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Home My WebLink About187-018MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 2-06 DUCK IS UNIT MPI 2-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 2-06 50-029-21699-00-00 187-018-0 G SPT 9393 1870180 2348 3294 3302 3297 3305 0 0 0 0 4YRTST P Bob Noble 5/16/2025 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 2-06 Inspection Date: Tubing OA Packer Depth 340 2712 2690 2689IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250516161123 BBL Pumped:3.6 BBL Returned:3.4 Wednesday, July 23, 2025 Page 1 of 1           Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/27/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230227 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 233-23 50283201360100 222050 1/20/2023 AK E-LINE Perf END 2-06 50029216990000 187018 1/23/2023 AK E-LINE Perf PBU 04-22A 50029214540100 194097 1/10/2023 AK E-LINE PPROF PBU 11-39 50029235180000 214099 2/8/2023 READ MultipleArrayProductionProfile SRU 23-33 50133101630000 161019 1/3/2023 AK E-LINE Plug_Cement_Jet Cut TBF A-01RD 50733100550100 190147 1/24/2023 AK E-LINE Tubing Punch Please include current contact information if different from above. END 2-06 50029216990000 187018 1/23/2023 AK E-LINE Perf 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Reperforate Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,265 feet N/A feet true vertical 10,191 feet N/A feet 5,492, 12,213 and Effective Depth measured 13,057 feet 12,403 feet true vertical 10,031 feet 4,965, 9,393, and feet 9,531 Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 7-5/8", Tubing (size, grade, measured and true vertical depth) 5-1/2" and 4-1/2" L-80 12,276' 9,438' 1,506' MD, Packers and SSSV (type, measured and true vertical depth) 4-1/2" QOS SSV See Above 1,504' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 9-5/8" Baker ZXP, 7- 5/8" Baker NSCT BXP and 9-5/8" LTP NA Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 67865 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jerimiah Galloway jerimiah.galloway@hilcorp.com 907-564-5005 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 2,502' 700 Size 2,499' 0100075351 0 42420 4287 measured TVD 7" 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 187-018 50-029-21699-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312828 ENDICOTT / ENDICOTT OIL DUCK IS UNIT MPI 2-06 Plugs Junk measured Length Liner 862' 6,886' Casing Surface 10,191' 9,513' 13,265' 12,378' 12,680' Intermediate Production Liner 13-3/8" 9-5/8" 2,502' None 8,510psi 4,790psi 6,870psi 11,220psi 6,890psi 12,680' 9,742' Burst 5,020psi Collapse 2,260psi 4,760psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:31 am, Feb 16, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.02.15 17:38:29 -09'00' Torin Roschinger (4662) DSR-2/22/23 RBDMS JSB 022123 WCB 1-10-2025 Well Name Rig API Number Well Permit Number Start Date End Date END 2-06 Slickline 50-029-21699-00-00 187-018 1/17/2023 1/24/2023 ELine. JOB CONTINUED FROM 1/21/2023. WELL INJECTING ON ARRIVAL. PRESSURE TEST PCE 200#LP-3,000#HP. RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, 1 11/16" GR/CCL, 1 11/16" SHOCK SUB, 2 7/8" GUN (14' LOADED W/ 15GRAM RAZOR XDP CHARGES). GUN #2: CCL OFFSET=9.7', PERF DEPTH=12,852'-12,866', CCL STOP DEPTH=12,842.3'. GUN #3: CCL OFFSET=8.6', PERF DEPTH=12,825'-12,839', CCL STOP DEPTH=12,816.4'. GUN #4: CCL OFFSET=9.7', PERF DEPTH=12,779'-12,793', CCL STOP DEPTH=12,769.3'. WELL LEFT SHUT IN. JOB CONTINUED ON 1/23/2023. 1/23/2023 - Monday JOB CONTINUED FROM 1/22/2023. WELL SHUT IN ON ARRIVAL. PERSSURE TEST PCE 200#LP-3,600#HP. RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, 1 11/16" GR/CCL, 1 11/16" SHOCK SUB, 2 7/8" GUN (14' LOADED W/ 15 GRAM RAZOR XDP CHARGES). GUN #5: CCL OFFSET=9.7', PERF DEPTH=12,741'-12,755', CCL STOP DEPTH=12,731.3'. WELL LEFT SHUT IN. 1/24/2023 - Tuesday CONT WSR FROM 1-23-23. (set wrdp-2 sssv). RAN 3.80" CENT, 4-1/2" BRUSH TO HQR-INSERT NIP AT 1,506' MD. SET 4-1/2" WRDP2-SSSV IN HQR-INSERT NIP AT 1,506' MD. PURGE 2 GAL DOWN CONTROL LINE (trbl sht, see log). PURGE 3 GAL DOWN BALANCE LINE. SET RQ-LOCK, WRDP2-SSSV (3.85" no-go ring on lock, 2nd lkdwn installed, 2 sets std pkg, bal-operated, control line plugged, 89" oal), IN HQR NIP AT 1,506' MD. WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS. 1/21/2022 - Saturday ELine. WELL SHUT IN ON ARRIVAL. PRESSURE TEST PCE 200#LP-3,600#HP. RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT, 1 11/16" WEIGHT, 1 11/16" GR/CCL, 1 11/16" SHOCK SUB, 2 7/8" PERF GUN (LOADED 14' W/ 15 GRAM RAZOR XDP CHARGES). GUN #1: CCL OFFSET=9.7', PERF DEPTH=12,885'-12,899', CCL STOP DEPTH=12,875.3'. WELL LEFT SHUT IN. 1/22/2023 - Sunday TAGGED SSSV @ 1,468' SLM (1,506' MD) W/ 3.84" CENT, NO RESTRICTIONS. PULLED 4-1/2" WRPD-2 (serial: HABS-0298) FROM 7" INSERT @ 1,468' SLM (1,506' MD), ALL PACKING & PINS RECOVERED. RAN 20'x2-7/8" DUMMY GUNS(3.166" Rings), 1- 3/4" SAMPLE BAILER (oal: 23.5'). DRIFT FREELY DOWN & OUT TUBING TAIL, S/D @ 12,881' SLM (12,919' MD, using 38' cor from sssv), RECOVERED THICK SHMOO IN BAILER. 1/17/2023 - Tuesday Hilcorp Alaska, LLC Weekly Operations Summary 1/18/2022 - Wednesday Slickline. RAN 4-1/2" TEL, 3.25" CENT, 3'x1-7/8" STEM, 3.25" CENT, SAMPLE BAILER, LOC TT @ 12,222' SLM (12,276' MD, 54' cor), S/D @ 12,879' SLM (12,933' MD). WELL S/I ON DEPARTURE, DSO NOTIFIED. SSSV LEFT OOH FOR ELINE ADD PERF. 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James B (CED) <jim.regg@alaska.gov> Subject: RE: DIU MPI 2-06 (PTD# 187018) OPERABLE: IA repressurization resolved Slight date correction From: Oliver Sternicki Sent: Monday, November 1, 2021 10:06 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: DIU MPI 2-06 (PTD# 187018) OPERABLE: IA repressurization resolved Mr. Wallace, Gas injector DIU MPI 2-06 (PTD# 187018) was reported to the AOGCC on 10/11/2021 for potential TxIA communication. Wellhead work was executed on 10/15/2021 to tighten the lock down screws on the tubing hanger, but the well would not pass a PPPOT-T. Subsequent monitoring has shown that the primary seals in the wellhead are holding and the TxIA repressurization has been resolved. The well is classified as OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Oliver Sternicki Sent: Monday, October 11, 2021 10:44 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: DIU MPI 2-06 (PTD# 187018) IA Repressurization Mr. Wallace, Gas injector DIU MPI 2-06 (PTD# 187018) IA pressure was bled on 10/9/2021 from 1850 psi to 350 psi. The IA pressure has increased to 1750 psi indicating potential TxIA communication. We currently plan to keep the well on injection to aid in diagnostics. Annulus pressures will be maintained under MOASP while diagnostics are performed, if the IA pressure cannot be managed with periodic bleeds the well will be shut-in. Plan Forward: 1. PPPOT-T 2. Reset SSSV if necessary 3. AOGCC witnessed MIT-IA. Please respond with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 thatany dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility isaccepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: DIU MPI 2-06 (PTD# 187018) IA Repressurization Date:Tuesday, October 19, 2021 9:09:58 AM Attachments:image004.png From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, October 11, 2021 10:44 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: DIU MPI 2-06 (PTD# 187018) IA Repressurization Mr. Wallace, Gas injector DIU MPI 2-06 (PTD# 187018) IA pressure was bled on 10/9/2021 from 1850 psi to 350 psi. The IA pressure has increased to 1750 psi indicating potential TxIA communication. We currently plan to keep the well on injection to aid in diagnostics. Annulus pressures will be maintained under MOASP while diagnostics are performed, if the IA pressure cannot be managed with periodic bleeds the well will be shut-in. Plan Forward: 1. PPPOT-T 2. Reset SSSV if necessary 3. AOGCC witnessed MIT-IA. Please respond with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 thatany dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility isaccepted 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 Cas Conservation Commission TO: Jim Regg b i 1( LSI DATE: Tuesday, June 8, 2021 P.I. Supervisor SUBJECT: Mechanical Integrity Tests Inj G 'iTVD Hilcurp Alaska, LLC 9393 2-06 FROM: Bob Nobie DUCK IS UNIT MPI 2-06 Petroleum Inspector 4537 - 5436 - See: Inspector Test Reviewed By: Test psi P.I. Supry ibr— NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-06 Insp Num: mitRCN210527134913 Rel Insp Num: Well 2-06 i Type PTD 1870180 Type BBL Pumped: 2 Interval 4YRTST Notes: API Well Number 50-029-21699-00-00 Inspector Name: Bob Noble Permit Number: 187-018-0 Inspection Date: 5/27/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Inj G 'iTVD 9393 Tubing 4535 '' 4573- 4537 - 4537 - 5436 - Test SPT Test psi 2345 - IA 818 2590 - 2582 2573 - 2568 BBL Returned: 2- OA 0 o a o 0 P/F P Tuesday, June 8, 2021 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6 DATE: Tuesday,June 20,2017 P.I.Supervisor ( /t 7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 2-06 FROM: Jeff Jones DUCK IS UNIT MPI 2-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-06 API Well Number 50-029-21699-00-00 Inspector Name: Jeff Jones Permit Number: 187-018-0 Inspection Date: 5/28/2017 Insp Num: mitJJ170618120606 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-06 - Type Inj G-ITVD 9393 - Tubing 4746 - 4751 ' 4753 - 4748 - PTD 1870180 Type Testi SPT Test psi 2348 - IA 558 2610 - 2595 - 2594 BBL Pumped: r 4.3 - BBL Returned: 4.2 - OA 20 20 - 20 - 20 Interval 4YRTST P/F P V Notes: 1 well inspected,no exceptions noted SCANNED AUG 3 0 2017 • Tuesday,June 20,2017 Page 1 of 1 • • 14 443"' - Post Office Box 244027 �y l� tt Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL L. 3 0 2 a h 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission Q f g 333 West 7th Avenue, Suite 100 ` �I Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request SCANNED SEP Q 1 2Q16 Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig New API_WeliNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/020 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/020 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/116 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 OF rilt e,Y N I%%i THE/STATE Ell v Ike/ =_ kj -- 333 West Seventh Avenue �' ; 7, GOVERNOR SEAN PARNFLI. Anchorage, Alaska 99501-3572 j Main: 907 279 1433 LASg�a'�� Fax: 907.276.7542 .0- 46Josiah Igwe SCpNN11C1 Production Engineer BP Exploration (Alaska), Inc. Q © t P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 2-06/J22 Sundry Number: 314-190 Dear Mr. Igwe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 7° a) Cathy P. F a erster Chair, Co missioner DATED this 3 day of April, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0.cr 9 f '3 O - 20 AAC 25.280 LA 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ Other. Water Wash Q. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill umber. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 187-018-0• 3.Address: Stratigraphic ❑ Service 2 • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21699-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? EPA 2-06/J-22 • Will planned perforations require a spacing exception? Yes ❑ No Cl 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • ENDICOTT, ENDICOTT OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13265 • 10191 . 13164 10113 None None Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 2462 13-3/8"68#L-80 40-2502 40-2498.88 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 4-1/2"QOS SSV 1506',1504.12' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service 2 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 + GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.Igwe©BP.Com Printed Name Josiah Igwe Title Production Engineer Signature — Phone 564-4753 Date Prepared by Garry Catron 564-4424 c- - tlej \'Lo 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number -'1`i \9 C3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSMAY 10 2014 Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /c 4 C 4 / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4_,-.3 -/ Form 10-403 Revised 10/2012 V Irlid for 12 months from the date of approval. Subm Form and Attachments in Duplicate, 21 / ./1 i}- —i it i� o (I) -a O p = 0 0 0 0 0 a, coccIDcococococo Z Z J J J J N, Q o o 0 0 0 0 0 0 0 0) CO 00 CO CA O) O U) � f� I� � O o co '7 O N r- Co U y N O o o o o o o o O O N 0) Q) C) N co co — o co co r-- m CO Co co O Co Co co N- N N Cr) co N 0) Tr N co m O M Co co o co co N- co O Cs,' O co O N •- O O • M• CD 0 C) 0 O 0) c!,73 O0) a) c co a) CO 03 EC ao O O f� C (y NO M 0) U 0 C1NCOo N O) m (n M NO N N N N .c o ~ 0) o o) co • O O O CO 2 CA p 0 0 0 CO O CO CO CO J CO D I-- Z0NNCD Cl) It N N Co N N O QD - - N o 5 Oo Qa0 do (N N Eo Ln LO LO N- CA I N- N- 'C O t • O N-COO O 0) CCOO N- Co O) co J O co COO O N C) CO ZZ• 00 Cr) F- W D p 000 0000 Clia. Q 0 O W Z Z Z Z w w O O w m m m Z Z W m » » = = aacnF- F- F- F- Perforation Attachment ADL0312828 Well Date _ Perf Code MD Top MD Base TVD Top _ TVD Base 2-06/J-22 4/16/11 RPF 12724 12738 9777 9788 2-06/J-22 4/16/11 RPF 12738 12758 9788 9803 2-06/J-22 4/16/11 RPF 12768 12790 9811 9828 2-06/J-22 ' 4• /15/11 ' RPF 12790 12810 9828 9844 2-06/J-22 4/15/11 ' RPF 12816 12840 9849 9867 2-06/J-22 ' 4• /14/11 ' RPF 12840 12860 9867 - 9883 2-06/J-22 4/13/11 RPF 12860 12880 9883 9898 2-06/J-22 1 4• /13/11 APF 12880 12900 9898 9913 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0312828 Well Facility Type MD Top Description _ TVD Top 2-06/J-22 _ SSSV 1506 4-1/2" QOS SSV 1504 2-06/J-22 PACKER 5492 7-5/8" Baker ZXP Top Packer 4965 2-06/J-22 PACKER 12213 4-1/2" Baker NSCT BXP Packer 9393 • bp 0 To: Len Seymore/Tyler Norene (ADW Well Service TL) Date: March 18, 2014 Jerry Middendorf/Rob Liddelow (AD Wireline TL) GPB Well Ops Team Leaders From: Troy Weiss, Well Integrity Eng AFE: AENWEINR Est. Cost: Subject: END2-06 MIT-IA and Water Wash IOR: Endicott is an elevated risk area. Please ensure that SOP: Wellwork at Elevated Risk Areas is followed. 1. W PPPOT-T& IC to 5100 psi; check LDS 2 S Drift & Tag well, Pull SSSV, Water wash and Load and Kill well and set TTP in tubing nipple, MITT to 2,500 psi, Load IA and MIT-IA to 5,100 psi while maintaining 4,100 psi on tubing, Pull TTP and reset the SSSV 3. F Assist Slickline Current Status Gas injection well 80 MMscfd @ 4600psi WHIP, 213 degrees F Maximum WHIP on gas injection is 5000 psi (MIT-IA above this pressure) Max deviation: 50° at 8100'MD Min. ID: 3.725" at 12263' MD at 4-1/2" XN Nipple Last TD tag: 4/11/2011; 12862'MD w/2-7/8" dummy gun, 3.25" restriction 12748' SLM. Integrity Issues Difficulty holding pressure on balance & CL, SSSV difficult to run 9/15/13. Latest H2S Injection gas has 230-260ppm H2S. SSSV status: Installed on 9/16/13; (7" insert with 4-1/2" RQ-WRDP-2) at 1506' MD Ser#hps-385, oal-89", 3 sets of standard packing SSSV Notes: 3/6/13: Gas injector/cap gas well. It has a surface controllable SSSV and is plumbed to provide gas to the plant for start-up. Higher pressure (6500 psi) needed to keep SSSV open. Insert needed for 4-1/2" SSSV in 7" profile. BHP/BHT: 4200-4400psi @ 10,000'SS, 214 degrees F: Calculated from SITP's Program Objective END2-06 is a gas injector which is currently injecting about 90 mmscfpd at 4,800 psi but has historically injected 136 mmscfpd at about the 4400 psi. Solvent wash is required to improve its injectivity. ✓ END2-06 MIT-IA page 1 It was noticed at the 4Q13 Gas Injector Review with Base Mgmt that the well had not been tested with an MIT-IA to maximum injection pressure. The decision was made to retest to 1.0x Maximum injection pressure. WIOP recommended 1.2x Maximum injection pressure, but this was declined at reviewing loads on the 14 year old production casing. Well Events > 2001: RWO's ran scab liner over deep PC > 11/15/12: Passed MIT-IA to 3000 psi > March '13: Troubleshooting SSSV operation > 05/31/13: Passed AOGCC MIT-IA to 4000 psi > Sept '13: Troubleshooting SSSV operation > 09/14-16/13: Difficulty running the 7" INSERT W/4-1/2 SSSV Wellhead 1. W: PPPOT-T and PPPOT-IC to 5100 psi. Slickline/Fullbore 1. SL: Drift and Tag to PBTD with sample bailer • Send any sample recovered to BP lab for analysis 2. SL: Pull 7"x4-1/2" HQR Insert @ 1506' MD 3. FB & SL: Water wash and Load and Kill well and set plug in TT • Fullbore to rig up hardline so we have the capability to pump at 8 bpm. • Pump 200 bbls of 50/50 Diesel/Xylene with 1% mutual solvent • Pump 200 bbls of 1% KCI with 0.2% F103 (Surfactant) • Finish loading well with 410 bbls 1% KCI • Pump as per attached pump schedule • FP tubing • Set TTP @ 12263' MD 4. FB: MIT-T 2,500 psi A. If MIT-T passes, continue to step 4 B. If MIT-T Fails trouble shoot TTP, plug is meant for holding tubing pressure to prevent tubing collapse. C. The ability to maintain pressure on the tubing during the MIT-IA is a requirement but a passing MIT-T is not a requirement of this job. 5. FB: Pressurize the tubing and IA together in increments. Hold the tubing pressure to 4000 psi, while conducting the MIT-IA to 5,100 psi as per attached pumping program, record LLR if fails. A. If MIT-IA passes, remove the UP, and set SSSV, RDMO. B. If MIT-IA fails, leave UP in hole, RDMO for secure and upcoming LDL. Note: Don't allow more than 2500 psi differential between the tubing and IA or 1500 psi differential between the IA and tubing throughout the tests. END2-06 MIT-IA page 2 Please call Troy Weiss at 564-5989w or 223-0290c or Josiah Igwe at 546-4753w or 590-0610c with any questions about this procedure. cc: well file Attachments: 1. Full bore pump schedule 2. Calculations of burst and collapse for designing MIT-IA END2-06 MIT-IA page 3 Versionl.1 04/28/2010 Fullbore Pumping Design Template Well Name Endicott 2-06i Job Scope MITIA H2S(ppm/date) WBL Cat Reg Compl Cost Tubing<4100 psi IA<5200 psi Max Pumping Pressure(psi) Well Type GI AFE AENWEINR Main Fluid Type Date 211812014 PE IOR 0 650 Main Fluid Volume(bbls) Engineer Troy Weiss Phone 907 223-0290 Diesel Freeze Protect Type 100 Freeze Protect Volume(bbls) Job Objective 12724=Perfs Recent Tbg Fluid Level(ft) Conduct a high pressure MIT-IA to at least normal maximum Surf:5/31/13 Recent IA Fluid Level(ft) injection pressure 5100 psig on gas injection. Recent OA Fluid Level(ft) 650 Expected Tbg Fill Up Volume(bbls) 10 Expected IA Fill Up Volume(bbls) Expected OA Fill Up Volume(bbls) 421 Wellbore Volume to Perfs(bbls) Fullbore Pumping Schedule 4200-4440 Anticipated Bottom Hole Pressure (psi) 4400 Anticipate Pressure at the Packer Pump Volume Rate Max Yes Tubing/Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 7.625 6890 5512 Spear Methanol(60/40) Tbg 10 8 2500 Tubing Collapse(psi) 7.625 4790 3832 Casing Burst(psi) 7.625 6890 5512 Solvent 50/50 Diesel Xylene Tbg 200 8 2500 Casing Collapse(psi) size 0 Load 1%KCI Tbg 610 8 2500 Select Input Depth Integrity Issues? TxIA 1506 MIT Diesel Tbg 100 8 4000 Select input Depth MIT Diesel IA >5 1 5100 No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing Yes Production Packer within Pressure Limits? Detailed Pumping Procedure 10000 Rated Packer dp Baker,BX; ,,Lx7-5/8 4975 Max Anticipated dp at Packer 1 PJSM. RU&PT lines 2 Pump per schedule above Yes-Tubing Hold Pressure on Other Strings? 3 Load as per the schedule above 4000 Tubing(psi) 4.Set UP and MIT T to 2500 psi 5000 IA(psi) 5. MIT IA to 5100 psi while holding 4100 psi on the Tubing 0 OA(psi) 6. RDMO END2-06 MIT-IA page 4 ' TTS= ` CTW END 2-0 6 S. f NOTES:Ii2S READINGS AVERAGE 230-260 WELLHEAD= FMC PPM ON A/L&GAS INJECTORS'"' WELL REQUIRES ACTUATOR= BAKERRCI ' ASSSV' INITIAL KB.REV 56' BF.aEV= ,--1 1504' —17-5/8"X 7"XO,D=6.276" KOP= Max Angle= 50"@ 8100' 1506' �7"RPB NP,D=5.963" Datum MD= 13090' �~� 1506' —1-177:X 4-1/2"FIQR NSERT,D=3.81"(06/16/13) Datum TVD= 10000 SS ----------1 _ 1510' 17"X7-5/8X0,1 =6.276' 13-3/8"CSG,68#,L-80 BTRS, — 2507 1 D=12.415" 7-5/8"LNR,29.7#L-80 STL, H 5340' 1--\ /—{ 5340' 17-5/8"X 5-1/2"XO,D=4.892 .0459 bpf,D=6.875" TOP OF 7-518"SCAB LNR —j 5492' f i. 5492' 9-518"X 7-5/8"ZXP FKR w/FLEXLOCK HY D LNR HGR,D=6.815" Minimum ID =3.725" @ 12263' s ` 4-1/2" XN NIPPLE f: Y, 5-1/2"TBG,16.7#,L-80 STL, —j 12154' 14 \ j f 12154' H5-1/2"X 4-1/2"X0,13=3.958" .0232 bpf,ID=4.892" i+ y,, r :4,'"% 12202' —14-1/2"X NP,D=3.813" '1', '$..)( 12213' —17-5/8"X 4-1/2"BXP BKR PKR,ID=3.875" ' , ,..7'. f 12237'—{4-1/2"X NIP,D=3.813"J 4-1/2"TBG,12.6#,L-80 NSCT, — 12274' }a j, .0152 bpf,D=3.958" 4.. ' , .'.� f 12263' j—f4-1/2"XN NP,D=3.725"J 7-5/8"SCAB LNR,29.7#,L-80 STL, — 12370' 0445 bpf,D=6.765' 12276' —I4-1/2"WLEG,D=4.00" 12267' H I ELMD TT LOGGED ON 04/13/11 TOP OF 7"LNR H 12403' f 12378' *7"BKR SIMPLEX TE-BACK STEM 9-5/8"CSG,47#,NT95HS,D=8.681" H 12680' 1\41 w/7-5/8"X 7"XO,D=6.25" 12403' �9 5/8"X 7"BKR LTP,D=? PERFORATION SUMMARY 11 REF LOG: DLL-GR on 03/25/87 12376'H MD(04113111) ANGLE AT TOP PERF:39" @ 12724' Note:Refer to Production DB for historical perf data SIZE SPF NTER'VAL Opn/Sqz Ss hot SQZ 4 8 12724-12758 0 05/20/87 4 4 12724-12758 0 04/23/92 • 4 4 12768- 12810 0 04/23/92 ✓ 4 8 12768- 12810 0 05/20/87 4 4 12816- 12860 0 04/23/92 4 8 12816-12860 0 05/20/87 ✓ 4 4 12860-12900 0 07/26/92 x.4.4.4..V.v4.4. PBTD(DIMS 05/21/01) H 13057' 7"LNR,29#,SM-110 BTC,.0371 bpf,D=6.184" —I 13265' DATE REV BY CONLE NTS DATE REV BY COMMENTS E DICOTT UNIT 05/20/87 13-15 INITIAL COMPLETION 11/07/13 MSS/PJC MO NSBRT(06/16/13) WELL.: 2-06/J-22 11/03/91 13•15 RWO 11/10/13 PJC SCAB LNR CORRECTION PERMIT No: 1870180 06/03/01 D-15 RWO API No: 50-029-21699-00 06/20/11 JMUMD PERF CORRECTIONS SEC 36,T12N,R16E,1852'RV_&2179'Fla. 08/12/11 DVII/JMD H2S SAFETY NOTE 11/26/12 TRP/AID TREE C/O(11/19/12) BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r"--) DATE: Friday,June 14,2013 TO: Jim Regg ctf,- �4 '3 P.I.Supervisor I l l SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 2-06/J22 FROM: Bob Noble DUCK IS UNIT MPI 2-06!J22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry—.1£S — NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-06/J22 API Well Number 50-029-21699-00-00 Inspector Name: Bob Noble Permit Number: 187-018-0 Inspection Date: 5/31/2013 Insp Num: mitRCN130604072149 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-06/J22 ' ,Type Inj G t,TVD 9393 IA 545 4059 . 4063 4059 - Test psi _- — Type Test I SPT i p 2348 OA II 11 7 1870180 i_ P/F TS Tubing', — 4714 ..'I 4713 - 4716 , Interval '4YRTST I 4714 g' Notes: They had a surface leak on the transmitter conection.Test was stopped at the 25 min mark.Leak was fixed and well was retested. SCANNED FEB 2 0 2014 Friday,June 14,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Tuesday,June 04,2013 P.I.Supervisor k,(1; L.(l3!l3 SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC 2-06/J22 FROM: Bob Noble DUCK IS UNIT MPI 2-06/J22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ac--- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 2-06/J22 API Well Number 50-029-21699-00-00 Inspector Name: Bob Noble Permit Number: 187-018-0 Inspection Date: 5/31/2013 Insp Num: mitRCN130604072950 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2-06/J22 Type Inj G• TVD 9393 IA 4041 4041 • 4035 . 4033 1870180 SPT � ,-1 PTD - IType Test', !Test psi 2348 - ' OA 6 6 7 5 Interval 4YRTST P/F P / Tubing 4718 4718 4713 4716 _ i-_ . ... _L .. - L --!- Notes: Re-test from test that has a serfice leak on pressure transmitter. - SCANNED FEB 2 © 2014 Tuesday,June 04,2013 Page 1 of 1 \ orb � TIv , s THE STATE Alaska Oil and Gas '�' °fALAS� Conservation Commission . ^ GOVERNOR SEAN PARNELL 333 West Seventh Avenue \ ro 7 1Tm P Anchorage, Alaska 99501 -3572 4L AS - * Main: 907.279.1433 Fax: 907.276.7542 • Josiah Igwe SCANNED JAN 1 0 2013 ' Production Engineer . 0 BP Exploration (Alaska), Inc. \ - P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2- 06/J -22 Sundry Number: 312 -415 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 40 1y, Jo N•rman 07 Co • missioner DATED this i day of November, 2012. Encl. , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION,, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Water Wash 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 187 -018-0 • 3. Address: Stratigraphic ❑ Service 0 . 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 21699 -00 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 462 EPA 2 -06/J -22 Will planned perforations require a spacing exception? Yes ❑ No ❑ i, �t "(p 2 _c 36/ 2 Z , /JY * :`i r 2--- 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312828 • ENDICOTT, ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13265 r 10191 • 13164 10113 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 105 30" Conductor 41 - 146 41 - 145.99 Surface 2462 13 -3/8" 68# L -80 40 - 2502 40 - 2498.88 5020 2260 Intermediate None None None None None None Production 12641 9 -5/8" 47# NT95HS 39 - 12680 39 - 9742.44 8150 5080 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (It): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths See Attachment See Attachment for SSV Depth 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ 0 • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG p 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.lgwe@BP.Com Printed Name Josiah Igwe Title Production Engineer Signature t -, c- 7 ,.; Phone 564 -4753 Date Prepared by Garry Catron 564 -4424 W' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 5 1 i-' 4 41 a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes IS ■ Q / t i 7 Subsequent Form Required: / v — 4 a 4- / APPROVED BY / Approved by: 19 COMMISBJ.ONER THE COMMISSION Date: del.. /!/ S'S r( OW k tV o v`1� S'�Y Sap(Di5 Mt 10- B c 312012 �" Form 1 -403 Revised 1/2010 Approved application is valid for 12 months rom the date of ap rf u mit in upli A Casing Summary ADL0312828 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 105 30" Conductor 41 146 41 146 LINER 862 7" 29# SM -110 12403 13265 9531 10191 11220 8510 SM -110 LINER 6886 7 -5/8" 29.7# L -80 5492 12378 4965 9513 6890 4790 L -80 PRODUCTION 12641 9 -5/8" 47# NT95HS 39 12680 39 9742 8150 5080 NT95HS SURFACE 2462 13 -3/8" 68# L -80 40 2502 40 2499 5020 2260 L -80 TUBING 5301 7 -5/8" 29.7# L -80 39 5340 39 4866 6890 4790 L -80 TUBING 122 4 -1/2" 12.6# L -80 12154 12276 9351 9438 8430 7500 L -80 • TUBING 6814 5 -1/2" 17# L -80 5340 12154 4866 9351 7740 6280 L -80 • Perforation Attachment ADL0312828 Well Date Perf Code MD Top MD Base TVD Top TVD Base 2- 06/J -22 4/16/11 RPF 12724 12738 9777 9788 2- 06/J -22 4/16/11 RPF 12738 12758 9788 9803 2- 06/J -22 4/16/11 RPF 12768 12790 9811 9828 2- 06/J -22 4/15/11 RPF 12790 12810 9828 9844 2- 06/J -22 4/15/11 RPF 12816 12840 9849 9867 2- 06/J -22 4/14/11 RPF 12840 12860 9867 9883 2- 06/J -22 4/13/11 RPF 12860 12880 9883 9898 • 2- 06/J -22 4/13/11 APF 12880 12900 9898 9913 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Ill Casing Summary ADL0312828 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 105 30" Conductor 41 146 41 146 LINER 862 7" 29# SM -110 12403 13265 9531 10191 11220 8510 SM -110 LINER 6886 7 -5/8" 29.7# L -80 5492 12378 4965 9513 6890 4790 L -80 PRODUCTION 12641 9 -5/8" 47# NT95HS 39 12680 39 9742 8150 5080 NT95HS SURFACE 2462 13 -3/8" 68# L -80 40 2502 40 2499 5020 2260 L -80 TUBING 5301 7 -5/8" 29.7# L -80 39 5340 39 4866 6890 4790 L -80 TUBING 122 4 -1/2" 12.6# L -80 12154 12276 9351 9438 8430 7500 L -80 • TUBING 6814 5 -1/2" 17# L -80 5340 12154 4866 9351 7740 6280 L -80 • • Packers and SSV's Attachment ADL0312828 Well Facility Type MD Top Description TVD Top 2- 06/J -22 SSSV 1506 4 -1/2" QOS SSV 1504 2- 06/J -22 PACKER 5492 7 -5/8" Baker ZXP Top Packer 4965 2- 06/J -22 PACKER 12213 4 -1/2" Baker NSCT BXP Packer 9393 • End2 -06 FCO AFE #: AENCAPSU To: J. Bixby /R.Liddlow: WireLine Team Leaders Date: Oct. 18, 2012 C. Olsen/T. Norene Well Ops Team Leaders From: Josiah Igwe End 2 & 5PE AFE: Est. Cost: Subject End2 -06 FCO: IOR: 220 Job Sequence: 1 S Pull SSSV. Drift as deep as possible. 2 C FCO /SBG/ Diesel & Xylene Treatment 3 S Drift and Tag TD and Set SSSV. Current Status: Online Last test: 21/10/2012: 67 mcfpd @ 4907 psi Max Deviation: 50 deg @ 8100' MD Last Downhole Op: 9/14/2011: Set SSSV at 1470' slm Last Tag 04/12/2011: S /Line tagged hard a *12,854' m Minimum ID 3.725" @ 12263' 4 -1/2" NSCT XN Ni Last BHP: 4199 psi Latest H2S Value: Injector Objective 5a Jet tubing and perfs with SBG to help dissolve schmoo within the tubing and in the near wellbore region to allow this well to inject at normal rate. Well History END2 -06 is 2A zone 105 MMSCFD steady gas injector originally drilled and completed in 1987. In June -01 END2 -06 was worked over and recompleted with 7 -5/8" to 5'/" to 41/2" tubing, leaving the 7" liner. On 14- Dec -08 the well suffered an injectivity reduction of around 25 MMSCFD after the plant lost a couple thousand gallons of seal oil (turbine 32) into the gas injection stream. END1 -05 and END2 -06 also suffered a loss in in injectivity due to the lube oil. Lube oil leakage into the gas injection system remains a problem, but estimated volumes have been reduced to roughly 250 gal /wk. Aiming to clean a broad frame of possible damages, a 12% DAD Acid wash (includes 50% xylene) was initially recommended but after further revision of wells historic response to HCL it 1 .. ., End2 -06 FCO • • FE #: AENCAPSU is considered to be poor and to be consistent also with the common damage mechanism in gas injector in Endicott of salt formation, the recommendations changed to a xylene /diesel mix followed by a regular water wash with F -103 surfactant. This solvent treatment was pumped in END2 -12 in Feb -09 and resulted in a loss of injectivity of -3 MMSCFD. Solvent treatments to END2 -06 and END1 -05 were not pumped seeing the results from the END2 -12. A 295 bbls water wash with F -103 surfactant was pumped in Sept -09 and resulted in slight loss of injectivity. Diesel/Xylene treatment using foam diversion in 11/7/2009 did not have any impact on • injection rate. Additional perforations were added on 4/17/2011 with corresponding increase in gas injection to 100 mmscfd. Recent well shut downs for valve greasing has been impacting . injection rate. Recent Slick Line drifts came out with samples of schmoo. CT FCO / SBG and diesel & xylene .i treatment is planned to clean the well bore and the perforation. ` Contact: Josiah Igwe Pad Engineer Office / Cell: 564 - 4753/590 -0610 Open Perforations Zone MDT MDB Ht Status K2M /K2A/S2A3 12,724' 12,758' 34' Open K2A/S2A3 12,768' 12,810' 42' Open K2A/S2A3 /S2A2 /S2A1 12,816' 12,860' 44' Open S2A1 12,860' 12,900' 40' Open 2 End2 -06 FCO • �AFE #: AENCAPSU Design Details Total Footage 160' # of Perforations 960 Wellbore Volume 422 bbls (to top pert) Frac Gradient 0.72 psi/ft Wellbore Volume to Top Perf 422 bbls Frac Gradient 0.72 psi/ft TVD Top Perf Depth 9777 ft 1%-KCI Grad 0.434 psi /ft Diesel grad 0.353 psi /ft BHP 4199 psi HS psi (1% KCI) 4243.218 psi Frac 7039.44 psi Max Pump Pressure (1% KCI) 2796.222 psi 1. Slickline 1. MIRU SL and SI well. 2. MU tool string and retrieve 4 -1/2" SSSV at 1506' md. 3. Drift and Tag fill with sample bailer and TEL • Send sample to lab for composition and solubility analysis in SBG and diesel /xylene mixture. 4. Return well to operations to POI. 5. RDMO 3 End2 -06 FCO �AFE #: AENCAPSU 2. CT FCO Procedure: 1. MIRU CTU 2. MU BHA with 2.50" JSN. • Note by SLB definition this well is termed as CAT 11 well so ensure PCE are rated to 10k 3. Fluid pack well down back side with 1% Kcl + 0.002% F103 • The reason for this is to knock down well head pressure to enable coil to run in and to wet the tubing. • Also ensure to have -450 bbls of 1% Kcl + 0.002% F103 on site for fluid packing well • Record the injectivity rate • Do not exceed 0.72 psi/ft frac gradient 4. Shut in well and RIH while jetting across tubing with SBG. 5. At 12,400', shut down um and RIH and gently dry tag fill at - 12,854' P P 9 Y rY 9 • Note that Slick Line last drift was to 12,854' • Be sure to review MSDS for SBG with all the crew on site 6. Once tag occurs, PUH to 12,400' to get full weight and re- establish pump rate, continue jetting across the tubing but do not exceeding 3500 psi CT pressure. 7. Once nozzle is on the fill, make 5' short bites and picking up frequently to prevent burying nozzle into soft fills. • Fluffing up the fills and pumping all the debris into the perfs method will be used le here since the debris cannot be brought to surface. 8. Once 12,950' or below is achieved reciprocate coil between the interval 12,270' - 12,920 at 20 fpm while still jetting SBG. 9. After make 3 consecutive passes between the above interval, PUH to 12,200' and park CT. 10. Freeze protect back side with 60/40 methanol and allow SBG to soak for 1 hour. • Ensure to keep pumping hot SBG at 0.25 bpm (- 15 bbls) to prevent CT from freezing. • Also reciprocate CT at 12,200' at regularly to enure the coil is free while waiting. 11.After an hour, RBIH jetting SBG and make up /down passes between the interval 12,270' - 12,920' (or 20' above the final CT cleaned out depth) at 20 fpm. PUH to 12,200'. 4 Enct2 -06 FCO AFE #: AENCAPSU • 12. Shut down pump, RBIH and dry tag final achieved depth, record this in AWGRS summary. 13. PUH to 12,200' and swap to 1% Kcl + F103, jet 100 bbls to chase SBG out of the tubing. 14.Swap to 50:50 diesel /x lene mixture and 'et while makin• an u• /down sasses with in the interval 12,270' — 12,920'. 15. POH while pumping 1% Kcl + F103 at .25 bpm. 16.At surface, line up to pump down back side to displace the entire tubing with 500 bbls of 1% Kcl + F103 at, at least 5 bpm • Record injection rate in the AWGRS summary page. 17. Freeze protect tubing with 110 bbls of diesel and secure well. 18. RDMO CT. 19. Secure well and notify Pad Operator. Chemical Requirement Please plan to have at least these volumes of chemicals; • 1000 bbls 1% Kcl + 0.002% F103 • 290 bbls of 140 deg F Diesel ( Freeze protect) • 290 bbls of SBG (49 bbls of conc. SBG mixed in 241 bbls of 160F hot water) • 100 bbls of 50/50 Diesel/ Xylene 3.Slick Line: 1. MIRU Slick Line and SI. 2. RIH and Set 4 -1/2" SSSV 3. RDMO and notify operations to POI well. 5 • End2 -06 FCO • AFE #: AENCAPSU TREE= MCEVOY SAFETY NOTES: H2S READINGS AVERAGE 230 - 260 WELLHEAD E ND 2 -0 6 PPM ON AIL & GAS INJECTORS. WELL REQUIRES A ACTUATOR = AXE SON PPMI/, KB. ELEV = 56' I l BF. ELEV = 1504' J- 17 -5/8" X 7" XO, ID = 6.276 ", KOP= Max Angle = 50° @ 8100' I 1506' Fir RPB NIP, ID = 5.963" I Datum NO = 13090' • Datum TV D = 10000 SS 1510' —17" X 7 -5/8" XO, ID = 6.276" I 13 -3/8" CSG, 68#, L -80 BTRS, -I 2502' I-A ID = 12.415" 7 -5/8" LNR, 29.7# L -80 STL, — 5340' I / I 5340' I- f7 -5/8" X 5-1/2" XO, ID = 4.892" 1 .0459 bpf, b= 6.875" (TOP OF 7 -518" SCAB LNR J--) 5492' I I 5492' I- 9-5/8" X 7 -5/8" ZXP PKR w /FLEXLOCK HYD LNR HGR ID = 6.815" Minimum ID = 3.725" @ 12263' 4 -1/2" NSCT XN NIPPLE 5-1/2"113G, 16.7 #, L -80 STL, -I 12154' I ---- -1 I 12154' - I5 -1/2" X 4-1/2" X0, 10= 3.958" I .0232 bpf, ID = 4.892" ' ' I 12202' H 4 -1 /2" NSCT X NIP, ID = 3.813" I 12213' H7-5/8" X 4 -1/2" NSCT BXP BKR PKR, = 3.875" ' I 12237' H 4 -1 /2" NSCT X NIP, ID = 3.813" 1 t t I 12263' H4- 1 /2 " NSCT XN NP, D= 3.725" 1 14-1/2" TBG, 12.64, L -80, .0152 bpf, ID = 3.958" —I 12276' 1--/ , - I 12276' H 4 -1 /2" WLEG, 10= 3.958" I 17-5/8" LNR 29.7 #, L -80, .0445 bpf, ID = 6.765" I 12375' I 12267' H -I ELMD TT LOGGED ON 04/13/11 I 'TOP OF 7" LNR (—I 12403' 'TOP OF 7" LNR (04/13/11) 1--I 12376' ELMD 19 -5/8" CSG, 47 #, NT95HS, ID= 8.681" 1-1 12680' (--• , PERFORATION SUMMARY REF LOG: DLL -GR on 03/25/87 ANGLE AT TOP PERF: 39° @ 12724' Note: Refer to Production DB for historical pert data SIZE SPF K4TERVAL Opn /Sqz DATE 4 8 12724 - 12758 0 05/20/87 4 8 12768 - 12810 0 05/20/87 4 8 12816 -12860 0 05/20/87 F 4 4 12860 - 12900 0 07/26/92 1 14'1 PBTD (DIMS 05/21/01) I ' 13057' I ••••••••• • 7" LNR, 29#, SM-110 BTC, -j 13265' 14.4.1.4.4.4.4.4• .0371 bpf, m = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTTUNIT 12/12191 JLH RWO 06 /20/11 JM/JMD HEFT CORRECTIONS WELL: 2 -06 / J -22 06/03/01 JWS RWO 08/12/11 DW /JMD ADDED H2S SAFETY NOTE PERMIT No: '1870180 08/18/07 RCT /PJC RPB NFPLE (08 /04/07) API No: 50- 029 - 21699 -00 -00 11/18/10 JM/JMD CONVERT TO CANVAS (07/05/11) SEC 36, T12N, R16E, 1852' FNL & 2179' FEL 02/16/11 MBIJMD ADDED SSSV SAFETY NOTE' 06/03/11_ SRO/ PJC PERF/ ELMD TT LOGGED (4/16/11) _ BP Exploration (Alaska) 6 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 &MINED SEP S 4 LU2 May 22, 2012 01 �. Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, ,0 Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 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 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2-64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2- 70/U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIOO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ ° 187 -0180 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21699 -00 -00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 312828 2- 06/J -22 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT POOL 11. Present Well Condition Summary: F, Total Depth measured 13265 feet 0 1 None feet true vertical 10190.9 feet _ ? Junk (measured) None feet Effective Depth measured 13057 feet Packer (measured) 1506 5492 12213 feet true vertical 10030.38 feet (true vertical) 1504 4965 9393 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 30" 41 - 146 41 - 146 Surface 2462' 13 -3/8" 68# L -80 40 - 2502 40 - 2499 4930 2270 Production 12641' 9 -5/8" 47# NT95HS 39 - 12680 39 - 9742 8150 5080 Liner 6886' 7 -5/8" 29.7# L -80 5492 - 12378 4965 - 9513 6890 4790 Liner 862' 7 -5/8" 29# SM -110 12403 - 13265 9531 - 10191 11220 8510 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ - Tubing: (size, grade, measured and true vertical depth) 7 -5/8" 29.7# L -80 39 - 5340 39 - 4866 5 -1/2" 17# L -80 5340 - 12154 4866 - 9351 4 -1/2" 12.6# L -80 12154 - 12276 9351 - 9438 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" QOS SSV 1506 1504 7 -5/8" Baker ZXP To Packer 5492 4965 4 -1/2" NSCT BXP BKR PKR i= 9393 12. Stimulation or cement squeeze summary: RECEIVED EI Intervals treated (measured): r pR 2 5 Z011 Treatment descriptions including volumes used and final pressure: Alaska Gil & Gas Cans. commission 13. Representative Daily Average Pittlenfialiiinjection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 65,929 5,021 Subsequent to operation: 16,692 3,239 14. Attachments: 15. Well Class after work: ,- Copies of Logs and Surveys Run Exploratory Development ❑ Service o Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ El ' SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N me J Last j! i Title Petrotechnical Data Technologist Signat e ' MIND Phone 564-4091 Date 4/25/2011 Form 10 -404 Revised 10/2010 * 2 F 8DMS APR 2 6 7 p ` f ! Submit O ' inal Only 2- 06/J -22 187 -018 PERF ATTACHMENT Sw Name Operation Date Pell Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2- 06/J -22 5/20/87 PER 12,724. 12,758. 9,776.83 9,803.42 2- 06/J -22 5/20/87 PER 12,768. 12,810. 9,811.24 9,844.05 2- 06/J -22 5/20/87 PER 12,816. 12,860. 9,848.72 9,882.61 2- 06/J -22 4/23/92 RPF 12,724. 12,758. 9,776.83 9,803.42 2- 06/J -22 4/23/92 RPF 12,768. 12,810. 9,811.24 9,844.05 2- 06/J -22 4/23/92 RPF 12,816. 12,860. 9,848.72 9,882.61 2- 06/J -22 7/26/92 APF 12,860. 12,900. 9,882.61 9,912.91 2- 06/J -22 4/13/11 APF 12,860. 12,880. 9,882.61 9,897.82 2- 06/J -22 4/14/11 APF 12,840. 12,860. 9,867.28 9,882.61 2- 061J -22 4/15/11 APF 12,790. 12,810. 9,828.44 9,844.05 2- 06/J -22 4/15/11 APF 12,816. 12,840. 9,848.72 9,867.28 2- 06/J -22 4/16/11 APF 12,724. 12,738. 9,776.83 9,787.78 • 2- 06/J -22 4/16/11 APF 12,738. 12,758. 9,787.78 9,803.42 2- 06/J -22 4/16/11 APF 12,768. 12,790. 9,811.24 9,828.44 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • 13 -21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY rTiCrt 4/12/2011 ** *WELL SHUT -IN ON ARRIVAL * * *( ELINE - PERFORATING) INITIAL T /I /O = 3000/200/0 MIRU ELINE FOR PERFORATING ** *JOB IN PROGRESS, CONTINUED ON 13- APRIL - 2011 * ** l � 4/13/2011 ** *WELL SHUT -IN ON ARRIVAL * * *( ELINE - PERFORATING) INITIAL T /I /O = 3000/200/0 PERFORATIONS MADE WITH 2 -7/8" HSD POWER JET OMEGA, 6 SPF, 60 DEG PHASING API DATA FOR GUNS: PENETRATION = 36 ", ENTRANCE HOLE = 0.34" PERFORATED INTERVAL OF 12860'- 12880' PERFORATING DEPTHS REFERENCED TO SLB DLL -GR LOG DATED 25 MARCH 1987. ** *JOB IN PROGRESS, CONTINUED ON 14- APRIL - 2011 * ** 4/14/2011 ** *WELL SHUT -IN ON ARRIVAL * * *( ELINE - PERFORATING) INITIAL T /I /O = 3000/200/0 PERFORATIONS MADE WITH 2 -7/8" HSD POWER JET OMEGA, 6 SPF, 60 DEG PHASING API DATA FOR GUNS: PENETRATION = 36 ", ENTRANCE HOLE = .34" PERFORATED INTERVAL OF 12840'- 12860' PERFORATING DEPTHS REFERENCED TO SLB DLL -GR LOG DATED 25 MARCH 1987. ** *JOB IN PROGRESS, CONTINUED ON 15- APRIL - 2011 * ** 4/15/2011 ** *JOB CONTINUED FROM PREVIOUS DAY * * *( ELINE - PERFORATING) INITIAL T /I /O = 3000/200/0 PERFORATED INTERVAL OF 12816'- 12840' AND 12790'- 12810'. PERFORATIONS MADE WITH 2 -7/8" HSD POWER JET OMEGA, 6 SPF, 60 DEG PHASING API DATA FOR GUNS: PENETRATION = 36 ", ENTRANCE HOLE = .34" PERFORATING DEPTHS REFERENCED TO SLB DLL -GR LOG DATED 25 MARCH 1987. ** *JOB IN PROGRESS, CONTINUED ON 16- APRIL - 2011 * ** • • 4/1 6/2011 ** *JOB CONTINUED FROM PREVIOUS DAY * ** ELINE - PERFORATING - INITIAL T /I /O = 3000/200/0 PERFORATED INTERVAL OF 12768 -12790 PERFORATED INTERVAL OF 12738 -12758 PERFORATED INTERVAL OF 12724 -12738 PERFORATIONS MADE WITH 2 -7/8" HSD POWER JET OMEGA, 6 SPF, 60 DEG PHASING API DATA FOR GUNS: PENETRATION = 36 ", ENTRANCE HOLE = .34" PERFORATING DEPTHS REFERENCED TO SLB DLL -GR LOG DATED 25 MARCH 1987. ** *JOB IN PROGRESS, CONTINUED ON 17 - APRIL - 2011 * ** 4/17/2011 ***WELL S/I ON ARRIVAL * ** (post adperf) ATTEMPTED TO SET 4 -1/2" QOS (SER# LQOS -405, RQ lock, no nogo ring) IN 7" INSERT @ 1506' MD; WHILE JARRING TO SET VALVE, QOS FELL THRU INSERT. PULLED BACK OOH. SET 4 -12" QOS SSSV (SER #QOS -25, RQ lock with 3.84" nogo ring, balance op) IN 7" INSERT @ 1470' SLM (1506' MD). WELL TENDER WITNESSED CLOSURE TEST, PASSED. * ** JOB COMPLETE, WELL TENDER NOTIFIED * ** _ _ I 4/17/20 ** *JOB CONTINUED FROM PREVIOUS DAY ** *(ELINE - PERFORATING) PULLED OUT OF HOLE AND RIGGED DOWN. CLOSED OUT PERMIT WITH DSO AND MOVED OFF LOCATION. ** *JOB COMPLETE ** *(WELL TURNED OVER TO DSO) F S { FLUIDS PUMPED BBLS 5 DIESEL 8 METH 13 TOTAL TREE'= MCEV OY WELLHEAD = FMC JMD D RAF• E ND 2 _0 6 SAFETY : WELL REQUIRES A SSSV. ACTUATOR = AXELSON KB. ELEV = 56' 1 BF. ELEV = 1504' I - - 5/8" X 7" XO, ID = 6.276" I KOP= Max Angle = 50 @ 8100' —datum . 1 1506' 1 RPB NIP, ID = 5.963" Datum MD = 13090' Datum TV D = 10000 SS 1510' I-17" X 7 -5/8" XO, ID = 6.276 "' 13 -3/8" CSG, 68 #, L -80 BTRS, --1 2502' (--, ID = 12.415" 7 -5/8" LNR, 29.7# L -80 STL, — 5340' 5340' H7-5/8" X5-112"X0, ID = 4.892" I .0459 bpf, ID = 6.875" TOP OF 7 -5/8" SCAB LNR H 5492' 5492' 1 — 9 -5/8" X 7 -5/8" ZXP PKR w /FLEXLOCK HY D LNRHGR, ID= 6.815" Minimum ID = 3.725" @ 12263' 4 -1/2" NSCT XN NIPPLE 5 -1/2" TBG, 16.7 #, L -80 STL, — 12154' 1 12154' I- 15 -1l2" X 4 -1/2" XO, ID = 3.958" I .0232 bpf, ID = 4.892" 1 12202' I -{4-112" NSCT X NIP, ID = 3.813" 12213' H7 -5/8" X 4-1/2" NSCT BXP BKR PKR, ID = 3.875" I 12237' 1 NSCT X NIP, ID = 3.813" 1 12263' H4-1/2" NSCT XN NIP, ID = 3.725" I 4 1/2" TBG, 17 #, L -80 ? ? ?? H 12276' 12276' H 4 -1 /2" WLEG, ID = 3.958" I TOP OF 7" LNR H 12403' I9 -5/8" CSG, 47 #, NT95HS, ID = 8.681" I 12680' PERFORATION SUMMARY REF LOG: DLL -GR on 03/25/87 ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 12724 - 12758 12768 - 12810 12816 - 12860 12816 - 12860 1 PBTD (DIMS 05/21/01) I 13057' Lfffccfcf+ 7" LNR, 29 #, SM-110 BTC, —i 13265' .0371 bpf, ID= 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 12/12/91 JLH RWO WELL: 2 -06 / J -22 06/03/01 JWS RWO PERMIT No: ® 1870180 08/18/07 RCT /PJC RPB NIPPLE (08/04/07) API No: 50- 029 - 21699 -00 -00 11/18/10 ? /JMD FORMAT REVISION SEC 36, T12N, R16E, 1852' FNL & 2179' FEL 02/16/11 MB /JMD ADDED SSSV SAFETY NOT BP Exploration (Alaska) U Mr. Jack Lau Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~l0~$ Re: Endicott Field, Endicott Pool, 2-06/J-22 Sundry Number: 310-015 Dear Mr. Lau: ~,~~ J~Iv ~; 4 20~C Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Chair nd DATED this ZZday of January, 2010 Encl. ' STATE OF ALASKA y, o EG~IVED ' ALAS~IL AND GAS CONSERVATION COMMISSI~~~ APPLICATION FOR SUNDRY APPROVALS JAN ~ U 2a1d 20 AAC 2s.2so 0 ~~Mta dil A Rtifc f'.n.. f'mrrnieen., 1. Type of Request: Abandon^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ Chaq~.,Aply~ygd Progra Alter casing^ Plug Perforations ^ Perforate^ Pull Tubing^ Ti a Extension m Operation Shutdown ^ Re-enter Susp Well ^ Stimulate^ Alter Casing ^ 0 . Other: Solvent Wash 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 187-0180 _ 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21699-00-00 - 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: ^ ^ 2-06/J-22 _ Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-312828 - ENDICOTT Field / ENDICOTT Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13265 ~ 10190.9 13114 10074 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 105 30" surface 161 surface 161 Surface 2446 13-3/8" 68# I-80 surface 2502 surface 2498 4930 2270 Production 12624 -5/8" 47# nt80s xo nt95 surface 12680 surface 9740 6870 4760 Production 844 7" 29# sm-110 12403 13247 9475 10121 11220 8510 Liner 6886 7-5/8" 29.7# stl I-80 5492 12378 4965 9513 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7-5/8" 29.7# L-80 SURFACE 5340 - - 5-1/2" 16.7# L-80 5340 12154 - - 4-1/2" 17# L-80 12154 12275 Packers and SSSV Tvoe: 7-5/8" bkp pkr Packers and SSSV MD and TVD fftl: 12213 9393 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/26/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^~ - WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact .Jack Lau Printed Name ck Lau Title Wells Engineer Signature Phone Date ~~"'-"" 564-5102 1/20/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY / '" (/~~ Number: 3! ( witness Sund r t tiv ma f l tif i i th t C diti N C ry y approva : omm ss on so a a rep esen a e on ons o o y , Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: uired: ~ ~/ ~ YV Subse uent Form Re q q APPROVED BY / ~~ ~ D Approved by: COMMISSIONER THE COMMISSION Date: // ~$DMS X1,2 1010 Form 10-403 Revised 12/2009 ORIGINAL ~~ ~(/~ Submit in Duplicate 2-06/J-22 187-018 PFRF ATTA(`I-IMFNT Sw Name Operation Date PerF Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 2-06/J-22 5/20/87 PER 12,724. 12,758. 9,776.83 9,803.42 2-06/J-22 5/20/87 PER 12,768. 12,810. 9,811.24 9,844.05 2-06/J-22 5/20/87 PER 12,816. 12,860. 9,848.72 9,882.61 2-06/J-22 4/23/92 RPF 12,724. 12,758. 9,776.83 9,803.42 2-06/J-22 4/23/92 RPF 12,768. 12,810. 9,811.24 9,844.05 2-06/J-22 4/23/92 RPF 12,816. 12,860. 9,848.72 9,882.61 2-06/J-22 7/26/92 APF 12,860. 12,900. 9,882.61 9,912.91 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 ' ~~ No Accidents, I~~arm to People, and No damage td~e Environment To: Jerry Bixby/Clark Olsen Date: 1/20/2010 Well Operations Supervisors From: Jack Lau, Wells Engineer (w: 564-5102 c: 227-2760) Subject: END2-06 CT Solvent Wash AFE: ENR02WL06 Please perform a CT Solvent Wash on END2-06 per the below procedure. 1 C Solvent Wash. Contingent Mud Acid Treatment. Current Status: Online Operable Gas Injector Current Injection: 10/20/09: 72,936 MSCFD @ 4681 psi Max Inclination: 58.8° at 8100' Minimum ID: 3.725" through the 4~h" XN Nipple @ 12,263'MD. Last TD tag: 09/18/09: Tag TD @ 12911'MD w/ 3-3/8" DMY gun, TEL, S-Bailer (sample of Schmoo) Last Downhole Op: 09/19/09: Set SSSV BHP/BHT: 2A = 4199 psi (100% 2A gas injector) / 200°F Objective The objective of this well intervention procedure is as follows: 1) ACT solvent jetting wash will be performed in an attempt to remove tube oil and tree grease damage from the entire perforation interval. The objective is to restore injection rates to pre-Dec 2009 rates of 105 MMSCFD. 2) Pending post solvent wash injectivity test results a contingent mud acid program may be pumped. Well History END2-06 is 2A. zone 105 MMSCFD steady gas injector originally drilled and completed in 1987. In June-01 END2-06 was worked over and recompleted with 7-5/8" to 5'/2" to 4~h" tubing, leaving the 7" liner. On 14-Dec-08 the well suffered an injectivity reduction of around 25 MMSCFD after the plant lost a couple thousand gallons of seal oil (turbine 32) into the gas injection stream. END1-05 and END2-06 also suffered a loss in in injectivity due to the lube oil. Lube oil leakage into the gas injection system remains a problem, but estimated volumes have been reduced to roughly 250 gal/wk. The plan forward is to perform a CT diesel xylene solvent wash using a nozzle and reciprocation to agitate and remove the tube oil damage. During the CT rig up an injectivity test will be performed subsequent to the solvent treatment. If the injectivity END2-06 CT Solvent Treatment Page 1 of 9 ' No Accidents, N>~arm to People, and No damage tame Environment test deems no benefit from the solvent treatment then a contingency Mud acid job will be immediately pumped. A reperf is pending the success of this job and compressor seal replacement to prevent tube oil from contacting the interval. Jack Lau is the SPOC for this procedure; if you have any questions or concerns regarding this program, please contact Jack at 907.564.5102 (work), 907.227.2760 (cell) or if unavailable contact Brad Gathman at 907.242.2034 (cell). Stimulation Target : Open Perforations Zone MDT MDB Ht Status K2M/K2A/S2A3 12,724' 12,758' 34' Open K2A/S2A3 12,768' 12,810' 42' Open K2A/S2A3/S2A2/S2A1 12,816' 12,860' 44' Open S2A1 12,860' 12,900' 40' Open Design Details Total Footage 160' # of Perforations 960 Wellbore Volume 422 bbls (to top perf) Diesel/Xylene Solvent 80/20 Diesel/Xylene 100 al/ft of perfs = 380 bbls Frac Gradient 0.72 psi/ft Wellbore Volume to To Perf 422 bbls Diesel/X lene Desi n 100 al/ft Diesel/X lene Volume 380 bbls Frac Gradient 0.72 si/ft TVD To Perf De th 9777 ft 1~KCI Grad 0.434 Diesel rad 0.353 si/ft X lene rad 0.377 psi/ft BHP 4199 si BHTP 5199 HS si Diesel/X lene 3568.605 si END2-06 CT Solvent Treatment Page 2 of 9 No Accidents, Nllarm to People, and No damage tie Environment HS si 1 %KCI 4243.218 si Frac 7039.44 si Max Pum Pressure D/X -backside 3470.835 si Max Pum Pressure 1 %KCI -backside 2796.222 si Pre-Solvent Treatment • Solubility testing indicates the seal oil is soluble/miscible in diesel xylene. • Solubility testing indicates the Clare 501 and 601 tree grease is partially soluble in diesel xylene and completely soluble in neat methanol. 1. Order out fluid volumes required. Acquire Xylene from C-Pad as the alternative is very expensive. CT Solvent Wash • Filter all fluids that will enter the perforations to 3 microns absolute. • Do Not exceed maximum pump pressure of 4000-psi when sweeping gas out of the tubing and Do Not exceed WHP 3300 psi when the wellbore is liquid ap cked• • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Note when solvent stages hit the perfs and the response. • Ensure well is prepared to be returned to injection choked back to 3000-3300 psi immediately following the treatment. 2. MIRU CTU. 3. Pre-heat filtered fluid to 90°F. (Minimum temperature of 80°F). 4. Hold PJSM. • Ensure that current MSDS sheets are onsite and that safe .handling procedures are followed. END2-06 CT Solvent Treatment Page 3 of 9 No Accidents, N~arm to People, and No damage tale Environment END2-06 Solvent Treatment Schedule Stage # Stage Descri tion Fluid T e Fluid Vol bbl Fluid Rate b m Cum Fluid bbls 500 Max 1 Well Kill (backside) 3% NH4C1 (min) 500 2 Infectivity Test (CT) Diesel 30 Max 530 3 Methanol Wash (CT) Neat Meth 10 Max 540 4 Solvent Wash (CT) 80:20 Diesel:Xylene 380 Max 920 5 In'ectivit Test CT Diesel 30 Max 950 Total Fluid Volumes 3% NH4CI 500 min bbls Diesel 60 bbls Neat Meth 10 bbls 80:20 Diesel:X lene 380 bbls Total 450 bbls 5. Pumping down the backside (CTxTbg annulus) knock down WHP and sweep gas from wellbore with a minimum of 1.2 wellbore volumes of 3%NH4C1 + 0.2% surfactant F103 (1.2 wellbore volumes = 504 bbls). Pump at max rate while loading tubing and displacing gas from wellbore. Max pump pressure with wellbore fluid packed with KCI is 2700 psi. Higher pressures will be required to knock down WHP, do not exceed 3500 psi when sweeping gas out of the tubing. Freeze protect to 500'. 3% NH4C1 should be used to fluid pack wellbore to account for the Mud acid contingency. HF should not contact any water other than NH4C1 to prevent the formation of alkaline precipitates. 6. RIH w/ jetting nozzle and dry tag TD. 7. PUH to 12,700'MD (24' above top perfs). Perform a step rate injectivity test by pumping diesel down the CT per the following schedule. Monitor both CT and WHP pressures. Make note in WSR summary. a) Perform injectivity test by pumping 20 bbls of diesel at 1 bpm. Record both CT and WHP as these pressures will be used later in the program to determine the effectiveness of the solvent wash. b) Continue injectivity test by pumping 20 bbls of diesel at an increased rate of 2 bpm. Record both CT and WHP. 8. Reciprocate while jetting 10 bbls of neat methanol across the entire perforated interval (12,724 -12,900'). Do Not Exceed 3300 psi pumping pressure. Methanol is an aggressive solvent on Clare 501 and 601 tree grease found downhole. 9. Reciprocate while jetting 380 bbls of 80/20 diesel/xylene across the entire. perforated interval (12,724 -12,900'). Do Not Exceed 3300 psi pumping pressure. END2-06 CT Solvent Treatment Pale 4 of 9 No Accidents, N~arm to People, and No damage td~e Environment PERFORATING SUMMARY Ref. Log: DLL-GR (31287) GO 4" 14 12,724`-12,758` 12,768`-12,$10` 12,81 fi`-12,860` HLS 4" 4 12860` - 129x0' 10. PUH to 12,700'MD (24' above top perfs). Repeat injectivity test by pumping diesel down the CT per the following schedule. Monitor both CT and WHP pressures. Make note in WSR summary. a) Perform injectivity test by pumping 20 bbls of diesel at pressure (CT and WHP) recorded from step rate test in step 7a. This will allow comparison of rates at the same injection pressures pre and post solvent treatment. Record both CT and WHP. b) Continue injectivity test by pumping 20 bbls of diesel at pressure (CT and WHP recorded from step rate test in step 7b. Record both CT and WHP. 11. Review and compare injectivity test results from steps 7 and 10. Determine change in injectivity from step 7a to step 10a (same WHP and CT injection pressures) and from step 7b to step 10b (same CT and WHP injection pressures). If change is not transparent or very close to threshold call Jack Lau at 227-2760 to discuss way forward. a) If injectivity test indicates improved injectivity of >_10% then .POOH. Freeze Protect. RDMO CTU. b) If injectivity test indicates negligible or negative benefit to injectivity of <10% then move to step 12 mud acid contingency. CT Mud Ac~c~ Contingency • Filter all fluids that will enter the perforations to 3 microns absolute. • Do Not exceed maximum pump pressure of 4000 psi when sweeping gas out of the tubing and Do Not exceed 3300 psi when the wellbore is liquid packed. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results END2-06 CT Solvent Treatment Page 5 of 9 No Accidents, N~arm to People, and No damage tam Environment available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • Spent acid will be displaced into the formation. • Ensure HF only contacts NH4C1 or HCI. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to Jack.Lau@bp.com. END2-06 Mud Acid Schedule Fluid Fluid Cum Stage # Stage Fluid Vol Rate Fluid Descri tion T e bbl b m bbls 1 Conditioning (CT) 3% NH4CI 30 Max 30 2 Acid Pre-Flush (CT) 10% HCI 190 Max 220 3 Acid (CT) 6:1 Mud Acid 190 Max 410 4 Over Flush CT 3% NH4CI 360 Max 770 Total Fluid Volumes 10% HCI 190 bbls 6:1 Mud Acid 190 bbls 3% NH4CI 390 bbls Total 770 bbls Total Additives Volumes A261 Corrosion Inhibitor 0.6% 96 gal A153 Corrosion Inhibitor 8 254 Ibs A179 Corrosion Inhibitor 4 64 Ibs W54 Non Emulsifier 0.5% 80 gal W60 Anti-Sludge 0.5% 80 gal F103 Surfactant 0.2% 65 gal L58 Iron Stabilizer 20 319 Ibs U74 Dispersant 2% 120 gal J285 Ammonium Chloride 3% 4097 Ibs U67 Mutual Solvent 5% 819 al 6:1 Mud Acid A261 Corrosion Inhibitor 0.5% 40 gal A153 Corrosion Inhibitor 8 64 Ibs A179 Corrosion Inhibitor 4 32 Ibs W54 Non Emulsifier 0.5% 40 gal W60 Anti-Sludge 0.5% 40 gal F103 Surfactant 0.2% 16 gal L58 Iron Stabilizer 20 160 Ibs L041 Chelatin A ent 50 399 Ibs 10%HCI A261 Corrosion Inhibitor 0.5% 40 al END2-06 CT Solvent Treatment Page 6 of 9 No Accidents, Nl~arm to People, and No damage td~ Environment A153 Corrosion Inhibitor 8 64 Ibs A179 Corrosion Inhibitor 4 32 Ibs W54 Non Emulsifier 0.5% 40 gal W60 Anti-Sludge 0.5% 40 gal F103 Surfactant 0.2% 16 gal L041 Chelating Agent 50 399 Ibs L58 Iron Stabilizer 20 160 Ibs 3% NH4CI - Conditionin Over Flush/S aces F103 Surfactant 0.2% 33 gal J285 Ammonium Chloride 3% 4097 Ibs U67 Mutual Solvent 5% 819 al 12. Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling .procedures are followed. 13. Preheat filtered NH4C1 to 90°F. (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture 14. Mix/Circulate acid to ensure homogenous solution at pump time. 15. Reciprocate while jetting 190 bbls of HCI pre-flush across the entire perforated interval (12,724 -12,900'). Do Not Exceed 3300 psi pumping pressure. 16.Immediately following HCI pre-flush reciprocate while jetting 190 bbls of 6:1.5 HCI:HF mud acid across the entire perforated interval. 17. Reciprocate while jetting 360 bbls of NH4C1 over flush acid across the entire perforated interval. 18. PUH to 12,700'MD (24' above top perfs). Repeat infectivity test by pumping 30 bbls of diesel @ 2500 psi. Make note in WSR summary. 19. POOH. Freeze Protect. RDMO. 20.Turn POI guidelines over to Endicott Ops. RDMO. POI Procedure for Endicott Operations END2-06 CT Solvent Treatment Page 7 of 9 No Accidents, N>I~arm to People, and No damage tom Environment 21. Return well to gas injection at 3000-3300 psig. Continue injection at this pressure until the well stops taking gas. • Note that the well may not take any gas at this pressure and that the WHSIP* after the pumping will soon tend to the WHSIP* prior to the water wash treatment. The gas is the over flush fluid. 22. Bump up gas injection pressure approximately 500 psig and continue injection until well stops taking gas again. Continue to bump up gas injection pressure in 500 psig increments until it reaches 4000 psig and continue injection until well stops taking gas or slows dramatically. 23. Finally, bump gas injection pressure up to desired .gas injection operating pressure/rate • END2-12 has been operating at injection pressures of 4500 psig over the past few months and we'd like to target this injection pressure again ' Procedure Contacts: Jack Lau WK: 564-5102 Cell: 227-2760 END2-06 CT Solvent Treatment Brad Gathman WK: 564-5778 Cell: 242-2034 Pabe 8 of 9 ' ~ No Accidents, arm to People, and No damage t e Environment 13-3t8". $eAYtt. L-$U. Strs Cog 2502' T" i~ Nil~'L> {5.963" I.O.1 1,505° Tap of T-5i$' scab finer --~~ 5492" 9 518°, 47fllfl MT805 xfl to NT95HS 10,T48' T518° 49.7~1t[ STl L-~0 Flasaic Crated tubing Folbwing guldelir~s f~ iMel! YYrrk 4 pest b ros T8f' O~ 7" Lft~R 12.37'8` _.~..".,.*~ 9~5~".4T#1it, M'95H5, NSCG 14,$80' ..~..~. i~~t~ofsa-r~a~ suf,~af:,r ~~. ~: Du {3145iaT~ CO 4° 14 14,724'-12.758` 12,7$8`-12.$ i tT 14,81$=12.8$0 WLS 4' 4 128$Cr -14906' F'$YD 13.,1 i4' 7", 49~,Kt, SH1-i 10, 13,2$5' ...~.~,. X X X 8trs-fi1CG END2-06 CT Solvent Treatment -T~5t8" 49_T#14t STL 1110 7-~i!~` 5!'.tfi5.1'"c STL~{3 534' 5-172' 3TL to 4-112° t~iCS7 12,154" 4114° X`~ --~. ° 12,202° (3.$13 I.D.) 4-112`. 1 Ttllft L-BD, TAILf~IPi_ "`~.. A-ii4"'X' NIPFLl= 1223$° ~TIS(3.813' I.D.) `~.,,,, 4-112" °XN' I+iIF'P1,J 122:$3° ©Tls (3 T2S' f~.~ 4-117' Wt~G 12,2T5' Page 9 of 9 MEMORANDUM To: Jim Regg P.I. Supervisor I~~{./~ `~ ji6/(~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-06/]22 DUCK IS UNIT MPI 2-06/]22 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~_ Comm Well Name: DUCK IS UNIT MPI 2-06/]22 Insp Num: mitLG090612152606 Rel Insp Num: API Well Number: 50-029-21699-00-0o Permit Number: 187-018-0 ,, Inspector Name: Lou Grimaldi Inspection Date: 6/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2-06/]22 Type Inj. G 'j'am 9393 ~ IA 700 4000 4000 4000 P.T.D Is7olso TypeTest SPT Test psi aooo pA o 0 0 0 Interval aYIZTST P/F P Tubing asoo asoo asoo asoo Notes: 4.5 bbl's pumped, 4 returned. Pretest observed for thirty minutes "OK". Good 4 year test. Z~~ ~l, n -~f.~~- ~~ ssWe- ~~ Monday, June I5, 2009 Page 1 of 1 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor <J ( K~q q Ib( D~ DATE: Friday, September 16,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 2-061J22 DUCK IS UNIT MPI 2-061J22 FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .~ Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 2-06/122 API Well Number 50-029-21699-00-00 Inspector Name: John Spaulding Insp Num: mitlS050916064547 Permit Number: 187-018-0 Inspection Date: 9/13/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2-061J22 [Type Inj. I G I TVD i 9393 ! IA ¡ 1200 I 2420 2440 i 2440 P.T. 1870180 TypeTest ! SPT i Test psi i 2348.25 OA i 40 40 40 i 40 4YRTST P Tubing! 4075 4075 4075 , 4075 Interval PIF i Notes ~'ÇANNel C: ~ 2005 Friday, September 16, 2005 Page 1 of I STATE OF ALASKA ALASKA ,,..,.L AND GAS CONSERVATION COMM,,~3ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 56.00' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Duck Island Unit/Endicott P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1852' SNL, 2180' WEL, SEC. 36, T12N, R16E, UM 2-06/J-22 At top of productive interval R E C E I VE D 9. Permit Number/ Approval No. 187-018 / 1195' SNL, 4676' EWL, SEC. 31, T12N, R17E, UM 10. APl'~hr~§~r At effectivedepth JUN 2, 0 ~001 50-029-21699-00 1227' SNL, 74' EWL, SEC. 32, T12N, R17E, UM 11. Field and Pool At total depth Alaska Oil & Gas Cons. Commission Endicott Field / Endicott Pool 1243' SNL, 169' EWL, SEC. 32, T12N, R17E, UM Anchorage 12. Present well condition summary Total depth: measured 13265 feet Plugs (measured) true vertical 10190 feet Effective depth: measured 13114 feet Junk (measured) true vertical 10074 feet Casing Length Size Cemented MD TVD Structural Conductor 105' 30" Structural Drive Pipe 161' 161' Surface 2446' 13-3/8" 2700 cu. ft. Permafrost 2502' 2498' Intermediate Production 12624' 9-5/8" 575 cu. ft. Class 'G' 12680' 9740' Liner 844' 7" 357 cu. ft. Class 'G' 12403' - 13247' 9475' - 10121' Tieback Liner 6886' 7-5/8" 651 cu. ft. Class 'G' 5492' - 12378' 4965' - 9513' Perforation depth: measured 12724' - 12758'; 12768' - 12810'; 12816' - 12900' true vertical 9777' - 9803'; 9811' - 9844'; 9849' - 9883' Tubing (size, grade, and measured depth) 7-5/8", 29.7#, L-80 x 5-1/2", 16.7, L-80 x 4-1/2", 12.6#, L-80 to 12276' Packers and SSSV (type and measured depth) 7-5/8", BXP Baker Pkr at 12213', SSSV Otis Landing Nipple at 1506'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 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: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service Gas Injection 17. I hereby certify that the fore_cloing is true and correct to the best of my knowledge Si~lned Sondra ~itle Technical Assistant Date ~,~' i~'~'(~ I Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate : Repo , , Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: ~ ::: :~:~:: ::~ ~i: ~ti~i:~ :~'~: ::~'~:: : Description of Operations 413012001 18:00 - 00:00 6.00 RIGU P PRE Move rig from SDI 3-15/K-33 to MPI 2-06/J-22. Setting Herculite and rig mats. 51112001 00:00 - 01:30 1.50 RIGU N PRE Pull rig over well MPI-2-06/J-22. 01:30 - 02:30 1.00 RIGU N PRE A glycol line is in the area of the driller side foot on the backside of the wellhead house. The foot is shored up as much as possible to avoid contact with the glycol line. Endicott personnel were present to witness if the plan would work to avoid contact. It did and the leg was jacked down and secured. 02:30 - 04:00 1.50 RIGU N PRE Move pit complex in ne~ to rig. 04:00 - 08:00 4.00 RIGU N PRE Rig up rig for acceptance. Accepted at 08:00 5-1-2001 for operations. 08:00 - 10:00 2.00 BOPSUF N DECOMP RU Drillsite Maintanence and pull BPV. RD lubricator 10:00 - 10:30 0.50 BOPSUF N DEOOMP FMC installed ~C. 10:30 - 14:00 3.50 BOPSUF N DECOMP Test ~C w/1000 psi from top and attempt to test ~C from :below. Bleeding off in hole in casing. Nipple down tree. 14:00 - 15:00 1.00 BOPSU~ N DEOOMP PU 7" landing joint and make up on hanger. LD same. 15:00 - 00:00 9.00 BOPSUR N DECOMP Nipple up BOP's. 51212001 00:00 - 01:30 1.50 BOPSUR P DEOOMP Nipple up BOPE. 01:30 - 02:30 1.00 BOPSUR P DECOMP Change lower rams to 4 1/2 x 7" varibles. 02:30 - 03:00 0.50 BOPSUR P DEOOMP Rig up flow line. 03:00 - 04:00 1.00 BOPSUR P DECOMP Rig up to lower mud cross to be able to test lower rams with landing joint rather than with a test joint. 04:00 - 04:30 0.50 BOPSUR P DEOOMP Make up 7" landing joint. Rig up to hold pressure inside the joint to allow a full 5000 psi test on the landing joint.(26~ Collapse 5400 psi) Witnessing waived by AOGCC rep John Crisp. 04:30 - 11:00 6.50 BOPSUR P DEOOMP Rig up and test BOP's, Annular 250~3500 psi ok. Test lower rams. Won't test to 5000 psi. 11:00 - 13:00 2.00 BOPSUF P DEOOMP Change lower rams to 7" pipe rams. 13:00 - 16:30 3.50 BOPSUF P DEOOMP Finish testing BOPE. Rams, valves, chokes, etc 25015000 psi. 16:30 - 18:00 1.50 BOPSUF P DECOMP Rig up lubricator and pull ~C. Rig down same. 18:00 - 20:00 2.00 PULL ~P DECOMP Rig up and reverse circulate out Freeze protection from tubing through choke and gas buster. 20:00 - 00:00 4.00 PULL P DECOMP Rig up and circulate out Freeze protection from tubing through choke and gas buster. Pumped 900 bbl around to flush annulus. Recovered 75 bbl. diesel along with some gas. 51312001 00:00 - 01:00 1.00 PULL P DECOMP Circulate through choke and gas buster total of 900 bbl around to clear wellbore of diesel and gas. Recovered 75 bbl diesel. Blow down lines. 01:00 - 02:00 1.00 PULL P DEOOMP Make up spear on 2 joint of 5" DP. 02:00 - 08:00 6.00 PULL ~ DEOOMP Attempt to pull hanger from well head. Pull to 450k, work pipe with tugger, check Iockdowns, flush hanger at 10 bpm. No SUCCESS. 08:00 - 09:30 1.50 PULL = DECOMP Make up jarring assembly. Spear, jars, 2 DC, accelerator, handling sub. 09:30 - 11:30 2.00 PULL = DECOMP Jar in tubing hanger. Work way up to 110k over. Came free. Pull hanger to rig floor. 11:30 - 13:00 1.50 PULL = DECOMP Rig down spear and jars. Lay down tubing hanger and make up XO and pump in sub. 13:00 - 16:00 3.00 PULL = DECOMP Circulate. 50 spin, 200 psi, 100 spm 675 psi. No gas no oil. 16:00- 17:00 1.00 PULL = DECOMP ~Rig up laydown equipment. Including control line roller. 17:00 - 21:30 4.50 PULL = DECOMP Pull and lay down tubing to the SSSV(38 jts). Roll up control line. Recovered 21 of 23 bands. Drag ranging from 350 to Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: Description of Operations 5/3/2001 17:00 - 21:30 4.50 PULL P DECOMP 450K. Acts like metal on metal drag with no length patern Drag reduced to 50K from 300 to 350k at SSSV. Loosing approx 6 bph. 21:30 - 22:00 0.50 PULL P DECOMP Rig down control line roller. 22:00 - 00:00 2.00 PULL P DECOMP Pull and lay down 7" tubing. Changing out elevators at 80 its(3100' out). still 40k drag. Still loosing approx. 6 bph. 5/4/2001 00:00 - 00:30 0.50 PULL P DECOMP Change out elevators from 250 ton to 150 ton. 00:30 - 10:00 9.50 PULL i P DECOMP Continue laying down 7" tubing. Corrosion on external tube at 5000' and again below 8000'. Large hole at 8425' with some collapse of the tube. 10:00 - 11:30 1.50 PULL P DECOMP Rig down casing handling equipment. 11:30 - 14:00 2.50 BOPSUF.P DECOMP Install test plug and change lower rams to 3 1/2" x 6" variables. 14:00 - 15:00 1.00 BOPSUF.P DECOMP Safety meeting. Crews and supervisors. 15:00 - 16:30 1.50 BOPSUF P DECOMP Test rams to 250/5000 psi. Pull test plug and set wear ring. 16:30 - 19:00 2.50 PULL ~ DECOMP Rig up and pick up 8 1/2" swedge BHA. Bull nose, Swedge, 1-DC, Bumpersub, Jars, 10-DC, accelerators. 19:00 ~ 23:00 4.00 PULL ~ DECOMP Pick up 90 joints 5" DP. 23:00 - 00:00 1.00 PULL ~ DECOMP Slip and cut drilling line. 5/5/2001 00:00 - 00:30 0.50 PULL ~ DECOMP Serviced Rig 00:30 - 03:00 2.50 PULL ~ DECOMP RIH w/8-1/2" Swedge P/U 80 jts of 5" drill pipe. 03:00 - 07:00 4.00 PULL P DECOMP RIH w/8-1/2" Swedge on 5" drill pipe from derrick to 12,196'. No restrictions in 9-5~8" casing observed. String weight up 315,000#, String weight down 240,000#. 07:00 - 09:00 2.00 PULL P DECOMP Pumped and circulated around 100 bbl Hi-Vis sweep. Pump rate 465 gpm, SPP 1,000 psi. Reciprocated pipe while circulating. Observed a few pieces of scale over shakers. 09:00 - 16:00 7.00 PULL ;P DECOMP POOH from 12,196' to surface. No Excess drag. 16:00 - 17:30 1.50 PULL P DECOMP Broke out and L/D 8-1/2" Swedge BHA. 17:30 - 19:30 2.00 PULL P DECOMP Made up 8 1/8" Overshot BHA. 8-1/8" overshot w/5-1/2" grapple, Bumpersub, Jars, 11-DC, accelerators. 19:30 - 23:30 4.00 PULL ~ DECOMP Trip in hole with 5" DP from derrick. Lay down single on #124. PU 125. PU 330K, SO 230k. 23:30 - 00:00 0.50 PULL ~ DECOMP Circulate over fish. Shut off pump, Jar on fish. 5/6/2001 00:00 - 00:30 0.50 PULL 3 DECOMP Jarred on fish up to 450,000#. Jarred SBR free. 00:30 - 01:30 1.00 PULL ~ DECOMP Circulated Bottoms up. Pump rate 465 gpm, SPP 1,000 psi. No gas. 01:30 - 07:00 5.50' PULL P DECOMP POOH with Fish. 07:00 - 08:30 1.50 PULL P DECOMP Broke out and L / D Fish. Recovered 2.5' - 5-1/2" Chemically cut tubing stump, 5.40' 5-1/2" tubing pup jt., 15.00' SBR. 100% recovery. 08:30- 09:00 0.50 PULL P DECOMP Serviced Rig 09:00 - 10:30 1.50 PULL P DECOMP Made up 8 1/8" Overshot BHA. 8-1/8" overshot w/6-1/2" grapples, Bumpersub, Jars, 11-DC, accelerators. 10:30 - 15:30 5.00 PULL P DECOMP RIH w/8-1/8" overshot on 5" drill pipe. String weight up 315,000#, String weight down 230,000#. 15:30 - 16:30 1.00 PULL P DECOMP Slip and cut drilling line. 16:30 - 20:30 4.00 PULL P DECOMP Worked pipe. Cannot rotate due to hole drag. Mixed and pumped viscus sweep at 40 spm and 100 psi to try to slick up the hole. Unsuccesful, ordered out EP Mud Lub to add to mud. Circulated out sweep. 20:30 - 22:00 1.50 PULL 3 DECOMP Circulated at 100 spin 650 psi while adding EP Lube at 0.5%. Drag reduced to 300k up and 250k down. Torque down to 13,500 ft / lbs. Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: .... i:!:~::::~ :::~:r~:: ~i~i~ ~ id~ P~ ~ Description of Operations .... 5/6/2001 22:00 - o0:oo 2.00 PULL P DEOOMP Washed over fish with 30 spm and 100 psi. Located top at 12,212'. Shut off pumps. Set grapple with jarring to 315k 3 times. Pulled up to 317k and rotated in 34 rounds. K anchor not free. Tried several times with increasing tension up to 350k and tried to rotate the anchor out. Unsuccessful. Grappel rotating on the fish. Continued to work pipe on fish. 5/7/2001 00:00 - 01:30 1.50 PULL P DECOMP Jarred on Slick stick to seat grapple. Rotated on fish to release K anchor with 10,000# tension, K anchor came free. 01:30 - 03:30 2.00 PULL P DEGOMP Circulated Bottoms up. Pump rate 465 gpm, SPP 600 psi. 03:30 - 09:30 6.00 PULL P !DEGOMP POOH with K anchor in overshot from 12,200' to BHA. 09:30 - 10:30 1.00 PULL P ~DECOMP POOH with BHA. L/D accelerators. Recovered Fish - 15.00' Slick Stick and K anchor. 100% recovery. 10:30 - 11:30 1.00 PULL ~ DECOMP NORM'd Slick Stick - OK. L / D overshot with fish. Overshot to be sent to Baker shop to break out fish. 11:30 - 15:00 3.50 PULL ~ DECOMP R / U 9-5/8" pack off retrieving tool and RIH. Pull old 9-5/8" pack off. Run and set New 9-5/8" pack off. 15:00 - 15:30 0.50 PULL ~ DECOMP Run and set wear ring. 15:30-19:00 3.50 PULL ~ DECOMP Make up 4 3/4 mill, 1jtDP, 81/2" string mill, 3jts5"DP, Bumper sub, jars, 11 DC, Accelerator 19:00 - 23:30 4.50 PULL ~ DECOMP RIH with 5" DP. to 12208' 23:30 - 00:00 0.50 PULL ~ DECOMP Establish parameters. PU 300k, SO 250k, Rot 270k, Break circulation. 40 spm at 175 psi, 80 spm at 700 psi, 100 spm at 1000 psi. Tagged packer at 12231'. 5/8/2001 00:00 - 00:30 0.50 PULL P DECOMP Washed & Reamed from the top of the 9-5/8" packer at 12,231' to the top of the plug inside the 5-1/2" tail pipe at 12,253'. Pump rate 465 gpm, SPP 1,000 psi. 00:30 - 02:00 1.50 PULL P DECOMP Pumped and circulated around 100 bbls Hi-Vis sweep. Pump rate 465 gpm, SPP 1,000 psi. Observed some CaCO3 over shaker screens. 02:00 - 09:00 7.00 PULL P DECOMP Held PJSM. POOH from 12,253' to BHA. No excessive drag. 09:00 - 10:00 1.00 PULL ~ DECOMP Broke out and L / D 4-3/4" mill BHA. Cleared floor of small BHA tools. 10:00 - 10:30 0.50 PULL ~ DECOMP Held PJSM with Rig crew and Schlumberger crew 10:30 - 11:00 0.50 PULL ~ DECOMP Rigged up Schlumberger wireline sheaves and equipment. 11:00 - 13:00 2.00 PULL ~ DECOMP Ran in hole with USlT logging tool. Checked tool calibrations. 13:00 - 19:30 6.50 PULL ~ DECOMP Logged out with USIT casing inspection log. 19:30 - 20:30 1.00 PULL ~ DECOMP Rig down Schlumberger tools 20:30 - 00:00 3.50 PULL ~ DECOMP Pick up RTTS packer - make up same - RIH with RTTS 5/9/2001 :00:00 - 01:30 1.50 PULL DECOMP RIH to 8,005 with RTTS packer. 01:30 - 02:00 0.50 PULL DECOMP Break circ Hold PJSM on pressure test 9 5/8" casing. 02:00 - 03:00 1.00 PULL DECOMP Tested casing - pressured up to 3675 psi - 3750 psi. Broke over, pumping away, pumped 88 stks 6.2 bbls - stopped pump held for 10 mins, pressure dropped to 700 psi still falling - released pressure - bled back back 0.5 bbls. 03:00 - 04:00 1.00 PULL DECOMP Released RTTS - POOH 5 stands - retested at 7527' to 1,000 psi. Pumped 27 stks 1.61 bbls - pressure dropped back to 600 psi - 0 bbls back - released pressure - Changed to Pump #1 pressured up to 1,000 psi pumped 27 stks 2.9 bbls, shut in pump with 900 psi, pressure dropped to 500 psi - released pressure, bled back +/- 0.25 bbls. 04:00 - 04:30 0.50 PULL DECOMP Released RTTS - POOH 5 stands to 7,052' - retested to 1,000 psi with #2 pump - pumped 34 stks 2.4 bbls - pressure dropped to 450 psi, bled back Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 413012001 End: 5/24/2001 Contractor Name: DOYEN Rig Release: 5/24/2001 Rig Name: DOYEN 15 Rig Number: · ~a~i [ro'~ :~ ::H6~'~ ~i;i~'~od~' ~'~T P~ase . Description of Operations 5/9/2001 04:00 - 04:30 0.50 PULL DECOMP +/- 0.25 bbls back. 04:30 - 06:00 1.50 DECOMP Pull out hole 16 stands to 5628' 06:00 - 07:00 1.00 PULL N RREP DECOMP Rig Repair Low Drum Transmission Chain 07:00 - 07:30 0.50 PULL P DECOMP Rig Service 07:30 - 12:00 4.50 PULL P DECOMP Set Rtts packer at 5628' test to 4500 psi ok - RIH to 5817 test leaked off - POH to 5722' test leaked off - POH to 5628 test to 4500 psi hold for 30 rains recorded on chart ok 12:00 - 16:00 4.00 PULL P DECOMP TIH to 12,219' 16:00- 17:00 1.00 PULL P DECOMP Cut drlg line 17:00 - 23:00 6.00 PULL P DECOMP Displace brine with filtered brine 23:00 - 00:00 1.00 PULL P DECOMP Set RTTS at 12,222' test tail pipe to 2500 psi held for 30 mins ok 5/10/2001 00:00 - 00:30 0.50 PULL P DECOMP Blew down top drive. Ran in hole and tagged 9-5/8" packer at 12,231'. 00:30 - 01:30 1.00 PULL P DECOMP Held PJSM. Set RTTS packer at 12,222'. Tested RTTS packer to 2,500 psi. OK. 01:30 - 04:30 3.00 PULL P DECOMP Held PJSM. R ! U Schlumberger's sheaves, Lubricator and wireline equipment. 04:30 - 05:00 0.50 PULL P DECOMP Tested Schlumberger's lubricator to 4,000 psi. OK. 05:00 - 07:00 2.00 PULL P DECOMP RIH w/Schlumberger's tubing punch gun to 12,253'. 10' gun wi 4 SPF. Total length of gun 26.3' 07:00 - 08:00 1.00 PULL P DECOMP Held PJSM. Correlated and shot tubing punch gun from 12,252' to 12,242'. 08:00 - 10:00 2.00 PULL P DECOMP POOH wi wireline and gun. All shots fired. Attempted to pump into formation through tail pipe. Pressured up to 2,500 psi, no fluid movement. 10:00 - 13:00 3.00 PULL N DFAL DECOMP R / U second tubing punch gun. 5' gun w/4 SPF, Heavy Loads, Bow spring centrilizer. Total length of gun 24.8' 13:00 - 14:30 1.50 PULL N DFAL DECOMP RIH w/wireline and gun to 12,253'. 14:30 - 15:00 0.50 PULL N DFAL DECOMP Held PJSM. Correlated and shot tubing punch gun from 12,252' to 12,242'. Well on slight vacuum. 15:00 - 16:00 1.00 PULL N DFAL DECOMP POOH w/wireline and gun. All shots fired. 16:00 - 16:30 0.50 PULL P DECOMP Held PJSM. Rigged down Schlumberger lubricator and wireline equipment. 16:30 - 21:00 4.50 PULL P DECOMP Bullheaded 217 bbls brine in drill pipe and 75 bbl Hi-Vis pill into formation. Pump rate 1.2 BPM, SPP 2,000 psi. Pumped total 2900 stks 292 bbls finish pressure 2450 at 12spm. 21:00 - 21:30 0.50 PULL P DECOMP Monitor well 30 mins - well static 21:30 - 00:00 2.50 PULL P DECOMP PJSM on filtering while CBU - open bypass - CBU, filtering brine 5/11/2001 00:00 - 01:30 1.50 PULL P DECOMP CBU filtering - 3000 stks well perculating - shut down 01:30 - 02:30 1.00 PULL P DECOMP Monitor well - well perculating - no flow - highest LEL reading 27 with gas sniffer dropping back to zero. 02:30 - 11:30 9.00 PULL = DECOMP con't circ filtering - filtering unit plugging off with poylmer - well con't perculating no flow or gain - fluid drops @ 15' after shut down of pump - highest LEL reading 37 dropping to zero while circ. 11:30 - 12:00 0.50 PULL = DECOMP monitor well- well static- release RTTs packer 12:00 - 15:00 3.00 PULL ~ DECOMP Con't Circ and filtering 15:00 - 15:30 0.50 PULL ~ DECOMP monitor well - well static 15:30 - 23:30 8.001 PULL :' DECOMP PJSM tripping - pump out hole 10 stands - flow check ok - pull 15 stands - flow check ok - Con't poh - L/D Rtts packer - some Printed: 5/29/2001 1:35:07 PM , ,, Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 !Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYEN Rig Release: 5/24/2001 Rig Name: DOYEN 15 Rig Number: ::::~:~: ~i~ity : Description of Operations 5/11/2001 15:30 - 23:30 8.00 PULL P DECOMP pieces of rubber chewed up on packer - over all elements in very good condition. 23:30 - 00:00 0.50 PULL P DECOMP Pull wear ring - set test plug - Hold PJSM on testing BOP's 5/12/2001 00:00 - 04:30 4.50 PULL P DECOMP Tested BOP's - Annular 250 Iow 3500 high - Rams 250 Iow 5000 high - Choke manifold / HCR valves / manual kill / choke valves / floor TIW / IBOP / Upper / Lower IBOP 250 Iow 5000 high. All tests held with no leaks or pressure loss. 04:30 - 05:00 0.50 PULL P DECOMP Rigged down test equipment and test plug - Ran and Set wear ring - Held PJSM picking up milling assy. 05:00 - 07:00 2.00 PULL P DECOMP M / U Milling assembly - 8-1/2" Packer Mill, Sub, 3 - Junk Baskets, Sub, Bumper Sub, Jars, 11 - 6-1/4" DC, Accelerator. 07:00 - 12:00 5.00 PULL P DECOMP Ran in hole with Packer Milling BHA on 5" Drill Pipe. Tagged 9-5/8" packer at 12,231'. 12:00 - 12:30 0.50 PULL P DECOMP Checked parameters, prepared to mill packer. String weight up 300,000#, String weight down 250,000#. String weight Rotating 250,000#. Rotating Torque 13,000 fi/lbs. Latched onto packer, 2ulled 10,000# tension. 12:30 - 19:30 7.00 PULL P DECOMP Milled on packer. Pump rate 170 gpm, SPP 250, Weight on Mill 10,000# - 20,000#, RPM 100, Torque 15,000 fi/lbs - 20,000 fi/lbs. Pumping filtered Brine - packer dropped - pushed packer to 12375' taking weight attempt to push through - no go 19:30 - 21:00 1.50 PULL P DECOMP CBU 100 spm 1250 psi - gas perculating on bottoms up no flow no gain stop pump. Monitor well !21:00 - 00:00 3.00 PULL P DECOMP Circ filter brine 3.5 bbls per min 5/13/2001 00:00 - 02:00 2.00 PULL P DECOMP CIRCULATED FILTERED BRINE. PUMP RATE 420 GPM, SPP 1,250 PSI. 02:00 - 02:30 0.50 PULL P DECOMP MONITORED WELL - WELL STATIC 02:30 - 15:00 12.50 PULL P DECOMP HELD PJSM. POOH W/9 5/8" PRODUCTION PACKER AND TAIL PIPE. PULLING VERY SLOW, DUE TO PACKER SWABBING HOLE AT NORMAL TRIPPING SPEED. HOLE TAKING PROPER FILL. BROKE OUT AND L / D TAIL PIPE, MILL OUT EXTENSION, MILL, AND JUNK BASKETS. 15:00 - 17:30 2.50 PULL P DECOMP Pick up and make up clean out assy. 17:30 - 23:00 5.50 PULL P DECOMP Run in hole with clean out assy - break circ - con't rih to top of liner- taking weight at 12373' 10K - pick up slack off 12K fell through - pull up through spot no over pull - slack off taking 20K weight at 12373' fell through - con't rih to 12455' - no indication of liner top at 12403' 23:00 - 00:00 1.00 PULL P DECOMP CBU - filtering brine to below 100 NTU 5/14/2001 00:00 - 08:00 8.00 PULL P DECOMP CIRCULATED HOLE TO CLEAN AND FILTER COMPLETION FLUID. PUMP RATE 3 BPM, SPP 250 PSI. 08:00 - 08:30 0.50 PULL = DECOMP BLOW DOWN TOP DRIVE. CONFIRMED TOP OF 7" LINER AT 12,374'. 08:30 - 09:30 1.00 PULL = DECOMP SLIPPED AND CUT DRILLING LINE. 09:30- 10:00 0.50 PULL = DECOMP SERVICED RIG. 10:00 - 16:00 6.00 PULL = DECOMP POOH W/6" MILL AND CLEAN OUT BHA. 16:00 - 19:00 3.00 PULL ~ DECOMP PJSM - tripping - Lay down 11 6 1/4" dc's - break down I scraper, mill, jars, bumper sub - lay down clean out tools 19:00 - 00:00 5.00 PULL ~ DECOMP PJSM - tripping - pick up 3 jts 3 1/5" dp - make up Howco RBP - rih with bridge plug. 5/15/2001 00:00 - 01:00 1.00 PULL = DECOMP RIH with RBP taking weight on top pf liner 12374 work RBP through liner top - con't rih with bridge plug to 12448'. 01:00 - 01:30 0.50 PULL = DECOMP 2ump 300 stks at 30spm Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: ::::~:::: :::~o;: :;:;:;~:: !~i~ity ~ Description of Operations 511512001 01:30 - 02:00 0.50 PULL P DEOOMP pull up to 12430 set bridge plug and release off tool - pull up to 12400 02:00 - 03:00 1.00 PULL P DECOMP pour 15 sxs CaCO3 down drill pipe 03:00 - 04:30 1.50 PULL P DEOOMP chase CaCO3 with pump 30spm for 201 bbls 2000 stks - shut down pump let CaCO3 fall 04:30 - 11:30 7.00 PULL P DECOMP rih tag CaGe3 taking weight at 12415' - poh with RBP running tool - L/D running tool 11:30- 12:00 0.50 PULL P DECOMP Rig Service 12:00 - 16:30 4.50 PULL P DEOOMP PJSM Tripping - Make up 7" polish mill - RIH tag up at 12374' 16:30 - 17:30 1.00 PULL P DECOMP Polish liner top - CBU 17:30 - 22:30 5.00 PULL P DEOOMP POH with 7" polish mill 22:30 - 23:30 1.00 PULL P DEOOMP Cut drlg line 23:30 - 00:00 0.50 PULL P DEOOMP Con't poh with 7" polish mill 511612001 00:00 - 00:30 0.50 CASE P TIEB1 POH - lay down polish mill 00:30 - 01:30 1.00 CASE P TIEB1 !pull wear ring - set test plug - change top rams from 4 1/2" X 7" !variable to 7 518" casing rams - body test to 2500 psi against annular ok - pull test plug and set wear ring. 01:30 - 04:00 2.50 CASE P TIEB1 rig up casing tools to run 7 5/8" liner. 04:00 - 18:00 14.00' CASE P TIEB1 PJSM running casing - Ran 174 jts of 7 5/8" liner. 18:00 - 20:30 2.50 CASE P TIEB1 Change elevator bails - pick up 5" elevators - pick up packer, hanger make up same - Rig down remaining casing tools - move casing tools off rig floor - liner weight 190K SIC wt 180 P/U wt 220 20:30 - 21:30 1.00 CASE P TIEB1 Circ liner volume 320 bbls - at 6 bpm 21:30 - 00:00 2.50 CASE P TIEB1 Run liner in hole with 5" drill pipe at 1 to 1 1/2 rains per stand - rabbit each stand - filling every 5 stands 5/1712001 00:00 - 02:00 2.00 CASE P TIEB1 Continued running in hole with 7-518" liner on 5" drill pipe to 12300'. 02:00 - 03:30 1.50 CASE P TIEB1 Make up top drive into string. Broke circulation and pumped 2 bpm. Space out seal assembly. Attempted to sting into PBR on 7" liner. Sat down 10K- Picked up string weight to 350K. Slacked off 20K - no go- added 10K for a total of 30K - seal assembly fell into PBR. Shut down pump and slacked off with no pressure. Pressured up to 500 psi. Pressure bled off- seals not holding. Picked up out of PBR with overpull to 440K. Sting back into PBR with 20K to get in - pressure up to 500 psi - seals not holding. 03:30 - 04:30 1.00 CEMT P TIEB1 Make up cementing head - hose - overpull out of PBR to 440K. Ran back in hole to 12370' (5' above top of PBR). 04:30 - 07:00 2.50 CEMT ~ TIEB1 Break circulation and condition hole for cement job. Pumped 7 bpm at 1200 psi and began losing 24 bbl/hr. Slowed rate to 4 bpm at 400 psi without losses. 07:00 - 07:30 0.50 CEMT ~ TIEB1 Held PJSM on cementing and releasing from liner. 07:30 - 08:30 1.00 CEMT ~ TIEB1 Batch mixed 116 bbls (560 sxs) class G cement + .2% D046 antifoam + .3% D065 dispersant + .1% XE902 retarder + .35% uniFLAC. Cement was weighted to 15.8 ppg with a yield of 1.16. Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: Description of OPerations 5/17/2001 08:30 - 09:00 0.50 CEMT P TIEB1 Pumped 5 bbls of CWl00 chemical wash. Tested lines to 4000 psi. Pumped 15 bbls of CWl00 chemical wash. Pumped 116 bls of cement from blender at 5 bpm at 900 psi. 09:00 - 10:30 1.50 CEMT P TIEB1 Dropped drill pipe wiper dart and kicked out with 10 bbls of water. Displaced cment with rig pumps at 5 bpm at 200 psi. Observed dart latch into liner wiper plug. Continued displacing at 5 bpm at 200 psi. Observed good pressure increase as cement was pumped up backside. Pressure increased from 200 psi at 5 bpm to 1980 psi at 3.8 bpm. Bumped plug at 1017 hrs with 3882 strokes (97% efficiency). Lost 24 bbls during cement displacement. 10:30 - 11:00 0.50 CEMT P TIEB1 Released pressure and stung seals into PBR. Pressured up to 3000 psi to set slips (8 bbls to pressure up). Bled off pressure and slacked off full string weight. Pressure up to 4000 psi to shear liner hanger. Bled off pressure. Picked up and released setting dogs. Sat 70K down to set ZXP liner top packer. Pulled pack off out of liner hanger. 11:00 - 11:30 0.50 CEMT P TIEB1 Reverse circulated out from top of liner. Recovered trace of cement and CW 100 chemical wash. Reversed 2 drill pipe volumes. 11:30 - 14:30 3.00 CEMT ~ TIEB1 Pulled up to 12330'. Close annular and waited on cement. Dowell called when compressive strength of sample was at 250 psi. 14:30 - 17:30 3.00 CEMT ~ TIEB1 poh 57 stands - Service break liner running tool - LID liner :running tool 117:30 - 18:00 0.50 CASE ~ TIEB1 RIH 15 stands of 5" drill pipe 18:00 - 20:00 2.00 CASE P TIEB1 Lay down 5" drill pipe 20:00 - 21:30 1.50 CASE P TIEB1 Set test plug - change rams from 7 5/8" to 4 1/2" X 7" varaible - Body test 4 1/2" X 7" vaiable 250 Iow 2500 high - test 3 1/2" to 250 Iow 5000 high -pull test plug install wear ring 21:30 - 00:00 2.50 CASE P TIEB1 Run in 5" drill pipe 5300' 5/18/2001 00:00 - 05:00 5.00 CASE P TIEB1 Pulled out of hole laying down 5" drill pipe. 17:00 - 18:00 1.00 CASE P TIEB1 pick up 6.75 bit - bit sub with float - 6 4.75 dc's - 7100' 3 1/2" drill pipe - con't RIH with 5" drill pipe to 11,543' 17:00 - 18:00 1.00 CASE P TIEB1 make up top drive - break circ - wash from 11,543' to 12,158' tag firm cement 18:00 - 18:30 0.50 CASE P ~TIEB1 drlg cement from 12,158' to 12,210' 18:30 - 20:00 1.50 CASE TIEB1 circ bottoms up to test casing 20:00 - 21:00 1.00 CASE ~ TIEB1 pick up to 12,180'- rig up test - close top rams - test casing to 4500 psi held for 10 mins ok - blow down choke 21:00 - 22:00 1.00 CASE ~ TIEB1 drlg cement from 12,210' to 12,274' stalling out torque 15K ftlbs - work string attempt to work through - string stalling out at 12274' 22:00 - 23:00 1.00 CASE ~ TIEB1 CBU for trip out of hole - blow down top drive 23:00 - 00:00 1.00 CASE ~ TIEB1 POH 5/19/2001 00:00 - 04:00 4.00 CASE ~ TIEB1 Finished pulling out of hole with 6-3/4" bit. Stand count is Printed: 5/29/2001 1:35:07 PM Report Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYEN Rig Release: 5/24/2001 Rig Name: DOYEN 15 Rig Number: ~'a~'i:~.!i ~ ~'~ ~iiHo~ ~i~i~~ CO~ NPT P~Se . Description of Operations 5/19/2001 00:00- 04:00 4.00 CASE P TIED1 correct. 04:00 - 10:30 6.50 CASE P TIED1 PJSM on testing DOPE. Pulled wear ring and set test plug. Choke manifold was pressure tested to 250 psi Iow for 5 minutes / 5000 psi high for 10 minutes. Tested remainder of valves and all rams to 250 psi Iow for 5 minutes / 5000 psi high for 10 minutes. Annular was tested to 250 Iow for 5 minutes / 3500 psi high for 10 minutes. All test were recorded on chart recorder. Right to witness test was waived by AOGCC Inspector, John Crisp. 10:30 - 14:30 4.00 CASE P TIED1 Make up 6" bit - rih with dc's and 3 1/2" dp to 7,352' 14:30 - 15:30 1.00 CASE ~ TIED1 cut drlg line 15:30 - 16:00 0.50 CASE 3 TIED1 Rig service 16:00 - 17:30 1.50 CASE ~ TIED1 rih with 5" dp to 12,212' - make up top drive - break circ 17:30 - 18:00 0.50 CASE ~ TIED1 wash from 12212 to 12274' - taking weight 18:00 - 19:00 1.00 CASE ~ TIED1 Drlg from 12274' to 12,361' 19:00 - 22:30 3.50 CASE 3 TIED1 Drill F/C @ 12361' - con't drilling cement to 12,398' - lost bit weight wash to 12,410'- Drlg CaCO3 from 12410' to 12,415'- wash from 12,415' to 12,428' top of RBP - set down 25K 22:30 - 00:00 1.50 CASE 3 TIED1 CBU at 8 bpm circ bottoms up twice - clean up hole 5/20/2001 00:00 - 01:00 1.00 CASE = TIED1 Circ bottoms up twice clean hole - pump hi-vis sweeps - rotate / recip pipe while circ. Top of RBP 12,428'. 01:00 - 02:30 1.50 CASE ~ TIED1 PJSM testing casing - rig up to test casing - test casing to 4500 3si held for 30 mins on chart recorder - bleed off pressure - rig down test line - blow down choke manifold. 02:30 - 08:00 5.50 CASE P TIED1 POH and stood back drill collars and broke off bit. 08:00 - 11:00 3.00 CASE P TIED1 Made up RBP retreiving tool and ran in hole on 3-1/2" drill pipe to 7164' 11:00 - 13:30 2.50 RUNCO~ P COMP Changed over elevators and finished running in hole with 5" drill pipe to 12408' (RBP set at 12430'). from 7164' to 12,408' 13:30 - 16:30 3.00 CASE P TIED1 Circulated and conditioned hole while waiting on brine due to the Sag River Bridge weight restrictions due to wind speed - spin 90 2300 psi 16:30 - 18:00 1.50 CASE P TIED1 Displaced dirty 9.6 ppg brine with clean 9.6 ppb brine. Circulated until NTU of 75 coming out of hole - spm 100 2700 psi 18:00 - 20:00 2.00 CASE = TIED1 Latch on to RBP - work free - pull to 12308' 20:00 - 20:30 0.50 CASE ~ TIED1 Monitor well - well static 20:30 - 23:00 2.50 CASE = TIED1 Circ bottoms up - brine 75 NTU out - monitor well - well static 23:00 - 00:00 1.00 CASE ~ TIED1 POH with Howco RBP. 5/21/2001 00:00 - 04:30 4.50 CASE ~ TIED1 Pulled out of hole with HOWCO RBP. Left one packer rubber OD 5.75 -left internal mandral @ 2.50 lenght plus mule assy 2.94 in hole ID of mandral 1.90 ID - XO 2 3/8" pin X 2 7/8" pin OD 3.1 - XO 2 7~8" box X 3 1/2" IF pin OD 4.8- Mule shoe 3 1/2" box OD 4.75 with 3.60 OD stem below. (Mule shoe length 1.59 - XO .80 - XO .55) 04:30 - 05:00 0.50 CASE ~ TIED1 Service rig. Printed: 5/29/2001 1:35:07 PM Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYEN Ri9 Release: 5/24/2001 Ri9 Name: DOYEN 15 Rig Number: ~:! i~ ~"'~ ~i~i~"~ode N~T:: phas~ · Description of Operations 5/21/2001 04:30 - 05:00 0.50 CASE P TIEB1 05:00 - 10:30 5.50 CASE P TIEB1 Picked up 6" bit, bit sub with float and drill collars. Picked up 15 jts of 3-1/2" drill pipe and tripped in hole to 7,830'. Changed out elevators, slip dies and iron roughneck dies. 10:30 - 14:00 3.50 CASE P TIEB1 RIH with 5" drill pipe to 13,057' (157' below bottom perfs). Sat down 20K. Old PBTD 13,114' new PBTD 13057'. 14:00 - 14:30 0.50 CASE N DFAL TIEB1 Pulled out of hole to 12,430'. 14:30 - 15:00 0.50 CASE N DF^L TIEB1 Monitor well-negative. 15:00 - 17:00 2.00 CASE ~ TIEB1 CBU - monitor well - well static 17:00 - 20:30 3.50 CASE ~ TIEB1 POH laying down 5" 20:30 - 21:00 0.50 CASE ~ TIEB1 RIH last 8 stands of 5" 21:00 - 22:00 1.00 CASE ~ TIEB1 cut drlg line 22:00 - 22:30 0.50 CASE ~ TIEB1 Lay down 5" drill pipe 22:30 - 23:00 0.50 CASE ~ TIEB1 Change out 5" handling equipment for 3 1/2" equipment 23:00 - 00:00 1.00 CASE ~ TIEB1 Stand back 55 stands of 3 1/2" drill pipe 5/22/2001 00:00 - 00:30 0.50 CASE ~ TIEB1 Stand back 3 1/2" drill pipe 00:30 - 03:30 3.00 CASE ~ TIEB1 Lay down 3 1/2" drill pipe - 4 3/4" dc's 03:30 - 04:30 1.00 RUNCOI~P COMP Pull wear ring - install test plug - change top rams to 7 5/8" - body test to 250 Iow 2500 high 04:30 - 07:00 2.50 RUNCOI~!:) COMP Rig up completion running tools. 07:00 - 18:00 11.00 RUNCOI~P COMP PU and run 4 1/2" tail pipe assembly, 4 1/2" x 7" baker packer, 157 joints 5 1/2" tubing. 18:00 - 19:30 1.50 RUNCOAP COMP PJSM. Run rest of 5 1/2" tubing. Torque to 2800 ft lb. 19:30 - 21:00 1.50 RUNCOI~P COMP Change out running tools to 7 5/8" along with running crossover joint. Using 200 ton equipment. 21:00 - 00:00 3.00 RUNCO~ P COMP PJSM. Run 7 5/8" tubing. Torgue to 5300 ft lb. 5/23/2001 00:00 - 05:30 5.50 RUNCO~ P COMP Continued running 7-5/8" completion to SSSV nipple. 05:30 - 09:30 4.00 RUNCO~ I~1 MISC COMP Found wiper rubber stuck in top ram body cavity. Unable to retrieve wiper rubber from drill floor. Made up 7-5/8" x 5" crossover and ran 5" drill pipe in hole. Closed 3-1/2" x 6" YBR. Opened top ram door and removed wiper rubber. Closed door and pressure test ram door. Pulled out of hole and laid out 5" drill pipe and crossover. 09:30 - 10:30 1.00 RUNCOI~ COMP Rigged up casing tools and stainless steel control line spool. Installed control lines and test to 5000 psi. 10:30 - 15:30 5.00 RUNCOI~ COMP Finished running 7-5/8" tubing string with stainless steel control line. Installed 39 stainless steel bands on control lines. 15:30 - 16:30 1.00 RUNCOI~ COMP Rig down casing running tools. 16:30 - 18:00 1.50 RUNCOI~ COMP PU casing hanger on landing joint with TWC installed. Hook up control lines and test to 5000 psi. Land tubing hanger. Lay down Camco spools. 18:00 - 19:00 1.00 RUNCOI~ COMP PJSM. Run in lock down screws. Lay down landing joint. Fill stack to test. 19:00 - 19:30 0.50: RUNCOr~F' COMP Attempt to test hanger and TWC against blind rams. No 3ressure to circulate. Call DSM to pull TVVC. Printed: 5/29/2001 1:35:07 PM ...... Legal Well Name: 2-06/J-22 Common Well Name: 2-06/J-22 Spud Date: 2/25/1987 Event Name: WORKOVER Start: 4/30/2001 End: 5/24/2001 Contractor Name: DOYON Rig Release: 5/24/2001 Rig Name: DOYON 15 Rig Number: Description of Operations 5/23/2001 19:30 - 21:00 1.50 RUNCOI~I~I DFAL COMP Rigging down all floor equipment in preparation to move while waiting on DSM with Lubricator to pull TWC. 21:00 - 22:30 1.50 RUNCOI~I~I DFAL COMP Rig up DSM lubricator to pull TWC. Pull same. Lay down lubricator and dry rod in new TWC. 22:30 - 23:00 0.50 RUNCOItl:' COMP Fill stack with water. Pressure test TWC and hanger against blind rams to 1000 psi for 10 minutes. Good test, no leaks. 23:00 - 00:00 1.00 BOPSUR P COMP Nipple down surface BOP's after changing top rams from 7 5/8" to 4 1/2" x 7" varibles. 5/24/2001 00:00 - 05:00 5.00 BOPSUR P COMP Nippled down BOP stack. 05:00 - 09:30 4.50 WHSUR P COMP Nippled up tubing head adapter and tested void to 7000 psi. Attempted to test tree to 5000 psi. Leaking at flanges on crossover spool. Tighten flanges and attempted to retest with no success. 09:30 - 11:00 1.50 WHSUR N I SFAL COMP Split tree at tubing head adapter and change out BX-156 ring. 11:00 - 11:30 0.50 WHSUR P COMP Pressure tested tree to 5000 psi. Pressure bled off internally. No visible leak on tree. 11:30 - 12:30 1.00 WHSUR P COMP Rigged up DSM lubricator on tree and pulled TVVC. 12:30 - 13:30 1.00 WHSUR ~ COMP , PJSM - Rigged up lines and reversed corrision inhibitor into annulus at 3 bpm at 450 psi. 13:30 - 14:30 1.00 WHSUR 3 COMP Rigged up HB&R and pumped 90 bbls of diesel into annulus at 3 bpm. Final pumping pressure 1700 psi. Shut down pumps and shut in casing pressure 800 psi. 14:30 - 17:30 3.00 WHSUR ~ COMP Equalized freeze protection with tubing. Well freeze protected to 1500'. 17:30 - 21:30 4.00 WHSUR P COMP Dropped ball and rod. Rig up to set packer and test tubing. HB&R pressured tubing to 2500 psi, checked for leaks, none, Presure to 4500 psi for 30 minutes no leaks. 100 psi drop in 30 minutes. Bleed tubing to 1000 psi. Rig HB&R to casing. Pressure to 4500 psi for 30 minutes. Pressure fell 50 psi in 30 minutes. Tubing remained at 1000 psi. Bleed off tubing and annulus. Rig down. ^OGCC rep John Spaulding waived witnessing the pressure testing. 21:30 - 22:00 0.50 WHSUR P :COMP Install BP¥ using Drill Site Maintenance. 22:00 - 00:00 2.00 RIGD P COMP Secure well. Rig down to move. Clean pits and cellar. Release rig at midnight to move to MPI 1-47NM-20. Printed: 5/29/2001 1:35:07 PM MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~..12~iL?~, t DATE: June 18, 2001 Commissioner _ ^ _.,~7$UBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~.C~rll~=~,'-_.:.,\ BPX P.I. Supervisor MPI -,~'\~ ~ Duck Island Unit FROM: Jeff Jones Endicott Field Petroleum Inspector I · Packer Depth Pretest Initial 15 Min. 30 Min. ~ I "' w'",! ~~" ~1 Ty,l~?,inj:i,'' ~ i T.v.i~:...I q~' I'T'.uun; ! ,,,~o, i"~o I',~ i' ,~ I',"tefva!l"w I ! P'T'D'I !87,:018 ITypetestl P ITestpsil 23~8 l:C,.aSi.ngl ,7600 I .,,2575, I 2575 ,I,2575 I, P/F I P! .Noah,: pre-test pressures monitored for, 30, ,,min. & obsewed,to be,. ,sl2~ble.' ..... _w~l 2-22~_~, IT~pe~.j.I, N ,I T-V-b-,I ,,9~ I Tum'nol .' .0 ,, 1,,.25.50 I 25.ml 2520 II ,r~,all, 41 P..T.,~,! ~89:0,. 3~ ITypetes, tl. p .,IT~ps!I 235,~ I C.~n9I ,,,0 !.,~575 I 25~01 25501 P~F i. EI Notes: Well has known communication between casing & IA. . ."'wa"l .". ..... '.' 'IT~.'"J-I ' ..'.1 T..V.~. i ' I Tu~'m3't ..... I ..... I '1 ...... I,.t~v=,l .... I · P.T.D.I ' ' ITypet~l .... IT~P~I" ,,' i c=;i"9"l ,, ",' I'., ,. I' , I". I PA: I. I ,,,, We"! , P.T.D.! ! Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING ' IT,"'.J:i' ' IT.VJ:J.i I TL~bingI ....... i ' "I' I I,.te.v.,I ' "lfYpet~i ,",,, ITeStp~l ", I,casirm.I'. '.., 1,'.,',' I", , I, ! P~FI ' I' 'I','t ' ' I', ! ' !, ' ,' I .... I'., I,""i, '1 ..... ,'1" Type Test Interval M= Annulus Monitoring I= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test O= Other (describe in nOtes) Test's Details Mopday~ J~une !8, ,200[: I traveled to BPX's Duck Island Unit Main Production Island to witness MIT's on wells 2-06 and 2-22. Mark Sauve was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable and then the MIT's were performed with one failure witnessed. Well 2-22 hasa known communication between the tubing and the inner annulus and a tubing tail plug had been installedf°r the resL I noted that over the 30 minute test on well 2-22 the tubing and IA pressures equalized and tracked closely and did not stabilize. I monitored the pressures for an additional 30 minutes and the pressures continued decreasing, failing the MIT. Well 2-06 passed its MIT and is suitable for continued injection. SummarY: ! witnessed a successful MIT on well 2-06 and well 2-22 failed its MIT at BPX's DIU MPI Endicott. M.I.T.'s performed: 2 Number of Failures: 1_ Total Time during tests: 2.hm Attachments: _0 CC: MIT BPX DIU MPI 6-18-01 JJ.xis 7/25/01 STATE OF ALASKA ALASK~ ,alL AND GAS CONSERVATION COMrv,,,SSION APPLICATION FOR SUNDRY APPROVAL REVISED: 03/29/01 1. Type of Request: [] Abandon 2. Name of Operator . [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate BP Exploration (Alaska) Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface V' ,./ ~/' 1852' SNL, 2180' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1195' SNL, 4676' EWL, SEC. 31, T12N, R17E, UM At effective depth 1227' SNL, 74' EWL, SEC. 32, T12N, R17E, UM At total depth 1243' SNL, 169' EWL, SEC. 32, T12N, R17E, UM , 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56.00' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-06/J-22 9: ,permit Number ¥ 187-018 / 301-005 10. APl Number 50- 029-21699-00 11. Field and Pool Endicott Field / Endicott Pool 12. Casing Present well condition summary Total depth: measured true vertical Effective depth: measured 13114 feet Junk (measured) true vertical 10074 feet Length Size Cemented MD TVD Structural Conductor 105' 30" Structural Drive Pipe 161' 161' Surface 2446' 13-3/8" 2700 cu. ft. Permafrost 2502' 2498' Intermediate Production 12624' 9-5/8" 575 cu. ft. Class 'G' 12680' 9740' Liner 844' 7" 357 cu. ft. Class 'G' 12403' - 13247' 9475' - 10121' 13265 feet 10190 feet ''/' Plugs (measured) Perforation depth: measured 12724' - 12758'; 12768' - 12810'; 12816' - 12900' RECEIVED true vertical 9777' - 9803'; 9811'- 9844'; 9849'- 9883' MAR 0 2001 Tubing (size, grade, and measured depth) 7", 26#, NSCC tubing with 5-1/2" tailpipe to 12286'.A~aska 011 & (~ (';~n~:;. Cornr~issiorl Packers and SSSV (type and measured depth) 9-5/8" TIW Packer at 12238', SSSV Otis Landing Nipple at 1541'. 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation April 7, 2001 16. If proposal ~a_s verbally approv(td L~/I ~ '- O 1 Name o ap~p r~ove r~~~"( Date Approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Gas Injection Contact Engineer Name/Number: Jeff Hupp, 564-5344 Prepared By Name/Nurnbec Sondra Stewman, 564-4750 17. I hereby certify that th Signed Jeff Hupp and correct to the best of my knowledge Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative may witness _~O00 ~c,~\ ~:>r<~ Plug integrity BOP Test '~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- &pproved by order of the Commission Form 10-403 Rev. 06/15/88 I Approval No.,_~/. ~ ~/ Commissioner Date//'/~?~¢'~)] Submit In Triplicate BP lUJ&SIIA BIILLINI & WELLS Date: March 29, 2001 To.' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Tom Maunder - Petroleum Engineer Re: Endicott Well MPI 2-06/J-22 Revised Rig Workover Scope The 2-06/J-22 gas injector is planned as a rig workover to repair the 9-5/8" casing leak and replace the leaking 7" tubing. The procedure was revised to reflect repairing the 9- 5/8" casing leak along with replacing the leaking 7" injection completion with a 7-5/8" x 5-1/2" injection completion. The present and proposed completion diagrams of Endicott Well MPI 2-06/J-22 are attached. The original Sundry Notice (187-018) was approved on 01/17/01. Pre-Rig Summary for the MPI 2-06/,I-22 Rig Workover Operations Completed under AOGCC Sundry 187-018 approved 01/17/01. 1. Set plug in tail pipe at 12262' MD. */ 2. Perforated the 7" tubing at 12,175'md. 3. Circulated entire well to 9.6 ppg brine. (Based on freeze protecting to 1500' MD w/ 6.73 ppg diesel). 4. Chemically cut 5-1/2" tbg at 12,208'. 5. Attempted to test 9-5/8" casing to 3000 psi. Casing test failed. 6. Ran leak detect log and located 9-5/8" casing leak at 8600' MD +/-) 7. Freeze protected well to 1500' md. Proposed Additional Pre-Rig Operations 1. Bullhead 75 bbls 9.6 ppg mud down 9-5/8" x 7" annulus followed by 9.6 ppg brine to the casing leak at 8600' MD. 2. Set a BPV and clear and level pad in preparation of the rig move. 3. Remove 7-1/16" 10M tree and replace with 5M Valve. 4. Assure annuli are freeze protected to 1500'. RECEIVED MAR 2001 Alaska 0il & ~a~ Cons. Rig Workover Proce~ .e 1. MIRU. ND 5M tree, NU and test BOPE. 2. Circulate out freeze protect fluid and circulate well to clean 9.6 ppg brine. 3. Pull 7" tubing down to the tubing cut at 12208'. 4. PU 5" drill pipe and retrieve tbg stub and SBR barrel. 5. Perforate tail pipe assembly and pump 9.6 ppg viscous pill below production packer. 6. Mill and recover the 9-5/8" production packer at 12238'. 7. Run casing inspection log to identify 9-5/8" casing leak. 8. Run and cement 7-5/8" tieback to above 9-5/8" casing leak. 9. Run new 7-5/8" x 5-1/2" x 4-1/2" L80 completion 10. Freeze protect permafrost prior to setting the production packer. 11. Set BPV, ND BOPE, NU and test tree. RDMO. 2-06/J-22 well data Last test: Well shut in due to 7" tubing leak and 9-5/8" casing leak. Plug set in tbg tail. Latest H2S value: 60 ppm (Injection gas concentration) The Pre-rig operations are expected to start 4/7/01 and the rig workover operations are could start as early as 5/1/01. Jeff Hupp Senior Drilling Engineer cc: MPI 2-06/J-22 Well File RECEIVED MAR ,5 0 200~ 0il & rj,~.~ con~. Con~rnissio~.~ TREE: 6"/ 1~0 psi/ McEvoy/Axelson 'R.T. ELEV = 55.25' WELLHEAD: ~5/8" / 10,000 psi / FMC B.F. ELEV = 14.55" 8100' MD Well freeze protected f/1500' to surface ,, Well loaded with 9.6 ppg brine )i~i; }i; NSCC ~ 7" Tbg collap,,sed at 8425' MD ~:~ (PDS inspection log 1, 1/26/00) ~ Drifted to 4.5 9-5/8 casing leak @ 8600' MD -.~ ~ ~ (leak detect log 2/08/01 ) ~~--- ,- ,~?~u _ Tbg leak f/8662-8672 ~ ~ (LDL 11/21/01) 9-5/8", 47¢/ft (4. 562" I .D. ) L T' Nsec to 5-1/2" TC4S L __ ~~ ~ __ SLIDING SLEEVE OTIS "X A" 12,202' ~ ~ / TI~SBR b 12,218, ~ TIW (HBBP) (Big Bore) ~ ~~ TAILPIP E OTIS (4.562" I.D.) L (4.455" -- WEE G Ref, Log: DLL-GR (3/25/87) BAT E BY COB M ENTS [NDICOT[~EL~: 2~6/J-22 12/1N91 JLH WORKOVER COMPLETION APl NO. 50~29-21699 4/24/92 MDM RE-PE RF ~s~nt W~ ] bo~8 7/26/92 dE H ADD P ERF 03/29/01 JLH Present Diagram B~ EXPLORATION (ALASD), INC R.T. ELEV = 55~25' TREE: 6"/ I 0 B.F. ELEV = 14.55" WELLHEAD: /8 / 10,000 psi/ FMC MAX DEV. ---- 58-28, @ 8100' MD Hallibur[on 7" SSSV Nipple Q ~1 (5.962" ID) I 1,5oo' 13~3/8'', 68#/ft, L-80, Btr~ C~g X0 to 7~5/8" above & below 7-5/g", 2~.7~ kg0 IPC STk tb~ ~ > f/7800-sufiace % / Baker 7-5/8" x 9-5/8" Inr top pkr ~ 8000' ~ ~ Csg leak ~8600'+/- ~ ~ ' (LDL 2/8/01 ) 5-1/2",17¢L80 IPC STL Tbg ~ f/12200~7800' ~ ~ 7~5/8", 29.7¢ L80 STL : ~ Tieback f/12403-8000' 9-5/8", 47¢/ft ~8os xo to ~95HS ~ 9-5/8" X 7-5/8" annulus will be cemented < Baker 7-5/8" x 4-~/2' Packer ~2200~ ~ ~ 4-1/2" tbg tail assembly %5/8" x 7" Baker Tieback Stem ~ ~ TOP OF7" LINER [ ] ~~NG SUMMARY Ref~ Log: DLL-GR (3/25/87) CO. GUN SP INT~VAL GO 4" 14 12,724'-12,7G 8' 12,816'-12.860' HLS 4" 4 12860' - I 2900' ::~ ENDIOOT~ WEL~: 2~6/J-22 12/1 ~91 JLH WORKOVER COMPLETION -- APl NO. 50~29-21699 4/24/92 MDM RE-PERF ~[oDosed Completion Diagram 2/21/01 JLH Proeosed scL Inr comBletion BP EXPLORATION (ALAS~), INC BPX Endicott MPI 2-06/J-22 Rig Workover Post on Riq Floor Summary of Operations: 2-06/J-22 has a tubing restriction at 8425' (4.5" ID) and a tubing leak f/8662-72'. A leak detect log identified a 9-5/8" casing leak at 8600' MD +/-. The scope of work will cut and pull the existing 7" tubing string and retrieve the seal assembly from the present production packer. The 9-5/8" packer will be milled and recovered. A 7-5/8" tieback will be run above the 9-5/8" casing leak. A new 7-5/8" 29.7 ppf L80 x 5-1/2" 17 ppf L80 STL completion assembly will be run with a new 7-5/8" x 4-1/2" packer assembly. (See drawing for completion details). Well is presently shut-in with a plug in the tbg tail. Brine Program: · Workover fluid: 9.6 ppg ppg brine (Brine wt plus diesel cap) Disposal: · No annular injection on this well. · All used completion fluids and all other Class II wastes will go to Grind & Inject. Tubing Program: · The gas injection well will be recompleted with 7-5/8" 29.7 ppf L80 and 5-1/2" 17 ppf L80 STL IPC tubing Well Control: · BOP diagram (Doyon 15 13-5/8" 5M stack on file) · Pipe rams, blind rams tested to 300 psi and to 5000 psi. · The annular preventer will be tested to 300 psi and 3500 psi. Hazards Latest H2S value: 60 ppm (Injection gas concentration) Surface Offset well H2S readings o MPI 2-04:87 ppm (12/3/00) o MPI 2-02: NA (Cretaceous Injection well) o MPI 2-08:95 ppm (11/08/00) o MPI 2-12:60 ppm (Injection gas concentration) Reservoir Pressure Res. press, is estimated to be 4500 psi at 9725' TVD (8.9 ppg). Max. surface pressure with gas (0.10 psi/ft) to surface is 3528 psi. RECEIVED MAR 30 2001 Alaska 0ii & G.