAN P OECOMP Length = 304.07' 12:00 - 17:00 5.00 CLEAN P DECOMP RIH with 4" Drill Pipe to top of packer at 11,786'. 17:00 - 17:30 0.50 CLEAN P DECOMP MIU Top Drive and Establish Parameters. Up Wt = 210,000 Ibs; Down Wt = 175,000 Ibs; Pump Pressure = 210 psi at 2.5 BPM and 2150 psi at 8.0 BPM. Pump High Viscosity Sweep and chase out the end of drill string. 17:30 - 18:00 0.50 CLEAN P DECOMP S/O and Stack 15,000 Ibs on packer at 11,814'. Shut down pumps and PUH with one stand. No over pull observed. S/O again, tag packer in same spot. S/O 15,000 Ibs again, packer drops and chase down hole to 11,830'. PUH and observe 5,000 Ibs over pull. Continue to PUH and observe up to 15,000 Ibs overpull. 18:00 - 19:00 1.00 CLEAN P OECOMP Pull out of 7" Liner to 10,554'. Fluid Loses - 3.5 BPH. 19:00 - 20:30 1.50 CLEAN P DECOMP Drop Dart and open Circulating Sub. Circulate Bottoms Up at 12 BPM with 3120 psi. Fluid Loses = 6 BPH while circulating. 20:30 - 00:00 3.50 CLEAN P OECOMP Continue POOH standing back 4" HT-38 Drill Pipe in Derrick from 10,554' to 1552'. 2/26/2007 00:00 - 00:30 0.50 CLEAN P OECOMP Continue POOH standing back 4" HT-38 Drill Pipe in Derrick from 1552' to 304'. 00:30 - 01 :30 1.00 CLEAN P OECOMP POOH and UO BHA #5. Stand back 3 Stands of Collars. Recover 7" PKR and Tail Pipe Assembly. Total Length of Recovery = 12.41'. 01 :30 - 02:30 1.00 CLEAN P OECOMP Pull Wear Ring and set Test Plug. RlU to test BOPE. 02:30 - 06:00 3.50 CLEAN P OECOMP Test BOPE to 250 psi Low Pressure and 3,360 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of the Test was Waived by John Crisp. Test Was Witnessed by Doyon Toolpusher and BP WSL. Test #1- Choke Valves 1, 12, 13, 14, Upper IBOP, HCR Kill, and Annular Preventer wI 4" Test Joint Test #2- Choke Valves 9, 11, Lower IBOP, Manual Kill, Upper Pipe Rams wI 4" Test Joint Test #3- Choke Valves 5,8, 10, and TIW Valve Test #4- Choke Valves 4, 6, 7, and Dart Valve Test #5- Choke Valve 2 Test #6- HCR Choke Test #7- Manual Choke Test #8- Lower Pipe Rams wI 4" Test Joint Test #9- Choke Valve 3 and Blind Rams Test #10- Upper Pipe Rams wI 5-1/2" Test Joint Accumulator Test- 2950 psi Starting Pressure, 1,650 psi After Actuation. First 200 psi in 16 seconds. Full Pressure in 1 Minute and 35 seconds. 5 Nitorgen Bottles at 2,100 psi. 06:00 - 06:30 0.50 CLEAN P OECOMP RID from BOP Testing Equipment. 06:30 - 08:00 1.50 CLEAN P OECOMP MlU BHA #6; 6" Bit, (3) 4-3/4" Boot Subs, Bit Sub, Bumper Sub, Jars, Circ Sub, XlO, and (9) Drill Collars. Ran Drill Collars from Derrick. Total BHA Length = 312.77' 08:00 - 12:30 4.50 CLEAN P OECOMP RIH with 4" HT-38 Drill Pipe from Derrick from 312' to 11,809'. 12:30 - 14:30 2.00 CLEAN P OECOMP Establish Initial Parameters. Up Wt = 217,000 Ibs; Down Wt = 171,000 Ibs; Rotating Wt = 195,000 Ibs; RPM = 60 wI 5500 ft-Ibs torque; Pump Pressure = 1450 psi at 8.5 BPM. Tag Up and Push Junk Down Hole from 11827'. Continue in Hole, Tag Top of Fill at 11,915'. Wash Through Fill and Tag Cement at Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 2/26/2007 12:30 - 14:30 14:30 - 17:00 17:00 - 17:30 17:30 - 19:30 19:30 - 23:00 2/27/2007 23:00 - 00:00 00:00 - 05:30 05:30 - 06:00 06:00 - 07:30 07:30 - 08:00 08:00 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 19:30 19:30 - 21 :30 21 :30 - 00:00 2/28/2007 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 2.00 CLEAN P OECOMP 11,925', Drill Cement to 11,975'. Continue to Clean Out Hole to PBTO. Found PBTO at 12,112'. Pump Four 40 bbl sweeps while cleaning out hole. OECOMP Circulate around 40 bbl High Viscosity Sweep at 12.5 BPM with 2900 psi. Large amounts of black schmoo, carbolite, metal shavings, rubber, and cement seen as sweeps came back. Continue to circulate until hole cleaned up. OECOMP Flow Check Well. Monitor Hole for 30 mins. Fluid level slowly falling. OECOMP B/O and BID Top Drive. POOH and UD 4" HT-38 Drill Pipe to 10,626'. OECOMP R/U and Reverse Circulate 20 bbl High Viscosity Sweep at 7 BPM with 450 psi. Loss Rate = 47 BPH while Circulating. Back Pumps Down to 4.5 bpm and 320 psi. Loss Rate slowed to -10 BPH. Initially saw a good amount of schmoo come back but quickly cleaned up. Did not see any cement cuttings or pieces of milled packer come around. Shut down and monitor well. OECOMP B/O and POOH. UO 4" HT-38 Drill Pipe from 10,626. OECOMP Continue POOH laying down 4" HT-38 Drill Pipe. OECOMP POOH standing back 4" HT-38 Drill Pipe in Derrick. OECOMP UO 4-3/4" DC's and BHA. Found Schmoo and a little Packer debris in Boot Baskets, -1.5 gals. OECOMP P/U Joint of OP and Flushing Tool and Flush Out Stack. OECOMP M/U 9-5/8" 47# HES RBP. RIH wI OP from Derrick and set top of RBP at 2611'. POOH and Stand Back 2 Stands of OP. OECOMP Pressure Test RBP to 1000 psi for 10 mins on Chart. OECOMP P/U HES 9-5/8" RTTS Storm Packer. M/U to Drill String and RIH to 93'. Set RTTS. OECOMP POOH and Stand Back 1 stand of OP. Pressure Test RTTS Storm Packer to 1000 psi for 10 mins on chart. OECOMP Blow down lines and hoses. Drain Stack. P/U a Joint of OP and RIH and Pull Wear Ring. M/U Test Plug and RIH and Set Test PLug. C/O Lower Set of Pipe Rams to 4-1/2" x 7". OECOMP Test Rams to 250 psi low and 3360 psi high with 4-1/2" and 5-1/2" Test Joints. Chart Tests. OECOMP Pull Test Plug and Reset Wear Ring. RIH with 4" OP and Engage RTTS. Confirm No Pressure Under Plug. POOH and UO RTTS Storm Packer. OECOMP RIH wI OP from Derrick. Engage RBP at 2611 '. P/U and Release. Circ Btms Up at 8.0 bpm and 250 psi. Took - 3 bbls to fill hole. OECOMP PJSM on Pulling and Laydown DP. Review Hand Safety Bulletin. OECOMP POOH and Lay Down OP And RBP. OECOMP NID Flow Riser, and N/U Shooting Flange. OECOMP PJSM R/U Slickline Equipment, Lubricator Extension, Pump in Sub, WL BOP, Pack ott. OECOMP Continue to Rig Up SWL, Lubricator Extension, Pump in Sub, WL BOPs, Packott. Tested Surface Equipment to 2,500 psi, for 5 Minutes. OECOMP RIH wI 8.5", Gauge Ring And Junk Basket, to 10,611' WLM. OECOMP Tagged Liner Top. POOH to 10,605', Wire Parted (P/U Weight 2.50 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 5.50 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 2.00 CLEAN P 2.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 0.50 CLEAN P Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 600#, Over Pull 436#) Approx 10,466' of .125 Diameter Wire and 21.58' of WL Tools Left in Hole. Pulled 145' Wire From Well Bore and UO Lubricator. Monitor Well, Waiting on Slick Line Fishing Tools, and wait on another S-Line Unit. Spot Up Second S-Line Unit. Rig Up Line and Sheeves. Make Up Wire Brush Locator and Wire Grab Tool String. Attempt to PT Lubricator to 2500 psi. Found small leak. Tighten Down Flange. Attempt to PT Lubricator again, still had leak. Drain Down Lubricator. B/O Lubricator and Stand Back. Nipple Down Shooting Flange and Replace API Ring. NIU Shooting Flange and Lubricator. PT to 2500 psi - Good Test. RIH wI Wire Grab and Locator. Found Wire at 450 ft. PIU on Line and POOH with fish. Spool Up to bottom of Lubricator wI 1000 Ibs Up Wt. PJSM wI Slick Line and Rig Crew on Stripping Wire. Strip Out Fished Wire, Clamp off, UD Fishing Tool String. Continue to Strip Wire till enough is through the top sheeve and to the unit. Make Up to Fished Wire to Slick Line Spool POOH wI Slickline and 8.5" Gauge Ring Junk Basket. No Damage to Slickline Tools, No Recovery in Junk Basket. RID SWS Tools and Equipment. NIO Shooting Flange and Nipple Up Flow Riser. Pull Wear Ring, MlU 7" Landing jt Assembly, RlU to Run 4.5",12.6, L-80, TC-II, By 5.5",17#, L-80, TC-II Completion Service Top Drive, Pipe Skate, and Oraworks. Run 4.5" Completion, 1 WLEG, 1-XN Nipple,1-Joint tubing, 1-X Nipple, 7" x 4.5" Packer, 1- X Nipple, 22 jts 4.5",12.6#, L-80, TC-II Tubing, 1-4.5" x 5.5" XO jt, 2- GLMs, 1- HRQ SVLN and 254 Jts of 5.5",17#, L-80, TC-II Tubing. Average MlU Torque for 4.5" = 3,850 ft-Ibs. Average MIU Torque for 5.5" = 4,350 ft-Ibs. Using Jet Lube Seal Guard Pipe Dope on all Connections. PIU and RlU HES Control Line Reels and Equipment, Test Lines to 5,000 psi for 10 mins. Continue to RIH wfTubing and Control Line From 1,519' to Surface, MIU Tubing Hanger and Landing jt. Terminate and Test Control Lines to 5,000 psi For 10 minutes, Land Hanger Up Weight=21 0,000#, Down Weight= 180,000#. RILOS. Test Circulating Lines to 4,000 psi. Reverse Circulate 290 bbls of 8.8 ppg Brine. Followed by 490 bbls of Corrosion Inhibited 8.8 ppg Brine. Pumped at 3 bpm and 160 psi. Lost approx. 65 bbls during RUNCMP Rig Up to Test Tubing and Annulus. Pressure Up on Tbg to 4200 psi wI Annulus shut in for 10 mins. Bleed Down Pressure to 3500 psi and hold Pressure Test for 30 mins. Bleed Down Tbg Pressure to 1500 psi. OPRB RUNCMP Swap Over to Annulus. Pressure Test Annulus to 3360 psi. Pressure Drops off to 2000 psi in 5 mins. Leak off to some where. Bump pressure back up to 3360 psi and try again. Same results. Double Check all valve line ups. Pump 2/28/2007 02:30 - 03:00 0.50 CLEAN P OECOMP 03:00 - 08:00 5.00 CLEAN N OFAL OECOMP 08:00 - 12:00 4.00 CLEAN N OFAL DECOMP 12:00 - 13:00 1.00 CLEAN N OFAL OECOMP 13:00 - 14:30 1.50 CLEAN N OFAL OECOMP 14:30 - 15:00 0.50 CLEAN N OFAL OECOMP 15:00 - 15:30 0.50 CLEAN N OFAL OECOMP 15:30 - 19:30 4.00 CLEAN N OFAL DECOMP 19:30 - 21 :30 2.00 CLEAN N OFAL DECOMP 21 :30 - 22:30 1.00 CLEAN P DECaMP 22:30 - 00:00 1.50 CLEAN P DECaMP 3/1/2007 00:00 - 01 :00 1.00 RUNCO RUNCMP 01 :00 - 01 :30 0.50 RUNCMP 01 :30 - 17:30 16.00 RUNCMP 17:30 - 19:30 2.00 RUNCO RUNCMP 19:30 - 00:00 4.50 RUNCO RUNCMP 3/2/2007 00:00 - 01 :00 1.00 RUNCO RUNCMP 01 :00 - 06:00 5.00 RUNCO P RUNCMP 06:00 - 07:00 1.00 RUNCO P 07:00 - 11 :30 4.50 RUNCO Printed: 3/1212007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: pressure holding steady above annulus pressure not bleeding back through pump. Pressure Up a third time to 3360 psi. Same Results. Bleed Down Annulus to zero psi and pressure up tbg again to 4200 psi and Held Pressure for 3.5 hrs While Discussing Options With Engineers in Anchorage. DPRB RUNCMP Bleed Off Pressure Tubing, PT Tubing to 4,500 psi for 15 minutes, Bleed off Pressure to 2,000 psi and PT IA to 3,360 psi, Still Bleeding Off Rapidly, RID Circulating Lines, BOLDS, MIU Top Drive to Landing jt, Pulled 310,000# Up Weight, SIO to 277,000# Pressure Test Tubing to 4,500 psi, and Held for 15 minutes. BID Lines. . Land Hanger, RILOS, BID Top Drive, RlU to Test IA. Pressure Up on Tubing to 2,000 psi, Attempt to Test IA to 3,360 psi Pressure StiI Bleeding Down. BID RID Lines. BOLDS, Pull Hanger Loose at 200,000# Up Weight, Pulled to 310,000# Up Weight. Pressure Tested Tubing to 4,500 psi. Good Test. Land Hanger RILOS, RlU to Test IA. Pressure Up on Tubing to 2,000 psi, Attempt to Pressure Test IA to 3,360 psi, Still Leaking. Bleed Down Tubing Pressure, Pressure Up Annulus to 2,500 psi, Shear OCR Valve. Pumped through OCR in Both Directions at 2.5 bpm With 110 psi. B/O and Lay Down Landing jt. Set TWC, M/U Landing jt and Pressure Test TWC to 3,360 psi from Above and 1,000 psi From Below. BID All Circulating Lines. Slip and Cut 93' Drilling Line. Pull Landing jt, Pull Flow Riser, Drain Stack, Install 4.5" x 7" Ram Blocks in Upper Rams, and 3.5" x 6" Ram Blocks in Lower Rams. N/O BOPs to Terminate Control Lines. Terminating Control Lines at Tubing Hanger N/U BOPs Repair Koomey Manifold Regulator. Test BOPE 4.5" x 7"VBR to 4.5" and 5.5"Test Jt, 3.5"x 6" with 4" and 5.5" Test Jt. To 250 psi Low Test and 3,360 psi Hi Test. P/U Lubricator Ext and OSM Lubricator. Pull TWC and UO Same. N/O Flow Riser and N/U Shooting Flange. Rig Up Slick Line Lub Ext, Pump In Sub, & BOP's. String Wire and Hang Sheaves. M/U 5-1/2" GR to Tool String and M/U Lubricator to BOP's. Pressure Test to 2500 psi. RIH to 1523' WLM and Pull HRQ Dummy Sleeve. POOH wI Dummy Sleeve and UO Tools. RID Slick Line Lubricator, BOP's, Lub Ext, and Sheaves. Service Roughneck, Blocks, and Top Drive. RlU E-line Sheaves, Lub Ext, Pump In Sub, and BOP's. Safety Meeting with Rig Crew and E-Line Crew discuss hazards associated with running chemical cutters and with general wire line work. Continue to RlU E-line Equipment. String Wire and Tie Head. Re position lower sheave. Pressure Test Lubricator, BOP's, and Shooting Flange to 2500 psi. 11 :30 - 15:00 15:00 - 15:30 0.50 DPRB RUNCMP 15:30 - 16:30 1.00 OPRB RUNCMP 16:30 - 17:00 0.50 DPRB RUNCMP 17:00 - 17:30 0.50 OPRB RUNCMP 17:30 - 18:00 0.50 OPRB RUNCMP 18:00 - 18:30 0.50 DPRB RUNCMP 18:30 - 21 :00 OPRB RUNCMP 21 :00 - 22:00 1.00 RUNCO OPRB RUNCMP 22:00 - 23:00 1.00 BOPSU OPRB RUNCMP 23:00 - 00:00 1.00 OPRB RUNCMP 3/3/2007 00:00 - 01:00 1.00 OPRB RUNCMP 01 :00 - 03:00 2.00 OPRB RUNCMP 03:00 - 04:00 1.00 OPRB RUNCMP 04:00 - 06:00 2.00 OPRB RUNCMP 06:00 - 07:00 1.00 OPRB RUNCMP 07:00 - 08:00 1.00 OPRB RUNCMP 08:00 - 10:30 2.50 N OPRB OECOMP 10:30 - 11 :00 0.50 PULL N OPRB OECOMP 11 :00 - 11 :30 0.50 PULL N OPRB OECOMP 11:30 -12:30 1.00 PULL N OPRB OECOMP 12:30 - 13:00 0.50 PULL N OPRB OECOMP 13:00 - 15:30 2.50 PULL N OPRB DECOMP 15:30 - 16:00 0.50 PULL N OPRB OECOMP 16:00 - 19:00 3.00 PULL N OPRB DECOMP Printed: 3/1212007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 31312007 19:00 - 20:00 1.00 PULL N OPRB OECOMP Break Down Sinker Bars and RlU Chemical Cutter. 20:00 - 23:00 3.00 PULL N OPRB OECOMP RIH with Chemical Cutter and Collar Locator, Shot Chemical Cutter in 7"x 4.5" Packer, at 11,398.5'. 23:00 - 00:00 1.00 PULL N OPRB OECOMP POOH with E-Line Chem Cutter. 3/4/2007 00:00 - 01 :00 1.00 PULL N OPRB OECOMP Continue to POOH wI Chemical Cutter Assembly. Upon Inspection of Firing Head Noticed That Only 1/3 of Cutting Head Shot. 01 :00 - 02:30 1.50 PULL N OPRB OECOMP Installed New Cutting Head Assembly. 02:30 - 05:30 3.00 PULL N OPRB OECOMP RIH wI Chemical Cutter to 7" x 4.5" Packer to Re-cut Mandrel. Positioned Cutter at 11,398.6'. Cutter Failed to Fire. 05:30 - 06:30 1.00 PULL N OPRB OECOMP POOH with Unfired Chemical Cutter. 06:30 - 07:00 0.50 PULL N OPRB DECOMP Safety Meeting with Crew and SLB E-Line on pulling and laying down an unfired chemical cutter. 07:00 - 08:00 1.00 PULL N OPRB OECOMP Lay Down Chem Cutter 08:00 - 09:30 1.50 PULL N DPRB OECOMP Rig Up New 3-5/8" Chem Cutter. Install New CCL and SAFE Firing Head. System Failure in Last Chemical Cutter was either in CCL or SAFE Firing Head. Will be investigated further. 09:30 - 11 :00 1.50 PULL N OPRB OECOMP RIH wI 3-5/8" Chem Cutter #3 to top 7" Packer and Log Up 11385'. Correlate CCL Log to 10' Pup Joints and X Nipple. Chem Cut in the Middle of the First Full 4-1/2" Tbg Joint at 11332'. 11 :00 - 12:30 1.50 PULL N OPRB OECOMP POOH wI Chem Cutter and UD Same. Visual Inspection of cutter showed positive indication of proper function of cutter. 12:30 - 14:30 2.00 PULL N OPRB OECOMP MIU 3-5/8" Chern Cutter #4 and RIH to 9-5/8" x 4-1/2" Packer at 10507' 14:30 - 15:00 0.50 PULL N OPRB OECOMP Tie in Chemical Cutter and Log into Place. Cut Packer 2.2' up from bottom connection as per Baker schematics. 15:00 - 16:30 1.50 PULL N OPRB OECOMP POOH wI Chem Cutter #4 and UO Same. Chemical Cutter Showed good indication of proper cut. Chemical Cutter #1-#3 used two 48" cylinders of chemical. Chemical Cutter #4 used one 80" cylinder of chemical. 16:30 - 18:00 1.50 PULL N OPRB DECOMP Stand Back E-Line Lubricator & BOP's. N/O Shooting Flange and N/U Flow Riser. 18:00 - 19:30 1.50 PULL N OPRB OECOMP PIU 7" TC " Landing Joint. RIH and Screw into Tbg Hanger. BOLDS. Pull Hanger, Unseated at 190,000# Up Weight, Pulled Free at 225,000# Up Weight. Pulled Hanger Up 7' to Ensure it Was Free. Slacked off and Reseated Hanger. 19:30 - 20:00 0.50 PULL N DPRB OECOMP Rig Down SLB E-Line from Rig Floor. 20:00 - 21 :00 1.00 BOPSU N OPRB OECOMP Set and Test TWC to 1,000 psi From Below, and 3,360 psi From Above, to Test BOPE. 21 :00 - 00:00 3.00 BOPSU N OPRB OECOMP Test BOPE to 250 psi Low Pressure and 3,360 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Scheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, Choke HCR, Kill HCR, TIW Valve, Test #2- Manual Choke, Manual Kill, Dart Valve, Test #3- Lower Pipe Rams to 4" Test Joint. 3/5/2007 00:00 - 02:00 2.00 BOPSU N OPRB OECOMP Test BOPE to 250 psi Low Pressure and 3,360 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Chuck Scheve. Test was Witnessed by the Doyon Toolpusher and BP WSL. PonIed: 3/12/2007 11:58:36AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOVON DRILLING INC. DOVON16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: Accumulater Test- 2,900 psi Starting Pressure, 1,700 psi After Actuation, First 200 psi in 21 seconds, Full Pressure in 1 Minute 30 Seconds. RID Test Equipment and BID Choke and Kill Lines P/U OSM Lubricator Extendsion and Pull TWC, RID OSM. P/U Landing Joint and Engage Hanger, BOLDS. RlU Control Line Spooling Unit, UO Hanger Observed Well. PJSM with Rig Crew, Cameron, HES Control Line Spooler. Pull Out of Hole and UO 5.5",17#, L-80 TC-II Completion using single joint elevators and compensator to lay down. Tbg connections cleaned and inspected in the pipe shed. UO Joints # 274-#237. Loosing - 2 bbls I hr while POOH. OPRB OECOMP Clean and Inspect 5-1/2" Tbg Connecitons in Pipe Shed. Re-dope connections with Jet Lube Seal Guard and Thread Protects reapplied. OPRB OECOMP Pull Out of Hole and Lay Down to Joint # 236- #212. 5.5", 17#, L-80 TC-II Completion using single joint elevators and compensator to lay down. Tbg connections cleaned and inspected in the pipe shed. OPRB OECOMP Well appears to be out of balance. Make Full Circulation. Equilize all pits and well to 8.7 ppg brine. Pump at 7.1 bpm at 630 psi. Loosing - .7 bpm while Circulating. Shut Down Pump and Flow Check. No Flow. Pump Down 10 bbl @ 9.5 ppg. Pull Out of Hole with Jts # 211- # 196. Well appears to be out of balance still. Make Full Circulation. Pump at 7.2 bpm at 600 psi. Loosing - .7bpm while circulating at this rate. Shut Down Pump and Flow Check. No Flow. Pull Out of Hole with Joints #195 to #114, ( GLM #1 wI OCR Shear Valve and GLM #2). Continue to POOH w/5.5", 17#, L-80, TC-II Completion From Jt #113 to 5.5" XO, 1-X-Nipple, and 9 5/8"x 4.5" Packer plus 21 and 1/2 joints of 4-1/2" tbg. Cut Joint Length = 20.29'. Cut in good shape. Clean and Clear Rig Floor. RID Stabing Board, Tongs, and Long Bails. Prep to Pick Up 4-3/4" OCs, RTTS, and 4" OP. RlU Short Bails. Move Tbg Jewelry off OP in Pipe Shed. Install Wear Ring P/U HES 9-5/8" RTTS, 12 - 4.75" DC's and 4" OP to 10,159'. Lost 1 7/8" drift for drill pipe. Attempt tlFind drift, Reverse Circulated 1.5 Times Drill Pipe Volume. Searched Pipe Shed, Rig Floor, Pipe Skate, Top Drive, and Derrick Girts, NO RECOVERY. OPRB DECaMP PJSM to Discuss Situation and Re-Focus Crew on Job at 02:00 - 02:30 0.50 BOPSU N OPRB OECOMP 02:30 - 03:30 1.00 BOPSU N OPRB DECOMP 03:30 - 04:00 0.50 PULL N DPRB DECaMP 04:00 - 05:00 1.00 PULL N OPRB OECOMP 05:00 - 05:30 0.50 PULL N OPRB DECaMP 05:30 - 08:30 3.00 PULL N OPRB OECOMP 08:30 - 10:00 1.50 PULL N 10:00 - 12:00 2.00 PULL N 12:00 - 13:30 1 .50 PULL N 13:30 - 14:30 1.00 PULL N OPRB DECaMP 14:30 - 16:30 2.00 PULL N OPRB OECOMP 16:30 - 00:00 7.50 PULL N DPRB OECOMP 3/6/2007 00:00 - 07:00 7.00 PULL N OPRB DECOMP 07:00 - 08:00 1.00 PULL N OPRB OECOMP 08:00 - 09:00 1.00 PULL N OPRB DECaMP 09:00 - 21 :00 12.00 PULL N OPRB OECOMP 21 :00 - 23:00 2.00 PULL N OPRB DECOMP 23:00 - 00:00 1.00 PULL N Continue to Test BOPE Test #4- Upper Rams to 5.5" Test Joint, Choke Valves #1,12, 13,14, and Upper IBOP. Test #5- Choke Valves # 9, 11, and Lower IBOP Test #6- Choke Valves # 5,8, 10. Test #7- Choke Valves # 4,6, 7. Test #8- Choke Valve # 2. Test #9- Lower Rams to 5.5" Test Joint. Test #10- Annular Preventer to 5.5" Test Joint. Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 316/2007 23:00 - 00:00 1.00 PULL N OPRB OECOMP Hand. Continue to P/U Drill Pipe from Pipe Shed 1x1 to 10,408'. 3/7/2007 00:00 - 03:30 3.50 CLEAN N OPRB OECOMP Obtain Parameter; 197,000# Up Weight, 158,000# Down Weight, Set RTTS Center of Element Depth at 10,408', Attempt to Pressure Test to 3,360 psi on 9 5/8" CSG. Pressure Bled Off 1,800 psi In 8 Minutes, Pressured Up to 3,360 psi Blocking in Secondary Set of Valves, Pressure Bled Off 2,000 psi In 10 Minutes. Pulled One Stand, and Re-Tested at 10,311' Pressured Up To 3,360 psi Pressure Bled Off 2,000 psi in 10 minutes. 03:30 - 04:30 1.00 CLEAN N OECOMP POOH f/10,311' to 7,000'. 04:30 - 05:30 1.00 CLEAN N OECOMP Obtain Parameters; 145,000 # Up Weight, 130,000 Down Weight, Set RTTS Center of Element at 6,994', Attempt to Pressure Test 9 5/8" CSG to 3,360 psi. Pressured up Two Times Bled Off 2,100 psi On Both Tests. Open Choke and Kill Side to Atmoshpere to Verify No Leaks at Surface. Release RTTS. 05:30 - 06:30 1.00 CLEAN N OECOMP POOH to 4,000' 06:30 - 08:00 1.50 CLEAN N OECOMP Obtain Parameters; 100,000# Up Weight, 100,000 Down Weight, Set RTTS Center of Element at 4,016'. Pressure Tested 9 5/8" CSG to 3,360 psi for 30 Charted Minutes Good Test. Released RTTS. 08:00 - 08:30 0.50 CLEAN N OECOMP RIH f/4,000' to 4,304', Obtain Parameter; 107,000# Up Weight, 105,000# Down Weight, Set RTTS, Pressured Tested 95/8" CSG to 3,360 for 15 minutes. Good Test, Released RTTS, 08:30 - 09:30 1.00 CLEAN N OECOMP RIH tl4,784' Obtain Parameters; 112,000# Up Weight, 110,000# Down Weight, Set RTTS and Pressure Tested 9 5/8" CSG to 3,360# for 15 Minutes, Good Test. Released RTTS. 09:30 - 12:00 2.50 CLEAN N OECOMP RIH f/4,784' to 5,262' Obtain Parameters; 117,000# Up Weight, and 113,000# Down Weight, Set RTTS and Pressure Tested 9 5/8" CSG to 3,360 psi for 20 minutes, Bled off 2,700 psi In 10 minutes, Released RTTS BID TID, Choke and Kill Lines. 12:00 - 12:30 0.50 CLEAN N OECOMP Mix and Pump Dry Job at 10 bpm with 900 psi. 12:30 - 13:30 1.00 CLEAN N DECOMP POOH. 13:30 - 14:00 0.50 CLEAN N OECOMP Lay Down RTTS Assembly. 14:00 - 15:00 1.00 CLEAN N DECOMP PIU MlU Over Shot Assemby Dressed to Retrieve 4.5" Tubing Stub, RIH with 4 3/4" Drill Collars. 15:00 - 18:30 3.50 CLEAN N DECOMP RIH to 10,477', Pick Up Drill Pipe From Pipe Shed to 11,300'. 18:30 - 20:00 1.50 CLEAN N DECOMP Circulate Bottoms Up at 12 bpm with 3,160 psi. Up Weight=210,000#, Down Weight=165,000#. 20:00 - 21 :00 1.00 FISH N DECOMP Tagged Fish at 11,330' Latch Fish Pull 10,000# Over Pull to Confirm Latch, Pull Up to 10,309' Dropped Ball and Rod to Open Pump Out Sub, Pump Out Sub Sheared at 2,350 psi, Monitor Well Pump Dry Job and Blow Down. 21 :00 - 00:00 3.00 FISH N DECOMP POOH with Fish Out of 7" Liner, Monitor Well Continue to POOH to 3,298'. 3/8/2007 00:00 - 01 :00 1.00 CLEAN N OPRB DECOMP Continue to POOH f/3,298' to 413'. 01 :00 - 03:30 2.50 CLEAN N OPRB DECOMP Stand Back 4 Stands of 4 3/4" Drill Collars, UO Overshot BHA, 1-Cut Jt =20.67', 1-X Nipple, 1-jt 4.5" TC-II Tubing, 7"x4.5" Packer, 1-X Nipple, 1-XN Nipple and Tail Pipe Assembly. 03:30 - 04:00 0.50 CLEAN N OPRB OECOMP Clear and Clean Rig Floor. 04:00 - 07:30 3.50 CLEAN N OPRB OECOMP PIU and RIH w/RBP to 4,110' Set and Test From 4,110 to Surface. Up Weight=102,000#, Down Weight=102,000#. Printed: 3/1212007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: 318/2007 07:30 - 10:00 2.50 CLEAN N OPRB OECOMP Continue to RIH f/4,013' to 110,400'. 10:00 - 10:30 0.50 CLEAN N OPRB DECaMP Set Top of RBP at 10,400' and Release From RBP. 10:30 - 14:00 3.50 CLEAN N OPRB DECaMP POOH f/10,400' to Drill Collars. 14:00 - 15:00 1.00 CLEAN N OPRB DECaMP Stand back Drill Collars, UO RBP Running Tool. M/U RTTS. 15:00 - 17:30 2.50 CLEAN N OPRB DECaMP RIH V5,300'. To Set RTTS. 17:30 - 18:30 1.00 CLEAN N OPRB DECOMP Set RTTS at 5,296', R/U to Test Casing f/5,296' to 10,400' 18:30 - 20:30 2.00 CLEAN N OPRB DECaMP Released RTTS, POOH f/5,296' to Drill Collars. 20:30 - 21 :30 1.00 CLEAN N OPRB OECOMP Stand Back Drill Collars, UO RTTS Assembly, MIU RBP Retrieval Tool. 21 :30 - 22:00 0.50 CLEAN N OPRB DECaMP Service Top Drive, Blocks and Iron Ruff Neck. 22:00 - 00:00 2.00 CLEAN N OPRB OECOMP RIH to Retrieve RBP at 10,400', RIH to 6,344'. 3/9/2007 00:00 - 01 :00 1.00 CLEAN N OPRB DECaMP Continue to RIH f/6,344' to 9,973'. 01 :00 - 02:00 1.00 CLEAN N OPRB OECOMP Slip and Cut Drilling Line, Cut 93'. cIa ODS Link Tilt Ram. 02:00 - 02:30 0.50 CLEAN N OPRB DECaMP Continue to RIH to 10,400' Obtain Parameters; Up Weight=202,000#, Down Weight=152,OOO#, Retrieved RBP Set 10,000# Down Weight to Latch, and Pulled 20,000# Over pull to Release. 02:30 - 06:30 4.00 CLEAN N OPRB OECOMP POOH Laying Down Drill Pipe. 06:30 - 07:00 0.50 CLEAN N OPRB OECOMP RIH w/9 Stands of Drill Pipe From Derrick. 07:00 - 13:30 6.50 CLEAN N OPRB OECOMP Continue to POOH and UD Drill Pipe. Pull Wear Ring. 13:30 - 15:00 1.50 RUNCO OPRB RUNCMP PJSM R/U to Run 4.5",12.6#, L-80, TC-II x 5.5",17#, L-80, TC-II Completion. 15:00 - 16:00 1.00 RUNCO OPRB RUNCMP Waiting On Orders Concerning Completion Equipment. 16:00 - 19:30 3.50 RUNCO OPRB RUNCMP PJSM PIU and Run 4.5", 12.6#, L-80, TC-II Tail Pipe and Packer Assembly Consisting of: WLEG X-Nipple #1, One jt of 4.5" Tubing, X-Nipple #2, 7"x 4.5" S-3 Packer, X-Nipple #3, Sliding Sleeve Assembly, 17 jts of 4.5" Tubing, 4.5"x 5.5" Tubing XO jt. 4.5" Pipe Was Made up Using Torque Turn and Compensator and Jet Lube Seal Guard Thread Compound on All Connections. Tubing Was Cleaned and Inspected Prior to Picking it Up. Average MIU on 4.5" Was 3,850 ft-Ibs Torque. 19:30 - 00:00 4.50 RUNCO OPRB RUNCMP PIU and Run 5.5", 17#, L-80, TC-II Completion. Using Torque Turn and Compensator and Jet Lube Seal Guard Thread Compound on All Connections. Tubing Was Cleaned and Inspected Prior to Picking it Up. Average M/U on 5.5" Was 4,350 ft-Ibs Torque. 3/10/2007 00:00 - 14:30 14.50 RUNCO OPRB RUNCMP Continue to PIU and Run 5.5",17#, L-80, TC-II Completion. Using Torque Turn and Compensator and Jet Lube Seal Guard Thread Compound on All Connections. Tubing Was Cleaned and Inspected Prior to Picking it Up. Average MIU on 5.5" Was 4,350 ft-Ibs Torque. Tubing was Drifted as it Was Run. 14:30 - 16:00 1.50 RUNCO OPRB RUNCMP M/U Tubing Hanger, Tie In Control Line VHanger, Test V5,OOO psi f/15 minutes. 16:00 - 16:30 0.50 RUNCO OPRB RUNCMP Land Tubing Hanger, Up Weight=212,000#, Down Weight=180,000#, 16:30 - 17:00 0.50 RUNCO OPRB RUNCMP R/U to Reverse Circulate Through Landing jt. 17:00 - 18:00 1.00 RUNCO OPRB RUNCMP Wait On Truck to Displace Well to Completion Fluid. 18:00 - 23:00 5.00 RUNCO OPRB RUNCMP PJSM with Rig Crews, Mud Engineer, and Truck Drivers To Discuss Displacement. Reversed in 275 bbls of 8.8 ppg, 140 deg, Brine. Followed by 480 bbls of 8.8 ppg, 140 deg, Corrosion Inhibited Brine. Pumped at 3 bpm w/100 psi. 23:00 - 23:30 0.50 RUNCO OPRB RUNCMP PJSM Little Red and Rig Crew, Tested Lines to 4,000 psi. Pumped 25 bbls of Diesel Freeze Protect Down lA, at 3 bpm Printed: 3/12/2007 11 :58:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-54/0-12 2-54/0-12 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 2/17/2007 Rig Release: Rig Number: Spud Date: 11/2/1991 End: w/150 psi. RlU and U-Tube the Well Bore. 3/11/2007 Drop Ball and Rod, Pumped it Down to Fill Tubing, Pressured up to 3,500 psi to Set 7"x 4.5" Baker S-3 Packer for 30 Charted Minutes, Good Test. 01 :00 - 02:00 RUNCMP Bleed Tubing to 1500 psi, Pressure Tested 9 5/8"x 4.5" Annulus to 3,350 for 30 Charted Minutes, Good Test. Inital Test Took 9 bbls to Obtain Test Pressure. 02:00 - 02:30 0.50 RUNCMP Bleed Pressure to Zero, Returns approx 7.5 bbls. Checked Pressure Testing Equipment. 02:30 - 04:30 RUNCMP Re-Test Annulus to 3,350 psi, 6 bbls to Obtain Test Pressure, Held for 15 Minutes, Good Test. Bleed Off Pressure, 6 bbls Returns. One Hour Time Change. 04:30 - 05:00 RUNCMP Little Red Suck Back Diesel From All Lines, Blow Down Squeeze Manifold and Surface Lines. 05:00 - 06:00 1.00 RUNCMP Set and Test TWC, and Test to 1,000 psi From Above. 06:00 - 06:30 0.50 RUNCMP UD Landing Joint. 06:30 - 08:00 1.50 RUNCMP Set TWC, RlU to Test From Above to 1,000 psi, Below Blind Rams. Tested Good to 1,000 psi for 10 minutes. 08:00 - 09:30 RUNCMP N/D BOPE 09:30 - 10:00 RUNCMP Terminate SSSV Control Lines at Tubing Hanger. 10:00 - 10:30 RUNCMP Install Adapter Flange and Production Tree on Tubing Spool. 10:30 - 11 :30 RUNCMP Reconfigure Tree as Per Endicott Well Tender. Remove Tree, Remove Adapter Flange from Tree. 11 :30 - 12:00 RUNCMP N/U Adapter Flange, Halliburton Re-Terminate Control Lines. 12:00 - 13:30 RUNCMP Lay Production Tree Down to N/U Adapter Flange and Test to 5,000 psi for 30 Minutes. 13:30 - 15:30 2.00 RUNCMP Install and N/U Tree, Install Blind Flange. 15:30 - 16:30 1.00 RUNCMP RlU Test Equipment and Test Tree to 5,000 psi for 30 Minutes. 16:30 - 17:30 1.00 RUNCMP RlU DSM Lubricator and Pulled TWC RID DSM. 17:30 - 18:00 0.50 RUNCMP DSM Installed BPV. 18:00 - 19:00 1.00 RUNCMP N/O Double Annulus Valve, Secure Well, Move Cuttings Tank. Rig Released at 1900 hrs on 3/11/2007. Printed: 3/1212007 11 :58:36 AM • ~1 ~T ~1 -~t~~~ ~~7~~~a ~T ~+®J®S~/1~~~ii®1`~ ~®llli1~7~~®ii • SARAH PALIAI, GOIJERFIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 1.003 Mr. Steve Rossberg, Well Program ~~~ J~~ ~, ~ ~~~~ ' ~,`~ BP Exploration (Alaska) Inc. ~. P.O. Box 196612 ~, Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 1.003 (Well DIU 2-54/Q12) Dear Mr. Rossberg: Pursuant to BPXA's request dated February 22, 2007 AOGCC hereby cancels Administrative Approval AIO 1.003, which allows water injection in Endicott well 2- 54/Q 12 within the Duck Island Unit ("DIU"). This well exhibited tubing by inner annulus pressure communication, and BPXA did not at the time propose repairing. the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has shut in the well awaiting a rig work over to replace the tubing. Consequently, Administrative Approval AIO 1.003 no longer applies to operation of this well. Instead, injection in well DIU 2-54/Q12 will be governed by provisions of the underlying Area Injection Order No. 1. DONE at Anchorage, Alaska and dated March 13, 2007. - - "- and Gas Conservation Commission Chairman • • .f I~~ s ~ ~ + I t i r . ! ~ r ~ FRANK H. MlJRKOWSKI, GOVERNOR ~it47ialf. OI~ ~ Vr0a7 /1 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA`1`I011T CODII-IISSIOI~T / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ` FAX (907)276-7542 November 18, 2004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. ~ ~ ~ , 900 East Benson 81vd. P.O. Box 196612 Anchorage, AK 99519-6612 RE: End 2-54/Q 12 (PTD 191-122) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 001.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on End 2-54/Q12. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, End 2-54/Q12 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not com- promise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in End 2-54/Q12 is condi- tioned upon the following; 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform a yearly MIT-OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform a CMIT-T x IA every two years to 1.2 times the maximum anticipated well pressure; 5. BPXA shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and • Mr. Steve Rossberg November 18, 2004 Page 2 of 2 • 6. after well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31..05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may nat appeal a Commission decision to Superior Court unless rehearing has been requested. 'ncerely Daniel T. Seamount Jr. Commissioner Re: FW: END 2-54 RWO Dave, et aI, De ja vu! The plan should provide the isolation desired. Once the cement has set, a pressure test of the annulus above the cement will need to be performed and when the well is placed in service a witnessed MIT of that annulus will need to be conducted. Given the shallow planned cement height the remainder of the integrity verification will be by MITT. The necessary operations on the well following cementing should be examined to determine if there would be an opportunity to conduct the MITT sooner rather than later. Call or message with any questions. Tom Maunder, PE AOGCC Reem, David C wrote, On 3/812007 2:43 PM: Tom, as mentioned in Paul's e-mail below, BP is proposing moving forward with END2-54 as described in the attached well bore schematic, We propose cementing in the completion string to a -4000'md set at -11 cement will plan forward and we wí!l add the approval to existing regarding this Thanks. From: Chan, Paul (PRA) Sent: Wednesday, March 07, 2007 2:38 PM To: 'Thomas Maunder' Subject: END 2-54 RWO scANIEDMAR 081ÞCU Tom We have a confirmed 9-5/8" casing leak (isolated between give you a call and discuss our options for this well. 4784' - 5262' MD). We would like to «END2-54 Proposed Cement Pkr.pdf» Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564- 52 54 (907) 440-0183 (cell) (907) 564-5510 (fax) 1 of 1 3/8/2007 3 :29 PM TREE = WHLHEAD= ACTUATOR = RT, ELEV = BF. ELEV = KOP= IvTax Angle = Datum MD = Datum TVD = 6" CrN 13-5/8" MCEVOY AXELSON 55,10' 16,20' END 2-54 Proposed Completion Rev 1 43 @ 6300' 11568' 10000' SS . I -1500 H5-1/2" HES HRQ SSSV LANDING NIP, ID - 4.562 ~ 2736' GAS LIFT MANDRELS I -4000 I :¡. ST MD TVD DEV TYÆ VLV LATCH PORT DATE ~ L .J. 2 )( 1 ~ K (4784' - 5262' MD I~ ~ S S S H 9483' ~ ~ ~V 92" I 10661' H5-1/2" x 4-1/2" CROSSOVER I S ~ I :> I :> :> '" NR I 10656' ~ )( Ä .9581 l .6811 10926' ~ I · -14-1/2" X NIP, ID=3,813" I ---f -11400 -i7" x 4-1/2" BAKER PREMIER PKR I I · -i4-1/2" X NIP, 10 = 3813" I MMARY I · -i4-1/2" XN NIP, ID = 3,725" I ?? H4-1/2" WLEG, ID = I 26° @ 11788' l or historical perf data ~ 11 648' HRA TAG I Opn/Sqz DATE J C 12/10/91 C 12/10/91 S 04/06/96 ] I PBTD I 12134' I 6.184" I 12175' " I 113-3/8" CSG, 68#, NT80CYHE, ID = 12.4 I ESTIMA TED TOP OF CEMENT 19-5/8" CASING LEA 19-5/8" CSG, 47#, NT80S XO TO NT95H 15-1/2"TBG, 17#, L-80, ,Q232bpf, ID=4.8 I TOP OF 7" L 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3 19-5/8" CSG, 47#, NT95HS, NSCC, ID = 8 PERFORA TION SU REF LOG: ? ANGLEAT TOP PERF: Note: Refer to Production DB f SIZE SPF INTERVAL 4-1/2" 5 11788-11881 4-1/2" 5 11894 - 11940 4-1/2" 5 11952 - 12062 17" LNR, 29#, L-BO,BTRS-TKC, ,0371 bpf, ID= DATE 01/20/92 05/05/96 06/13/00 12/31/05 11/23/06 12!11ì06 REV BY JLH JTP MAS EZUPJC CJNiPJC ?! PJC COMMENTS DATE COMPLETION SANDBACKI GMT TBG PA TCH REVISEDWAVIERSFTY NOTE SET XX A..UG @ 10650 CONVERT NE'N FORW, T ENDICOlT UNIT WELL: 2-54/ Q-12 PERMIT No: 1911220 API No: 50-029-22218-00 SEC. 36, T12N,R16~ 2328'FEL,2078'FNL REV BY COMMENTS BP exploration (Alaska) END2-54 (PTD #1911220) Internal Waiver Cancellation - Trouble Well . . All, An internal waiver was issued for a TxlA communication on well END2-54 (PTD #1911220) on /' 12/31/05. The well is scheduled for a RWO to replace the tubing and restore integrity. A letter to cancel the Administrative Approval has been sent to the AOGCC. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, }f.nna (])u6e, œ 'E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 sCANÞlE1D \JI~R 2 'i 2007 .........' I of I 3/5/2007 8:47 AM Re: Endicott 2-54 RWO . . Paul, Restoring integrity to the wellbore is a goal ofthe workover. The straddle will isolate a communication problem that you did not know existed when you went into the wellbore. I will add this message and diagram to the well information. Good luck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC \~ \ - \d..--d- Chan, Paul (PRA) wrote, On 2/23/2007 2:05 PM: Tom We have isolated a leak at the 7" liner top at 10656' MD. We have pressure tested the 9-5/8" casing from surface to 10569' MD and pressure tested the 7" casing from 10661' to 11737' MD. We would like permission from the AOGCC to straddle and isolate the liner lap leak with a 9-5/8" packer at -1051 A' MD and a 7" packer at -11400' MD. Enclosed is a revised well bore schematic on the planned completion. «2-54 Proposed WBS Rev 1.pdf» Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564- 52 54 (907) 440-0183 (cell) (907) 564-5510 (fax) ~~ FEB .2 (; 20D7 , . .~,. -~ '. "'~""" "~'''·_,A."..."" ,....'I,....~:.i...~.,~.....:.:., 1 of 1 2/23/20072: 10 PM TREE = WELLHEAD = ACTUATOR = RT. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 6" CrN 13-5/8" MCEVOY AXELSON 55.10' 16.20' END -54 Proposed Co.letion Rev 1 43 @ 6300' 11568' 10000' SS 113-3/8" CSG, 68#, NT80CYHE, 10 = 12.4 19-5/8" CSG, 47#, NT80S XO TO NT95HS 15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" 1 TOP OF 7" LNR I 14-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958'1 9-5/8" CSG, 47#, NT95HS, NSCC, ID = 8.6811 ÆRFORA TION SUMMARY REF LOG: 111 ANGLEATTOPÆRF: 26° @ 11788' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 11788 - 11881 C 12/10/91 4-1/2" 5 11894 - 11940 C 12/10/91 4-1/2" 5 11952 - 12062 S 04/06/96 IPBTD I 17" LNR, 29#, L-BO,BTRS-TKC, .0371 bpf, ID = 6.184" I DATE 01/20/92 05/05/96 06/13/00 12/31105 11/23/06 12!11i06 REV BY JLH JTP MAS EZUPJC CJNlPJC ?i PJC 12134' 12175' COMMENTS DATE COMPLETION SANDBACKI GMT TBG PA TCH REVISED WA VIER SFlY NOTE SET XX PLUG @ 10650 CONVERT NEW FOR!'v1A T REV BY . -i5-1/2" HES HRQ SSSV LANDING NIP, ID = 4.562" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 COMMENTS H5-1!2" x 4-1/2" CROSSOVER -i4-1/2" X NIP, ID = 3.813" -19-5/8" X 4-1/2" BA KER PREMIER PKR -14-1/2" X NIP, ID = 3,813" -17" x 4-1/2" BAKER PREMIER PKR -14-1/2" X NIP, 10 = 3.813" I -;4-1/2" XN NIP, 10 = 3.725" I -14-1/2" WLEG, ID = -1RA TAG I ENDICOTT UNIT WELL: 2-54 1 Q-12 PERMIT No: 1911220 API No: 50-029-22218-00 SEC. 36, T12N, R16E, 2328' FEL, 2078' FNL BP Exploration (Alaska) . . SARAH PALIN, GOVERNOR AI"/A~1iA OILA5D GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK .-. ,··'c··- Re: Endicott Field, Endicott Oil Pool, END 2-54/ Q-12 Sundry Number: 307-058 .-tSJ fEB 1 42007 \'\~ \0\ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4: 30 PM on the 23rd day following the date of this letter, or the next wor~ng 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. K. Chai DATED this I~ day of February, 2007 Encl. Z((;3 /7 ~ Qr1 2-n-01 ~ RECEIVED I I .~ STATEOFÂ~S~ ..r- ALAS~OILAND GAS CONSERVATION COMMBoN d-h:>- FEB ,0 8 2007 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25.280 . 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development D Exploratory 191-122 / 3. Address: o Stratigraphic 181 serv~e,~J 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22218-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: END 2-54/Q-12 I Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): / 11. Field / Pool(s): / ADL 034633 j 55.10 Endicott Field / Endicott Pool 1.Z.; < '. ....« < <i ............ ....... VVt:.LL '; 'y< . <)2 « ~i<;Y' ::.;:<:<ii«<.\i)<;« Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12175 10602 11941 10389 None None Casino Lenoth Size MD TVD Burst Collaose Structural Conductor 131' 30" 131' 131' Surface 2735' 13-318" 2735' 2734 5020 2270 Intermediate 9483' 9-5/8" 9483' 8292' 6870 4760 Production 1443' 9-5/8" 9483' - 10926' 8292' -9498' 8150 5080 Liner 1519' 7" 10656' - 12175' 9269' - 10602' 8160 7020 Liner 15' 4-1/2" 11737' - 11752' 10205' - 10219' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11788' - 11940' 10251' - 10388' 5-1/2", 17# L-80 10661 ' Packers and SSSV Type: 9-5/8" x 5-1/2" SAB Packer, 7" Otis WD Packer, 5-1/2" I Packers and SSSV MD (ft): 10569', 11737', 3709' HES DWP Retr Straddle Assy, 5-1/2" HES HRQ SSSV -3730',1560' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal o BOP Sketch D Exploratory o Development 181 Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commenèina Ooerations: February 16, 2007 DOil o Gas o Plugged o Abandoned 17. Verbal Approval: Date: DWAG DGINJ 181 WINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Pnnted Nam]Jë: Reem Title Drilling Engineer Prepared By Name/Number: 2. 18/0 7 Signature f(.f..(. ~ Phone 564-5743 Date Sondra Stewman, 564-4750 Commission Use Onlv I Sundry Number: ~?.£)7. ' ,... .;<) .. -, K.J T"'I Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~echanicallntegrity Test o Location Clearance Other: Subsequent Form Required: ~()'1 OJ H'4MMISSIONER/ REtDMS 8Ft 1 :i 2007 APPROVED BY Date JI-I g --ð l' Aooroved Bv: THE COMMISSION Form 10-403 Revised 06/2006 V - '" ----- Submit In Duplicate ORIGINA . . - bp Endicott 2-54/Q-12 Rig Workover Scope of Work: Pull 5-%" completion, mill and retrieve 9-5/8" Baker SAB and Otis WD packer, run USIT log, cleanout to PBTD, run 5-%" x 4-%" L-80 completion. MASP: 3300 psi Well Type: Injector Estimated Start Date: February 16, 2007 Pre-ri S 1 rep work: Set XX plug in reducer nipple at 10650' MD. Pull HES DWP patch at 3709' MD. Drift tubing for caliper survey and tubing cut to 10640' MD. Caliper tubing from surface to 10640' MD. If patch was fished, pull XX plug and reducer bushing at 10650' MD. Set XX or XN plug in tailpipe of 7" WD packer to secure well. Pressure test plug to 3360 psi. If PT fails, set reducer bushing and lu in XN ni Ie at 10650'. Jet cut 5-%" tubing @ 10537' MD (near the top of the second 10' pup above Baker SAB packer at 10569' MD. De ths referenced to Tubin Summa dated 12/06/1991. Circulate well with -8.5 ppg NaCI brine and cap with 200' diesel thru the cut. Estimated reservoir ressure is 4300 si at 10000' TVDss. MITOA to 2000 si. Bleed WHPs to 0 si. Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Set a BPV in the tubin han er. Remove the wellhouse & flow line. Level the ad as needed for the ri . E F 3 o 4 o 5 o 6 Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3360 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-1/2" tubing string to the cut. 3. Mill and retrieve the Baker SAB packer. 4. Run US IT log from surface to 10656' MD. 5. Mill and retrieve the Otis WD packer. 6. Cleanout to PBTD of 12137' MD. 7. Run 5-1/2" x 4-%" L-80 completion with Baker S-3 packer. Set packer at -11400' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3360 psi. Freeze protect to 200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. Note: Doyon 16 will be using a 4 preventer "drilling" stack configuration (reference PBU Well V-212, PTD: 205150) TREE = WELLHEAD = ACTUATOR = RT. ELBI = BF. ELBI = KOP= Max Angle = Datum MD = Datum TVD = 6" CrN 13-5/8" MCEVOY AXELSON 55.10' 16.20' . 43 @ 6300' 11568' 10000' SS 113-3/8" CSG, 68#, NT80, CYHE, ID = ? 19-5/8" CSG, 47#, NT80S XO TO NT95HS I Minimum ID = 2.313" @ 10650' 2-7/8" NIP REDUCER 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I I TOP OF 7" LNR I 19-5/8" CSG, 47#, NT95HS, NSCC, /D = ?? I ÆRFORA TION SUMMARY REF LOG: ??? ANGLEATTOPÆRF: 26° @ 11788' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 11788-11881 C 12/10/91 4-1/2" 5 11894-11940 C 12/10/91 4-1/2" 5 11952 - 12062 S 04/06/96 IPBTD I 17" LNR, 29#, L-80,BTRS-TKC, .0371 bpf, ID=6.184" I DATE 01/20/92 05/05/96 06/13/00 12/31/05 11/23/06 12/11/06 RBI BY JLH JTP MAS EZLlPJC CJNlPJC ?/ PJC COMMENTS DATE COM PLETION SANDBACKI CMT TBG PATCH RBI IS ED WAVIER SFTY NOTE SET XX PLUG@ 10650 CONVERT NEVV FORMAT END2-54 S~OTES:***RAPID TxlA COMM. OPERATING LIMI AX lAP = 2500 PSI, MAX OAP = 1000 PSI (1 31/05 WAlVER)*** . -15-1/2" HES HRQ SSSV LANDING NIP, ID = 4.562" I 3709' 5-1/2" HES DWP RETR STRADDLE ASSY w /1" GLM, ID = 2.340" (06/13/06) GAS LIFT MANDRB...5 DBI TYÆ VLV LATCH PORT DATE 20 7 DMY RA 0 12/06/91 32 ? DMY RA 0 12/06/91 ST MD TVD 2 3913 3889 1 10527 9158 10560' -15-1/2" OTIS X NIP, ID = 4.562" I 10569' -19-5/8" X 5-1/2" SAB A<R, ID = 4.75" -15-1/2" OTIS X NIP, ID = 4.562" I -15-1/2" OTIS XN NIP, ID = 4.455'1 -15-1/2" X 2-718" XN NIPwl NIP REDUCER, ID= 2.313" -12-7/8" HES XX TTP (11/23/06) I -15-1/2" TIW LG-6 SEAL NIP, 10 = 4.892" I 11941' ELM -iSA NDBACK1 CEMENT (04/06/96) I RBI BY ENDICOTT UNIT WELL: 2-54/ Q-12 ÆRMITNo: 1911220 API No: 50-029-22218-00 SEC. 36, T12N, R16E, 2328' FEL, 2078' FNL COMMENTS BP Exploration (Alas ka) T~= WELLHEAD = ACTUATOR = RT. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 6" CWV 13-5/8" MCEVOY AXELSON 55.10' 16.20' EN~-54 Proposed Co.pletion 43 @ 6300' 11568' 10000' SS 113-3/8" CSG, 68#, NT80CYHE, ID = 12.4 9-5/8" CSG, 47#, NT80S XO TO NT95HS I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I 10661' 1 TOP OF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958'1 19-5/8" CSG, 47#, NT95HS, NSCC, ID = 8.681 I ÆRFORA TION SUMMARY REF LOG: ??? ANGLEATTOPÆRF: 26° @ 11788' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 5 11788-11881 C 12/10/91 4-1/2" 5 11894-11940 C 12/10/91 4-1/2" 5 11952 - 12062 S 04/06/96 IPBTD I 17" LNR, 29#, L-80,BTRS-TKC, .0371 bpf, ID=6.184" I DATE 01/20/92 05/05/96 06/13/00 12/31/05 11/23106 12111106 REV BY JLH JTP MAS EZLlPJC CJNlPJC ?I PJC 12134' 12175' COMMENTS DA TE COM PLETION SANDBACKI CMT TBG PATCH REV ISED WA VIER SFTY NOTE SET XX PLUG @ 10650 CONVERT NEW FORMAT REV BY . -45-1/2" HES HRQ SSSV LANDING NIP, ID = 4.562" I ST MD 2 1 GAS LIFT MANDRELS TVD DEV TYÆ VLV LATCH PORT DATE -l5-1/2" x 4-1/2" CROSSOVER COMMENTS ENDICOTT UNfT WELL: 2-54/ Q-12 ÆRMfTNo: 1911220 API No: 50-029-22218-00 SEC. 36, T12N, R16E, 2328' FEL, 2078' FNL BP Exploration (Alaska) RE: Endicott 2-54/Q-12 . . Tom The reason for the 3360 psi test pressure is that the casing head has a 3M bottom flange that has been up rated to a maximum of 3360 psi. The BOPE test pressure is then limited to the 3360 psi limit. I have also included a sketch of the 3 ram stack currently on the rig. Thanks Paul Chan Workover Engineer BP Alaska/Wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) -----Original Message----- From: Thomas Maunder lto:tom maunder@admin.state.ak. Sent: Monday, February 12/ 2007 9:04 AM To: Chan, Paul (PRA) Cc: Reem, David C Subject: Endicott 2-54/Q-12 Paul and Dave, I am reviewing the sundry to workover the subject well. A couple of questions. 1. On the BOP test pressure, why the specificity of 3360 psi? Based on prior work/operations, it would seem that the appropriate pressure would be 3500 psi. 2. Having a 4 preventer stack is appropriate according to the BOP regulations (MASP > 3000 psi). Could you please send a copy of the stack drawing so I can attach it to the application? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: Doyon 16 BOP Sketch.pdf Doyon 16 BOP Sketch.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 2/12/2007 10:45 AM IVd ~Z:OT NOK LOOZIZT/ZO ZOOIZOO ~ .I.(S GROUND :t.EVEL rrAJITlllO WW> .' .~ .:JR 'i,l~ \'ì.~¡¡, L3-~j~ ILl. 2.'- 10.:>/ HYD1ULOK 13",f85M ROTARY TABLE . . [JJb - Lf-/8/S -Fð DOYON RI~ 16 I BOP STACK MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 124.(;1- {7k)l~ P.l. Supervisor r DATE: Wednesday, December 13,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-54/Q12 DUCK IS UNIT MPI2-54/Q12 \ ~ \ ' l 'ð-'Y FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.l. Suprv~ Z.- IZ/,<5(Db Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 2-54/QI2 API Well Number 50-029-22218-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS061208063831 Permit Number: 191-122-0 Inspection Date: 12/7/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. !Type Inj:' ¡ ---~~ I ,-- Well 2-54/Q12 N TVD 9195 , IA 460 3360 3320 I 3310 ! ! i iTypeTest I SPT I , , - ! P.T. 1911220 Test psi 2298.75 OA 0 0 i 0 0 -,-, -- _ ~_w_______ . ---. -- ~ Interval REQVAR P/F P I Tubing i 520 3420 3400 3390 j ---~--- Notes CMITTxlA / 1\-30 (.003 ret-'lii-"'S Z-(Z C;l{ÿ\ TX:!;A. ·'jC~~îw..~~r- \ -1-,¡H'! 'I!~. ~, C} , .\i' lr Wednesday, December 13, 2006 Page I of 1 . . State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg 7c2¿¡;Ú(' f/!2Cf!a(p P.I. Supervisor \,\ L DATE: Monday, November 27,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-54/QI2 DUCK IS UNIT MPI 2-54/Q12 FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL \~ ~ s;'~ :::t" éJ..-~¡-CP-I'Y Permit Number 191-122-0 Inspector Name: Lou Grimaldi Inspection Date 11/24/2006 Well Name: DUCK IS UNIT MPI 2-54/QI2 Insp N urn mitLG061127062312 Rei Insp Num API Well Number 50-029-22218-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~54/QÜ ¡Type Inj. iN! TVD' I IA 240 '~-;' 3340 3260 i - i P.T. I 1911220 !TypeTest i SPT; Test psi 3360! OA!~;-~IO-'To--r-- Interval Required by Varia,n,=-- P/F __ Incomplete ..-/Tubing :~~~_I~~_l~O----,_ Notes Tubing tail plug set below packer for Combo MIT. Possible leak past plug and down Inj Flow Line. [nj. Line valves to be repaired and TTP reset. Retest in future Monday, November 27, 2006 Page 1 of I ) ') STATE OF ALASKA . ALASKA OIL AND GAS ~ONSE~VATION COMMISSION , , 'V t'J;."'V Mechanical Integrity Test \4\ \: . Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us '59~\\'?\O; OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / END 02/26/05 Joe Anders Packer Depth Well 2-54/Q-12 Type Inj. PWI TVD P.T.D. 1911220 Type test P Test psi 3,360 Notes: MITOA to 3360 psi for annual sundry compliance. Tubing Casing Outer Pretest 2,050 1,950 o Initial 2,050 1,950 3360 15 Min. 30 Min. 2,050 2,050 Interval 1,950 1,950 P/F 3320 3320 v P v' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Outer Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: SCANNED Þ PH 2, E'\ 20lVi ¿ . ._. 'H "'-' IV . ,I.\\,. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting 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) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-0226_MIT _DIU_2-54.xls ) ~1T~7Œ (ill~ fÆ~fÆ~&~ AT~A.SKA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 18,2004 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage,AJe 99519-6612 RE: End 2-54/QI2 (PTD 191-122) Request for Administrative Approval Dear Mr. Rossberg: Per Rule 9 of Area Injection Order ("AIO") 001.000, the Alaska Oil and Gas Conserva- tion Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subj ect well. AOGCC finds that BPXA has elected to perform no corrective action at this time on End 2-54/QI2. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, End 2-54/QI2 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not com- promise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in End 2-54/QI2 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXAshall perform a yearly MIT -OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform a CMIT - T x IA every two years to 1.2 times the maximum anticipated well pressure; 5. BPXA shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure; and SCA~\!NE.[) NOV 1 9 2004 --) Mr. Steve Rossberg November 18,2004 Page 2 of2 6. after well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. SCANNED NO\! 1 20D/J '~ -~) ) BP Exploration (Alaska) Inc. Steve Rossberg, Wells Manager Post Office Box 19661 2 Anchorage, Alaska 99519-6612 October 20, 2004 ocr z Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Endicott 2-54/Q-12 (PTD 1911220) 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 2-54/Q-12. Endicott well 2-54 has tubing by inner annulus communication. Based upon sound engineering practice, two competent barriers have been established and thus the well can be safely operated. The 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 attached proposed operating and monitoring plan includes frequent monitoring of the competency of the barriers by recording daily pressure and injection data, increasing the frequency of mechanical integrity tests and increased reporting to the AOGCC. These measures will ensure continued safe water injection operations. Considering the presence of two competent barriers, physical repairs in this well are not necessary for safe operation. If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. This request is consistent with Area Injection Order 1, Rule 9, in that sound engineering practices have established two competent barriers and an operating and monitoring plan has been developed to ensure continued safe operations. There is no underground source of drinking water and therefore no USDW is endangered. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, rJ;A:-¿ Æ_~ Steve Rossberg - ---7- Wells Manager SCANNED NO\/ 1 9 lOU[~ ) Attachments Technical Justification for Administrative Relief Request Wellbore Schematic TIO Plot SCANNED NO\J 1 9 2004. -) ') Endicott 2-54/Q-12 Technical Justification for Administrative Relief Request October 20, 2004 Well History and Status Endicott weIl2-54/Q-12 (PTD 1911220) has tubing by inner annulus communication. A CMIT-TxIA passed to 3000 psi on 10/31/03. An MITOA passed to 3360 psi on 02/24/04. These tests indicate competent production and surface casing. Recent Well Events: - 09/29/03: MITIA failed, LLR-IA 1 BPM @ 1875 psi. - 10/31/03: Set TTP at 10650' md, CMIT-TxIA passed to 3000 psi. - 02/24/04: MIT-OA passed to 3360 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. Both of these systems have been pressure tested to 1.2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), a Pressure/Rate plot and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Production casing competency is demonstrated by the passing CMIT-TxIA to 3000 psi on 10/31/03. 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 - TxIA. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT-OA to 3360 psi on 02/24/04. 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. Any pressure in the OA would relieve into the formation through the production casing and tubing, mitigating the potential of OA overpressure. 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: The tubing is not considered a component 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. SCANNE[) NO\J 1 ~ ZOGL) -) ) 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 anticipated 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. 5CANNE[i NO\11 9 2004 4,000 3,000 ~ :::J en en ( ) L- 0. 2,000... 1,000 w oA 10/20/2003 ~) 111"-11) ~ II 12/20/2003 2/20/2004 2-54 TIO Plot T ~ ,I II 'I , I, II ~ 4/20/2004 6/20/2004 8/20/2004 ) 5CANNED NO\J 1 ~ 20[)lf 10/20/2004 -fþ- Tbg -11- IA -*- OA OOA -II- OOOA R.T. ELEV= 55.10' B.F. ELEV = 16.20' MAX DEV = 42:34° @ 6300' -) TREE: 6" 15000 psi I ) WELLHEAD: 13-5/8" I 5000 psi I McEvoy I 0-< SSSV LANDING NIPPLE 11560' OTIS (4.562" I.D.) 13-3/8", 68#1ft, NT80CYHE, Btrs I 2735' ~ ~ I -< 5-1/2", 17 #1ft, L-80, NSCC HES DWP Re1rievable 5-1/2" s1raddle -----.. ~ pack-off assembly w/1" GLM (ID 2.340") 1.1 OAL: 30.24' I I 3709' c GLM's (5/1" OTIS), (RA Latch) No. MD-BKB TVDSS I l. #2 #1 3913 10527 3833 9103 I 9-5/8", 47#1ft NT80S XO to NT95HS 5-1/2'''X' NIPPLE I I I > ~ (4.562" I. D.) 10560' 9483' 9-5/8" PACKER I 10569' I r BIG BORE WI g 5-1/2", 17#/ft L-80, TAILPIPE - 5-1/2" 'X' NIPPLE I I ¿. OTIS (4.562" I.D.) 10629' .) ( - 2-7/8" 'X' NIPPLE I I TOP OF 7" LINER REDUCER (2.313" I.D.) 10650' 110656' ~ SET IN 5-1/2" 'XN' NIPPLE > ~ OTIS (4.455" I.D.) 9-5/8", 47#1ft, NT95HS, NSCC I 10925' I >- A 5-1/2" SEAL I 10661' I NIPPLE ~ CJ¡ c::;\ ~ ðð c~ PERFORATING SUMMARY Ref. Log: CO SIZE SPF 80S 4.5" 5 SOS 4.5" 5 SOS 4.5" 5 [ r 7'''OTIS WD PKR W/4-1/2" X & XN NIPPLES (3.725" I --E- MIN I.D.) --E- 4-1/2" WLEG I 11737' I INTERVAL 11788' - 11881' 11894' - 11940' 11952' - 12062' sqzd 11752' I :(~',i! W z z <C Ü (f): PBTD 112137' 7", 29#1ft, L-80, B1rs- 112175' TKC !..- SANDBACKlCMN . >< X X X I 11941' I Date By Comments ENDICOTT WELL: 2-54/Q-12 11 127/91 PC PROPOSED COMPLETION API NO. 50-029-22218 1/20/92 JLH COMPLETION COMPLETION DIAGRAM 5/5/96 JTP SANDBAC KICM NT 6/13/00 MAS Tubing patch BP EXPLORATION (ALASKA), INC .r'"\ ,~ NSU, ADW Well Integrity Engineer IQ/-/¡v From: Sent: To: Cc: NSU, ADW Well Integrity Engineer Thursday, May 27,20042:28 PM AOGCC - Winton Aubert (E-mail) Reeves, Donald F; NSU, ADW Well Operations Supervisor; Engel, Harry R; Francis, Michael J; McMullen, John C; Patterson, Teresa J. (VEGO); Dube, Anna T Sundries in the Mail Subject: Hi Winton. We just put 3 sundry requests in the mail, addressed to you: END2-34: A 10-403 for rapid TxlA comm. END2-54: The well has gone from slow to rapid TxlA comm. There's a 10-404 to cancel the exiting slow TxlA comm sundry and a 10-403 for a new rapid TxlA comm sundry. NS27: A 10-404 to cancel the existing sundry. The RWO fixed the TxlA communication. Thanks for the help, let me know if you have any questions when you get the sundries. Joe (907) 659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 r"t¡ r"' ,..." w'- I \ t r'" I, ' f\L:tl'~:~~ .,l~' ... f JUN 02 ?fJO'J ^la:.!(,1DiI;'(;"'.I,I", ^W;I\Jf'I'~!:~ .'" . , 1 ~ ,~ BP Exploration (Alaska) Inc. Atin: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 ò to. May 27, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 Subject: END2-54/Q-12 (PTD 1911220) Application for Cancellation of Sundry #302-344 Application for Sundry Approval for PWI with Rapid TxlA Communication Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 302-344 and Application for Sundry form 10-403 for Endicott weIl2-54/Q-12. Purpose of this request is to revise sundry requirements to those for rapid TxlA communication. Sundry 302-344 is for slow TxlA comm. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, j w. rLÞa Joe Anders, P.E. Well Integrity Engineer Attachments Application for Sundry Cancellation form 10-404 Application for Sundry form 10-403 Description Summary of Proposal Well bore Schematic RE.CE.\\lEO jUN 0 '21004 .." (J't ." ~. '\ &. Gas Cons. u . , ~\as\(a Q~ þ.ncMt'3\}e OR\G\NAL .r'"\ .r'"\, .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved ProgramD 2. Operator SuspendD Repair Well 0 Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New PaolO 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended WellD Cancel Sundry 5. Permit to Drill Number: 191-1220 Other[]] Name: BP Exploration (Alaska), Inc. Development 0 StratigraphicD 9. Well Name and Number: 2-54IQ-12 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit Exploratory 0 ServiceŒ 6, API Number 50-029-22218-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.10 8. Property Designation: ADL-o34633 11. Present Well Condition Summary: Total Depth measured 12175 feet true vertical 10601.8 feet Effective Depth measured 11941 feet true vertical 10389.3 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Liner 1519 7" 29# L-80 10656 - 12175 9268.6 - 10601.8 8160 7020 Liner 15 4-1/2" 12.6# L-80 11737 . 11752 10205.5 . 10218.9 8430 7500 Production 9446 9.518" 47# NT80S 37 - 9483 37.0 - 8292.3 6870 4760 Production 1442 9.5/8" 47# NT95HS 9483 - 10925 8292.3 - 9496.9 8150 5080 Suñace 2697 13-3/8" 68# NT80CYHE 38 - 2735 38.0 - 2733.7 5020 2270 Perforation depth: Measured depth: 11788 -11881, 11894 -11940 @ @ @ @ RECEIVED 10661 JUN 3713 022004 3'Mska Oil & Gas Cons. LUrn¡11"""on 11737 ' , ,~." 10569 Anchoragg True vertical depth: 10251.33 -10335.11, 10346.82 -10388.36 Tubing (size. grade, and measured depth): 5.112" 17# L-80 Packers & SSSV (type & measured depth): 3-112" AVA DWP Patch Packer 3-112" AVA DWP Patch Packer 4-112" Otis WD Packer 5-1/2" TIW Big Bore 9%Cr Packer @ 35 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 13 Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: - 8Ft 'JJN 0 S ~ß' 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG 0 GINJD WINJOO'DSPLD Prepared by Garry Catron (907) 564-4657. ¡Sundry Number or N/A if C.O. Exempt: 302-344 Well Integrity Coordinator Copies of Logs and Surveys run - Daily Report of Well Operations - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders, P .E. Printed Name Joe Anders, P .E. Signature 1~ {~ Form 1¿04 Revised 12/2003 OR\G\NAl::" 659-5102 Date 5/27104 ,r'\ ~ .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: BP Exploration (Alaska), Inc. Development 0 PerforateD Waiver!!! StimulateD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number. 191-1220 Annular DisposalD OtherD 3. Address: Exploratory 0 6. API Number 50.Q29-22218-o0-o0 P.O. Box 196612 Anchorage, AI< 99519-6612 7. KB Elevation (ft): 55.10 KB 8. Property Designation: ADL-o34633 StratigraphicD Service ŒI 9. Well Name and Number: 2-54/Q-12 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): IEffective Depth TVD (ft): 10601.8 12137 10511.9 Length Size MD TVD Plugs (md): None Burst Junk (md): None Collapse 11. Total Depth MD (ft): 12175 Casing Liner 1519 Liner 15 Production 9446 Production 1442 Suñace 2697 Perforation Depth MD (ft): 11788 - 11881 11894 - 11940 Packers and SSSV Type: 3-1/2" AVA DWP Patch Packer 3-1/2" AVA DWP Patch Packer 4-1/2" Otis WD Packer 5-1/2" TIW Big Bore Packer 12. Attachments: Description Summary of Proposal 0 7" 29# L-80 4-1/2" 12.6# L-80 9-5/8" 47# NT80S 9-5/8" 47# NT95HS 13-3/8" 68# NT80CYHE Perforation Depth TVD (ft): 10251 10335.1 10347 10388.4 top bottom top bottom 10656 12175 9268.6 10601.8 8160 7020 11737 11752 10205.5 10218.9 8430 7500 37 9483 37.0 8292.3 6870 4760 9483 10925 8292.3 9496.9 8150 5080 38 2735 38.0 2733.7 5020 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 5.5" 17# L-80 35 10661 Packers and SSSV MD (ft): 3713 3730 11737 10569 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 ExploratoryD DevelopmentD ServiceŒ 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Date: 15. Well Status after proposed work: Oil 0 GasD PluggedD AbandonedD WAG 0 GINJD WINJI"XI WDSPLn '4>repared by Garry ~atron 564-4657, June 10, 2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders, P.E. Printed Name Signature J~ cu::.' Title Phone Well Integrity Coordinator 659-5102 5/27/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: Plug Integrity 0 BOP TestD Mechanciallntegrity Test 0 Location Clearance D Other: Subsequent Form Required: Approved by: BY ORDER OF THE COMMISSION Date: Form 10-403 Revised 12/2003 SUBMIT IN DUPLICATE r-. "" Endicott 2.54/Q.12 Description Summary of Proposal OS/27/04 Problem: Produced Water Injector with rapid T x IA communication. Well History and Status: Endicott weIl2-54/Q-12 (PTD 1911220) has rapid T x IA communication. The well currently has sundry #302-344 for slow TxlA communication. A leak rate test conducted 9/29/03 indicated the leak rate has increased to 1 BPM @ 1875 psi. Recent Well Events: > 12/02/02: AOGCC issued Sundry #302-344 for slow TxlA comm > 09/29/03: LLR-IA 1 bpm @ 1875 psi > 10/31/03: Set TIP 10650' md, CMIT-TxIA Passed to 3000 psi, pull TIP, Set SSSV > 02/24/04: MITOA Passed to 3360 psi This Sundry request is to allow for continued water injection in this well. The following supports the request: . A CMIT-T x IA passed to 3000 psi on 10/31/03, indicating the production casing is capable of withstanding injection pressure. . A MIT-OA passed to 3360 psi on 02/24/04, indicating the surface casing is capable of withstanding injection pressure. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a production or surface casing leak. Proposed action plan: 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Perform 2-year CMIT-T x IA. 4. Stop injection and notify the AOGCC if there is an indication of a loss of production casing integrity. MEMORANDUM TO: THRU: FROM: Mike Bill ~¢'J' Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 1,2003 Tom Maunder ~ P.I. Supervisor , . ~;~(~ Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX MPI 2-54 DIU Endicott Packer Depth Pretest Initial 15 Min. 30 Min. I WellI 2-54 I Typ.,ni.I N I T.V.D. 19156 I Tubing 12050 I 3ooo I ~ooo 13ooo I,nt~rv~,I VI P.T.D.I 191-122 I Type testl P I Testpsil 2289 I CasingI 1800I 2775I 2775I 2775I P/F I D I Notes: CMIT known tubing leak I WellI Type Inj. P.T.D. I I Notes: WellI P.T.D. I Type test Notes: WellI I Type Inj. P.T.D. I I Type test Notes: I We,I Type Inj. P.T.D.I Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I-- Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover · O= Other (describe in notes) Test's Details I arrived at MPI to find the pump truck and wire line unit rigged up on well 2-54. A plug had been set in the X nipple at 10650 MD, the packer is at 10569. The tubing was pressured up to 3000 psi with the casing tracking it. The test was held for thirty minutes with no pressure loss noted. This well passed its MIT of the casing under the variance for a tubing leak M.I.T.'s performed' 1_ Number of Failures: 0 Attachments: Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. MIT DIU 2-54 2-1-03 CS.xls 2/6/2003 ALASKA OIL AND GAS CONSERYA~ION COPl~I~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Robertson BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re' Duck Island Unit / Endicott Well 2-54 / Q- 12 BP Exploration (Alaska) Inc. Permit No: 191-122 Approval No. 302-344 Dear Mr. Robertson: Your request to continue injection in Duck Island Unit / Endicott well 2-54 / Q-12 .(PTD 191-122) is hereby approved. Conditions of approval are as follows: 1. water injection only; 2. continue monthly reporting of daily injection rate and pressure; 3. perform a CMIT Tubing x IA every two years; 4. perform an annual IA leak rate test; 5. cease injection and notify the AOGCC of any IA or OA pressure change .not attributable to thermal cycling. This sundry approval does not exempt you from obtaining additional.permits required by law from other governmental agencies, and does not authorize conducting operations until all other required permitting determinations are made. BY ORDER OF THE COMMISSION DATED this z ~ day of December, 2002 Sincerely, Michael L. Bill Commissioner jjc/Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2078' FNL, 2328' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 828' FNL, 1623' FEL, SEC 35, T12N, R16E, UM At effective depth 685' FNL, 1711' FEL, Sec. 35, T12N, R16E, UM At total depth 624' FNL, 1780' FEL, Sec 35 T12N, R16E, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service_X (asp's 258875, 5982342) (asp's n/a) (asp's 254259, 5983885) (asp's 254184, 5983949) 6. Datum elevation (DF or KB feet) RKB 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-54/Q-12 9. Permit number / approval number 191-122 10. APl number 50-029-22218 11. Field / Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 76' 30" Surface 2880' 13-3/8" Intermediate 9429' 9-5/8" Intermediate 1443' 9-5/8" Liner 1518' 7" 12175 feet 10602 feet 11941 feet 10389 feet Plugs (measured) Junk (measured) Cemented 2021 c.f. Permafrost 2371 c.f. Class 'G' 502 c.f. Class Sand back/CMN @ 1 41RECEIVED AUG 1,t 2001 ert' I D th Measured Depth Alaska 0~'Jr~ 131' Anc'l~},a, ge 2735' 2679 9483' 8237' 9483' - 10928' 8237' - 9443' 10656'- 12175' 9213'- 10547' Perforation depth: measured Open Perfs 11788' - 11881', 11894' - 11940', Squeezed Perfs 11952' - 12062'i true vertical Open Perfs 10196' - 10279', 10290' - 10332', Squeezed Perle 10343' - 10448' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5-1/2", 17 ppf, L-80 TBG to 10569' w/5-1/2" Tailpipe to 10661'. 2-7/8" 'X' Nipple set @ 10650' HES DWP Retrievable 5-1/2" Straddle PO Assembly w/l" GLM. Top Element @ 3713 - Bottom @ 3730'. 9-5/8" x 5-1/2" Packer Big Bore @ 10569'. 7" Otis WD Packer W/4-1/2" 'X' & 'XN' Nipples @ 11737'. 5-1/2" Otis SSSVLN @ 1560' 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 15. Status of well classification as: ' 14. Estimated date for commencing operation August 22, 2001 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Suspended _ Service Water Injection. 17. I hereby~fy that the foregoing is true and correct to the best of my knowledge. Questions? Call Dan Robertson @ 564-5546. Signed Title: E.=__.!::= Pmd',,'finn ~w.ii. r'~,erd!na.+~,r Date Au.qust 13, 2001 Dan Robertson Prepared by DeWayne R. Schnorr 564.5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 'Plug integrity__ BOP Test__ Location clearance_ I Mechanical Integrity Test_ Subsequent form required lo- ORIGINAL SIGNED BY , Commissioner Date Approved by order of the Commission J M, Heusser IIUI Form 10-403 Rev 08/15/88 · - SUBMIT IN TRIPLI OATE BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson Blvd Anchorage, Alaska 99519-6612 bp November 5, 2002 Mr. Winton Eubert Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Endicott Well 2-54/Q-12 Application for Sundry Approval Dear Mr. Eubert: Attached is Application for Sundry Approval form 10-403 for Endicott water injection well 2-54/Q-12 (PTD 191-122). This request is for approval to continue water injection only with known tubing by inner annulus communication. A summary proposal and wellbore schematic are attached. If you require any additional information or clarification, please contact Dan Robertson at 564-5546. Sincerely, Dan Robertson, P.E. Sr. Petroleum Engineer Attachments ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: VARIANCE H20 INJECTION Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 2078' FNL, 2328' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 828' FNL, 1623' FEL, SEC 35, T12N, R16E, UM At effective depth 685' FNL, 1711' FEL, Sec. 35, T12N, R16E, UM At total depth 624' FNL, 1780' FEL, Sec 35 T12N, R16E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 258875, 5982342) (asp's 254342, 5983740) (asp's 254259, 5983885) (asp's 254184,5983949) 6. Datum elevation (DF or KB feet) RKB 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-54/Q-12 9. Permit number / approval number 191-122 10. APl number 50-029-22218-00 11. Field / Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 76' 30" Surface 2880' 13-3/8" Intermediate 9429' 9-5/8" Intermediate 1443' 9-5/8" Liner 1518' 7" 12175 feet 10602 feet Plugs (measured) 11941 feet 10389 feet Junk (measured) Sand back/CMN @ 11941' Cemented Measured Depth 131' 2021 c.f. Permafrost 2735' 9483' 2371 c.f. Class 'G' 9483'- 10928' 502 c.f. Class 'G' 10656'- 12175' True vertical Depth 131' 2679' 8237' 8237' - 9443' 9213' - 10547' Perforation depth: measured Open Perfs 11788' - 11881', 11894' - 11940', Squeezed Perfs 11952' - 12062'. true vertical Open Perfs 10196'- 10279', 10290'- 10332', Squeezed Perfs 10343'- 10448' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5-1/2", 17 ppf, L-80 TBG to 10569' w/5-1/2" Tailpipe to 10661'. 2-7/8" 'X' Nipple set @ 10650' HFS DWP Retrievable 5-1/2" Straddle PO Assembly w/l" GLM. Top Element @ 3713 - Bottom @ 3730'. 9-5/8" x 5-1/2" Packer Big Bore @ 10569'. 7" Otis WD Packer W/4-1/2" 'X'& 'XN' Nipples @ 11737'. 5-1/2" Otis SSSVLN @ 1560' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation November, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas __ Service Water Injection. Suspended__ 17. I hereby/C'~rtify that the foregoing is true and correct to the best of my knowledge. Signed ~_ ~ Title: Petroleum Engineer Dan Robertson FOR COMMISSION USE ONLY Questions? Call Dan Robertson @ 564-5546. Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance Mechanical Integrity Test_ ' f ' ' ~),0- ,~r~ _¢~,./~._/,:~¢~,/~;~-~ ORIGINAL SIG~~ Approved by order of the Commission ~t hm ~ '71111/ Commissioner Form 10-403Rev06/~5/ee- R~D~S ~F[ JA~' 9 200,~nch°rage Date November 05, 2002 Prepared by DeWayne R. Schnorr 564-5174 J Approval no...~ SUBMIT IN TRIPLICATE Wavier Check List PTD: I q / - / Z 7...- Sundry #: '5 t9 Z- - Z~ q/ct/- Order(s): Item Y/N Comments 1. Notified of pressure communication or leakage? 2. Diagnostics planne&/run? Method? 3. Form 10-403 submitted requesting waiver? 4. Alternate MIT passed? Method? AOGCC witnessed? 5. MIT Part II verified? How? 6. Area.~eview examined? Date: Definition of Terms T IA OA MIT CMIT LLRT Tubing Inner Annulus (tbg x csg) Outer Annulus (csg x csg) Mechanical Integrity Test Combined test of annular spaces Leak Loss Rate Test Integrity # Barriers Condition AOGCC Notification Enhanced Operational Restrictions Category Affected Requirements Monitoring Requirements1 Normal 0 Full wellbore integrity ~ MIT - 4 years Water, slurry, gas, MI upon approval (/ TxIA communication (tubing (Next business day if~Y~sig Annual MITIA/LLRT . 1 leak; packer leak quantifiable) k,..change in annnt'tl~"i)ressure CMIT TxlA - 2 yrs Water only ............. ................. "~' Annual MITIA & CMIT IAxOA Water only; annulus PSV w/alarms & set points IAxOA communication '~ ....... 2 1 Production casing leak MIT Tubing - 2 yrs for ESD < MIYP of next outer casing TxlAxOA communication Kill well; submit Sundry (10-403) outlining 1 > 1 Release beyond wellbore Next business day Daily reports until well secured repairs In addition to Monthly Report of Daily Operating iParameters; Annulus Pressure Monitoring 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 finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: waiver chklst.doc:8/2/2002 -- Endicott Water Injection Well 2-54/Q-12 Summary Proposal 11/05/02 Problem: Water injection well with slow tubing by inner annulus communication Well History and Status /' Endicott water injection well 2-54/Q-12 developed a tubing leak in mid 2000. A tubing patch was installed across the leak, but was not completely successful at restoring tubing integrity. The following operations have been performed: · 5/7/2000 Leak det/ect log confirmed tubing leak at 3716 MD. · 6/13/2000 Tubing patch installed across leak // · 7/17/00 MIT inner annulus. 8% pressure loss in 30 minutes, but pressure did not stabilize. · 8/6/00 Combination MIT o~...tu'b'~ng-~d 9 5/8" casing with plug in tailpipe. Passed."''~ · 8/22/00 Sundry approval('#300-20..9~llowed retum to water injection only.- · 7/31/01 Annual IA leak r~e_t~'~ 600 psi pressure loss in 7 minutes, after which annulus equalized with tubing pressure. Not possible to establish injection rate through leak with pump truck d.u.e't6'~low leak rate. · 8/17/01 Sundry approval #.30:l"-24(Yallowed continued water injection.