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Home My WebLink About174-064Nolan 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: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' 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: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 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: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' 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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. T41280TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 22, 2025 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-24A PTD 1740640 Dear Mr. Marlowe: On October 10, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-24A located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 1 additional times. There were no oil or gas flow rates observed during the no-flow test. Trading Bay Unit D-24A may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion of the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-24A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.12.24 10:03:20 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,600 Casing Collapse Structural Conductor Surface 1,540psi Intermediate 4,760psi Production 8,160psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 228A McArthur River Hemlock Oil & Middle Kenai G Oil Same 10,170 12,235 9,199 1,785psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 174-064 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20224-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-24A Length Size Proposed Pools: N-80 TVD Burst 11,789 7,020psi MD 6,870psi 3,090psi1,948' 6,583' 2,100'13-3/8" 9-5/8"8,627' 2,100' 8,627' 11,930 - 13,526 13,600' 9,000 - 10,118 10,152'7" Other: Convert to GL Producer 11/5/2025 3-1/2" Baker FB-1 & N/A 11,729 (MD) 8,856 (TVD) & N/A 13,600' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:34 am, Oct 22, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.10.22 03:18:54 - 08'00' Dan Marlowe (1267) 325-657 A.Dewhurst 23OCT25 DSR-10/30/25 10-404 MGR31OCT25 * Additional no-flow test required if fill clean out operations are performed. 48 hour notice for AOGCC to witness. JLC 10/31/2025 11/03/25 Convert to Production Well: Dolly Varden D-24A Well Name:D-24A API Number:50-733-20224-01-00 Current Status:Shut in Injector Leg:NE Corner (A-1) Regulatory Contact:Juanita Lovett Permit to Drill Number:174-064 First Call Engineer:Casey Morse (603) 205-3780 (c) Second Call Engineer:Eric Dickerman (907) 564-4061 (o) Maximum Expected BHP: 2,710 psi @ 9,250 TVD Max from offset D-20 shut-in Max. Potential Surface Pressure:1,785 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-24A was initially completed in 1974 as a Hemlock Oil Pool injector. Perfs were added in the Middle Kenai G Oil Pool in 1986 and the well became a commingled Hemlock and Middle Kenai G injector. The well was shut-in in 2015 for a suspected tubing x IA leak. The goal of this project is to convert the well to gas lift production. Hilcorp requests a variance to 20 AAC 25.265(c)(1) and the letter agreement from April 11, 2011, regarding placement of the surface safety valve on wells in McArthur River Field for a 30-day flow test to evaluate productivity of this well.Hilcorp plans to route production from the D-24A through approximately 10 ft of temporary piping to pass through the safety valve and flow line of an adjacent shut-in well during the 30-day trial period. After completion of a 30-day flow test, the well will either be shut in or a dedicated surface safety valve will be installed on the wing valve of the D-24A wellhead per the April 11, 2011 letter agreement. Pertinent wellbore information: - Inclination: o Max inclination of 50 degrees at 3,000 MD with ~45 degree angle from >2,000 through PBTD - Pertinent History o Oct-2025 No flow test: Hilcorp performed a witnessed no flow test on 10/1/2025 that met the AOGCC criteria for passing. o Sep-2025 Slickline: RIH w/ 2.5 DD bailer, tag @ 12,081. Return with 3 cups scale in bailer. Make 2 additional bailer runs with scale in bailer each time. Final depth 12,100. Pressure test: pressure up IA with gas lift to 1200 psi. Tubing at 0 psi. Monitor pressures for 6 hours and maintained stable at 1200 / 0. Unable to see any obvious TxIA communication. o Sep-2015 IA pressure increased during injection. Well was shut in and notification made to AOGCC of potential TxIA communication. o Aug-2012 Most recent passing MIT-IA Convert to Production Well: Dolly Varden D-24A Eline Procedure 1. RU and PT lubricator to 250psi low / 2500psi high 2. Run GPT survey to determine bottomhole pressure 3. Punch hole in tubing to enable gas lift operations at ±9,000 based on GPT survey results. 4. RD eline and turn well over to production Contingent Wireline Procedure 1. RU and PT lubricator to 250psi low / 2500psi high 2. Bail fill as necessary 3. Re-perf the Middle Kenai G Oil Pool from ±11,920 12,225 MD (±8,980 - 9,180 TVD) per Engineers perf table 4. RDMO eline If Contingent Wireline Procedures above are executed, an updated no flow test will be performed within 14 days of returning the well to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic If Contingent Wireline Procedures above are executed, an updated no flow test will be performed within 14 days of returning the well to production. _____________________________________________________________________________________ Updated By: JLL 08/19/25 SCHEMATIC McArthur River Field Well: D-24A Last Completed: 03/24/1986 PTD: 174-064 PBTD =13,540 TD =13,600 RKB: = 38.92 7 G Zone 4 5 9-5/8 1-3 Tag Fill 12,100 9/25/25 13-3/8 Hemlock Zone X CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8 61 J-55 Butt 12.515 Surf 2,100 KOP 9-5/8 47 N-80 Butt 8.681 Surf 4,742 9-5/8 47 P-110 Butt 8.681 4,742 7,600 9-5/8 47 N-80 Butt 8.681 7,600 8,627 7 29 N-80 Butt 6.184 Surf 8,433 7 29 N-80 X-Line 6.184 8,433 13,600 TUBING DETAIL 3-1/2 9.2 N-80 Hydril 501 IPC 2.992 Surf 11,789 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 38.92 Hanger - CIW DCB-FBB 1 11,712 8,844 2.94 Baker G-22 Locator Assembly 2 11,729 8,856 4.00 Baker FB-1 Permanent Packer 3 11,729 8,856 4.00 10 Seal Bore Assembly & Bell Guide 4 11,759 8,877 2.75 X Nipple 5 11,789 8,899 3.00 ½ cut Mule Shoe Notes 9/25/25 2.5 bailer down to 12,100 8/28/15 2.5 GR tagged up at 12,235 8/22/07 2.5 GR tagged up at 13,427 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)SPF Date Status G-2 11,930' 11,960' 9,000' 9,021' 4 G-3 12,030' 12,060' 9,071' 9,092' 4 G-4 12,080' 12,140' 9,107' 9,149' 4 G-4 12,120' 12,220' 9,135' 9,205' 4 HB-Stray 12,600' 12,610' 9,469' 9,476' HB-1 12,685' 12,705' 9,529' 9,543' HB-2 12,753' 12,864' 9,577' 9,654' HB-3 12,905' 12,965' 9,683' 9,725' HB-4 13,033' 13,216' 9,773' 9,900' HB-5 13,259' 13,451' 9,930' 10,065' HB-6 13,466' 13,526' 10,076' 10,118' _____________________________________________________________________________________ Updated By: CDM 09/30/25 PROPOSED SCHEMATIC McArthur River Field Well: D-24A Last Completed: 03/24/1986 PTD: 174-064 PBTD =13,540 TD =13,600 RKB: = 38.92 7 G Zone 5 6 9-5/8 2-4 13-3/8 Hemlock Zone 1 X CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8 61 J-55 Butt 12.515 Surf 2,100 KOP 9-5/8 47 N-80 Butt 8.681 Surf 4,742 9-5/8 47 P-110 Butt 8.681 4,742 7,600 9-5/8 47 N-80 Butt 8.681 7,600 8,627 7 29 N-80 Butt 6.184 Surf 8,433 7 29 N-80 X-Line 6.184 8,433 13,600 TUBING DETAIL 3-1/2 9.2 N-80 Hydril 501 IPC 2.992 Surf 11,789 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 38.92 Hanger - CIW DCB-FBB 1 ±9,000 ±6,945 Tubing Punch 2 11,712 8,844 2.94 Baker G-22 Locator Assembly 3 11,729 8,856 4.00 Baker FB-1 Permanent Packer 4 11,729 8,856 4.00 10 Seal Bore Assembly & Bell Guide 5 11,759 8,877 2.75 X Nipple 6 11,789 8,899 3.00 ½ cut Mule Shoe Notes 8/28/15 2.5 GR tagged up at 12,235 8/22/07 2.5 GR tagged up at 13,427 5/86 Tag Fill @ 13,256 WLM PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)SPF Date Status G-2 11,930' 11,960' 9,000' 9,021' 4 G-3 12,030' 12,060' 9,071' 9,092' 4 G-4 12,080' 12,140' 9,107' 9,149' 4 G-4 12,120' 12,220' 9,135' 9,205' 4 HB-Stray 12,600' 12,610' 9,469' 9,476' HB-1 12,685' 12,705' 9,529' 9,543' HB-2 12,753' 12,864' 9,577' 9,654' HB-3 12,905' 12,965' 9,683' 9,725' HB-4 13,033' 13,216' 9,773' 9,900' HB-5 13,259' 13,451' 9,930' 10,065' HB-6 13,466' 13,526' 10,076' 10,118' 2025-1001_No-Flow_TBU_D-24_gc Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/01/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector TBU D-24A Hilcorp Alaska LLC PTD 1740640 10/01/2025: I arrived on the Dolly Varden Platform and met with Jon Loomis (Hilcorp) to witness the No-Flow Test on this well. The set-up of gauges, valves and the flowmeter were acceptable. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 08:00 0 / 0 / 200 / 10 Shut in to build pressure 08:15 0 / 0 / 200 / 10 08:30 .01 /.01 / 200 / 10 08:45 .01 /.01 / 200 / 10 09:00 .01 / .01 / 200 / 10 0 0 Open; immediately bled to 0 psi 09:00 0 / 0 / 200 / 10 Shut in to build pressure 09:15 0 / 0 / 200 / 10 09:30 .02 / 0/ 200 / 10 09:45 .02 / .02 / 200 / 10 10:00 .02 / .02 / 200 / 10 0 0 Open; immediately bled to 0 psi 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr The no-flow test ended after two hours of monitoring due to no significant buildup of pressure during the monitoring periods. I believe this well cannot flow to surface unassisted and meets the requirements to be flowed without the need for a subsurface safety valve. The well is currently shut in and unhooked from the flowlines. Attachments: none       • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Tuesday,August 16, 2016 8:56 AM To: 'Juanita Lovett' Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#315-633 PTD: 174-064 Well: Trading Bay Unit D-24A Juanita, The AOGCC will withdraw the sundry 315-633 as per your request below. Regards, :;. �„x..w,a:.,. .-- -• �.,, _, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell CAM” JAN 4 KIT 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett[mailto jlovett@hilcorp.com] Sent: Monday, August 15, 2016 12:55 PM To: Schwartz, Guy L(DOA) Cc: Dan Marlowe Subject: Withdraw Sundry # 315-633 PTD: 174-064 Well:Trading Bay Unit D-24A Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to install patch. Thank you Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: Ilovett@ hilcorp.com 1 RBDMS AUG 2 5 2016 ' tiOF TfJ� • • �w\��,„j�,s� THE STATE Alaska Oil and Gas ti�.;s��, „ALASKA Conservation Commission ;' __ ` t itt _,_ 333 West Seventh Avenue QTR. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS�� Fax: 907.276.7542 coot) � � (t� www.aogcc.alaska.gov 5. Dan Marlowe — D 69.- Operations Engineer I I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-24A Sundry Number: 315-633 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7)444,-;V-z . Cathy P. oerster Chair DATED this /3 day of October, 2015 Encl. �0 1"3 0 0 RECEIVED STATE OF ALASKA OCT ® 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION !d 1011s APPLICATION FOR SUNDRY APPROVALS AOG CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate ❑ Other Stimulate El Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well 0 , Re-enter Susp Well ❑ Other. Install Patch 0e 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 174-064 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 , 6.API Number. Anchorage,AK 99503 50-733-20224-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes CI No 0 / Trading Bay Unit D-24A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 , McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools , 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): .13,600 10,150 13,148 9,857 N/A 13,148 Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,000' 13-3/8" 2,000' 1,903' 3,090 psi 1,540 psi Intermediate 8,627' 9-5/8" 8,627' 6,583' 6,870 psi 4,760 psi Production 13,600' 7" 13,600' 10,152' 7,020 psi 8,160 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,930-13,526 ' 9,000-10,118 3-1/2" 9.2#/N-80 11,789 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker FB-1 Perm Pkr&N/A ' 11,729'(MD)8,856'(ND) &N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/21/2015 OIL ❑ WINJ 0 ' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe©hilcorp.com Printed Name Dan Marlowe Title Operations Engineer a.,-/...7 1'1'1�v` Signature 4' 7 Phone (907)283-1329 Date 10/7/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 — G233 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: DMS t 15llt Spacing Exception Required? Yes ❑ No Subsequent Form Required: / ( RB APPROVED BY Approved by: 72926444_ 2/Z7 COMMISSIONER THE COMMISSION Dater— /3 -/S Submit Form and Form 10-403 Revised /2015 , 0DfrD 41Gpii oA Lid for 12 months from the date of approval. Attachments in Duplicate • • 14Well Work Prognosis Well: D-24A Hileorp Alaska,►Lc Date: 10/07/15 Well Name: Trading Bay Unit D-24A API Number: 50-733-20224-01 Current Status: Injection Well Leg: NE Corner(A-1) Estimated Start Date: 10/21/15 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 174-064 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Ted Kramer Office:907-777-8420 Cell: 985-867-0665 Current Bottom Hole Pressure: -4,273 psi @ 9,959' TVD 0.43 psi/ft Top of Hemlock Bench 2 Maximum Expected BHP: -4,273 psi @ 9,959'TVD 0.43 psi/ft Top of Hemlock Bench 2 Max.Allowable Surface Pressure: -3,300 psi water flood pressure Brief Well Summary The D-24A was initially completed in 1974. Currently the well has Tubing by IA communication.This procedure will pinpoint the leak and install a patch. / Procedure: 1. MIRU Slick-line, PT lubricator to 3,300 psi Hi 250 Low. 2. RIH with slick-line and install tubing patch-depth TBD. 3. Pressure Test IA to 2500 psi 4. RD slick-line Attachments: .. 1,,itA �-�.- 4 t T ifs U 1. Current Well Schematic 2. Proposed Well Schematic , ll • 40 McArthur River Field Well: D-24A SCHEMATIC Last Completed: 03/24/1986 Hilcorp Alaska,LLC PTD: 174-064 RKB:=3892' CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 J-55 Butt 12.515" Surf 2,100' KOP 9-5/8" 47 N-80 Butt 8.681" Surf 4,742' 9-5/8" 47 P-110 Butt 8.681" 4,742' 7,600' 9-5/8" 47 N-80 Butt 8.681" 7,600' 8,627' 7" 29 N-80 Butt 6.184" Surf 8,433' 13 3/8 7" 29 N-80 X-Line 6.184" 8,433' 13,600' Al A TUBING DETAIL 3-1/2" 9.2 N-80 Hydril 2.992" Surf 11,789' 501 IPC JEWELRY DETAIL Depth Depth No (MD) (TVD) ID Item 1 38.92' Hanger-CIW DCB-FBB 2 11,712' 8,844' 2.94 Baker G-22 Locator Assembly 3 11,729' 8,856' 4.00 Baker FB-1 Permanent Packer 4 11,729 8,856' 4.00 10'Seal Bore Assembly&Bell Guide 5 11,759' 8,877' 2.75 X Nipple 6 11,789' 8,899' 3.00 'A cut Mule Shoe PERFORATION DETAIL 9-5/8' 4 6 Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) SPF Date Status G-2 11,930' 11,960' 9,000' 9,021' 4 G-3 12,030' 12,060' 9,071' 9,092' 4 iiir . 111 yet`M1.t ) G-4 12,080' 12,140' 9,107' 9,149' 4 G-4 12,120' 12,220' 9,135' 9,205' 4 HB-Stray 12,600' 12,610' 9,469' 9,476' x HB-1 12,685' 12,705' 9,529' 9,543' HB-2 12,753' 12,864' 9,577' 9,654' HB-3 12,905' 12,965' 9,683' 9,725' HB-4 13,033' 13,216' 9,773' 9,900' HB-5 13,259' 13,451' 9,930' 10,065' HB-6 13,466' 13,526' 10,076' 10,118' Notes 8/28/15 2.5"GR tagged up at 12,235' ' Tag Fill @ 13,526' 8/22/07 2.5"GR tagged up at 13,427' 7, WLM5-86 5/86 Tag Fill @ 13,256'WLM •r, PBTD=13,540' TD=13,600' Updated By:11.1 09/21/15 McArthur River Field I ' Well: D-24A 4 PROPOSED Last Completed: 03/24/1986 0, �.