~',', C~ns. C0[lllilissi0~ ST~,TE OF ALASKA --' ALASKA OIL AND GAS. CONSERVATION COMM,,.,SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface ,~/ 1852' SNL, 2180' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1195' SNL, 4676' EWL, SEC. 31, T12N, R17E, UM At effective depth 1227' SNL, 74' EWL, SEC. 32, T12N, R17E, UM At total depth 1243' SNL, 169' EWL, SEC. 32, T12N, R17E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED JAN .1. 0 2001 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum Elevation (DF or KB) KBE = 56.00' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-06/J-22 9. Permit Nu,,m,I;~r 187-018" 10. APl Number 50- 029-21699-00 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13265 feet Plugs (measured) 10190 feet ''/ 13114 feet Junk (measured) 10074 feet Length Size Cemented 105' 30" Structural Drive Pipe 2446' 13-3/8" 2700 cu. ft. Permafrost 12624' 9-5/8" 575 cu. ft. Class 'G' 844' 7" 357 cu. ft. Class 'G' MD TVD 161' 161' 2502' 2498' 12680' 9740' 12403'-13247' 9475'-10121' Perforation depth: measured 12724' - 12758'; 12768' - 12810'; 12816' - 12900' true vertical 9777'-9803';9811'-9844';9849'-9883' Tubing (size, grade, and measured depth) 7", 26#, NSCC tubing with 5-1/2" tailpipe to 12286'. Packers and SSSV (type and measured depth) 9-5/8" TIW Packer at 12238', SSSV Otis Landing Nipple at 1541'. 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation January 20, 2001 [] Detailed Operations Program [] BOP Sketch 16. If proposal was verbally approved 115. I Name of approver Date Approved Contact Engineer Name/Number: Jeff Hupp, 564-5344 Prepared By Name/Number: Sondra Stewman, 564-4750 Status of well classifications as: [] Oil [] Gas [] Suspended Service Gas Injection 17. I hereby certify that is true and correct to the best of my knowledge Signed Jeff Hupp Title Senior Drilling Engineer Conditions of Approval: Notify Commission so representative may,~vitness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test ,~. Subsequent form required 10- [~'~ ORIGINAL SIGNED BY Approved by order of the Commission ,~ T-,,,,~,,S~h-r~.-lt('"'~ ~ ~ I J~ ! Form 10-403 Rev. 06/15/88 ..... ~ .... U'r~'l ~il~ ~-~ L I Approval No. ~ L - ©O %~ Commissioner Date Submit In 71'ril~li~:~te ~ BP ALASKA DRILIJNG & WELLS Date: January 10, 2001 To' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re.' Endicott Well MPI 2-06/J-22 Rig Workover Scope The 2-06/J-22 gas injector is planned as a rig workover to replace the leaking 7" tubing. The following summarizes the procedure required to replace the 7" tubing. A schematic diagram of this proposed completion is attached. Pre-Rig Summary for the MPI 2-06/J-22 Rig Workover 1. Test 9-5/8" casing to 4500 psi. 2. Test the 9 5/8" mandrel packoff. 3. Perforate the 7" tubing at 12,175'md. 4. Circulate entire well to 9.6 ppg brine. (Based on freeze protecting to 1500' MD w/ 6.73 ppg diesel). Presently the annular packer fluid is inhibited 9.9 ppg brine. 5. Chemically cut 5-1/2" tbg at 12,208'. 6. Set a BPV and clear and level pad in preparation of the rig move. 7. Assure annuli are freeze protected. Rig Workover Procedure 1. MIRU. ND tree, NU and test BOPE. 2. Circulate out freeze protect fluid and circulate well to clean 9.6 ppg brine. 3. Pull 7" tubing down to the tubing cut at 12208' 4. PU 5" drill pipe and retrieve tbg stub and SBR barrel. L/D drill pipe. 5. Run new 7" L80 completion including SBR w/o seals w/ a new 9-5/8" x 5-1/2" packer. 6. Freeze protect permafrost prior to setting the production packer. 7. Set BPV, ND BOPE, NU and test tree. RDMO. 2-06/J-22 well data Last test: Well shut in due to tubing leak. Plug set in tbg tail. Latest H2S value: 60 ppm (Injection gas concentration) The Pre-rig operations are expected to start 1/20/01 and the rig workover operations are planned to start 3/15/01. Senior Drilling Engineer cc: MPI 2-06/J-22 Well File Alaska Oil & Gas Cons. Commission Anchorage R:'T?ELEV = 55.25~ MAX DEV. = 58°28' @ 81 00' MD TREE: 6" / psi / McEvoy/Axelson / 10,000 psi / FMC SSSV LANDING NIPPL OTIS (5.962' LD.) l 13-3/8% 68#/ft, L-80, Btrs Csg 9-5/8", 4 7#/ft NTGOS XO to NT95HS TOP OF7" LINER PBTD I 13,114, 7",Btrs_TKC2 9#/ft, SM-110, DATE I BY I COMMENTS 12/12/91 JEll WORKOVER COMPLETION 7/28/92 JLH ADD PERF NSCC CROSSOVER, [ 12,194' 7" NSCO to 5-1/2" TO4S SLIDING SLEEVE (4.562" I.D.) TIW SBR [ 12,218' (12' Long W/ 8 Sets Seals) 9-5/8" PACKER __ TIW (HBBP) (Big Bore) 12,238' 5-1/2", I 7#/ft L-80, TAI LP IP E 5-112" 'X' NIPPLE 12,262' OTIS (4.562" I.D,) 5-1/2" 'XN' NIPPLE r OTIS (4.455" I.D.) [ 12,274' WbE G _ENDICOTT WEL_L: 2-0§/J-22 APl NO, 50-029-21699 _.~ (~M P LETION DIAGRAM BP EXPLORATI O N (ALAS[,,(A) ;I NC Q TREE: 6" / psi / McEvoy/Axelson R.T..E LEV 55.25' WELLHEAD: ~/8" / 10,000 psi / FMC B.F. ELEV = 14.55" MAX DEV. = 58028, @ 8100' MD SSSV LANDI,NG NIPPL O ~1 OTIS (5.962 I.D.) I 1,50 13%3/8", 68#Pt, L-80, Btrs Csg ~ 7", 26¢/ft, L-80 NSOC TO SURFACE 9-5/8", 4 7¢/ft NT80S XO to ~95HS CROSSOVER, [ 10,748' ] ~ ~ 7" NSOCt° 5-1/2" NSOCI 12'180' 9-5/8" x 5-1/2"PACKER r X ~ I ~ OTIS (4.562" I.D.) 12,208' [ ~/ TIWSBR (w/o Seals) I 12,218, 9-5/8" PACKER ~ ~ TIW(HBBP)(Big Bore) ~ 12,238' TAILPIPE OTIS (4.562" I.D.) 12,262' ~ ~% 5-1/2" 'XN' NIPPLE TOP OFT" LINER OTIS (4.455" 12,274' -- WLE G 9-5/8", 47¢/ft. NT95HS, NSCC Ref. Log: DLL-GR 0/25/87) CO, GUN PF INTERVAL PBTD [ 13.114' ] Btr~TKC DAm E BY eOM M ENTS ~NDICOTT WE~[: 2~6/J-22 12/12/91 JLH WORKOVER COMPLETION AP~ NO. 50~29-21 4/24/92 MDM RE-PE RF ~OM ~[ETION DIAGRAM 7/26/92 JLH ADD PERF 122/03/00 JLH PROPOSED WORKOVER BP EXPLORATION (ALAS~), lNG BPX Endicott MPI 2-061J-22 Rig Workover Post on Ri_~ Floor Summary of Operations: 2-06/J-22 has a tubing restriction at 8425' (4.5" ID) and a tubing leak f/8662-72'. The scope of work will cut and pull the existing 7" tubing string and retrieve the seal assembly from the present production packer. A new 7" 26 ppf NSCC tubing string will be run with a stacker packer assembly (See drawing for completion details). Well is presently shut-in with a plug in the tbg tail. Brine Program: · Workover fluid: 9.6 ppg ppg brine (Brine wt plus diesel cap) Disposal: · No annular injection on this well. · All used completion fluids and all other Class II wastes will go to Grind & Inject. Tubing Program: · The gas injection well will be recompleted with 7" 26 ppf L80 NSCC tubing Well Control: · BOP diagram (Doyon 15 13-5/8" 5M stack on file) · Pipe rams, blind rams tested to 300 psi and to 5000 psi. · The annular preventor will be tested to 300 psi and 3500 psi. Hazards Latest H2S value: 60 ppm (Injection gas concentration) Surface Offset well H2S readings o MPI 2-04:87 ppm (12/3/00) o MPI 2-02: NA (Cretaceous Injection well) o MPI 2-08:95 ppm (11/08/00) o MPI 2-12:60 ppm (Injection gas concentration) Reservoir Pressure Res. press, is estimated to be 4500 psi at 9725' TVD (8.9 ppg). Max. surface pressure with gas (0.10 psi/fi) to surface is 3528 psi. STATE OF ALASKA AI_~'~''~ OIL AND GAS CONSERVATION COMMIS N REPORT bF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate~ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not required) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" '3 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9~0' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#Irt IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 7" SSSV at 1541' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 113561 114969 Tubing Pressure 15. Attachments MIT 8/16/00 Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas__ Suspended Service ~.~ In.i~.~.tnr 17. I hereby certify that the for~e_~oing is true and correct t?, the best of my knowledge. Signed !* ~' ''), ~ k~L_~L£~ Title Senior Technical Assistant IV [564-$234l Date 8/7/00 Form 10-404 Rev 06/1~5~/~8 SUBMIT IN DUPLICATF_% ~ BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 8-16-00 WELL N°-: 2-06 / J-22 TYPE OF OPERATION: MIT BP EXPLORATION REP: LAWSON SERVICE COMPANY: APC DATE/TIME OPERATIONS SUMMARY 1600 SAFETY MEETING 1605 I PRESSURE TEST LINE FLOW RATE: 4200 IA: 750 OA: 0 1610 START PUMPING DIESEL DOWN IA. 1620 PUMPED 6 BBLS OF DIESEL. PRESSURE UP TO 2500. WATCH FOR 30 MIN.. ~=i GOOD TEST WITH STATE WITNESS. RD. BLEED DOWN IA TO 300 psi. I IA: 300 OA: 0 SUMMARY: MIT IA WITH STATE WITNESS. GOOD TEST. RD. SSSV: IN MEMORANDUM state of Alaska AlaSka Oil and Gas Conservation Commission TO: Dan Seamount Chairman THRU: Blair W°ndzell P.I. Supervisor FROM: John Spaulding . ,~ DATE: August 16, 2000 SUBJECT: Mechanical Integrity Tests BPX MPI 2-34/P-14, 2-06/J-22 DIU Petroleum InspectOr Endicott NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellJ 2-06/J-22 J Typelnj. J S I"T.V.D. I 9354 JTubingJ 4200J 4200J 4200J 4200 J lntervalJ V P.T.D.J 187-018 JTypetestJ O JTestpsiJ 2339 J-CasingJ 750 J 2~50J 2550J 255oj P/F I P Notes: We,,J2-34/P-14JType,nj.! s J T.V.D;I~ J TubingJ 1950 J 1950 J 1950 J 1950 JlntervaiJ' V P.T.D.J 198-119 JTyPetestJ P JTestpsiJ 2280 JCasingJ 2OOOI 2600 I 26001 25501 P/F I P Notes: We,,J5-01/SD-07JType,nj.J G J"T.V.D.I ~ I~u~i'~l ~oo I~oo I~oo I ~oo J,ntervalJ V P.T.D.J 180-120 JTypet~'stJ P JTestpsiJ 2236 jCasingJ 1550J 2450J 2370J 2370J P/F "J P,' Notes: we,,J J Type,,~. I I" ~'~'~' I I ~u~,n~ I I I I' J,nte~va,J P.T.D.J JTypetestJ JTestpsiJ J CasingJ J I I I P/F I 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 Testing went quite well, all wells were found to be in compliance. The lack of activity over the last 18 months has definetly had an impact on the "shine" that this field has had in the past. Type the test details in here. Expand or cotract the row height as needed. The sheet is protected so you will need to unprotea first, there is no password. .I.T.'s performed: 2_ Number of Failures: 0 Total Time during tests: 5_ Attachments: cc: MIT report form 5/12/00 L.G. mit diu mpi 8-16-00js.xls 9/7/00 MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE Of ALASKA ALA,q~ Oil AND GAS CONSERVAT[ON 0OMMISS!QN REPORT t..: SUNDRY WELL OP . IATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Ex/~loration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number /87-18 (not reouired) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total .depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 105' 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Size Cemented Measured depth BKB 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. fi. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9740' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 13. Stimulation or cement squeeze summary 7" SSSV at 1541'MD 14. Intervals treated (measured) 0 R I( INA L 000 Treatment description including volumes used and final pressure Alaska 0ii & Gas Coos. Commis$ior,, Representative Daily Average Production or Injection Data"~l~r~lrd~]~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 113561 0 Subsequent to operation 114969 0 15. Attachments MIT 3-21-00 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations × Oil__ Gas__ Suspended .__ Service _(~s In/~.~.tnr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · · ( ~ Signed \~0~.¥'~?~%-~ I'"~L'~(~',~(-D~(~J~--~,---, Title~eni,~rTechnir.~l,.~.~i_~tentlVl~;6,~.~;2:~,~) Date 4/19/00 Form 10-404 Rev 06/li15~8 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department MIT with AOGCC Witness DATE: 3-21-00 WELL N-°: 2-06/J-22 BP EXPLORATION REP: Sauve SERVICE COMPANY: HB&R DATE/TIME OPERATIONS SUMMARY WHP= 4650 IA = 1000 OA = 0 1400 MIRU TO IA PT HARDLINE TO 3000 PSI. START PUMPING 60/40 MEOH 3 BBLS AWAY. lAP= 2700 PSI. START TEST. GAUGE IS BUILDING PRESSURE. TEST IS GOOD. BLEED BACK IA TO 1000 PSI RDMO. WHP=4650 IA=1000 OA=0 Summary: MIT with the state AOGCC witness (Lou Grimaldi) Pump Summary: 3 60/40 moth. RECEIVED [.PR 1 9 2000 Ataska 0ii & Gas Co~s~ co~-n~nission Anchorage STATE OF ALASKA ALA,~-~-A OIL AND GAS CONSERVATION COMMIS°-~N REPORT L..-' SUNDRY WELL OP._RATIONS 1. Operations performed: Operation shUtdown __ Stimulate__ Plugging__ Pull tubing __ Alter caSing Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_c/e, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R 17E 5. Type of Well: Development __ Exploratory Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not reauired) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 105' 30" Drive Pil~e 2446" 12624' 13 3/8" 2700 cu. ft. Permafrost 9 5/8" 575 cu. ft. Class "G" 844' 7" 357 cu. ft. Class "G" measured 12724'- 12758', 12768'- 12810', 12816'- 12900' Measured depth BKB 161' True vertical depth BKB 161' 2502' 2498' 12680' 9740' 12403'- 13247' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7"26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 9475'- 10121' klask~. 0il -& Gas O0i;s. 7" SSSV at l~b~ 13. Stimulation or cement squeeze summary~8-30-9 '9.~ Intervals treated (measured) Treatment description including volumes used and final pressure 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 99015 95971 4363 4382 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service ~s In/~.c.f_~r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~('-~ t'~-,~%¢ . " Title ~eni~r Techni~, A,~i,t, nt IV/¢¢a-~2~l Date 9/17/99 ' Form 10-404 Boy 0~/15/8 SOBMIT I~ D~klGAT~ BPX Endicott Production Engineering Department , , MIT with AOGCC Witness DATE: 8-30-99 (, 5-01,5-02, 2-16, 2-16, 1-64, 2-06, 2-/3~4. WELL N-o: BP EXPLORATION REP: Peruzzi, Williams SERVICE COMPANY: APC pump truck with Beardsley, Neuman and Linberg Summary: On 8/28 and 8/29 all seven wells were fluid packed and pre-MIT'ed to 2500. All passed. On 8/30 a.m. all wells were witnessed by Chuck Scheve who filled out the data sheets attached. All passed. Attachments: State form Pump sheet for official MIT ¢ Well .... Pre. MiT diesel ....... MiT 'diesel pumped Notes ...... , .... PumPed, BBL. S .... , BBLS ..................... 5-01 9 3 5-02 5 7 , ....... , ...... , ,, .... 2-34 I 8 2-06 6 "' 4 .... ~sed 60/40'for pre-Ml'T' 2-16 54' ' :15 "' pumped 120 barrels of 60/40 prior't~) .pumping diesel ...... i-64 6 6 2-64 4 4 ...... Summary: Pumped a total of 132 bbls of Diesel STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechan~! I~ntegrity Test OPERATOR: ELo'X FIELD I UNIT I PAD; Endic.oU:./D!U' J MPI DATE: 8/'30/99 Diesel 9,354 ..u~ 4~400 ,: 4,400 4,400. 4,400 2-06 G P I?~ne !2~3_8 ...... .9 5~"_/4_7#_/NT-80 7" 23,38.5 t.100. 2,600 2,$50., _ ~ 2,550 11:20 ................. 'COMMENTS: PTO~ 87'-I 8 Semi Annual t1800 COMME~$: PT~I~ 4Year .... i --I I~"~'~''''~ ........ I ! ' ,.o, PT~ ~-172 Semi ~al ' i ............. ~ 1o I~ ! ~'~'~'*°~° I..,~-! ,~, }-'~ B~. ~.~ 9 5t8, ! 47~ / NT~ . . 400 COMME~S: PT~ 90-77 4Year ...... ¢OgM[~$: ............ ................ ~ ....... , . TBG. tNJ. FLUID CODES F = FRESH WATER INJ. g =GAS S = SALT WATER ~NJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRES,.~URE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D - DIFFERENTIAL TEMPERATURE TES~ ANNULAR FLUID: P.P.G. Grad. WELL TEST: DIESEL ; 0.00 tn~at GLYCOL ! 0.00 4 - Year X SALTWATER ~ 0,00 Workover DRILLING MUD .... -.~ OTHER orig - Well File ¢-~ ~- Dalabar~ c -Trtp Apt File c- Inspector OPERATOR REP SIGNATURE: Tave PeruzTJ j~kha~.xls , AOGCC REP SIGNATURE: Chuck Scheve (Rev 9/17/96) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 14echanical ;Z~rity Test OPERATOR: BPX FIELD t U NIT t PAD; _ Endicott /DIU · Diesel 8,94_.~4 4~100 4,1 IX) 4,100 4,t0~.. 5-01 G P Brine .. 10,842 .... 9 5/9" f47# / L-80 _ 7'.i .... 2236 1,650 2,500 2,400 ~2,~00j. 9:25 COMMENTS: .......... PTD#8_0.~I_20_ .~_emi Ar'~ual Diesel I 9,045 ........ [.i"'"i.,400. I ~4~01 ~,400 1_ ~4001 5-02 s P Brine I 11,277 95J9"/47#/NT-95 4,5" 2261,,,25,[ 0 i 2,52~!_2,$25 } 2,525 I 9:45 COMMENTS: '" PTD~ 8~t-118 Semi Annual , , , , , ,,,,, ,, , ,,, , - t- I ,I ...1' I I !o - "1"5111-'~ I ~-I--:-!-,.11.,---~."', t I o 1 '"1~ :'~'' ..... 'i' ..... t' I COM~ENT~: ,, ............. ... ,,, ............. TBG. INJ. FLUID CODES F = FRESH WATER tNJ. g = GAS I NJ. 8 - SALT WATER INJ. N = NOT IN~I, ECTING TEST TYPE: M ~ ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R -- INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOHALY TEST O -- D]:F~.RENTZAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 · ,. W~LL TEST: Initial 4 -Year Workover Oflle~ X OPERATOR REP SIGNATURE: Tare PeruzzI Jk-gkh4gf. xts . AOGCC REP SIGNATURE: (R~v 9t17/96) STATE OF ALASKA ALAS'--OIL AND GAS CONSERVATION COMMIS.e' ' REPORT SUNDRY WELL OPL-rlATIONS 1. Operations performed: Operation shutdown_ Stimulate__ Plugging m Pull tubing m Alter casing __ Repair well Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development KBE = 53.20 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchora.oe , Alaska 99519-6612 Service X Duck/s/and Unit/Endicott 4. Location of well at surface 8. Well number 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R 17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not rec/uired) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9~0' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#1ft IJ4S tubing with 5 1/2" tailpipe to 12286' ORIGINAL Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 13. Stimulation or cement squeeze summary 7" SSSV at 1541' MD · i 14. Intervals treated (measured) ,. Treatment description including volumes used and final pressure ..i~,,~:~;:-~?~:: i i' .~ .~: · Representative Daily Average Production or OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 46613 61402 4071 4369 15. Attachments MIT 4-1-99 Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas__ Suspended Service ~.~ Ini.~ctr)r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~:~ (~~ Title~_ni~rT~hnin~lA.~_~i~t~ntlV[~t~4-5~?34! Date 4-14-99 Form 10-404 Rev 06/1~8 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 4-1-99 WELL N°: 2-061J-22 BP EXPLORATION REP: Lovelace SERVICE COMPANY: APC MIT with AOGCC Witness DATE/TIME 4/1/99 OPERATIONS SUMMARY WHP= 4400 IA = 500 OA = 0 MIRU TO IA PT HARDLINE TO 3000 PSI. START PUMPING 60/40 MEOH 4 BBLS AWAY. lAP= 2450 PSI. START TEST. LOST 50 PSI IN 30 MIN. TEST IS GOOD. BLEED BACK IA TO 500 PSI. RDMO. WHP=4400 IA= 500 OA= 0 Summary: MIT with the state AOGCC witness Pump Summary: BBLS FLUID 4 60/40 meth. STATE OF ALASKA AL/' ...... ~"JILAND GAS CONSERVATION COMMm- ..... REPORT SUNDRY WELL OF. ATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.ae , Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not recluired) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate ProdUction Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. fl. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9~0' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 91561 93427 Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas ~ Suspended Service Gas Ini. ec.t_or 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 0~/15/88 SUBMIT IN BPX Endicott Production Engineering Department DATE: 1012/98 WELL N°: 2-061J-22 BP EXPLORATION REP: C. Lovelace SERVICE COMPANY: HB&R MIT WITH STATE WITNESS COST CODE: N16206 DETAIL CODE: DATE/TIME I OPERATIONS SUMMARY 1558 1618 1648 FP=4300 IA=1100 OA=200 MIRU HB&R. P/I- to 3000 ps~. Pump 4 bbls of diesel down I/A & Pressure up to 2500 psi. RDMO. Monitor for 30 min. Passed MIT. Bleed back to 400 ps~. FP= 4300 IA=400 OA=200 SUMMARY: * Pump a total of 4 bbls of diesel. Passed MIT. * Witnessed by AOGCC REP. Lou * I/A =400psi OIA =200psi FWHP = 4300psi ..... STATE OF ALASKA · ALASK ',L AND GAS CONSERVATION COMMISSI¢ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well_ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorac/e, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development Exploratory __ Stratigraphic __ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not required) 10. APl number 50- O29-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 105' 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Size Cemented Measured depth BKB 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9740' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7"26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 7" SSSV at 1541' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Dailv Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 110514 117610 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil Gas Suspended 17. I here. by.,,certify th~ th~foregoing is'"'~rue and correct to the best of my knowledge. Signe((I.~~j~f,//~~ Title~eninr T~nhnin~l A_~i.~t~nt IV Form 10-4(~ev 06/1~/88 Service Date 5/5/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 415198 WELL N°: 2-061J-22 BP EXPLORATION REP: D. Williams SERVICE COMPANY: A.P.C. MIT WITH STATE WITNESS COST CODE: N16206 DETAIL CODE' DATE/TIME t OPERATIONS SUMMARY 1239 MIRU HB&R. P/T to 3000 psi. 1306 Pump 11 'bbls of diesel down I/A & Pressure up to 2500 psi. Monitor for 30 min. 1336 Passed MIT. Bleed back to 500 psi. RDMO. SUMMARY: * Pump a total of 11 bbls of diesel. Passed MIT. * Witnessed by AOGCC REP. JOHN SPAULDING * I/A =500psi O/A =200psi FWHP = 4400psi STATE OF ALASKA ALAS'~-'")IL AND GAS CONSERVATION COMMISS"=" ! REPORT SUNDRY WELL OPL, ATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well Perforate Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle , Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not recluired) 10. APl number 50- O29-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Line~ Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' True vertical depth BKB 161' 2498' 9740' 9475'- 10121' ORIGINAL Packers and SSSV (type and measured depth) 9 5/8" TIW Packerat 12238' MD; 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 7" S ~, ' 25 997 Alasl Oil .& Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 103076 105265 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended Service ~., Ini.~.~.t_nr 11~., ,er~o;:,~,;h~t t~~ t~ru.e and correct ,o the best of my knowledge. Signed ~'1/',..C/~L/{~/~ ~~ Title 5;eni~r Te~hni~el A~ni_et~nt IV Form 10-4(~1/Rev 06/15/88 Date 09/22/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: WELL N°: 9/12/97 2-06/d-22 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT With State witness Lovelace Tri-plex TIME OPERATIONS SUMMARY 1315 RIG UP Tri-plex AND PoTEST LINES TO 3000 PSlG FP = 4400 IA = 50 OA = 0 1317 BEGIN PUMPING METHANOL AT .5 BPM 1331 7 BBLS AWAY. IA = 2500 FP = 4400 OA = 0. MONITOR. For 30 minutes .... 1350 IA = 2560 SIP = 4400 OA = 0. GOOD TEST. 1355 IA BLED DOWN TO 50 PSIG. RIG DOWN Tri-plex. Summary: Pumped 7 bbls of methanol into the inner annulus and held 2500 psi for 30 min. then bled back to 500 psi STATE OF ALASKA ALAS~',,OIL AND GAS CONSERVATION COMMI?--"J REPORT L .: SUNDRY WELL CPc:RATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing ~ Alter casing __ Repair well_ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.~Te , Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R 17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development Exploratory ~ Stratigraphic ~ Service .. 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not required) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth BKB 105' 30" Drive Piled 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. fl. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9740' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7"26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' ORI$1NAL Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) 9 5/8" TIW Packer at 12238' MD; v/' h,l r-r- Treatment description including volumes used and final pressure 14. 7" SSSV at 1541'MD Alas.~a 0il & Gas Cons. 60rnrnisslu Representative Daily Average Production or Injection Da~Ch°rage Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 144717 136277 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations × 16. Status of well classification as: Oil Gas Suspended Service G~.~ Ini. p. otnr 17. I herebv certify that.the¢oregoing is true and correct to the best of my knowledge. Signed ......;,~L~~C-~ ~'...,/ /'~(,~'~'~. ¢~/ Title Seni, r Technic,! A.~.~i.~t~nt IV Form 10-4(J4/Rev 06/15/88 ' V Date 4/28/97 SUBMIT IN DUPLICATE~ Endicott Production Engineering Department DATE: 3/8/97 WELL N°-: 2-06/J-22 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: OPERATIONS REPORT MIT VARBLE HB&R DATE/TIME OPERATIONS SUMMARY 1032 MIRU HB&R. P/T TO 3000 PSI 1040 PUMP 4 BBLS DIESEL DOWN IA & PRESSURE UP TO 2500 PSI. MONITOR FOR 30 MIN. 111 0 PASSED MIT. BLEED BACK TO 500 PSI. RDMO SUMMARY: PASSED MIT. WITNESSED BY AOGCC REP. DOUG AMOS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska)/nc. Development KBE = 53.20 feet Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 2-06/J-22 MPI 9. Permit number/approval number 87-18 (not required) 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 105' 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) ORIGINAL Size Cemented Measured depth True vertical depth BKB BKB 30" Drive Pipe 161' 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 2498' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 9740' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' PackersandSSSV(typeandmeasureddepth) 95/8" TIWPackerat12238'MD; 7" v , E EIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OCT 2 1 1996 Alaska 011 & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 106502 111753 Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Gas Injector Signed (~~j~/~, Title Senior Technical Assistant II/ Form 10-404 ~/ev 0671§i88 - -~ Date 10/17/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department OPERATIONS REPORT DATE: 8/26/96 WELL N-°: 2-06/J-22 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: M.I.T. · VARBLE HB&R DATE/TIME OPERATIONS SUMMARY 1135 MIRU HB&R P/T TO 3000 PSI 1155 START PUMPING DIESEL DOWN IA 1210 i8 BBLS AWAY. IA PRESSURED UP TO 2500 PSI. HOLD FOR 30 MIN. 1240 GOOD TEST. RIG DOWN 8/27 91 7 RU HB&R 928 BUMP PRESSURE UP. TO 2500 PSIG WITH 10 BBLS OF DIESEL. 959 GOOD TEST. RD. PASSED MIT. WITNESS: Chuck Scheeve RECEIVED OCT 2.. I 1996 Alaska 011 & ~a;; Con~ Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development __ /(BE = 53.20 feet Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R 17E ORIGINAL 2-06/J-22 MPI 9. Permit number/approval number 87-18/93-059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9740' 9475' - 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 95/8" TIW Packer at 12238'MD; 7" SSSVat 1541'MD 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injectioh"D~t~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 97403 Subsequent to operation 99417 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas__ Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed <~,¢~/~ ,'~/, /-~,~,~_~Z~- Title Senior Technical Assistant ,, Form 1Q./~0"4 Rev 06/15/88 SUBMIT IN DUpLIO/~I'E Endicott Production Engineering Department MIT DATE: 3/11/96 WELL N°: 5-01/SAG 07 & 2-06/J-22 BP EXPLORATION REP: R. Clump SERVICE COMPANY: HB & R DATE/TIME OPERATIONS SUMMARY 5-01/SAG 7 1330 Miru HB & R to IA. (lAP= 500 psi, OAP= 0, IWHP= 4100 psi). Pressure test lines to _ 3000 psi. Pump 8 bbls 50/50 meoh. Shut down. 1340 Start test. lAP= 2500 psi. 1410 lAP= 2480 psi. Passed. Bleed back IA to 320 psi. RDMO HB & R. 2-06/J-22 1430 Miru HB & R to IA. (lAP= 850 psi, OAP= 150 psi, IWHP= 4200 psi). Pressure test line to 3000 psi. Pump 10 bbls 50/50 meoh. Shut down. 1440 Start test. lAP= 2500 psi. 1510 lAP= 2350 psi. Passed. Bleed back IA to 750 psi. RDMO HB & R. Summary' 5-01 & 2-06 Passed required (6) month MITs. STATE OF ALASKA ALA,.,.,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E Perforate__ v Other X 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 8 7-18/93 - 059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9~0' 9475'- 10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238' MD; 7" SSSV at 1541'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 97403 99417 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/L./~!..,, b/~_ ,/~/~.~ Title Senior Technical Assistant ll Form 10-40'.4/Rev 06/15/88 Date , ( //~ /~,~ SUBMIT IN DUtSLIC'ATE ~ Endicott Production Engineering Department SEMI-ANNUAL MIT DATE: 10/8/95 WELL N-°: ~ BP EXPLORATI'ON REP: R. CLUMP SERVICE COMPANY: HB & R / AOGCC REP: J. HERRING DATE/TIME OPERATIONS SUMMARY I 1000 MIRU HB & R TO IA. (WHIP= 4000, lAP= 530). PT LINE TO 3500 PSI. 1009 START PUMPING DIESEL. 1030 PUMPED 10 BBLS DIESEL. lAP= 2500 PSI. RDMO HB & R. START TEST. 1 100 lAP= 2500 PSI. TEST IS GOOD. BLEED lAP TO 375 PSI LATER. PASSED SEMI-ANNUAL MIT. J. HERRING (AOGCC REP) WIT. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 5. Type of Well: Development ExPloratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 53.20 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18/93-059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 1202'SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227'SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Ddve Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True vertical depth BKB 161' 2498' 9740' 9475'- 10121' feet true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 95/8" TIW Packer at 12238'MD; 7" SSSVat 1541'MD 13. Stimulation or cement squeeze summary i"~ '~ C ~ !~/~ ~ Intervals treated (measured) Treatment description including volumes used and final pressure d U L - 14. Representative Daily Average Production or In]ection~at*a ' t;~ii,~l'lt~,"." Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 98548 61430~''~ 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended__ Service Gas Injector 17. I hereby certify that the foregoing ~ect to the best of my knowledge. Signe~ ~. Title Senior Technical Assistant Il Date Form 10~1~"4 Rev 06/15/88 SUBMIT IN DUPdCATE -,,,~_.~ Endicott Production Engineering Det)artment OPERATIONS REPORT DATE: 5/5/95 WELL N;: 2-06/J-22 TYPE OF OPERATION: MIT BP EXPLORATION REp: VARBLE SERVICE COMPANY: HB&R DATE/TIME OPERATIONS SUMMARY I 1305 RIG UP - P/T TO 3500 1310 PUMP 28 BBLS OF DIESEL DOWN IA & PRESSURE UP TO 2500# - MONITOR FOR 30 MIN.- LOST 175# - TEST GOOD- BLEED IA DOWN TO 600#- RD WHP- 4000 IA- 950 OA- 100 NOTE: MIT TEST GOOD - WITNESSED BY AOGCC REP. J. HERRING STATE OF ALASKA · ,,.ASKA OIL AND GAS CONSERVATION COM~,..~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1852'SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E ' At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) Perforate Other × 6. Datum elevation (DF or KB) KBE = 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI Permit number/approval number 87-18/93-059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. fl. Class "G" 12680' 844' 7~' 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True veBr~l depth 161' 2498' 9740' 9475'-10121' true vertical (Subsea) 9721'- 9747, 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7"26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIWPacker at 12238' MD; 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0il & Gas Con . CommissiOn Anch0r ' 14. Prior to well operation Subsequent to operation Representative Daily Average prod~lction or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 93659 85018~~'~ Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10~4 Rev 06/15/88 SUBMIT IN DU/PLI~:AT~,..~-. Endicott Production Engineering Department DATE: 9/28/94 WELL N°: 2-06/J-22 TYPE OF OPERATION: BP EXPLORATION REP: AOGCC REPRESENTATIVE: SERVICE COMPANY: MECHANICAL INTEGRITY TEST MARTIN BOBBY FOSTER HB&R DATE. TIME OPERATIONS SUMMARY ~/28/94 1330 lAP -- 1500. BLEED OFF lAP TO 600 PSI. 1600 RIG UP HB&R TO THE INNER ANNULUS. INITIAL lAP -- 600 PSI. WHP = 4000 PSI. OAP = 50 PSI. PUMP 26 BBLS OF DIESEL DOWN INNER ANNULUS TO PRESSURE UP TO 2525 PSI. MONITOR lAP FOR 30 MINUTES. FINAL lAP = 2400 PSI. FINAL OAP = 50 PSI. BLEED lAP TO 1250 PSI. PASSED MIT. ALASKA OIL AND GAS CONSERVATION COMMISSION MECHANICAL INTEQRITY TEST Date · 9/28/94 Company' *M FLUID DIESEL SEAWATER PKR TVD MD 9,730' 15,448' BP EXPLORATION ALASKA~ INC. TBG CSG PRESS 1,700 2432 300 Field: ENDICOTT UNIT START TBG CSG PRESS 1,640 15 MIN TBG CSG PRESS 1,680 2,600 30 MIN TBG CSG PRESS 1,720 2,640 CASING sTIBzGE REQ SI ZE/WT/GRADE TEST PRESf 9-5/8", 47#/FT NT-95 TO 16,058' 2,550 START TIME 1150 P F PASS MMENTS: CO-MINGLED SEAWATER AND PRODUCED WATER INJECTOR. 5-01/SAG-07 GA I & SEAWATER ~.OMMENTS: SIX (6) MONTH TEST. 8'892'i 10,842' 9-5/8", 47#/FT, L-80 TO 11,554' 4,100 1,425 4,100 2,550 4,100 2,350 4,100 2,390 1455 IPASSI 2-06/J-22 GAS I & SEAWATER COMMENTS: SIX (6) MONTH TEST. 9'350'I 12,288' 9-5/8", 47#/FT NT-80 TO 10,748' NT-95 TO 12,680' ~ENTS: 2337 4,000 600 Ii 4,000 2,525 4,OO0 4,000 1625 2,400 2,400 , ~-- I~, - Workov~r IPASSI TUBING INJECTION FLUID: P = PRODUCED WATER INJ S = SALT WATER INJ M = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING ANNULAR FLUID GRADIENT: DIESEL 0.353 PSI/FT GLYCOL SALT WATER 0.45- PSI/FT DRILLING MUD OTHER OTHER WELL TEST: Initial 4-year Explain 2-06 & 5-01 ARE ON A 6 MONTH SCHEDULE AOGCC WITNESS SIGNATURE COMPANY REP SIGNATURE /S/ MICHAEL D. MARTIN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMiS,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service ., 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205'WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265 feet 10189 BKB feet 13114 feet 10071 BKB feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 53.20 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18/93-059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True ve~l depth 161' 2498' 9740' 9475'- 1O121' feet true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7" 26~/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 12238'MD; 13. Stimulation or cement squeeze summary 7" SSSVat 1541'MD 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 91888 83318 Gas Cons. c0ma'~ssl0n Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended . Service Gas Injecfer 17. I hereby certify that the foregoing is t. ru)e and correct to the best of my knowledge. Signed ~,'L-~.