~, · 6/23/02 Annual IA leak rat"~'f. 860 psi pressure loss in 7 minutes. Leak rate consistent with prior year. Still unable to establish injection rate through leak with pump truck due to Iow leak rate. This sundry request is to allow for continued injection of water. The following supports the request: - The consistent leak rate from year to year indicates little change in tubing leak severity and a Iow probability of a casing leak. - The successful combined tubing and casing pressure test with the tubing 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 annual IA leak rate test will be conducted to monitor the leak severity. - A combined tubing and casing pressure test against a tubing 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. Submit a monthly report of daily pressures and injection rate. 3. Perform an annual IA leak rate test. 4. Perform combination MIT Tubing x IA against a tailpipe plug every 4 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TREE: 6" / 5000 psi/~""" R.T. ELEV = 55.10' WELLHEAD: 13-5/8"~. 0 psi/McEvoy B.F. ELEV = 16.20' MAX DEV : 42:34° @ 6300' O ,~ __ __ SSSV LANDING NIPPLE ,I 1560' OTIS (4.562" I.D.) 13-3/8", 68#/ft, NTS0CYHE, Btrs I2735' I · HES DWP Retrievable 5-1/2" straddle ' ~ pack-off assembly w/l" GLM (ID 2.340") OAL: 30.24' · · 3709' I GLM's (5/1" OTIS), ( RA Latch ) No. MD-BKB TVDSS I~ #1 10527 ~)103 9-5/8", 47#/ft NT80S XO to NT95HS -- _ (4.562"5'1/2"'X'NIPPLEi. D.) I 10560' I 9483' 9-5/8" PACKER ~ BIG BOREW/ )~ ~ 5-1/2", 17#/ft L-80, TAILPIPE ....~- 5-1/2" 'X' NIPPLE OTIS (4.562" I.D.) 10629' I 2-7/8" 'X' NIPPLE I SET IN 5-1/2" 'XN' NIPPLE 10656' ~ OTIS (4.455" I.D.) 9-5/8", 47#/ft, NT95HS, NSCC I ~ ~ 5-1/2" SEAL ,10925' f NIPPLE 10661' PERFORATING SUMMARY Ref. Log: ~ 7" 'OTIS WD PKR W/4-1/2" I 11737' CO sIZE' SPF INTERVAL ! ! ~ X&XNNIPPLES(3.725" MIN I.D,) SOS 4.5" 5 11788' - 11881' I SOS 4.5" 5 11894'- 11940' ~ 4-1/2" WLEG 11752' SOS 4.5" 5 11952' - 12062' sqzd I ?¢/¢t! S A N DBA C K/C M N 11941' 7",29#/ft, L-80,Btrs- I 12175' / ... <X X XI TKCI J Date By Comments ENDICOTT WELL: 2.541Q-12 11/27/91 PC PROPOSED COMPLETION APl NO. 50-029-22218 1/20/92 JLH COMPLETION COMPLETION DIAGRAM 5/5/96 JTP SANDBACK/CMNT 6/13/00 MAS Tubing patch BP EXPLORATION (ALASKA), INC 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 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of September 2002 from 2-54/Q-12 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, '' ' Madelyn A. ~illholland Data Manager MAM Enclosure cc: File: 76.13 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE I IA (9-5/8) psi pA (13-3/8) psI WHP (psi) Iniection Rate (MBD)I WriT (F) I 9/1/2002 2150 250 2230 17636 170 9/2/2002 2150 250 2216 17612 170 9/3/2002 2150 250 2235 17038 167 9/4/2002 2150 250 2237 17295 168 9/5/2002 2150 200 2212 17648 168 9/6/2002 2150 250 2189 16158 166 9/7/2002 2150 250 2266 18465 168 9/8/2002 2150 250 2234 17102 169 9/9/2002 2150 250 2247 17213 167 9/10/2002 2150 250 2231 16451 165 9/11/2002 2150 0 2201 16671 171 9/12/2002 2150 0 2213 16511 162 9/13/2002 2200 1 O0 2217 17565 172 9/14/2002 2200 150 2224 17249 169 9/15/2002 2200 150 2231 18115 167 9/16/2002 2200 150 2207 16561 159 9/17/2002 2000 0 2092 12693 161 9/18/2002 21 O0 0 2084 16757 175 9/19/2002 1950 300 1999 16063 170 9/20/2002 2050 250 2049 15738 167 9/21/2002 2150 0 2186 16354 164 9/22/2002 2150 0 2187 17555 173 9/23/2002 2150 300 2161 16862 172 9/24/2002 2150 300 2174 15952 174 9/25/2002 2150 200 2189 16745 172 9/26/2002 1950 1 O0 2189 13891 168 9/27/2002 1950 1 O0 2183 15225 171 9/28/2002 1950 1 O0 2200 16364 171 9/29/2002 1950 1 O0 2172 15847 173 9/30/2002 1950 1 O0 2160 15477 174 Note 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 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of August 2002 from 2-54/Q-12 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, Madelyn A. I~lillholland Data Manager MAM Enclosure cc: File: 76.13 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE I~A (9-5/8) psi pA (13-3/8) ps~ WHP (psi) Iniection Rate (MBD)I WHT (F) I 8/1/2002 1500 0 2071 16549 150 8/2/2002 2100 0 2167 16490 152 8/3/2002 2000 0 2170 15963 159 8/4/2002 2100 0 2154 15921 157 8/5/2002 2100 0 2190 17992 150 8/6/2002 2100 0 2189 16812 155 8/7/2002 2000 0 2177 16005 157 8/8/2002 2000 0 2224 18049 168 8/9/2002 2000 0 2230 17686 167 8/10/2002 2200 0 2228 18750 171 8/11/2002 2000 300 2217 17911 169 8/12/2002 2100 100 2232 17432 166 8/13/2002 2100 100 2247 17960 169 8/14/2002 2150 150 2221 16739 168 8/15/2002 2150 150 2226 15663 167 8/16/2002 2200 100 2231 16166 167 8/17/2002 2150 200 2242 16729 169 8/18/2002 2200 200 2248 17176 170 8/19/2002 2200 200 2247 17542 169 8/20/2002 2200 300 2246 17088 170 8/21/2002 2200 250 2249 17034 169 8/22/2002 2200 200 2252 16810 169 8/23/2002 2200 400 2257 18896 174 8/24/2002 2150 400 2237 19168 173 8/25/2002 2150 250 2213 18148 171 8/26/2002 2150 250 2207 18305 171 8/27/2002 2150 250 2217 18418 172 8/28/2002 2150 250 2228 18496 171 8/29/2002 2150 250 2252 18184 171 8/30/2002 2150 250 2206 16007 166 8/31/2002 2150 250 2238 17465 165 Note 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 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2002 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED JUL £ 2002 Anchorage · SC~NED JUL :l 0 2002 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE I IA (9-5/8) psi pA (13-3/8) psI WHP (psi) Injection Rate (MBD)I WriT (F) I 6/1/2002 2250 250 2236 17363 172 6/2/2002 2250 200 2248 16551 173 6/3/2002 2250 250 2239 16335 171 6/4/2002 2250 250 2233 16390 172 6/5/2002 2250 300 2239 16646 173 6/6/2002 2250 300 2229 17452 174 6/7/2002 2250 300 2205 17915 178 6/8/2002 2250 300 2217 16469 176 6/9/2002 2250 400 2206 17419 178 6/10/2002 2250 400 2226 16948 176 6/11/2002 2250 350 2225 16589 175 6/12/2002 2250 350 2205 16199 176 6/13/2002 2250 350 2202 15947 177 6/14/2002 2250 400 2242 17039 175 6/15/2002 2250 450 2251 18292 178 6/16/2002 2250 450 2210 16920 176 6/17/2002 2250 450 2101 15123 163 6/18/2002 2250 375 2246 16832 175 6/19/2002 1950 300 2210 16745 173 6/20/2002 2250 350 2228 16685 174 6/21/2002 2250 350 2233 17170 175 6/22/2002 2250 250 2223 16325 171 6/23/2002 2150 250 2234 16594 170 6/24/2002 2150 250 2243 17405 174 6/25/2002 2100 350 2199 17471 175 6/26/2002 2150 300 2209 13202 172 6/27/2002 2150 100 2246 17000'* 168 6/28/2002 2200 150 2247 17000** 169 6/29/2002 2150 150 2246 17000** 170 6/30/2002 2150 250 2193 16000* 173 Note **Estimated due to flow indicator not working. R. Jones *FI repaired today. R. Jones SCANNED JUL I O 2.002 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 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2002 from 2-54/Q-12 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, Madelyn A. Millh~land Data Manager MAM Enclosure cc: File: 76.13 RECEIVED JUH 0 4 2.00'2 Nask~ 0il & Gas Cons. C0mm~s~u, Anchorage SCANNED JUN ANNULUS PRESSURE REPORT FOR ENDICO'n' WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA {13-3/8) psi WHP {psi) Injection Rate (MBD) WHT 5/1/2002 2200 300 2237 17013 169 5/2/2002 2200 250 2237 18048 167 5/3/2002 2200 150 2251 18448 166 5~/2002 2200 300 2247 18506 169 5/5/2002 2200 200 2240 19484 168 5/6/2002 2200 400 2217 19256 171 5/7/2002 2100 400 2204 18758 173 5~/2002 2100 400 2201 18619 173 5/9/2002 2100 400 2201 18727 171 5/10/2002 2100 400 2226 18887 173 5/11/2002 2200 400 2220 17696 173 5/12/2002 2250 400 2258 19429 174 5/13/2002 2200 400 2250 18661 174 5/14/2002 2250 400 2280 18772 173 5/15/2002 2200 400 2288 19074 173 5/16/2002 2300 400 2277 19292 172 5/17/2002 2300 400 2253 19236 171 5/18/2002 2200 400 2246 19753 171 5/19/2002 2200 300 2246 18665 170 5~0/2002 2250 200 2261 18603 169 5/21/2002 2250 300 2253 18818 172 5/22/2002 2250 300 2252 17913 172 5/23/2002 2250 450 2253 17608 176 5~4/2002 2250 400 2246 18593 177 5~5/2002 2250 450 2264 17870 172 5~6/2002 2250 200 2269 16577 167 5~7/2002 2250 200 2257 16625 167 5~8/2002 2250 200 2267 16568 171 5/29/2002 2250 250 2248 16320 173 5/30/2002 2250 350 2256 16700 173 5/31/2002 2250 350 2253 17960 174 Note ,SCANNED JUN 2002 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 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 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of April 2002 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 SCANNED JUL ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Injection Rate 4/1/2002 2250 350 2286 19149 (MBD) WHT 170 4/2/2002 2250 350 2297 19631 171 4/~2002 2250 350 2298 19441 169 4/4/2002 2250 250 2299 17656 166 4/5~002 2250 400 2298 17123 170 4/6/2002 2250 200 2311 18910 165 4/~2002 2250 250 2294 18135 168 4/~2002 2250 300 2290 17607 168 4/9/2002 2250 300 2301 16928 166 4/10/2002 2250 300 2284 17376 165 4/11/2002 2300 100 2307 17719 163 4/12/2002 2300 100 2279 18151 164 4/1~2002 1700 500 1663 11446 173 4/14/2002 1750 500 1643 11568 177 4/15/2002 900 300 1824 13333 170 4/16/2002 1800 300 1973 15331 162 4/17/2002 2200 0 2259 18525 162 4/18~002 2300 0 2238 17439 164 4/19/2002 2300 0 2258 18424 164 4/20/2002 2200 0 2262 18649 163 4/21/2002 2200 200 2250 18805 165 4/22/2002 2300 200 2248 19020 163 4/23/2002 2300 200 2261 18899 163 4/24/2002 2200 150 2249 18666 167 4/25/2002 2200 350 2242 19274 171 4/26~002 2200 400 2201 18355 173 4/2~2002 2200 450 2204 16454 174 4/28/2002 2200 300 2235 18740 168 4/29/2002 2200 250 2236 17417 168 4/30/2002 2200 250 2234 16613 171 Note SCANNED IVlA¥ ?~ 8 2002~ BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 5, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for ~pproval # 399-136) Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of March 2002 from 5-02/SD-10 in the Endicott Reservoir. The enclosed data is to be forwarded to the State on a monthly basis until the leak path is eliminated. Endicott is to maintain an average WHP of no greater than 2000 psi and the annular pressures are to be maintained below 500 psi. This well is currently shut-in. If there are any questions regarding this data, please contact me at 564-5234. Sincerely, Madelyn A. Millholland Data Manager MAM Enclosure cc: File' 76.13 Sheet1 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Injection Rate (MBD) WHT (F) Note 2/1/2002 2200 0 2246 18493 163 2/2/2002 2200 0 2197 17397 165 2/3/2002 2200 150 2251 17905 162 2/4/2002 2200 150 2124 15885 166 ~ 2/5/2002 2200 150 2144 15996 156 2/6/2002 2200 0 2204 17620 158 2/7/2002 2200 0 2219 18211 158 2/8/2002 2200 0 2235 18328 159 2/9/2002 2250 0 2257 18717 164 2/10/2002 2250 100 2257 18538 163 2/11/2002 2250 100 2257 18538 163 2/12~002 2200 150 2249 18151 164 2/13/2002 2200 150 2270 17808 165 2/14/2002 2200 150 2295 18289 168 2/15/2002 2200 150 2274 17990 169 2/16/2002 2300 150 2257 18937 169 2/17/2002 2300 150 2268 16608 168 2/18/2002 2300 150 2255 18535 162 2/19/2002 2250 300 2274 19358 168 2/20/2002 2250 300 2333 20386 169 2/21/2002 2250 300 2321 20105 167 2~2/2002 2250 300 1982 14544 168 2/23/2002 2250 200 2301 20252 164 2/24/2002 2250 200 2318 20437 165 2/25~002 2250 200 2329 18987 164 2/26/2002 2300 300 2319 18831 168 2/27/2002 2300 300 2314 20192 169 2/28/2002 2300 300 2325 20572 168 Page 1 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 4, 2002 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of January 2002 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 ECEIvED FEB 0 8 ZO0 Alaska Oii & Gas Co~$ t.... Sheet1 ANNULUS PRESSURE REPORT FOR ENDICO'i-I' WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Injection Rate (MBD) WHT (F) 1/1/2002 2200 0 2255 17275 158 1/2/2002 2200 0 2255 17782 157 1/3/2002 2251 17573 157 1/4/2002 2300 0 2249 16700 156 1/5/2002 2300 0 2282 16995 160 1/6/2002 2300 0 2148 15515 158 1/7/2002 2300 0 2315 18516 164 1/8/2002 2300 0 2315 18516 164 1/9/2002 2200 0 2283 17455 157 1/10/2002 2300 0 2293 18959 167 1/11/2002 2300 0 2298 18143 164 1/12/2002 2300 200 2306 19131 165 1/13/2002 2300 200 2176 17226 150 1/14/2002 2300 200 2278 18084 163 1/15/2002 2300 0 2281 18047 162 1/16/2002 2300 0 2251 17663 161 1/17/2002 2200 0 2210 16294 158 1/18/2002 2300 0 2206 17093 156 1/19/2002 2200 0 2209 17331 157 1/20/2002 2200 0 2218 17532 158 1/21/2002 2200 0 1554 9537 143 1/22/2002 2200 0 2141 17247 162 1/23/2002 2200 0 2232 18061 164 1/24/2002 2200 0 2213 17499 163 1/25/2002 2200 0 2230 17841 160 1/26/2002 1850 0 2168 17260 160 1/27/2002 1850 0 2171 17362 160 1/28/2002 2050 50 2174 16969 158 1/29/2002 2150 150 2188 17205 161 1/30/2002 2150 150 2242 17464 161 1/31/2002 2150 150 2246 17517 165 RECEIVED ~laska 0ii & Gas Co~s. ~nc~ora~e Page 1 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED J~N 0 ~ Alaska Oil & Gas Cons. Commission Anchorage Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of December 2001 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 12/1/2001 12/2/2001 12/3/2OO 1 12/4/2OO 1 12/5/2OO 1 1 2/6/2001 12/7/2001 12/8/2001 12/9/2001 12/10/2001 12/11/2001 12/12/2001 12/13/2001 12/14/2001 12/15/2001 12/16/2001 12/17/2001 12/18/2001 12/19/2001 12/20/2001 12/21/2001 12/22/2001 12/23/2001 12/24/2001 12/25/2001 12/26/2001 12/27/2001 12/28/2001 12/29/2001 12/30/2001 12/31/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2100 0 2081 15975 159 2200 0 2228 17672 160 2200 0 2235 17590 156 2200 0 2153 16868 146 2200 0 2128 17483 158 2200 0 2242 18534 151 2200 0 2255 17327 155 2200 0 2260 18391 156 2200 0 2249 17803 157 2200 0 2264 18257 155 2300 0 2265 18274 155 2300 0 2262 18393 154 2200 0 2264 17865 154 2200 0 2251 17807 150 2300 0 2267 18568 158 2300 0 2255 18280 156 2200 0 2255 17861 156 2300 0 2274 17961 157 2200 0 2158 16364 158 2200 0 2194 16912 162 2200 0 2227 18068 158 2200 0 2245 18131 155 2250 0 2245 18009 155 2200 0 2244 17885 155 2200 0 2244 17911 157 2200 0 2234 18529 160 2200 0 2151 17278 156 2200 0 2189 16917 159 2200 0 2236 16933 156 2200 0 2250 17734 156 2200 0 2238 17838 158 Note BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 3, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of November 2001 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED DEC 0 Alaska 0~1 & Gas Cons. Comm~ss~o Anchorage Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 11/1/2001 11/2/2001 11/3/2001 11/4/2001 11/5/2001 11/6/2001 11/7/2001 11/8/2001 11/9/2001 11/10/2001 11/11/2001 11/12/2001 11/13/2001 11/14/2001 11/15/2001 11/16/2001 11/17/2001 11/18/2001 11/19/2001 11/20/2001 11/21/2001 11/22/2001 11/23/2001 11/24/2001 11/25/2001 11/26/2001 11/27/2001 11/28/2001 11/29/2001 11/30/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) 2200 0 2185 16651 156 2200 0 2215 17513 160 2150 0 2132 15879 162 2150 0 2082 15977 163 2200 0 2108 15811 162 2200 0 2156 15981 157 2200 0 2169 16573 155 2200 0 2192 17448 157 2200 0 2199 17129 160 2200 0 2192 17448 157 2200 150 2165 18185 166 2200 0 2198 18357 161 2250 0 2211 18302 166 2300 0 2203 18624 165 2300 0 2207 17598 162 2200 0 2226 17030 157 2200 0 2269 17838 154 2200 0 2262 17611 154 2200 0 2262 17216 155 2200 0 2260 18676 159 2300 0 2280 18404 163 2300 0 2271 17361 155 2250 0 2260 17326 155 2200 0 2235 17568 160 2200 0 2235 18215 165 2200 0 2243 17590 165 2250 0 2234 17131 153 2200 0 2249 17819 157 2250 0 2249 18394 159 1950 0 1981 14399 153 Note RECEIVED DEC 0 2001 Aiask~ 0il & Gas CMs. ¢0mmissi0~ 10/30/01 .................... 10/31/01 I/I/01 I t2/01 1/3/01 1/4/01 1/5/01 1/6/01 11710 I 11810 I I/9/01 1/10/01 I/I 1/01 1/12/01 1/13/01 I / 14/0 I 1/15/01 1/16/01 1/17/01 1/15/01 1 / 19/01 1/20/01 1/21/01 1/22/01 11/23/01 11/24/01 11/25/01 11/26/01 I/27/01 1/28/01 1/29/0 I 1/30/0 I 12/1/01 12/2/01 MBD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 PSI and Temp (F) o o o o o BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 1,2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of October 2001 from 2-54/Q-12 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, \ Madelyn A. r~llholland Data Manager MAM Enclosure cc: File: 76.13 RECEIVED OCT 0 ~ 20o~ Alaska Oil & Gas Cons. Cornmis$io~ Anchorage Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 9/1/2001 9/2/2001 9/3/2001 9/4/2001 9/5/2001 9/6/2001 9/7/2001 9/8/2001 9/9/2001 9/10/2001 9/11/2001 9/12/2001 9/13/2001 9/14/2001 9/15/2001 9/16/2001 9/17/2001 9/18/2001 9/19/2001 9/20/2001 9/21/2001 9/22/2001 9/23/2001 9/24/2001 9/25/2001 9/26/2001 9/27/2001 9/28/2001 9/29/2001 9/30/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2200 200 2225 18626 169 2250 50 2225 18441 170 2250 200 2236 18726 170 2250 150 2230 18897 170 2300 100 2198 18422 169 2300 100 2224 18179 171 2250 300 2216 17948 174 2250 275 2228 18308 169 2200 300 2202 17647 173 2250 250 2209 17518 174 2250 250 2220 18305 173 2200 250 2226 18237 174 2200 250 2211 18217 170 2200 0 2200 17835 163 2200 0 2165 17303 165 2200 0 2171 17551 169 2200 100 2182 17505 168 2200 100 2185 17191 169 2200 100 2193 18034 167 2200 0 2185 17176 168 2200 0 2180 17240 167 1850 0 1875 11823 169 1900 0 1781 11022 144 2200 0 2158 17509 164 2150 250 2123 16666 171 2150 200 2111 16821 175 2150 0 2155 16857 160 2200 0 2187 17836 162 2100 150 2103 16915 174 2100 200 2051 14432 165 Note RECEIVED OCT 0 3 2001 Alaska 0ii & Gas Cons. Commission Anchorage 0 O. 1 6 o o o o o co o o o o o o o o o (-i) dtuei pue c) 1.13 o o o o o o o o o 0~ o co o o o o o o o o o o I O/E/O 1 I0/I/01 10/0[/6 10/6i5/6 10/g I O/LE/6 [ 0/9E/6 I O/~Z/6 [ O/t~Z/6 [ O/[Z/6 I O/EZ/6 l O/I U6 I 0/0i~/6 10/61/6 10/g I/6 10/L l/6 10/9 l/6 10t~ l/6 l 0/1~ I./6 l 0/£ l/6 10/E 1/6 [O/l [/6 I 0/01/6 10/6/6 10/8/6 lO~L~6 10/9/6 10/~;/6 I 0/1~/6 10/[/6 I O/E/6 I0/1/6 l O/I [/8 I 0/0 [/8 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 6, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED SEP O 7 2001 Alaska Oil & Gas Cons. Cornmissio:~ Anchorage Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of August 2001 from 2.54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER,INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 8/1/2001 812/2001 8/3/2001 8/4/2001 8/5/2001 8/6/2001 8/7/2001 8/8/2001 8/9/2001 8/10/2001 8/11/2001 8/12/2001 8/13/2001 8/14/2001 8/15/2001 8/16/2001 8/17/2001 8/18/2001 8/19/2001 8/20/2001 8/21/2001 8/22/2001 8/23/2001 8/24/2001 8/25/2001 8/26/2001 8/27/2001 8/28/2001 8/29/2001 8/30/2001 8/31/2001 IA(9-5/8) 2250 2200 2200 2200 2200 2200 2150 2300 2200 2200 2200 2200 2200 2200 2200 2250 2200 2200 2200 2300 2300 2300 2250 2200 2250 2250 2250 2250 2250 2250 psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) Note 150 2182 17137 171 100 2193 16524 167 0 2182 15769 163 0 2089 15142 153 0 2196 16635 168 0 2193 17545 169 0 2164 17485 155 100 2145 16354 169 100 2163 18415 172 225 2165 18307 158 100 2177 17807 167 0 2145 17256 174 150 2139 17393 160 0 2207 16586 164 0 2211 16296 167 0 2233 16161 168 0 2115 15068 163 0 2215 16179 163 0 2235 17814 171 0 2246 17719 169 0 2260 17366 172 0 2262 17567 171 0 2216 17186 163 200 2213 18710 173 350 2215 18710 175 260 2215 18574 175 260 2250 18928 173 360 2252 18688 174 100 2232 18831 168 40 2229 18789 167 RECECVE,D SEP 0 7 2001 ,Alaska Oil & Gas Cons. Commissior~ Anchorage (..-I) dine1 puc lsd o o o o o o o o o i~ o Lo o o 04 oki ~- ~-- Lo 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O0 ~0 ~ O~ 0 O0 CO ~- O/E/6 [0/i/6 O/[ £/8 0/0 £/8 0/6E/8 0/8E/8 O/L E/8 0/9E/8 O/~;E/8 O/'vE/g 0/£~/8 O/EE/8 0/I E/8 0/0 U8 0/61/8 0/81/8 O/L 1/8 0/91/8 0/~ 1/8 0/1~1/8 0/£1/8 O/Z: I/8 0/1 I/§ 0/01/8 0/6/8 10/8/8 O/L/8 0/9/8 O/g/8 0/1:'/8 0/£/8 O/Z:I8 10/I/8 OII £1L 0/0 £/L bp (" BP Exploration (Alaska) Inc. 900 East Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 August 13, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501 Re: Endicott Well 2-54/Q-12 Variance Request Dear Mr. Maunder, Please find attached an Application for Sundry Approval for Endicott water injection well 2-54/Q-12. This application is for a variance to continue water injection in this well. A tubing leak was identified in this well in 5/2000. A tubing patch was installed across the leak 6/13/2000. Initial indications were that the tubing patch was successful at restoring tubing integrity, but subsequent monitoring indicated a small amount of communication was still occurring. A 7/17/00 MIT indicated 8% pressure loss in 30 minutes, but did not stabilize. A later combination MIT of the tubing and casing with a plug in the tailpipe confirmed casing integrity. A variance to allow continued injection was then applied for and approved. The current variance expires 8/22/01. One stipulation of the existing variance approval is an annual inner annulus pressure test to monitor the leak rate. The required annual inner annulus pressure test to monitor the leak rate was performed 7/31/01. The inner annulus pressure was increased by approximately 600 psi above the tubing pressure. This 600 psi pressure increase bled down to equalize with the tubing pressure in 7 minutes. Although the leak rate is still Iow enough that it was not possible to establish a pump rate through the leak, it does appear to have increased relative to last year's observed leak rate. This well prove..~ essential waterflood support fo -one 3A as it is one of 2 water injectors in this zone. Given the continued relatively Iow rate of leakage, lack of indication of outer annulus communication, and importance of the well in maintaining offtake, it is desirable to keep the well on water injection. It is requested that the provisions of the current variance be continued. The injection rate, tubing and annuli pressures will be recorded daily and reported to the AOGCC on a monthly basis. A pressure test of the inner annulus to monitor the leak rate will be performed annually and a casing mechanical integrity test performed every 4 years unless daily monitoring indicates more frequent testing is warranted. Please contact me at 564-5546 if you require additional information. Dan Robertson Endicott Production Engineer Attachments: Form 10-403 Application for Sundry Approval 7/31/01 2-54/Q-12 Inner annulus leak rate test job report STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2078' FNL, 2328' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 828' FNL, 1623' FEL, SEC 35, T12N, R16E, UM At effective depth 685' FNL, 1711' FEL, Sec. 35, T12N, R16E, UM At total depth 624' FNL, 1780' FEL, Sec 35 T12N, R16E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service_X (asp's 258875, 5982342) (asp's n/a) (asp's 254259, 5983885) (asp's 254184, 5983949) 6. Datum elevation (DF or KB feet) RKB 55.1 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-54/Q- 12 9. Permit number / approval number 191-122 10. APl number 50-029-22218 11. Field / Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 76' 30" Surface 2880' 13-3/8" Intermediate 9429' 9-5/8" Intermediate 1443' 9-5/8" Liner 1518' 7" 12175 feet 10602 feet Plugs (measured) 11941 feet 10389 feet Junk (measured) Cemented 2021 c.f. Permafrost 2371 c.f. Class 'G' 502 c.f. Class 'G' Sand back/CMN @ 11 ,,1,R ECEi VED AUG 2001 rt' I D th Measured Depth ^laska 0Tr~ ~t~,~s.e~,~mmissim 131' An~c~go 2735' 2679 9483' 8237' 9483' - 10928' 8237' - 9443' 10656'- 12175' 9213'- 10547' Perforation depth: measured Open Perfs 11788'- 11881', 11894'- 11940', Squeezed Perfs 11952'- 12062'. true vertical Open Perfs 10196' - 10279', 10290' - 10332', Squeezed Perfs 10343' - 10448' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5-1/2", 17 ppf, L-80 TBG to 10569' w/5-1/2" Tailpipe to 10661'. 2-7/8" 'X' Nipple set @ 10650' HES DWP Retrievable 5-1/2" Straddle PO Assembly w/l" GLM. Top Element @ 3713- Bottom @ 3730'. 9-5/8" x 5-1/2" Packer Big Bore @ 10569'. 7" Otis WD Packer W/4-1/2" 'X'& 'XN' Nipples @ 11737'. 5-1/2" Otis SSSVLN @ 1560' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 22, 2001 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Service . Water Iniection. Suspended__ 17. I hereby~c~,,ify that the foregoing is true and correct to the best of my knowledge. Questions? Call Dan Robertson @ 564-5546. Signed ~ Title: F__nd!cc.'t. Pred,,,-tinn R,___W~II~ Coordin~t,.r Date August 13, 2001 Dan Robertson Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I ApprovaLno. j Plug integrity__ BOP Test__ Location clearance __ I Mechanical !ntegrity Test__ Subsequent form required 10- Approved by order of the Commission -J, I~,. Heusser Commissioner Date Form 10-403 Rev 06/15/88 · -. SUBMIT IN TRIPLICATE BPX Endicott Production Engineering Department Pre- Leak Rate Test DATE: 7/31/01 WELL N°: 2-54/Q- 12 BP EXPLORATION REP: Fuller/Spearman SERVICE COMPANY: APC Initial Well I TUBING lAP 0AP Status (psi) (psi) (psi) TIME OPERATION 1730 R/U pump equipment to perform a pre MIT leak rate test 1750 Tubing by IA equalize in first 15 min reading 1815 Tested a,gain to see time for equalization. TiME Fluids Rate Volume TUBING IA OA BWIPD REMARKS (bpm) (bbls) (psi) (psi) (psi) i730 Meth 2200 2230 120 TGSM PT line to 4000 psi. 1735 .75 0 2220 2230 120 17150 Start pumping 1740 Meth 0.75 3 2200 2850 180 Shut down 1745 0 2200 2240 100 16800 15 min bleed off 1815 2200 2220 80 Initial readings 1817 Meth 0.5 0 2220 2220 80 17260 1821 Meth 0.5 2 2220 2850 140 16920 Shut down 1826 2220 2340 80 17290 5 min readin~l '1828 2200 2240 60 17220 Tubing x IA equalized. Final Well I TUBING lAP 0AP Status (psi) (psi) (psi) I , SUMMARY l,~;600:Psi,'pressui~e:increaSe 'off 'th~"lA Will comr~Unic~te to'tithing pressure in 7 minUnte§!~!!~OA pressure l.:~b.g..nge.~..is,assumed to be expansion and contraction of tubulars. '~ BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of July 2001 from 2-54/Q-12 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, Data Manager MAM Enclosure cc: File: 76.13 /lUG 0 3 2001 Alaska Oil & Gas Cons. Commission Anchorage Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 7/1/2001 7/2/2001 7/3/2001 7/4/2001 7/5/2001 7/6/2001 7/7/2001 7/8/2001 7/9/2001 7/10/2001 7/11/2001 7/12/2001 7/13/2001 7/14/2001 7/15/2001 7/16/2001 7/17/2001 7/18/20O 1 7/19/2001 7/20/2001 7/21/2001 7/22/2001 7/23/2001 7/24/2001 7/25/2001 7/26/2001 7/27/2001 7/28/2001 7/29/2001 7/30/2001 7/31/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) 2250 200 2248 17796 176 2250 400 2165 16753 179 2250 400 2236 18880 176 2250 400 2252 18718 175 2250 400 2259 18658 175 2300 300 2260 18493 174 2250 300 2266 18622 171 2300 350 2268 18644 173 2200 300 2249 18270 173 2250 200 2243 18234 172 2250 350 2239 17926 225 2250 375 2237 17543 171 2200 250 2162 16613 171 2200 200 2199 16986 167 2200 100 2218 18024 169 2250 150 2218 18024 169 2200 400 2191 17884 177 2200 400 2190 17921 174 2200 400 2206 16862 163 2200 0 2141 16818 167 2200 0 2073 16270 177 2200 0 2149 17494 172 2200 400 2093 16884 176 2150 350 2085 16486 175 2200 0 2163 17324 170 2200 200 2200 16809 164 2200 200 2135 16837 167 2150 0 2130 15794 166 2100 100 2185 16706 167 2200 0 2207 17293 165 2200 0 2227 18285 170 Note RECEIVED AUG 0 3 2001 Alaska OJj & Gas Cons, C,omm, iss o~ ,A,r~chora9~ o o CD 0 0 0 0 0 0 0 0 0 0 0 00 (4) dina1 puc IScl *%-- ~ 0~1~ o o i0I~/8 10/I/8 lOll ElL I010£/£ I016~1£ IOISE/L IOIL~/L IO/9Z/L [01~1£ IOI~/L IOI£Z/L IOIEZ/L lO/IZ/£ IO/OZ/L 10/61/£ 10/~ [/L [O/L [/L [0/9[/L IOI~I/L IO/PllL IO/£1/L [OI~[/L IO/ll/£ 10/0 [/L IO/6/L [O/8/L IO/L/L lO/9/L IO/g/L IO/~/L I O/£/L I()/~/£ ] IO/I/L I 10/0£/9 i ~0/6Z/9 0 0 0 CD CD CD CD BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Alaska 0il & Gas Cons Anchorage' C°mr~ission Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of June 2001 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. ,The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 6/1 ~2001 6/2/2001 6/3/2001 6/4/2001 6/5/2001 6/6/2001 6/7/2001 6/8/2001 6/9/2001 6/10/2001 6/11/2001 6/12/2001 6/13/2001 6/14/2001 6/15/2001 6/16/2001 6/17/2001 6/18/2001 6/19/2001 6/20/2001 6/21/2001 6/22/2001 6/23/2001 6/24/2001 6/25/2001 6/26/2001 6/27/2001 6/28/2001 IA(9-5/8) 2300 2200 2300 2250 2000 2250 2250 2200 2300 2200 2250 2250 2200 2150 2200 2250 2200 2200 2250 2250 2300 2250 2200 2200 2300 2250 2250 2250 psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT (F) Note 150 2197 16770 169 0 2232 17400 166 200 2228 17361 171 400 2218 17474 177 400 2190 17009 172 0 2269 17340 167 100 2261 16827 169 100 2271 17369 172 200 2254 17692 165 200 2246 17652 172 300 2255 17906 173 350 2229 17324 165 100 2227 17002 173 350 2213 17084 172 250 2248 17709 174 400 2228 17318 171 250 2201 16843 173 300 2200 16830 174 300 2243 17654 172 250 2230 17481 172 100 2262 16961 167 0 2275 16975 166 200 2274 17053 170 250 2260 17050 168 250 2278 18138 169 150 2266 18242 169 0 2227 15961 168 150 2253 16544 174 6/29/2001 6/30/2001 225O 2250 350 2264 16734 176 150 2249 17690 176 RECEIVED JUL 0,3 20r A/aska O~1 & Gas Cons. Commission Anchorage ~130101 $131 I0 I 611/01 612/0 I 613101 61410 I 6/5/0 I 61610 I 6~7~0 I 6/8/0 I 6/9/0 I 6/I 0/0 I 6/I 1/01 6/12/01 6/13/0 I 6/14/01 6/15/01 6/16/0 I 6/17/01 6/18/0 I 6/19/0 I 6/20/0 I 6/21/0 I 6/22/0 I 6/23/0 I 6/24/01 6/25/0 I 6/26/01 6/27/0 I 6/28/0 I 6/29/01 6/30/0 I "7/I/01 '~ 7/2/01 o o o o o o o o MBD o o o o o o o PSI and Temp (F) o o o co o o o o BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 1, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of May 2001 from 2-54/Q-12 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, Madelyn A: Millholland Data Manager MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 5/1/2001 5/2/2001 5/3/2001 5/4/2001 5/5/2001 5/6/2001 IA(9-5/8) 2200 2200 2200 2200 2200 .2200 5/7/2001 5/8/2001 5/9/2001 5/10/2001 5/11/2001 5/12/2001 5/13/2001 5/14/2001 5/15/2001 5/16/2001 5/17/2001 5/18/2001 5/19/2001 5/20/2001 5/21/2001 5/22/2001 5/23/2001 5/24/2001 5/25/2001 5/26/2001 5/27/2001 5/28/2001 1800 1850 1900 2050 2200 2200 2200 2200 2200 2200 2200 2200 2250 2200 2250 2250 2200 2200 2200 2200 2250 2250 psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WriT (F) Note 0 2216 16318 158 0 2104 15769 147 0 1987 11839 126 0 2075 14620 154 0 2215 14511 148 0 1889 14709 176 300 2074 10552 143 350 1758 12449 175 600 1841 11623 165 0 2036 14689 148 0 2175 16058 152 0 2196 16478 154 0 2196 16533 153 0 2206 16989 158 0 2216 17151 158 0 2200 16719 158 0 2212 16766 156 0 2204 16453 155 0 2228 17041 158 0 2228 17034 161 0 2237 17485 163 0 2245 17540 165 0 2232 17350 164 0 2215 17121 163 0 2252 17922 168 100 2237 17568 166 0 2261 18166 165 100 2257 18244 166 5/29/2001 5/30/2001 5/31/2001 225O 1950 1950 150 2257 18244 166 300 2253 17828 172 150 1833 11575 155 (..-I) du~ai pue lsd o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o 101~1c) 101119 101 [ ~'1~ 10/0£/~; 101~1~ l O/L~/~ I 0/9~/~; I ()/~/~ I O/b~/~ ~()/~/~ 1 ()/~/~ 10t I ~/~ 10/0~/~ 10/61/~ 1 OIL I/~ 10/91/~ 1 ()/~ 1/~ I0/~I/~ I()/~ I/~ I O/I I/~ I 0/01/~ I 0/6/~ 1 ()/8/~ 10/L/~ l 0/9/~ I O/S/~ I()/~/~ I()/~/~ [ ()/~/~ I0/I/~ 10/()~/~ 10/6 ~/~ BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED Alaska 13il & Gas Cons. Commission Anchorage Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of April 2001 from 2-54/Q-12 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, Madelyn A. Millholland Data Manager MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 4/1/2OO 1 4/2/2001 4/3/2001 4/4/2001 4/5/2001 4/6/2001 4/7/2001 4/8/2001 4/9/2001 4/10/2001 4/11/2001 4/12/2001 4/13/2001 4/14/2001 4/15/2001 4/16/2001 4/17/2001 4/18/2001 4/19/2001 4/20/2001 4/21/2001 4/22/2001 4/23/2001 4/24/2001 4/25/2001 4/26/2001 4/27/2001 4/28/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2200 0 2274 17343 158 2300 0 2275 18075 156 2300 0 2291 18344 156 2300 200 2288 18813 161 2250 150 2276 18535 160 2250 150 2293 18641 161 2300 200 2294 18269 164 2300 400 2290 18165 165 2300 400 1713 10597 146 2300 200 2268 17957 161 2300 200 2267 17652 163 2250 150 2288 17834 170 2250 200 2187 16304 162 2050 0 2143 16074 160 2200 0 2158 16316 165 2300 0 2270 17759 160 2250 0 2269 17023 155 2000 500 2170 15216 171 2000 400 2091 15185 169 2200 0 2227 17544 157 2100 0 2248 17622 156 2000 0 2239 16949 157 2250 0 2210 16586 151 2050 0 2206 16793 148 2241 0 2400 16040 153 2264 0 2300 16487 153 2200 0 2248 16433 150 1000 0 2219 16115 146 Note 4/29/2001 4/30/2001 2200 0 2233 16246 149 2200 0 2264 15974 146 0 O. n' o o o 00 1-- o o o o o o o o o (=1) dma.l, puc lSd o o o o o o o o o o o o o o o o o o o o o o o ! 0/[/~ IO/l/; l 0/0 £/~ 1016~l~ 10/8 [/¢ lOIL[/~ I0/9~/1~ I 0/~/~ 10/~[/~ I0/[~/~ I Ol~,[/~' IO/l~/~ ! 0/0~/~' 10/6 I I0/8 I/~ I OIL I I~ I0/91/~ IO/gI/~ I 0/~ I/~ IO/[l/~ lO/EI/~ lOll I/~ IO/OI/? I0/6/~ I0/8/~ I O/ L/~ I0/9/~ I0/~/~ I O/W'F IO/g/~ lO/[/~ lO/l/~ 10/I IO/O[/~ BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April, 3, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 RECEIVED APR 05 2001 (,ol~s. C01~lmissJ0n Ar~chorage .Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of March 2001 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTI' WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 3/1/2001 3/2/2001 3/3/2001 3/4/2001 3/5/2001 3/6/2001 3/7/2001 3/8/2001 3/9/2001 3/10/2001 3/11/2001 3/12/2001 3/13/2001 3/14/2001 3/15/2001 3/16/2001 3/17/2001 3/18/2001 3/19/2001 3/20/2001 3/21/2001 3/22/2001 3/23/2001 3/24/2001 3/25/2001 3/26/2001 3/27/2001 3/28/2001 IA (9-5/8) psi OA (13-3/8) psi WHP (psi) Inject Rate (MBD) WHT 2300 200 2346 18071 166 2200 250 2334 17889 161 2250 200 2355 18137 160 2300 200 2340 18715 160 2300 200 2348 18480 163 2300 200 2374 19283 167 2350 400 2380 19425 167 2300 0 2383 19065 168 2300 300 2111 18004 133 2300 300 2374 18016 166 2300 200 2378 18016 167 2300 200 2346 18016 165 2300 200 2295 19498 165 2300 300 2349 19601 164 2300 300 2351 19495 162 1700 300 2092 16647 157 1700 300 1830 13610 167 1700 300 1755 12238 172 2100 0 13773 1848 157 1700 0 14046 1895 147 1920 0 14838 1950 147 2050 0 14066 1957 143 2200 0 16031 2165 151 2200 0 16066 2181 151 2200 0 17051 2214 153 2200 0 16651 2192 157 2150 200 2221 17347 156 2225 0 2220 17317 152 Note PA Down used adjusted 3/9 data for Rate PA Down used adjusted 3/9 data for Rate PA Down used adjusted 3/9 data for Rate 3/29/2001 3/30/2001 3/31/2001 2100 2200 2300 0 2208 16907 156 0 1997 14171 162 0 1879 12773 167 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 4, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of March 2001 from 2-54/Q-12 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, Madelyn A. Mdlholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 Note: ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJEC REPORT PER AOGCC VARIANCE Well has confirmed leak. Well can remain on injec The data below must be recorded daily and sent to the AOGC( DATE 2/1/2001 2/2/2001 2/3/2001 2/4/2001 2/5/2001 2/6/2001 2/7/2001 2/8/2001 2/9/2001 2/10/2001 2/11/2001 2/12/2001 2/13/2001 2/14/2001 2/15/2001 2/16/2001 2/17/2001 2/18/2001 2/19/2001 2/20/2001 2/21/2001 2/22/2001 2/23/2001 2/24/2001 2/25/2001 2/26/2001 2/27/2001 2/28/2001 IA(9-5/8) 2200 2300 2300 2300 2300 2300 2300 2300 2300 2300 2300 2300 2300 1950 2300 2300 2300 2200 2200 2300 2300 2200 2250 2200 2300 2250 2300 2250 psi CA (13-3/8) psi WHP (psi) Inject Rate (MBD) WriT (F) 0 2328 18208 151 0 2341 18506 151 0 2335 19141 153 0 2327 18959 154 0 2336 19189 156 0 2324 18794 157 0 2318 18797 159 0 2341 19979 161 0 2352 20099 163 0 2328 19709 161 0 2332 19420 159 0 2343 20037 162 0 2316 19243 162 150 2332 19712 160 0 2292 18640 160 0 2340 19618 157 0 2307 18649 155 100 2284 18550 155 100 2267 18087 155 100 2276 18309 156 0 2271 18403 156 0 2263 18610 156 0 2259 18619 155 150 2280 18657 158 100 2298 19125 161 150 2258 18373 160 100 2298 19006 160 200 2294 17829 167 0 6 ?..001 Alaska Oil 8, Gas cons. C0m~'ts$~0tl BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of January 2001 from 2-54/Q-12 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, Madelyn A. r~illholland Sr. Technical Assistant RECEIVED MAM Enclosure cc: File: 76.13 FEB 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 2, 2001 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of December 2000 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 /v o 8 2 z '4~/r. o// ,~,4eO~o~' c°o;o~/Ss/oo Sheet1 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi)Injection Rate (MBD) WHT (F) Note 12/1/2000 2250 0 2261 19,239 157 1 2/2/2000 2200 0 2262 19,058 156 1 2/3/2000 2280 0 2206 18,067 168 1 2/4/2000 1900 50 1821 13,328 167 1 2/5/2000 1900 50 1852 13813 166 1 2/6/2000 1900 1 O0 1808 13119 164 12/7/2000 1900 1 O0 1789 12722 165 1 2/8/2000 2300 0 2136 17757 152 1 2/9/2000 2200 50 2234 18757 147 1 2/10/2000 2200 0 2235 18331 154 12/11/2000 2200 0 2228 18228 156 12/12/2000 2250 0 2256 18644 153 12/13/2000 2250 0 2241 18377 157 12/14/2000 2300 0 2287 19027 157 12/15/2000 2300 0 2297 18942 158 12/16/2000 2300 0 2137 15050 141 1 2/17/2000 2300 0 1474 9946 81 1 2/18/2000 2220 0 2225 19138 145 1 2/19/2000 2300 0 2253 19039 147 12/20/2000 2300 0 2271 18191 153 12/21/2000 700 0 2251 18246 154 12/22/2000 2200 0 2270 18219 151 1 2/23/2000 2300 0 2254 18482 160 12/24/2000 2300 0 2320 18152 157 1 2/25/2000 2300 0 2326 18392 154 12/26/2000 2300 0 2260 18005 162 12/27/2000 2270 0 2328 18672 153 1 2/28/2000 2300 0 2303 19049 153 12/29/2000 2360 0 2310 18901 150 12/30/2000 2000 0 2190 17774 151 1 2/31/2000 2000 0 2143 18175 156 (use this section to recorde significant events such as loss of SW etc', Page I BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 4, 2000 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Maunder: Attached in duplicate is the daily inner and outer annular pressure data for the month of November 2000 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 e£C£1v£b Os zooo 41~ka 011 & ~s Cons. 4n~horage C°n~mi~ion Sheet1 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-541Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance, The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi CA (13-3/8) psi WHP (psi) Injection Rate (MBD) WHT (F) 11/1/2000 2200 0 2251 17111 149 11/2/2000 2200 0 2240 17116 153 11/3/2000 2200 0 2180 16838 162 11/4/2000 2200 0 2150 16289 152 11/5/2000 2100 0 2188 16724 154 11/6/2000 2100 0 2245 16468 153 11/7/2000 2100 0 2240 16754 147 11/8/2000 2100 0 2201 17769 154 11/9/2000 2200 0 2172 17187 157 11/10/2000 2200 0 2157 17079 157 11/11/2000 2200 0 2160 17215 153 11/12/2000 2200 0 2196 17531 152 11/13/2000 2100 0 2172 17035 156 11/14/2000 2200 0 2178 17351 156 11/15/2000 2200 0 2180 17768 158 11/16/2000 2200 0 2192 18051 155 11/17/2000 2200 0 2183 17818 159 11/18/2000 2100 0 2063 15835 148 11/19/2000 2100 0 2179 17150 158 11/20/2000 2100 0 2222 17988 155 11/21/2000 2100 0 2241 18563 161 11/22/2000 2300 0 2244 17960 157 11/23/2000 2300 0 2217 17522 157 11/24/2000 2200 0 2196 17242 154 11/25/2000 2200 0 2216 17644 152 11/26/2000 2249 18076 155 11/27/2000 2300 0 2268 18434 155 11/28/2000 2200 0 2236 18628 152 11/29/2000 2200 0 2219 18471 152 11/30/2000 2200 0 2238 18961 153 (use this section to recorde significant events such as loss of SW etc', RECEIVED DEC 05 000 Alaska Oil & Gas Cons. Commission Anchorage Page 1 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 2, 2000 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Wondzell, Attached in duplicate is the daily inner and outer annular pressure data for the month of October 2000 from 2-54/Q-12 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, Madelyn A. Milll~olland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 RECEIVED Gas Co¢¢s. Corr~r~lissior~ ANNULUS PRESSURE REPORT FOR ENDICOTi' WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi)Injection Rate (MBD) WHT (F) Note 10/1/2000 2300 0 2230 17726 163 10/2/2000 2300 100 2224 17539 163 10/3/2000 2300 0 2233 16290 155 10/4/2000 2300 0 2298 17422 158 10/5/2000 2200 0 2220 17283 148 10/6/2000 2200 0 2208 17529 155 10/7/2000 1650 0 1890 12826 152 10/8/2000 2250 0 2235 17757 165 10/9/2000 2300 0 2255 18141 156 10/10/2000 2300 0 2297 19449 155 10/11/2000 2300 0 2329 19809 154 10/12/2000 2200 0 2011 14539 152 10/13/2000 2100 0 2191 16111 157 10/14/2000 2200 0 2197 16751 160 10/15/2000 2200 0 2209 16752 156 10/16/2000 2100 0 2187 16296 156 10/17/2000 2000 0 2199 16752 153 10/18/2000 2200 0 2209 17986 155 10/19/2000 2200 0 2208 17985 156 10/20/2000 2200 0 2230 18471 154 10/21/2000 2200 0 2213 17633 155 10/22/2000 2200 0 2207 17285 156 10/23/2000 2200 0 2195 17820 156 10/24/2000 2200 0 2180 17449 156 10/25/2000 2200 0 2240 16498 155 10/26/2000 2200 0 2243 16365 153 10/27/2000 2200 0 2238 16127 148 10/28/2000 2200 0 2175 14814 148 10/29/2000 2200 100 2234 17018 151 10/30/2000 2200 0 2248 18299 150 10/31/2000 2200 0 2165 16716 160 (use this section to recorde significant events such as loss of SW etc) Page 1 BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 2, 2000 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive .Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Wondzell, Attached in duplicate is the daily inner and outer annular pressure data for the month of September 2000 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 Sheet1 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi)Injection Rate (MBD) WHT (F) Note 9/1/2000 2000 100 1750 9/2/2000 2000 100 1681 9/3/2000 2000 100 1749 9/4/2000 2000 0 1969 9/5/2000 2000 0 1954 9/6/2000 2000 0 1999 9/7/2000 2000 0 2062 9/8/2000 2100 0 2108 9/9/2000 2200 0 2119 9/10/2000 2100 0 2071 9/11/2000 2100 0 2086 9/12/2000 2150 0 2090 9/13/2000 2200 0 2102 9/14/2000 2050 0 2000 9/15/2000 2050 0 2035 9/16/2000 2100 0 1849 9/17/2000 1800 0 1835 9/18/2000 1800 0 2129 9/19/2000 2150 0 2075 9/20/2000 2150 0 2157 9/21/2000 2150 0 2183 9/22/2000 2150 0 2125 9/23/2000 2000 0 2012 9/24/2000 2200' 0 2189 9/25/2000 2200 0 2200 9/26/2000 2200 0 2183 9/27/2000 2200 0 2204 9/28/2000 2200 0 2252 9/29/2000 2300 0 2246 9/30/2000 2200 0 2226 12239 169 11169 166 11834 165 14605 161 14196 164 14430 169 15990 157 16468 160 15970 171 14650 172 ,15371 166 '16026 167 16800 159 15237 167 15743 159 13802 123 14356 130 17251 152 16419 157 17827 156 18284 158 17231 159 15251 161 17856 157 18559 158 18185 164 18438 165 17325 160 17786 165 17197 162 P-1802 Shutdown P-1802 Down P-1802 Online P-1907 down (TAPS slowdown) P-1907 down (TAPS slowdown) P-1907 down three hours P-1802 down nine hours NOTES: (use this section to recorde significant events such as loss of SW etc', Page I BP EXPLORATION 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 6, 2000 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Wondzell, Attached in duplicate is the daily inner and outer annular pressure data for the month of August 2000 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 SOO 1 ! 2000 Gas Cons. 08-01-00 2-54 .xls ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE IA (9-5/8) psi OA (13-3/8) psi WHP (psi) njection Rate (MBD WHT (F) 8/1/2000 2200 200 2227 18746 155 8/2/2000 2200 200 2250 7449 150 8/3/2000 2200 200 2515 0 66 8/4/2000 400 0 2370 0 63 8/5/2000 400 0 2314 0 61 8/6/2000 400 0 420 0 56 8/7/2000 1500 0 58 0 58 8/8/2000 1800 0 2188 8657 157 8/9/2000 2150 250 2069 8657 157 8/10/2000 2150 250 2146 17508 160 8/11/2000 2200 200 2175 18200 153 ;8/12/2000 2150 150 2143 17761 ~ 153 8/13/2000 1900 800 1961 14456 174 8/14/2000 1950 350 1909 14151 172 8/15/2000 1950 350 1914 12890 173 8/16/2000 1950 350 1926 14754 173 8/17/2000 1900 450 1894 14541 173 8/18/2000 2000 600 1963 15262 175 8/19/2000 2000 350 1961 15116 175 8/20/2000 2000 150 1983 15254 174 8/21/2000 2050 100 1985 15614 173 8/22/2000 2000 100 1990 15760 173 8/23/2000 2000 100 1994 15526 173 8/24/2000 2000 0 1994 15691 173 8/25/2000 2000 100 2011 15724 173 8/26/2000 2000 100 2015 15720 173 8/27/2000 2000 100 2032 15907 174 8/28/2000 2000 100 2029 15951 174 8/29/2000 2000 100 1995 15275 173 8/30/2000 2000 100 1975 14815 173 8/31/2000 2000 100 1911 14270 174 Note Shut in well at 0930 8/2/00 Shut in well at 0930 8/2/00 Shut in well at 0930 8/2/00 Shut in well at 0930 8/2/00 Shut in well at 0930 8/2/00 Shut in well at 0930 8/2/00 Well bol @ 1305 NOTES: (use this section to recorde significant events such as loss of SW etc) Page 1 NOTE TO FILE Date: August 16, 2000 In Re: Endicott well 2-54/Q-12 (PTD 191-122) Request for Waiver to Continue Injection with a tubing leak (300-209) Endicott well 2-54/Q-12 is a Class IIR water injection well in Endicott Field on the North Slope of Alaska. In early May, routine wellhead pressure monitoring indicated potential communication between the tubing and inner annulus (IA) of the subject well. Subsequent diagnostic tests confirmed a leak in the 7" tubing to the 9-5/8" x 7" annulus. On May 9, the operator (BP) notified Blair Wondzell regarding the leak and diagnostic work performed to date. Further work was planned and it was requested to keep the well on injection. Blair concurred with a 2 week time set for submitting additional information. A tubing caliper survey was performed on May 19, however analysis had not been received by May 30 when the earlier request to keep the well on injection was repeated. Concurrence was granted with 2 weeks again being stated for submitting additional information. On June 13 a tubing patch was installed over the leak. Continued daily monitoring indicated that a slight leak still existed. A standard IA pressure test was attempted on July 17. According to the report submitted by Inspector John Crisp, the pressure loss during the witnessed test was linear and resulted in a 200 psi loss in 30 minutes. The test was observed for an additional 30 minutes with a similar 200 psi loss. Following the unsuccessful IA test, it was determined through discussions with Tom Maunder, that a variance approval was possible however casing integrity must be demonstrated. With a known tubing leak, casing integrity can be demonstrated by simultaneously pressure testing the tubing and IA. This test is known as a combination MIT tubing x IA (CMIT TIA) and is performed by placing a plug in the tubing tail below the packer and simultaneously pressuring the tubing and annulus. According to Inspector Jeff Jones report of August 6, this test was successfully performed. On August 15, BP submitted a sundry request (Form 403) requesting a variance to continue injection in the well. In support of their request, BP cited the successful CMIT TIA, their assessment that the leak was small and their commitment to increased surveillance activities and monthly reporting to the Commission. They proposed to keep the MIT schedule at the normal 4 years based on the Iow leak rate. An assessment of the leak rate can be determined by relating the observed pressure loss and the compressibility of the pressured fluid. The calculated leak rate based on the pressure decline is: Volume leaked - (compressed volume) x (pressure loss) 300,000 The compressed volume was the fluid in the 9-5~8" casing x 7" tubing annulus (IA). The calculated volume of the IA is: IA volume = (packer depth) x (annulus specific volume) 10560' x .0256 bbl/ft = 270.3 bbls (9-5/8" 47# casing x 7" casing annulus per Halliburton Red Book) Volume leaked = (270.3 x 200) / 300,000 = .18 bbl = 7.5 gallons Leak rate = .18 bbl -- 7.5 gallons in 30 minutes Leak rate = 7.5 / 30 = .25 gpm 20 AAC 25.402 (e) requires that the mechanical integrity (MI) of an injection well be demonstrated before injection begins. Continued MI must be confirmed by monitoring the injection pressure and rate and the pressure of the casing x tubing annulus during actual injection. 20 AAC 25.402 (f) requires the operator to notify the Commission of any pressure communication or leak determined through the monitoring required in (e) by the next working day and implement corrective action or increased surveillance as the Commission may require to ensure protection of fresh water. 20 AAC 25.402 (g) allows the Commission to require additional MITs as necessary. BP's notification of the pressure communication/suspected leak and their diagnostic and repair work has complied with the requirements of (e) and (f) as noted above. Mechanical integrity of the 9-5~8" casing has been demonstrated by an alternate pressure testing means familiar to the Commission. Injection fluids are confined within the wellbore and can only exit at the perforations. Although pressure communication exists between the tubing and IA, the leak path and resulting rate are small. Increased monitoring and reporting of the injection well's daily pressures and rate will aid in continually assessing the condition of the wellbore and allow quick response to any observed change in the injection parameters. Decision: Based on the above analysis, the waiver to continue injection is granted subject to the increased monitoring as proposed in the application and performing a CMIT TIA on 4 year intervals. In addition to the actions proposed in the application, an annual investigation of the pressure communication from the IA to the tubing should be performed to quantify any change in the known leak path. bp ( BP Exploration (Alaska) Inc. 900 E. Benson P.O. Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 August 15, 2000 Tom Maunder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Endicott Well 2-54/Q-12 Variance Request Dear Mr. Maunder, Please find attached an Application for Sundry Approval for Endicott water injection well 2-54/Q-12. This application is for a variance to continue water injection in this well. As previously reported, this well has a slow leak from the tubing to the inner annulus. A tubing patch was set in this well on 6/13/00. Initial indications were that the tubing patch was successful at curing the tubing to inner annulus communication completely. However, subsequent daily monitoring of the inner annulus pressure seemed to indicate a small amount of communication was still present. A mechanical integrity test performed 7/17/00 resulted in an 8% pressure loss in 30 minutes. Further diagnostic work was performed 8/2-6/00. A plug was set in the tailpipe and both the tubing and inner annulus pressure tested. The test confirmed that slow tubing to inner annulus communication did exist and that inner to outer annulus communication did not exist. This well provides essential waterflood support for Zone 3A as it is one of two water injectors in this zone. Given the relatively low rate of leakage, inner annulus integrity, and importance of the well in maintaining offtake, it is desirable to keep the well on water injection. The injection rate, tubing and annuli pressures will be recorded daily and reported to the AOGCC on a monthly basis. A mechanical integrity test will continue to be performed every 4 years unless daily monitoring indicates more frequent testing is warranted. Please contact me at 564-5230 if you require additional information. Anna T. Dube Endicott/Badami Production Engineer ACT! Production Optimization Team Attachment: Form 10-403 Application for Sundry Approvals CC: ACT! Production Team Leader (w/o attachment) E.~ "' '~ott Production and Wells Coordinato~', -/o attachment) F~: .... 2-54/Q-12 Well File & Files 06.10,'3~ .3 SENT BY: BP EXPLOIO, T I ON · ; 8-15- 0 ; 11' 23.~ ; !~ EXPLOR. END 1COTT-~ ALASKA OIL AND ()A§ GOISISEFIVATIOI~ C,O~MI~IO~ APPLICATION FOR SUNDRY APPROVAL I-l~~Pmgram I-]Opm~i=rk~ Rm-P. fl~BLmpenaedWel I--l~ BP ~t~ C~IMKa) inc. I. oca~n of well at r,l..fic~ ~' ~N~ 1775' ~, ~. ~. T12N. R16E At ~al ~4' ~L, 1780 W;~ S~. ~, TI~, RI~ T0tal dept~: measured 1;175 IsM true vePtlmd 10aOi lest ~.ffiatlv~ (3aptS.: mmiaiz, ee lP.137 t~Je vertical 10567 feet C)aain0 I..ngth Suff~ae ' ~660' 13-8/6' InTem~ble 0,4~6' Procll, lotlon t44~' I;I-5/8" L.In.r 1~1g' ._ tme~v.~tLcM . Tubing (rjr, omcla, aP',d rnauured ,qq:m) r-i Explora.iory I'"! Stmtlg mpl~ie · ,J~k ~)07 564 5200;~ 2/ 2 I ~. Datum ~-i-auari (DF= ! 7. Unit or l;ml~_ .ffjf Name '- 8. Well Number ._ e, Permit Numl~r 91-122 10. APl Ndm)er 50' 02~-22218 ;t 1. F'mld and Pool Enclicett Reid / Endicott PoM ORIG.'INAL Cemafltid ... MD TVD 20al cu ~ Permafrost Z~71 GU ft (:;iaaa '(3' 502 cuft ?, Otb WD p~gW ~'4-1/E, Y'& 'XN' Nip,lee ~ 11787' la. AtllonmenlA ,~ Oesoriptlon .un'lmary of Pr°lCxiMi 14. EsBiTmted clate lot commencing operation 1 B, T"I DltmlllCi ~Matlont pfo0rlrn [-J IK3q3 sketch tS. Stlt~lt 0f wlll ' Sen~ic,. W~er In, ii.on )rover 0onditlont ol Approval: Nodly Oomml.elon so mpmeerg,dlve may w~nM~ Plug intalgrity --- BOP Test ~on ol4ulranoe___._ -- ' . . oU~uee T ' ........ ~bmk In ~pmved Copy .?~iL~iNAL SIGNED BY Returned STATE OF ALASKA ALASI~,~ OIL AND GAS CONSERVATION COMMISSI~ ' ' - REPORT SUNDRY WELL OPE¼ATIONS __ 1. Operations performed: Operation shutdown Stimulate~ Plugging__ Perforate Pull tubing __ Alter casing __ Repair well __ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.ae, Alaska 99519-6612 4. Location of well at surface 2078' SNL, 2328' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic Service .. 6. Datum elevation (DF or KB) KBE =55.1 . Unit or Property name Duck Island Unit/Endicott 8. Well number 2-54/Q- 12 At top of productive interval 9. 828' SNL, 1523' WEL, Sec. 35, T12N, R16E At effective depth 10. 634' SNL, 1775' WEL, Sec 35, T12N, R16E At total depth 624' SNL, 1790' WEL, Sec. 35, T12N, R16E Permit number/approval number 91-122 (not required) APl number 50- 029-22218 feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12175 feet 10602' BKB feet 12137 feet 10567' BKB feet Plugs (measured) Junk (measured) XX Plug @ 10615' MD ORIGINAL Casing Structural Length Size Cemented Measured depth BKB True vertical depth BKB Conductor Surface Intermediate Production Liner Perforation depth: 76' 30" 131' 2680' 3-3/8" 2021 cu fl Permafrost 2735' 9428' 9-5/8" 9483' 1443' 9-5/8" 2371 cu ft Class G 9483'-10926' 1519' 7" 502cu ft Class G 10656'-12175' measured 11788'-11881'; 11894'-11940'(open) 11952'- 12062' (squeezed) true vertical 10195'-10279'; 10290'-10332' (open) 10343'- 10442' (squeezed) Tubing (size, grade, and measured depth) 7" 29#/ft L-809 tubing with 5-1/2" tailpipe to 10667' Packers and SSSV (type and measured depth) 9-5/8" Packer Big Bore w/Latch @ 10560' 131' 2679' 8237' 8237'-9443' 9213'-10547' 7" Otis WD Packer w/4-1/2" 'X' & 'XN' Nipples at 1~,1..737' 13. Stimulation or cement squeeze summary MIT 7/17/00; Set Plug 8/2/00; MIT 8/5/O0 Intervals treated (measured) Treatment description including volumes used and final pressure (see attached) 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 16649 0 2257 0 0 2500 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service W~tp.r Ini. P. ntr~r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,(~~~ -~, ~X.~~~~ Title.~ni~r T~chnical A~i-~tant IV Form 10-404 Rev 06/1 ~38 Date 8/7/~ ~ SUBMIT IN DUPLIC~ BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 7-17-00 WELL N-°: 2-54 / Q-12 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: MIT ROBERTSON LAWSON / APC DATE/TIME OPERATIONS SUMMARY ,. 0815 TUBING: 2180 IA: 2220 OA: 150 VOID: 0 INJECTION RATE: 2350 0820 PRESSURE TEST HOSE TO 4000# FOR PUMPING DOWN IA. 0830 PUMP DIESEL DOWN IA. 0845 PUMPED 1.2 BBLS OF DIESEL. WATCH FOR 30 MIN. 0845 TUBING: 2140 IA: 3000 OA: 350 VOID: 0 RATE: 2450 0900 TUBING: 2140 IA: 2920 OA: 380 VOID: 0 RATE: 2400 0915 TUBING: 2080 IA: 2800 OA: 380 VOID: 50 RATE: 2250 0930 TUBING: 2180 IA: 2660 OA: 340 VOID: 75 RATE: 2400 0945 TUBING: 2180 IA: 2600 OA: 350 VOID: 80 RATE: 2400 0950 STILL WAITING FOR FINAL SAY FROM STATE IF MIT PASSED. RD. MIT WAS WITNESSED BY STATE. SUMMARY: MIT IA FOR STATE TEST. IA HAD LOST ABOUT 8% IN 30 MIN. STILL WAITING ON STATE TO SAY IF IT IS A PASS OR NOT. SSSV: IN BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: WELL N-°: TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: 8-2-00 2 -54/Q 12 PULL ISSSV, SET 2 7/8 XXPLUG M. SAUVE HES / JORDAN DATE/TIME OPERATIONS SUMMARY FWHP:SI WHT:SI SIP:600 lAP:600 OAP:0 16:00 RU 17:00 PRESSURE TEST LUBRICATOR TO 3000# 18:00 RIH W/5 1/2 GS AND PRONG TO BVN @ 1524' WLM. 19:00 POOH W/MCX, SERIAL #NM-502 20:00 RIH W/2 7/8 XX PLUG (12" FILL EXT.)TO X NIPPLE @ 10615' WLM 21:00 SET PLUG. POOH 22:00 RDMO SUMMARY: PULLED ISSSV, SET 2 7/8 XX PLUG @ 10615'WLM SSSV: OUT ENDICOTT, ALASKA TO: MARK SUAVE FROM' M. NEWMAN- S. POWELL WELL NAME: 2-54 MAIN CATEGORY: I MAINT. SUB CATEGORY IMIT (AOGCC Jwitness) OPERATION DATE 18/6/00 DATE: 18/6/00 I OPERATION: MIT OF TUBING AND IA WITH AOGCC WITNESS, WELL SHUT-IN AND TUBING PLUG SET IN TAILPIPE. IA AND TUBING ARE BOTH FLUID PACKED INITIAL PRESSURES: WHP 700=PSIG, IAP 350=PSIG, OAP 0=PSIG. SUMMARY: Pumped up tubing to 2800 psi and watched IA slowly build up. Periodically pumped up tubing and fluid leak over to IA. When AI pressure reached -2200 psi switched over hard line to IA and pump it up to 2500 psig, observed tubing pressure rise with IA pressure up to 2500 psig. Both tubing an IA pressure held rock steady at 2500 psig for 30 minutes. Inner annulus passed MIT. AOGCC inspector Jeff Jones witnessed test. Final Pressures: SIWHP 2500=PSIG, IAP 2500=PSIG, OAP 0=PSIG. Fluid Summary: 11 bbls methanol. CONCLUSION: Production tubing has leak to IA. However, inner annulus has integrity. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Chairman THRU' Blair Wondzell P.I. Supervisor FROM: Jeff Jones~ Petroleum Inspector DATE: August 6, 2000 SUBJECT: Mechanical Integrity Tests BPX MPI 2-54/Q12 DUI Endicott NON~ CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. . WellI 2-541Q12 I Typelnj. I S I T.V.D. i 9992 ITu . I 50o 125001250o12500I lntervall V p.T.D.I 191_l??OITypetestI P ITestpsil 2498 I casin, I 360 I 25001 24901 24901 P/F I P Notes: Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunda_v, Auinlst 6, 2000: I traveled to BPX's Endicott Field, Duck Island Unit, Main Production Island to witness a standard pressure test on the inner annulus of well #2-54/Q12. On arrival at the location I met with Mark Sauve, the BPX representative in charge of the test, and discussed the status of the well and the test particulars while the field crew finished rigging up for the test. Mr. Sauve indicated that the purpose of the test was to obtain a variance for saltwater injection despite a known leak in the tubing string. He also indicated that he had been in contact with Tom Maunder, AOGCC engineer in charge of class II injection wells, regarding the variance. To facilitate the test a tubing tailpipe plug was set ~ 10615' MD in the 2 7/8" 'X' nipple reducer. The pre-test tubing and casing pressures were observed for 20 minutes and remained stable. The tubing was pressured up to 2700 psi and allowed to leak to the inner annulus, which was then pressured up until both the tubing and inner annulus pressures equalized at 2500 psi. The tubing and casing pressures were monitored for 30 minutes. I observed no change in the tubing pressure while the casing pressure dropped 10 psi to 2490 psi and stabilized, passing the pressure test. Summary: I witnessed a successful pressure test of the inner annulus of BPX's Endicott well # 2-54/Q12. Number of Failures: 0 Total Time during tests: .1.5 hrs .I.T.'s performed: ~_ - Attachments: Endicott well #2-541Q12 completion diaQram cc: Mark Sauve; Endicott production Coordinator MIT report form 5/12/00 L.G. 191-122254Q12mitpass080600JJ.xls 9/8/00 ~e: .Endico~ 2-54/Q-12 (PTD 191-122) Combinaion MIT Subject: Re: Endicott 2-541Q-12 (PTD 191-122) Combination MT Date: Fri, 04 Aug 2000 11:29:52 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "END, Production Coordinator" <ENDProductionCoordinator@BP.com> Mark, Got the information just fine. I look forward to the variance application. Thanks. Tom "END, Production Coordinator" wrote: > Tom, As per our earlier conversation this morning, here is a summary of the data we collected from well 2-54/Q-'12 yesterday. <<000803 2-54 MIT of tubing & IA. doc>> Please let me know if you cannot read the endosure for any reason. I have left a message on Troy Weiss's phone mail to call me back so that we can get you a variance request to continue injection ASAP. Mark Sauve Endicott Production & Wells Coordinator Ph: 907-659-6546 e-mail: sauvema@bp, com From: Tom Maunder[SMTP:tom_maunder@admin. state, ak. us] Sent: IVbnday, July 24, 2000 9:59 AM To: END, Production Coordinator Subject: Re: Endicott 2-54/Q-'12 (PTD '19'1-'122) Combination MIT <<File: torn_maunder, vcf> > Anna, Thanks for the information regarding your plans. In the interim, since the integrity is suspect please begin recording the daily tubing, IA and OA pressures and the injection rate. This information should be reported to us monthly as is being done for 5-02/SD-'10. If ~ou have any questions, please call. Tom Maunder "END, Production Coordinator" wrote: > Tom, > This is to confirm our plans to set a plug in the tubing tail and > combination MIT test well 2-54/Q-'12. The purpose of this is to test the > integrity of the casing. We plan to run this test in the relative short > term. Although this test is not required to be witnessed by the state, we > will notify the inspector in advance of when we plan to test the well. 8/4/00 11:30 AM 1 of 2 ENDICOTT, ALASKA TO: MARK SUAVE FROM: M. NEWMAN- S. POWELL WELL NAME: 2-54 MAIN CATEGORY: MAINT. SUB CATEGORY MIT OPERATION DATE 8/03100 DATE: 18103100 I OPERATION: MIT OF TUBING AND IA, WELL SHUT-IN AND TUBING PLUG SET IN TAILPIPE. IA AND TUBING ARE BOTH FLUID PACKED INITIAL PRESSURES: WHP 700=PSIG, IAP 550=PSIG, OAP 0=PSIG. SUMMARY: Pumped up IA to 2500 psig and observed it bleed off to 1850 psig in 17 minutes. Switched over hard line to tubing and pump it up to 2500 psig, observed IA pressure rise with tubing pressure up to 2050 psig. Switched back hard line to IA and pumped up to 2500 psig. Both tubing an IA pressure held rock steady at 2500 psig for 30 minutes. Final Pressures: SIWHP 2500=PSIG, IAP 2500=PSIG, OAP 0=PSIG. Fluid Summary: 11 bbls diesel, 5 bbls methanol. CONCLUSION: Production tubing has leak to IA. However, inner annulus has integrity. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 1,2000 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Daily Annulus Pressure Report for 2-54/Q-12 Dear Mr. Wondzell, Attached in duplicate is the daily inner and outer annular pressure data for the month of July 2000 from 2-54/Q-12 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, Madelyn A. Millholland Sr. Technical Assistant MAM Enclosure cc: File: 76.13 ANNULUS PRESSURE REPORT FOR ENDICOTT WATER INJECTION WELL 2-54/Q-12 REPORT PER AOGCC VARIANCE Note: Well has confirmed leak. Well can remain on injection under variance. The data below must be recorded daily and sent to the AOGCC on a monthly basis. DATE 7/1/2000 7/2/2000 7/3~2000 7/4~2000 7/5/2000 7/6/2000 7/7/2000 7/8/2000 7/9/2000 7/10/2000 7/11/2000 7/12/2000 7/13/20OO 7/14/2000 7/15/2000 7/16/2000 7/17/2000 7/18/2000 7/19/2000 7/20/2000 7/21/2000 7/22/2000 7/23/2000 7/24/2000 7/25/2000 7/26/2000 7/27/2000 7/28/2000 7/29/2000 :7/30/2000 7/31/2000 IA (9-5/8) ps)A (13-3/8) p,' WHP (psi) njection Rate (MBD WHT (F) Note 2200 200 2190 17246 154.6 2200 200 2235 18256 152 NOTES: (use this section to recorde significant events such as loss of SW etc) Page 1 MEMORANDUM TO: Dan Seamount Commissioner THRU' Blair Wondzell P.I. Supervisor FROM: John Crisp:/~4~.~ Petroleum ltispector State of Alaska Alaska Oil and Gas Conservation Commission SUBJECT: Mechanical Integrity Tests BPX Endicott MPI MPI 2-54 / Q-12 Duck Island unit Endicott Field - DIU NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI MPI2-54 I Typelnj. I $ IT-V'D' I 9120 IT"bingl 21S01 2~001 2~001 2~00 I lntervall 4 P'T'D'I 191-122 ITypetesq P ITestpsil 3000 I Casingl 22201 30001 29201 28001 P/F I F Notes: Pressure on IA after 45 min. 2660 psi. - after 1 hr. 2600 psi. Notes: Well P.T.D. Notes: P.T.D. Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER IN J, G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P: Standard Pressure Test R= Internal Radioactive Tracer Survey A-- Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4- Four Year Cycle V= Required by Variance W= Test during Work°ver O= Other (describe in notes) Test's Details This well had tbg. leak that was repaired w/tbg, patch. Well was tested for 1 hr. to monitor continued pressure drop. Dan Robertson ~ 659 6544 was BP rep. performing MIT. 1 Number of Failures: 1_ Total Time during tests: 1 hour .I.T.'s perfOrmed: _ Attatchments: none cc: MIT report form 5/12/00 L.G. MIT DIU 2-54 7-17-00jc 7/18/00 IJ.I ~~_~~ Memory Multi-Finger Caliper ~i~,~ Log Results Summary Company: BP Exploration (Alaska) Inc. Well: 2-54 / Q-12 Log Date: February 25, 2000 Field: Endicott Log No.: 1043 State: Alaska Run No.: 1 APl No.: 50-029-22218-00 Pipe Desc.: 5.5" 17 lb. NSCC Top Log Intvl: Surface Pipe Use: Tubing Bot. Log Intvl: 10,661 Ft. (MD) Inspection Type' Corrosive Damage Inspection COMMENTS ' 0 R ! G! h! A L This survey was run to assess the condition of the tubing with respect to corrosive damages. The condition of the tubing ranges from fair to poor, with penetrations ranging from 40% to 60% wall thickness recorded in a majodty of the joints logged. Penetrations in excess of 20% wall are recorded in over 90% of the joints logged. The damage is recorded in the form of a Line or Corrosion extending from the bottom of the stdng up to approximately 4,250 ff., where the recorded penetrations begin to disperse into Isolated Pits up to the top of the tubing string. No significant cross-sectional wall loss or tubing restrictions are recorded throughout the logged interval. The distribution of the wall penetration damage recorded throughout the logged interval is illustrated in the Body Damage Profile page of this report. MAXIMUM RECORDED WALL PENETRATIONS · Isolated Pitting (64%) Jt. 105 @ 4,227' MD Line Corrosion (61%) Jt. 104 @ 4,179' MD Isolated Pitting (60%) RE,CE I VED Isolated Pitting (60%) Jt. 83 (~ 3,330' MD Isolated Pitting (59%) Jt. 87 ~ 3,497' MD ~AR 08 ~000 MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · qaska Oil & Gas Cons. CommissiOl Anchorage No areas of significant cross-sectional wall-loss (in excess of 5%) were recorded throughout the interval logged. J Field Engineer' R. Richey MAXIMUM RECORDED ID RESTRICTIONS · No areas of significant ID restriction (in excess of 0.05 in.) were recorded throughout the interval logged. ~ ..... f'i ;~ ~i~" ~'~' ' , ', t' ' ~ ~'. / '~ ,' ~.-.~;; .,, "~' i .., gate / / Witness:~ave Ceru~i Analyst: J. Burton J Well: 2-54/Q-12 Field: EN DICO'FF Company: BP EXPLORATION ALASKA INC. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: Feb. 25, 2000 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 Anah/sed: J. Burton Tubing: Size Weight Grade & Thread 5.5 ins 1 7 ppf L-80 NSCC Nom. OD Nom.iD Nom. Upset 5.5 ins 4.892 ins 5.5 ins Penetration and t~elal Loss (% wall) penetration body : metal loss body 2OO 15O 100 5O 0 0to 1 to 10to 20 to 40 to above 1% 10% 20% 400/o 85% 85% Number of joints analysed (total = 2 79) Pene 2 20 23 75 159 0 Loss 80 198 1 0 0 0 , , Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 257) 89 4 163 1 0 Damage Profile (% wall) penetration body ...... metal loss body 0 5O 100 ....... ~ ,~_~ ?~' ~ - GLM 2 GLM 1 Bottom of Survey = 267 Analysis Overview page 2 RE CEIVED MAR 08 ;!000 Alaska Oil & Gas Conu. ~;ommission Anchorage PDS CA .JER JOINT TABULATION r Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 2-54/Q-12 ENDICOTT BP EXPLORATION ALASKA INC. ~ penetration body USA metal loss body Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches 3 50 10 .1 0 .01 5 1 0 0 4.86 1 0 .10 32 2 0 0 4.86 Isolated pitting. '-'-- 2 0 .10 35 2 0 0 4.86 Isolated pitting. 3 0 .01 2 1 0 0 4.86 4 0 .08 27 1 0 0 4.85 Isolated pitting. -' ~'~ 5 0 .07 22 1 0 0 4.85 Isolated pitting. '~' 6 0 .05 18 1 0 0 4.87 Shallow pitting. ......... 7 0 .09 31 1 0 0 4.86 Isolated pitting. ':'~ 8 0 .09 29 1 0 0 4.87 Isolated pitting. ' ...... ' 9 0 .10 34. 1 0 0 4.85 Isolated pitting. "~'"' "' 10 0 .05 17 1 0 0 4.86 Shallow pitting. ' ....... 11 0 .04 12 1 0 0 4.85 Shallow pitting. 12 0 .03 9 1 0 0 4.84 ... 13 0 .11 37 2 0 0 4.86 Isolated pitting. 14 0 .08 27 1 0 0 4..86 Isolated pitting. 15 0 .09 31 1 0 0 4.84 Isolated pitting. 16 0 .12 38 2 0 0 4.86 Isolated pitting. 17 0 .07 23' 1 0 0 4.87 Isolated pitting. 18 0 .09 30 1 0 0 4.86 Isolated pitting. ~'~ ..... 19 0 .07 24' 1 0 0 4.86 Isolated pitting. ~'": 20 0 .05 17 1 0 0 4.85 Shallow pitting. 21 0 .03 11 1 0 0 4.86 Shallow pitting. ','~' 22 0 .01 2 1 0 0 4.86 23 0 .18 60 2 0 0 4.87 Isolated pitting. 24 0 .12 41 2 0 0 4.87 Isolated pitting. "~' ~'~ '~'~ . 2.5 0 .02 7 1 0 0 4.86 .... 26 0 .00 1 1 0 0 4.86 27 0 .01 2 1 0 0 4.86 28 0 .15 50 2 0 0 4.83 Isolated pitting. :~'~ ::'~ ;~'. '~ ...... ' 29 0 .17 55 3 0 0.. 4.87 Isolated pitting. 30 0 .05 16 1 0 0 4.86 Shallow pitting. 31 0 .03 8 I 0 0 4.86 32 0 .17 57 2 0 0 4.86 Isolated pitting. 33 0 .03 9 1 0 0 4.87 34 0 .08 25 1 0 0 4.86 Isolated pitting. 35 0 .02 8 1 0 0 4.87 36 0 .03 8 1 0 0 4.85 '~ 3 7 0 .02 8 1 0 0 4.85 38 0 .07 24 2 0 0 4.85 Isolated pitting. 38.1 0 0 0 0 0 0 4.83 X-OVER 38.2. i 0 .01 5 1 0 0 4.83 PUP 38.3 0 0 C 0 0 0 4.84 SSV ,, 38.4 0 .06 21 12 0 0 4.84 PUP '~!? '~' 38.5 0 0 O 0 0 0 4.86 X-OVER 39 0 .09 29 1 0 0 4.86 Isolated pitting. 40 0 .14 46 3 0 0 4.86 Isolated pitting. 41 0 .06 19 1 0 0 4.87 Shallow pitting. 42 0 .05 15 1 0 .04 4.83 Shallow pitting. 43 0 .13 41 2 0 0 4.85 Isolated pitting. "~' ~:" 44 0 .12 38 2 0 0 4.87 Line corrosion. ,r'- ,,?~ ,~,, Pipe Tabulations page 1 RECEIVED MAR 082000 Alaska 011 & Gas Cons. Commission Anchorage PDS CA-.. ER JOINT TABULATION Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 2-54/Q-12 EN DICO-I-I- BP EXPLORATION ALASKA INC. ~ penetration body USA .... metal loss body Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches 3 50 1 45 0 .11 37 1 0 0 4.85 Isolated pitting. 46 0 .08 28 1 0 0 4.86 Isolated pitting. '-" 47 0 .08 26 1 0 0 4.85 Isolated pitting. ' ...... 48 0 .08 2 7: 1 0 .04 4.86 Isolated pitting. '"- ..... 49 0 .08 27 1 0 0 4.87 Isolated pitting. 50 0 .07 24 1 0 0 4.85 Isolated pitting. 51 0 .17 56 3 0 0 4.86 Isolated pitting. 52 0 .05 18: 1 0 0 4.86 Shallow pitting. .,53 0 .12 40 2 0 0 4.87 Line corrosion. 54 0 .11 35 1 0 0 4.85 Isolated pitting. ' 55 0 .09 28 2 0 0 4.86 Isolated pitting. 56 0 .08 26 1 0 0 4.87 Isolated pitting. 57 0 .04 13 1 0 0 4.85 Shallow pitting. ' 58 0 .16 54 2 0 0 4.85 Isolated pitting. '"~ .... ;'~ i ........ 59 0 .04 13 1 0 0 4.86 Shallow pitting. 60 0 .08 28 2 0 0 4.86 Isolated pitting. ~' 61 0 .04 12 1 0 0 4.86 Shallow pitting. '."~" 62 0 .07 23 1 0 0 4.87 Isolated pitting. '~" '": 63 0 .12 40 1 0 .03 4.83 Isolated pitting. ~I....... :':':" 64 0 .09 31 1 0 0 4.87 Isolated pitting. .... 65 0 .11 37 1 0 0 4,.86 Isolated pitting. '"'" ':": ..... 66 0 .02 8 1 0 0 4..86 67 0 .04 12 1 0 0 4.86 Shallow pi'tting. 68 0 .04 13 1 0 .04 4.84 Shallow pitting. 69 0 .05 16 1 0 0 4.86 Shallow pitting. :'~' ,, ,70 0 .09 28 3 0 0 4.84 Isolated pitting. '::'"~' ............ 71 0 .04 13 1 0 0 4.85 Shallow pitting. 72 0 .08 27 1 0 .03 4.83 Isolated pitting. ' ~" 73 0 .14 45 2 0 0 4.86 Line corrosion. ~" ':?' " 74 0 .03 11 1 0 0 4.85 Shallow pitting. , , 75 0 .14 47 2 0 0 4.85 Isolated pitting. ::~'" 76 0 .08 27 1 0 0 4.85 Isolated pitting. 77 0 .05 16 1 0 0 4.88 Shallow pitting. 78 0 .07 24 1 0 0 4.87 Line corrosion. ~':~:"'~: 79 0 .13 43 2 0 0 ,, 4.86 Isolated pitting. ~'~' ':'~ ~!~::' "~ 80 0 .08 28 1 0 0 4.86 Isolated pitting. ?''"' '~ 81 0 .15 49 2 0 0 4.85 Isolated pitting. '~' 82 0 .03 9 1 0 0 4.86 83 0 ,.18 60 3 0 0 4.87 Isolated pitting. 84 0 .17 57 2 0 ,0 4.84 Isolated pitting. 85 0 .12 41 1 0 0 4.84, Isolated pitting. '~'""? ~"~""~'~' 86 0 .04 14 1 0 0 4.84 Shallow pitting. 87 0 .18 59 3 0 0 4.85 Isolated pitting. 88 0 .03 11 1 0 0 4.86 Shallow pitting. '~ 89 0 .14 45 2 0 0 4.86 Isolated pitting. ?'"' ?~?,i ...... 90 0 .04 12 1 0 0 4.86 Shallow pitting. '"'!' 91 0 .08 26 1 0 0 4.86 Isolated pitting. 92 0 .15 48 2 0 0 4.86 Isolated pitting. '~,' ?I~' ~''~' 93 0 .17 58 3 0 .03 4.87 Isolated pitting. ~'~? :'!:'~ 94 0 .17 57 3 0 .01 4.87 Isolated pitting. Pipe Tabulations page 2 RECEIVED MAR 0 8 2000 Alaska Oil & Gas Cons. (.;ommission Anchorage -. PDS CA _., ER JOINT TABULATION SH,__.I- Pipe: 5.5 ins 17 ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 2-54/Q-12 ENDICOTI- BP EXPLORATION ALASKA INC. ~ penetration body USA .... metal loss body Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches 3 50 10 95 0 .17 58 3 0 0 4.86 Isolated pitting. 96 0 .17 54 3 0 0 4.86 Isolated pitting. 97 0 .17 55 3 0 0 4.83 Line corrosion. 97.1 0 0 0 0 0 0 4.85 X-OVER 97.2 0 .01 3 1 0 0 4.85 PUP 97.3 0 0 0 0 0 0 4.87 GLM 2 (Latch @ 3:00) 97.4 0 .01 2 1 0 0 4.87 PUP 97.5 0 0 0 0 0 0 4.86 ×-OVER 98 0 .15 49 3 0 0 4.86 Isolated pitting. '" .......... "'''~ 99 0 .16 52 2 0 0 4.87 Isolated pitting. 100 0 .16 53 3 0 0 4.85 Isolated pitting. 101 0 .18 58 3 0 0 4.86 Isolated pitting. ' 102 0 .16 54 3 0 0 4.86 Line corrosion. '~' 103 0 .14 46 2 0 .04 4.84 Line corrosion. 104 0 .19 61 3 0 .03 4.85 Line corrosion. 105 0 .20 64 3 0 0 4.86 Isolated pitting. 106 0 .17 55 3 0 0 4.86 Line corrosion. 107 0 .15 50 3 0 0 4.85 Line corrosion. ~' 108 0 .18 58 3 0 .03 4.85 Line corrosion. 109 0 .16 53 2 0 0 4.84 Line corrosion. I~" 110 0 .16 51 3 0 0 4.86 Line corrosion. 111 0 .16 ,. 53 3 0 0 4.86 Line corrosion. 112 0 .13 44 2 0 0 4.86 Line corrosion. 113 0 .13 43 2 0 0 4.86 Line corrosion. 114 0 .14 44 3 0 0 4.86 Line corrosion. 115 0 .13 42 3 0 0 4.87 Line corrosion. , 116 0 .14 45 3 0 0 4.85 Line corrosion. 11 7 0 .12 41 2 0 .02 4.85 Line corrosion. 118 0 .11 35 2 0 0 4.85 Line corrosion. ~,;'.'r'7' ?~i'f 119 0 .11 37 2 0 0 4.87 Line corrosion. 120 0 .14 47 2 0 0 4.85 Line corrosion. 121 0 .14 47 2 0 0 4.85 Line corrosion. ' ' ' 'i"2'2 0 .14 47 3 0 0 4.86 Line corrosion. '"'?' 123 0 .14 44 2 0 0 4.86 Line corrosion. "~";;:"~:~': ?'"?"' 124 0 .12 41 2 0 0 4.85 Line corrosion. '?'"'