�, �, PTD: 174-064 ,,,,q RKB:=38.92' CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 J-55 Butt 12.515" Surf 2,100' KOP 9-5/8" 47 N-80 Butt 8.681" Surf 4,742' 9-5/8" 47 P-110 Butt 8.681" 4,742' 7,600' 9-5/8" 47 N-80 Butt 8.681" 7,600' 8,627' 7" 29 N-80 Butt 6.184" Surf 8,433' 133/8" 7" 29 N-80 X-Line 6.184" 8,433' 13,600' 4 A TUBING DETAIL 3-1/2" 9.2 N-80 Hydril 2.992" Surf 11,789' 501 IPC JEWELRY DETAIL Depth Depth No (MD) (TVD) ID Item 1 38.92' Hanger-CIW DCB-FBB 2 11,712' 8,844' 2.94 Baker G-22 Locator Assembly 3 11,729' 8,856' 4.00 Baker FB-1 Permanent Packer 4 11,729 8,856' 4.00 10'Seal Bore Assembly&Bell Guide 5 11,759' 8,877' 2.75 X Nipple 6 11,789' 8,899' 3.00 'A cut Mule Shoe Z PERFORATION DETAIL 9-5/8 4 6 Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) SPF Date Status G-2 11,930' 11,960' 9,000' 9,021' 4 G-3 12,030' 12,060' 9,071' 9,092' 4 ..., -1 G-4 12,080' 12,140' 9,107' 9,149' 4 y G-4 12,120' 12,220' 9,135' 9,205' 4 HB-Stray 12,600' 12,610' 9,469' 9,476' x z-'' HB-1 12,685' 12,705' 9,529' 9,543' HB-2 12,753' 12,864' 9,577' 9,654' HB-3 12,905' 12,965' 9,683' 9,725' HB-4 13,033' 13,216' 9,773' 9,900' HB-5 13,259' 13,451' 9,930' 10,065' HB-6 13,466' 13,526' 10,076' 10,118' Notes 8/28/15 2.5"GR tagged up at 12,235' Tag Fill @13,526' 8/22/07 2.5"GR tagged up at 13,427' 2 �MMS86 5/86 Tag Fill @ 13,256'WLM 4 6 PBTD=13,540' TD=13,600' Updated By:JLL 10/07/15 • S Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, September 21, 2015 10:49 AM To: 'Larry Greenstein'; Regg,James B (DOA) Cc: John Lee; Stan Golis; Dan Marlowe Subject: RE: D-24A PTD# 1740640 pressure anomaly Larry, Testing and diagnostics plus up to 14 days injection monitoring is approved. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue auk• `; Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.ciov. From: Larry Greenstein [mailto:Igreenstein@ hilcorp.com] Sent: Monday, September 21, 2015 10:25 AM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: John Lee; Stan Golis; Dan Marlowe Subject: D-24A PTD# 1740640 pressure anomaly Good morning, Chris and Jim This is to notify you that we have a potential tbg x IA communication issue with the Dolly Varden D-24A well. The IA pressured up and the well was shut-in Saturday morning and we are requesting some diagnostic time and pressure testing to confirm or disprove the communication. If mechanical integrity is confirmed, AOGCC notification will be provided for a witnessed MIT after bringing the well back on to stable injection. Attached is a schematic and a 90 day TIO plot for the well. Per the plot,there wasn't any indication of a loss of integrity prior to the increase in IA pressure this weekend. Larry 1 S • C.> 0 0 0 CD tr, 0 CD .—, .--A in CD .... _____.....4 1 1 in •-.4 '1%.• 1relif i 0 irs4 -...... 01 0 on, •••I J P... CI 0 1 ______.................. ........ a a U .-i .6., us co Iff 0 C: 0 CO IA 1..4 * '.."...""............1 .4( 0 411•••••••"/ CO Ci = tr M CT c = I- I Lel *I 0 A....' CD ........ • I I _ . I 1 A 1 ca ' CV k0 0 0 0 0 0 0 0 0 CZ> 0 111 CD Lf1 C=. in C., C•1 irsi v-41 •—i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggI ID�7Ii2 � DATE: Friday, September 28, 2012 P.I. Supervisor � SUBJECT: Mechanical Integrity Tests HILCORP ALASKA, LLC D -24A FROM: Jeff Jones TRADING BAY UNIT D -24A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 11g, NON -CONFIDENTIAL Comm Well Name TRADING BAY UNIT D -24A API Well Number 50-733-20224-01-00 Inspector Name: Jeff Jones Permit Number: 174-064-0 Inspection Date: 8/31/2012 Insp Num: mitJJ120927203600 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wel �T e In TVD IA 250 2400 2370 2370 p - - 19 D -24A W 8855 _i— 190 - 190 190 190 PTD . l�aobao ---Type Test SP 2213 Test psi OA Interval P/F Tubing' - 33oo 3300 YRTST P � 3250 3300 i Notes: 1 well room inspected; no exceptions noted. Friday, September 28, 2012 Page I of 1 • • SEAN PARNE ] , GOVERNOR a1 �7 yy �yy 1LL.1p1�. 7 �J115k ( �i ay +llue d�Sb�111y lllrA3 333 W. 7th AVENUE, SUITE 100 EDRIB EIRT LEION \ O :5=501101 V ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Keith Elliott Asset Team Leader Hilcorp Alaska, LLC I I / — 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock 86 Middle Kenai G Oil Pool, D -24A Sundry Number: 312 -112 Dear Mr. Elliott: - SLANNED APR 2 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 -; /, : 7 Cathy V. Foerster Chair DATED this day of March, 2012. Encl. • p7 3 X29Sl i STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ cr 1FL, , Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ A ,,, et Stimulate 5 - Alter Casing ❑ Other. Circulate Bottoms Up 0 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 174 -064 ' 3. Address: Stratigraphic ❑ Service 5 . 6. API Number. 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 50-733-224-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: a f, property line where ownership or landownership changes: a r Spacing Exception Required? Yes ❑ No IN D -24A • MA/ ,r •> 9. Property Designation (Lease Number): 10. Field / Pool(s): _ '" f. tit) ADL0018729 - McArthur River Field/ Hemlock Oil and Middle Kenai G Oil pffo / 3 ic, t'0/PS 8 11. PRESENT WELL CONDITION SUMMARY 43 n.,,�, k ")lSRegtT Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): (measured): 13,600 . 10,150 - 13,148 9,857' N/A 13,148' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,000' 13 -3/8" 2,000' 1,903' Intermediate 8,627' 9 -5/8" 8,627' 6,583' 6,870psi 4,760psi Production 13,600' 7" 13,600' 10,152' 7,020psi 8,160psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment #1 See Attachment #1 3 -1/2" 9.21b/ N -80 11,789' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FB -1 Perm. Packer and N/A 11,759(MD); 8,875(TVD) and N/A 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 5 Exploratory ❑ Development ❑ Service E 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/1/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ 5 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Dunn Phone 777 -8382 Printed Name Keith Elliott Title Asset Team Leader c Signature "......4__.......4 kt( ----.13hone 777 -8355 Date 3/23/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 L-117_ Plug Integrity ❑ BOP Test gi Mechanical Integrity Test ❑ Location Clearance ❑ lc �, Other: '-3 0 ,,, , 5 c . ie , s i- Subsequent Form Required: l 0 - qLSL( APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 .� -/ �D S APR �f R G , �/ i ''" 0 1 0 -4 03 Toed LO�� / t � L ' N L /r��Submit in Duplicate ✓� • • ATTACHMENT #1 • WELL D-24A PERFORATIONS BENCH MD 11/D G-2 • 11,930' - 11,960' 8,987' - 9,008' G-3 12,030' - 12,060' 9,056' - 9,077' G-4 12,080' - 12,220' 9,091' - 9,187' B-Stray 12,600' - 12,610' 9,452' - 9,459' B-1 12,685' - 12,705' 9,511' - 9,525' B-2 12,753' - 12,864' 9,558' - 9,636' B-3 12,905' - 12,965' 9,664' - 9,706' 3 /if d(46 13,033' - 13,216' 9,754' - 9,881' , B-5 13,259' - 13,451' 9,912' - 10,048' B-6 13,466' - 13,526' 10,058' - 10,100' RECEM A 0 2, S AlLsote. • • D -24A CTCO Procedure McArthur River Field Hikorp Alaska, LLC March 15, 2012 WELL: D -24A JOB SEQUENCE: No. 1 of 7 (First job in Leg A -1) OBJECTIVE: Clean out fill over lower Hemlock perforations. Clean the perfs of Iron sulfide scale with 10% HCI acid. Restore injection rate to full capacity. BACKGROUND: D -24RD is an active injector, currently injecting about 1000 bwipd while supporting updip producers from the eastern flank, north of the Dolly fault. The well took as much as 10,000 bwipd early in life. Recent SL diagnostics ' indicate fill covering most of HB -4 perfs. The casing will be cleaned out as deep as possible with coiled tubing. CURRENT STATUS: Current BHP: 4273 psi @ 9559' TVD — based on a 68 day shut -in survey on 5/7/00 Max Downhole Pressure: 4273 psi @ 9559' TVD (No new perfs being added) MASP: 115 psi (based on a pressure gradient of .435/ft back to surface) Leg: A -1 (NE Corner, Inner rig) RKB to MSL: 106.2' BHT: 185 °F Max Deviation / Max Dogleg: 50.17° at 3000' MD / 4.86 °/100 ft. at 775' Maximum TD with coil: 13,540' Recent intervention: FiII was tagged at 13148' on 2/28/12. Sample was taken with 2" bailer, sample noted to be scale and formation fill (sandstone). The analysis shows the sample to be 60% FeS, with some organics. Acid would be expected to dissolve and /or loosen the fill. It appears that approximately 70' of HB -4 perfs are covered with fill, all 192' of HB -5 perfs are covered, and all 60' of HB -6 perfs are covered with fill. The tubing pressure was noted to be 0 psi pressure when the well was shut -in for slickline work. HIGH LEVEL PROCEDURE SUMMARY: 1. If this is the first CT operation on the platform, notify AOGCC at least 48 hours in advance of well operations to witness test of BOPE and to inspect equipment. 2. MIRU Coiled Tubing Unit. Spot tanks, fill with 8.4ppg Filtered Inlet Water (FIW). Pumping from tanks and back to tanks is the secondary option. The preferred approach is to take FIW from a waterflood charge pump and take returns back through Separator 5, and on to the Trading Bay Facility. 3. Install BOPE on top of tree. Test BOPs to 250 psi (low) and 3500 psi (high) per standard procedure. Record pressures. Notify AOGCC (if not present) of successful test. 4. RIH with 1 -3/4" coiled tubing and down jet nozzle and tag fill. With sweeps, N2, and /or foam as necessary to clean hole, wash and jet down to PBTD at +/- 13400' (or as deep as +/- 13500' if CT will allow). Reverse circulate as necessary to clean all fill from wellbore. Take returns to Separator 5. 5. Note: If a hard cap is found on top of fill, and jetting is unsuccessful, try pumping a small volume of acid to loosen the material. The other option is to POOH and PU a bit and motor to drill the hard cap. If considerable scale is observed, place acid behind the perfs via the bullhead method to dissolve calcium carbonate and /or iron sulfide scale. 6. Once several bottoms up have been pumped, take returns to open top tank to inspect returns for solids. If none, POOH. 7. RD CTU. D -24RD CTCO Procedure Page 1 of 9 M.Dunn 03.16.2012 • • D -24A CTCO Procedure McArthur River Field Hi core Alaska, LLC March 15, 2012 Attachment A — Welibore Schematic TOU Uell D -24A Norkover Completed Harek 24, 1986 • 9 5/8 ", 471, 11004 P'110 Butt. 3 1/2 ", 9.26, N -80, ICC tbt. w /501 cple. 1 ", 290, N -80 Butt. Tle beck 12/21/76 � I 8433' 7 ", 290, 11 -80 Duct a Locator 11,712', 2.94" 1D. Baker "TB -1" perm pkr 11,729'. 10' seal bore extencion - J 4 Dell {side • • C -Zone Pacts X- nipples 11,759', 2.75" ID 4 t1?. 90• Phasing 11,789' - 1/2 cat mele shoe • • 6 -2 11,930' - 11,960' 6 -3 li,o30' 12,060' 1W*1.ek Pert* C -4 12,120' - 12,220' &-4 I2. 0tQ' -.ft,40' 8 -1 12,683' - 12,705' \s_ Snr'y lu,00'. 00 B -2 12,733' - 12,064' 6 12,905' -- 12,965' 8-4 13,033' - 13,216' 6-3 13,259' - 13,451' B - 13,446' - 13,526' PBTO 13,540' 'rx"•• Tag Fill @ 13,526' IILM 5 -86 ~ T.D. NEC 9 -87 13,600' REC % AttrAt. moon 3:49/f • D -24RD CTCO Procedure Page 6 of 9 M.Dunn 03.16.2012 , • • Dolly Varden Well Head Rig Up Maw BAKER Ve 00111111114.4, a 5r . i tji-- --I96" Gooseneck f r ip 1 i i I 1. hill. ,9ii1i .r �` f S &S 800E Injector Head ....... f 1 . ,4 • . I r Hydraulic Stripper 4 1/6" 10K 11111 4 4 , Crossover 41/16" 10K x 5 1/16" 10K .. 41/16" 10K Lubricator 1• ∎(j 4 1/16" 15K Comb] BOPs f Blind/Shear Ram Is 1'1 Pipe /Slip Ram V. 4,,, ::,, , , j f +41/16" 10K Flow Cross ,. -1 f 41/16" 10K Safeties - : Blind/Shear Ram • • (- 7:7 L, _ - F SEAN PARNELL, GOVERNOR i I- AZ ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Elliott Asset Team Leader ci&ti- Hilcorp Alaska, LLC T'' 3 800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock 86 Middle Kenai G Oil Pool, TBU D -24A Sundry Number: 312 -095 Dear Mr. Elliott: 5La° NE OMAR -1. 5 LUIZ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ag, / ?.6,zil l e_L___ Cathy /. Foerster Chair a/L DATED this day of March, 2012. Encl. , 079 /3 //Z • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . ,p APPLICATION FOR SUNDRY APPROVA S 20 AAC 25.280 4laalt Q! 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 6ioRt*eeElmlYieR Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing I Ancn Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Circulate B off " V a 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. uJ / Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 174 -064 . 3. Address: Stratigraphic ❑ Service 0 6. API Number. 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 50 -733- 20224 -01 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: T 6L( . Spacing Exception Required? Yes ❑ No 0 D -24A f � 31 tZ ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018729 - McArthur River Field/ Hemlock Oil and Middle Kenai G Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,600 • 10,150 , 13,148 9,857' N/A 13,148' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,000' 13 -3/8" 2,000' 1,903' Intermediate 8,627' 9 -5/8" 8,627' 6,583' 6,870psi 4,760psi Production 13,600' 7" 13,600' 10,152' 7,020psi 8,160psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment #1 See Attachment #1 3 -1/2" 9.21b/ N -80 11,789' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FB -1 Perm. Packer and N/A 11,759(MD); 8,875(TVD) and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development ❑ Service El . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/18/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ El . GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Elliott Printed Name Keith Elliott Title Asset Team Leader Signature C --- ' , .�..," Phan& 777 -8355 Date 3/7/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Z Plug Integrity ❑ BOP Test i gs Mechanical Integrity Test ❑ Location Clearance ❑ Other: r4 3 6o 0 es ` 13c Subsequent Form Required: 10 — 4( 0 , , . APPROVED BY Approved by: A ,�7 �� j OM MISSIONER THE COMMISSION Date: -` 3 Form 10 -403 R vised 1010 (/ / / OR1G INTbJDMS MAR 1 i sum, in D plicate � RA Iv • • ATTACHMENT #1 WELL D -24A PERFORATIONS BENCH MD TVD G -2 • 11,930' - 11,960' 8,987' - 9,008' G -3 12,030' - 12,060' 9,056' - 9,077' G-4 12,080' - 12,220' 9,091' - 9,187' (B-Stray 12,600' - 12,610' 9,452' - 9,459' B -1 12,685' - 12,705' 9,511' - 9,525' ■ B -2 12,753' - 12,864' 9,558' - 9,636' B -3 12,905' - 12,965' 9,664' - 9,706' B-4 13,033' - 13,216' 9,754' - 9,881' B -5 13,259' - 13,451' 9,912' - 10,048' B -6 13,466' - 13,526' 10,058' - 10,100' CE V 1" A AP2 0 - 1r3r AL 4 nip 17,1'7 Cr,7. • • McArthur River Field March 1, 2012 Hilcorp Alaska, LLC OBJECTIVE: D -24A is an active injector, currently injecting about 1,000 bwipd while supporting producers from the eastern flank, ✓ north of the Dolly fault. The well took as much as 10,000 bwipd early in life. Recent SL diagnostics indicate fill covering most of HB -4 perfs. The casing will be cleaned out to PBTD with coiled tubing. Current BHP: 4,273 psi @ 9,559' TVD — based on a 68 day shut -in survey on 5/7/00 Max Downhole Pressure: 4,273 psi @ 9,559' TVD (No new perfs being added) MASP: 115 psi (based on a pressure gradient of .435/ft back to surface) Recent intervention: Fill was tagged at 13,148'. Sample taken with 2" bailer. Half a bailer recovered, sample noted to be scale and rock. It appears that approximately 70' of HB -4 perfs are covered with fill, all of HB -5 perfs are covered, and all of HB -6 perfs are covered with fill. The tubing pressure was noted to be 0 psi pressure. PROCEDURE SUMMARY: 1. If this is the first CT operation on the platform, notify AOGCC at least 48 hours in advance of well operations to witness test of BOPE and to inspect equipment. 