~ ~, /~¢¢~'_~:;2-~ Title Senior Technical Assistant II Form 10-~r~Rev 06/15/88 Date~/](~/~ / SUBMIT IN DUPI'ICA~E ii Production Engineering Dep,.artment ....... OPERATIONS REPORT DATE: 3/10/94 WELL N~: 2-06/J-22 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE .COMPANY: MIT (6 MONTH TEST FOR THREAD LEAK) POWERS HB&R II DATE/TIME' " ': OPERATION'S SUMMARY '"" " '" I 3/8/94 0800 'I~LEED IA FROM 2350 TO 50 PSI ..... '- 1200 RDMO :~)9/94 0800 BLEED IA FROM 250 TO' 50 PSIG. 0830 RU HB&R TO THE IA. WHIP = 4050 PSIG ........ 0900 ' PUMP 32 BBLS OF DIESEL TO PRESSURE IA TO 2500 PSIi SHUT DOWN. WATCH lAP FOR 30 MIN. PRESSURE AT 2500 PSI. ,,, ~LI~ED lAP BACK TO 500 PSI. RDMO. 3/10/941200 RU LINES TO IA. lAP@ 1200 PSI. WHIP = 4050. "' 1220 PUMP'3 BBLS OF DIESEL TO PRESSURE IA TO 2500 PSI. SHUT DOWN. WATCH lAP FOR 30 MIN. PRESSURE AT 2500 PSI. PASSED MIT: WITNESSED BY AOGCC REPRESENTATIVE DOUG AMOS. 1300 BLEED lAP BACK TO 500 PSI. RDMO. RECEIVED MAY 20 1994 Alaska 0il & Gas Cons. Commission Anchorage ' ¢-_.. STATE OF ALASKA AL ,KA OIL AND GAS CONSERVATION COMMIS~,.ON REPORT OF SUNDRY WELL OPERATIONS ,. 1. Operations performed: Operation shutdown Stimulate Plugging .. Perforate Pull tubing ' Alter casing Repair well Other X 5. Type of Well: 6. Datum elevation (DF or KB) Development KBE 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202'SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241' SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Exploratory Stratigraphic Service 13265 feet Plugs (measured) true vertical 10189 BKB feet measured 13114 feet Junk (measured) true vertical 10071 BKB feet Length Size Cemented 105' 30" Drive Pipe Measured depth BKB 161' 2446" 13 3/8" 2700 cu. fl. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18/93-059 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' True V~PBal depth 161' 2498' 9740' 9475'-10121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size. grade, and measured depth) 7" 26,¢/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 95/8" TIW Packer at 12238'MD; 13. Stimulation or cement squeeze summary 7" SSSVat 1541'MD Intervals treated (measured) Treatment description including volumes used and final pressure OCT 1 9 t995 Alaska Oil & Gas Cons. bur~miss~o" 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data .OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 70899 88496 Anchorage Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~.~:~//~J. /~/~/c~ TitleSenior Technical Assistant ll Form ~3"~04 Rev 06/15/88 Date,/~ ,~._~//'~/,~ SUBMIT IN DIJPLI~3ATE il i Endicott Production Engineering ,Department OPERATIONS REPORT DATE: 9/12/93 WELL N~: 2-06/J-22 TYPE OF OPERATION' BP EXPLORATION REP: SERVICE COMPANY: . MIT (6 MONTH TEST FOR THREAD LEAK) LOVELAND/LUEDKE-CHAN LITTLE RED (ERIK) DATE/TIME ,, OPERATIONS SUMMARY ,, 9/12/930800 BLEED IA FROM 2650 TO 400 PSi ' '~" 1200 RU LINES TO IA~ lAP @ 400 PSI. WHIP = 4050. 0852 PUMP 30 BBLS OF DIESEL TO PRESSURE IA TO 2500 PSI. SHU~' DowN. WATCH lAP FOR 30 MIN. PRESSURE AT 2500 PSI. PASSED MIT: WITNESSED BY AOGCC REPRESENTATIVE JOHN SPALDING. , , 1330 BLEED lAP BACK TO 500 PSI. RDMO. OCT Ataska Oil & Gas Cons. Anchorage 1. Type of Request: STATE OF ALASKA ~'~ ALASKA OIL AND GAS CONSERVATION COMMISb,oI',I '"-~ APPLICATION FOR SUNDRY APPROVALS . Abandon Suspend Operation Shutdown Re-enter suspended~-'el!'lateo,,,,u Alter casin--~--~ Repair ~ Plugging ----Time extension __ ' ~ Change approv~:~ program 'Pull tubing Variance Perforate Other ;~ 5. Type of Well: 6. Datum elevation (DF or K~ KBE 53.20" feet 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Development __ Exploratory __ Stratigraphic__ 7. Unit or Property name Service X Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number 87-18 10. APl number [3 50- 029-21699 11. Field/Pool Endicott Pool 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical RECEIVED MAR - 9 199, Alaska Oil & Gas Cons. CommJssi~ Anchorage 13265 feet 10189 BKB feet Plugs (measured) Effective depth: measured true vertical 13114 feet 10071 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 105' 30" Drive Pipe 2446" 13 3/8' 2700 cu. ft. Permafrost 12624' 9 5/8" 575 cu. ft. Class "G" 844' 7" 357 cu. ft. Class "G" measured 12724'- 12758', 12768'- 12810', 12816'- 12900' Measured de~ TrueBv~¢ical depth 161' 161' 2502' 2498' 1268O' 974O' 12403'- 13247' 9475'-1O121' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' Tubing (size, grade, and measured depth) 7"26,~/ft IJ4S tubing with 5 1/2" taiipipe to 12286' Packers and SSSV (type and measured depth) 95/8" TIW Packer at 12238'MD; 7" SSSV at 1541'MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation not applicable 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Gas Injector Suspended~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Con(ii'ns of approval: Notify Commission so representative may witness I Approval No. Plug integrity ~ BOP Test__ Location clearance Mechanical Integrity Test__ Subsequent form required/~--~,~o .--~ e ~' ~',~ 7',~//¢ ,,, ~,//~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Oriain*~ ~;"*ned By David ~,v. ,Johnston CommissiOner~ Date ,z~ --/~ '-~ L~' ~ '/~' '-~ SUBMIT IN TRIPLICATE 2-06/J-22 and 5-01/~;D-07 Ges In!ectors Situation: There is Iow level communication between the tubing and the inner annulus (9-5/8"x7") on gas injection wells 5-01/SD-07 and 2-06/J-22. Outer annulus (13-3/8" x 9-5/8") pressure remains stable and does not indicate further communications. Neither well has failed to pass a Mechanical Integrity Test (MIT); the last being performed on November 20, 1992. Pressure build rate: Leak rate is indicated by whether the inner annulus can be bled to zero and how long it takes to build to a stabilized pressure. The inner anulli of both wells can be bled to zero. Stabilization pressure for well 2-06/J-22 is 2500 to 2700 psi, depending upon inner annulus bdne weight and wellhead temperature. Time to inner annulus pressure (lAP) stabilization is 7-10 days depending upon tubing injection pressure and temperatures. Well 5-01/SD-07 builds to 1100-1300 psi over a 14-21 day period. Both leaks are very small with a stabilized pressure within the safety factors on the 9- 5/8" burst and the 7" collapse ratings. These stabilized pressures indicate the leak is above the packer on both wells. Leak Type and Location' Leak detection utilizing conventional noise/temperature logging was performed on well 2-06/J-22 October 27, 1992. The results indicated no conclusive evidence of a leak. Novel leak detection work followed utilizing a downhole video camera, fluid packed tubing and gas pressure on the inner annulus. This technique identified a small thread/connection leak at 6283' WLM (VHS video tape available). No leak detection work has been done on 5-01 but the very slow build rate and lack of deterioration over several bleed cycles indicates a similar source. .Mitigation: We have investigated non rig repair of this leak and feel that the probability of sucess of a mechanical patch is relatively Iow due to the large tubing size (7"), fluid composition (gas), and pressure and temperature requirements while in service. Recommendation; We recommend continued injection operations while closely monitoring for changes in IA pressure on these wells. We propose a much more rigid MIT program which would test the hydraulic integrity of the 9 5/8" casing to 3000 PSI every six months.. Remedial actions will be prompted either by the lAP exceeding 3000 psi or failure to pass any of the semi-annual MITs. Remedial actions may include non-rig or rig alternatives depending on an economic and operational analysis of available options at that time. We request your concurance with this operating plan. If additional information is required, please don't hesitate to call Rosemary Hornbro°k at 564-4405. 2541/prh Afaska Oil &. Ga.~; Cons. A,%faorag~ BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT' FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-29/M-25 1-49/P-21 2-06/J-22 2-58/S-09¢e -~'~ 11/1 5/92 3-01/N-29 1 1/9/92 3-05/0-29 11/1 6/92 3-21/L-34 11/1 6/92 3-23/N-32 1 1/9/92 4-02/Q-28 ('1 0/29/92 ~.1 0/29/92 4-40/P-43q,?....¢3.1 0/21/92 11/15/92''/ 1 11/19/92~/ 1 1 0/25/92 ~' 1240'-12260' 13900'-14328' 11900'-12850' 11300'-12400' 11950'-12742' 11 050'-11664' 11800'-13000' 11800'-13000' 1 3100'-14069' (~PDK-10CG~ 0600'-11200' CPDK-100)GR/CCL NOISE/TEMP SURVEY PDK-100/GR/CCL PRODUCTION LC)C-~ING (CALIPER SURVEY) PRODUCTION L~ING (CALIPER SURVEY) PFIODUCTION LOC-~ING (CALIPER SURVEY) · PRODUCTION LOC-.-.-.-.-~21NG (CALIPER SURVEY) JEWELRY LOG INJECTION PROFILE SURVEY 2550'-13570',/ INJECTION PFIOFILE WARM BACK ATLAS WIRELINE ATLAS WIREUNE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE CAMCO CAMCO CAMCO R ECEIVED DEC 1 0 !992 AJaska 0ii & Gas Cons. ConmiJssion Anchorage BLUELINE AND SEPIA INFORMATION TOTHE STATE ENDICOTI' FIELD ONLY WELL NAME DATE INTERVALS LOG NAME ~.- t c,~' 1-43/P-26 8/21/92 12850'-13750' ~ ~--'?,.~ 1-55/R-25 8/22/92 12900'-13195 ' ~?.,1~ 2-06/J-22 ~ 4/23/92"" 12180'-12900' 7/26/92 "'" 12650'-13010' 2-64/U-10~e-~/~ 9/8/92 S750'-11300' ~.~)..I ~' 3-23/N-32 9/4/92 11240'-11500' ~,~ ..- It I 4-28/N-37 9/8/92 10950'-11280' 4-40/P-43 ~7.~,? ~ 6/5/92 12600'-13695' Perforating Record Production Profile Log Perforating Record Perforating Record Leak Detection Survey (FLEXSTAK) Production Logging Services Production Profile Survey (FLEX STACK) Perforating Record, Jewelry Log SAG DELTA NORTH ONLY 2-32/8N-03 9/13/92 12860'-13266' Perforating Record STATE OF ALASKA AL~,.,~A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operato~ BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 Stimulate Plugging Perforate X Alter casing Repair well Other 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service ---~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265feet 10189 BKBfeet 13114feet 10071 BKBfeet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) Junk (measured) Length Size Cemented Measu~)KdBdepth 105' 30" Drive Pipe 161' 2446" 13 3/8" 2700 cu. ft. Permafrost 2502' 12624' 9 5/8" 575 cu. ft. Class "G" 12680' 844' 7" 357 cu. ft. Class "G" 12403'- 13247' measured 12724'- 12758', 12768'- 12810', 12816'- 12900' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9857' 6. Datum elevation (DF or KB) KBE 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott Tubing (size, grade, and measured depth) 7" 26~/ft IJ4S tubing with 5 1/2" tailpipe to 12286' TIW Packer at 12238' MD; 7" J\t EI V EL) Packers and SSSV (type and measured depth) 9 5/8" 13. Stimulation or cement squeeze summary 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18/92-187 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool True vel~.~ depth 161' 2498' 9740' Intervals treated (measured) AUG 2 8 1992 14. Treatment description including volumes used and final pressu/~aska 0il .& Gas Cons..Commission RePresentative Daily Average Produc~(~'~'~ction Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation SSSV at 1541' MD 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 50182 102562 16. St~us of wellclassification as: Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic, lned '--'~~7_./7~ ~'~, ~;~"' Title Senior TechnicalAssistant II Form 10,.4'",e'4 Rev 06/15/88 9475'-1O121' Tubing Pressure Service Gas In/ector D at e 0~/.~//¢~.._ SUBMIT IN DOPLi'CATE ii Endicott Production Engineering Department DATE: 7/26/92 WELL N~: 2-06/J-22 BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS HLS DATE/TIM E OPERATIONS SUMMARY I' i 1 5 0 0 RU. Post radio silence signs at the entrance to island and next to well site. 1515 Install SSV fusible cap. SIWHP = 600 psig. lAP = 0 psig. OAP = psig. 1 5 3 0 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 1700 RIH with Gun #1 (20 feet). SlWHP = 700 psig. 1 73 0 Tie in to CBL dated 3-29-87. The CBT is one foot deep to the open hole reference log (DLL-GR 3-25-87). All of the depths listed below are from the open hole reference log. Flag line for next run. SlWHP = 750 psig. ,,, 1 745 Hang gun #1 Top Shot at 12860 MDBKB. 1748 Shoot gun #1 from 12860°-12880. MDBKB. SlWHP = 750 psig. 1 75 0 Log collars while POOH. 1915 RIH with Gun #2 (20 feet). SlWHP = 950 psig. 1959 Tie in to CBT logging up. Shoot gun # 2 from 12880-12900' MDBKB. SlWHP = 950 psig. 2040 Log collars while pooh. WHP- 1000 psi. 21 20 End radio silence. Final SlWHP = 1200 psi. PERFORATION SUMMARY: GUN INTERVAL(DLL) CBL DEPTH FEET SUBZONE I 12860- 12880 12861 - 12881 2 0 2 A 1 2 12880-12900 12881-12901 20 2A1 All intervals were shot using 4" guns at 4 spf, and 45 deg. orientation, with 36 gram charges. 90 degree phasing 6 2 8 1992 Gas Cons. Commission A~chora~e 1. Type of Request: STATE OF ALASKA ALA~r,,A OIL AND GAS CONSERVATION COMMISS,,.,,q APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging __ Time extension __ Stimulate ~ Change approved program x Pull tubing__ Variance__ Perforate, X Other__ 2. Name of Operator . BP Exploration (Alaska) Inc. 3. Address P. O; Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1227' SNL, 5205' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development __ Exploratory __ Stratigraphic Service X Effective depth: measured true vertical RECEIVED j U L 1 5 1992 Alaska 0il & Gas Cons. C0mm'tss'~0n Anch0r .qe Measured de~ 161' 6. Datum elevation (DF or KB) KBE 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 13265 feet Plugs (measured) 10189 BKB feet 13114 feet Junk (measured) 10071 BKB feet Size Cemented 30" Drive Pipe casing , Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 105' 9. Permit number 87-18 10. APl number 50- 029-21699 2446" 13 3/8" 2700 cu. ft. Permafrost 12624' 9 5/8" 575 cu. ft. Class "G" 844' 7" 357 cu. ft. Class "G" measured 12724'- 12758', 12768'- 12810', 12816'- 12860' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9827' Tubing (size, grade, and measured depth) 7" 26~/ft IJ4S tubing with 5 1/2" taiipipe to 12286' Packers and SSSV (type and measured depth) TIW9 5/8" Packerat 12238'MD; 13. Attachments Description summary of proposal X 14. E~timated date for commencing operation July~ 1992 Date approved 16. If proposal was verbally approved Name of approver 11. Field/Pool Endicott Pool 2502' 12680' 12403'- 13247' SSSV at 1541' MD Detailed operations program I15. Status of well classification as: Oil Gas Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe ~~~/~/.~c~- ~ Title SeniorTechnicalAssistantll FOR COMMISSION USE ONLY Tru eBv~ical depth 161' 2498' 9740' 9475'-10121' BOP sketch × Suspended I Approval No. ~pproved Gopy Returned Commissioner Date Condl[iO"ns of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Orlglnal Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ENDICOTt FIELD Well 2-06/J-22 Injectivity of this well has decreased since the reperf and mud acid stimulation in April, 1992, forcing gas over-injection into well 1- 05/0-20 (3AMPI). Continued over-injection into 3AMPI will negatively impact reserves. The additional perforations are expected to increase 2-06/J-22 injectivity and allow more gas injection into 2AMPI. A more balanced gas re-injection scenario will lead to higher recovery of the MPI gas cycling intervals. We plan to perforate the following interval using the biggest available gun for maximum pentetration: 12860'-12900' BKB (Ref. DLL-GR, 3/25/87) A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforations are added. RECEIVED JUL 1 5 199 Alaska Oii& Gas Cons. Commiss\O~ Anchorage il BASIC SYSTEM MAKEUP !1 //. ~ ~sE SEAL F'LOWLINE E ~ ~ . o . FLOWLINE V. ALVE __ BOWEN PACKOFF 1-'-- HAND .PUMP GREASE MANIFOLD GREASE · PUMP -. RISER GREASE RESERVO. BOP RECEIVED d U L 1 5 199~ Alaska Oil & Gas Cons. CommissiOr~ Anchorage o. 0 I o,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3: Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 'X'- 4. Location of well at surface 1852' SNL, 2180' WEL, SEC. 36, T12N, R16E At .top of productive interval 1202' SNL, 108' WEL, SEC. 31, T12N, RI~7E At effective depth 1230'SNL, 5190' WEL, SEC. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, SEC. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13265'feet BKB 10189'feet Plugs (measured) 13114 feet Junk (measured) BKB 10064feet BKB Perforate Other 6. Datum elevation (DF or KB) KBE = 55.25 feet 7. Unit or Property name 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18~Conservation order 258 10. APl number 50- 029-21699 1. Field/Pool Endicott Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" 161' 2446' 13-3/8" 2700 cu ft 2502' 12624' 9-5/8" 575 cu ft 12680' 844' 7" 357 cuft measured 12724'-12758', 12768'-12810', 12816'-12860' True ve~ depth 161' 2498' 9740' 12403'-13247, 9475'-10135' true vertical (subsea) 9720'-9747', 9755'-9788', 9793'-9827' Tubing (size, grade, and measured depth) 7", 26#, I J4S to 12194', 5-1/2", 17#, L-80 tailpipe to 12286' Packers and SSSV (type and measured depth) 9-5/8" TIW Packer @12238', SSSV@ 1541'MD 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) J ~J L. ... 9 7992 .Alaska Oil & Gas Cons. Treatment description including volumes used and final pressure Representative Daily Averac]e Production or Iniection Data ..... -a,~ Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to th~. best of my knowledge. Sicjned ~.~r~f,f~~ ~ -~/~'~ /~~./~/~" Title Workover Engineer Supervisor Form 10-404 Rev 06/15/88 SUeU,T,. OU".,C^T ACTIVIT~ SUMMARY for WELL ~ROJECT 176209 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : 2-06/J-22 Page: 1 RECEIVED DRLG RIG : DOYON 15 WO/COMP RIG: DOYON 15 JUL - 9 (COMP) NU ND: 6.0 10/15/91 ( 1) TD:13265 PB:13164 SUPV:MCH Alaska Oil & Gas (sons. Comrrli~ ,~ncnora.qe .... ~- ASSEMBLE BOPE. MW: 9.9 NaC1 RIG ACCEPTED @ 00:01 HRS, 10/15/91. ASSEMBLE BOPE STACK. (176209) DAILY: $ 23,073 CUM: $ 23,073 EFC: $ 1,260,000 (COMP) KILL: 4.0 NU ND: 6.0 OTHER: 14.0 -- 10/16/91 ( 2) R/U TO PUMP DN TBG. MW: 9.9 NaC1 TD:13265 ASSEMBLE BOPE. MOVE RIG OVER J-22. BLED OFF PRESSURE IN PB:13164 ANNULUS. R/U TO PUMP DN TBG. SUPV:JBS (176209) DAILY: $ 46,258 CUM: $ 69,331 EFC: $ 1,260,000 (COMP) KILL: 12.5 NU ND: 11.5 10/17/91 ( 3) TEST BOPE. MW: 9.9 NaCl TD:13265 VENT GAS. R/U LUB. R/D LUB. R/U TO PUMP 9.9 PPG BRINE. PB:13164 PUMP DN TBG. AFTER 8300 STK, WELL CLEANED UP. CHANGE SUPV:JBS LINES TO TBG. PUMP 3000 STKS. WELL CLEAN UP. CHECK FOR FLOW. OK. N/D TREE. N/U BOPE. TEST BOPE. (176209) DAILY: $ 47,988 CUM: $ 117,319 EFC: $ 1,260,000 (COMP) NU ND: 19.5 PL TBG: 4.5 10/18/91 ( 4) PULL 7" TBG. MW: 9.9 NaCl TD:13265 TEST BOPE. NO TEST. N/D BOPE. CHANGE MUD CROSS. N/U PB:13164 BOPE. RETEST BOPE. OK. PULL 7" TBG. TBG FREE. L/D TBG SUPV:JBS HGR. R/U OTIS. L/D BALL VALVE. R/D OTIS. PULL 7" TBG. (176209) DAILY: $ 39,658 CUM: $ 156,977 EFC: $ 1,260,000 (COMP) CLN OUT: 8.0 PL TBG: 16.0 10/19/91 (-- 5) POOH~ MW: 9.9 NaC1 TD:13265 POOH W/ 7" TBG. TEST COPE. RIH W/ BHA. RIH W/ RTTS TO PB:13164 45' & 157'. TEST CSG OK. POOH FOR WEAR RING. SUPV:JBS (176209) DAILY: $ 56,752 CUM: $ 213,729 EFC: $ 1,260,000 (COMP) CLN OUT: 14.5 OLD PROB: 8.0 TEST CSG: 1.5 10/20/91 ( 6) RIH TO PULL RTTS. MW: 9.9 NaCl TD:13265 POOH. INSTALL WEAR RING. RIH W/ RTTS TO 12158' CBU. PB:13164 POOH TO 10000'. BACKOFF F/ RTTS. RIH. SCREW IN~O RTTS. SUPV:JBS POOH TO 2535'. SET RTTS. RELEASE F/ RTTS. POOH. RIH TO PULL RTTS. (176209) DAILY: $ 53,653 CUM: $ 267,382 EFC: $ 1,260,000 (COMP) CLN OUT: 6.5 NU ND: 7.5 OLD PROB: 1.0 TEST CSG: 9.0 10/21/91 ( 7) CIRC. MW: 9.9 NaCl TD:13265 POOH W/ RTTS. RIH TO 10007' M/U RTTS. RIH W/ RTTS TO PB:13164 1998'. SET RTTS. N/D BOPE. CHANGE PACKOFF. TEST PACKOFF. SUPV:JBS N/U BOPE. TEST BOPE. POOH, L/D RTTS. RIH TO SBR @ 12158' WORK TO 12215'. CBU. REV CIRC W/ BRINE. (17620~) DAILY: $ 39,658 CUM: $ 307,040 EFC: $ 1,260,000 10/22/91 (8) TD:13265 PB:13164 SUPV:JBS (COMP) CLN OUT: 6.0 OLD PROB: 18.0 POH MW: 9.9 NaCl/Br REVERSE CIRC. FILTER BRINE. POH SLM. MADE UP 4-3/4 BIT RIH TO 12158. COULD NOT ENTER SBR. CBU. POH. MADE UP 4-1/8 BIT. RIH. SLIP & CUT DRILLING ILNE. RIH TO 12158' WORK INTO SBR, ROTATED AT 12215. COULD NOT MAKE ANY HOLE. POH. (176209) DAILY: $ 89,935 CUM: $ 396,975 EFC: $ 1,260,000 ACTIVITY SUMMARY for WELL ~ROJECT 176209 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : 2-06/J-22 Page: 2 DRLG RIG : DOYON 15 WO/COMP RIG: DOYON 15 (COMP) OLD PROB: 0.5 OTHER: 8.5 RUN COMP: 15.0 10/23/91 (-- 9) FILTERING BRINE -- MW: 9.9 NaC1/Br TD:13265 POH. SER. RIG. RIH. POH - LAYING DOWN 5" & 2-7/8" DP. PB:13164 PULL WEAR BUSHING & CHANGE RAMS TO 7" RIG UP & RUN 7" SUPV:MCH TUBING 7" 26# NSCC 307 JTS. STAB OVER SBR - RIG UP & TEST SAME TO 1000# TO ENSURE SEAL OK. RIG UP & FILTER BRINE. (176209) DAILY: $ 40,385 CUM: $ 437,360 EFC: $ 1,260,000 (COMP) OLD PROB: 24.0 10/24/91 (--10) MW: 9.9 NaCl/Br TD:13265 CIRC & FILTER BRINE. SPACE OUT AMKE UP TUBING HANGER & PB:13164 TEST SAME. LAND 7" TUBING & RIG DOWN CASING TOOLS & OTIS. SUPV:MCH RIG UP CASING TOOLS - PULL & LAND HANGER. LAND SAME & TEST TO 1000#. RIG UP OTIS & TEST LIBRICATOR. RIH WITH SLICK LINE & RECOVER DUMMY VALVE. RIH TO X-NIPPLE AT 12229 WITH SPEAR - PULLED OUT RIH WITH GS PULLING TOOL POH - RIH WITH GR PULLING TOOL - NO SUCCESS. POH RIG DOWN OTIS & RIGH DOWN SHOOTING FLANGE. (176209) DAILY: $ 57,401 CUM: $ 494,761 EFC: $ 1,260,000 (COMP) OLD PROB: 24.0 10/25/91 (11) RIH W/ 8-1/8 BWN OVERSHOT TD:13265 RIH WITH FISHING ASSEMBLY PB:13164 SUPV:MCH (176209) DAILY: $ 62,426 CUM: $ MW: 9.9 NaCl/Br 557,187 EFC: $ 1,260,000 (COMP) PL PBR: 24.0 10/26/91 (12) TD:13265 PB:13164 SUPV:MCH RIH MW: 9.9 NaC1/Br RIH W/OVERSHOT. NO RECOVERY. RIH W/FISHING ASSY. CBU. POH. RIH W/5" STABILIZER. (176209) DAILY: $ 55,980 CUM: $ 613,167 EFC: $ 1,260,000 (COMP) CLN OUT: 24.0 10/27/91 (--13) RIH W/MILL & PRT MW: 9.9 NaCl/Br TD:13265 RIH TO PACKER @ 12175' RIH W/WIRELINE PERF GUNS. PB:13164 PERFORATE 12198'-12203~ 12204'-12208', 34 HOLES CBU , · . SUPV:MCH RIH DOWN SCHLUMBERGER. CBU, POH. RIH TO MILL PACKER. (176209) DAILY: $ 67,069 CUM: $ 680,236 EFC: $ 1,260,000 (COMP) CLN OUT: 22.0 TEST CSG: 2.0 10/28/91 (--14) POH W/P--ACKER MW: 9.9 NaC1/Br TD:13265 POH W/PACKER & TAILPIPE. RIH W/PACKER. CBU. TEST 7" PB:13164 LINER LAP TO 4000#. POH. SUPV:MCH (176209) DAILY: $ 278,426 CUM: $ 958,662 EFC: $ 1,260,000 (COMP) CLN OUT: 24.0 10/29/91 (--15) FILTERING BRINE MW: 9.9 NaC1/Br TD:13265 POH, LD PKR & SCRAPER, SER RIG RIH W/ BIT DCS & DP,WASH PB:13164 F/12389' TO 13114',CBU FILTERING R BRINE. SUPV:MCH (176209) DAILY: $ 47,020 CUM: $ 1,005,682 EFC: $ 1,260,000 ACTIVIT. Y SUMMARY for WELL ~ROJECT 176209 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : 2-06/J-22 Page: 3 DRLG RIG : DOYON 15 WO/COMP RIG: DOYON 15 (COMP) CLN OUT: 24.0 10/30/91 (--16) CHANGE RAMS MW: 9.9 NaCl/Br TD:13265 RIH. CBU. R/U SCHLUMBERGER. RIH W/GAUGE RING TO 12389' PB:13164 POH W/SAME. CHANGE OUT TOP RAMS TO 7" SUPV:MCH (176209) DAILY: $ 84,318 CUM: $ 1,090,000 EFC: $ 1,260,000 (COMP) OTHER: 13.0 RUN COMP: 11.0 10/31/91 (17) RIH--W.PLUG MW: 9.9 NaCl/Br TD:13265 PULL WEAR RING. CUT DRILLING LINE, SERVICE RIG. RIG UP PB:13164 AND RUN 7" TUBING. LAND TUBING. RIH W/PLUG ON WIRELINE. SUPV:JBS (176209) DAILY: $ 51,154 CUM: $ 1,141,154 EFC: $ 1,260,000 11/01/91 (18) TD:13265 PB:13164 SUPV:JBS (COMP) NU ND: 5.0 RUN COMP: 19.0 NU A--DAPTER FLANGE MW: 9.9 NaCl/Br RIH W/PLUG. SET PLUG, POH. RIH, SET SLEEVE IN SSSV NIPPLE, POH. SET AND TEST PACKER. P/U LANDING JOINT, SHEAR OFF SBR. P/U TUBING, HOOK UP CONTROL LINES AND LAND TUBING. TEST TUBING TO 3000 PSI, TEST WITNESSED BY AOGCC. ND BOP'S, NU ADAPTER FLANGE. (176209) DAILY: $ 73,863 CUM: $ 1,215,017 EFC: $ 1,260,000 11/02/91 (19) TD:13265 PB:13164 SUPV:JBS (COMP) NU ND: 11.0 OTHER: 7.5 TEST CSG: 1.5 RELEASE RIG @2000--HRS 11-1-91 MW: 9.9 NaCl/Br NIPPLE UP ADAPTER FLANGE. NU/ND MASTER VALVE AND TEST. PULL 2 WAY CHECK. RIH, OPEN SLIDING SLEEVE. DISPLACE WELL TO DIESEL AND U-TUBE. CLOSE SLIDING SLEEVE. TEST ANNULUS TO 2500 PSI, TEST TUBING TO 3000 PSI. SET 2 WAY CHECK. RELEASE RIG AT 2000 HRS 11-1-91. (176209) DAILY: $ 178,361 CUM: $ 1,393,378 EFC: $ 1,260,000 0 R I G IN A ALAb~A OIL AND GAS CONSERVATION COMMISS~vN 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: 6. Datum elevation (DF or KB) BP Exploration (Alaska) inc. Development KBE 53.20 feet Exploratory 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service ~( Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 1852,'SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202'SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1230' SNL, 5190' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 2-06/J-22 MPI 9. Permit number/approval number 87-18/92-013 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13265feet 10189 BKBfeet 13164feet 10112 BKBfeet Plugs (measured) Junk (measured) Length Size Cemented M easu r,.,e,d.,.,d e pt h 2461' 13 3/8" 2700 cu. fl. Permafrost 2502' 12639' 9 5/8' 575 cu. ft. Class "G" 12680' 862' 7" 357 cu. ft. Class "G" 12403'- 13265' measured 12724'- 12758', 12768'- 12810', 12816'- 12860' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9827' Tubing (size, grade, and measured depth) 7" 26,~/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 5 1/2' Packer at 12238'MD; SSSV at 1541' MD 13. Stimulation or cement squeeze summary True ver~ depth 2498' 974O' 9475'- 10135' RECEIVE[ JUN 2 6 7992 Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. C0mm ;Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 57657 127727 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Gas In/ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sicjned~/7-.~ ~. ~-~-:~ Title Endicott Senior Technical Assistant ll Date~-~/~_ Form 10-/~J:~'4 Rev 06/15/88 SUBMIT IN DOPLIC'ATE ;sion Endicott Production Engineering Department DATE: 4/23/92 WELL NM: 2-06/J-22 BP EXPLORATION REP: SERVICE COMPANY: Reuerforate Luedke-Chan HLS/Little Red/Peak DATE/TIME I OI;ERATIONS SUMMARY 0800 RU. Post radio silence signs at the entrance to island and next to well site. Install SSV fusible cap. SIWHP = 1500 psig. IAP = 0 psig. OAP = 0 psig. 0930 RU Little Red and pressure test lubricator to 4000 psi. 1015 Pump 560 bbl SW + 7 bbl MEOH. 1245 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 1405 RIH with Gun #1 (20 feet). SIWHP = 1100 psig. 1450 Tie in to CBL dated 3-29-87. The CBT is one foot deep to the open hole reference log (DLL-GR 3-25-87). All of the depths listed below are from the open hole reference log. Flag line for next run. SIWHP = 1150 pslg. 1500 Hang. ,gun #1 Top Shot at 12840 MDBKB. 1504 Shoot nun gl from 12840'-12860' MDBKB. SIWHP = 1150 psig. 1510 Log collars through sliding sleeve ~ 12,202' while POOH. 1615 RIH with Gun #2 (20 feet). SIWHP = 1150 pslg. 1650 Tie in to CBT logging up. Shoot gun # 2 from 12820'-12840' MDBKB. SIWHP = 1150 psig. POOH. 1800 RIH with Gun #3 (22 feet). SIWHP = 1150 psig. 1847 Tie in to CBT logging up. Shoot gun # 3 from 12808'-12820' MDBKB. SIWHP = 1150 psig. POOH. 1945 RIH with Gun #4 (20 feet). SIWHP = 1200 psig. 2030 Tie in to CBT logging up. Shoot gun # 4 from 12788-12808' MDBKB. SIWHP = 1200 psig. POOH. 2130 RIH with Gun #5 (20 feet). SIWHP = 1475 psig. 2235 Tie in to CBT logging up. Shoot gun # 5 from 12768'-12888' MDBKB. SIWHP = 1500 psig. POOH. SIWHP = 1600 psi & rising. 2330 Pump 307 bbl SW + 7 bbl MEOH. SIWHP = 800 psi. 0100 RIH with Gun #6 (20 feet). SIWHP = 900 psig. 0200 Tie in to CBT logging up. Shoot gun # 6 from 12738'-12758' MDBKB. SIWHP = 900 psig. POOH. 0300 RIH with Gun #7 (14 feet). SIWHP = 1100 psig. 0405 Tie in to CBT logging up. Shoot gun # 7 from 12724'-12738' MDBKB. SIWHP = 1450 psig. POOH. 477 out of 480 shots fired. 0530 End radio silence. Final SIWHP = 1600 psi. 0530 RD. Turn over to Mike and ACT, etc. for mud acid job. .. PERFORATION SUMMARY: GUN INTERVAL(DLL) CBL DEPTH FEET ~ 1-3 12816-12860 12817-12861 44 2A! 3-5 12768-12810 12769-12811 42 2A3 6-7 12724-12758 12725-12759 34 2A3 All intervals were shot using 4" guns at 4 spf, 90 degree phasing and 45 deg. orientation, with 36 gram charges. RECEIVED JUN 2 6 1992 Alaska Oil & Gas Cons. Comraissio~ Anchorage STATE OF ALASKA ALAo,,A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging.__ Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202'SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1230' SNL, 5190' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E RECEIVED JUN 2 6 992 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) KBE 53.20 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number/approval number 87-18/92-105 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 13265feet 10189 BKBfeet 13164feet 10112 BKBfeet Plugs (measured) Junk (measured) Length Size Cemented Measu~/~.Bdepth True ve~ depth 2461' 13 3/8" 2700 cu. fl. Permafrost 2502' 2498' 12639' 9 5/8" 575 cu. fl. Class "G" 12680' 9740' 862' 7" 357 cu. ft. Class "G" 12403'- 13265' 12724'- 12758', 12768'- 12810', 12816'- 12860' (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9827' 9425'- 10135' Tubing (size, grade, and measured depth) 7" 26~/ft IJ4S tubing with 5 1/2" tailpipe to 12286' Packers and SSSV (type and measured depth) 5 1/2" Packer at 12238'MD; SSSV at 1541'MD 13. Stimulation or cement squeeze summary Mud acid stimulation Intervals treated (measured) 12724'- 12758', 12768'- 12810', 12816'- 12860' Treatment description including volumes used and final pressure 74 Bbls methanol, 58 Bbls 6% HCl acid, 117 Bbls. 6% - 1.5% Mud acid, 120 Bbls 2% NH~Cl and 83 Bbls Seawater 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 57657 127727 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereb_y certify that the foregoing is true and correct to the best of my knowledge. S i~lned~~f~.,~ ~ ~-~, ~Y~~ Title Endicott Senior Technical Assistant II Date SUBMIT IN DOP~ICATE Form 10~{~4 Rev 06/15/88 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X . Change approved program X Pull tubing ~ Variance~ Perforate ;~ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E 6. Datum elevation (DF or KB) KBE 53.2O 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MPI 9. Permit number 87-18 10. APl number 50-029-21699 At effective depth 1230' SNL, 5190' WEL, Sec. 32, T12N, R17E At total depth 1241'SNL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical 13265 feet 10189 BKB feet Plugs (measured) 11. Field/Pool Endicott Pool feet Effective depth: measured true vertical 13164 feet 10112 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured de~/~ TrUeBV/~ical depth 120' 30" Drive Pipe 161' 161' 2461' 13 3/8" 2700 cu. fl. Permafrost 2502' 2498' 12639' 9 5/8" 575 cu. fl. Class "G" 12680' 9740' 862' 7" 357 cu. ft. Class "G" measured 12724'- 12758', 12768'- 12810', 12816'- 12860' 12403'- 13265' 9475'- 10135' RECE[¥ED true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9827' Tubing (size, grade, and measured depth) 7" 26#/ft IJ4S tubing with 5 1/2" tailpipe to 12~'ka Oil & Gas Oop, s. Oo~t~t~'t$$~oQ Anch0ra~ Packers and SSSV (type and measured depth) 5 1/2" Packer at 12238'MD; SSSVat 1541'MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation I 15. Status of well classification as: April25, 1992 I 16. If pro sal was verbally approved Oil Gas Suspended~ N v Date approved I Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~'.~_.~/7~., ~? ~ Title Senior TechnicalAssistant II FOR COMMISSION USE ONLY Conditi(~of approval: Notify Commission so representative may witness ~ Approval No. Plug integrity BOP Test Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- OR)G!NAL SIGNED BY . ..¢', I..-...c/_~___ tM . . Approved by order of the Commission 1 f~N,, IE C. SMITH Commissioner Date Form 10-403 Rev 06/15/68 SUBMIT IN TRIPLICAT~~,x 2-06/J-22 Perfs and Stimulation 1. Following immediately upon wellhead valve repair, pull the SSSV and run a dummy gun to TD to ensure the perforations are accessible. 2. While well is loaded, perforate the following intervals at 6 spf (ref: DLL/GR 3/25/87): ~ Irten/eJ feet 2A3 12724-12758 34 2A3 12768-12810 42 2A3 12816-12860 44 At some point during the gun runs, get a corrected TD tag for the purpose of later tying in the coiled tubing. . MIRU coiled tubing with 2 check valves, large swirl nozzle (minimum ID is 4.455" at the 5-1/2" XN tailpipe valve) and flanged BOPs. Isolate the SSV with fusible cap. Function and pressure test the BOPs. Pressure test the coil to 4000 psi. RIH pumping water to ensure that annulus remains liquid packed during treatment. . MIRU stimulation company. Isolate the SSV with a fusible cap. Ensure acid transports are rolled continuously. Pull acid samples and visually inspect for suspended solids. Ensure Fe conc. are less than 350 ppm. Check acid to ensure acceptable concentration. 6% HCI, acceptable conc. 4 - 7% 6% / 1.5% mud acid, acceptable conc. 4 - 7%HCI, 0.75 - 1.5%HF 5. Tag PBTD while pumping at minimum rate and correct coil depths to E-line measurement. . Pump the following fluids at maximum allowable coil pressure (3800 psi). Filter all fluids on the fly to 3tz. Reciprocate across the perforations (12860'MD - 12724'MD = 136' gross interval, 120' of peals). Pump additional SW down the backside (tubing x coil) as necessary to maintain liquid packing. Consider displacing the coil with SW so that pumping can be continued on the way out of the hole, keeping the checks open and pressure equalized. a. 60 bbls 6% HCI b. 120 bbls 6% / 1-1/2% mud acid (42 gal/ft) c. 120 bbls 2% NH4CI ovedlush d. Displace coil 7. POOH while pumping at minumum rate down the coil. When approaching surface, displace the coil over to methanol. RDMO. . Return the well to gas injection as quickly as possible to fracture the well and push insoluble solids away from the near wellbore region. Put the well on trend and report observations of well response. Fluid Summary l~,-~.r~, r,.~o~, t~t~:~, rc=-f~;. Fluid Additive Conc. D/S I~1 Titan Halliburton 6% HCI (70 bbls) Corr. lnhib. 0.2-0.3% A-250 Ci-25 HAl-85 Surfactant 0.2% F-75N NE-18 Losurf-300 Iron Control Per IV!g.?_l 25# L58 25# Ferrotrol-210 54# Fercheck-A 6% HCl/1.5% HF Corr. lnhib. 0.2-0.3% A-250 Ci-25 HAl-85 (120 bbls) Surfactant 0.2% F-75N NE-18 Losu rf-300 Iron Control Per Mqal ~5~ L58 25# Ferrotrol-210 54# Fercheck-A 2% NH4CI (120 bbls) Surfactant 02% F-ZION I~-11~ Losurf-300 NOTE: If using DS, request the MISCAll system for HCI and MA stages; it couples corrosion inhibition, iron control and sudactant in a miscible system which should improve the responsiveness of all components. prh/2546 · BASIC SYSTEM MAKEUP BOWEN PACKOFF" ~~SE SEAL FLO.W~B~. ·PUMP F'LOWLINE FLOWLINE VALVE -- GREASE LINE GREASE --MANIFOLD · . GREASE PUMP: RISER GREASE RESERVO. BOP 1. Type of Request: STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISS,tJN 0 APPLICATION FOR SUNDRY APPROVAI"S' Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program__ Pull tubing__ Variance__ Perforate X Other ;~ ,. 2. Name of Operator BP. Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 13265 feet 10189 BKB feet 13164 feet 10112 BKB feet 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 4. Location of well at surface 1852' SNL, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, Sec. 36, T12N, R17E At effective depth 1230' SNL, 5190' WEL, Sec. 32, T12N, R17E At total depth 1241' SAIL, 5127' WEL, Sec. 32, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Plugs (measured) Junk (measured) Length Size Cemented 120' 30" Drive Pipe Measured de~B 161' 6. Datum elevation (DF or KB) KBE 53.20 7. Unit or Property name Duck Island Unit/Endicott 2461' 13 3/8" 2700 cu. fl. Permafrost 12639' 9 5/8" 575 cu. ft. Class "G" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 862' 7" 357 cu. ft. C/ass "G" measured 12724'- 12758', 12768'- 12810', 12816'- 12860' true vertical (Subsea) 9721'- 9747', 9755'- 9788', 9793'- 9827' Tubing (size, grade, and measured depth) 7"26#/ft IJ4S tubing with 5 1/2" tailpipe to 12286' 8. Well number 2-06/J-22 MPI Packers and SSSV (type and measured depth) 5 1/2" Packer at 12238'MD; 9. Permit number 87-18 10. APl number 50- 029-21699 11. Field/Pool Endicott Pool 2502' 12680' 12403'-13265' Suspended __ 13. Attachments SSS V at 1541'MD Description summary of proposal X Detailed operations program __ Date approved 15. Status of well classification as: Oil Gas Service Gas Injector feet 14. Estimated date for commencing operation January 28, 1992 16. If proposal was verbally approved Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~, ~ Title Endicott Operations & Production Lead Engr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- -! 