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186-106
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-05 DUCK IS UNIT MPI 1-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 1-05 50-029-21605-00-00 186-106-0 G SPT 9473 1861060 4245 4103 4104 4107 4104 143 151 159 161 REQVAR P Austin McLeod 6/27/2024 Two year to MAIP. AIO 1.009. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 1-05 Inspection Date: Tubing OA Packer Depth 1074 4760 4703 4685IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240628161247 BBL Pumped:4.5 BBL Returned:4.5 Thursday, July 25, 2024 Page 1 of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Water Wash Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,266'feet N/A feet true vertical 10,394'feet 10,855' & 11,170'feet Effective Depth measured 10,855'feet 10,223 feet true vertical 10,027'feet 9,471 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 5-1/2" 17# / L-80 9,353' MD 8,749' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 10,280' MD 9,521' TVD 10,223' MD 9,471' TVD Packers and SSSV (type, measured and true vertical depth)5-1/2" MCX SSSV 1,493' MD 1,493' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 322-330 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 24,229 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 3,761 8,160psi Joleen Oshiro joleen.oshiro@hilcorp.com 907-777-8486 4-1/2" Bker S-3 Perm. Packer measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 1,15975,542 0 4,170 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 131' 2,499' 10,387' 1,561 Conductor TVD 131' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-106 50-29-21605-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312828 ENDICOTT / ENDICOTT OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: DUCK IS UNIT MPI 1-05 measuredPlugs Junk measured N/A Length 131' 2,459' 10,387' Size Surface Intermediate Production 30" 13-3/8" 9-5/8" 7-5/8" Production Liner 9,633' 105' 1,504' Casing 2,499' 9,615' 8,973' 9,059' 7" 9,633' 9,738' 11,260' 10,388' 7" 4,790psi 7,020psi 4,930psi 8,150psi 6,890psi 8,160psi Burst N/A Collapse N/A 2,670psi 5,090psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 9:49 am, Jul 19, 2022 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2022.07.19 07:44:13 -08'00' Torin Roschinger (4662) Well Name Rig API Number Well Permit Number Start Date End Date END 1-05 Fullbore 50-029-21605-00-00 186-106 7/5/2022 7/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Water Wash. Pumped 10 bbls 60/40, 50 bbls 120*F Diesel, 211 bbls .2% surfactant water then SD and soaked for 2 hours. Over flushed with 374 bbls surf. 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Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-05 DUCK IS UNIT MPI 1-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1-05 50-029-21605-00-00 186-106-0 G SPT 9473 1861060 4750 4349 4349 4476 4465 100 100 105 110 REQVAR P Matt Herrera 6/5/2022 MIT-IA Performed to MAIP Per AIO 1.009. Pressures OOA - 180/180/180/180/180/180. Inconsistent Injection pressure by Operations resulted in fluctuating IA temps and pressures, test was extended to verify stabilization 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 1-05 Inspection Date: Tubing OA Packer Depth 1534 4754 4757 4744IA 4463 110 45 Min 4733 4459 110 60 Min 4731 Rel Insp Num: Insp Num:mitMFH220606122807 BBL Pumped:2.7 BBL Returned:2.7 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 MIT-IA AIO 1.009.Inconsistent Injection pressure James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:53:16 -08'00' MEMORANDUM State of Alaska Permit Number: 186-106-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 e 91 �2l DATE: Tuesday, July 21, 2020 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial Hilcorp Alaska, LLC FROM: Bob Noble 1-05 G .q'pD DUCK IS UNIT MPI I-05 Petroleum inspector Tubing Sm: Inspector Reviewed By: P.L. Supry NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-05 API Well Number 50-029-21605-00-00 Inspector Name: Bob Noble Permit Number: 186-106-0 Inspection Date: 6/14/2020 IBSp Num: mitRCN200614153357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-05AT'ype G .q'pD 9473 � Tubing 3960 3961 � 3960' 3960 - PTO 1861060 SPT Test psi 4400 IA 680 4750 . 4692 - 4670 BBL Pumped:L Returned: 4.5 OA 80 90 - 90, 90 . Interval REQVAR p/F P Notes: 2 year MIT -IA to max anticipated injection pressure of 4400 psi as per AIO 1.009 Tuesday, July 21, 2020 Page 1 of ] MEMORANDUM I State of Alaska Inspection Date: 6/14/2020 ✓ Alaska Oil and Gas Conservation Commission TO: Jiro Regg P.I. Supervisor \ —yr,� 4 1 zal'o DATE: Monday, June 15, 2020 SUBJECT: Mechanical Integrity Tests L Hflcorp Alaska, LLC FROM: Bob Noble 1-05 DUCK IS UNIT MPI 1-05 Petroleum Inspector Type Inj Ste: Inspector Reviewed By: P.I. Supry uL71Z..-_ NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-05 API Well Number 50-029-21605-OMO Inspector Name: Bob Noble Permit Number: 186-106-0 Inspection Date: 6/14/2020 ✓ IUsp Num: mitRCN200614153357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-05 Type Inj G ' TVD 9473 'Tubing 3960 3961 - 3960 - 3960 ' PTD 1861060 Type Test SPT Test psi 4400 IA 680 4750 4692 4670 - BBL Pumped: 4.5 - BBL Returned: 4.5 OA 80 96 90 90 ^ Interval xEQvax P/F P NOteS: 2 year MIT -IA to max anticipated iniestioon pressure of 4400 psi as per AIO 1.009 Monday, June 15, 2020 Page I of 1 i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 21,2016 Jim Regg r- P.I.Supervisor � 1 .16t 67lZ`t f it. SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 1-05 FROM: Bob Noble DUCK IS UNIT MPI 1-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-05 API Well Number 50-029-21605-00-00 Inspector Name: Bob Noble Permit Number: 186-106-0 Inspection Date: 6/20/2016 Insp Num: mitRCN160620160848 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-05 Type Inj G 'TVD 9473 : Tubing 4723 4723 - 4740 - 4756 - 4756 PTD 1861060 Type Test SPT Test psi' 4723 - IA 1359 4723 - 4705 - 4722 4708 Interval OTHER P/F P OA 100 110 110 110 110 Notes: Bi Annual to max anticipated injection presssure as per AIO 1.009. sCOMED DEC 2 9 2.M Tuesday,June 21,2016 Page 1 of 1 Post Office Box 244027 g (� Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 201`a 3800 Centerpoint Drive Suite 100 AGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster I Q�O Alaska Oil & Gas Conservation Commission 1.36, 333 West 7th Avenue, Suite 100 I -- 057-- Anchorage, --Anchorage, AK 99501 SCANNED AUG 2 9 201f. Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" 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 r New API_WeIINo PermitNumber WellName WellNumber WeIlNumber 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 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/5N4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 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/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j&~ _~_~_~o Well History File Identifier Organization (done) ¢~~Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: ~ .... Other: ~ TOTAL PAGES: ~:~? ~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT,~'~I~Y.~ MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: /gOo /.~o /¢)~ /S/ <~//' Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl SCANNED BY: BEVERLY ,~ VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) , 017 77274, • 4,i7A\�)/7,cV THE STATE L :11 ("-"' � � ' , ,Vi; -' r I. r' r - -_- h '---/J1, , j. .. }tf: 15� _� — 333 West Seventh Avenue �' ` b : ; . Anchorage Alaska 99501 3572 F-� �, r,� GOA 1-RNC)R SiSF,AN 1 AP.I�HI L � Main: 907 279 1433 ®A' AS 4' Po : 9J-'276.7542 Josiah Igwe aNNv JUL 3 v- Production Engineer S BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field Endicott Oil Pool EPA 1-5/0-20 j..6._...-------j----'-...-tb Sundry Number: 314-189 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, it, p . ' Cathy P. roerster Chair, C•mmissioner DATED this'j day of April, 2014. Encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION ±i3 / APPLICATION FOR SUNDRY APPROVALS " ` 20 MC 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 . ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 186-106-0- 3.Address: Stratigraphic ❑ Service 0 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21605-00-00 III 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? EPA 1-05/0-20 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • ENDICOTT, ENDICOTT OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11266 . 10396 . 11177 10316 None See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 2459 13-3/8"72#L-80 40-2499 40-2498.85 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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 ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(It): 10239,9487.46 5-1/2"MCX SSSV 1493',1492.8T 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joshia lgwe Email Joshia.lgwe©BP.Com Printed Name Joshia Igwe Title Petroleum Engineer Signature '\...-/-•--, — Phone 564-4753 Date Prepared by Garry Catron 564-4424 �= 1 \ 1 �Ib olt4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\4.--`13 ck Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMe MAY 1 0 2014 Spacing Exception Required? Yes ❑ No I" Subsequent Form Required: /b — 4 G 4- 6.,127p APPROVED BY Approved by: ` JP COMMISSIONER THE COMMISSION Date: 4_3 —/ Form 10-403 Revised 10/2012 Approve a i i i nths from the date of approval. Submit Form an ttachme�5ts in Dup irate JUNK SUMMARY ADLO312828 SW NAME MEAS DEPTH MEAS_METHOD_CODE RUN DATE SUBSEA_DEPTH TVD 1-05/0-20 10855 JUNK 38815 _ 9974 10030 1-05/0-20 11170 JUNK 38736 10254 10310 u) v o = 0 0 0 0 O 0 O 0 00 tD CO CO CO CO CO CO Op Cr)J J J J J J Z a) CL• O O O O O O O O (Ti CO CO N CV N 0) N- O oO N- O O O O N- CO Cn N O U) N- N- N ,r N N- CD U L O O O O O O (9) O O M co - co 0) N N- CO CO CO CO CO CO CO Nr CO N- a) O • CC) CO `- co N- 0) N- M m N- M co co M N- co 0) co CO oto OP OP ca CO N 0) co Q O O ti N- CO O O COCM ' O N- U) 00) 00)) c C co E(13 03 N E w m 4 N N CSO N M OUC) CA O) N CD 0) 0) C • M U Q ~ co vvrn o� � CO tco(V) ci 0 � � rn rn w = o o O O O COCO ZC10 C) COD -II J - 00 O Z J J J N CO *k IN 'It d CI) N- 0) 0) 0) N - N N N _ 0\0 CV oi CO N- 6 N- +-' N- M N- 0) 0) C 0 M coC70 M •- O In N M C M CO ,r O M J CC) U r co N 0) Q Q Z Z O O cww w X 2 2 D 1 9 0 0 � WrXCLoOtiZZ U w w w O O Ce m ? ? _1 _1aCL Cf) I- F- Perforation Attachment ADL0312828 Well Date Perf Code MD Top MD Base TVD Top TVD Base 1-05/0-20 11/15/89 APF 10409 10439 9637 9663 1-05/0-20 11/15/89 APF 10470 10484 9690 9703 1-05/0-20 11/15/89 APF 10512 10524 9727 9738 1-05/0-20 11/15/89 APF 10538 10550 9750 9761 1-05/0-20 4/11/88 APF 10560 10622 9769 9824 1-05/0-20 4/11/88 APF 10622 10668 9824 9865 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 -- o O = 0 0 0 0 0 0 0 al co Cn 0? CO 0D CO CO CO CO Z J J J J J J J Z Q 0N. 0 0 0 0 0 0 0 0 N O O ON O O CN.O COCCN O in N. N- N N N. CO 0 N 0 0 0 0 0 0 0 0 LN. CDCOCOCOCnMMv • co - - - - CD 0) N- CO CO CO 00 00 OD CO cr CO N. a) U) m N CD N. a) co co CO 0 Cir 613 OM) ace) 00) O O cr.; Q, O ~ O N. P. 000 CD O O CMO N. CCD 0) a) O COCU co E N E CV N CO COCO 0) 0 0 COrn r mc,j O O C T ODrn N •C L CnM Ni U ~• V tl � CLO CO M M • Cn O O O O L) O = aDo00DCDO ZF- CCOOCCOOCCOO ao Z J J J N CO 4$ # 4 4t 4t O N N N. C%) .- N. O O O N - _ N N N _ 00 Co N C -0\0 I� ti ti MI CA I N. Cn COCOCr)N N O 0) D N M • CCD C M O C O co I— I— Z Z Q Q O O O) 0 0 I— I— W DDV< 00 N CCCLCLO Ou. Z Z U W W W O O c m m H _,,UJ D D D Z j -J CO I- by 0 Wellwork Procedure Request To: T. Norene/L.Seymour: Well Services TL Date: 3/18/2014 J. Midendorf/R. Liddlow: Wireline Team Lead AFE: AENWEINR From: Eric Dickerman - Interventions Engineer IOR: Est. Cost: Subject: AOGCC END1-05 MITIA and Solvent wash Job Sequence 1. W PPPOT-T and PPPOT-IC. 2. S Pull MCX/Solvent wash and L&K TBG / Set TTP/ Pull TTP /Set MCX. 3. F Assist Slickline / MIT-T/MIT-IA to 5,100 psi. Well Detail On Production/Injection or SI Well is currently on injection AnnComm Status: Operable GI Last Well Test: 6/24/2012 MIT T passed 3,000 psi/ MIT IA passed 4,900 psi Minimum ID: 3.725" XN Nip at 10,268' MD Max Deviation: 38° at 8,300' MD Fluid Level (T/IA): Unknown (has been on injection)/ Near Surface (12/17/13) Last Tag: 6/24/12 Pull plug body at 10,258' MD Last Downhole Op: 6/25/12 Set MCX at 1,493' MD SBHP: 4,457 psi at 10,055' TVD Latest H2S: Injection gas averages 230-260 PPM Job Objective: AOGCC witnessed MIT-IA for AA compliance. Pump 200 bbls of 50/50 Diesel/Xylene to solvent wash perforations before testing followed by 150 bbls 1% KCI with 0.2% F103 (surfactant) and finally displace with 250 bbls neat 1% KCI. Background: END1-05 is a gas injection well with known IA repressurization (TxIA). The well is operated under an AA from 10/02/08 and requires an AOGCC MIT-IA to 1.2x maximum anticipated injection pressure every two years, however the on 11/04/10 the AA was revised requiring MIT's up to the maximum anticipated injection pressure. Program Contacts: Contact Work Phone Mobile Phone Interventions Engineer Eric Dickerman 564-4306 307-250-4013 END PE Igwe Josiah 564-4753 590-0610 Page I 1 of 4 END1-05 MIT-IA-2/06/2014 Discussion: PPPOT— Check status of LDS TBG Collapse— To minimize external stress on the TBG and to avoid TBG collapse, hold 4,100 psi on the TBG at surface during the MIT-IA. Fluids in the IA — the IA currently has 6.8 ppg diesel to 2,500'and 8.9 ppg completion brine to the packer. Wellhead PPPOT-T and PPPOT-IC Planned Procedure 1. Perform PPPOT-T to 5,100 psi. 2. Perform PPPOT-IC to 5,100 psi. Slickline w/ Fullbore Assist Pull MCX/ Solvent wash and L&K TBG / Set TTP / MIT-T/ MIT-IA/ Pull TTP / Set MCX Planned Procedure 3. Shut in well 4. Pull MCX from 1,493' MD. 5. Drift and Tag to PBTD with sample bailer • Send any sample recovered to BP lab for analysis 6. Solvent wash and Load and kill TBG and set TTP • Pump 200 bbls of 50/50 Diesel/Xylene with 1% mutual solvent • Pump 150 bbls of 1% KCI with 0.2% F103 (Surfactant) • Finish loading well with 250 bbls 1% KCI as per attached pump schedule • FP tubing • Set TTP in XN Nip at 10,268' MD. 7. MIT-T to 2,500 psi to ensure TTP is holding. • If MIT-T passes, continue to step 8 • If MIT-T fails trouble shoot TTP good enough to hold support pressure for the MIT-IA 8. MIT-IA with diesel to 5,100 psi pre-AOGCC witness. • Maintain 4,100 psi on tubing to prevent tubing collapse 9. MIT-IA with diesel to 5,100 psi. • AOGCC witnessed for AA compliance. • Maintain 4,100 psi on tubing to prevent tubing collapse • If MIT- IA passes pull TTP, Set MCX, RDMO • If MIT-IA fails record LLR, leave TTP in hole, RDMO for secure and upcoming LDL. Page 12 of 4 END1-05 MIT-IA-2/06/2014 Version 1.1 03/18/14 Fulibore Pumping Design Template Well Name END1-05 Job Scope MITIA H2S(ppmldate) WBL Cat Reg Compl Cost $100K 5100 Max Pumping Pressure(psi) Well Type GI AFE AENWEINR 1%KG Main Fluid Type Date 212812014 IOR 100 400 Main Fluid Volume(bbls) Engineer Dickerman Phone 564-4306 Diesel Freeze Protect Type 35 Freeze Protect Volume(bbls) Job Objective NA Recent Tbg Fluid Level(ft) AOGCC witnessed MIT-IA for AA compliance. Pump 200 bbls of 50150 NA Recent IA Fluid Level(ft) DiesellXylene to solvent wash perforations before testing followed NA Recent OA Fluid Level(ft) by 150 bbls 1%KCI with 0.2%F103(surfactant)and finally displace 230 Expected Tbg Fill Up Volume(bbls) with 250 bbls neat 1%KCI. <5 Expected IA Fill Up Volume(bbls) If Applicable Expected OA Fill Up Volume(bbls) If Applicable Wellbore Volume to Perfs(bbls) 4100 Anticipated Bottom Hole Pressure (psi) Fulibore Pumping Schedule 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) 4.5 8430 6744 Spear Methanol(Neat) Tbg 5 5 2500 Tubing Collapse(psi) 4.5 7500 6000 Casing Burst(psi) 5.5 7740 6192 Solvent 50150 Diesel Xylene Tbg 200 5 2500 Casing Collapse(psi) 5.5 6280 5024 Load 1%KCI Tbg 400 5 2500 Select Input Depth Integrity Issues? Select Input Depth Freeze Protect Diesel Tbg 35 3 2500 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 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 _____________ 4100 Tubing(psi) 4.Set UP and MIT T to 2500 psi IA(psi) 5.MIT IA to 5100 psi while holding 4100 psi on the Tubing OA(psi) 6. RDMO Page 13 of 4 END1-05 MIT-IA-2/06/2014 IP TREE- 7-1116'CIW(6500 PSI) WELLFEAD= 11'X 5K FMC GEN N(6540 PSI) SAFETY NOTES:1425 READINGS AVERASE 230-260 ACTUATOR- A - 55.3' END 1 -05 SSSV.PPM N AIL&GAS INJECTORS WELL REQUIRES A AT BF.ELEV- 15.6' KOP- L ir Max Angle-, 38?8300' A I I-- �4 I 1493' H51/7 HES X NP,ID 4.567 I Datum MD- 10884' 14 Datum TVD- 8800'SS v M0. 113-3/8'CSG,724.L-80 MRS,D=12.347' H 2499' X • • 0. I9-5/8'CSG.474,NT84S,D 8.681' H 5477' I-•-__.y(I • H 0. 4 1 MIN ID=3.725"@10268' L 4-1/2"XN NIPPLE 4 5-1/2'TBG.174.L-80 TCN,.0232 bpf,D=4.892' -I 9353' I 1 \ / r I 9353' H5-1/2'X 4-117 XO.D=3.958' I 4 17-5/8'SCAB CSG,29.7#.L-80 STL,121 .'6.875' f-I 9633' I 4.. ` 9634' H7-SS"X r XO,0=6.276'I 44 �� 4, 44 17'TACK CSG 29#,L-80 BTC-M,D=6.276' H 9738' 4 9738' H7'Lt'RTEBAC3(SEAL STEM ASSY.D=6.276' 1TOP OF r T BACK LFR -I 9756' I 14 41 1 j4 I 10203' ,-I4-1/7 HES X NP.D=3.813' 4 k0 i4: 10223' }--17'x 4-117 BKR S-3 PKR D 3.875" I • 41 ' I O. I 10247' I-I4-1;2^FES X NP,D=3.813' I 144 � � { 10268' H4-112'HES XN NIP,D-3.725' I I4-112'TBG..12.6#,L-64 TCH,.0152 ,D bpf, =3.958' H 10280' I 141 � �4 14 14 4/ 1 �4 t 10280' H4-1/7 WLEG,D 3.958' I ITOP OF r LFR H 10123' I- -al 1' I H[LAC TT NOT LOGGED I 19.518'CSG.47#,NT9514S,D-8.681' H 10387' I--a IlL PERFORATION SL AWRY I REF LOG. DLL-GR(07/04/86) ANGLE AT TOP PERF: 7?`e 10409' ' Note.Refer to Production DB for Fastorfcal perf data SIZE SPF INTERVAL Opn/Sqz DATE I 4' 4 10409.10439 0 4' 4 1(470-10484 0 ' 4' 4 10512-10524 0 4' 4 10538-10550 0 4' ' 4 10560-10622 0 2-1/8' 4 10622-10668 0 4' 4 10622-10668 0 10855' GBP PUS FED TO BTM(04/08/06) I ???? HBKRBP(01/19/06)I PBTD 11177' '4f�r' M 4'41 41,04 17'LFR 29#,L-80 BTRS..0371 bpf,D=6.184' 11260' 01 ►01 11 DATE REV BY COMMENTS DATE REV BY COMMENTS EJ`DICOTTtNNIT ORIGINAL C'O?PLETON 08/12/1 1 DW/JMD ADDED FCS SAFETY NOTE WELL. 1-05/0-20 03112188 MOM POST RWO PERMIT No:'1861060 04/10/06 016 RWO(2006) - AR No: 50-029-21605-00 05/06/'06 CGrTLH DRLG DRAFT CORRECTIONS SEC T N R E 11117/06 PJC DATUM MD CORRECTION 02116/'11 t43/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Page 1 4 of 4 END1-05 MIT-IA-2/06/2014 • • bp BP Exploration (Alaska) Inc. t Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 ; } '4: ' U g 6, Mr. Jim Regg I Alaska Oil and Gas Conservation Commission -C 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing b Ro g y conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing extemal corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, / Mehreen Vazir BPXA, Well integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 I1END1-05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0 -25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 _ NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 /0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / Q-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / Q -20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / 0-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 I " ~ AOGCC MITIA Forms END1-OS (•1060), END1-15 (1930560), NS-10 (2!820), NS-32 (20... Page 1 of 2 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) ~ ~ (_..~ ~~ Sent: Tuesday, July 06, 2010 10:46 AM ~LJ To: AK, D&C Well Integrity Coordinator ~i ~~ ~ Cc: Regg, James B (DOA) ---, j/ Subject: RE: AOGCC MITIA s END1-05 1861060) END1-15 (1930560), NS-10 (2001820), NS-32 (2031580), MPF-42 (19702 ,MPJ-17 (1 0), MPS-11 (2021130), MPS-31 (2020140) Attachments: MIT ACT NS-10 NS-32 06-18-10 Revised.xls; MIT MPU J'-17 06-05-10.x1s JerryJTori n, Our database only allow numeric data for the Pretest, Initial, 15 Min., and 30 Min. data so I've removed the verbiage from report MIT ACT NS-10 NS-32 06-18-10, well NS-10 PTD #2001820 that was included for the Pretest Casing data and included "VAC" in the notes. I've also removed the NAs (OA data) for MIT MPU 5-115-3106-05-10 and MIT MPU J-17 06-05-10 and include OA-1VA in the notes as well. Well MPJ- 20 PTD #2001850 did not include any data (as the well was shut in) so I removed this well from report MIT MPU 1-17 J-20 06-05-10. Also, can you please verify the Packer TVD for well MPU 5-31 PTD #2020140 (we have 3857')? Thank you, Phoebe f~ ^. Phoebe Brooks `,~ ~``"~?-F <<IJ~~ .'- k ~.(?~II Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator ~[mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 4:13 PM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Subject: AOGCC MITIA Forms END1-05 (1861060), END1-15 (1930560), NS-10 (2001820), NS-32 (2031580), MPF-42 (1970200), MPJ-17 (1972080), MPS-li (2021130), MPS-31 (2020140) Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: ~ND1 X05 (PTD #1861060 END1-15 (PTD #1930560) NS-10 (PTD #2001820) NS-32 (PTD #2031580) MPF-42 (PTD #1970200) MPJ-17 (PTD #1972080) MPS-11 (PTD #2021130) MPS-31 (PTD #2020140) «June 2010 MIT Forms END-NS-MPU.zip» 7/12/2010 ' ~ AOGCC MITIA Forms END1-OS (1.060), ENDI-15 (1930560), NS-10 (20.20), NS-32 (20... Page 2 of 2 Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/12/2010 n , c STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /ACT / NS DATE: 06/18/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well NS-10 Type Inj. I TVD 3,987' Tubing 520 520 520 515 Interval O P.T.D. 2001820 Type test P Test psi 3500 Casing VAC 3,500 3;360 3,320 P/F P Notes: Annual MIT-IA for Class I disposal regulatory OA 50 50 50 50 compliance. Well NS-32 Type Inj. W TVD 4,070' Tubing 2,000 2,010 2,005 2,008 Interval O P.T.D. 2031580 Type test P Test psi 3500 Casing 20 3,500 3,420 3,420 P/F P Notes: Annual MIT-IA for Class I disposal regulatory OA compliance. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT ACT NS-10 NS-32 06-18-10.x1s • MEMORANDUM Toy Jim Regg l P.I. Supervisor ~~ ~' Z ~ I ~ ~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 28, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-OS/020 DUCK IS UNIT MPI 1-OS/020 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: DUCK IS UNIT MPI I-OS/020 API Well Number: s0-029-21605-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG1006261408s9 Permit Number: 186-106-0 Inspection Date: 6/26/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-OS/020 Type Inj. N TVD 9473 ~ IA ~ 61s 4790 ~~ 4760 47s0 ~ I P.T.D 1861060 T eTest ~sPT TCSt St 4790 Yp -~~~ QA s0 --- s0 ~ _ s0 ' s0 ~ - _ Interval REQvAR p/F P ~ Tubing 2soo szoo slso 31so NOtes: Test required by Adminsitrative Approval. Tubing plug set in HES XN nipple @ 10248" (WLM). 2.8 Bbl's diesel pumped and returned upon bleed off. 7 s/8" x 9 s/8" cemented annulus rose s80 psi during test (180,720,740,760). Rest of test very solid. Instructed Mr McGuinness to note cemented annulus increase. ~y~ 5~ ~ G/ j~y~_I ~~, '~ ia? ~ ~I .. 1.' 4 ~.. Monday, June 28, 2010 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) 6 ~2~ ~~ Sent: Monday, June 21, 2010 2:10 PM ~~~/~ To: DOA AOGCC Prudhoe Bay _ t Cc: Maunder, Thomas E (DOA) Subject: MIT at END 1-05 (PTD 1861060) ~ Just spoke with Torin in BP's Well Integrity group; approved delay of MIT on Endicott 1-05 (due 6/23) until Inspector can get out for witness. They are targeting Friday, 6/25. Told him to contact Tom or I if delayed past next week. This will not change anniversary date for future MITs (fixed by revised AIO 1.009 issued last year) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/21 /2010 ENDI-OS Automatic Shut-in Equi~ent Installation Complete Page 1 of 1 t Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer (NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, December 29, 2008 10:53 AM '~,~~~ ~~Zc~ (7,~~t~ Jim, To: Regg, James B (DOA) Subject: END1-05 Automatic Shut-in Equipment Installation Complete The automatic shut-in equipment for END1-05 was installed on 11/28/08. It is set to alarm at an IA pressure of 2,300 psi and shut-in at an IA pressure of 2,500 psi. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, November 06, 2008 2:15 PM To: 'Regg, James B (DOA)' Cc: NSU, ADW Well Integrity Engineer Subject: ENDl-05 Automatic Shut-in Equipment Jim, ~2~-ion Thank you for returning my call and providing verbal approval for continued injection in well END1-05. Further correspondence is not necessary, as I have made a note in our database. Thanks again, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 12/29/2008 END 1-OS Automatic Shut-in Equipment Page 1 of 1 Regg, James B (DOA) (~ f ~- ~~~, From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, November 06, 2008 2:15 PM To: Regg, James B (DOA) ~ ~ ~ ~ I ~ Cc: NSU, ADW Well Integrity Engineer l Subject: END1-05 Automatic Shut-in Equipment Jim, Thank you for returning my call and providing verbal approval for continued injection in well END1-05. Further correspondence is not necessary, as I have made a note in our database. Thanks again, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ,. ~: J: i U u ~.' 11 /6/2008 1-OS/0-20 (PTD #1861060) Request for AA Page 1.-e~~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, October 14, 2008 10:32 AM ~ To: Regg, James B (DOA) 1~~~ ~~ tQ-~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: 1-05/0-20 (PTD #1861060) Request for AA Jim, Our records indicate the packer MD is 10223 ft. Given our directional data, the TVD is 9473 ft. I also cross- referenced this with the packer depth spreadsheet submitted early this year and they agree. Please let me know if you need supporting information. Thank you, Andrea Hughes __ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 14, 2008 10:16 AM To: NSU, ADW Well Integrity Engineer Cc: Fleckenstein, Robert J (DOA) Subject: RE: 1-05/0-20 (PTD #1861060) Request for AA Packer TVD 7473 instead of 94737 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Fro SU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Mo ay, October 13, 2008 6:07 PM To: Regg, Ja s B (DOA) Cc: Colombie, Jo J (DOA); NSU, ADW Well Integrity Engineer Subject: RE: 1-05/ 0 (PTD #1861060) Request for AA Jim, I can confirm the plots attached to the app ` ation are for END1-05 as labeled in the chart area instead of END1- 15 as otherwise labeled. Would you like a cu nt copy of the plots? In addition, I have attached an MIT form for the NifT-l~aerformed on 09123f08. 10/14/2008 OPERABLE: ENDI-OS / 0-20 (PTD #1861060) IA Repressurization -Plan to request AA Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ IGIt3~t7>3 Sent: Thursday, September 25, 2008 11:32 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Daniel, Ryan; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Lau, John, Jack; Soto, Jose A Cc: Townsend, S. Eliot; Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: OPERABLE: END1-05 / 0-20 (PTD #1861060) IA Repressurization -Plan to request AA ~' Wefl END1-0510-20 (PTD #1861060) passed an MITiA to 5800 psi on 09/23/08 but historically exhibits siow IA re-pressurization when on injection. This well has been reclassified as Operable in alignment with the internal BP Welf Integrity Policy. A request far Administrative Approval with slow IA re-pressurization will be submitted to the AOGCC next week. Endicott operations may continue to operate the well, once the TTP is pulled, as necessary White the request for Administrative Approval is being submitted and reviewed. Please call with any questions ar concerns. Thank you. On behalf of Anna Dube, alternate -Taylor Wellman by Alaska - Weli Integrity Engineer office: 907-659-5098 `~~"~~'" ~\~`''~'° ~:~ "~~~~° cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, September 09, 2008 9:44 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; END/BAD Area Manager; END, 0&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Daniel, Ryan; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Lau, John, lack; Soto, lose A Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Wellman, Taylor T Subject: UNDER EVALUATION: END1-05 / 0-20 (PTD #1861060) IA Repressurization Jim and Tom, Well END1-05 / 0-20 (PTD #1861060) has been found to have IA repressurization. The IA was bled on 09/08/08 with minimal repressurization. However, this event triggered a review of the TIO plot which indicates stow repressurization over some time. The last AOGCC witnessed MIT-IA passed on 05/13 The plan forward for the well is as follows: 1. D: Bleed IA -DONE 10/13/2008 OPERABLE: ENDl-OS / O-ZO (PTD #1861060) IA Repressurization -Plan to request AA Page 2 of 2 • 2. S: Set TTP 3. F: MIT-IA to 1.2 x max injection pressure with backpressure on the tubing 4. S: Pull TTP when MIT-IA passes 5. WIC: Apply for Administrative Approval for continued gas injection Our intention is to leave the well on injection until the plug has been set and return the well to injection if the MIT- IA passes. A TIO plot, injection plot and wellbore schematic have been attached for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/13/2008 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov C~-~; i C+ 14 I OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: Endicott /END/ Row 1 09/23/08 Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. Well 1-05/0-20 Type Inj. N TVD ,473' Tubing 1,050 2,800 2,800 2,800 Interval O P.T.D. 1861060 Type test P Test psi 800 Casing 840 ,800 5,680 5,640 P/F P Notes: MIT-IA for AA application. OA 30 40 40 40 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Oq TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT END 1-OS(0-20) 09-23-OS.xls • • ~~ ~ -~ P ~ ~ 1 ~~ - ~~c~ -. _,~. ~,. ~:.;,ro nntro~ vnWV~ mnWre a:n~u o3ntwie gnaw ~~k r.~~ ~ "~ I ~, i ~, ~ :.~ ,- v il'CCG° !-!!lb- I.IVV tbaUU I 'WELLHEAD = 11" X 5K FMC GEN N (6500 I A CTUA TOR = KB. ELEV = 5 -.~ . BF. ELEV = 1 KOP= Max Angle - 38 @ 8: _ r -~-n- Datum MD = . 101 Dalun~ TV D _ _ ~ 8800' S IVQTEJ: E 1- 5 14$3' (-{ 5-112" HES X NIP, iD = 4.562" 13-318" CSG: 72#, L-80 BTRS, ID = 12.347" 2499' - 9-518" CSG; 47#; NT80S; ID = 8.681" 547T IUIIN ID = 3,725" @ 10268' 4-112" XN NIPPLE 5-1/2" TBG, 17#, L-80 TCII, .0232 bpf, ID = 4.892" 9353° 7-518" SCAB CSG, 29.7#, L-80 STL, ID = 6.875'" 9633° 7" TIEBACK CSG 29#, L-80 BTC-M, ID = 6.276" I 9738' TOP OF 7" TIEBACK LNR 9756' ~4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID= 3.958" # 10280' TOP OF 7" LNR 10123' 9-518'° CSG, 47#, NT95HS, ID = 8.681" 10387° PERFORATION SUMMARY REF LOG: DLL-GR (07104186) ANGLE AT TOP PERF: ?? @ 10409' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL OpnlSgz DATE 4" 4 10409 - 10439 O 4" 4 10470 - 14484 O 4" 4 10512 - 10524 O 4" 4 10538 - 10550 O 4" 4 10560 - 10622 O 2-118" 4 10622 - 10668 O 4" 4 10622 - 10668 O PBTD 11177' 7" LNR. 29#, L-80 BTRS, .0371 bpf, ID = 6.184" 11260' $353' --~ 5-112" X 4-112" XO, ID = 3.958" $534' 7-5/8" X 7" XO: ID = 6.276" 9738° ~-{ 7" LNR TIEBACK SEAL STEM ASSY, ID = 6.276" 10203' -~ 4-112" HES X NIP, ID = 3.813" ")0223' 7" X 4-1(2" BKR S-3 PKR, ID = 3.875'° 10247' 4-112°' HES X N{P, ID = 3.813" 10268' - 4-1l2" HES XN NIP, lD = 3.725" 102$0' 4-112" WLEG; ID = 3.958" ~_ ~ ELMD TT NOT LOGGED 10~ 855 ??7? DATE REV BY COMMENTS DATE REV BY 03/12/88 M DM POST RWO 04110/06 D16 RWO {2005) 05106106 CGITLH DRLG DRAFT CORRECTIONS 11117106 PJC DATUM MD CORRECTION COMMENTS CIBP PUSHED TO BTM (04/08106) BKR IBP (01/19106) ENDICOTT UNIT WELL: 1-05 ! 0.20 PERMiT No: 1861060 API No' S0-02 9-2 1 6 05-00 SEC T N R E BP Exptoration {Atas ka) STATE OF ALASKA .fL:b?/o~ If¿ ALASa'L AND GAS CONSERVATION .MISSION REPORT ()f SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 312828 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Tieback Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 55.30 11266 10396 11177 10316 90' 2499' 5477' 4911' 1504' 9720' 4. Well Class Before Work: o Development 0 Exploratory o Stratigraphic 181 Service 99519-6612 186-106 6. API Number: 50-029-21605-00-00 9. Well Name and Number: END 1-05/0-20 10. Field 1 Pool(s): Endicott Field 1 Endicott Pool feet feet Plugs (measured) None feet Junk (measured) 10855' feet Size MD TVD Burst Collapse 30" 131' 131' 13-3/8" 2499' 2499' 4930 2670 9-5/8" 5477' 5475' 6870 4760 9-5/8" 5477' -10388' 5475' - 9618' 8150 5080 7" 9756' - 11260' 9075' - 10389' 8160 7020 7-5/8" 24' - 9744' 24' - 9065' 6890 4790 1 0409' - 10668' 9637' - 9883' 5-1/2" x 4-1/2",17# x 12,6# L-80 x 9CR 10279' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" BKR S-3 Packer 5-1/2" HES X Nipple 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1 0223' 1493' R8DMS 8Ft MAY 3 0 2006 Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Representative Dail Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 181 GINJ 0 WINJ 0 WDSPL est 0 my nowledge. Sundry Number or N/A if C.O. Exempt 306-034 o Copies of Logs and Surveys run 181 Daily Report of Well Operations ~ Well Schematic Diagram Title Technical Assistant Phone O C-'. "X- -, ì Prepared By Name/Number: Date )~ ~,,_,:;' C ""Sondra Stewman, 564-4750 Submit Original Only 564-4750 '1j 1REE= WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= 7-1/16" CrN (6500 PSI) 11" X 5K FMC GEN rv (6500 PSI) . 55.3' 15.6' END1-05 L:e'NOTES: 38 @ 8300' 8800' SS 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 19-5/8" CSG, 47#, NT80S, ID = 8.681" MIN ID = 3.725" @ 10268' 4-1/2" XN NIPPLE 15-1/2" TBG, 17#, L-80 TCII, .0232 bpf, ID = 4.892" H 9353' 17-5/8" SCAB CSG, 29.7#, L-80 STL, ID = 6.875" 9633' 17" TIEBACK CSG 29#, L-80 BTC-M, ID = 6.276" TOPOF 7" TIEBACK LNR I 14-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" I 10280' TOPOF 7" LNR H 10123' 19-5/8" CSG, 47#, NT95HS, ID = 8.681" I PERFORA TION SUMMARY REF LOG: DLL-GR (07/04/86) ANGLEATTOPPERF: ??@ 10409' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 4 10409 - 10439 0 4" 4 10470 - 10484 0 4" 4 10512 - 10524 0 4" 4 10538 - 10550 0 4" 4 10560 - 10622 0 2-1/8" 4 10622 - 10668 0 4" 4 10622 - 10668 0 PBTD I 11260' 11177' 17" LNR, 29#, L-80 BTRS, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS ??? ORIGINAL COMPLETION 03/12/88 MDM POST RWO 04/10/06 D16 RWO (2006) 05/06/06 CGITLH DRLG DRAFT CORRECTIONS DA TE REV BY 1493' -15-112" HES X NIP, ID = 4.562" I 9353' -15-1/2" X 4-1/2" XO, ID = 3.958" I -- 7" LNR TIEBACK SEAL STEM ASSY, ID = 6.276" I 10203' -14-1/2" HES X NIP, ID = 3.813" I 10223' -17" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 10247' -14-1/2" HES X NIP, ID = 3.813" I 10268' -14-1/2" HES XN NIP, ID = 3.725" I 10280' -14-1/2" WLEG, ID = 3.958" I H ELMD TT NOT LOGGED I -1 CIBP PUSHED TO BTM (04/08/06) I - BKR IBP (01/19/06) I COMMENTS ENDICOTT UNIT WELL: 1-05/0-20 PERMIT No: '1861060 API No: 50-029-21605-00 SEC T N R E BP Exploration (Alaska) BP EXPLORATION Page 1 of·15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/20/2006 00:00 - 00:00 24.00 MOB N WAIT DECOMP Wait on 1-05 Well Kill and Preparation, Perform General Maintainance and Cleaning on Rig. 3/21/2006 00:00 - 02:00 2.00 MOB P DECOMP PJSM, Build Up Around 1-05, Set Tree and Well Head Equipment in Cellar. Lay Herculite and Mats. 02:00 - 06:00 4.00 MOB P DECOMP PJSM, Move Generator Unit, Move #2 Mud Pump. Move Sub Off of 2-22 to 1-05 06:00 - 07:30 1.50 MOB P DECOMP Spot #2 Mud Pump Complex, Spot #4 Motor Complex 07:30 - 10:30 3.00 MOB P DECOMP Close in Cellar, Put Well Equipment In Place. 10:30 - 12:00 1.50 KILL P DECOMP FVU Circulating Manifold and Lines, RlU DSM to Pull BPV. 12:00 - 14:30 2.50 WHSUR P DECOMP Pull BPV w/ DSM Lubricator. Tbg = 50 psi. IA = 250 psi. R / U Bleed Tank and Bleed IA. 14:30 - 17:30 3.00 KILL P DECOMP Bleed IA from 250 psi to 0 psi. Bleed Tbg from 50 psi to 0 psi. 17:30 - 18:00 0.50 KILL P DECOMP FVU 10K Double Annulus Valve. Line up Brine Water Trucks. Prime Pumps and PT Lines to 3500 psi. 18:00 - 20:00 2.00 KILL P DECOMP Circulate in 120 degree 9.7# NaCL Brine, down 7" x 9-5/8" Annulus and take returns up 7" Tbg. Circulation Rate = 13.2 bpm at 2720 psi. Pump 40 bbls Hi-Visc Detergent Sweep followed by 850 bbls of 9.7# Brine. Crude and Gas in Returns. Lost 330 bbls during circulation. 20:00 - 00:00 4.00 KILL P DECOMP Monitor well and wait for 9.7 ppg Brine to be delivered. 3/22/2006 00:00 - 01 :00 1.00 KILL P DECOMP Take on 9.7 ppg Brine. Displace Crude and Safe Clean Sweep out of well with 100 bbl. 8 bpm at 1,160 psi. 01 :00 - 02:00 1.00 KILL P DECOMP B/D and B/O lines. Install TWC and Attempt to test from below, Pumping away 4 bpm at 250 psi. 02:00 - 03:30 1.50 WHSUR P DECOMP PJSM, Bleed gas from Control lines, De-energize pack-off, Nipple down master valve assembly. Pull valve assembly with -10,000# pull to break free. 03:30 - 09:00 5.50 BOPSUF P DECOMP Nipple Up Adaptor flange and BOPE. Fill annulus, took 30 bbls of fluid in 3.5 hours. 09:00 - 18:00 9.00 BOPSUF P DECOMP Pressure Test BOPE; Pipe Rams, Blind Rams, HCR Choke and Kill Valve, Upper and Lower IBOP, Floor Valves, and Choke Manifold Valves to 250 psi Low /4000 psi High. Test Hydril to 250 psi Low / 3500 psi High. Fluid Losses at 24 bbls / hr during Test. John Crisp w/ AOGCC waived Witness of Test. Test Witnessed by BP WSL. 18:00 - 18:30 0.50 BOPSUF P DECOMP B/D lines and RID test equipment. 18:30 - 19:30 1.00 BOPSUF P DECOMP Pull TWC with DSM. 19:30 - 20:30 1.00 PULL P DECOMP M/U Spear assembly and spear into hanger. 20:30 - 21 :30 1.00 PULL P DECOMP BOLDS, Pull hanger to rig floor. Hanger pulled free at ~~95,000#. 21 :30 - 22:30 1.00 PULL P DECOMP B/O and LID Spear assembly, B/O and LID Tubing hanger. 22:30 - 23:00 0.50 PULL P DECOMP FVU Circulating head and lines. 23:00 - 00:00 1.00 PULL P DECOMP Circulate bottoms up, 1,100 psi at 8 bpm. Loss Rate 60 bph while pumping. Loss Rate 30 bpm static. 3/23/2006 00:00 - 01 :30 1.50 PULL P DECOMP Spot 40 bbl of 30 ppb Mix II LCM Pill at 4,150'. Static losses 24 bph. 01 :30 - 15:00 13.50 PULL P DECOMP Lay down 7" IJ4S Tubing Completion. Recover 4 sets of c;ontrolline, 10 Stainless Steel Bands, 57 Clamps, One SSSV and Injection Mandrel, 244 Jts of 7" Tbg, 5-1/2" x 7" XO, 5-1/2" Sliding Sleeve Assembly, and One Cut 5-1/2" Joint. Cut Joint Measured 20.3', Max Flare at cut -6-1/4" OD. Cut is in very uniform in shape and looks to have been fully severed by the . . Printed: 4/14/2006 11 :04:20 AM BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1 /20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2006 01 :30 - 15:00 13.50 PULL P DECOMP jet cutter. 15:00 - 16:00 1.00 PULL P DECOMP R / D Tubing Handling Equipment. Clear and clean rig floor. Load and Strap DC's and HWDP in Pipe Shed. 16:00 - 19:00 3.00 CLEAN P DECOMP Install Wear Bushing, P / U DC's and HWDP from Pipe Shed. 19:00 - 20:00 1.00 CLEAN P DECOMP P/U and Set Storm Packer, PT to 250 psi. Up Weight 73,000#, Down Weight 73,000#. 20:00 - 20:30 0.50 BOPSUF P DECOMP Pull Wear Bushing and Install Test Plug. 20:30 - 21 :30 1.00 BOPSUF P DECOMP C/O 7" Pipe Rams to 3 1/2" X 6" Varibles. 21 :30 - 22:30 1.00 BOPSUF P DECOMP M/U Test assembly and test 3 1/2" X 6" Varibles to 250 psi Low and 4,000 psi High, Test Annular with 4" Drill Pipe to 250 psi Low and 3,500 psi High. Test Witnessed by Doyon Toolpusher and BP WSL. 22:30 - 23:00 0.50 BOPSUF P DECOMP RID Test assembly, Pull Test Plug and install Wear Bushing. 23:00 - 00:00 1.00 BOPSUF P DECOMP P/U Running tool and sting into Storm Packer, Release Storm Packer and Establish loss rate. 8.5 bph while changing and testing Rams. 3/24/2006 00:00 - 04:00 4.00 CLEAN P DECOMP RIH picking up 4" DP from pipeshed to 4,157'. 04:00 - 05:30 1.50 CLEAN P DECOMP Break Circulation, 5 bpm at 280 psi. Establish Injection Rate, 2 bpm at 220 psi. Spot 40 bbl of 100 ppb LCM Pill. Squeeze at 2 bpm, Squeeze pressure built to 600 psi. Pressure bled off to 0 psi with pumps off. Static Loss rate 6 bph. Call Anchorage and discuss options. Decision made to pump another LCM Pill. 05:30 - 09:00 3.50 CLEAN P DECOMP Mix 40 bbl11 0 ppb LCM Pill, containing Mix II, Nut Plug, and CaC03. 09:00 - 11 :00 2.00 CLEAN P DECOMP Break Circulation, 5.0 bpm = 520 psi, 2 bpm = 90 psi, 1 bpm = 40 psi. Shut-in and Establish Injection Rate 1 bpm = 140 psi. Circulate LCM Pill to the End of Pipe, actual pill size able to get out of pits was 36.4 bbls. Shut in well and Bullhead at 1 bpm ( 12 stk/min). Pressure Slowly built from 170 psi to 617 psi, no break down in pressure observed. Pressure built constantly at 1 - 1.5 psi per pump stroke. Shut Down Pumps and monitored pressure. Instant Shut-In Pressure = 561 psi and went to zero in just under 20 mins. 11 :00 - 12:00 1.00 CLEAN P DECOMP Consult with Anchorage on results of LCM Squeeze. Monitor Well for losses. Fluid Loss Rate <4.0 bbl/ hr. Decision made to POOH and proceed with Well Plan. 12:00 - 14:30 2.50 CLEAN P DECOMP POOH and Stand Back DP, HWDP, and DC's. 14:30 - 15:30 1.00 WHSUR P DECOMP Pull Wear Ring. Bleed Down OA from 15 psi to zero. P/U Pack Off Pulling Tool on Joint of DP. Confirm no pressure in void area of pack off. Back Out LDS and POOH. 15:30 - 19:00 3.50 WHSUR P DECOMP Redress 9-5/8" Pack Off Seals on Location. Original Seals not in too good of shape, very brittle. C/O Seals, and test. Lower seals would only test to 3,300 psi, Secondary seals tested to 5,000 psi. Discussed test with Anchorage. Decision made to continue with well operations. 19:00 - 19:30 0.50 WHSUR P DECOMP M/U Running tool and install Wear Bushing. 19:30 - 21:30 2.00 CLEAN P DECOMP M/U BHA #2, Oversized guide, Hollow mill container, Overshot bowl (5.5" Grapple), Bushing, Overshot bowl (5.5" Grapple), Overshot Extension, Top Sub, Pump out sub, Lubricated bumper sub, Oil jar, XIO, 9 x 6.25" DC's, XIO, Accellerator jars, XIO, 21 x HWDP = 970.71' 21 :30 - 23:00 1.50 CLEAN P DECOMP RIH with BHA #2 from 970' to 4,190' 23:00 - 00:00 1.00 CLEAN P DECOMP P/U 4" DP from 4,190' to 5,288' . . Printed: 4/14/2006 11 :04:20 AM · BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/25/2006 00:00 - 08:00 8.00 CLEAN P DECOMP P/U 4" DP from 5,288' to 9480'. Joint #266. 