2. MIRU Coiled Tubing Unit. Spot tanks, fill with 8.5 ppg Filtered Inlet Water (FIW). ✓ 3. Install BOPE on top of tree. Test BOPs to 250psi low/ 3,000psi high per standard procedure. Record pressures. Notifiy AOGCC (if not present) of successful test. 4. RIH with 1 -3/4" coiled tubing and down jet nozzle and tag fill. With sweeps, N2, and /or foam as necessary to clean hole, wash and jet down to PBTD at 13,540'. CBU into Separator 5. ✓ 5. Once several bottoms up have been pumped, take returns to open top tank to inspect returns for solids. If none, POOH. 6. RD CTU. D -24A REVISED BY: MD 3 -7 -2012 4 • • . TIM Well 0-Z4A Horkovar Completed Uarck 24, 1986 • • ♦ 13 -3/8" Surface Casing 9 5 /8 ", 471, 8D0} . • Pilo Hutt. • s _ 3 1/2 ", 9.29, N -80, Irc tbs. w /501 cple. 7 ", 290, V -80 Butt. Tie back 12/21/76 8413' _ 0627' 296, U - 80 Butt ..�� Locator 11,112', 2.94" ID. x Baker "7'11-1" perm pkr 11,729'. 10' seal bore extension Dell guide - • 0 -Zone Perf.s X- nipple 11,759', 2.75" ID 4 SP?, 90° Phasing 11,789' - 1/2 cut mule shoe • (7-2 11,930' - 11,960' 0-3 12,030' - 12.060' Hemlock Paris 0 -4 12,120' - 12,220' • 6-1 12,685' - 12,705' 57 iiLW D B-2 12,753' - 12,364' 8 -3 12,905' - 12,965' 2/28/12: 2.37" OR - ` 11-4 13.033' - 13,216' tagged up at 8 -5 13,259' - 13,451 13,148' TOF. 8-6 13,466' - 13,526' • POW 1,3,540' 'r sr , ( T.O. i1EC 9.87 ✓" 13,600' • R'FC /h 3l / • , . .. 0 Dolly Varden Well Head Rig Up Milli BAKER Q �� ,, HUGHES Qy ,./ �/�I 96" Gooseneck 0y , .iii. Milli. i i I ■ i• ■ ZI • S &S 800L Injector Head z r Hydraulic Stripper 4 1/6" 10K lig • 4 Crossover4 1/16" 10K x 5 1/16" 10K 4 1/16" 10K Lubricator d Om ..' 4 1/16" 15K Combi BOPs 4 Blind /Shear Ram (k .I) Pipe /Slip Ram T ",i 4i j�> I� > >I . 14 1/16" 10K Flow Cross Il_ 4 1/16" 10K Safeties Blind /Shear Ram 1 MEMORANDUM • To: Jim Regg ~ ~ ~ ~ ~ I ~ ~ ~~~ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 23, 2008 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-24A TRADING BAY UNIT D-24A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `j ~~'~- Comm Well Name: TRADING BAY UNIT D-24A Insp Num: mitLG080913062403 Rel Insp Num: API Well Number: 50-733-20224-01-00 Permit Number: 174-064-0 J Inspector Name: Lou Grimaldi Inspection Date: 9/10/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-24A (Type Inj. ~ W TVD ~ 8855 IA 110 2330 2310 2310 ~ ~ P.T 1740640 jTypeTest i SPT Test psi 2330 ~I OA 190 200 200 200 ~ Interval 4YRTST prn, P ~ Tubing ~ 2850 2850 ~ 2800 i 2825 NOteS• Good test. Observed pretest conditions for 15 minutes "OK". Well pressured up with water flood, checked before hand for fluid to surface in IA. Tuesday, September 23, 2008 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (7 9/ P.I. Supervisor ~~q t I~Ò+ DATE: Monday, September 13,2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA D-24A TRADING BAY UNIT D-24A FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 3§'?- Comm NON-CONFIDENTIAL Well Name: TRADING BAY UNIT D-24A API Well Number: 50-733-20224-01-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40908163536 Permit Number: 174-064-0 Inspection Date: 9/3/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well D-24A Type Inj. s TVD 8832 IA 350 2260 2240 2240 P.T. 1740640 TypeTest SPT Test psi 2208 OA 240 280 280 280 Interval 4YRTST P/F p Tubing 2850 2850 2850 2850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Monday, September 13,2004 Page 1 of 1 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOr-.AL G. Russell Schmidt Drilling Manager Thursday, March 21, 1996 Ms. Joan Miller AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Ms. Miller: DOLLY VARDEN PLATFORM D-24A APl NUMBER 50-733-20225-01 On June 4, 1995 the following intervals were perforated in Well D-24A. BENCH TOP (MD) BOTTOM (MD) FEET G-2 11930 11945 15 G-3 12035 12050 15 G-4 080 140 60 G-4 155 165 10 Heml. Stray 600 12610 10 Total 110 GRS/leg G. Russell Schmidt Drilling Manager *-" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 106' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: "~r~ ~ P.O. Box 196247 Anchorage, AK 99519 Service: ~ Trading Bay Unit 4. Location of well at surface 8. Well number 470' FNL, 480' FWL, Sec. 9, T7N, R9W, SM D-24A At top of productive interval 9. Permit number/approval number 441' FNL, 517' FEL, Sec. 8, T7N, R9W, SM 74-64/94-119 At effective depth0 II INAL 10. APl number 50- 733-20224-01 At total depth 11. Field/Pool 396' FNL, 603' FEL, Sec. 8, T7N, R9W, SM McArthur Field Hem/Mid Kenai "G" 12. Present well condition summary Total depth: measured 13600' feet Plugs (measured) true vertical 10150' feet Effective depth: measured 13540' feet Junk (measured) true vertical 10110' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2000 13-3/8" 185 sx 2000 1903' Intermediate 8627 9-5/8" 1750 sx 8627' 6583' Production 13600 7" 600 sx 13600' 10152' Liner Perforation depth: measured See attachment #1 true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.:2~, N-80, IPC tbg Packers and SSSV (type and measured depth) ~E [ Baker "FB-1" Perm Packer @ 11,729' ~ 13. Stimulation or cement squeeze summary 0 ? Intervals treated (measured) .: Treatment description including volumes used and final pressure Alr,¢',a 0il & 63,s 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 3930 0 4199 Subsequent to operation 0 0 3930 0 4171 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: Suspended: Service: x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: (~ r~,.~ ~,~ Title: ~ (~-. ~ t,,t,-- t.4k..~ ~,~ t~-~'~ ~-~.~(L Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ATTACHMENT #1 WELL D-24A PERFORATIONS BENCH MD TVD G-2 11 930' - 11 960' 8,987' - 9,008' G-3 12,030'- 12,060' 9,056' - 9,077' G-4 12,080' - 12,220' 9,091' - 9,187' B-Stray B-1 12,600' - 12,610' 12,685'- 12,705' 9,452' - 9,459' 9,511' - 9,525' B-2 12,753'- 12,864' 9,558' - 9,636' B-3 12,905'- 12,965' 9,664' - 9,706' B-4 13,033' - 13,216' 9,754' - 9,881' B-5 13,259' - 13,451' 9,912' - 10,048' B-6 13,466' - 13,526' 10,058'- 10,100' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Operation shutdown__ Re-enter suspended well __ Aiter casing Repair well __ Plugging ~ Time extension Stimulate Change approv'~ed program~ Pull Tubing__ Variance__ P'--~rforate ~ Othe~._.. 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development 106' KB above MSL feet Exploratory ~ 3. Address Stratigraphic -- 7. Unit or Property name P.O. Box 196247 Achorage, AK Service'X" Trading Bay Unit 4. Location of well at surface Leg A-l, Conductor #12, Dolly Varden Platform 8. Well number 755' FSL, 1213' FWL, Sec. 6-8N-13W-SM D-24A At top of productive interval 0~/~'~1~/,~~, 9. Permit number/approval number 1868' FSL, 3102' FWL, Sec. 5-8N-13W-SM 74-64 At effective depth 10. APl number 50- 733-20224-01 At total depth 11. Field/Pool 1611' FSL, 4264' FWL Sec. 5-8N-13W-SM ._ McArthur River Fieldv,' 12. Present well condition summary ~1~,44~/~[ Total Depth: measured 1 3,600' feet Plugs (measured) true vertical 1 O, 150' feet Effective depth: measured 13,540' feet Junk (measured) true vertical 1 O, 1 1 O' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor surface 2,000' 13-3/8" 185 sx 2,000' 1,903' Intermediate 8,627' 9-5/8" 1,750 sx 8,627' 6,583' Production 13,600' 7" 600 sx 13,600' 10,152' Liner Perforation depth: measured See Attachment #1R E¢ E IV E D true vertical MAY 1 1994 Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80, IPC Tbg. Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage Baker "FB-i" Perm Packer @ 11,729' 13. Attachments Description summary of proposal X.~ Detailed operations program__ BOP sketch X.~ Estimated date of commencing operation 15. Status of well classification as: April 28, 1994 If proposal was verbally approved Oil__ Gas__ Suspended Service Water Injector Name of approver Date approved 17. I hereby certify th.at t,J[ e foregoing is true and correct to the best of my knowledge. Signe(~~~ Title A~'~,/~,.~,~,ll/~Vlt!_ /}~,~ Date ,~/q~'/"' FOR COMN~I~SION U_~E Ol~crY Conditions of approval: Noiify CommiSsion so representative may witness IApproval No.o Plug integrity__ BOP Test__ Location clearance__~,/.,,j [I Mechanical Integrity Test w Subsequent form required 10- .~ :~Dp'oved Copy Original Signed By Returned Approved by order of the Commision David W. ,lr~hn~tnn ~!(-,--?c(,,i:. Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE~,~ Bench G-2 G-3 G-4 Attachment #1 Well D-24A Perforations MD TVD 11,930' - 11,960' 12,030' - 12,060' 12,120' - 12,220' 8,987' - 9,008' 9,056' - 9,077' 9,118' - 9,187' B-1 B-2 B-3 B-4 B-5 B-6 12,685' - 12,705' 12,753' - 12,864' 12,905' - 12,965' 13,033' - 13,216' 13,259' - 13,451' 13,466' - 13,526' 9,511' - 9,525' 9,558' - 9,636' 9,664' - 9,706' 9,754' - 9,881' 9,912' - 10,048' 10,058' - 10,100' RECEIVED MAY ] ] ~994 Alaska Oil & Gas Cons. Commissio~ Anchorage [SUNDRYI.XLW]Perf Database PROCEDURE WELL D-24A OBJECTIVE: Improve injection conformance in the G-Zone by perforating new interval in the G-4 sands and reperforation of selected interval in the G-2, 3 and 4 sands. 1. Test tree valves and ensure operational and holding. 2. Conduct pre-job meeting. Ensure adequate lighting for night operations. 3. RU E-line unit. . . . . . Pressure test lubricator & BOPE to 4000 psi. Function test BOP's operation under pressure. Shut-in injection to RIH and correlate. Return to injection immediately before firing guns to achieve overbalance for perforating. NOTE: Prior to arming guns and until guns are 1,000' in the hole, complete perforating safety measures. Re-complete perforating safety measures while POOH above 1,000'. RIH w/2-1/2" HSD, 6 SPF, 60 degree phasing (note: if unavailable or unable to utilize with select fire, backup gun system is 2-1/8" Hyperdomes (hollow carriers), 4spf, 180 degree phasing). Perforate the following intervals while injecting at 3700 psi tubing pressure for overbalance. Observe and record injection rates and pressures before and after firing each gun to determine by zone injection performance. Run Sand Interval (DIL) Footaqe la Stray 12,600-12,610 10' lb G-3 12,035-12,050 15' 2a G-4 12,155-12,165 10' 2b G-2 11,930-11,945 15' 3 G-4 12,110-12,140 30' 4 G-4 12,080-12,110 30' RECEIVED MAY 11 1994 Alaska 0il & Gas Cons. Commission Anchorage Note: for runs 1 and 2 which used select fire, correlate and fire the bottom gun, then recorrelate and fire the top gun. RD E-line. Return well to injection. 4/22/94 H:\wp\Sundry\D-24A TBU Well D-Z&A Workover Comp£e~--d Ha£ch 2~, 1986 ? 5/$", '", , 2~?. , :I-80 Butt. Tie back 12/2L/76 8433' ~627' 7", 29g, :I-80 C-Zone Perfs 4 SPF, 90° FhasinR G-2 11,930' - 11,900' G-3 12,030' - [2,060' G-4 12,120' - 12,220' PBTD 13,540' T.D. 13,600' 3 1/2", 9.2~, N-80, IFC tbn. w/501 cpls. REc£%V£I) ~Y 1 1 1994 Gas Cons. Commis~,' Anchorage Locator I1,712', 2.94" ID. Daker "FB-I" perm pkr 11,729' 10' seal bore exCencion Dell nutde X-nipple 11,75~', 2.75" ID I1,78~' - 1/2 cu= mule shoe Ilemlock Ferfs 12,685' 12,753' 12,905' 13,033' 13,25~' 13,466' Tag F~ll 12,705' 12,864' 12,965' 13,216' 13,451' 13,526' 13,526' WLM 5-86 WEC 9-87 13OLLY VARDEN PL/~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP 4' ~1Z~.6'-;.. '5 O0 0 CHISTMAS TREE - GREASE HEAD (Hydraulically Activated) ,. LUBRICATOR RECEIVED 1994 Gas Cons. Commissie' Anchorage POSITIVE CHOKE ---- 2" 5000 psi ....-. 2" 3000 psi 13 3/8' CASING Unocal North AmeH( Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region APril 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear MS. Johnson: I have attached surface survey locations of the "Legs" and conduCtors for the four Platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any Plats from a registered surveyor but I hope this Will meet your needs. Yours very truly, G u Regional Drilling Manager GSB/lew APR 2 ~, 197 .~il ~ aa~ ¢o~ C0~s~n DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, lSN~ .R1..3.W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG ~A-1: LAT = 60o48, 28.272" LONG =151°37' 57.620" 1 2 3 4 5 6 7 8 9 l0 ll 12 2,490,836.22 208,461.20 757.5 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' D-32 762.9 · 2,490,837.76 208,467.60 D-40 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 LEG #A- 2' 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 . D-1 755.3 2,490,840.19 208,376.67 D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 '2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 LEG ,B-l' LAT = 60048' 27.485" LONG =151°37' 57.564" 2,490,756.22 208,462. O0 677.5 1 2 3 4' 5 6 7 8 9 l0 ll 12 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-lO 681.3 2,490,756.87 208,464.53 D-12 & RD 678.3 2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 LEG #B-2: 2,490,755.43 208,382. O0 (Reserved for Compressors) 674.8 FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 121'9.5 1215.4 1211..1 1208.5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Telecopy No. (907) 276-7542 October 27, 1988 D K Corlett ReEion Operations Eng Marathon Oil Company P 0 Box 190168 Anchorage, AK 99519 Dear Mr Corlett~ On SePtember 26, 1988 we received the cement bond logs on wells D-6RD, D-15 RD2, D-16RD, D-24A, and D-29RD. Thank you for 7o'ur prompt help. Sincerely, Sr Petr Engineer Jo/A.BEW. 122 Alaska Region Domestic Production Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519 Telephone 9071561-5311 September 23, 1988 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Sir: Enclosed are sepia copies of the cement bond logs you requested for Dolly Varden water injection wells D-6RD, D-15RD2, D-16RD, D-24A, and D-29RD. Should you have any questions or require further assistance please contact Mr. Norm Fahnholz at (907) 561-5311. Sincerely, D. K. Corlett Region Operations Engineer NEF/em/878/OE34 A ~:~,h,,=:idimrv nf USX Corooration STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. · Unocal * 74-64 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50733-20224-01 4. Location of Well Surface: Leg A-1. 755' FSL, Cond. #12, Dolly Varden Platform 1213' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, otc,) 106' KB Above MSL 12. I6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-24A 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I-I Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation r-~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU Well D-24A Workover Workover operations were completed on March 24, 1986, as indicated by the attached procedure. RECEIVED Ata~t<~ Oil ~ ~:,S C~:,?~S C~,n'~m~.-,n-~"U ~ ~,:-,,.:~: ~ :~ APR 2 1 1986 Marathon Oil Company - Sub Operator Ak Envir0nmental Group 14. I hereby certify that the foregoing is true and correct to the best of my knowledge,~' Signed ~~, _~~ The spac~owL)fbr go~i~ use TitIe Environmental Engineer Da,e 4/23/86 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate TBU Well D-24A Workover Attachment 1. The well was killed with 8.7 PPG NaC1 in FIW. 2. Set BPV, ND tree, NU and test BOPE. 3. POH and LD 3 1/2" injection tbg. 4. Drill and recover packers from 12,476' and 12,988' 5. Wash fill to 13,542' DPM 6. Set EZSV at 12,400' 7. . Perf G-4; 12,120' - 12,220' with 4 SPF, 90° phasing. 