4. ORIGINAL SIGNED B~, LONNIb t'; Approved by order of the Commission Form 10-403 Rev 06/15/88 Tru eBv~ical depth 161' 2498' 9740' 9475'-1O135' RECEIVE ~laska 0il & Gas Cons. C0m AnChorage BOP sketch X Date //2.//,~ 2 D SUBMIT IN TRIPLICATE nissie ENDICOTt FIEI~D Well 2-06/J-22 The following 2A perforations will be reperforated at 6 spf while flowing gas to allow the perforation debris to be cleaned up. We request an exemption to flare 100 MMSCF of gas during this operation. 12724'- 12758' BKB (Ref. DLL, 3/25/87) 12768'- 12810' BKB (Ref. DLL, 3/25/87) 12816'- 12860' BKB (Ref. DLL, 3/25/87) A lubricator will be installed and tested to 7000 psi for all well work. The SSSV will be reinstalled and tested after the perforations are added. RECEIVED Alaska Oil & Gas Cons. Commission Anchorago il BASIC SYSTEM MAKEUP ' BOWEN PACKOFF" F~ o ~/ , .. 1~- HAND .PUMP ,~ ~o,.,.'~ ~se SEAL F,_O.W~BE. F'LOWLINE -- FLOWLINE V. ALVE GREASE LINE GREASE - MANIFOLD · . ~ GREASE PUMP: ., -- RISER GREASE RESERVO. BOP ECEIVED ,]AN ? 1 '~992 & Gas Cons. 6ommissio~ Anchorage BP EXPLORATION Rp Exp;orat~on (A,as~a) inc. 900 East Ben,son Boulevard Ancnora~e. ,A~a~a 99519-66:2 (907) 561-5111 November 12, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: Enclosed please find one sepia and one biuetine print for the well logs rUn on the following Endicott wells: Well 1-27/P-20 4/12/91 9800' - 10700' ~ Run One Perforating Record Halliburton Logging Services Well 1-69/V-19 ~'" 120' - 2O2O' ,_)~ d~ Temperature Survey Camco Well 2-06/J-22 12140' - 1 2205' Tubing Puncher Record Schlumberger 2-22/L-14 11 284' - 11700' Perforating Record Schlumberger 9/20/91 Run One 10/26/91 Run One 9/'28/'91 Run One 2063/JLH/clt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIuN APPLICATION FOR SUNDRY 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well ~ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing X Variance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1852' SNL, 2180' WEL, SEC. 36, T12N, R16E At top of productive interval 1202' SNL, 108' WEL, SEC. 31, T12N, R17E At effective depth At total depth 1241'SNL, 5127' WEL, SEC. 32, T12N, R17E 6. Datum elevation (DF or KB) KBE = 55.25 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-06/J-22 MP! 9. Permit number 87-18 10. APl number 50- 029-21699 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13265'MD feet Plugs (measured) 10189'TVD feet BKB Effective depth: measured true vertical 13164'MD feet Junk (measured) 10111'TVD feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 105' 30" 161' 2446' 13-3/8" 2700 cu ft 2502' 12624' 9-5/8" 575 cu ft 12680' 844' 7" 357 cu fl 12403'- 13247' measured 12724'-12758', 12768'-12810', 12816'-12860' true vertical (subsea) 9720'-9747', 9754'-9787', 9792'-9826' Tubing (size, grade, and measured depth) 7" L-80 to 12088', 5-1/2" tailpipe to 12178' True vertical depth BKB RECEIVED Alaska Oil & Gas Cons. C0m~iss[~n ~nchorage Packers and SSSV (type and measured depth) 9-5/8" Packer @12178', SSSV@ 1562' 13. Attachments Description summary of proposal x 14. Estimated date for commencing operation October 15, 1991 16. If proposal was verbally approved Name of approver Lonnie Smith 10-15-91 Date approved Detailed operations program ~ BOP sketch x 15. Status of well classification as: Oil Gas Service Gas Injector Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~C~-"~-~'~,JL..--- Title Senior Technical Assistant Date / ~j/r)j?} FOR COMMISSION USE ONLY /' / ' Conditions of approval: Notify Commission so representative may witness Plug integrity B(~P,'l'est Location clearance Mechanical Integrity Test_7~ Subsequent form required lO- ORIGINAL SIGNED B'~' Approved by order of the Commission ! ONNIF ~, .,qM!TN Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Ob!ective: WORKOVER 2-06/d-22 ATTAI;HMENT I Well J-22 is currently shut-in due to an inner to outer annulus communication. The well is completed with 7" tubing and a 5-1/2" tailpipe assembly. The objective of the rig workover is to pull the 7" tubing, replace the 9-5/8" packoff and recomplete the well with 7" tubing. Detailed Procedure: Move in rig. Pull BPV. Set 2-way check valve. ND tree. NU BOP and test BOP to 5000 psi. Pull 2-way check valve. Recover tubing. RIH and set test packer below mandrel packoff. Test casing and lap to 4500 psi. Set storm packer at 1000'. ND BOP and recover packoff. Install new packoff and test to 5000 psi. RIH and recover storm packer. RIH with 7" 26# NT80S completion assembly. Change over to filtered inhibited brine. Land tubing hanger. Pressure up the tubing by 9- 5/8" annulus to 2500 psi. Open sliding sleeve. Displace 100 bbls of diesel down the tubing. Connect the tubing and inner annulus and allow the diesel to U-tube. Close sliding sleeve. Retest annulus to 2500 psi, hold for 30 min. Test to be witnessed by State man. Install a 6" BPV in the tubing hanger. ND BOP and NU tree and test. Insure that the tree and annulus valves are freeze protected with diesel and that all wellhead and tree accessories have been installed. Close annulus and tree valves. Release Rig. A1~sk~ 0il & G~s Cons. Commts~,,,t~ BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRI PLE RAM STACK WORKO VER RISER ANNULAR PREVENTER P l PE RAMS 2" KILL LINE I i ' i PI PE RAMS MANUAL HYDRAULIC GATE GATE DRILLING SPOOL I BLIND RAMS I 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE ! WELL5-03/SAG DELTA #9 I,/*PRODUCTION PROFILE 11100' - 12214' Run No. 1 CAMCO WELL 3-47/Q-35 t.,,/~PRODUCTION PROFILE LOG 10000' - 10500' Run No. 2 CAMCO WELL 2-52/S-14 ~:~PRODUCTION LOGGING SEP, VICES 11600' - 12200' ATLAS WIRELINE SERVICES; I~PRESSURE DATA GRADIENT/PBU HP/TEMPERATURE '- 11600' - 12662 Run No. 1 ATLAS WiRELINE SERVICES · .~'ELL 4-48/K-43 *ELECTROMAGNETIC WAVE RESISTIVITY *DUAL GAMMA RAY 16050' - 16292' Run No. 1 16292' - 16510' Run No. 3 SPERRY- SUN DRILLING SERVICES ' *~DUAL GAMMA RAY *COMPENSATED NEUTRON POROSITY *SIMULTANEOUS FORMATION DENSITY 16050' - 16292' Run NO. 1 16292' - 16510' Run No. 3 SPERRY-SUN DRILLING SERVICES ~'I~uAL GAMMA.RAY-/' *COMPENSATED NEUTRON POROSITY 15490' - 16040' Run' No. 1 SPERRY- SUN DRILLING SERVICES WELL 2-06/J-22 ~,~rPRODUCTION PROFILE .'I'EMP WARMBACK 12550' - 12865' Run No. 1 CAMCO ' RECEIVED JAN Alaska 0i! ~' ~s Cons. Commission Anchorage Standard Alaska ~-~ Production Compar 900 East Benson Bou .rd P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 564-511 t JUN 17, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia and blueline print for: J-22 Run 1 May 19, 1987 * Collar and Perforating Log Sincerely, Received / ' ~ ~ b r/~ '- A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. .... STATE OF ALASKA ALASKA .LAND GAS CONSERVATION C( ,MISSION WELL COMPLETION OR RECOMPLETION I:IEPORT AND LOG [' 1. Status of Well Classification of Service Well OIL ~-,~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Gas Suppl¥/Tnjection Well , , 2. Name of Operator 7. Permit Number Standard Alaska Production Company 87-18 ' 3. Address 8. APl Number P.O. Box 196612 Anchorage, Alaska 99519-6612 50- 029-21699 '4. Location of well at surface 9. Unit or Lease Name 1852' SNL, 2180' WEL, Sec 36, T12N, R16E ...Duck Island Unit/ Endicott At Top Producing Interval 10. Well Number 1202' SNL, 108' WEL, Sec 31, T12N, R17E 2-6/J-22 MPI At Total Depth 11. Field and Pool . 1241' SNL, 5127'WEL, Sec. 3.2, T12N, R17E Endicott Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Endicott Pool KBE = 55.25'I ADL 312828 12. Date Spudded 13. Date T.D. Reached 14. D.ate .Comp., Susp. or Aband. [ 15. Water Depth, if offshore 16. No. of Completions 2-25-87 3-25-87 5-20-87 .N/A feet MSL one 17. Total Depth (M D+TVD)18. Plug Back Depth (MD+TVD)19. Directional Survey I sssv,ot 13265 ' MD 10189 ' TViD13164 ' MD 10111' TVDYES ~ NO [] 1562 feet MD 1466 ' 22. Type Electric or Other Logs Run DLL/MSFL, CNL, CBT, CET, GCT 23. CASING, LINER AND CEMENTING RECORD .. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 30" Stru(:tural Dr:Lye Pi~e Rurf~ 13-3/8" 68~ L-80Butt Rurfsc_~ ~.502 ' ] 7%" 2700 ~.]]. ft__ pe.r~fr~ ~t. 9-5/8" I 47# NTRO.q .~l]r fa~-~- ] 0748 ' ] 2¼" 9-5/8" 43.~. NT95HS 10748' 12680' ]2%" 575 cu_ft_ Class G . ?5% CFR-2+.25%HR-J 7" 29#I SMll0 12403' 132~ ' 8%" 357 cu. ft_ 24. Perforations opmn to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD 0 2% CFR-2 interval, size ~'~umber) MD TVDss S!..ZE DEPTH SET (MD) pACKER SET (MD) Endicott Oil Pool Top: 12724' 9720' 7" L-80 IJ4.~ 12310"MD 12178'MD ..,~. BOttom: 12860 ' 9826 ' 26# 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. 1~2724'-1275,~3~ MD BRT (9720'-9747'TVDss) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 12768'--12810' MD BRT (9754'-9787'TVDss) 13-3/8" x 9~.5/8" Downsqueeze 13-3/8" x 9-5/8" 12816'-128~0' MD BRT (9792'-9826'TVDss) .~ annulus with ~45 skil Permafr( ~, followed by 115 bbls dry tcru~. 27. PRODUCTION TEST : Date First Productlo~ I Me~hod of Operation (Flowing, gas lift, etc.) · I , Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF wATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,k OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (co'r) Press. 24-HOUR RATE "F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips· LWL ~t Form 10~407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~,..; GEOI~OG'IC-.MA'I~KE.I~S i.,';" · ~'. :~ ' :i i~' .... ' ' :.. ?'FORMA]~'IbN'TESTS · NAME SS; Include interval tested, pressure data, all fluids recovered and gravity, MEAS. ·DEPTH TRUE vERT. DEPTH GOR, and time .of-each phase. Top HRZ 12334' 9425' LCU 12701 ' 9703 ' Top KEKIKTUK 12701' . 9702 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Division ) Drilling /~/ Signed (~, ~, ~ TitleEngine'er Date - 3 INSTRUCTIONS General' This form is' designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ~TANDARD ALASKA PRODUCTION COMPANY DRILLING DEPARTMENT DALLY P.E. REPORT = ENDICOTT 2400 HRS TO 0600 HRS, 5-20-87 WELL: 2-05/J-22 (MPI) OPERATIONS: Perforate and flow well thru test separator. STANDARD ALASKA PRODUCTION COMPANY DRILLING DEPARTMENT DAILY P.E. REPORT = ENDICOTT 0001 HRS TO 2400 HRS- 5-20-87 WELL: 2-06/J-22 (MPI) OPERATIONS: Complete perforating operations. Flow well to clean up. Flare gas at 9.0 MMSCF/day on 20/64" choke. Flowing WHP = 3280 psi. $ UB.$ URFA CE DIRECTIONAL SURVEY F~UIDANCE [~ ONTINUOUS r"~ OOL Company STANDARD ALASKA Well Name 2-6/J-22 MPI (1852' Field/Location ENDICOTT, NORTH PRODUCTION COMPANY SNL,2180' WEL~SEC 36,T12N,R16E) SLOPEt ALASKA Job Reference No. 72262 Log:ed SARBER Date ,, 02-APR-87 Computed By; SINES SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE~ALASKA SURVEY DATE: 2-APR-87 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPGLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 85 DEG 0 MIN EAST COMPUTATION DATE: 8-APR-87 PAGE I STANDARD ALASKA PRODUCTION C0. 2-6/J-22 ENDICOTT NORTH SLOPE~ALASKA DATE DF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.25 PT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET PEET DEG MIN 0.00 0.00 -55.25 0 0 N 0 0 E 100.00 100.00 44.75 0 44 N 47 14 E 200.00 199.99 144.74 0 33 N 51 17 E 300.00 299.99 244.74 0 41 N 63 33 E 400.00 399.98 344.73 0 46 N 72 30 E 500.00 499.97 444.72 1 2 N 79 44 E 600.00 599.93 544.68 1 56 S 86 5 E 700.00 699.84 644.59 3 3 S 78 30 E 800.00 799.63 744.38 4 12 S 78 43 E 900.00 899.35 844.10 4 17 S 78 46 E 0.00 0.00 0.00 N 0.00 0.32 0.25 0.27 N 0.30 1.19 0.20 0.95 N 1.11 2.09 0.20 1.53 N 1.96 3.34 0.16 2.01 N 3.17 4.82 0.63 2.37 N 4.63 7.41 0.98 2.5I N 7.22 11.46 1.67 1.84 N 11.35 17.71 0.40 0.50 N 17.74 24.88 0.14 0.95 S 25.06 O.O0 N 0 0 E 0.40 N 48 7 E 1.46 N 49 29 ~ 2.49 N 52 2 E 3.75 N 57 43 E 5.10 N 62 54 ~ 7.65 N 70 48 11.50 N 80 47 ~ 17.75 N 88 23 25.08 S 87 49 E 1000.00 999.07 943.82 1100.00 1098.81 1043.56 1200.00 1198.58 1143.33 1300.00 1298.40 1243.15 1400.00 1398.24 1342.99 1500.00 1498.11 1442.86 1600.00 1597.98 1542.73 1700.00 1697.87 1642.62 1800.00 1797.75 1742.50 1900.00 1897.64 1842.39 4 12 S 79 6 E 4 I S 78 20 E 3 37 S 76 37 E 3 22 S 75 37 E 3 4 S 76 2 E 2 54 S 74 53 E 2 45 S 75 8 E 2 42 S 74 25 E 246 S 75 11E 2 47 S 74 51 E 32.01 0.22 2.40 S 32.34 E 38.96 0.52 3.83 S 39.44 f 45.34 0.43 5.25 S 45.97 E 51.05 0.13 6.67 S 51.83 E 56.40 0.50 8.05 S 57.32 E 61.31 0.30 9.37 S 62.36 E 65.93 0.17 10.77 S 67.1Z E 70.39 0.05 12.04 S 71.71 E 74.91 0.44 13.24 S 76.35 E 79.46 0.18 14.49 S 81.03 E 32.43 S 85 44 E 39.62 S 84 27 E 46.27 S 83 29 E 52.25 S 82 40 E 57.89 S 82 0 E 63.06 S 81 27 E 67.98 S 80 53 E 72.72 S 80 28 E 77.49 S 80 9 E 82.32 S 79 51 E 2000.00 1997.52 1942.27 2100.00 2097.39 2042.14 2200.00 2197.27 2142.02 2300.00 2297.14 2241.89 2400.00 2396.99 2341.74 2500.00 2496.85 2441,60 2600.00 2596.71 2541.46 2700.00 2696.49 2641.24 2800.00 2796.06 2740.81 2900.00 2895.26 2840.01 2 49 S 74 36 E 2 51 S 73 36 E 2 55 S 73 3 E 2 59 S 71 13 E 3 2 S 70 57 E 3 1 S 68 55 E 3 12 S 70 40 E 4 22 N 88 26 E 6 16 N 79 38 E 8 10 N 77 28 E 84.04 0.29 88.69 0.07 93.37 0.27 98.13 0.13 102.95 0.14 107.78 0.22 112.58 0.77 118.98 1.97 128.12 1.85 140.60 1.40 15.80 S 85.75 E 87.19 S 79 33 17.14 S 90.5~ f 92.14 S 79 16 18.57 S 95.35 E 97.14 S 78 58 E 20.17 $ 100.27 E 102.28 S 78 37 E 21.87 S 105.26 E 107.50 S 78 15 E 23.68 S 110.26 f 112.77 S 77 52 E 25.60 S 115.25 E 118.06 S 77 28 26.48 S 121.75 E 124.60 S 77 43 25.24 S 130.82 E 133.23 S 79 4 E 22.78 S 143.13 E 144.93 S 80 57 E 3000.00 2993.99 293~.74 10 3 3100.00 3092.15 3036.90 11 56 3200.00 3189.59 3134.34 13 55 3300.00 3286.18 3230.93 16 0 3400.00 3381.82 3326.57 17 48 3500.00 3476.76 3421.51 18 42 3600.00 3570.98 3515.73 20 43 3700.00 3563.68 3608.43 23 19 3800.00 3754.47 3699.22 26 15 3900.00 3843.25 3788.00 28 34 N 74 17 E N 75 17 E N 77 28 E N 77 27 E N 74 57 E N 71 31 E N 71 ~8 E N 72 38 E N 72 26 E N 72 19 E 156.25 2.04 175.05 1.52 197.23 2.20 222.90 1.99 251.76 1.98 282.45 1.10 315.01 2.59 351.55 2.84 392.47 2.84 437.37 2.89 18.77 S 158.49 E 159.60 S 83 14 E 13.74 S 176.92 E 177.45 S 85 33 E 8.57 S 198.73 E 198.92 S 87 31 E 3.08 S 224.02 f 224.04 S 89 12 E 3.76 N 252.39 E 252.42 N 89 8 E 13.06 N 282.39 E 282.69 N 87 21 E 23.68 N 314.14 ~ 315.03 N 85 41 E 35.07 N 349.82 E 351.57 N 84 16 E 47.59 N 389.81 E 392.70 N 83 2 E 61.52 N 433.66 E 438.00 N 61 55 E COMPUTATION DATE: 8-APR-87 STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLDPE~ALASKA DATE OF SURVEY: 2-APR-87 KELLY B~SHING ELEVATION: 55.25 PT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. 'AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3929.81 3874.56 31 23 4100.00 4013.89 3958.64 34 2 4200.00 4095.42 4040.17 36 55 4300.00 4173,85 4118.60 39 42 4400.00 4248.97 4193.72 42 54 4500,00 4320.20 4264.95 46 17 4600.00 4387.09 4331.84 49 14 4700.00 4452.07 4396.82 49 34 4800.00 4516.44 4461.19 50 10 4900.00 4580.77 4525.52 49 41 N 72 19 E N 72 11 E N 72 14 E N 72 26 E N 72 47 E N 73 1E N 72 58 E N 72 53 E 486,19 2.81 538,96 2.45 595.42 '3.32 655,91 2,74 720.37 3.23 788.99 3.70 861.68 1.53 936.00 0.95 O.29 0.28 N 72 54 E 1010.83 N 72 55 E 1085.70 7b.75 N 481.33 k 487,41 N 80 56 k 93,.16 N 532.86 E 540.96 N 80 4 E 110.88 N 587.99 E 598.36 N 79 19 E 129,75 N 647.07 b 659.95 N 78 39 E 149.43 N 710.05 E 725.61 N 78 6 ~ 170,01 N 777.13 E 795.51 N 77 39 ~ 191.72 N 848.19 E 869,59 N 77 15 ']) 214.06 N 920.85 E 945.40 N 76 54 c 236.56 N 994.00 E 1021.76 N 76 36 E 259.04 N 1067.18 ~ 1098.17 N 76 21 E 5000.00 4645.55 4590.30 49 40 5100.00 4710.25 4655.00 49 36 5200.00 4774.97 4719.72 49 42 5300.00 4839.66 4784.41 49 38 5400.00 4904,61 4849.36 49 24 5500.00 4969.92 4914.67 49 7 5600.00 5035.20 4979.95 49 7 5700.00 5101.34 5046.09 47 57 5800.00 5168.52 5113,27 47 37 $900.00 5236,33 5181.08 47 2 N 72 52 E 1160.18 N 72 46 E 1234.73 N 72 33 E 1309.20 N 72 33 E 1383.65 N 73 1 E 1457.97 N 72 52 E 1532.05 N 72 46 E 1606.10 N 75 0 E 1679.53 N 79 48 E 1752.92 N 85 0 E 1826.31 0.29 0.52 0.18 0.67 0.39 0.51 1.05 3.80 4.21 3.81 281.44 N 1139.99 E 1174.12 N 76 7 ff 303.93 N 1212.86 E 1150.36 N 75 55 e 326.63 N 1285.63 E 1326.47 N 75 44 E 349.55 N 1358.36 E 1402,61 N 75 34 E 372.00 N 1431.00 E 1478.56 N 75 25 E 394.16 N 1503.42 E 1554.23 N 75 18 E 416.55 N 1575.79 E 1629.91 N 75 11 E 438.12 N 1647.62 E 1704,87 N 75 6 E 454.31 N 1719.87 E 1778.86 N 75 12 E 463.95 N 1792.69 E 1851.76 N 75 29 E 6000.00 5304,50 5249.25 47 14 6100.00 5371.92 5316.67 47 58 6200.00 5438.42 5383.17 48 38 6300.00 5504.27 5449.02 48 52 6400.00 5570.02 5514.77 49 8 6500.00 5634.98 5579.73 49 45 6600.00 5699.26 5~44.01 50 12 6700.00 5763.08 5707.83 50 23 6800.00 5826.83 5771.58 50 20 6900.00 5890.78 5835.53 50 6 N 87 28 E 1899.43 N 87 32 E 1973.21 N 87 33 E 2047.82 N 87 39 E 2123.00 N 87 43 E 2198.26 N 87 48 E 2274.21 N 87 55 E 2350.71 N 87 58 E 2427.59 N 87 58 E 2504.53 N 88 5 E 2581.30 0.68 0.73 0.35 0.38 0.87 0.60 0.46 0.16 0.52 0.50 468.08 N 1865.74 f 1923.5~ N 75 54 E 471.26 N 1939.52 E 1995.95 N 76 20 E 474.46 N 2014.14 E 2069.27 N 76 44 E 477.62 N 2089.32 ~ 2143.22 N 77 7 ~ 480.63 N 2164.61 E 2217.32 N 77 28 E 483.62 N 2240.5~ f 2292.18 N 77 49 E 486.46 N 2317.I~ E 2367.64 N 78 8 489.20 N 2394.07 E Z443.54 N 78 27 491.96 N 2471.06 E 2519.56 N 78 44 E 494.62 N 2547.89 E 2595.46 N 79 0 E TO00.O0 5955.12 5899.87 49 36 7100.00 6020.49 5965.24 48 58 7200.00 6086.02 6030.77 49 5 7300.00 6151.49 6096.24 49 6 7400.00 6216.88 6161.63 49 12 7500.00 6282.23 6226.98 49 10 7600.00 6347.50 6292.25 49 21 7700,00 6412.60 6357.35 49 36 7800.00 6477.10 6421.85 49 56 7900.00 6541.38 6486.13 50 8 N 88 19 E 2657.74 N 88 42 E 2733.27 N 89 16 E 2808.63 N 89 20 E 2884.00 N 89 23 E 2959.44 N 89 36 E 3034.90 N 89 35 E 3110.41 N 89 51E 3186.07 S 89 34 E 3262.18 S 89 23 E 3338.42 0.84 0.44 0.22 0.11 0.17 0.16 0.07 0.96 0.24 0.70 4~7.04 N 2624.42 E 2671.06 N 79 16 E 499.02 N 2700.06 e 2745.78 N 79 31 E 500.28 N 2775.59 E 2820.31 N 79 46 E 501.16 N 2851.17 E 2894.08 N 80 1 E 502.03 N 2926.8~ E 2969.56 N 80 16 E 502.70 N 3002.51 E 3044.30 N 80 29 k 503.22 N 3078.27 E 3119.12 N 80 42 E 503.65 N 3154.18 ~ 3194.13 N 80 55 E 503.41 N 3230.59 E 3269.58 N 81 8 E 502.72 N 3307.19 E 3345.18 N 81 21 E COMPUTATION DATE= 8-APR-87 PAGE STANDARO ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALASKA DATE OF SURVEY: 2-APR-87 KELLY BUSHING ELEYAT[ON: 55.25 PT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COOROINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6605.21 6549.96 50 22 8100.00 6668.79 6613.54 50 28 8200.00 6732.69 6677.44 50 17 8300.00 6796.41 6741.16 50 26 8400.00 6860.46 6805.21 49 23 8500.00 6927.04 6871.79 47 14 8600.00 6995.47 6940.22 46 46 8700.00 7063.88 7008.63 47 0 8800.00 7131.89 7076.64 47 Il 8900.00 7199.65 7144.40 47 16 S 89 10 E 3415.02 S 88 59 E 3491.80 S 88 45 E 3568.27 S 88 34 E 3644.88 S 89 43 E 3721.21 N 86 45 E 3795.67 N 85 6 E 3868.58 N 85 9 E 3941.52 N 65 2 E 4014.83 N 84 50 E 4088.38 0.23 1.37 0.49 0.09 3.26 3.23 0.62 0.80 0.37 0.45 501.77 N 3384.17 E 5421.16 N 81 33 E 500.53 N 3461.34 E 5497.35 N 81 46 E 499.00 N 3538.25 E 3573.26 N 81 58 E 497.12 N 3615.30 E 36~9o33 N 82 10 E 495.62 N 3692.07 E 3725.19 N 82 21 E 497.59 N 3766.63 E 3799.36 N 82 28 ~ 503.23 N 3~39.35 E 5872.17 N 82 31 509.44 N 3912.00 E 3945.03 N 8l 34 515.67 N 3985.05 E 4018.27 N 82 37 E 522.13 N 4058.31 E 4091.76 N 82 40 E 9000.00 7267.49 7212.24 47 17 9100.00 7334.90 7279.65 47 58 9200.00 7402.18 7346.93 47 34 9300.00 7469.41 7414.16 48 1 9400.00 7536.27 7481.02 48 0 9500.00 7602.69 7547.44 48 50 9600.00 7668.57 7613.32 48 33 9700.00 7734.19 7678.94 49 16 9800.00 7799.47 7744.22 49 25 9900.00 7864.29 7809.04' 49 42 N 84 42 E 4161.85 N 84 40 E 4235.72 N 84 20 E 4309.68 N 84 20 E 4383.72 N 84 16 E 4458.06 N 84 11 E 4532.83 N 84 13 E 4608.05 N 84 18 E 4683.49 N 84 27 E 4759.23 N 84 44 E 4835.38 0.04 0.49 0.36 0.27 0.44 0.6b 0.13 0.10 0.96 0.64 528.85 N 4131.4~ E 4165.19 N 82 42 E 535.67 N 4205.03 E 4239.01 N 82 44 E 542.75 N 4278.66 E 4312.95 N 82 46 E 550.06 N 4352.34 E 4386.96 N 82 47 E 557.41 N 4426.32 E 4461.28 N 82 49 E 564.93 N 4500.72 E 4536.03 N 82 50 E 572.54 N 4575.56 E ~611oZ4 N 82 52 E 580.07 N 4650.63 E 4686.67 N 82 53 E 587.51 N 4726.01 E ~762.38 N 82 54 E 594.67 N 4801.8l E 4838.51 N 82 56 E 10000.00 7928.85 7873.60 49 49 10100.00 7993.14 7937.89 50 7 10200.00 8057.21 8001.96 50 10 10300.00 8121.33 8066.08 50 8 10400.00 8185.45 8130.20 50 4 10500.00 8249.65 8194.40 50 0 10600.00 8313.93 8258.68 49 57 10700.00 8378.45 8323.20 49 43 10800.00 8443.18 8387.93 49 39 10900.00 8508,15 8452.90 49 14 N 84 ~3 E 4911.75 N 84 52 E 4988.34 N 85 15 E 5065.13 N 85 43 E 5141.86 N 86 4 E 5218.58 N 86 24 E 5295.24 N 86 27 E 5371.81 N 86 46 E 54~8.18 N 87 6 E 55Z4.37 N 87 37 E 5600.33 0.31 0.28 0.50 0.43 0.18 0.20 0.17 0.37 0.33 0.56 601.66 N 4877.87 E 4914.84 N 8Z 58 E 608.64 N 4954.15 E 4991.59 N 82 59 E 615.27 N 5030.64 E 5068.I3 N 83 1 E 621.30 N 5107.14 E 5144.80 N 83 3 E 626.76 N 5183.6~ E 52Z1.43 N 83 6 E 631.79 N 5260.20 E ~298.00 N 83 9 E 636.55 N 5336.63 E 5374.46 N 83 11 r 641.10 N 5412.90 E 5450.73 N 83 14 645.15 N 5689.03 E 5526.81 N 83 17 ~ 648.65 N 5564.97 E 5602.64 N 83 Zl E 11000.00 8573.67 8518.42 48 56 11100.00 8639.54 8584.29 48 39 11200.00 8705.78 8650.53 48 25 11300.00 8772.21 8716.96 48 23 11400.00 8838.58 8783.33 48 26 11500.00 8904.99 8849.74 48 21 11600.00 8971.42 8916.17 48 23 11700.00 9038.03 898Z.78 48 4 11800.00 9105.19 9049.94 47 37 11900.00 9172.78 9117.53 47 1Z N 87 49 E 5675.78 N 88 7 E 5750.92 N 88 7 E 5825.72 N 88 5 E 5900.36 N 88 0 E 5975.05 N 88 0 E 6049.72 N 88 6 E 6124.36 N 88 30 E 6198.82 N 89 0 E 6272.76 N 89 32 E 6346.24 0.36 0.47 0.18 0.28 0.12 0.04 0.51 0.43 0.37 0.66 651.65 N 5640.45 E 5677.97 N 83 24 k 654.32 N 5715.6~ E b752.97 N 83 28 E 656.73 N 5790.52 E 5827.64 N 83 31 E 659.23 N 5865.22 E 5902.15 N 83 35 E 661.76 N 5939.98 k 5976.73 N 83 38 E 664.37 N 6014.70 E 6051.28 N ~3 41 E 666.94 N 6089.40 E 6125.82 N 83 44 E 669.18 N 6163.96 E 6200.17 N 83 48 E 570.78 N 6238.03 E 6273.99 N 83 51 E $71.70 N 6311.7Z E 63~7.36 N 83 55 ~ STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 8-APR-87 PAGE 4 DATE DF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.25 PT ENGINEER: SARBER TRUE MEASURED VERTICAL VERTICAL DEVIATION AZIMOTH DEPTH DEPTH DEPTH DEG MIN DEG MIN INTERPOLATED VALUES FOR EVEN 100 FEET DP MEASURED DEPTH SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE AZIMUTH DEG MIN 12000.00 9241.22 9185.97 46 16 12100.00 9310.79 9255.54 45 23 12200.00 9381.82 9326.57 44 6 12300.00 9453.99 9398.74 43 27 12400.00 9527.41 9472.16 42 9 1ZSO0.O0 9602.29 9547.04 40 51 12600.00 9678.58 9623.33 39 37 12700.00 9756.26 9701.01~-'~38 32 12800.00 9834.82 9779.57 38 36 12900.00 9911.58 9856.33 41 18 N 89 48 E 6418.91 N 89 57 E 6490.48 S 89 25 E 6560.58 S 89 2 E 6629.45 S 88 15 E 6696.93 S 87 7 E 6762.67 S 86 28 E 6826.65 S 85 13 f 6888.84 S 84 35 E 6949.71 S 83 32 E 7012.63 1.54 2.98 1.39 0.65 2.74 1.30 1.41 1.92 1.77 2.93 672.0~ N 6384.63 E 6419.91 N 83 59 E 672.29 N 6456.45 E 6491.36 N 84 3 E 672.00 N 6526.85 f 6561.35 N 84 7 E 671.01 N 6596.07 E 6630.11 N 84 11 E 669.58 N 6663.93 f 6697.49 N 84 15 E 666.83 N 6730.16 E 6763.12 N 84 20 ~ 663.17 N 6794.70 E 6826.99 N 84 25 658.82 N 6~57.5Z E 6889.09 N 84 30 ~, 653.04 N 6919.12 E 6949.87 N 84 36 E 646.48 N 6982.86 f 7012.72 N 84 42 E 13000.00 9985.56 9930.31 ~2 6 13100.00 10061.73 10006.48 39 22 13200.00 10139.04 10083.79 39 22 13265.00 10189.28 10134.03 39 22 S 82 32 E 7078.45 S 80 17 E 7141.38 S 80 17 E 7202.74 S 80 17 E 7242.62 2.92 12.66 0.00 0.00 638.37 N 7049.64 E 7078.49 N 84 49 E 628.62 N 7113.67 E 7141.39 N 84 56 E 617.92 N 7176.19 E 7202.74 N 85 4 E 610.96 N 7216.83 E 7242.65 N 85 9 E SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. FEET DEG/IO0 PEET FEET PEET COMPUTATION DATE: B-APR-B7 PAGE '5 STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALASKA DAT~ OF SURVEY: 2-APR-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FE~T FEET DEG MIN 0.00 0.00 -55.25 0 0 1000.00 999.07 943.82 4 12 2000.00 1997.52 1942.27 2 49 3000.00 2993.99 2938.74 lO 3 4000.00 3929.81 3874.56 31 23 5000.00 4645.55 4~90.30 49 40 6000.00 5304.50 5249.25 47 14 7000.00 5955.12 5899.87 49 36 8000.00 6505.21 6549.96 50 22 9000.00 7267.49 7212.24 47 17 N 0 0 E 0.00 S 79 6 f 32.01 S 74 36 E 84.04 N 74 17 E' 156.25 N 72 19 E 486.19 N 72 52 E 1160.18 N 87 28 E 1899.43 N 88 19 E 2657.74 S 89 10 E 3415,02 N 84 42 E 4161.85 0.00 0.22 0.29 2.04 2.81 0.29 0.68 0.84 0.23 0.04 0.00 N 0.00 E 0.00 N 0 0 E 2.40 S 32.34 E 32.43 S B5 44 E 15.80 S 85.75 E ~7.19 S 79 33 E 18.77 S 158.49 ~ 159.60 S 83 14 f 76.75 N 481.33 f 487.41 N 80 56 E 281.44 N 1139.99 E 1174.22 N 76 7 E 468.08 N 1865.74 E 1923.56 N 75 54 ' 497.04 N 2624.41E 2671.06 N 79 16 L 501.77 N 3384.17 f 3421.16 N 81 33 E 528.85 N 4131.48 f 4165.19 N 82 w2 E 10000.00 7928.85 7873.60 49 49 11000.00 8573.67 8518.42 48 56 12000.00 9241.22 9185.97 46 16 13000.00 9985.56 9930.31 42 6 13265.00 10189.28 10134.03 39 22 N 84 43 E 4911.75 N 87 49 E 5675.78 N 89 48 E 6418.91 S 82 32 E 7078.45 S 80 17 E 7242.62 0.31 0.36 1.54 2.92 0.00 601.66 N 4877.87 E 4914.8~ N 82 58 E 651.65 N 5640.45 E 5677.97 N 83 24 E 672.08 N 6384.63 E 6419.91 N 83 59 E 638.37 N 7049.64 f 7078.~9 N 84 49 E 610.96 N'7216.83 E 7242.65 N 85 9 E STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE= S-APR-87 PAGE 6 DATb OF SURVEY: 2-APR-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: 'SARBER INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEeT PEET DEG MIN 0.00 0.00 -55.25 0 0 N 0 0 E 55.25 55.25 0.00 0 0 N 0 0 E 155.26 155.25 100.00 0 33 N 51 37 E 255.26 255.25 200.00 0 35 N 55 12 E 355.27 355.25 300.00 0 45 N 68 56 E 455.28 455.25 400.00 0 51 N 75 41 E 555.30 555.25 500.00 I 33 N 86 36 E 655.36 655.25 600.00 2 22 S 79 54 E 755.51 755.25 700.00 3 51 S 78 3 E 855.75 855.25 800.00 4 17 S 78 42 E 956.06 955.25 900.00 1056.33 1055.25 1000.00 1156.58 1155.25 1100.00 1256.77 1255.25 1200.00 1356.94 1355.25 1300.00 1457.08 1455.25 1400.00 1557.21 1555.25 1500.00 1657.34 1655.25 1600.00 1757.45 1755.25 1700.00 185'7.56 1855.25 1800.00 4 15 S 78 34 E 4 9 S 78 28 E 3 49 $ 77 29 E 3 24 S 76 43 E 3 15 S 75 28 E 2 59 S 75 23 E 2 53 S 72 3'% E 2 42 S 74 26 E 2 44 S 76 12 E 2 46 S 75 22 E 1957.68 1955.25 1900.00 2057.81 2055.25 ZO00.O0 2157.93 2155.25 2100.00 2258.06 2255.25 2200.00 2358.20 2355.25 2300.00 2458.34 2455.25 2400.00 2558.48 2555.25 2500.00 26~8.65 2655.25 2600.00 2758.97 2755.25 2700.00 2859.61 2855.25 2800.00 248 S 74 20 E 2 50 S 74 11 E 2 53 S 73 43 E 2 58 S 71 36 E 3 1 S 71 51E 3 2 S 70 4 E 3 3 S 68 28 E 3 54 S 84 16 E 522 N 81 0 E 7 24 N 78 35 E 2960.70 2955.25 2900.00 9 23 3062.33 3055.25 3000.00 11 13 3164.67 3155.25 3100.00 13 12 3267.87 3255.25 3200.00 15 23 3372.1~ 3355.25 3300.00 17 23 3477.31 3455.25 3400.00 18 31 3583.20 3555.25 3500.00 20 17 3690.81 3655.25 3600.00 23 3 3800.87 3755.25 3700.00 26 16 3913.72 3855.25 3800.00 28 58 N 7~ 39 E N 74 51E N 76 58 E N 77 46 E N 75 52 E N 71 53 E N 71 39 E N 72 37 E N 72 26 E N 72 18 E 0.00 0.00 0.00 N 0.00 0.00 0.00 0.00 N 0.00 0.82 0.17 0.68 N 0.77 1.63 0.28 1.28 N 1.53 2.76 0.14 1.81 N 2.61 4.10 0.27 2.22 N 3.92 6.04 1.11 2.52 N 5.85 9.45 1.01 2.23 N 9.29 14.68 1.30 1.15 N 14.64 21.70 0.24 0.30 S 21.81 28.90 0.15 1.78 S 29.17 35.96 0.43 3.19 S 36.33 42.65 0.26 4.62 S 43.22 48.63 0.24 6.06 S 49.35 54.17 0.55 7.48 S 55.05 59.22 0.17 8.80 S 60.22 63.98 1.08 10.20 S 65.11 68.50 0.23 11.51 S 69.77 72.96 0.18 12.75 S 74.35 77.51 0.26 13.97 $ 79.03 32.10 0.14 86.73 0.22 91.38 0.35 96.13 0.15 100.92 0.70 105.78 0.18 110.54 0.33 116.03 1.62 123.94 2.53 135.14 2.35 149.73 2.13 167.58 1.87 189.04 1.90 214.28 1.93 243.47 1.63 275.43 1.04 309.25 2.64 347.98 2.74 392.85 2.82 443.86 2.93 0.00 N 0 0 E 0.00 N 90 0 E 1.03 N 48 18 E 1.99 N 50 4 f 3.17 N 55 16 E 4.51 N 60 51 F 6.37 N 66 39 9.55 N 76 30 ~ 14.68 N 85 31 E 21.81 S 89 13 E 29.22 S 86 30 E 36.52 S 84 59 E 43.47 S 83 54 E 49.72 S 83 0 E 55.53 S 82 15 E 60.86 S 81 40 E 65.91 S 81 5 E 70.72 S 80 38 E 75.43 S 80 16 E 80.25 S 79 58 E 15.24 S 83.75 L 85.12 S 79 41 E 16.56 S 88.51 E 90.05 S 79 24 E 17.97 S 93.30 E 95.01 S 7~ 5 E 19.48 S 98.20 E 100.11 S 78 46 E 21.17 S 103.16 E 105.31 S 78 24 E 22.90 S 108.19 E 110.59 S' 78 Z g 24.80 S 113.14 g 115.82 5 77 38 ~ 26.39 S 118.78 E 121.68 S 77 28 t 25.97 S 126.66 E 129.32 S 78 24 ~ 23.92 S 137.75 k 139.81 S 80 8 E 20.56 S 152.10 E 153.48 S 82 18 6 15.70 S 169.60 E 170.32 S 84 42 E 10.39 S 190.67 E 190.95 S 86 52 E 4.93 S 215.53 E 215.59 S 88 41 k 1.68 N 244.25 k 244.26 N 89 36 E 10.77 N 275.54 E 275.75 N 87 45 E 21.83 N 308.52 ~ 309.29 N 85 57 E 33.99 N 346.34 t 3~8.00 N 84 23 ~ 47.70 N 390.1~ ~ 393.08 N 83 1 E 63.54 N 440.00 E 444.56 N 81 46 E COMPUTATION DATE: 8-APR-87 PAGE 7 STANDARO ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPEsALASKA DATE OF SURVEY: Z-APR-ST KELLY BUSHING ELEVATION: 55.25 PT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EASI/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4029.95 3955.25 3900.00 32 13 4150.25 4055.25 4000.00 35 20 4275.97 4155.25 4100.00 39 2 4408.62 4255.25 4200.00 43 10 4551.60 4355.25 4300.00 48 5 4704.89 4455.25 4400.00 49 37 4860.51 4555.25 4500.00 49 53 5014.99 4655.25 4600.00 ~9 42 5169.51 4755.25 4700.00 49 42 5324,04 4855.25 4800.00 49 33 N 72 17 E 501.60 N 72 18 E 566.80 N 72 20 E 641.08 N 72 48 E 726.14 N 73 0 E 826,03 N 72 53 E 939.64 N 72 55 E 1056.22 N 72 52 E 11'71.36 N 72 38 E 1286.49 N 72 40 E 1401.52 2.81 2.86 2.75 3.27 3.21 1.02 0.78 0.13 0.22 0.70 81.54 N 496.39 E 505.04 N 80 40 E 101.95 N 560.05 E 569.25 N 79 40 E 125.15 N 632.58 E 644.84 N 78 48 E 151.17 N 715.68 E 731.48 N 78 4 E 181.06 N 813.35 E 833.26 N 77 26 E 215.15 N 924.40 E 949.11 N 76 53 F 250.20 N 1038.37 E 1068.08 N 76 27 284.81 N 1150.9l k 1185.64 N 76 6 C 319.67 N 1263.43 E 1303.25 N 75 48 E 355.02 N 1375.81 E 1420.88 N 75 31 E 5477.60 4955.25 4900.00 49 7 5630.56 5055.25 5000.00 48 51 5780.27 5155.25 5100.00 47 43 5927.73 5255.25 5200.00 46 58 6075.14 5355.25 5300.00 47 47 6225.50 5455.25 5400.00 48 43 6377.46 5555.25 5500.00 48 58 6531,44 5655.25 5600.00 49 54 6687.72 5755.25 5700.00 50 23 6844.46 5855.25 5800.00 50 15 N 72 55 E 1515.50 N 72 51 E 1628.62 N 78 45 E 1738.39 N 86 13 E 1846.58 N 87 32 E 1954.79 N 87 34 E 2066.96 N 87 43 E 2181.25 N 87 51 E 2298.21 N 87 58 E 2418.15 N 88 0 E 2538.68 0.42 0.90 3.75 2.86 0.76 0.34 0.64 0.45 0.19 0.23 389.18 N 1487.24 E 1537.32 N 75 20 E 423.40 N 1597.80 E 1652.95 N 75 9 E 451.56 N 1705.53 E 1764.29 N 75 10 E 465.46 N 1812.91 E 1871.71 N 75 36 E 470.47 N 1921.09 E 1977.86 N 76 14 E 475.27 N 2033.27 E 2088.08 N 76 50 E 479.96 N 2147.59 E 1200,57 N 77 24 E 484.52 N 2264.60 E 2315.85 N 77 55 E 488.87 N 1384.6l ~ 2434.21 N 78 24 E 493.16 N 2505.23 E 2553.31 N 78 51 k 7000.21 5955.25 5900.00 49 36 7152.99 6055.25 6000.00 49 4 7305.74 6155.25 6100.00 49 6 7458.73 6255.25 6200.00 49 11 7611.90 6355.25 6300.00 49 ZO 7766.06 6455.25 6400.00 49 52 7921.69 6555.25 6500.00 50 15 8078.62 6655.25 6600.00 50 33 8235.36 6755.25 6700.00 50 25 8391.95 6855.25 6800.00 49 33 N 88 19 E 2657.90 N 89 4 E 2773.18 N 89 19 E 2888.32 N 89 30 E 3003.77 N 89 35 E 3119.41 S 89 42 E 3236.32 S 89 21 E 3355.02 S 89 2 E 3475.34 S 88 42 E 3595.34 S 89 31 E 3715.11 0.84 0.65 0.09 0.18 0.09 0.47 0.48 0.89 0.35 2.97 497.04 N 2624.57 E 2671.22 N 79 16 E 499.80 N 2740.04 k 2785.25 N 79 39 E 501.21 N 2855.51 E 2899.16 N 80 2 E 502.46 N ~971.28 E 3013.47 N 80 24 E 503.27 N 3087.29 E 3128.04 N 80 44 E 503.59 N 3204.6l E 5243.95 N 81 4 ~ 502.54 N 3323.8'7 k 3361.64 N 81 24 ~' 500.80 N 3444.80 E 3481.01 N 81 43 L 498.41 N 3565.47 E 3600.14 N 82 2 E 495.70 N 3685.95 E ~719.1! N 82 20 ~ 8541.29 6955.25 6900.00 46 48 8687.37 7055.25 7000.00 46 55 8834.40 7155.25 7100.00 47 21 8981.95 7255.25 7200.00 47 18 9130.39 7355.25 7300.00 47 49 9278.84 7455.25 7~00.00 47 53 9428.39 7555.25 7500.00 48 11 9579.89 7655.25 7600.00 48 38 9732.28 7755.25 7700.00 49 13 9886.03 7855.25 7800.00 49 39 N 85 33 E 3825.81 N 85 8 E 3932.29 N 84 59 E 4040.09 N 84 43 E 4148.59 N 84 35 E 4258.28 N 84 19 E 4367.99 N 84 15 E 4479.18 N 84 12 E 4592.97 N 84 20 f 4707.94 N 84 43 E 4824.73 I .37 0.65 0.67 0.14 0.91 0.79 0.87 0.60 0.37 0.71 499.65 N 3796.71 E 3829.45 N 82 30 E 508.66 N 3902.81 E 5935.82 N 82 34 E 517.87 N 4010.2l ~ 4043.52 N 82 38 E 527.63 N 4118.28 E 4151.94 N 82 41 E 537.78 N 4227.50 E 4261.5'7 N 82 45 E 548.51 N 4336.68 E 4371.23 N 82 47 E 559.53 N 4447.34 E 4482.40 N 82 49 E 571.03 N 4560.56 E 4596.17 N 82 51 E 582.50 N 4674.97 E 4711.12 N 82 53 E 593.70 N 4791.22 E 4827.86 N 82 56 k STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALA~SKA COMPUTATION DATE= 8-APR-87 PAGE DATE OF SURVEY: Z-APR-8? KELLY BUSHING ELEVATION: 55.25 ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SDB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG MIN 10040.98 7955.25 7900.00 49 57 10196.94 8055.25 8000.00 50 10 10352.96 8155.25 8100.00 50 7 10508.72 8255.25 8200.00 49 59 10664.08 8355.25 8300.00 49 45 10818.66 8455.25 8400.00 49 37 10971.93 8555.25 8500.00 49 0 11123.77 8655.25 8600.00 48 35 11274.47 8755.25 8700.00 48 20 11425.11 8855.25 8800.00 48 24 11575.62 8955.25 8900.00 48 22 11725.76 9055.25 9000.00 47 56 11874.16 9155.25 9100.00 47 21 12020.25 9255.25 9200.00 46 3 12162.89 9355.25 9300.00 44 34 12301.74 9455.25 9400.00 43 28 12437.36 9555.25 9500.00 41 33 12569.63 9655.25 9600.00 40 2 12698,71 9755.25 9700,00 38 33 12826.21 9855.25 9800.00' 39 8 12958.83 9955.25 9900.00 42 31 13091.62 10055.25 10000.00 39 16 13220.97 10155.25 10100.00 39 22 13265.00 10189.28 10134.03 39 22 DEG MIN FEET DEG/IO0 FEET FE~T FEET DEG MIN N 84 44 E 4943.09 N 85 14 E 5062.77 N 85 55 E 5182.52 N 86 25 E 5301.92 N 86 37 E 5420.78 N 87 10 E 5538.58 N 87 45 E 5654.62 N 88 9 E 5768.73 N 88 4 E 5881.30 N 87 59 E 5993.80 N 88 2 E 6106.14 N 88 38 E 6217.94 N 89 25 E 6327.31 N 89 49 E 6433.46 S 89 41 E 6534.80 S 89 2 E 6630.64 S 87 40 E 6721.67 S 86 38 E 6807.41 S 85 15 E 6888.05 S 84 24 E 6965.85 S 83 0 E 7051.22 S 80 19 E 7136.24 S 80 17 E 7215.61 S 80 17 E 7242.62 0.39 0.48 0.51 0.17 O.18 0.52 0.18 0.34 0.16 0.02 0.49 0.84 0.68 1.36 3.26 0.62 2.05 1.45 1.92 2.54 1.83 2.63 0.00 0.00 604.55 N 4909.0U E 4946.16 N 82 58 E 615.08 N 5028.30 E 5065.78 N 83 I E 624.25 N 5147.71 E 5185.42 N 83 5 E 632.21 N 5266.86 E 5304.67 N 83 9 E 639.51 N 5385.53 E 5423.37 N 83 13 E 645.87 N 5503.23 E 5541.01 N 83 18 F 650.83 N 5619.28 E 5656.84 N 83 23 654.89 N 5733.46 E 5770,75 N 83 29 ~ 658.59 N 5846.15 E 5883.13 N 83 34 E 662.42 N 5958°75 E 5995.45 N 83 39 E 666.32 N 6071.17 E 6107.63 N 83 44 E 669.65 N 6183.11 E 6219.26 N 83 49 E 671.53 N 6292,73 E 6328.46 N 83 54 E 672.12 N 6399.23 E 6434.43 N 84 0 E 672.21 N 6500.95 E 6535.61 N 84 5 E 670.99 N 6597.26 E 66~1.30 N 84 Il E 668.69 N 6688,84 E 6722.18 N 84 17 E 664,32 N 6775.29 E 6807.78 N 84 24 E 658.89 N 6856.72 E b888.30 N 84 30 E 651.47 N 6935.46 E 6965.99 N 84 38 E 641.85 N 7022.00 E 7051.27 N 84 46 E 629.51 N 7108.43 k 1136.Z5 N 84 56 E 615.68 N 7189.30 ~ 7215.62 N 85 6 E 610.96 N 7216.83 E 7242.65 N 85 9 E STANDARD ALASKA PRODUCTION C0. 