08:00 - 08:30 0.50 CLEAN P DECOMP P/U Joint #267 and RIH. Tag up -13' in on Joint = 9493', approximately 50 ft high. Set Down 15,000 Ibs, will not go down. Double Count Joints in Pipe Shed. Establish Parameters; Up Wt= 200,000 Ibs, Ow Wt = 165,000 Ibs, Rot Wt= 183,000 Ibs. Free Torque = 5,500 ft-Ibs with 20 rpms. Establish circ rate at 4.0 bpm with 430 psi. Wash down Joint. P/U Joint #268 and Wash Down. 08:30 - 10:00 1.50 CLEAN P DECaMP Circulate bottoms up after washing down Joint #268. Large amounts of LCM Material and Pieces of Control Line Rubber in Returns. Circulated at 12.0 bpm and 2600 psi. 10:00 - 11 :30 1.50 CLEAN P DECOMP MIU Joint #269. RIH and Tag Up at Tool Joint = 9544'. Top of Tubing Stub. Establish Parameters. WI Pumps on, Up Wt = 198,000 Ibs, Down Wt = 167,000 Ibs, Rot Wt = 183,000 Ibs. Circ Rate = 5.5 bpm and 615 psi. Free Torque = 5,500 Ibs at 60 rpms. Rotate over Tubing Stub. Went over Jet Cut Flare Easily. Rotated Down while pumping another 10 ft. Pressured up from pack off on overshot and set down 15,000 Ibs. Picked up and attempt to release Anchor with right hand turns. Made two attempts to complete with no success. On Second attempt grapples released from fish. Made multiple attempts to shear off SBR. Able to make three Jar licks at 100,000 Ibs over pull with out success. Tried to continue to Jar, having problems keeping grapple engaged on fish. Made two more attempts to Shear SBR loose. Grapples released after each jar lick. Decide to POOH and C/O BHA. Fluid Losses to hole from Midnight to 12:00 hrs = 8 bbls. 11 :30 - 13:00 1.50 CLEAN P DECOMP Circulate 20 bbl High Visc Sweep Surface to Surface. Returns Contained More LCM Material and Control Line Rubber. 13:00 - 17:00 4.00 CLEAN P DECOMP BID and BID Top Drive. POOH w/4" DP, HWDP and DC's, Stand Back in Derrick. 17:00 - 17:30 0.50 CLEAN P DECOMP BID Overshot BHA. Mill Guide showed wear on inside from Stubing Stub. Both Grapples were worn dull and the Pack Off Showed a small wash out. 17:30 - 19:30 2.00 CLEAN P DECOMP MIU BHA #3, 8-1/2" x 8-1/4" Wash SHoe, 2 Joints of Wash Pipe Ext, Hollow mill container, Overshot bowl (5.5" Grapple), Bushing, Overshot bowl (5.5" Grapple), Overshot Extension, Top Sub, Pump out sub, Lubricated bumper sub, Oil jar, XIO, 9 x 6.25" DC's, XIO, Accellerator jars, XIO, 21 x HWDP = 984.32' 19:30 - 20:30 1.00 CLEAN P DECOMP Slip and Cut 95' of Drilling Line. 20:30 - 00:00 3.50 CLEAN P DECOMP RIH with BHA #3 from 984' to 8,373' 3/26/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RIH from 8,373' to 9,540' Establish Parameters, Up Weight 199,000#, Down Weight 169,000#, Rotating Weight 183,000 #, 6,500 ftIlbs Torque at 60 rpm, 600 psi Pump Pressure at 5 bpm. 00:30 - 02:30 2.00 CLEAN P DECaMP Wash down and Engage Fish at 9,544'. SIO to 150,000#, P/U to 275,000#, Jar, P/U to 285,000#. Continue Working pipe working up to 350,000# to Jar Fish Loose. 02:30 - 04:00 1.50 CLEAN P DECOMP Circulate Well, 8 bpm at 1,580 psi. 04:00 - 05:00 1.00 CLEAN P DECOMP Derrick Inspection and Service Top Drive. 05:00 - 10:00 5.00 CLEAN P DECOMP BID and BID Top Drive. POOH from 9,544', 10,000# to 15,000# Overpull initially on trip out. Stand Back 4" DP, HWDP, and DC's. Printed: 4/14/2006 11 :04:20 AM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/26/2006 10:00 - 12:00 2.00 CLEAN P DECOMP BID Fish from Overshot BHA and LID. BIO Overshot Assembly, LID Wash Pipe Extensions, and Pull Grapples. Fish recovered = 21.23 ft 5-1/2" Tbg Cut Joint, 8.05 ft 5-1/2" Tbg Pup Joint, and 14.6 ft SBR Assembly. Total Length = 43.88 ft. Fluid Loss Rate Increasing, up to 7.5 bbl/ hr. 12:00 - 13:00 1.00 CLEAN P DECOMP M/U BHA #4, 8-1/2" x 8-1/4" Wash Shoe, XO Bushing, Overshot Bowl (6.5" Grapple), Bushing, Overshot Bowl (6.5" Grapple), Overshot Extension, Top Sub, Pump out sub, Lubricated bumper sub, Oil jar, XIO, 9 x 6.25" DC's, XIO, Accellerator jars, XIO, 21 x HWDP = 970.7' 13:00 - 16:30 3.50 CLEAN P DECOMP RIH wI 4" DP from Derrick to 8573' 16:30 - 17:30 1.00 CLEAN P DECOMP P/ U Stand #90 and RIH. Establish Parameters; Up Wt = 201,000 Ibs, Dw Wt = 166,000 Ibs, Rot Wt = 183,000 Ibs. Free Torque = 5,000 Ibs at 30 rpms. Circulating Rate= 4.0 bpm at 400 psi. Continue to RIH and Tag at 9575'. Kick on Pumps at 5.0 bpm and wash down to 9580'. P / U with 10,000 # over pull - have fish. SID and unable to get deeper. P / U to 50,000# over and set off jars, SID to neutral weight and P I U to 10,000 # over. Unable to rotate out Anchor Assembly. Repeat again at 5,000 # over, unable to rotate out. Repeat Third time at 2,000 # over, Torqued up to 10,000 ft-Ibs while rotating, then torque fell off and weight fell off. PI U slowly while making 21 turns at surface. Able to pull free. SID and Tag 2' higher, PI U and see 10,000 # over pull but quickly drops off. Repeat twice with same results. 17:30 - 19:00 1.50 CLEAN P DECOMP Circulate 20 bbls High Visc Sweep Surface to Surface at 10.0 bpm and 2250 psi. Sweep brought back more LCM, Control Line Rubber & Pieces of Seal Ring. 19:00 - 23:00 4.00 CLEAN P DECOMP BID and BID Top Drive. POOH and Stand Back 4" DP, HWDP, and DC's in Derrick. No Fish. 23:00 - 23:30 0.50 CLEAN P DECOMP Break Down Overshot and Inspect. Some Marks on Lower Grapple and No Indication that Upper Grapple Made Contact with Fish. Bottom of SHoe had Metal Shaving and One Chunk of Iron Stuck in Teeth. Out side of the Overshot One big 1/4" x 3 ft Scar ( Linear) between two Bowls. Redress Overshot. 23:30 - 00:00 0.50 CLEAN P DECOMP M/U BHA #5. 3/27/2006 00:00 - 00:30 0.50 CLEAN P DECOMP M/U BHA #5, 8-1/2" x 8-1/4" Wash Shoe, XO Bushing, Overshot Bowl (6.5" Grapple), Bushing, Overshot Bowl (6.5" Grapple), Overshot Extension, Top Sub, Pump out sub, Lubricated bumper sub, Oil jar, XIO, 9 x 6.25" DC's, XIO, Accellerator jars, XIO, 21 x HWDP = 970.7' 00:30 - 04:00 3.50 CLEAN P DECOMP RIH wI 4" DP from Derrick to 9,511' 04:00 - 06:00 2.00 CLEAN P DECOMP M/U Top Drive and establish Parameters. Up Weight 198,000#, Down Weight 172,000#, Rotating Weight 186,000#. Rotary Torque 5,000 ftllbs at 40 rpm. 1,420 psi Pump Pressure at 8 bpm. Wash to 9,580', Engage Fish, Attemp to Release Slick Stick. Limiting out at 15,000 ftilbs of Rotary Torque, Work up from 215,000# to 250,000# and then Attempt to Rotate Slick stick free, Would not rotate free. Discuss options with Anchorage. 06:00 - 07:30 1.50 CLEAN P DECOMP Continue to Work Pipe with varied parameters in attempt to Rotate Slick Stick free. Decide to POOH and P/U Burn Over Shoe and Wash Pipe. . . Printed: 4/14/2006 11 :04:20 AM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2006 07:30 - 08:30 1.00 CLEAN P DECOMP Circulate Bottoms Up at 10 bpm and 2450 psi. No significant material seen in returns. 08:30 - 13:00 4.50 CLEAN P DECOMP BID and BID Top Drive. POOH and Stand Back 4"DP, HWDP, and DC's. 13:00 - 14:30 1.50 CLEAN P DECOMP BID and LID BHA#5. Clean and Clear Rig Floor. 14:30 - 15:30 1.00 CLEAN P DECOMP M/U BHA #6; 8-7116" x 7-1/8" Burn Shoe, XO, 1 Jt Wash Pipe, Boot Basket Drive Sub, Double Pin SUb, Boot Basket, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jar, XO, 9-DC's, Accel Jar, XO, 21- HWDP. Total Length = 1006.45' 15:30 - 20:30 5.00 CLEAN P DECOMP RIH wI BHA #5 on 4" DP to 9,545'. 20:30 - 00:00 3.50 CLEAN P DECOMP M/U Top Drive and establish parameters. Up Weight 200,000#, Down Weight 173,000#, Rotating Weight 185,000#. Torque 6,500 ftllbs at 80 rpm off bottom. Pump pressure 1,600 psi at 8 bpm. Wash from 9,545' to 9,583'. Mill from 9,583' to 9,589', WOM 5,000 - 15,000 Ibs, Torque 8,000 - 14,000 ftllbs at 80 rpm, 460 psi at 4.5 bpm. 3/28/2006 00:00 - 06:30 6.50 CLEAN P DECOMP Millon Packer from 9,589', 10,000 - 30,000# WOM, 7,000- 15,000 ftllbs of torque at 80 rpm, 460 psi at 4 bpm. Pump 20 bbl High-Visc Sweep. Small amount of Metal, LCM, and Other Material seen over the Shakers. 06:30 - 07:00 0.50 CLEAN P DECOMP Monitor Well, B/O and BID Top Drive. 07:00 - 07:30 0.50 CLEAN P DECOMP Lubricate and Service Blocks, Top Drive, Crown, and Rig. 07:30 - 11 :00 3.50 CLEAN P DECOMP POOH and Stand Back 4" DP, HWDP, and DC's 11 :00 - 12:30 1.50 CLEAN P DECOMP LID BHA#6, Burn Shoe, Wash Pipe, and Boot Baskets. Collected approximately 2 gallons of material from Boot Baskets. Mostly Metal Shavings mixed wI LCM Material, Scale, pieces of Stainless Steel Banding, and a couple pieces of larger metal. Burn Shoe in good shape, missing a few chunks off some teeth and inner side of carbides worn. Out Side of Barrel scard. Connections between Wash Pipe and Burn Shoe found to be slightly mushroomed / over torqued. 12:30 - 13:30 1.00 CLEAN P DECOMP M/U BHA#7; Cut Lip Guide, Overshot Bowl wI 6.5" Spiral Grapple, Top Sub, Bumper Jars, Oil Jars, DC's, Accel Jars, HWDP. Total Length = 965.58 ft. 13:30 - 16:30 3.00 CLEAN P DECOMP RIH wI BHA #7 with 4" DP from Derrick. 16:30 - 18:00 1.50 CLEAN P DECOMP M/U Stand #90 and Establish Parameters. Up Wt = 197,000 Ibs, Dw Wt = 168,000 Ibs, Rotating Wt = 184,000 Ibs at 30 rpm's at 5000 ft-Ibs torque. Establish Pump Rate of 4.0 bpm @850 psi. Tag up at 9578' and engage Slick Stick another 6' to bottom out, Pump Press up to 1300 psi. P/U to 50,000 Ibs over and let jars go off and straight pull to 75,000 Ibs over. SID to just below string weight and P/U to 10,000 Ibs over and attempt to rotate out Anchor, Stall Out with torque at 15,000 ft-Ibs after 18 rotations. Attempt to Rotate Out 2nd time with 5,000 Ibs over, Stall Out with 15,000 ft-Ibs torque. Attempt to Rotate Out 3rd time with Neutral Weight, Stall Out with 15,000 ft-Ibs torque. Grapple released on this attempt. Run Back in and engage fish. P/U to 50,000 Ib over and jar, straight pull with 75,000 Ibs over. Continue to Jar from 50,000 Ibs over to 150,000 Ibs over. After 6 plus Jar Licks at 150,000 Ibs over came free. Run in and try to engage again. Able to only see about 5-10,000 Ibs over pull then falls off quickly. Pump Pressure still increses on bottom and holds till over pull falls . . Printed: 4/14/2006 11 :04:20 AM BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/28/2006 16:30 - 18:00 1.50 CLEAN P DECOMP off. 18:00 - 19:00 1.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep around and Circulate around. 19:00 - 22:30 3.50 CLEAN P DECOMP POOH f/9,577' to BHA 22:30 - 00:00 1.50 CLEAN P DECOMP SB, BO, LD, BHA #7. Over Shot was belled in three spots and grapple assembly was left in the hole. 3/29/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to LID BHA. 00:30 - 01 :00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 01 :00 - 01 :30 0.50 CLEAN P DECOMP Pull and Service Wear Ring. 01 :30 - 07:00 5.50 CLEAN P DECOMP Test BOPE, Tested Annular to 250 psi Low and 3,500 psi High for 5 minutes. Tested all other Equipment to 250 psi Low and 4,000 psi High for 5 minutes. Jeff Jones with AOGCC Waived Witness of BOP Test. Witnessed By BP WSL and Doyon Tool Pusher. Test #1 Annular Test #2 Pipe Rams Test #3 Valve 12, 13, 14, Man Kill, Blinds, FOSV. Test #4 Valve # 9, 11, Upper IBOP. Test #5 Valve 5,8,10, Lower IBOP, Kill HCR. Test #6 Valve 4,6, 7. Test #7 Valve #2. Test #8 Valve #1,3. Test #9 Choke HCR. Test #10 Man Choke Test #11 IBOP Dart Valve. Acccumulator Test - Starting Pressure 2,950 psi, 1850 psi after functioning BOPE , First 200 psi in 15 seconds, full pressure in 1.10 minutes. 5 nitrogen Bottles at 2,100 psi. 07:00 - 08:00 1.00 CLEAN P DECOMP Rig Down BOPE Test Equipment and Install Wear Ring. 08:00 - 10:00 2.00 CLEAN P DECOMP PJSM, P / U BHA #8. 8-7/16 x 3-7/8" Packer Mill. 3 Boot Baskets, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jars, DC's and HWDP. Total Length = 973.37 ft. 10:00 - 11 :00 1.00 CLEAN P DECOMP RIH with BHA#8 on 4" DP from Derrick. 11:00-13:30 2.50 CLEAN P DECOMP Slip and Cut 108' of Drill Line. Change Out Dead Man Bolts and Adjust Brakes. 13:30 - 16:00 2.50 CLEAN P DECOMP Continue to RIH with BHA#8 from Derrick. To 9,515' 16:00 - 00:00 8.00 CLEAN P DECOMP M/U Top Drive and Establish Parameters - Wash down and Tag up at 9,575'. Commence Milling with 80 rpm, 7 - 10,000 ftllbs Torque, Pump Off 169,000# Down Weight, 199,000# Up Weight, 183,000# Rotating Weight, Pump On 171,000# Down Weight, 196,000# Up Weight, 179,000# Rotating Weight, 440 GPM with 2350 psi. 3/30/2006 00:00 - 07:30 7.50 CLEAN P DECOMP Milling Slick Stick and Packer, Parameters WOM 24,000# Rotary 75 rpm, Torque 9 - 10,000 ftllbs, Pumping 260 gpm with 1,416 psi. Pumping Hi-vis Sweeps Every two Feet of Slick Stick Milled. At 06:00 Current Depth 9,589' Pump Rate Varying From 260 gpm to 440 gpm Pressure from 1400 psi to 2400 psi. 07:30 - 09:00 1.50 CLEAN P DECOMP Circulate 40 bbl High Visc Sweep at 12 bpm at 2650 psi, surface to surface. Large Volume of Metal Cuttings with sweep. 09:00 - 12:00 3.00 CLEAN P DECOMP Continue to Mill at 9589'. Unable to make more footage. Varied Wt on Mill from 5,000 - 35,000 Ibs and rpm's from 60 to 120. Torque would rise from 7,000 to -13,000 ft-Ibs with several revolutions and then quickly drop off again. Circulate Printed: 4/14/2006 11 :04:20 AM · BP EXPLORATION Operations Summary Report Page 7 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-05/0-20 1-05/0-20 REENTER+COMPLETE Start: 1/20/2006 Rig Release: Rig Number: Spud Date: 6/6/1986 End: 3/5/2006 Date From - To Hours Task Code NPT Phase Description of Operations 3/30/2006 09:00 - 12:00 3.00 CLEAN P DECOMP around another 40 bbl High Visc Sweep at 8 bpm. The sweep showed only a small increase in cuttings volume over normal brine returns at same rate. Varied Pump rate from 0-10bpm. Continue to try and mill on fish. Still unable to get consistant torque or bite on fish. Dry Drilled for -20 mins with very limited increase in torque. Try to mill again with pumps on at 2-4 bpm required 35,000 Ibs Wt on Mill to see anything over free torque. Consult with BP and BOT in Town, no footage since 6 am, decide to POOH to inspect BHA, over 18 hrs on mill. 12:00 - 13:30 1.50 CLEAN P DECOMP Circulate 40 bbl High Visc Sweep at 12.5 bpm at 2750 psi, surface to surface. Increase in cuttings volume seen from last sweep. 13:30 - 14:00 0.50 CLEAN P DECOMP Service and Inspect Top Drive and Blocks. 14:00 - 17:30 3.50 CLEAN P DECOMP POOH and Stand Back 4" DP, HWDP, and Collars 17:30 - 18:30 1.00 CLEAN P DECOMP LID Packer Mill BHA and Empty Boot Baskets. Face of Mill in decent shape, still plenty of cutting edge left. Outside edge of cutting face worn down tapering from 6-5/8" to 8-7/16". A few pieces of large metal found lodged in flutes. All three Junk Baskets completely full. The majority of the volume was fine cuttings and shavings of metal but quite a few large metal slabs measuring several inches in length and chunks measuring over 3/4" x 3/4" found inside basket as well. Consult with BP and BOT in ANC. 18:30 - 21:00 2.50 CLEAN P DECOMP MIU BHA #9 BHA Consists of Packer Mill, 3 Boot Baskets, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jar, xo, 9 Drill Collars, xo, Accelarator Jar, xo, 21 HWDP = 975.66'. 21 :00 - 00:00 3.00 CLEAN P DECOMP RIH From 975' to 9,516'. 3/31/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Establish Drilling Parameters, 60 rpm, 6,000 ftllbs Torque, 120 rpm, 9,000 ftllbs Torque, 198,000# Up Weight, 182,000# Down Weight. Wash and Ream several passes across top of fish at 9589' at 13 bpm. Milling on fish with 20,000 Ibs, 120 rpms, and torque of 9-15,000 ft-Ibs. Initially had to work on top offish but able to start milling ahead. 00:30 - 01 :00 0.50 CLEAN P DECOMP Lost Circulation @ 9,591' Filled Hole on the Back Side, 32 bbl to Fill Hole, and Monitor Well. 01 :00 - 02:00 1.00 CLEAN P DECOMP Continue to Mill Packer From 9,591' Only Small amount of Gas Breaking Out at Bell Nipple. 02:00 - 02:30 0.50 CLEAN P DECOMP Monitor Well for Flow - No Flow. Circulated at 7 BPM with 900 psi. 02:30 - 04:00 1.50 CLEAN P DECOMP Continue to Mill on Packer from 9,591' to 9592'. Packer Released, Pushed Packer to 9,605'. Circulate at 12 bpm, with 2684 psi, 10-12,000# WOM, 60 rpm, 10,000 ftllbs Torque. 04:00 - 05:00 1.00 CLEAN P DECOMP Circulate High Visc Sweep at 12.5 bpm and 3030 psi surface to surface. 05:00 - 09:00 4.00 CLEAN P DECOMP Monitor Well, BIO and BID Top Drive, POOH and Stand Back 4" DP. 09:00 - 09:30 0.50 CLEAN P DECOMP Monitor Well for Flow. Monitor Static Fluid Losses = 6.8 bph. 09:30 - 10:30 1.00 CLEAN P DECOMP Stand Back HWDP and DC's. BID Mill and Boot Baskets. Only lower boot basket completely full. Mill face in good shape. Stinger I Guide Extension below Mill broke off. Piece left in hole 3-1/8" by -4 ft with 1" diameter hole through center. 10:30 - 11 :00 0.50 CLEAN P DECOMP Lubricate Top Drive, Blocks, Draw Works, and Rig. Consult with town on next BHA to run. Printed: 4/14/2006 11 :04:20 AM · BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/31/2006 11 :00 - 12:30 1.50 CLEAN P DECOMP PI U BHA #10: ITCO Spear wI 4.805" Grapple, Spear Stop Sub, Pump Out Sub, Bump Sub, Oil Jar, XO, DC's, XO, Accel Jar, XO, HWDP. Total Length = 962.42' 12:30 - 13:00 0.50 CLEAN P DECOMP Clean and Clear Rig Floor. LID unused fishing tools off floor. 13:00 - 17:00 4.00 CLEAN P DECOMP RIH with BHA#10 on 4" DP from Derrick. 17:00 - 18:00 1.00 CLEAN P DECOMP M I U Jt #271 and Establish Parameters. Up Wt = 198,000 Ibs, Down Wt = 170,000 Ibs. Circ Rate = 11.7 bpm @ 3240 psi. RIH and Tag up at 9605', SID with 15,000 Ibs weight on Spear. P/U to confirm Fish, No Over Pull. SID with 15,000 Ibs on Spear. P/U to confirm Fish, No Over Pull. SID to 20,000 Ibs on Spear. P/U to confirm Fish, No Over Pull. Increase Pump Rate to 12.25 bpm @ 3370 psi. S/O to 20,000 Ibs on Spear, Pump Press up tp 3460 psi. P/U to confirm Fish, Small Weight Gain off Bottom. SID to 20,000 Ibs on Spear, Pressure up to 3450 psi. P/U to confirm, Small Weight Gain off Bottom. SID to 20,000 Ibs on Spear, no Pump. PI U with 2,000 Ibs Over Pull. SIO to 37,000 Ibs on Spear, no Pump. PIU with 3-4,000 Ibs Over Pull. Assume We Have Fish. 18:00 - 19:00 1.00 CLEAN P DECOMP Circulate Bottoms Up at 11.5 bpm at 2850 psi. 19:00 - 22:30 3.50 CLEAN P DECOMP BID and BID Top Drive. POOH and Stand Back 4" DP 22:30 - 23:00 0.50 CLEAN P DECOMP Handle BHA, 23:00 - 00:00 1.00 CLEAN P DECOMP Spear Showed Evidence of Entering Packer Approx 2" to 3". Spear In The Release Position at Surface. LID Spear Assembly, Clean Junk Basket, MIU Milling Assembly. 4/1/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Continue MIU Milling BHA. BHA#11 Consists of Junk Mill, 2 7/8" Extension, Bit Sub, xo, Double Pin xo, Boot Basket, Bit Sub, Pump Out Sub, Bumper Jar, Oil Jar, xo, 9 Drill Collars, xo, Accelerator Jar, xo, 21 jts HWDP. Total Length = 974.73'. 01 :00 - 05:00 4.00 CLEAN P DECOMP RIH wi 4-1/2" Milling Assembly to top of PKR @9605' 05:00 - 06:00 1.00 CLEAN P DECOMP Establish Drilling Parameters. Pumps Off 200,000# Up Weight, 170,000# Down Weight, Pumps On 202,000# Up Weight, 170,000# Down Weight, Rotating Weight 185,000#,pumping 8 BPM with 1410 psi. Tagged up at 9,605', Rotated into Packer, Ran 5,000# Wt on Mill, 60 rpm's at 7,000 ft-Ibs torque. Cleaned out to 9,612'. PIU Out of Pkr and SID with No Rotation to Confirm Tag Up Depth. No Go Tag @ 9,612' on XO. Saw 300 psi Increase in Pump Pressure On No Go. Pressure Reduced as P/U Off Bottom. 06:00 - 07:00 1.00 CLEAN P DECOMP Circulate around Hi-Visc Sweep at 9612',12.3 bpm @ 2780 psi. 07:00 - 12:00 5.00 CLEAN P DECOMP Monitor Well. BID and BID Top Drive. POOH and Stand Back DP, HWDP and DC's. 12:00 - 12:45 0.75 CLEAN P DECOMP LID 4.5" Mill, 2-7/8" Ext, XO, and Boot Basket. Some wear on the face of mill. Boot Basket contained -1.5 gals of metal cuttings with several large pieces of copper strips. 12:45 - 13:30 0.75 CLEAN P DECOMP MIU BHA #12; 4-3/4" 00 Hyd Release Grapple, 4-1/4" PRT Ext and Stinger, Packer Mill, Triple Conn Sub, Boot Basket, Bit Sub, Pump Out Sub, Bumper Sub, Oil Jars, XO, DC's, Accel Jar, XO, HWDP. Total Length of BHA = 974.27' End of PRT to Grapple = 1.7' 13:30 - 16:00 2.50 CLEAN P DECOMP RIH with BHA#12 on 4"DP from Derrick to 9605'. 16:00 - 19:00 3.00 CLEAN P DECOMP Establish Parameters. WI No Pump Up Wt = 198,000 Ibs, OW Wt = 174,000 Ibs, Rot Wt = 185,000 Ibs with 60 rpm's and Printed: 4/14/2006 11:04:20AM BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1 /20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/1/2006 16:00 - 19:00 3.00 CLEAN P DECOMP 5500 ft-Ibs torque. With Pump Up Wt = 199,000 Ibs, Dw WT = 171,000 Ibs. SID and tag top of pkr at 9605', continue to SID and stack 10K on PRT at 9608.5'. P/U to confirm fish, no over pull. Make Several more attempts wlo pumps on, only able to get to 9609' and no over pull off bottom. Kick on pumps 10 bpm, 1750 psi and rotate at 30 rpms. Continue to tag up around 9609' with strong increase in pump pressure and see no over pull off bottom. Pump 20 bbl High Visc Sweep at 12 bpm and wash to off top of packer at 9605' to 9609'. Make another attempt to stab pkr with PRT. Unable to with pumps on. Shut-off Pump and SID. Able to get to 9613' w/15K WOM. P/U and see solid 5K over pull. Repeat 3 times. All with 5 K over pull. Circulate out Sweep and Drop Dart. 19:00 - 23:30 4.50 CLEAN P DECOMP BID and BID Top Drive. POOH and Stand Back DP, HWDP, and DC's. 23:30 - 00:00 0.50 CLEAN P DECOMP LID 9 5/8" Packer. 4/2/2006 00:00 - 01 :30 1.50 CLEAN P DECOMP LID 3 Joints 5.5" Tubing, Punching Hole in Each Joint to Bleed Off Trapped Pressure, First Joint Significant Amount of Metal Shaving In Tubing, Last Two Joints Pack With Sand. 01 :30 - 02:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 02:00 - 03:00 1.00 CLEAN P DECOMP Run 6.25" Collars in Hole, POOH Laying Down Same. 03:00 - 06:00 3.00 CLEAN P DECOMP CIO Elevators, Prepare to Handle BHA#13, BHA Consists Of Reverse Circulating Junk Basket, xo, Boot Basket, 7" Scraper, Bit Sub, Bumper Sub, xo, 6 - 4 3/4" Drill Collars, 21 jts HWDP BHA = 874.74'. 06:00 - 08:00 2.00 CLEAN P DECOMP RIH wi BHA#13 to 5673' 08:00 - 09:30 1.50 CLEAN P DECOMP Slip and Cut 101' of Drill Line. Service Rig and TD. 09:30 - 12:30 3.00 CLEAN P DECOMP Continue to RIH wI BHA#13 to 9511' with DP from Derrick. P/U 24 Jts of DP from Pipe Shed and RIH 1x1 to 10260'. 12:30 - 14:30 2.00 CLEAN P DECOMP Pump 40 bbl Hi Visc I Surfactant Sweep follow by 8.9 ppg brine, Displace Well from 9.7 ppg Brine to 8.9 ppg Brine. Pump Till 8.9 ppg Brine In & Out. Total Volume Pumped = 876 bbls Pump rate 11.5 bpm @ 3580 psi. 14:30 - 15:30 1.00 CLEAN P DECOMP Monitor Well - No Flow, Fluid Level Slowly Falling. P/U Single Jts of 4" DP, M/U, Drop Ball for Rev Circ Basket and RIH to Tag Sand Above IBP. Do Not Tag Up on IBP at 10309'. Continue in the hole P/U Single in Pipe Shed to 10821', No Change in Down Weight. 15:30 - 18:00 2.50 CLEAN P DECOMP Circulate around 40 bbl Sweep at 5 bpm and 900 psi. Fluid Losses - 8 bph While Circulating. 18:00 - 21 :30 3.50 CLEAN P DECOMP Monitor Well BID POOH From 10,821'. 21 :30 - 22:30 1.00 CLEAN P DECOMP LID Reverse Circulating Assembly. 22:30 - 23:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U CIBP Assembly. BHA Consists of - EZSV, Setting Tool, Pup Joint, 6 - 4.75" Drill Collars, 21 jts HWDP, BHA = 840.84'. 4/3/2006 00:00 - 04:30 4.50 CLEAN P DECOMP Continue to RIH w/EZSV from 840' to 5640', Break Circ 207 GPM at 400 psi. Continue to RIH to 10,234' 04:30 - 04:45 0.25 CLEAN P DECOMP Obtain Drilling Parameters, 183,000# Up Weight, 170,000# Down Weight, 175,000# Rotating. Set EZSV With 38 Turns to the Right, Stage Up Weight to 193,000# Set 2 minutes, Pulled Up to 200,000# Set 2 Minutes, Pulled Up to 251,000# Set For 2 minutes, Pulled up and Sheared At 238,000#. Set Down 10,000# to Confirm Set. . . Printed: 4/14/2006 11:04:20 AM · BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/3/2006 04:45 - 06:00 1.25 CLEAN P DECOMP Circulate Bottoms Up at 12.2 bpm and 3100 psi. 06:00 - 10:00 4.00 CLEAN P DECOMP POOH and Stand Back 4" DP, HWDP, and DC's 10:00 -11:00 1.00 CLEAN P DECOMP LID Setting Tool for EZSV. P/U HES Champ Packer. BHA; Champ Packer, XO Pump Joint, DC, HWDP. Total Length = 841.71' 11 :00 - 15:30 4.50 CLEAN P DECOMP RIH w/ Champ Packer to Top of 7" Liner at 9745'. 15:30 - 16:00 0.50 CLEAN P DECaMP Establish Parameters: Up Wt = 180,000 Ibs, Down Wt = 170,000Ibs. Break Circulation. Set Packer just below top of liner at 9763' and confirm set by S/O 15,000 Ibs. 16:00 - 16:30 0.50 CLEAN P DECOMP M/U Circulating head. Pressure Test 7" liner to 4000 psi for 15 mins. Initial Pressure = 4050 psi, Pressure after 5 mins = 4026 psi, Pressure after 10 mins = 4015 psi, Pressure after 15 min =4008 psi. 16:30 - 18:30 2.00 CLEAN P DECOMP Blow Down Lines and POOH f/9763 tl5351'. 18:30 - 19:00 0.50 CLEAN P DECOMP Service Rig. 19:00 - 20:00 1.00 CLEAN N RREP DECOMP Repair Draworks Air Line. 20:00 - 21 :00 1.00 CLEAN P DECaMP Continue to POOH f/5351, to 874.74'. 21 :00 - 22:00 1.00 CLEAN P DECOMP Handle BHA, LID Champ Packer. 22:00 - 22:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor 22:30 - 23:30 1.00 CLEAN P DECOMP M/U Polish Mill Assembly. BHA Consists of, Polish Mill Assembly, 8.5" OD Watermelon Mill, XO, Bumper Sub, Jar, Pump Out Sub, XO, 6 - 4.75" Drill Collars, 21 jts HWDP = 870.32'. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH to 1924'. 4/4/2006 00:00 - 03:00 3.00 CLEAN P DECOMP RIH f/1924' tl9720' 03:00 - 03:30 0.50 CLEAN P DECaMP Established Parameters. String Weight Up 183,000#, String Weight Down 175,000#, Rotating String Weight 183,000#, 30 rpm, Torque 3,000 ft-Ibs, 5 bpm, 490 psi. RIH Tagged Liner Top At 9,738', Washed Down To 9,744' Rotated 20 rpm, Torque 2,500 to 5,000 ft-Ibs, 50 psi Increase in Pump Pressure At 9,744' No Goed Top Of Polish Bore. 03:30 - 05:00 1.50 CLEAN P DECOMP Pumped 40 bbl Hi-Vis Sweep, 14.5 bpm, 4,000 psi. 05:00 - 09:00 4.00 CLEAN P DECOMP Monitored Well, Static. B I a, BID Top Drive. POOH w/4" DP. 09:00 - 10:00 1.00 CLEAN P DECOMP PI U HES Storm Packer and M / U to 4" HWDP. RIH and Set Storm Packer 2 Joints Below RT. POOH w/ Setting Tool. Tested Packer to 1,000 psi. 10:00 - 11 :00 1.00 CLEAN P DECOMP P / U Wear Bushing Pulling Tool on Joint of DP. RIH and Latched into Wear Bushing, BOLDS, and Pulled to Floor. LID Wear Bushing and Pulling Tool. P / U Test Plug on Joint of DP. RIH and Set, POOH, RILDS, L / D Joint of DP. 11 :00 - 12:00 1.00 CLEAN P DECOMP C/O Lower Rams to 7-5/8" CSG Rams. 12:00 - 13:00 1.00 CLEAN P DECOMP R / U And Tested 7-5/8" CSG Rams to 250 psi Low and 4,000 psi High, Test Recorded and Witnessed by BP Drilling Supervisor. R / D Test Equipment. 13:00 - 13:30 0.50 CLEAN P DECOMP Cleared and Cleaned Rig Floor. 13:30 - 14:30 1.00 CLEAN P DECOMP M I U Retrieving Tool, RIH, Latched and Released Storm Packer. POOH, B / 0 and LID Same. 14:30 - 16:30 2.00 CLEAN P DECOMP POOH wi BHA, Stood Back Collars, L / D Polish Mill Assembly. Brass Indicators Showed Top of Mill No Goed on Liner Top At 9,738'. 16:30 - 18:00 1.50 CASE P TIEB1 R I U Tie Back Assembly Handling Equipment. 18:00 - 19:00 1.00 CASE P TIEB1 M / U and Ran 7" Seal Stem Assy; 7" Seal Stem, 2 Centrilized Printed: 4/14/2006 11:04:20AM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1 /20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2006 18:00 - 19:00 1.00 CASE P TIEB1 Joints of 7",26#, L-80, BTC-M Casing. Make Up Torque 9,000 ft-Ibs, Used Best 0 Life 2000 Pipe Dope. 19:00 - 19:30 0.50 CASE P TIEB1 RID 7" Handling Equipment, R I U 7-5/8" STL Casing Handling Equipment. 19:30 - 00:00 4.50 CASE P TIEB1 Ran 7-5/8", 29.7#, L-80, STL Casing, Torqued Turned All Connections, Make Up Torque 5,300 ft-Ibs, Used Jet Lube Seal Guard Pipe Dope. Ran Casing To 1,740'. 4/5/2006 00:00 - 22:00 22.00 CASE P TIEB1 PJSM Continued to Run 7-5/8", 29.7#, L-80, STL Casing, Torqued Turned All Connections, Make Up Torque 5,300 ft-Ibs, Used Jet Lube Seal Guard Pipe Dope. 22:00 - 22:30 0.50 CASE P TIEB1 Tagged Liner Top At 9738', Stacked Out At 9744', w/10,000 # Down Weight to Confirm. Up Weight 300,000#, Down Weight 255,000#. 22:30 - 23:30 1.00 CASE P TIEB1 MIU XO Joint, 7 5/8" STL to 7 5/8" Buttress, MIU Cement Head, RID Casing Equipment, 23:30 - 00:00 0.50 CASE P TIEB1 Tested Liner Tie Back Seals t/500 Psi. Dropped Ball, and Loaded Wiper Plug. 4/6/2006 00:00 - 01 :00 1.00 CASE P TIEB1 Pumped Ball On Seat, At 3 bpm With 200 psi. Ball On Seat Tested Casing to 2500 psi, f/15 min, Increased Pump Pressure to 3000 psi f/15 min, Increased pressure to 3450 Ball and Seat Sheared. 01 :00 - 03:00 2.00 CASE P TIEB1 Circulated Bottoms Up at 5 bpm With 500 psi. Held PJSM With Rig Crew, Cementing Crew, Little Red, Veco Truck Crew Discussed Plan Forward And HSE. Rig Up Equipment and Batch Mixed Cement. 03:00 - 03:30 0.50 CASE P TIEB1 Shut Down Pumping, Lined Up And Tested Little Reds Lines to 3,500 psi. Switched to SLB Cementers Pumped 5 bbls of Water, 5 bpm, 420 psi. Shut in Manifold and Pressure Tested Lines to 4,700 psi. 03:30 - 04:30 1.00 CASE P TIEB1 Lined Up Rig Pump and Pumped 40 bbls of 9.7 ppg Brine at 6.75 bpm With 990 psi. Switched To Little Red and Pumped 24 bbls of Diesel, Pumped 2 bbls of Glycol, Dropped Bottom Plug and Pumped Out wi 3 bbls of Glycol, 5 bpm, 700 psi. Shut Down and Loaded Top Wiper Plug. 04:30 - 07:00 2.50 CEMT P TIEB1 Switched to SChlumberger, Pumped 170 bbls (350 sks) 11.5 ppg Lite Crete Cement wI 0.500 %bwoc Dispersant, 0.220 %bwoc Retarder, 0.200 %bwoc Antifoam, 1.50 gal I sk GASBLOK, 46.00 %bwoc Extender, 24.00 %bwoc Silica; Followed by 50 bbls (242 sxs) 15.8 ppg Premium Class G Cement wi 0.200 %bwoc Dispersant, 0.170 %bwoc Retarder, 0.200 %bwoc Antifoam, 0.350 %bwoc Fluid Loss. Pumped Cement at the Following Rates: Lead Cement Pumped Rate Pressure 5.00 bbls 5.00 bpm 1,050 psi 50.00 bbls 5.25 bpm 770 psi 100.00 bbls 5.25 bpm 750 psi 150.00 bbls 5.25 bpm 570 psi 170.00 bbls 5.00 bpm 500 psi Tail Cement Pumped Rate Pressure 10.00 bbls 3.25 bpm 400 psi 20.00 bbls 4.75 bpm 475 psi . . Printed: 4/14/2006 11 :04:20 AM · BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/6/2006 04:30 - 07:00 2.50 CEMT P TIEB1 30.00 bbls 4.25 bpm 565 psi 40.00 bbls 4.25 bpm 560 psi 50.00 bbls 3.50 bpm 420 psi Dropped Top Wiper Plug, Pumped 5.0 bbls Water 4.25 bpm, 200 psi. Displaced Cement with 445 bbls of 8.9 ppg Brine at the Following Rates: Pumped Rate Pressure Flow 25.00 bbls 6.90 bpm 475 psi 12% 50.00 bbls 6.90 bpm 490 psi 15% 100.00 bbls 6.90 bpm 490 psi 15% 150.00 bbls 6.90 bpm 490 psi 15% 200.00 bbls 6.90 bpm 490 psi 16% 250.00 bbls 6.90 bpm 490 psi 14% Caught Cement wI 285 bbls Pumped 300.00 bbls 6.65 bpm 1,277 psi 15% 350.00 bbls 6.65 bpm 2,550 psi 13% 400.00 bbls 5.00 bpm 3,000 psi 14% 420.00 bbls 5.00 bpm 3,350 psi 13% 445.00 bbls 4.00 bpm 3,500 psi 7% Bumped Plug wI 448.00 bbls Total Displacement Pumped. Pressured up to 4,300 psi to Bump Plug, Held fl 5 Minutes. RIH and Landed Out Seal Assy in Top of Tie Back PBR. Bled Down Pressure and Checked Seals, Seals Held. Cement In Place at 0630 hrs. 5 bbls of Cement to Surface. Note: Diverted Returns to Pits wI 300 bbls of Displacement Pumped to Monitor Returns vs Displacement wI Cement at Casing Leak at 4,150': Pumped Total Returns 25.00 bbls 23.00 bbls 50.00 bbls 48.00 bbls 75.00 bbls 60.00 bbls 100.00 bbls 73.00 bbls Monitored a Total of 100 bbls of Displacement Pumped wI Returns of 73 bbls, (Lost 27 bbls), Observed Diesel to Surface, Diverted Returns to Slop Tank. 07:00 - 07:30 0.50 CEMT P TIEB1 Flushed Stack wI Retarder I Citric Acid Mix and 20 bbls of Brine. 07:30 - 08:00 0.50 CEMT P TIEB1 N I D BOP Stack, Split and P I U Stack. 08:00 - 10:00 2.00 CEMT P TIEB1 Set 7-5/8" Slips in Wellhead Bowl, Set Slips wI 200,000# Down Weight. R I U Wachs Cutter, Cut 7 5/8" Casing per FMC Rep. 10:00 - 10:30 0.50 CEMT P TIEB1 Set Down BOP Stack, N I D DSA, P I U BOP Stack and Set Back onto Pedestal. 10:30 - 13:30 3.00 CEMT P TIEB1 Install New 7-5/8" Pack Off, N I U Tubing Spool. Tested Seals to 5,000 psi. 13:30 - 18:30 5.00 CEMT P TIEB1 N I U BOP Stack, Changed 7-5/8: Rams to 3.5" x 6" Variable Rams. 18:30 - 19:00 0.50 CEMT P TIEB1 Held PJSM. R I U BOPE Testing Equipment. 19:00 - 00:00 5.00 CEMT P TIEB1 Tested BOPE. Tested Annular Preventer 250 psi I 3,500 psi, Pipe Rams 250 psi 14,500 psi, Blind I Shear Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves and IBOPs to 250 psi I 4,000 psi. All Tests Held fl 5 Min. AOGCC Rep. John Crisp Waived Witness of Test. Test Printed: 4/14/2006 11:04:20 AM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: 1-05/0-20 Common Well Name: 1-05/0-20 Spud Date: 6/6/1986 Event Name: REENTER+COMPLETE Start: 1/20/2006 End: 3/5/2006 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/6/2006 19:00 - 00:00 5.00 CEMT P TIEB1 Witnessed by Doyon Tool Pusher and BP Drilling Supervisor. Lost 3 hrs Tracing Down Leaks and Pressure Losses. 4/7/2006 00:00 - 04:00 4.00 BOPSUF P TIEB1 Tested BOPE. Tested Annular Preventer 250 psi 1 3,500 psi, Pipe Rams 250 psi I 4,500 psi, Blind I Shear Rams, Choke Manifold and Valves, HCR's, Kill Line, Choke Line, Floor Valves and IBOPs to 250 psi 14,000 psi. All Tests Held fl 5 Min. AOGCC Rep. John Crisp Waived Witness of Test. Test Witnessed by Doyon Tool Pusher and BP Drilling Supervisor. Test #1Choke Valves #3,4,6, FOSV. Test #2 Choke Valves #5,8,2, Upper IBOP. Test #3 Choke Valves #7, 9, ManualIBOP. Test #4 Choke Valves #10, 12. Test #5 Choke Valves #13, 11, HCR Kill, Blinds. Test #6 Choke Valve # 1. Test #7 Choke HCR. Test #8 Manual Choke. Test #9 Annular. Test #10 Varible Pipe Rams. Choke Valve #14, and Manual Choke Failed Test. 04:00 - 08:00 4.00 BOPSUF P TIEB1 Rebuilt Choke Manifold Valve #14, N I D Manual Choke, Rebuilt and N I U Same. 08:00 - 08:30 0.50 BOPSUF P TIEB1 Tested Choke Manifold Valve #14 and Manual Choke Valve, 250 psi 1 4,000 psi fl 5 Minutes wI No Leaks or Pressure Loss. Tests Witnessed by Doyon Tool Pusher and BP Drilling Supervisor. 08:30 - 09:00 0.50 BOPSUF P TIEB1 BID and RID Lines. RID BOPE Test Equipment. Pulled Test Plug, Ran and Set Wear Bushing. 09:00 - 10:30 1.50 DRILL P TIEB1 M 1 U Clean Out BHA: 6" Mill, 3 x Junk Baskets, Bit Sub, 6" String Mill, Bumper Jars, Oil Jars, Pump Out Sub, XO, 6 x 4-3/4" DC, 21 Joints 4" HWDP, 11 Joints 4" DP, XO, 6-3/4" String Mill, XO. BHA Total Length: 1,230.52'. 10:30 - 11 :30 1.00 DRILL P TIEB1 Held PJSM. Slipped and Cut Drilling Line. 11 :30 - 12:00 0.50 DRILL P TIEB1 Serviced Rig. 12:00 - 14:30 2.50 DRILL P TIEB1 RIH wI BHA on 4" DP to 9,590'. 14:30 - 15:30 1.00 DRILL P TIEB1 M I U Top Drive, Established Parameters, String Weight Up 200,000#, String Weight Down 163,000#, String Weight Rotating 170,000#, 80 rpm, Torque 6,000 ft 1 Ibs, 7 bpm, 1,270 psi. RIH Tagged Up at 9,598'. PI U to 9,590', Circulated Bottoms Up, 13 bpm, 3,920 psi. 15:30 - 16:30 1.00 EVAL P TIEB1 B 1 0 and BID Top Drive. M I U Circulating Head and Lines. Closed Pipe Rams. Pressure Tested 7-5/8" Casing to 4,500 psi fl 30 Minutes. Bled Down Pressure, BID and RID Lines and Circulating Head. 16:30 - 19:00 2.50 DRILL P TIEB1 M 1 U Top Drive, Drilled Out Cement and Shoe Track from 9,598' - 9,744'. WOM 10,000# - 20,000#, 75 - 110 rpm, Torque on Bottom 8,000 - 10,000 ft Ilbs, 7 bpm, 1,300 psi. Pumped 10 bbl Hi-Vis Sweep Every 30 Minutes While Drilling Out. 19:00 - 19:30 0.50 DRILL P TIEB1 Pumped and Circulated Around 20 bbl Hi-Vis Sweep. 13 bpm, 3,800 psi. 19:30 - 20:30 1.00 DRILL P TIEB1 Washed and Reamed Down from 9,744' to 10,229', Washed Trough Cement Stringers. WOM 1,000#,50 rpm, Torque 8,000 ft Ilbs, 7 bpm, 1,400 psi. 20:30 - 21 :00 0.50 DRILL P TIEB1 Circulated Bottoms Up, 13 bpm, 3,970 psi. . . Printed: 4/14/2006 11 :04:20 AM BP EXPLORATION Operations Summary Report Page 14 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-05/0-20 1-05/0-20 REENTER+COMPLETE Start: 1/20/2006 Rig Release: Rig Number: Spud Date: 6/6/1986 End: 3/5/2006 Date From ~ To Hours Task Code NPT Phase Description of Operations 4/7/2006 21 :00 - 21 :30 0.50 EVAL P TIEB1 BID and BID Top Drive. M I U Circulating Head and Lines. Closed Pipe Rams. Pressure Tested 7-5/8" Casing to 4,500 psi fl 30 Minutes. Bled Down Pressure, BID and RID Lines and Circulating Head. 21 :30 - 23:00 1.50 DRILL P TIEB1 M I U Top Drive, Drilled Out CIBP from 10,229' - 10,232'. WOM 10,000# - 20,000#,100 rpm, Torque on Bottom 10,000- 11,000 ft Ilbs, 7 bpm, 1,450 psi. Pumped 10 bbl Hi-Vis Sweep Every 30 Minutes While Drilling CIBP. 23:00 - 00:00 1.00 DRILL P TIEB1 RIH, Pushed CIBP Down Hole. 4/8/2006 00:00 - 00:30 0.50 DRILL P TIEB1 Pushed CIBP to 10,855', Dropped Ball fl Pump Out Sub. POOH LID 6 Joints of 4" DP to 10,700'. 00:30 - 01 :00 0.50 DRILL P TIEB1 Pumped and Circulated 40 bbl Hi-Vis Sweep, 10 bpm, 1,700 psi. 01 :00 - 01 :30 0.50 DRILL P TIEB1 Observed Increase In Flow, Shut Down Pump and Monitored Well, Strong Gas To Surface, Shut In Well, SICP 320 psi, SIDPP 20 psi. Notified AOGCC, BP Drilling Superintendent, Endicott Control Room. 01 :30 - 05:00 3.50 DRILL P TIEB1 Circulated Well Using Drillers Method, Pump Rate 3.5 bpm, Held Constant DP Pressure 250 psi. Circulated Full Annular Volume. Shut Down Pump, SICP 0 psi, SIDPP 0 psi, Monitored Well Through Choke No Flow. Opened Annular Preventer, Monitored Well, No Flow. Pumped and Circulated Around 40 bbl Hi-Vis Sweep, 13 bpm, 3,800 psi. Shut Down Pumps, Monitored Well, No Flow. 05:00 - 15:00 10.00 DRILL P TIEB1 POOH, LID 4" DP. 15:00 - 15:30 0.50 DRILL N TIEB1 Repaired Pipe Skate. 15:30 - 16:00 0.50 DRILL P TIEB1 Serviced Rig. 16:00 - 18:00 2.00 DRILL P TIEB1 POOH, LID BHA. 18:00 - 18:30 0.50 RUNCO RUNCMP M/U Lubricator, R/U Slick Line. 18:30 - 21:00 2.50 RUNCO RUNCMP RIH w/5.75" Gauge Ring and Junk Basket.Tight At 9,739' To 9,740' Worked through Continue RIH to 10,420'. 21 :00 - 21 :30 RUNCMP RID Wireline. 21 :30 - 22:00 RUNCMP Pull Wear Ring. 22:00 - 00:00 RUNCMP PJSM R/U To Run Tubing, P/U Mule Shoe and XN Nipple. 4/9/2006 00:00 - 01 :30 RUNCMP RIH wI 20 Jts 4-1/2" 12.6# L-80 TC-II Tubing. Torque Turned Every Connection, Average M I U Torque 3,850 ft-Ibs. Used Jet Lube Seal Guard Thread Compound on All Connections. 01 :30 - 03:00 SFAL RUNCMP Air Boot On Riser Failed, 5 bbl 8.9 ppg Brine Leaked Into Secondary Containment In Cellar. Shut Down Rig Operations Secured Well, Reported Uncontrolled Discharge to ACS Representative Lance Douglas. PJSM, Repaired Air Boot. Cleaned Up Brine from Cellar Containment. 03:00 - 03:30 RUNCMP C I 0 to 5-1/2" Handling Equipment. 03:30 - 18:00 RUNCMP RIH wI 229 Jts 5-1/2" 17# L-80 TC-II Tubing. Torque Turned Every Connection, Average M I U Torque 4,350 ft-Ibs. Used Jet Lube Seal Guard Thread Compound on All Connections. Tested Tubing to 4,000 psi f/15 Minutes Every 3,000'. 18:00 - 20:00 RUNCMP M I U Tubing Hanger and Landing Joint, RIH and Landed Tubing Hanger in Wellhead, RILDS. 20:00 - 20:30 RUNCMP R I U and Tested Tubing to 4,000 psi, Held f/15 minutes. 20:30 - 21 :00 RUNCMP Held PJSM, R I U 7" Lubricator and Slickline Equipment to Retrieve D-16 Plug. 21 :00 - 22:30 RUNCMP RIH wI SlickLine Retrieving Tool to 10,202', Latched, Released Printed: 4/14/2006 11 :04:20 AM Page 15 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/9/2006 4/10/2006 1-05/0-20 1-05/0-20 REENTER+COMPLETE From - To Hours Task Code NPT Phase 21 :00 - 22:30 1.50 RUNCO RUNCMP 22:30 - 23:00 0.50 RUNCO RUNCMP 23:00 - 23:30 0.50 RUNCO RUNCMP 23:30 - 00:00 0.50 RUNCO WAIT RUNCMP 00:00 - 02:00 2.00 RUNCO WAIT RUNCMP 02:00 - 04:00 2.00 RUNCO RUNCMP 04:00 - 05:00 1.00 RUNCO RUNCMP 05:00 - 06:00 1.00 RUNCO RUNCMP 06:00 - 06:30 0.50 RUNCO RUNCMP 06:30 - 10:30 4.00 RUNCO RUNCMP 10:30 - 11 :30 1.00 RUNCO RUNCMP 11 :30 - 12:00 0.50 WHSUR P WHDTRE 12:00 - 14:00 2.00 BOPSU P WHDTRE 14:00 - 18:00 4.00 WHSUR P WHDTRE 18:00 - 20:00 2.00 WHSUR P WHDTRE Start: 1/20/2006 Rig Release: Rig Number: Spud Date: 6/6/1986 End: 3/5/2006 Description of Operations and Retrieved D-16 Plug, POOH wI Plug. RID Slickline Equipment, Pulled and LID 7" Lubricator. R I U Circulating Head and Lines. Waited on Vac Truck wI 140 deg Seawater per Central Dispatch. Waited on Vac Truck wI 140 deg Seawater per Central Dispatch. Pumped and Circulated 290 bbls 140 deg Seawater wI Corrosion Inhibitor down 7-5/8" x 5-1/2" Annulus. 3 bpm, 330 psi. Held PJSM, R I U Little Red to Circulating Manifold. Pressure Tested Lines, C I 0 Lines and Valves, Retested. Pumped 45 bbls Diesel Freeze Protect Down 7-5/8" x 5-1/2" Annulus, Shut In Annulus Valve, Switched to Tubing Side, Pumped 5 bbls Diesel Down Tubing. Dropped BallI Rod Assy and Allowed to Fall on Seat on RHC Sleeve in XN Nipple at 10,267'. Pressured up to 2,500 psi to Set Baker S-3 Packer, Increased Pressure to 5,000 psi and Tested Tubing f/30 Minutes, OK. Bled Down Tubing Pressure to 2,500 psi and Shut In. Pressure Tested 7-5/8" x 5-1/2" Annulus to 4,500 psi fl 30 Minutes, OK. Bled Down All Pressures, BID and RID All Lines and Circulating Head. RID Little Red, BID and LID Landing Joint. Ran and Set TWC. Held PJSM. N 1 D BOP Stack and Equipment. N 1 U Adapter Flange and Tree. Test Void and Neck Seals to 5,000 psi. Test Tree to 5,000 psi. R I U DSM Pull TWC, Ran and Installed BPV. Secured Well. Rig Released at 20:00 hrs. Printed: 4/14/2006 11 :04:20 AM MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: . ~ I' JIm Regg ")\/0'" c:: ¡c·/'/n/. j i::~lI'''ì'''' -- _ v- \.!.os P.I. Supervisor' . r( , DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-05/020 DUCK IS tJNIT MPI 1-05/020 Src: Inspector .l ..... ''ò, -(p'''~ .rtÔ! ,·ft\:¡¡ \ FROM: Chuck Scheve Petroleum Inspector Well Name: DUCK IS UNIT MPI 1-05/020 API Well Number 50-029-21605-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060513195118 Permit Number: 186-106-0 Inspection Date: 5113/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. , 1-05/020 ¡Type Inj. I I .. ! I ! I Well G TVD 8956 I IA 830 2400 2390 2390 I ITypeTest I SPT I -- I ! i I P.T. 1861060 Test psi 2239 OA 0 0 0 0 I i --- TUbing: I I I WRKOVR P 4300 4300 I 4300 4300 , Interval P/F , Notes Pretest pressures were observed and found stable, Well demonstrated good mechanical integrity, NON-CONFIDENTIAL Reviewed By: P.I. SuprÚ5e- Comm ';;;;'i"".'