~ ?!~: '~r 125 0 .14 44 3 0 0 4.87 Line corrosion. 126 0 .16 52 3 0 0 4.85 Line corrosion. :'~.:~ ! 2 7 0 .14 46 3 0 0 4.86 Line corrosion. '""~ "~ 128 0 .13 43 2 0 0 4.87 Line corrosion. 129 0 .12 39 2 0 0 4.85 Line corrosion. 130 0 .13 41 2 0 0 4.87 Line corrosion. 131 0 .12 38 2 0 0 4..87 Line corrosion. '~~'"?~'~ 132 0 .15 49 2 0 0 4.86 Line corrosion. ! 33 0 .14 46 2 0 0 4.87 Line corrosion. ~'~'."I'~? "~ r.? 134 0 .13 43 2 0 0 4.86 Line corrosion. 135 0 .13 42 2 .04 0 4.87 Line corrosion. 136 0 .11 36 2 0 0 4.87 Line corrosion. ""'" ':~'' 137 0 .13 42 3 0 0 4.87 Line corrosion. ~'~ 138 0 .13 41 3 0 0 4.85 Line corrosion. ~'"' '''~ ?'I~'~' 139 0 .13 44 2 0 0 4.86 Line corrosion. Pipe Tabulations page 3 RECEIVED MAR 0 8 2000 Alaska Oil & Gas Cons. Commission Anchorage PDS CAL,/ER JOINT TABULATION SHL,_ I- Pipe: 5.5 ins 17 ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 2-54/Q-12 ENDICOTT BP EXPLORATION ALASKA INC. ~ penetration body USA metal loss body Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (%wall) inches inches % % inches inches inches 3 50 1 140 0 .14 45 2 0 0 4.86 Line corrosion. 141 0 .13 43 2 0 0 4.85 Line corrosion. 142 0 .14 47 2 0 0 4.87 Line corrosion. 143 0 .13 42 2 0 0 4.87 Line corrosion. 144 0 .12 40 2 0 0 4.85 Line corrosion. 145 0 .14 45 2 0 0 4.86 Line corrosion. 146 0 .15 49 2 0 0 4.87 Line corrosion. 147 0 .14 45 2 0 0 4.85 Line corrosion. 148 0 .14 47 3 0 0 4.87 Line corrosion. ~ .... ~" ?":'""~ 149 0 .15 50 2 0 0 4.86 Line corrosion. '::" ~:' ~"? ...... 150 0 .17 55 2 0 0 4.85 Line corrosion. 151 0 ,12 41 2 0 .02 4.80 Line corrosion. 152 0 .14 45 2 0 0 4.85 Line corrosion. ' .... ? ~"'! 153 0 .11 36 2 0 .03 4.83 General corrosion. 154 0 .12 39 2 0 .03 4.84 General corrosion. = ........ ~ .... 155 0 .14 45 2 0 0 4.85 Line corrosion. 156 0 .10 32 2 0 0 4.87 Line corrosion. 157 0 .14 48 2 0 0 4.84 Line corrosion. 158 0 .14 46 2 0 0 4.86 Line corrosion. ~" ,,1,59 0 .14 45 2 0 0 4.85 Line corrosion. '": ,, 160 0 .12 39 2 0 .04. 4..85 Line corrosion. ':~:' ....... ':' 161 0 .12 4.0 2 0 .02 4.84 General corrosion. 162 0 .11 37 2 0 0 4.87 Line corrosion. 163 0 .14 45 2 0 .04. 4.87 Line corrosion. 164 0 .13 43 2 0 0 4.85 Line corrosion. 165 0 .12 39 2 0 0 4.86 Line corrosion. 166 0 .12 4.0 2 0 .03, 4.85 Line corrosion. '"~ '~"' 167 0 .12 38 2 0 0 4.86 Line corrosion. ~";~' 168 0 .13 41 2 0 0 4.86 Line corrosion. 169 0 .14 4.6 3 0 .03 4.84 Line corrosion. ,, 170 0 .18 59 2 0 '0 4.85 Line corrosion. 171 0 .15 49 2 0 0 4.85 Line corrosion. 172 0 .14 47 2 0 0 4.85 Line corrosion. "'~ I':!? 'I~ ?'~: 1 73 0 .12 39 2 0 0 4.86 Line corrosion. 174 0 .14 46 3 0 0 4.86 Line corrosion. 175 0 .16 51 2 0 0 4.85 Line corrosion. 176 0 .15 48. 2 0 0 4.86 Line corrosion. 177 0 .14 46 2 0 .04 4.85 Line corrosion. , 178 0 .14 45 2 0 0 4.86 Line corrosion. ~'~' 179 0 .13 43 2 0 0 4.87 Line corrosion. ~','," 180 0 .16 51 2 0 .04 4.86 Line corrosion. 181 0 .14 4.5 2 0 .04 4.86 Line corrosion. 182 0 .14 46 2 0 0 4.87 Line corrosion. ~' 183 0 .16 54 3 0 .03 4.82 Line corrosion. ~,~,~ ,?-,;,:? ~,, r,.~, ~ 184 0 .14 45 2 0 0 4.85 Line corrosion, ~' 185 0 .12 39 2 0 0 4.86 Line corrosion. 186 0 .12 38 2 0 0 4.86 Line corrosion. ',' 187 0 .10 34 1 0 .03 4.85 Line corrosion. 188 0 .12 39 2 0 0 4.86 Line corrosion. "'"'"~' 189 0 .10 33 2 0 .04 4.86 Line corrosion. Pipe Tabulations pa§e 4 RECEIVED MAR 0 8 .000 Alaska Oil & Gas Cons. Commission Anchorage PDS CA ..,;ER JOINT TABULATION SH _ 1- Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Well: Field: Company: Country: Date: 2-54/Q-12 ENDICOTT BP EXPLORATION ALASKA INC. ~ penetration body USA metal loss body Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches O 50 10 190 0 .17 55 3 0 0 4.86 !Line corrosion. 191 0 .13 42 2 0 .03 4.85 Line corrosion. 192 0 .15 50 2 0 0 4.86 Line corrosion. 193 0 .10 33; 1 0 0 4.86 Line corrosion. 194 0 .14 47 3 0 0 4.86 Line corrosion. 195 0 .11 35 1 0 .03 4.85 Line corrosion. - 196 0 .11 38 2 0 0 4.84 Line corrosion. 197 0 .14 46 2 0 0 4.86 Line corrosion. 198 0 .14 47 2 0 0 4.86 Line corrosion. 199 0 .12 41 2 0 0 4.86 Line corrosion. ' 200 0 .12 39 2 0 .03 4.86 Line corrosion. ,2,01 0 .13 41 2 0 .02 4,.85 Line corrosion. ' 202 0 .12 40 2 0 0 4.86 Line corrosion. ""'~? 1~"'~' 203 0 .10 34 2 0 0 4.86 Line corrosion. 204 0 .12 38 2 0 0 4.85 Line corrosion. 205 0 .12 40 3 0 .04 4.85 Line corrosion. ~'~' ?..17. -?.:~ ,206 0 .13 41 2 0 .04 4.86 Line corrosion. '~'~ 207 0 .12 41 2 0 .03 4.86 Line corrosion. 208 0 .12 39 2 0 0 4.84 Line corrosion. ,209 0 .12 38 2 0 .03 4.85 Line corrosion. 210 0 .13 44 3 0 0 4..87 Line corrosion. ?"'?' "'? ~?' 211 0 .13 43 3 0 0 4.85 Line corrosion. ~' ,,212 0 .11 36 2 0 0 4.85 Line corrosion. 213 0 .12 38 2 0 0 4.85 Line corrosion. :"~'~" '~'" 214 0 .12 40 2 0 0 4.86 Line corrosion. ~'~ ~ "~' ':": ..2.! 5 0 .15 50 1 0 0 4.85 Line corrosion. ~''~:~' 216 0 .13 43 2 0 0 4.85 Line corrosion. 217 0 .12 39 2 0 0 4.84 Line corrosion. 218 0 .14 47 2 0 0 4.86 Line corrosion. 21. 9 0 .13 42 2 0 0 4.85 Line corrosion. 220 0 .14 48 3 0 0 4.85 Line corrosion. ,, 221 0 .14 45 2 0 0 4.85 Line corrosion. ,,222 0 .14 45 2 0 .04 4.87 Line corrosion. 223 0 .16 51 3 0 0 4.83 Line corrosion. "~' 224 0 .13 41 2 0 0 4.85 Line corrosion. 225 0 .14 45 2 0 .04 4.83 Line, corrosion. 226 0 .14 47 3 0 .03 4.85 Line corrosion. 227 0 .14 47 2 0 .04 4.86 Line corrosion. 228 0 .15 49 2 0 .04 4.84 Line corrosion. 229 0 .15 49 2 0 0 4.85 Line corrosion. 230 0 .15 48 2 0 0 4.83 Line corrosion. :~? '~'~:' '~?l~t 231 0 .18 58 3 0 .04 4.85 Line corrosion. 232 0 .16 53 2 0 .03 4.84 Line corrosion. 233 0 .1 7 57 2 0 0 4.85 Line corrosion. '~"' 234 0 .15 49 2 0 .04 4.84 Line corrosion. '~ 235 0 .16 51 2 0 .05 4.86 Line corrosion. 236 0 .14 48 2 0 .04! 4.83 Line corrosion. 237 0 .14 45 2 .03 .04 4.85 Line corrosion. 238 0 .16 51 3 0 .04 4.83 Line corrosion. !'~: ?'~':' ~"'~? 239 0 .14 47 2 0 .03 4.85 Line cor.rosion. '~' ......... "? '"~ Pipe Tabulations page 5 RE,CEIVED MAR 0 8 2000 Alaska Oil & Gas 6:.ms. vulu:nlsslo~ Anchorage PDS CA'L.,'ER JOINT TABULATION SHL._ I- Pipe: 5.5 ins 17 ppf L-80 N SCC Well: 2-54/Q-12 Wall thickness. Body: 0.304ins Upset = 0.304ins Field: ENDICOTr Nominal ID: 4.892 ins Company: BP EXPLORATION ALASKA INC. ~ .m~.. penetration body Country: USA metal loss body Date: Feb. 25, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (% wall) inches inches % % inches inches inches O 50 1C 240 0 .14 47 2 0 .03~ 4.84 Line corrosion. , .I -j· 241 0 .15 49 2 0 .04 4.84 Line corrosion. 242 0 .14 47 2 0 .03 4.84 Line corrosion. '~' ...... 243 0 .17 56 2 0 .04 4.83 Line corrosion. -"-'........ ", 244 0 .16 52 3 0 0 4.83 i Line corrosion. 245 . 0 .16 53 2 0 .03 4.81 ; Line corrosion. '~' ?"? ~' - 246 0 .13 43 2 0 .04 4.83 Line corrosion. 247 0 .14 4.8 2 0 .03 4.83 Line corrosion. :~' 248 0 .14 46 3 0 0 4.83 . Line corrosion.. 249 0 .15 48 3 0 .04 4.83 'Line corrosion. 250 0 .14. 46 2 0 0 4.84 Line corrosion. ~""? " " ,,.251 0 .15 50 2 0 .04 4.84 Line corrosion. 252 0 .14 47 2 0 .03 4.84 Line corrosion. 253 0 .14 46 3 0 .04 4.84 Line corrosion. "~" 254 0 .14 47: 2 0 0 4.84 Line corrosion. ~?"'~"' "'::' 255 0 .14 47 2 0 0 4.83 Line corrosion. 256 0 .16 52 2 0 .03 4..83 Line corrosion. :? ~!:?'?""'~ ...... 257 0 .13 41 2 0 0 4.83 Isolated pitting. "?~' 258 0 .16 52 3 0 .03 4.85 Line corrosion. 259 0 .13 42 2 0 0 4.84 Line corrosion. '"" 260 0 .15 49 2 0 0 4.84 Line corrosion. '~*" ~'~': ~'~ ~'~l"~' ,,261 0 .17 55 2 0 0 4.83 Isolated pitting., 262 0 .13 43 2 0 .03 4.84 Line corrosion. 263 0 .13 42 2 0 .03 4.85 Isolated pitting. 264 0 .1 7 57 3 0 0 4..84 Line.corrosion. 265 0 .14. 46 2 0 0 4.76 Line corrosion. 265.1 0 .02 5 1 0 0 4.87 PUP 265.2 0 0 0 0 0 0 4.87 GLM 1 (Latch @ 2:00) 265.3 0 .03 9 1 0 0 4.87 PUP ':'",' 265.4 0 .17 55 1 0 0 4.84 PUP General corrosion. '?. ~'. ..2..65.5 0 0 0 0 0 0 4.81 X-Nipple 265.6 0 .03 11 1 0 .04 4.81 PUP Shallow pitting. 265.7 0 0 0 0 0 0 4.87 PACKER 265.8 0 .03 11 1 0 0 4.87 PUP Shallow pitting. , 266 0 .17 58 1 0 .02 4.82 Line corrosion. J266.1 0 0 0 0 0 0 4~84 X-Nipple 266.2 0 .02 7 3 0 .03 4.84. PUP '~:~ 266.3 0 0 0 0 0 0 4.86 XN-Nipple 266.4 0 .01 3 1 0 0 4.86 PUP r 267 0 0 c 0 0 0 0 Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 1.250 feet. Pipe Tabulations page 6 RE,CEIVED MAR 0 8 2000 Alaska Oil & G~s Cons. Commission Anchorage PDS(' ..ALIPER JOINT TALLY SHEET Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Joint Depth Length Measured Type No. ID feet feet inches .1 40.41 4.45 4.885 PUp 1 44.86 39.46 4.901 2 84.32 39.73 4.902 3 124.05 38.54 4.902 4 162.59 39.40 4.902 5 201.99 39.27 4.900 6 241.26 39.28 4.906 7 280.54 39.1 7 4.900 8 319.71 38.19 4.911 9 357.90 39.09 4.906 10 396.99 39.01 4.905 11 436.00 38.54 4.91 7 12 474.54 41.15 4.907 13 515.69 39.1 7 4.90,1 14 554.86 39.23 4.902 15 594.09 39.06 4.900 16 633.15 38.68 4.901 1 7 671.83 39.25 4.906 18 711.08 39.40 4.902 19 750.48 39.39 4.905 20 789.87 40.74 4.907 21 830.61 39.19 4.902 22 869.80 39.77 4.901 23 909.57 39.77 4.901 24 949.34 39.30 4.907 25 988.64 39.74 4.908 26 t028.38 36.08, 4.907 27 1064.46 39.53 4.905 28 1103.99 39.66 4.902 29 1143.65 39.72 4.902 30 1183.37 39.26 4.904 31 1222.63 39.94 4.903 32 1262.57 39.70 4.906 33 1302.27 39.74 4.907 34 1342.01 39.04 4.913 35 1381.05 38.99 4.910 36 1420.04 39.37 4.912 37 1459.41 39.00 4.910 38 1498.41 41.55 4.902 38.1 1539.96 2.10 nominal X-orr 38.2 1542.06 10.53 4.916 Pup 38.3] 1552.59 14.43 nominal Ssv 38.41 1567.02 10.48 4.887 Pup 38.5 1577.50 2.44 nominal X-ovr 39 1579.94 39.63 4.903 40 1619.57 39.60 4.902 41 1659.17 39.04 4.902 42 1698.21 37.43 4.914 43 1735.64 41.56 4.910 44 1777.20 38.32 4.913 Well: 2-54/Q-12 Field: ENDICOTT Company: BP EXPLORATION ALASKA INC. Country: USA Date: Feb. 25, 2000 Joint Depth Length Measured Type No. ID feet feet inches 45 1815.52 39.64 4.910 46 1855.16 38.87 4.909 47 1894.03 39.04 4.902 48 1933.07 39.56 4.907 49 1972.63 37.22 4.913 50 2009.85 39.08 4.904 51 2048.93 39.06 4.910 52 2087.99 39.61 4.901 53 2127.60 38.74 4.913 54 2166.34 40.02 4.907 55 2206.36 39.32 4.906 56 2245.68 38.35 4.907 57 2284.03 38.62 4.907 58 2322.65 39.50 4.902 59 2362.15 39.49 4.902 60 2401.64 40.02 4.910 61 2441.66 39.59 4.906 62 2481.25 40.06 4.909 63 2521.31 38.70 4.902 64 2560.01 40.17 4.90,5 65 2600.18 3.6.84 4.913 66 2637.02 39.67 4.906 67 2676.69 39.90 4.905" 68 2 716.59 39.42 4.907 69 2,756.01 39.19 4.907 70 2 795.20 39.,71 4.910 71 2834.91 39.72 4.906 72 2874.63' 40.37 4.903 73 2915.00 38.1,0 4.904 74 2953.10 40.61 4.913 75 2993.71 40.37 4.906 76 3034.08 39.52 4.901 77 3073.60 39.65 4.913 78 3113.25 39..47 4.90'8. 79 3152.72 39.30 4.902 80 3192.02. 3.9.57 4.908 81 3231.59 39.62 4.912 82 32 71.21 39.80 4.906 83 3311.01 39.34 4.911 84 3350.35. 39.31. 4.907 85 3389.66 40.13 4.90'7 .... 8.6 .. 3429.79 39.58 4.907 87 3469.37 39.72 4.907 88 3509.09 39.36 4.908 89 3548.45 39.45 4.906 90 3587.90 39.53 4.906 ,~ , 91 3627.43 39.72 4.903, 92 3667.15 39.43 4.905 93 3706.58 3 7.84 4.908 94 3 744.42 36.44 4.912 Joint Tally pa~e 1 RE.CEIVED MAR O8 Alaska Oil & Gas Cons. Commission Anchorage PDS( ,..ALIPER JOINT TALLY SHEETi( Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset = 0.304ins Nominal ID: 4.892 ins Joint Depth Length Measured Type No. ID feet feet inches 95 3780.86 39.87 4,907 96 3820,73 39.70 4.904 97 3860.43 39.28 4,900 97.1 3899.71 2.66 nominal X-ovr 97.2 3902.3 7 10,22 4.902 Pup 97.3 3912.59 9.44 nominal GIm2 97.4 3922.03 8,64 4.902 Pup 97.5 3930.67 3.13 nominal X-ovr 98 3933.80 40.44 4.903 99 3974.24 37.78 4,906 100 4012.02 37.01 4.91 7 101 4049,03 39.46 4.902 102 4088.49 38.76 4.902 103 4127.25 37.93 4.901 104 4165.18 38.81 4.897 105 4203.99 38.52 4.901 106 4242.51 39.63 4,899 107 4282.14 39.20 4.901 108 4321.34 39.54 4.895 109 4360.88 38,73 4,899 110 4399.61 39.17 4,901 111 4438,78 39,61 4,897 112 4478.39 39,21 4,902 113 4517.60 39.05 4.901 114 4556.65 39,08 4.905 115 4595.73 38.76 4,901 116 4634.49 39.62 4.900 11 7 4674.11 39.09 4.900 118 4713.20, 39.82 4.898 119 4753.02 40.94 4.904 12,0 4793.96 38.52 4,899 121 4832.48 38.61 4,899 122 4871.09 38.71 4.901 123 4909.80 38,.99 4.900 124 4948.79 39,20 4.898 125 4987.9:9 39.25 4.902 126 502 7,24 39.04 4,900 12 7 5066,28 39.44 4.900 1,28 5105.72 39.53 4,900 129 5145.25 38.36 4.901 130 , 5183.61 39.04 4.904 131 5222.65 38.73 4,901 132 526! .38 40.32 4.898 133 5301.70 38.98 4.902 134 5340.68 40.24 4,901 135 5380.92 39.29 4,905 136 5420,21 39.09 4.901 137 5459,.30 39.1 7 4.900 138 5498.47 39.47 4,900 139 5537.94 39.47 4,900 Well: 2-54/Q-12 Field: ENDICOTT Company: BP EXPLORATION ALASKA INC. Country: USA Date: Feb. 25, 2000 Joint Depth Length Measured Type No. ID feet feet inches 140 5577.41 39.00 4,902 141 5616.41 39.05 4,904 142 5655.46 39.02 4.905 143 5694.48 38.86 4,904 144 5733.34 39.46 4.905 145 5772.80 39.32 4.899 146 5812.12 40.23 4.906 147 5852.35 39.50 4.906 148 5891.85 39.24 4.901 149 5931.09 39.40 4,900 150 5970.49 39.08 4.902 151 6009.57 39.35 4.902 152 6048.92 38.79 4.901 153 6087.71 39.31 ,4.901 154 6127.02 40.14 4,901 155 6167.16 38.83 4.897 156 6205.99 39.06 4.901 157 6245.05 39.06 4.901 158 6284.11 39.05 4.900 159 6323.16 39.00 4.900 160 6362.16 39,45 4,901' 161 6401.61' 39.44 4.90,1 162 6441,05 39.63 4.904 163 6480,68 38,05 4,906 164 6518,73 39.78 4,905 '165 6558.51 39.59 4,902 166 6,5,98.10 39.19 4.904 16:7 6637,29 37.87 4.897 168 6675,.16 38.70 4.900 169 6713.86 39.18 4.900 1 70 6753.04 39.13 4.901 1 71 6792.1 7 40.34 4,899 1 72 6832,51 3 7.86 4.900 173 6870.37 40.8,7 4,898 1 74 6911.24 39.89 4,901' 1 75 6951.13 39:43 4.903 1 76 6990.56 39.10 4,900 1 77 7029.66 40.08 4.900 178 7069,74 38,13 4.907 1 79 7107,87 38.62 4,910 180 71'46.49 39.09 4.912 181 7185.58 37.40 4.913 182 7222.98 3 7.59 4.906 183 7260.57 39.66 4.910 184 7300,23 39.67 4.906 185 7339.90 39.71 4,901 186 7379.6,1 37.73 4.91 7 187 741 7.34 39.46 4.904 188 7456.80 39.31 4.904 189 7496.11 39.87 4,905 Joint Tally page 2 RECEIVED MAR 0 8 2000 Alaska 0il & Gas Cons. Commission Anchorage PD ...ALIPER JOINT TALLY SHEET(''' Pipe: 5.5 ins 17ppf L-80 NSCC Wall thickness. Body: 0.304ins Upset: 0.304ins Nominal ID: 4.892 ins Well: 2-54/Q-12 Field: ENDICOTT Company: BP EXPLORATION ALASKA INC. Country: USA Date: Feb. 25, 2000 Joint Depth Length Measured Type No. ID feet feet inches 190 7535.98 38.50 4.903 191 7574.48 41.56 4.901 192 7616.04 38.83 4.904 193 7654.87 39.82 4.904 194 7694.69 39.31 4.906 195 7734.00 40.38 4.901 196 7774.38 40.15 4.897 197 7814.53 39.13 4.907 198 7853.66 39.56 4.901 199 7893.22 38.79 4.909 200 7932.01 39.53 4.901 201 7971.54 38.59 4.900 202 8010.13 38.84 4.902 203 8048.97 39.33 4.900 204 8088.30 39.26 4.904 205 8127.56 39.54 4.910 206 8167.10 38.04 4.902 207 8205.14 39.62 4.903 208 8244.76 39.48 4.895 209 8284.24 39.26 4.902 ~ 210 8323.50 38.75 4.901 211 8362.25 39.42 4.896 212 8401.67 38.99 nominal 213 8440.66 39.10 4.900 214 8479.76 39.26 4.902 , , 215 8519.,02 38.53 4.899 216 8557.55 3.9.27 4.900 217 8596.82 39.64 4.899 218 8636.46. 39.56 4.904 219 8676.02 38.55 4.906 , ,, 220 8714.57 39.11 4.899 2.21 .8753.68 39.58 4.906 222 8793.26 38.18 4.907 223 8831..44 40.6.7 4.898 224 8.872.11' 39.18 4.905 225 8911.29 36.68 4.896 226 8947.97 39.39 4.902 227 8987.36 39.11 4.901 228 9026.47 39.83 4.895 229 9066.3'0 39.12 4.902 230 91. 05.42 39.63 4.8'95 231 9145.05 39.22 .4.896 232 9184.27 38.49 4.898 233 9222.76 39.02 4.897 234 9261.78 . .39.84 4.896 235. 9301.62 39.33 4.90'1 236 9340.95 39.47 nominal 237 9380.42 38.70. 4.896 238 9419.12 39.33 4.896. 239 9458.45 39.46 4.897 Joint Dep~ Lengb~ Measured Type No. ID feet feet inches 240 9497.91 38.72 4.894 241 9536.63 40.08 4.902 242 9576.71 38.10 4.894 243 9614.81 39.12 4.895 244 9653.93 38.66 4.888 245 9692.59 39.08 4.894 246 9731.67 38.69 4.894 247 9770.36 39.68 4.895 248 9810.04 39.17 4.891 249 9849.21 39.04 4.897 250 9888.25 38.61 4.895 251 9926.86 39.11 4.894 252 9965.97 39.26 4.891 253 10005.23 39.95 4.895. 254 10045.18 38.85 4.896 255 10084.03 39.14 4.890 256 10123.17 39.63 4.898 257 10162.80 37.51 4.894 258 10200.31 39.55 4.896 259 1023.9.86 39.88 4.889' 260 10'279.74 38.04 4.89'4 261 10317.78 40.36 4.894 262 1'0358.14 38.96 4.895 263 10397.10 39.29 4.899 264 10436.39 39.22 4.889 265 10475.61 41.08 4.894 265.1 1.0516.69 12.32 4.90.5 Pup 265.21 10529.01" 9.46 nominal: Giro1 ,, 265.3 10538.47 7.48 4.904 Pup 265.4 10545.95 15.13 nominal Pup 265.5 10561.08 2.40 nominal X-nip 2:65.6 10563.48 7.06 4.898 Pup 265.7 10570.54 11.03 nominal Packer 265.8. 10:581.57 6.40 4.906 Pup 266 1,0587.97 39.87 4.90'2 266.1 10627.84 1,.79 nomi. nal X-nip 266.2 10629.63 20.31 4.888 Pup 266.3 10649.94 1.66 nominal Xn-nip 266.4 10651.60 -63.63 4.908 Pup 267 10587.97 unknown 4.902 WLeg Joint Tally page 3 RECEIVED MAR 08 2000 Alaska Oil & Gas Cons. Commissi,or~ Anchorage III ~UU~ R£.C£1VE MAR 0 8 200~ ~UU~ U ~zzn/ ., Alask~ ~ion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 13, 1996 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Blair: Enclosed is the AOGCC Report of Sundry Well Operations Form 10- 404 for BC-9 (Approval Number 92-122). A 4-point is scheduled for next week. I will forward the results to you as soon as the work/interpretation is complete. If you have any questions, please contact me at 564-6315. Sincerer, Michael R. Olson Production Engineer Attachments cc: CEF A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ." ALASKA ~_ ._ AND GAS CONSERVATION CC~,.,,vllSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Pull Tubing__ Alter Casing Repair Well Perforate X Other 2. Name of Operator ,5. Type of Well: Marathon Oil Company Development X 3. Address Exploratory P.O. Box 196168, Anchorage, AK 99519-6168 Stratigraphic 4. Location of Well at Surface Service 1168' FNL, 1568' FWL, Sec. 34, 1'7N, RIOW, SM At top of Productive Interval 2811' FNL, 1277' FWL, Sec. 34, TTN, RIOW, SM (~ 7039' 'I'VD At Effective Depth ,~'~-"I I"~'~ ~; '.-.~' i ~"~"~ ~ ~ i'"~:,,~.,i ~ l!; / '~, 2792' FNL, 1259 FWL, Sec. 34, T7N, R10W, SM (~8427' TVD At Total Depth 2792' FNL, 1259 FWL, Sec. 34, T7N, R10W, SM ~8500' TVD 6. Datum Elevation (DF or KB) 183' KB feet 7. Unit or Property Name Beaver Creek Unit 8. Well Number BC-9 9. Permit Number/Approval Number 92-122 10. APl Number 50- 133-20445 11. Field/Pool Beaver Creek Field, Sterling & Beluga 12. Present Well Condition Summary Total Depth: measured true vertical 8881 feet Plugs (measured) 8808' md 8500 feet Effective Depth: measured 8808 feet Junk (measured) Fill ~ 8028' md true vertical 8427 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 13-3/8" Driven 116' 116' Conductor Surface 9-5/8" 575 SX 1853' 1725' Intermediate Production 7" 440 SX 5950' 5555' Liner 3-1/Z' 500 SX 6881' 8500' Perforation Depth: measured 7420-7460', 7534-7574', 7640-7660', 7705-7755', 7762-7842', 7852-7882', 7893-7933', 7980-8030', 8036-8054', 8072-8098', 8167-8187', 8241-8246', 8254-8261', 8276-8292', 8399-8409', 8432-8452' true vertical 7039-7079', 7153-7193', 7259-7279', 7324-7374', 7381-7461', 7471-7501 ', 7512-7552', 7599-7649', 7655-7673°, 7691-77~i 7', 7786-7806', 7860-7865', 7873-7880', 7895-7911 ', 8018-8028', 8051-8071' Tubing (size, grade, and measured depth) 3-1/2", 9.2~ L-80 to 5824' Packers and SSSV (type and measured depth) Baker Liner Hanger w/Seal Bore Extension - 5814', SSSV - N/A 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) N/A Treatment Description Including Volumes Used and Final Pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 4000 5 750 1850 Subsequent to Operation - 11700 15. Attachments 116. Status of Well Classification as: I Copies of Logs and Surveys run Daily Report of Well Operations X Oil~ Gas ~ 17. I hereby certify that the f.oreg_oing is true and correct to the best of my knowledge. Signed~~~ 'f~/~~ Title 4 780 1850 Suspended Production Engineer Service Date 12/13/96 Form 10-404 Rev. 06/15188 Submit in Duplicate OPERATION SUmmArY REPORT: POST RIG WELL: BC-9 ,, 8/5/96 8004' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-21 with the well flowing: 7893-7933' (40'). Had one missrun. Tagged fill at 8004' Q = 4200 mscfpd, 1850 psig WHP, 9 bwpd. 8/7/96 8079' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-20L with the well flowing: 7852-7882' (30'). Tagged fill at 8079' Q = 4200 mscfpd, 1850 psig WHP, 9 bwpd. 8/9/96 8070' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-20U with the well flowing: 7812-7842' (30'). Tagged fill at 8070' Q = 5240 mscfpd, 1850 psig WH?, 7 bwpd. 8/13/96 8064' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-19L with the well flowing: 7762-7812' (50'). Tagged fill at 8064' Q = 8900 mscfpd, 1850 psig WHP, 5 bwpd. 9/25/96 8045' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-19U with the well flowing: 7725-7755' (30'). Tagged fill at 8045' Shut down due to high winds. 9/26/96 8051' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-19U with the well flowing: 7705-7725' (20'). Tagged fill at 8051' Q = 10200 mscfpd, 1860 psig WHP, 3 bwpd. 9/28/96 8032' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-18 with the well flowing: 7640-7660' (20'). Tagged fill at 8032'. Q = 10500 mscfpd, 1850 psig WHP, 3 bwpd. 9/30/96 8029' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-17 with the well flowing: 7534-7574' (40'). Tagged fill at 8029' Q = 11400 mscfpd, 1850 psig WHP, 4 bwpd. 10/2/96 8028' RU SWS. RIH w/ 2-1/2" HC, 6 SPF, 60 deg. phasing, and perf B-16 with the well flowing: 7420-7460' (40'). Tagged fill at 8028' Q = 11700 mscfpd, 1850 psig WHP, 4 bwpd. Work complete ~-' ~KB- 40. 60. BO 1050 1852 SURFACE CASING: 0.0 - 1853.0 (OD:9 5/8) INTERMEDIATE CASING: 0.0 - 59500 (OD'7) STRUCTURAL CASING: 0,0 - 116.0 (OD:13 3/8) 3-1/2"TUBING 23~7 - 1011.7 (00:3 1/2 ID:2 63/64) OTIS SSSV LANDING NIPPLE: 1011 7 - 1028.5 (OD:5 3/8 ID:2 - 13116) 3.1/2" TUBING: 1028,5 - 5822.6 (OD:3 1~2 ID:2 63164) BC-9 1853 'i 5815 582O 5830-. 5835-.. 5840 ~845 ~ 5850-J 5855 .~ ' 5950d 6400 ~ 6410 6420 6430 6440 '7400 ,. 7500 - 7600 7700, 7800 7900..~ , 8000 "I 'Fr~-r~'~t~"7~8o-o-:'~',:o 8o2o..i ~ OTIS X NIPPLE: 5822,6 - 5824,0 (OD:3 61/64 ID:2 13/16) ................................. TUBING LOCATOR SUB:: 5824,0 - 5824.7 (OD:5 ID:2 63164) ..... i., MODEL H PACKER: 5822,9 - 5827,5 (OD:5 29132) ,, LINER HANGER: 5827,5 .. 5833,7 (OD:5 7~8) SPACER SEAL ASSEMBLY: 5824,7 - 5842.0 (OD:4 ID:2 63164) SBE: 5833,7. 5644.0 (OD:5) --J 3-1/2" TUBING: 5844,0 - 8881,0 (OD:3 1/2 W[:9,20) PEK:7420.0-7460.0 ........................................... ~_. Perf: 7534.0 - 7574.0 Pe~: 7640.0- 7660.0 ............................................................... B-15 ...................................................... B-18 Pe~:7705.0-7725.0 Pe¢:7725.0-7755.0 --,.;::'~ Pe¢: 7762.0-7812.0 Peri: 7812.0- 7842,0 Pe~:7852.0-7882.0 Pe¢:7893,0-7933.0 Pe~: 7980,0- 8030.0 8040 ..-J Pe~: 8036.0 - 8054.0 8060 .J E"C--°--~-'/989"0'-/~-0-9i0-',i'--[-~'-""~iiiifli~.ii,[i'.i'-ii'i~'i~.'iii--'[~i ....................... f'-'-"'l , FILL: 8028,0 - 8808.0 (OD:2 63/64) 8080 Perf: 8072,0 - 8098.0 . Perf: 8167.0 - 8187.0 ................................... ~ .... ............................................. B-19 81oo -..! 8170 ..-] 8175, 'l 8180 8185 · 8260 8280 UWl 50-1:33-20445 Pe#: 8241.0 - 82460 .... Pe~:8254.0-8261.0 Ped:8276.0-8292,0 '". ........ B-21 ........................................................................ B-25., .... B-27 10/4/96 Ped: 8399.0 - 8409.0 ........................ ---"-'.-. Pe~ 8432.0-8452.0 , .... Cement Plug: 8808.0 - 8881.0 (OD:2 63/64) STATE OF ALASKA !~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Perforate__ Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development 3. Address Exploratory_ Stratigraphic __ 7. P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service X 4. Location of well at surface 8. 2078' SNL, 2328' WEL, Sec. 36, T12N, R16E At top of productive interval 828' SNL, 1523' WEL, Sec. 35, T12N, R16E At effective depth 634' SNL, 1775' WEL, Sec 35, T12N, R16E At total depth 624'SNL, 1790' WEL, Sec. 35, T12N, R16E 12. Present well condition summary Total depth: measured 12175 feet Plugs (measured) true vertical .10602' BKB feet Datum elevation (DF or KB) KBE =55.1 Unit or Property name Duck Island Unit/Endicott Well number 2-54/Q-12 9. Permit number/approval number 91-122 (not required) 10. APl number 50- 029-22218 11. Field/Pool Prudhoe Oil Pool feet Effective depth: measured 12137 feet true vertical 10567' BKB feet Junk (measured) Casing Length Size Cemented Structural Conductor 76' 30" Surface 2680' 13-3/8" 2021 cu ft Permafrost Intermediate 9428' 9-5/8" Production 1443' 9-5/8" 2371 cuft C/ass G Liner 1519' 7" 502 cu ft Class G Perforation depth: measured 11788'- 11881 '; 11894'- 11940' (open) 11952'-12062' (squeezed) true vertical 10195'-10279'; 10290'-10332' (open) 10343'- 10442' (squeezed) Tubing (size, grade, and measured depth) ORIGINAL Measured depth True vertical depth BKB BKB 131' 131' 2735' 2679' 9483' 8237' 9483'- 10926' 8237'-9443' 10656'- 12175' 9213'- 10547' 7"29#/ft L-809 tubing with 5-1/2" tailpipe to 10667' Packers and SSSV (type and measured depth) 9-5/8" Packer Big Bore w/Latch @ 10560' R E C E I V ~ D 7" Otis WD Packer wi4-1/2" 'X' & 'XN' Nipples at 11737' 13. Stimulation or cement squeeze summary Sandback/Cement Cap 4/6/96, Sandback/Cement Cap 5/3/96~1~ ~/~6~9~996 Intervals treated (measured) 1788'-11881'; 11894'-11940'; 11952'-12062' Treatment description including volumes used and final pressure (see attached) Alaska 011 & Gas Cons. Co~nmission Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13393 0 1378 18540 0 1895 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereb~rtify ,haUh~,,~!e2~n,,g is~,~d correct to the best of my knowledge. Signed ( ~ ~rrf~/(~ ~ Title Senior Technical Assistant IV Form 10-~4 ~v 06/1~8 - ' Date 10/17/96 SUBMIT IN DUPLICATE DATE' 4/6/96 WELL: 2-54/Q-12 OPERATION' SANDBACK/CMNT CAP BP REP: POWERS ITIME I OPERATION 0800 MIRU CAMCO 4932. 14,500' 1.75" COIL. CTV 33 BBLS. 1020 SAFETY MEETING 1030 PT LUBRICATOR 1 100 RECOVER METHANOL 1 134 OPEN SWAB AND RIH TIME IDEPTH Ii, ATE CTP PM I WHP I REMARKS 1134 0 0/1 440 430 RIH PUMPING TO DISPLACE METHANOL. 1220 5000 .25 530 510 6500# UP WT. 1300 10000 590 500 14000# UP WT. 1321 12047 .25/0 440 430 TAG TD , 1329 12000 0/1 432 450 CORRECT DEPTH TO 12041'. DO INJECTIVITY TEST. LOOKED LIKE WE MAY HAVE BROKEN THROUGH A CRUST AND FELL ABOUT 15'. 1344 CORRECTED BACK TO ORIGINAL SIT DOWN THEN LOST ANOTHER 16'. '1411 12000 0/MI N 500 430 WENT UP AND TRIED. TO TAG WD WLEG. GOT 2 REPEAT BOBBLES WHERE WE THOUGHT THEY SHOULD BE. RIGHT NOW C~UR BEST GUESS IS A NEW TD OF i2.058'. PLAN TO USE ORIGINAL CORRECTION AND SEE WHERE A 75' SAND DUMP WILL LEAVES US. WAIT ON BJ TO BRING OUT A NEW VMT. 1530 .BJ ON LOCATION. 1556 11970 430 419 FP CAMCO 1615 12048 PT BJ 1626 2 3470 600 BEGIN PUMPING SAND WITH 3 BBL GEL SPACERS BEFORE AND AFTER 1635 3600 670 SW TO FW TO DISPLACE. 1640 2/1 1600 705 SLOW DOWN TO LAY IN SAND. 1643 12048 680 SAND AT NOZZLE. LET A BBL GET OUT AND POOH AT 20 FPM. 1700 11600 0 650 730 PARK @ SAFETY 1730 - GO TAG 1737 12050 665 GEL DIDN'T BREAK? 1800 11600 0 470 560 GO TAG 1825 12058 0 470 550 NO SAND. 1857 12058 0 475 540 TAG AGAIN. SAME DEPTH. ORDER ANOTHER 2000#S OF SAND. SUSPECT THAT WE ARE.SITTING DOWN ON A RESTRICTION AT 12058' AND THAT THE SAND' FILLED UP THE LINER BELOW THIS. OTHERWISE, WE ARE PUMPING THE · SAND AWAY AND WILL NEEDTO RE-THINK OUR STRATEGY. 2000 11600 437 521 READY TO PUMP SAND. GO TAG AND POSITION COIL. 2007 12050 0/2 TAGGED AT 12058'. PU TO 12050 AND START PUMPING. 2015 2.11 675 3800 4 BBLS OF SAND AWAY. 2021 14.4 BBLS OF SAND AWAY SW TO GEL SPACER AND DISPLACE WITH SW. 2030 1 745 1380 SAND AT NOZZLE. POOH AT 15 FPM 2049 11775 1/0 750 850 PLF TO SAFETY. 2118 GO TAG. 2125 TAGGED AT 12042. PU TO SAEFTY. 2131 AT SAFETY. 2150 GO TAG 2207 11965 TAGGED TWICE @ 11965. ORDER CEMENT. 023 11960 TAGGED AGAIN AT 11965. POSITION COIL TO DUMP CEMENT. 044 1/0 PUMP 5 BBL FRESH WATER SPACER. 051 PUMP CEMENT 058 DROP PIG/BALL 110 O/MAX 3800 550 DISPLACE CEMENT WITH FSW. 124 1/0 BALL ON SEAT. SD PUMP AND POOH. SHEAR OUT CIRC SUB AND PUMP 20 BBLS. 305 3500 FP CAMCO 400 FID 530 RETURN WELL TO INJECTION. I BHA I LENGTH I COMMENTS I' TUBING CONN 0.92 2.75" OD ClRC SUB 1.5" 2.75" OD DUMP NOZZLE .5 3.00" OD OVERALL LENGTH 2.92' OC T Alaska 011 & Gas Cons. Anchorage ,SUMMARY: " '-' RIH TO 12031' CTMD. CORRECTED DEPTH TO 12041' THEN TAGGED TD AGAIN. TAGGED TD 15' DEEPER AFTER BREAKING THROUGH WHAT APPEARED TO BE A CRUST. PU AND TAGGED AGAIN SEVERAL FEET DEEPER. AFTER FINALLY GE~-FING 3 GOOD TAGS AND TRYING TO TIE-IN AT THE WD PACKER, DECIDED THAT ORIGINAL TAG WAS MOST LIKELY 12041 AND THAT WE HAD PUSHED SOME DEBRIS DOWN HOLE. NEW TD IS 12058' CTMD. LAYED IN 75' OF 20/40 SAND. WENT IN TO TAG AND FOUND NO FILL. ASSUMED THAT WE ARE TAGGING UP ON A OBSTRUCTION AND SAND FILLED LINER BELOW. PUMPED ANOTHER 85' OF 20/40 SAND AND TAGGED TD AT 11965. PUMPED 0.85 BBLS OF CEMENT AND CHASED DOWNHOLE WITH A FOAM PIG AND BALL. LAYED IN CEMENT, PU HOLE AND JETTED 20 BBLS OF SW ACROSS WD PACKER AND TAILPIPE. FP COIL WHILE POOHING. ESTIMATED PBTD = 11945' CTMD. FLUIDS PUMPED i B B L S. DESCRIPTION ., 1 2 CLEAN GEL 26.4.. SAND SLURRY 60 FRESH WATER 289 FSW I38 I METHANOL BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE FROM: POWERS WELL: 2-54/Q-12 OPERATION: SANDBACKJ CEMENT CAP LOCATION' DATE' ENDICOTT 5~3~96 Initial Well I FWHP StatusI (psi) (psi) (psi) (psi) (psi) (o F) II 1900 I 120 I 0 I "/A I 2300 I N/A TIME I OPERATION 7:30 MIRU CAMCO 4906. MU BHA. CTV=33.7 BBLS 8:30 PT to 4000 psi- OK. Recover mech. SI well to let pressure bleed off. 9:18 Open swab and RIH 9:21 0 MIN 550 560 0 RIH PUMPING MIN RATE. 10:05 5000 MIN 512 632 10:49 10000 MIN 500 612 26 117.6K UP 11:14 12040 MIN 495 590 33.7 TAG TD. CORRECT DEPTH TO 12035'. PU TO 12025 AND WAIT ON BJ. 11:37 12025 MIN/0 500 500 39.7/0 PT BJ. , 11:39 0/1.5 570 2210 STAGE SAND 12:05 1.5/1 580 1260 22.5 LAY IN 1350#S OF 20/40 CARBOLITE WITH 3 BBLS OF GEL AHEAD AND BEHIND. 12:16 12940 1 630 1425 31 POOH TO SAFETY 12:19 AT SAFETY 12:40 GOTAG. 11978. WAIT FOR CEMENT. 14:23 12700 .5 550 750 GO TAG 14:30 12978 0 475 497 SAND TOP IS NOT MOVVING. 15:05 11938 .25 505 570 STAGE 50 GALS OF CEMENT IN COIL WITH A FOAM PIG IN FRONT AND BEHIND. 15:21 11970 1.4 680 2400 PARK AND WAIT FOR CEMENT. 15:48 11940 .33 464 470 33.7 LAYED CEMENT IN AND SHEARED NOZZLE. 15:55 11900 .3 420 470 POOH PUMPING MIN RATE. ..17:37 SURF 0 400 400 89 RD. LEAVE WELL SI FOR 24 HRS. , Final Well DATE Status WHP lAP (psi) (psi) 0AP GLP' I FLT (psi) (psi) I (° F) II 5/3/96 400 I 0 120 I Tagged TD and corrected depth to 12135. Layed in 1350#'s of 20/40 Carbolite with 3 bbls of clean gel ahead and LI SUMMARY behind. Tagged TD at 11978. layed in 1 bbl of cement on top of sand with shear nozzle. FP top 500' of well while POOH. BBLS. I DESCRIPTION 76 FSW 1350 #'S 20/40 CARBOLITE 1 CEMENT 4O METHANOL CEMENT DETAILS BJ SERVICES 15.8 PPG Class G Cement containing: 0.1% CD-32 0.15% R-11 0.2% FL-33 1 gal/100 sx FP-6L Thickening Time = 4:50 + 2 Lab APl Fluid Loss - 154 Field APl Fluid Loss = N/A RECEIVED OCT ~ 1 199~ Alaska Oil & Gas Con,~ A.~..,%:,~ " Endicott Production Engineering Department OPERATIONS REPORT DATE: 8/26/96 WELL N-°: 2-54/Q-12 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: M.I.T. VARBLE HB&R ,. DATE/TIME OPERATIONS SUMMARY I 1 300 MIRU HB&R P/T TO 3000 PSI 1306 START PUMPING DIESEL DOWN IA 1315 12 BBLS AWAY: IA PRESSURED UP TO 2500 PSI. HOLD FOR 30 MIN. 1245 GOOD TEST. RIG DOWN 8/27 1016 RUHB&R 101 9 BUMP IA PRESSURE UP TO 2500 PSIG WITH 5 BBLS OF DEISEL. 1102 GOOD TEST. RD. PASSED MIT. WITNESS: Chuck Sheeve RECEIVED O~T ~-1 1995 Alaska 0il & (las Cong. Commission ADehorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 3 June 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-26/O-14 (MPI) 2-36/O-14 (MPI) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PLS FINAL BL+RF ECC No. Run # 1 4205.06 Run # I 4205.07 Run $ i 6602.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: ~ Date: JUN 2 1 ]995 DOCUMENT STORAGF,, INC. ,, "State-of-the-Art. Archivin& '' , 2410 Enst 88th Avenue m Trnutwein Anchota$¢, Al~slm 99507 re Store Mannger 'lei (90'/) 522-2684 Fnx (90'/) 522-2686 PLORATION ALASKA INC. . AMPLE TRANSMITTAL FROM: BP Exploration Alaska, Inc. c/o Document Storage Core Store 2410 W. 88th Ave. Anchorage,Alaska 99507 Attn: John Trautwein (907) 522-2684 TO: ~oC-,-.cc_ "State-of-the-Art A.rchiving" AIRBILL #!, CHARGE: · ~-'t,~"'F TRANSMITTAL NO.: WELL NAME: P 7- /ac. 'H ~/ SAMPLE TYPE: ~_~i~' ~P ~ NUMBER OF BOXES: /2. 2'-SF~--r z,. 1 REFERENCE: DESCRIPTION OF MATERIALS TRANSPORTED: Please acknowledge receipt in whole of the. material described above by signing this transmittal and returning a copy to the address shown above. Received b v · Date: Date: ^~a'ska Oil & C~as Cons. Conlmission Anchorage ,qR,lO ~,nlnvln RI,',,r'I · ^,~cht'.'n~.e, Aln,qk:~ 09507 ?ER~4IT # )PERATOR DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS )1-122 BPX )1-122 BPX )1-122 BPX )1-122 BPX 31-122 BPX -)1-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX 91-122 BPX DISKETTE CBT Page · 1 Date: 12/22/93 CDN RUN SCALE DATE_RECVD CDN D CORE ANALYSIS,II,<F-II694.4% CDN L 11240-12170 CDR L 9710-10550 1 L BLUELINE ONLY L 10900-12160 CDR L 9430-10550 CDR L BLUELINE ONLY 05/04/1992 CET 5 01/21/1992 L 10662-12126 INJP/WARM BACK L 10620-12063 2&5 01/21/1992 LDT/GR L 10500-12164 LDT/GR L 11300-12].64 2&5 01/21/1992 MFDT L 11439-11618 03/09/1992 RFT L 11439-12044 2&5 01/21/1992 TCP GUN 2 01/21/1992 L 11488-11710 WD PACKER/TAILPI L 11300-11782 407 R COMP DATE:12/7/91 DAILY WELL OP R 11/03/91-12/11/91 R l1415-11694(CORED~l1384) 03/09/1992 1 5 01/21/1992 1 5 10/30/1992 2 2&5 01/21/1992 2 TVD 01/21/1992 1 01/21/1992 2 01/21/1992 1 5 01/21/1992 1 5 01/21/1992 03/27/1992 03/27/1992 91-122 REPORT 05/04/1992 AOGCC Individual Well Geological Materials Inventory PERMIT # DPE RATOR DATA T DATA_PLUS Page: 2 Date: 12/22/93 RUN SCALE DATE_RECVD ~PX )1-122 SURVEY SCHLUMBERGER 31-122 SURVEY BPX R 0.00-12175 R SS DIRECTIONAL Well Data Summary Section Dry ditch samples required and received?...yes ...no Cored intervals' - Description and analysis received...yes ...no ...not required Are well tests required and received?...yes ...no Well is in compliance. Comments 03/27/1992 03/27/1992 initial r'T"l Z BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 28, 1992 Mr. Robert Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Crandall' Enclosed is the State of Alaska copy of the routine core analysis data and DOS disk for Duck Island Unit Well 2-54/Q-12. Please acknowledge receipt of this material by signing and returning a copy of this letter to Jeanne Haas. Call me at 564-4613 if you have any questions relating to these data. Si n ¢,..~..¢/ly~cere Rob~rtfl~etzge r Endic6~ Development R EE,:E I v E 1.,: 2559/RRM mm. { · j_~ ~ -- mmmmmml_~m_m,m,,..I _: _~ ~ {i ,i{i mmi~iiimmiiilii{! [] { II! {iii{m mmi~m II imm--{ - · -_. _=--;-"="=_=_~ --- __ ===...... ~ -=_~-------=_-=---.- ................ Htit ,:I - g--~l I IIBB Il[iii l_II_"lBBBIIlll_m _E.~ --~_~_~niB_mn BBB[nB _n_nn-nnn-n ___n .... = ::: := r - ;__:.,.~ ,,,,,,,,: _ ,,.,....,,,...... ..... ,~ ,,..,,,.,.. ,,...,..,,,:~ ....... ______ __:____: _:_:,, ....... ,..,,.. ,,...,,,,,.,.,.,,..,.,,.... ,,.,.,...,.,,_,=-_:,_,_. ;:__-;_~ _:_:___:: .:- ............. _~_~ _~_~_:~ ~_==__-= _-= .............. ==; = _~__= __--~= = _~ __-- == _~= .~ ==.=.............................. .._=; _== ~__=- ====.~ :==:=== ~..... ZL.... = ~__=___.==-~ .... ===~ ~i---- II IIII II,, II II ~ kl Illl Il -- r i[,,,,l, i,,I ,, N' ~I,!t~l~ ~1 /,~ ' J'i Ill II,~ ' ~=N~/ II :, l:l ,1N ~ i ~l Illl II , i;I '~i"fl,, I t I~,l i,I I.I. .,. IJ I~;I ~:11 :~ , I , I!,t i'~,ll,t!, ,I/'l ,/,~ I~l II" I ~,,,,'i[~[~ '~/ ~ ' IlII ~'~, I ,'II i tllllll ' ' II IIII ' I II I'l'lll II IIII · oi Alaska Oil and Gas Conservation March 9, 1992 Page 2 WELL 2-44/R-12 10800'-12005' PERF RECORD ATLAS WlRELINE LL 2-54/Q-12 11230'-12185' LWD-CDN (CORRECTED COPY~ vX"' SCHLUMBERGER ' 10900'-12150' ~WD- CDR (CORR_ECTED~G,Opy) SCHLUMBERGER WELL 2-64/U-10 8800'-14450' INJECTION PROFILE AND LEAK DETECTION LOG WELL 3-15/K-33 11925'-12891' SQUEEZE PERF RECORD SCHLUMBERGER 2/8/92 RUN 1 I 1/21 -30/91 RUN 1 11/21 -30/91 RUN 1 2/13/92 RUN 1 2/1 7/92 RUN 1 12029'-12679' USIT CEMENT & CORROSION SCHLUMBERGER 2/15/92 RUN 1 12029'-12821' USIT CEMENT & CORROSION SCHLUMBERGER WELL 3-49/J-40 14400'-14920' TEMPERATURE SURVEY WELL 4-02/Q-28 12700'-13330' STATIC TEMPERATURE SURVEY C,~ 2/23/92 RUN 2 12/28/91 RUN 1 RECEIVED MAR 1 2 1992 1 / 8/9 2 RUN 1 Alaska 011 & Gas Cons. Commission Anchorage 2471/JLH/clt Oil and Gas Conservation Commission January 15, 1992 Page Two WELL 2-54/Q-12 10900'-12160' LwD CDR SCHLUMBERGER 9430'- 10550' LWD TVD CDR SCHLUMBERGER 11/21-30/91 COMPOSITE 11/21-30/91 COMPOSITE 11240'-12170' LwD"'0DN SCHLUMBERGER 11/28-30/91 RUN ONE 9710'-10550' LWD TVDCDN SCHLUMBERGER 11/28-30-91 RUN ONE 11/30/91 11439'- 11618' RU N,,(~N E MODULAR FORMATION DYNAMICS TESTER, SCHLUMBERGER 12/2/91 10500'- 12164' ,,RUN TWO : LITHO-DENSITY-GR 2"&5" RHOB & PORO SCHLUMBERGER 1212/91 10300'- 12164' I:~IN TWO ,LIT.HO-:DENSITY-GR 2" TVD WRT SUBSEA SCiHLUMBERGER / 11439'- 12044' / SCHLUMBERGER 12/2/91 RUN TWO 2995'- 12103' CBT " SCHLUMBERGER 12/6/91 RUN ONE RECEIVED JAN 2 1 1992. 