8. Set RTTS at 12,043' and injection test G-4. 9. Pump acid into G-4 perfs: 27 bbls. of 7 1/2% HCL, 97 bbls. of 6 - 1 1/2% Mud Acid, 24 bbls of 3% NH4CL. Injection test G-4. 10. Set EZSV cmt ret. at 12,099' CBL. 11. Perf G-3; 12,030' - 12,060' with 4 SPF. 12. Set RTTS at 11,890' and injection test G-3. 13. Pump acid into G-3 perfs: 12 bbls of 7 1/2% HC1, 48 bbls. of 6-1 1/2 Mud Acid, 12 bbls of 3% NH4C1. Injection test G-3. 14. Perf G-2; 11,930' - 11,960' with 4SPF 15. ~Set RTTS at 11,850' and injection test G-2 & 3. 16. -Drill out EZSV packer @ 12,099'. 17. Set RTTS @ 11,800' and injection test G-2, 3 & 4. 18. -Drill EZSV packers and push junk to 13,540'. 19. .Injection test Hemlock and G-Zone. 6258 BWIPD, 1439 BWIPD in G-Zone (23%) 4819 BWIPD in Hemlock (77%). 20.~ Ran 3 1/2", 9.3#, N-80, IPC injection tubing. 21. Set BPV, ND BOPE, NU and test tree. 22. Return well to injection. WJL/mcm/163 RECEIVED APR 91986 TBU Well D-24A Attachment Zone G-2 G-3 G-4 B-1 B-2 B-3 (FIT) B-4 B-5 B-6 11,930' - 11,960' 12,030' - 12,060' 12,120' - 12,220' 12,685' - 12,705' 12,753' - 12,864' 12,905' - 12,965' 13,033' - 13,216' 13,259' - 13,451' 13,466' - 13,526' TVD 8,987' - 9,008' 9,056' - 9,077' 9,118' - 9,187' 9,511' - 9,525' 9,558' - 9,636' 9,664' - 9,706' 9,754' - 9,881' 9,912' - 10,048' 10,058' - 10,100' Acid Treatment G-4 12,120' - 12,220' Pump acid into G-4 perfs: 27 bbls. of 7 1/2% HCL, 97 bbls. of 6 - 1 1/2% Mud Acid, 24 bbls of 3% NH4CL. Injection test G-4. G-3 12,030' - 12,060' 12 bbls of 7 1/2% HC1, 48 bbls of 6-1 1/2 Mud Acid, 12 bbls of 3% NH4Cl. WJL/mcm/163 APR2 9 lg86 A.,ch .... '~-~ STATE OF ALASKA SUNDRY NOTICES AND REPORTS DRILLING WELL ~ COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Unocal * 74-64 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50733-20224-01 4. Location of Well Surface: Leg A-i. 755' FSL, Cond. #12, Dolly Varden Platform 1213' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB Above MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-24A 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU Well D-24A Workover Workover operations were completed on March 24, 1986, as indicated by the attached procedure. Marathon Oil Company - Sub Operator APR 2 1 1986 Ak Environmental Group 14. I hereby certify that the foregoing is true and correct to the best of my knowledge.~'- Signed ~:j~Cj~ _~~ The spac~o~fbr ~oOr~mei~s'J~o'~ use Tit,eEnvironmental Engineer Date 4/23/86 Conditions of APproval, if any: BV Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TBU Well D-24A Workover Attachment · · Be 0 Be · · · · The well was killed with 8.7 PPG NaC1 in FIW. Set BPV, ND tree, NU and test BOPE. POH and LD 3 1/2" injection tbg. Drill and recover packers from 12,476' and 12,988' Wash fill to 13,542' DPM Set EZSV at 12,400' Perf G-4; 12,120' - 12,220' with 4 SPF, 90° phasing. Set RTTS at 12,043' and injection test G-4. Pump acid into G-4 perfs: 27 bbls. of 7 1/2% HCL, 97 bbls. of 6 - 1 1/2% Mud Acid, 24 bbls of 3% NH4CL. Injection test G-4. 10. Set EZSV cmt ret. at 12,099' CBL. 11. Perf G-3; 12,030' - 12,060' with 4 SPF. 12. Set RTTS at 11,890' and injection test G-3. 13. Pump acid into G-3 perfs: 12 bbls of 7 1/2% HCl, 48 bbls. of 6-1 1/2 Mud Acid, 12 bbls of 3% NH4C1. Injection test G-3. 14. Perf G-2; 11,930' - 11,960' with 4SPF 15. Set RTTS at 11,850' and injection test G-2 & 3. 16, Drill out EZSV packer @ 12,099'. 17. Set RTTS @ 11,800' and injection test G-2, 3 & 4. 18. Drill EZSV packers and push junk to 13,540'. 19. Injection test Hemlock and G-Zone. 6258 BWIPD, 1439 BWIPD in G-Zone (23%) 4819 BWIPD in Hemlock (77%). 20~ Ran 3 1/2", 9.3#, N-80, IPC injection tubing. 21. Set BPV, ND BOPE, NU and test tree. 22. Return well to injection. WJL/mcm/163 , /~. STATE OF ALAS A ALASKA i!LAND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION 1. Status of Well ~f~lt~o~l~lv, ic~V~101~ ;ion OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Wa ion ;~. Name of Operator 7. Permit Number UnOcal* 74-64 3. Address 8. APl Number P.O. Box 6247, A~chorage, AK 99502 50- 733-20224-01 4. Location of well at surface 9. Unit or Lease Name Le~,A-1. Conduc, tor #12, Dolly Varden Platform 77~ FSL, 1213 FWL, Sec. 6-gN-13W-SM Trading Bay Unit At Top Producing Interval 10. Well Number D-24A Workover At Total Depth 1i. Field and Pool ,, 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSt 'J ADL - 18729 McArthur River Field 'i2. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ,15. Water Depth, ifoffshor, .16. No. of Completions 3/24/86ll90 feetUSL (2) T~o 17. Total Depth (M D+TVD)18. Plug Back Depth (MD+TVD)19. Directional Survey I 2o. Depth where SSSV set I 21. ThickneSs of Perma,r°st 13600' 10150' 13540!MD,~0110'TVE YES [] NOJ~] feet MD 22. Type Electric or Other Logs Run CCL/Temp/RA Tracer '23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEIWT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 61# J-55 3urfaCe 2,000' 17 1/2" 185 sxcmt 9 5/8" 47# N-80 P-110 Surfa'ee ~ ~-'o~-~, ~2 1/4" 1750 sx 2 stages -. 7" 29~/: N-80 8~33~' .13.,600' 8 1/2" 600 sx emt: 7" 29# N-80 ~Sa~aee 8',43~' Tie back' to surface 12/Z1/76 · 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) 'z,~eo-,z~Z~ 3 1/2" 11,789' 11,729' RECEIVED -,', ......... Attachment 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. APR 2 9 1986 o..~., N T E R V A L ( M D ) AMOUNT · K ' N D O F M A T E R ' A L I U S E D See Attachment Alaska 011 & Gas Cons. Commission Anchorage - 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) March 20, 1986 J Water Injection "Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/20/86 24 TEsT PERIOD ~ I Flow Tubing Casing Pressure cALCULATED OIL-BBL GAS-MCF WATER-BBL Gl L GRAVITY-APl (corr) Press, 3928 180 24.HOUR RATE I~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. APR 2 11986 Ak Environmental Group · Marathon Oil Company - Sub Operator Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct ro the best of my knowledge R~ D. Roberts .......... 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- ~-,,-,4 ~.,.,., ~,'-,m: iO Of ti-, Ce.i.~,er-~tii~.,, ~ern ,_,:..:::,' [!: r~o cort~,s taxers, indicate "none". Form 10-407 Unocal Oil & Gas Divisi~ Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District April 7, 1986 Hr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001Rorcupine Drive Anchorage, Alaska 99501 Dear Hr. Chatterton: HONTHLY REPORT WELL D-24A DOLLY VARDEN PLATFORM Attached please find two (2) copies of the Monthly Report of Drilling and Workover Operations for D-24A, Trading Bay Unit for your information and files. Very truly yours, Environmental Engineer OO280 cc: Trading Bay Unit Participants RECEIVED APR 0 8 1986 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ~',~: ALASKA ~ AND GAS CONSERVATION C¢...,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation I~ 2. Name of operator 7. Permit No. Unocal * 74-64 3. Address 8. APl Number P.O. BOX 6247, Anchorage, AK 99502' 50- 733-20224-01 4. Location of Well atsurface ~ A-l, Conductor #12, Dolly Varden Platform 755' FSL, 1213' FWL, Sec. 6, T8N, R13W, SM Marathon Oil Company - Suboperator 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB Above MSLJ ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-24A 11. Field and Pool McArthur River For the Month of. Ma~ch ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks The old 3-1/2" tubing was pulled and two permanent packers were successfully ~ fished. Fill was cleaned out to PBTD of 13,542'. The perforations at 12,220'-12,120' and 12,060'-12,030' were acidized with 7-1/2% HCL and mud acid. A permanent packer was set at 11,706' and the 3-1/2" completion equit~nent was run. The well was completed as a ccmmingled G-Zone/Hemlock water injection well. 13. Casing or liner run and quantities of cement, results of pressur9 tests The 7" casing was pressure tested to 2500 psi. 14. Coring resume and brief description RECEIVED APRO Alaska 0ii & G~s Cons. CommiSsion Anchorage 15. Logs run and depth where run A caliper log was run in 7" casing from 13,368' to surface. The log showed the casing to be in very good condition. A CBL/GR/CCL was run from 12,391'-11,000'. A CCL/temp/radioactive tracer log was run from 13,520'-11,800'. I 6. DST data, perforating data, shows of H2S, miscellaneous data New zones were perforated at the following depths: G-4 Sand, 12,220 '-12,120 ' CBL G-3 Sand, 12,060'-12,030' CBL G-2 Sand, 11,960'-11,930' CBL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I---~" .SIGNED ,...,, D. Roberts TITLE Environ~ Eng~n~r DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate ~--,, STATE OF ALASKA ALASKA .LAND GAS CONSERVATION CL ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [~ 2. Name of operator 7. Permit No. Unocal * 74-64 3. Address ~ 8. APl Number P.O. Box 6247, Anchorage, AK~' 99502 50- 733-20224-01 4. Location of Well atsurface Leg A-I, Conductor #12, Dolly Varden Platform 755' FSL, 1213' FWL, Sec. 6, T8N, R13W, SM * Marathon Oil Company - Suboperator 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB Above MSL ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-24A 11. Field and Pool McArthur River For the Month of Febr,_,ary ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks The well was backflowed to relieve shut in tubing pressure of 120 psi. The tubing was perforated and the well killed with filter inlet water weighted to 8.7 ppg with NaC1. 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run RECEIVED 1 §. DST data, perforating data, shows of H2S, miscellaneous data . MAR 1 3 1986 Alaska u, ~,~mmission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. £¢F~'1 Ro~D. Rober~cs Envt ronmenta! Engi. neer SIGNED TITLE. DATE 03/11/86 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate -_ Unocal Oil & Gas Divisi('~' ' Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL .-/ , Environmental Group Alaska District February 25, 1986 Hr. C.V. Chatterton AK. Oil & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: SUNDRY NOTICE INTENTION Attached for your approval are three (3) copies of a Sundry Notice of Intention for D-24A, Trading Bay Unit. Work on D-24A is expected to commence as early and February 28th therefore, we would appreciate approval as soon as possible. Very truly yours, Environmental Engineer tj/O124n Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of'California* 74-64 3. Address 8. APl Number ?,0, 30× 6247 Anchorage, AK 99502 50Z33-20224-0! 4. Location of Well Surface: Leg A-1. 755' FSL, Cond. #12, Dolly Varden Platform 1213' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB Above MSL 12. I6. Lease Designation and Serial No. ADL 18729 9, Unit or Lease Name Trading Bay Unit 10. Well Number D-24A 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [--I Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU Well D-24A It is Marathon's intention to workover Well D-24A beginning February 28, 1986 as described in the attached procedure. * Marathon Oil Company - Sub Operator 14. I hereby f0~D: ce fy t t th egoi g is true and correct to the best of my knowledge. Signed Roberts Title Env i ronmenta 1 Eng i neer The space below for Commission use Date 02/26/86 Conditions of APproval, if any: COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TBU Well D-24A Workover Procedure 2. 3. 4. 5. 6. 7. 8. Rig up on the well. Kill the well with FIW. ND tree, NU and test BOPE. POH and LD the 3 1/2" injection tubing. Pressure test the casing to 2500 psi. Cement squeeze as necessary. Run CBL. Squeeze G-2 and G-4 if necessary. Perforate G-2 and G-4 zones, run injectivity logs, acidize to increase injectivity if required. 9. Run 2 7/8" and 2 3/8" dual completion assembly. 10. ND BoPE, NU and test the tree, place the well on dual Hemlock and G-Zone injection. Verbal approval to begin operations, subject to approval of the written Sundry Notice of Intent, was received from Russ Douglass of AOGCC by W. J. Laverdure on February 26, 1986. Form ~qo. P-4 · REV. ~-1-70 ~ ~ ............. ~UBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL O GAS [] Water InjectOr WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL 755'FSL, 1213'FWL, Conductor //12, Leg A-l, Dolly Varden Platform, Sec. 6, T8N, R13W, SM K I COMM' :'..:.':, "'5.' APl NUMERICAL CODE ~' I . ~ ~' ;': ": y_ 50- 3- 022/-01 _---i 2 6. LEASE DF_~IGNATION AND $ ~ ~O~. ~k- 1872~ .~ ~~- .. GirO[ 8. UNIT FARM OR LEASE NAM, '~[' T,tadino Bay UniE-j · WELL SO. D-24A WO ---- gll 10. F~ELD*N~ ~OOL, Og W~L~?~_~-' ' ~ ... McArthur River Field ,,, 11. SEC. T. R. M. (BOSOM HOLE OB~E~IVE) Sec. 5, T8N, R13W, SM ,, ,, 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. JULY REPORT OF WORKOVER OPERATIONS 07-01 13,600'TD 13,549' PBTD WOC. Drld cmt to DBP @ 12,980'WLM. Circ hole clean. POH. RU Retrievamatic. RIH & set @ 12,885'WLM. Press up to 500 psi 5 min--no press loss. Press to 1000 pSi 5 min--no press loss; press to 2000// 5 min--no loss; held 2000// for 30 min--no press loss. Released press & POH. LD pkr. Pu bit //3 & basket & RIH. Drld plug & junk @ 12,980'. Pushed junk to btm @ 13,549'DPM. POH w/ bit //3. 07-02 13,600'TD 13,549'PBTD RIH w/ bit & scraper. CO fill from 13,536' - 13,564'. Circ hole clean. POH. RU DA & perf Bench 1 of Hemlock from 12,685' - 12,705' (FDC/CNL) w/ 4" Jumbo.c'sg jet (4 HPF). RD DA. RU FIW injection to rig floor. RIH w/ Baker RBP & Retrievamatic pkr to acidize Bench 1 perfs. 07-03 13,600'TD Set BP @ 12,750' &. pkr @ 12,650'. RU Dowell. Tstd lines to 13,549'PBTD 5000#. Press Bench 1 perfs to 4500 psi--could not pump in. Bled to 2500 psi in 25 min. Press to 4500 psi--bled to 1800 F~ECEIV ~:' D psi in 25 min. Unseated pkr. RIH to 12,745'. Spotted 10 bbls Super Mud Acid' across Bench 1 perfs. Set pkr @ 10,652'. Press to 3000 psi--no bleed off. Attempted to place pkr in J posi- ~,~$~ ~ ~7~ tion & retrieve BP. Unable to get pkr to go dwn hole. Set pkr. Press to 4500 psi. Failed to pump acid away. Worked w/ pkr A]aSMl0ii & G~s G0ns. gut,tmm~ltqtempting to lock slips. POH w/ pkr & retrieving tool. In- Ai~tlorag0 spected pkr & found stripped key in rotating & releasing mechan- ism. RIH w/ retrieving tool. Found BP @ 12,650'. (BP was probably latched prior to spotting acid &;:then pulled up hole above perfs.) Reset BP @ 12,750'. Press annls to 2800 psi. No /~ lo~k off PflH er~ fore i tru and correct SIGNED. ¢~*"~1-~... -- C~t~------- TITLE · DATE NOTE-~ort on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. *Marathon Oil Company - Sub-Operator Monthly Report of Workover Operations - July Page 2 07-04 13,6OO'TD 1 3,542' PBTD RIH w/ pkr & BP to 12,741'. Set BP @ 12,741'. Spotted lO bbls mud acid across Bench 1 perfs. Set pkr @ 12,660'. Estab inj rate of ½ BPM'@ 4000 psi into Bench 1 perfs. Aci- dized Bench 1 perfs w/ 800 gals 15% HCL followed by 18OO gal 12.6~o Super Mud Acid followed by 200 gals 15% HCL. Displ acid into perfs ~ ½ to 3/4 BPM @ 4000 to 4300 psi. Over- displ acid w/ 29 BW. Released pkr & RIH PU BP. Set BP @ 13,564'. PU & set pkr @ 12,540'. Inj FIW into Hemlock fm @ 6900 BPD @ 3800 psi. 07-05 13,6OO'TD 13,542' PBTD Stabilized inj @ 7000 BPD @ 3900 psi. RU Schl & started run- ning inj profile logs. 07-06 13,600'TD 1 3,549' PBTD Ran inj profile & temp surv. RD Schl. Unseated pkr & latched BP @ 13,560'. POH. 07-07 1 3,600'TD 1 3,549' PBTD Fin POH w/ Baker pk~ & BP. Tstd BOP & related eqpmt. RU DA & set Baker F-1 perm pkr @ 12,970'DIl. RD DA. Cut & slipped drlg line. RIH w/ seal assy on 3½" DP & landed in pkr. Tstd pkr & seals to 2500 psi. Off-loaded acid & eqpmt prior to acidizing Benches 4, 5, & 6 of Hemlock. O 7-O8 13,600' TD 13,549' PBTD Fin off-loading Dowell acid & eqpmt. ~RU Dowel1. Tstd lines to 5000 psi. PI Benches 4, 5, & 6 of Hemlock @ 2 BPM @ 2500 psi. Pulled seals out of perm pkr @ 12,970' & circ acid to pkr. Stabbed into pkr & started pumping acid @ 2 BPM @ 2500 psi. Engine on Dowel l pump broke dwn after pumping 2000 gals of 7½% HCL & 3050 gals 12.6 Mud Acid. Displ acid into fm w/ FIW & rig pump 3 to 3'3/4 BPM w/ press decr from 2500 psi to 1900 psi. Flushed lines. Cleaned up & WO replacement Dowel l unit. 07-09~F~(~0~?T~ wo replacement Dowel l unit for 5 hrs. RU to acidize Benches -~I~3~ ~49~P~T~I~ 4, 5, & 6 of Hemlock. Estab inj rate of 2~ BPM ~ lO00 psi w/ [~'~ ~7~ FIW. Acidized w/ 4000 gals 7~% HCL & 18,OOO gals 12.6 Mud ~ ~ Acid (to~a] of both stages). Final acid rate was 4 BPM ~ 2500 psi. RD Bowel1. RU to inj. Inj into Benches ~, 5, & AJaS~ O~J & g:~ ....... :~" ~.'