.~' . ,:i.i1\t;Àjlt;;:;r. ¡U. hi " e" ~~\;'~1f.i¡j~' \J' - ".,¡ ...... ti Wednesday, May 17,2006 Page I of I Well control Doyon 16 Endicott 1-05 e e Pit)-#- ì B~ - ¡D(p Doyon 16 called 0100 hrs 4-8-06 with 320 psi. on casing & 20 psi drill pipe. Circulated out with existing workover fluids with no problems. I followed up on the call this morning. They are finishing the well & will be on Endicott 2-22 tomorrow night. Doyon 16 used the Annular Preventer for well control, I asked if the bag had been tested since it was used to circulate out gas. I think this was issue worked out between Harry Engel & Winton with Chuck in the middle. The Drilling Foreman was under the impression I was involved with this issue about the required test of annular preventer. Is there an interpretation of testing annular preventer of which I am not aware? We have had several contacts from Nabors 4ES on NGI 08. Lou has last contact information on well control issues. j &<;~'\~ ./ ~c2&~..{-ü ft" ':iJ l ~ ~{ ~-3~ ft'D +5 -tV.-- ~~. ~SU~ (YPf UàeÅ c:(U1.(( ~ LJea \j 3'i2. 94 4 ( (t{ 0(., SCANNEJ!i "'. ;!~ ')nD~ à <!1 t..o.,.,;¡ 1 of 1 4111/20062:50 PM Re: Variance Request for Doyon .16 on Ef\tq~ -05 RWO I ¡~- ·;M··/tJ (p -'1 ) Subject: Re:Variance Request for Doyon 16 on END1-05 RWO From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Mon, 06 Feb 2006 10:35:44 -0900 To: "Kara,..OannyT"<Danny.Kªra@bp.com> Dan, Per 20 AAC 25.285 (h), AOGCC hereby approves alternate BOPE,as described below, for your proposed workover (App. No. 306~034) of well End 1-05/020 (PTD 186-106). All other stipulations apply. Winton Aubert AOGCC 793-1231 Kara, Danny T wrote: Winton, Doyon 16 will be moving to the Endicott 1-05/0-20 workover later this month or early next month. The scope of this workover has been detailed in the Application For Sundry Approval (Form 10-403) recently submitted to your office dated 1/24/06. The rig currently has in place a 13-5/8" 5000 psi BOP stack with 3 preventors (annular, variable pipe rams, blind rams). The maximum anticipated surface pressure for this well is 3400 psi and the BOP test pressure specified in the well program is 4000 psi. Considering the maximum anticipated surface pressure and the inability to add a fourth preventer due to height restrictions in the substructure, BPXA requests a variance from 20 AAC 25.285 (c)(2)(B) for this workover. The current BOP stack configuration provides adequate well control protection and does not compromise the overall safety of the workover. Please call me if you have any questions. Dan Kara BP Drilling 564-5667 (office) 240-804 7 (cell) 564-4440 (Fax) . j ß ?JJÙ'ò ~fi\\tt-~Ne.D f£.B ~ StJ~~~ .... karadttWbp.com 'í', . 1 of 1 2/6/2006 3:45 PM ,@ 11 illlT rr Œ) UW:i L6 ) rm Ii? tiß~,\~', :,"""::,1 ~,/ðÃ\" " :¡'fù,: ",( i"ol",r",r7/ ßifii'~\ ,I I r L iil \ : 'j i i,\\ I', !'.i i;l\, I ~ i ¡;;;ìJ i,l\', ¡ ¡ /(1\ \\~, :,1:1 /if' '. lill U ,/ i~ [ ~ LnJ (Q) [j,~ Lfl !\ ) AItJt.SIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR John McMullen Sr. Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 l~b- tö(P Re: Endicott, END 1-05/0-02 Sundry Number: 306-034 " '\: (¡J) .~ 0)008, 5CANNEl); J~E¡hi ~JJ Ji.. ~ Dear Mr. Mullen: 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, 01~ Cathy P. Foerster Commissioner 3' ¡Jf DATED this_ day of January, 2006 Encl. 'VJ6A- /30 12..0 D /p RECE\VED ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 6 2006 APPLICATION FOR SUNDRY APPROVAL G C ns cQl1l1ÏlSÏOll C Alaska Oi' & 8S 0 . 20 AA 25.280 R . L ...............-1 C . epalr e""n""...... aSlng ) STATE OF ALASKA ) 1. Type of Request: [J Abandon [J Suspend [J Operation Shutdown [J Periorate II Other [J Alter Casing II Repair Well 0 Plug Periorations 0 Stimulate 0 Re-Enter Suspended Well [J Change Approved Program II Pull Tubing' [J Periorate New Pool [J Waiver [J Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 55.30 8. Property Designation: ADL 312828 11. Total Depth MD (ft): 11266 Casins Structural Conduct9f Surface Intermediate Production Liner 4. Current Well Class: o Development 0 Exploratory o Stratigraphic a Service /' 5. Permit To Drill Number 186-106 ,/ 6. API Number: 50- 029-21605-00-00 ,.,,/ 10. Field / Pool(s): 9. Well Name and Number: END 1-05/0-20 ./ 1311 24991 5477' 54771 - 103881 97561 - 112601 1311 24991 54751 54751 - 96181 90751 - 103891 Endicott Field / Endicott Pool PRESENTWELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): 10396 11177 / 10316 None Length Size MD TVD Burst 901 24991 5477' 4911' 1504' 30" 13-3/8" 9-5/8" 9-5/8" 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): 104091 - 106681 / 9637' - 9883' Packers and SSSV Type: 9-5/8" IHBBP-Big Bore packer SSSV Landing Nipple 12. Attachments: a Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch March 1, 2006 / Date: Tubing Size: / 7" x 5-1/2",26# x 17# Junk (measured): None Collapse 4930 6870 8150 8160 2670 4760 5080 7020 Tubing Grade: Tubing MD (ft): L-80 97421 Packers and SSSV MD (ft): 96111 /' 15201 13. Well Class after proposed work: o Exploratory 0 Development a Service 15. Well Status after proposed work: o Oil 0 Gas / 0 Plugged o WAG a GINJ 0 WINJ 16. Verbal Approval: Commission Representative: 17. I hereby certify that t fore~Oin ~,i~~ a; correct to the best of my knowledge. Printed Name J,?.JJ" VI" k..-- Hie Sr. Production Engineer Signature "f/ ( ~ Phone 564-4711 Date Commission Use Only o Abandoned o WDSPL Contact John McMullen, 564-4711 f i( ;.._ u t / Prepared By Name/Number: '/ <--fjOto Sondra Stewman, 564-4750 I Sundry Number: ~ - Ó ~ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity æ(SOP Test (!('Mechanicallntegrity Test 0 Location Clearance Tes-c- BoPE to 4000 )"!.-G. j\/l!.r v~D~V"t!J . Other: p~ 1.-0 ML LS. l-85 (k)¡ lLlt¿y~t~ f:)oPE t~f- f.y()t..e~~ s'S (14 ?.[) Mt.. -Z}) . 1-. (p S (t\) L 2..\ I C(...J t~~t e. ~ S S V t' s. ct..p()YL?\I~d. Subsequent Form Required: \ D - 4. 0 4- . Approved By: Iê& _ /.- f2. r I Fonn 10-403 Re~:.to~5 ~ OR¡GI(~AL RBDMS BFL JAN 3 } 2005 ctf f' rei ({ eJ · COMMISSIONER APPROVED BY THE COMMISSION Date (- 3/- 0 Co Submit In Duplicate ) ') bp Endicott WeIl1-05/0-20(Gas Injector) Sundry Notice f/RWO Well Historv Well 1-05/0-20 was originally drilled and completed in August 1986 as a K3A gas producer and in March 1988, a __ AWO was performed to convert the well to a gas injector. Currently, five sets of perforations are open, covering sub-zones Fi, S3A4, S3A3, S3A2, and upper K2B. Since gas injection startup in May 1988, well maintenance consisted of perforation water washes and CNUIPAOF surveillance procedures. Prior to MIT-IA failure in September, 2005, this well has had limited maintenance/complications. Current Well Condition Well 1-05/0-20 has been shut-in since faih;re of two MIT-IA tests in early September 2005; a leak detection log later confirmed a production casing leak.I'Based on the current condition of the well and limited historical maintenance, the planned AWO should not have difficulty pulling the current completion string, running and cementing a tie-back string to surface to cover the leak in the current production ca~in,", ~á d to run a new completion string into the well. The current reservoir is 4450 psi @ 10,000' SSTVD . pg EMW (measured 1/15/2006). ' _ Workover Obiective A rig workover will be performed on this well to cover/isolate the leak in the 9-5/8" production casing (confirmed 9/21/05) by running and cementing a 7-5/8" tie-back string from the top of the existing 7" production liner all the way back to surface, filling the 7-5/8" x 9-5/8" annulus with cement to surface, installing a new 5-1/2" x 4-1/2" completion and return the well to fulltime gas injection. This workover will include the following tasks: Pre-Rig Operations 1. Function lock down screws. PPPOT IC, tubing. 2. No-flow IA test. 3. Pull the TTP, drift well for IBP placement, make TD tag & TEL for corrected depth. 4. Run SBHPS (depths to be provided by Endicott PE). 5. Bullhead kill well 2x hole volume w/180 degree F. seawater. /'" 6. Install Baker 4-1/4" IBP at 10,309' MD & PT to 1000 psi. 7. Dump bail sand on IBP & install plug in tubing tail and PT to 2500 psi. /' 8. E-line chemical cut tubing -9561' MD. 9. Circulate well over to KWF through the tubing cut and freeze protect well to 200'. 10. Install BPV. RWO Operations (Estimated Start Date: 02/20/06) c!:' ) 1. MIRU D16. Circulate well to 8.8 ppg KWF, install TWC, AU/test BOP~~psi. 2. Pull existing 7" x 5-1/2" completion from above tubing cut. /' . 3. Mill/fish out 9-5/8" TIW packer/tail-pipe assembly. 4. Run 7" scraper and install 7" RBP at -9836' and cover with 40-50' sand. 5. Run 9-5/8" casing scraper and polish BOT tie-back assembly. 6. Run & cement 7" x 7-5/8" tie-back casing. / 7. ND/NU BOPE for installing casing slips and a new tubing head.." 8. Drill out shoe track. Clean well out to RBP pull same. / 9. 7" casing scraper run to IBP and circulate the well clean. ) ) 10. PuIlIBP. 11. Clean-out well to 11,118' MD. 12. Run 5-1/2" x 4-1/2" TC-II completion (4-1/2" x 7" packer setting depth -10,172' MO). 13. Set packer. MIT T/IA to 4000 psi. (NOTE: Will MIT T/IA to 6000 psi after tree installed.) * 14. Install TWC, NO BOPE, NU adapter flange & master valve. NOTES: 1. BPXA requests a variance to the provisions of 20 MC 25..oas (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent ~i~ (;;' (Jj purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. 2. Regarding 20 MC 25.265. Approval is requested to run a non-surface controlled subsurface safety valve. \L The new completion size (5-1/2" tubing inside of 7-5/8" casing) and the operating conditions of the well --r::- 1/.r"; lCl) l~ì dictate the use of this type of valve. Specifically, plans are to use a wireline retrievable MCX injection SSSV placed in a standard X-nipple. 1-05/0-20 RWO Page 2 RT. ELEV = 55.3' BF. ELEV = 15.6' MAX. DEV. = 38:48 8300'MD 13-3/8", 72#/ft, L-80, BTRS. CSG. I 2,499' 1 9-5/8", 47#/ft, 1 NT80S XO TO 5,477' NT95HS TOP OF 7" TIE BACK 9,756' LINER TOP OF 7" LINER 10,123' I 9-5/8", 47#/ft, NT95HS, ) Endicott 1-05 Current -) A ~ 1--' 1-' . 10,387' 1-. A PERFORATION SUMMARY REF: LOG: DLL-GR (7/4/86) CO SIZE SPF INTERVAL SOS 21/8" 4 10,622' to 10,668' GO 4" 4 GO 4" 4 ATLAS 4" 4 ATLAS 4" 4 ATLAS 4" 4 ATLAS 4" 4 W/O CLEAN- PBTD 7" - 29 #/ft, L-80, BTRS DATE 3/12/88 12/20/89 REV. BY MOM JLH 10560' to 10622' 10622' to 10668' 10409' to 10439' 10470' to 10484' 10512' to 10524' 10538' to 10550' 11,151' 1--' 11,177' 1--' 11,260' 1--' AFTER WORKOVER ADDITIONAL TREE: 6" 1 10,000 psi 1 McEVOY WELLHEAD: 13-5/8" 1 10,000 psi 1 FMC o SSSV LANDING NIPPLE 1,520' .- . .-- 7", 26#/ft, L-80, IJ4S TUBING LANDING NIPPLE o .- (5.962" MIN. 10) 4,478' FOR METHANOL 7" IJ4S XO TO 5-1/2" TC4S SLIDING SLEEVE OTIS "XA" (4.562" MIN. 10) TUBING SEAL ASSY. 9,513' f :g II E \ 9-5/8" PACKER 1 J .- (TIW "HBBP-BIG BORE") 9,611' :8: f 5-1/2", 17#/ft, L-80 TAILPIPE 5-1/2" "x" NIPPLE (OTIS) (4.562" 10) 9,661' 5-1/2" "XN" NIPPLE (OTIS) (4.455" 10) 9,702' .. "'- 9,526' 9,590' 5-1/2" WLEG 9,742' ~ ENDICOTT WELL: 1-05/0-20 API NO: 50-029-21605 COMPLETION DIAGRAM BP EXPLORATION, INC. RT. ELEV = 55.3' BF. ELEV = 15.6' MAX. DEV. = 38:48 8300'MD ) 13-3/8", 72#/ft, I L-80, BTRS. CSG. 2,499' 7-5/8",29.7#, L-80, TC-II Tie-Back Casing f/-2500 MD to Surface 9-5/8", 4 7#/ft, NT80S XO TO 5,4 77' NT95HS 7-5/8",29.7#, L-80, BTC-M Tie-Back Casing f/2500'MD to 9665' MD 5-1/2", 17#/ft, L-80, TC-II Tubing TOP OF 7" TIE BACK 9,756' LINER TOP OF 7" LINER 10,123' I 9-5/8", 4 7#/ft, NT95HS, 10,387' I -) Endicott 1-05 Proposed / / / / ~ 1-11",;1 r/ ~/ / / ;I' / / / ;I' ,- ,- ,- I-~ / / / , / / / ;I' ,- ,- ,- ,- ,;I ,- ;I' ;I' / / ;I' ;I' ~ . TREE: 7-1/16" I 6500 psi I Cameron WELLHEAD: 13-5/8" I 6500 psi I FMC ./ ,- / ;I' /77 / //' ~. ~- OA Down-Squeeze Gmt 2000'- ,. - Prod csg leak 4150' ,;I (Deepest; maybe more shallower) / / / / / / / ,- ;I' / / ;I' ;I' ;I' / ;I' / ;I' ,- ;I' ;I' ,- ;I' ;I' ,- ,- ;I' ;I' , X-Nipple f/SSSV -1500' MD ./ 9-5/8"x7 -518" Annulus Cemented to surface 7 -5/8" to 7" XO -9665' MD 7", 29#, L-80, BTC-M Casing ! j ~ '- 7~~:~::~~:::':~::.~::ï::'105' MD · - 4-1/2" "X" NIPPLE (3.813") -10,207' MD · - 4-1/2" "XN" NIPPLE (3.725") -10,238' MD " .- 4-1/2" WLEG -10,249' MD 4-1/2",12.6#, TC-II, L-80Tubing PERFORATION SUMMARY REF: LOG: DLL-GR (7/4/86) CO SIZE SPF INTERVAL SOS 21/8" 4 10,622' to 10,668' GO 4" 4 GO 4" 4 ATLAS 4" 4 ATLAS 4" 4 ATLAS 4" 4 ATLAS 4" 4 W/O CLEAN- PBTD 7" - 29 #/ft, L-80, BTRS DATE REV. BY 3/12/88 MOM 12/20/89 JLH 01/03/06 JGR . 10560' to 10622' 10622' to 10668' 10409' to 10439' 10470' to 10484' 10512' to 10524' 10538' to 10550' 11,151' 1-" 11,177' 1-" 11,260' I ~ AFTER WORKOVER ADDITIONAL Planned Workover 1- Perforations f/1 0,409' to 10,668' (Last SL Tag - 10,640' MD (9/18/05)) EN DICOTT WELL: 1-05 I 0-20 API NO: 50-029-21605 COMPLETION DIAGRAM BP EXPLORATION, INC. , RE: Proposed MCX SSSVfor Endicott 1-('''- ') ') Subject: HE: Proposed MCX SSSV for Endicott 1-05 From: "McMullen, John C" <McMuIlJC@BP.com> Date: Mon, 30 Jan 2006 11 :08:35 -0900 To:..Wihtgr)..A\.Jbert·.<winton..Jàqbert@agmin..state.ak.u$> No proposed change to the testing requirement or frequency. 1-05's SSV and SSSV will be tested every six months (AOGCC notified/witnessed) just like our other gas injectors. From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Monday,January 30, 2006 10:36 AM To: McMullen, John C Subject: Re: Proposed MCX SSSV for Endicott 1-05 John, Is there an accommodation for testing this valve every six months? Thanks, Winton 793-1231 McMullen, John C wrote: «MCX info.ZIP» «5.5 MCX EDS.PDF» Winton - attached is some general information on the Halliburton MCX safety valve. Specific to the proposed MCX for Endicott 1-05, design conditions are 85 MMSCFD; 4500 psi. With a bean size of 2.094", the minimum injection to keep the valve in the "opèn position" would be 60 MMSCFD. In the future, if we want to decrease the injection below 60 MMSCFD, we would need to pull theMCX and resize the bean. Please call me if you have any more questions. John 564-4711 1 of 1 1/30/2006 11 :20 AM ) ) HALLIBURTON 'm!r'imll'lfiflll1/filfj',¡jIWN'lllfillfll'ilijIIWii:ii1íi1Ii/liff'((ja"í(I ¡'jr iliW4(II'fI(f/ " dífiiii:1I_'j iliif'lif~ij¡il_j("'fi'-íljIWW(1f'tjijiW¡'\f~i i/jiijf¡'i'liW..¡¡t'\;'W{W'\ffl'¡r'/ j _' / '''Uf''1~jjdN/''fmi:' i'~jjlfi(ioWIWI/ ifilii'\fjjj ¡-'iiIjj jjii~jj í_'i'fjim (i ijifii(ldij i iiildiWiji_'i: ilijf¡iiiiji¡'ill¡l i'i!liljli~'iiili1¡Wjilijifllii":mi~iá:'iilifilirjWi~;(liiltiii ldjil(aaíji'ij(fl¡'f~ MC '..ièctiou VatvEt$ HalHbt.utoll MC (t1apper~typt) Injection V<úvu are 'ttsedin injet.1ion welts tQ auton~1tkanY$h\lt in tÌ1etubingstring ,,-hen l~jedi()n stops 01' t1owreverses. MC inJe<tion valves artspring~loaded, wiretioo--rtt1'ir.-able \lllves with huge bores. The Ì\.'lC injection vah"e$ also feature sealing areas that ute out Qf d~ dIred: ßow puth. Ttwme vatves are designed to beheld opm by in,ÌectiQn pressure rorfl1..1id p:aS$age, If injection 110\\' becol11Cs static or ''<e\'~rfW$fOr an}' reas()n~ tMspring andlorreverse now cð:u,ses the v,tlves to dose, The$e,,'alve$ arc designed to remain <:Jos.ed until pres$uredîfferential acro'$$ the 'h'th-es i$ equalized and inie<:;tion is fe$Ull100, Appli~at¡on$ .. Injccti('Ul ''''ells I" .' Flow Tube 'I:; ; i~,",~,¡,· rtí ¡, , :~ Flapper ,~,, ¡ Features. .. Þ,ifC valves have sealing areas that al~ out of tbe direct flow path. BeRef'. '" Valves designed to 3lttQtnatkallY$Òut Ìtltuhing $tdng jf, in.iection is stripped öri[ßo'¡.o;' reverses . .. h'l$talted andl,ttdc'\<'ed by wit'eline ul,der pressure .. Designed to be set .on variOl'L$ HaJiihtutönlock ITtandrels MCln)tctìon Vii....·" MC Iniection Valves (Flitl)per..Type Closlue) 1 11'2 3R10 i.5OC ;Ie ~ .420 3€.Ot' 0,150 19.05 ~ ti(J· t 6LJN 2 StUD 1.815X UðD 447C 0$10 ZO.57 r 3iS·t4 UN 21'2 63.50 2.313 x: 2.180 55.37 1.DOO 25.40 1 314-12 UN g39;:) ~.562 ~. ;:.!.~~ ~Ô( 1 ~OC 25,"0 ¡.1: SLS 31/2 ea,$C ;2.750 X 2.620 $.6,,~5 1,3$0 $5.05 ZI,~t2 $LB 4 101.60 3.313 X 3.270 83,06 1.830 46.48 2 314-12 SLB r1430 3 ð88 R 2.43D 91 fE 1,3S0 $5.05 ~ ·...,e.-12 SLB < 1,2 3.813 X 114,.30 :3,,710 $4,2",3 2.000 $0.$0 3 151&·12 SLB 1Z7'JJO ..t25 X 3.asO .$5 2,000 so.8ö ;'),3114ð2$Ul ðH2 f39,7!) 4.562 X 4.42'0 l1Z,27 2,62\1 ~6.$5 4-12 $L8 7 f77JJO 5.062R 5.goo 149.86 3.500 00.90 51i1ð-$SLÐ Ordering Information Spøcify: nippl4~'~ and ¡ode profile, SQn/;:e (s~andard, %H;:O. !i~CC~. ,1mínes). p!~SSUfe ~ing .1nè limperat\JTe. few r:¡:e. Part Hwnbtr Prefix: flapp&r·t:.~22MC::t MCX 1-30 Subsurface Safety Equipment Engineering Data Sheet ') ') HALLIBURT'DN Engineering Data Sheet 1/30/2006 EQUIPMENT MATERIAL NO.: 101051722 WLRIV,MCX,4.562,4.42 2.62,02S PART NUMBER: 22MCX45612 DESIGN SPECIFICATIONS VALVE MODEL CLOSURE TYPE SIZE SEJlVICE MEETS REQUIREMENTS OF NACE MR-01-75 PRESSURE RATING MAXIMUM OD INSIDE DIAMETER WITHOUT BEAN LENGTH TEMPERATURE RATING MA TERIAL O-RING MATERIAL O-RING BACK-UP MATERIAL TOP THREAD CONNECTION TYPE TOP SUB THROAT INSIDE DIAMETER BEAN, INC-925 BEAN INSIDE DIAMETER FLOW AREA (CONTINUED) MCX FLAPPER 4.562 H2S YES 5000 pounds/sq. inch 4.42 inch 2.62 inch 23.10 inch 20 TO 300 Deg. F 9CR-IMO/INCOLOY 925 VITON TEFLON 4-12 SLB BOX 3.14 inch 101051912 (22M753) .891 inch .632 sq. inch http://houcapel14.corp.halliburton.comlReports/displayx...Injection/l 01051722 _22MCX45612.xml&xsl=/reports/EDS.xsl (I of 2) 1/30/2006 9:02:45 AM Engineering Data Sheet ) PRESSURE DROP ACROSS BEAN TO HOLD VALVE OPEN SPRING LOAD WITH VALVE OPEN LOCK MANDREL TYPE TEST FIXTURE , DRIFT SLEEVE DRIFT SLEEVE INSIDE DIAMETER DRIFT SLEEVE LENGTH (END) (U nless specified, Dim~inches, pres-psi, weight-Ibs, temp-deg F) ) 5.6 pounds/sq. inch , 26.5 pound X 101088393 (81 T01396) 101088166 (81RI56) 4.432 inch 3.00 inch NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. Halliburton, Dallas, Texas, U.S.A. http://houcapeI14.corp.halliburton.comlReports/displayx...Injection/1 0 1 051722_ 22MCX45612.xml&xsl==/reports/EDS.xsl (2 of 2) 1 /30/2006 9:02:45 AM STATUS: ENDl-05 e e -it:- [>it> I<G'" --10'-" Sub.iect: 51'1\ TLJS: E1\iD 1-05 From: "NSU, ADW Well Integrity Engineer" <NSU1\DWWcIllntcgrityEnginccr(éþBP.com> Date: Sat, 19 No\! ?005 21 :06: 1 0 ~0900,. 1/( 1-/j)( To: James Rcgg <:IIITI_regg@admm.state.ak.us> 'Ke.r¡ 1- CC: Winton GAubert <winton._aubert(ii}admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWc1I1ntcgrityEnginccr(éi~BP.com>, "Luckett, Ely Z. (VECO)" <luckcz@BP.com>, "Holt, Ryan P (VECO)" <:Ryan.Holt@.BP.com>, "Mielke, Robert L." <robert.mielkc@BP.com>, "Dube, Anna T" <Anna.Dubc@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWc1l0pcrationsSupervisor@BP.com>, "Rossbcrg, R Stcyen" <RossbeRS@ßP.com>, "Engel, Harry R" <EngclHR@ßP.com>, "McMullen, John C" <McMuIIJC@BP.com> Hi Jim. Endicott 1-05 is currently SI due to a production casing leak at 4150', leak rate = 2 BPM @ 1250 psi. Current plans are to conduct a rig workover to fix the PC leak. Ga-s5r1 JeoÞ- Please call with any questions. Joe 1-907-659-5102 SCANNED' DEC 1 () 2005 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, October 24, 2005 11:02 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Status of Injectors w/Failed MITs Need an updated status on the following wells. Also, these wells should be added to the monthly report you provide for injectors unless integrity concerns have been eliminated. PBU 9-25: according to last info we have (email 7/18/05), SI; plan was to take water sample for analysis; any change PBU 13-25: email dated 8/1/05 said this would be added to not showing up in last rpt we received; status? PBU 13-32A: email dated 8/4/05 said would do diagnostics; results? PBU AGI-07: reported failed MIT 8/25; well is not listed in montly rpt; status? PBU AGI-10: status? DIU 1-05/020: well was SI 9/18 after failing MIT; suspect packer leak; well is not listed in montly rpt; status? the well is in status? monthly rpt; reported failed MIT 8/25; well is not listed in montly rpt; Jim Regg AOGCC 1 of 1 11/22/20054:38 PM ENDI-05 Failed MITIA (PTD 1861060) e e . Subject: END I-OS F" . From: "Anders, Joe L' Date: Mon, 19 Sep 2005 16:12:23 -0800 To: jlm_regg@admin.statc.ak.us, winton _ aubert@admin.state.ak.us CC: "Rossberg, R Steven" <RossbeRS@BP.eom>, "McMullen, JohnC'~<MeMulIJC@BP.eom>, "NSU, ADW Well Operations Supervisor" <NSUADWWcllOperationsSupervisor@BP.eom>, "Reeves, Donald F" <ReevesDf@BP.eom>, "Hughes, Andrea (VECO)" <hugha4@BP.com>,"Holt, Ryan P (VECO)" <Ryan.Holt(4)BP.com>, "Engel, Harry R" <EngelHR@BP.com>, END/BAD Area Manager <ENDBADAreaManager@BP.com>, "END, Operations Lead Tech" <ENDOpcrationsLeadTeeh@BP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEnginccr@BP.com>, "Wiggs, Craig L" <wiggscIl@BP.com>, bob _ neckcnstein@admin,state.ak.lIs i \-z.z~ ù.;-- K4fé1 _. t ...,1................... ... ..... .~,,¡;': 'iol" ~,:;:t,,·, Hello Jim & Winton. :~~" j" . . Gas injection well END1-05 (PTD 1861060) failed a recent MITIA. During pre-4-year AOGCC MITIA testing, a leak rate of 2 BPM @ 1250 psi was established down the IA. Subsequent testing against a TTP resulted in a passing MIT-T and the MITIA again failing. The well is currently SI with a TIP and a packer leak is suspected. Recent events: > 09/11/05: MIT-IA Failed LLR=2 bpm @ 1250 psi. > 09/18/05: Set TIP @ 9702' MD, MIT-T Passed to 2500 psi, MITIA Failed, 3.5 bpm @ 1500 psi Current plans are to further evaluate the failed MITIA with a Leak Detect Log. Attached is a well bore schematic and MIT form, please call if you have any questions. «MIT END 1-05 09-11-05.xls» «1-05.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~\;A\N!~lE[; (.. c 20n¡¡:¡ .) òJJ Uc Content-Description: MIT END 1-05 09-II-05.xls MIT END 1-05 09-11-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: I-05.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 9/22/2005 8:29 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Endicott 09/11/05 Anna Dube ~ Packer Depth Pretest Initial 15Min. 30 Min. WeIlIEND1-05 I Type Inj. I G TVD I 8,956' Tubing 4,200 4,2001 4,200 4,200 Interval! 4 P.T.D.11861060 I Type test I P Test psi I 2500 Casing 150 1,2001 1,250 1,250 P/FI F Notes: MITIA Failed, LLR 2 BPM @ 1250 psi OA 100 140 1140 140 Weill I Type Inj. I I TVD I I Tubingl I Interval! P.T.D.I I Type test I I Test psil I Casing I I P/FI Notes: I OAI I Weill I Type Inj.1 TVD I I Tubingl Interval! P.T.D.I I Type test I I Test psil I Casing I I I P/FI Notes: I OAI I I Weill I Type Ini.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Typetestl I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G=Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT END 1-05 09-11-05.xls TREE: 6" 110,000 psi I McEVOY RT. ELEV = 55.3' WELLHEAD: 13-5/8"/10,000psi/FMe BF. ELEV= 15.6' MAX. DEV. = 38:48 8300MD 13-3/8", 72#/ft, 0 SSSV LANDING 1,520' NIPPLE L-80, BTRS. CSG. 1 2,499' I ~ 7', 26#1ft, L-80, IJ4S TUBING LANDING NIPPLE (5.962' MIN. 10) 4,478' FOR METHANOL 9-5/8", 4 7#1ft, 1 1-. NT80S XOTO 5,477' NT95HS 7" IJ4S XO TO 5-1/2' TC4S 9,513' SLIDING SLEEVE I I OTIS "XA" 9,526' (4.562" MIN.ID) TUBING SEAL ASSY. 9,590' 9-5/8" PACKER 1 9,611' (TIW"HBBP-BlG BORE") 5-112', 17#/ft, L-80 TAILPIPE 5-112' ''X'' NIPPLE 9,661' (OTIS) (4.562" ID) 5-112' ''XN'' NIPPLE 9,702 TOP OF (OTIS) (4.455" 10) 7" TIE BACK 9,756' I ~ 5-1/2" IAn..EG 9,742 LINER TOP OF 10,123' 1 ~ 7" LINER 9-5/8", 47#1ft, 10,387' I~ NT95HS, PERFORATION SUMMARY REF: LOG: DLL-GR (114186) SOS 21/8" 4 10,622' to 1 0,668' GO 4" 4 10560' to 10622' GO 4" 4 10622' to 10668' ATLAS 4" 4 10409' to 10439' ATLAS 4" 4 10470' to 10484' ATLAS 4" 4 10512' to 10524' ATLAS 4" 4 10538' to 10550' WIO CLEAN- 11,151' 1-. PBTD 11,177' 1-. 7" - 29 #/ft, L-80, 11,260' 1--' BTRS DATE 3/12/88 12/20/89 REV. BY MDM JLH AFTER WORKOVER ADDITIONAL ENDICOTT WELL: 1-05/0-20 API NO: 50-029-21605 COMPLETION DIAGRAM BP EXPLORATION, INC. STATE OF ALASKA ALAm'~' OIL AND GAS CONSERVATION COMMIS°' "~N REPORT SUNDRY WELL OP._RATIONS Operations performed: Operation shutdown__ Stimulate Plugging__ Pull tubing__ Alter casing Repair well __ Perforate__ Other X Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 1945' SNL, 2038' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1961' SNL, 540' EWL, SEC. 31, T12N, R17E, UM At effective depth 1989' SNL, 796 ' EWL, SEC. 31, T12N, R17E, UM At total depth 1993' SNL, 835' EWL, SEC. 31, T12N, R17E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 6. Datum elevation (DF or KB) KB£ - 55.26 AMSL feet 7. Unit or Property name 8. Well number 1-05/0-20 MPI 9. Permit number/approval number 86-106 10. APl number 50- 029-21605 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured 11266 feet Plugs (measured) true vertical 10395 BKB feet Effective depth: measured 11177 feet Junk (measured) true vertical 10315 BKB feet Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Con d ucto r 90' 30" Driven 131' 131' Surface 2458" 13 3/8" 2100 c.f. Permafrost 2499" 2499" Intermediate 10347' 9 5/8" 425 c.f. Class G 10388' 9618' Production 458 c.f. Class G w/.5% , Liner 1504' 7" 458 c.f. Class G 9756' - 11260' 9074' - 10391' Perforation depth: measured 10409'- 10439' 10512'- 10524' 10560'- 10668' ORIGINAL true vertical 9582'- 9608' 9672'- 9682' 9714'- 9809' 9635'- 9647' 9695'- 9705' Tubing (size, grade, and measured depth) 7"26#/ft L-80 IJ4S tubing with 5 1/2" tailpipe to 9742' Packers and SSSV (type and measured depth) 9 5/8" HBBP - Big Bore Packer at 9611'; 7" SSSV at 1520'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 5 0 1997 Alaska, .Oil .& Gas Cons. r~nnfinra0ei 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 79746 87985 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas.__ Suspended 17. I hereby certify ~th~; the foregoi_ng- is true and correct to the best of my knowledge. , , ~/¢,¢'L~ ..-/~¢' ¢ .,-.. ~ ~.~,~. ? Title ~enior Technical A~i~t~nt IV Form 10-404 Rev 06/15/88 Service R~.~ Ini,_~.ot_nr Date 4/28/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 3/8/97 WELL N°: 1-05/O-20 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: MIT VARBLE HB&R DATE/TIME OPERATIONS SUMMARY 0800 MIRU HB&R. P/T TO 3000 PSI 0820 PUMP 3 BBLS DIESEL DOWN IA & PRESSURE UP TO 2500 PSI. MONITOR FOR 30 MIN. 0850 PASSED MIT. BLEED BACK TO 500 PSI. RDMO SUMMARY: PASSED MIT. WITNESSED BY AOGCC REP. DOUG AMOS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP 1-05/O-20 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Date: RE: 14 March 1995 Transmittal of Data ECC #: 4063.02 Sent by: ANCH.EXPRESS Data: LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 6 March 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ¢ DESCRIPTION 1 CN/GR FINAL BL+RF 1PFC/PERF FINAL BL+RF Run # 1 Run # 1 ECC No. 4063.02 6192.07 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Stree5 Suite 201 Anchorage, ~ 99518 Or FAX to (907) 563-7803 Received by: Date: Alaska Oil & Gas Cons. Commission Anchorage .J ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 March 1994 RE: Transmittal of Data ECC #: 4063.01 Data: CN/GR Dear Sir/Madam, Reference: BP 1-05/O-20 ~---[0~ ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL CN/GR/CCL FINAL BL C~GR/CCL RF SEPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ') \) -r ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 15 February 1994 RE: Transmittal of Data ECC #: 4063.01 Data: CN/GR Dear Sir/Madam, Reference: iSw - 10(0 BP 1-05/0-20 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 CJt..... CN/GR LDWG TAPE+LIST Sent by U.S. MAIL ~ ltœFi Run # 1 i 0 c..)"=t ll- \ \ \ \ ~ Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ¡þ }'" i ¡.... #.... "'~. ." ~ ¡.... ,/! f., ... /" f'" fl. ,!::" ^' " [:-1 .!,... ·ç~~~t:., ~,. <~1 ~~, ' !~ I~ , Of¡ ':-' '" .. ~) . ~,~~~~:;~" c:::'~ /"',5>:'" u~? Date: /o~l~~/ (;ilt ~~~ . -- ~ .I Received by: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 26, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 1-05/O-20 5/22/90 *INJECTION PROFILE 10300' - 11121' Camco Run No. 1 WELL 1-21/K-25 6/10/90 *PRODUCTION PROFILE SURVEY 13600' - 13984' Run No. 1 Camco WELL 1-27/P-20 6/17/90 *COMPENSATED NEUTRON LOG 9945'- 10703' Run No. 2 Schlumberger WELL 1-43/P-26 *INJECTION PROFILE 13600' - 14070' Camco 5/19/90 Run No. 1 WELL 1-57/R-23 6/1/90 *TEMPERATURE SURVEY 11600' - 12390' Run No. 1 HRS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907') 561-5111 January 17, 1990 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Endicott Field Well 1-05/O-20 Additional Perforations Gentlemen' Enclosed in duplicate is Form 10-404, Report of Sundry Well Operations, for the above named well. We added perforations to this gas injection well on December 3, 1989. Please contact Gary Adamson at 564-4624 if any additional information is required. Sincerely, H. L. Hellman Reservqir Development Coordinator HLH/d~slk Enclosures xc: W. R. Blosser J. L. Haas H. L. Hellman G. Adamson R. Q. Meads Well File Working Interest Owners File 76.10 232JLH STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIL, N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address Po O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1945' SNL, 2038' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1961'SNL, 540' EWL, SEC. 31, T12N, R17E, UM At effective depth 1989' SNL, 796 'EWL, SEC. 31, T12N, R17E, UM At total depth 1993'SNL, 835' EWL, SEC. 31, T12N, R17E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55o26 AMSL feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-05/0-20 MPI 9. Permit number/approval number 86-106/9-9 71 10. APl number 50- 029-21605 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 90' 2458" 10347' 1504' measured 11266feet 10395 BKB feet 11177 feet 10315 BKBfeet Plugs (measured) Junk (measured) Size Cemented true vertical 30" Driven 13 3/8" 2100 c.f. Permafrost 9 5/8" 425 c.f. Class G 458 c.f. Class G w/.5% 7" 458 c.f. Class G Measured depth BKB 131' 2499" 1O388' , 9756'- 11260' 10409'- 10439' 10512'- 10524' 10560'- 10668' 10470'- 10484' 10538'- 10550' 9582'- 9608' 9672'- 9682' 9714'- 9809' 9635'- 9647' 9695'- 9705' Tubing (size. grade, and measured depth) 7"26#/ft L-80 IJ4S tubing with 5 1/2" tailpipe to 9742' True vertical depth BKB 131' 2499" 9618' 9074'-1O391' Packers and SSSV (type and measured depth) 9 5/8"HBBP - Big Bore Packerat 9611'; 7"BVD at 1520'. : 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 32134 400 397O2 5OO : Tubing Pressure 3800 365O 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. t %Signed ~ ¢,~ ~~,~4.~.¢~ Title ReservoirDevelopmentCoordinator, Endicott Form 10-404 Rev 06/15/88 Date SUBMIT IN D'UPL'fCATE Attachment 1 BP Exploration Endicott Field Gas Injection Well 1-05/O-20 Additional Perforations We perforated the following intervals in subzones 3A2, 3A3, and 3A4 on November 15, 1989: 10409 - 10439 ft. M.D. 10470 - 10484 ft. M.D. 10512- 10524 ft. M.D. 10538 - 10550 ft. M.D. A lubricator was installed and tested to 3000 psi for all well work. 232JLH P r o d tt c rio n Engineering =_ .... _Departm-ent D pE.R ATJ_ON S~:l E P. OJ~L[ p . ¢--j9 DATE: 1 1/1 5/89 WELL N~: 1-05/O-20 TYPE OF OPERATION: ADDITIONAL PERFORATIONS BP EXPLORATION REP: DANCARTER SERVICE COMPANY; WESTERN ATLAS DATE/TI M E OPERATIONS SUMMARY _ ~,: ....... =.5, .-~.-¢-, ,-_- _ ---=_ ---_ ........... 11/15/89: 0700 RU WESTERN ATLAS. WHCIP,,3500PSI, ARM GUN #1AND PULL INTO LUBRICATOR. P-TEST WITH WELl. HEAD PRESSURE. 0950 RIH GUN #1~.TWO 12 FT SELECT FIRE SECTIONS. 1 1 3 0 OPEN WELL. TO FLOW THROUGH FUEL GAS HEATER IN PLANT. TIE IN TO C@T(7/7/86) AND MAKE -23 FT CORRECTION. WHFP,,,3390 PSI. SNOOT 12 FT SELECT FIRE INTERVAL FROM t 0538-10550 FT, MISSFIRE. SHOOT 12 FT INTERVAL FROM 10512-10524. FT. SI WELL. POH, 1 4 0 0 AT SURFACE GUN #1, BOTTOM HALF WAS UNFIRED, TOP HALF FIRED, ARM GUN fl2, 1 51 5 _.RIHG._~U_N.~¢¢2, ONE 14 FT AND ONE 10 FT SELECT FIRE SECTIONS. 1 61 5 FLOW WELLTO PLANT. WHFP-,3880 PSI. TIE IN TO CBT, SHOOT 14 FT SELECT FIRE INTERVAL FROM 10470-.10484 FT, PULL UP AND SHOOT 10 FT INTERVAL FROM 10429-10439 FT, SI WELL, POH, 1 81 0 AT SURFACE GUN/f2, ALL SHOTS FIRED, RE-FIF_.AD WIRE AND CI-IANGE LUI~RJCATOR PACKOFF. ARM GUN 1 9 0 0 RIH GUN #3~_ ONE 20 FT SECTION. 2000 FLOWWELL TO PLANT, WHFP.~3880 PSI. TIE IN TO CBT. SHOOT 20 FT INTERVAL FROM. j04_09-1.04_29 F_TJ. MISSFIRE. S1 WELL AND 2 ~ 0 0 AT SURFACE GUN ¢~:3, GUN WAS UNFIRED, ARM GUN t/'4, 2230 RIH GU_N #~4., ONE 12 FT SECTION. 2320 FLOW WELL TO PLANT, WHFP,.3890 PSI, TIE IN TO CBT, SHOOT 12 FT INTERVAL FROM 10538-105,~0 FT. SI WELL. PO,H. 11/16/89:0100 AT SURFACE GUN #4. ALL SHOTS FIRED. ARM GUN #5, 01 30 RIH GUN t/5,QNE 20 FT SECTION, 0230 FLOW WELL TO PLANT. WHFP-.3890 PSI, TIE IN TO CBT. SHOO'F 20 FT INTERVAL FROM 10409-_1.0,42_:.9 FT, SI WELL, PO.H, 0 3 3 0 AT SURFACE GUN #5. ALL SHOTS FIRED. RD WESTERN ATLAS. 0 4 3 0 SECURE WEI.L PERFORATION SUMMARY: ALL PERFORATIONS WERE SHOT L/SING WESTERN ATLAS 4" CARRIER GUNS A-r' 4 SPF. DEPTHS ARE REFERENCED TO DLL(7/,~/86). 1 IN T~ n VA.t,,. ~TJ:I_..._~O~_E_ I0409-10439 FT MD BRT 30 PT 3A4 , 10470-10484 FT MD BRT 14 FT 3A4 10512-10524 FT MD gRT 12 FT 3A3 10558-10550 FT MD BRT 12FT 3A2 _ ! ~- , :....:., ,; ii:: ~i-!'.. :'" :" · .- [ ::.':,. .". :':' 7.:;,.:: ~ ;;L ::" .: i:-. '.'; ' 2 ': "i.::'::~ ': j,.-: ?: :,'. -..'} ::;]:; :.... :.¢ :,-....: .,,: .,. ;- '~,.,. , ?. - .. .. -.- . ;;..~ - ~. . i · . ~ ... .. ,:, ..... ~ · ~- . . ..i-~ :,. . '3, ~) ";'~-'.: :;' ·: ': : "., 3~/.~, ' :- f, .,:...~: ,.~...~; .. ,- : t' .': ' ~': '.~:' :~ ~;.~: ~}~ 4 [::..~::: ·: :?':;:- . ':~:;- .' ;.,:;':-.., ;;. ,:%.: ). ,.,: ,.. ,.:. ...:.?. _;-:: .. s'. ?' ,- ,t: - ,...::.',i% :;,' ~, .. ... : -... .-... I , ' - - ':'.{-' · . . .. ~UAL INDUCTION - SFL 10956' - 12090' Run No. 1 .~HLUMBERGER *REPEAT FORMATION TESTER 11330' - 11722' Run No. 1 SCHLUMBERGER '*r~sPECTRAL DENSITY DUAL SPACED NEUTRON LOG 2470'- 10961' Run No. 1 HALLIBURTON ~OMPLETION RECORD PACKER 11490' - 11800' Run No. 4 SCHLUMBERGER . I~CEMENT EVALUATION LOG (CET) 10510' - 12035' Run No. 1 LUMBERGER CEMENT BOND LOG (CBT) 10510' - 12035' Run No. 1 SCHLUMBERGER ,,WELL 1-05/O-20 INJECTION PROFILE SURVEY 10100' - 11117 Run No. 1 CAMCO t/,WELL 3-05/O-29 *PRODUCTION PROFILE LOG 11750' - 12270" Run No. 1 CAMCO . ./r~. ELL 3-33/K-37 ~*SPI'NNER TEMISERATURE 13100' - N/A HRS .~. ELL 3-47/Q-35 *ISERFORATING RECORD · 9990'- 10500' Run No. 1 SCHLUMBERGER ~**pELL 4-.46/N-39 RODUCTION LOGGING SERVICES 11600' - 12000' Run No.-1 RECEIVED Ap~REs WIRELINE SERVICES SSURE DATA GRADIENT/PBU 11650' - 11750' Run No. ATLAS WIRELINE SERVICES _ WELL 1-43/P-26 *TEMPERATURE SURVEY 12900' - 14290' Run No. 1 CAMCO WELL 1-05/O-20 *COLLAR LOG 10312' - 10670' Run No. 1 ATLAS WIRLELINE SERVICES WELL ;~-34/P-14 MPI *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 WELL 3-35/L-36 SDI *PRODUCTION PROFILE 12000' - 12350' CAMCO Run No. 1 WELL 2-:~4/P-14 MP! *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 Sincerely, Lynda I~1. Stamper LMS cc: File 06.10 WELL 3-41/K-39 *SPINNER TEMP LOG 12900'-13664' Run 1 OTIS *DIFFERENTAL TEMPERATURE LOG 12900'-13660' Run 1 HALLIBURTON WELL 4-50/K-41 *PACKER CCL-LOG 12875'-13622' Run 1 HALLIBURTON *PULSE ECHO CEMENT EVALUATION (PET) LOG 13103'-13927' Run 1 HALLIBURTON WELL 1-05/O-20 *INJECTION PROFILE LOG 10350'-11000' Run 1 CAMCO WELL 3-.33/K-37 *TEMPERATURE LOG 12700,-13280' CAMCO Run 1 WELL 3-39/J-39 *TEMPERATURE LOG 13800'- 14614' CAMCO Run 1 1092/GND BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 3, 1989 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Endicott Field Well 1-05/O-20 Additional Perforations Gentlemen' Enclosed in triplicate is Form 10-403, Application for Sundry Approvals, for the above named well. We are planning to add perforations to this gas injection well. Please contact Bill Blosser at 564-4401 if any additional information is required. Sincerely, 158JH ¢ /Manager Reservoir and Production Engineering, ~ Endicott JFO/WRB/slk Attachment xc: Working Interest Owners W. R. B!_9,,~ser J. H. L. Hb'llman R. Q. Meads Well File File 76.10 Drilling STATE OF ALASKA ~;¢ ;~ AL....,KA OIL AND GAS CONSERVATION COMMISSION ~, ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request; Abandon__ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well__ Plugging __ Time extension __ Stimulate __ Change approved program__ Pull tubing __ Variance__ Perforate X Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development__ KBE = 55.26 AMSL 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 1945' SNL, 2038' WEL, SEC. 36, T12N, R16E, UM 1-05/0-20 MPI At top of productive interval '-'~---- 9. Permit number 1961' SNL, 540' EWL, SEC. 31, T12N, R17E, UM 86-106 At effective depth 10. APl number 1989' SNL, 796 'EWL, SEC. 31, T12N, R17E, UM 50- 029-21605 At total depth 11. Field/Pool 1993' SNL, 835' EWL, SEC. 31, T12N, R17E, UM Endicott Oil Pool 12. Present well condition summary Total depth: measured 11266 feet Plugs (measured) true vertical 10395 BKB feet Effective depth: measured 11177 feet Junk (measured) true vertical 10315 BKB feet Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 90' 30" Driven 131' 131' Surface 2458" 13 3/8" 2100 c.f. Permafrost 2499" 2499" Intermediate 10347' 9 5/8" 425 c.f. Class G 10388' 9618' Production 458 c.f. Class G w/5% Liner 1504' 7" 458c. f. Class G 9756'- 11260' 9074'- 10391' Perforation depth: measured 10560'- 10668' true vertical (subsea) 9714'- 9809' .. ,... Tubing (size, grade, and measured depth) 7"26#/ft L-80 IJ4S tubing with 5 1/2"tailpipe to 9742' :/'~'~ Packers and SSSV (type and measured depth) 9 5/8" HBBP - Big Bore Packer at 9611'; 7" BVD at 1520'. 13. Attachments Description summary of proposal X Detailed operations program__ BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: November 7, 1989 16. If proposal was verbally approved Oil Gas __ Suspended __ Name of approver ~ /q Date approved Service Gas Iniector 17. I hereb/~y th~~, r~/g/~~ and correct to the best of my knowledge. , . Signed ~///~r~~~.~ " Title Manager, Reservoir & Production Engineering Date ///¢~ /, u' ' ~ y ~ .,v .... ""' - ~'/ FOR COMMISSION USE ONLY Condit/iCns ~f approval: Notify Commission so representative may witness / Approval No. ¢.~ ~',~// [ /Plug integrity__. BOP Test Location clearance Subsequent form required 10- ~'~/o~/ ~. ~.F~eturoec~ ~k.//Mechanical Integrity Test ~,,pr~roveO Original S~gned By-- / ¢/~ ~ Approved by order of the Commission f~RVi¢ W. Johnston ~ Date //-~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 BP Exploration Endicott Field Gas Injection Well 1-05/O-20 Additional Perforations Proposal We propose to perforate the following intervals in subzones 3A2, 3A3, and 3A4: 10409-10439 ft M. D. 10470-10484 ft M.D. 10512-10524 ft M.D. 10538-10550 ft M.D. A lubricator will be installed and tested to 3000 psi for all well work. 158JH BASIC SYSTEM MAKEUP BOWEN PACKOFF' HAND PUMP SEAL - ow'ru E. F'LOWLINE GREASE LINE FLOWLINE VALVE NIFOLD GREASE ~ PUMP ER .__.GREASE RESERVO. Slundard ~l~ka Production Company - 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 JUL 5, 1988 STANDARD ALASKA PRODUCTION John Boyle Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The following log information for Endicott wells is enclosed: 1-05/O-20 April 11, 1988 Run 1 thru 7 * 1 sepia and blueline print for; - Collar and Perf log Sincerely, /'i~,~ .... ~ .... <~ j~. ,.,,' Bruce St. Pierre Received by A unit af the original Standard Oil Company Fclunded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter casing [] Other [] , Name of Operator Standard Alaska Production Company Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1945' SNL, 2038' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1961' SNL, 540' EWL, SEC. 31, T12N, R17E, UM At effective depth 1989'SNL, 796'EWL, SEC. 31, T12N, R17E, UM At total depth 1993'SNL, 835'EWL, SEC. 31, T12N, R17E, UM 5. Datum elevation (DF or KB) KBE= 55.26AMSL feet 6. Unit or Property name Duck Island Unit/Endicott 7. Well number 1-05/0-20 MPI 8. Approval number 8-74 9. APl number 5 0 - 029-21605 ;10. Pool Endicott Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 9O' S u rface 2458' I nte rm ed i ate 10347' Production Liner 1504' Perforation depth: measured 11266 feet 10395 BKB feet 11151 feet 10292 BKB feet Size 30" 13-3/8" 9-5/8" Plugs (measured) Junk (measured) Cemented Driven 2100 c.f. Permafrost 425 c.f. Class G Measured depth BKB 131' 2499' 10388' 7" 458 c.f. Class G 9756'- 11260' 10560'-10668' true vertical (subsea) 9714'-9809' Tubing (size, grade and measured depth) 7"26#/ft L-80 IJ4S tubing with 5-1/2" tailpipe to 9742' True Vertical depth BKB 131' 2499' 9618' 9074'- 10391' Packers and SSSV (type and measured depth) 9-5/8" HBBP-BIG BORE PACKER at 9611'; 7" BVN at 152..0'.~ 2. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 3, Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Injection is only on a demand basis. Tubing Pressure 4. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 5. I hereby certify that the foregoing is true and correct to the best of my knowledge ;~'i'~1Sig ne~~d ~ ~ Title Workover/CompletionsSupervisor Form 10-404 Rev./~-1-85 Submit in Duplicate/ WELL 1-05/O-20 RIG WORKOVER PROGRAM SUMMARY I , Moved in rig (Doyon 15). Accepted rig at 1430 hours on 2-22- 88. , , . , , Killed well with NaCI brine. ND tree. NU and tested BOP's to 5000 psi. Pulled 3-1/2" tubing string and 7" heater string. Milled out and recovered 9-5/8" packer and tailpipe. Replaced current tubing spool with new 10,000 psi equipment. Ran and cemented 7" - 29#/ft. scab liner from 9756' - 10123'. , Cleaned out well to PBTD. . o 10. 