2370/JLH/clt Alaska 0il & Gas Cons. Commission Anchorage (~o ~ ~'~ WEL Oil and Gas Conservation Commission January 15, 1992 Page Throe WELL 2-54/Q-12 (cont'd) 10662'-12126' CE];' ' SCHLUMBERGER 11300'- 11782' WD"PACKER/TAILPIPE RECORD SCHLUMBERGER 11488'-11710' / ~CPi GUN CORRELATION "SCHLUMBERGER L 2-58/S-09 13000'- 14343' STATIC TEMPERATURE SURVEY CAMCO L 2-64/U-10 13807'-14259 PERFORATING RECORD HALLIBURTON LOGGING SVCS. O ,~(~ WEL 13980'-14250' CCL LOG F/SETTING INFLATABLE BP CAMCO L 3-05/0-29 11200'-12572' PUMP-IN-TEMPERATURE SURVEY CAMCO L 3-25/M-27 13550'- 13930' PRODUCTION LOGGING ATLAS WIRELINE SERVICES WELL 4-02/Q-28 11737'- 13330' PUMP-IN-TEMPERATURE SURVEY CAMCO 12/6/91 RUN ONE 12/9/91 RUN ONE 12/6/91 RUN ONE 12/12/91 RUN ONE 9/20/91 RUN ONE v~R0/17/91 UN ONE 12/15/91 RUN ONE 12/2/91 RUN ONE 11/25/91 RUN ONE RECEIVED JAN 2 1 1992 Alaska 0il & Gas Cons. Commission Anchorage 2370/JLH/clt ,, " L , ss,o,O R I G ! L "I. ALAS~t,--, OIL AND GAS CONSERVATION -,./' ,~" WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUS~DED [] ABANDONED [] SERVICE [] Water Injector '2. Name of Operator 17. Permit Number BP Exploration 191-122 3. Address B. APl Number .P.O. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-22218 :4. Location of well at surface ~ L'.0~4¢!_~T'.0i~I ~ 9. Unit or Lease Name 2078'SNL, 2328' WEL, SEC. 36, T12N, R16E ~. "~.-- /'~ ...... ! ~,.~,~?;'~.~' Duck Is/and Unit/Endicott At Top Producing Interval i '~'="~""--"?' I' 10. Well Number 828' SNL, 1523' WEL, Sec. 35, T12N, R16E~ ~.~__ ,.~I' ;',/~-RIFd~.~ .... ~ !; ...~,~,.~ ~ ~ 2-54/Q-12 11. Field and Pool At Total Depth,- .~ ~ Endicott Fie/d/Endicott Pool 624' SNL, 1790' WEL, Sec. 35, T12N, R16E ~5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE 55.1' ADL 34633 !12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/2/91 12/2/91 12/7/91I 6-12feet MSL ONE 117. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12175'MD/10602'TVD 12137'MD/10567'TVD YES rx'j NO []I 1560'feet MD 1466' 22. Type Electric or Other Logs Run LD T/RFT/CET/CB T/GC T-Gyro/CDR/CDN/GR/MAD PASS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PUt LED 30" Surface 131 13-3/8" 68# NT8OCYHE/L-80 Surface 2735' 16" 2021 cu ft Permafrost 9-5/8" 47# N T80S Surface 9483' 12-1/4" 9-5/8" 47# NT95HS 9483 10926' 12-1/4" 2371 cu ft Class G 7" 29# L-80 10656 12175' 8-1/2" 502 cuft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ' interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Schlumberger 4.5" 5spf 5-1/2" 10667 10569' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11788'-11881' 10195'-10279' 'DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11894'-11940' 10290'-10332' 11952'- 12062' 10343'- 10442' _ ~ , ...... .... 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 1/5/92 Water Injector D.~te of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO . TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. CONTINUED ON REVERSE SIDE Submit in duplicate Form 10-407 Rev. 7-1-80 29. 30. GEOLOGIC MARK ' . ~ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Itkilyariak 10898' 9474' Kekituk 11415' 9919' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / ':~" ~'" "~' Sign ........... ~,'::'.i?.:~.:......,.,:,,,, .;' ~ ./,~"~:,/::?'/"Tffi'~ Senior Technical Assistant pate , ....... ,:.. ', ,, .......... .,,'/ ,/" 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". EEEIVED Form 10-407 MAR 2' 7 1992 Alaska 0il & Gas Cons. Comm[Ss[o~ Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK ENDICOTT 2-54/Q-12 MPI DOYON 15 MOVE OTHR: 10.0 (o) TD: 0' ( 0) SUPV: HOLE ANGLE: 0 0 MOVE OTHR: 24.0 11/03/91 ( 1) TD: 0'( 0) SUPV:JBS HOLE ANGLE: 0 0 MOVE RIG. SPOT CUTTINGS WASHER MW: 0.0 VIS: 0 DAILY:SO CUM:S0 ETD:SO EFC:$0 SPOTTING CUTTINGS WASHER MW: 8.8 VIS:188 RIG UP, FILL PITS W/WATER, MIX SPUD MUD. SPOTTED CUTTINGS WASHER. ACCEPTED RIG @1300 HRS 11-2-91. DAILY:S61,536 CUM:$61,536 ETD:S61,536 EFC:$3,773,000 SURF DRIL: 2.0 TRIP: 2.5 SURV: 2.0 OTHR: 17.5 11/04/91 ( 2) RIH W/MUD MOTOR MW: 8.9 VIS:220 TD: 600' ( 600) SPUD WELL AT 0030 HRS 11-4-91. DRILLED AND SURVEYED TO SUPV:JBS 600'. POH. RIH W/ MUD MOTOR. HOLE ANGLE:28 48 DAILY:S79,670 CUM:$141,206 ETD:S141,206 EFC:$3,773,000 SURF DRIL: 21.5 TRIP: 2.5 11/05/91 ( 3) MW: 9.2 VIS:165 TD: 2073' (1473) DRILLED AND SURVEYED TO 1324'. POH. RIH AND DRILLED AND SUPV:JBS SURVEYED 16" HOLE TO 2073'. HOLE ANGLE:28 48 DAILY:S67,637 CUM:$208,843 ETD:S208,843 EFC:$3,773,000 SURF DRIL: 6.5 CASG: 9.0 PROB: 8.5 PROB CODE: TH 11/06/91 ( 4) WASHING/REAMING HOLE MW: 9.7 VIS: 90 TD: 2748' ( 675) DRILLED AND SURVEYED TO 2742'. CIRCULATE. WASHED AND SUPV:JBS REAMED FROM 1400'-1900' CIRCULATE. POH. STARTED RUNNING HOLE ANGLE:28 48 13-3/8" CSG. SAT DN @ 163', LD CSG. REAM 16" HOLE. DAILY:S57,931 CUM:$266,774 ETD:S266,774 EFC:$3,773,000 SURF PROB: 24.0 PROB CODE: TH 11/07/91 ( 5) RUN 13-3/8" CASING MW: 9.8 VIS: 81 TD: 2748' ( 0) CBU. POH. RIH AND REAM TO 1080'. RAN WIRELINE SURVEY. SUPV:JBS REAM TO BOTTOM, CBU. POH. RIG UP TO RUN 13-3/8" CASING. HOLE ANGLE:28 48 DAILY:S45,457 CUM:$312,231 ETD:S312,231 EFC:$3,773,000 SURF CASG: 13.5 BOPE: 10.5 11/08/91 ( 6) NU BOPE MW: 9.8 VIS: 76 TD: 2748' ( 0) RAN 13-3/8" CASING. CIRCULATE, CEMENT CASING. POH. NU SUPV:JBS BOPE. HOLE ANGLE:28 48 DAILY:S146,182 CUM:$458,413 ETD:S458,413 EFC:$3,773,000 RECEIVED MAR 2 ? 1992 Alaska OJJ & Gas Cons. Commission Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK ENDICOTT 2-54/Q-12 MPI DOYON 15 P1 DRIL: 7.0 TRIP: 2.5 CIRC: 1.0 EVAL: 0.5 CASG: 0.5 BOPE: 12.5 11/09/91 ( 7) DRILLING MW: 9.1 VIS: 44 TD: 3022' ( 274) NU AND TEST BOP'S. RIH W/MUD MOTOR. TEST CASING TO 3000 SUPV:JCL PSI. DRILL FLOAT COLLAR AND SHOE, CIRCULATE. PERFORM HOLE ANGLE:28 48 LEAK-OFF TEST. DRILLED AND SURVEYED TO 3022'. DAILY:S41,310 CUM:$499,723 ETD:S499,723 EFC:$3,773,000 P1 DRIL: 24.0 11/10/91 ( 8) TD: 4675' (1653) SUPV:JCL HOLE ANGLE:28 48 DRILLING/SURVEYING MW: 9.2 VIS: 42 DRILLED AND SURVEYED FROM 2992'-4675'. DAILY:S176,361 CUM:$676,084 ETD:S676,084 EFC:$3,773,000 P1 DRIL: 13.0 TRIP: 3.0 RIGS: 0.5 EVAL: 0.5 OTHR: 1.0 PROB: 6.0 PROB CODE: TH 11/11/91 ( 9) MW: 9.4 VIS: 44 TD: 5460' ( 785) DRILLED AND SURVEYED TO 5157'. REAMED UP 5157'-4207'. PUMP SUPV:JCL DRY JOB. POH. RIH AND DRILLING @5460'. HOLE ANGLE:28 48 DAILY:S43,839 CUM:$719,923 ETD:S719,923 EFC:$3,773,000 P1 DRIL: 13.5 TRIP: 6.0 SURV: 2.0 RIGS: 0.5 OTHR: 2.0 11/12/91 (10) DRILLING/SURVEYING MW: 9.6 VIS: 40 TD: 6350' ( 890) DRILLED AND SURVEYED TO 6350' POH, CHANGE BIT. RIH TO SUPV:JCL SHOE. DRILLING @ 6350' HOLE ANGLE:28 48 DAILY:S47,905 CUM:$767,828 ETD:S767,828 EFC:$3,773,000 P1 DRIL: 19.5 TRIP: 2.5 CIRC: 2.0 11/13/91 (11) POH MW: 9.5 VIS: 38 TD: 7835' ( 1485) DRILLED AND SURVEYED 12-1/4" HOLE TO 7226'. CBU. SHORT SUPV:JCL TRIP. DRILLED AND SIRVEYED TO 7835'. POH FOR BHA CHANGE. HOLE ANGLE:28 48 DAILY:S45,021 CUM:$812,849 ETD:S812,849 EFC:$3,773,000 P1 DRIL: 18.0 TRIP: 5.0 RIGS: 0.5 OTHR: 0.5 11/14/91 (12) DRILLING MW: 9.6 VIS: 36 TD: 8789' ( 954) POH FOR BIT AND BHA CHANGE. RIH TO BOTTOM. DRILLED AND SUPV:JBS SURVEYED TO 8789'. HOLE ANGLE:28 48 DAILY:S49,861 CUM:$862,710 ETD:S862,710 EFC:$3,773,000 P1 DRIL: 15.5 TRIP: 6.5 SURV: 0.5 RIGS: 1.5 11/15/91 (13) DRILLING MW: 9.7 VIS: 37 TD: 9224' ( 435) DRILLED AMD SURVEYED 12-1/4" HOLE TO 8989'. DROPPED SURVEY, SUPV:JBS POH. RIH W/BIT %6. SLIPPED AND CUT DRILLING LINE. WASHED HOLE ANGLE:28 48 AND REAMED TO BOTTOM. DRILLED AND SURVEYED TO 9224' DAILY:S51,708 CUM:$914,418 ETD:S914,418 EFC:$~,773,000 RECEIVED P_ ? 1992 & Gas Cons. Commission Anchorage BP/AAI SHARED SERVICE END I COT T DOYON 15 ACTIVITY SUMMARY NORTH SLOPE 2-54/Q-12 MPI R'ECEIVED MAIR 2 ? 1992 Alaska Oil & Gas Cons. Commission Anchorage P1 DRIL: 24.0 11/16/91 (14) TD:10008' ( 784) SUPV:JBS HOLE ANGLE:28 48 DRILLING MW: 9.8 VIS: 36 DRILLED AND SURVEYED 12-1/4" HOLE TO 10008' DAILY:S46,872 CUM:$961,290 ETD:S961,290 EFC:$3,773,000 P1 DRIL: 14.0 TRIP: 6.5 SURV: 0.5 BOPE: 3.0 11/17/91 (15) DRILLING MW: 9.8 VIS: 36 TD:10329' ( 321) DRILLED AND SURVEYED 12-1/4" HOLE TO 10028' POH. POH FOR SUPV:JBS BIT CHANGE. RIH AND DRILL AND SURVEY TO 10~29'. HOLE ANGLE:28 48 DAILY:S60,842 CUM:$1,022,132 ETD:S1,022,132 EFC:$3,773,000 P1 DRIL: 12.0 TRIP: 10.5 SURV: 0.5 RIGS: 1.0 11/18/91 (16) POH MW: 9.9 VIS: 37 TD:10546' ( 217) DRILL AND SURVEY 12-1/4" HOLE TO 10364'. POH. RIH W/NEW SUPV:JBS BIT TO SHOE. TEST MWD. RIH TO BOTTOM. DYNADRILL TO HOLE ANGLE:28 48 10546' POH FOR BHA CHANGE. DAILY:~62,976 CUM:$1,085,108 ETD:S1,085,108 EFC:$3,773,000 P1 DRIL: 16.5 TRIP: 5.5 SURV: 0.5 PROB: 1.5 PROB CODE: TH 11/19/91 (17) DRLG. MW:10.1 VIS: 38 TD:10922' ( 376) POOH. CHANGE BHA, P/U BIT. TEST MWD. RIH. REAM F/ SUPV:JBS 10546'-10364'-10546'. DRLG F/ 10546'-10922' HOLE ANGLE:28 48 DAILY:S51,520 CUM:$1,136,628 ETD:S1,136,628 EFC:$3,773,000 P1 DRIL: 2.0 TRIP: 5.0 CIRC: 5.0 CASG: 10.0 BOPE: 0.5 OTHR: 1.5 11/20/91 (18) CIRC TO RUN CSG MW:10.1 VIS: 48 TD:10935' ( 13) DRILLED 12-1/4" HOLE TO TD 10935' LAY DOWN BHA. RUN 9-5/8 SUPV:JBS CASING. CIRCULATED. HOLE ANGLE:28 48 DAILY:S366,503 CUM:$1,503,131 ETD:S1,503,131 EFC:$3,773,000 P1 DRIL: 4.5 TRIP: 2.5 RIGS: 1.0 CIRC: 8.5 CASG: 4.0 BOPE: 1.0 OTHR: 2.5 11/21/91 (19) DRILLING MW: 9.7 VIS: 38 TD:10950' ( 15) CEMENT 9-5/8" CASING. TEST PACKOFF. RIH, CIRC & CONDITION SUPV:JCL MUD, TEST 9-5/8" CASING TO 3000 PSI-OK. DRILLING CEMENT, HOLE ANGLE:28 48 SHOE @10950'. DAILY:S165,200 CUM:$1,668,331 ETD:S1,668,331 EFC:$3,773,000 PROD DRIL: 23.0 TRIP: 0.5 RIGS: 0.5 11/22/91 (20) DRILLING MW: 9.7 VIS: 37 TD:lll60' ( 210) DRILLED TO 11122' SHORT TRIP TO SHOE. RETRIEVED SUPV:JCL STABILIZERS, SERVICED RIG. DRILLING @11160' HOLE ANGLE:28 48 DAILY:S62,345 CUM:$1,730,676 ETD:S1,730,676 EFC:$3,773,000 PROD DRIL: 10.0 TRIP: 6.5 EVAL: 6.5 OTHR: 1.0 11/23/91 (21) DRILLING MW: 9.7 VIS: 37 TD:l1250' ( 90) DRILLED TO 11216' POH FOR LOGGING TOOLS. RIH AND LOGGED SUPV:JCL 8-1/2" HOLE TO 11~16'. HOLE ANGLE:28 48 DAILY:S39,789 CUM:$1,770,465 ETD:S1,770,465 EFC:$3,773,000 BP/AAI SHARED SERVICE ENDICOTT DOYON 15 ACTIVITY SUMMARY NORTH SLOPE 2-54/Q-12 MPI RECEIVED Oil & Gas Cons. Commission 'Anchorage PROD DRIL: 12.5 TRIP: 4.0 CIRC: 1.5 EVAL: 1.5 BOPE: 2.5 OTHR: 2.0 11/24/91 (22) DRILLING MW: 9.7 VIS: 37 TD:11384' ( 134) DRILLED TO 11384' SHORT TRIP TO 9-5/8" SHOE. CBU, POH. SUPV:JCL L/D LOGGING TOOLS. PULLED WEAR RING, TESTED BOPE. INSTALL HOLE ANGLE:28 48 WEAR RING. P/U CORE BBL & NEW BHA. DAILY:S43,919 CUM:$1,814,384 ETD:S1,814,384 EFC:$3,773,000 PROD DRIL: 8.5 TRIP: 10.5 RIGS: 1.0 OTHR: 4.0 11/25/91 (23) 5 MW: 9.7 VIS: 37 TD:11454' ( 70) RIH. CARED FROM 11384'-11452'. CUT 68', RECOVERED 62' SUPV:JCL HOLE ANGLE:28 48 DAILY:S42,467 CUM:$1,856,851 ETD:S1,856,851 EFC:$3,773,000 PROD DRIL: 10.5 TRIP: 8.0 RIGS: 1.0 EVAL: 0.5 OTHR: 4.0 11/26/91 (24) CORING MW: 9.7 VIS: 38 TD:11552' ( 98) CORED FROM 11452'-11542' POH. RIH, CALIBRATE ANNADRILL SUPV:JCL DEPTH SENSOR. WASH TO BOTTOM. CORING FROM 11542'. CUT 90' HOLE ANGLE:28 48 RECOVERED 84.75' DAILY:S49,502 ~UM:$1,906,353 ETD:S1,906,353 EFC:$3,773,000 PROD DRIL: 13.0 TRIP: 8.0 OTHR: 3.0 11/27/91 (25) MW: 9.8 VIS: 40 TD:l1661' ( 109) CORED HOLE TO 11606'. POH W/CORE #3. CUT 64', RECOVERED SUPV:JCL 62.75'. RIH W/CORE #4. WASH FROM 11516'-11606'. CORE HOLE ANGLE:28 48 8-1/2" HOLE TO 11661'. DAILY:S44,616 CUM:$1,950,969 ETD:S1,950,969 EFC:$3,773,000 PROD DRIL: 7.5 TRIP: 11.0 RIGS: 1.0 OTHR: 4.5 11/28/91 (26) CHANGE BHA MW: 9.7 VIS: 38 TD:11694' ( 33) POH W/CORE #4. RIH FOR CORE #5. WASH FROM 11569'-11664'. SUPV:JCL POH W/CORE #5. P/U NEW BHA. CORE #4 - CUT 58', RECOVERED HOLE ANGLE:28 48 59.25' CORE #5 - CUT 30', RECOVER ED 30'. DAILY:~45,142 CUM:$1'996,111 ETD:S1,996,111 EFC:$3,773,000 PROD DRIL: 13.0 TRIP: 3.5 EVAL: 4.5 OTHR: 3.0 11/29/91 (27) DRILLING MW: 9.7 VIS: 38 TD:12010' ( 316) MAKE UP NEW BHA. RIH TO 11330'_ LOG WELL FROM SUPV:JCL 11330'-11694'. DRILL AND LOG 8-1/2" HOLE TO 12010'. HOLE ANGLE:28 48 DAILY:S122,278 CUM:$2,118,389 ETD:S2,118,389 EFC:$3,773,000 PROD DRIL: 4.0 TRIP: 5.5 CIRC: 1.5 EVAL: 13.0 11/30/91 (28) RIH W/MDT TOOL MW: 9.7 VIS: 39 TD:12175' ( 165) DRILL AND LOG 8-1/2" HOLE TO 12175'. POH TO 11399'. MAD SUPV:JCL FROM 11399'-12175'. CBU, POH. LAY DOWN LWD. RIH HOLE ANGLE:28 48 SCHLUMBERGER AND RIH W/MDT TOOL. DAILY:S53,235 CUM:$2,171,624 ETD:S2,171,624 EFC:$3,773,000 PROD EVAL: 3.0 PROB: 21.0 PROB CODE: LT 12/01/91 (29) POH W/FISH MW: 9.8 VIS: 39 TD:12175' ( 0) RIH W/MDT TOOL, STUCK TOOL. RIH W/WIRELINE TO FISH TOOL. SUPV:JCL FOUND FISH @11578', POH W/FISH. HOLE ANGLE:28 48 DAILY:S171,349 CUM:$2,342,973 ETD:S2,342,973 EFC:$3,773,000 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK ENDICOTT 2-54/Q-12 MPI DOYON 15 PROD RIGS: 1.0 EVAL: 6.0 PROB: 17.0 PROB CODE: HOLE 12/02/91 (30) POH W/WIRELINE MW: 9.7 VIS: 42 TD:12175' ( 0) POH WITH FISH. POH W/WIRELINE. SUPV:JCL HOLE ANGLE:28 48 DAILY:S89,730 CUM:$2,432,703 ETD:S2,432,703 EFC:$3,773,000 COMP TRIP: 7.0 RIGS: 1.0 CIRC: 1.5 EVAL: 5.5 PROB: 9.0 PROB CODE: HOLE 12/03/91 (31) POH FOR LINER MW: 9.7 VIS: 42 TD:12175' ( 0) RIH FOR WIPER RUN. POH FOR LOGS. RIH W/LDG, LOG FROM SUPV:JCL 12175'-11300' POH RIH TO 12165'. WASH & REAM FROM HOLE ANGLE:28 48 12165'-12175'. POH FOR 7" LINER. DAILY:S156,558 CUM:$2,589,261 ETD:S2,589,261 EFC:$3,773,000 RCSG: 23.0 OTHR: 1.0 12/04/91 (32) PU BHA MW: 9.7 WBM TD:12175 RIH W/ 7" LINER. CEMENT LINER. POH. PU CLEANOUT BHA. PB: 0 SUPV:JCL DAILY:S169,617 CUM:$2,758,878 ETD:SO EFC:$6,531,878 RCSG: 23.0 OTHR: 1.0 12/05/91 (33) CIRC BOTTOMS UP MW: 9.7 WBM TD:12175 CUT DRILLING LINE. RIH, DRILL CMT FROM 10411' - 10659' PB: 0 (LINER TOP). CBU. POH. RIH W/ 6" BIT. TAG CEMENT @ SUPV:JCL 12023' DRILL TO LANDING COLLAR. TEST CASING AND LAP TO 3000 PSI - OK. DRILL LANDING COLLAR AND CMT TO 12137' (FLOAT COLLAR). CBU. DAILY:S41,853 CUM:$2,800,731 ETD:SO EFC:$6,573,731 COUT: 7.0 RCSG: 16.0 OTHR: 1.0 12/06/91 (34) FILTERING BRINE MW: 9.3 NaCl TD:12175 POH. RIH W/POLISH MILL. CUT DRLG LINE. RIH POLISH TIE PB: 1063 BACK RECEPTACLE. POH. RIH W/7" CASING SCRAPER. RIH. CIRC. SUPV:JCL HOLE CLEAN, DISPLACE W/100 BBLS H20 FOLLOWED BY 9.3 BRINE. INJECT MUD, CLEAN PITS. DAILY:S57,857 CUM:$2,858,588 ETD:S2,858,588 EFC:$3,773,000 RCSG: 7.0 LPRF: 17.0 12/07/91 (35) RIH W/PERF GUNS MW: 9.3 NaCl TD:12175 FILTERED BRINE. TEST LINER TO 3000 PSI - OK. POH. RIG UP PB: 1063 SCHLUMBERGER, RUN GR/CCL/CBT/CET/GCT. RIG DOWN SUPV:JCL SCHLUMBERGER. PICK UP PERF GUNS, RIH. DAILY:S81,225 CUM:$2,939,813 ETD:S2,939,813 EFC:$3,773,000 RECEIVED Alaska ,Oil & Gas Cons. [;ommiSsiO~ ;Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK ENDICOTT 2-54/Q-12 MPI DOYON 15 LPRF: 24.0 12/08/91 ( 36) TD:12175 PB: 1063 SUPV:JCL POH W/PERF GUNS MW: 9.3 NaC1 RIH W/PERF GUNS. RIG UP WIRELINE, LOG PERF GUNS INTO PLACE, SET PACKER. PERFORATE. FLOWED WELL TO TIGER TANK. REVERSE CIRC TO KILL WELL. FLUID LOSS 110 BBLS/HR. MIXED AND PUMPED KILL PILL. SQUEEZED TO 700 PSI. WELL STABLE. POH SLOW. DAILY:S52,000 CUM:$2,991,813 ETD:S2,991,813 EFC:$3,773,000 RPKR: 17.0 LPRF: 6.0 OTHR: 1.0 12/09/91 (37) RIH W/WD PACKER MW: 9.3 NaCl TD:12175 POH W/PERF GUNS. RIH W/ 6" BIT. REVERSE CIRCULATE. POH - PB: 1063 LAY DOWN DRILL PIPE & COLLARS.RIH W/8.495" GAUGE RING TO SUPV:JCL LINER TOP, RUN 5.95" GAUGE RING TO 11788' (TOP OF PERFS). RIH W/WD PACKER. DAILY:S122,831 CUM:$3,114,644 ETD:S3,114,644 EFC:$3,773,000 NDNU: 5.0 RPKR: 3.5 RCMP: 15.5 12/10/91 (38) NIPPLE UP TREE MW: 9.3 NaCl TD:12175 SET "WD" PACKER. RUN 5-1/2" TUBING. TEST TO 5000 PSI- OK. PB: 1063 REVERSE CIRCULATE LAND TUBING, NIPPLE DOWN STACK, NIPPLE UP SUPV:JCL ADAPTER FLANGE & TREE. DAILY:S139,482 CUM:$3,254,126 ETD:S3,254,126 EFC:$3,773,000 NDNU: 6.0 12/11/91 ( 39) TD:12175 PB:10603 SUPV:JCL RELEASE RIG @1200 HRS 12-10-91 MW: 9.2 NaC1 TEST TREE TO 5000 PSI. PULL 2-WAY CHECK. PRESSURE UP TBG TO 3000 PSI-SET PACKER HELD FOR 15 MIN, TEST DOWN TBG ANNULUS WITH 2500 PSI-HELD FOR 30 MIN-OK PRESS UP TO 2900 PSI-SHEARED RP VALVE. RIG UP U-TUBE, U-TUBE 110 BBLS DIESEL. RELEASE RIG @1200 HRS 12-10-91. DAILY:S295,357 CUM:$3,549,483 ETD:S3,773,000 EFC:$3,549,483 R ECEIVI D AJaska Oij & Gas Cons. Commissic, Anchorage 4450 W. 50TH AVENUE · ANCHORAGE, ALASKA 99502 TELEPHONE (907) 243-2822 April 24, 1992 Mr. Bob Metzger British Petroleum Exploration P.O. Box 196612 900 E. Benson Boulevard Anchorage, AK 99519-6612 Re: Core Analysis 2-54/Q-12 Endicott Field Dear Mr. Metzger, This report presents final Core Analysis Data for conventional cores taken from your Endicott 2-54/Q-12 Well. Laboratory procedures are included for your reference. Four sections of the report include: 1) <i"-RCA> Routine core analysis on one-inch plug samples. Samples with the notation "<1>" in COMMENTS, indicates samples were partially dessicated prior to analysis. 2) <2"-RCA> Routine core analysis on two-inch plug samples. 3) <UNCLEANED> Permeability values for dried but uncleaned one-inch plug samples. 4) <OB> Overburden porosity and permeability data. We appreciate this opportunity to be of service, and trust these data prove helpful in the modeling and development of this reservoir. Sincerely, P~..~OLEUM TEST. ING SE~ICE INC. -Pete T. schuyler President BRITISH PETROLEUM EXPLORATION 2-54/Q-12 ENDICOTT April 1992 FILE 70096 ate I© Reports submitted by Petroteum Testing Service are based on the analysis of materials and information supplied by the client, and cannot be guaranteed. These opinions and interpretations expressed represent our best judgement; however, Petroleum Testing Service assumes no responsibility nor makes any warranty regarding profits or performance resulting from the use of such reports. British Petroleum Exploration 2-54/Q-12 Endicott Field ROUTINE CORE ANALYSIS 1. Trim one-inch (two-inch) diameter plug to right cylinder. 2. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volume. 3. Vacuum dry at 150'F until weight is stable. Allow sample to cool and weigh to the nearest 0.01 gram. 4. Measure bulk volume using mercury immersion method. 5. Measure sand grain volume using a Boyle's Law helium porosimeter. Calculate porosity, saturations, and grain density. 6. Mount samples in hydrostatic Hassler-type sleeve using a confining stress of 300 psi. 7. Measure permeability with nitrogen gas using a calibrated flow tube type permeameter. British Petroleum Exploration 2-54/Q-12 Endicott Field OVERBURDEN POROSITY AND PERMEABILITY PROCEDURES 1. One-inch plug sample is mounted in Hassler-type sleeve using a confining stress of specified pressure. 2. Pore volume at stress is measured using helium and Boyle's Law. Permeability at stress is determined using flowing dry nitrogen. 3. Sand grain volume is measured in a matrix cup utilizing helium and Boyle's Law. 4. Porosity at overburden pressure is calculated using pore volume and sand grain volume data. ee ee Z le ee J ~ ee ee ee ee Lid 0 ~e ee e. ~1 el el ee '"0 0 0 0 t_ 0 u u t- Z Z ee el ee ee Z Z Z L~ Z Z ~ ~ g 0~,,~ el el ee ee ell ee ee 4~ 0 Z ee lo eo el z Z I.== >-. I~ Z I-- >- I-- 1.1.1 Z ee ee ee ee Z Z o leee ee el ee Z ee I-- Z le ®e el Z ee el el ee (-- 0 N O. LAJ 0 Z i-' ~' t-- LAJ Z ~ N N ~ 0 h~ r~ L~ 0 0 0 (~ 0 0 CD ~-- el ee Z Z I-- ~-- I-- Z -1 0 ~ N O 0 u. oe oo oo m. 0 el ee ®e ,tie I~ ~-', 0 !.-- lo ee el el z I--- :>- J-* ee ee ee ee I-- z z Z I-- f- 0 Z ~ 0 .~ N O ee ee le el Z I-- ~. I-- Z h- ee ee ee ee ee el el Z Z t. ieee ee ii ii il el b.,I ,-'~ 0 I.-. CO O~ Z ee el el ee ~ ~z~ Z I-- - 0 ,,+- lo e® eo · ee ee ee ee el e® e® ee LAJ Z 0 0 22 CZ~ Z u.I Z 2~ el ee e,~ee el -J --] Z ~- i,i Z ~ ee ee ee el el el ee W '"~ 0 I-- el el ee el Z i- ee el ee I® ee ®® t- O 0 0 ~ 0 0 V ~ooo~ i i i i PETROLEUM TESTING S[,~VICE, INC. FILE NO.- 70096 DATE: APRIL 22, 1992 CLIENT: BRITISH PETROLEUM EXPLORATION WELL: 2-54/Q- 12 FIELD: ENDICOTT STATE: ALASKA DEPTH INTERVAL: 114-15.50-11630.70 POROSITY HISTOG;~M (feet) 100 9o 8O 7o ~ so ~ 5o E ~o 30 20 10 Cumulative Frequency Arithmetic Mean 1 1.0 ...... Median Value 7.8 10 15 20 POROSrlYo percent 25 100 9o 8o 70 ~ ~o ~ E 3O 2O 10 o 30 PETROLEUM TESTING SERVICE, INC. FILE NO. DATE: ,. ?U096 APRIL 22, 1992 CLIENT: BRITISH PETROLEUM EXPLORATION WELL: 2-54/Q- 12 FIELD: ENDICOTT STATE: ALASKA DEPTH INTERVAL: 11415,50-11694,65 (feet) PERMEABILITY HISTOGRAM 100 9O 8O 7O ~ 6O ~ 50 E ~o 3O Cumulative Frequency Geometric Mean 3.2 Medlan Value 0.4 2O 10 100 9O 8O ~o ~ E 3O 0 2O 10 0 .005 .01 .02 .04 .08 .16 ~ .64 1.25 2.5 5 10 20 40 80 160 320 640 1280 2560 5120 10240 PERMEABILITY, md PETROLEUM TESTING Si:.,<VICE, INC. FILE NO.' DATE: '/u096 APRIL 22, 1992 CLIENT: BRmSH PETROLEUM EXPLORATION WELL: 2-54/Q-12 FIELD: ENDICOTT STATE: ALASKA DEPTH INTERVAI~ 11415.50-11694.65 (feet) GRAIN DENSITY- POROSITY CROSSPLOT 3.50 3.00 z 2.50 z (.-3 2.00 1.50 ' m m~ mm m~ mmm mmm 0 10 20 ,.30 POROSITY, percent PETROLEUM TESTING S(L,<VICE, INC. FILE NO' DATE: /d096 APRIL 22, 1992 CLIENT: BRITISH PETROLEUM EXPLORATION WELL: 2- 54./Q- 12 FIELD: ENDICOTt STATE: ALASKA DEPTH INTERVAL: 114-15.50-11694..65 POROSITY - PERMEABILITY CROSSPLOT 10000 1000 100 10 0.1 0.01 J. EAST-SQUARE REGRESSION EQUATION Permeobility = 10(0-21 x Porosity-1.98) I mira Il 0 10 mm II m 20 30 POROSITY, percent (feet) 0 0 0 0 UN-CLEANED PERMEABILITY VALUES British Petroleum Exploration 2-54/Q-12 Endicott Field Sample Number 244 245 246 v 247 248 249 v 250 251 252 253 Depth Feet 11623.61 11623.75 11623.76 11625.85 11625.95 11625.96 11627.05 11628.05 11629.25 11630.70 Permeab i 1 ity (md) 261. 1510. 997. 418. 543. 32. 495. 311. 1420. 94. d ~J N N N ~ ~J N N 0 0 0 0 0 0 0 0 II II II II II II II II II 11 II II II ii II I! 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REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY MPI 2-54/Q-12 WELL NAME ENDICOTT LOCATION AL1091D41 MWD 12/09/91 JOB NUMBER KEVIN DESORMEAUX TYPE SURVEY DIRECTIONAL SUPERVISOR DATE NAME TITLE SIGNATURE 0.0 FT. 10935 FT. DEPTH INTERVAL FROM TO 11/03/91 11/19/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. Alaska Oil & Gas Cons. ~nchorage ee ee ee ee ee · o0 O4040 .~ Q 0 r~ II II II Z. II 11 11 II II ~m ii ii rtl ii ii II Z II II 0 r~ II II I-~ ~ II II ~ ~ II II rO~ II II 12. 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II I-~~ II Q ee 0 H 0 0 0 II II ~> ~ II II ~ II II ~ ~ II II ~ ~ II II I I-t II II I~1 I~1 II II ~ II 00000 00000 II ~ II 00000 II~ II 00000 II r~ II II ~ 1~ II II ~ ~1 II II r.O ~ II ooooo ooooo ooooo ,-I ,-I ,-I ,-I Z~ZZZ ~o~ ZZZ~Z ooooo 00000 00000 ,-I ,-i ,-'l ,--I ,-I o~~ ~o~ oo~ eee 00000 JJJJJ 00000 00000 ZZZZZ ooooo JJJJJ 00000 00000 0 0 00000 00000 00000 00000 00000 00000 0~~ 0~0~ ~0~ ZZZZZ o~~ o~~ ~~o .00000 00000 0~0 ~00~ ZZZZZ ~0~ ZZZZZ ~~0 0~~ 00000 00000 o 0 II o o ~... o m II II II II ~0 o~ ~0 II II II II II ooooo II ooooo II ~ ~--. c0 m o II ~~u~ II II ~mo~ ZZZ~Z ~oo~ ~o~ eeeme 00000 00000 ~~o ZZ~Z~ ~o~ eeeee ~o~ ~~m ~o~ ~~o ooooo ooooo ~0 ~ 00 c~ o ~o~ 00oc0oo ooooo ooooo o~~ ~o~ 00000 00000 ~0 ~ O00~ 0 m o o ,-.-I co H o 0 m II II II II II ~ II II ~ II II ~ II II ~ 1~1 II II ~ ,,~ II II H ~ II II ~ ~ II II I~ II II Oi--1 II O~ II ~ ~ II II ~: II II r~ II II D ~ II II ~ o II II ~ I~ II II ~ ~ II II~ II II ~ II II ~ II II ~ II II 03E-I II ~ II II 00000 00000 0,~ O~ ~ L~ 00000 00000 00000 000~0 000 ooo ooo 0 ~0 Z om: o ~ ! o O~ I ZZZZ~ ~0~0~ ~00~ ~mmmm ~0 ~~0 ~~0 00000 00000 00000 00000 00000 00000 A/ A I PRUDHOE BAY DRTLLTN6 Marker Idenbtf~cation HD N/S E/N &) KB 0 0 N 0 BI TD t0935 t~87 N 4257 MPI 2-54/B&2 PLAN VIEH CLOSURE .....: 44t9 ft N 74.42 DECLINATION.: 30.00 E SCALE .......: 1 inch = 800 feet BRANN .......:~.2/09/9~. ,, SPear Land D~rect~onal 5200 ........ · 4800 ............................................................................................................................................................. 4400- 4000 ....................................................................................................................................... + ......................................................... ~ .................... ~ .................. : ............................................ q ................. 3600- ' 3~00 ............................................................................... : ......................................... ~ ................... ~ ................... ~ .................. ~ ........................ 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I i 7201 961 -600 0 600 t200 t800 2400 3000 3600 Section Depar~.ure 4200 4800 5400 6000 6600 SUB - S URFA CE DIRECTIONAL r-~ UIDANCE i'~ ONTINUOUS I-fl OOL SURVEY ,:'':~ RECEIVED ~nchorage Company BP EXPLORATION Well Name 2-54/Q-12 MPI (2078'SNL,2328'WEL,SEC 35,T12N,R16E) Field/Location ENDICOTT, NORTH SLOPE, ALASKA Job Reference No. 92013 Lo~lcjed By: JEFF FORMICA Date 06-DEC- 1991 Computed BV: R. KRUWELL Z J I- uJ L U :~ ~ O U u / z O 0 ,'- I- _1 i / I-- 13. 0 0 X ~ U T Q. I Z 0 nn O,,I I.IJ Z U I Ul ! 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F'F'F"i ...... !'"F'F'! ...... i'"f"'f'"i ...... FT"i"'i ...... !'"f'"F'! ...... i'"~"'i'"~ ...... !"T"f"T"i"T"FT'T": ........... ""'"?"?' ....... ?'"" ...... ?'"'"?"~ ............................................................... ~'"'"'~'"~ ...................... i ili i:i:ii i i!i l:::iiii::::::i:iil ii i::i[iiii iii :: .... :,:'"F'!'"F'f ...... ;~'~"'"f"T"?"f ...... !"'T"'!'"f"."'T'"FT"i ....... F'F'f'"f ...... f'"f"!"'f ...... r'T"f"'f'"t'"FT"F'I ...... f"f"'f'"i ..... FT"F'f'"t"'f"T"F'~ ..... i"'FT'T" AOGCC GEOLOGICAL MATERIALS INVENTORY LIST COMPLETION DATE ! ~- I ,"° I .~,~' CO. CONTACT & NO. i form received received date comments 407 ' no 3/~ ?//ga~. completion report 403 yes no sundry application 404 yes no report of sundry application Open 'req~iired received Cased required received r~rodudiorrequhed received ,!!,,°,l,.e Io9 hole log MUD GCT I'EMP 'DI~SFL ' ' 'cNL" P~OD ' DLL' cbt ~ ~ PRES8 '" BHCISL CET ~ - ,~ SpINNEfi 811C/AC E~ OTHER DATA LSS " PERF ~EC 'Sss ac[ n Data .... FDC- [~ ~ Well FDC '" ~WD rcqui,cd ,cccivcd ~AMPL~ icqui~Cd'~C'Ccivcd MWD , , , LOOK, ~.,. / Analysis ,, , , ii ii ....... , , ,, , ....... , ..... i , .u i i i i MEMORANDUM Sta e of Alaska ALASKA OIL ~ GAS CONSERVATION COI~ISSION TO: Lonnie · Smi~:!,,,/" DATE: Nov 11,. 1991 Commissioner FILE NO: DA. 1111.4 Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test BPX DIU MPI Q-12 Permit. No. 91-122 Endicott Oil Field FROM: Doug Amos~ Petroleum Inspector Friday Nov... 8,~ 99~ I traveled this date from AAI's KRU 'to BPX DIU MPI 2-54/Q-12 well to witness the BOP test on Doyon Rig No. 15. 'The testing commenced at 10:30 am .and was concluded at 5:30 pm. As the attached AOGCC BOP test report indicate~ there were two failures during this test. The choke ].ine HCR and .manual valves were replaced and retested. I found no other non compliance items. In summary', I witnessed the BOP test at BPX DIU MPI 2-54/Q- 1.2 well on Doyon Rig No. 15. The two failures encountered during the test were replaced and re.tested by me. Doyon Rig .No, 15 has bee.n stacked out for the past 3 months. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report OPERATION: Drlg / Wkvr Operator D/~/ Well ~/U~'T~I~.~_ //v~P/ ~.,,~/,./~,)-/~_. Location: Sec ~ T JZ~ R J~ M ~, &~, Drlg contrctr ~~ Rigg Location (general) ~ Well sign ~0 Housekeeping (general) Rig ~ Reserve pit ~ .... MUD SYSTEMS: Visual Audio Trip tank .V~ J ~ Pit gauge ~"~ I J Flow monitor' J / Gas detectors , y J ~/~' BOPE STACK: Test Pressure Annular preventer Pipe rams U ~L ~ Blind rams ~t~ Choke line valves HCR valve ~ v~l~ Kill line yes Check valve TEST RESULTS: DATE Other TEST: Initial J Weekly.__ Representative Permit # / ~ '~{~ Casing set ~ ~ ¢ ~ / ~ Rep ,,,(/j ]~ ~ ACCUMULATOR SYSTEM: ~' Full charge pressure Press after closure /1 Pump incr clue press 200 psig min Full charge press attained ~ min ~., Controls: Master Remote Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly J _~Test pressure Lower Kelly j ~ Test pre~sure Ball type I ~Test pressure Inside BOP ~ ~Test pressure Choke manifold ~'~f'' ! Test pressure Number va1 yes Number flanges Adjustable chokes :"~ ~, Hydraulically operated choke /// i / ft psig psig sec sec Failures ~- Test time 7 hrs Repair or replacement of failed equipment to be made within ~days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: J / Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) WITNESS ALASKA OIL AND GAS CONSERVATION COMMISSION October 15, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501~3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Karen M. Thomas PBU Senior Technical Assistant BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 2-54/Q-12 MPI BP Exploration (Alaska) Inc. Permit No. 91-122 Sur. Loc. 2078'SNL, 2328'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 252'SNL, 1860'WEL, Sec. 35, T12N, R16E, UM Dear Ms. Thomas: 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 mechanical integrity of the injection wells ~ust be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3) before operation. Please contact the commission at least 24 hours before pressure testing so that a representative of the commission may witness the test. rman ervation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game~'"¥'H~'bitat Section w/o encl. Department of Environmental-'~Conservation w/o-.encl. .... STATE OF ALASKA { ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillFIIlb. Type of well.~'x'~l~;i;;~l-I Stratigraphic Test [-I Development oii'l-I Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator :5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 fe et Endicott Field/Endicott Pool 3. Address ,6. Property Designation Po O. Box 196612~ Anchorage~Alaska 99519-6612 ADL 34633 4. Location of well at surface '7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 2078' SNL, 2328 WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 320' SNL, 1680' WEL, SEC. 35, T12N, R16E 2-54/Q-12 MPI 2S100302630-277 At total depth 9. Approximate spud date Amount 252' SNL, 1860' WEL, SEC. 35, T12N, R16E October 15, 1991 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 34634 ~ 3598' feet 2-52/S-14 @ surface -101eet 2560' 12252'MD/10546'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) KicKott depth 3000' feet Maximum hole an~lle 38.1 o Maximum surface 3900 pslg At total depth (TVD) 10000'/4890 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 75' Surface 131' 131' Drive 16" 13-3/8" 68# NTSOCYH~: BTC 2644' Surface 2700' 2700' 2305 cu fl Permafrost 12-1/4" 9-5/8" 47# NTSOS NSCC 9594' Surface 9650' 8500' 12-1/4" 9-5/8" 47# NTgSHS NSCC 1280 9650 8500' 10930' 9506' 2370 cuft Class G 8-1/2" 7" 29# ~..~o TKC 1572 10680 9310' 12252' 10546'401cu ft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production 00~' U ~ Liner Perforation depth' measured ~0il & ~aS (:;0~S. true vertical i NtCh0f~g~l~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis l-I Seabed reportr-I 20 AAC 25.050 requirementsl"] 21. I hereby.~rtify that the foregoing is true and correct to the best of my knowledge Sign?d~ ~_~. C'~'-'~_~o-,~t.~_.- Title Senior TechnicalAssistant Date/c~//~)/~/ /-- CommiSsion Use Only / / Permit Number IAPI number IApproval date See cover letter ~//-//.~2-- 150-E3 2...~'--- ~ ~ ~//~ I / ~"'/'---'")"-- ~' / for other requirements Conditions of approval Samples recLuire~d [] Yes /I~[NO Mud Icg required. CIYes,~ 'No Hydrogen sulfide measures [] Yes .,~ No Directional survey requ~rea ~ Yes II'No Required~.j;zE.e.~sure for BOPE" 1-12M; 1~3M; Ii'SM; I-IIOM; []151rvl; ~.^---r-~~--'~-~ ~ ~_~.p_p u,v~e,~~~---,)~ ..... Commissioner by order of the commission Date Form 10-401 Rev. 12 Submit ate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-54/(;I-12 (MPI) Ob!ective Well 2-54/Q-12 will be drilled as a water injection well. Zone 3A is the primary objective. The completion will be run at the time of drilling and will consist of a packer tail pipe assembly. ODeration Execute a ' move to slot 2-54 and rig-up. Vertically drill 17-1/2" hole to 2800 feet. rl~un and cement 13-3/8" 68#/ft NT-80CYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4890 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Drill 12-1/4" hole to the intermediate casingpoint above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Approximately 240' of Zone 3C will be cored. Run open hole logs. Run and cement 7" 29#/ft, L-80 buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to landing collar. Test casing and lap to,, 3000 psi. Change over to NaCI packer fluid. Run CET/CBT/GR/CCL in 7 liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with a simple completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Fluids incidental to the drilling of the well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. PC 10-7-91 ~ ENDICOTT PROPOSED DIAGRJi'" WELL 2-54/Q-12 (MPI) NON-FREEZING FLUID TVD (BKB) MD (BKBI 30" DRIVE PIPE BASE PERMAFROST SSSV 131 FT 131 FT 1466 FT 1466 FT 1550 FT 1550 FT 13-3/8" 68#/FT NT~8OCYHE BTC 2700 FT KOP ( DIR: N 69.24° W; ANGLE: 38.14 °) 2700 FT 3000 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3000 FT TOP OF 9-5/8" CEMENT (ESTIMATED) 3500 FT 5-1/2", 17#/FT L-80 TUBING WITH 5-1/2" TAILPIPE 9-5/8" 47#/FT NT80S NSCC 8500 FT 9650 FT 9-5/8" PACKER 9270 FT 10630'FT 7" LINER TOP 9310 FT 10680 FT 9-5/8" 47#/FT NT95HS NSCC 9506 FT 10930 FT 7" WD PACKER WITH 4-1/2" TAILPIPE PLUG BACK TD 7" 29#/FT NT95HS TKC LINER 10546 FT 12172 FT 12252FT PC~10-7.91 ~ ENDICOTT DEVELOPMENT WELL 2-54/Q-12 (MPI) TRUE DEPARTURE TO BHL: 5148 FT NORTH 12252 FT MD GRID 10546 TVD (BKB) DEPARTURE TO 11941 _FT__MD -~._N 69.24° W 10301 TVD (BKB) ~ SLOT 2-54 SURFACE LOCATION X = 258,875 FT; Y = 5,982,342 FT 2078 FT SNL; 2328 FT WEL SEC 36 , T12N , R16E NOTE: THE NEAREST WELL TO 2-54/Q-12 IS 2-52/S-14 LOCATED 10 FT EAST AT SLOT 2-52. 1~C 10/7/91 BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM STACK DRILLING RISER i I ANNULAR PREVENTER I PI PE RAMS I I BLIND RAMS 2" KILL LINE MANUAL HYDRAULIC GATE GATE (, DRILLING SPOOL I 4" CHOKE LINE HYDRAULIC MANUAL , GATE GATE i · PI PE RAMS ! ,'50 $6 ___ ii I 'tO ¢/' ~ 0 ~1 0 ~g 0 CERTIFICATE OF SURVEYOR I llearby certify that I em properly registered and licensed to proctice land surveying in the State o~ Alaslcaend that this plat represents an proposed location for tko'Well numbers shown above. Ail surveying was done by me or under my supervision, and that ell dimns~ons end details ere correct. DRW. 116-85 . SHEET Z of I0 REV. 0 0 Indicates well  Indicates Celc~lated Section Cern4r Posit~on Indicates PerlNndicaler Offset Distance lndicstee ~~iculer Off~t Distance ( ~endicular ~stQnc~ ' PLAT ~PI PROPOSED WELL LOCATIONS LOCATED IN IEC. ~l~ T.I~ N., I. Il E. UNIAT M. I~EPARE0 /:OR SOHIO ALASKA PETROLEUM CO, PREPARED BY F.R. BELL & ASSOC.' PRUDHOE BAY OFFICE PRUDflOE BAY, AI. ASKA I I DATE' NOV. I$, I~lS SCALE~ I '. ORA'MN IY: R.~.T. CHECKED BY' I.E. . _ __ I I~ I" I I IIII I~LL ~IP ZO~ $ UTh ~ : 6 L~TIT~E Lk ~. ~ JlIT~ JilT ~ 43 Y- S9i22~.7l N- 7105263.~3 70~2~'00.0909' 14~S7'24,~26' ll~.JJ liS?.9& X' '~9043.09 E' 464096.41 2306,26 X47~57'28.4623' 2036.36 44 ~- 598238~,29 N' 7805292 9~ ~TO'2X'Gg.0054' X' 259903.84 E' 46405~50' . + .... 4~ ~='-~277.~ ~ N' 780~2~X'.~0 70-2X'08.008~' ~47~57'24.4~2~' 2~7'.-70 ~X~ 2~057.~6 ~' 4640~4.70 4~ 'Y'x- ~982375258898:10 ~N'll E- 7805290.414640,1.79 ' 70:21-:~-9230:'i 147~57'28:6221:: 2044'73~ 2305.73 X- 25903~.62 E- 464092,99 ~ , N- 7B05287.B9 ~70c21'08.8407" 147~7'28.7~20' 2053.10 ~ 2~1.20 4B y- ~982366.91 X- 2~8892.37 E- 4640~0.08~, 49 Y~ 5982261.21 N- 7805256.35 70~2~,07.8439. 147o57'24.7122· 21~4.44 ~ 2~74.38 X- 259025.89 E- 46409~.29 ~0 Y- ~98235B.71 ~- 7~05285.36 70o2~,08.7584· 147o57'2~,94~,· 2061.47~ 2316.67 X~ 258886.63 E- 464048.38 5~ Y- 5982253.02 N= 7805253.83 70c2~,07.76~6. ~47o~7'24.9420" 2162.11I 2X79.~6 X- 2~9~20. ~5 E- 464089.58 52 Y- 5982350.52 N- 7805282.84 70c21,08.6760· 147o57'29.1017" 2069.,5 2322.14 X- 2~8880.90 E- 464046.67 ~3 Y= 5982244.83 N~ 780~251.3~ 70o2~,07.6793. 147o57'25.10~9" 2171.19 218~.33 X- 2590~4,41 E~ 464087.88 ~4 Y- ~982342.33 N- 780~280.31 70~21,08.5937· 147o~7'29.26~5· 2078.22~ 2327.62 X- 258875.~6 E- 4640~4.96 55 Y- 598223664 N- 780~248.78 70c21'075969" ~47°~7'25.26~7" 2179'56~' 2190'80 X= 259008.68 E- 464086.17 . ~6 Y~ 5982334.14 N~ 780~277.79 70~2~,08.5113. ~47o57'29.4214· 2086.