~,.~s~0~ ~ 8300 BPD rate ~ 3500 psi w/ FIW. Pulled seals from perm ~r~e pkr Circ. LOaded eqpmt on boat. RU to LD 3~" DP. Started LD 3~" DP. O7-10 13,600'TD 1 3,549' PBTD Fin Ld 3½" DP. RU DA. Ran gauge ring & JB to 12,6OO'. RIH w/ Baker FB-1 perm pkr. Stopped @ 8595'. POH. Ran JB & gauge ring. Rec 3 small pieces of rubber. RIH w/ perm pkr. Stopped @ 8595'. POH. Cut 5' off of lO' seal bore ext of pkr. RIH. Set Baker FB-1 pkr @ 12,460' (FDC/CNL). RD DA. RU to run 3½" tbg. Now running 3½" tbg, hydrotesting to 5000 ps i. O7-11 13,600'TD Fin RIH w/ 3½'1 tbg, hydrotesting to 5000#. Spaced out & 13,549'PBTD' spotted inhibited pkr fluid. Instld hgr & landed tbg. ND BOPE & instld Xmas tree. Started connecting inj system to wellhead. Monthly Report of Workover Operations - July Page 3 O7-12 13,600'TD 13,549'PBTD 07-13 13,600'TD 13,549'PBTD 07-14 13,600'TD 13,549'PBTD 07-15 13,600'TD 13,549'PBTD Dismantled BOPE. Cleaned & greased all parts for stacking. Cleaning'& mothballing all rig eqpmt. Inj FIW into Well D'-24A for lO hrs f~ rate of 8000 BPD @ 3100 psig. Cont stacking & mothballing rig eqpmt for SD. Inj FIW into D-24A @ 10,400 BPD @ 3150 psi. Cont stacking & mothballing rig eqpmt for SD. Cont stacking & mothballing rig eqpmt for SD. Released drlg crew @ 1200 hrs, 07-14-79. FINAL REPORT Marathon Oil Company Anchor~ Division Productiun Operations US & Canada PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 July 23, 1979 Mr. J. R. Callender Union Oil P. O. Box 6247 Anchorage AK 99502 Dear Mr. Callender: Enclosed for your further handling are the sundry notice for~ and the well completion report for D-3RD. C, ~.'DOWDEN ~ %--~ Operations Superintendent CAD: ro Attachments Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I~-I OTHER Water Injector 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P, 0. Box 6247, Anchorage AK 99502 4~" LOCATION OF WELL At surface 755'FSL, 1213'FWL, Conductor #12, Leg A-l, Dolly Varden Platform, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2' KB MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50- 1 ;3;3-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ---- 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-24A WO 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W~ SM 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF= WATER SHUT-OFF r'~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion ReDort and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 06-30-79 Cement squeezed two formation interval tester holes in Bench 3, Itemlock Zone (12,905' and 1.2,965') with 50 sx C1 G cement. 07-02'79 07-O4-79 Perforated Bench. 1., Hemlock (12,685' - 12,705') wi th 4" casing gun, 4 HPF. Acidized Bench 1 with 1000 gals 15% HCL and 1800 gals 12-6 Super Mud Acid. 07-09-79 Acidized Benches 4, 5, & 6, Hemlock, with 4000 gals 7½% HGL and 18,000 gals 12-6 Super Mud Acid. 07-11-79 Ran 3½" tubing to perm pkr at 12,460' and returned well to injection service. 16. I hereby cer~that the foregoing is true and correct E!V F D AL, ska Oi" .: ,, T IT LE DATE (This sl~e for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE *Marathon 0i 1 Company - Sub- See Instructions On Reverse Side Operator Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OiL r-1 GAs r-I WELL L.--J WELL L--J OTHER Water Injector 2. NAME OF .OPERATOR Union Oil Company of California* 3. ADDRESS OF OPERATOR P, 0. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL At surface 755IFSL, 1213.'FWL, COnductor #12, Leg A-I, Dolly'Varden Platform, Sec. 6, T8N, R13W,' SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2' 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-24A WO 10. FIELD AND POOL, OR WILDCAT McArthur River Field ].1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM ].2. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF [-----I FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MU LTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work; It is proposed to cement squeeze two formation interval tester holes in Bench 3, Hemlock Zone (12,905' and 12,965'), and to reperforate and acidize Bench 1. Currently, the formation interval tester holes are taking about 1500 BWPD, 32% of the total 4670 BWPD. which is reaching the Hemlock. Due to the thief nature of Bench 3 in the area of D-24A, it is desirable to cement squeeze these holes. Bench 1 is currently taking no water in D-24A. A Bench 1 pressure, obtained recently with a repeat formation tester in D-34A, confirmed the need for additional Bench 1 injection. It is proposed to perforate Bench 1 from 12,685' - 12,705' (existing Bench 1 perfs are from 12,695' - 12,705') and acidi.ze in an effort to improve injectivity. JUL t 4 1979 SIGNED ..... , ,,,ll~,SJOtl TITLE Dist. Drl~ Suoerintendent DATE (T h for State~ use~)_ T IT LE CONDITIONS OF ~PPROVAL, IF ~t~ See Instructions On Reverse Side *MarathOn 0il Company - Sub-Operator .Tu%y ]~o,. lg7g DATE GEOPHYSICAL/GEOLOGICAL DATA TRANSMITTAL LIST I/ DATE ,, July 13, 1977 FROM: /~ARATHON OIL COMPANY TO: Harry Kugler ExplorationJ l'{ober't M. llilos State DJ.:v. of Oil. P. O. Box 2380 A~lchor,~e, Al.sk:~ 995 I0 VIA QUANTITY & Gas Porcupine Drive Anchorae, AK ......................... l v k=~' '~-%'~'1 i'~ p ~ ~ 7/13/77 D_~ ~.~/~' DESCRIPTION Comgensated Format±on Density T,og--Blueline 5" 5" Compensated Neutron Formation Density Log--Blueline Sepia of each above . .. ~ PLEASE RETURN ONE . // /? ~o~ ..... ~-'.'~.'~'~'--,",~ t/.'. lC ~ ABOVE ADDRESS - ~ / ~C~,VEO By / ~ ' Union Oil and Gas D ion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 Division of Oil & Gas State of Alaska 3001 Procupine Drive Anchorage, AK 99504 RE' tbu D-24A WO Dear Mr. Hamilton- Enclosed for your files are two (2) copies each of the Sundry Notice of job completion, Well History, and open hole formation test report for the above captioned project. CC' ~ Sincerely y~urs, _ \'~-i~Jim~R. Callender ~'~trict Drilling Supt. Atlantic Richefield Co. Phillips Petroleum Co. Skel ly Oi 1 Company Standard Oil Co. Amoco Production Co. Rodney Smith - USGS RECEIVED ' AN 34 lg77: DJvlslon of 01t In~t OAi Goneervatlon Form 10-403 REV. 1-10~73 Submit "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ].' Ow~LL,r"l GAS r-'! Water Injector WELL U OTHER , 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99510 4. LOCATION OF WELL At surface 755'FSL, 1213IFWL, Conductor //12, Leg A-1 Dolly Varden Platform, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2' KB MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-24A WO (33-5) 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, TBN, R13W, SH 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MU LTI PLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF I~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Tested 7" tbg & 9-5/8" csg w/ pkr @ 8450' & BP @ 12,646I. Found hole in csg @ 5164' and obstruction ~ 5300'. Cemented 201 jts 7" tieback csg from 8445' to surface & tested. Acidized Bench 6 perfs w/ 7200 gals acid. I nj rates: Bench 1 No flow Bench 2 2500 BPD Bench 3 1870 BPD Bench 4 2060 BP D Bench 5 1267 BPD Bench 6 475 BPD Ran & set Baker Model F 4" x 7" pkr @ 12,390'. Ran 421 jts 3½" tbg & set into pkr @ 12,390'. Job complete at 12 Midnight, 01-02-77. * Marathon Oil Company - Sub-Operator Dist. Drlg. Supt. (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 404 RICV. DATE_ 01-..10-77 MAhATHON OIL COMP~..~IY HISTORY OF OIL OR GAS WELL FIELD_ HcArthur R!,,,ver WELL NO.~ 0-24A W~_EASE STATE A1 as ka Trading Bay Unit PARISH Kenai Pen i n- COUNTY sula Borough ..~ 106.2'ELEV. KB .. - FToP oF OIL STRING ELEV. ~ MEASUREMENTStToP OF ROTARY TABLE . ELEV. ,. TAKEN FROM [GRD. OR MAT ELEV. BLOCK ... SEC. , 5 --TWP. 8N R. 13W, _ 'HISTORY PREPARED BY M. E. Krugh TI?LEL ?elto. Enq r.. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dotes thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1976_ 12-10 12-11 12-12 12-13 . 12-14 12-15 12-16 12-17 12-18 12'19 12-20 13,600'TD 13,526' PBTD 13,600'TD 13,526' PBTD ._ 13,600'TD - 13,526'PBTD 13,600'TD 13,526'PBTD 13,6OO'TD 13,526'PBTD 13,6OO" TD 13,526' PBTD 13,600' TD 13,526'PBTD 13,600'TD 13,526'PBTD 13,600'TD 13,526'PBTD 13,600'TD 13,526'PBTD 13,6OO'TD 13,526'PBTD WELL HISTORY - TBU WELL D-24A WO (Marathon AFE 4572) Released rig. from D-31RD at 12 Midnight, 12-O9-76. Began moving 'rig over D-24A at OO01 hrs, 12-01-76. Finished RU on D-24A WO. Installed BPV in tbg' Removed prod lines. ND Xmas tree. Installed BOPE. PU & worked tbg seal assy free. PU & removed tbg hgr. Circ FIW. Circ well & took 3½" DP off boat. LD tbg & seal assy. Threads were washec~ out of pup jt threads @'2185'. Tbg broke out e'xceedingly hard. Finished PU DP. Put on DP rubbers. Circ on top of pkr. Started milling pkr ~ 4:30 AM. Finished milling over 7" Baker pkr. POH. LD milling tools. Pull wear bushing. Ran test plug & tested BOP lines, choke manifold to to 3500 psi, Hydril to 2500 psi--all OK. Installed wear bushings & PU 7" ret BP & pkr. Set BP @ 12,646', pkr Q 8450'. Press to 4000 psi. Pumped in @ 2 BPM. Released pkr @ 8450'. I~kr would not go down. POH. Found key had sheared leaving pkr in set position. Repaired pkr & RIH to 8470'. Tested csg to 4500 psi--OK. Released pkr & RIH to PU BP. BP would not go down hole. POH to check tool. Had pkr & BP & found DP rubber lodged between. RIH w/ 7" BP & pkr. Set BP Q 8497'. PU to 8469' & tested BP to 4500 psi--OK. POH w/ 7" pkr to 9-5/8" pkr. POH LD 7" pkr & BP. PU 7" DBP. RIH to 8535' & set BP. Tested DP to 4500 psi--OK. POH. PU 9-5/8" pkr & RIH testing csg every 1000'. Tested to 3500 psi--found hole in csg between 5147' - 5164'. Pumped 4 BPM @ 1900 psi. Cont running pkr in hole. Pkr stopped Q 5300'. Could not move up or down. Displ wtr out of hole w/ mud & worked pkr loose. POH. Made up 8½" bit, DC's, & jars. RIH. Sat down Q 5297'. Rotate & work bit. POH. Made up 6" bit, DC's, & jars· RIH to 5800'. POrt. Made up Tri-State 6" bullnose, 8½" csg roller, DC's, BS, & jars. RIH. Reamed tight spot.Q 5297' - 5300'. POHto 5267' & circ. POH. LD 5" DP & Tri-State tools. ND BOPE. Removed tbg spool. Mounted csg spool. NU BOPE. · . Tested csg spool to 2500 psi--OK. Tested BOPE to 3000 psi--OK. Serviced rig & prep to run 7" csg. Waiting on delivery of TIW csg equlpmt. Well History - TBU Welt D-24A WO Page 2 12-21 13,600 'TO , 13,526'PBTO RU & ran 201 jts 7", 29//, N-80, Butt csg as tieback string from 8433' - surface. Cmtd w/ 825 sx Class $ neat w/ 1~; D-31, .2% R-5. Bumped plug to 4500 psi. Set csg slips. Cut csg. WOC. Tieback Casing Oetai.I. I tern ~ Fro~ T_~o' KB to 7"x9-5/8" csg slips 1 jt 29#, N-80, Butt csg 157 its 29#, N-80, Butt csg 41 jts 29//, N-80, Butt csg Baker cmt float clr 2 its 29#, N-80, Butt csg 7" Tieback seal nipple w/ 6 "O" ring seals, 7.25"0D built by Tri-State for TIW, Type S Tieback sly 41..22' O' 41.22' 9.60' 41.22' 50.82' 6579~44' 50.82' 6630.26' 1725.43' 6630.26' 8355.69' 1.58' 8355.69' 8357.27' 85.59' 8357.27' 8442.86' 2.98' 8442.86' 8445.84' 12-22 12-23 12-24 12-25 12-26 12-27 12-28 12-30 12-30 12-31 13,600'TD 13,526'PBTD 13,600'TD 13,52.6'PBTD 13,600'TD 13,526'PBTD 13,600 ' TD '13,526' PBTD 13,600'TO 13,~526'PBTD 13,600'TD ' 8,339' PBTD 13,600'TD 8,497'PBTD i3,600'TD 8,497'PBTD 13,600'TD 13,542'PBTD 13,600'TD 13,542'PBTD PU 3½" DP & RIH to 8339' top of cmt PU 90' & circ hole clean Closed pipe rams. Put in inside BOP. WOC. Drained rig & conditioned for holiday SD. SD for holidays. SD for holidays. SD for holidays. Started RU to drl out cmt @ 12 Midnight. Hooked up all mud lines & well head lines. Circ mud out of hole & displ w/ FIW. Drld hard cmt from 7339' - 8355'. Drld float & hard cmt from 8355' to 8470'. CO to BP ~g 8535'. Circ hole clean· Press tested 7" csg to 3000 psi for 15 min--OK. POH.. Ran HOWCO test tools. Set pkr ~ 8380'. Tail pipe ~ 8397'. Opened 15 min--very slight blow for 5 min. Closed 30 rain & opened for 2 hrs. No flow. Closed 2 hrs.. P0H ~ 7 AM. POH & LD HOWCO test too'Is. PU 6" bi't & 2 boot baskets. RIH. Drld 7" BP @ 8535'. Drld & pushed plug to 13,542'. Circ. POH to PU csg scraper. PU csg scraper & bit. CO to 13,542'. Circ & POH. PU 7" Baker ret pkr w/ 38' of 3½" stinger below pkr. RIH to 12,459'. Tested pkr to 3000 psi--OK. RIH to 13,477'. Ran GO Int'l GR, CCL. PU pkr 13' & set. RU Dowell & press tested lines to 4000 psi. Inj into Bench 6 @ .1 BPM ~ 3000 psi. Inj down annulus @ 7000 BPD rate g 2500 psi. Opened pkr bypass. Spotted acid on Bench 6. Spotted acid to Bench 6 perfs. Closed pkr bypass. Init inj rate of .2 BPM @ 3000 psi down DP. inj down annulus total of 1435 bbls wtr t~ 2500-3300 psi during acid job. Pumped 400 gals 12-10 UMA w/ 0.4% A-130 & 1% W-35; 1500 gals 5% HC1 w/ 0.4% A-130, 7% U-66 & 0.5% W-35; 3300 gal 12-10 UMA & additives; and 2000 gals 5% HC1 & additives. Inj 3000 bbls in 6 hfs down annulus ~ 3800 psi. Meter would not record rate down DP. SI inj. POH to 12,347' & set'pkr. RU GO Int'1. RIH & located w/ spinner. Inj down DP ~ 8325 BPD ~ 3750 psi for 6 hrs.' Running spinner survey. Well History - TBU 14el D-24A 140 Page 3 01-01 01-02 13,600'T0 13,S42'PBTD 13,600 'TD 13,S42'PBTD Finished running spinner survey. POH LO tools. Bench #1 No flow; #2 2500 BPD; //3 1870 BPD; //h 2060 BPD; #5 1267 BPD; //6 475 BPD. POH w/ ret pkr. LD DP. Pul led wear bushing. GO Int'l ran JB to 12,390'. Ran Baker Model F q" x 7" pkr. Set @ 12,390'. POH. RD WL tools. RU 3~'' tbg tools. Made up Baker 4" seal assy & tested to 4500 psi. PU & ran 421 jts 3½"; 9.2#, N-80, SL tbg. Set into Model F pkr ~ 12,390'. Tested pkr to 2000 psi--OK. PU 1'. Spaced out & landing tbg. 01-03 13,600'TD 13,Sq2'PBTD 3½" Tub i n~l Oeta i 1 I tern Length F.rom T_~o KB to tbg hgr Cameron tbg hgr (4½"EUE 8rd top x 4½" Butt btm) Xover (4½"Butt Pin x 3½"SL pin) 1 pup j t S L tbg pup j t I pup jt SL tbg pup jt 1 pup jt SL tbg pup j t 419 jts 9.2#, SL, N-80 Xover (3½"SL top x 3½"Butt btm) Baker 4"OD seal assy (25 units) Iocator on top Fu 11 mu le shoe 38-92' 0 38.'92' 1.25 38.92' qO. 17' · 65' 40.17' 40.82' 6.04' 40.82 ' 46.86' 4.10' 46.86' 50.96' 2.13 ' 50.96 ' 53.09' 12,376.07' 53.09' 12,429.16' 2.06' 12,429.16' 12,431.22' 19.70' 12,431.22' 12,450.92' .70' 12,450.92' 12,451.62' Baker Model F perm pkr (7"OD x 4"Bore) set ~ 12,390'WLM. Landed 3½" tbg. Flanged down BOP. Installed Xmas tree. Tested all sea]s to 5000 psi. Released rig @ 12 Midnight, 01-02-77. RECEIVED JAN 2, 4 1977 Dlvlsi0, of Oil and Gas Conservation Anchorage Union Oil and Gas Di,. ~'"'"n: Western Region Union Oil Company of California P.O. Box 6247. Anchorage, Alaska 99502 Telephone' (907) 276-7600 Dear Mr. Hamiltoh: .January 1S, 1977 Mr. Hoyle Hamilton Division of 0il & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 . Enclosed for your files are two {2) copies of the Monthly Report of Drilling & Workover Operations .for the aboye captioned wells. Very truly yours, Jim R. Callender District Drilling Superintendent jw Encl. CCI Marathon Oil Company Atlantic Richfield Company Amoco Production Company Phillips Petrole~un Company Skelly Oil Company Standard Oil Company USGS Rodney Smith RECEIVED JAN Division of 011 and Gas Conservation Anohomge Fo~m No. P.