11. Ran new 7"- 26#/ft. IJ4S tubing, 9-5/8" packer, and 5-1/2" tailpipe. Released rig at 2400 hours on 3-13-88. Installed new 7-1/16" - 10,000 psi tree. Perforated well on April 10, 1988, with 4" wireline conveyed guns. Intervals' 10,560'- 10,622' 10,622'- 10,688' 8 shots/ft. 4 shots/ft. 12. Flowed well to clean up perforations. Put well on gas injection. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover February 23, 1988 at 0600 hfs Rig: Doyon #15 Well: 1-05/0-20 MPI 0600 Depth: 11,177' Day: 2 Current Operation: RIH to perforate tubing. Accept rig on 1-05/O-20 at 1430 hours on 2/22/88. Rig up. Attempt to open sliding sleeve. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover February 24, 1988 at 0600 hfs Rig: Doyon #15 Well: 1-05/O-20 MPI '° 0600 Depth: 11,177' PBTD Day: 3 Current Operation: Nipple up BOP. Perforate tubing. Displace hole to 9.7 ppg brine. Nipple down tree. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover February 25, 1988 at 0600 hfs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' PBTD Day: 4 Current Operation: Installing adapter flange. Pull 3-1/2" tubing. Pull 7" heater string. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover February 26, 1988 at 0600 hrs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' PBTD Day: 5 Current Operation: POH. Install and test 9-5/8" packoff. RIH with spear and engage PBR. Rotate and release from packer. STANDARD ALASKA PRODUCTION Rig: Doyon #15 Daily Drilling Report -- ENDICOTT -- Workover February 29, 1988 at 0600 hfs Well: 1-05/O-20 MPI 0600 Depth: 11,177' PBTD Day: 8 Current Operation: Milling on packer. Attempt to release and retrieve PBR. STANDARD ALASKA PRODUCTION Daily Drilling Report --'ENDICOTT -- Workover March 1, 1988 at 0600 hrs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' PBTD Day: 9 Current Operation: Milling on packer. Attempt to release & retrieve PBR. STANDARD ALASKA PRODUCTION Rig: Dovon#15 l)ailv Drilling Report -- ENDIC()'I"I' -- \V{}rk(~ver March 2, 1988 at 060(} hfs Well: 1-05/0-20 MPI 0600 Depth: 11,177' PBTD Day: 10 Current Operation: R IH. Attempt to release & retrieve PBR. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 3, 1988 at 0600 hfs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' Day: 11 Current Operation: RIH with mill and washpipe. Attempt to release and retrieve PBR with string shots. No success. Attempt to release packer with string shot. No success. POH. STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT-- Workover March 4, 1988 at 0600 hrs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' PBTD Day: 12 Current Operation: RIH with mill and washpipe. Mill on packer. Trip for new mill. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 7, 1988 at 0600 hrs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,177' Day: 15 Current Operation: RIH to clean out 7" liner. Mill on packer. POH with PBR attached. RIH. Mill and push packer to 7" liner top. Trip for spear. Engage packer with spear and POH. RIH with overshot and recover tailpipe. Clean out 9-5/8" casing. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 8, 1988 at 0600 hrs Rig' Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,158' PBTD Day: 16 Current Operation: Testing casing. Clean out 7" casing. Circulate well clean. RIH with RTI'S. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 9, 1988 at 0600 hfs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,158' PBTD Day: 17 Current Operation: RIH with polishing mill. Test 7" liner lap and 9-5/8" casing; lost pressure. POH. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 10, 1988 at 0600 hours Rig: Doyon #15 Well: 1-05/0-20 MPI 0600 Depth: 11,158' PBTD Day: 18 Current Operation: RIH to clean out cement. Polish tieback sleeve with mill. Run and cement 7'° scab liner. New 7" liner top at 9756'. POH. STkND~ ~LASK~ PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March I1, 1988 at 0600 hours Rig: Doyon #15 Well: 1-05/0-20 MPI 0600 Depth: 11,151' PBTD Day: 19 Current Operation: POH. Clean cement from liner. Circulate and condition brine. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT -- Workover March 14, 1988 at 0600 hrs Rig: Doyon #15 Well: 1-05/O-20 MPI 0600 Depth: 11,151' PBTD Day: 22 Current Operation: Released rig. Run 9-5/8" casing scraper, gauge ring and junk basket. Run and land 7" tubing. Nipple up tree and test valves to 7500 psi - OK. Test annulus to 2000 psi - OK. Test tubing to 3000 psi - OK. Displace well to diesel. Released rig from well 1-05/O-20 at 2400 hours on 3/13/88. MAR 18, 1988 STANDARD John Boy] e Alaska Oil and Gas Conserva[ion Commissio~ 3001 Porcupine Drive ^nchorage, ^laska 99501 Dear Hr. Boyle: The follouing log information for Endicott x,,,ells Js e~closed: 1 sepia and blueline print for; 1-05/0-20 R~n 1 Feb. 23, 1988 * CCL Perf Record ?XDa t e .. Sincerely, Bruce St. Pierre , ; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing . Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Amend order [] Perforate [~: Other [] 5. Datum elevation (DF or KB) KBE = 55.26 AMSL feet 6. Unit or Property name Duck Island Unit/Endicott 7. Well number 1-05/0-20 MPI 8. Permit number 9. APl number 5 0 - 029-21605 10. Pool Endicott Oil Pool Name of Operator Standard Alaska Production Company Address P. 0. Box 196612, Anchora~le, Alaska 99519-6612 Location of well at surface 1945' SNL, 2038' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1961'SNL, 540'EWL, SEC. 31, T12N, R17E, UM At effective depth 1989'SNL, 796 'EWL, SEC. 31, T12N, R17E, UM At total depth 1993'SNL, 835'EWL, SEC. 31, T12N, R17E, UM 1. Present well condition summary Total depth: measured 11266 feet Plugs (measured) true vertical 10395BKB feet Effective depth: measured 11177 feet Junk (measured) true vertical 10315BKB feet Casing Length Size Cemented Measured depth True Vertical depth Structural BKB BKB Conductor 90' 30" DRIVEN 131' 131' Surface 2458" 13 3/8" 2100 c.f. Permafrost 2499" 2499" Intermediate 5436' 9 5/8" 425 c.f. Class G+.75% 5477' 5434' Production 4911' 95/8" 458c. f. Class G w/.5% 10388' 9618' Liner 1137" 7" Ha/ad344+LWL 10585'-11260' _9,?,q~'-¢~391' Perforation depth: measured 10622'-10668' ~ ~. ~ ~ true vertical (subsea) 9768'- 9809' Tubing (size, grade and measured depth) 3 1/2" 9.3,¢ L-80 TDS tubing with 2 7/8" tailpipe to 10182' GaS Cof~s, Packers and SSSV (type and measured depth) 9 5/8" TIW Packer at 100717 3 1/2" SSSV with flow couplings at 1506' Description summary of proposal [~ Detailed operations program [] BOP sketch .13. 2. Attachments 3. Estimated date for commencing operation February 1988 Date approved 4. If proposal was verbally approved Name of approver and correct to the best of my knowledge Title Completion/Workover Supervisor Commission Use Only 15. I hereby~ertify that the fo, r,~ego~ing is,true Notify commission so representative may witness IApproval No. [] Location clearance I by order of Commissioner the commission Date ~/i-'~ Submit in triplicate Conditions of approval [] Plug integrity )~" BOP Test .~-. :~-'!~.~ i:-~'~ ' .-' ~.: i "~' '"'--' ".'~'."~" Approved by Form 10-403 Rev 12-1-85 WELL 1-05/O-20 RIG WORKOVER PROGRAM OUTLINE . Kill well with NaCI brine. Use sized salt pill if necessary. . Move in rig (Doyon 15). Rig up and test BOP's. , Pull 3 1/2" tubing string and 7" heater string. . Mill out and recover 9 5/8" packer and tailpipe. Circulate and condition brine. . Replace current tubing spool with new 10,000 psi equipment. . Run new 7"- 26#/ft. IJ4S tubing, 9 5/8" packer, and 5 1/2" tailpipe. . Install new 6"- 10,000 psi tree., . Release rig. . Perforate well with 4" wireline conveyed guns. 10. Intervals: 10,560' - 10,622' 10,622' - 10,688' Flow well to clean up perforations. Put well on gas injection. B.O.P. STACK CONFIGURATION 1:3-518 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER Z IN. KILL LINE GATE GATE I I PIPE RAMS I 1 RAHS I I DRILLING SPOOL ] I [ RAMS 4 IN. CHOKE LINE GATE GATE Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 ~907~ 561-5111 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells April 3, 1987 Dear Mr. Smith, ~v"((( ~tlc3 ' We are requesting that the AOGCC adopt dual designation for all STANDARD ALASKA PRODUCTI , ,,'~. :-. I ', ? m ,-- ;. 7<.. ~.- ........... · .. -. future " well names in the Duck Island/Endicott Unit for operational and safety reasons. Dual designation lists the numeric surface location followed by an alpha-numeric bottom hole location. This will be indicated in future wells on Form 10-401 in Item Number 8. We also ask that wells drilled to date be referenced by this dual designation. For your use is a list of wells drilled to date. WELL NAME PERMIT NUMBER API NUMBER 1-5/o-20 (~i) 1-27/P-20 (MPI) 1-29/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 (SDI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/L-36 (SDI) 3-47/Q-35 (SDI) 4-s/p-~? (SDZ) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) ~u . ~ ~ ~l~nit of the originoJ Standard Oii Company ~ O~f f Founded in Cle,,e ond. Ohio, in 1870. 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 We thank you for your assistance and should you have any questions, give me a call at 564-5007. Yours very truly, R. S. Allan Division Drilling Engineer RSA/MAW/pm/1664D cc: R. H. Reiley_ s. L. Rose. , J. O. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development Standard A!aska Production Company~ 900 East Renson Boul J P.O. Box i96612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALA$ PI C)DUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. C. V, C~atterton September 5, 1986 Well 0-20 (MPI) Gentlemen' Enclosed in duplicate, is Form 10-404, Report of for t~e above-named well. T~is contains our perforating and production testing the well. If you have any questions, please contact S' Sundry Well Operations subsequent report of R. Bundy at 564-5226. Very truly yours, RSA pm/1 Enclosures 132D CC' R. H. Reiley B. Ross Drilling Well File #17 Working Interest Owners (4) R. S, Allan Division Drilling Engineer A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALAt .A OIL AND GAS CONSERVATION COt,', "ISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [~' Pull tubing [] Alter Casing [] Other ~ Production Test 2. N~¢aen~farO~e~a~rSka Production Company 3. Address P. O. Box 196612,. Anchorage, Alaska 99519-6612 4. Location of well at surface 1945' SNL, 2038' HEL, Sec. 36, T12N, R16E, UM At top of productive interval 1961' SNL, 540' EHL, Sec. 31, T12N, R17E, UM At effective depth 1989' SNL, 796' El, iL, Sec. 31, T12N, R17E, UM At total depth ]993' SNL, 835' EHL, Sec. 3], T]2N, R]7E, UH 11. Present well condition summary Total depth: 5. Datum elevation(DF or KB) KBE = 55.26 AHSL Feet 6. Unit or Property name Duck Island Unit/Endicott M 7. Well number 0-20 (MPI) 8. Approval number 320 9. APl number 50-- 029-21605 10. Pool Endicott Oi 1 Pool measured 11266 true vertical 10395 feet Plugs (measured) feet Bridge Plug 2523' Effective depth: measured ] 1177 true vertical 10315 feet Junk (measured) feet Casing Length Size Structural 90 ' 30" Conductor 2458' ] 3-3/8" Surface 5436' 9-5/8" Intermediate 4911 ' 9-5/8" Production 1135' 7" Liner Perforation depth: measured Cemented Measured depth Driven 131 ' 2100 c.f. Permafrost 2499' 425 c.f. Class (;+.75% 5477' CFR-2+. 15%HR7 10388' 458 c.f. Class G w/.5% Halad 344 + LNL 11258' 0668'MD BKB . True Vertical depth 131' 2499' 5434' 9618' 10386' true vertical 9768'-9809' TVDss Tubing (size, grade and measured depth) 3-1/2" 9.3# L-80 TDS tubing @ 10055' .... ~:"~ ;-'~:' 'r"~ ~'~': ~,',:~ !:.~:~i.' · '. Packers and SSSV (type and measured depth) 9-5/8" TIN PaCkP. r at: 16)F)71"- q,-l/2" c,q~V with flow couplings at !506' 12, Stimulation or cement Squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation See Attachment 14. Attachments He l I test data Daily Report of Well Operations [~ Copies of Logs and Surveys Run L~/ 15. I hereby certify that the foregOing is true and correct to the best of my knowledge :orm 10-404 Rev. 12-1-85 Title Division Drilling Engineer . Submit t'e 4_-- A P P E N D I X I I I ENDICOTT FIELD 0-20 WELL TEST DIARY OF EVENTS FOR 0-20 WELL TEST 8-2-86 14:50 'Lines are pressured up. Run in hole with CCL/perf gun. 16:10 CCL not reading collars, therfo~e come back up hole wi th gun. 19':00 Run in h(~le with CCL/perf gun. 21:.00 Perforated interval 10622-10645 .M.D. (9768-9789 TVDSS) The well was perforated underbalanced using a strip charge gun, 4 SPF, zero-degree phasing, and zero degree orientation. 22:45 Run in hole with second CCL/perf gun. 8-3-86 00:30 Perforated interval 10646-10668 M.D. (9790-9808 TVDSS), followed by five minute flow period. 03:20 Run in hole with CCL/GR/HP/TEMP-tool and three max · reading thermometers. 04:35 Begin monitoring pressure at 10545 M.D. (9700 TVDSS) P=4805 psia T=204 F 05:35 Begin monitoring pressure at 10656 M.D. (9800 TVDSS) P=4854 psia T=208 F 06:03 Begin monitoring pressure'at 10718 M.D. (9855 TVDSS) P-4880 psia T-208 F 06:29 Begin monitoring pressure 'at 10656 M.D. (9800 TVDSS) P-4854 psia T-204 F 07:27 Reach TD of 111'53 M.D. -HP computer fails. 07:45 Begin to run out of hole and HP computer begins .to operate again. Monitor pressure at 11148 M.D. P-5068 psia T=216 F 08:05 Run out of hole. Max reading thermometers: #1-217 F #2=218 F #3-218 F 09:00 Rig down Schlumberger unit. 10:31 Open up well at 14/64 choke. 11:30 Choke to 12/64 and flow to separators. 12:05 Choke to 10/64. 12:30 Choke to 12/64. 13:05 Choke to 11/64. 13:22 Choke to 10/64. 16:10 Well shut in due to a leak in the flow line. End of flow period #1. Gas Rate=1070 MSCFPD FWHP=3239 psig 18:20 Open well at 5/64 choke. 18:25 Choke to 6/64. Page 1 18:35 Choke to 9/64. 18:55 Choke to 16/64. 19:02 Choke to 17/64. t9:09 Choke. to 14/64. 1-9:19 Choke to 15/64. 8-4 -86 03:10 Beg~n samplin9. 03:~5 Finish sampling. 04:00 End of flow period #2. Gas Rate=3500 MSCFPD FWHP=3246 psig. Oil Rate-ll8 STB/D GOR=29700 SCF/STB Main Separator Pressure/Temperature-- 520 psig/ll0 F Oil Gravity-48.2-API .@ 60 F Gas Gravity=.802 05:00 Choke to 16/64. 05:34 Choke to 17/64. 05:36 Choke to 18/64. 05:40 'Choke to 18.5/64. 10:40 Begin sampling-. 11:20 Finish sampling. 12:00 End of flow period #3. _ ~Ga$ Rate-5400 MsCFPD FWHP=3335 psig Oil Rate-190 STB/D ._GOR-28400 SCF/STB Main Separator Pressure/Temperature- 780 psig/107 F Oil Gravity-49 API@ 70 F Gas Gravity=.8 12:20 Choke to 19/64. 13:15 Rate drops down and choke begins to plug. Begin pumping methanol into system. 13:45 Rate remains low and choke remains plugged. Shut in well and examine flow line. Pebbles found in choke. 15:00 Open well with-choke of 21/64. 20:10 Begin sampling. 20:45 Finish sampling. 21:00 End of- flow period #4. Gas Rate-8300 MSCFPD FWHP=3360 psig Oil Rate-276 STB/D GOR=30100 SCF/STB Main Separator Pressure/Temperature= 840 psig/106 F Oil Gravity-48.8 API@ 64 F Gas Gravity=.804 21:01 Choke to 20/64. 21:03 Choke to 19/64. 21:04 Choke to 18/64. 21:08 Choke to 17/64. Page 2 21:12 24:00 8-5-86 _ 03:20 03:'55 04:00 04:02 Choke to 16/64. End of flow period 1~5. (Sas Rate=4000 ~ISCFPD FWHP=3392 Oil Rate=130 STBPD GOR=30800 psi9 SCF/STB Begin sampling. Finish sampling. End of flow period #6. Gas Rate=5100 MsCFpD FWHP=3381 psi9 Oil Rate=175 STB/D GOR=29100 SCF/STB Main Separator Pressure/Temperature= 825 psig/ll7 Oil Gravity=47.5 API@ 60 F Gas Gravity=.8 Shut in well.- PRESSURE/RATE ANALYSIS Pressures and rates Were monitored in order to estimate the potential absolute open flow of the well. The pressure at the reservoir (9800 TVDSS) is 4854 psia. Contrary to expectations, the flowing wellhead pressure increased with increasing rate during the first four rates. This may have been due to fluid buildup in the wellbore and/or continued cleaning of the perforations. The final two rates (4000, 5100 MSCFPD), which were-a decrease from the previous rate (8300 MSCFPD), did yield a higher pressure with a decreasing rate. The increase _in pressure was very small though. The data are tabulated below: P q pR2-p2 (pR2-p2)/q Prod Index (psia) (MSCF/D) (psia2 6 ' xl0 ) (psia2/MSCF) (MSCF/day/psi) 3254 1300 12.969 9977 0.81 3261 3500 12.924 3693 2.19 3350 5400 12.336 2284 3.59 3375 8300 12.168 1466 5.61 3403 4000 11.981 2995 2.76 3396 5100 12.026 2358 3.50 Page 3 2 2 A plot of {(P reservoir - FWHP )/q versus q} yields a negatively sloping curve. An average gas well is expected to yield a.~straight line with a positive slope when these values are plotted. Plotting (pressure versus Flowrate} for the last three rates results in a straight line with a negative slope, Which is as expected. Extra'polating the line to a FWHP of 3000 psig y-ields a flow ra'te estimate of 56 MMSCFPD. SAMPLE LISTING No sampling was performed at the first flow rate (q=1300 MSCFPD) because the separator had not been fully cleansed by the flowing fluid. Samples were taken at the second flow rate (q-3500 MSCFPD), but the samples were discarded because it was later determined that the separator was still not clean enough for a sample representative of the reservoir. At 10:40 on 8/4/86 a one-liter separator liquid sample was taken in Welker sampler #9999 for flow rate #3 (q=5400 MSCFPD). Three three-gallon samples of separator gas were then collected (#966933D, #966934D, #258656D). These samples were sent to Warrensville for constant volume depletion analysis. At 20:10 on 8/4/86 a one- liter separator liquid sample was taken in Welker sampler #10001 for flow rate #4 (q=8300 MSCFPD). Three three-gallon samples of separator gas were then collected (#966929D, #966935D, #966950D). These s~mples were also sent to Warrensville for constant volume depletion analysis. A't 03:20 on 8/5/86 three one-half liter separator liquid samples were taken in Welker samplers #4153, #4154, and #4156. The flow rate was 51.00 MSCFPD. Three three-gallon samples of separator gas were then collected (#634090, #966940D, #966943D). These samples were also sent to Warrensville for constant volume depletion analysis. CONCLUSIONS Well 0-20 was perforated in zone 3A of the Kek'iktuk in order to deliver fuel gas for drilling rigs and future facilities on the MPI. Throughout the test the gas specific gravity approximated 0.80 and the condensate gravity was 48.2 API at 60 F. These gravities resemble data obtained from other Endicott wells. Page 4 An anomaly seen during the first four flow rates of the test was an increasing flowiag wellhead pressure with increasing flow gat'e. This may have been due to continued cleaning of the perforations. The final three flow rates did show increasing flowing wellhead pressure with decreasing rate, which is as expected. The increase in pressure (28 psi) was small though, and occurred over a significant change in rate (4300 MSCF/day).. The small pressure drop, even at high,rates, and an increasing productivity index with increasing rate show the good deliverability of this well. A constant rate of 8.3 MMSCF/day was maintained at a pressure of 3360 psig. From an extrapolation of the last three rates, the well could produce 56 MMSCF/day at a flowing wellhead pressure of 3000 psig. Due to the pressure data inconsistency and mechanical problems (pebbles in choke), the pressure plots cannot be interpreted with high confidence. The gas/oil ratio approximated 30000 SCF/STB for all flow rates. If 5 MMSCF are produced per day, 167 STB of condensate would be produced. This converts to production of 33 STB of condensate for every MMSCF of gas and requires a 0.12 STB/minute injection rate into well M-19. Page 5 S.TANDARD ALASKA PRODUCTION COMPANY ENDICOTT WELL TESTING PROGRAM SUMMER SEASON 1-986 WELL 0-20 (GAS SUPPLY/INJECTION WELL) PERFORATE THE FOLLOWING INTERVAL: 10622-10668 M.D. ([ef. CNL/LDT 7-4-86) 9768-9809 TVDSS TEST OBJECTIVES 1. Fluid/gas samples will be taken for PVT and compositional characterization of the reservoir. Separator samples will be taken from this test, but no bottomhole samples will be taken. 2. A normal 3 point backpressure test will be performed on the well at rates of 1, 3 and 5 MMSCF/D, in order to calculate the AOF of the well. WELL TESTING PROGRAM Rig up for testing. Pressure-test well. Perforate the interval specified above. Flow well for 5 minutes, then shut in. Retrieve guns. Run in hole with CCL/GR/HP/TEMP. tool with 2 max readin.~ thermometers. Monitor the static bott0mhole pressure a't 10545, 10656, and 10718 M.D. for 30 minutes in each position. Hang the tool at 10656 M.D. and monitor the pressure for at least one hour. obtain shut in bottom ~ole pressure. Tag T.D. Pull up 5 feet and monitor 'pressure for 15 minutes. Retrieve tools fr-om we.ll. Compare max 'reading thermometers with bottomhole temperatures. Bring the well on at a reduced choke. Adjust rate to approximately 1 MMSCF/D, and stabilize the well. Ensure that wellhead, pressure and temperatures are monitored while flowing the well. · After stabilizing the well at the iow flow rate and monitoring wellhead pressure, open the well and stabilize at flow rates of 3 MMSCF/D and 5 MMSCF/D. Surface samples o.f condensate and gas are required from the gas wells, but no bottomhole samples will be taken. Rig down, move off well. ri(.( |.l!|ll[:l||||:::|| II*|||l:l|l|:ll||l| WELL # 0- 20 C0hdPIETION OETnlL fill OEPTtlS rifle I'dEflSUFIEO FF{O~ 1iii flOTflRY TflOLE 1506' 3 1 /2' SSSV ¥1TH FLO¥ COUPLINGS 13 3/O' ¢tlSING SII0[ __10055', 1005§' 0057' i l~lO0?l' --100761lllI ~ 34el '--~7 - 26 ' IJ45 HEATER STRING J '-" '! ~ ~z~-' ~-~ ' ~-~o ~s 0001 ' Jt 3 I /21 SLIDING SLEEVE J i ~.,.~.'-.o-oo ~oc~o. i l [HILL-OUT EXTENSIOH l IXO 3 I/2'TDS BOX x 2 7/8' 8 END. PIN J 10082'_ [ _ ~lOIl:i', [2 7/e- X NIPPLEJ 7" LINER HUNG@ 10123' I0148' {2 7/8' X NIPPLEI ~|!2 7/8' 8 RND. TUB lNG ] 10182' {2 7/0-YIRELINE GMIDE } 9:~/0" CSG. SHOE ]0387' ::::::::::::::::::::::::::::: ============================= 7" LINER $110E II260' g, t i 'f ,t,"" V/ell Fl~re ¢ Wel[he~J. · 4000 ...... 32OO 2400 1600 8OO 0 0 WELL-HEAD PRESSURE ENDICOTT WELL TEST (0-20) OIL FLOW RATE -- · , . GAS FLOW RATE BARRELS/DAY ~4SCF/DAY ~0000 8000 6000 4000 2000 0 3 AUG. 2 10' O0 DAYS AUG. 5 lO' O0 l'O'1'1'I'/% T.I,:$'i' i;¥s'r[~l~IS. IIMIC. UlLLS ',%"YO~,~hNG. US A 82~>44. T E S T O A T A S H E E T WELL No. 0-20 STATE_ .4T.A,$JCA DATEAIIP. II.qT ?~ I 986 . , ,HIGH sTAG-'~ ORIFICE & M~TEh RUN SIZE 1'. b0x2. 904 'LOW STAGE ORIFICE & METERRUN SIZE 1..500 X 2" ~'06,1 ...... !iT No .......... ~ ...... JOB NO. 5'~1 FLOWING: TUBING ~ H~S. METER$1ZE I5OO~ X 1OD" ' CALIBRATED~~ HRS.~ , ANNULUS ~ , ' L.S. METER'SIZE ...... ~OO~ X 10~~ ~LIB~TED~ ~HRS._ ..... j{ WELLHEAD READINGS HEATER", HIGH sTAGE SE~A~ATOR RE~DINGS ' ;"' " '" ' .... "' ........ ~ , , ' ' "" " ,, , . , , ,LgWST~ES~"A~ATO""EA~*NGS" ' ~B C"O~ ~LOW TUm. O ~N~ULUS ~T. ' STaTiC P"~SS. .} ~... SE". r[0W STATIC M.~, SE". ' ' ~LOW ~ T'EMP ' DIFF., DIFF. TiME SIZE TEMP, PRESS. ,PRESS, TEMP. ' 'DEAD ~. ' METER TEMP, TEMP ,R~TE PRESS. TEMP. TEMP ~TE L , ..... ~ .,, ~ ' ,.' -~. ;s,~ ~,p .~ p~,~ ~ "] =~.. .~ ' 'F , , , i ,,,, : ~ ..... , ~ .. ...... ~-;'T~,,'. ...... ~', .... ..... J~" ~' ..... 2~ ...... , ~s~c~ts,, . ,~ .~, ~ ~s~,,, ........ ~s~S~a- ~'~s ~u~g . 1:05 i~ .... ~-~ .... 1248, INJECT MET~OL Ta ~PLUO } ......... 1260 .... ~}.~.}'~'~'[."'' .... ~ .......... C ...... 1252 ..... ,,,. ~ .... . ..... ' "' "' ~", ...... ...... ::. _1 ..... .......... ,, - '" '~ - ....... . g i ~ - '2:45 ~, ;' ; ~ OOI~ I~ HOL~~ ~ITH SECOND --~ .... ~ ..... ~ ........... & ............. ............... ~ ......... ~ .................... ~ ............ , .... ~...3_;. [ 5._ ~. .. ~j. .[_ _ ~. Z.3_8_ . ............. ) 3 · 30 t~ :'. 123.8 ............ ~ ' 't ~ t ................................ Z 3..:.Ai j ..... '~ ,. ' .. ~2 3.7_ .................... , ........ . ................... , .. i ....... ~ ......... ~ ..... ,, ~ "-t ...... t ..................... 9 ........ T ....... t .......... ...... j .... ~ ............................... ..~ ~- -; ...... . .............. · . ~ -t ~ ...... " ~ ~ J ' ; ...~ '~ .- _~ ............................. . ...... ........... , ...... ~ ~ .~ ..... .. . ............ .. ~,, ...... ~ ~ .............. )' _ ............. ' i ~ '~ ................. ..................... ~ ................. . ..... SHE .2 .. ... ,, o ~o, s~ cOmPANY ~LLS '~,WOMING, USA ~ , ,, :' : TEST DATA SHEET WELLNO.; 0-20 STATE ~AS~ : DATE 'AUGUST 3. 1986_ HIGH ST,~GE ORII~ICE &M'ETERRUN siZE[' ]..'0'0 X. ~ 004 ~.LOW.STAGE ORII~IC£ & MI~TER'R~J~I SIZE' ANNULUS D.. L.S. METERSIZE [500~ ~ X [00't .... CALIBRATED~~HRS. W~LLHEAO RE~OINGS 'HEATER ...... ' ' "' HI~ sTA~',E,$EpA'~TOR READINGS' " ,, ,, LOW STAGE sEpARATOR READINGS .... :-=Ii '~ c,o~ ,~o~ ~'u,,~,,,ULUS,,'t" .... ST,r,C,,~S'S.0~"~. M.~.' S~,.' '" ~LOw .STATIC ~.~. S~,. ",LO~' ' ~{ TE~p ~" DIFF. SIZE TEMP. PRESS.' PRESS. TEMP. DEAD ~, METER ' , TEMP, TEMP RATE PRESS. TEMP. TEMP ~TE i[ IN ...... PSIG mlG "' . IN.' 'F ~F .... ~F "" MCF~' , , , . " - - tl , . . .~..~_ . .... ~ · ~.. ', ; ~ , ,, , , . )~ ~ ~.7.. ~ .. ~ ...................... ,.12~0_. _ P~F(.~E ~ND~ SET ...... , ~.~.2..~:. . .~ ..... ~___~..~ ~_ __ s~u~ z, ~ ............ )o:~5 :: .; ~ ~ ~f.. , 5-i":"~'0":] ~s ~', _.~ .... ~ ...... z.z~.~_~'-"' ........ " ....... ............ ~ .......... ~ ................. , , , , ~ ....... )1:~5 ',, ~ , ; 1310 '" ' ' . ~-;'~'~'~ E .......... '-~ .......... t. '-'~3'0'7- ' · : ;~ "' '" "' ~~; ....... ~. ...... ~ ...... ~ .... ~.~ ................ ~,..___ , ~;';'~-~' ....... 'i ..... --'~ : 'R'S~6- ........ : ....... ' ........... ' ;~;"~¢~ .......... 7 ............ 7 ......... ~ .... ~7-" :-'- ......... , " ....... T ...... 1 .......... ~ .... ~ ..... ' ' .......... )_~. :..~i.~ ......... ~ ', '&35Z ....... 35:00 ~ ~ i ; 1358 ~3-~-~ ......... C .- _t_ ...... ~-]].g-~ ~ .......... o 4 ~ 13 _ ~_;__5..~ ] ............. ~ ..... 7~ ................. .............. h ............. ..... o~:4~ ~ : ~ ~ ~4oo ~~, ....... ~ ...... ~ .......... yin- - 0 7 :~~ ...... ~ ........... 14AS_ ..... 07 ;DO_ ..... ~ .... ~ 27 ......... 07:45 ......... ~iQ .... Q~0 ........ 1437 ....... O&~!5 .g.444 08:30 ~ 1445 . . ..... ,.o,,-r^ ~-.,.:~.,. ~¥~-r~$. ,,~c. COMPANY ,o so,+~ COMPANY STANDARD ALASKA PRODUCTION ' E S T O A TA S H E E T WELLNo. 0-20 , , STATE~,AT,AM~ DATE AUGUST 3, ~986 ~ HIGH ~T.~-(~--0RIFICE & MELTER RuN size1 .... w'~ . 'Low ST~ ~"iF,~E'~ ~'~ fi'b~' ~,Z~ ' ~ 50X2. .... 00 ~ 90~ ........... HEET No ..... ~. ......... JOB No.. 541 FLOWING: TUBING. ~ H.S. METERSIZE 1500~ x 100" CALIBRATED~~ HRS.~ ANNULUS ~ t.S. METER SIZ~ [500~ X 1~0~' CALIB~TED ~ ~ HRS. ,, .....~ '" ,, , , , , -,~ .... : , ,, ,, , .., , , ,: ..... 'WE'~LH~A'O READING~ HEAT[~ HIGH STAGE ..... SEPARATOR READINGS .... j LOW STAGE SEPARATOR READINGS .... [~ AM8 '"CHO~ FLOW TUBING ANNulUs BATH STATIC PRESS. ~ M.R. ~P. '"' FLOW STATIC M.,' 'S~P.' FLOW T~.~E ~ TE MP S~ZE TEMP. PRESS. PRESS. TEMP. DEAD ~. METER DIFF. DIFF. TEMP. ~EMP ~TE PRESS. TEMP. TEMP .... _ . . . ff o ...... ~ F ,~' '~ ~ Ps~ .... ,s,~ .~ Ps,~ ' '~i~ ' ,N. '~ 'F ~cF,o ,s,~ ,N. '~ 'F MMC~ ='~~[ ....... ..... 1 ' ' .... ~J 'i43'3,' .... -60 : '~ ,' ......... , "6~'~-'~'--T6-'] '= ....... ] ..... 145S '6d--',' ~" ' , ' '. ',.,.. , ,,"' . ,: : , .... '~"~[~ ............ ~ ............. -" SHUT :IN ~ST ;R 'To' ],Ig' OuT ~I'ELI} E ' .....JJJ it~l'i$!i- .... JZ .......... ~f]., ~, ~]' '~' ~o ' "< , ,] ..... e~s.~ .~ ~" ~ , 10:27 [{ JJ m [484 60 ' ~{_. .. ' '~P~S} U~ UL10 CRCKE :,')'=5.~'_, ......... i./'/'; f';'~Y'2~'"2.~.~_~ · _ ~' ...,. ' . ' .... . .. .". " _z._o_=~.~ ........... ~_ ~.l~__ ~ .... . ..... . .... -l~.~.~ ................. J __*~_.~._~_= ~.o. . : .. ...... _zo=zs_~___ ~ ......... ;..~o.. ~.-,~s..9- -6o .............. [0:3~ ~ ......... ~ ..... .~_0...L._~$.[ .... _60 _. . L. ~'3~=~.,_.___~ ................. ~_o .... ~___~.7_ ....... ~ ......... .. .... " . . _.z~,.~_~.--__.~ ................ ~s_..~_ ~.~ ___ ~n .... ~ ............. zo.,s.~_.~_ "J ........... _~ ..... ~ ..... ~.~..~s_ . ~6 ............ - ........... &g.~o ] ~ _~_~_.4 .... ~z~ ~o_ ............ ~0'~.~.~ _] 8~ ! ~s22 70 ' . .......... ~o:so ~ ' .............. ~' -j 'T~'~: ~o .......... ~;'~l LT. 7.~__;~_~_.]'~~. 70,; -- -.. ' ' ~: OD ~. ~ ............... 8~ ..... ~.5 ?o _ _LL~05 ............... ~_~_~.6~ _ .7o . &L:10 '. ................... 86 .... '_~gA~_ Tfl . . i ~:20 i ................... 3~_._ 2~8 .... 70 .... t~:25 ~ 85 2250 70 ~0~____; 8s, 2390 70 . .. ~!;45 _ 8~ 2750 70 .... . I !~:3~ ___ 74___~00 70 ~R0 480 6 ~ 115 .290 150 /, 64 1~34 _ . 12/64 I~C~ASE CHOKE . . · ~A~'~S: ..... GAS GRAVITY 0. 782 r'ol<'rA-l'.l.j$'i' ~,Y.e, TI;I~I$. Il.lC. ;~ 0 90~,~ 522 ~.~II.L$ ~,¥¥O~"',~G USA 8.26.~,~ COMPANY STANDARD ALASKA PRODUCTION COMPANY T E S T D A T A S H'E E T WELL No. 0-20 STATE ALASKA, DATE AUGUST 3 ~ 1986 HEET No, 4 JOB NO. 541 FLOWING: TUBING {~ H.S. METERSIZE ' 1500# x 100" ............... CALIBRATED @ __ HRS. ., ANNULUS 'El L.S. METER SIZE 1500# X 100f, CALIBRATED ~ __ HRS. , · ' .......... ' WELLHEAD REAoII~G$ ........... HEATER', ' ' ..... ~"'HIGH'STAGE SEPARATOR READINGS, ...... , , LOW STAGE SEPARATOR REA~II~G'S "' J{ AHI3 -- CHOKE FLOW TUBING ANNOLUS BATH , ~TATIC PRESS. M.R. SEP. FLOW STAT'lC M.R. SEP. FLOW T~'MP DIFF. DIFF. T~M£ S~ZE TEMP. PRESS. PRESS. TEMP. DEAD W~. METER TEMP. TEMP RATE PRESS. TEMP. TEMP RATE °F IN, *F PSIG PSIG *F PSIG PSIG , IN. *F °F MMCFID 'PSIG IN. 'F °F MMCFfO . _13':.00 .... 4_ 0 12/64 78. _, 30.37. ,7..0__. 180 .... 500 0-,'?~ ..... {3'~i 114, S0.. 70 72 74 . _8.~. 13:05 11/64 13:21 10/6~ 13:3b ..................... .82- 3179. --'~0 1'..8.0 . ' .. $00 61.'8 _ 137 '124 .958 !80 11 94 __,94 .,599_.7_ 14:00 3_9___ 79 3192 7__0 .... 182 500 5.5, 134 126 .860 ,.. 180 1.8, 94 94 .755 14:05 __SW_.I_IC__H___F_RO_M 2" TURN ME~_E_~ TO 1" TURN I[ETER 14:30 78 3226 70 180 500. 64 137. 130 .940 180 24 98 102 15:00 3'8 78 ._12~....4_.__7_0. 172 500 [. 67 135 132 .965 180 25 98 102 _865 _16.: Q0_ __3.7 19 .. L_3239 70 17& ~o~ 89_ !3& ~ ~9 ! mT ~ ~a 33 98 102 1.00 16:10 ~ . ._O,.0/_64 ...... SHU~ IN WEL; TO RE'AIR .... LIAK IN ]~'LO~rLiN~ CHANGg TO 1 750 X ' 904--' O] IFICE, CLEAN OUT D,P, CELL 3~_~_20 ............. '_._33,25_ 7o ........... 18-' OD 37 ..... 3343 70 .... , . ._t~._ZS_ .............. -33f7: 70 .... . 3357 To. ,, 18:22 I 5_J64 OPE~ TO TEST 'UNIT , 18;_2 t_ .,5_.Z 6 4 _ ._~.1_ ' .3=~._0__ _ 7 0 .1_~;_2,_4__ 5.l .... ~ 315_2,_. 70 , _L8~.25 ........ 6L64__.51._ 3334 70 ~ ,, .L~:26 .................. 5.1--. _3355 . 7_0' , ......... 18:27 51 3355 70 18:28 51 3355 70 t " ~8:29 7/64 51 3355 70 ,, 1.8: 30 _87 64 _ 5_.__2_ ...... r.__'_3.3__5_,6_ _ 70 _ -. 18.____.~: 35 __~. 9/64 49__ 335 7~0 ..... _ 18: 4 o_ ......... 9. / 64 ..... 42_ ..... 3_3_5_f_ .... lO_ ........... 18:42 . .12/64 ......... .1.~_8; 45 12/6/4 46 .... 73347 ...... -~'6- ......... }_8:52 15/64 ........ , ...... , 'z~a.s-_ GP~AVITY '= 0.7821 DOW'LAND BACH D.P. CELL PLUGGED rEsT DATA SHEET COMPANY STANDA][D ALASKA PRODUCTION COMPANY WELL No. 0-20 STATE ALASKA ., DATE AUGUST 3~ 19~6 ~ · ;~:s _.. 19 00 - 2.250 PLATE IN SECONDARY SEPARATOR ' HIGH STAGE' ~)RIF!~E"[ ME...TER RUN SIZE~ ~'].~ ~5'0X2.90,4' ' LOW STAGE 'O'l~i'~i~E,,& METER 'RUN s,.z.E' t i'1~0x~II 9104 ........... NEET No. 5 JOB NO. _ 541 FLOWING: TUBING J~ H.s. METERSIZE [500~ X ~ 100I' CALIBRATED@-- HRS ..... ANNULUS E] L.S. METER SIZE 1500# x 100t~ CALIB~TED ~ ~. HRS. , , ' WELEHEAD'READINbS HEATER : H'ldH STAGE s~A'~T~0R 'READINGS · LOW STAGE SEPARATOR READINGS ........ , .... , A~B. CHO~ FLOW TUBING ANNULUS BATH STATIC P~ESS. M.~. SEP. FLOW STATIC M.R. SEP. 'FLOW' TE ~P ~EAD ~. METER OIFF, DIFF. ~>~ME SIZE TEMP. PRESS. PRESS. TEMP. TEMP, T~MP ~E PRESS. TEMP. TEMP ~ oF IN. ' ''F PSlG pSIG *F PSIG ' ~IG ' IN. ~F ' ' ~F MMCF~' ~IG iN. ~ ~F MMCF~' ', ~ , ,~ ....... ., . ..... ..,_ · , _ ...... .... .............. ,. . , 19:00 38-j ~ ~321 76 176 500 ' '46 "125 12~ ' 1.89 C~NG]NC ORIFICE ..... }~='d~'" 17/64 C~N~:E' OA~F::CE IN SEcoNDAR~ sEP~ToR T,) 2',2~0 ,,, ........ ~ .................. 19:09 14/64 T9:~5 ~,- 89 3~87 70 ................. : ......... 19:19 15/64 , ,'" ' . . 19:30 90 -~-~0 70 170 ~ __ 520 , 68 123 1'99 3_97 lqn ' ~2 qA 32 3.~ ~'%~60TM 34 15/%~ 92 3171 70 ,,!68 520 51 121 120 2.79 190 .~2 94. 20:30 j 9~-",~" 3150 168 520 51 119 118 2 79 190 32 21:00 34 ...........................J 94 ~ 3180 ~ [70 ~ .... ~.i... ~ ~ 520 4s ~[8 ~[7 2.7[ ~0 ~9 gs 21:30 ~82 170 520, 64 118 115 ' 3.13 190 38 93 92 2.~ 22:30 89 ,[_' 32Q2 ..... 23:00 32-- 89;~6~' 170 520 65 112' 111 t_17 190 4! 90 62 169 520 ' 66 112 110 3.20 1~0 42 90 91 3.00 '23:30 .......... 8~--"I 3205 - 168 ...... 520 ' 6~ 111 110 3.20 190 41 . . 89 91 2.95 '24'00 3~' 88~ 3212 62 169 520 69 110 110 3.28 190 43 88 . .... ...... , ...... k ..... , , . , ....... ........................ ............... . ..................... ' T ' ' ............................. , ........ ...... ,. ,'o,,T^.T.,.:s',' ~¥~T~-,~S.' - ,~C. ALAS~ coMP~Y · ~ O ~,~ cOMPANY , ,, STANDA~ PRODUCTION ~LLS' ~O~ING ~ S ~ ~4 ~ rEST DATA SH'EET WELLNo. 0-20 :.,sTATE ALAS~ DATE_AUGIIgT 4_ 1986 : '_'ET ~Wo .... 6 ........ JOB No. _3_4_1 ............... FLOWING: TUBING [~ H.S. METERsIZE 1500~ ' X 1,00i' CALIBRATED@ -- HRS. ANNULUS E] L.S. METERSIZE 1500~ X 100I' CALIBRATED@.~HRS. .. .... WELLHEAD READINGS HEATER HIGH sTAGE ~EPARATOR READINGS LOW STAGE SEPARATOR READINGS CHOKE FLOW TUBING ANNULUS BATH STATIC PRESS. M.R. SEP. FLOW S~'ATIC ' M.R. SEP. FLOW T,ME SIZE TEMP. PRESS.. PRESS, TEMP. DEAD WI"' i~E~ER DIFF. DIFF. TEMP. TEMP RATE PRESS. TEMP. TEMP RATE , °F IN "F *- PS~G "PSIG 'F PSIG PSIG ' 'IN.' 'F °F MM'CF/D PSIG IN. 'F °F MMCF/O . i0;~0 ................. j'-' ~'8 3213 ...... ' 170 .... ~' 520 70 !11 110 :~.30 190 44 89 90 3.06 i}:__00..1'--~-2' '15/64 . 89 ' '3'220" -'g'i ...... i68 .... .." 520 .7,1 110 ,. 110 3,32''' 190 44 ' ' 88 ' 90 3,06 )1:30 87 3225 170' , ..... 520 71 109 110 3.3,3 190 44 87 89 3.06 )2:00 32 87 3230 62 169 520 72 110 110 $ 35 190 4~ 88 88 3 10 )2:30~ j 87 3233 168 520 73 10.9 110 3,37 ..190 J 45 8.7 86 3..!Q_ i~:_~_0.~_~.~-~--] ..... _67_ ........ .3_2_4Q ......... $_Z___. 170 .... 520 73'~ -- 109' 110 3.37 190 45 88 86 .. 3.10 ~ i 8~7 j+ 3244 170 .... 520 72 , 109.., 108 3.35 190 45 87 86 .3.!,0 ~ 57 :' ___87 3246 62 168 5.2.0 ' 73 107 1.07. 3.38, .!90 65 86 85 .,, 3.!8., ~ .:_.Q0__b_._,12_..L__ ............. [_87 __6.2.__ 73 10'8 86 3 15 3- ._~02~5- i_,L_ ...... L_1.6./_ 6_4 _, ...... ',__. 3.2.,%3_. ~ i 520 1i0 3'.38 190 64' 88 .... Lo. z ,., 35_'.~0 ~,~-~__~. ' 87 . ? .3.252 ...... 18Z 'R20 25 111 111 3.40 ion ' , ....... 05:36 18/64 .,,. O.~ :40 18.5/64 I "-, ..... 3-~:00 35 18.5/.64 86 :k 3190 62 182 - 780' 6~ 110' 1'11 5.15 450 .7.0:', ' 91 "8'9 4.'90 36:30 85. 3265 178 780 48 110 111 4.61 450 58 91 90 4.45 .... ~-! ...... ~ .......... .__8_5__ ...... 3.~_O.~ ..... 62 ..... 182_ 780 _._52 _. 110 111 4,79 405. 60 92 .90 Q2.;..3 -i .......... ~ .... 85 ....... 3_293__ __.. .L8_O_ 78Q _.57. 109 109 ., 4.90 450 66 90 88 08_;.00 .i,___3_6_ _~_,~ .....:8__4. ~ .8_5.._. _._ 3_3.0.0. ....... 6_2.__ __182_ 780 58 107 108 4.99 450 68 88 88 4.85 ,, 08:30 ~ ....... " 33.2.2 182 780 56 107 107 4.89 450 65 88 86 a..71~ .... _:...O_O__I 36 .... 85 3322 62 183 780 5.6 107 108 4.89 450 65 88 86 4.71 p.~__: 3_0..i ..... 85 3322 183 780 56 107 108 4.89 450 65 88 86 4 71 i--' ~-3-~--' 62 .... 4. 10:00 36 ~ ..... 85 182_ 770 56 107 1'08 4.88 450 65 87 85 71 :_.o-..37_:_7 t; 770 ~(, 107 108 4.88 450 64 87 ~.5 4,70 1,i.;_00_:.___33__l ........... _8.6_..1'. ..... 33.3._4. ...... _62 1..Et2. .__ 780 56 107.. 108 4.89 450 64 87 8_5 4.70 iL:3.0_: I 8_6_~ ~3335 180 _ 780 55 105 108 4.88 450 64 i2.:.O0 ..... 37__1 85 ..... 3335 .... 62__181 780 55 105 107 4.88 450 6/-, 86 86 4.70 ].2:.27_ ............ !__1_9_Z_$4 INCREASE CF, 0KE INCRE,kSE BA. Cl~ PRESSIi~_, TO 1050 BLOCK CUT LOW STAGE HETER 12 .: 3_0_ i 85 ..... 336_6 18.0 1050 20 114 109 3,49 · .. :._~_==:._--_= , ~ .... ~ _ . , ., :. ;NEE 0 0 Z) 04:00 GAS GRAVITY .802 ',:~,~K S ...... 03:30 CHANGE ORIFICE TO 2.125 IN SECONDARY SEPARATOR _k0_.:_3_0_ _GAS GRAVITY .800 , i ,'o,,",'^ T.,:S',' ~¥.~T,Z.,~,S: ,,'.,¢. COMPANy STANDARD ALASKA PRODUC~TION C0~PANY' ~' 0 805 s~ ...... k41LLS. W'~rOMIING. US A &~6,44 ' · T E S T O A T A S H E E T WELL No. 0-20 .. STATE ,ALASKA' DATE AUGUST 4, 1986 H, IGH ST.,AG,.E ~)RIFICE'~ I~IE1LER RUN sIZ'E2."12'SX2. ~0/f, , LOW STAGE OI~IFICE & METER ~dN'SIZE,,. .......... 2.1'~'5 X 2;904' NET No, ._7. JOB NO. 541 FLOWING: TUBING J~ ' ~ H.S. METER SIZE ]-500~ X 100'~,, , CALIBRATED ~ __ HRS.~ ANNULUS [~] .... WELLHEAD READINGS I~iEATER. ' ' :"' HIGH STAGE SEpARATO~ READINGS "LOW STAGE SEPARATOR'READINGS A~IEI CHOKE ..... Fi. OW TUB'ING ANNULUS BATH .' STAtiC PRESS., M.R' SEP. ' i~LoW sTaTIc ' , M.R. ' sEP., FLOTM TE.P ' DIFF. ' DIFF. .......... , ....... , °F 'mN 'F PSIG PSIG' 'F ' P'SmG ...... ~IG , '~N. 'F ' eF UUCF~O PSIG IN. 'F °F ~UCF~ ........ ,,,,, , , , , ~ ..... , m '~F --'~ .... r" 85 33~6 ". ~ ~z ' ~ ~u~u zo ~4 z°9 ...... 3,~9. ....... ~:X2~ ........... ' s~u'r ~ '~.~ ~o'c~c~ c~o[~s (}~g~"~i~a'~o~:~s) t~:_~ ...... ~4~ ........ . ......... ........ ._[~z~ ,_ ~o/~ j '. . . ' ' . .' ' ['.... ..... . .. ........... ...[g.;.3O[ ~ .[ 80 j 33'[~ 65 .~83 ..... ~40 '~0 92 89 6'.09 " _~5=0_0[_~-~] .............. _ ..~_.[__ 3292 .~5 ISi~ 840 7d 98 I04 6.60 ..~5:30[__~ ............ _8.5. J ..... 3305 l~"~ '840 74 ' 98 ' l~0. 6'.~5 ~ 3~o~ ....... l~.o~ 37 ~', 8~ 3320 ~' . ~0 E4o . .76 ~z ~Ub' b.80 .... ~.7~0_oj_~.~_.~ ........ ~__ .SJi 3332 ~i ~8~ 840 78 92 z~. ~J ~ 2 "-~2-J" 5~5q' '- ~0 840' 88 ..... : ......... ~- ' ..... * ....... 840 89 96 9~ 7.55 . i8~.00. .3.~_,[ ....... i 83J 3342 65 2~0 ..~:~ ~ .... ~ ...... 8~'i~ii~3~.z~]2_i2 ~0~ 840 87~0~ ,,~00 ~.~s .... ,. .. ~9=3~ .......... ~ ......... ~ s3g___~352_ 2o2 ,840 87 ~0.8 ~04' 7.30 ~2:00 35 ~ ] 83_~ 3353 62 20~ 840 86 ~07 ~06 7.~0 -' ~ ~. o~ ..... ~z 9 7~-4'--~ ................ . . "-' .. ~ ....... ~ .............. ~ ..~-~ ...... ~.~-t ...... ., =~j2[~--..~ ....... ~.~ly~ ............ .., .. ,, GRAVITY = .800 ~,: .... 20~ 3D___GAS._GRAILTY ~_804 ' 21.:_O.O___INJECT--~LITHANOL AT HEATER INLET · ~ o m~ ~ COM~Y STAND~.'~LAS~ PRODUCTION TEST DATA SHEET WELLNo. 0-20 . STATE. A~S~ OATEAUGUST 4, 1~86 .',GH"STXG'E OR,F~CE & "ET£"',UN,SlZE 2.,125X2.90~ . 'CO'v~ ST.~G,'E,o'mF~cE ~ ~E~ ~U.'S,ZEg. [ Z3~,'X 2.90~,' ....... ;HEET No. 8 JOB No. 5~ 1 FLOWING: TUBING ~ H.S. METER SIZE 1500~ X 100" ~LIB~D ~ HBS.~ ANNULUS ~ L.S. METER SIZE 1~00~ ,. , X 100" ~LIB~D ~ ~ HRS., . , , ......... AUB. cHO~ FLOW TUBIN~ '" ANNULUS BATH STATIC PRESS. M,R. SEP.' ' FLOW STA~C M.[ SEP. FLOW TEUP ' OIFF. DIFF. T~M[ SIZE TEMP. PRESS. PRESS. TEMP. DEAD ~. METER TEMP. TEMP ~TE. , PRESS. ;F 'IN 'F PSI,G I ' PS'I6 , 'F "PsiG" ~IG, ' IN. , 'F oF MMC~~ ' ~iG IN. ~ oF MMcF~ , , ,' , , , ,' ~, , -, ' , ~ ' ............. ~ - - ~ ..... · ~ ~, i i ....... ~ '" ~'~2 ~':'~'5 "' 3602 ':'83 3407 203' r ' 830 '25 113 113' , 3 '~i ..... -2~:2o~/6~' , ~ ,. ," ',' ",'"' ~,~ ,, . . ~ , 22:00 ~ 3~_ __ 83 3604 62 ,~88 '~830" 23 , 129 12! ~.68 '330 ~'~ _.~.~ .... $3 3600 182 ~0 : 23 125 , 122. ~ 3.69 330 55 93 90 3. ~2~0 3fi. 83 ~ 33)_7 . _62. ,182 825, 23._ 123 121 3.68 330 55 92 90 3.74 ~~0_ 83 3395 182 ,, 8t5 2~ 12t 121 g.76, 330 55 92 90 3.74 24:00 3S 83 '3392 62 180-'~ 825' 23 122 120' 3.74 330 55 87 " 89 ' 3'.75 ............ , , , , ~,. ................. ..[ ........ ., · ........ ....... , ....... ........................ . , , ............................. · ......... ........ , . ............. ._i -~ ........... ~: ~ ............ ~ .......... ..... ~._ ~ ...... ~ 21:45 BEGIN METERING GAS FLOW SECONDARY SEPARATOR TEST COMPANY STANDARD ALASKA PRODUCTION COMPANY ~HEE 00 01 01 02 O2 O3 03 0A O4 O4 / DATA SHEET WELLNo. 0-20 _STATE..Ai'~sKA' DATE AUGUST 52 1986 ', .~ ', .j., ~ ...' . ~, · ; . . . HIGH ST^GE OmF,C£1'~., .ME. T~. RUN S,Z.E2 .. 125X2 i"904 ]'.~'' ' LOW ST~,G'~ 6me,CE & METER RU. N S,~ ]'.i. 2 ..i 25 X2. ~J 0'~ ...... r No.9JOB NO.541 FLOWING: TUBING '~ H.S, METER'SIzE ~'~00~' '":'?":~ '~'i']:'' ~':~001, ' ' .... ':" , ~LI~ED ~ ~ HRS. ANNULUS ~ L,S, METER SIZE..' [500~:u:. "'~'~: . x' 100" .. :' ~LIB~TED~ HnS. ~ ,, ,.' ... ~LL~EAO READINGS HEATER . HIGH STAGE SEPA~TOR READINGS. "'" % ."[. · .'.' '::.': /LoW"'~'T~G~ ~EPA~TOR READINGS · ~' CHO~ ~LOW TUmN~ ANNULUS ~AT. STAnC'P,ESS. '" "' ' . "'. .... TE~P '.',,'.~D~FF. M.a.: . ..SEP. '~ .; 'FLOW'.':' STA~C . ': ' ~.~ S~P. ~LOW ~ SIZE TEMP. PRESS. PRESS. TEMP. O~AD ~, ' METER ... TEMP, ' TEMP. "' :"'~TE''' (pREss. DIFF, TEMP. TEMP ........... , ,, .,, [ ..... . .......... gF IN 'F PSIG PsiG 'F PSIG ~lg IN. 'F '°F MMCF~ ~IG' IN] ~ °F MMCF~ . ..... , L..... ' ,~ ' L' , .... ~ -- ' '~" .~ ........... --~ --: , r ' ,z7 , 840., ...... z 9" .3 0 87 ;00 i 36 86 3380 62 176 840' "34 112 .1_15, ,, 4,60" 330 , 83 82 84 4,6' '['~ ..... ......... 85 3380 ~74 840'" 34'. '. 111 113'~''' ~ '".4'~58.' .... 330 83 81 83 4.61 :~_g_..L_~ ........ 87 ~3.80 62 184 '840 33 113" .'~1:3.~:C'. :: 4..49 .. 330' 83 83 : 30 87 3380 . . 182 840 ,. 33 114 ~':::1~4'~5~· . 4'~49".:'~ '""330 ": 82. ' 85 .' :00 36 I1 ~ 87 -~ 3381 62 183 840 · ...,3~. '114' '1.14'" .... 4.49',. .¥330' 8g. ". 83 TF0--~ .... ~ ......... ; 87 .... 338[- [~8 .... .'::840 ':'."'33'...11s" ~ [z4' ~;.:4~' :330 8~' 8~ 8~ 4,~0 3 8z. z8.3 .':840',.' 33. zz3 . zr2.:.. .... . 83 , : 02 t~ ;~ SHU~ IN ~L.g END OF TE:;T . ,. .,...{, " ."-: ....... ,, .... '"' . '" : 15 ~ ~ 34~[ "?'~ .(~ ..:,:.'..': .:.?. ,.::::~:~: ::,,,~.':.:.>'.'" .... ::. :,~..:.,'.:~%:,',L "~:"" .... ' '. r..~.~,"*'i', .... ,, . "d.' .¢"r: '~ [':'" ,..i". 'Y::~ :"'-' ...... .. .. ..~fS's~.. ;~ [ :r.... . ..~..... . , .. . '. ..:.