2-6/J-22 ENDICOTT NORTH SLOPEgALASKA MARKER TOTAL DEPTH COMPUTATION DATE: 8-APR-87 PAGE DATE OF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.25 .PT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN= 1852 SNL9 2180 WEL~ SEC ~6~ TIZN~ RI6E TVD R~CTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 13265.00 10189.28 10134.03 610.~6 N 7216.83 E COMPUTATION DA'TE: B-APR-87 PAGE 10 STANDARD ALASKA PRODUCTION CO. 2-6/J-22 ENDICOTT NORTH SLOPE,ALASKA DATE DF SURVEY: 2-APR-B7 KELLY BUSHING ELEVATION: 55.25 PT ENGINEER: SARBER ,~~~ STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH 6ELOW K6 FROM KB SURFACE LOCATION AT ORIGIN: 1852 SNL, 2180 WEL, SEC 36, T12N, R16E TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST TOTAL DEPTH 13265.00 10189.28 10134.03 610.96 N 7216.83 E FINAL WELL LOCATION AT ~D: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 13265.00 10189.28 10134.03 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7242.65 N 85 9 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY STANDARD ALASKA PRODUCTION CO NELL 2-6/J-22 MPI FIELD ENDICOTT COUNTRY USA RUN 02-APR-8? 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T'T"T'TTT~T"T"T"T"T"T'T"TTT"T"'T"T"I ~.,..~....m..;....~....~....m.,; .......................... ~ ......... , ......... ,...~ .4-.~..A..,~.-~-.~...~.-.;.-.;,.~.-.~...~-- ......... ~ .... : ..... . . ..... 12000 ..-F.T-,,t-.T,..T....t...,t...T,...F.- PROJECT[ON ON VERTICAL PLANE 8S. - ~6S. $CALEO IN VERT]£AL OEP~HS HORIZ SCALE = 1/2000 IN/FT LAND DIRECTIONAL DRILLING IN(] kE. FOR1 ElF' SUB-SURFACE DIRECTIONAL SURVEY :.,IANDARD OIL PRODUCTION COMPANY ..... ' ENDICO'I'T MF'I WELL ..,,:..,-.. !,.J ~!i] L. !... iH .,':"-~ ?i iZ ENDICOTT ~ F.'. 1"'/" ';" ii'. }"! AL,-.870~ MWD a~ SS ,5"-'~,.6--87 ,j Ci Ii!', N !.i !"I Ii!, !i!: F,?. T Y F' !!i: ~i!i; L! F:. V !ii: Y r'.-, ,.:':.~ i' !::: t...RIAN WEST DIRECTIONAL SUPERVISOR.~ i'-.~ :p., ffl t::. 'i" :I: .... i ' .... .... t .... ,= '.i!!; i[ ':':: ~''~/'.', 'i" U i';: [!i THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WEt...t... WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR F'ILES FOR YOUR CONVENIENCE; HOWEVER~ SHOUL[) YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL .P.E FORWARDED TO YOU ON WRITTEN REQUEST. ALL SUF(VEYS ARE k'EPT IN A LOCKED FILIF AND ARE HELl) IN STRICTE:S'¥ CONFIDENCE ~ ~ ~' :" "' ~" GREAT LAND DIRECTIONAL DRILLING, IN(3 Weli ClosL~Z:'e Di:c. ection...: Magnetic Dec 1'~ nat ion: Dmt(i file nome ...... - 'q . STANDARD A[_A~KA PRODUCT ION C() ENDICOTT MPI WEI..L~ 22 N 8[5.00 E :.'31 deg 30 r,',in EE B-MPI lo~ DAT REC:ORD (iF SURVEY iWell ctn:-~urf~ed vez-ticol to Computation- Su=vev dote- Method ..... : RKB Height_: 200. RADIUS OF CURVATURE 3-2(5-87 MWD X. 55.3 ft .. Oil q- r .... . MEAS DR I F:]' TRI IVERT c~_ B~EEA c~Et..T ION DEPTH DG MN DEPTH DEPTH DIST 200 0 24 200.00 :144.75 0.18 40~ 0 42 400.99 346.74 0.65 5~3 2 0 5~+2.97 ~487.72 2.23 630 :1 ~+5 629.95 57~+.70 4.22 720 3 ~.5 7:I9.86 664.6I 7.81 DIRECTION ANGLE N I0.00 E N 8.00 E S 86.00 E S 70.00 E S ?2.0O E RELATIVE COORDINATES FROM WELL-HEAD 0.69 N 0.:12 E 2.59 N 0.~+2 E 3.80 N !.91 EE 3.37 N 3.9~. ~ E 2.09 N 7.66 E C[_OSURE DISTANCE D(3 MN S 0.70 N 10 0 0 E 2.63 N 9 15 57 E 4.25 N 2(5 42 27 E B.19 N 49 5to,~,_ 35 E ?.9~ N ?4 45 14 E [JOG LEE de, 'tOO 0.200 O. 149 0.212 O. 862 1. 667 810 -5 36 80 ,.'9.6 F, 7 S,4. ,40 13.48 103.5 4 i Fi 10 '-' ' . :- t-,; 8 72 ,:J o 34 _ ,.u3 '-'7 '~'"' . ~_.-' . 1490 3 !5 1488.00 :1-432.75 5.5.08 1940 ::-? 45 1937,38 1882.13 75.3.5 2500 3 1.B 2496. ,4:t. 2.4~1 _ 3(5 100.16 S 72.00 E 0.18 N 13.52 E S 70.00 E 5.47 S 29.93 E S 60.00 E 18.03 S .56.87 E S 69.00 E 28. lc.3 S 78.10 E S 57.00 E 41.44 S 104.17 E 1.SOC O. 0 0.111 O. 09( 2607 3 18 2603.43 2548.18 105.38 2702 ~+ 2-4 ~'a,-':; 9 c~,_,. 22 2642_ 97. :111 .,_=qq 2797 6 12 2792.81 2737.56 120.33 ~r~c,u 8 6 2887 06 283~ 8:1 :l~° 02 2986 9 ~,8 2979.92 2924.67 i46.37 S 71.00 E 44.11 S 109.65 N 85.00 E 44.88 S 115.93 N 77.00 E ~3.51 S 124. 559 N 76.00 E 40.75 S 136.09 . . 1~0:14 N 72 O0 E 38 72 S 'q 118. :19 S 68 .5 6 E 124.32 S 68 SO 10 E :131.97 S 70 44 57 E 1~+2.06 S 73 19 48 E 154.5V S 76:16 2~ E O. 06l 1. 161 J '~.91 ;:. 1.81.: 3082 11 42 3074.23 3018.98 :163.85 3177 13 12 3:166.99 3111.74 184. O~ 3276 15 24 3262.92 3207.67 208.29 .q:q64 17 24 33-49 '°5 '-~P~-~, O0 233 42 3431 18 12 3~+11.'!4 :3355.89 252.92 N 73.00 E 31.34 S 167.22 E N 78.00 E 26.2:I S 187.04 E N 77.00 E 20.92 S 210.9:1 E N 76.00 E 14.99 S 235.62 E N 72.00_ E o...51o. ~' 2.54.72 E 170_:13 S 79 23 9 E 188.87 S 82 I 22 E 2:11.95 S 84 20 9 E 23¢5 lO c 8¢:; 21 ~a E 2q~, ao- ~ a7 Si 42 E 1.98( 1.60: 2. 1. 365 :-~4f16:, .... ~.'--,0 54 3.576 .... n3 3520 78 ._,:=09.85 37c~'':. 2,4 :q;::, Yi7-49 87 3694 6P_ 384 ..... · _' _ ~._, ~':' 386 47 o,mo~:: "-"1 12 391R ,_.. g 04 :'q 20 4175 W6 O 40'73. [-50 4018. ;'75 575.41 4365 4 ....... '1 k ,q 4 >321 30 -4166 o F4 ,_,:.:i ~ .'1 . i N 71.00 E 9.07 N 310.24 E N 72. O0 E 33.34 N 382.78 E N 72.00 E 61.56 N 469.63 E N 7:1 O0 E 94 '=1 N q,'~,~ '~1 E N 71. 00 E 1°''-~,.,,_, . 74 N ,_:':°~,_,,_ . 07 E 310.38 N 88 19 33 E 473.64 N 82 3i E, 7 E 577.26 N 80 S2 7 E 69q fi6 N 78 R~ '~'~ g ENDICOTT NPI WELLtt 22 3 MEAS DRIFT TF~UVERT SUBSEA SECTION DEPTH DE'; MN DEPTH DEEPTtt DIST -.'+7.`+.849 .`+8 , +8,_. 20 4426.9q 963.62 4936 -4-9 48 4603.54 46~8.27 !103.54 5119 49 .`+2 ~721.78 4666.53 :123~.63 5307 49 42 4843.38 4788.13 1B?~.OS +.',,~: -~+937 SO 1649 10 5,,.~9 48 30 507'9. qo r-~ . ........ ~ ,~024 28 1646.21 $765 47 S4 S14S.Si 5088.28 1716.68 5865 47 24 5210.88 5155.63 1790.22 ~ .... 42 22 .97 :~0~ 47 53~7. 5291 ~939.2I 6262 -48 ~ .c, . _ . +.:, S 47 n 40 541 S_ 1 S 2077.2 :t ,~447~ 49 30 5595 33 ._~0 08 22~:t 64 6636 50 18 5719.65 5664.40 2369.18 6824 ~F) 24 ~:ci~o - . 25 .... ~ ...... a, 1 S784 36 13.88 7012 49 24 5961.3S S906.10 2668_39 '7203 ~t9 12 ,.50¢ t- 26 03 . 28 3,:,. __ 6 0 O0 02.30 '-"'-~'--'~, ~_,.--_, 4°~ 12 6209 ..... 4F) 6:154 15 2945 q~3. 7583 49 24 6Fq~Fq :qO 6278_05 3089.71 '/a~;~ .... Sfi e:; 6514 ~_~:l 6458 . oz~. :~;qo2 .75 8053 50 38 dd3%.kS dS80.20 3k48.48 8,~+ 4 :18 < ~* z ~ 00 8622 46 48 7005 02 ~'"~ ..... . .~:, +9 77 388n 01 8o-, F, 4-7 ~'~ 7136 ,.,~. ~, ~ 0 40~el 22 9001 47 36 7263.30 7207. OS 9:!9'6 -57 36 '7393. '79 7338.54 4302.08 9='"~ :+ 48 ;-4 7r4'i 9 96 7464.71 444 :i 9574 4B ~+~ 7~4q °Fi 7590 73 4583 4 ~"~'~=q. 32 7700.07 4709_ 63 RECORD OF SURVE:.Y D I REC:'[' I ON ANGLE N 72.00 E N 72.00 E N 72_00 E N 72.00 E N 7:1. O0 E RELATIVE COORDINATES FROM WEL L-.--HEAD 176.74_4 N 809..`+1 E 22:1.35 N 947.94 EE 265.73 N 1084.50 E 308.89 N 1217.34 E 364.38 N 1363.31 E N 72.00 E N 73.00 E N 77.00 E N 82.00 E N 86.00 E 409.88 N .`+39.79 N 458.31 N 471.77 N 487.35 N 15:19.16 E :1614.03 E 1683. I-'+ E :1755.78 F 1903.98 E N 86.00 E N 87.00 E N 87.00 E N 86.00 E N 87.00 E 496.97 N SOS. 79 N SiB. 52 N S22.2,6 N 53:1.18 N 20.`+1.67 E 2185.87 E 2333.30 E 2477.78 E 2622.08 E N 88.00 E N 88.00 E N 89.00 E N 90.00 E N 90. O0 E S37.47 N 542.49 N S46.26 N S48 1~ N . £_ 548.12 N 2765.98 E °09 72 E ~ . . 3053.72 E 3267.41EE 3413_70 E N 90.00 E N 88.00 E N 84.00 E N 83.00 E N ~ O0 E ~._~ ~_ . .~+8:12 N ~qf) 43 N 561.06 N 577_ 06 N t-:o.:2 7q N 3661.29 E 3693.69 E 3845.74 E 3986.10 E 4122.10 E N 83.00 E N o.u O0 E N 83.00 E N 83.00 E N 83.00 E 611.30 N 628.29 N 645.62 N 661.00 N 678.64 N 4265.03 E 4403.37 E .`+544.50 E 4669.79 E 4813. 40 E CLOSURE DOG L E(3 DISTANCE DG MN S deg/lO0 828.40 N 77 .`+2 33 E 3.381 973.44 N 76 51 23 E 0_829 1116.58 N 76 :i3 57 E ' )00 ~255.92 N 75 45 44 E 0.055 1398.94 N 75 19 33 E 0.309 :IS73.48 N 7.`+ 54 3 E 0.30.`+ 1672.87 N 7.`+ 46 29 E 0.740 1744.42 N 74 46 5 E 2.377 1818 06 N 74 57 ~7 E ~ 755 1965.37 N 75 38 34 E 1.095 2101.28 N 76:19 10 E 0.595 2243.63 N 76 ,~r:°,~ :17 E 0.47 2389.14 N 77 ,~:qr: 17 E O. 2'532.24 N 78 5 43 E 0.320 2675.34 N 78 32 53 E 0.611 2817.72 N 79 0 13 E 0 2959.86 N 79 26 21 E O.JOC · )'~ 79 5 3i8~.19 N I 29 E 0.32_I 3313.07 N 80 28 37 E 0.327 3457.43 N 80 52 4'I.E 0.28;7: 3603.23 N 81 15 i E O.OOC 3734_-'~8 N 81 31 27 E 1.002 3886.45 N 81 4! 58 E 1.60'i 4027.66 N 81 45 46 E 0.38~, 4164.64 N 81 48 12 E 0.16'~ 4308.61 N 8:i SO 36 E 0.00( 4447 97 N 4590. :13 N 81 54 E, 2 EE 0.36E 47:!6.34 N 81 56 36 E O. 4861.00 N 8:1 S8 29 E 0.21: ENDICO1T MPI WE[_LN 22 3-26-87_ RECORD OF oUR~iEY MEAS DRIFT TRUVERI' SUBSEA SEC'.'I'ION E~ZREC. TION REI_ATIVE COORDINATES CLOSURE DOG LEG DEPTH DG MN DEPTH DEEPTtt g I.,'r ANGLEE FROM WELL-HEAD DISTANCE DG MN S deg/lO0 10121 .... i0309 S0 ~8 8~20.30 80~.06 5:[~.67 N 8~ 00 E 7:1.0.27 N 5~02.:i8 E S~51 ~8 N 82 ~ 30 E 0 053 . ~ RO 6 82~I 9~: 8186 67 5290 63 N 85 O0 E ,2~.26 N 521+7 ~8 E 5297 aa N 82 8 30 E C ']27 ~0~81~ ~9 0 8361.9.~ 8306.69 5~31.~0 N 86.00 E 735.30 N 5387.82 E 5!~.37.77 N 82 13 1,3 E 0.670 1087~q z~9 58 81~B7.52 8~~.27 ~R'~,s 62 N 86. O0 E 7~.5.z~3 N ;:;;:~.70 E ~,~d2.69 N 82 19 36 E O. 156 11064 ~8 54 8610.62 8655.37 5718.67 N 87.00 E 111515 ~8 2~+ 8670.71+ 8616.1~9 5786.95 N 86.00 E I!3~7 48 2~ 8798.2i 87~2.96 S930.12 S 88.00 E ii~96 ~8 30 8897.01~ 88~I.79 60~0.91 S 89.00 E :11684 48 6 9022.10 8966.8S 6180.50 S 89.00 E 75~.11N 567~.53 E 758.28 N 57~2.72 E 760.78 N 5886.21E 757.86 N 5997.68 E 755.~1N 6138.02 E 572~.1+2 N 82 2['5 1+8 E 5792.56 N 82 28 ~1 E 5935.17 N 82_ 38 8 E 601~5.37 N 82 ~+7 Sl~ E 6:tS-q_33 N 82 59 2 E 0.36~ 0. O. 382 0.216 11919 ~+7 6 9180.56 912G.3:t 6353.z~8 N 88_00 E 1210.~t 1~5 6 9308.83 9253.58 6~86.53 N 89.00 E 12335 ~+2 ~8 9z+75.13 9~+19. 88 66~+6. 3~ N 90.00 E 12~+93 ~+0 ~+8 9592.91 9537.66 675~.16 S 89.00 E 1'~'~ 39 30 9692 [~7 9637 02- 683!~ ~5 M ,_=.00 E 756.93 N 6311_53 E 760.~t2 N 68~.78 E 761.82 N 6605.08 E 760.90 N 6710.38 E 758.70 N 679~.17 E 6356.76 N 83 9 itl E 6~89.i~8 N 83 16 ].5 E 66~8_87 N 83 25 1~ E 6763.38 N 83 3:1 51E 6836.~0 N 83 37 ~1E 0.80d :1.1:rE 1.01a 1. '~9 1.01~7 12695 39 0 97~.8.03 9692.78 6879.66 S 88.00 E 757.11 N ¢3839.70 E 6881.88 N 83 ~+:1 0 E 0 '59~! ENDICOTT MPI WELL~J 22 DATA INTERPOLATED FOR EVE;N 100 FEET OF .__,.,,.,,..,,..,-, DEPI'H 26-8? MEAS. DEPTH 355 TRU VERT SUB SEA MD--TVD DEPTH []EPTti D I FF. E,$ 0 0 :l S G :l 00 0 2SG 200 0 355 3300 0 -4 G B h 00 0 VEER T I CAt._ CORREC 7' 0 0 0 0 0 555 SG5 SO0 0 0 655 (5[35 600 0 0 755 755 700 0 0 856 85G 800 I 1 956 955 900 1 0 1 1:1.57 1257 :[ .'.-i57 lh57 :1657 1858 2058 2. 1055 !000 1 :l 1 G G 3.100 ~.~ ._'t 2R~:,_, ,_, :1.200 ,_.~ 1 "-* Rr::,_, ._, ._, 1.300 ~_ "-" :14.S S I h 00 ,._'~ :1 r.: c r: I G 00 16 G S i 600~ 1755 :1700 3 I q ~ n 18 n 0 1 '.:9 E, 5 1900 3 205 .rS 2000 3 '-~ 155 2100 3 ,:_,_._,,_. 2200 3 23G5 2300 3 2455 =- _ . '--::' .q F; 5 2 .q 0 tO 4 ~ 4 ~:: r_': 2600 2755 2700 4 '~aqr'-' 2800 "-~ c' R ~7' ;2900 26F,? r"t .";d [- 28,50 2961 F, tEI_AT I VE COORD I NATES FROM WELL-HEAD 0. O0 0. O0 0.00 0.00 1.11 N 0_17 E 2.07 N 0.35 E B.P. 9 N 0.32 -3.79 N 2.1h E 3.07 N h.76 E :1.,~-1 N 9.73 E 0.93 S 16.98 E 3.22 S 2,4-.~2 E 19_88 S 60.16 E 22.~.0 S 64.98 E 2~. 67 S 69.72 E 26.69 S 7h.37 E 28.46 S 78.91 E 30.11S 83.53 E 31.62 S 88.37 E 33.0! S 9B.~O E 3~.25 S 98.63 E 35_33 S 104.06 E 2+3.07 S 107.08 E -44.81 S 112.82 44 ":~r: ,::- 120 '-""-~ E . . -41.79 S :13:t.87 E 37.96 S lZ}6.18 E ENDICOTT MP! DATA iN fEF,.P,._LATED FOR EVEN 100 FEE T OF: SUBSEA DFP'f'H 3..26-8~ MEAS. DEP'I-ti 31615 3372 3]~78 3693 3802 3m . ~033 -['RU VERT SUB SEA MD-TVD DEPTH [)EPTtt D I FF. 3055 3000 8 3:155 3 :t 00 10 325S 3200 13 u -~ t:: q 3300 :I 7 3h-55 3~,00 23 355[-] 3[500 29 3655 3600 38 3755 3700 47 3855 3800 6:1 "~°5q 9, c~00 78 4153 ---', OSS l~O 00 98 4280 ~ 1SS -~', 100 :125 4413 ~255 4200 158 .~ 555 ~,355 ~;300 200 ,'4861 h555 hSO0 306 5016 ~655 ,'+600 361 r::: 171 ~., 755 ],7rl.. 0 z, 16 5325 ~ 85E, ~800 .~Y 0 5~79 ~955 4900 52~ 5632 [5055 5000 577 5~ a:o r.; 1 r: 5 51 n r~ 627 5931 E, 255 G20 0 676 6079 r:; ;q R 5 c ~ ..... ~o 00 6229 5~55 5~00 77~ 6382 [5555 [5500 827 6692 575[5 [5700 937 ~::8 q 8 F: or: c:,. 5800 LJ ~ · ~ ,..~ hJ '.3 ~,..~ .-' .--' ,..._~ VERT I CAL C. ORREC T 2 6 9 9 1~.~ 17 20 27 33 .52 55 5/, 53 50 h9 -~8 F: 0 53 56 S6 56 RELATIVE C. OORDINAI'ES FROM WELL-HEAD 90.76 N 557.20 E 115.78 N 629.93 E lh~.39 N 712.79 E :t78.~1~ N 808.32 E 2:I1.68 N ~18.17 E 2.q. 8.07 N 1030.15 E 28~.61 N 11z~2.61 E 321.17 N 1251~.8h E 358.93 N 1366.!~.8 E 397.87 N 1~76.96 E 432_1t, 8 N 1587.27 E z~61.31 N 1695.70 E h79.05 N 1803.66 E ~-87.97 N 1912.89 E -595.78 N 202~.60 E r:Oq- ~9 N 21:~9 3k E 509.5:1 N 2256.71 E 51E,.88 N 2376.17 E 523.68 N 2h96..~2 E 533.08 N 262]~.7]~ E END I COl'7 MP i WELL,~ 22 DATA INTERPOi. ATED FOR EVEN 100 FEEl' OF SUBSEA DEPTH MEAS. '" 'q qItP c.- t F~.J VFRT ...... : ,::EA MD-TVD VERTICAL [) E P T H [) E P T H D E P T t4 D I F F. C 0 R R E C T 72 E, ? 60 B S 6000 ~ & 02 E, 3 7310 6 i 55 6 i 00 i 1 S 5 53 ?'~ ¢~ z~qq ~200 ~208 53 7617 ~,~,.~ ~: q 6300 '.l ~_~,~_ -3~o G~ 7772 6~ 55 6z+ 00 ~ 3 &7 SS '-7~27 ,::r: q~- 6500 :1372 8084- 6655 6600 82~+2 6755 6700 :1~87 8397 6855 6800 85~+8 6955 6900 q 593 8696 7055 7000 16~ :1 ~'~ 8-~+__ ~..q7:1 ~,~q~: 7:100 ~ 688 i ~ ~Rrzq 7300 :178z+ 9288 7~+ SE. 7~ 00 1833 9h37 7555 7500 :1882 9588 7655 7600 1933 97h i 7755 7700 '.[986 ~'8°t: 7800 20 ~+ 0 ::. -..., .::, 785.rS _ '_10051 7955 7900 2096 :10207 "~55 o o_ o000 ,_°152 10364 8155 8100 2209 10520 8255 8200 2265 1067~ 8355 8300 2319 10827 8~5B 8~00 2372 SS 57 58 SS Sl ~8 51 56 56 57 56 53 52 53 BO 51 S :l REt_ATI VE COORD I NATES FROM WELL--ttEAD r..~3,.,_,,_ N 2731 . :10 E ShO.30 N 28z+7.03 E ~6_73 N 307.9.53 E 549.6! N 3197.49 E 5~8.12 N 3316_81E 548.12 N 3~37.8~ E 5~8.12 N 35S9.55 E 5~9.9~ N 3678.67 E 5S6.01N 3791.29 E 566.87 N 3899.25 E 579.5g N 1~006.30 E 592.82 N ~+lig.z+6 E 606.16 N ~+223.13 E 619.56 N ~332.28 E 633.12 N !+~2.7~, E 6~6.92 N ~555.08 E 660.99 N ~+669 . 71 E 675.30 N z~786.26 E 690.31 N ~90~.3~ E 702.07 N B02h. IS E 714.76 N 5:[g3.93 E 725.65 N S263.17 E 736.9~+ N 5379.86 E 7~2.83 N 5~95.~50 E 7Bi.2'7 N 5610.77 E 757.09 N 5725.21 E 768.21 N 5837.37 E 758 8(5 N r:~SO r:-- .z~.::, ._,,_,. 5;2 N 6063 . :11 E EN[')!CC~TT NPI WELL// 22 DATA :[NTERPOI._A'rED FOR [EVEN :tOO FEET OF SUBSEA DEEP-I-FI MEAS. TRU VERT SUB SEA MD--TVD VERTICAL DEP]' H D ["-P T H DEP T H D ~ FF. CORRECT :t 733 '-'2055 9000 2678 288 ~. ? :[ 55 9 :[ 00 2726 ~ 8 2027 9255 92 0 0 2772 ~ 6 :t2 ~68 9355 9~00 28 ~3 :[2307 ¢2~B. - · ~ ~¢+0. -, 0 2852 :',t:'ir.::: ~_ ~ =.,r: 9['500 .-_ ~.,~_ .'= o.q"'z, 9655 9600 2920 RELAT'fVE COORDZNA FROM WELL-HFAD 75~.98 N 756.08 N 760.05 N 762.32 N 763.97 N 6:t7-~. 55 E 628~. O~ E 6389.63 E 6~ 90. 29 E 6586.23 E 762.25 N 760.27 N 6677.~6 E 6763.23 E ENDICOTT DATA INTERPOLA'TED FOR EVEN :lO00 FEET OF- MEASURED DEPTH MEAS. ]"RU VERT SUB SEA b E P T H D E F"' T H b E P T I''t :[ 0 00 999 '..¥' a. 4 2000 1997 19~.+2 3000 2994 2939 4000 :'a,:;oq 3873 S 000 ~ 6 ~ S 4 S 90 6 0 0 0 53 0 2 7000 S9S3 5898 8000 6602 65~7 9000 7262 7207 :[0000 7923 7868 :l 1000 8569 8514 :'1.200 o ',::~ :.-" ~'a,-'- 9 :t 8 :l RELAT I VE COORD I NATES FROM WELL-HEAD z,,-..'17 S 27.,"::,1 E 29.17 S 80.83 E "'~:: 97 .q iS2 4~, E 63.98 N ;+77.06 E 280.83 N J.:[30.98 E .487.92 N S32_ 8h N $.g8.12 N 593.66 N 685.23 N 1853.99 E 2612.06 E 3372.79 E ~ :1.2:[. 37 E 4865.77 E 752.52 N 759.2']. N 5626.25 E 6370.40 E ___ ] HOBZZONTAL VIEW STANOARO ALASKA PRODUCTION ENDICOTT MPI ~ELL# 22 CLOSURE: 688t f~ N B3.7 E DECLINATION: 3t,50 dec E SCALE: I Inch: t500 feet DRAWN: 3-26-87 2000 ~000 4~00 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-51 I 1 APR 6, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells: I sepia and I blueline print for: L-36 Run 1 April 2, 1987 . CNL~/J. , o rJ * CBT ~/ * CET J-22 Run 1 April 2, 1987 March 29, 1987 * GCT * CBT * CRT K-37 Run 1 April 2, 1987 . CET~./ P-27 (Gearhart) Run 1 February 25, 1987 * CNL .- A un,t of the or,ginol Stondard O~1 Co,npo.y Founded in Clevelond. Ohio. in 1870 (/ /~laska Oil & Gas Cons. Commission k.._,/ Anchorafle Sincerely/~,~ Bruce St Pierre Standard Alaska ~ Production Comp,. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alosl~a 99519-6612 (9071 564-511 I APR 6, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The'following log information for Endicott wells: 1 sepia and 1 blueline print for: 0-29 Run 2 March 24, 1987 * HP Gradient Log.~x J-22 Run 1 March 25, 1987 * DLL/MSFL J * CNL./ March 29, 1987 * CBT ~'" * CET ~- L-36 Run 1 March 26, 1987 * DLL/MSFL~' Oil & Gas Cons. Commissio~ Sincerely, - -"', // Bruc~ St. Received by A unit of the original $1ondord C~I Company Founded in Cleveland, Ohio. in 1870 STATE OF ALASKA .... ALASK,~, OIL AND GAS CONSERVATION COMN'. JION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well E] Alter casing El Time extension [] Change approved program [] Plugging E] Stimulate [] Pull tubing [] Amend order E] Perforate I;~ Other 2. ~lameof OJ~e~ator 5. Datum elevation (DF or KB) ~tandard-Alaska Production Company KBE = 55.25 3. Address 6. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Duck Island Unit/Endicott~ 4. / Location of well at surface 1852' St{L, 2180' WEL, Sec. 36, T12N, R16E At top of productive interval 1202' SNL, _108 WEL, Sec. 31, T12N, R17E At effective depth At total deDth 1241' SNL, .2~43' WEL, Sec. 31, T12N, R17E 11. Present well condition summary Total depth' measured true vertical 7. Well number 2-6/J-22 MPI 8. Permit number 87 -18 9. APl number 50_029-21699 10. Pool E~idicott Pool Effective depth: measured true vertical 13265 feet 10189 feet Plugs (measured) Casing Length Size Structural Conductor 30 ' Surface 2502 ' 12680' Intermediate Production 862 ' ?" Liner Perforation depth: measured feet feet Junk (measured) true vertical Cemented Measured depth Structural Drive Pipe 13~3/8" 2700 cu.ft. Permafrost 9-5/8" 575 cu.ft. Class G 161' 2502' 12680' 357 cu.ft. Class G 13247 ' RECEIV True Vertical depth 161' 2502 ' 9740' Tubing (size, grade and measured depth) 7" 26#/Ft IJ4S tubing at 12310' MD Packers and SSSV (type and measured depth) Packer at 12178' ~4D RRRV ~t- 1R62' MD 12.Attachments Description summary of proposal E~ 13. Estimated date for commencing operation July 1987 Alaska 0il & Gas Cons. Commissinn Anchorage Detailed operations program [] BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby_certify that the foregoing is true and correct to the best of my knowledge Signed 2,S~ ~¢~--~ TitleD iv is ion Dr illinq Engineer Conditions of approval Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I Approved by Form 10-403 Rev 124~5 Date 5"/~//~- 7 No. 7~,~/,¢~ by order of /j_~ the co~on D,ate _~~' '~ //c~ ~"~j,~ Submit i n tri pi icate ~.~, ENDICOTT WELL 2-6/J-22(MPI) Permit Number: 87-18 Approval Date: 2/24/87 Well Status Well operations were shut down after running 7" tubing, nippling down BOPE, and installing the tree. A ~E~.~.~_~ has been run in the 7" liner and a gyroscopic survey has been run from PBTD to surface. The 13-3/8" x 9-5/8" annulus has been downsqueezed with cement and non-freezing fluid. Remaining Drilling Operations The well will be completed by perforating underbalanced with wireline conveyed guns. Perforations to be consistent to current development strategy. Flow well for simple cleanup. Install sub surface safety valve in ball valve nipple. W/pm/171 2D Rig' Doyon //15 Well · 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT February 25, 1987 at 0600 hours AFE // 717626 API 50-029-21699 0600 Depth- ' Day' -1 24-Hour Ftg- ' Current Operation- Prepare to spud. Accept rig at 0400 hrs. on 2/25/87. Prepare to spud. MUD TYPE-NaC1 WT:9.6 VIS- PV- YP- FL' SOLIDS- TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION , , COORDINATES DLS 1507h' Ri§: Doyon #15 Well: 2-6/J-22 ~MPI) SAPC Daily Drilling Report -- ENDICOTT February 26, 1987 at 0600 hours AFE # 717626 API 50-029-21 699 0600 Depth: 850' Day: 1 24-Hour Ftg: ' Current Operation: Drill 17-1/2" hole. Spud well at 1400 hrs on 2/25/87. Drill 17-1/2" hole to 500 ft. PON. RIX w/dynadrill. Dynadrill 17-1/2" hole. POH to check muleshoe. RIH. Dynadri11 to 850 ft. MUD TYPE-Spud Mud WT:9.1 VIS:300 PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1507h: Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT February 27, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 2515' Day: 2 24-Hour Ftg: 1665' Current Operation: Run 13-3/8" casing. Dynadrill 17-1/2" hole to 852 ft. POH. RIH w/bit. Drill to ft. CBU. POH. Run 13-3/8" casing. MUD TYPE-Spud Mud WrF:9.$ VIS:200 PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1507h: Rig- Doyon #15 Well ' 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT February 28, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth' 251 5' Day' 3 24-Hour Ftg' ' Current Operation' R/U to test BOP's. Run 13-3/8" casing hanger. RIH w/stab-in. Mix and pump cement. POH. N/U starting head and tubing spool. N/U up BOP's. (13-3/8" shoe at 2502 ft.). MUD TYPE-SPUD WT'9.6 VIS-200 PV: YP' FL- SOLIDS' TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1507h- SAPC Daily Drilling Report -- ENDICOTT March l, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 (M?I) AFE # 717526 APl .~0-029-21 699 0600 Depth- 2700' Day- 4 24-Hour Ftg' 185' Current Operation- Dynadrilling. Test BOP's. RIH w/12-1/4" bit and tag cement. Test 'casing to 3000 psi - OK. Drill float equip and 10 ft. new hole. Conduct FIT to 13.2 ppg EMW. Drill to 2600 ft. POH. RIH w/dynadrill. Dynadrill 12-1/4" hole to 2700 ft. MUD TYPE-Polymer WT:8.6 VIS:40 PV-7 YP:8 FL'20 SOLIDS:4 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 51 3h' SAPC Daily Drilling Report -- ENDICOTT March 2, 1987 at 0600 hours Rig- Doyon #15 Well' 2-6/J-22 IMPI) AFE # 717526 API 50-029-21699 0600 Depth' 4,380' Day- 5 24-Hour Ftg' 1680' Current Operation- Drilling. Dynadrill 12-1/4" hole to 3490 ft. POH. RIH w/bit. survey 12-1/4" hole to 4380 ft. Drill and MUD TYPE-Polymer WT- 9. (1 VIS-47 PV-IO YP'23 FL'16 SOLIDS'5 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 11 2607 3.3 S71E 2603 105 ~'46 ~111 18 3276 1 5.4 N77E 3263 208 ~ 23 ~ 213 24 41 75 36 N71 E 4074 575 ~ 93 ~ 511 DLS _ .8 2.3 2.5 1 51 3h' SAPC Daily Drilling Report -- ENDICOTT March 3, 1987 at 0600 hours Rig' Doyon #15 Well- 2-6/J-22 (MPI) AFE # 71 7526 API 50-029-21 699 0600 Depth' 5566' Day- 6 ~4-Hour Ftg' 1186' Current Operation- Drilling. Drill and survey 12-1/4" hole to 4609 ft. Trip bit. 5024 ft. POH for washout. RIH. Drill to 5586 ft. Drill to MUD TYPE-Polymer WT'9.4 VIS-52 PV:13 YP:21 FL'12 SOLIDS-7 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 26 4555 48.2 N72£ 4356 822 ~J174 ~ 810 28 4936 49.8 N72E 4604 ll04 6)264 (~1085 30 5307 49.7 NT1 £ 4844 1379 iN 352 ~1354 DLS 3.3 0 1 1 51 3h' Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT March 4, 1987 at 0600 hours AFE # 717526 API 50-029-21699 Current Operation: MUD TYPE-Polymer 0600 Depth: 6280' Day: 7 24-Hour Ftg: 714' Dri 11 i ng. Drill and survey 12-1/4" hole to 5678 ft. to 5932 ft. Trip bit. Drill to 6280 ft. Trip bit. WT:9.6 VIS:41 PV:lO YP:16 FL:8.5 SOLIDS:8 Dynad ri 11 TEMP:85'F SURVEY MD ..... 33 5725 35 6O27 ANGLE DIRECTION TVD SECTION 47.8 N77E 5118 1687 47.7 N86E 5322 1 910 N447 476 COORDINATES 1655 1875 1513h: DLS 3.1 1.5 SAPC Daily Drilling Report -- ENDICOTT March 5, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 IMPI) AFE # 717526 API 50-029-7! 699 0600 Depth- 6971' Day' 8 24-Hour Ftg' 691' Current Operation' Drilling. Drill and survey 12-1/4" hole to 6683 ft. Trip bit. Drill to 6971 ft. MUD TYPE-Polymer WT:9.6 VIS'40 PV'IO YP'19 FL'8.5 SOLIDS:8 TEMP'85°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 36 62l 6 48.8 N86E 5447 2050 r4485 ~'20l 6 . 6 38 6596 50.3 N87E 5693 2339 I~/504 ~:2304 . 4 1 51 3h' SAPC Daily Drilling Report -- ENDICOTT March 6, 1987 at 0600 hours Rig' Doyon #15 Well- 2-6/J-22 (MPI) AFE # 717.~26 API 50-029-21699 0600 Depth' 8050' Day- Q 24-Hour Ftg' 1079' Current Operation- Drilling. Drill and survey 12-1/4" hole to 7782 ft. Trip bit. Drill to 8050 ft. MUD TYPE-Polymer WT-9.7 VIS:42 P¥-lO YP-20 FL'8.0 SOLIDS-7.5 TEMP'84°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 40 6973 49.4 N87E .~935 2629 Id $22 ~ 2594 42 7353 49.4 N88E 6183 2916 ii 533 ~-2881 44 7823 50.1 EAST 6488 3273 r~ 539 ~ 3239 DLS .6 .4 1 51 3h' Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAP£ Daily Drilling Report -- ENDICOTT March 7, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 8451' Day: l0 24-Hour Ftg: 401' Current Operation- Dynadrilt ing. Drill and survey 12-1/4" hole to 8325 ft. w/dynadrill. Dynadrill to 8451 ft. MUD TYPE-Polymer WT:9.6 VIS:45 PV:9 YP:20 FL:7.5 SOLIDS:7 POH. TEMP:°F RIH SURVEY MD ANGLE DIRECTION TVD SECTION 50, 6 EAST 6609 3419 COORDINATES N539 E3385 1 51 3h: DLS = .3 SAPC Daily Drilling Report -- ENDICOTT March 8, 1987 at 0600 hours Rig- Doyon #15 Well' 2-6/J-22 IMPI) AFE # 717526 API 50-029-21699 Current Operation- Drilling~ Dynad ri 11 MUD TYPE-Polymer WT:9.7 0600 Depth- 8982' Day' 11 24-Hour Ftg' 531' 12-1/4" hole to 8494 ft. Trip bit. Drill to 8982 ft. VIS:45 PV:IO YP'18 FL'7.5 SOLIDS' 7 TEMP'86°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 47 8377 49.3 8775 47.3 N88E 6842 N83£ 7111 3698 k; 54l ~ 3664 3991 ~J 568 ~ 3956 1.1 . 1 51 3h' SAP¢ Dait.y Drilling Report -- ENDICOTT March 9, 1987 at 0600 hours Rig: Doyon #15 Well: 2-6/J-22 (MPI) AFE # 717526 API 50-029-21699 0600 Depth: 9708' Day: 12 24-Hour Ftg: 726' Current Operation-Tripping. Drill and survey 12-1/4" hole to 9708 ft. Top drive failure. POH. MUD TYPE-Polymer WT:9.7 VIS:46 PV:9 YP:21 FL:7 SOLIDS:7 TEMP:88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 51 91 56 -47.6 N83E 7368 4272 ~602 (~4335 0 53 9534 48.8 N83E 7620 4554 ~Y637 ~4515 .4 1513h: SAPC Daily Drilling Report -- ENDICOTT March 10, 1987 at 0600 h~urs Rig' Do¥on #15 Well · 2-6/J-22 (MPI) AFE # 717526 API 50-029-21 699 0600 Depth- 9708' Day- 1 3 24-Hour Ftg' ' Current Operation' Tripping. POH. Lay down top drive for repairs. Pick-up Kelly. Test BOPE. RIH. MUD TYPE-Polymer WT:9.7 VIS:47 PV-IO YP-22 FL'7 SOLIDS-7 TEMP- °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 151 3h' SAPC Daily Drilling Report -- ENDICOTT March l l, 1987 at 0600 hours Rig: Doyon #15 Well' 2-6/J-22 {MPI) AFE # 717526 API 50-029-21699 Current Operation- Drilling. 0600 Depth- 9950' Day. 14 24-Hour Ftg- 242' RIN to shoe. P/U and test kelly. RIH, Drill and survey 12-1/4" hole to 9950 ft. MUD TYPE-Polymer WT:9.9 VIS-43 PV-12 YP'24 FL'7.0 SOLIDS:7.5 TEMP-83°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 54 9701 49.4 N83E 7729 4680 A,,/652 ~ 4640 DLS ,, .4 1 51 3h- Rig' Doyon #15 Well' 2-6/J-22 (MPI) SAPC F)ailv Drilling Report -- EHDICOTT March 12, 1987 at 0600 hours AFE # 717526 API 50-029-21 699 0600 Depth- 10,300' Day' 1 5 24-Hour Ftg' 350' Current Operation' Drilling. Drill and survey 12-1/4" hole to 10,300 ft. MUD TYPE-Polymer WT:9.8 VIS:45 PV:ll YP-23 FL'7 SOLIDS'8 TEMP-°F SURVEY MD ANGLE DIRECTION TVD SECTION 55 9891 49.8 N83E 7853 4824 d 670 56 lO081 50.4 N84E 7974 4970 kY 686 COORDINATES ~4784 4929 1 51 3h' DLS .2 .5 SAPC Dail.y Prillin.q Report -- ENPICP, TT ~;arch 13, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 ~MPI) AFE # 717526 API 50-029-21699 0600 Depth- 1 O, 422' Day- 1 6 24-Hour Ftg' 122' Current Operation' Drilling. Drill and survey 12-1/4" hole to 10,341 ft. Trip bit. Drill to 10,422 ft. MUD TYPE-Polymer WT'9.9 VIS-50 PV'12 YP-26 FL'7 SOLIDS'8 TEMP'95°F SURVEY ~ ANGLE DIRECTION TVD SECTION COORDINATES ..... 57 10'269 50,3 N84E 8094 5115 ~701 ~ 5073 DLS .1 1 51 3h' Rig' Doyon #15 Well' 2-6/J-22 IMPI) SAPC Daily Drilling Report -- ENDICOTT March 14, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth' 10,751' Day' 1 7 24-Hour Ftg' 329' Current Operation' Drilling. Drill and survey 12-1/4" hole to 10,751 ft. MUD TYPE-Polymer WT:IO VIS-46 PV'12 YP'20 FL'7.2 SOLIDS:8 TEMP-95°F SURVEY MD ANGLE DIRECTION TVD 58 10459 ' 50.1 N85E 8216 59 10644 49 N86E 8336 SECTION 5261 5401 COORDINATES ~715 726 ~5218 5358 1513h' DLS .3 .8 SAP£ Daily F)rilling Report -- ENDICOTT March 15, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 (MPI) AFE # 717526 API 50-029-21 699 0600 Depth' 11,070' Day- 1 8 24-Hour Ftg' 31 9' Current Operation' Drilling. Drill and survey 12-1/4" hole to ll,070 ft. MUD TYPE-Polymer WT:IO VIS'46 PV:12 YP-22 FL- 7.0 SOLIDS-9 TEMP'IOO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 60 10836 49.3 N86E 8462 5547 IJ 736 k.Y 5503 .2 151 3h- Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAPC, Dail.v Drilling Report -- E~DIC, OTT March 16, 1987 at 0600 hours ArE # 717526 API 50-029-21699 0600 Depth: ll,190' Day: 1 9 24-Hour Ftg.' 120' Current Operation: Drilling. Drill and survey 12-1/4" hole to 11,169 ft. ll,190 ft. Trip bit. Drill MUD TYPE-Polymer WT:IO VIS:47 PV:IO YP:23 FL:7.0 SOLIDS:9 TEMP:°F to SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 61 11024 48.9 N87E 8585 5689 ~745 ~5645 62 1111 5 48.4 N86E 8645 5757 /~/749 ~ 571 3 1513h: DLS .4 .7 Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT March 17, 1987 at 0600 hours AFE # 717526 API 50-029-21 699 0600 Depth: 11,540' Day: 20 24-Hour Ftg: 350' Current Operation: Drilling. Drill and survey 12-1/4" hole to 11,540 ft. MUD TYPE-Pol)qner WT:IO VIS-46 PV:12 YP:26 FL:7.0 SOLIDS-9 TEMP:IO$°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 63 11307 48.4 · . .'. ~; ~ .~ ~ . -~- .... ~ ~ ~- ~ ~ ,, .. ~, S88E 8772 5900 rd752 1 513h: DLS 2.3 SAPC Daily Drilling Report -- ENDICOTT March 18, 1987 at 0600 hours Rig' Doyon #15 Well · 2-6/J-22 (MPI) AFE # 717526 API 50-029-21 699 Current Operation. Test BOP's. 0600 Depth- 11,860' Day' 21 24-Hour Ftg' 320' Drill 12-1/4" hole to 11,860 ft. POH. Test BOP's. MUD TYPE-Polymer WT:IO VIS:46 PV:9 YP'26 FL:7 SOLIDS'9 TEMP:102°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 64 11456 48.5 S89E 8871 6011 749 5968 65 11644 48.1 S89E 8996 61 51 746 6108 .3 .2 Rig- Doyon #15 Well' 2-6/J-22 (MPI) SAP(C. Daily Drilling Report -- ENDICOTT March 19, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth' 12,084' Day- 22 24-Hour Ftg' 224' Current Operation- Drilling. Test BOPs. RIH. Drill and survey 12-1/4" hole to 12,084 ft. MUD TYPE-Polymer WT'lO. 1 VIS:49 PV'12 YP'32 FL-6.8 SOLIDS-9 TEMP:92°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 66 11879 47.1 N88E 915.5 I 6324 Id 748 L¢~6282 1 51 3h- DLS .9 Rig' Doyon #15 Well' 2-6/J-22 IMPI) SAPC Daily Drilling Report -- ENDICOTT March 20, 1987 at 0600 hours AFE # 717526 API 50-029-21699 Current Operation- Tripping. MUD TYPE-Polymer 0600 Depth- 1~,283' Day' 23 24-Hour Ftg' 199' Drilling; Lost 500 psi, POH found washout in stab: RIH. -- WT'lO. 1 VIS:46 PV:IO YP'24 FL'7.0 SOLIDS:9 TEMP.92°F SURVEY MD 67 '12064 · ANGLE DIRECTION TVD SECTION COORDINATES 45.1 N89E 9283 6457 N751 E6415 1513h' DLS 1.2 Rig: Doyon #1.6 Well: 2-6/J-22 (MPI) SAPC Daily Drillin.q Report -- ENDICOTT March 21, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 12,695' Day: 24 24-Hour Ftg: 412' Current Operation: POH. RIH. Drill and survey 12-1/4" hole to 12,695 ft. CBU. POH to run 9-5/8" casing. MUD TYPE-Polymer WT:IO.2 VIS:43 PV:9 YP:24 FL:6.4 SOLIDS:lO Short trip. TEMP:IO4°F SURVEY MD ANGLE DIRECTION TVD SECTION ..... ~'67 12104 45.1 N88.5 9308 6486 69 12493 40.8 S88E 9592 6751 COORDINATES N760 N760 E6445 ' S6710 1 51 3h: DLS .... '1,2 1.4 Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAP¢ Daily Drilling Report -- ENDICOTT March 22, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 12,695' Day: 25 24-Hour Ftg: ' Current Operation: Tes-tpack-off. PON. Rig up and run 9-5/8" casing. CBU. Mix and pump cement. (9-5/8" shoe at 12,680 ft.). MUD TYPE-Polymer WT:IO.2 VIS:43 PV:9 YP:24 FL:6.4 SOLIDS:lO TEMP:104°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1513h: DLS SAPC Daily Drilling Report -- ENDICOTT March 23, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 (MPI) AFE # 717526 API 50-029-21 699 0600 Depth' 12,718' Day' 26 24-Hour Ftg' 23' Current Operation' POH~ .................. Set and test pack-off. Test BOP's. RIH. Test casing to 3000 psi Drill cement and FC and test casing. Drill shoe plus lO ' /2" ft. new hole. Perform FIT to 13.5 ppg. Drill 8-1 hole to 12,718 ft. Lost 250 psi. POH. MUD TYPE-Polymer WT:IO VIS:40 PV-IO YP:20 FL-7.2 SOLIDS:lO TEMP :88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h- SAPC, Daily Drilling1 Report -- ENDICOTT March 24, 1987 at 0600 hours Rig' Doyon //15 Well' 2-6/J-22 (MPI) AFE # 71 7526 API 50-029-21699 0600 Depth' 13,018' Day' 27 24-Hour Ftg' 300' Current Operation: Drilling.' ........ POH. Looking for washout. RIH. Drill 8-1/2" hole to 13,018 ft. MUD TYPE-Polymer WT:IO VIS'40 PV-8 YP'18 FL'9.2 SOLIDS:lO TEMP'88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS ,. 1 51 3h' Rig: Doyon #15 Well: 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT March 25, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 13,265' Day: 28 24-Hour Ftg: 247' Current Operation: Run 'open- hole"-togs-; .................... Drill 8-1/2" hole to 13,265 ft. Short trip. CBU. POH. Run open hole logs. MUD TYPE-Polymer WT:IO VIS:40 PV:IO YP:13 FL:8 SOLIDS:8 TEMP:94°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1 51 3h: DLS SAPC Daily Drilling Report -- ENDICOTT March 26, 1987 at 0600 hours Rig' Doyon #15 Well' 2-6/J-22 (MPI) AFE # 717526 API 50-029-21699 0600 Depth' 13,265' Day' 29 24-Hour Ftg' ' Current Operation' Run 7" liner~ ........................... Run open hole logs. RIH. CBU. Short trip. CBU. POH. Run 7" liner. MUD TYPE-Polymer WT:IO VIS:40 PV:lO YP:13 FL'8 SOLIDS'8 TEMP'95°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h' SAPC Daily Drilling Report -- ENDICOTT March 27, 1987 at 0600 hours Rig' Doyon #15 Well- 2-6/J-22 (MPI) AFE # 717526 API 50-029-21699 0600 Depth: 13,265' Day' 30 24-Hour Ftg: ' Current Operation- Drilling cement. Run 7" liner. Circ and work pipe. Mix and pump cement. POH. RIH w/ 8-1/2" clean-out assy, Tag cement stringers at 12,020 ft. Clean-out cement. 7" shoe at 13,265 ft; hanger at 12,403 ft. MUD TYPE-Polymer WT:IO VIS-38 PV:IO YP-9 FL'8.5 SOLIDS'8 TEMP' °F SURVEY MD ANGLE DIRECTION' TVD SECTION COORDINATES DLS 1513h' Rig' Doyon #15 Well · 2-6/J-22 (MPI) SAPC Daily Drilling Report -- ENDICOTT March 28, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth' 13,162' Day' 31 24-Hour Ftg' ' Current Operation: Clean-out linerj Clean-out to liner top at 13,385 ft. CBU. POH. RIH w/6" clean-out assy to liner. Test liner to 3000 psi - OK. Drill cement to LC and to 13,162 ft, MUD TYPE- WT:IO VIS- PV- YP- FL' SOLIDS: TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h' Rig: Doyon #15 Well: 2-6/J-22 /MPI) SAPC Daily Drilling Report -- ENDICOTT March 29, 1987 at 0600 hours AFE # 717526 API 50-029-21699 0600 Depth: 13,164' Day: 32 24-Hour Ftg: ' Current Operation- L/D drillpipe, CBU. Test liner to 3000 psi - OK. Displace well to 9.8 ppg NaC1. Test liner to 3000 psi - OK. POH. L/D drillpipe. MUD TYPE-NaC1 WT:9.8 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h: SAPC Daily Drilling Report -- ENDICOTT March 30, 1987 at 0600 hours Rig: Doyon #15 Well: 2-6/J-22 (MPI) AFE # 717526 API 50-029-21699 0600 Depth: 13,164' Day: 33 24-Hour Ftg: ' Current Operation' Rig up Otis' L/D drillpipe. R/U Schlumberger and run cased hole logs. 7" completion and land in wellhead. R.U Otis. Run MUD TYPE-NaC1 WT:9.8 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h: SAPC Daily Drilling Report -- ENDICOTT March 31, 1987 at 0600 hours Rig' Doyo'n #15 Well' 2-6/J-22 (MPI) AFE # 717526 API 50-029-21699 0600 Depth' 13,164' Day: 34 24-Hour Ftg: ' Current Operation' Displace tubing w/diesel. Set plug in 'XN' nipple. Set packer. Shear-off seal assy. Re-run hanger and land tubing. N/D BOPE. N/U adaptor flange and master valve. Test same to 7500 psi - OK. Test tubing to 3000 psi - OK. Test 9-5/8" x 7" annulus to 2000 psi - OK. Open sliding sleeve. Displace tubing to diesel. MUD TYPE-NaC1 WT-9.8 VIS' PV- YP- FL' SOLIDS- TEMP'°F SURVEY HD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 513h: Rig' Doyon #15 Well' 2-6/J-22 IMPI) SAPC Daily Drillin§ Report -- ENDICOTT April l, 1987 at 0600 hours AFE # 717526 API 50-029-21699 Current Operati on' MUD TYPE- WT' 0600 Depth' 13,164' Day' 35 24-Hour Ftg' ' Displace tubing to diesel. Close sliding sleeve. Install BPV. Release rig at 1200 hrs. on 3/31/87. Move to 1-41/0-23. VIS- PV- YP' FL' SOLIDS' TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1513h' ex?,~ple$ · reol,.; t Is Standard Alaska Production Company 900 Eost Benson Boulevor~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells Dear Mr. Smith, ALASKA PRODUCTI~;, ~ lco,,:,,,~,~ ..... ~ ~ ~,prll 3, 1987 i;'?'