~9~ 2333.0~ X~ 258869.43 E~ 464043.26 57 Y- 5982228.44 N= 7805246.26 70021 '07.5146" 147o57'2~.42~6" 2~B7.93 ~ 2196.27 X- 2~9002.94 E- 464084.46 58 Y~ ~982325.95 N~ 7B05275.27 70o21,08.4290· 147o~7'29.~812" 2094.96 2338,56 Xm 258863.69 E- 59 yt 5982220.25 N- 7805243.73 70c21,07.4323, ~47o57'25.5114· 2196.30 2201.74 ~- 258997.2~ Es 464082~ 60 Ys 5982317,76 N- 7805272.74 70~2~,0B.3467· 147o57'29.7~1· 2~0~.33 2344.0~ Xs 258857.96 E- 46403q.85 61 Y- 5982212.06 N- 7805241,21 70e21,07.~499· 147o57'25.7413' 2204.67 2207.2~ Xm 258991.47 Em 464081.05 62 Y- 5982~09.57, N- 7805270.22 70c21,08.264~. 147o57'29.9009' 2111.71 2349.50 Xs 258852.22 E' 464039.14 - 63 Y- 5902203.87 Ns 7805238.69 70°21'07,2676' 147o57'25.90~' 2213.05 2212.69 X- 258985.74 E- 464079.34 MPI PRO~SED WE~ L~TION LIST ~ ~ A/'.~I~. LOCATED IN ~C. 36,T. IZN.,R. I6E. UMIAT A ~4' L ~~~~~ s.[[r ~ ~o F.~. aELL & ~SSOC. SC,L[' ./* - PRUDHOE 'BAY OFFICE - - DRAWN BY : R~.T eEV. O PRUOHOE "" \;;, ,~ -- ::'~ t ix ( ,:,:-; .' ,~; ( .- r ( -- ~ , t ( I '" ,. " .. .- A()29-21722C1C= 1..Z2-A 6-2 ??ûD-Q C-f" .220.Q..£ A029-2171300 'Ml-n'"7~ 269. 9 O. 0 0.0 0.0 O. 8 f'-1I-J22 219. 8 f À. x-A 4. 1;1,.;17· .~.l J Jii.~Ói:6.,~.:_:.::. AÖ29-2164800 1'11-01-" A029-2166200 !'1I-P14 A029-2lf.a:;¡90 foil -M25 {,029-2167200 "MT-f125' AD29-2169300 NI-P;;:O 4t"'\~c--'-; \~=~t;.-. .L I. , 2099 S o û ;;: 1 Or) 3 l...2.L..:.E- ~ A .4..O!L-O .Q........Q An 1 o· 226. 4 O. 0 Ü.Q 0.0 0, 9 127. 3 4. 1 11 00. 0 '\..!'. ..... 1100.0 .. 4£L..1 , 0-..--2 ~ ~ .t~9- INEARBY\ ïVD ' DEPART r~+-Ð"""..e~titìj 225.2 lSQ::ì~'ÇL _0.:9 .--~.-- ."----- ." 6.3 1800. '7 173.1 0.0 0.0 0.0 :J;=~~~¡~;:;~2_~~g~~-=: ~:;:,-~;:~~:~<~c~<:E~~g~s~c:;-~,~~~~;7~J¥;'""..i~~;~:,: 7':.- r-7IST"1îO' .c.....""!"' ":' "'C;-" ...,. Ltl!"H ~ "'.a~ h "c, 11,L,.R ":! . , A029-2156800 MI-P18 4n~9-2158C:'OQ .J'I--:!"1)_9. A029__2160~OO t·n -Q;!O A029-2162~OO 1"11 -G21 0.9 30.5-3 .l..5--2 23QÇ 0. r, r, ?4t'\...... ~. 2601. 1 ..c_9i~o "-.. 280~6'" 2600:'0 289. 6 2.0 1100.0 0.0 1100.8 1689. 6 14.6 2799,,9 2807. 2 AOOO-0000051 ¡,¡¡ - 1 ^ 0nf"\-f"\~"''''\(''\''~'? Mf':' 33';;~;c- AOQQ.-OoqOO86 MT.;..;.:J6~-' AOOO-0000119 riI -69· -ifR~~âÞ'~~;~'?- A029:""'2Ó245ÓO. . MI-SD4 A029-2051800 M!-SD7 r., r. NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 'N~4-~:;~œ!~~~~rr~lI~1¥E1fÉJ~~~f;f"~;~~il'~¿~3~·.;;....;;t~~d~:':!;;~~ - . ,. NQ COQRDINATE :=:p:-;;:r¡n~"\,n -"HÏ~t:êpE(, IF IED:-SEAR(,H~WI NDQ^ìT~ .-. --_._-_._-.-;---;-~----- _~___ __. ~~. u____...__ ~ NO COORDINATE~POINTS WITHIN SPECIFIED SEARCHWINDöW:';:·~ NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW ,:. € VERTICAL DISTANCE ¡..sEt.L,~IDr;~T ,,[; ----~--- t .: Page ---""":;:":--··..;.--:.::-~-2~....:- /NEARBY\ TVD.::- . -DEPART ¡PROPOSED\ TVD"~:~'DEF ART .>CLOSEST 'DISTANCE "ST'~ic,;¡l Mt-Î " &t'11 _.~-' ------------------------------------------------------------------------------------------------------------------ bkl.:t.a . I t'p" 1:' ····r...."'··J ........_01'0":..1 I']-rf"'-''''§ 10490.00 ~~Oð£~ o~ ~OO~~4~ ~0 254123.42 5984324.08 Bott.om ~ .5.6......0f' TVD(SBS) S-N W-E Location Search Radius= 900 COURSE LJN~ r::""'" p"''''rç<:,ol'f ,..-",. 2-"tLLG~'f~ £31,·.,35-12=1-6.J ---- -------- I.LJJ-\1'~ L ..L.. Of _.t. ~ -c:: ..,: _~·1 r,~ Closes·t Approach Analysis 4-0CT-1991 15:25 S4·:f~[;!.¡A-::~£'~-:· ~j.-,h·i..~!·..;::~~:::.::.:_;!f-i1(~:j;~ C-i_.C1~~AF- :-:'~Cj;::- =_:.:::.; ¿b -~---- "---.. -- ---" O. I] 199.7 ..¡ O. Q 140. ,- SO. ~ -' --- --- --- -- ----- -. - - - --- i.J. ._~ -~---~--------- tJ. lJ \...J. v -; :!~i! \ ~ 0.0 o. (] J ~n~9-~~1!~{ln(1 --. j ~"1 'r - ~-3 r~ (; \1 .., 2-32íS :~ _----8-02-~- ,~::,rY:r(;Q,ü___ ___ ___i.DÜ0......9 :-'1 T -, ! i ,-. A029-~?20R400 ". Î;QZ9-2~CS5C~J ).. ) O. 9 ì'H-L15 148. 6 57, :5 . ~'·-'O _ 0 ....~ ---- --------" ? 2698.0 ,.ntdo:o~~c~-''C·'~7~I·c"''E·'3~·:·:~:~:·~::~:'!;";;~-a9.~· 5'~:'?~::" 170.6 5. .;;.1 '"0' ¡ui '", -; ;: - _~.=_ . " .-- ,_. ~ I __ .:;: ~ A029";'2189900 ~ ,_. ::.0. .2~-"-: _ . ~,"'", 11._~_. ._:1'¡=J~¡.5.., . _~_.._~JºJ){t_?,___... ,..,.It. Q~.u. :. 'jQ~J;L~_-"-,__7:1_ :L~. ~-"-"'-E~ë.~;3<o.2,=. C"< ~ S'i:~!~;!~~7~~!~:~~:~~~~~~0P:!~~'c~: .. iJ.¡! f'1I-G15 3926. 7 154. :5 3925. 3165. 4~' 22.1 .,;) ,35: A029-2193100 J...~I ¡....-¡ !"1T -t i ~~ :3ìi ~~Ä029=21ge~O MI-T20 ';'¡','''',--.~--:' ::.~"-<".:...~ '~ ;':""'183.9 0.0 -~, ,-..., 6--:;:~~,.o.~'-"c.-;-"_:'-':~;·~:~:·;·· '-:Ó"~" _~'-ê;: . ~~'--_..' .~~--....-",-",",-;,..---~ 1.8.6-6 "1 -: 211~. 9 208. 0 61~4.8 195.8 4039.8 '_". >~ t.." " .. ......,~;...--':-.....:¡;'..;- ";';~é"--£~t..,.....·-~iD?~_..~~r..=,~~~-.,,-~·.. -,~7_"!<I._~.-~~~"',~ ~ ~-t-~-;;~~_ .._ __ _..._. ___,,_ 0'-- ..,- ,~~ ~~-'-~,..,.~-,---.,....~~ "--' . -·~::;~,~;--~~::=-:::=~:.~:,,~~~~~::::·~~v.;--¿::::;·~';~Z?:=-~ -~=-;_.~~-:--.:3i.~::' ~·:·~i~=~-·::- '-;r--,.--,.--",__·~__, ~-':"."'''~'- . .~, -.......-........,- .-. =,- J::-j:....r'.......':7__-__~ , .1.O..5-..S? 586. 3 ~ 3207. 0 'k 17 f... ~ .._c 8642.0. '<'>'ï:~ 4 R ' c; ..3193.0 -- 8056.2 A::.·... ~'1 -"'. -- " ----_._---~.._~--- ......~,::.. 98. 9 72. 6 :::0:-;0:';'" _ --",0'::_..0<;-,;",,", - - - " n~'.7o -:;'i-~~177': 11 160. 1 0.0 o 0 -~:--- :....::..:.".::---:~;.:E~~;~.....:H--;;."-,·~.'~~~'_··:..,..:.;..~l.. .~-.;~"". . - '-'-'- - "- ----- -- -" - -- - -" -' . ..::o:'.-....I.'-;-~.;;.;:..~"-~ - ';"":.-:;:~..,..c.;..:.J~....-.:-_,...:..-.;--;-::::".~ ~;~....""'.... _-,,_,.-: '. 169. 2-- 'n' ¿ 0 333-B 6:.....0. ~--'-------'-,- - ~~-, ~,_ _~~_',..'_'f.~'_"w~ 0; 0 ' ':: ~~'n:~i7Õ:"2 ~_ :=-00 t; 2100.0 "'0:0 0.0 " n (). (1 " D.G ',0. 0- -"<'-~" ,;..'.;....-,..;..:;..-<:'--'-y--;,;.........."._#, ,"- f\ ~.. ---.-':""-->!<"",-,',~-..-c:--"- -- .~~ ."~C_~~.M.-,,-~ Or1!" :::.. ~ r-.no. r\ ~ ,. ,'----'" 1 ;'1f;'o::-~::Ä~-': 2600,/ A029-220,q.l00 1-11-509 v. '1 '~0. r¡ íL...û ,j; ,~! 'j,..,.r1 ,:.) ~..1T _t ~ '_ \;4# ! ~~ .~~ A029-2203¿00 Id ;:'A029"'::':i201400 .J} 1H!,.-"c'"~~1"'::tlf4 ..' "". 'T40EO' .~s¡ 'AO::¡q.....??():;7f)()O 'MI-V19 ¿6~~. : ;:?Dl.L.::.ì r"'l T _IÁ ~-= l4~ .-' Î~:¡ 2100. Q MI-G26 A029-2200500 A{1:;C;-:'J 1 ~q i Chi I......., 0.9 ::>ono = 1.0.0-5 ~h__f1I":;M16: "'2'A029~2189200 MI;::':pì3 2598.2 tqJ 117! i ! j19! i19} ~.f" Î_J _9 :«', f21i l??f .~ ¡~! 1241 I~:f c~ ¡i~ :"'i~ 2599. ¡.., I -R23 ~n'"70-~'Q~Q~nu ~:!:::,::l1l;Sl·'ig'f.~ê~7é:::··~'~":Z~ '~~'3 :100:·C()!ti:.?~'"Ë;:'~..:~>.i .'7,:~~::~:;"3:~:t'~Q~â~t;7 ">A029io-2186400'" ~~ '..2 '.;"õ, , . . . ','L, ':'"?;~~~~~:"'_d H ,>.C"·";C';I""Ti;.D-:tL,'··'=·"";""'=~·_"~h~"=,~._,~ 1't..,,..,· ','."~"-"'-- . n, rv~'··' - ~-,~,,*,',·"i"'t"1't':+n ""-cF Av29~.21a73ûû 100.0 .:zo.œ:.a -'~~~-'--- .- ~'~"'~.' ~:--(ì;·"O 1699.3 0. 0 ~. '(;:0 0.0 1.0 MI-P19 , , I Q ¡ ,'f i1~ A029-2181500 ~~ ¡11i - "1'1! -N14 o¡::_~~~~~~~~~~~-' !!5i ~,,,-,c_. "'f{i'~P':"'t"~ ,,,,~<,,. '·'-f.t..¡'jf"! 7' }',"'-' "',"'~'- "'f¡--ri"'" ~':H'. ",~j1"iqqi'è'7" '-""', , ,~o ~''''''';l4:-'"'O"''C'"""' '!-4?"~':;(~R '.3. !15; 0.0 ~¿600~O 17liil í1 A02::ÿ-21a470û 260!J,'=? -~ 100 :;; 11-.7Q 4 ..,--~Ml'-S ; 4.. -"""-"'-, (4 2,....Ä:';O-,".· ..,;.;L'?,...... t·'v~' ....;....,¿, ~ '-/'... '-'-'oJ ·3 - .. o~·o.- ¡..tT'-...I1Q ,. ~ :~; 259. 8 o. ~' .~) J' .7:Z.O.-.4 30.8-5 .- q .-"'7~.~.~,.- ~~...-.-4cf'r-a-- ~("j~~ ~ 293-6 A26.3. -"--~---- 1865.3- ··12.6 5041..ó, 3157,2 ~">",·,,·,-,,o;· 0 . c~·--:-·""." .-.....~~-.-.-1 0.' 8 4.7 .- 156.9 34. 4 P -3 i~ e - I _~ 4-0CT-lS'::;1 ¡V: n° r..-~...-;,~: ,t:- . r ló99.8 MI-P24 ',.1 " . _~"'''~l.JVM:::':'~l. ~l...r:"Í.M~,,·p·.Jw::;.!\:':ì.l~:.:il.¿_"__i.-IJ~H""" _~Hi_jH i. Li~::J :¿6 AC29-2174800 -_._---_._-~--- ------- - ---- . ---- .. :~~ " < - :':: 0 ,;:r ~ '~~ G) ~~ - :..- 0 nO ~-----~---" - ~- .-..-------~-.,--~- -~--.. ---- - .,....,..,.~""_r_~7__O_=.. o ~":~_:1 G ~,-'-" --...."..--"'"""'--...,- - c c ::~ 0 -,; ~ 0 ,- ~r\~ ;;: 0 ,,(-, :~~; e ;3: ;~ ;~' ø :':1:: :~:' €) !.:,-~¡ ~ 1! :;~: @ -~, ._I_.;..·...J1.,.¡··.¿.-._...-,,,_ -... -- ..._..._.. - ____ ~_ -0- _. __ _,____ ___ ."-~-. - .~,-~.-. - ~........--""""/'oO_ ..,.-- 't-".. -,.--- - ---... - '---'- -. .--- .' :;:'~-~;'..7<";':"'" ;;......-..: -- ~~; n_______._~..._.O..____ _."_ '. ~ ..---.. - - ..~...-.:-.. '-'--- -_..- - --- ~""'!~~- ~.._,":;:"-~'-- ~ . -~"'_-.:_"~~~:2 .-.___-~~---'__- __~__;._ o~~___._~ __ ~ ___h..____.....______ _~-.__.._ ------ 3000. C) feet ~lCK OFF fDr this run The well which comes clQsest to the prcpcsed well i5: c SUMMARY' :' ~9~ -; 60G (, C'_ 0 60 :, c. 1-11 c P.3ue -:: 4-0CT-1991 15.25 S4$DVA247: [DRAN035JMIQ12_CL05AP~5HOR1_LI5;26 -------- -~----- ------- ~------ 2100.3 0.0 2099.8 17.7 219.8 0.8 U.U 0.0 0.0 269.9 ~~"0 0 n n ~~onn ~ ~ 17~ 4 -,.\ H r ," '-'.'J 900. 0 .. .~ 238. - iì .. . I 1 1 . ~ n .'-! -,~::: ::; !'rlT_. 11 q r-i I -N22 ;\')29-2174300 ~~~J29-21 72200 - rn -,,)22 AQ29-2171300 M!-C::?? 5J.¿ .-...., .:;?: .~ ! '0: :.-! ;-'1; 1461 ;- ;~~ - ~..-,--~ ----" "- ~ '...' ~ 3 !3~ ;35Í ~-<..~~~=~~~:z-_ :ã!~=~~,...:......,.- ·--:._~i·~Jo~~~.~,...i;¡.1Æ~-~t:;.;::: '.;7"',::-:: .-....-,~.i::~.}""'!--.:<~... ::,_·-.::~.~-:;"-::Sr-:~~"f:;-"_:-;~71·.-:-'"··-F~~·'" - __ _., -"--0<- ~ __~.." I ,..,., , "'-i' ._....~_. ,r, . .-. '; ,. -'" ;j -.j in; t?,!! I t '25¡ ) ;--. ¡'ot .3 ~2~ 9803·8 -c' -,:c4946 9 ·"--'~·-;--7i1.F4.-=-"--'-"·"-'-;=c; ~··i.-iS';'~-- ...a.~_'.. ~:-,_", _.....:.¡¡:r..'-, ..-~~-.-:!I.- .o.---..._~. 0- _"_...Þ._.~___ __~"~-~__ _. -VERTICAL "'- . 'DISTANCE:--·· .. . i '. 'J .¡~-.~ ~ I .' ~ w ¡ ì ----~ ,,-.- -j'NEARBY\"-' --·--'7TVD -,.,:' --DEPART -- -"_._---~------ .,.., :1::' ;..:l i ~: !9L 110¡ 11¡ ------------------------------------------------------------------------------------------------------------------ W-E :;;¡5~~'!:;. n...... ! ~ i ". ',¡ Search Radius= 900 Fu~-p?Qpø~96-~911: ~ ~--~-~-- ~.:.. --- Closest App~oach Analysis --- ---.--------- ~ ---'-- --.--------- ----~ ,:)":'I~L.5. 23L.3 .8.0_4-- 1-+0. 1 .. --,..... --.. .....,....-- .... ;..,1.._:-'::':,",,!-.=.:¿ i. :_;\_:~;~.J ~,,:. G. a '.; 1.1 72.6 .<L..O. 24~'CO -- ,'-' - '0.0 1.4...-0 .c'SOÒ9· 2.0 ó..=O -.-, ,. ~~",,~-...,., ,'~';"-"",-,..,'--¥"'--,"-,,~ .u.ö~ 0 0.2 '''''1''';qc 'O'=~_~___ ',__n_ __ ~... - --------1:"l~St~ID_- _____________~__l_ !l-----~0_0 47. 3 ~ 17.2 {1 {) 3. 'c {L,Q 18. :5 0. 0 2-32/5 A029-2209000 --- 210. 3 l.4B....-6. 252. 4 1.ZO....cb. 183.9 186.6 36-7. O. 1 5,7 --5. ,-,-'--"'-'---~"',-- ~, co.,,-.l._3 5. 1 5....d 0.0 3.7 ~~': 17'.1 """~~"-'-''':'''''..'>---''~ -~~-,;,::- Al-"~Q-?~{"'H~4(jQ l(}OO. iJ '-J. íj 1000, ~ {"\ .a () '"' '7 tofT -p i ~ A029-21B9900 -- MI-U15 ~O,~~ì~~~~~~~ A029~2~92100 ¡,n:'=.lt í'5 1\029-2193100 i'-n -L 1 .. A029-:-2198500 -'--".", --.- MI-T20 A029-2199100 MI-Q;26 A029-2200500 1'11-1.<25 ð.O;'9-??01¿ ,QO NI-Q14 A029~2202000 r'1T-Vl<;¡ A029-2203200 I'U -L 16 AO;::q-;:J;:tO"¡100 1"11-509 A029-2204800 MT -I 1 ~ A029-2205500 r'! I -Ij 1 0 0 -....,Ji I ¡'P~¡ (, ::'; ! ~ !22; ......~ ;__..J ~ C"f , ¡¿51 o :2€~ :23; Q ¡2~ I ~ ~J(ìf ;~1t ð ;d ;:;.t f3 :'~ ¡36: ¿¡ o "0' "- ..Ii> (;3 ;~ ! , ". e :J&; (J§ '~7: ð-- 23.8 íL21 ... , - -- ,- ---'~7"-,_.-.~,--'~_______,.._.,.... :,:;;O,~9 ~ ~... 2=99.8 C.O 2600. 7 .~._--- . -- 200.0 O. 0 n ',L,,"':J1"':J n 200.9 :::~qM {j Ù-Û ;:>¡."c:¡¡:¡ 9 1400.0 ._~,...--_.. 1200.0 0,0- 1200,c; ~~1{)l1 () ,. û..-O -2100 9 0,0 00 O. 9 2000.0 0. 0 2000. :5 ~A1=:?, ,..~. ~ 3000.4 98.9 60.S' 160. 1 1-58. ~ '105:9 169. 2 ~' 170.2 259.8 ~ =;¿¡¿ ,2 ~ 4701 ~ ., îO:SL'."" 3174."1 156.9 73.2 .6.0..2. 2999.8 O. 0 lD.O-Q iLû ,-':t {'in "} '0"":0;0 :::'~ M ~::-" 16~"~:~ :,~-.~.---,~.~,~.,c;.__ , "Ä029-2189200 ·:·0.0" ~-"--;-- - 4.\.n?Q-~ 1 MH Sí10 2598.2 0.0 2599. 1 ï1I-P 19 ?1029-218 -1:1' '0 My.....S17 1\029:'-218"6406 MT~P-T~- .. A029-2187300 MI-R23 0-0. ,~ '317i~;5: 3172.7 5:6 0.0 V.O 1.0 I' {'\1 599 f A ::~; A029-21815ûQ. '-, i' NI-N14 2600. 9 :': .... A;ì.2~~27C'0 ~) ::~;5';~~S~§S'~f~¡1~bd::~~::~~~;::=::_2893;""O : t'iI-P21 HI' .Q A029-2184700 242-2 1873':T-'_.._·_m~. P.3ge 2 ~ -13:7 5.6.0--2 5046. 8 5. Ó 4-0CT-1991 15:26 ---------~--'----------------------- ----- 0.0 2600.0 , 17000 .:zo.o...-O A~""'29-21 ""7eo::.f""\nf' -:"~:.....tjf.:.ê_"_f4_-:..:-~.~=:----"·~~ :c O----..-·~ -'-þ:-Ö 'A029-2176700~ MT'-!?i'=' --, ',or; Q n(1 A029-2177100 MI-K16 100.9 0.0 At'l;?9-217osr,n MI~R25 -I.D 0_0 'A029-2180100 '"Ml:o-t19 ¿ 6,9 4 () 0 4y' . ;3' 'c,-,O..O 1"""\ '""'" - ' 100.0 0- __ ··__~'~_~._~__,'~_,'___~_~r______ . 34. 4 . -, 1699.3 O. Q 1699.8 A029-2174800 MI-P24 _~4$DUA24ï: [DRAr;!t)~~~ Ji'1I Q l:~__~:LtJSAP _SHORT"? LIS; 13 .,' 0 ¡ ;) ; ~ ~ .. _.~ t') ~ ,~ 0 () g ~ f9 Q) G F:>¡ "".- C) (~ :'; 42; ¡~3! Q :.~ ;~~ ";í) ~.-J ,4ï¡ ~- ~~B¡ '~;i Q:ëi Jo.¡ --j Q ~,: ~ it .- --- .------ -------- - ._---~----------------- -- ---- --------- -. ".·~·~~.'o_c___·""'."..._."...,.....>-~-~..._.<_.__~_,__"'"'...____.~-=-~___~"'.__~~= _. .,..~__"""'"'""___=__~_=_.<,_'_.,._=_~._ -'40_<.0..-,........_ ~ _.,",.~. - I J !'II I.l 1. 1. ~ ~o;¡.;.ct. -------- ._------ ,-.~ Page 3 4-0CT-IÇ91 15:26 ~l~: ' .... _··~",+~JUVH¿-'-+.I = L L't'(H!\H_ ~~ .1S"11 ~~ 1 ¿_',-"LU=-i~}'-I _-=rEj~~ : - - ASKII iii ?f - ,g/IA I -I ::1 8-0 ~9 (~oa) 4.6~-15.f0 Do IF IN DOUBT--- ASKll i ~ I~ [ Il ilL' L - I Il I '/ __ l DOYON DRILLING, INC. RI G NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Shaker Desander Mu dci ean er s ~en tri fuge Manufacturer Brandt Nominal Model Capaci t~ Dual Double Demco 2-12" cones Tri Flow 1000 gpm 700 gpm (each) Double 400 gpm 8 each - 4" (each) cones Pioneer Mark II, i50 gpm Decant i n g }egasser Dr i 1 co ~9i tarots Brandt ~ol~pers Geosource Vacuum 1000 gpm 8 each - 25 h.p. Dual Sidewinders 1000 9pm Fhe trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drilling recorder system that contains ~isual and audio warning devices located in the driller's console. ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL 2-54/Q-12 Interval 0- 2700' Mud Weight Viscosity Fluid Loss ~ .(S.e.g./g~ i'ml/3Omin) 8.8 - 9.8 100-200 Set 13-3/8" casing 20-15 9.0-9.5 Mud Type/ Com.Donents Generic Mud #5 Seawater Fresh water Gel Soda Ash 2,7OO - 10,930' 9.0 - 10.2 40-45 Set 9-5/8" casing 15-16 9.0-10.5 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill 10,930 - 12,252' 9.O - 10.5 40-45 Hang 7" Liner 6-8 9.0-11.0 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill --TEST PLUG --PACKING PORT TEST .PORT --LOCKSCREW CASING HANGER SPLIT SPEEOHEAD ! 3 - 3/8 -- 9 - 5/8 1. ] 1B-5/8" APl-SO00, I3-5/8' API-3000¢ CONTROL LINE-- 13-3/8" 9-5/8" CONTROL LINE 4-1/2:' WELLHEAO ASSEMBLY,ENOICOTT 5KSI IB-B/8"x 9-5/8"× 4-1/Z" SOHIO ALASKA PETROLEUM COMPANY 1." £CtJR~ I (3) -- SPL I T SPEEDHEAO TEST PLUG (30) 13-3/8" 0.O. CASING II. 3. 9-5/8' CASING AND WELLItEAD EQUIPMENT 3.1 TESTING B.O.P. STACK 1. After B.O.P.'s are nippled ~p to split speedbead, make .p 13' x 4-1/2 Inter~al Fl.sb B.O.P. test plug, Accessories Item 7, Part No. 538116. 2. Lower plu~ into head (it will land on lower step). Tighten 4 lockscrews 90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plug. CAUTION: It is very important not to have the lockscrews protruding into the bore of the head while either running or pulling the B.O.P. test plug. Always check them if in doubt. (29) ACCESSORIES ITEM 6 /~-~ {F ~E~LE ~hO 2'1,0 BOP TEST PLLT..} FOG UPPF...R BOWL - ACCESSORIES ITEM 7 t2.~ OIA /t,.V2 I~ F'E~4 AL ~ , / ;I l v I / 210 · F_.,."- 'c'T__ ;LJ.} ,cOF~ LDWERP_.OWL '~:8~:6) (19) II. 4. 4-1/2 TUBING AND WELLHEAD EQUIPMENT 4.1 TESTING B.O.P.'s 1. After 9-5/8' has been set and tested, run in B.O.P. test pluM, Accessory Item 6, Part Number 538117, which lands in upper bowl of the split speedhead. Run ~n 4 lockscrews liMhtly, 90° apart to keep plum from movinM. 2~. After test, retract lockscrews and pull pl-M. 3. Run in short bowl protector, Accessory Item 8, Part Number 538114, usinM the same running tool, Accessory Item 5, Part Number 5381~5, that was used for the long protector. 4. After bowl protector is in place, run in 4 lockscrews liMhtly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P~ test plug is either run or pulled. ALASKA OIL AND GAS CONSERVATION COMMISSION October 14, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. f~02.1~. Re: Spacing exception for Endicott 2-54/Q-12 MPI well Mr. Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Chan: We have received your correspondence dated October 7, 1991 requesting a spacing exception for the Endicott 2-54/Q-12 MPI well. As proposed, the well will penetrate the top of the Kekiktuk Formation within 577 feet of the 2-44/R-12 well and 846 feet of the 2-42/P-13 well. Well 2-54/Q- 12 is programmed as a water injection well to be completed in the Zone 3A interval. Neither of the immediately adjacent wells are to be completed in Zone 3A. The Commission has determined placement of the well will not promote waste, will enhance recovery, and hereby approves the drilling of the Endicott 2-54/Q-12 MPI well as proposed pursuant to Rule 3 of Conservation Order No. 202. Sincerely, Russell A. Douglas~ Commissioner BY ORDER OF THE COMMISSION BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 October 7, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. David W. Johnston Rt:CEIVED OCT u ~J 19~1 2-54/Q-12 MPI Endicott BP Exploration respectfully requests an exception to Endicott Pool Rule 3 as contained in Conservation Order 202 in order to drill and inject into Zone 3A of proposed well 2-54/Q-12 in the Endicott Pool. The distance between well 2-54/Q-12 and existing well 2-44/R-12 is 577 feet at the top of the Kekiktuk. Well 2-44/R-12 is in service as a water injector in Zone 3C/3B/3A, but will converted to a Zone 3C/3B injector after the completion of well 2-54/Q-12. As well 2-44/R-12 will be injecting into Zone 3C/3B and well 2-54/Q-12 will be injecting into Zone 3A, there will be no interference between the two wells. The distance between well 2-54/Q-12 and existing well 2-42/P-13 is 846 feet at the top of the Kekiktuk. Well 2-42/P-13 is in service as an oil producer in Zone 3C/3A, but will converted to a Zone 3C producer after the completion of well 2-54/Q-12. As well 2-54/Q-12 will be injecting into Zone 3A and well 2-42/P-13 will be producing from Zone 3C, there will be no interference between the two wells. Attached is a proposed drilling program for well 2-54/Q-12. The Application for Permit to Drill is enclosed. For our planning purposes, a response by October 11, 1991 would be appreciated. The scheduled spud date for this well is October 15, 1991. Thank you for your assistance in this matter.~ Bottom hole locations at top of Kekiktuk: 2-54/Q-12: 2-44/R-12: 2-42/P- 13 632' SNL, 1562' WEL, Sec 35, T12N, R16E 1073' SNL, 1934' WEL, Sec 35, T12N, R16E 389' SNL, 752' WEL, Sec 35, T12N, R16E Encl: Permit to Drill :~~.~You s very trul Paul Chan Drilling Engineer ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE Lz cnru' v thru 13] ' [10 $ 13] (4) Casg ~',~ /~-~-~/.. [14 thru 22] (5) BOPE ~'. ~/'~/./~-¢ -q / [23 thru 28] (6)Other (~fthr~/~/~J~/~/3 { ] (6) Addl ~.~.~..( )~_~,¢]! geology: engineering:: .. I)WJ~. MTM ~ LCS RPC i'>i"~. BEW ,/-"' RAJ) rev 03/29/91 jo/6.011 · e 3. 4. 5. 6. 7. 8. 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company Lease & Well ~'~(~ Y/Y~S NO Is permit fee attached ............................................... Is we.li..J to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage avaL-Table in this pool ............. Is well to be deviated & is wellbore Plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ........................... ". ....... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on e~,~r-& surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~l~mlJJllJ~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~_~sig ..... Does choke manifold comply w/API RP-53 (May 84) ......... ~ ............ Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. INITIAL GEd1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 1 ! R~RKS 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. 2-54/Q- 12 ENDICOTT AUG 02 199~ Run 1: 14 - June - 1996 CNIGR Cased Hole WESTERN ATLAS Logging Services 11394' 11942' Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BA.Y UNIT CASED HOLE WIRELINE LOGS #. WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB N-0MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT. FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2 - 54 / Q- 12 500292221800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 26-JUL-96 6602.02 D. BARBA B. CLUMP 36 12N 16E 2078 2328 55.10 54.10 16.20 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10925.0 47.00 7.000 12175.0 29.00 5.500 10661.0 17.00 4.500 11752.0 12.60 BASELINE DEPTH 11386.0 11387.0 11411.0 11424.5 11428.0 11437.0 11439.5 11445.5 11467.5 11479.5 11483.0 11487.0 11491.0 EQUIVALENT UNSHIFTED DEPTH PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GRCH 11390.5 11391.5 11418.0 11431.5 11436.0 11444.0 11448.0 11454.0 11475.0 11488.0 11490.5 11494.5 11498.5 LDT GR 2 1 18-NOV-94 ANADRILL 114~7.5 11502.5 11507.0 11518.5 11522.5 11531.5 11549.5 11561.5 11570.5 11573~5 11585.5 11589.0 11590.0 11591.0 11600.0 11603.0 11607.0 11608.0 11608.5 11609.0 11610.5 11611.5 11613.5 11624.0 11628.0 11629.5 11630.0 11636.0 11638.5 11639.5 11641.0 11651.0 11651.5 11652.5 11663.5 11664.0 11664.5 11665.5 11669.0 11669.5 11670.0 11671.0 11676.5 11682.0 11688.0 11693.0 11694.0 11694.5 11701.0 11730.5 11738.0 11748.5 11757.0 11763.0 11772.5 11790.5 11791.0 11792.5 11793.5 11806.0 11505.5 11510.0 11515.0 11527.0 11531.5 11540.0 11556.0 11568.0 11577.5 11580.0 11593.5 11597.0 11597.5 11598.5 11606.5 11609.5 11613.5 11614.0 11614.5 11615.5 11617.0 11617.5 11619.5 11632.0 11634.5 11637.5 11638.0 11643.0 11645.5 11646.0 11647.5 11658.5 11659.0 11659.5 11670.5 11671.5 11672.0 11672.5 11676.0 11677.0 11677.5 11678.0 11683.5 11690.0 11696.0 11701.0 11701.5 11702.0 11708.5 11738.5 11744.0 11754.0 11765.0 11769.5 11780.5 11795.0 11798.0 11799.5 11800.0 11814.0 11817.5. 11837.5 11864.0 11866.5 11877.0 11882.5 11888.5 11889.0 11890.0 11900.0 11901.0 11901.5 11902.0 REMARKS: 11824.0 11845.0 11873.0 11875.0 11883.0 11889.0 11895.0 11895.5 11896.0 11906.0 11906.5 11907.0 11907.5 CN/GR Cased Hole. TIED INTO CDR AT 11632', DATED 21 THRU 30-NOV-91. WELL SHUT-IN AT 0900, 14-JUN-96. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 11386.0 11400.0 BASELINE DEPTH 11386.0 11387.0 11411.0 11425.0 11427.5 11437.0 11439.5 11445.5 11467.5 11479.5 11483.0 11487.0 11491.0 11497.5 11502.5 11507.0 11518.5 11522.5 11531.5 11549.5 11561.5 11570.5 11573.5 11585.5 11589.0 11590.0 11591.0 11600.0 11603.0 11607.0 11608.0 11608.5 11609.0 11610.5 11611.5 11613.5 11624.0 11628.0 11631.5 STOP DEPTH 11928.0 11942.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH NPHI 11390.5 11391.5 11418.0 11430.0 11435.5 11444.0 11448.0 11454.0 11475.0 11488.0 11490.5 11494.5 11498.5 11505.5 11510.0 11515.0 11527.0 11531.5 11540.0 11556.0 11567.0 11577.5 11580.0 11593.5 11597.0 11597.5 11598.5 11606.5 11609.5 11613.5 11614.0 11614.5 11615.5 11617.0 11617.5 11619.5 11632.0 11634.5 11640.0 11636.0 11638.5 11639.5 11641.0 11651.0 11651.5 11652.5 11663.5 11664.0 11664.5 11665.5 11669.0 11669.5 11670.0 11671.0 11676.5 11682.0 11688.0 11693.0 11694.0 11694.5 11701.0 11730.5 11738.0 11748.5 11757.0 11763.0 11768.0 11776.5 11783.5 11789.5 11797.5 11806.0 11817.5 11837.5 11864.0 11866.5 11877.0 11882.5 11888.5 11889.0 11890.0 11900.0 11901.0 11901.5 11902.0 $ REMARKS: 11643.0 11645.5 11646.0 11647.5 11658.5 11659.0 11659.5 11670.5 11671.5 11672.0 11672.5 11676.0 11677.0 11677.5 11678.0 11683.5 11690.0 11696.0 11701.0 11701.5 11702.0 11708.5 11738.5 11744.0 11754.0 11763.5 11770.0 11776.5 11783.0 11791.5 11795.5 11804.0 11814.0 11824.0 11845.0 11873.0 11875.0 11883.0 11889.0 11895.0 11895.5 11896.0 11906.0 11906.5 11907.0 11907.5 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN / ? ?MATCH1B. OUT $ : BP EXPLORATION : 2 - 54 / Q- 12 : ENDICOTT : NORTH SLOPE (ALASKA) ,STAT, : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves-. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68' 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 4 42 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 11960.000000 Tape File End Depth = 11370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5906 datums Tape Subfile: 2 298 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: i START DEPTH 11386.0 11400.0 BASELINE DEPTH 11383.5 11388.5 11397.0 11401.5 11404.0 11413.0 11413.5 11422.0 11425.0 11427.5 11436.5 11439.0 11443.5 11445.5 11467.5 11471.5 11482.0 11486.5 11487.5 11491.0 11499.5 11507.5 11512.0 11515.0 11518.5 11519.0 11536.0 11540.0 11550.0 11552.5 11553.0 11561.5 11577.5 11580.5 11599.5 11600.0 11603.0 STOP DEPTH 11928.0 11942.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 11388.0 11392.5 11407.5 11418.5 11428.0 11430.5 11452.5 11471.0 11492.0 11513.5 11518.5 11526.0 11554.5 11565.5 11582.5 11605.0 11608.5 NPHI 11403.0 11409.0 11417.0 11428.5 11434.0 11442.0 11446.0 11450.5 11477.5 11488.0 11493.5 11497.5 11506.5 11522.0 11526.0 11543.0 11547.0 11554.5 11557.0 11564.5 11585.5 11604.5 11609.5 11617.5 11624.5 11628.0 11631.0 11631.5 11634.5 11640.5 11642.0 11649.0 11649.5 11655.5 11659.0 11660.5 11664.5 11667.5 11682.0 11684.5 11691.5 11694.5 11700.5 11701.0 11710.5 11713.5 11715.0 11717.5 11721.5 11726.0 11727.5 11730.5 11734.0 11738.0 11741.0 11743.5 11744.0 11747.5 11748.0 11751.0 11752.5 11754.5 11756.5 11757.0 11763.0 11765.0 11769.5 11772.0 11773.5 11776.5 11780.0 11783.5 11789.5 11791.5 11797.5 11800.5 11802.5 11806.0 11809.0 11817.5 11818.0 11821.5 11614.5 11623.0 11631.0 11633.5 11637.5 11645.5 11655.5 11661.0 11666.0 11673.0 11688.5 11698.0 11700.5 11707.0 11717.0 11729.5 11732.5 11738.0 11740.5 11743.0 11745.0 11748.5 11752.0 11755.5 11761.0 11763.5 11768.0 11770.0 11775.5 11778.5 11782.0 11785.5 11795.5 11802.5 11806.0 11809.0 11813.0 11815.0 11822.5 11827.0 11639.5 11642.5 11647.5 11656.5 11664.5 11670.5 11690.5 11707.0 11720.0 11722.5 11725.0 11732.0 11748.0 11752.5 11758.5 11762.5 11769.0 11771.5 11779.0 11790.0 11797.5 11812.0 11824.0 118427.5 · 11832.5 11833.5 11840.0 11844.5 11848.5 11852.0 11854.0 11854.5 11857.5 11863.5 11864.0 11866.5 11877.0 11879.0 11882.5 11891.0 11894.5 11901.5 11903.5 11905.5 11906.0 11911.0 11916.5 11918.5 11924.5 R.~D'~ARKS: 11833.0 11838.0 11839.5 11845.5 11851.0 11855.0 11859.0 11861.0 11862.0 11864.0 11870.5 11872.0 11873.5 11882.0 11883.5 11887.5 11895.5 11899.0 11899.0 11905.5 11907.5 11909.5 11910.5 11915.0 11920.5 11920.5 11923.0 11930.5 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ? ?MATCH2 B. OUT $ : BP EXPLORATION (ALASKA) : 2- 54 / Q- 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 i CPS 4 4 42 995 99 1 4 4 42 995 99 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPES 0) Total Data Records: 24 1006 BYTES * Tape File Start Depth = 11960.000000 Tape File End Depth = 11370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5906 datums Tape Subfile: 3 181 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: I START DEPTH 11386.0 11400.0 BASELINE DEPTH 11387.0 11392.0. 11396.5 11398.5 11401.5 11404.0 11417.0 11422.0 11424.5 11425.0 11427.5 11436.5 11444.0 11445.5 11451.0 11464.5 11467.5 11471.5 11472.5 11482.5 11484.0 11487.5 11491.0 11494.0 11497.5 11500.0 11502.5 11507.5 11511.5 11512.5 11515.0 11519.0 11522.5 11531.0 11536.0 11538.0 11540.0 STOP DEPTH 11928.0 11942.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH GRCH 11390.5 11396.0 1'1407.0 11409.5 11427.0 11430.0 11452.5 11469.0 11473.5 11479.0 11489.0 11497.0 11501.0 11504.0 11509.0 11514.5 11518.0 11521.5 11526.0 11530.0 11544.0 NPHI 11402.0 11404.0 11421.5 11428.0 11434.0 11441.0 11450.0 11456.0 11478.0 11489.0 11493.5 11497.0 11506.0 11520.0 11526.0 11536.0 11542.5 11547.0 11541 o 0 11550.0 11552.5 11555.0 11561°§ 11562 ° 0 11565 ° 0 11570 ° § 11574 o 0 11579.5 11580.5 11593.5 11600.0 11612.5 11618.0 11619.5 11628.0 11631.0 11634.5 11640.5 11642.5 11649.0 11649.5 11653.5 11662 · 0 11664.0 11667.5 11675.0 11682 · 0 11684.5 11688.0 11694 · 5 11700 · 5 11703.5 11710.0 11713.0 11713.5 11715.0 11721.0 11724.5 11727.5 11730.5 11738.0 11743 · 5 11745.0 11747 · 5 11750.0 11751.0 11763.0 11765.0 11769 · 5 11773.5 11776.5 11783 · 0 11783.5 11784 · 0 11787.0 11787 · 5 11788.5 11789.0 11547.0 11556.0 11566.5 11575.5 11585.0 11605.5 11618.0 11622.5 11633.5 11637.5 11647.0 11655.0 11658.5 11668.0 11672.5 11681.5 11688.5 11694.0 11700.5 11706.5 11715.0 11719.0 11728.5 11731.0 11737.0 11743.0 11748.0 11752.0 11755.5 11768.0 11770.5 11775.0 11782.5 11786.5 11787.0 11790.0 11791.0 11792.0 11792.5 11554.5 11559.0 11565.0 11569.0 11579.0 11585.5 11599.0 11624.0 11641.5 11647.0 11656.0 11670.0 11690.5 .11709.0 11719.5 11721.5 11732.0 11750.5 11754.5 11768.5 11771.0 11779.0 11782.0 11790.0 11797.5 11800.0 11806.0 11809.0 11813.0 11817.5 11821.5 11824.5 11831.5 11834.5 11837.5 11844.5 11852.0 11854.0 11863.5 11864.0 11866.5 11876.5 11882.5 11884.5 11887.0 11891.5 11894.0 11894.5 11903.5 11906.0 11910.5 11913.0 11916.5 11918.5 11919.0 11925.0 11930.0 11944.5 11945.5 11946.5 11947.0 11950.0 11950.5 $ REMARKS: 11803.0 11813.0 11815.0 11822.5 11827.0 11837.5 11843.5 11850.5 11858.5 11860.5 11870.5 11873.5 11880.0 11887.5 11889.5 11898 .5 11805.0 11817.0 11829.0 11840.0 11870.0 11907.5 11909.0 11914.5 11917.0 11920.0 11923.0 11892.5 11897.0 11899.5 11923.5 11929.0 11934.5 11947.5 11948.5 11949.0 11950.0 11953.0 11953.5 PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. / ??MATCH3A. OUT /??MATCH3B. OUT $ CN : BP EXPLORATION WN : 2- 54 / Q- 12 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME (ALASKA) Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GRCH 2418 68 i GAPI 2 NPHI 2418 68 i PU-S 3 FUCT 2418 68 I CPS 4 NUCT 2418 68 i CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 11960.000000 Tape File End Depth = 11370.000000 Tape File Level Spacing = 0,500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11812 datums Tape Subfile: 4 194 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBUTOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 11386.0 11400.0 BASELINE DEPTH 11387.0 11388.5 11390.5 11392.0 11397.0 11398.5 11401.5 11404.0 11413.0 11422.0 11424.5 11425.0 11427.5 11437.0 11439.0 11444.0 11445.5 11449.0 11451.0 11464.0 11464.5 11467.5 11471.5 11472.5 11482.5 11484.0 11487.5 11490.5 11491.0 11497.5 11499.5 11500.0 11502.5 11507.0 11511.5 11515.0 11518.5 STOP DEPTH 11928.0 11942.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH GRCH 11390.5 11391.5 11393.5 11396.0 11407.0 11409.5 11427.0 11430.0 11452.5 1~469.0 11473.5 11479.0 11497.0 11504.0 11506.0 11508.0 11513.0 11518.0 11521.5 NPHI 11403.0 11404.5 11408.0 11418.5 11428.5 11433.5 11442.0 11446.0 11450.5 11456.5 11458.0 11470.5 11477.5 11488.5 11492.5 11496.5 11506.0 11525.0 11519.0 ' 11522.5 11530.5 11536.0 11538.0 11540.0 11541.0 11547.5 11552.5 11561.5 11562.0 11570.5 11574.0 11577.0 11579.5 11580.5 11600.0 11612.5 11618.0 11619.0 11624.5 11628.0 11631.0 11631.5 11637.0 11640.5 11649.0 11649.5 11653.5 11659.0 11662.0 11664.5 11667.5 11675.0 11682.0 11688.0 11694.5 11700.5 11710.0 11713.0 11715.0 11716.5 11718.0 11721.0 11724.5 11727.0 11730.5 11738.0 11743.5 11747.5 11751.0 11752.5 11763.0 11765.0 11769.5 11773.5 11776.5 11784.0 11787.0 11526.0 11530.0 11544.0 11547.0 11555.0 11566.5 11575.5 11581.5 11585.0 11605.5 11618.0 11622.5 11631.0 11633.5 11637.5 11647.0 11654.5 11658.5 11668.0 11672.5 11681.5 11688.5 11694.0 11700.5 11706.5 11715.0 11719.0 11728.5 11731.0 11737.0 11743.0 11748.0 11752.0 11755.5 11768.0 11770.5 11775.0 11782.5 11786.5 11787.0 11790.0 11536.5 11543.0 11546.0 11552.0 11564.5 11579.0 11585.5 11604.0 11625.0 11637.0 11643.5 11656.0 11664.5 11670.0 11699.0 11718.5 11720.5 11723.0 11724.5 11731.5 11748.0 11752.0 11757.0 11768.0 11770.5 11778.0 11782.0 11790.0 11787.5' 11788.5 11789.0 11797.5 11799.5 11806.0 11809.0 11817.5 11821.5 11827.5 11831.5 11837.5 11839.5 11844.5 11852.0 11854.0 11857.5 11864.0 11866.5 11876.5 11879.0 11882.5 11884.5 11887.0 11891.0 11894.0 11894.5 11903.5 11905.5 11906.0 11911.0 11912.5 11913.5 11916.5 11918.5 11923.0 11930.0 $ REMARKS: 11791.0 11792.0 11792.5 11803.0 11805.0 11813.0 11815.0 11822.5 11827.0 11823.5 11832.5 11837.5 11843.5 11843.0 11850.5 11858.5 11860.5 11863.5 11870.0 11873.0 11880.0 11883.5 11887.5 11889.5 11891.5 11894.0 11894.5 11898.5 11898.5 11907.0 11909.5 11910.0 11914.5 11916.5 11918.0 11920.0 11922.5 11927.0 11935.0 PASS 4. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH4A.OUT /??MATCH4B.OUT BP EXPLORATION 2 - 54 / Q- 12 ENDICOTT NORTH SLOPE ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F (ALASKA) 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod I GRCH 2418 68 I GAP I 4 2 NPHI 2418 68 i PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 i CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 i 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 11960.000000 Tape File End Depth = 11370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11812 datums Tape Subfile: 5 192 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3, 4 1, 2, 3, 4 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 4 PASSES. $ : BP EXPLORATION (ALASKA) : 2 - 54 / Q- 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID:. F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 1 PU-S 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 11960.000000 Tape File End Depth = 11370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17718 datums Tape Subfile: 6 47 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11380.0 2418 11394.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11942.0 11956.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-JUN-96 FSYS REV. J001 VER. 1.1 1428 14-JUN-96 12137.0 11944.0 11394.0 11942.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8220XA 2418XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW' SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 54 / Q- 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 11959.000000 Tape File End Depth = 11375.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32846 datums Tape Subfile: 7 Minimum record length: Maximum record length: 160 records... 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11380.0 2418 11394.0 $ LOG HEADER DATA STOP DEPTH 11941.0 11955.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS . FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (.FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-JUN-96 FSYS REV. J001 VER. 1.1 1457 14-JUN-96 12137.0 11944.0 11394.0 11942.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8220XA 2418XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2- 54 / Q- 12 : ENDICOTT .· NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 11958.000000 Tape File End Depth = 11374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38752 datums Tape Subfile: $ Minimum record length: Maximum record length: 160 records... 62 bytes 1014 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11378.0 2418 11392.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11941.0 11955.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WET.r~EAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-JUN-96 FSYS REV. J001 VER. 1.1 1524 14-JUN-96 12137.0 11944.0 11394.0 11942.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8220XA 2418XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 54 / Q- 12 ·' ENDI CO'I~ : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 11958.000000 Tape File End Depth = 11374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53880 datums Tape SUbfile: 9 Minimum record length: Maximum record length'. 160 records... 62 bytes 1014 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11381.0 2418 11395.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11941.0 11955.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-JUN-96 FSYS REV. J001 VER. 1.1 1600 14-JUN-96 12137.0 11944.0 11394.0 11942.0 1500.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8220XA 2418XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELTNE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS) : 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 2 - 54 / Q- 12 : ENDICOTT : NORTH SLOPE ·° ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68' 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 42 995 99 1 4 42 890 01 1 4 42 334 31 1 4 42 334 30 1 4 42 150 01 1 4 42 636 99 1 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 84 Tape File Start Depth = 11958.000000 Tape File End Depth = 11374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59786 datums Tape S~bfile: 10 Minimum record length: Maximum record length: 160 records... 