~..... :.;., .. :...?... ~ ,.:~', 2%-] , . ,,. ~' ,~,,, .' ,.:.~ ~'... , ....... , ~ , , ,,., ,. ,, . ,,, , ,,,,. , ', .., :25 J ' .... ~,:.:::'::-:"/;' ~...:.::v.' ~:t.~:~: ~...~';~ ..... .',.,~?~....',.~,.' ~..'.~-.--" .' . ;'. " ' ...... : ..... ~. ,," , · ,.~, ..,.,,¢ , . . . . ':'3o-1 t 34,30 ..... :"' ..'~",~:.'.' ?.'..":;: .". '.?/~[,.;;'::; ':',' ':;" '~':~ . '"' ' '" ,_ ......... ,: ,,,.,., ..%~ . ~.:':,;',:~ :' . .... _ 3430. , ' "a:" " "'""'.'~ .~::'... ' "'" '" ': ....... "~' . ' .; t' ' '." ' ' ...... ' ...... ]4 o :. -.'. '~-~" ..... ~ ........ ]~] .~-~" ~ , , . ,.. . . , , .... ., 3.431 ~'.' '"' ' . -. , . .,,'? , ., ~ 34~0 :~_~ ..... ~ ........ ,., .,. - ....... :30.~ ............ ~ .................... ~&?7. · . .' ,.. ,',' ,:0~I ...... ] . ~27 ... " , , ~;~0-% ' -~25 ..... '" ""' '':''" ,. ' ,., ', ,, ,, :O~.L .... ~ -- 34~- - - ' , "' "' " ~ ' ., o~' ~'~, ..... .......... ---343-~ ..... ' .... " : 0~ ......... ~ " SET 'LUG BL D O~F 'P~$~. "' / · :"';";?'~'"" -" ;'~''' .:':'.: ..' .. :...,', :. "" . .~ .. · .. ., , .............. . . ...... , ! . ,,.. . ....... ....,.:-. ... :~:,(~:-..~ '" .....:~,....x , 4 ........... , '.. , ~' - . .- m" ' ., m, , . ."" ':.:'~?.-,5';( ".' .: ';:~.-~.)." ·., .'. . ,-~':~.. 71-. '::. ?. '":.?' "- ,' ...... ~-~.~.~: .... ....... .......... 7 ......... ': '~:. ~ ' ~ ' ' '"~'": ' ' ' ' :""' ] '~;' ' · = ........ . _ ~= . ~ .' , ., · .... -. .:... ,. .... . .-..... '.. ~.:: ... 'i~.'~' ...~i... . . -- , : , , , TIN~I 04 O4 O5 _0.6 -08 08 O9 10 10 ','ARKS .... 00: 25 _OBSTRUCTION IN CHOKE' BROKE ~LOOSE .':' ......? ,,..,u,........;~::...:..: '.'!.. ='~ :::(!':' ..:.,::.'~. :.1;,.":,. .:' ;5't?'::.:..fi:.'~';.:.'r.'..-.l.2:;. '. .... . ." · ..' :.-.~' ;;,.~.''L. ,~ ,,'. '. , . . :,-.. .~,:.... .... .~ ·· , . : . -..~.,, .-:;, .,, ;'., · . . . 03:30 T,A. KING OIL AI",rD (;AS SAMPLES , ".:?".:'. ,, :,',z' .'- ..'.;. '.'. .... '.',:,,'...?.:-.,.'...:'.' .... !.-,,.".:'..,F~..'..s,'-~--:.."-',. · -..: .... · ., . · . .. . , .. . .., . , . .-, ., . .,. , ~.: ~., *l~ ,.r,..,~ .., , . . · .~,..,;..:. :":.:.(:)' .'. ......: ;..~: ;, ,.': :.c"..?'....:C.~,~.:;~-...'.,.t~,?'.~'%': ~,..~;'..:,-:% :..,...~,:,. , ,-..; .:,: ,,., .... , ...... - ' ~ :.:'.~"..'": · "," '""'"' '.". '7 '."'~" .... '~'!'~<' .... :'."? ....:~.,;,v.'.,.,.,..! ..... ... , .... .... ..: ,,:,;~. :,'..: .-~::,,:~t~!::' :.','.' ,;~,',?.,,:::~;.,~i,' ~:ff~-~,;~l.;~':,_".'~:,:~,~j: k;. :~:~6~i:,~'..'~:.;.;.~'...,: .:t~37 ~'.- · . ," "'--.. '~;', ' - ':~".'.',~ ""l', ', ,'~ :'_~'." '~'~"' ', .-~,r,'~ -~,",::'-. 'e.'~,.'. '.'--,,,., ...... · . ........ · . .. . .. · '..'.. : . :.,, '_,~. h :',:;~ · ' ': ~. '"".'¢~," '~;'~ .;v' ,..'-,:~ -'~, . · , '. '..,.~., · '.-' , .. ...... ' ...~. · ,' ..,t~.p,~ ,, ...,,,~,1,,~.., v,'~.,',/ .,;~.~,.., .~',~ ~.,f.,.,,._.. .... .. ,;= ... ,. ~ ...... . ' ' ' ;' : : ...... , ~':" ",""?'""- ....."':: '" "=" "' ..... ' .... i'' ~ ' .?"~"'~:"?':'!"~¥""['"'"'-"'"'" 'r- -.....:.' ...... ... .. :". .... :' ":"~ .... '~"T(:,';~a'S''. . ','.'.' '::'::"~'g'~_,%'~'~.trS':~. ':"~" - r ~':.~¥:~t~.k'' ':,,&v,;a' ~.'~. ;'...C.,' '.. . ' ' · ., '. ,' '- ' ' . '.d~L'k:- · ','.;~ =: ,v ',,.: ..... :. '""'1'~T,.~t-'~r~?,'.."..'.;~;'.' '.~.:C'~;',%/.,: ','. ,)~'.".:.~:,':',~:;-.~ . ' ' .';: :.r;',,,. · .... ~:t/.::,~L:b~- f)a~!'A;.w ... ~-e'.';:: ,'...q ~,,,;;z~.,~;~.: :.H"r...b~,J,~,~¢_'_l~ ,~.~3.-~.':; ,':: .-, .'~. ... '... · -.,, P.O, eOx~ ~' COMPANY STANDARD ALASKA PRODUCTION COMPANY ............ M~LLS. W~QMING, U.S.A. 82644 , F L U I D P R O D U C T I O N WELL No. .STATE ALASKA 0-20 AUGUST 3 1986 DATE , RUN · 1 N .... ' ........ 'TIME OFF GRAVITY FLOW RATE SHEET No. I JOB No. 541 11 .. 33 8/03/86 47.3 @ 60° f ....... 'rANK No. J. ,, SIZE .500 B-Bm TANK NO.... 2 .... S~ZE ....~00" BBL CONDENSATE WATER 'PROD. SHIPPI'NG TEMP. CONDENSATE WATER ~, PROD. SHIPPING TIME CONOl WATER COHO. WATER ~F ..... COND. WATER COHO. wATER' Ins. Bbls. Ins. Bbls, Bbl=, Bbl$, Bbls. Bbls. Ins, Bbls. Ins. Bbls. Bbls, Bbls, Bbls. Bbls. ,.'_'7:,.71~ .... 2.1..18 0 ........ ...0 .... ppEN].NG GAl'GE .'...,' ....... 149,.0 ...82.20 0 ..... 0'i'O?ENi]~C GAUGE ... " 0'1:00 8.00 22.10 · 92 O]'ENED W,~.LL ,,,ON BY-PAS; TO ..TA~rK,, ON 8/ 64 FOR ~ MIN. ,, ,. i0":31 oPENED ON BY-PASS 11:00 16.00 51.40 " 29.3( 76 ............. 11:30 25.00'" '84.40 33.0( 76 12:00 27.00 91.80 7.4( " 72 ............. l ...... ?"i2:30 28.5(j' '97.25 ........ 5..4.5 ..... 70 ....................... !' 13":00 "~9.50 100.95 3.7¢ 66 13:30 30.50 104.60 "3'~6'~ 64 .......... " 14':0'0 30.75 105.50 ..... .9£ 62 .......... . !,4:30 31.00 106.40 ,. .9C .... 62 . . 15:00 31.12 106.86 .4{~ 62 ....... 15:30 31.50, 108.25, .., 1.3~. 64 ....... 16:00 31.50 108.25 0.0( 16:10 SHUT Z; TO FIX LEAK BLE~ DOWN !sEPARAtoR 17:00 35.00 121.10 12.8.~ ..... ,, , 18: 20 19:00 35.00 121.10 0.0( 60 ,,, 20:00 35.00 1.21.10 0,0( ,.o 58 . _ 21:00 , 35.00 121.10 0.O( . 58 . 22:00 35.25 122.03 . ,9~ 62 23:00 36.50 12o.'...60 4.57 . 64 24:00 37.00 128.40 1.8¢ 62 ~,il TOTALS 103.22 TOTALS 0.00 REMARKS: TANK ~1 J TANK ~ 2 COND. J WATERJ. COND. J WATER OPENING GAUGE 21.18 J 0.0 t82.210.0 PLUS PRODUCTION !07 22 0 0 O. 0 O. 0 TOTALS 128.40 0.0 ~ $2.2J 0.0 ... MINUS SHIPPING O. DC) CLOSING GAUGE 128.40 0.0 J]' 82~2 J 0,0. , TO REORDER PHONE MILLS, the COMPANY (307) 674-7473 or (800) 442-3~36 TOLL FREE iN'WY0'~IN~ ~'1'6i' i'l-M 1~5) ' "P'OI:~TA-?£$T $¥$T£I'~$, Il,lC. P,O. mox ~ " COMPANY ,, STANDARD_ ALASKA PRODUCTION COMPANY MILLS. V~r'OMING. U.S.A. 82644 / WELL No. 0-20 STATE_ ALASKA DATE AUGUST 4, 1986_ FLUID PRODUCTION ..... RON# i T'ME O N I I I ..... ' I '' I iTIME OFF I I I GRAVITY .... ' ' ~L 0W RAMIE II I SHEET No. 2 JOB No. 541 11: 33 8/03/86 47.3 ,@ 600., · ,. , ..... TANKNo. 1 SIZE '500 BBL, .... '" ,,T.ANKNo' 2,,,' ,,, SiZE 400. ]BL" ,, CONDENSATE WATER PROD. SHIPPING TEMP, CONDENSATE WATER PROD. SNIPPING TIME ....... CONG, 'WATE'R CONOl WATER 'F ............. COND. " WATER cOHo] WATER .. .. , Ins. 8bls. Ins. Bbls. Bbls, Bbl$, Bbls. Bbls. Ins. Bbls. Ins, Bbls. Bbls. Bbls. Bbls. 'Bbls, 37.00 128.40 ...... 49.0(.8.2,,,.2.0,, 0.0O 0.0O O.OO O.O0 0.00 O.00 01':'00' -39.2"~' "~.36.95, 8.55 7'0 02: 00 40.50 141.75 4.8C ' 68 " 03:00 42.00 147.70 5.95 68 04':00 ~3.00 151.70 4.0C 70 05:00 ~4.00 155.80 4. lC 68 06'00 46.00 1'64 1'0 ~'.'3C 72 ..... 07:00 'i8.50 174~"'55 .......... 10.4.= 74 ........................... 08:00 50.50 182.90 8.3." 72 .j. 09:00 52.50 191.30 ,, 8,.4( ..... 70 ...... 10:00 54.00 197,§0 6.30 .. 70 ...... 11:00 55.50 203.85 6.25 70 12:00 57.50i212.20 8.35 70 ..... 13:00 59.00 218.50 6,3C . . 70 14:00 59.00 218.50 0.0C 68 15:00 61.00 226,90 8.4C 68. 16:OO 63_50 237.35 lO_&= 6A ., 17:00 67.00 252.00 14.6! 68 ,, 18:00 69,50 262.50 10.5( . -., 68 ....... 19:OO 71_rio 270.8fl 20:00 74.00 281.30 10.5G 70 21:00 77.50 296.00 14.7C 72 22:00 79.50 304.30 8.3£ 68 23:00 80.00 306.40 2,1C 68 24:00 80.50 308,..5_.0 2.1C 66 ,,....... . i TOTALS ! 0 TOTALS 0,00 0,00 0,00 0,00 : _. REMARKS: . TANK # ]. J ]~'ANK # 2 04:00 OIL GRAVITY 48.2 @ 60°F COHO. J WATERJ COND. ] WATER 10:00 49 ~70°F OPENING GAUGE 128 40 t 0.00 I 82.20[ 0.00 "' PLUS PRODUCTION '180[ 10t It lO 00 0 00 ~,00 MINUS SHIPPING ' 0 0_0._,l_~0_0 0~._.00 0.00_ :; CLOSING GAUGE 308 50 i 0 ~ 00 ~ 82.2-0 [ 0 0U- TO REORDER PI'4ONE MILLS. the COMPANY (307) 674-7473 or (800) 44:)-,360~ TOLL FREE iN"wyOMIN~ '~'1'8i' ~'I-M I~./~S)" ' · PC~FtT,~I,-T£$T SYST£MG. p,o, Mx ~ ~ COMPANY STANDARD ALASKA PRODUCTION. COMPANY MILLS, WYOMING, U.S.A. 82644 ~ WELL No. 0-20 STATE__ALASKA DATE AUGUST 5: 1986 FLUID PRODUCTION ...... RISN'~ I ' ':I'IME"o'N :' ' TIME OFF ....... GRAVITY ................. FLOW RATE .................. SHEET No. 3 JOB No. 541 11;'33 8/03/86 47,5 @ 60°F TANK'No. 1 SIZE" 5'O0'"BBL ...... TANkN'o.' 2 SIZE 500 '..BBL ...... ' ...... . ............................... , CONDENSATE WATER PROD. SHIPPING TEMP. CONDENSATE WATER PROD. ~HIPPIN~ TIME ,., COND. wATER COND. WATER 'F , ,, C'ohD. ,, WATER CONDi wATER Ins. Bbl$. Ins. Bbl$. Bbl=. 8bls. 8bls. ' "' BbI$. '1 Ins. Bbl$. Ins. Bbls. Bb'l~. Bbls. ebls. ' ' 80.50 308.50 '0.00 ...... 0.0( ............. . '"_i.~9_i 0j._82~.2_0 ....O.d'O 0.00 O 'O'O .O';G0 b.'OO 0.00 L"Oi:~O'0 ~:'8-1-~-50 312.70 4'.20 66 .... 02:0'0 '83.00 319,00 .... 6.30 68 .............. '"03: O0 84 ,'50 "325,3'b "' 6,30 68 ......... 04:"00 . 86 .'bO' 331'..50 · .. 6.20 ..... 68 ........... ..... 05:00 i 06:00 i., 07 :oO ........................... 0 8 : 00 09:00 10:00 11:00 12:00 13:00 ,, 14:00 15:00 16:00 17:00 REMARKS: 03: 30" SPECIFIC GRAVITY WAS MEASURED AT ' ' TANK 47.5 @ 60° CONO. [WA'~E~'] COND, [ wATER" ....PLUS PRODUCTION 23.00 0 00 O. 00 I 0.00 -., TOTALS 331.50J 0.00 "82.20] 0.00 MINUS SHIPPING 0.00 CLOSING GAUGE 331'.50'1"0.00 ~ 82,20( O.OO , , TO REOROER PHONE MILLS. tn, COMPANY (307) 674-7473 or (800) 44'2-3606 TOLL F~REE iN'WY0'i~iNG P.O. Box 522 STANDA~ ALAS~ PRODUCTION COMPANY Mills, Wyoming 82644 COMPANY FLUID M~ER AND 55 WELLNO. 0-20 STA~E ALAS~ D~ AUGUST 3, 1~86 'OIL~M~TE" #' OIL METER #Z WATER METER" wAT~R METER '2 FL0~ RATE M k4CF/D_ SHEETNO ....... ! JOBNO.~ , 541 _ SERIAL#, 1SF36808 ,.,SERIAL # SERIAL # ....... SERIAL ' ..... RATE I ........... FACTOR991 92 FACTOR FACTOR FACTOR FLUID TEMP. , , ·'~- '" b'IL'METER #1 OIL METER 12 WATER METER #1 W~TE'R METER #2 . 55 GALLON.DRUM ........ ., , PRODUCTION, ..... MET. I~DC." .. PROD. MET. RDG. PR0'I:). MET, ROG. PROD. MET. RDG. PROD. ~ C6'N~)EN'SATE ~ WATER ~ OIL wATER TIME " Bbls. I Bbls. Bbls. Bbll. Bbll. abll. ' Bbl/. Bbl$. Ins. U,S, Gals,_ Ins. U.S. Gals. Gals. Gals.._ _ 9.33,4 ..... ............ 22:00 933,5 0,1 ............... 23:00 937.5, 4.0 ....................... 3_4:O0 942.3 4.8 ........................... _ _ ., ...... , ., , . , · .., __ _ .... .... _, ., .... ..... , , .... __ ......... _ ., , ... , ..... __ .., . . , . · , · ., _ . _ __ _ . . . _ · _ , . , . - .... CUMULATIVE PRODUCTION OIL WATER 'U.S. GALLONS REMARKS BBI$. ' ..... 8.~' TO REORDER PHONE MILL~. ~e COMPANY (;X;)7) 174-7473 or (~30} 442-.T~0~ TOCL FREE IN WYOMING 8161 (1M 12/851 P.O. Box 522 Mills~ Wyoming 82644 COMPANY STANDARD ALASKA PRODUCTION COMPANY FLUID METER AND 55 WELLNO. 0-20 STATE ALASKA DATE AUGUST 4, '~986 GALLON DRUM DATA SHEET OIL I~'rER'#I oIL METER'S2 WATER METER"#1 WATER METER 12 FLOW RATE MMCF/C) i i ~6808 SHEET NO. ? JOB NO. 541 SERIAL it 1 FACTOR 9(~1,92 FACTOR FACTOR FACTOR FLUID TEMP. 'F · ', , ..... , ...... OIL METER #I OIL ~ETER it2 wATER METER #1 WA~ER METER #2 55 GALLON DRuM PRODUCTIOn('' MET. RDG. pROD. MET. RDO. PROD. MET. RDG. PROD. MET. RDG. PROD.' CONDENSATE WATER OIL WATER TI M E Bbli. Bbl$. Bbll. Bbll. Bbl$. Bbls. Bbls. Bbls. Ins. U.S. Gals. Ins. U.S. Gals. Gals. Gals. 942.3 , , 01:00 . 948.3 6.0 .............. 02:00 9}2.1 . 3.8 .................... 03:00 956,4 4,3 ................. 04:00 960.5 4,1 , 05.00 964.2 3,7 06:00 968.8 4.6 07:00 975.9 7.1 08:00 984.1 8.2 ..... 09:00 .... 990.5. 6.4 . . '10:00 997.4 6.9 11:00 1003.4 6.0 12 ;m 00 1013,3 ...... 9,9 .13:00 1018,6 5.3 !14:20 OPEN UP t!OR 7 M~F/D RATE ......... .. 15:00 1026.2 7.6 , , 16;00. 1039.5 13,3 ... ,, 17:00 1052.2 12.7 18:00 1065.6 13.4 ,19 _.-BO lO7q.O l't.& .... '" 20:00 1089.2 10.2 21:00 1101 .0., 11.8 22:00 1107.0 6.0 23:00 1112.2 ~.2 ,, . 24:00 1117,7 5,5 175,4 .. "CUMtJLATIVE PRODUCTION OIL WATER REMARKS U.S. GALLONS ,-, Bbls. 1~4.3 0.0 TO REORDER PHONE MILL~. mI COMPANY (307) ~"/4-7473 ot (~00} 44-2-360~ TOLL FREE IN WYOMING ~1~1 (1M 12./851 PO'I~T;~-T:EST ~YST~E:Z~S. I~C. P.O. Box 52'~ Mills, WTOming 82644 COMPANY STANDARD ALAS~ PRODUCTION COMPANY ~ FLUID METER AND 55 WELLNO. D-2O STATE ALAS~ O~T~ AUGUST 5: 198( GALLON DRUM DATA SHE~ L Old'METE. #,' ' OiL METER #2 WATER METER #1 WATE'R METER ,2 FLOW RATE SHEET NO. 3__JOB NO. _ 541 SERIAL#ISF 00 SERIAL, SERIAL I SERIAL I RATE, FACTOR 991 · 92 ~AC*OR FACTOR FAC. T~.R .. FLUID TEMP ..... . . . . ... . ' OIL METE~ ,1 "' OIL U~ IZ WATEd METER 11 WATER METER 12 55 GALLON ORU. P'RODUCTION ,, , MET. RDG. PROD. MET. ROG. PROD. MET. RDG. PROD. MET. ROG. PROD. CONDENSATE WATER O~L ] WATER TI M E Bbls. Bbls. Bbll. Bbls. ~bl$. Bbls. Bbla. Bbls. Ins. U.S. Gals. Ins. U.S. Gars. Ga Is Gals . ~ ...... , .* ~z~7..'.7 .................................. o~oo ~.~ ~.~ 02:00 ' 1131.7 7.~ ..................... ......... 03:00 1138.8 7.1 , .............. 06:00,, 11~5.7 6 ~ ..... i , , - · ,., . ............. ........................ ~ ....... , .... ,,~,,,,,, .... ,,,:,,,,,,,,, ..... ,.,:,,,, .,,. ..... ,, :"',",' ..... ....... ,:.,,..,~ .... ,,., .... ,,.',',~:~' ....... [ ........... ., , ....... ~ .... ......... ,, , .... ....... ...... ..... , . ..... .... i ...... , . ....... , , , . ...... ..... 28.t " ,CUuu~v[ ~Oauc~ou ,,9~ REMARKS END OF TEST U.S. GALLONS Sbis. 212.30 TO REOROER PHONE MILL~.'the COMPANY (307) 674-7473 or (800; 442-3~:~ TOLL FREE IN WYOMING 8181 (1M 12/85) WELL TEST DAT/~ "~'O:~"TO.MER LISTING FOR STANDARD ALASKA PRODUCTION CO 1-5 / 0-20 MPI ENDICOTT NORTH SLOPE 4L~SKA RECORDED: 02-AUG-86 COMPUTED: 2?-AUG-86 JOB NUMBER: 71645 COMPANY: WELL: STSNDARD ALASKA PRODUCTION CO LOCATION: NORTH SLOPE 1-5 / 0-20 MPI FIELD: ENDICOTT A . sKA FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 8:12:39 ON 8/02/86 TVD SUE,-SEA DEPTH 10223.7 MEASUREO DEPTH 11137.0 DATE TIME M PEP TVD PRESSURE (FEET) (FEE'T) (PSIA) TEMP (OEG F) 8/02/86 8:12:39 11137.0 10279.0 5068.23 215.85 8/02/86 8:12:51 11137.0 10279.0' 5068.23 215.85 8/02/86 8:13:01 11137.0 10279.0 5068.32 216.23 8/02/86 ~:13:11 11137.0 10279.0 5068.62 216.24 ~/02/86 8:13:23 11137.0 10279.0 5069.05 216.25 8/02/86 $:13:35 1113-7..0 10279.0 5069.72 216.26 8/02/86 8:13:47 111~37",0 10279.0 5071.09 216.27 8/02/86 8:13:59 11137.0 10279.0 5125'38 216.28 PAGE ,, COMP~N¥~ W~LL: TVD DATE 8102185 8/02186 8102/86 8102186 8102186 8/02186 8102186 8102/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02/86 8102/85 8/02/86 8/02/86 8/02/86 8/02/86 8/02/56 8/02/86 8/02/86 8/02/86 8/02/85 8102/85 8/02/86 3102/85 8/02/86 8/02/86 8/02185 8102/86 8/02185 8/02/86 8102185 8102186 8/02/85 8102/86 5/02/86 8/02/36 8/02/86 STANDARD ALASKA PRODUCTION CO 1-5 / 0-20 NPZ LOCATION: NORTH SLOPE FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 7:15:08 ON 8/02/86 SUB-SEA DEPTH 979'9.2 MEASURED DEPTH 10656.0 TIME M, DEP TVD PRESSURE TEMP (FEET) (FEET) (PSIA) (DEG F) 7:15:08 10656.0 9854.0 4853,51 207.27 7:15:19 10656,0 9854,0 4853,51 207,27 7:15:29 10656.0 9854.0 4853,59 208,02 7:15:39 10656,0 9854,0 4853.60 208,02 7:15:49 10656,0 9854,0 4853,61 208.02 7:15:59 1065.5.0 9854,0 4853,62 208,02 7:16:09 105'56'~"0- 9854,0 4853,62 208,02 7:16:19 10656,0 9854,0 4853,64 208,02 7:16:29 10656.0 9854.0 4853,64 208.02 7:15:39 10656,0 9854,0 4853,64 208.02 7:16:49 10656.0 9854,0 4853,64 208.02 7:16:59 10656,0 9854,0 4853,65 ZO8,O1 7:17:09 10656.0 9854,0 4853,65 208,01 7:17:19 10656.0 9854,0 4853,66 208,01 7:17:29 10656,0 9854,0 4853,66 208,01 7:17:39 10656.0 9854,0 4853.67 208,01 7:17:49 10656,0 9854,0 4853.67 208,01 7:18:01 10656,0 9854.0 4853.68 208,01 7:18:11 10656.0 9854,0 4853.68 208,00 7:18:23 10656.0 9854,0 4853.69 208,01 7:18:33 10656,0 9854.0 4853,71 208.00 7:18:43 10656.0 9854,0 4853,71 208,00 7:18:53 10656.0 9854.0 4853.72 208.00 7:19:03 10655.0 9854.0 4853.72 208.00 7:19:13 10656.0 9854.0 4853.72 208.00 7:I9:23 i0656.0 9854.0 4853.72 208.00 7:19:33 10656.0 9854,0 4853.72 208,00 7:19:43 10656.0 9854.0 4853,71 208,00 7:19:53 10656.0 9854.0 4853.71 208,00 7:20:05 10656.0 9854.0 4853.71 208,00 7:20:15 10656.0 9854.0 4853.71 208,00 7:20:27 10656.0 9854.0 4853.72 208.00 7:20:37 10656.0 9854,0 4853.73 208,00 7:20:47 10656.0 9854,0 4853,73 208,00 7:20:59 10656.0 9854,0 4853,73 207.99 7:21:09 10656.0 9854,0 4853.72 207.99 7:21:19 10656.0 9854.0 4853.73 207.99 7:2I:29 10656.0 9854.0 4853,73 207.99 7:21:39 10656.0 9854,0 4853.73 207.99 7:21:49 10656.0 9854.0 4853.74 207,99 ALASKA PAGE COMPANY: WELL: STANDARO ALASKA PROOUCTION CO 1-5 / 0-20 FLOWING GRADIENT PRESSURE LOCATION: FIELD: SURVEY NORTH SLOPE ENDICOTT ALASKA PAGE TVD SURVEY BEGAN AT SUB-SEA DEPTH 9799.2 7:15:08 ON 8/02/86,. MEASURED DEPTH 10656.0 D~TE 8102/86 8/02/86 8102/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/85 8/02/86 8/02186 8/02/86 8102186 8102/86 8/02/86 8/02/86 8/02/86 8102/86 8102186 8/02/86 8/02186 8102186 8102186 8102/86 8/02/86 8102/85 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 5/02/86 9/02/86 8/02/86 8102/86 8/02/86 8/02/86 TIME M OEP (FEET) TVD PRESSURE TEMP (FEET) (PSIA) (DEG F) 7:21:59 10656.0 9854'0 4853.75 7:22:09 10656.0 9854.0 4853.75 ?:22:i9 10656.0 9854.0 4853.76 ?:22:31 10656.0 9854.0 4853.76 7:22:43 10656.0 9854.0 4853.76 7:22:53 1065,6.0 9854.0 4853.77 7:23:03 106'56;0 9854.0 4853.77 7:23:13 10656.0 9854.0 4853.79 7:23:23 10656.0 9854.0 4853.79 7:23:33 10656.0 9854.0 4853.79 7:23:43 10656.0 9854.0 4853.79 7:23:53 10656.0 9854.0 4853.78 7:24:03 10656.0 9854.0 4853.78 7:24:15 10656.0 9854.0 4853.77 7:24:27 10656.0 9854.0 4853.78 7:24:39 10656.0 9854.0 4853.77 7:24:51 10656.0 9854.0 4853.77 7:25:01 10656.0 9854.0 4853.77 7:25:11 10656.0 9854.0 4853.77 7:25:21 10656.0 9854.0 4853.77 7:25:31 10656.0 9854.0 4853.78 7:25:41 10656.0 9854.0 4853.78 7:25:$1 10656.0 9854.0 4853.77 7:26:01 10656.0 9854.0 4853.77 7:26:13 10656.0 9854.0 4853.77 7:26:25 10656.0 9854.0 4853.79 7:26:35 10656.0 9854.0 4853.78 7:26:45 10656.0 9854.0 4853.77 7:26:55 I0656.0 9854.0 4853.78 7:27:05 10656.0 9854.0 4853.78 7:27:15 10656.0 9854.0 4853.77 7:27:25 10656.0 9854.0 4853.77 7:27:3~ 10656.0 9854.0 4853.77 7:27:45 10656.0 9854.0 4853.77 7:27:55 10656.0 9854.0 4853.77 7:28:05 10656.0 9854.0 4853.77 7:28:17 10656.0 9854.0 4853.77 7:28:27 10656.0 9854.0 4853.78 7:28:39 10656.0 9854.0 4853.77 7:28:51 10656.0 9854.0 4853.77 207.99 207.99 207.99 207.99 207.99 207.99 207.99 207.99 207.99 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 207.98 '207,98 207.98 207.98 207.98 COMPANY: STANDARD AL,~SKA PRODUCTION CO WELL: 1-5 / 0-20 MPI LOCATION: NORTH SLOPE ALASKA FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 7:15:08 ON 8/02/86 TVD SUB-SEA DEPTH 9799,2 MEASDRED DEPTH 10656.0 DATE 8/02/86 8/02186 8/02186 8/02/86 8/02/86 8102/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/85 8/02/86 8/02/86 8/02/86 8102186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/85 8102185 8/02/86 8/02/86 8/02/86 8/02/36 8/02/86 8/02/86 8/02/86 TIME M OEP TvD (FEET) (FEET) 7:29:03 10656.0 9854'0 7:29:15 i0656.0 9854.0 7:29:25 10656.0 9854.0 7:29:37 10656.0 9854.0 7:29:47 10656.0 9854.0 7:29:57 1065.6,0 '9854,0 7:30:07 106'56";'0- 9854.0 7:30:17 10656.0 9854.0 7:30:27 10656,0 9854.0 7:30:37 10656.0 9854,0 7:30:47 10656,0 9854,0 7:30:59 10656'0 9854.0 7:31:09 10656.0 ,9854.0 7:31:19 10656.0 98'54'-0 7:31:29 10656"0 9:'854.0 7:31:39 10656.0 9854'0 7:31:49 10656.0 9854.0, T:31:59 10656.0 ,9854.0 7:32:09 10656.0 9854.0 7:32:21 10656.0 9854,0 7:32:33 10656.0 9854.0 7:32:43 10656.0 9854.0 7:32:53 10656.0 9854.0 7:33:03 10656.0 9854.0 7:33:13 10656.0 9854.0 7:33:23 10656.0 9854.0 7:33:33 10656.0 9854.0 7:33:43 10656.0 9854.0 7:33:55 10656.0 9854.0 7:34:05 10656.0 9854.0 7:34:17 10656.0 9854.0 7:34:27 10656.0 9854.0 7:34:37 10656.0 9854.0 7:34:47 10656.0 9854.0 7:34:57 10656.0 9854.0 7:35:07 i0656.0 9854.0 7:35:17 10656.0 9854.0 7:35:27 10656.0 9854.0 7:35:37 10656.0 9854.0 7:35:47 10656.0 9854.0 PRESSURE (PSIA) 4853.76 4853.76 4853.77 4853,77 4853.77 4853,77 '4853.76 '4853"76 ,4853'77 4853-77 4853.75 4853,76 4853.77 4853.751 4853,75 4853.75 '4853'76 4853,76 4853'76 4853.76 4853,76 4853.76 4853,77 4853.77 4853.77 4853.77 4853.77 4853.76 4853'.76 4853.77 4853.77 4853.78 4853.79 4853,79 4853,79 4853.79 4853.79 4853.80 4853.80 4853.80 TEMP OEG F) 207.98 207.98 207.98 207.97 207-97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.98 207.98 207.97 207.97 207,97 207'97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207.97 207,97 207.97 207.97 207.97 207.97 207.97 207.96 PA~E COMPANY: WELL: TVD DATE 8/02/86 8/02/86 8/02/86 8/02/86 5/02/86 8/02/86 8/02/86 8102186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02/86 8/02/86 8/02/86 8/02/85 8102/86 8/02/86 8102186 8102/86 $/02/86 8/02/86 3/02/86 8/02/86 3/02/86 8/02/86 8/02/86 3/02/86 8/02/86 8/02/86 8/02/86 8102/85 8102/36 3/02/86 8/02/86 STANDARD ALASKA PRODUCTION CO LOCATION: NORTH SLOPE 1-5 / 0-20 NPI FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 7:15:08 ON 8/02/96 SUB-SEA DEPTH 9799.2 MEASURED DEPTH 10656.0 TIME M OEP TVD PRESSURE (FEET) ,(FEET) (PSIA) 7:35:57 10656.0. 9854.0 4853'80 7:36:07 10656.0 9854.0 4853.79 7:36:17 10656.0 9854.0 4853.79 7:36:27 10656,0 9854,0 4853,79 7:36:37 10656.0 9854,0 4853,78 7:36:47 10~5.6'0 9854.0 4853,77 7:36:57 10656~0" 9854,0 4853,77 7:37:07 10656,0 9854,0 4853,77 7:37:17 10656,0 9854,0 4853,78 7:37:27 10656.0 9854,0 4853,78 7:37:37' 10656,0 9854,0 4853,78 7:37:47 10656'0 9854,0 4853,77 7:37:57 10656,0 9854,0 4853,78 7:38:07 10656,0 9854,0 4853,78 7:38:17 10656,0 9854,0 4853,78 7:38:27 10656,0 9854,0 4853,78 7:38:39' 10656,0 985~,0 4853.78 7:38:51 10656.0 9854.0 :4853,'79 7:39:01 10656,0 9854,0 4853,79 7:39:11 10656.0 9854,0 4853,79 7:39:21 10656,0 9854,0 4853,78 7:39:31 10656,0 9854,0 4853,79 7:39:41 10656.0 9854.0 4853,79 7:39:51 10656.0 9854,0 4853,79 7:40:01 10656.0 9854,0 4853.78 7:40:11 10656.0 9854.0 4853,78 7:40:21 10656.0 9854,0 4853.78 7:40:31 10656.0 9854,0 4853,78 7:40:41 10656.0 9854.0 4853.79 7:40:51 10656.0 9854.0 4853.78' 7:41:01 10656,0 9854.0 4853,77 7:41:11 10656.0 9854.0 4853.77 7:41:23 10656.0 9854.0 4853.77 7:41:33 10656,0 9854.0 4853,77 7:41:43 10656.0 9854.0 4853,77 7:41:53 10656.0 9854.0 4853,78 7:42:03 10656,0 9854.0 4853,77 7:~2:13 10656,0 9854.0 4853,77 7:42:23 10656,0 9854,0 4853,77 7:42:33 10656,0 9854.0 4853,76 TEMP (DEG F) 207.96 .207.96 20'7.96 207.96 207.96 207.96 207,96 20?.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 Z07.95 207.95 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.96 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 ALASKA PAGE COMPANY: WELL: TVD DATE 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/.86 8/02/86 8/02/86 8/02186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02/86 8/02/86 8102185 8102186 5/02/86 8/02/36 8/02/~6 8~02186 8102/86 8102/86 8/02/85 8/02/86 STANDARD ALASKA PRODUCTION CO LOCATION: NORTH SLOPE 1-5 / 0-20 MPI FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY ~EGAN AT 7:15:08 ON 8102186 SUS-SEA DEPTH 9799.2 MEASURED DEPTH 10656,0 TIME M OEP TVD (FEET) (FEET) 7:42:43 10656,0 985'4,0 7:42:53 10656.0, 9854.0 7:43:03 10656.0 9854.0 7:43:13 10656.0 9854.0 7:43:23 10656.0 9854-0 7:43:33 10 5-6,, 6 0 9854 0 7:43:43 10656,'0 ....... 9854.0 7:43:53 10656.0 9854.0' 7:44:03 10656.0 98,54.0' 7:44:15 10656.0 9854.0, 7:44:27 10656.0 9854.0 7:44:39 10656.0 9854.0 7:44:51 10656.0 9854.0 7:45:01 10656.0 9854.0 7:45:13 10656.0 9854.0 7:45:23 10656.0 9854'0 7:45:35 10656.0 9854.0 7:45:47 10656.0 9854.0 7:45:59 10656.0 9854.0 7:46:09 I0656.0 9854.0 7:46:21 10656.0 9854.0 7:46:3I i0656.0 9854.0 7:46:43 i0656.0 9854.0 7:46:53 10656.0 9854.0 7:47:03 10656.0 9854.0 T:47:i3 I0656.0 9854.0 7:47:23 i0656.0 9854.0 7:~?:33 10656.0 9854.0 T:47:43 10656.0 9854.0 T:47:53 10656.0 9854.0 7:48:03 10656.0 9854.0 7:48:13 10656.0 9854.0 7:48:23 10656.0 9854.0 7:4~:35 10656.0 9854.0 7:48:47 10656.0 9854.0 7:48:57 10656.0 9854.0 7:49:07 10656.0 9854.0 7:49:17 10656.0 9854.0 7:49:29 10656.0 9854.0 7:49:39 10656.0 9854.0 PRESSURE (PSIA) 4'853.76 4853.77 .4853'78 :4853.77 .4853.77 4853.78 ,4853.79 '4853.79 ::~B53.80 4853.81 4853.81 4853.82 4853.81 4853.81 4853.81 4853.81 4853.81 4853.82 4853.81 4853.82 4853.81 4853.81 4853.80 4853.79 4853.80 4853.80 4853.79 4853.79 4853.79 4853.79 4853.77 4853.78 4853.79 4853.79 4853.79 4853.79 4853.79 4853.79 4853.79 4853.78 TEMP (DEG F) 207.95 207.95 207.95 207.94 207.94 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207.95 207,94 207.94 207,94 207.93 207.94 207.94 207,94 207.94 207.93 207.94 207.94 207.94 207.94 207.94 207,94 207,94 207,94 207,94 207.94 207.93 ALASKA PAGE COMPANY: WELL: TVD DATE 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102186 8102/86 8102186 8102186 8102/86 8/02/86 8/02186 8/02/86 8102186 8/02185 8/02/85 8102/86 8/02/86 8102/85 8102/85 8/02/86 8/02186 8/02185 8/02/86 8102186 8102186 8/02/55 8/02/86 8102/86 8102156 8102186 8102/85 8102/86 STANDARD ALASKA PROOUC'TIO'N CO LOCATION: NORTH SLOPE ALASKA 1-5 / 0-20 MPI FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 7:15:08 ON 8/02/86 SUE-SEA DEPTH 9799.2 MEASURED DEPTH 10656.0 TIME M OEP TVD (FEET) (FEET) 7:49:49 10656.0 9854.0 7:49:59 10656.0 9854.0, 7:50:11 10656.0 9854.0 , 7:50:21 10656.0 9854.0 7:50:31 10656.0 '.9.8:54.0 7:50:41 106~6,,.'0 '98'5'4.0 7:50:51 10556~0 ...... 9854.0 7:51:01 10656'0 9854.0 7:51:11 10656'0 9854.0 7:51:21 10656.0 9854.0 , 7:51:31 10656.0 7:51:41' 10656.0 7:51:51 10656.0 7:52:01 10656.0 7:52:11 10656'0 7:52:23 I0656.0 7:52:33 10656,0 7:52:43 10656.0 7:52:55 10656.0 7:53:05 10656.0 7:53:15 10656.0 7:53:25 10656.0 7:53:35 10656.0 7:53:45 10655.0 7:53:55 I0656.0 7:54:05 i0656.0 7:54:I5 10656.0 7:54:25 10656.0 7:54:35 10656.0 7:54:45 10656.0 7:54:55 10656.0 7:55:07 10656.0 7:55:19 10656.0 7:55:29 10656.0 7:55:39 10656.0 9854.0 9854.0 9854..0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 PRESSURE (PSIA) 4853.79 4853.79 4853'80 4853.80 4853'.79 4853.79 '.485.3'80 4853~80 4853.80 4853,80 4853.80 4853.80 4853'79 4853.80 4853.79, 4853.80 4853.80 4853.79 4853.78 4853.78 4853.78 4853.77 4853.76 4853.77 4853.78 4853.79 4853.79 4853.79 4853.79 4853.79 4853.76 4853.78 4853.78 4853.77 4853.77 TEMP (DEG F) 207.93 207.93 207.93 207.93 207.93 207.93 207.93 207.93 Z07.93 207.93 207.93 207.93 207.93 207.93 207.93 207.92 207.93 207.93 207.93 207.93 207.93 207.93 207.92 207.92 207.92 207.93 207.93 207.93 207.93 207.92 207.92 207.92 207.92 207.92 207.92 PAGE COMP,ANY: STANDARD ALASKA PRODUCTION CO LOCATION: WELL: 1-5 / 0-20 MPI FIELD: TVD FLOWING GRADIENT PRESSURE SURVEY NORTH SLOPE ENDICOTT SURVEY BEG~N AT 6:28:15 ON 8/02/86 SUB-SE& DEPTH 9852.7 M~ASURED DEPTH 10718.0 DATE TiME M:DEP TVD PRESSURE TEMP (FEET) (FEET) (PSIA) (DEG F) 8/02/86 6:28:1'5 10718,0 9908,0 4879.61 207,27 8/02/86 6:28:26 10718.0 9908.0 4879.61 207.27 8/02/86 6:28:36 10718.0 9908.0 4879.77 208.20 8/02/86 6:28:46 10718,0 9908,0 48:79,78 208,20 8/02/86 6:28:56 10718,0 9908,0 4879,80 208,20 8/02/86 6:29:06 10718.'0 9908,0 4879,8! 208.20 8/02/86 5:29:16 10T18~'0'. 9908,0 4879,83 208.20 8/02/86 6:29:26 10718,0 9908,0 4879,85 208.20 8/02/86 6:29:36 10718,0 9908,0 4879,87 208,20 5/02/86 6:29:46 10718,0 9908,0 4879,88 208,20 8/02/86 6:29:56 10718,0 9908,0 4879,89 208,20 8/02/86 6:30:06 10718,0 9908,0 48'79,90 208,20 8/02/86 6:30:16 10718,0 9908,0 4879,91 208,20 8/02/86 6:30:26 10718,0 9908,0 48.79,92 208,20 8/02/86 6:30:36 10718.0 9908,0 4879,92 208,20 8/02/86 6:30:46 10718,0 9908,0 4879,92 208,20 8/02/86 6:30:56 10718,0 9908,0 4879,94 208,20 8/02/86 6:31:06 10718,0 9908.0 4879.94 208,19 8/02/86 6:31:16 10718.0 9908,0 4879,95 208,19 8/02/86 6:31:26 10718,0 9908.0 4879,96 208,19 ~/02/86 6:31:36 10718.0 9908.0 4879.96 208.19 8/02/86 6:31:46 10718,0 9908.0 4879,97 208,19 8/02/86 6:31:56 10718.0 9908.0 4879.98 208,19 8/02/86 6:32:06 10718,0 9908,0 4879.98 208.19 8/02/86 6:32:16 10718.0 9908.0 4879.98 208.19 8/02/86 6:32:26 10718.0 9908.0 4879.98 208.19 8/02/86 6:32:36 10718,0 9908,0 4879,99 208.19 8/02/86 6:32:46 10718.0 9908.0 4879.99 208,19 8/02/86 6:32:56 10718,0 9908.0 4879,99 208,19 ~/02/86 6:33:06 10715,0 9908.0 4879.99 208.19 ~/02186 6:33:18 10718.0 9908.0 4880,00 208.19 8/02/86 6:33:28 10718.0 9908.0 4880.01 208.19 8/02/55 6:33:38 10718.0 9908.0 4880,00 208,19 8/02/36 6:33:48 10718.0 9908.0 4880.00 208,19 8/02/86 6:34:00 10718.0 9908,0 4880,01 208,19 8/02/86 6:34:12 10718.0 9908,0 4880,01 208,18 8/02/86 6:34:22 10718,0 9908,0 4880,02 208,18 8/02/86 6:34:34 10718.0 9908.0 4880.02 208.18 8/02/86 6:34:44 10718.0 9908.0 4880,02 208,18 8/02/86 6:34:54 10718.0 9908.0 4880.02 208.18 ALASKA PAGE COMPANY: WELL: TVD DATE 8/02/86 8/02/96 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/56 8/02/86 8102/85 8/02/86 8/02186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8102/86 8102/86 8102/85 ,8102185 8102/85 8102/85 8102/86 8/02186 8102/86 8/02/26 8/02/85 STANDARD ALASKA PRODUCTION CO 1-5 / 0-20 ~PI LOCATION: NORTH SLOPE FIELD: ENDICOTT PLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 6:28:15 ON 8/02/86 SUB-SEA DEPTH 9852.7 MEASURED DEPTH 10?18.0 TIME M OEP TVD PRESSURE (FEET) (FEET) (PSIA) 6:35:04 10718.0 9908.0 4880.03 6:35:14 10718.0 9908.0 4880.03 6:35:26 10718.0 9908.0 4880.03 6:35:38 10718.0 9908.0 4880.03 6:35:48 10718.0 9908.0 4880.04 6:35:58 1071-8.0 9908.0 4880.04 6:36:10 107'18"0 9908.0 4880.04 6:36:20 10718.0 9908.0 4880,04 6:36:32 10718.0 9908.0 4880.04 6:36:42 10718.0 9908.0 4880.04 6:36:54 10718.0 9908.0 4880.04 6:37:04 10718.0 9908.0 4880.05 6:37:16 10718.0 9908.0 4880.06 6:37:26 10718.0 9908.0 4880.06 6:37:36 10718.0 9908.0 4880.05 6:37:46 10718.0 9908.0 4880.06 6:37:56 10718.0 9908.0 4880.06 6:38:06 10718.0 9908.0 4880.06 6:38:16 10718.0 9908.0 4880.06 6:38:26 10718.0 9908.0 4880.06 6:38:36 10718.0 9908.0 4880.07 6:38:48 10718.0 9908.0 4880.07 6:39:00 10718.0 9908.0 4880.06 6:39:10 10718.0 9908.0 4880.06 5:39:22 10718.0 9908.0 4880.06 6:39:32 10718.0 9908.0 4880.06 6:39:44 10718.0 9908.0 4880.06 6:39:54 10718.0 9908.0 4880.06 6:40:04 10718.0 9908.0 4880.06 6:40:14 10718.0 9908.0 4880.06 ,TEMP (DEG F) 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208,18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.18 208.17 208.17 208.18 208.18 6:40:26 10718.0 9908.0 4880.07 6:40:38 10718.0 9908.0 4880.06 6:40:48 10718.0 9908.0 4880.07 6:40:58 10718.0 9908.0 4880.07 6:41:08 10718.0 9908.0 4880.07 6:41:18 10718.0 9908.0 4880.07 5:41:30 10718.0 9908.0 4880.07 6:41:40 10718.0 9908.0 4880.07 6:41:50 10718.0 9908.0 4880.07 6:42:00 10718.0 9908.0 4880.07 208.18 208.17 208.17 208.17 208.17 208.17 208.17 '208.17 208.17 208.17 ALASKA PAGE COMPANY: WELL: STANDARD ALASKa PRODUCTION CO 1-5 / 0-20 MPi DATE 8/02/86 8/02186 8/02~86 8/02186 8/02186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02186 8102/86 8/02/86 8/02/85 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02/86 8~02/86 8102/86 8102185 8102/86 8102186 8102/86 8102/85 8/02/86 8/02/86 8/02/85 LOCATION: NORTH SLOPE ALASKA FIELD: ENDICOTT FLOWING GR&DZENT PRESSURE SURVEY SURVEY 5EG~N AT 6:28:15 ON 8/02/86 TVO SUB-SEA DEPTH 9852.7 MEASURED DEPTH TIME M OEP TVD (FEET) (FEET) PRESSURE (PSI. A) 6:42:10 10718.0 9908.0 6:42:22 10718.0 9908.0 6:42:34 10718.0 9908.0 6:42:46 10718.0 9908.0 6:42:58 10718.0 9.908.0 oHk8 6:43:18 10 " ....... 9908'0 6:43:28 10718.0 990.8-0 6:43:38 10718.0 9908'0 6:43:48 10718.0 9908.0 4880.07 4880.07 4880,07 4880.07 4880-07 4880.07 4880,07 .4880.07 6880.07 4880.07 6:43:5'8 10718,0 9908.0 6:44:08 10718,0 9908.0 6:44:18 10718-0 99'08'0 6:44:28 10718.0 .,99'08.0 6:44:38 10718.0 9908.0 6:44:48 10718'0 9908.0 6:44:58 10718.0 990:8.0 6:45:08 10718.0 9908.0 6:45:18 10718.0 99'08.0 6:45:28 10718.0 9908.0 4880-07 4880.0? 4880'08 4880.08 4880.07 4880-07 4880-07 '48'80.07 48.80.07 4880-07 6:45:40 10718.0 9908.0 6:45:52 10?18.0 9908.0 6:46:04 10718.0 9908.0 6:46:16 10718.0 9908.0 6:46:26 10718.0 9908.0 6:46:36 10718.0 9908.0 6:46:48 10718.0 9908.0 6:47:00 10718.0 9908.0 6:47:12 10718.0 9908.0 6:47:24 10718.0 9908.0 4880.07 4880.07 4880.06 4880.07 4880.07 4880.07 4880.07 4880.07 4880.08 4880.07 5:47:34 10718.0 9908.0 6:47:46 10718.0 9908.0 6:47:58 10718.0 9908.0 6:48:08 10718.0 9908.0 6:45:18 10718.0 9908.0 6:48:28 10718.0 9908.0 6:48:38 10718.0 9908.0 6:48:48 10718.0 9908.0 6:48:58 10718.0 9908.0 6:49:08 10718.0 9908.0 4880.07 4880.08 4880.07 4880.08 4880.07 4880.07 4880.07 4880.08 4880.08 4880.08 10718.0 TEMP (DEG F) 208,17 208'17 208,17 208,17 208.17 208,17 208,17 208,17 208,17 208.17 208.17 208-17 208,17 208.17 208,17 208,17 208,17 208.17 208.17 208.17 208'17 208,17 208.17 208,17 208.17 208.17 208,17 208.17 208.17 208.17 208.17 208.17 208.17 208.17 208,17 208,17 208.17 208.17 208,17 208.17 PAGE 10 COMPANY: WELL: STANOARD ALASKA PRODUCTION CO 1-5 ! 0-20 DATE 8/02186 8102186 LOCATION: NORTH SLOPE ALASKA FIELD: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 6:28:15 ON 8/02/86 TVD SUB-SEa DEPTH 9852.7 MEASURED DEPTH 10718.0 TIME M DEP (FEET) 6:49:18 6:49:30 10718.0 10718.0 , TVD (FEET) · ¢o8.o:, .~.,~o 8. o ' PRESSURE (PSIA) 48.80.08 ' ,.4880.07 TEMP (DEG F) 208.17' 208.17 PAGE 11 COMPANY: WELL: STANDARD ALASKA PRoDUcTION,CO 1-5 / 0-20 MPI FLOWING GRADIENT PRESSURE LOCATION: FIELD:' SURVEY NORTH SLOPE ALASKA ENDICOTT PAISE 12 TVD DATE 8/02/86 8102/86 8t02/86 8102/86 8102186 8/02/86 8/02/86 8/02/86 8/02/86 8t02/86 8/02/85 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102/86 8/02185 8/02185 8102135 8102186 8/02/86 8/02/86 8/02/86 8/02/36 8/02/86 8102/86 8102/85 8/02/35 8/02/86 8/02/86 8102/85 8/02/86 8/02/86 8/02/86 8/02/86 SURVEY BEGAN AT SUB-SEA DEPTH 9799-3 5:58:08 ON 8/02/86 MEASURED DEPTH 10656.0 TIME M'DEP (FEET) 5:58:08 10656.0 5:58:19 10656.0 5:58:31 10656.0 5:58:4! 106~'~.0 5:58:51 106 ~0 5:59:0'1 10656.,0 5:59:11 10656.'0 5:59:2I 10656.0 5:59:31 10656.0 5:59:41 10656,0 5:59:51 10656.0 6:00.:01 10656.0 6:00:11 10656.0 6:00:21 10656.0 6:00:33 10656.0 6:00:45 10656.0 6:00:57 10656.0 6:01:07 10656.0 6:01:17 10656.0 6:01:27 10656.0 6:01:39 10656.0 6:01:49 10656.0 6:01:59 10656.0 6:02:09 10656.0 6:02:19 i0656.0 6:02:29 10656.0 6:02:39 10656.0 6:02:51 10656.0 6:03:0i 10656.0 6:03:I3 10656.0 ,: 'TVD, .'(FEET) 9854.0 9854',0 98540 985'4:.0 9854'0 9854.0 9854,0 9854,0 9854,0 9854,0 9854.0 9854.0 9854,0 9854.0 ·9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 'PRESSURE ,.,(PSIA) 4853.48 4853.59 4853.60' 4853.60 4853.60 4853.60 4853.60 4853.60 :4853.60 4853.60 4853'61 4853.61 48.53.61 4853.60 ~4853.61 ·4853.61 '4853.61 4853.61 4853.61 4853.62 4853.63 4853.64 4853.65 4853.66 4853.65 4853.65 4853..65 4853.66 4853.66 TEMP (DEG F) 207.25 207-25 208.15 208.15 208,15 208.15 208.15 208.15 208.14 208.14 208.14 208.14 208.13 208..13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.13 208.1:3 208.12 6:03:25 10656.0 6:03:35 10656.0 6:03:47 10656.0 6:03:59 10656.0 6:04:09 10656.0 6:04:19 10656.0 6:04:29 10656.0 6:04:39 10656.0 6:04:49 10655.0 6:04:59 10656.0 9854,0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 4853.66 4853.66 4853.67 4853.66 4853.66 4853.66 4853.65 4853.66 4853.66 4853.66 208.12 208.12 208.12 208.12 208.12 208.12 208.12 208.12 208.12 208.12 COMPANY: WELL: TVD D4TE 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/85 8/02/86 8/02/86 8/02/85 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 9/02/~6 8/02/86 8102/85 8102/86 8102/86 8/02/86 ST4NDARD ALASKA PRODUCTION CO 1-5 / 0-20 MPI FLOWING GRADIENT PRESSURE LOCATION: FIELD: SURVEY NORTH SLOPE ENDICOTT ALASKA SURVEY BEGAN AT 5:58:'08 ON 8~02~86 SUE-SEA DEPTH S799.3 MEASURED DEPTH 10656.0 TIME M OEP PRESSURE (FEET) (PSIA) 6:05:09 10656.0 6:05:19 10656.0 6:05:31 10656.0 6:05:43 10656.0 6:05:53 10656.0 6:06:05 1065'6.0 6:06:15 10656.0 6:06:25 10656.0 6:06:35 10656.0 6:06:45 I0656.0 TV,D (FEET) 9854'o '9854-:0 985'4.0 .' 9854.0 · 9..854.0 :9'854° 0 9854.0 '9854.0 9854.0 9854.0 4853"66 4853.66 4853.66 4853'66 4853'66 4853'65 4853,65 4853.65 4853.65 4853.65 TEMP (DEG F) 208.12 208,12 208.12 208.11 208.11 208.11 208.11 208,11 208.11 208,11 6:06:55 10656.0 9854.0 4853.66 208.11 6:07:05 10656.0 9854.0 4853.66 208.11 6:07:15 10656.0 9854.0 4853.67 208..11 6:07:25 10656.0 9854.0 4853'67 208.1'1 6:07:35 10656.0 9854.0 4853.67 208.12 6:07:45 10656.0 9854.0 4853.67 208.12 6:07:57 10656.0 9854.0 4853.67 208.11 6:08:09 10656.0 9854.0 4853.67 208.11 6:08:2! 10656.0 9854.0 4853.66 208.10 6:08:31 10656.0 9854.0 4853.67 208.10 6:08:41 10656.0 6:08:53 10656.0 6:09:03 10656.0 6:09:13 10656.0 6:09:23 10656.0 6:09:35 10656.0 6:09:45 10656.0 6:09:55 10656.0 6:10:05 10656.0 6:10:15 10656.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 9.854.0 4853.67 4853-66 4853.67 4853.67 4853,67 4853.67 4853.67 4853..67 4853.67 4853.67' 208.10 208.10 208.10 208.10 208.10 208.10 208.10 208.10 208.10 208.10 6:10:25 10656.0 9854.0 4853.67 208.10 6:10:35 10656.0 9854.0 4853.67 208.10 6:10:45 10656.0 9854.0 4853.67 208.10 6:10:55 10656.0 9854.0 4853.67 208.10 6:11:05 10656.0 9854.0 6853.67 208.10 6:11:15 10656.0 9854.0 4853.67 208.10 6:11:25 10656.0 9854.0 4853.67 208.10 6:11:35 10656.0 9854.0 4853.67 208.10 6:11:45 10656.0 9854.0 4853.66 208.10 6:11:55 10656.0 9854.0 4853.67 208.10 PAGE '13 COMPAN¥~ WELL~ STANDARD ALASKA 1-5 / 0-20 MPI . PRODUCTION CO LocATION: FIELD: NORTH SLOPE ALASKA ,ENDICOTT FLOWING GRADIENT SURVEY BEGAN AT TVD SUB-SCA DEPTH 9799,3 PRESSURE SURVEY 5:58:08 ON 8/02/86 MEASURED DEPTH 10656.0 DATE 8/02185 8102185 8102/85 8/02/85 8/02/85 8/02185 8102186 8/02/86 8/02/86 8/02186 8/02/86 8102186 8/02/86 8/02/86 8/02/86 8/02/86 8102/85 8/02/86 8/02/8'6 8/02/86 8/02/86 8102/85 8102185 8/02186 TIME 6:12:05 6:12:15 5:12:25 6:12:35 6:12:45 6:12:55 6:13:07 6:13:17 6:13:27 6:13:37 6:13:47 6:13:57 6:14:07 6:14:~17 6:14:29 6:14:4! 6:14:51 6:15:01 6:15:11 6:15:21 6:15:31 6:15:41 6:15:51 6:16:01 M OEP (FEET) 10656.0 10656.0 10656.0 10656.0 10656.0 1065.6.0 106-56~0 10656.0 10656.0 10656.0 10656'0 10656.0 10656.0 10.656.0 10656'.0 10656-0 10656.0 10656.0 10656.0 10656.0 10656.0 10656.0 10656.0 10656.0 TVD PRESSURE TEMP (FEET) (PSIA) (DEG F) 9854.0 4853.67 9854.0 : 4853.66 9854.0 4853.6,7 9854.0 4853.67 9854.0 4853'68 '9854.0 4853.69 9854.0 4853.,69 "9854- 9854; "985'4.0 9854.0 9854.0 9854.0 9854.0 · 9854.0 9854.0 9.8514'0 9854.0 9854.0 9854.0 9854.0 9854.0 9854.0 0 ,:.~853.69 8'53-69' :4853'70 4853.69 .4853'70 .4853.'69 '4853.69 ,'4853,69 4853,69 4853.69 4853.69 'L 4853.69 4853.69 4853.69 4853.69 208,10 2.08,10 208,10 208,10 208'10 208,10 208,10 208,10 208,10 208,09 208.09 208.09 208.09 208.09 208.09 208.09 208.09 208.09 208°09 208.09 208.09 208.09 208.09 208,09 PAGE 14 COMPANY: STANDARD ALASKA PRODUCTION CO NELL: 1-5 / 0-20 MPI LOCATION: NORTH SLOPE ALASKA FIELD: ENDICOTT FLOWING GRAOIENT SURVEY BEGAN AT TVD SUB-SEA DEPTH 9700.2 PRESSURE SURVEY 5:28:03 ON 8/02/86 ME~SU.R.ED DEPTH 10545.0 DATE 8102186 8102186 8102/86 8/02186 8102186 8102/8'6 8/0 Z/86 8/02186 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/$6 8102/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/85 8/02/86 TIME M DEP (FEET) 5:28:03 10545.0 5:28:14 10545.0 5:28:24 10545.0 5:28:34 10545.0 5:28:46 10545.0 5:28:56 1054'5,~..0 5:29:08 10545.'.0 5:29:18 1.05'45.0 5:29:2'8 10545.0 5:29:38 10545.0 5:29:48 10545.0 5:29:58 10545.0 5:30:08 10545.0 5:30:20 10545.0 5:30:30 10545.0 5:30:40 10545.0 5:30:50 10545.0 5:31:00 10545.0 5:31:10 10545.0 5:3,1:.,20 10545.0 5:31:30 10545.0 5:31:40 10545.0 5:31:50 10545.0 5:32:02 10545.0 5:32:14 10545.0 5:32:26 10545.0 5:32:36 10545.0 5:32:46 10545.0 5:32:56 10545.0 5:33:06 10545.0 5:33:16 10545.0 5:33:26 10545.0 5:33:36 10545.0 5:33:48 10545.0 5:33:58 10545.0 5:34:08 10545.0 5:34:18 10545.0 5:34:28 10545.0 5:34:38 10545.0 5:34:48 10545.0 TVD PRESSURE (FEET) (PSIA) 975.5.0 4804.'98 9755.0 , 4804:,.98 9755.0 4805"01 975.5,0..' '.~ 4805'02 L9.'.75:5, 0 .:....~ ..i....:.:~: ~ 80.5 ',.0.2 975'5 '~ 0 :..::..' :. '.;' ."4805 ':'02 97 55.. 0'" ..> 4 805 .:, 02 9755.0 4805;02 9755.0 4805."02 9.755.0 :' .-" 48'05.01 .9755.0 4805.01 9755.0 .4805.02 9755.0 4805.02 ,975.5,. 0 ': 4805,02 975.5.0 4805.02 9755°0 4805.01 9755.0 4805,01 9755.0 -'" 4805.01 975'5.0 4805.02 9755.0 4.805.02 9755.0 .'4805,.01 9755.0 '.4805.01 9755.0 4805.01 9755.0 ,4805.01 9755.0 4805"00 9755.0 4805.00 9755.0 4805.00 9755.0 4805..01 9755.0 4805.01 9755.0 4805.01 TEMP (DEG F) 204.34 204.34 204.63 204.63 204.62 204.63 204.63 204.63 204.62 204.62 204.62 204.62 2.04.62 204.62 204'.62 204.62 204.63 204.62 204.6'2 204'.62 204.62 204.62 20'4.62 204.62 204.62 204.62 204.61 204.63 204.62 204.62 9755.0 4805.00 204.62 9755.0 4805.00 204.62 9755.0 4805.01 204.62 9755.0 4805.02 204.62 9755.0 4805.02 204.6! 