-d KEY. )-1-70 SL~MIT IN DUPLICATE · , STATE OF ALASKA OIL AND GAS CONSEFIVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOYER OPERATIONS 4. LOCATION OF WELL 755'FSL, 1213'FWL, Conductor #12, Leg A-l, Dolly Varden Platform, Sec. 6, T8N, R13W, SH 5. APl NUMERICAL CODE ~ 50-133-2022f-01 6. LEASE DESIGNATION AND SERIAL NO. ADL"18729 !. ?. IF INDIAN'ALOTTEE OR TRIBE NAME OIL r-] GAS I-'] Water Injection -'.-' WELL OTHER WELL 2. SAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Union Oil Company of California* Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 6247, Anchorage, AK 99510 D-24A WO (33-5) 10. FIELD AND POOL, OR WILDCAT McArthur River Field !i. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 5, TBN, R13W,' SM I~. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MON'I'H, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACl[ED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. TRADING BAY UNIT WELL D'-24A WO - WATER INJECTOR - DECEMBER, 1976 TD as of 12-31-.76 13,600'TD 13,526'PBTD 7" Inr from 8433' - 13,600' 12-10-76 - 12-20-76 RU over 'D-24A, 12-10-76. Mi lle~l over 7" pkr. RIH w/ 7" ret BP & pkr. Set BP @ 12,6461 & pkr @ 8450'. Press up to 4000 psi. Pumped 2 BPM. Press tested 7I' lnr & 9-5/8" csg to 3500 psi. Found hole @ 5164' & obstruction @ 5300'. Pumped into hole @ 4 BPM w/ 1900 psi. Rolled csg from 5297' - 5300' w/ 8½" Tri-State csg roller. 12-21-76 - 12-31-76 Ran & cmtd 201 jts 7", 29#, N-80, Butt csg from 8433' - surface. Drld out cmt & float (8355') & CO hole to top of BP ~ 8535'. Press tested csg to 3500 psi--held OK. Dry tested lnr tie back-- held OK. Drld out' BP @ 8535' & CO to PBTD. RIH w/ 7" ret pkr w/ 38' 3½" stinger & set ~ 13,464'. Acidized Bench 6 perfs. Final inj rate 1.2 BPM @ 4000 psi. Tied into wtr inj system & inj 3000 bbls in 6 hrs @ 3800 psi. Re-set pkr @ 12,347'. Ran spinner survey. Marathon Oil Company - ~ub-Operator 14. i hereby certify that the~fc~regoing is tr~e and correct yi'-" : .... '=~- Dist Drlg Supt ;~,G~EI~~': )'/t~'/*A~ .~[. ~ ,~(' TITLE. ' ' .. . DATE ~'/] ~ ~7 .[/ R {:~:!Je6d~'~ - : .... ' ' ~OT~-R~rt on thi~ form is r~quir~ lot ~a~h ~$1~nd~r month, r~gardle~ ot th~ ~atua of op~r~tiom, snd mu~t b~ {il~d in ~li~aI~ with tho ~ii ~n~ ~ ~on~r~ation :ommittm by th~ l~th o{ th~ ~:~ing month.unl~ oth~rwim ¥orm 10-403 REV. 1o10-73 sUbmlt"lntentlons" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) O,L !--'1 GAs I---I WELLL--.I WELL L..J OTHER Water Injection Well 2. NAME OF OPERATOR Un i on 0 i ] Company of. Ca ] [ fern i a. ,? 3. ADDRr:-~S OF OPERATOR P. 0. Box 6247,.An.chorage, AK 99510 4. LOCATION OF WELL At so trace 755'FSL, 1213'P~/L, Conductor #12, Leg A-l, Dolly Varden Platform, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-133-20225-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18729 7. IF' INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-24A (33-5) 10. FIELD AND POOL, OR WILDCAT McArthur River Fie]d-Hemlock :11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) 1597' FSL, 4582' FWL Sec..5, T8N, R13W, SM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OP-~RA1 ION5 (Clearly state ail pertinent details, and cjive partincnt dates, including estimated date of startirlg any proposed work. SUrveys on D-24A indicate we have leaks in the tubing~ at about 500' and 2100'. The flow meter shows about 4500 BPD leaving the tubing at these areas. A temperature survey indicates the water leaving the casing at the liner lap and being dispersed in several zones between 8500' and 11,000'. We plan topull the tubing & test the 9-5/8" casing with a packer through pressure tests. A test of the 7" liner through the use of a seal assembly in the 7" permanent packer at 12,499"and an RTTS packer through pressure testing. We plan to acidize Bench 6 to improve the injectivity using 3700 gallons 12/10 MCA and 3500 gallons of HC1. The acid will be spotted and displaced through the use of a packer. Bench 6 perforations are from 13,466' to 13,526I. If the casing tests OK, a 9-5/8" permanent packer will be set above the liner lap. A dual seal assemb,y wi,1 be run to pack off both the 7" and 9-5/8" c r ' SEE ATTACHMENT 16. I here fy tha ng Is true and correct SIGNEI~/ ~- ..... _~ TITLE DJ,st,,. Prig. Supt. /~v/ J. K. Cai lender - (Thi~pace for State office use) CONDITION5 OF IF ANY: ,./ See Instructions On Reverse Side Sub-Operator Marathon 0il Company ~ TOU] NC/CASI NG ' $, " DEZ AlL ANC]]ORAGE DIVISION _ Well No. :]5-~'/-~ /q/_Z /P~W£~,~eA/T'~ -/<~ .Date set J No. Length From To Size Wt. Thd. Gr. R~.e. '. Cond. Remarks ~ ~ P~ 1~7 &~.~ ~o,~ ~3o.~ 7" ~ ~ ~-~a J . I cs ~ ........ , .... - , ..... .... , .... . .... ~ ' " ':" ~" ;~e~c~: ~e~L ~.v,P;=~I ~/~ l'a" ~w~ . , . .. , . , . , - . , ~ .. ~ ~//'ya ~-~ l ~-~ '". ;:% ~-~: b~ ~FF~-~-~x.-i .... __ . z _ _ ~I . . i I _ ' ~~3 ~ , .,ii ...... ., ~ K , ~ _ , [ . _ . I~ ~ ~ /~ _/ __ ...... ~~ L ~zB ) ' ~ ~ ~.~ ): . - ....... ._1'. ~ ..... ~ .......... ~~ - ~,,~-~! .... ~-''~ .... ' ........ ~,-~1.. -- . ...... _ ........ I...... ,,..... I....~'.. .~"-' .~. DE'IAIL · · ANCIIORA(;E D1V! SION .o Well No. ~_S~ -' " Date _ .. . · · · · · · · /-.2-77 · Set No. Len~.'th From To Size Wt. Thd. Gr. R~.e. '~': Cond. Rema ?ks Union Oil and Gas Division: Western Region LJnion Oil Compan~ California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 Dear Mr. Hamilton: union .July 26, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 RE: TBUS D-8 Rd. j~-l~]~J S D- 24 ~~ -TBUS D:2§ ........... I REV I CONFER: FILE:. Enclosed for your files are two (2) copies of the Well History for TBUS D-8 Rd., two (2) copies of the Sundry Notice & Reports on Wells for TBus D-24 A and two (2) copies each of the Well History, Surveys and Well Comple- tion Report for TBUS D-28, Doily Varden Platform, Cook Inlet, Alaska. Very truly yours, Callender District Drlg. Supt. sk Encl. (6) cc: Marathon oil Co. Atlantic Richfield Co. Amoco Production Co/ Skelly Oil Co. Phillips Petroleum Standard Oil Co. USGS-Rodney Smith Pedro Denton (Completion Report D-28) DIVISION OF OIL ^T~P GAS ANCI'I ():"' ,,k (',', '~ Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL]] OTHER Water Injection Well 2. NAME OF OPERATOR Union Oil Company~ of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue 4. LOCATION OF WELL Atsurface 755.3 ' FSL, & 1213.5' FWL Conductor 912 A-1 Leg, Dolly Varden, Section 6, T8N R13W SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106' KB CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE ~. LEASE DESiGNATiON ANO S~ ADL- 18 7 2 9 8. UNIT, FARM OR LEASE NAM Trading Bay Unit D-24A (33-5) 10, FIELD AND POOL, OR WILl McArthur River Hemloc~ 11. SEC.,T., R.,M.,{BOTTOMHOLEOBJECTIVE) 1597' N of S Line, 4581.72' E of W., Sec. 5, T8N R13W SM 12. PERMIT NO. 14. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING sHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple.completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The objective is to improve water injection into Bench 6 by perforating (13466' to 13526') RDL Log, with two holes per foot using Dresser Atlas 2-1/2" Bar gun. The well will be perforated while flowing back to obtain maximum cleanup of perforations. Current injection into the well is 10,000 BWPD at 3750 PSIG; an injectivity of 2.67 B/D/PSI. The work was accomplished on 7/18/76. Injection after perforating was 11,200 BWPD at 3800 PSIG -- an injectivity increase of 2.95 B/D/PSI. D~ISlON OF OIL A,"'J,D GAS ANCHO,%AG~.~ TITLE Drlg. Superintendent DATE 16. I hereby cel SIGNI (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side [ ~Approved Copy Returned , I /llll TUBING/CASING DE TAIL ANCtlORAGE DIVISION Set No. Length From To Size Wt. Thd. Gr. Rge. Cond. Remarks - 8.97 R.4: :--- ~.44!-- --/'l~,d -t;,~ S- ,/~,_.~,,,,o ~. - t0.!0 ~.44/d._7&4:51F~-r. "7"or Zr-~r.o-~:,,..w~<d,°~.~ ..... - ._4.3G g45/x~'__ &4:5.:5-,_.~. -v'/~ v"~,5% "/4 ,,_,,,:,_.. I¥,.,.o,,~. . ......... - 0.~'_'~ g4~5---- ~,45r=,~-~X--O S~ ~ ,~0o x X'-L,~ ~ o,:,~,,.,') . 3~ 8~ "2:~ /Zg ~cD57W · 2B _ z , 8z.3~. _~_o/A~:~-~-~ v~ - - 2.50 /3,5q7 '7'1,.~ ' .i ..... I , · ' .~_ . ......... · · · _ , , .... I .............. · ........ ~ .... t , , · .... ....... . ...... ~ .,. ·.. " I'. . ......... i' --!'. " ' ...... -'' · ' '~ t ........ , , , . ~, -- , . , ~ ..... ............ ]~ ~ .... · , , ~ .,~ I' ' I ' · Union Oil and Gas F~ion: Western Region Union Oil Company c~' ~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 unl®n J.une 4, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99503 RE: TBUS G-23 (23-33) TBUS G-21 (21-33) TBUS G-22 (12-32) TBUS D-24 (33-5) Dear Mr. Marshall: Listed below are the enclosed reports required for each of the above captioned wells. TBUS G-23 (23-33) TBUS G-21 (21-33) rBtJs G-22 (12-32) TBUS D-24A (33-5) Form P-4 Monthly Report Form 10-403 Sundry Notice Form P-4 Monthly Report Form 10-403 Sundry Notice Form P-4 Monthly Report Form P-7 Completion Report Well History Directional Survey sk Encl. cc: Marathon Atlantic Richfield Amoco Production Phillips Petroleum Skelly Oil Standard Oil Rodney Smith - USGS V e~% truly ~¥~ur s, David A. Johnson Drilling Engineer OIL AND GAS CONSERVATION COMMITTEE ' WELL COMPLETION OR RECOIviPLETI m):L-18729 WELL WELL DRY [] Other Hem!.ock Water IF IND17~q. ALLO'i~rEE OR TRIBE TYPE OF COMPLETION: Injection NEW ~-~ WOnK ~1 WELI, _ OYER 2. NAME OF OPERATOR * Union 0il Company of California . 3. ADDRESS OF OPERATOR Box 6247 Anchorage~ Alaska 99~02 4. LOCATION OF WELL (Report lodation clearly and in accordance with any State requirements)* ~tsu~ace 755'N & 1214' E of the SW corner, Sec. 6, TaN, R13W, SM-Conductor 12 Leg A-1 At top prod. interval reported below' Hemlock Zone: 12,695' MD 9,518' T~D At total depth Hemlock Zone: 13,600' MD 10,150' TVD, Distance out 7,789' @ Na0°E rradinm Bay Unit g. WE~L N~. - .D-2,4A (33-S) ~o. ~z~ ~a~D ~OOL. OR WlUOC~T McArthur R. Field, Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 2230'N & 560' W of SE corner Sec. 5, TaN, R13W, SM 12. P~q~IVIIT iNTO. 74-64 t DRILLED BY is. TOTAL DEPTH, NLD & TVDII9. PLUG,'B~CK AVID & '1~V~,',',',',',',',',20, ~ 1VUJLTI~'LE CO~L,, 21. INTERVALS 13,600 ~ / ~ /Z~'Z~! ~ow~' ~o~, ~oo~ ~,~,.~ ~oo,,~ lO:l 5d tvn / =;v33- -T~ todq°s / - - All - ~. PRODUCING !N~RVAL($), OF ~IS CO~P~TIo~ToP,"BO~O~, NA~E (~ AND ~), , 23. %VASsuRvEyDIRE~ONAL~ADE Hemlock: 12,570 ~ 9,430' TVD ~ Yes 13,516 ~.10,093' TVD , ~ 24, TYPE ELECTRIC AND OTHt~, LOGS RUN Compensated Neutron FDL, Cementing Bond Log, Formation Tester, In~ection ,Profile Lo~ 28. pEI{FO1R.ATiONS OPF-2q TO PRODUCI~ION Hemlock- 12695-12705 12753-12864 13033-13216 13259-13451 CASING RECORD (Report all strings'set in well) 13-3/8" 61 "/ J-55 ! 2.000i ' i17-1/p,, 185 sx "g" cut I 9-518" 47# '/17-80 147~0/9~00'/12-1/4"/ 1ooo s:~ "0"/;L35 sx "c" wl/4z 9-5/8" 47# /r- zo17600/xz,oo 12-1/4"[ Gel & 330 sx G nmat 2nd L~.~ ' 1~5 ~x "G" w/A% Gel. 150 ~x ~G" ne~t cut s,z. -t I s,= t See A~achm~nt #1 ' m e~ ~ ~-!/2 lO to 8,326" 7" / 8,432' 1~,600' [~~ nea~ 2-]/~ ~ ~n12533 . 12.5qq' (interval, size and number) 29. -ACID, ~~'~~ ~~,~' D~i 1NT~V.~ (MD) ~ AMOUNE 2~D I'2!ND OF M~IEP2AL US~ .2~753'-12~864' ~200"~ 2-1/2%HC1+800 gal 13,259'-13,451' ~5800~ ~/2%~C1+9600gal 13486-13516 1~, 456 ' -13.516 ' ~000 g~ 2-1/22 30. DATE FIRST PI%ODUCTION 3-11-75 PRODUCTION Tn ~e£~ ~ nn ~ODUCT1ON ME'ii{OD (Flowh~g, ga~-~ft, pu~p[n-g----size and type of pump) Water-In ~ e ct ion DATE OF TEST, IHOUSS TF. STD ICI*tO-'CE SIZE IPROD'N FOR I JTE~T i~iOtLIOD 4-2-75 24 ~' FLOW. TUBING ICASma PR~SURE [CAb~~ OI~BBL. I~S. I ,t24'HOUR R~ [ -'4300 psi 31. DISPOSITIONOF O~S (Sold, used for ~ueI, vented, etc.)' 32. LIST OF ATTACHMENTS V/ELL STATUS (Producing or shut-in) ater Ingection oIL--BDL. G,~S--iV~CF, W/~'ri'EI-~'-BBL'I ~AS-OIL IL%TIO [ - i - Is,o3x I - GA~-t~CF. WA'r~BBL. ] OIL GRAVITY-~I (CO~.) TEST WITNESSED BY L~mer Record .23. I hereby certify that the foregoJ4~g and attached information is complete and correct a. determined fromr~v~'~bl~'~ee~d" ~' ~ suot.. ,,,,.. j:; ' ,Ti'm '1~,' C ::, I .I ,= r, H ,:, ',,. _/! "'- I , ,~ , · ' *(See Instructions and Spaces [or Additional Data on Reverse Side) DIV:$1ON OF OIL AND · Marathon Oil Company - Sub-operator ANCHORAGE iNSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lan:Is and leases in Alaska. Item: l&: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven in other spaces on this form and in any attachments. Items ]0, an~i '~]:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p, cJuci~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackiitional data pertinent to such interval. Item'S6: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMM.~RY OP PORMATION TESTS INCLUDING INTERVAL TESTED. PHE~U~E DAT~ ~ ~OV~I~ OF OIL, GAS. WAT~ AND MUD 'Formation Interval Tests Schlumberger ...... {~s, o~,~v~ v~. 4-4-75 7 tests 1) 13485 FSIP 4550 Rec 9050 cc water 2) 12699 3850 . 10100 cc ~aCer D Zone 5,638 4,416 3) 12963 ~625 8500 ec mud ~) 13~11 ~175 5900 cc water G Zone 11,390 8,596 6100 ce mud 5) 13101 ~650 10100 cc mud Hemlock 12,688 9,5~3 6) 12903 3325 10200 cc water 7) 12763 3050 100 cc waeer ~ 13,580 10,138 None D~TE MARATHON., OIL COMPA, t~IY HISTORY OF OIL OR GAS WELL FIELD McArthur R~ver WELL NO. 24-A STATE Alaska BLOCK Surface: LEASEDolly Varden Platform~ Trading SEC. 6 TWP. 8N PARISH Bay Unit COUNTY Kenai Peninsula Borough ~B · , ELEV. 106 ' MSL MEASUREMENTS TAKEN FROM R._ iBW i s~ 'TOP OF Oil STRING ~ ELEV ~ .TOP OF ROTARY TABLE , ELEV.~ HISTORY PREPARED BYL Dean Wolstenholm TITLE Clerk GRD. OR MAT ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 12-21 12-22 12-23 12-24 12-25 12-26 12-27 12-28 12-29 12-30 12-33 1_975 1-1 1-2 1-3 Reports as of 7:00AM for previous 24 hrs activity. FIRST REPORT. Off loaded pipe racks & mud tanks - to move rig from B-1 leg room to A-1 leg room. Finished off loading rig equipment. Moved rig from leg room B-1 to leg room A-1. Unable to load pipe racks back onto platform due to high wind. Started rigging up over conduction ~12. Finished rigging up over Well 24A. Off loaded all mud tanks & pipe racks off boat. Rigging up. Continued to rig up. Shut down for Christmas. Shut down for Christmas Transferred mud to rig pits. Connected up steam& water lines, PU 6" bit, 12 jts 3-1/2" pipe & 5" DP. RIH to 2225'. Could not pass thru. Found salt water in surface pipe. PBTD 2,225' POH & laid down 3-1/2" DP. PU4" x 7-1/2" swedge & lO-l/2" swedge, 1-8" DC, bumper sub, oil jars, ll-8" DC, accelerator weight 50,000~ & 58 jts 5" DP, & surface jars. RIH to 2,225' swedged on'csg B-l/2 hrs. POH & laid down 25 jts crooked 5" DP. Left 7-1/2" swedge in hole.