..''::is !-::-~',!',~ ..... i'F ~ I.n~':':':':~ ....... ~'-'I I ii for all future "~'~' ..... (~ ,~1i We are requesting that the AOGCC adopt dual designation well names in the Duck Island/Endicott Unit for operational and safety /)~,~.~'~'~ reasons. Dual designation lists the numeric surface location followed by an alpha-numeric bottom hole location. This will be indicated in future wells on Form 10-401 in Item Number 8. We also ask that wells drilled to date be referenced by this dual designation. For your use is a llst of wells drilled to date. WELL NAME PERMIT NUMBER API NUMBER 1-5/0-20 (MPI) 1-Z7/P-20 (MPI) 1-29/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 (SDI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/5-36 (SDI) 3-47/Q-35 (SDI) 4-8/P-27 (SDI) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) , ~ ~,~ ~'bni' of the original Standord Oil C .... party ~[ound~d in Cleveland, Ohio, in t870. 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 We thank you for your assistance and should you have any questions, give me a call at 564-5007. Yours very truly, R. S. Allan Division Drilling Engineer RSA/MAW/pm/1664D cc: R. H. Reiley_ J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development February 24, 1987 Mr. R. S. Allan District Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, AK 99519-6612 Telecopy: (907) 276-7542 Re: Duck Island Unit/Endicott J-22 IIPI Standard Alaska Production Company Permit No. 87-18 Sur. Loc. 1852'SNL, 2180'WEL, Sec. 36, T12N, R16E, UM. Btmhole Loc. 125t'SNL, 237'EWL, Sec. 32, T]2N, R17E, UM. Dear Mr. Allan Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~V~> truIff zy~s~ f ~ C. V. Chae~r~on/ Chairman ~' Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION jo Enclosure CC: Department of Fish & Game, Habitat Section W/o encl. Department of EnVironmental Conservation w/o encl. Mr. Doug L. Lowery Gas Injection Well STATE OF ALASKA ..... J-22 MPI ALASKA ,L AND GAS CONSERVATION C~ .4MISSION Row 2 PERMIT TO DRILL 20 AAC 25.005 t la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [3 DeepenE]I Service [] Developement Gas [] Single Zone ~J Multiple Zone , 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56 feet '" Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612 ~ Anchoraqe, Alaska 99519-6(~.12 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1852' SNL, 2180' WEL, Sec. 36, T12N, Ri~E Duck Island Unit/Endico~:t At top of productive interval 8. Well nu ,mber Number J-22 MPI K00683449-G-14 1275' SNL, 190' WEL, Sec. 31, T12N, R17E At total depth 9. Approximate spud date Amount 1251' SNL, 237' EWL, Sec. 32, T12N, R17E February 25~ 1987 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 13341' MD ADL 47502 4005 feet Surface 10 feet 2560 10546 ' TVD feet 16. To be completed for deviated wells~ o 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2600 feet Maximum hole ang~7' 9 0 Maximum surface 3900 psig At total depth (TVD) 9855 4840 psig 18. Casing program Settin~l Depth I size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Str~lctural Driw PiPe ] 3] ' ]231' Dr~va 17-1/2" 13-3/8" 68~ L-80 Butt. 2444' Surfac; 2500' 2500' 2700 cu.ft. Permafrost 12-1/4" 9-5/8" 47~ .~T80S NSCC 10725' Surfac,; [0781' 8500' 320.'cu.ft. 12-1/4" 9-5/8" 47~ .~T95H: NSCC 1784' 10781'~ 8500' [2565' 9696' 425 cu. ft. Class G 8-1/2" 7" 29~ SM-11( Butt. 1026' 12315' 9528'[3341' 10546' 375 cu.ft;~. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ~':'E ~ ~'_ (.3 Liner Perforation depth: measured Naska 0il & Gas 60¢,s, true vertical Anchorage 20. Attachments Filing fee [] Property plat ~i BOP Sketch [] DiverterSketch Q Drilling program ~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. ~o ~ Title Division Drilling Engineer Date2//~/~) Commission Use Only Permit Number I APl number I Approy, a,t date, ,.,-, I See cover letter ,~ ? -( ,~ [ 50-- © ,"k- ~ - 'i¢----i (~ (f ~ I u z/z/4 / ~ / .J for other requirements Conditions of approval Samples requir.ed [] Yes '~i¢'No Mud Icg required LQ Yes ,~ No Hydrogen sulfide measures [] Yes '~ No D. irectional survey required ,~!~,Yes [] No Required working~p.r.e~sure/f, pr ~/J~M; ~ 3J~/I; ~ 5M; [] 10M; [] 15M Other: ~/,~,-~ ~~ - - " ~ by order of Commissioner the commission Date Approved by Form 10-401 Rev. 12-1-85 i , / Sub~i :ate PROPOSED DRILLING AND COMPLETION PROGRAM WELL .I-22 (MPD .Operation Execute a rig move from slot 1-27 to slot 2-6 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., L-80 Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 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. Vertically drill 12-1/4" hole to 2600 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run logs. Run and cement 7" 29#/ft, SM-Il0 buttress liner to TD with approximately 250 ft. ~f.,~l~p in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3~000 psi. Change over to NaC1 packer fluid. Run CET/CBT/VDL/GR/CCL in 7" liner and 9-5/8" casing to top of cement. Run gyroscopic survey from PBTD to surface. Run 7" completion and install and test tree° Release rig. Perforate the well using wireline conveyed casing guns. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. RECEIVED FEB 2 0 ]987 glaska Oil & Gas Cons, bommlssio,~ Anchorage ENDICOTT PROPOSED DIAGRAM WELL 2-6/,,I-22 (MPI) DIESEL NON-FREEZING FLUID TYD (eKe) MD CBKB) 3O" DRIVE PIPE BASE PERMAFROST SSSV TOP OF DOWN SQUEEZ~ CEMENT 131FT 131FT 1410 FT 1410 FT 1516 FT 1516 FT (ESTIMATED 2000 FT) 13-3/8" 68#/FT L-80 BUTT 2500 FT KOP ( DIR: N 85 E; ANGLE: 47.9 DEG ) 2500 FT 2600 FT BO'I-I'OM OF DOWN SQUEEZE CEMENT (ESTIMATED 3000 FT) 7" 26#/FT L80 IJ4S TUBING W/ 5-1/2" TAILPIPE 9-5/8" 47#/FT NT80S NSCC TOP OF 9-5/8" CEMENT 8500 FT 10781 FT (ESTIMATED 10885 FT) 5-1/2" SLIDING SLEEVE 9-5/8" TIW BIG BORE PACKER "X" NIPPLE (4.562" ID) "XN" NIPPLE (4.455" ID) WIRELINE RE-ENTRY GUIDE 7" LINER TOP 9428 FT 12165 FT 9528 FT 12315 FT 9-5/8" 47#/FT NT95HS NSCC 9696 FT 12565 FT PLUG BACK TD 7" 29#/FT SM-110 BUTT LINER 10546 FT 13261 FT 13341 FT 2-17-87 B.O.P. STACK CONFIGURATION 13-5/6 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER I I I I PIPE RAMS [ 1 ,, BLIND RAMS 1 2 IN. KILL LINE GATE GATE DRILLING SPOOL PIPE RAHS , ! ! ,, 4IN. CHOKE LINE GATE GATE I RECEIVED ~a~ka Oil & Gas Cons. ~,;~mmi~sior? Anchorage __ II III DRW NO. IlO' i5 SHE:ET I ®f IO RE:¥. O i i i Gas Cons, Com, mi~sion Anchorage PLAT OF PROPOSED WELL LOCATIONS MPI 1~111 L/cited IA I;A¢.II,,T. IZN.,R.I$[.,Umi~t M. :lOl WMII LooMed la &t-~'. tBT. IIN.,R.I?[.~UB~.~ It PR[PAR[D IroR SOHIO ALASKA P£TROLEUM CO. i ii ii i i iii il PRgP&RIB IY F.R. BELL & AS:SOC. PRUDHOE BAY OFFICE PRUDHOE ~l, yo &L&I4(A iii I I I I · ATE: NOV. ICALE: I'"1 MILE N · Y: NB.T, IV' $1 14 0 I~ 0 24 I 70 ii ,, ~) 0 53 0 575~ 0 5~_ 0 36 36 CERTIFICATE OF SURVEYOR I #earby certify that I em properly registered end licensed to practice land surveying In the State c~ Alaska and that this plat represents en propoled location for the'Well numberl shown above. Ail lurveying was done by me or under my supervision, and that ell dimensiofls end details ere correct. Indicates well Indicates CalcUlated Section C:er~er PosltJon Indicates Parllendic.ler Offset Distance Indicatqs h~iculer Off~t Dimte.ce PLAT ~ MPI PROPOSED WELL LOCATIONS LOCATED IN SEC. SI, T. Ii~II.,R. II E. UMIAT M. DRW. 116-8§ SHEET 2 of I0 REV. 0 PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED IY DATE: Nor. IS, 1818 F.R. BELL S ASSOC. ' SCALE' I "" PRUDHOE BAY OFFICE PRUDflOE BAY, ALASKA CHECKED mY: B.E. I~LL liSP ZlI~ $ UTL JN~ 6 LAT!TU~E LI~ ~ i I Y- S912412.~7 N- 710~324.S1 7~Z1'10.0670~ 14~17'~,q~' X- 2~9~10.7~ E- 464~37.36 2 Y- 5982579.88 N- 7805353.~2 70~21'10.t814' 147057'24.6257. Xm 2~904~.49 E- 464094.45 ~ Y- 5982474.18 ~N- 7805521.98 70~ 21' 09. 9846' 14~757'20,6258' 19~6.77" 20~2.1i ~X= 259175.01 ~ E- 464155.65 ~ iX- 259055 76 E- 464092 74 5 ~Y= 59824~5~99 N= 7805519 46 70° 21' 09. 9025' 147c57'20.78'5~'~i-~-~5'~ ~7.'-5'8 ~X- 259169.27 E- 464155.95 6 Y- ~982563.~0 N- 780~348.47 70°21'10.816B"'' 1'47°~7'24.94~4" IB~2.17 2179.88 X- 2~9030.02 E- 464091,04 7 Y- 59824'~7.80 N- 78053~6.94 70021'09.8200, 1470~7'20.945~' 1953.~2 2043.06 X- 2~9163.~4 E- 464132.24 8 Y- ~9825~5.30 N- 7B0~34~.94 70o21'10.7344' ~47°~7'25.10~3' IB60.~'4 21B~.3~ X- 2~9024.29 E- 464089.33 9 Y- ~9B2449,61 N- 7~0~14,41 700 21, 09, 7~76' i ~47°~7'21~Q~4' X- 2~9~7.10 E- 464130.53 10 Y- 5982~47.11 N-'7B0~343.42 70o21'10.6521, 1470~7'25.2651' IB6B.91 2190.13 X- 2~9018.S~ E- 464~87.62 11 Y- 5982441.42 N- 78053~1.B9 70~21'09.6~53' '"147057'2~.2653' 1970.26 20~4,00 X- 259~52.07 E- 464128,83 12 Y- ~9B2~38.92 N- 780~340.90 70~21'10.5697' 147~57'2~.4250' lB77,2B 2196.'30 X- 2~9012,82 E- 464085.92 , 13 Y- 5982433,23 N- 780~309.36 70°21'09.~730' 147°~7'21.4251" 1978.63~ 20~9.47 X- 2~9146.33 E- 464127.12 ~ 14 Y- 5982530.73 N- 7805338,37 70~21'10.4874" 147°57'25.~B49" iB8~.~6~ 2201.77 X- 2~9007,08 .~' 464084,21 15 Y- 598242~.03 N- 780~306.84 70c21'09.4906" 147c57'21.5B50" 1987.00 20'64,94 X- 2S9140.&0 E- 464125,42 16 Y" 5962522,~4 N- 7605335.65 70o21'10.40~1· 147o57'2~,7447· 1194.03 2207,24 x- 259001.35 E- 464062,~0 17 Y- 59824'14.04 N- 7605~04.31 70°21'09.40e3· 147o57'21.7449· i995.36 2070.41 l- 259134.66 E- 464123,71 11 Yn 5962514,35 N' 7B05333.32''~ 70~21'10~'3227' 147057'2~,9046' " 1902.40 2212.71 X- 2~8995.61 E- 464060.80 19 Y- 5982408,65 N- 7B05301.79 70~21'09.3260' 147°57'21.9047' 2003.7~ 2075.19' X" 239129.13 E' 464122.00 20 Y' ~9B2506,16 N' 7805330.B0 70c2~'~0.2404" 147°~7'2&.O&44" ~9~0.77 2211.1g X" 2~8989,B7 E' 464079.09 21 Y' 5982400.46 N' 7805299.27 70°21'09,2436" 147°57'22.0&4&" 2012.12 20~1.36 X' 2~9~23.39 E' 464120,30 i II ~~-- ~< [; ~ ?: ~ V ~ L~ MPI PRO~SED WELL L~ATION LIST ~ '~ ,' ~ An..,~,.~,¢~ SOHIO ALASKA PETROLEUM CO. ~. OFES$~~ SHE g S of IO F.R. BELL A ASSOC. SC*L[ · N/~ ~~~~ ~ PRUDHOE BAY OFFICE D~AWN aY: ~.~ REV. O PRUDHOE BAY, ALASKA CHECKED BY~ I.E. i ~ Zlal I V, 6 L&TITIIfl Lk TUN ii Y- 19124t7.97" N- 710s32i.z7 7F'Zi;'i0".'iHl'14~17'~21.224~ X-,~ltl4. i4 E- 414077.31 23 Y- 59B2392.27 NI 7B0529&,74 70°2J'09."ib13' 147~57'22~2244 '24 ,Y' 5982489.77 N' 7805325.75 ~70~'21'10.~0757' 147~57'26.38~2' 1927.53 2229.~3 X= 258978.40 E= 464075.68 . 2~ Y- ~982~4.0e ~ Zeo~2e4~22-~o~2~'o~.o~'0'~ ~14~:~'22.~4~' 202e.ee 20~2.~0 X= 259111.92 .~ E= 464116.88 ~ i .... 26 Y= 5982481.58 ~ N= 7e05~2~.2~ 70~ 21'09.99~4" ~147~57'26.5440" ~ 19~5.90 22~4.b0 .X= 258972.67 ~ E= 46407~.97 ~ 27 TY= 5982~75.89 ' N= 7805291.69~ 70~21'08.9966" 147~57'22,~442· ~ 2037.24. 2097.77 X= 2~9106'18 E= 46411~,18 ~ ._ 28 Y= ~982473;39 N= 7'805320, 70~70~21'09.9111· ' 147c~7'2~;7039· ~944."27 2240,07 X= 2~896693 E= 464072.27 i 29 Y= ~982367,70 N= 7805289,17 ~70c21'08,9143" 147c~7'22,7040· 2045.'&1 2103~2~ X= 2~9100,4~ ~E' 4&4~13.47~ 30 Y= ~98246~,20 N= 710~318.18 jTOe21'09,12B7· 147~7'2&,1~37' 19~2,~4 ~2245,S4 X= 2~8961,20 E- 4&4070,S6 ~ 3~ Y= ~9823~9.~0 N= 710~28~.&~ jTO~2t'08.B320· ~47cs7'22,B&39· 20~3, 98 ~ 2101, 72 X= 2S9094,71 E= 464111,7& ~ 32 Y= ~9824S7,01 N= 780~31~,&5 ~70c21'09;74&4· 147~7'27,0236· I~&l,Ol i22~1,01 I X= 2~895~,46 E= 464068,B5 { 33 Y= ~982351,31 N= 7805284,12 ~70~21'08,7496" ~'47eS7'23,0237' 2062,3~ {21141 .19 X= 259088'98 E= 464'i0'06 i : ~4 Y- ~982448.82 N- 780~,~ 70c2~ 09.6642' ~47~57'27.~1~4' ~9&9"~'38 r22~6.49 X- 2~8949.7~ E- 464067.~ ~ 3~ Y- ~9823~8.~ N- 780~274,02 70~2~ 08.4203' 247G~7'2~.&&~2' ~ 209~.14 2~6.07 X- 2~9066.03 E~ 464~0~,2~ 36 Y= ~982416.05 N= 7805303.03 70°21'09.3347' 147c 57 ' 27,1229' 2002.17 2278.37 X= 258926.78 E= 464060,32 ~ 37 Y= ~982310,36 N= 780~271.50 ~70°21';0B;33'79' 147°57'23.B230' 2104.21 2141.5~ L X' 259060,30 E= 46410t'~3 3B Y' ~982407.B6 N= 780~300.~1 ~70°21'09.2524' 147°~7'27.9127' 2011.24 2283.84 X' 2~892~.05 E= 4&4058.&l 39 Y' ~912302.17 Nm 710~26B.98 7~'21'0B.25~' 147~57'23.9B29' 21'12.51 2147,02 X' 2~90~4.~6 E' 464099.B2 40 Y= ~982399.&7 N= 7B05297.98 j70o21'09.1700' 1470 57 " 2B'.142&' 2019;~2' 2289.31 X= 2~891~.31 E= 4640~6.91 41 Y' ~9B2293.97 N= 7B0~266.45 70°21'08.1733, 147G57'24.1427' 2~20.~5 2'152.49 X= 239048.B3 E= 464098.11 , 42 Y' ~9~2391.48~ N= 7B0529~.46 70021"09.0877, 147°57'28.3024' 2'~27.99 2294.79 X- 2~8909.~8~ E= 4640~'20 , I i ~--~~",~.~ o~ & uas Cons. Co~ An~o,~ge SOHIO ALASKA PETROLEUM CO. m ii I i i '"~'~'~'~ ~ F.R BELL & ASSOC '~~~~ SHEET 4 of IO · · SCALE: N/A -~~~ PR UDHO E BAY O~ CE -', ,Er. O PRUDHOE BAY, · CHECKED BY: B.E. i iii i i i ii i iiii iiii I ~ I IIII L ~ i i i ~ - I I KLL ~IP ZO~ Z UTh .ONf & L~TITUIE Lk .r~E IllT~ 43 Y-S9122fl.71 N-710~2&3~'93 70~2'~'0i.0909· '14~b7~'24.~&' ~1~'1i X' '~9043.09 E- 46409&.4~ 44 .... Y- ~982383.29 N- 780~292.93 '"7'0~21'09.00~4'' 147'°~7'2i.4&23'' 203&.3& 2300.26 X. 2~8903.84 E- 464053.~0 . . ~ X- 2~9037.36 [- 464094.70 -~~ ....~-~-~9B237~.10 N- 7G0~290.41 70' 21":-~B~ 9230' . 147~7'2B.6221''*~ X- 2~gggB. 11 E- 4640~1.79 ~ 47 Y- ~9B2~69.40 N- 7G0~2~B.B~. 70c21'07.926~' 147c~7'24.6223' ' 2146.07 X- 2~9031.62 E- 464092.99~ ; x- E- 4640 0.0e 49 Y- ~9B2261.21 N- 7~0~256,35 70~21"07,8439· 147°~7'24.7122' 2~4.44'~ 2174.38 X- 2~902~,89 E- 464091,29 ~0 Y- 59B2358.71 ~- 780528~,36 70o21'08',7584' A47°57*2B,941B' '20,1',47 j 231&,&7 X- 2~886,63 E~ 464048.3G ' ~1 Y- ~98225~.02 N- 78052~3',83 70~2'1"07,7616' [ 147°~"7"24,9420' 21&2,1~ ~ 2179,'b6 X- 2~9020,1~ E- 464089.~8 / ~2 Y- 5982350.~2 N- 7805282,84 70c21'08.6760' ' 147°57'29'~'0~7' 2069,15 2322,~4 X- 2~B880.90 E- 464046.&7 ~3 Y- 5982244,B3 N- 780~251,31 '70~21'07.6793' 147o57'25,1019' 21~1,19 218~.33 X- 259014,41 E- 464087,88 ~4 Y- ~982342,33 N- 7805280,31 70e21'08,~93'7' 147°57'29,2&~5' 2078,22) 23'27,&2 X- 258875.Z6 E' 464044.96 5~ Y-' ~982236.64 N= 780~248,78 70c21'07,5~69' 147o57'25,2&27' 2179.56 2~9'0',80 X- 259008.68 E- 464086,17 ~6 Y- 5982334,14'~ N-'780~277,79 70~2i"08,5113' 147o57'29,4214, 2086.~9~ 2333.09 X- 258869,43 E- 464043,26 57 Y- 5982228,44 N- 7B05246,26 70o2~'07,~14'6' 147o57'2~.421&' 2'187,93 2196:27 X- 259002,94 E- 464084,46 0o2 *0 .42 0' z47 7'29. ;z;· X' 2~8~63,&9 E- 46404~,~5 59 Y- ~982220,25 N- 7805243,73 70o21'07,4323" 147°57'25,~114" 21~&,'30 2201'~74 X" 258997.21 E- 4&40B2,7& &O Y- S9823~7.76 N- 7805272.74 70o2~'0B.'3467' 147~'57'29.741~' 21'03.33 2344.03 X- 2~8857,96 E- 4640~9.B5 Al Y-59822~2,06 N-"7'805241.21 '70~'21'0'~.3499' 147057'25.741~' 2204.&7 2~07,21 X- 2~8991.47 E- 46408~.0~ &2 y,' ~982309.57. N- 7805270.22 '70c2~'08.2643· '~47o57'29.9'009· 21~'7'~ X- 258852.22 E- 464038.14 ~3 Y-~91220~'S7 N-78052~8.&9 70o2Z'OT.267&' '~47o~7'25.90~' ~ 22~3~'~ 22Z2.&9 X- 258985.74 E- 464079.34 ,d .......... II I I IIII I I I II I III I I I I I B .~, PRO~SED WE~L TION LIST ~_ ~ ~-- ~ LOCATED IN ~C. 3&,T.I~N.,R. I~E. UMIAT M. . ~ ~ ~' ~*~(~/ PR E PARED FO R _ ~~ldc. a 0~i & Cas Cons, Co)nm ......... I'0 A~,,~o,~.;~ SOH ALASKA ~TROLEUM CO. II I ,. , '" ~I?~-~~ ~-- ' F.R BELL S ASSOC ~k~'v~-E~~--~ SHEET Sol IO ' ' ~CALE' N/A '~~~ . PRUDHOE BAY OFFICE ~R'*wN IY : RG.1 REV. O PRUDHOE ~Y, ALAS~ C~gCK[O~Y ~.~. I lira I I I I I II II I I II I I tlLrLL ~IP ZONE ~ IIT~ ONE 6 I. iTITIIll LO~ .TUll ~ Y- 191230i,31 II- 7105267,69 70021'01,1120· 147c~17"I0,0i~01' ZlSe,fl l$S4,97 X" 251146.41 E" 464036.43 63 Y- 5982195'.68 N- 7105236. J'6 70°21'07.1852" 147°S7'26.0610' 22~1.43 2211.1& X~ 2~8980.00 E- 464077.&4 66 ~Y- ~8229~.18 N- 780~2&~.17 70-21'08.0997" 147'~7'30.2206' 212~.4~ 2~0.4~ ~ X= 258840.75 E= 464054.73 X= 258~74.26 E- 46407~.~3 ~ 68 Y= 5~82284.99 N- 7805262.64' 7~21'08.0173" 147~57'30.3805" "~ 2136.82 2365.92 X= 258835.01 E- 464033.02 ~ : X= 258968'~31 E= 464074 23 70 Y- 5982276.10 N= 7B05260,Z2 70~2~'07.9350' ; ~47cS7'30.5403' 2~4~.~9 237~,39 X= 2~8829 28 E- 464031 MPI PRO~SED WE~ L~ATI~ LIST PRE PARED FOR 'i~d~---~~~ S.EET 6 of ~O ~.R. BELL & ASSOC. q~ss[~~ pR U DHOE BAY OF FICE ,, ~. o PRUDHOE B&Y~&L&SKA ~&WN ~Y. ~.;~. .... , , CHECKEO BY: B.E. ENDICOTT DEVELOPMENT WELL ~1-22 (MPI) SLOT 2-6 SURFACE LOCATION X = 259,030 FT ; Y = 5,982,564 FT 1852 FT SNL; 2180 FT WEL SEC 36, T12N, R16E TRUE NORTH GRID ~, ,,,,85 E DEPARTURE TO TARGET: 6876 FT 12764 FT MD 9829 FT TVD BKB DEPARTURE TO BHL: 7304 FT 13341 FT MD 10216 FT TVD BKB RECEIVED 2-18-87 _$25DUA88:[DRANO15]MId22_CLOSAP_SHORT, LIS;1 Search Radius= 1000 COURSE LINE For proposed well' d-22 [41-31-12-17] Location = W-E S-N TVD{SBS) Top 259030,00 5982564,00 -56.00 Bottom 266324.55 5982944.29 10160,00 Note' All depths in Feet Below Kellg Bushing (BKB) Closest Approach Analgsis 18-FEB-1987 07'10 Date' 18-FEB-87 Time' 07'10'00 Page WELL IDENT Closest Approach /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART A000-000005! MI-1 0,0 0.0 A000-0000083 MI-33 0,0 0,0 A000-0000086 MI-36 0,0 0,0 AO00-O000119 MI-6~ 0.0 0.0 AO00-O000]~O MI-70 0.0 0,0 A029-~051800 MI-SD7 8362,0 5251. 9 A0~9-2064000 MISDIO 5153~ 0 ].6~9. ~ A0~9-2156800 MI-P18 2827 6 ii~8 AoDg-~i58500 MI-M19 ~ ~ = Aozg-2].60500 MI--020 3375. 2 1'35. 3 MI-~21 100 9 O. 0 A0;9-~163900 Mi-016 A029-2164800 MI-Qi7 A029-2166200 MI-PI4 A0~9-2166900 M!-M~5 0.0 0.0 CLOSEST DISTANCE 171, 8 0.0 0.0 221.0 0 0 0.0 0 0 0.0 0 0 0.0 8834 9 4842 9 5566 3 0 0 9 ~ 3378. 7 0,9 0.0 100. cc ~' 0 2aO0. 0 O. 0 .i. 00, 0 0 0 _5 0,0 i00. 0 260O. 9 6 I O. 8 0.0 0.0 0 0 180,3 389. 8 350, 4 991. 5 596 6 14 4 3 7 9~,) 9 ~o~ 0 41. 0 3]0 S 136 3 209 ! Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY\ TVD DEPART VER T I C AL D I STANCE 4984~2 1512.3 5818. 2 209!. ! The ~ell u_~h J. ci~ COl'~eS /.: Q. ~..,"~ q'--, 2 1 5.) 8,9 0 0 c.,.~os,,,st_ to ',,he N il .... M 1 ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLAND WELL J-22 (Iv[PI) Interval 0-2,500 Mud Weight (PPg) 8.8-9.8 Viscosity (sec/qt) 100-200 Fluid Loss (ml/30min) 20-15 9.0-9.5 Mud Type/ Components Generic Mud #5 Seawater Fresh Water Soda Ash Set 13-3/8" Casing 2,500 - 12,565 9.2-10.2 40-45 10-12 10.0-10.5 Generic Mud #7 Seawater Fresh Water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite New Drill Set 9-5/8" Casing 12,565 - 13,341 9.6-10.2 40-45 6-8 9.7-10.5 Generic Mud #7 Seawater Gel Caustic Soda Soda Ash Barite Lignosulfonate Drlspac Lignite New Drill G~V/pm/ 1563D Hang 7" Liner DOYON DRILLING, INC. RIG NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equ i preen t Manufacturer Nominal Model Capaci tM Shaker Desander Mudcleaners Centr i fuge Brandt Dual Double Demco 2-12" cones Tri Flow Double 8 each - 4" cones 1000 9pm 700 9Pm (each) 400 9Pm (each) Pioneer Mark I!, 150 9pm Decant i n 9 Degasser Dr i I co Agitators Brandt Geosource Vacuum 1000 9pm 8 each - 25 h.p. Hoppers Dual Sidewinders 1000 9pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drillin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. I I I IF IN I~OUBT - . - ASK. I! I'f ' C. IZ 'C ' jt .,L -7 ~o° - ASKtl Ill I11 I I. I -79 '.-o TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4%" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG. 7) · 1.) Make up the 13-1/8" x 4%" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the ~est plug through the B.O.P. stack until it lands on the low6r load shoulder of the. split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back.out ~all lockdown 6.) Remove the test plug. screws which have been run in. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG THIS END UP L . FMC P.N 48-261-082 REQ'D PART NO. DESC~i~i'bN 1 48-261-268 Test Plug 1 48-261-083 Body 1 " 48-26I,-673 Compression Ring 4 7~-0'~0-'074 Set screw's ,, 1 48-081-529 Packing 1 51-092-001 2" Ball Check Figure #7 .(part number :48-261-082 continued on next page) FMC P.N. 48-261-082 continued REQ'D. PART NO. D~SCRIPTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug 1 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 WP 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13%" X 4%" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13%" x 4%" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. · 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG IS END UP L FMC P*N. 4,8-261-068 'REQ'D ' . PART NO. ,i,~ DESCRIPTION ,48-261-067 Body · .48-261-'671 Compression Ring ~79-040-074 ~'~Set screw '82-741-1117. · cking , , , 51-0'92L061 2" Ball Check 19'-505-663 Coil Spring , , , 25-411-356 Retaining Plate 25-411-357 Cir<.-O-Lox Ring , 48-180-027 Pipe Plug Figure i#19 ILLUSTRATION# 13 STACK :5/8" 5000 WP 13-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4%" IF test plug (combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill Pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all .the lockdown scres which have been run in. 6.) Remove the test plug. 10" COMBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL THIS END UP . - -FMC-i~ART31%i~N0..~4 8 ~ 2.6 !,? 5 03;~. .- ~--':'-· "~r:¥~._ . %';~:.'r~'~:~Vg~':~, !...':~?<:.:~'. - . ..". · ": · " ' 1 . . 48-26IV~504 - ,BODY , , ! 48--085-833 '. BELT' PACKING . 4 ;4~-180-015 P~U6, ~ ~.P. ., . ,. '. --,~ . , 1 48- 010- 009~R~NCH (Figure t22A) "~ B.O.P. STACK ........... 1" 5000 WP 13-5/8" 3000 ~ B.O.P. STACK 5000 WP 11" 5000 WP 13-5/8" 3000 WP / . , / CHECK LIST FOR NEW W~.1. PERMITS ~ APPROVE DATE (1) Fee ~A~/ ~ - ~ ~ - yz 1. Is (2) Loc ~ ~_ ~-~-4r7 ('2ttLru 8) ® 4. 5. 6. 7. (3) Admin , ~-~z ~-~? 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg -~,~.~., ~-ag-g? (14 thru 22) h./;, (29 thru 31) (6) Add: Geology: rev: 01/28/87 n!l YES NO RMWARKS the permit fee attached .......................................... ~ -- , ,, Is well to be located in a defined pool ............................. IS well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Does operator have a bond in force ........................ , ......... ~ Is a conservation order needed ...................................... . ~ Is administrative approval-needed ................................... Is the lease number appropriate ...................... ~ Does the well have a unique name ~'~~' .. .111 .... [ ..... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will c~t cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipme_nt adequate ~ Are necessary diagrams and descriptions of ~'~r~_~r-_~nd BOPE attached. Does BOPE have sufficient pressure rating - Test to Maoo~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .... /. ............ Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented- 32. Additional requirements ............................................. INITIAL GEO. UNIT DN/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. L~36I Z- AV~I ;;~ ..... SCHLUM5 ERGER ....... L2S T~ V'~Ri~iCATZON LZSTZNG VP OiO.H02 VERIFIC4, TISN LZST~NG PAG5 :~= REEL Hr-"ADER,.. -,-' ...... ;,- ERVICE NA,l~ :~DiT ,ATE :87104/ 1 i~iGlN : EEL NAM6 :TZZ$? ,ONTINUATION ~ :Oi 'R~ViOUS ~E~L ~MMENIS .LiS T~P~, 5TA;10~Rn E N :3 T C i,3'T T 50-029-21699 ~';= TAPE, HEADER ...... -,,--,- ;ERVICE NANE :EDIT )AT~ :$7/04/ '~ IRIGIN :7ZZ4 'APE N~PIE : 'ONTiNUATION ~ :0i ~REVZOUS TAPE : 'OMMENTS :LiS TA~E, MPI, AP I 50-029-21699 ~ PILE NEADER :iLE N~M~_ :EDIT ;ERViCE NAME : 'ERSION ~ : )ATE : tAXIMUM LENGTH : :ILE TYRE : 'REVZOUS FiLE .00i 1024 ~;:-' iNPORMAT!ON RECORCS ;k~ ~NEH CgN'TENTS UNIT TYPE CA'TE SIZE CODE 'N : STAND~R:3 &LASK.~ PRODUCTION CgH 000 000 030 065 ~N : 2-6/J-Z2 (~Pi) go0 000 014 065 :N : ENDICOTT 000 000 008 065 ~ANG: 16E go0 000 004 065 ~OWN: i2N 000 000 004 065 i~CT: 35 000 000 002 065 'OUN: NORTH SLOP~ 000 OOO 012 065 ~TAT: ALASK& 000 003 006 065 ]TRY: USA 000 OOO 003 065 4NEM CO~'~TEN'TS UNiT TYPE CATE SIZE CODE :RES ,VP OiO.H02 V~I~IC~TiON tiSTiN% .~LASK~ COMPUTING CENTER GMPANY : STANDARD ALASKA PRSDUCTiON CO ELL = Z-A/j-.Z2 MPZ i~LO = ENDZCO'TT OUN'TY = NORTH SLOPE BOROUGH T&TE = ,6LASKA fOB NUMBER AT AKCC: 7£247 UN ~1, ATE LOGGED. DP: RIrK KRUWELL ~A S i N G 'YPE FLUID iENSITY ~ISCOSiTY ;LUiD LOSS IATR!X SANDSTONE = 9.525" J~ 12580' - BiT SiZE = 8.5" TO 13265' = 10 LB/G RM = 2.32 @ 62 DF = 4C S NMF = 2.30 ~ 67 OF = 10.5 RMC = 5.30 @ 67 DF = 8.0 C3 'RM ~&T 8HT = .825 @ !87 OF THIS OAT~ H~S BEEN DEPTH SHi~TEC VP OiO.H02 YERiFiC~TiON LISTING P A G E -,. $CHLUM~E!~;3ER t-nGS TNCLUnED WITH '" DUAL LAT~RLOG (DLL) -~. DATA AV'A!LABL~:', c. ~ 3P34'~ Tg 12656' ~. LiTH~ DENSITY cOMPENS,~TEO LOG (LDT) .... '~ ABLE' 13200' -,. DA'TA A'V ~, ~_ · ~ -,- uOMP" ~'SATEo N~UT ~'~ ~uN LOG (LOT) =~A'TA ~.VA'rL,~Lci 13200' 'T~ 12656' :.'~T ~ Y' ~LDCKS TY?E SIZE REPR CODE ENTRY 4 I 66 I 8 4 73 9 ~ 55 . I IN 16 1 56 1 0 1 66 O )ATUM SPECIFICATION SLgCKS ~NEM SERVICE SERVICE UNIT AP~ ~ -.- ~ ~ ~i AP1 AP1 Fltm SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS >EPT FT O0 OOC O0 .LS OLL OHMM O0 220 .LD OLL OHMM O0 220 i0 )ALS DLL iN O0 000 O0 iP DLL MV O0 010 ;R DLL GAPi O0 310 C1 )VO OLL MV O0 000 OO PROCESS C2DE (OCTAL) i 68 00000000000000 1 ~ 00000000000000 i 68 00000000000000 1 63 00000000000000 i 68 O000000OO00000 I 68 00000000000000 I 68 O0000000000000 VP 010.~02 ~'0 OLL VO DLL I0 DLL Vi DLL RES OLL TEM DLL ENS DLL HO~ LDT EMO LDT PHI LDT EF LOT AL~ LDT SHY LDT SHY LDT LS LOT SS LDT ,L LDT U L3T ,S LOT ,.iTH LDT ,S1 LOT S 2 L DT PHZ LDT RAT LDT NRA LDT CNL LOT CNL LOT iRES LDT I'T E M L O T '~NS LDT V=RI~:TCATT'O"' ' ~.,i LZST~'NG UA O0 000 OO 0 ~4 V 00 00 O O O U A O 0 000 MY O0 000 O0 0 L~ OO 63S 21 0 G / C 3 00 350 0 Z 0 G/C3 O0 356 O! O PU O0 890 O0 0 O0 358, 01 IN O0 280 O! 0 G ~ P l 0 O 3 ! 0 O 1 0 V 00 000 00 0 V O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 CPS O0 354 01 0 CPS O0 3:54 Oi 0 C :P S 00 35 ~ 0 i 0 CPS O0 354 O1 0 C~S O0 000 O0 0 CPS O0 OOO O0 0 F'U O0 890 OO 0 O0 000 O0 0 CPS O0 330 3i 0 CPS O 0 330 30 0 CHMM O0 823 50 0 OEGF gO 560 50 0 L~ O0 635 ~PT ~P ~TEM )PHi .S~V .L ~S1 :NRA ITEM )EPT ;P ~VO ITEM .SHV .L ~Si 13272.5000 LLS -999.2300 -999.2500 SiO -$99.2500 -9'99.2300 PEF -~9.2500 $SHV -~ 9'9. 2300 LU -~99.2500 Sq2 2. 1777 NCNL -999.2500 TaNS 13200. OOOO LLS - 20.92 i 9 G R 5.0391 183.0D00 T~N3 63.~297 1~51.0000 SSHV 734.0000 LU 261.7500 SSZ 2500 2.500 2500 2500 2500 2500 2500 2500 2500 2358 ~125 OOO0 7~02 CO00 O000 LLD DVO DVI CALl QLS LS NPH l FCNL LLD DVI CaLl LS 4 ' 4. 4 4 4. 4 4. 4 4 4 4. 4 - 999.2300 -99~. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 2500 20.~5~3 12~0.0000 14.~+177 7.0156 7.02'73 1.5593 I !. 296 0.0029 13~5.0000 i ~. 8430 ! 68 00000000000000 i 68 00000000000000 ! 68 00000000000000 i 63 00000000000000 i 68 O000OO00000000 I 68 00000000000000 i 68 O0000OO0000000 I 68 00000000000000 I 68 00000000000000 ! 63 00000000000000 I 68 O00OO000000000 1 68 00000000000000 i 5~ O0000000OO0000 i 68 00000000000000 1 6B 00000000000000 1 58 00000000000000 i 68 00000000000000 t 68 00000000000000 I 6~ 00000000000000 !' 65 00000000000000 i 68 0000000000000.0 I 68 00000000000000 1 68 OOO00000000000 i 68 00000000000000 I 6~ 00000000000000 I 68 O0000000OO0000 I 68 00000000000000 I 68 00000000000000 i 68 00000000000000 i 68 00000000000000 i 65 00000000000000 CALS -999.2500 OlO -999.2500 MRES -999.2500 ORHJ -999.2500 GR -999.2500 QSS -999.2500 LiIH -999.2500 NRAT 2.1172 MRES -999.2500 CAES $.5325 OiO ~33.0000 MRES 0.7422 DR~G 0.0332 GR 118.8125 QSS 0.1157 LITH ~*~.5000 NR~T 2.0480 ~E PT P VO ~TSM PHZ SHV L $1 NRA T E M E PT P VO TEH PHi. SHV L NRA TEH EPT P VO iTEM ~P ri i . SHV .L ~NRA >EPT ;P iTEM )PHi. .SHV .L ;Si ~NRA 'iT EM )F. PT ~P ~VO .SmV _L OtO.M02 VERIFICATION 2.1641 NCNL 183.0000 'T2N3 13100,0000 LLS · -61.6563 GR 18.5094 SIO 153.6750 TF,NS 24.4141 PEF 1455.0000 3SHV 216.2500 LO 220.5250 SS2 2.2=~ ~ ~ N~NL 183.~750 T~NS 13000.0000 LLS -19 · 7969 7.4219 SiO 181,5000 TENS 25.92'77 1448.$359 $SHV 234.6250 LO 227.6563 SSZ 4 358~ N~,NL 182.5000 T~NS 12900. 0000 LLS -81.1250 GR 18,6406 i81.2500 TENS 24. 5554 1454.8770 SS'HV 210.1445 LO 206.0820 SSZ 2.3069 NCNL 181.2500 T~KS IZSO0.O00O tLS -57.3750 G'R 25.5938 SiO 181. 3750 TENS 25.~603 PEF 1~5~.0000 SS~V 220.5000 LU ZIO .4590 SSi 1.5172 NCNL 181.3~50 TEN5 i2700.0000 LLS -11.3510 GR 3.2500 SiO 180.~250 T~NS 5.50~4 PEF 1456.6000 SSHV 131.132d LO LiSTiNG 275'9.'7500 FCNL uu O0 108.2858 LLD 22.0156 OVO 249.2500 OVl 8688.0000 RHCB 1.75,3'9 CALi i340.0000 QLS 367,0000 ES 335.0000 N:PHi 38~8.0000 FCNL 86~8.0000 25.6367 LtD 97.7500 DVO 419.7500 DVI 5224.0000 R~O5 1.9883 CALI 1339.8359 QLS 3~$.7500 LS 330.7031 NPHI 2462.0000 FCNL ~224.0030 124.4486 LLD 21.4844 DVO 217.'2500 $048.0000 1.7344 CALi 1'341.0000 QLS 349.a336 hS 3i7.5547 NPHi 4278.6250 FCNL 8048.0000 ':~79 ~547 LLF 20,0~38 132.62~0 2V1 8160.0000 RHO~ 2.0~1~ CALi 1341.0000 ~LS 361.5559 LS 314.2500 NPHi ~5'76.0000 FCNL $160.0000 7.5221 LLD 144.3750 OVO 6£6.5000 3256.0000 3.1312 CALl 1340.6660 ~LS 240.0~3~ LS 1290.5000 ~,!n79 22.67i9 ~ 65~3 2.2461 8,4609 0.0078 399.7500 21.7'773 1724.0000 20.0188 8.6797 8.68'75 2.2216 8.6519 0.0201 429.t250 51.97'75 564.2500 292.8182 30.3750 30,406'3 2.2441 8.5898 384.9863 22.5662 1854.5000 348.6~70 ~2 ~3'75 32.4063 2.2207 ~.~5!0 0.0350 401,5000 11.2976 3082.5625 7.1715 4.4180 2.5573 -0.0Z37 255.1953 CALS MRES GR LiTH NRAT MRES CAtS MRES D R HO GR :~ S $ LiTH NRAT MRES CALS OIO MRES DRHO GR QSS LITH NRAT MRES CALS OIO MRES O Rd g GR ~SS LITH NRAT MRES CALS MRES GR eSS LiTM 0.7422 7.8359 165.1250 O.7~OZ 0.0073 22,0156 0,0029 160.7500 2.1914 0.7~02 8.6250 396.0000 0.7622 0.0163 97.7500 0.0411 204.5000 3.9883 0.7622 7.6758 92,3125 0,7515 -0.0160 21.4844 -0.0068 154.8437 2.2531 0.7515 7.7852 82.8125 0.7637 -0.0109 20.0938 0.0189 140.4219 1.5040 0.7637 6.3828 544.5000 0.7612 0.0694 144.3750 0.0399 68.4248 ,S~i ITeM )PHI .SHV .L [T EM )E P'T ~VO )PHI .SHV .L ;Si 'ITEM ":PT ;P ;¥0 iTEM )PHI .SHV .L ~S1 ~NRA 4TEM }EPT ~VO ,iTEM ]PHI .SHV _L SS1 qTEM 9EPT SVO qTEM _SHV OiO.HO2 VERiFICATi2N LISTING 223,4609 SS2 2,8901 NCNL I $0,6 250 T iN S 2377,,~5750 FCNL 12500,000.0 LLS -10,6015 G~i 0,0625 .GlO 175,8'750 TENS 18. '7561 P ~ F 1458.7441 SSHV 74.5~1~ hU ~6.8008 SS2 · 4. ~023 NCNL 175.8750 TENS 0,1508 LLD i26,6250 DVO 2288,0000 PVl 8248,0000 24.1240 CALl 1342.0000 QLS 151.5525 LS t03,~590 NPHi 1'744.0000 PCN:L 8248,0000 12500.0000 LLS -7.0588 GR 0.120~ SIO 172.5000 TENS 20.57'76 t~59.4238 SSHV 7~-2'a54 LU 56.i406 SSZ 4.342'7 NCNL 172.5000 'TENS 0.1512 LLD 138.3750 DVO 2282.0000 DV1 3120.0000 RHOB 30.8594 CALI 13~2,0000 QLS 155.8~37 LS 100.0'732 NPHi 14,48.5000 FCNL 8120.0000 12400.0000 LLS -2.115.2 GR 0.1055 SiO 189.6250 TENS 17.0865 PEF 1458.0000 SSMV 73,2471 LU 59.1592 SS2 4.2571 NCNL 169.E'250 T~NS 0.1514 LLO 94.0000 OVO 2278.0000 7900.0000 73.593.8 CALi 13~1.0059 QLS !4S.9955 LS 101.S!84 NPHI 1579.1250 FCNL 12300.0000 LLS 19.7500 GR 0.0635 SIO 167.6250 TENS -24,2920 PSF 1~38.0000 SSHV 31.203i Lb ~2.$781 SSZ 4.4219 NCNL 167.6250 T~NS 0.t49~ LtD ~$4.8750 DVO 2310.0000 DVl 7700.0000 RH3~ 02.5000 CALl 13~1.0000 QLS 35.3281 LB I¥91.000C FCNL 7700.0000 12292,5Gj0 LLS -999,2500 GR -99~,250q. - $~0~ -999.2300 T~:,NS 16.~7~2 PE~ 1458.0000 SSMV -999.2~00 LLD -999.2500 OVO -~9.2500 -~'~9.2500 30.6797 CALl 13~,1.9512 %L$ 31.3629 NRAT 822.5875 MR~S 1.1205 CALS i.258~ 1.2344 MRES 2.3391 DRHO 8,7155 GR 0,03?3 DSS 150,3125 LITH 50.4761 NRA'T 396.8750 MRES 1.0999 CALS 1.1953 DID 1.2305 MR~S 2,3085 ORHO 8.7266 GR 0.0219 ~SS 154.1602 LiTH 54,6600 NRAT 333,4375 MRES 80,5200 CALS -0,0234 OIO O. i~Ii- MR~S~. 2,3672 ORHO 8.6'797 GR 0.04:34 DSS 147.7471 LITH 51.9714 NRAT 388,2148 MRES 60..5200 CALS -0,0273 glo 0,0545 MRES 3,0~+93 DRHO 2,7¢00 GR 0.1827 QSS 74.3438 LiTH :58.39B4 NRAT ~50.0000 MRES -999,2500 CALS -99~,2500 DIO -999,2500 MRES 2,i700 ORHO 2.7501 GR P~GE 2,8594 0.7812 8.7656 lO00.O000 0.7817 -0.4770 126.6.2.50 -0.2095 17,7656 3.9146 0.7817 19,1406 967.5000 0.7954 -0.4852 138,3750 -0.1944 17.2871 -4.1460 0.7954 4.4883 -24.0469 0.8071 -0.4565 94.0000 -0.1743 15.6279 4.0011 0.~071 4.4883 -66.6875 0.8149 -0.5164 84.8750 -0.0413 7.2793 3.9707 0.8149 -999.2500 -999.2500 -999.2500 -0.~309 -999.2500 -0.1756 VP OIO.H02 V ER iFiCAT iOii LiSTiNG L, · 76.2.500 LU Si 62.96¢8 SS2 - .2500 N ~,., N ~ TEN -99'9.2500 TENS ~:~ FiLE 'TR.AIL~R ILE NA~E :EDIT ERViC; NANE : ERSi~N ~ : ATE : AXINU~ LENGTH iLE TYPE EXT FiLE NA~E .001 1024 153.5938 LS 110.0505 NPHZ -999.2~00 FCNL -9:~9.25 O0 - 999. :~.' 50 O -999.2500 LiTH NRA T MRES PAGE 17.5293 - 999.2500 -99'9. 2500 ::;: FiL6 HEADER iLE NAME ::EDIT ERViCE NAME : ~ R.SiON ~ : .ATE : .AXZMUM LPNGTH .ZLE TY~:E 'REVZ~U$ FiLE : . O02 102~ DATA fORMAT NTRY BLOCKS R E C S R D.,."' ~:: TYP~ 4 );1TUM SPECiFICATiCN ~,N.~M SERVICE Si2VtC~Z iD ORJ~R : )EPT ~SFL DLL aLOCKS UNiT FT aP! L 0 G O0 OO SiZE I 1 4 i t APl TYPE 000 270 66 7 3 6~ :ENTRY O 1 20 .lin I 0 APl APl FiLE SiZE SPL CL,~,SS MOD NO. O0 0 O 4 04 0 0 4 i REPR CODE 65 PROCESS (OCTAL) OOO00000000000 00000000000000 ;'- ~',-' DATA )'EPT )EPT )EPT SE P'T 13269.8359 13200.1630 13100.1580 i3000.!,~80 M S FL MS FL NSFL MSFL 17.2656 Z1.25!3 6.351o VP 010 HO2 VERi~iC~TIO~ ~ iSTiNr ?PT " 12900.1580 f4$FL EPT 12:800.1680 MSFL EPT' !Z700.t680: ?4SFL EPT 12600.1680 f~'S FL EP'T 1Z500. i680 ?4SFL EF'T 12400.1580 MSFL 2PT 12300 .t680 ~'~ ,~ SF L EPT 12293.6680 fISPL 4."'9. i 37~,,.., 0,3452 0.14,21 0.13,877 0,3857 0. 3550 :;;-' PILE TRAILER .... iLE N.~,'q= :EDIT .002 ERViCE NAME ERSION ~ ATE : AXiMUM L~NGTH : iLE TYPE : EX~ FiL~ ~AME : :~= FILE HE~DER e.~1-. ;ZLE NAME :EDIT ;ERViCE N~ME : ~ERS!ON # : )ATE : 1.&XIMUM LENGTH : :ILE TYPE : >REViOUS FiLE : .003 :-';:-~ DATA FORMAT 'NTRY 5LOCKS TYP~ SiZE Z ! q- 1 16 i 3 I }ATUN. SPECIFiCaTiON SLDCKS qNEH S-RVICE SERViC~ U~!T APl &Pi lC ORDER ~ LOG 'TY~E 3~PT RT O0 000 1TEN DLL L~ 00 000 iT~¢~ LOT L5 00 000 66 73 66 APl FZL~ O0 0 0 '30 0 S 03 0 0 ENTRY 0 i 5 .lin i 0 :SIZE SPt R'EPK CODE 4 i 6B ~ 1 68 PROCESS (OCTAL) O000000OO00000 OOO00000000000 00000000000000 010.~0£ VfRIF!CATIu~ LTSTiNG P~E DATA EPT i3Z69.9609 EPT 13200.2930 MiEN EPT 13100.2930 EPT 13000.293'0 HT~N EPT 12900.2930 HTEN ,EPT iZ800.2930 MTEN ,EPT !g?00.2930 MTEN ~EP7 12600.2930 MIEN ~EPT 12500.2930 MiEN ~EPT 1£400o2930 i6PT 12300.2930 ~T~N ifPT 12£95.5680 HTEN -4t.06i5 HTEN 1639.0000 MTEN 1489.0000 HTEN 1362.0000 MIEN 1308.0000 :~'T EN 1293. 0000 ~TEN 15il.0000 NIEN 1494.0000 HTEN 1456,0000 HTEN 1346,0000 ~TEN i318,0000 HT.EN 1345,0000 ~TEN -4!.0625 1639.0'000 1362.0000 1308.0000 1293.0000 1511.0000 1494.0000 i456.0000 1346:.0000 131~.0000 t345,0000 :~ FILE TRAILER :iLl NAME :EDIT ;ERViCE NAME : FERSIGN ~ : )~TE : ~AXIMUM LENGTH : :iLE TYPE : ~EXT FIL~ NAME : .003 ;'-~:-' T~PE TR'~iLER ~ERViCE NAME :EDIT ~ATE :87/0~'/ 1 ]RiGiN :?224 F~,PE NAME : ]ONTiNU~TION ~ :01 gEXT T~E N~ME : ]OMMENTS :LIS TAPE, r;NDi~wTT"'""' 2-6/J-2£ ,,~Pi"", ~°I, 50-029-21599 ',-,,- REEL TRA~'LER ...... ~ERV!CE NA~qE :EDIT ]ATE :87104/ I VP OIO.HO2 V~R!FiCATiO.N L£S'TiNg P A ~ :~= 10 RiGiN : EEL NAME :72247 3NTiNUATION ~ :01 EXT REEL N&ME : OMM~NIS :LIS TAPi~ $1ANDARD ENDICOTT 2-6/j-22 kiP!, API 50-029-21599