9755.0 4805.02 204.62 9755.0 4805.00 204.62 9755.0 4805.02 204.62 9755.0 4805.02 204.63 9755.0 4805.02 204.62 PAGE 15 COMPANY: WELL: TVD DATE 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8/02/86 8102186 8/02/86 8/02/86 8102/86 8/02186 8/02/86 8/02/86 8/02/86 8/02186 8/02/86 8/02/86 8102186 8/02/86 8102/86 8102/86 8102/85 8102/86 8102/86 8102/86 8102/86 5102186 8102/85 8102186 S/02/86 8/02/~6 3/0£/~5 5102135 5102135 8102/85 8/02/~,5 8/02/55 5/02/85 STANDARD ALASKA PRODUCTION CO 1-5 / 0-20 MPi LOCATION: NORTH SLOPE FIEL'D: ENDICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 5':28:03 ON 8/02/86 SUB-SEA DEPTH 9700.2 MEASURED DEPTH zo 4 .o TIME M DEP TVD PRESSURE (FEET) (FEET) (PSIA) 5:34:58 10545.0 9755.0 4805.01 5:35:08 10545.0 9755.0 4805.01 5:35:18 10545.0 9755.0 4805,02 5:35:28 10545.0 9755.0 4805.00 5:35:38 10545.0 9.755.0 4805.00 5:35:48 105,~',5,.0 9755.0 4805.00 5:35:58 10545.0'- 9755.0 4805.01 5:36:10 10545.0 9755.0 4805.01 5:36:20 10545.0 9755.0 4'805.01 5:36:30 i0545.0 9755.0 4805.00 5:36:40 10545,0 9755.0 4805.01 5:36:50 10545.0 9755.0 4805.00 5:37:00 10545.0 9755.0 4805.01 5:37:10 10545.0 9755.0 4805.02 5:37:20 10545.0 9755.0 4805.02 5:37:30 10545.0 9755.0 4805.02 5:37:40 10545.0 9755.0 4805.03 5:37:50 10545.0 9755.0 4805.03 5:38:00 10545.0 9755.0 4805.03 5:38:12 10545.0 9755.0 4805.03 5:38:22 10545.0 9755.0 4805,02 5:38:32 10545.0 9755.0 4805.02 5:38:42 10545.0 9755.0 4805.02 5:38:52 10545.0 9755.0 4805.02 5:39:02 10545.0 9755,0 4805.02' 5:39:12 10545.0 9755.0 4805.02 5:39:22 10545.0 9755.0 4805.02 5:39:32 10545.0 9755.0 4805.03 3:39:42 10545.0 9755.0 4805.02 5:39:52 10545.0 9755.0 4805.02 3:40:02 10545.0 9755.0 4805.02 5:40:14 10545.0 9755.0 4805.02 5:4~:26 10545.0 9755.0 4805.02 5:&0:35 105&5.0 9755.0 4805.02 5'a0:45 10545.0 9755.0 4805.04 5:40:58 10545.0 9755.0 4805.04 5:41:03 10545.0 9755.0 4805.03 5:&l:l~ 10545.0 9755.0 4805.03 5:41:£$ 10545.0 9755.0 4805.00 5:~1:3~ 10545.0 9755.0 4805.00 TEMP (DEG' F) 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.63 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.63 204.62 204.62 204.6I 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.62 204.61 204.62 204.51 204.6.2 204.62 204.51 204,62 204.62 ALASKA PAGE 16 TVD DATE STANOARO ALASKA PRODUCTION CO LOCATION: NORTH SLOPE ALASKA 1-5 / O-ZO HPi FIELO: ENOICOTT FLOWING GRADIENT PRESSURE SURVEY SURVEY BEGAN AT 5:28:03 ON 8102186 SUB-SEA DEPTH 9700.2 MEASURED DEPTH 10545.0 TIME M OEP TVD PRESSURE TEMP (FEET) (FEET) (PSIA) (DEG F) 8/02/86 5: 8/02/86 5: 8/02/86 5: 8/02/86 5: 8/02/86 5: 8102/56 5: 8/02186 5: 8/02/86 5: 8102186 5: 8/02/86 5: 8/02/85 5: 8/02/86 5: 8/02/86 5: 8102186 5: 8~02~86 5: 8/02/86 5: 8102186 5: 8/02/86 5: 8/02/86 5: 8/02/86 5: 8/02/86 5: 8/02/86 5: 8/02186 5: 8/02/85 5: 8/02186 5: 8102/86 5: 8/02/86 5: 8/02186 5: 8102/86 5: 8/02/85 5: 8102/86 5: 8702/36 5: 8/02/86 5: 8/02/86 5: 5/02/86 5: 8/02/86 5: 8/02/86 5: B/02/86 5: 8/02/86 5: 8/02/~6 5: 41:48 10545.0 9755.0 4805.00 204.61 41:58 10545.0 9755.0 4805.00 204.62 42:08 10545.0 9755.0 4805.00 204.62 42:18 10545.0 9755.0 4805.00 204.62 42:30 10545.0 9755.0 4805.01 204.62 42:40 10545.0 9755.0 4804.99 204.62 42:50 10545.0 9755.0 4805.00 204.62 43:00 105.45.0 9755.0 4805.00 204.52 43:!0 10'545,0 9755.0 4805.00 204.62 43:20 10545.0 9755.0 4805.00 204.62 43:30 10545.0 9755.0 4804.99 204.52 43:40 10545.0 9755.0 4804.99 204.61 43:52 10545.0 9755.0 4805.00 204.62 44:02 10545.0 9755.0 4805.00 204.61 44:14 10545.0 9755.0 4805.00 204.61 44:24 10545.0 9755.0 4805.00 204.61 44:36 10545.0 9755.0 4805.00 204.61 44:46 10545.0 9755.0 4805.00 204.62 44:56 10545.0 9755.0 4805.00 204.62 45:06 10545.0 9755.0 4805.00 204.62 45:16 10545.0 9755.0 4805.00 204.62 45:26 10545.0 9755.0 4805.00 204.62 45:36 10545.0 9755.0 4805.00 204.61 45:46 10545.0 9755.0 4805.01 204.61 45:58 10545.0 9755.0 4805.00 204.61 46:10 10545.0 9755.0 4805.00 204.62 46:20 10545.0 9755.0 4805.00 204.62 46:30 10545.0 9755.0 4805.00 204.51 46:40 10545.0 9755.0 4805.00 204.62 46:50 10545.0 9755.0 4804.99 204.61 47:00 10545.0 9755.0 4805.00 204.61 47:10 10545.0 9735.0 4804.99 204.61 47:20 10545.0 9755.0 4804.99 204.62 47:30 10545.0 9755.0 4805.00 204.61 47:40 10545.0 9755.0 4805.00 204.61 47:50 10545.0 9755.0 4805.00 204.61 48:00 10545.0 9755.0 4805.00 204.62 43:10 10545.0 9755.0 4804.99 204.61 48:20 10545.0 9755.0 4805.00 204.52 49:30 10545.0 9755.0 4805.01 204.62 PAGE 17 C2MP~N¥: ST~',]C:;~F~C ~,LASK~ ~,iELL: 1-:' / 0-20 !,1PI PRODUCTION CO LOC~TION: fIELD: NCRTH SLOPE ENDICOTT ~LASKA 18 TV"J PRESSURE SURVEY DEPTH 9700.2 5:28:03 ON 3/02/$5 ¢,tE&SUR~D DEPTH 10545.0 TIM~ M DEP ;~/32/66 5:43:40 10545.0 8/02/~5 5:a~:52 10545.0 ~.,°102/°6~ ~/0£/,{6 5:~9:i~ 10545.0 ,$/02/56 5:4'~:26 13545.0 ~/0Z/.~6 5:49:4~ 10545.0 2/01/~6 5:~:5~ 10545.0 ,{,/02/~6 5:50:10 10545.0 ~/02/B~ ...... ~45.0 °-./02136 5:=~0:30 10545.0 '~/3Z/B"r~ 5:50:40 13545.0 3/02/~5 5: 50:50 10545. 0 ~.1 C, 2/'~ 5 5: 5i: O0 10545.0 ~,/02/86 5:51: I0 10545.0 8/02/~6 5: 51: 20 10545.0 ~/02/~6 5: 51:32 10545.0 8/02/86 5: 51: 42 10~45.0 [/02/~6 5: 51:52 10545.0 ~/02/~6 5: 52: 02 10545.0 .,.{102186 ~/C, 2/86 i;/02156 5102136 {/02/~6 3/02/~6 '-'- 1 O Z/~ 6 5/02/~6 5:~2:12 10545.0 5:52:22 10545.0 5:52:32 10545.0 5:52:42 10545.0 5:52:52 !,3545.0 5:53:02 10545.0 5:53:12 10545.0 =:5~:22.. ~ i~545.0 5:53:32 10545.0 }:53:~1 10~45.0 TVD PR ES SUP E (FEET) (mSIA) TEMP (D8G ~) 9755.0 4804.9'9 204.60 9755.0 4804.99 204.50 9755.0 4804.98 204.60 9755.0 4804.99 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4305.00 204.51 9755.0 4B05.00 204.61 9755.0 4804.9~ 204.61 9755.0 4804.98 204.61 9755.0 4804.99 204.61 9755.0 4504.98 204.61 ~755.0 4804.9~ 20~.6! 9755.0 4504.99 204.61 9755.0 4804.~ 204.61 9755.0 4804.99 204.62 ~755.0 4905.C'3 204.62 9755.~ ~804.99 204.61 9755.0 4804.99 204.61 9755.0 4804.9') 204.61 9755.0 4804.98 204.61 9755.0 4904.9~ 204.60 9755.0 4804.99 204.61 9755.0 4805.00 204.60 '~755.0 4805.00 204.60 9755.3 4B04.98 204.60 9755.0 4804.99 204.61 9755.0 4B05.00 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4805.00 204.61 9755.0 4804.99 204.62 9755.0 4B04.99 204.61 9755.0 4804.99 204.61 9755.0 4804.~9 204.61 9755.0 4804.99 204.61 9755.0 4804.9~ 204.61 C iD ~.! p .& ,N Y: W:LL: ST-~,;C,:lq2 ~L-flSKA PROCUCT!DN CC, LOCATZON: NSRTH SLCPE i-5 / 6-20 ~.IP~' FZELD: 6NSZCOTT &L$,SKA 19 '~.'.::'v':¥ ~.:"%:~N .~,T ~'2_~,:03 r2N 6/C2185 TV,.) SU"-,S-i, ~[-:.FTM 9700.2 ,V,E..qsuqE9 DEPTH 105~,5.0 :J102/36 $/02/35 ~.:,f'~ :'/36 9t02/~.~ J/OZ/S6 3102136 9102186 Sf02/85 8102136 8/0£186 8/02/85 8102/85 S/02/35 6,/02/36 ,~/']2/~5 ~./32/8~ 3102155 31:221.56 'q/0£/~6 ~/0£/36 '3/2,2/$~ ~/OZ/~ TVO PRESSURE (FEET) (PSIA) 5:53:3~ 105~5.0 9755.0 4804.99 5:5::~t 10545.0 9755.0 4805.00 5:55:5~ 10545.0 9755.0 4804,99 5:56:0..:~ 105a5.,3 '9755.0 4804.98 5: 5.6' i~ 10545.0 9755.0 4804.9,~ 5: 5~:2S 105,45.0 9755.0 4805.00 5:56:40 1~545.0 9755.0 4B05.00 ~: 55:52 10545.0 9755.0 5:57:02 10545,0 9755.0 4805.00 5:57:12 13545,0 9755,0 4804.99 5:~7:22 10545.0 9755.0 4805,00 5:57:32 i0545.0 9755.0 4805.00 5:57:42 10545.0 9755.0 5:57:52 10545.0 9755.0 5:5~:02 10545.0 9755.0 4805.00 5:5~:12 10545.0 ~755.0 ~804.99 5:58:22 105a5.0 9755.0 4804.99 5:J:~:32 10945.0 9755.0 4804.99 5:5:::42 10545.0 9755.0 4805,00 5:59:52 105a5.0 9755.0 4504.98 5'59:02 1.3545,0 '9755.0 4804,97 ~:59:12 !0~45.3 9755.C 4804.98 5:59:25, i95a5.0 9755,0 4804.98 5'5%:22 !0545.0 ~755.0 4~04.97 5'59:44 5:59'5~ 1'~545.0~ '9755 .0 4804 .97 5:00:06 10545.0 9755.0 4804.97 5:~0:i~ 1 ~ 545 0 9755 0 4804 98 6:']0:~'~ 1~5~5~ .0 9755.0 4804.98 ~:'2, j:~? i054 - .,.~, 97~5.0 4904.9~ ;'00'52 '"' . , . ~545 O 9755 0 4304 97 ~ :"1' 02 I0545.0 9755°0 4804.97 5:'i'!a 10545.0 9755.0 4~30q.98 ,6:$i:£~ 19545.0 9755.0 4804.98 5'31'~ 10545.0 9755.0 480~.93 ~'0~:~~ ,_ i3:~.0 ~755, .0 4804.9~ ~ _ o~ .~ 9755 0 4804 98 5'0':06 I0~5.0 9755.0 4804.97 5:J2'1~ 10545.0 9755.0 4804.96 ~:~1:2~ 105a5.0 '9755.0 4804.97 TEMP (DEG ~) 204.61 204.61 204.61 204.51 204.61 204.61 204.51 204,60 20z,.60 204.60 204.60 204.61 204.61 204.61 204.62 204.61 204.61 204.60 204.60 204.60 204.60 204.6O 204.51 204.61 204.60 ~4 60 '204,60 204.60 204.50 204.60 204,60 204.60 204.60 204.60 204.60 204,60 204.50 204.60 204.61 204.60 N 0 h'~ T ,'-t SLCPE ~L~SKS (~:--T) (F::ET) (PS'A) · ~, : · .], ~ -_ ,- . '.: .., :4.5 i0::~.~.0 ~755..,.,., ~';]' 'S,-;, 'l :,)5&5 0 973~.0 ~ ' :3:0' i']~4:',.0 5795.0 4:..304..9 -,: '3' .I.,:: i,.',: ~5." '975~.C, 4~0&.~5., · : }?: ; ' l:}Sz~ 5. O ,4,'7-35.,'3 '~BO4.ST ~:-' "'-: '-,-,] 1"2 :'.;5.3 97_55.0 4804.97 t,:'3' '.3 } i,]:aS.O 975;.0 ~804..98 5':3.' 03, 13545.3 9755.0 ~80a.97 ~ : 3-,,' 1- I }l:4b.'3 '9755.0 ~,S04.9o :_ ":~' 3.~ lO' c5.0 ~7:,5.0 4.804.97 -: ~ :. ' I 5 i ,_", 54. 5.0 ':)755. C, ,:,-8.34.98 5','3~'2~ i'35a~.O 97E5.3 483z..9~ · · "~5~5 O '-5755.u 4~0~ 9,~ ~ ' ' .-3: ~.c : ~' :' ~- 5.. 2 9755. C 4504.98 < ' - - ' 35 i 35->. O ¢7 -5.0 4~04. 9 5 :' '7'- ' 1:}~5.3 9755.0 ~6,34.98 -:~7 _~ /:5~.q. 5755.0 ~04, .~9. --.' '2 7' N2 1354" C 9755.0 4:~04.93 : :.: 7: f ,, l:.: :; 5. O 975.5. O ~+ 504.9 ~ - ' C:: ~- 125~.' 5.0 975,:.,.:.', 4804..9.: T '" MP (3 ~_ S = ) 204.50 2'3~. 50 ~04 60 204. 50 20~.61 204.,51 2or+. 5o 20~.59 204.50 20..50 204.50 2 ~ ~.59 20~,.50 2OZ.. 60 r04.60 20".60 23~. 50 iO~.6C 204.,-30 20". 50 20,:,-. 6,3 204.60 204..50 20/-.,-. ,50 20/-+.60 20~.59 204..50 20~.59 £04..51 STANDARD ALASKA PRODUCTION COMPANY DRILL ING DEPARTMENT DAILY P.E. REPORT = ENDICOTT 0001 HRS TO 2400 HRS, 7-15-86 WELL' 0'20 ' OPERATIONS: Pulled dummy bail valve. Ran bailer and drift run to PBTD. .- STANDARD ALASKA PRODUCTION COMPANY DRILL ING DEPARTMENT DAILY P.E. REPORT : ENDICOTT O001HRS TO 2400 HRS, 7-20-86 WELL' M-19 and 0-20' OPERATIONS' Rig up test equipment for production well test. STANDARD ALASKA PRODUCTION COMPANY DR ILL I NG DEPARTMENT DAILY PiE- REPORT = ENDICOTT O001 HRS TO 2400 HRS, 7-31-86 WELL' 1-5/0-20 ' OPERATIONS' Rigging up.tes~..equipment. STANDARD ALASKA PRoDuCTIoN COMPANY DRILL ING' DEPARTMENT ~ DAILY P.E. REPORT : ENDICOTT .O001 HRSI TO 2400 HRS, 8-01-86 WELL' 1-5/0-20 . OPERATIONS' Continue rig up. for flow test. · STANDARD ALASKA PRODUCTION COMPANY DRILL ING DEPARll4ENT DAILY PiE. REPORT : ENDICOTT .O001 HRS TO 2400 HRS, 8'02-86 WELL' 105/0-20 OPERATIONS' Complete well ..test rig up. Perforate well.- STANDARD ALASKA PRODUCTION COMPANY DRILLING DEPARTMENT DAILY P';E; REPORT : ENDICOTT .0001 HRS TO 2400 HRS, 8-03-86 . WELL: 1-.5/0-20 - - OPERATIONS: Complete perfor.;ati_ng, Run cased hole logs. Start well test. STANDARD ALASKA PRODUCTION COMPANY DRILL ING DEPARTMENT DAILY P'E. REPORT = ENDICOTT .0001 HRS TO 2400 HRS, 8-04-86 WELL:. 1-5/0-20 OPERATIONS· Continue well test. · · STANDARD ALASKA PRODUCTION COMPANY DRILL ING DEPARTMENT DAILY P.E. REPORT = ENDICOTT 0001' HRS TO 2400 HRS, 8-04-86 WELL' 1-5/0-20 , OPERATIONS' Flow test well Standard A,aska Production Compare 900 East Benson Bouk, J P.O. Box 196612 Anchorage, Alaska 99519-6612 (907} 564-5111 STANDARD ALASKA PRODUCTION July 14, 1986 William Van Alert Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 0-20 July 4, 1986 Run I t of sepia prints, 1 set of blueline prints: imulteneous Dual Laterolog Micro-SFL imulteneous Compensated Neutron-Litho Density rray Sonic atural Gamma Ray Spectrometry Log ual Dipmeter ased Hole GR + OH tape & listing-DLL/LDT/NGT/STC/CNL Sincerely, Laura Fujik~a LAF:plW Received by Date A unit of the original Standard Oil Company 003 9~l~J in Cleveland, Ohio, in 1870. Standard Alaska .... Production Compan~ 900 East Benson Boulevc, rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION July 16, 1986 William Van klen Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print: 0-20 July 7, 1986 Run 2 o Cement Bond Tool o GCT Directional Survey Sincerely, LAF:plw Received by Date A unil of the original Standard Oil Company 0039~fn~ed i~ Cleveland. Ohio, in ~870. WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well ~-/",,~z Gas Supply/ Injection Wel~ OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Name of Operator 7. Permit Number Standard Alaska Production Company 86-106 3. Address 8. APl Number P. O. BOX 196612 Anchorage Alaska 99519-6612 50-029-21605 4. Location of well at surface 9. Unit or Lease Name 1945' SNL, 2038' WEL, Sec. 36, T12N, R16E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 0-20 MPI At Total Depth 11. Field and Pool 1993' SNL, 835' EWL, Sec. 31, T12N, R17E Endicott Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Endicott Oil Pool KBE = 55.30'I ADL 312828 1'2. Date Spudded6_6_86 13. Date T.D. Reached7_4_86 14' Date C°mp'"Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns7-9-86 N/A feet MSL one 17. Total Depth (MD+TVD) i18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set ] 21. Thickness of Permafrost 11266 ' MD 10395 ' T~ZD 11177 ' MD YES ~ NO [] 1506 feet MDI 1410 ' SS 22. Type Electric or Other Logs Run CBT, GCT, DLL/MSFL, LDT/CNL, Array Sonic, NGT, Dual Dipmeter, Cased Hole GR ,.. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" StrlLctural DJ:ire Pipe Surface 131' DRIVE 13-3/8" 72# L-80 Surface 2499' 17%" 2100 cu ft. Permafr¢,st 9-5/8" 47~ NTSOS Surface 5477 ' 12g" 9-5/8" 47# NT95HS 5477' 10388' 12%" 425 cu. ft. Class G4 .75%CFR-2+.15%HR7 ._7" 290 L-80 10123' 11258' 8%" 458 cu. ft. Class G~/ .5% Halad344+LW 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10,622-'10,668' MD BKB ~" 9.2~ TI-80, ]0055'MD IO071'MD 7" 26~ L-[ 0 IJ4S Heater Strinq Surface to 3Z 9,768.'~9809' TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4 shots per foot DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9--5/8" x 13-3/8" Downsqueeze 9-5/8" x 13-3/8" annulus with 345.5 sx. Perma. frost_ cement followed bv " .. ]]5 bbl~ 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) R- 3-~6I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8/3&8/5/8~ 37 TEST PERIOD ~ 184 6210 0 21/64I 30,000 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 3360 3000 24-HOUR RATE ~ 265BPD 8300 - 49© @ 64© F 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ? :81' ~rm 10~,07 Submit in duplicate ,V. 7-1-80 CONTINUED ON REVERSE SIDE ~ [ ~ ./; ~ : -, . .'.' . '. :,. .. : .': , . ~.-": ,'; - '- - ~ ".GEOLOGICMARK-ERS ~' . ~ ' ' ' ' FORMATION TESTS · . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. LCD 10408' 9575 ' Top Kekik 10408 ~ 9575' BSMT 11200' 10273' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division ~~/~ Drilling ~~~ Signe ~ ~~' Title Engineer Date.. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". .Form 10-407 S APC Daily Drilling Report - - Endicott June 6,1986 at 0600 hours Rig: Doyon # 15 AFE# 717509 Well: 0-20 APl# 50-029-21605 0600 Depth: Day: - 1 24-Hour Ftg: .... Current Operation: Make uP BHA. 24 hour Summary: Move rig to 0-20. Rig up. Take on spud mud. Note: Accept rig (~ 2300 hrs. 6/6/86 Mud Type: Spud Wt:--- Vis:-- PV:-- YP:-- FL:-- Solids:--% Temp:--F Survey MD An_ele Direction TVD Section Coordinates DLS SAPC Daily Drilling Report - - Endicott June 7,1986 at 0600 hours Rig: Doyon # 15 AFE# 717509 Well: 0-20 APl# 50-029-21605 0600 Depth: 2510 ft. Day:l 24-Hour Ftg: 2430 ft. Current Operation: POH to run 13-3/8 in. casing. 24 hour Summary: Drill 17-1/2 in. hole to 960 ft. Trip for bit. Drill to 2510 ft. Conduct short trip. Note: Spud well o 0630 hrs 6/6/86 Mud Type: Spud Wt: 9.9 Vis: 300 PV:-- YP:-- FL:-- Solids:--% Temp:-- F Survey MD Angle l~ TVD Section Coordinate~ DLS SAPC Daily Drilling Report - - Endicott June 8,1986 at 0600 hours Rig: Doyon # 15 AFE# 717509 Well: 0-20 APl# 50-029-21605 0600 Depth: 2510 ft. Day: 2 24-Hour Ftg: ..... ft. Current Operation: Nipple up. 24 hour Summary: RIH 62 jts. 13-3/8 in. casing. Cement with 2190 sks Permafrost cement at 15.0 ppg with returns to surface. Back out landing joint. Note: Float shoe ~ 2499 ft. Float collar ~ 2456 ft. Mud Type: Spud Wt: 9.7 Vis: 150 PV:-- YP:-- FL:-- Solids:--% Temp:-- F Survey MD Aag~ Dir=e_cldg_a TVD Section Coordinates 'DiS SAPC Daily Drilling Report - - Endicott June 9,1986 at 0600 hours Rig: Doyon # 15 Well: 0-20 AFE# 717509 APl# 50-029-21605 0600 Depth: 2510 ft. Day: 3 24-Hour Ftg: ..... ft. Current OPeration: Nipple up. 24 hoUr Summary: Install starting head. Nipple up BOPE. Note: RT to BF: 39.70 ft RT to GL: 40.76 ft Mud Type: Gel benex. Wt: 9.0 -Vis: 38 PV:-- YP:-- FL:-- Solids:--% Temp:-- F Survey MD An_~le Direction TVD Section Coordinates DLS · Sohio Daily Drilling Report -- ENDICO1-F June 10, 1986 at 0600 hours Rig: Doyon Well: 0-20 AFE # 717509 API# 50-029-21605 Current Operation: RIH. 0600 Depth: 3319' Day: 3 24-Hour Ftg: 809' Test BOPE. Tag cement at 2450 ft. and test casing to 3000 psi. Drill out cement and float equipment and l0 ft. of new hole. Conduct leak off test to 12.8 ppg EMW. Drill 12-1/4" hole to 3319 ft. Trip for bit. MUD TYPE-Gel Benex WT:9.2 VIS:35 PV:6 YP:5 FL:20 SOLIDS:3 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0932H: Rig: Doyon //15 Wel 1 · 0-20 Sohio Daily Drilling Report -- ENDICOTT June l l, 1986 at 0600 hours AFE # '717509 API// 50-029-21605 0600 Depth' 4927' ' Day' 5 24-Hour Ftg' 1608' Current Operation: RIH, RIH. Drill 12-1/4 in. hole to 4927 ft. Trip for bit. MUD TYPE-Gel/Benex WT:9'5 VIS:37 PV:8 YP:6 FL-10 SOLIDS:5 TEMP' °F SURVEY MD ANGLE .DIRECTION TVD SECTION COORDINATES 0932H' DLS Rig D°Yon #15 Wel 1_': O' 20 Sohio Daily Drilling Report -- ENDICOTT June 12, 1986 at 0600 hours AFE # 717509 API# 50-029-21605 Current .Opera ti on' Drilling. 0600 Depth' 5505' Day: 6 24-Hour Ftg: 578' Drill 12-1/4 in. hole to 5400 ft. Trip for bit, kick-off BHA, and mud motor. Orient and directionally drill 12-1/4 in. hole to 5505 ft, MUD TYPE-Gel/Benex WT:gj6 VIS'45 PV-IO YP-12 FL'9.8 SOLIDS-6 TEMP-66°F ~-SDRVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 0932H- DLS Sohio Daily Drilling Report -- ENDICOTT June 13, 1986 at 0600 hours Rig: Doyon Wel 1: 0-20 #15 AFE # 717509 API# 50-029L21605 0600 Depth: 6143' Day: 7 24-Hour Ftg: 638' Current Operation: Drilling. Orient and mud motor drill 12-1/4 in. BHA and bit change. Drill to 6143 ft. hole to 5880 ft. Trip for MUD TYPE-Seawater WT:9:6 VIS:38 PV:IO YP:5 FL:7.8 SOLIDS:7 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 2 5351 3 5458 4 5552 5 5647 7 5830 9 6040 1:8 N25W 1:4 N40E 3:3 N80E 5:8 N83E 10:6 N85E 15:.1 N86E 5351 -.70 N1.44 W67 5458 --.36 N4.40 W28 5552 2.86 N6.14 E2.97 5647 10.30 N7.25 E10.43 5828 36.29 N9.96 E36.48 6032 82.94 N14.25 E83.21 DLS 1.8 1.8 2.5 2.6 2.5 2.1 0932H: Sohio Daily Drilling Report -- ENDICOTT June 14, 1986 at 0600 hours Rig: Doyon #15 Wel 1: 0-20 AFE # 717509 API# 50-029-21605 0600 Depth: 6940' Day: 8 24-Hour Ftg: 797' Current Operation: POH. Drill 12-1/4" hole to 6645 ft. POH. Change BHA. RIH. Drill to 6940 ft: MUD TYPE-SW-Ligno. WT:9.7 VIS:43 PV:16 YP:IO FL:5.8 SOLIDS:8 TEMP:74°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 10 6135 12 6322 14 6510 16 6700 18 6891 16j9 N89E 6124 109 N15.39 EllO 2.2 20j 4 S88E 6301 169 N14.57 E169 1 . 9 25~ 7 S86E 6474 242 N10. 72 E242 3.2 30~ 4 S83E 6633 327 N1 . 97 E327 2.4 35 ~ 8 S81 E 6793 430 S12.53 E430 2.9 0932H: Sohio Daily Drilling Report -- ENDICOTT June 15, 1986 at 0600 hours Rig' Doyon #15 Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 0600 Depth' 7051' Day: 9 24-Hour Ftg: llO' Current Operation' Drilling. POH'- RIH with mud motor and drill 12-1/4" hole to 7034 ft. Lost 300 psi pump pressure. POH. RIH with new motor and drill to _7051 ft' MUD - TYPE'SW-Li gno. wT-9'7 VIS:39 PV-15 YP'9 FL:5.6 SOLIDS'8 TEMP'76°F SURVEY 19¸ MD ANGLE 6985 37~-1 D I RECT I 0 N TVD SECT I 0 N COORD I NATES S82E 6868 485 S20.91 E485 DLS = 1.6 0932H' Sohio Daily Drilling Report-- ENDICOTT June 16, 1986 at 0600 hours Rig' Doyon #15 Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 0600 Depth: 7248' Day: l0 24-Hour Ftg: 197' Current Operation: Drilling. Drill 12-1/4" hole with mud motor building angle and direction. POH~ Change BHA. RIH. MUD TYPE-SW-Ligno WT:9,6 VIS:38 PV-13 YP:8 FL'5.6 SOLIDS-6 TEMP'64°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 20 7065 36-7 21 7178 36' 5 S88E 6932 533 S25. O0 E533 3.4 N87E 7023 601 S24.41 E600 3.4 0932H- Rig' Doyon #15 Well: 0-20 Sohio Daily Drilling Report -- ENDICOTT June 17, 1986 at 0600 hours AFE # 71 7509 API# 50-029-21605 0600 Depth: 7762' Day: ll 24-Hour Ftg: 513' Current Operation: Drilling. Drill 12-1/4" hole to 7762 ft. MUD TYPE-S.W. Li§no WT:9.7 VIS:40 PV:14 YP:9 FL:5 SOLIDS:7 TEMP:80°F SURVEY MD ANGLE DIRECTION TVD 22 7357 36.2 N85E 7176 23 7541 36.7 N86E 7324 SECTION 711 820 COORDINATES S17.38 E711 S8.80 E819 0932H: DLS .7 .4 Sohio Daily Drilling Report -- ENDICOTT June 18. 1986 at 0600 ~ours Ri g' Doyon Wel 1 · 0-20 #15 AFE # 717509 . AP I # 50-029- 21605 0600 Depth: 8196' Day' 1 2 24-HOur Ftg: 442' Current Operation' Drilling. Drill 12-1/4" hole to 8196 ft, MUD TYPE-S.W. Ligno WT:9.8 VIs:40 PV'15 YP-9 FL-5.0 SOLIDS:8 TEMP:80°F SURVEY MD ANGLE 24 7747 36.9 25 7922 37.8 26 8107 38.7' DIRECTION ~- TVD N86E NO6E N8-?E ' 7488 7627 7772 SECTION 942 1048 1162 COORDINATES S. 17 E942 N7.25 E1048 N14.24 E1163 0932H- DLS · .2 .4 .6 Sohio Daily Drilling Report -- ENDICOTT June 19, 1986 at 0600 hours Rig:' Doyon ~;ell · 0-20 AFE # 717509 API# 50-029-21605 Current Operation: POHo MUD TYPE-Li gno 0600 Depth: 8460' Day: 15 24-Hour Ftg: 264' Drill 12-1/4'' hole to 8460 ft. POH for bit change. WT:9.7 VIS:38 PV:12 YP:7 FL:5.0 SOLIDS:8 TEMP:80°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 28 29 8299 8395 38.9 N88E 7922 1282 38.8 N89E 7997 1342 N1 9.49 E1284 . 4 N21.07 E1344 .7 0932H: Sohio Daily Drilling Report -- ENDICOTT June 20, 1986 at 0600 hours Rig' DOyon #15; Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 Current Opera ti on: Drilling. 0600 Depth: 8590' Day' 14 24-Hour Ftg' 130' POH. Test BOPE. Change bit. RIH. Drill 12-1/4" hole to 8590 ft. MUD TYPE-S.W~ Ligno WT-9.9 VIS:38 PV-12 YP-7 FL-5.0 SOLIDS'8 TEMP'90°F sURVEy . ANGLE DIRECTION TVD SECTION COORDINATES 0932H' DLS SAPC Daily Drilling Report -- ENDICOTT June 21, 1986 at 0600 hours Ri g' Doyon Wel 1 · 0-20 #15 AFE # 717509 API# 50-029-21605 0600 Depth' 8895' Day: 15 24-Hour Ftg: 305' Current Operation' Drilling. Drill 12-1/4" hole to 8895 ft. MUD TYPE-S.W. Ligno WT:9.8 VIS:39 PV-13 YP:8 FL:5.0 SOLIDS'9 TEMP'88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 30 8585 38.7 N89E 8145 1461 N23 E1462 31 8775 35.5 P/89E 8293 1579 N23 E1581 0932H: SAPC Daily Drill ing Report -- ENDICOTT June 22, 1986 at 0600 hours Rig' Doyon #15 Well · 0-20 AFE # 717509 API# 50-029-21605 0600 Depth' 9254' Day' 16 24-Hour Ftg' 359' Current Operation' Drilling. Drill 12-1/4" hol.e to 9254 ft. MUD TYPE-S.W.Ligno WT:9.8 VIS'38 PV:15 YP'9 FL:4.5 SOLIDS:9 TEMP-90°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 32 8965 38.4 N89E 33 9156 38.5 &q)gE 8442 1698 N21 E1699 . 1 8592 1817 N21 E1818 ,7 0932H- SAPC Daily Drilling Report -- ENDICOTT June 23, 1986 at 0600 hours Rig' Doyon #15 Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 0600 Depth' 9410' Day- 17 24-Hour Ftg' 156' Current Operation' Drilling. Drill 12-1/4" hole to 9372 ft. Drill to 9410 ft. POH. Change bit and BHA. RIH. MUD TYPE-S.W.Ligno WT:9.9 VIS-38 PV-ll YP-5 FL-5.0 SOLIDS'8 TEMP-90°F SURVEy MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 34 9307 38.2 EAST 8710 1910 N21 E1911 0932H- Rig' Doyon #15 Wel 1 · 0-20 SAPC Daily Drilling Report -- ENDICOTT June 24, 1.Q86 at 0600 hours AFE # 717509 . API# 50-029-21605 Current Operation- Drilling. 0600 Depth' 9820' Day: 18 24-Hour Ftg: 410' Drill 12-1/4'.' hole to 9820 ft. MUD TYPE-S.W.Ligno WT'IO VIS'40 PV'15 YP-IO FL'5.0 SOLIDS'9 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 35 9440 37.4 EAST 8815 1991 N21 E1993 36 9630 35.6 S89E 8968 2104 N20 E2106 0932H' SAPC Daily Drilling Report -- ENDICOTT June 25, 1986 at 0600 hours Rig. ' Doyon #15 Wel 1 · 0-2O AFE Cf 717509 API# 50-029-21605 0600 Depth' 10,025' Day: 19 24-Hour Ftg: 205' Current Operation' RIH. Drill 12-1/4" hole to i0,025 ft. MUD TYPE-S.W.Ligno WT:IO.O VIS:39 PV:13 YP'8 FL '4.8 SOLIDS'9 TEMP'llO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS _ 37 . 9819 33.9 S89E 9124 2213 N19 E2214 0.9 0932H' SAPC Daily Drilling Report -- ENDICOTT June 26. 1986 at 0600 hours Rig' Doyon #15 Well' 0-20 AFE # 717509 API# 50-029-21605 0600 Depth' 10.067' Day' 20 24-Hour Ftg' 42' Current Operation: Fishing, Drill 12-1/4" hole to 10,067 ft. POH. Lost cone off bit, RIH wireline Ivtagnet to recover cone. Unsuccessful. RIH globe/junk basket and fish for cone. MUD TYPE-S.W. Ligno WT:9,9 vis'38 PV'12 YP-8 FL:5 SOLIDS'9 TEMP')IO°F SURVEY MD- 38 ANGLE DIRECTION TvD 9984 30'9 S88E ' 9263 SECTION COORD I NATES 2301 Ikq6.73 E2302 DLS 0932H- SAPC Daily Drilling Report -- E~,~DI£OTT June 27, 1986 at 0600 hours Rig: Doyon #15 Wel 1: 0-20 AFE # 717509 API# 50-029-21605 0600 Depth: 10,067' Day: 21 24-Hour Ftg: -- Current Operation: RIH w/Globe Basket. Mill over cone wi th Globe BasKet. POH. Did not recover cone. RIH with flat bottom mill and junk baskets. Mill on lost cone. POH. RIH wi th Globe Basket. MUD TYPE-S.W. Ligno WT:IO VIS:40 PV:17 YP:ll FL:4.8 SOLIDS:9 TEMP: -- SURVEY MD ANGLE DIRECTIO~ TVD SECTION COORDINATES DLS .... 0932H: R~g' Doyon #15 Wel 1 · 0-20 SAPC Daily Drilling Report -- ENDICOTT June 28, 1986 at 0600 hours AFE # 717509 API# 50-029-21605 Current opera ti on: Drilling. 0600 Depth' 10,214' Day- 22 24-Hour Ftg' 147' MUD TYPE, S. W. Li gno RIH. Mill over cone. POH wi th lost cone. hole to 10,214 ft. WT:IO VIS-40 PV-16 YP'12 FL-4.8 RIH. Drill 12-1/4" SOLIDS'lO TEMP:-°F SURVEY_ MD 'ANGLE DIRECTION TVD SECTION COORDINATES 0932H' DLS SAPC Daily Drilling Report -- ENDICOTT June 29, 1986 at 0600 hours Rig: Doyon /fl5 Wel 1: 0-20 AFE # 717509 · API# 50-029-21605 0600 Depth: 10,405' Day: 23 24-Hour Ftg: 191' Current Operation: Running 9-5/8" casingl Drill 12-1/4" hole to 10,405 ft. Conduct short trip. POH. Run 9-5/8" Casing. MUD TYPE-S.W. Ligno WT:IO VIS:39 PV:13 YP:9 FL:4.8 SOLIDS:lO TEMP:IOO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 38 39 10,235' 29.8 10,331' 28.65 S86E 948l ' 2426' N8. O' E2427' S87E 9565' 2472' NS. 19' E2473' 0.9 0.5 0932H: SAPC Daily Drilling Report -- E~'DICOTT June 30, 1986 at 0600 hours Rig: Doyon #15 Well: 0-20 AFE # 717509 API# 50-029-21605 0600 Depth: 10,405' Day: 24 24-Hour Ftg: - Current Operation: Layout BHA. Run 266 joints 9-5/8" casing and landed. Cemented with 425 cu. ft. Class G cement. Nipple down landing joint. Test 9-5/8" seal assembly. Test BOP. Lay out 12-1/4" BHA. MUD TYPE-S.N. Ligno WT-9.9 VIS'44 PV'15 YP-IO FL'5.2 SOLIDS'lO TEMP'-°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0932H: Rig' Doyon #15 Wel 1 · 0-20 SAPC Daily Drilling Report -- ENDICOTT July l, 1986 at 0600 hours AFE # 717509 API# 50-029-21605 'Current Operation. Drill ng. 0600 Depth- 10,545' Day: 25 24-Hour Ftg: 140' RIH-and tag cement at 10217 ft. Drill out float collar and test casing to 3000 psi. Drill out shoe and conduct F.I.T. to 13.5 ppg~ Drill 8-1/2 in. hole to 10545 ft. . .. Note' 9-5/8" shoe @ 10,387 ft. .MUD TYPE-S.W. Lign° WT:9.8 VIS:37 PV-ll SURVEY MD ~ ANGLE YP:9 FL:5.4 SOLIDS:9 TEMP'94°F DIRECTION TVD SECTION COORDINATES DLS 0932H' SAPC Daily Drilling Report-- ENDICOTT July 2, 1986 at 0600 hours Rig: Doyon #15 Wel 1: 0-20 AF£ # 717509 API# 50-029-21605 0600 Depth: 11,010' Day: 26 24-Hour Ftg: 465' Current Operation: Drilling. Drill 8-1/2" hole to ll,OlO ft. MUD TYPE-S.W. Ligno WT:9.8 VIS:38 P¥:15 YP:8 FL:4.8 SOLIDS:9 TEMP:IO4°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDI NATES DLS 0932H: Rig- Do.yon #15 Well 0-20 SAPC Daily Drilling Report -- ENDICOTT · July 4, 1986 at 0600 hours AFE # 717509 API# 50-029-21605 0600 Depth' 11,269' Day' 28 24-Hour Ftg' 89' CUrrent Opera ti on' Logging. Drill-8-1/2" hole to 11,269. Short trip l0 stds. CBU. POH. RU Schlumberger. Run #1 NGT/SP/DLL/MLL/LDT/CNL. Run #2 NGT/Array Sonic. MUD TYPE-S.W. Ligno WT'9.8 VIS'38 PV'13 YP:8 FL'5 SOLIDS'9 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0932H' SAPC Daily Drilling Report -- ENDICOTT July 5, 1986 at 0600 hours Rig: Doyon Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 0600 Depth' ll,266'CORR Day:. 29 24-Hour Ftg- O' Current Operation: Running 7" liner. Finished logging run #2. RD Schlumberger. RIH. Ream 11,200-11,266'. CBU, Short trip. CBU. POH. RU casing crew. GIH with 7" liner and Baker hanger on DP. MUD TYPE-S.W. Ligno WT:9.8 VIS'38 PV:14 YP-6 FL'5 SOLIDS-9 TEMP-°F SURVEY MD ANGLE DIRECTION TVD- SECT I0 N COORD I NATES DLS 0932H: SAP¢ Daily Drilling Report -- ENDICOTT July 6, 1986 at 0600 hours Rig' Doyon #15 Wel 1 · 0-20 AFE # 717509 API# 50-029-21605 Current Amount: $ 2,991,023 0600 Depth' 11,266' Day: 30 24-Hour Ftg: O' Current Operation' POH w/DP. F.I.H. w/7" liner. RU Howco and cement liner with 385 sx Class "G" cement. Bumped plug w/3200 psi. F1 oats held. Release from hanger and POH. RIH w/8-1/2" bit and 9-5/8" scraper. Tag cement and drill to top of hanger @10,123'. C & C hole. POH. MUD TYPE-S.W. Ligno WT'9.8 VIS-38 PV'14 YP:6 FL-5 SOLIDS'9 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0932H- SAPC Daily Drilling Report -- ENDICOTT July 7, 1986 at 0600 hours Rig' DOyon #15 Well · 0,20 AFE # 717509 API# 50-029-21605 current Operation: POH w/DP 0600 Depth' 11,177 PBTD' Day: 31 24-Hour Ftg: O' FOH. PU 6" bit. RIH 10' inside 7" liner. Test lap to 3000 psi, OK. GIH. Drill cement and FC to 11,177'. CBU Displace well to 9.6 ppg Brine water. Test casing and liner t~ 3000 psi, OK. POH. MUD TYPE-NACL WT'9.6 VIS' PV- YP- FL' .sURVEY . · ._ SOLIDS' TEMP'°F MD ANGLE DIRECTION TVD SECTION COORDINATES 0932H' DLS SAPC Daily Drilling Report -- ENDICOTT July 8, 1986 at 0600 hours Rig: Doyon #15 Wel 1: 0-20 AFE # 717509 ,. API# 50-029-21605 0600 Depth: 11,177 PBTD' Day: 32 24-Hour Ftg: O' Current Operation: POH. FOH w/DP. RU Schlumberger.. Run #1 Gyro from ll,ll2 to surf. Run #2 C~.~BT/VDL/GR/CCL; Run #3. Gauge ring w/junk basket. RD Schlumberger. RIH w/TIW pkr. and 3 its. tailPipe to 10,072. Set pkr. POH w/DP. MUD TYPE-NACL WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES __ DLS , 0932H: Rig: Doyon #15 Wel 1: 0-20 SAPC Daily Drilling Report -- ENDICOTT July 9, 1986 at 0600 hours · AFE # 717509 API# 50-029-21605 0600 Depth' 11,177 PBTD' Day' 33 24-Hour Ftg' O' Current Operation' Landing Tubing. POH. LD DP. Run 7" curtain string. ND BOPE. Install ll" 5000 psi intermediate spool. NU BOPE and test to 5000 psi, OK. Run 230 jts 3-1/2 9.2# TDS tubing. Stab in PBR. Space out to land tubing~ MUD TYPE-NACL WT:9.6 VIS' PV- YP: FL' SOLIDS' TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0932H:~ -Rig: Doyon Well · 0-20 #15 SAPC Daily Drilling Report -- ENDICOTT July 10, 1986 at 0600 hours AFE #. 717509 API# 50-029-21605 .0600 Depth: 10,177 PBTD' Day: 34 24-Hour Ftg: O' Current Operation: Release Rig/Moving to 0-21. spaCed out and landed tubing. Unstung and displaced tubing to dies'el._:.Stab-in and press tubing to 3000 psi, OK. Press annulus to 2300, .OK. Set BPV' ND BOPE NU tree, fill with diesel and test- to 5000 psi, OK' Test control lines. Released rig at 1900 Hrs.-7/9/86. MUD TYPE- .WT: vis: P¥' FL' SOLIDS- TEMP' OF yp. SURVEY ANGLE DIRECTION TVD SECTION COORDINATES 0932H': DLS I TELECDI Teleco Oilfield Se~ s of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 July 1, 1986 JOB # 507 TAK STANDARD ALASKA PRODUCTION CO. WELL: MPI 0-20 ENDICOTT DOYON 15 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opPortunity to provide service to Standa.rd Alaska Production Company. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ,~1~'i' COMPANY Date 06/10/86 TELECO OILFIELD SERVICES JOB 507 SURVEY CALCULATIONS Page Company: SAPC Well: MPI 0-20 Location: ENDICOTT Rig: DOYON 15 TELECO Job # 507 Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.50 degrees 30.50 degrees 91.00 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE-IN 5458.00 1.4 39.6 N 39 36 E 5457.95 -0.36 4.40N 0.28W 4.40 N 3.641W 0.000 TELECO MWD 5740.00 8.3 83.9 N 83 54 E 5738.81 21.91 8.80N 22.06E 23.76 N 68.250E 2.506 5830.00 10.6 84.6 N 84 36 E 5827.59 36.58 10.28N 36.77E 38.18 N 74.373E 2.559 5945.00 13.2 83.9 N 83 54 E 5940.11 60.13 12.66N 60.36E 61.67 N 78.154E 2.264 . _ , 5640.00 5.8 82.5 N 82 30 E 5639.58 9.75 7.35N 9.88E 12.31 N 53.357E 2.848 5552.00 3.3 80.1 N 80 06 E 5551.86 2.87 6.29N 2.98E 6.96 N 25.358E 2.567 TELECO Job # 507 06/10/86 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 6040.00 15.1 86.0 N 86 00 E 6032.22 83.22 14.70N 83.49E 84.77 N 80.012E 2.071 6135.00 16.9 88.9 N 88 54 E 6123.53 109.35 15.87N 109.65E 110.79 N 81.765E 2.073 6228.00 18.6 91.0 S 89 00 E 6212.10 137.70 15.89N 138.00E 138.91 N 83.430E 1.953 6322.00 20.4 92.4 S 87 36.E 6300.71 169.07 14.96N 169.36E 170.02 N 84.951E 1.978 6417.00 22.7 93.1 S 86 54 E 6389.06 203.95 13.28N 204.21E 204.64 N 86.277E 2.436 6510.00 25.7 94.1 S 85 54 E 6473.88 242.03 10.89N 242.26E 242.50 N 87.425E 3.256 6596.00 28.1 95.9 S 84 06 E 6550.57 280.84 7.50N 281.01E 281.11 N 88.470E 2.947 6700.00 30.4 96.9 S 83 06 E 6641.30 331.43 1.84N 331.51E 331.51 N 89.682E 2.261 6795.00 32.9 97.6 S 82 24 E 6722.17 380.97 4.45S 380.95E 380.98 S 89.331E 2.660 6891.00 35.8 98.7 S 81 18 E 6801.42 434.71 12.12S 434.57E 434.74 S 88.401E 3.089 6985.00 37.1 97.6 S 82 24 E 6877.03 490.12 20.04S 489.85E 490.26 S 87.657E 1.548 7065.00 36.7 92.0 S 88 00 E 6941.00 538.03 24.06S 537.69E 538.23 S 87.438E 4.231 7178.00 36.5 87.5 N 87 30 E 7031.72 605.38 23.77S 605.05E 605.52 S 87.750E 2.381 7357.00 36.2 85.0 N 85 00 E 7175.89 711.10 16.83S 710.91E 711.11 S 88.644E 0.845 7541.00 36.7 85.7 N 85 42 E 7323.89 819.88 7.97S 819.87E 819.91 S 89.443E 0.353 7747.~00 37.1 85.7 N 85 42 E 7488.63 943.04 1.32N 943.21E 943.21 N 89.920E 0.194 7922.00 37.8 86.0 N 86 00 E 7627.56 1049.02 9.01N 1049.34E 1049.38 N 89.508E 0.413 TELECO Job # 507 06/10/86 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 8107.00 38.7 87.1 N 87 06 E 7772.84 1163.21 15.90N 1163.66E 1163.77 N 89.217E 0.610 8299.00 38.9 88.2 N 88 12 E 7922.47 1283.31 20.83N 1283.87E 1284.04 N 89.070E 0.374 8395.00 38.8 88.9 N 88 54 E 7997.24 1343.48 22.36N 1344.07E 1344.26 N 89.047E 0.470 8585.00 38.7 89.2 N 89 12 E 8145.41 1462.34 24.33N 1462.99E 1463.19 N 89.047E 0.112 8775.~00 38.5 91.0 S 89 00 E 8293.90 1580.88 24.12N 8965.00 38.4 90.6 S 89 24 E 8442.70 1699.02 22.47N 1581.54E 1581.72 1699.67E 1699.82 N 89.126E 0.601 N 89.242E 0.141 9156.00 38.5 89.2 N 89 12 E 8592.29 1817.79 22.68N 1818.46E 1818.60 N 89.285E 0.459 1912.15E 1912.29 1993.66E 1993.80 9307.00 38.2 89.9 N 89 54 E 8710.71 1911.45 23.42N 9440.00 37.4 89.6 N 89 36 E 8815.80 1992.94 23.77N N 89.298E 0.350 N 89.~317E 0.618 10331.00 28.4 93.1 S 86 54 E 9564.94 2473.13 ll.13N 2473.70E 2473.72 N 89.742E 0.628 10235.00 28.9 93.8 S 86 12 E 9480.69 2427.14 13.90N 2427.76E 2427.80 N 89.672E 0.899 9984.00 30.9 91.7 S 88 18 E 9263.11 2302.09 19.90N 2302.79E 2302.88 N 89.505E 1.853 9819.00 33.9 90.6 S 89 24 E 9123.81 2213.69 21.68N 2214.41E 2214.52 N 89.439E 0.907 9630.00 35.6 91.0 S 89 00 E 8968.53 2105.97 23.18N 2106.69E 2106.82 N 89.370E 1.044 3200 =~LECO 0 i i ~ i e i d Serv i c~s PLAN ViEW EAST 6400 mT-'-~ .... ~'-'T'-[-' ?"-?"'t--~--~ ..... ~"T~~-T-'- ~ : ~ ~ ~. :: . ,~ .: ~ ........... ~,,.~..~_.~ ...... : ...... , .... : .... ,...:._, .... , ..... ~ ..... ,_.~ .... ~..., i~ ~ ~ I~ ~ I :..~_ ~ i ~ .~ J~, ~~L.~__.~...:_..L.'~ .... ...... ~.._J ~.., .~, ,. , .... : ..., ~ .... ,. .... , ,, ....... , .s_u.~[~..~ 4800 ~ . ~ ~ , ~ , ~ :. . 4000 2400 ~'~" '~ ~-- · ~ ~ : ~ ; I ; : ; , , -. i - ' · ~ ~ ' ' ' ' 800,' ~ ' ' ~ ~ ~ : ~ ~ i ; ' ~ ~ ~ , ', ~ , ' J '~ , ~ ' : I ~ ] ~ : ~ ~ -K - : ? :-'1~ ..... ~7-' , , , , :. ' : ~ , I i ~ : : · : ' ' ; ~ ; ' ; I ' ~ : ' u.._~ .~___ ~_L~..4_,~,_~ ..... L~_ ..~_._L,,.. L,~,,..J ..... 800 0 800 1600 2400 3~',00 4000 TELECO Oil~imld Smrvicms VERTICAL PROJECTION - 1000 0 ! 000 2000 3000 4000 5000 5000 t ' . · . ~ I ~ ~ - 6000 7000 9 ~ooo _ 9000 10000 llOOO 12000 13000 14000. VERTICAL SECTION (~t) GREA*i-LAND DIRECTIONAl_.. DRIL..LING INC. REPORT .'..']F SUB"-'SURFACF DIRECTIONAL SURVEY 6-10-86 6-29-86 ~'~: rf.'~ 7 ic. ::':: i ! ~;!" .-'" F' "~'" 7 ..... ~ ..' r-' :, ..' r" r', -'"~ ~., ................ : ;'ii'.,i:.:'! ~.. i.,..l..~1,! '¥1'~1,..., THIS tS A RECORD OF A SUB-"SURI'"rACE SLIRVEY OF YOUR WELL WE HAVE t:;.'.ETAINED A COPY OF YOUR SURVEY REPORT IN OUR F:'II...IZS I:'-OR YOUR CONVENIENCEI HOWEVER,, SHOULD YOU SO DESIRE: Al_t_ COPIES OF' THE SURVEY REPORT WILL BE F'OI:;.:WARDIE!.') TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE i-(EF:'T !N A L..OCKED FII._E AND ARE HELD IN STRICTEST C 0 Fi. F ! L3 E N ClE ,, STANIT)AF;:D AI...ASt.::'A fqF' ]] 02!0 S ~3':? ,, O0 ¥O ct,:~!~! 7:0 min E f"!i::' ;11 ()'2(),, [)t:~'i" F:'I:~OI)UCT 'r '~ ... .,. !.,N crlfflI::'AN'Y i',! :!!i,::., ,,OO Iii: i'4 (36 ,, (.':,O E i',! ~ii 9 ,. O O Iii; !!!; (ii4.C)C, E; i'J.~ii'.:.;' <)<) i"l ~]1'5;., 00 N t.::'.~ 6.00 i'4.1:3,<:.00 ?.4 (:i 6 ,, <) <) f'"l '; '.:' ' ? ' ,:: ';i :' ,, ? (:, .'.":;. D A T A ? ? (.) '? ,.'.~ 32 7 ~i.i :i}i ii. '/7 (),:':':, ,..! C) .(. ,") t;;' :' ;...' .,;. ;.J ,7.) ,."':, .i::!, !/:.; ,:!:, ,:'!:, 4 '5 ,:'.'!, 6 ,.t'i, 0 C', (.., 7 ,'.'.) 0 ,:'!:, :!!i: ,:.-.) (') 6 '? () 0 7 () 0 0 7 :t. ,'.} 0 7 2 C, C, '.;:" 7.; ,'3,1) ';:." .4 () 0 7 5 0 () ".,." ,5 () ('. :, 7 7 ,"),3 '? ~ 0 C, ?' ,:? ,-.'.) 2.4 24 · ") h;' -") ..-) "') C) "') ? 1.'!i; ()() ,:;;, ..:..'~. ()() ]. 750 t500 3000 3750 450O 5~50 6000 6750 7500 8P.50 go00 9750 i0500 ii~50 i2000 i2750 13500 -750 VERTICAL SECTION I STANDARD ALASKA'PRODUCTION COMPA MPI 020 SECTION AT S 89.00 E CONPUTED BY RADIUS OF CURVATURE SCALE: i inch = i500 feet DRAWN: 7-i-86 H~ksr Identtftcs~ton HD TVD DEPRT A} TO t0405 9628 25t2 .. ,. , ,. . , ., , . __~ ......... ,,.. ........ ,, ........... ...... 0 750 t500 2250 3000 3750 4500 5;~50 6000 6750 7500 8850 Departure HORIZONTAL VIEW STANDARD ALASKA PRODUCTION COMPA MPI 020 CLOSURE: 25t2 ft N 89.9 E DECLINATION: 30.50 deg E SCALE: I inch = 500 ~eet DRAWN: 7-1-86 i750 t500 lO00 7§0 §00 ~0 ~0 §00 750 lO00 i500 i750 0 250 500 7~0 1000 i250 t500 i750 2000 2250 2500 ~750 $ UB-S URFA CE DIRECTIONAL SURVEY I~ UIDANCE E~]ONTINUOUS [~]OOL Company Well Name Field/Location STANDARD ALASKA PRODUCTION COMPANY Job Reference No_, 71582 SALAZAR 1-5/0-20 MPI (1945'FNL,2038'FEL, I ENDICOTT~ NORTH SLOPE~ ALASKA i S36,T12N,R16E) / '~ Date Computed By;. CUDNEY ,t GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. 1-5/0-20 MPI ENDICOTT' NORTH SLOPE~ALASKA SURVEY DATE: O7-JUL-86 ENGINEER: SALAZAR METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DIST. PROJECTED ONTO A TARGET AZIMUTM OF SOUTH 89 DEG 0 MIN EAST COMPUTATION DATE: 14-JUL-B6 PAGE I STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 07-JUL-B6 1-5/0-20 HPI ENDICOTT NORTH SLOPEsALASKA KELLY BUSHING ELEVATIQN: ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.30 100.00 100.00 44.70 200.00 199.99 144.69 300.00 299.98 244.68 400.00 399.97 344.67 500.00 499.95 444.65 600.00 599.93 544.63 700.00 699.92 644.62 800.00 799.91 744.61 900.00 899.90 844,60 55.30 1000.00 999.90 944.60 1100.00 1099.89 1044.59 1200o00 1199.88 1144.58 1300.00 1299.88 1244.58 1400.00 1399.87 1344.57 1500o00 1499.87 1444,57 1600.00 1599.87 1544.57 1700.00 1699.87 1644.57 1BO0.O0 1799.86 1744.56 1900.00 1899.86 1844.56 2000.00 1999.86 1944.56 2100.00 2099.85 2044.55 2Z00.00 2199.85 2144.55 2300.00 2299.85 2244.55 2400.00 2399.85 2344.55 2500.00 2499.84 2444.54 2600.00 2599.84 2544.54 2700.00 2699.84 2644.54 2800.00 2799,83 2744.53 2900.00 2899.81 2844.51 3000.00 2999,78 2944.48 3100.00 3099.75 3044.45 3200.00 3199.72 3144.42 3300.00 3299.66 3244.36 3400.00 3399.56 3344.26 3500.00 3499.45 3444.15 3600.00 3599.33 3544.03 3700.00 3699.24 3643.94 3800.00 3799.16 3743.86 3900.00 3899.06 3843°?6 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH. FEET DEG/IO0 FEET FEET FEET DEG MIN 0 0 N 0 0 E 0.00 0 24 S 30 15 W 1.51 0 40 S 40.22 W O.BB 0 52 S 27 49 W 0.11 1 0 S 20 29 W -0.51 I 7 S 17 8 W -1.10 I 3 S 14 14 I~ -1.55 0 56 S 17 3 W -2.00 0 43 S 10 21 W -2.32 0 38 S 15 17 W -2.51 0 39 S 20 31 W -2.89 0 39 S 24 32 W -3.28 0 42 S 28 4 W -3.83 0 33 S 33 22 W -4.37 0 25 S 40 56 W -4.88 0 14 S 48 52 W -5.27 0 16 N 66 18, W -5.62 0 31 N 26 21 W -6.08 0 29 N 21 1 W -6.44 0 27 N 21 42 W -6.76 0 29 N 19 43 W -7.06 0 24 N 26 34 W -7.38 0 21 N 27 13 W -7.68 0 25 N 23 22 W -7.97 0 23 N 23 4 W -8.27 0 17 N 16 30 W -8.52 O 27 N 7 39 W -8.63 0 38 N 5 6 W -8.74 0 59 N 5 43 W -8.89 i 13 N 5 40 W -9.14 1 20 N 4 2 W -9.36 1 25 N 3 17 W -9.55 1 35 N 2 50 W -9.74 2 21 N 2 42 W -9.96 2 40 N 1 41 W -10.22 2 45 N 0 48 W -10.39 2 35 N 0 13 W -10.51 2 24 N 0 33~W -10.61 2 27 N I 54 W -10.78 2 32 N 2 34 W -11.03 0.00 0.00 N 0.00 E 0.81 2.61 N 1.56 E 0.10 1.76 N 0.91 E 0.29 0.69 N 0.12 E 0.11 0.82 S 0.53 W 0.19 2.57 S 1.14 W 0.19 4.43 S 1.63 W 0.20 6.10 S 2.11 W 0.13 7.47 S 2.45 W 0..24 8.61 S 2.66 W 0.04 9.67 S 3.06 W 0.16 10.73 S 3.46 W 0.05 11.79 S 4.04 W 0.33 12.79 S 4.60 0.11 13.44 S 5.12 W 0.31 13.90 S 5.52 W 0.39 13.96 S. 5.86 W 0.19 13.38 S 6.32 W 0.13 12.51 S 6.66 W 0.03 11.76 S 6.96 W 0.07 11.00 S 7.25 W 0.17 10.23 S 7.56 0.19 9.70 S 7.85 W 0.05 9.06 S 8.13 W 0.02 8.40 S 8.42 W 0.34 7.85 S 8.66 W 0.23 7.15 S 8.76 W 0.37 6.28 S 8.85 W 0.42 4.88 S 8.98 W 0.06 2.89 S 9.19 W 0.06 0'.64 S 9.37 W 0.12 1.74 N 9.53 W 0.32 4.33 N 9.67 W 0.63 7.72 N 9.83 N 0.11 12.20 N 10.01 W 0.07 16.97 N 10.10 W 0.29 21.67 N 10.14 W 0.10 25.99 N 10.16 W O.lO 30.19 N 10.26 W 0.14 34.55 N 10.43 W 0.00 N 0 0 E 3.04 N 30 46 E 1.98 N 27 11 E 0.70 N 10 Oo 97 S 32 5 2.81 S 23 56 N 4.72 S 20 12 W 6.45 S 19 2 W 7.86 S 18 10 W 9.02 S 17 9 N' 10.14 S 17 32 W 11.27 S 17 53 W 12.47 S 18 54 W 13.59 S 19 46 14.38 S 20 51 W 14.95 S 21 38 W 15.14 S 22 46 W 14.80 S 25 16 14.17 S 28 1 W 13.67 S 30 37 W 13.17 S 33 23 W 12.,72 S 36 27 12.48 S 38 58 W 12.18 S 41 54 u 11.69 $ 47 47 11.30 S 50 47 W 10.86 S 54 38 W 10.22 S 61 28 W 9.64 S 72 32 9.40 S 86 4 W 9.68 N 79 38 W 10.59 N 65 53 W 12.50 N 51 51 15.78 N 39 21 W 19.74 N 30 45 W 23.93 N 25 .. 3 W 27.90 31.89 N 18 45 W 36.09 N 16 47 W STANDARD ALASKA PRODUCTION CO. 1-5/0-20 MPI ENDICOTT NORTH SLOPE~ALASKA COMPUTATION DATE: 14-JUL-86 PAGE 2 DATE OF SURVEY: 07-JUL-86 KELLY BUSHING ELEVATION: ~ 55,30 F1 ENGINEER: SALAZAR 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 DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3998.95 3943.65 4100.00 4098.85 4043.55 4200,00 4198.76 4143.46 4300.00 4298,67 4243.37 4400.00 4398.58 4343.28 4500.00 4498,51 4443.21 4600.00 4598.44 4543.14 4700,00 4698,37 4643.07 4800.00 4798.32 4743.02 4900.00 4898.27 4842.97 2 35 N 3 35 W 234 N 4 30 W 224 N 6 9 W 224 N 744 W 2 17 N 9 44 ~1 2. 