62 bytes 1014 bytes Tape Subfile 11 is type: LIS 96/ 7/24 01 **** REEL TRAILER **** 96/ 7/26 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 26 JLY 96 3:43p Elapsed execution time = 16.26 seconds. SYSTEM RETURN CODE = 0 JUL 2 6 '!99% 2-54/Q- 12 ENDICOTT WESTEI~N ATLAS Logging Services T~pe S~bfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 2 -54 / Q- 12 500292221800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 22-JUL-96 6602.02 D. BARBA B. CLUMP 36 12N 16E 2078 2328 55.10 54.10 16.20 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 7.000 12175.0 3RD STRING 5.500 10661.0 PRODUCTION STRING 4.500 11752.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE'FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: LDT GR 2 1 18-NOV-94 ANADRILL BASELINE DEPTH 11411.5 11412.0 11413.0 11420.5 11428.5 11437.0 11438.5 11444.5 11445.0 11450.5 11478.0 11478.5 11481.5 GRCH 11419.0 11419.5 11420.0 11427.5 11434.0 11442.5 11444.5 11450.5 11451.5 11457.0 11485.5 11486.0 11488.0 EQUIVALENT UNSHIFTED DEPTH 29.00 17.00 12.60 11483. 11486. 11486. 11487. 11512. 11517. 11520. 11523. 11533. 11561. 11562. 11572. 11583. 11584. 11585. 11592. 11605. 11612. 11627. 11629. 11637. 11637. 11638. 11639. 11650. 11651. 11655. 11662. 11663. 11664. 11665. 11666. 11666. 11667. 11668. 11668. 11669. 11669. 11670. 11677. 11678. 11679. 11687. 11692. 11693. 11699. 11700. 11708. 11718. 11727. 11762. 11774. 11786. 11786. 11788. 11789. 11791. 11793. 11866. 11871. 11489.5 11493.0 11493.5 11494.0 11518.5 11523.5 11526.5 11530.0 11540.5 11566.6 11568.0 11578.0 11590.0 11590.5 11591.0 11598.0 11610.5 11617.0 11634.5 11636.5 11643.0 11643.5 11644.0 11645.0 11656.5 11658.0 11661.5 11668.5 11669.5 11670.5 11671.0 11672.0 11673.0 11673.5 11674.0 11674.5 11675.5 11676.0 11676.5 11683.5 11684.0 11685.0 11694.0 11699.0 11699.5 11705.5 11706.5 11715.0 11725.0 11734.5 11769.5 11780.0 11792.0 11793.0 11794.5 11795.0 11797.5 11798.0 11873.5 11876.5 11882.5 11891.0 11900.0 11900.5 $ REMARKS: 11887.0 11895.5 11904.5 11905.0 PDK-100/GR. TIED INTO CDR AT 11632' DATED 21 THRU 30-NOV-91. LOGGING SUITE ORGANIZATION: 1) WELL SHUT-IN AT 0900 14-JUN-96 2) LOGGED 3 PASSES NO DIFFUSION CORRECTED SGMA CURVE WAS COMPUTED SINCE WELLBORE FLUIDS WERE NOT SPECIFIED IN ENOUGH DETAIL. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR THE THREE PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ? ?MATCH1A . OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11388.0 11924.0 11400.0 11936.0 BASELINE DEPTH SGMA 11399.0 11404.0 11406.5 11413.5 11411.5 11418.5 11412.5 11420.0 11413.0 11420.5 11428.0 11433.5 11431.0 11436.5 11432.0 11437.0 11436.0 11442.5 11445.0 11452.5 11470.0 11477.5 11480.5 11488.0 11481.5 11488.5 11483.5 11490.5 11486.0 11492.5 11512.5 11519.0 11516.0 11523.0 11525.5 11532.5 11526.0 11533.5 11529.0 11536.5 11542.0 11548.0 11544.0 11550.0 11545.5 11552.0 11547.0 11553.5 11548.0 11554.0 11548.5 11555.0 11549.0 11555.5 11550.0 11556.0 11562.0 11565.5 11564.5 11569.0 11571.0 11575.5 11571.5 11576.5 11572.0 11577.0 11572.5 11578.0 11574.0 11579.5 11576.5 11582.5 11578.5 11584.5 11582.5 11589.0 11586.5 11593.0 (MEASURED DEPTH) -- EQUIVALENT UNSHIFTED DEPTH ......... 11587.0 11589.0 11590.0 11592.0 11604.0 11608.5 11609.5 11618.0 11624.0 11628.5 11636.0 11637.0 11637.5 11640.0 11649.5 11651.0 11651.5 11653.0 11653.5 11662.5 11663.5 11665.0 11665.5 11671.0 11671.5 11673.5 11689.5 11690.0 11691.0 11694.5 11700.5 11707.0 11726.0 11734.5 11750.0 11757.0 11762.5 11770.0 11776.5 11781.0 11782.0 11786.0 11787.0 11788.5 11789.0 11789.5 11790.0 11791.0 11792.5 11793.5 11806.5 11808.0 11814.0 11815.0 11816.0 11816.5 11818.0 11819.0 11822.5 11823.0 11594.0 11596.0 11596.5 11598.5 11609.5 11614.0 11614.5 11623.0 11630.5 11633.5 11641.5 11642.5 11643.5 11646.0 11655.0 11656.5 11657.5 11659.0 11660.0 11669.0 11669.5 11671.0 11672.0 11677.5 11678.5 11680.5 11696.0 11696.5 11697.0 11700.5 11707.0 11713.0 11732.5 11741.0 11756.5 11764.5 11768.5 11776.0 11783.0 11787.5 11788.0 11792.0 11792.5 11793.0 11793.5 11795.5 11796.0 11796.5 11798.0 11798.5 11812.0 11813.5 11820.0 11821.0 11821.5 11822.5 11824.0 11824.5 11828.0 11828.5 11823.5 11828.5 11829.5 11863.0 11867.0 11882.0 11890.5 11893.5 11895.0 11896.0 11902.5 11903.0 $ REMARKS: 11829.0 11834.0 11834.5 11870.0 11874.0 11887.5 11896.0 11898.5 11900.0 11900.5 11907.0 11907.5 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : 2 - 54/Q - 12 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 2 BIF PDK 68 1 3 BKL· PDK 68 1 4 BKS PDK 68 1 5 CSLS PDK 68 1 6 LS PDK 68 1 7 MSD PDK 68 1 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 13 SGMB PDK 68 1 14 SS PDK 68 1 15 PHI PDK 68 1 GAPI CPS CPS CU CPS CU CU CU CPS PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 75 Tape File Start Depth = 11385.000000 Tape File End Depth = 11940.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17777 datums Tape Subfile: 2 374 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11388.0 11924.0 11400.0 11936.0 BASELINE DEPTH GRCH 11387.5 11394.0 - EQUIVALENT UNSHIFTED DEPTH SGMA (MEASURED DEPTH) 11398.5 11403.5 11411.0 11418.0 11417.5 11414.0 11420.5 11417.0 11422.5 11423.5 11423.0 11429.0 11423.5 11429.5 11433.5 11440.0 11434.5 11440.5 11443.5 11450.5 11451.5 11457.5 11461.0 11468.5 11467.5 11474.0 11472.0 11478.0 11472.5' 11479.0 11477.5 11483.5 11478.5 11485.0 11482.5 11488.5 11488.0 11495.0 11494.5 11489.0 11495.0 11491.5 11498.0 11496.0 11502.5 11500.5 11506.5 11501.0 11507.0 11501.5 11508.0 11503.0 11509.0 11507.5 11514.0 11508.5 11515.0 11509.5 11515.5 11510.5 11517.0 11511.5 11517.5 11517.5 11523.5 11518.0 11524.5 11521.0 11527.5 11521.5 11528.5 11524.5 11530.5 11525.0 11531.5 11531.0 11532.0 11532.5 11535.5 11545.5 11548.5 11553.5 11557.0 11561.5 11562.0 11567.0 11567.5 11568.5 11569.5 11570.0 11577.5 11582.5 11583.5 11587,5 11588.0 11589.5 11590.5 11593.0 11594.5 11595.0 11597.0 11599.5 11600.5 11603.5 11604.0 11605~5 11606.5 11607.5 11608.0 11609.5 11610.5 11613.0 11613.5 11623.5 11624.5 11625.0 11628.5 11632.5 11635.5 11637.5 11640.5 11641.5 11652.0 11652.5 11654.0 11654.5 11659.5 11660.0 11662.5 11663.5 11664.0 11664.5 11665.0 11666.0 11672.5 11537.5 11539.0 11539.5 11565.5 11572.0 11573.0 11574.0 11574.5 11575.5 11583.0 11588.5 11593.5 11594.5 11596.0 11596.5 11611.0 11615.0 11615.5 11618.0 11619.0 11629.0 11631.0 11641.5 11643.0 11659.5 11660.5 11668.5 11669.0 11669.5 11670.5 11671.0 11671.5 11542.5 11551.0 11553.5 11559.0 11562.0 11564.5 11589.5 11599.0 11601.0 11601.5 11603.0 11605.5 11606.0 11609.0 11610.0 11611.5 11612.0 11613.0 11614.0 11619.0 11631.0 11633.5 11637.0 11645.5 11646.0 11656.5 11657.5 11664.5 11665.5 11669.0 11670.0 11678.5 11673~ 11675. 11677. 11678. 11679. 11693. 11694. 11695. 11700. 11705. 11706. 11709. 11715. 11720~ 11721. 11722. 11722. 11723. 11724. 11726. 11732. 11732. 11739. 11747. 11750. 11757. 11758. 11765. 11768. 11770. 11770. 11771. 11772. 11773. 11774. 11774. 11775. 11775. 11781. 11782. 11785. 11786. 11787. 11790. 11791. 11793. 11794. 11795. 11796. 11797. 11797. 11798. 11799. 11800. 11806. 11808. 11814. 11817. 11833. 11833. 0 5 0 0 0 0 5 0 5 5 5 0 5 5 0 0 5. 5 5 5 0 5 5 5 0 0 0 0 5 0 5 5 0 0 0 5 0 5 5 5 5 0 0 0 0 5 0 0 0 0 5 5 5 5 5 5 5 5 0 5 11681.0 11683.5 11684.5 11685.0 11699.0 11699.5 11700.0 11706.5 11711.5 11712.0 11714.5 11726.5 11727.5 11729.0 11729.5 11738.0 11739.0 11754.0 11765.0 11775.5 11778.0 11779.5 11780.0 11781.0 11781.5 11782.0 11788.0 11788.5 11792.0 11792.5 11795.5 11796.0 11799.0 11804.0 11805.0 11820.0 I1838.5 11839.5 11679.5 11707.0 11722.0 11727.0 11729.5 11732.0 11745.0 11756.0 11764.0 11770.5 11776.0 11776.5 11777.0 11780.5 11781.5 11791.5 11792.5 11796.5 11797.0 11799.5 11800.5 11801.0 11802.0 11803.0 11804.0 11811.0 11813.0 11823.0 11834.0 11835.0 11837.5 11838.0 11845.0 11845.5 11847.5 11854.0 11866.5 11867.0 11871.0 11876.0 11876.5 11880.0 11882.5 11885.0 11893.5 11896.5 11897.0 11897.5 11901.0 11902.0 11903.0 11904.5 11909.0 11916.0 11927.0 11928.0 11928.5 $ REMARKS: 11840.0 11840.5 11843.0 11844.0 11851.0 11852.0 11860.5 11873.0 11876.5 11880.5 11884.0 11889.0 11898.0 11909.0 11913.0 11920.0 11853.0 11860.0 11873.0 11881.0 11887.5 11901.5 11902.0 11902.5 11906.0 11906.5 11907.5 11931.0 11932.0 11932.5 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68~ 1 CPS 15 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 75 966 BYTES * 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 60 Tape File Start Depth = 11385.000000 Tape File End Depth = 11940.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17777 datums Tape Subfile: 3 295 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 11388.0 11924.0 11400.0 11936.0 BASELINE DEPTH GRCH 11400.5 11411.5 11414.5 11415.0 11421.0 11417.0 11423.0 11417.5 11423.0 11418.0 11423.5 11421.0 11426.5 11423.5 11428.0 11425.5 11430.5 11426.5 11432.5 11427.5 11432.5 11428.0 11434.0 11428.5 11433.0 11429.0 11434.5 11432.0 11436.0 11434.0 11439.5 11435.0 11440.0 11435.5 11440.5 11436.0 11441.5 11441.5 11436.5 11442.0 11438.0 11444.0 11439.0 11445.0 11443.5 11450.5 11444.5 11451.5 11446.0 11452.0 11447.0 11454.0 11466.5 11473.0 11471.5 11477.5 11478.0 11476.5 11483.0 11478.5 11483.5 11482.5 11488.0 11484.0 11488.5 11486.5 11492.0 11487.0 11492.0 11488.5 11494.0 11489.5 11494.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH - SGMA 11405.5 11417.5 11420.5 11490.0 11490.5 11491.5 11510.5 11511.0 11511.5 11516.0 11519.0 11521.0 11521.5 11522.0 11522.5 11529.0 11529.5 11531.0 11532.5 11533.5 11536.0 11537.0 11543.5 11545.5 11548.5 11549.5 11551.0 11561.5 11562.0 11570.5 11571.5 11575.5 11580.5 11582.5 11584.0 11585.0 11585.5 11586.0 11589.0 11590.0 11598.0 11609.0 11610.0 11615.0 11616.0 11616.5 11619.0 11620.0 11620~5 11621.5 11624.5 11626.0 11626.5 11633.0 11637.0 11638.0 11639.0 11640.0 11641.5 11647.0 11651.5 11652.0 11658.0 11495.0 11496.0 11516.0 11525.0 11527.0 11527.5 11530.0 11537.0 11539.0 11540.0 11555.5 11565.5 11575.0 11575.5 11579.5 11588.0 11589.5 11590.0 11590.5 11591.5 11594.5 11595.0 11614.0 11614.5 11620.5 11621.5 11624.0 11624.5 11625.5 11631.0 11632.0 11642.5 11643.0 11656.5 11657.5 11496.5 11516.0 11517.0 11522.5 11527.0 11528.0 11535.5 11536.5 11543.0 11543.5 11550.0 11551.5 11554.5 11555.0 11563.5 11585.5 11589.0 11603.0 11620.5 11626.5 11630.0 11637.5 11643.5 11644.0 11645.5 11651.5 11662.5 11658.5 11662.0 11662.5 11663.0 11664.0 11674.0 11674.5 11709.5 11710.0 11711.0 11715.0 11716.0 11721.5 11722.5 11723.5 11724.0 11724.5 11727.5 11728.0 11730.0 11740.0 11741.0 11743.0 11747.5 11748.5 11749.0 11750.0 11750.5 11753.5 11761.0 11762.0 11762.5 11763.0 11763.5 11764.5 11770.5 11771.5 11772.5 11774.0 11775.0 11777.5 11778.0 11781.0 11782.0 11787.5 11788.5 11789.5 11790.5 11793.5 11794.5 11795.5 11796.5 11798.0 11799.0 11805.5 11808.0 11813.0 11817.5 11818.0 11818.5 11668.5 11669.0 11714.5 11727.5 11728.5 11729.0 11730.0 11733.5 11734.5 11746.5 11747.0 11753.5 11755.5 11760.0 11767.0 11768.0 11768.5 11769.5 11778.0 11778.5 11780.0 11780.5 11786.5 11787.0 11792.5 11793.0 11802.5 11803.0 11809.5 11817.5 11823.0 11663.5 11667.0 11668.0 11679.5 11680.5 11716.0 11716.5 11720.5 11721.0 11729.5 11736.0 11749.0 11754.0 11755.5 11756.5 11769.5 11770.0 11776.0 11776.5 11782.5 11783.5 11795.0 11795.5 11798.5 11799.0 11800.0 11800.5 11811.5 11822.0 11822.5 11823.5 11819 0 11828.0 11832.5 11833.0' 11838.5 11842.0 11844.5 11847.5 11849.5.' 11850.5 11853.5 11854.5 11863.0 11863.5 11867.0 11871.5 11876.0 11876.5 11879.5 11882.5 11883.5 11894.0 11901.0 11902.0 11902.5 11903.5 11905.0 11909.5 11910.0 11910.5 11911.0 11912.5 11914.5 11915.5 $ REMARKS: 11824.0 11833.0 11837.5 11838.5 11843.0 11847.5 11850.5 11852.0 11856.5 11857.5 11859.0 11860.0 11868.5 11869.5 11872.0 11876.0 11880.0 11881.0 11883.0 11887.0 11887.0 11898.0 11905.5 11906.0 11906.0 11906.5 11907.0 11909.0 11913.0 11913.0 11913.5 11914.0 11916.0 11918.5 11919.0 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ??MATCH3A. OUT / ? ?MATCH3 B. OUT $ : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA * 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 Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 PHI PDK 68 1 PU-S 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 * DATA RECORD (TYPE~ 0) 966 BYTES * 60 Total Data Records: 75 Tape File Start Depth = 11385.000000 Tape File End Depth = 11940.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35554 datums Tape Subfile: 4 300 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 5 is type:' LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PDK GRCH $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units 1 GRCH PNAV 68 1 GAPI 2 BKL PNAV 68 1 CPS 3 BKS PNAV 68 1 CPS 4 BIF PNAV 68 1 5 CSLS PNAV 68 1 CU 6 LS PNAV 68 1 CPS 7 MSD PNAV 68 1 CU 8 RATO PNAV 68 1 9 RBOR PNAV 68 1 10 RICS PNAV 68 1 11 RIN PNAV 68 1 12 SGMA PNAV 68 1 CU 13 SGMB PNAV 68 1 CU 14 SS PNAV 68 1 CPS 15 PHI PNAV 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 4 4 53 995 99 1 60 * DATA RECORD (TYPE# 0) Total Data Records: 75 966 BYTES * Tape File Start Depth = 11385.000000 Tape File End Depth = 11940.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35554 datums Tape Subfile: 5 97 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11378.5 PDK 11390.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11940.0 11952.0 14-JUN-96 FSYS REV. J001 VER. 1.1 1024 14-JUN-96 12137.0 11944.0 11398.0 11936.0 1200.0 YES TOOL NUMBER 3913NA 2725XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -700 FAR COUNT RATE HIGH SCALE (CPS): 4300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS. 1. $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool code Samples Units 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1~ CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 MON PDK 68 1 CPS 13 MSD PDK 68 1 CU 14 RATO PDK 68 1 15 RBOR PDK 68 1 16 RICS PDK 68 1 17 RIN PDK 68 1 18 SGMA PDK 68 1 CU ~9 SGMB PDK 68 1 CU 20 SPD PDK 68 1 F/MN 21 SS PDK 68 1 CPS 22 TEN PDK 68 1 LB 23 PHI PDK 68. 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 310 01 1 4 4 51 995 99 1 4 4 51 391 51 1 4 4 51 390 51 1 4 4 51 150 01 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 01 1 4 4 51 995 02 1 4 4 51 391 99 1 4 4 51 391 99 1 4 4 51 430 01 1 4 4 51 995 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 400 01 1 4 4 51 995 99 1 4 4 51 636 99 1 4 4 ~51 390 99 1 4 4 51 635 99 1 4 4 51 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 229 966 BYTES * 92 Tape File Start Depth = 11380.000000 Tape File End Depth = 11950.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 90299 datums Tape Subfile: 6 304 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11381.0 11940.0 PDK 11393.0 11952.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP'TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS~ FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL .RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-JUN-96 FSYS REV. J001 VER. 1.1 1059 14-JUN-96 12137.0 11944.0 11398.0 11936.0 1200.0 YES TOOL NUMBER 3913NA 2725XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0,0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -700 FAR COUNT RATE HIGH SCALE (CPS) : 4300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): REMARKS: PASS 2, $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA 0,0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK' 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MON PDK 68 1 CPS 4 13 MSD PDK 68 1 CU 4 14 RATO PDK 68 1 4 15 RBOR PDK 68 1 4 16 RICS PDK 68 1 4 17 RIN PDK 68 1 4 18 SGMA PDK 68 1 CU 4 19 SGMB PDK 68 1 CU 4 20 SPD PDK 68 1 F/MN 4 21 SS PDK 68 1 CPS 4 22 TEN PDK 68 1 LB 4 23 PHI PDK 68 1 PU-S. 4 4 51 310 01 1 4 51 995 99 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 391 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 1 1 1 1 4 51 636 99 4 51 390 99 4 51 635 99 4 51 995 99 92 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 229 Tape File start Depth = 11380.000000 Tape File End Depth =. 11950.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 90299 datums Tape Subfile: 7 304 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START .DEPTH GR 11380.0 PDK 11392.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL. (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR,TOOL CODE TOOL TYPE SWIV SWIVEL SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11940.0 11952.0 14-JUN-96 FSYS REV. J001 VER. 1.1 1135 14-JUN-96 12137.0 11944.0 11398.0 11936.0 1200.0 YES TOOL NUMBER 3913NA 2725XA 0.000 12175.0 0.0 PRODUCED WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : -700 FAR COUNT RATE HIGH SCALE (CPS): 4300 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION : 2 - 54/Q - 12 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL' PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MON PDK 68 1 CPS 4 13 MSD PDK 68 1 CU 4 14 RATO PDK 68 1 4 15 RBOR PDK 68 1 4 16 RICS PDK- 68 1 4 17 RIN PDK 68 1 4 18 SGMA PDK 68 1 CU 4 19 SGMB PDK 68 1 CU 4 20 SPD PDK 68 1 F/MN 4 21 SS PDK 68 1 CPS 4 22 TEN PDK 68 1 LB 4 23 PHI PDK 68 1 PU-S 4 4 51 310 01 1 4 51 995 99 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 391 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 636 99 1 4 51 390 99 1 4 51 635 99 1 4 51 995 99 1 92 * DATA RECORD (TYPE~ 0) 966 BYTES * Total Data Records: 229 Tape File Start Depth = 11380.000000 Tape File End Depth = 11950.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 145044 datums Tape Subfile: 8 304 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 9 is type: LIS 96/ 7/22 01 **** REEL TRAILER **** 96/ 7/22 01 .' Tape Subfile: 9 Minimum record'length: Maximum record length: 2 records... 132 bytes 132 bytes End of' execution: Mon 22 JLY 96 10:48a Elapsed execution time = 24.88 seconds. SYSTEM RETURN CODE = 0 isl_sunmmary:8367.sum created Wed May 11 17:02:01 1994 by CLEANUP Vl. 0 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 11 MAY 94 ISL Input File Name - 8367 ISL BP Exploration 2-54/Q-12 MPI ENDICOTT 11-30-91 SCHLUMBERGER CDR/CDN /LDT/GR CORRECTED VERSION IN CASING RECEIVED AUG 0 4 1994 Alaska Oil ,& ,Gas ,,Coils. ,Commission Anch,o, rage File 1 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 12175.5 - 10829.0 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 File 1 - Log Header Information % LOG HEADER LISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54/Q-12 MPI Field: ENDICOTT : NORTH SLOPE Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: RKB Drilling Measured From: Date: 92/ 1/17 Run No: Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 12175.0 12167.0 12164.0 10500.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 Longitude: 0.0 0.0 0.00 0.0 Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: LIGNOSULFONATE 9.70 39.00 9.50 4.80 / 1.790 1.430 0.000 11: 00 12-2 0.0 at 72.000 at 72.000 at 72.000 E.GOEBEL, J. SALARIO + .... ISL ISL .... + Remarks: - LOG HEADERLISTING Page 2 -+ Other Services:- Equipment Numbers :- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat DEPT 1 1 ROS2 1 1 RHOB 1 1 DRHO 1 1 PEF 1 1 DCAL 1 1 DPHI 1 1 DPOR 1 1 TNPH 1 1 HEF1 1 1 HEF2 1 1 HEF3 1 1 HEF4 1 1 HEN1 1 1 HEN2 1 1 HEN3 1 1 HEN4 1 1 ATR 1 1 PSR 1 1 ROPE 1 1 GR 1 1 InUnit OutUnit Start 01 ALLO FT FT 12175. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ALLO -999. LWD 01 ALLO IN IN -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO CPS CPS 8. LWD 01 ALLO CPS CPS 7. LWD 01 ALLO CPS CPS 7. LWD 01 ALLO CPS CPS 8. LWD 01ALLO CPS CPS 302. LWD 01 ALLO CPS CPS 312. LWD 01 ALLO CPS CPS 311. LWD 01 ALLO CPS CPS 302. LWD 01 ALLO OHMM OHMM -999. LWD 01 ALLO OHMM OHMM -999. LWD 01 ALLO F/HR F/HR 105. LWD 01 ALLO GAPI GAPI -999. 50O 250 25O 25O 25O 25O 250 250 250 630 560 860 700 O00 000 000 000 250 250 036 250 Stop 10829.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 File 1 - Conm~_nts Listing >> >> >> >> >> >> >> SCHLUMBERGER WELL SERVICES BP EXPLORATION 2-54/Q-12 MPI ENDICOTT NORTH SLOPE ALASKA 50-029-22218 2078' SNL & 2328' WEL SECTION: 35 TOWNSHIP: 12N RANGE: 16E PERMANENT DATUM: MSL ELEVATION: 0 LOG MEASURED FROM RKB 56 ABOVE PERMANENT DATUM ELEVATIONS KB: 56 DF: 56 GL: 14.5 ********************************** LWD PASSES DATE LOGGED: NOV 21-30, 1991 RUN NUMBER: ONE TD DRILLER: 12175 TD LOGGER: BIT SIZE : 8 1/2" TYPE FLUID IN HOLE: LSND DENSITY: 9.7 VISCOSITY: 14 PH: 9 FLUID LOSS: 5.2 MUD RESISTIVITY: 1.79 @ 72 FILTRATE RESISTIVITY: 1.43 MAXIMUM TEMP RECORDED: 185 LOGGING DISTRICT: PRUDHOE BAY LOGGING ENGINEER: PERRY TOOL NUMBERS: RGS603 NDS055 FIELD REMARKS: BIT RUN ONE: WASHDOWN PASS 10925 TO 11216 DRILLING PASS 11216 TO 11384 FT BIT TO GR = 37 FT, BIT TO RES = 27 FT, BIT TO DENS 91 FT, BIT TO NEUT = 98 FT. BIT RUN TWO: WASHDOWN PASS 11300 TO 11695 DRILLING PASS 11695 TO 12175 FT MAD PASS 11300 TO 12175 FT BIT TO GR = 38 FT, BIT OT RES = 28 FT, BIT TO DENS 93 FT, BIT TO NEUT -- 99 FT. GR, PSR, TNPH, RHOB, PEF SAMPLING RATE = 20 DENSITY MATRIX = 2.65 GM/CC FLUID DENSITY = 1.0 GM/CC >> COMPANY NAME: WELL: FIELD: BOROUGH: STATE: API NUMBER: LOCAT I ON: ENVIRONMENTAL CORRECTIONS FOR TOOL SIZE, HOLE SIZE, MUD WEIGHT. COMPUTING CENTER REMARKS: THE FIELD BLUELINE CDR CURVE LA~..T,~,,D RPS IS SAME AS PSR ON THIS TAPE. RAD IS SAME AS ATR ON THIS TAPE. NO DIELECTRIC RESISTIVITY DATA (DER) ~ PROCESSED BY FIELD. MAD PASS DATA (WASHDOWN/REPEAT) CAN BE FOUND IN FILE EDIT.002 OPEN HOLE WIRELINE PASS DATA CAN BE FOUND IN FILE EDIT.003 CASED HOLE WIRELINE GAMMA RAY CAN BE FOUND IN FILE EDIT.004 THE RATE OF PENETRATION CURVE (ROPE.LWD) OVER THE INTERVAL FROM 11695' TO 11660' IS INCONSISTENT FROM THE CDN FIELD LOG TO THE CDR FIELD LOG. THE ROPE OVER THAT SECTION OF THE CDN BLUELIN SHOULD BE CONSIDERED ERRONEOUS AND WILL NOT MATCH THE ROPE.LWD ON THIS LIBRARY TAPE. * FILE - EDIT.001 * BP EXPLORATION * ENDICOTT * 2-54/Q-12 MPI * 50-029-22218 >> , , >> , MAIN PASS LWD LOG DATA THE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FROM 'RHOB MAX' DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME RGS NDS .LWD LOGGING WHILE DRILLING RESISTIVITY/GR 10926' TO 1214 .LWD LOGGING WHILE DRILLING NEUTRON/DENSITY 11233' TO 1208 File 2 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 2 LIS File Nbr - 002 Start - Stop Depth : 12178.0 - 11197.5 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Conm~nts - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 File 2 - Log Header Information LOG HEADERLISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54/Q-12 MPI Field: ENDICOTT : NORTH SLOPE Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: RKB Drilling Measured From: Date: 92/ 1/17 Run No: Depth - Driller: 12175.0 Depth - Logger: 12167.0 Bottom Log Interval: 12164.0 Top Log Interval: 10500.0 Longitude: Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 Casing - Driller: 0.0 0.0 0.0 Casing - Logger: 0.0 0.0 0.0 Casing: Weight: 0.00 0.00 0.00 Bit Size: Depth: 0.0 0.0 0.0 Drilling Fluid Type: LIGNOSULFONATE Density: 9.70 Viscosity: 39.00 Ph: 9.50 Fluid Loss: 4.80 Source of Sample: Source Rmf/Rms: / Rm: 1.790 Rmf: 1.430 Rmc: 0.000 Time Circ. Stopped: 11:00 12-2 Time Logger on Bott.: Max. Recorded Temp.: 0.0 Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: E.GOEBEL, J.SALARIO at 72.000 at 72.000 at 72.000 + .... ISL ISL .... + Remarks:- LOG HEADER LISTING Page 2 -+ Other Services: - Equipment Numbers :- + .... ISL ISL .... + File 2 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 ROS2 1 1 RHOB 1 1 DRHO 1 1 PEF 1 1 DCAL 1 1 DPHI 1 1 DPOR 1 1 TNPH 1 1 HEF1 1 1 HEF2 1 1 HEF3 1 1 HEF4 1 1 HEN1 1 1 HEN2 1 1 HEN3 1 1 HEN4 1 1 ATR 1 1 PSR 1 1 ROPE 1 1 GR 1 1 ServID Stat InUnit OutUnit Start 01 ALLO FT FT 12178. MAD 01 ALLO G/C3 G/C3 -999. MAD 01 ALLO G/C3 G/C3 -999. MAD 01 ALLO G/C3 G/C3 -999. MAD 01 ALLO -999. MAD 01 ALLO IN IN -999. MAD 01 ALLO PU PU -999. MAD 01 ALLO PU PU -999. MAD 01 ALLO PU PU -999. MAD 01 ALLO CPS CPS 8. MAD 01 ALLO CPS CPS 9. MAD 01 ALLO CPS CPS 9. MAD 01 ALLO CPS CPS 7. MAD 01 ALLO CPS CPS 299. MAD 01 ALLO CPS CPS 306. MAD 01 ALLO CPS CPS 309. MAD 01 ALLO CPS CPS 306. MAD 01 ALLO OHMM OHMM -999. MAD 01 ALLO OHMM OHMM -999. MAD 01 ALLO F/HR F/HR -999. MAD 01 ALLO GAPI GAPI -999. 000 25O 250 25O 25O 250 25O 25O 250 530 O3O 100 730 000 000 000 000 250 250 250 250 Stop 11197.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 File 2 - Conm~_nts Listing ************************** * FILE - EDIT.002 * BP EXPLORATION * ENDICOTT * 2-54/Q-12 MPI * 50-029-22218 REPEAT/WASHDOWNPASS LWD LOG DATA NO DIELECTRIC RESISTIVITY DATA (DER) WAS PROCESSED BY FIELD. MAIN PASS LWD DATA CAN BE FOUND IN FILE EDIT.001 OPEN HOLE WIRELINE PASS DATA CAN BE FOUND IN FILE EDIT.003 CASED HOLE WIRELINE GAMMA RAY CAN BE FOUND IN FILE EDIT.004 THE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FROM 'RHOB MAX' * DATA SAMPLED EVERY -.5000 FEET * DATA INCLUDED - * TOOL EXTENSION TOOL * TYPE USED NAME * RGS .MAD LOGGING WHILE DRILLING RESISTIVITY/GR 10926' TO 1214 >> , * NDS .MAD LOGGING WHILE DRILLING NEUTRON/DENSITY 11197' TO 1208 >> , , ****************************************************************************** File 3 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 3 LIS File Nbr - 003 Start - Stop Depth : 12180.5 - 11283.5 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 File 3 - Log Header Information LOG HEADER LISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54/Q-12 MPI Field: ENDICOTT : NORTH SLOPE : ALASKA Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: RKB Drilling Measured From: Date: 92/ 1/17 Run No: Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 12175.0 12167.0 12164.0 10500.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 Longitude: 0.0 0.0 0.00 0.0 Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: LIGNOSULFONATE 9.70 39.00 9.50 4.80 / 1.790 1.430 0.000 11:00 12-2 0.0 at 72. 000 at 72. 000 at 72. 000 E. GOEBEL, J. SALARIO + .... ISL ISL .... + Remarks: - LOG HEADER LISTING Page 2 -+ Other Services:- Equipment Numbers:- + .... ISL ISL .... + File 3 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 DPHI 1 1 RHOB 1 1 DRHO 1 1 PEF 1 1 QLS 1 1 QSS 1 1 LS 1 1 LU 1 1 LL 1 1 LITH 1 1 SS1 1 1 SS2 1 1 LSHV 1 1 SSHV 1 1 S1RH 1 1 LSRH 1 1 LURH 1 1 CALI 1 1 GR 1 1 TENS 1 1 MTEM 1 1 MRES 1 1 HTEN 1 1 ServID Stat InUnit OutUnit 01 ALLO FT FT LDT 01 ALLO PU PU LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO LDT 01ALLO LDT 01ALLO LDT 01ALLO CPS CPS LDT 01ALLO CPS CPS LDT 01ALLO CPS CPS LDT 01ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO V V LDT 01 ALLO V V LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO IN IN LDT 01 ALLO GAPI GAPI LDT 01 ALLO LB LB LDT 01 ALLO DEGF DEGF LDT 01 ALLO OHMM OHMM LDT 01 ALLO LB LB Start 12180.500 32. 355 2.116 0.164 1.978 -0.043 0.066 632.000 587.000 338.500 195. 750 288.000 407.250 1729.000 1393.000 1.637 1. 952 1.958 2.770 15.664 2745.000 180.388 0.393 -47.875 Stop 11283.500 -3.183 2.703 -0.008 3.381 -0.049 -0.008 177.125 182.125 86.000 41.063 184.375 253. 875 1733.000 1394.000 2.738 2.709 2.697 9.609 68,500 5245. 000 167.900 0.466 696.500 File 3 - Comments Listing ********************************** WIRELINE PASS DATE LOGGED: 02-DEC-91 RUN NUMBER: TWO TD DRILLER: 12175 TD LOGGER: 12167 BIT SIZE : 8 1/2" TYPE FLUID IN HOLE: LIGNOSULFONATE DENSITY: 9.7 VISCOSITY: 39 PH: 9.5 FLUID LOSS: 4.8 MUD RESISTIVITY: 1.79 @ 72 FILTRATE RESISTIVITY: 1.43 TIME CIRCULATION ENDED: 11:00 12-2 MAXIMUM TEMP RECORDED: 178 LOGGING DISTRICT: PRUDHOE BAY LOGGING ENGINEER: CHENEVEY WITNESS: E.GOEBEL, J.SALARIO TOOL NUMBERS: DRS 4969 NSC 793 PDH 881 PGD 868 GSR 7075 SGC SA 404 TCCA 079 AMMAA 950 FIELD REMARKS: TOOL STRING: LDT-GR-TCC-AMS MDEN = 2.65, FLUID DENS = 1.0 SINGLE SHOT DATA FOR TVD SUPPLIED BY CLIENT SINGLE SHOT DATA REFERENCED TO SUBSEA. LDT-GR USED FOR MAIN DEPTH REFERENCE. HIGH RES(1.2") DATA PUT TO TAPE ON REPEAT. CHGR RUN FROM 10990-10500'. DATE JOB STARTED: 10-DEC-9 JOB REFERENCE NO: 75287 LDP/ANA: KOHRING COMPUTING CENTER REMARKS: LWD DATA (DRILLING/MAIN) CAN BE FOUND IN FILE EDIT.001 MAD PASS DATA (WASHDOWN/REPEAT) CAN BE FOUND IN FILE EDIT.002 CASED HOLE WIRELINE GAMMA RAY CAN BE FOUND IN FILE EDIT.004 ************************************************************************** * FILE - EDIT.003 * BP EXPLORATION * ENDICOTT * 2-54 / Q-12 MPI * 50-029-22218 MAIN PASS WIRELINE LOG DATA IS FROM FIELD FILE .011 DATA SAMPLED EVERY -.5000 FEET * DATA INCLUDED - * TOOL EXTENSION * TYPE USED * LDT .LDT TOOL LITHO DENSITY File 4 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 4 LIS File Nbr - 004 Start - Stop Depth : 11000.0 - 10460.0 (FT) Service Name - EDIT Service Sub Nam~ - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54/Q-12 MPI, 50-029-22218 File 4 - Log Header Information LOG HEADER LISTING Log Heading: Company: BP EXPLORATION Well: 2-54/Q-12 MPI Field: ENDICOTT : NORTH SLOPE : ALASKA Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: RKB Drilling Measured From: Date: 92/ 1/17 Run No: Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 12175.0 12167.0 12164.0 10500.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 Longitude: 0.0 0.0 0.00 0.0 Pge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 Page 1 -+ 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: LIGNOSULFONATE 9.70 39.00 9.50 4.80 / 1.790 1.430 0.000 11:00 12-2 0.0 at 72.000 at 72.000 at 72.000 E.GOEBEL, J.SALARIO + .... ISL ISL .... + Remarks: - LOG HEADER LISTING Page 2 -+ Other Services: - Equipment Numbers :- + .... ISL ISL .... + File 4 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 GR 1 1 TENS 1 1 MRES 1 1 MTEM 1 1 HTEN 1 1 CALI 1 1 ServID Stat InUnit OutUnit 01 ALLO FT FT CSG 01 ALLO GAPI GAPI CSG 01 ALLO LB LB CSG 01 ALLO OHMM OHMM CSG 01 ALLO DEGF DEGF CSG 01 ~ LB LB CSG 01 ALLO IN IN Start 11000.000 63.875 4785.000 0.501 163.175 593.000 2.270 Stop 10460.000 69.000 4570.000 0.528 156.087 620.000 8.477 File 4 - Comments Listing ************************** * FILE - EDIT.004 * BP EXPLORATION * ENDICOTT * 2-54/Q-12 MPI * 50-029-22218 MAIN PASS CASING DATA IS FROM FIELD FILE .012 DATA SAMPLED EVERY -.5000 FEET * DATA INCLUDED - * TOOL EXTENSION * TYPE USED * GR .CSG TOOL GAMMA RAY isl_summary: 8130. sum created Wed May 11 13:38:43 1994 by C~ Vl. 0 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 11 MAY 94 ISL Input File Name - 8130 ISL BP Exploration 2-54/Q-12 MPI ENDICOTT 11-30-91 SCHLUMBERGER CDR/CDN /LDT/GR IN RE¢'EIVED AUG 0 4 1994 Alasi{a Oil & Gas Cons. Commission Anchorage File 1 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 12175.5 - 10829.0 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 File 1 - Log Header Information ~ LOG HEADER LISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54 / Q-12 MPI Field: ENDICOTT : NORTH SLOPE : ALASKA Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: DF Drilling Measured From: Date: 91/12/12 Run No: Depth - Driller: 12175.0 Depth - Logger: 12175.0 Bottom Log Interval: 12175.0 Top Log Interval: 10926.0 Longitude: Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 Casing - Driller: 0.0 0.0 0.0 Casing - Logger: 0.0 0.0 0.0 Casing: Weight: 0.00 0.00 0.00 Bit Size: Depth: 0.0 0.0 0.0 Drilling FlUid Type: LSND Density: 9.70 Viscosity: 14.00 Ph: 9.00 Fluid Loss: 5.20 Source of Sample: Source Rmf/Rms: Rm: 1.790 Rmf: 1.430 Rmc: 0.000 Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: 0.0 Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: / at at at 72.000 72.000 0.000 + .... ISL ISL .... + Remarks: - LOG HEADER LISTING Page 2 -+ Other Services:- Equipment Numbers:- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 ROS2 1 1 RHOB 1 1 DRHO 1 1 PEF 1 1 DCAL 1 1 DPHI 1 1 DPOR 1 1 TNPH 1 1 HEF1 1 1 HEF2 1 1 HEF3 1 1 HEF4 1 1 HEN1 1 1 HEN2 1 1 HEN3 1 1 HEN4 1 1 ATR 1 1 PSR 1 1 ROPE 1 1 GR 1 1 ServID Stat InUnit OutUnit Start 01 ALLO FT FT 12175. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ALLO G/C3 G/C3 -999. LWD 01 ~ -999. LWD 01 ALLO IN IN -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO PU PU -999. LWD 01 ALLO CPS CPS 8. LWD 01 ALLO CPS CPS 7. LWD 01 ALLO CPS CPS 7. LWD 01 ALLO CPS CPS 8. LWD 01 ALLO CPS CPS 302. LWD 01 ALLO CPS CPS 312. LWD 01 ALLO CPS CPS 311. LWD 01 ALLO CPS CPS 302. LWD 01 ALLO OHMM OHMM -999. LWD 01 ALLO OHMM OHMM -999. LWD 01 ALLO F/HR F/HR 105. LWD 01 ALLO GAPI GAPI -999. 5O0 250 250 250 25O 250 250 25O 250 63O 560 86O 700 000 000 000 000 250 250 036 250 Stop 10829. 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 File 1 - Comments Listing * FILE - EDIT.001 * BP EXPLORATION * ENDICOTT * 2-54/Q-12 MPI * 50-029-22218 >> , , >> , MAIN PASS LWD LOG DATA THE DENSITY DATA PRESENTED ON THIS LIBRARY TAPE IS FROM 'RMOB MAX' DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME RGS NDS .LWD LOGGING WHILE DRILLING RESISTIVITY/GR 10926' TO 1214 .LWD LOGGING WHILE DRILLING NEUTRON/DENSITY 11233' TO 1208 File 2 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 2 LIS File Nbr - 002 Start - Stop Depth : 12180.5 - 11283.5 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 Tape Con~nents - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 File 2 - Log Header Information ~ LOG HEADER LISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54 / Q-12 MPI Field: ENDICOTT : NORTH SLOPE : ALASKA Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: DF Drilling Measured From: Date: 91/12/12 Run No: Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 12175.0 12175.0 12175.0 10926.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 Longitude: 0.0 0.0 0.00 0.0 Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: LSND 9.70 14.00 9.00 5.20 1.790 1.430 0.000 0.0 / at at at 72.000 72.000 0.000 + .... ISL ISL .... + Remarks: - LOG HEADERLISTING Page 2 -+ Other Services:- Equipment Numbers :- + .... ISL ISL .... + File 2 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat DEPT 1 1 DPHI 1 1 RHOB 1 1 DRHO 1 1 PEF 1 1 QLS 1 1 QSS 1 1 LS 1 1 LU 1 1 LL 1 1 LITH 1 1 SS1 1 1 SS2 1 1 LSHV 1 1 SSHV 1 1 S1RH 1 1 LSRH 1 1 LURH 1 1 CALI 1 1 GR 1 1 TENS 1 1 MTEM 1 1 MRES 1 1 HTEN 1 1 InUnit OutUnit 01 ALLO FT FT LDT 01 ALLO PU PU LDT 01 AIJ/) G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO LDT 01 ALLO LDT 01 ALLO LDT 01 ~ CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO CPS CPS LDT 01 ALLO V V LDT 01 ALLO V V LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO G/C3 G/C3 LDT 01 ALLO IN IN LDT 01 ALLO GAPI GAPI LDT 01 ALLO LB LB LDT 01 ALLO DEGF DEGF LDT 01 ALLO OHMM OHMM LDT 01 ALLO LB LB Start 12180.500 32. 355 2.116 0.164 1.978 -0.043 0.066 632. 000 587.000 338.500 195. 750 288.000 407.250 1729.000 1393.000 1.637 1.952 1. 958 2.770 15.664 2745.000 180.388 0.393 -47.875 Stop 11283.500 -3.183 2.703 -0.008 3.381 -0.049 -0.008 177.125 182.125 86.000 41.063 184.375 253.875 1733.000 1394.000 2.738 2.709 2.697 9.609 68.500 5245.000 167.900 0.466 696.500 File 2 - Comments Listing ************************** * FILE - EDIT.002 * BP EXPLORATION * ENDICOTT * 2-54 / Q-12 MPI * 50-029-22218 MAIN PASS LOG DATA IS FROM FIELD FILE .011 DATA SAMPLED EVERY -.5000 FEET * DATA INCLUDED - * TOOL EXTENSION * TYPE USED * LDT .LDT TOOL LITHO DENSITY File 3 - File Header Information Reel Nbr - 0 Tape Nbr - 1 File Nbr - 3 LIS File Nbr - 003 Start - Stop Depth : 11000.0 - 10460.0 (FT) Service Name - EDIT Service Sub Name - FLIC Origin of Data - FLIC File Type - LO Reel Comments - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 Tape Comments - BP EXPLORATION, ENDICOTT, 2-54 / Q-12 MPI,50-029-22218 File 3 - Log Header Information + LOG HEADER LISTING Page 1 -+ Log Heading: Company: BP EXPLORATION Well: 2-54 / Q-12 MPI Field: ENDICOTT : NORTH SLOPE : ALASKA Nation: USA Location: 2078' SNL & 2328' WEL Field Location: Sec: 35 Twp: 12N Latitude: Permanent Datum: MSL Elevation of Permanent Datum: 0.0 Log Measured From: DF Drilling Measured From: Date: 91/12/12 Run No: Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 12175.0 12175.0 12175.0 10926.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 Longitude: 0.0 0.0 0.00 0.0 Rge: 16E Elevations:- KB: 56.0 DF: 56.0 GL: 14.5 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: LSND 9.70 14.00 9.00 5.20 1.790 1.430 0.000 0.0 / at at at 72.000 72.000 0.000 + .... ISL ISL .... + Remarks: - LOG HEADER LISTING Page 2 -+ Other Services:- Equipment Numbers :- + .... ISL ISL .... + File 3 - Channel Listing Mnem NbrSamp NbrEntry D~T 1 1 ~R 1 1 TENS 1 1 MRES 1 1 MTEM 1 1 HTEN 1 1 ServID Stat InUnit OutUnit 01 ALLO FT FT CSG 01 ALLO GAPI GAPI CSG 01 ~ LB LB CSG 01 ALLO OHMM OHMM CSG 01 ALLO DEGF DEGF CSG 01 ALLO LB LB Start 11000.000 63.875 4785.000 0.501 163.175 593.000 Stop 10460.000 69.000 4570.000 0.528 156.087 620.000 File 3 - Conmments Listing ************************** * FILE - EDIT.003 * BP EXPLORATION * ENDICOTT * 2-54 / Q-12 MPI * 50-029-22218 MAIN PASS CASING DATA IS FROM FIELD FILE .012 DATA SAMPLED EVERY -.5000 FEET * DATA INCLUDED - * TOOL EXTENSION * TYPE USED * GR .CSG TOOL GAMMA RAY