* Laid down lO-l/2" swedge &'tools & DCs. RIH w/5" DP open-ended to 2215', circ'd & cond. mud. Building viscosity. *Note: Pin on tool jt between 7-1/2" swege & lO-l/2" swedge parted leaving 4" x 7-1/2" swedge in hole. PBTD 2,225' Milled on 13-3/8" 4 hrs. Circ'd to build mut weight & viscosity· POH. RU Dresser-Atlas & ran CBL to 2,225'. Log shows good bonding. Rigged down Dresser-Atlas. PU Kelly & installed motor on Kelly Spinner. Started picking up tools, 13-3/8" sec mill. RIH to 2100', attempted to find collar. Stsa-ted mill- ing @ 2100'. PBTD 2,225' - Milled window from 2100' to 2110'. POH for short trip & stopped @ 1982'. Worked tools free. RIH back to 2,110'. Circ & cond mud. PO}]. Found wear bushing on jars had backed off leaving ll-1/2" guide (2') in hole. RIH w/bit & pushed guide to 2,221'. PBTD 2,225' - Circ & cond mud @ 2221'. POH. Waited on tools due to b~d weather. RIH w/sec mill w/gui, de to 2100'. Remilled from 2100' to 2110'. Mill would not stay on shoulder of csg. POH. Blades on mill duld., apparently bad set of blades. RIH w/n~ll. Circ & cond mud to build w;.scosity. PBTD 2,225' -, Continued circulating & building viscosity. Attempted to mill casing @ 2,110'. Unable to mill - POH & blades broken off. RIH w/milling tool & stabilizer, Mi~ed 13-3/8 csg from 2110' to 2122' Circ hole clean & POH. PBT~ 2,2~5' - Finished changing blades & RIH. Started milling @ 2118' & broke blades. POt{. RiH w/]mill & milled 2118' to 2122'. PO]{ & changed blades. RI]-] & milled from 2118' to o~o~.-, ~..-,~ . Circ mud & tOH. ~TD 2,225' ,~lled ~om 2118' to 212,'. Blades.broke RIH w/mill & reamed from 2100- to 2120'. ~H, Ch~ged b].ades DiV',SION '-~ "I~ ~,ND GAS ~Histo~y of Trading Bay Unit ,~11 #D-24~continued 1-4 TD 2,126' - Milled from 2109' to 2120'. POH & changed blades. RIH & milled from 2120' to 212.4'. POH & ~ehanged blades. RIH & milled from 2124' to' 2126'. 1-5 1-6 TD 2,152' - Finished milling ta 2130'. POH. Cut & slipped drlg line. Layed down Tri-State sec mill. PU Servco sec mill & RIH. Milled from 2130' to 2152'. Circ & cond mud. TD 2,180' - Changed BHA & blades on mill. Milled from 2152' to 2180'. Circ & cond mud. Window from 21OO' to 2180'. 1-7 TD 2,180' - Finished circ hole clean. POH & laid down BHA. RIH open-ended to 2,191'. Circ &cond mud. Spotted 200 sxs neat cmt w/.~O~ sand, 16.6~/gal slurry from 2191' to 1980'. Cmt in place @ 3 PM. Pulled up to 1909' & reversed out - no cmt. Circ &cond mud. I%;l]ed i stand. Pressured 13-3/8" csg to 600 psi. - bled to 500 psi. & held for 6. hrs. Released press. & POH. Changed rubber in 1-8 TD 2,180' - WOC. Tested Hydril to 1500 psi - OK. Thawed out mud lines & repaired steam boiler. Pulled wear bushing. Tested BOPE to 3000 psi - OK. Installed wear bushing. RIH w/bit to 1900'. Washed to 1960'. Drld cmt to 2000'. Circ & cond mud. Drld hard cmt to 2081'. 1-9 TD 2,190' - Drilled hard cement to 2,110'. Circ. & cond. mud. POH. RIH with Dyna-drill with 2° bent sub. Oriented @ 2,110' - high & to the left. Drilled from 2,110' to 2,190'. POH. Laid down Dyna-~rill. PU BHA & RIH. 1-10 TD 2,563' - Finished in hole. Washed & reamed from 2,110' to 2,190'. Drilled to 2,249' & surveyed. Drld to 2,407' & surveyed. Drld to 2,501' & surveyed. Drld to 2,563' & surveyed. POH. 1-11 TD 3.,120' - Changed BHA & RIH. Drld from 2563' to 3091'. POH to change BHA. RIH & drld to 3120'. 1-12 TD 3,980' - Drld & surveyed 'from 3120' to 3980'. 1~13 TD 4,790' - Drld from 3989' to 4135'. Surveyed. POH for new bit & changed BHA. RIH to 2100'. Cut & slipped ~drlg line. RtH. Drld & surveyed to 4790'. 1-14 TD 5,130' - Surveyed @ 4790'. Drld to 4803'. Viscosity too high to drill - no drill wtr due to extreme ice condition limiting boat operations. Circ & cond mud - cleaned shale shakers & return lines. POH to 2100' clean shale tank. Circ & cond mud using filtered Inlet wtr. RIH & drld to 5052' & surveyed. Drld to 5130'. NOTE: Converting mud to polymer type mud. 1-15 TD 5,850' - Drl'd to 5,225'. Surveyed & POH for bit. RIH & drld & surveyed to 5,850'. 1-16 TD 6,190' - Dr!d to 5,873'. Tripped for new bit. Drld from 5873' to 6124'. Surveyed & POH. Changed bit & RIH. Drld to 6190'. 1-17 TD 6,730' - Drld to 6300' - repaired Kelly spinner. Drld to 6580', surveyed & tripped for new bit. Drld to 6730'. 1-18 TD 6,925' - Drld from 6730' to 6853'. Surveyed, POH to change BHA. Blade stabilizer hung on 13-3/8" csg @ 2100'. Worked stab'ilizer into csg by rota- tion. POH. Lost i blade of stabilizer in hole. RIH w/12-1/4" tapered mill. Dressed shoe jnt & ran blade stabilizer below 13-3/8" & it would not come into pipe until rotated into right position. Redressed shoe w/mill. POH. RIH w/drlg assy. Drlg ahead. 1-19 TD 7,228' - Drld & surveyed bo. 7228'. Tripping for new bit. 1-20 TD 7,603' - Finished trip. Drld & surveyed to 7603'. 1-21 TD 7,950' - Drld to 7613'. POH for bit & BHA change. RIH to 2100'. Cut & slipped drlg line. RIH. Drld & surveyed to 7950'. 1-22 TD 8,150' - Drld to 7989', surveyed & POH. Tested BOPE - OK. Drld to 8150'. 1-23 TD 8,411' - Drld to 8194'., surveyed & POH. Changed out 2 roller reamers. RIH & drld to 8411'. 1-24 TD 8,491' -.Drld to 8463', surveyed & POH. RIH w/Dyna-drill & 2° bent sub. Oriented Dyna-drill. Drtd to 8491'. 1-25 TD 8,612' - Finished out of hole. Layed down Dyna-drill. RIH with dri].ling · assy. Re~ed from 8463' to'_8491~. Drld~-to 8532 & surveyed Drld to 8593' & stu-veyed. Drld to 86~12~'. poW..- ~-- ;~'-. '~'-' :~".' ' ~-~-. .~ % - History of Trading Bay .Uni.t Well #D-24A continued. 1-26 TD 8,862' - Finished trip to change out BHA, Drld to 8862'. 1-27 TD 9,~4' - Drld & surveyed to. 90OB'. POH. Lost pin out of roller reamer (l' long x 1½" OD). RIH with bit & drilling assembly and found pin on btm. Drld one ft. POH. 1-28 TD 9,0B5' - Changed out BHA. RIH w/ll½" OD magnet w/slotted skirt, Circ. cond. mud @ 8~950'. Washed down over junk. POH. Recov'd roller reamer pin 1.~'' D w/drlg assy & drld to 9,035' (12"lon~x ~ 0 ). ~H · 1-29 1-3o 1-31 2-1 TD 9,241' - Drld to 9241', surveyed & POH. TD 9,505' - Finished trip for new bit. Slipped & cut drlg line. Drld to 9,505'. Circ prior to trip. TD 9,505' - POH & laid down 3 - 8" drill collars. Left one roller reamer pin in hole. RIH w/ll~" magnet w/skirt. Circ. mud. Fished for pin. POH-- ~o recovery. RIH w/12~" bit & chased pin to btm. Started out of hole w/bit. TD 9,559' - Finished out of hole. RIH w/magnet circ above fish. Worked over fish @ 9505'. POH - recovered approx. 1/4 of pin. Changed BHA. Cut & slipped drlg line. RIH. Drld on junk for l½ hr. Drld to 9559'. 2-2 2-3 2-4 2-5 TD 9,722' - Drld to 9571', dropped survey & POH. Changed out roller reamer & bit. RIH. I~ld to 9722', dropped su.mrey & t:~H. TD 9,821' - Finished out of hole. Changed BHA. RIH & reamed from 9694' to 9722'. Drld to 9821' & dropped survey. Circ mud while surveying. Pipe stuck while surveying & circ. Pipe stuck @ 2:30 AM, 2/3/75, w/bit @ 9766'. TD 9,821' - Worked stuck pipe @ 9766'. Spotted 34 BBLS diesel oil mixed w/1 BBL Drileze 405 around btm thole assy, leaving l0 BBLS in pipe, moving i BBL every 30 min. RU Dia-Log @ 6 PM & ran free point. Pipe free to 8820'. POH w/Dia-Log. Circ & worked pipe. RIH w/Dia-Log & string shot. Had free point of 34 @ 8852'. Attempted back-off @ 8852'. Pipe backed off @ 8510'. Screwed back into'~fish & "worked pipe. Made ~up string shot ~2. Ran back to 8852' & attempted to back off @ 8852' ~ (btm of daily jars) & pipe backed off @ 310'. Screwed back into fish & worked pipe. TD 9,821' - Finished out of hole w/Dia-Log & rigged down unit. POH with DP & layed do~a~ 9 jts grade "E" pipe. Recovered all DP & 7 its HW. Top fish @ 8825'. RIH w/12-1/4" bit & BHA to 2100'. Circ & cond mud. Lowering weight from 10.H to lO.1. RIH to 4100'. Circ & cond mud. 2-6 2-7 2-8 TD 9,821' - Finished trip into 6100'. Circ & cond mud. Made short trip to shoe. RIH to 7200'. Circ& cond mud. RIH to 8740'. Circ & cond mud. Had tight & rough hole from 8740' to 8765'. BHA was attempting to stick between 8740' & 8765'. POH - measuring out. Worked pipe thru tight place @ 8650'. TD 9,821' - Finished out of hole & layed down BHA. Pulled wear bushing. RU & ran 9-5/8" casing: 214 its, 47#, N-80 & P-110 with shoe @ 8627' & plug catcher @ 8546'. Circ & cond mud. TD 9,821' - Cmt'd 9Z5/8' csg w/20 BBLS wtr ahead .~f 1880 sxs C1 "G" cmt w/h% GRL, 1~ D-31, & 0.25 R-5 (14~ slurry) followed w/300 sxs C1 "G" neat cmt w/0.8% D-31, & 0.2% R-5 (15.5~ slurry). Dropped plug followed w/10 BBLS wtr & 626 BBL$ mud. Plug do~en w/1800 psi - pressured to 2500 psi - OK. Bled off press. Plug down @ 8:30 AM, 2/7/75. Raised BOPE & installed slips. Installed tbg spool & tested to 3000 psi - OK. RU BOPE & tested to 3000 psi. - OK. Hydrtl to 1500 psi - OK. Installed wear bushing. Started laying down 8" DC. TD 9,821', PBTD 8,825' - RIH w/8-1/2" bit & BHA. Washed cat from 8530' to 8545'. Drld float collar @ 8545'. Drld soft cmt to 8620'. Circ & cond mud. Tested csg to 3000 psi. - OK. Drld hard cmt to 8626'. Drld shoe @ 8626', & hard cmt to 8629'. Washed & reamed to 8825' - top of fish. Circ & cond hud. POH. Started in hole open-ended to set.plug. 2-10 PBTD 8,627' - Finished in hole open-ended to 8826'. Circ & cond mud. RU & spot- ted 180 sxs neat cat w/5% sand, 0.8% D-31, & 0.2% R-5 from 8826' to 8536'. POH to 8536' & reversed out & recovered 5 BBLS wtr & 4 BBLS cmt. Circ & cond 'mud. POH. RIH w/8-1/2" bit & BHA to 8500' installing pipe rubbers. Circ &cond hud. Plug in pla~e @ 12 noon. 2-11 · PBTD 8,441' - WOC. Washed cmt to 8608'. Drld soft cmt to 8673'. Drld cmt to 8723' w/last lO' hard. Circ& cond mud. POH. RIH open-ended & spotted cmt, 150 sxs neat~ 20~. s~and,O.8~ 'D-31, 0.~2~ R--5~,~ 1D.2.// slurry, from 8723~ to 8441'. History of Tradin~g Bay. Unit Well #D-24A continue~: 2-11 POH to 8441' & reversed out approx 7 BBLS cmt. Circ & cond mud. POH to 8347' & pressured cmtplug to lOOOpsi. Plug in place @ 4:15 AM. · 2-12 PBTD 8,490' - WOC holding 1000 psi back press on cmt plug. Released press @ 4:BO PM, 2/11/75. Tagged' plug @ 8460'. POH & RIH w/clean-out BHA. Circ & drld cmt from 8460' to 8~90' - i min/ft @ 25,0OO~ - firm cmt. TD 8,6~5' - Drld cmt to 8645'. Circ& cond mud. POH. Changed BHA& RIHw/dyna- drill w/2-1/2° bent sub. Oriented tool & survey tool hung in bent sub. Pulled sand line in two @ BOO'. Pulled ~ stands DP & tied on to sand line. Sand line parted @ 500'. Pulled 9 stands & attempting to pull tools. 2-14 TD 8,645' - ~l~ed survey tool loose & spliced sand line. POH survey tool - left lower sec in DP. POH w/DP, Redressed mue shoe sub. RIH. PU Kelly & thawed out same. Orienting tool. 2-15 TD 8,815' - Finished orienting tool. Drld to 8675'. Surveyed. Drld to 8727' Sdrveyed & POH. Changed BHA & RIH. Reamed from 8645' to 8727'. Drld to 88!5;. 2-16 TD 9,050' - Drld to 8868'. Circ & surveyed. Drld'to 8900'. POH~for bit' ~hange. changed BHA& RIH. Drld to 8990'· Circ & surveyed. Drld to~9050'. 2-17 TD 9,260' - Drld & surveyed to 9i48'. POH & changed BHA. RIH & drld to 9260'. 2-18 TD 9,66~' - Drld & surveyed to 9,664'. 2-19 TD 9,845' - Circ & surveyed. POH. Changed BHA & bit. RIH to 8600'. Changed weight indicator & spliced sand line. RIH to 9664'. Drld to 9785'. Surveyed. Dr id to 9845'. 2-20 TD IO,OBO' - Drld to 9880' Surveyed & POH. Changed BHA RIH Drld to 10,004' · · · surveyed, plugged 1 jet in bit. POH & changed BHA. RIH &. drld to 10,030'. 2-21 TD 10,212' Drld to 10,102'. Surveyed. Drld to 10,212' & ran survey. Reran survey. Dropped survey & POH. Stand back BHA. RIH open-ended to set plug -circ & cond mud. Ail three surveys @ 10,212' were same 32°. Necessary to plug back due to drop in angle. Will plug back to approximately 8980'. 2-22 TD 10,212' - Circ & cond mud. RU & spotted 100 .sxs C1 "G" cmt, lOd~ sand, 0.8% D-31, 0.2% R-5 from 9200' to 8960'. POH to 8960' & reversed out ~ BBLS cmt. .POH to 8600'. Circ & cond mud· Plug in place @ 9:15 AM, 2/21/75. POH. Tested BOPE - OK. RIH w/8-1/2:? bit. 2-23 TD 10,212', PBTD 8689' .- Cleaned out to hard cmt @ 9065'. Ran survey - 37°, N?7E. POH. RIH open-ended W/DP to 9065'. Spotted :30 sxs C1 "G" cmt, l0 sxs sand, l~ D-31, O.H~0 R-5, 16.5~ ~lurry from 9065' to 8689'. POH to 8595'. Circ & cond mud. Plug in place @ 7:15 PM, 2/22/75. 2-24 PBTD 8823' - Circ & cond mud. POH. RIHw/BHA to 8600'. Circ & WOC. Washed down to 8823' - hard cmt. Circ hole clean. Surveyed - 41°. POH. PU Dyna-drill & RIH. Started rigging up steering tool on WL. 2-25 TD 8,988' (8,823' KOP) - Finished rigging up to rub steering tooll & RIH w/tool. Oriented tool to right & up. Drld from 8823' to 8881'. Surveyed & made com~ection - survey no good. Drld to 8909'. Surveyed - no good. POH. Layed do~m steering tools & Dyna-drill. RIH w/BHA. Drld from 8909' to 8915'. Circ & surveyed. Drld to 8978'. Circ & surveyed. Drld to 8988'. 2-26 TD 9,143' - Drld to 9045'. Surveyed & POH. Changed BHA & RIH. DC power failure. Drld to 9143'. 2-27 TD 9,343' - Drld to 9218'. Surveyed & POH. Slipped & cut dmlg line. RIH & drld to 9343'. 2-28 TD 9,503' - Drld to 9361'. Surveyed. POH & Changed BH^. Installed new bearing in cathead. RIH & drld to 9503'. Ran survey - misrun. Rerunning survey. 3-1 TD 9,765' - Reran survey. Drld to 9538'. Surveyed & tripped for new bit. Hole in good condition. Drld to 9687'. Surveyed. Drld to 9765'. Surveyed & I~H. TD 9,925' - Finished POH. Tripped for new bit. Changed BHA. Cut drlg line. RIH. Drld to 9863'. Survyed. Drld to 9925-~. Surveyed. History of TradingBay~.Unit Well D-2~A continued: · 3-3 TD 10,219' - POH @ 9925' to change bit. RIHand drld to lO,030'.'Surveyed. Drld to 10,156', surveyed. Drld to 10,219'. Survyed. POH. e TD 10,370' - Finished POH & changed BHA. RIH. and drld to 10,277.'. Surveyed. Drld to 10,370'. 3-5 TD 10,5OO' - Drld from 10,370' to 10,377'. Surveyed. POH. Changed BHA, RIH, checked survey. Drld to 10,439'. Surveyed. Drld to 10,5OO'. 3-6 3-7 TD 10',842' - Drld to 10,565'. Surveyed. Drld to 10,692'. Surveyed. Drld to 10,816'. Surveyed. POH. Rib w/new bit. % TD 11,036' - Repaired mud pump. Drld to 10,943'. Surveyed.. Drld to 11,036'. Surveyed. POH. Changed BHA. RIH. 3-8 TD 11,225' - RIH & drld to 11,179'. Surveyed. Drld to 11,194'. POH to change bit & BHA, RIH to shoe, cut drlg line. RIH to 11,194' & drld to 11,225'. 3-9 TD 11,307' - Drld to 11,259'. Surveyed. Drld to 11,327'. Surveyed. POH to check BHA& test BOPE. Test plug stuck in wellhead. Working on stuck plug. 3-10 TD 11,385' - Attempted to pull test plug from tree. PUBOPE & changed tbg spool, Tested tree to 3000 psi. Installed BOPE. RIH to 3000'. Had electrical problems. RIHto 11,327'. Drilling ahead. 3-11 TD 11,557' - Drld to 11,437'. Surveyed. Drled to 11,552'. POH. RIHw/new bit and drld to 11,557'. 3-12 TD 11,758' - Drld & surveyed from 11,557' to 11,758'. POH. Slipped & cut drlg line. Down 1½hrs repairing sand line. 3-13 TD ll,910' - Finished repairing sand line. RIH & drld to 11,821'. Survyed. Drld to ll,910'. 3-1~ TD. 12,037' -~Drld to 11,9~7'. Surveyed. Drld to 11,972'. Tripped for new bit. Drld to 12,037'. 3-15 TD 12,220' - Drld to 12,168'. Surveyed. Drld to 12,205'. Tripped for new bit. Drld to 12,220'. 3-16 TD 12,524' - Drld to 12,387'. Surveyed. Drld to l2,SBk'. Surveyed. POH. 3-17 TD 12,720' - Finished out of hole. RIHw/new bit. Slipped & cut drlg line. Drld to 12,720'. POH looking for wash-out. 3-18 TD 12,885'- Finished out of hole. Found wash-out @ 1162' , 6' above pin. RIH. Drld to 12,863'. Surveyed. Drld to 12,885'. 