13 N 10 47 W 2 6 N 12 4 W 2 0 N 13 25 W 1 50 N 14 40 W I 35 N 1S 29 W -11.35 0.19 39.03 N 10.67 W -11.74 0.21 43.59 N 10.98 W -12.21 0.16 47.86 N 11.38 W -12.80 0.22 52.10 N 11.89 W -13.52 0.29 56,16 N 12.54 W -14,27 0.11 59.97 N 13,22 W -15.08 0.17 63.72 N 13.97 W -15,95 0,14 67,22 N 14,78 W -16.81 0.08 70.46 N 15.59 W -17,65 0,36 73,39 N 16,38 W 5000,00 4998,24 4942.94 5100,00 5098,20 5042,90 5200,00 5198,16 5142,86 5300,00 5298.14 5242,84 5400.00 5398.10 5342.80 5500.00 5498.07 5442.77 5600.00 5597,93 5542.63 5700,00 5697,46 5642.16 I 28 N 16 56 W tl. 30 N 16 58 W I 31 N 16 58 W 1 30 N 16 18 W 1 26 N 12 48 W i 47 N 49 38 E 4 8 N 77 gE 6 50 N 83 11 E N 86 53 E N 85 7 E 5800,00 5796.44 5741,15 9 28 5900,00 5894,67 5839,37 11 52 -18,42 0,15 75,88 N 17,09 W -19,22 0.08 78,35 N 17.86 W -20.04 0.04 80.88 N 18.63 W -20,84 0.05 83.42 N 19.39 W -21,60 0,48 85,95 N 20,10 W -21,11 2,57 88,05 N 19.57 W -16.40 2,74 89,73 N 14.84 W -7,02 2,87 91,20 N 5,43 W 7,08 2-91 92,29 N 8,69 E 25,69 2,25 93,64 N 27,33 E 6000,00 5992,12 5936.82 14 1 :N 86 8 E 6100,00 6088,67 6033.37 16 2 N 88 52 E 6200.00 6184,30 6129.00 17 53 6300.00 6279,00 6223.70 19 39 6400.00 6372.53 6317.23 21 57 6500,00 6464,28 6408,98 24 57 6600.00 6553.69 6498.39 27 55 6700,00 6641.14 6585.84 30 13 6800.00 6726,40 6671.10 32 50 6900,00 6808,98 6753.68 35 36 48.01 2,30 73.96 2.11 S 87 56 E 103.18 1.89 S 86 16 E 135.26 2.18 S 84 54 E 170.57 2,89 S 83 54 E 210,18 3.47 S 82 45 E 254,69 2,04 S 81 35~E 302,84 2.80 S 80 32 E 354.57 2,89 S 79 33 E 410.23 2.47 7000.00 6889,34 6834.04 36 50 S 80 57 E 468.97 7100.00 6969,56 6914.26 36 35 S 85 52 E 528,39 7200,00 7049,92 6994.62 36 22 7300,00 7130.69 7075,39 36 1 7400.00 7211.68 7156.38 36 4 7500,00 7291,95 7236,65 36 41 7600,00 7372.55 7317.25 36 29 7700,00 7452.27 7396.97 37 14 7800.00 7532,08 7476,78 37 12 7900.00 7611.72 7556.42 37 28 N 89 26 E 587,87 N 86 52 E 646,73 N 87 3 E 705,23 N 87 38 E 764,73 N 87 59 E 823.84 N 88 7 E 884.13 N 88 9E 944,30 N 88 25 E 1004,71 2,50 2,54 2,73 0,55 1.01 1.41 1.64 0.81 0.59 1.49 40.47 N 15 17 44.95 N 14 8 W 49.19 N 13 22 W 53.44 N 57.54 N 12 3 61.41 N 12 26 W 65.23 N 12 22 W 68.83 N 12 23 W 72.16 N 12 28 W 75.19 N 12 34 W 77.78 N 12 41W 80.36 N 12 50 ~ 83.00 N 12 58 W 85.65 N 13 5 W 88.27 N 13 9 W 90.20 N 12 31 W 90.94 N 9 23 W 91.36 N 3 24 W 92.70 N 5 22 E 97,55 N 16 16 E 95~46 .N 49,68 E 107.62 N 27 29 E 96,63 N 75,66 E 122,73 N 38 3 E 96.33 N 104.87 E 142,40 N 47 25 E 94.65 N 136,94 E 166,47 N 55 20 E 91.88 N 172.20 E 195.18 N 61 55( 88.00 N 211,74 E 229,30 N 67 25-- 82,81'N 256,18 E 269,23 N 72 5 E 76,21 N 304,21E 313.61 N 75 56 E 68,06 N 355.81 E 362.26 N 79 10 E 58,22 N 411.31 E 415.41 N 81 56 E 47,65 N 469.88 E .472,29 N 84 12 E 40,92 N 529,18 E 530.76 N 85 34 E 39.00 N 588.64 E 589.93 N 86 12 E 41.41 N 647.55 E 648.87 N 86 gO E 44,64 N 706.12 E 707.52 N 86 22 E 47,37 N 765,68 E 767.14 N 86 27 E 49.63 N 824.83 E 826.32 N 86 33 E 51.65 N 885,17 E 886,67 N 86 39 E 53,63 N 945,38 E 946.90 N 86 45 E 55,45 N 1005,83 E 1007,36 N 86 50 E COMPUTATION DATE: 14-JUL-86 PAGE 3 STANDARD ALASKA PRODUCTION CO, 1-5/0-20 MPI ENDICOTT NORTH SLOPEgALASKA DATE OF SURVEY= 07-JUL-86 KELLY BUSHING ELEVAT[ON= ENGINEER= SALAZAR 55.30 FT DEPTH DEPTH DEPTH DEG MIN 8000.00 7690,70 7635,40 37 48 8100.00 7769.31 7714.0! 38 26 8200,00 7847.54 7792.26 38 43 .8300,00 7925.45 7870.15 38 48 8400,00 8003.35 7948.05 38 48 8500,00 8081.34 8026.04 38 39 8600.00 8159.48 8104.18 38 36 8700.00 8237,67 8182.37 38 31 8800,00 8315,92 8260,62 38 26 8900,00 8394.32 8339,02 38 21 9000°00 8472.80 8417,50; 38 17 9100,00 8551,26 8495,96 38 ZO 9200,00 8629,63 8574,33 38 17 9300.00 8708°18 8652.88 38 1! 9400,00 8787.01 8731,71 37 38 9500.00 8866.51 8811.21 37 1 9600,00 8946.81 8691.51 36 0 9700.00 9028.29 8972.99 35 3 9800.00 9110.59 9055,29 34 5 9900.00 9194.12 9138.82 32 31 10000.00 9279,25 9223.95 30 44 10100,00 9365,68 9310,38 29 46 10200,00 9452.85 9397.55 29 2 10300.00 9540.46 9485.16 28 33 10400.00 9628.44 9573.14 28 32 10500,00 9716,00 9660,71 28 44 10600.00 9804,25 9748.95 27 36 10700-00 9892,58 9837°28 28 16 10800.00 9980,60 9925.30 28 16 '10900.00 10068.82 10013.52 27 58 11000.00 10157.25 10101.95 27 40 11100.00 10246.15 10190.85 26 14 11200.00 10336.03 10280.73 25 57 11266.00 10395.37 10340,07 25 57 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN N 88 42 E 1066,00 N 89 2 E 1127,76 N 89 42 E 1190,02 S 89 22 E 1252,69 S 88 35 E 1315.39 S 88 4 E 1377,98 S 87 58 E 1440.38 S 87 53 E 1502,71 S 87 46 E 1564.95 S 87 40 E 1627,02 S 87 30 E 1688.97 S 87 31 E 1750,96 S 87 36 E 1813,04 S 87 40 E 1874,94 S 87 35 E 1936.42 S 87 40 E 1997.08 S 87 16 E 2056,64 S 86 50 E 2114.58 S 86 33 E 2171,35 S 86 30 E 2226.28 S 86 9 E 2278,68 S 85 50 E Z328,91 S 85 3 E 2377,79 S 84 9 E 2425,87 S 82 45 E 2473.19 S 82 24 E 2521,16 S 82 25 E 2567,89 S 82 14 E 2614.46. S B2 59 E 2661.61 S 83 58 E 2708.49 S 84 17 E 2755.01 S 84 54 E 2800.65 S 85 0 E 2844.38 S 85 0 E 2873.21 0.26 0,49 0.73 0.48 0.48 0.27 0,22 0,13 0,21 0,14 0,08 0.21 0.58 0.50 0.73 0,89 1.50 0,72 1,22 1.61 1.50 1,07 0,53 0.67 1,47 1,05 0.40 0,25 0,62 0,52 0.24 2,86 0,00 0,00 56,98 N 1067.15 E 1068,67 N 86 56 E 58,20 N 1128,94 E 1130.44 N 87 2 E 58.93 N 1191.23 E 1192,68 N 87 10 E 58.75 N 1253.91E 1255,29 N 87 19 57.60 N 1316,60 E 1317,86 N 87 55,74 N 1379.16 E 1380.29 N 87 41~ 53.58 N 1441.54 E 1442.53 N 87 52 E 51.34 N 1503.83 E 1504.71 N 88 2 E 48,98 N 1566.04 E 1566,81 N 88 12 E 46.53 N 1628o08 E 1628.74 N 88 21E 43.92 N 1690.00 E 1690.57 N 88 30 E 41.22 N 1751.95 E 1752.43 N 88 39 E 38.59 N 1813.99 E 1814.40 N 88 46 E 36.06 N 1875,85 E 1876.20 N 88 53 E 33.53 N 1937.30 E 1937,59 N 89 0 E 31.00 N 1997.93 E 1998°17 N 89 6 E 28,48 N 2057.45 E 205.7,65 N 89 12 E 25,42 N 2115.35 E 2115.50 N 89 18 E 22.16 N 2172.06 E 2172.18 N 89 24 E 18.81 N 2226,94 E 2227.02 N 89 30 E 15,52 N 2279.30 E 2279,35 N 89 36 E 12,03 N 2329,48 E 2329,51 N 89 42 E 8,15 N 2378,30 E 2378,31 N 89 48 E 3,61 N 2426,31 E 2426,31 N 89 54 E 1,69 S 2473,53 E 2473,53 S 89 57 ~.~ 8.12 S 2521,40 E 2521.41 S 89 48 , 14,40 S 2568.03 E 2568.07 S 89 40 E 20.55 S 2614.50 E 2614,58 S 89 32 E 26,75 S 2661.55 E 2661.68 S 89 25 E 32°11 S 2708.34 E 2708.53 S 89 19 E 36~82 S 2754,79 E 2755,04 S 89 14 E 41,19 S 2800,36 E 2800,66 S 89 9 E 45.02 S 2844.03 E 2844.39 S 89 5 E 47,.54 S 2872-81 E 2873.21 S 89 3 E INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH COMPUTATION DATE: 14-JUL-86 PAGE 4 STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 07-JUL-86 1-5/D-20 MPI ENDICOTT NORTH SLOPE~ALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 55.30 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,. AZIMUTH FEET DEG/'IO0 FEET FEET FEET OEG MIN 0.00 0.00 : -55.30 0 0 1000.00 999.90 944.60 0 39 2000.00 1999.86 1944.56 0 29 3000.00 2999.78 2944,48 I 20 4000.00 3998.95 3943.65 2 35 5000,00 4998.24 4942.94 1 28 6000.00 5992.12 5936.82 14 1 7000.00 6889.34 6834.04 36 50 8000.00 7690.70 7635.40 37 48 9000.00 8472.80 8417.50 38 17 10000.00 9279.25 9223.95 30 44 11000.00 10157.25 10101.95 27 40 11266°00 10395.37 10340.07 25 57 N 0 0 E 0.00 0.00 S 20 31 W -2.89 0.04 N 19 43 W -7.06 0.07 N 4 2 W -9,36 0.06 N 3 35 W -11.35 0.19 N 16 56 W -18.42 0.15 N 86 8 E 48.01 2.30 S 80 57 E 468.97 2.50 N 88 42 E 1066.00 0.26 S 87 30 E 1688.97 0.08 S 86 9 E 2278.68 s 84 17'E 275 .Ol s ss 0 E 2873.21 1.50 0.24 0.00 0.00 N 0.00 E 0.00 N 0 0 E' 9.67 S 3.06 W 10.14 S 17 32 W 11.00 S 7.25 W 13.17 S 33 23 W 0.64 S 9..37 W 9.40 S 86 4 " 39.03 N 10.67 W 40.47 N' 15 1~ ,' 75.88 N 17.09 W 77.78 N 12 41 W 95.46 N 49.68 E 107.62 N 27 29'E 47,65 N 469,88 E 472.29 N 84 12 E 56,98 N I067,15 E 1068,67 N 86 56 E 43.92 N 1690.00 E 1690.57 N 88 30 E 15.52 N 2279.30 E 2279.35 N 89 36 E 36.82 S 2754.79 E 2755.04 S 89 14 E' 47.54 S 2872.81 E 2873.21 S 89 3 E COMPUTATION DATE: 14-JUL-86 PAGE STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 07-JUL-86 1-5/0-20 MPI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR 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 0.00 0.00 -55.30 0 0 55.30 55.30 0.00 0 7 155.30 155.30 100.00 0 38 255.31 255.30 200.00 0 46 355.32 355.30 300.00 0 57 455.34 455.30 400.00 I 4 555.36 555.30 500.00 1, 5 655.37 655.30 600.00 0 59 755'38 755.30 700.00 0 47 855.39 855.30 800.00 0 39 N 0 0 E S 24 34 E S 37 57 W S 36 42 W S 23 8 W S 19 25 W S 14 10 W S 16 14 W S 13 24 W S 9 30 W S 22 3 W S 20 31 W S 30 14 W S 28 34 W S' 40 51 W S 39 3 W S 76 40 W N 38 52 W N 20 40 W N 22 21 W N 20 17 W N 22 18 W N 29 27 N N 23 57 W N 23 27 W N 23 44 W N 7 14 W N 6 9 W N 4 53 W N 6 22 W N 4 27 W N 3 30 W N 3 12 W N 2 33 W N 2 10 W N 1 4 W N 0 23 W N 0 19 W N i 25 ~ N 2 20 W ~.40 955.30 900.00 I .41 1055.30 1000.00 1155.41 1155.30 1100.00 1255.42 1255.30 1200.00 1355.43 1355.30 1300.00 1455.43 1455.30 1400.00 1555.43 1555.30 1500.00 1655.43 1655.30 1600.00 oo.oo 0 39 0 38 0 42 0 39 0 27 0 20 0 12 0 26 0 32 0 27 1955.44 1955.30 1900.00 2055.45 2055.30 2000.00 2155.45 2155.30 2100.00 2255.45 2255.30 2200.00 2355.45 2355.30 2300.00 2455.46 2455.30 2400.00 2555.46 2555.30 2500.00 2655.46 2655.30 2600.00 2755.47 2755.30 2700.00 2855.48 2855.30 2800.00 0 28 0 28 0 19 0 24 0 24 0 20 0 26 0 30 0 49 1 10 2955.50 2955.30 2900.00 3055.53 3055.30 3000.00 3155.57 3155.30 3100.00 3255.61 3255.30 3200.00 3355.69 3355.30 3300.00 3455.80 3455.30 3400.00 3555.92 3555.30 3500.00 3656.02 3655.30 3600.00 3756.11 3755.30 3700.00 3856.Z0 3855.30 3800.00 1 18 I 22 I 29 I 58 2 35 2 44 2 41 2 27 2 24 2 3O 55.30 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH,, ' FEET DEG/IO0 FEET' FEET FEET DEG 0.00 0.00 0.00 N 0.00 E 1.56 0.76 2.76 N 1.61 E 1.20 0.15 2.16 N 1.23 E 0.45 0.31 1.13 N 0.47 E -0.24 0.14 0.11 S 0.24 W -0.84 0.08 1.77 S 0.87 W ,1.37 0.12 3.61 S 1,43 W -1.79 0.14 5.38 S 1.89 W -2.21 0,18 6.89 S 2.33 W -2.42 0.19 8.13 S 2.56 W -2.71 0.07 9.20 S 2.87 W -3.09 0.08 10.26 S 3.27 W -3.57 0.25 11.31 S 3.77 W -4.14 0.14 12.38 S 4.35 W -4.66 0,12 13.18 S 4.89 W -5.12 0.27 13.73 S 5.37 W -5.45 0.11 13.98 S 5.70 W -5.88 0.43 13.73 S 6.12 W -6.29 0.06 12.89 S 6.52 W -6.62 0.03 12.09 S 6.83 W -6.92 0.03 11.35 S 7.12 W -7.23 0.14 10.54 S 7.42 W -7.55 0..14 9.91 S 7.73 W -7.84 0.06 9.36 S 8.01 W -8.14 0.05 8.69 S 8.30 W -8.43 0.26 8.06 S 8.57 W -8.57 0.43 7.52 S 8.71 W -8.69 0.25 6.72 S 8.81 W -8.81 0',31 5.57 S 8.91 W -9.03 0.25 3.83 S 9.09 W -9.27 0.15 1.67 S 9.30 W -9.47 0.10 0.66 N 9.46 W -9.66 0.15 3.15 N 9.60 W -9.85 1.08 6.00 N 9.74 W -10.11 0.29 10.15 N 9.93 W -10.32 0.11 14.84 N 10.06 W -10.47 0.20 19.64 N 10.13 W -10,57 0.16 24.13 N 10.15 W -10.69 0.15 28.33 N 10.20 W -10.91 0.06 32.63 N 10.34 W 0'00 N 0 0 E 3.20 N 30 12 E 2.49 N 29 43 E 1.32 N 20 45 ~ O. 27 S 66 34 ,' 1.97 S 26 15 W 3.88 S 21 35 W 5.70 S 19 21 W 7.28 S 18 41 W 8.52 S 17 29 W 9.63 S 17 20 W 10.77 S 17 41 W 11.92 S 18 26 W 13.12 S 19 22 W 14.06 S 20 21 W 14.74 S 21 20 W 15,10 S 22 10 W 15.03 S 24 I W 14.45 S 26 49 W 13.89 S 29 27 W 13.40 S 32 7 W 12.89 S 35 6 W 12.57 S 37 56 12.31 S 40 33 12.01 S 43 40 11.76 S 46 46 11.51 S 49 10 11.08 S 52 41 W 10.51 S 57 59 W 9.87 S 67 9 W 9.45 S 79 47 W 9.49 N 85 59 W 10.11 N 71 50 W 11.44 N 58 22 W 14.20, N 44 22 N 17.93 N 34 8 W 22.10 N 27 16 W 26.17 N 22 48 W 30.11 N 19 47 W 34.23 N 17 35 W STANDARD ALASKA PRODUCTION CO, 1-5/0-20 MPI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 14-JUL-86 PAG~ DATE OF SURVEY: 07-JUL-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH' 55.30 F1 3956.30 3955.30 3900.00 4056.41 4055.30 4000.00 4156.50 4155.30 4100.00 4256.59 4255.29 4199.99 4356,67 4355,29 4299.99 4456.75 4455.30 4400,00 4556.83 4555.30 4500,00 4656,90 4655,30 4600,00 4756°96 4755,30 4700,00 4857.01 4855.30. 4800.00 2 34 N 3 9 W -11.20 0.10 37.08 N 10.55 W 2 37 N 3 53 W -11.56 0.08 41.60 N 10.84 W 2 25 N 5 26 W -12,00 0,19 46,04 N 11,19 W 2 27 N 6 58 W -12.53 0,15 50.26 N 11.66 W 2 Z1 N 9 25 W -13,18 0,17 54,41 N 12,23 W 2 12 N 10 21W -13,93 0,05 ~58.33 N 12,92 W 2 11 N 11 22 W -14,73 0,20 62,14 N 13,65 W 2 3 N 13 8 W -15,57 0.13 65,74 N 14.43 W I 53 N 14 7 W. -16,44 0.16 69,10 N 15,24 W 1 43 N 15 7 N -17,30 0,28 72,18 N 16,05 W 4957.05 4955.30 4900.00 5057.08 5055.30 5000.00 5157.12 5155.30 5100.00 5257,15 5255,30 5200,00 5357,19 5355,30 5300,00 5457.22 5455.30 5400.00 5557,28 5555.30 5500.00 5657,58 5655,30 5600.00 5758,36 5755.30 5700.00 1 27 N 16 10 W -18,08 0,08 74,83 N 16,78 W I 28 N 17 12 W -18,88 0,08 77,29 N 17,53 W 1 30 N 16 57 W -19.69 0.04 79.79 N 18.30 W 1 31 N 16 30 W' -20,50 0,04 82,33 N 19.07 W 1 30 N 15 44 W --21,28 0,02 84,87 N 19,81 W 1 19 N 18 50 E -21,70 2,01 87,23 N 20,18 W 3 2 N 70' 53 E -18.96 2.67 89.04 N 17.41 W 5 40 N 81 26 E -11,61 2,71 90,60 N 10,03 W 8 24 N 85 58 i 0,68 2,38 91,95 N 2,29 E N 85 40 E 17,79 2,22 92,99 N 19,41 E 5859.83 5855.30 5800.00 10 59 5.962.11 5955.30 5900.00 13 12 6065.33 6055.30 6000.00 15 23 6169.56 6155.30 6100,00 17 21 6274,88 6255.30 6200.00 19 9 6381.48 6355,30 6300.00 21 28 6490.08 6455.30 6400.00 24 37 6601,82 6555,30 6500,00 27 57 6716.41 6655.30 6600.00 30 40 6834.61 6755.30 6700.00 33 50 6957.42 6855.30 6800.00 36 42 7082.23 6955.30 6900.00 36 35 7206.68 7055.30 7000.00 36 19 7330.42 7155.30 7100,00 35 55 7454.17 7255.30 7200.00 36 40 7578.62 7355.30 7300.00 36 12 7703.80 7455.30 7400°00 37 12 7829,19 7555.30 7500.00 37 11 7955.21 7655.30 7600.00 37 55 8082.10 7755.30 7700.00 38 24 8209.96 7855.30 7800.00 38 45 N 85 25 E 39.14 2.12 N 87 47 E 64.58 2.02 S 88 46 E 93.93 1.98 S 86 39 E 126.94 1.96 S 85 6 E 163.78 2.56 S 84 1 E 205.98 3,44 S 82 44 E 255.53 2.00 S 81 22 E 311.05 2,84 S 80 7 E 373.40 3.05 S 79 46 E 443,71 1,34 S 85 6 E 517.79 N 89 8 E 591.83 N 86 47 E 664.55 N 87 24 E 737.26 N 87 54 E 811.23 N 88 7 E 886.43 N 88 13 E 961.97 N 88 35 E 1038.57 N 88 59 E 1116.61 N 89 48 E 1196.25 2.62 2.73 0.42 1,14 0.32 0.78 0.83 0.99 0.60 0.69 94.80 N 96.35 N 96.63 N 38.55 N 15 53 W 42.99 N 14..35 47,39 N 13.3g.w 51.60. N 13 55,77 N 12 4L ' 59"74 N 12 29 63,62 N 1.2 23 W 67,30 N 12 22 W 70,76 N 12 26 W 73,95 N 12 31 76,68 N 12 38 W 79,25 N 12 46 W 81,87 N 12 5.4: ii 84,51 N 13 2 W 87.15 N 13 8 W 89,54. N 13 1 W 90.7.3 N 11 3 N 91,15 N 6 18 W 91,98 N 1 25 E 94.99 N 11 47 E 40.80 E 103.21 N 23 17 E 66.27 E 116.94 N 34 31 E 95.63 E 135.95 N 44 42 E 95.16 N 128.62 E 160.00 N 53 30 E 92.47 N 165.42 E 189.51 N 60 47 88.45 N 207.55 E 225.61 N 66 55 82.70 N 257.01 E 269.99 N 72 9 ~ ' 74.99 N 312,41 E 321.28 N 76 30 E 64.86 N 374.59 E 380.16 N 80 10 E 52.03 N 444.68 E 447.7Z N 83 19 E 41.72 N 518.60 E 520.28 N 85 24 E 39.08 N 592.60 E 593.89 N 86 13 E 42,41 N 665.39 E 666,74 N 86 21 E 46.19 N 738.18 E 739.63 N 86 25 E 49.19 N 812.21 E 813.70 N 86 32 E 51.72 N 887.46 E 888.97 N 86 39 E 54.19.N 963.07 E 964.59 N 86 46 E 56.33 N 1039.71 E 1041.24 N 86 53 E 58.00 N 1117.80 E 1119.30 N 87 1 E 58.96 N 1197.46 E 1198.91 N 87 10 E TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZI'MU'TH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH BEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN COMPUTATION DATE: 14-JUL-86 PAGE 7 STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 07-JUL-86 1-5/0-20 MPI KELLY BUSHING ELEVATION: ENDICOTT NORTH SLOPEtALASKA ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ' VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG 8338.'30 7955.30 7900.00 38 50 8466.63 8055.30 8000.00 38 43 8594.65 8155.30 8100.00 38 36 8722.54 8255.30 8200.00 38 31 8850.24 8355.30 8300.00 38 21 8977.68 8455.30 8400.00 38 17 9105.15 8555.30 8500.00 38 21 9232.64 8655.30 8600,00 38 14 9359.87 8755.30 8700.00 37 55 9485.95 8855.30 8800.00 37 8 9610.46 8955.30 8900.00 35 52 9732.95 9055.30 9000.00 34 47 9853.79 9155.30 9100.00 33 17 9972.06 9255.29 9199.99 31 12 10088.03 9355.30 9300.00 29 52 10202.80 9455.30 9400.00 29 1 10316.90 9555.30 9500.00 28 27 10430.62 9655.30 9600.00 28 50 10544.69 9755.30 9700.00 28 7 10657.70 9855.30 9800.00 28 1 10771.26 9955.30 9900.00 28 20 10884.69 10055.30 10000.00 28 0 10997.80 10155.30 10100.00 27 40 11110.21 10255.30 10200.00 25 59 11221.44 10355.30 10300.00 25 57 11266.00 10395.37 10340.07 25 57 DEG MIN FEET DEG/iO0 S 89 3 E 1276.69 S 88 12 E 1357.13 S 87 59 E 1437.,04 S 87 51 E 1516.74 S 87 44 E 1596.14 S 87 31 E 1675.15 S 87 31 E 1754.16 S 87 38 E 1833.22 S 87 38 E 1911.84 5 87 39 E 1988.62 $' 87 12 E 2062.75 S 86 46 E 2133.44 S 86 30 E 2201.23 S 86 18 E 2264.31 S 85 5~ E 2322.9S S 85 I E 2379.15 S 84 I E 2433.91 S 82 19 E 2487.79 S 82 19 E 2542.30 S 82 26 E 2594.60 $ 82 42 E 2648.04 S 83 50 E 2701.32 S 84 16 E 2753.99 S 84 59 E 2805.17 S 85 0 E 2853.74 S 85 0 E 2873.21 0.64 0.39 0.21 0.11 0.20 0.19 0.24 0.26 0.64 0.84 1.41 0.97 1.81 1.87 0.89 0.51 0.62 1.09 1.53 0.97 0.60 0.59 0.22 1.58 0.00 0.00 55.30 F1 FEET FEET FEET DEG HIN 58.43 N 1277.91 E 1279.24 N 87 22' E 56.42 N 1358.32 E 1359.49 N 87 37 E 53.70 N 1438.20 E 1439.20 N 87 51 E 50.82 N 1517.86 E 1518o. 7! N 88 & ~ 47.76 N 1597.21 E 1597.93 N 88 11 .., 44.52 N 1676.18 E 1676.77. N 88 28 : 41.08 N 1755o14 E 1755.62 N 88 39 E 37.74 N 1834.16 E 1834.55 N 88 49 E 34.55 N 1912.74 E 1913.05 N 88 57 E 31.34 N 1989.47 E 1989.72 N 89 '5 E 28.18 N 2063.55 E 2063.75 N 89 13 E 24.37 N 2134.19 E 2134.33 N 89 20 E 20.34 N 2201.92 E 2202.01 N 89 28 E 16.46 N 2264.94 E 2265,00 N 89 35 E 12.45 N 2323.52 E 2323.55 N 89 41E 8.03 N 2379.65 E 2379.67 N 89 48 E 2.79 N 2434.33 E 2434.34 N 89 56 E 3.62 S 2488.11 E 2488.11 S 89 55 E 10.94 S 2542.50 E 2542.52 S 89 45 E 17.89 S 2594.69 E 2594.75 S 89 36 E' 15.07 S 2648°00 E 2648.12 S 89 27 E 31.36 S 2701.19 E 2701.37. S 89 20 E 36.72 S 2753.77 E 2754.02 S 89 14 E 41.60 S 2804.87 E 2805.18 S 89 9 E 45.84 S 2853.38 E 2853.75 S 89 4 47.54 S 2872.81 E 2873.21 S 89 3 _ COMPUTATION DATE: 14-JUL-86 PAGE 8 STANDARD ALASKA PRODUCTION CO. DATE OF SURVEY: 07-JUL-86 1-5/0-20 MPI ENDICOTT NORTH SLOPEsALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR, 55~30 FT INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN: 1945' FNL~2038' FEL. SEC 36.T12NsR16E TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH ,EAST/WEST DRILLERS T.D. 11266.00 10395°37 10340.07 47o54 S 2872o81 E STANDARD ALASKA PRODUCTION CO. 1-5/0-20 MPI ENDICOTT NORTH SLOPE,ALASKA MARKER DRILLERS T.D. COMPUTATION DATE: 14-JUL-86 ~*~**~*~*~ STRATIGRAPHIC MEASURED DEPTH BELOW KB 11266.00 PAGE 9 DATE OF SURVEY: 07-JUL-B6 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR SUMMARY 55.30 FT SURFACE LOCATION AT ORIGIN= 1945' FNL,2038~':CTAN~ULARFEL SEC_ ~ _ !_ _36 TZ2N R16E TVD R [.O.URDJ~NATE$ FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10395.37 10340.07 47.54 S 2872.81 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 11266.00 10395.37 10340.07 2873.21 S 89 3 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY STANDARO ALASKA PRODUCTION WELL 1-S/0-20 MPI FIELD END I COTT COUNTRY USA RUN TWO DATE LOOOED REFERENCE 00007]582 WELL' 1-5/0-20 MPI (1945'FNL,2038'FEL, S36,T12N,R16E) HORIZONTAL PROJECTION NOR'tH ~000 1000 ~00 -SO0 -1000 - ! 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'::..:",:..i ':; ".] h¢---~-+~'--i---~'--~---~'--~--~.~...~,.~..~..~...~...~....~...~...i...~....~...~...~...~+~...~...~+4...~.~...:..~.;..;+.h..;..7.;...~".~...~...~..;...~...l..~;...;...;...;...~...;..;~...;...~..~...;....;...~..~¥.~.;.; ..... ~ ........ :'-:, -: ..., F'r"F'¥!'¥'-?"?'F'r' ~..~fR~¥...¥:..T..;~F.7..¥.~.¥?~.¥?F~F~¥?¥F.;.~.~.F.F.~.~..~F.?.~.~..?r..r~;...: ;"7"7";'"t-'?"':'"'~'"'~-T'T"t"i"'r'"t ...... ; .... ~ .... ": ....... 91. m ii "13 PROJECTION ON VERTICAL PLANE 91. - 2'7]. SCALED IN VERTICAL OEPTHS HORIZ SCALE = l/SOO IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: _ Date Required Date Received Remarks C°mpleti°n Rep°rt Well History / Samples Mud Log Core Chips · Core Description . Inclination Survey Directional Survey - '--':' ~ q". .:c-tx' ~,,--,?-- ~. ~_ ,....> ..~. _ Drill Stem Test Reports Production Test Reports ! Digitized Data Y _ Standard Alaska Production Company 900 East Benson Boule, P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION July 30, 1986 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Nell 0-20 (MPI) Gentlemen: Enclosed in triplicate, is Form 10-403, Application for Sundry Approvals, for the aDove-named well. This contains our proposal to perforate and production test the well. If you have any questions, please contact S. R. Bundy at 564-5226. Very truly yours, RSA/~pm/09. Enclosures 90D CC' R. H. Reiley B. Ross Drilling Nell File #17 Norking Interest Owners (4) R. S. Allan Division Drilling Engineer A~chor~Be A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALAS,.,~ OIL AND GAS CONSERVATION COM,,.,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension .,~ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate/~Other,'~ 2. Name of Operator Standard Alaska Production Company 3. Address P. O. BOX 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1945' SNL,. 038. NEL, Sec 36, TI2N R16E UH At top of productive ~merva/ · ' ' 1961' SNL, 540' ENL., Sec. 31 T12N R17E UM At effective depth ' ' ' ]989' SNL, 796' ENL, Sec. 31, T12N, R17E, UM At total depth 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 90' Conductor 2458 ' Surface 5436' Intermediate 4911 ' Production Liner 1135' Perforation depth: measured true vertical 5. Datum elevation (DF or KB) KBE = 55.26' feet uuck 6. Unit or Property. name Island Unit/Endicott MPI' 7. Well number 0-20 (MP~_) 8. Permit number 9. ~A~PI ~nber 50-- 029-2! 605 10. Pool Endicott Pool 11266 10395 11177 1-0315 Size 30m' 13-3/8" 9-5/8" 9-5/8" 11 feet Plugs (measured) feet Bridge Plug 2523' feet Junk (measured) feet Cemented Measured depth True Vertical depth Driven 2100 c.f. Permafrost 425 c.f. Class G + .75% CFR-2+. 15%HR7 458 c.f. Class G w/.5°/o Hal ad 344 + LNL 131' 131' 2499' 2499' 5477' 5434' 10388' 9618' 11258. I'-~ ~ L_ _ Tubing (size, grade and measured depth) J U L 0 1986 Alaska Oil & Gas Cons. Commission 3-1/2" 9.3// L-80 TDS tubing @ ]O0~q~qb°rage Packers and SSSV (type and measured depth) 9-5/8" TIN Packer at 10071'; 3-1/2" SSSV with flow couplings at 1506' 12.Attachments Description summary of proposal ~ Detailed operations program F~'" BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 5. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~"~. %. C~~ Title Division Drilling Engineer Commission Use Only Date ?/z~/1i"C Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance f " oP/> '" ~' - missioner Approved by J ApprovalNo. ~,,~/ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate STANDARD ALASKA PRODUCTION COMPANY WELL 1-5/0-20 ENDICOTT - MAIN PRODUCTION ISLAND INITIAL PERFORATING PROPOSAL Ne propose to perforate the following interval and perform a production flow test during the early part of August, 1986. The well is completed as a gas supply well. 10622'-10668' MD BKB (9768'-9809' TVDss) 4 shots per foot Ref. CNL/LDT 7/4/86 The tubing/casing annulus will be pressure tested to 1500 psi prior to perforating. The AOGCC will be notified 24 hours prior to pressure testing. A lubricator will be installed and tested to 3500 l~_si for all well work A sub-surface safety valve will be installed"and tesi~ed after perforating. STANDARD ALASKA PRODUCTION COMPANY ENDICOTT WELL TESTING PROGRAM SUMMER SEASON 1986 WELL 0-20 (GAS SUPPLY/INJECTION WELL) PERFORATE THE FOLLOWING INTERVAL: 10622-10668 M.D. (ref. CNL/LDT 7-4-86) 9768-9809 TVDSS TEST OBJECTIVES 1. Fluid/gas samples will be taken for PVT and compositional characterization of the reservoir. Separator samples will be taken from this test, but no bottomhole samples will be taken. 2. A normal 3 point backpressure test will be performed on the well at rates of 1, 3 and 5 MMSCF/D, in order to calculate the AOF of the well. WELL TESTING PROGRAM Rig up for testing. Pressure test well. Perforate the interval specified above. Flow well for 5 minutes, then shut in. Retrieve guns. Run in hole with CCL/GR/HP/TEMP tool with 2 max reading thermometers. Monitor the static bottomhole pressure at 10545, 10656, and 10718 M.D. for 30 minutes in each position. Hang the tool at 10656 M.D. and monitor the pressure for at least one hour. Obtain shut in bottom hole pressure. Tag T.D. Pull up 5 feet and monitor pressure for 15 minutes. Retrieve tools from well. Compare max reading thermometers with bottomhole temperatures. Bring the well on at a reduced choke. Adjust rate to approximately 1 MMSCF/D, and stabilize the well. Ensure that wellhead pressure and temperatures are monitored while flowing the well. After stabilizing the well at the low flow rate and monitoring wellhead pressure, open the well and stabilize at flow rates of 3 MMSCF/D and 5 MMSCF/D. Surface samples of condensate and gas are required from the gas wells, but no bottomhole samples will be taken. Rig down, move off well. FLUID SAMPLES REQUIRED * The following table summarizes the samples that will be required from 0-20. Also listed are the planned tests, laboratories doing the work, representatives, and addresses. * Ensure that any chemical treatment of the well is suspended during the sampling period. Take fluid samples for following work: TEST Sep. Sam. Bot.hol. Crude WELL O/G/C PVT* PVT** Char. Slim tube EPRCo Form.dam. 0-20 CONDo 2 LIT. GAS 12 GAL° * Includes backup samples 1. Standard PVT/Compositional analysis --Separator samples * 12 gallon sample of gas * 2 liter sample of oil * Take samples in sliding piston cylinders * Send samples to Warrensville, C/O Mark Pestak ADDRESSES PETROLEUM TESTING SERVICE 12051 RIVERA ROAD SANTA FE SPRINGS, CALIFORNIA 90670-2211 WARRENSVILLE RESEARCH LABORATORY 4440 WARRENSVILLE CENTER ROAD CLEVELAND, OHIO 44128 EXXON PRODUCTION RESEARCH COMPANY 3319 MERCER STREET HOUSTON, TEXAS 77027 BASIC SYSTEM MAKEUP · o FLOWUNE VALVE FLo GREASE LINE BOWEN PACKOFF' RISER HAND PUMP GREASE D " 'PUMP ..,_.GREASE RESERV. O~ J~_tne 4, 1986 ~.ir. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy'. (907) 276-7542 Re: Duck Is land Unit O- 20 b~I Standard Alaska-Production Company Permit No. 86-]06 Sur. Loc. t945'S~U~, 2038'WEL, Sec.36, T]2N, R16E, Btmhole Loc. 2020'S~U~, 1000'EIqL, Sec.31, T12M, R17E, Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not inde_~mmify 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 e~uipment so that .a representative of the Commission may be p~esent to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours prior to comm_encing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~v~ tru!v~v~ur s, Chai~n of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. L°wery row 1 slot 5 M?I Endicott STATE OF ALASKA Revised 6-3-86 ALASKA O,L AND GAS CONSERVATION CO~,.~ISSION Bottom Hole Location PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill '~1 lb. Type of well. Exploratory [] Stratigraphic Test ~. Development Oil Re-Entry [] Deepen~11 Service [] Developement Gas ~. Single Zone [] Multiple Zone 2. Name of _Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ;tankard Alaska Production Company BKB = 56 - feet Endicott Field 3. Address 6. Property Designation · O. Box 196612 Anchorage Alaska 99519-6612 ADL 312828 Endicott Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1945'SNL 2038' WEL Sec. 36, T12N R16E Duck Island Uni_t/ ' ' ' Endicott Blanket At top of productive interval 8. Well nu ,mber Number 0-20 MPI K00683449-G-14 2000' SNL, 575' EWL, Sec. 31, T12N, R17E At total depth 9. Approximate spud date Amount 2020' SNL, 1000 EWL, Sec. 31, T12N, R17E June 5, 1986 200,000. 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVB) property line ADL 34633 175 feet 170 feet 4300 11362 'MD 10446 'Tv~et 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5800 feet Maximum hole angle 35 0 Maximum surface 3900 psig At total depth ¢rVD)9855 ' 484(~sig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" St:ruct. ~rive ~ipe 75' Surfac~. 131' 131' Drive 17%" 13-3/8" 72# L-80 Butt. 2444' Surfac.~ 2500' 2500' 3500' cu. ft. Permafr¢ 12¼" 9-5/8" 47# NTa0S NSCC 5444' Surfac.~ 5500' 5b00' 380 cu. ft. Class G 12¼" 9-5/8" 47# NT95H; NSCC 4823' 5500' 5500' 10323 9596 450 cu. ft. Class G 8%" 7" 29% L-80 Butt. 1289' 10073' 9392' 11362'10446' 400 cu. ft. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ;.~ Intermediate ~ECEIV ED Production Liner JUN 0 ~ 1986 Perforation depth: measured Alaska 0il & Gas ¢;0,% u, ,~J,,,,~ true vertical A;~ch[.,.i.~r i¢ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch [] DiverterSketch []' Drilling program ~ Drilling fluid program ~ Timevs depth plot [] Refraction analysis ~ Seabed report '% 20 AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~..S. (""~~ Title Division Drillinq Enqineer Date(.~/~4 ~ Commission Use Only ! ' I APInumber ._-- IApprovaldate i See cover letter Permit Number ~--/oL, 50- o%~'z~i ~ c,.~ 06/04/86 for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ¢~, No Hydrogen sulfide measures iq Yes ~ No Directional survey required ~ Yes ~ No R equiredworkin~~S~'¢~M; ~ 10M; ~ 15M ~//~ Other: by order of Approved by ~ ~.../ ~ \ -?_/~/,¢F4Fa,~ Commissioner the commission Date .st Form 10-401 Rev. 12-1-85 Sub triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 0-20 (MPI) Drill 17-1/2" hole to 2500' run and cement 13-3/8" 72#/ft L-80 · · · Buttress casing to surface. Install BOPE. Maximum BHP is 4900 psi at 10000' TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Directionally drill 12-1/4" hole to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8", 47#/ft., NT80S and NT95HS, NSCC casing. No fresh water sands are anticipated below the surface casing shoe. No abnormal pressure intervals are expected in the 12-1/4" hole section. The programmed 9-5/8" casing cement will provide over 500 ft. of annular fill-up above all significant hydrocarbon zones. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a nonfreezing fluid. Pressure test the 9-5/8" casing to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commission may witness the test. Drill 8-1/2" hole to TD. Log and run and cement 7", 29#/ft., L-80 Buttress ~-i-ne~ to TD with approximately 250' of lap in the 9-5/8" casing. Clean out to float equipment. Test casing and lap to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commission may witness the test. Change over to NaC1 packer fluid. Run CBL in 7" liner and 9-5/8" casing. Run and set 9-5/8" packer 50' above liner top. Run 3-1/2", 9.3#/ft., L-80, TDS tubing with a sliding sleeve. A subsurface safety valve will be placed 50' below base of permafrost. Install and test tree. Shut in well. Move rig off. Rig up to flow test the well. Perforate as close to G0C as possible, above shale. Flow for one day for stabilization· collect fluid sample. Flow for one day at stabilized rate. Shut in for pressure build up. Rig down test equipment. The well will initially be used as a gas supply well and later a gas injection well. JGV/bg/0736D 0 Alaska Oil & Gas Cons. Oo~-m'~t ::: .... ' O/~ZL L _L-~¥G Pt~OGi~Ahl Pt~Ot~OSEO AI~'L L HOt~E O£A GNAf~ N:L L 0 - ~ 0 (Mm TVD BKB RZG: DO YON d5 t4D BKB BKB: 56' AMS£ i~I6 ' BO00' 3000° 3.qO0 ° ~00° 8778 ° do. 446' t466 ' t~t6 ' ~000 ' a~O0 ' 3000' 3.qO0° ~00° 9383 t0. 083 t0. 073 ' t0. 383 ' 30' S~ruc~ut'al Pipe Base Permafrost SSSV Top of Dounsqueeze Cement t3-3/8" 7~ d/fl L-80 BTC Bottom of Dounoqueeze Qemon~ Heater (Curtain) 9--S/B" 47 Tubtn~ Top of gomon ~/~" TXN Packe~ £1ne~ Hanwat' 9-~/B " 47 ~/f t NTgb-I~ NSCC ~ U N 0 ~ lgaG An¢orago 7" ~ ~/f ~ L -~O B T£ - B.O.P. STACK CONFIGURATION 15 5/8" TRIPLE RANI STACK 5000 PSI WP DRILLING ANNULAR PREYENTER '- J ,'J i 1 I I 8LIND RAMS CHECK KILL UNE HAND GATE GATE DRILLING SPOOL PIPE RAMS I I ,4" CHOKE LINE HAND GATE HYDR. ASST. GATE I II NO. I15- 15 SHEET I ef I0 REV. 0 PLAT OF PROPOSED WELL LOCATIONS MPI IIIII L~llld I# $1¢.&~T. IZI~R.16E.~Umi~t i. SDI Wdll LecMed Il Seg. I~T.IIN.,R.ITE.,Um'~e~ iL PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPAR II IY F.R. BELL I A.S$OC. PRUDHOE BAY OFFICE PRUDHOE BAY, ALA~A IATE: NOV. I$, Ills ICALE: I""1 MILE N I Y: RG.T. CNICXEO IY' I[. ~ 22 0 ° 4~o I ~)o rr ~ 0 ~ 0 t~ 0 272~)° $6 6 61' 0 s.o o CERTIFICATE OF SURVEYOR I llearby certify that l mn properly registered and licensed to practice land surveying in the State 04r Alaska ef~d that this plat represents Qn propoled location for the-Well numbers shown above. Ail aurveyGng wes done by me or under p~y eupervision~ and that ail dim4ns(ons end details are correct. i~laska 0il & Gas Cons, Cor~?,-:i'.:t.'.:" tV O YES' :56 Indicates well Indicates CalcUlated Section Cor~er PoeitioA IRd&catee PerlNndicular Offer Oistence Indicates ~~iculer Off~t Distance perpena~cular ~stonc~ ~ries tgr to~ will } PLAT ~ ~PI PROPOSED IELL LOCATIOgS DRW. IIS-85 · SHE:ET :~ ef I0 l REV. 0 PREPARED FOR SOHIO ALASKA PETROLEUM CO. D~TE' NOV-I$, I~IS ICALEs I"" SO' I)RAWN BY: RJ.T. CHECKED BY' I.E. i i I PREPARED BY F.R. BELL '~t ASSOC. ' PRUDHOE BAY OFFICE PRUDflOE BAY. ALASKA - _ --- I II II '1 I IIII -- -" _ _ _ II I ii i i IKLL AlP J01~ $ UT!../NE 6 L~TZTUBE L~ ~ IIIT(~) IIlT(~ I Y- S912412.37'~ N- 7105324.S~ 7~21'10,0670~ 14~17'~e,~' ' '1921,41 X' 2~110,7~ E- 4&41~7,~& 2 Y- ~982~79.8B N- 780~353.~2 70°2~'20.9814' ~47°57'24.62~7' 1135,43 X- 259041.49 E- 464094.4~ . 3 Y- 5982474.18 ~N- 7805321.98 70c21'09.9846' 147'57'20.6258" 1916.77 2032.11 iX- 259175.01 ~ E- 4641~5.65 ~' ! 4 ~Y- 5982571.69 [ N- 7805~50.99 70c21'10.8991" 147~57'24.7856· 184~.80 : 2174.41 X- 2~90~5 76~ E' 464092 74 5 Y- 5982465.99 N- 7805~19.46 70c21'09.902~" 147c57'20,7857' ~ 1945.15' 201~- X- 259169.27 E- 4641~.95 . i Y- 598256~.50 N- 7B05~48.47 70°21'10.8168" 147~57'24.9454' IB52,{7' 2~79.~8 X- 2S90~0.02 E- 464091.04 7 Y- 5982457.80 N- 7B05~16.94 70~21'09.8200' 147°57'20.9455' 195~.52 204~.06 X- 259~6~.54 E- 4641~2.24 , B Y- 5982555.I0 N- 7805~45.94 70°21'10.7~44' 147°~7'25.105~' 1160.~4 2115.~ X- 259024.29 E- 464089.~ 9 Y- 59B2449,61 N- 780~14.41 70°21'09.7~76' 147°57'21.i~54' lg&l.19 204B.5~ l- 2~91~7.10 E- 4641~0.~ 10 Y- sgB2547.1t N- 7B0~4~.42 70o21'10.6521' 147°~7'25.2&51' IliB.tl 21~0.1~ X- 259018,~5 E- 464~87.62 11 Y- 5982441.42 N- 7805~11.B9 70°21'09,655~' 147°57'21.265~' 1970.26 2054.00 X- 2sgI52.07 E- 464128.B~ . t2 Y' 59B25~8.92 N' 7B05~40,90 70°21'10..5697' 147°57'25.4250' 1177.21 X' 259012,82 E' 464085.92 Il Y' 59824~,2~ N' 7B05~09.~6 70~21'09.57~0' 1470~7'21.4251' 1978.6~! 2059.47 X' 259146.II E' 464127. t2 t4 Y' 59825~0.7~ N' 7805~8.17 70°21'10.4874, 147°~7'25.5B49' lBBS.&6 2201.77 l' 2~9007,08 E' 464~4.21 t5 Y- 5982425,0~ N- 780~306.B4 70c21'09.4906" t470~7'21,~850" 1987,0~ 2064.94 X- 259140.&0 E- 464125.42 ~6 Y" S9~2522.54 N- 7805335.B5 70°21'10,4051" ~47°57'25,7447" ~194.03 2207.24 X- 2~9001.35 E- 4640B2.~0 t7 Y" 59B2416,B4 N" 7805304.3~ 70°2~'09.40B3" ~47°~7'21.7449" ~99~.3B 2070.41 X- 2S9134.16 E" 464~23.71 lB Y" 5982514.35 N- 7B05333.32 70021'10.3227" 147°57'25.904&" 1902.40 22i2.71 X- 258995,61 E- 464080.80 19 Y' 5982408.65 N- 7B0530~.79 70c21'09.3260' 147°57'21.9047' 2003.75 2075.19 X- 259129.13 E- 464122.00 20 Y- ~982~06.16 N- 780~330.B0 70c21'10.2404' ~7°~7'26.0&44' 1910.77 221B.18 X- 2~8989.B7 E- 464079,09 21 Y- 59B2400.46 N- 7805299.27 70°21'09,2436' ~47°~7'22.0&4&' 2012.12 2081.36 X- 2~9~23.39 E- 464120.30 I I MPI PRO SED WELL L ATION LIST ~,g ~ a(~ _ ,~, ~ ~,:3:'~ LOCATED IN SEC. SS. T. IZN. R.16E. UMIAT M. .~~~~ ,~]~_ ~,, ~ ...... PREPARED FOR SOHIO ALASKA PETROLEUM CO. ~~ ~1~ -'~ ~ ORW NO, 116-85 PREPARED BY DATE'NOV. 13 1985 t ~a ~'~~ F.R. BELL ~ ASSOC. Jk_~F~ ..... ,~ SHEET ~ of IO SCALE: ~~~ PRUOHOE BAY OFFICE OeAWN aEV. O PRUOHOE BAY, ALASKA CHECKED BY: I.E. i i OIR£C TIONA L DRILL INa P/EL L 0 - ~ 0 (klP I] PLA 7- Sunf~e to~atdon Sec. 36, Td~¢, RI~E 0 $ e9 £ (TN) range ~ Departure X= ~d, 779 Y= ~, 9B~ 3B7 ~ec. 3i, Td~ RiTE 0 0 Departure X= R6~ ~4 Y= ~ 9B~ 307 dj, 36~ ' (lO, 446' TVD) Sec. 3J, TJ~ RJ7E $255UA88' [DRANO15. DDMS 3- ~I020 CLOSAP SHORT. LIS; 7 Closest Approach Anal§sis Dmte' 3-dUN-86 Time': 10' 18'56 Search Radios= 81307 COURSE LINE For proposed well' MPI020112-31-12-17] Location Top Bottom Note. All W-E S-N TVD(SBS) 209169,00- 5982466.00 -56.00 259080.42~ 5979866.84~ 9766.80 ~epths in '~eet Below Kellg Bushing (BKB) WELL IDENT Closest ApprOach /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOiSEST DISTANCE A029-2028000 SI-DI1 9822.8 2600.5 11229. 5 4924. i 12846.2 SI-DI3 '9659.2 2485. 4 6393. 6 108. 1" 22~'~. 7 A029-2051800 SD-7 82.3 O. 0 75.0 0.2 158~. 9 A029-2063900 " SD-9 107.5 0.0 100.0 0.2 t619.1 A029-2064000 f~- SD-10 5137.5 0 0 5130.0 1362.2 1064.9 A029-2156800 P-18 O. 0 O. 0 O. 0 O. 0 170.~7 TVD SUMMARY The well which comes A029-2156800 closest to the P-18 proposed well is: Closest mppromch KICK OFF ~or this distance !70.7 ~eet 5400.0 ~eet E~,!DICOTT MUD PROGRA~ MAIN P~ODUCTION ISLAND ~WELL 0-20 (MPI) Interval 0-2500 Mud Weight Viscosity Fluid Loss (ppg) sec/qt ml/30 rain 8.8-9.4 100-200 20-15 Set 13-3/8" 9.0-9.5 Mud Type/ Components Generic ~.qud #5 Seawater Fresh Wate Soda Ash 2,500-1 0,323' 8.8-9.4 ~0-45 10-1 2 Set 9-5/8" 10.0-10.5 Generic Mud #7 Seawa te r Fresh Water Gel Caustic Soda Soda Ash Barite Li gnosul fonate Drispac l. ignite 10,323'-11,362' 9.4-9.6 40-45 6-8 Hang 7" Liner 10.0-10.5 Generic ~,ud #7 Seawater Gel Caustic Soda Soda Ash Barite Lignosul fonate Drispac Lignite lO13H DOYON DR!LL!NG, !NC. RiG NO. 15 MUD AND SOLIDS CONTROL EQUIPIdENT Equipment Manufacturer Nominal Model Capacity Shaker Desander Mudcleaners Centri fuge Brandt Dual Double Demco 2-12" cones Tri Flow 1000 9pm 700 9Pm (each) Double 400 9pm 8 each - 4" (each) cones Pioneer Mark II, 150 9pm Decantin9 Degasser Dr i i co Agi tarots Brandt Hepp er s Geo so u rce Vacuum 1000 9pm 8 each - 25 h.p. 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 v:sual and audio warnin9 devices located in the driller's console. [ J., qef ' B_ TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4½" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG. 7) .. 1.) Make up the 13-1/8" x 4½" 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 test plug through the B.O.P. stack until it lands on the lowest 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: Ail lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG REQ'D TH/S END UP L FMC P.N. 48-261-082 PART NO. DESCRIPTION 48-261-268 48-261-083 48-261-673 Test Plug Body Compression Ring 79-040-074 Set Screws 48-081-529 Packing 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~SC~iPTION 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 I - ' B.O.P. STACK -5/8" 5000 WP 3-5/8"~ TESTING THE B.O.P. STACK WITH THE 13½" X 4½" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13½" x 4½" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG tlIS END UP FMC P.N. 48-261-068 REQ'D PART NO. DESCRIPTION 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 ~ Pipe Plug Figure #19 ILLUSTRATION# 13 B.O.P. S TACK 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. 22AI 1.) Make up the 10" x 4½" IF test plug (combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown acres which have been run in. 6.) Remove the test plug. 10" COMBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL THIS END UP FMC PART NO. 48-261-503 REQ'D ..... pA~J-~'~ ..... 6'~SCRIPTION .. 1 48-261-504 BODY 1 48-085-833 BELT PACKING . ,, 1 48-180-025 PLUG, 1¼ L.P. 1 48-180-025 PLUG, 1¼ L.P. 4 I. 48-180-015 PLUG, ½ L.P. · . 1 l 48-010-009 WRENCH ,! (Figure #22A) ~..c ~" ~ B.O.P. STACK 1" 5000 WP ' 13-5/8" 3000 W . - B.O.P. STACK 5000 WP 11" 5000 WP 13-5/8" 3000 WP S.A~E OF ALASKA ALASKA OIL A~N~ GAS CONSERVATION CO~-~MISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF STAI~ARD ) ALASKA PRODUCTION CO~;J~Y ) for a waiver of Endicott ) Field Rules, Conservation ) Order No. 202, Rule 4(b), ) so that no conductor casing ) will be required for all ) subsequent wells drilled ) in the Endicott Field. ) Conservation Order No. 216 Endicott Field Endicott Oil Pool Duck Island Unit June 2, 1986 IT APPEARING THAT: Standard Alaska Production Company, operator of the ~ck Island Unit submitted a request, dated May 13, 1986 = ~ - , ~o~ a blanket waiver o~ Endicott Field rules, Conservation Order No. 202, September 20, 1984, Rule 4(b), Casing and Cementing Requirements, for all the remaining wells to be drilled in the Endicott Field, Duck Island Unit. The referenced rule requires that conductor casing be-set and cemented at least 75 feet below the island surface for each well drilled. Notice of the request was published in the Anchorage Times on May 16, 1986. 3. There were no protests to the requested waiver. FIh~DINGS: Structural casing has been driven to at least 75 feet below the island surface for all wells on the Main Production Island (M~I) and the Satellite Drilling Island (SDI). The primary use of the conductor casing is for instal- lation · and use of a diverter system while drilling the hole for the Surface casing. . Following the drilling of one well on each island, the requirement for a diverter system on all future wells to be drilled from either the M~I and SDI was waived by letter dated April 25, 1986. Development and service wells have been drilled from each island without indication of shallow surface gas. Conservation Order No. 2!6 Page 2 June 2, 1986 CONCLUSIONS: A Conductor casing is no longer necessary to drill wells from either the Miami or the SDI. NOW, THEREFORE, IT IS ORDERED: Rule 4(b) of Conservation Order No. 202 is amended to read as follows: Rule 4(b) Conductor casing to provide for proper anchorage shall be set at least 75 feet below the island surface and sufficient cement shall be used to fill the annulus behind the pipe to the island surface. Cement fill shall be verified by obse~-~'ation of cement returns. The cement may be washed out or displaced to a depth not exceeding the depth of the structural casing shoe to facilitate casing removal upon well abandonment. Ail future development and sec'ice wells which are drilled from either the Ymin Production island or the Satellite Drilling island after June 2, 1986, need not have a conductor casing. DONE at Anchorage, Alaska and dated June 2, 1986. ~. V. Chatrerr~ -~na~..rman Alaska Oil and G,~C6nse~ation Co~ission Lonnze C. Sma~~mm~ssioner Alaska Oil and Gas Conservation Co~r~ission Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of STANDARD ALASKA PRODUCTION COb~ANY for an Amendment to Rule 4(b) of Conservation Order No. 202 pertaining to the Endicott Oil Pool. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated May 13, 1986, to issue an order amending Rule 4(b) of Conservation Order No. 202 to allow the drilling of development wells from the Main Production Island and the Satellite Drilling Island without setting conductor casing. Data from past wells and currentlY drilling wells indicates the absence of shallow gas under the Islands, thus obviating the need for conductor casing to anchor diverter equipment. Parties who may be aggrieved if the referenced order is issued granting the request are allowed 15 days from the date of this publication in which to file a written protest stating in detail the nature of their aggrievement and their request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If such a protest is timely filed, a hearing on the matter will be held at the above address at 9:00 AM on June 18, 1986 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after June 2, 1986. If no such protest is timely filed, the Commission will consider the issuance of the order without a hearing. Harry W. Kug Commissioner Alaska Oil & Gas Conservation Commission Published May 16, 1986 Standard Alaska Production Company 900 East Benson Boulev P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) ,564-5111 May 13, 1986 STANDARD ALASKA PROB Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Standard Alaska Production Company hereby requests a blanket waiver to Endicott Field Rules, Conservation Order No. 202, September 20, 1984, Rule 4,b Casing and Cementing Requirements, for all wells drilled in the Endicott Field, Duck Island Unit. Current drilling plans specify that a 20" conductor casing is set and cemented at 390' followed by 13-3/8" sur- face casing which is cemented to surface from 2500'. Structural casing has been driven to 75' and 120' below the island surface for all wells on the Main and Satellite Islands respectively. Standard is requesting a waiver of the requirement to set conductor casing in lieu of utilizing the 13-3/8" surface pipe to provide for proper anchorage. The referenced regulation requires a conductor casing to be set at least 75' below the island surface and cemented to surface. The primary use of the conductor is to provide support for subsequent casing strings and to allow use of a diverter system while drilling the 17-1/2" hole for the 13-3/8" surface pipe. Standard does not feel that the 20" conductor is essential to safely drill and control the well. Three wells have been drilled to date on the two islands without indication of surface gas or severe lost circulation. The most recent well, M-19 on the Main Produc- tion Island, used neither a 30" nor 20" diverter system but utilized a simple ri ser-fl owl i ne configuration while drilling the 26" and 17-1/2" holes. Standard would like to eliminate the 20" conductors by drilling below the 30" structure pipe with a 17-1/2" bit to 2500' then cement the casing back to surface. The 13-3/8" casing will then be held in tension until the cement has had ample time to set, providing sufficient strength to allow us to nipple up wellhead and BOPE. STAT'rECHI RSA/em cc' R. Reiley B. L. Rose 0706D ^ .n,, o, ,he original StondorcJ Oil Company Founded in Cleveland, Oh o, in' 1870. R. S. Allan Division Drilling Engineer RECEIVED Alaska 011 & Gas Cons. Commi~loll Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 (907) 276-7542 April 2, 1986 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P. O. Box 6612 Anchorage, AK 99502-0612 Re: Waiver of Formation Leak-off Tests and Structural Casing Diverter Systems for Endicott Field Dear Mr. Allan: We have your letter of March 26, 1986, requesting a blanket waiver of the requirements for formation leak-off tests during drilling of the hole for the structural and conductor casings; also, your telephone request 0~~i-~, 1986, f0r--~-i~er of the diverter system requirements on structural casing. It is under- stood that these requests are for all wells to be drilled in the Duck Island Unit, Endicott Field. The Alaska Oil and Gas Conservation Commission hereby authorizes under sections 20 AAC 25.030(h) and 20 AAC 25.035(b)(3) waiver of formation leak-off tests required by 20 AAC 25.030(c)(3), and waiver of a diverter system on the structural cas~n_n_n~as required by 20 AAC 25.035(b)(1) for all wells~~~6-~either of the two artifically constructed gravel islands of the Duck Island Unit, Endicott Field. Yours very tp~{y, ---/ , ~ Lonn±e C. ~sm±th Comm±ssioner jo:F.LCS.4 STATE OF ALASKA ALASKAL _ AND GAS CONSERVATION CC. MISSION PERMIT TO DRILL 20 AAC 25.005 & la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Straticlraphic Test Re-Entry ~ Deepen ~ Service.,~ Developement Gas Single Zone ',~ Multiple Zone [;i ' 2. Name of Operator 5. Datum Elevati'o~'~DF or KB) 10. Field and Pool Standard Alaska Production Company BKB = 56 feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P. O. Box 196612 Anchorage Alaska 99519-661~ ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) Duck Island Unit/ 1945' SNL , 2038' WEL, Sec. 36 T12N, R16E Endicott Blanket At top of productive interval 8. Well nu ,mber Number 2375' SNL, 175' EWL, Sec. 31, T12N, R17E 0-20 MPI KOO683449-G-14 At total depth 9. Approximate spud date Amount 2563' SNL, 517' EWL, Sec. 31, T12N, R17E June 5 1986 $ 200,000. 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 175 feet 170 feet , ~-~,5~.64~ ~ ~'q q' 7~' 11076 ' MD 10296TVDfeet ADL34653 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5800 feet Maximum hole angle 35 0 Ma×imumsurface 3900 psigAttotaldepthCVD¢855' 4840 psig 18. Casing program Setting] Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Dri~'e Pioe 75 ' ~h]rf~_~ ] ~] , ] ~] , Drive " 20" 94# .~T60L~ Butt. 334' ~;urface Rg0' q9¢)' 1700 cu. ft. Permafrost 17%" 13-3/8' 72~ F,-80 Butt. 2444' .~;urface 2500' 2500' 3500 cu. ft. Permafros~ 12%" 9-5/8" 47# ~Ta0S NSCC 5444' ~:urface 5500' 5500' 380 cu. ft. Class G 12¼" 9-5/8" 47# ~T95H~ NSCC ~576' 5500' 5500' _0199' 9576' 400 cu. ft. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true Vertical feet Effective depth: measured feet Junk (measured) true vertical feet · Casing Length Size Cemented Measured depth True Vertical depth Structural 18. (continued) Setting Depth Conductor Hole: 8~" Top MD: 9949 ' Surface Casing: 7" Top TVD: 9371' Intermediate Weight: 29# Cement: 300 cu. ft. Class G Grade: L-80 Bottom MD: 11076' Production Coupling: Butt. Bottom TVD: 10296' Liner Length: 1127 ' Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Q.~-~, ~ TitleDivisi°n Drilling Engineer Date-C/A0/~ , Commission Use Only Permit Number,~_ /'C)~ 50-- '--' ~' -,'~-I ~ '"" ~,¢O~g'" for other requirements Conditions of approval Samples required [] Yes '~i~No Mud log requir, ed ~ Yes d~No Hydrogen sulfide measures Q Yes Q No D, irectional~urvey required ,~.Yes ~; N Required working pressure for BOPE ?I2M; ~ 3M; ,'~.5M; Other:-- / ' by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate PROPOSED DRILLING A~!D COMPLETION PROGRAM WELL 0-20 (MPI) Drill 26" hole to 390' and cement 20", 133#/ft. K-55 Buttress casing to surface. Drill 17-1/2" hole to 2500', run, and cement 13-3/8", 72#/ft., L-80 But- tress casing to surface. Install BOPE. Maximum BHP is 4900 psi at lO000' TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Directionally drill 12-1/4" hole to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8", 47#/ft., NT80S and krF95HS, NSCC casing. No freshwater sands are anticipated below the surface casing shoe. No abnormal pressure intervals are expected in the 12-1/4" hole section. T~e programmed 9-5/8" casing cement will provide over 500 ft. of annular fill-up above all significant hydrocarbon zones. Downsql;eeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a nonfreezing fluid. Pressure test the 9-5/8" casing to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commission may witness the test. Drill 8-1/2" hole to TD Log and run and cement 7t'~e 29#/ft., L-80 But- tress liner to TD with a~proximately 250' of lap in 9-5/8" casing. Clean out to float equipment. Test casing and lap to 3000 psi. Prior notice to be given to the AOGCC so that a representative of the commis- sion may witness the test. Change over to ~,~aC1 packer fluid. Run CBL in 7" liner and 9-5/8" casing. Run and set 9-5/8" packer 50' above liner top. Run 3-1/2", 9.3#/ft., L-80, TDS tubing wi th a sliding sleeve. A subsurface safety valve will be placed 50' below base of permafrost. Install and test tree. Shut in well. Move rig off. · Rig up to flow test the well. Perforate as close to ~OC as possible, above shale. Flow for one day for stabilization, collect fluid sample. F1 ow for one day at stabilized rate. Shut in for pressure buildup. Rig down test equipment. The well will initially be used as a gas supply well and later a gas injection well. - ........ 0504D O/~.TL L ./-NG 14~-L L 0-~0 (~I,~_T) TVD BKB RZ6: DoYeN I 5 t~ BKB BI(~' 56 ' AMS! 131 ° 937t t3t ' t5t6 ~00 ' 8500' 3000' 9t99 9~99 t0, t99' I0, 076 ' 30" Slructural Pipe t33 ~/ft K-55 B TC Crop as. 94 ~/ft) Base Perma fros~ SSSV Top o1' £emene 9-5/0" TXN Packer w/PBR £ lner Hanger 9-5/B" 47 d/fl NT95HS NSCC I~o)ec~ed Perforations 7" ~9 d/f ~ £ -80 B TQ STACK CONFIG' ~ATION B.O \ 1 3 5/8" TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER" PIPE RAMS BLIND RAMS CHECK 2" KILL LINE HAND HAND GATE GATE DRILLING SPOOL 4" CHOKE LINE HAND GATE HYDR. ASST. GATE PIPE RAMS 36 ~ 31 32 33 Moin Productkx Island (IdPl) '~f" ~ T. II~ N. ' I 5 4 T. IIN. $etellite Drillln! IMend ($DI) · ,..,,,,-.:d?-., i~ ~..-..: .'-. ~-'~ "~*':-' .~;..:..,. ~ ,~.~.--~ ..- . .: - .-.,,~-.q ,~ DflW NO. 116- 15 SHEET I ef I0 REV. 0 PLAT OF PROPOSED WELL LOCATIONS MPI 11~111 Leceted li~ Se¢.&6eT. IZN-~R. IEE.,Umiet M. SDI 1Wdll I.J(:eted Ill See. I,T. IIN.,R.I?E.,Um*)It M. ! PREPARED FOR SOHIO ALASKA PETROLEUM CO. PRE:PAR EB BY F.R. BELL & ASSOC. PRUDHOE BAY OFFICE PRUDHOE BAY, ALA~I:A _'%~ i - ] I I I ~ 14 I% ~ 20 22 0 o~<::)°'-~ I 13 0 ~7 ~) 0 '~l 0 ~ 0 3%% s ~0© 57 ~b o 36 NO YES' 36 CERTIFICATE OF SURVEYOR I heerby certify that I sa properly registered end licensed to practice lend surveying i~ the State c~ Alaska end that this plat represents an proposed tacetioa for the 'Well num~rs ~hown above. Ail endt~t ell dimnsioas end details ere correct. DRW. 116-85 SHEET Z ef I0 REV. 0 Indicates well Indicetel Calc[Jleted Section Cer~er Polttiea IRdicefes Plr~Rdieallr Off~t Oiste~ct I~d~c~t8 ~~ic~ler Off~t DiBteace )endicvler d~stonc~ PLAT ~ MPI PROPOSED WELL LOCATIONS L~CA~D IH BEC. ~6, T. 12 ~., R. 16 E. UMIAT M. ~EPARED FOR SOHIO ALASKA PETROLEUM CO. PR E P~R E D BY F.R. SELL '~ ASSOC.' PRUDHOE BAY OFFICE PRU~OE BAY, ~ASKA DATE' NOV. I$, ills SCALEs I"8 SO' CHECKED BY' I.E. I~LL ~lF' loll: $ UTI, Jl~: 6 LRTITUI[ LII, ~ III ~IIT . I Y- S912412,]7 N- 710~324.~l 7~21'10.0670~ 14~7'le,4~' 19Zl,4e X- 2~92B0,7~ E- 4&4Z~7,36 2 Y- 5982~79,B8 N- 7805353.~2 70°21'10.9814' 147°57'24,&237" 113~,43 211B.94 X- 259041,49 E- 464094,45 3 Y- 5982474.18 ~N- 7805~2~,9~ 70~21'09.9e46" 247~57'20,625B" ~936,77 4 Iy. 5982571.69 N- 7805550.99 70021'10.8991" 147~57'24.7856' ~ 1845.80 2174.41-- X- 2590~5.76 E- 464092.74 ~ 5 Y- 5982465.99 N= 7805~19.46 70021'09.902~" 147c57'20.7857' , 1945.15' 20~7.58- X- 259169.27 E' 4641~.95 & Y- 5982563.50 N- 7B0534B.47 70°21'10,~16B" 147~57'24.9454' IB52.17' 2179.~8 X- 259030,02 E' 464091,04 , 7 Y- 5982457,80 N- 7805316.94 70~21'09.B200' 147057'20,9455, 1953.~2 2043.06 X- 2~9163.~4 E- 464132.24 ~ Y- 59B2555,30 N- 7805345,94 70~21'~0,7344' 147° 57 ' 25.1053' IB&0.~4 X- 259024,29 E- 464089.33 9 Y- 59B2449,61 N- 7805314,41 70°21'09.7376' 147°57'21,1054' 19Al,B9 204B.53 X' 259~7,10 E' 464130,53 ZO Y- 5982547.~ N- 7B0~43.42 70o2Z'Z0.6~2Z' Z47G~7'2~.2&~Z' ~l&8.9~ 2~90.l~ X- 2~90Z8.~ E- 464~87.62 11 Y- ~9B2441,42 N- 7805311.B9 70°21'09,6~3' 147°57'21,26~3' 1970.26 2054.00 X- 2~9~52,07 E- 464128,83 ~2 Y- 59B2~38.92 N- 7805340,90 70~21'10.~697' 147°57'2~.4250' IB77,21 219&.30 X- 2~9012,82 E- 46408~.92 ~3 Y- ~982433.23 N- 7805309.36 70°21'09,~730' 147°~7'21.42~1' 1978.63~ 20~9.47 X- 2~9146,33 E- 464127,~2 14- Y- ~9B2530.73 N- 7805338,37 70~21'10,4B74' 147°~7'25,~B49' IBB~,&6 2201.77 X- ~9007,08 ~' 464~B4,2~ ~ Y- 59B242~,03 N- 780~306,84 70021'09.4906, 1470~7'21,5B~0' 19B7,00 2064,94 X- 259140.&0 E- 464125,42 16 Y- ~9B2~22,~4 N- 780533~,8~ 70°21'~0,4051' 147°~7'25,7447' 1194'03 2207,24 ;- 259001,3~ E' 4640B2,50 17 Y' 59B2416,B4 N' 78053'04.3~ 70°2~'09.40B3' 147°57'21.7449' 1995.3B 2070,41 X' 259~34,16 E' 464i23.71 lB Y' 5982514.35 N' 7805333.32 70021'10.3227' 147°57'25.904&' 1902,40 22i2,71 l' 258995,&1 E' 464080,80 19 Y- 5982408,65 N- 7B05301.79 70c21'O9.3260' 147o57'21.9047, 2003.75 2075.B9 X- 259129,13 E- 464122.00 20 Y' 5982506,16 N' 7805330, B0 70c21'10.2404' 147057'26,0644, 1910,77 221B,18 X' 258989.B7 E' 464079,09 21 Y' 5982400.46 N' 7805299.27 70021'09.2436, 147°57'22.0&4&' 2012,12 20BI.36 X- 259123,39 E- 464120.30 MPI PRO~SED WELL L~ATION LIST --.C ~ 4L~,- LOCATED IN SEC. SI',T. IZN. R.ISE. UMIAT ~~ · ~"~~~'.. . ~ SOHIO ALASKA PETROLEUM CO. · ,'~ ~1~ .'/,~ DRW. NO. 116-85 PREPARED IY DATE:NOV. IS, , ~o~,~~ ~ F.R BELL & ASSOC q ~0F ~ SHEET 3 of IO ' ' SCALE: N/A ~ ESS~ ~ -~%~~ PRUDHOE BAYOFFICE DRAWN BY: RG.T ~EV. O PRUDHOE BAY, ALASKA CHECKED ii 01£E£ TION~ L ORIL LING ~EL L 0-~0 TWPI? ~L~ ? 466 Target Departure 2260' X = 26t, 366 Y = ~, 98t. 935 10, 43t' (9766' TVD) Sec. 3d, Td2N, Rd7E BI-IL Departure 2629 ' X = 26d, 708 Y = L~ 981, 747 Id, 076' ~ (dO, 296 ' TVD) Sec. 3d, Td~ RdTE w _$25DUA88' [DRANO15. DDMS]MPIO~O_CLOSAP_SHORT. LIS;3 ~-MAY-1986 09:18 Search Radius= 31130 COURSE LINE For p'roposed well' MPI0~0[12-31-12-17] Location = W-E S-N TVD(SBS) Top 259169.00 59824&6.00 -56.00 Bottom 259096.93 5980224~59 9684,96 --- Closest Approach Analgsis --- Date' 9-MAY-86 Time' 09'18:38 Note' All depths in Feet Below ½ellg Bushing .Closest Approach WELL I.DENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART' A029-2028000 DI-1 9741,0 2242,6 A029-2028001 DI'2A 227,6 0,0 A029-2051000 DI-3 9741,0 2242,6 A029-~051800 SAG-7 82,3 0,0 SAG-9 107,5 0,0 A0~9-2064000 SAG-lO 5342,7 0,0 11060,4 100,0 ' 6390.2 7D.O 100,0 533D, 2 4827. 8 181, 7 0,2 0,2 1581, 0 SUMMARY The well which comes closest to the proposed well is' A029-2064000 WAO-IO CLOSEST DISTANCE 18600.6 20514,6 24216.8 1585, 1619,1 1117,5 Vertical /PROPOSED\ TVD DEPART Closest approach distance = 1117,~ Feet KICK OFF For this run = ~800,0 Feet ENDICOTT MUD PROGRAM MAIN PRODUCTION ISLA~!D WELL 0-20 (MPI) Interval 0-300' Mud Weight Viscosity Fluid Loss (ppg) sec/qt ml/30 rain 8.8-9.0 200-300 N/C Set 20" LH 8.5-9.0 Mud Type/ Components Generic Mud #5 Fresh Water Gel Soda Ash 300-2,500' 8.8-9.4 1 00-200 20-1 5 9.0-9.5 Set 13-3/8" Generic Mud #5 Seawater Fresh Water Soda Ash 2,500-10,1 99' 8.8-9.4 40-45 lO-12 Set 9 5/8" 10.0-10.5 Generic Mud #7 Seawater Fresh Water Gel Caustic Soda Soda Ash Barite Li gnosul fonate Dri spac Lignite 10,199'-11,076' 9.4-9.6 40-45 6-8 Hang 7" Liner 10.0-10.5 Generic Mud #7 Seawater Fresh Water Gel Caustic Soda Soda Ash Barite Lignosul fonate Dri spac Li gni te 0504D DO¥ON DRILLING, INC. RIG NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Nominal Model Capacity Shaker Desander Mudcleaners Centrifuge Brand% Dual Double Demco Z-ir" cones Tri Flow 1000 gpm 700 gpm (each) Double 400 gpm 8 each - 4" (each) cones Pioneer Mark II, 150 gpm Decanting Degasser Drilco Agitators Brandt Hoppers Flow Sensor Totco Vacuum 1000 gpm 8 each - 25 h.p. Dual Sidewinders 1000 gpm The %rip tank and mud tank sections have one vertical pit level float indicator which are connected to %he drilling recorder system that contains visual and audio warning devices located in the driller's console. IF IN DOUBT . - - ASK. II · e -o' ~6.:c' I 1 - T · t I I~ 'C °' i. -t- o~ I I ~., ii,--,: ?, !" · 0 (8) (3): Adm/n (10 and 13) ( .(5) BOPE (23- t'hr~ ~ (6) OTHER - ~.'~ (29 thru 31) Geology~;~ Eng~ering: , Lcs 'WVA MTM ~;~.~ HJH JAL. rev: 04/03/86 6.011 pERM£TS · 2. 3. 4. 5. 6. 7. 8. COmpany Is the permit fee attached ' ' ee:e®ee®®®eeee®e®eeee®e,eeeeeeeeeeeeeeeeeee Lease & Well "No. D/ &( o- o YES NO REMARKS /. Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. ls 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 ten-day wait ........................ 10. 11. ]2. 13. 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 . eeeeeeeeeeeeeeeeeeeee,eeeeeeee,eeeeee Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known produCtive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~/ Are necessary diagrams and descriptions of~_~v-~.'~o~n3 BOPE attached. Does BOPE have sufficient pressure rating - Test to ly /AP ) ' Does the choke manifold comp w I 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 Additional requirements ..................... . ........................ , · INITIAL OEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ofoo 29o ? 8) ompany YES Is the' permit fee attached . ~ ' · ~ · 3'ii, Is wel~ii~iOca~ed~ii~ppe,r_-dist~fije-?from property line ..... '-'~irYi~!~i:',i'ils ~ell to be deviated and is wellbore plat included ... :~':'i';i'?i~'IS operator the only affected party .................... Can permit be approved before ten-day wait .......................... (4) Casg ~~.~, (1,4 thru 22) (23 thru 28) (6) OTttER ~,~, (29 thru 31) (6) Add: Geology: WVA JAL Engineering: LCS ~ MTM ~ HJH ~ rev: 04/03/86 6.011 NO. REMARKS e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~ Is administrative approval needed .~'. Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ . .. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ........ ;... Is adequate wellbore separation proposed ..................... , ...... 23. 24. 25. 26 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient· pressure rating - Test to ~oo~z/~oo¢ 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 ON/OFF POOL CLASS STATUS AREA NO. SHORE ; o,oo J .r" I-esop 8"?o l O Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. 1 - 05/0- 20 ENDICOTT Run 1' 28 - February- 1995 CN/GR Cased Hole 1O6O0 11115 R E C E IV E D ~JtT-r~l~l~ MAR 1 ? 1995 Anohorag,Wireline Se~ices Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING i - 05/0 - 20 500292160500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 13-MAR-95 4063.02 HARPER J. POWERS 36 12N 16E 1945 2038 55.30 54.30 45.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10387.0 47.00 7.000 11260.0 29.00 7.000 9513.0 26.00 5.500 9742.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 04-JUL-86 SWS BASELINE DEPTH 10581.5 10593.5 10594.0 10606.0 10611.0 10612.5 10664.0 10674.0 10674.5 10688.5 10689.5 10693.0 10740.5 GRCH 10580.5 10592.5 10593.5 10605.5 10610.5 10612.5 10663.0 10673.0 10674.0 10688.0 10688.5 10692.0 10740.0 EQUIVALENT UNSHIFTED DEPTH 10774.5 10776.0 10776.5 10777.0 10778.0 10818.5 10819.5 10829.5 10840.5 10843.0 10862.5 10872.5 10878.5 10913.0 10913.5 10926.0 10930.0 10931.0 10937.0 10942.0 10947.0 10948.5 10962.0 10967.0 10971.0 10971.5 11012.5 11021.5 11025.0 11032.0 11032.5 11033.0 11041.0 11061.5 11063.5 11065.5 11072.0 11075.5 11091.0 11092.0 11094.5 $ REMARKS: 10774.0 10775.5 10776.5 10777.0 10777.5 10818.0 10819.5 10829.5 10841.0 10843.5 10863.0 10873.5 10880.0 10913.0 10914.0 10926.0 10930.5 10931.0 10937.0 10942.5 10947.5 10948.5 10962.5 10967.0 10971.0 10972.0 11014.5 11023.5 11028.0 11035.0 11036.0 11036.5 11044.0 11064.5 11066.0 11068.0 11075.5 11079.0 11093.5 11094.5 11097.5 CN/GR Cased Hole. CORRELATED WITH CBL OF 07-JUL-86. PUMPED 525 BBLS OF SEAWATER. MADE CN PASS ONE PUMPING AT 3 BBLS PER MINUTE. MADE CN PASS TWO PUMPING AT 5 BBLS PER MINUTE. MADE CN PASS THREE PUMPING AT 1 BBL PER MINUTE. PUMPED AN ADDITIONAL 225 BBLS DURING LOGGING PROCESS. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER CORRECTION = 0.00, CASING CORRECTIONS OFF, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A . OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 10576.0 2418 10587.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH NPHI 10593.5 10592.5 10594.0 10593.5 10606.0 10605.5 10611.0 10610.5 10612.5 10612.5 10616.5 10615.5 10664.0 10663.0 10674.0 10673.0 10688.5 10688.0 10689.5 10688.5 10693.0 10692.0 10740.5 10740.0 10774.5 10774.0 10778.0 10777.5 10818.5 10818.0 10819.5 10819.5 10829.5 10829.5 10840.5 10841.0 10843.0 10843.5 10862.5 10863.0 10872.0 10872.0 10878.5 10880.0 10913.0 10913.0 10913.5 10914.0 10926.0 10926.0 10930.0 10930.5 10931.0 10931.0 10937.0 10937.0 10942.0 10942.5 10947.0 10947.5 10948.5 10948.5 10962,0 10962.5 10967.0 10967.0 10971.0 10971.0 10971.5 10972.0 11012.5 11014.5 11019.0 11020.5 11021.5 11023.5 11025.0 11028.0 for each run in separate files. STOP DEPTH 11103.0 11115.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11032.0 11032.5 11033.0 11041.0 11061.5 11063.5 11065.5 11072.0 11074.5 11075.5 11091.0 11092.0 11094.5 $ REMARKS: 11035.0 11036.0 11036.5 11044.0 11064.5 11066.0 11068.0 11075.5 11077.0 11079.0 11093.5 11094.5 11097.5 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH1B . OUT $ : BP EXPLORATION (ALASKA) : i - 05/o- 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 23 Tape File Start Depth = 11130.000000 Tape File End Depth = 10565.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS. representation code decoding summary: Rep Code: 68 5656 datums Tape Subfile: 2 238 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 10577.0 10588.0 BASELINE DEPTH 10578.5 10582.5 10600.5 10601.0 10612.5 10617.5 10623.0 10623.5 10628.0 10629.0 10631.5 10656.0 10661.0 10664.0 10665.0 10669.5 10671.5 10672.0 10683.5 10684.5 10687.0 10692.0 10710.0 10710.5 10714.5 10722.0 10727.5 10734.5 10771.0 10774.0 10775.0 10776.0 10779.0 10786.5 10787.5 10793.0 10796.5 GRCH 10577.5 10581.5 10599.5 10600.5 10663.5 10664.0 10670.5 10671.5 10683.0 10683.5 10691.0 10774.0 10775.0 10775.5 STOP DEPTH 11103.0 11115.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 10612.5 10617.0 10622.5 10623.5 10628.0 10628.5 10631.0 10657.5 10662.5 10664.0 10669.5 10672.5 10685.0 10687.0 10710.0 10711.0 10715.0 10722.0 10727.5 10735.0 10771.5 10779.5 10787.0 10787.5 10793.5 10797.5 10804.0 10805.0 10816.5 10817.0 10818.5 10820.0 10823.0 10824.0 10824.5 10828.5 10829.0 10829.5 10837.5 10838.0 10839.0 10841.5 10842.0 10845.5 10850.0 10853.0 10854.0 10855.0 10860.5 10912.5 10913.0 10914.0 10916.0 10918.0 10922.5 10928.5 10930.5 10931.0 10938.5 10947.0 10948.5 10949.0 10970.0 10971.5 11012.5 11013.5 11015.0 11019.5 11021.0 11022.5 11023.0 11025.0 11026.5 11027.5 11028.0 11034.0 11038.5 11042.0 11046.0 11047.0 11058.5 11069.0 11069.5 11072.0 11076.5 11078.5 10818.0 10824.5 10828.5 10829.5 10830.0 10913.5 10914.0 10914.5 10923.0 10928.5 10930.5 10931.5 10947.5 10949.5 10950.0 10970.5 10972.0 11015.0 11017.0 11023.0 11025.0 11025.5 11028.0 11037.0 11045.5 11049.5 11050.0 11072.0 11073.0 11075.0 11080.0 11082.0 10805.0 10805.5 10817.0 10818.0 10821.5 10824.5 10825.0 10830.0 10839.5 10840.0 10840.5 10843.0 10844.0 10847.5 10851.5 10854.5 10855.0 10855.5 10861.5 10915.5 10917.0 10919.0 10930.0 10940.0 11016.5 11022.5 11031.0 11032.0 11032.5 11042.5 11062.0 11079.5 11081.0 11087.0' 11088.5 11091.5 11093.0 11094.0 11094.5 11095.5 11098.5 11108.5 $ REMARKS: 11082.5 11089.5 11091.0 11094.5 11097.0 11097.5 11098.0 11085.5 11089.5 11097.0 11102.0 11110.0 PASS 2. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH2A. OUT /??MATCH2B. OUT $ : BP EXPLORATION (ALASKA) : 1 - O5/O- 2O : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TaPe depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 23 Tape File Start Depth = 11130.000000 Tape File End Depth = 10565.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep, Code: 68 5656 datums Tape Subfile: 3 165 records.., Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 10586.0 10598.0 BASELINE DEPTH 10593.0 10610.0 10618.0 10624.5 10625.0 10664.0 10665.0 10671.0 10671.5 10672.0 10677.0 10685.0 10692.5 10693.0 10710.5 10744.0 10745.0 10756.5 10757.0 10768.0 10771.0 10772.0 10774.5 10776.0 10777.0 10778.0 10780.5 10781.5 10788.5 10789.5 10790.0 10794.0 10804.0 10805.0 10815.0 10815.5 10818.5 STOP DEPTH 11103.0 11115.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... NPHI GRCH 10591.0 10608.0 10662.5 10670.0 10671.0 10691.5 10774.0 10780.0 10780.5 10787.5 10788.0 10789.0 10817.5 10617.0 10622.5 10623.0 10664.5 10670.5 10677.0 10684.5 10692.0 10710.5 10744.0 10744.5 10757.5 10758.0 10768.0 10771.0 10773.0 10777.0 10777.5 10778.0 10790.0 10794.5 10804.5 10805.0 10815.0 10816.0 10823.0 10825.5 10826.5 10829.0 10829.5 10837.5 10841.5 10869.0 10873.5 10876.5 10878.0 10880.5 10912.5 10914.0 10915.0 10915.5 10916.5 10919.0 10920.5 10925.5 10927.5 10929.5 10932.0 10936.0 10937.0 10939.0 10946.5 10971.0 10972.0 10972.5 10978.5 10983.5 10986.0 10987.5 11012.5 11013.0 11014.0 11021.0 11023.0 11025.0 11025.5 11026.0 11027.0 11028.0 11028.5 11035.5 11039.5 11040.0 11041.0 11044.5 11048.0 11053.0 11060.0 11061.5 11068.5 11073.0 11075.5 11077.0 11083.0 11086.5 10822.5 10828.5 10874.0 10877.0 10879.0 10881.5 10913.0 10914.5 10915.0 10920.5 10925.0 10939.0 10971.0 10971.5 10972.0 10979.0 10984.0 10987.0 10988.5 11014.5 11025.0 11027.5 11030.5 11031.5 11042.5 11044.5 11047.5 11051.0 11055.5 11062.5 11063.5 11071.5 11080.0 11085.0 11089.0 10826.0 10826.5 10829.5 10838.5 10842.5 10870.0 10914.0 10917.0 10917.5 10920.0 10928.5 10931.0 10933.5 10937.5 10938.0 10947.5 11015.5 11016.0 11016.5 11023.5 11029.5 11030.5 11031.5 11032.0 11039.5 11044.0 11076.5 11080.0 11088.5 11093.0 11095.0 11095.5 11103.5 11108.5 11115.0 $ REMARKS: 11091.0 11097.0 11097.5 11091.0 11099.0 11094.5 11106.0 11110.0 11097.0 11115.0 PASS 3. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3A. OUT /??MATCH3B.OUT $ : BP EXPLORATION (ALASKA) : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 23 Tape File Start Depth = 11130.000000 Tape File'End Depth = 10565.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11312 datums Tape Subfile: 4 161 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REM~tRKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ : BP EXPLORATION (ALASKA) : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 23 Tape File Start Depth = 11130.000000 Tape File End Depth = 10565.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11312 datums Tape Subfile: 5 46 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes TaPe Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10575.5 2418 10586.0 $ LOG HEADER DATA STOP DEPTH 11114.0 11124.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PCM/CCL GR GAMMARAY CN COMPENSATED NEUTRON $ 28-FEB-95 FSYS REV. J001 VER. 1.1 1456 28-FEB-95 11177.0 11117.0 10600.0 11115.0 1500.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 O.OO0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS) : 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : i - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 81 Tape File Start Depth = 11128.000000 Tape File End Depth = 10568.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31482 datums Tape Subfile: 6 155 records... Minimum record length: Maximum record length: 42 bytes 1014 bytes Tap~ Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10576.0 2418 10587.5 $ LOG HEADER DATA STOP DEPTH 11114.0 11125.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ 28-FEB-95 FSYS REV. J001 VER. 1.1 1528 28-FEB-95 11177.0 11117.0 10600.0 11115.0 1500.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION XN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 81 Tape File Start Depth = 11129.000000 Tape File End Depth = 10569.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31482 datums Tape Subfile: 7 155 records... Minimum record length: Maximum record length: 42 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10586.0 2418 10597.0 $ LOG HEADER DATA STOP DEPTH 11113.0 11124.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ 28-FEB-95 FSYS REV. J001 VER. 1.1 1556 28-FEB-95 11177.0 11117.0 10600.0 11115.0 1500.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REM3tRKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : i - O5/O- 20 : ENDICOTT : NORTH SLOPE · o ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 i GAPI 4 2 CNC 2418 68 1 PU-S 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 27 466 87 5 4 28 122 23 5 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 79 Tape File Start Depth = 11128.000000 Tape File End Depth = 10576.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51364 datums Tape Subfile: 8 153 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tap~ Subfile 9 is type: LIS 95/ 3/13 01 **** REEL TRAILER **** 95/ 3/13 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 13 MAR 95 l:03p Elapsed execution time = 8.35 seconds. SYSTEM RETURN CODE = 0 1 - 05/0 - 2O ENDICOTT Run 1' 04 - February - 1994 CN/GR Cased Hole 10574 1113 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING i - 05/0 - 20 500292160500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 14-FEB-94 4063.01 D. BARBA M. MARTIN 36 12N 16E 1945 2038 55.30 54.30 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10387.0 47.00 7.000 11260.0 29.00 7.000 9513.0 26.00 5.500 9742.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 04-JUL-86 BASELINE DEPTH 10356.0 10668.0 10678.5 10684.5 10690.0 10740.0 10776.5 10783.0 10787.5 10801.0 10807.0 10810.5 10812.0 GRCH 10356.0 10667.0 10677.5 10684.0 10689.5 10737.5 10776.0 10782.0 10787.0 10801.0 10806.5 10809.5 10811.0 EQUIVALENT UNSHIFTED DEPTH 10816.0 10825.0 10844.0 10862.5 10872.0 10878.0 10896.5 10917.5 10920.5 10926.0 10929.5 10934.0 10939.0 10941.0 10943.5 10962.0 10965.0 10967.0 10979.5 11005.0 11019.0 11028.0 11032.5 11038.0 11048.5 11056.0 11068.5 11074.5 11087.0 11091.5 11098.0 11132.0 $ REMARKS: 10815.5 10824.5 10844.0 10863.5 10872.5 10879.0 10897.0 10917.5 10921.0 10926.0 10929.5 10933.5 10939.0 10941.5 10944.0 10962.5 10965.5 10967.5 10980.5 11005.5 11021.5 11031.0 11036.0 11041.0 11051.5 11060.0 11072.0 11079.0 11090.5 11094.5 11101.5 11132.0 CN/GR Cased Hole. LOG TIED TO LDT/CNL RUN 04-JUL-86. NEUTRON LOG PARAMETRS: SANDSTONE MATRIX, CHISM FILTERING ACTIVE, CALIPER CORRECTION = 8.5", CASING CORRECTIONS APPLIED CASING THICKNESS = 0.408" CEMENT THICKNESS = 0.750" NO SALINITY CORRECTIONS. THE CNCF CURVE WAS USED AS NPHI IN THE EDITED FILES INSTEAD OF THE CNC CURVE PER CUSTOMER'S REQUEST. PUMPED 976 BBLS OF SEAWATER BEFORE LOGGING PASS 1. PUMPED AN ADDITIONAL 38 BBLS & MADE PASS 2. MADE PASS 3 WHILE PUMPING AT 1 BBL PER MINUTE. OPEN HOLE GAMMA RAY DOWNLOADED FROM THE BP EXPLORATION UPS/CSS SYSTEM 09-FEB-94. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2435 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 10645.0 10645.0 STOP DEPTH 11105.0 11113.0 (MEASURED DEPTH) BASELINE DEPTH NPHI 10356.0 10356.0 10668.0 10667.0 10678.5 10677.5 10684.5 10684.0 10690.0 10689.5 10740.5 10740.5 10782.5 10782.0 10787.5 10787.0 10801.0 10801.0 10807.0 10806.5 10816.0 10815.5 10825.0 10824.5 10844.0 10844.0 10862.5 10863.5 10872.0 10872.5 10878.0 10879.0 10896.5 10897.0 10916.5 10917.0 10920.5 10920.5 10926.0 10926.0 10929.5 10929.5 10934.0 10934.5 10939.5 10940.0 10941.0 10942.0 10943.5 10944.5 10962.0 10962.5 10969.0 10969.5 10979.5 10980.5 10989.0 10990.0 11005.0 11006.0 11019.0 11021.5 11032.5 11036.0 11038.0 11041.0 11043.0 11047.5 11048.5 11052.0 11053.0 11057.0 11056.0 11059.5 11068.5 11071.0 11071.0 11073.5 in separate files. EQUIVALENT UNSHIFTED DEPTH 11074.5 11086.0 11091.5 11098.0 11132.0 $ REMARKS: 11079.0 11090.0 11094.5 11101.5 11132.0 PASS 1 (NPHI = CNCF). FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH4. OUT $ : BP EXPLORATION : 1 - 05/o - 2o : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TENS 2435 68 1 LB 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 37 Tape File Start Depth = 11132.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9319 datums Tape Subfile: 2 242 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 10645.0 2435 10645.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 10356.0 10356.0 10650.5 10649.5 10659.0 10661.5 10663.0 10664.0 10662.5 10664.5 10668.5 10669.5 10670.5 10669.0 10671.5 10669.5 10673.5 10674.0 10680.0 10678.5 10684.5 10685.0 10689.5 10690.0 10691.0 10692.0 10690.5 10708.5 10709.5 10710.5 10713.5 10720.0 10721.0 10725.5 10726.5 10735.0 10732.0 10735.5 10744.0 10744.5 10745.5 10742.5 10746.0 10771.0 10771.5 10772.5 for each pass in separate files. STOP DEPTH 11102.0 11110.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 10356.0 10649.5 10658.5 10661.0 10661.5 10662.0 10663.0 10667.0 10667.5 10671.5 10672.5 10683.0 10684.0 10688.5 10689.5 10690.5 10709.0 10710.0 10710.5 10713.5 10719.0 10720.0 10725.5 10726.5 10734.5 10743.0 10744.0 10745.5 10771.0 10771.5 10772.0 10775.0 10778.5 10779.5 10780.0 10780.5 10787.0 10787.5 10788.5 10789.5 10790.0 10790.5 10794.0 10797.5 10798.5 10801.0 10808.5 10813.5 10817.0 10818.0 10818.5 10821.0 10826.0 10827.0 10830.5 10837.0 10839.0 10840.0 10841.5 10844.0 10845.0 10846.0 10846.5 10861.5 10870.5 10872.5 10876.0 10878.0 10885.5 10897.5 10919.5 10920.0 10921.5 10922.0 10922.5 10928.0 10929.0 10930.0 10930.5 10931.0 10932.0 10934.0 10934.5 10937.0 10939.0 10941.0 10946.5 10947.0 10969.5 10971.5 10988.5 10774.0 10786.5 10787.0 10788.0 10789.0 10789.5 10794.0 10800.5 10808.0 10813.0 10841.5 10844.0 10862.0 10872.5 10878.0 10885.5 10898.0 10919.0 10920.0 10922.0 10929.5 10934.0 10938.5 10941.0 10946.5 10947.5 10969.5 10971.5 10778.0 10778.5 10779.0 10780.0 10786.5 10787.5 10797.5 10798.0 10816.5 10817.0 10817.5 10820.5 10825.5 10826.0 10829.5 10836.5 10838.5 10839.0 10844.0 10844.5 10845.0 10870.0 10872.0 10876.5 10922.0 10922.5 10928.0 10928.5 10929.5 10930.5 10931.0 10931.5 10933.5 10934.5 10937.5 10989.0 10989.5 11005.0 11012.5 11013.0 11021.0 11023.0 11023.5 11024.0 11024.5 11025.0 11028.5 11029.5 11039.0 11039.5 11040.0 11040.5 11041.0 11042.0 11046.0 11046.5 11048.0 11053.0 11055.0 11055.5 11059.0 11066.0 11068.0 11070.5 11073.5 11074.0 11076.0 11078.0 11081.5 11082.5 11089.5 11091.5 11096.0 11100.0 11132.0 $ REMARKS: 10989.5 11005.5 11014.5 11015.0 11023.0 11025.5 11025.5 11026.5 11027.5 11027.5 11031.5 11032.0 11041.5 11042.5 11043.0 11044.0 11044.5 11045.0 11048.5 11049.5 11051.0 11056.0 11058.5 11059.0 11062.0 11069.5 11067.5 11070.0 11072.5 11077.0 11078.0 11079.5 11082.0 11085.5 11086.0 11092.5 11095.0 11099.0 11103.5 11132.0 11132.0 PASS 2 (NPHI = CNCF). FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH2. OUT /??MATCH5 . OUT $ CN : BP EXPLORATION WN : 1 - 05/0 - 20 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TENS 2435 68 1 LB 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 37 Tape File Start Depth = 11132.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9319 datums Tape Subfile: 3 207 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2435 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 10574.0 10574.0 BASELINE DEPTH GRCH 10356.0 10356.0 10581.5 10576.5 10586.5 10582.0 10589.0 10584.5 10596.0 10592.5 10601.5 10597.5 10607.5 10603.5 10612.0 10608.0 10651.0 10657.5 10660.5 10661.5 10663.5 10664.0 10665.0 10662.0 10666.0 10668.0 10669.0 10673.0 10670.0 10675.0 10672.5 10676.0 10676.5 10677.0 10684.5 10682.0 10685.0 10683.0 10685.5 10691.0 10691.5 10689.5 10710.5 10711.5 10712.5 10713.0 10713.5 10735.5 10736.5 10740.5 10736.0 10746.0 STOP DEPTH 11102.0 11110.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 10356.0 10649.0 10656.0 10659.0 10659.5 10660.0 10660.5 10664.0 10666.0 10666.5 10670.5 10673.0 10673.5 10674.5 10682.5 10683.5 10689.0 10709.0 10710.0 10710.5 10711.0 10712.0 10734.0 10734.5 10744.0 10757.0 10759.5 10763.0 10776.5 10777.5 10778.5 10780.5 10781.0 10789.0 10789.5 10791.0 10791.5 10794.0 10795.5 10796.5 10798.0 10799.0 10803.0 10805.0 10817.0 10817.5 10822.0 10824.0 10825.0 10826.5 10827.0 10829.5 10838.5 10839.5 10840.5 10844.0 10846.0 10847.0 10862.0 10869.5 10870.0 10872.0 10873.0 10879.0 10898.0 10913.0 10913.5 10914.5 10915.5 10916.0 10918.0 10919.0 10931.0 10931.5 10932.0 10932.5 10933.0 10933.5 10934.5 10939.5 10946.0 10946.5 10947.0 10948.0 10949.0 10774.0 10775.0 10775.5 10788.0 10792.5 10801.5 10803.0 10815.5 10821.5 10827.0 10844.0 10861.0 10870.5 10878.5 10897.0 10912.0 10912.5 10913.0 10929.5 10930.5 10931.0 10931.5 10944.5 10945.5 10946.0 10947.5 10948.5 10754.0 10756.5 10760.5 10778.0 10779.0 10787.0 10788.0 10789.5 10790.5 10794.5 10795.0 10796.5 10797.0 10815.0 10819.5 10821.5 10822.0 10823.5 10824.5 10827.0 10837.0 10838.0 10838.5 10844.0 10844.5 10868.5 10869.5 10872.5 10912.5 10913.5 10914.0 10915.0 10917.0 10917.5 10930.0 10930.5 10931.0 10932.0 10933.0 10938.5 10960.0 10963.5 10966.5 10980.0 10985.0 10989.0 11005.0 11012.5 11013.5 11014.0 11014.5 11021.5 11022.0 11023.0 11023.5 11024.0 11024.5 11025.0 11026.0 11026.5 11027.5 11028.0 11029.0 11039.5 11040.0 11049.0 11053.5 11058.0 11062.5 11063.5 11068.5 11069.0 11069.5 11070.0 11074.0 11079.0 11082.0 11083.0 11091.0 11094.0 11094.5 11095.5 11098.0 11099.0 11100.0 11105.0 11105.5 11106.0 11106.5 11132.0 $ REMARKS: 10959.0 10962.0 10965.0 10979.0 10984.0 10987.0 11004.5 11013.0 11012.0 11013.0 11015.5 11022.0 11023.0 11024.0 11025.0 11027.0 11025.5 11026.5 11028.0 11028.5 11029.0 11029.5 11030.0 11030.5 11041.0 11042.0 11050.5 11055.5 11060.0 11063.5 11064.5 11069.0 11069.5 11070.5 11071.0 11076.5 11081.0 11083.5 11084.5 11085.0 11091.0 11095.0 11095.5 11096.0 11099.5 11100.0 11101.0 11104.5 11105.0 11105.5 11106.0 11132.0 11132.0 PASS 3 (NPHI - CNCF). FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH3. OUT /??MATCH6. OUT $ CN WN FN COUN STAT : BP EXPLORATION : 1 - 05/0- 20 : ENDICOTT : NORTH SLOPE .' ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TENS 2435 68 1 LB 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 37 Tape File Start Depth = 11132.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18638 datums Tape Subfile: 4 218 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS GRCH 2435 $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES $ : BP EXPLORATION : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 32 Tape File Start Depth = 11132.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER LIS representation code decoding summary: Rep Code: 68 17085 datums Tape Subfile: 5 54 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10645.0 2435 10645.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11114.0 11121.0 04-FEB-94 FSYS REV. J001 VER. 1.1 1722 04-FEB-94 11108.0 11116.0 10645.0 11113.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507XA 1309XA 2435XA 2318XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 20 FAR COUNT RATE HIGH SCALE (CPS): 820 NEAR COUNT RATE LOW SCALE (CPS): 100 NEAR COUNT RATE HIGH SCALE (CPS): 1100 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNCF 2435 68 1 PU-S 4 3 CNC 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 CCL 2435 68 1 4 8 SPD 2435 68 1 F/MN 4 9 TTEN 2435 68 1 LB 4 10 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 90 640 78 6 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 135 Tape File Start Depth = 11132.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52794 datums Tape Subfile: 6 Minimum record length: Maximum record length: 210 records... 62 bytes 1018 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10644.0 2435 10644.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11106.0 11113.0 04-FEB-94 FSYS REV. J001 VER. 1.1 1843 04-FEB-94 11108.0 11116.0 10645.0 11113.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507XA 1309XA 2435XA 2318XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.O00 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 20 FAR COUNT RATE HIGH SCALE (CPS) : 820 NEAR COUNT RATE LOW SCALE (CPS): 100 NEAR COUNT RATE HIGH SCALE (CPS): 1100 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION : 1 - 05/0 - 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNCF 2435 68 1 PU-S 4 3 CNC 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 CCL 2435 68 1 4 8 SPD 2435 68 1 F/MN 4 9 TTEN 2435 68 1 LB 4 10 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 90 640 78 6 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 134 Tape File Start Depth = 11124.000000 Tape File End Depth = 10356.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 50889 datums Tape Subfile: 7 Minimum record length: Maximum record length: 209 records... 62 bytes 1018 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10574.0 2435 10574.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11106.0 11113.0 04-FEB-94 FSYS REV. J001 VER. 1.1 1914 04-FEB-94 11108.0 11116.0 10645.0 11113.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507XA 1309XA 2435XA 2318XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11260.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 20 FAR COUNT RATE HIGH SCALE (CPS) : 820 NEAR COUNT RATE LOW SCALE (CPS) : 100 NEAR COUNT RATE HIGH SCALE (CPS) : 1100 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION : 1 - 05/0- 20 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNCF 2435 68 1 PU-S 4 3 CNC 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 CCL 2435 68 1 4 8 SPD 2435 68 1 F/MN 4 9 TTEN 2435 68 1 LB 4 10 TEN 2435 68 1 LB 4 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4 90 640 78 6 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 112 Tape File Start Depth = 11124.000000 Tape File End Depth = 10484.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 80966 datums Tape Subfile: 8 Minimum record length: Maximum record length: 187 records... 62 bytes 1018 bytes Tape Subfile 9 is type: LIS 94/ 2/14 01 **** REEL TRAILER **** 94/ 2/15 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 15 FEB 94 10:07a Elapsed execution time = 36.53 seconds. SYSTEM RETURN CODE = 0 ;i:; ;;': T ;i F' E .-:. E ::", 3 ..E R :;; x':-' 'T ;,. ',::, E ,N .&/,t E "OL,'T-NU,~ITi,3!'.~ a =31 ?kE',,/I3"JS TAPE ,,,. · (} ':,') i 1 3 Z 4 'j ;,,, "' 'r T Y P .... 2~ T" q 'r 7: C C. '~ ;: STAT: 1-5/.--2,} %Pi "'4 2, l C £ T T ,, ',~]::;l~ ':_"P ' ~'",! = i.2,~0 ~ 57.0 OF Ri"qF = !.020 ; ,57.0 OF, RMC : 1o590 .~ ''~ ~7. O DF ~,~ AT ~MT = .a5£ ~ 1'90. O~ MATRIX SANF..'STC"NE ) 15 -' ::. P T S C-,< } - L U :'.; l T L25 TYn7 310 CL,: iS 9 1 ! :} i:,! :: C 1) '] - '7 3 i ., ( CST aL ) 3OO00000 "' ' 0 O "' "' 0 ~' OC OOO L) L L 3 L L DLL ,2 L L .3 ~ L D L~ E:L L LDT LDT L3T L D 'T LOT ,L .3 T LDT L-'T LiT L 3T Li)T L3T L 0 T L,,~ LDT L3T L 3 T L 0 T L L 3 T .. ", 'F L 3T ~,i ] T N LiT h ..'} T VSL k' ST · ',! }T 'S T C STC, 5 TC S T C .$ S T C i',': '? ',...q 0 i',.' V .,3 () U :~ ?, C, '3 d M M 00 ? 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