3-19 TD 12,949', Drld to 12,891'. POH. Slipped & cut drlg line. RIH. Drld to 12,949'. Surveyed. POH. RIH. 3-20 TD 13,175' - Finished in hole to 8000'. Had electrical failure. Finished in hole & drld to 13,175'. 3-21 TD 13,3~0' - Drld to 13,181'. Dropped survey & POH. RIH. Drld to 13,340'. 3-22 TD 13,525' - Drld to 13,~20'. Surveyed. Tripped for new bit. Drld to 13,525'. 3-23 TD 13,600' - Drld to 13,600' TD. Circ & cond mud. Made short trip to 8600,. Circ & ;cond mud. POH. RU Schlumberger & rmn DIL logging tools. Tools stop- ped @ 9100'. Pulled tools out of hole. RIHw/bit to 13,600'. No obstruction @ 9100'. Circ & cond mud @ 13,600'. 3'24 TD 13,600' - Finished conditioning hole for logging. POH. RU Schlumberger & ran DIL logging tools. Tools stopped @ 9134'. POH. Changed guide on tools & RIH. Tools stopped @ 9115'. POH. Changed guide on tools & RIH. Tools stopped @ 9115'. PO}{ & rigged down Schlumberger. RIH w/bit to 13,600' - no obstruct- ion @ 9100' - 9150'. Circ& cond mud. POH. Slipped & cut drlg line. RU to run 7" liner. Started in hole w/7" liner testing collars to 500Opsi. .H. isto. r~. of Trading~ Bay uni..~t Well D-24A continued: 3-25 TD 13,600 - Finished in hole w/7", 29~, N-80 X-line csg w/TIW hanger & pkr. Liner set from 8433' to 13,600'. Circ & cond mud. Dropped ball & set TIW hanger. Rotated loose from hanger. RU to cmt. Cmt'd w/50 sxs ll#/~,al Class "G" neat ahead of 900 sxs Class "G", 15.5# slurry. Displaced w/mud. Good returns while cmtg. Bumped plug & pressured to 2500 psi. Bled off press & checks held OK. Set hanger-pkr. Pulled running tool from hanger. Rev'd out - recovered small amount of contaminated mud. Circ mud to clean pipe. POH. Cmt in place @ 10:45 PM, 3-26 TD 13,600: - Finished out of hole laying down extra 5" DP. RIH w/8-1/2" bit to top of liner @ 8433' - no cmt on top of liner. POH & layed down DCs & HW drill pipe. Started in hole w/nine 4-3/4" DCs & 6" bit on 3-1/2" & 5" DP. 3-27 TD 13,600' - Finished in hole w/6" bit. WOC til total of 40 hrs. Tagged cmt stringer @ 13,460' (5~' above float collar). Cmt drld & washed away. Drld float collar @ 13,514'. Cleaned out of 7" shoe @ 13,600' - no cmt bet~¢een float & shoe. Circ hole clean. POH. Rigged DA & running CBL/VDL/ GR logs. 3-28 TD 13,600' - Finished running CBL/VDL/GR logs. Logs indicated poor bonding & cmt had not set. RU ran gyro from 13,600; to 2,200'. RIH w/7" Halliburton cmt rtnr & set 13,585' (P.M.). Started in hole with Halliburton 9-5/8" RTTS squeeze tool. 3-'29 TD 13,600' - Finished in hole w/RTTS squeeze tool & set @ 8284'. Pressured annulus to 2000 psi. Tested liner lap to 4500 psi - OK. POH w/test tool. RU D-A & ran CBL. Log indicated better bond thru Bench ~, but remainder almost same as first log. RU Schlumberger & started running FDC Log. 3-30 TD 13,600' - Finished running Schlumberger FDC Logs. Ran CBL from 13,585' to 8~00'. Rigged down WL Unit. RIH W/Halliburton stinger for- rtnr & set into rtnr @ 13,585'. Broke down formation @ 4000 psi. Pumped into formation @ rate of 1 BPM @ 3500 psi. Squeezed 7" shoe w/150 sxs Class "G" cmt, 1% D-31, 0.4% R-5. Min. press. 3500 psi @ 1 BBL/min. & max. press. ~500 psi. Reversed out 10 sxs cmt. Circ & cond mud. 3-31 TD 13,600' - Finished circ & cond mud. POH. RU D-A & perforated for block squeeze from 12,998' to 12,993' (2 shots/ft). POH & RIH w/Halliburton rtnr & set @ 12,947' (P.M.). Circ & cond mud. Pumped into formation @ 4750 psi - ~ Max. press. 360o psi @-1/2 BPM. Reversed out 20 sxs cmt. Job complete @ AM, 3/31/75. Approx. 14 BBLS slu?ry thru perforations. 4-2 TD 13,600' - Finished~ci~ond mud. POH. RU D-k & perforated for block squeeze fron~_~~$/~~_~0~'>(WL) w/2 shots/ft w/csg gun. RIH w/Halliburton rtnr on DP & set @ 12,785'. Circ & cond mud. Broke down formation @ 5000 psi. Pumped in @ 3 BPM w/~O00 psi. Sqzd perfs 0.~% R-5. Min. press. 3000 psi @ 3 BPM. Final press 4000 psi @ 1/2 BPM. Rever- sed out ~W~LS~cm~t-~ Pumped total 2Q BBLS cmt into perfs. Circ & cond )dud to clean DP. POH. RU D-A. TD 13,600' - Finished in hole & perf'd from 12,675' to 12,680' w/2 shots/ft - csg gun. Rigged down D-A. RIH w/Halliburton cmt rtnr .'~on DP & set @ 12,595' (PM). Circ & cond mud. Broke down perfs @ ~800 psi @ 2 BPM. Squeezed perfs W/lO0 sxs class "G" cms w/l~ D-Bi & 0.4% R-5. Min. press 3500 psi, max. press 4~00 psi. Ail cmt below rtnr - 18 BBLS cmt into perfs. Reversed out. POH. RIH w/6" bit ]~ drld rtnr @ 12,595' & cmt to 12,675'J ~< TD 13,600' - Drld cmt from 12,675' to 12,746'. POH. Changed bit. Slipped & cut drlg line. RIH & drld cmt to 12,750'. RIH to 12,785' (rtnr). Drld rtnr & hard cmt to 12,8~3'. POH. TD 13,600' - Finished out of hole. RIH w/new bit to 12,8h3'. Drld cmt to 12,893'. RIH to 12,942' (rtnr). Drld rtnr & cmt to 13,O43'. RIH to 13,585'. Circ & cond mud. POH. RIH w/bit & scraper to 13,585'. Circ & cond mud. TD 13,600' - Finished ctrc& cond mud. POH. RU Schlumberger & ran WL formation test ~1 @ 13,~85.'. Flowing press - ~00 psi, shut-in press - ~-550 psi & hyd.. press - 5150 psi. P0H & recovered 100% mud filtrate. RIH w/tester #2 @ 12,699'o Flowing press - 1750 psi, shut-in press - 3850 psi, hyd. press - 4775 psi & recovered mud A emulsion (after 7 AM). Histor~ of Trading Bay .13nit Well D-24A continued: 4-6 TD 13,600' - Finished out of hole with test ~2. Ran FIT #3, 4, 5, 6, & 7.' Rigged down Schlumberger. RIH w/6" bit & scraper. Circ & cond mud. Data on FIT Schlumberger Amerada Psi. NO' Depth Bench ~ .F'~ .$.I.. ~ F. S.I.' Hyd. Recovery o. 13,485 6 4400 4550 5200 4211 4286 4990 12,699 I 1750 3850 4775 .... 4607 12,963 Lower 4500 4625 ~800 44~2 4677 4702 13,4~ 5 415o 4200 5ooo 4o42 4054 4842 13,101 4 4550 46OO 465O .... 4699 12,903 Upper 3075 3175 4975 3146 3282 4636 12,763 2 175 3O5O 4925 146 2748 468O 100% Mud Filtrate Mud ~ Emulsion 85% Mud, 15% Water 100% Water, CHL. 15,000 PPM 100% Water, CHL. 1,200 PPM TD 13,600' - Finished circ & cond mud. POH. RU D-A & perf 13,096' to 13,116' (Schlumberger CBL) Bench ~4 w/1 shot/ft w/csg gun. Rigged down D-A. RIH w/7" RTTS pkr to 13,O80'. Displaced mud in DP w/filtered Inlet wtr. Set pkr @ 13,080' Open test head .@ surface - no flow - open 1 hr, no flow. Released pkr & reversed · out wtr. RIH to 13,585'. Reversed mud out of hole w/filtered Inlet wtr. Watched for flow for BO min - no flow. Started out of h°le. 4-8 TD 13,600' - Finished out of hole. RU D-A to perforate Bench #4 with Jumbo Jet csg gun. Perf 1 hole/ft from 13,216' to 13,184', 13,184' to 13,162', 13,150' to 13,116', 13,086' to 13,056', & 13,053' to 13,033' (138 ft total). Rigged down D-A. RIH w/RTTS pkr & auxiliary valve with 7500' filtered Inlet wtr for cushion. TD 13,600' - Finished in hole w/RTTS pkr, aux. Valve & 7500' wtr cushion. Set per @ 13,O36'. Opened aux. valve - had light blow on surface. Tool open for 45 min. Released pkr & reversed out. Recovered 37 BBLS mud, emulsion, etc. RIH to 13,511'. Reversed out 18 BBLS of mud, emulsion, etc. POH to 13,036' & set pkr. RU to inject wtr. Injected @ 3700 psi - had returns on csg. Reset pkr @ 13,028' attempted to inject - had returns on annulus. Released pkr & POH. Found 2 tool joints leaking. Re.dressed pkr & RIH. 4-10 TD 13,600' - Finished in hole w/RTIS & set @ 13,028'. Pressured to 3500 psi - had returns on csg. POH to 12,464' & set pkr. Pressured to 2500 psi on annulus - returns on DP. POH. Layed down 2 Jts of 5" DP & J Jt of 3-1/2" DP that were leaking. Redressed RTTS pkr. RIH w/DP to 8550' & set pkr. Pressured .annulus to '2500 psi - OK. RIH w/pkr. Breaking & doping pipe in hole. 4-11 TD 13,600' - Finished ~n hole w/RTTS. Set pkr @ 13,028'. Pressured csg to 1250 psi. Pumped filtered Inlet wtr into Bench 4 perfs @ 1/2 BPM w/3500 psi. l%nmped 1 hr & rate declined to 1/4 BPM & annulus press increased slowly to 2300 psi & held. Stopped injection. DP press declined to 1200 psi-& annulus to 1450 psi. Bled press off-well & p,;lled 6 stds & set pkr @ 12,464'. Pressured csg to 2500 psi--no flow back on DP. RIH to 13,028'. RU Dowell & spotted 2300 gals 2-1/2% HC1 w/7~ U66, 0.5% W35, 0.4% Al30; 3200 gals 12-6 UMA w/l~'W35 & 0.4% Al30; 1092 gals 2-1/2% HC1 in DP. Set pkr @ 13,028'. Pressured csg to 1500 psi & pumped 462 gals 2-1/2% HC1 @ 1/2 BPM @ 2500 psi - annulus increased to 2500 psi. Shut down pump. Pulled pkr loose. Reversed acid to tanks. Reverse circ to clean DP. Acid did not reach perfs. At btm of pkr when communication occurred. PBTD 13,585' - Finished circ DP clean. ~_,!~l_ed 6 stands & set pkr @ 12,464'. Pressured annulus to 2500 psi - bled to 2000 psi in 30 min. Fluid falling in DP. RIH to 13,O28' & set pkr. Pressured annulus to 2500 psi - press bled off slowly w/returns on DP. Reset pkr @ 12,997' & pressured annulus to 2500 psi - press bled off slowly - fluid falling in DP. Reset @ 13,028'. Installed Hal- liburton test head & RU Dowell to acidize Bench ~4. Released pkr & spotted acid. Treated Bench #4 w/15,8OO gals 2-1/2~ HCL w/7~ U66; 0.5% W35; 0.4~ A-lB0; & 9,600 gal. 12-6 UMA w/l~ W35; 0.4~ A-lB0 & 2~00# anm~nium chloride & 1~00~ J-145. Sta~e ! - Pumped 55 BBLS 2-1/2% HCL, 76 BBLS 12-6 UMA & 31 BBLS 2-1/2% HCL. Set pkr @ 13,028'. Maintained annulus press same as DP press. Pumped 24 BBLS 2-1/2% HCL followed w/24 BBLS 2-1/2~ HCL w/6OO# dtverter @ 4 BPM @ 2300 psi. Press increased to 2500 psi when-diverter reached formation. Press declined to 2300 psi @ 4 BPM after l0 min. Stage 2 - Pumped 55 BBLS 2-1/2% HCL, 76 BBLS 12-6 UMA, 55 BBI£ 2-1/2~ HCL &. 2-~ BBLS 2-1/2% HCL w/700~ diverter. Pumped @ 2 BPM @ 1000 psi w/press increas- ing to 2000 psi. Press increased to 2900 psi @ 2 BPM when diverter reached formation. Press declined to 2750 psi (* 2 BPM after 15 min. S%_~e 3 - Pumped. ~5 BBLS 2-1/2~ HCL, 7g BBLS 12-6 UMA, 95 BBI~ 2-1/.2~ HCL @ 27~0'~p~i @ 1-1/2 Bt~4. Pumped DP clear w/210 BBLS w~r @ 1-1/2 DPM w/2750 psi. Shut down p~mrp - press dropped to 1300 psi in 5 min. 'Bled press off & released History of Trading Bay Unit Well D-24A continue~: pkr. Pumped 100 BBLS down annulus to clear csg. Reset pkr @ 13,028'. RU to wtr inJ. system. Pressured annulus to 2500 psi. Injected @ rate of 2-3/4 BPM w/3100 psi. Appears that communication between injection perfs & block perfs plugged. Pumped 1318 BBLS wtr into Bench ~ @ 3100 psi in 8 hrs - rate of 3954 BPD. - i PBTD 13,585' - Continued to inject wtr into Bench #4. Total injection after acid Job - 1976 BBLS w/3100 psi on DP & 2500 psi on annulus. Final rate 2.75 BPM @ 3100 psi. Shut well in after 12 hrs of injection. 30 min shut-in. - DP press O psi @ 250 psi on annulus. Well on vacuum.' Pulled pkr loose & POH. RU D-A & perf-d Bench #5 w/Jumbo jet csg gun. 1 shot/ft from 13,~25' to 13,451', 13,383' - 13,413', 13,336-13,366', 13,284' - 13,314' & 13,259' - 13,284' (141 total feet). Started in hole w/pkr. PBTD 13,585' - Finished in hole w/RTTS pkr & set @ 13,255'. Pumped into annulus @ 3 BPM @ 2500 psi. Pumped down DP into Bench #5 @ 1/2 BPM @ 3100 psi. Released pkr & spotted acid. Acidized Bench #5 w/15,800 gal. 2-1/2~ HCL w/7~ U66, 0.5~ W35, 0.4~ A-130, 9600 gal. 12-6 UMA w/l~ W35 & 0.~ A-130 & 240# ammonium chloride & 1200~ J-145 diverter. Stage 1- Pumped 2300 gal. 2-1/2~ HCL, 3200 gal. 12-6 UMA, 1470 2-1/~ HCL ~ set pkr. Balanced DP & csg press. Pumped 830 gal 2-1/2~ HCL followed by 1000 gal 2-1/2~ HCL w/600~ J-145 @ 2500 psi @ 4 BPM. Press increased to 2950 psi @ 1-1/2 BPM When J-145 reached formation. Rate of 2-1/2 BPM @ 2800 psi after 10 min. Stage 2 - Pumped 2300 gal. 2-1/2~ HCA, 3200 gal. 12-6 UMA, 2300 gal. 2-1/2~ HCL, 1OO0 gal 2-1/2~ HCL w/600~ J-145 @ 2750 psi @ 2-1/2 BPM. Press increased to 3000 psi @ 2 BPM when diverter reached formation. Press after 10 min - 2700 psi @ @ 2 BPM, 3 - 23OO 2-1/2 HCL, 32O0 gal 12-6 U A, 23O0 gal 2-1/2% HCL @ 2700 psi @ 2 BPM. Pumped DP clear w/200 BBLS wtr @ 2 BPM w/3000 psi. Shut well in - after 1 rain 2000 psi. After 5 rain - 1000 psi. RU to wtr inj system & pumped down annulus after'releasing tool to clear csg. Reset pkr. Injected wtr into Bench ~5 down DP @ rate of 2490 BPD @ 3000 psi & into Bench ~4 down annulus @ rate of 3625 BPD @ 2500 psi. Shut well in @ 6:45 AM for fall-off test. 4-15 PBTD 13,585' - Finished fall-off test of Bench ~5. Released pkr & POH. Pulled DP rubbers. RU D-A & perf-d w/csg jumbo jet i shot/ft. Bench ~6: 13,511-13,514'; 13,488'-13,491'; Bench ~2: 12,834'-12,864'; 12,812'-12,834'; 12,753'-12,777'; Bench #l: 12,695'-12,705'. Gun stopped @ 13,523' (below all perfs). RD D-A~ RIH w/7" RTTS pkr & set @ 12,565'. RU to wtr injection system & started inject- ing @ 4 AM. Rate of injection 3.64 BPM @ 3000 psi. Rate of 5242 BPD. 4-16 PBTD 13,585' - Cont'd to inject wtr into Hemlock zone @ following rates: 3OOO psi - 5240 BPD 3300 psi - 8280 BPD 3600 psi - 8820 BPD 3000 psi - 7728 BPD RU Go-International & started running profile log. Injecting @ rate of 8000 BPD @ 3400 psi. Finished running profile log & temperature survey. Layed down Go-International tools. RU & '~nJected into Hemlock @ rate of 8256 BPD @ 3400 psi. POH to 8530. Pressured annulus to 2100 psi - bled off to llO0 psi in 15 rain - no returns on DP. POH. RU D-A & perforated with Jumbo jet cSg gun i shot/ft. Bench 6 13,486' to 13,516' & Bench 2 12,760 to 12,770 & 12,815 - 12,825. RD D-A. Started in hole with~ RBP and pkr. Profile results: Bench 6 - 600 BPD Bench 5 - 5300 BPD Bench 4 - 2700 BPD Bench 3 - 500 BPD Bench 2 - IOOBPD Bench 1 - 0 PBTD 13,585' - RIH w/Baker 7" Model C retrievable bridge plug & retrievamatic pkr. Set BP @ 13,563', released Bench 6 & pulled to 13,485' & set pkr. Began injecting wtr, but meter showed no injection @ 4300 psi. Pulled pkr loose. Retrieved BP. Pulled to 12,885' & set BP. Set pkr @ 12,775'. Injected into Bench #2, but meter showed no injection rate @ 3500 psi. Hooked up BJ pump & pumped @ 3500 psi - injection rate of 0.6 BPM (864) & rate dropped to 0.3 B~4. Injected for 2 hrs - no change. Pulled pkr loose & retrieved BP. RIH & set BP @ 13,543' & set pkr (Bench 6) @ 13,485'. Injected w/BJ pump @ 4000 psi - bled off to 3500 psi in 15 min. Press up to 4000 psi & injected 0.2 BBLS of wtr. Waiting for boat to bring Dowell equip & acid. History of Trading Bay Unit Well D-24A Continued: PBTD 13,585' - Waited on acid & equipment 7{- hrs. RU & spottted 600 gals 2~!~' ~tcl'~-~4OO gals 12-6 UMA & 400 gals 2~_-~ HC1 acid. Pulled pkr above perfs & set @ 13,485'. Started pumping acid away @ 4000 psi @.1 BPM. Pressure dropped to 2500 psi in 3 min. Pumped all 38 BBLS acid & 12 BBLS wtr & press. increased to 3000 psi @ 1 BPM. Pulled pkr loose & pumped 60 BBLS down annulus to clear csg. Reset pkr & injected @ 1 BPM @ 3000 psi. Pumped 20 BBLS & press. dropped to 1000 psi & had returns on csg. Possible communication between Benches 5 & 6 or leaking tool it. POH to 12,600' & set pkr. Injected into well @ 3300 psi @ 6.7 BPM for 5 hrs. Attempted to pull pkr loose & DP backed off. Screwed back into DP & pulled pkr loose. RIH to 13,543' to pick up ret. BP. 4-20 PBTD 13,585' - PU ret. BP @ 13,543' & set @ 12,816:. Set pkr above BP & pressured to 3500 psi - all held OK. Pulled pkr loose & reset @ 12,749'. RU Dowell & pumped into upper section of Bench ~2 @ 1/4 BPM @ 3500 psi. Released pkr & spotted 600 gals 2~ HCL, 800 gals 12-6 UMA, & 600 gals 2~ HC1 acid. Set pkr @ 12,749'. Injected acid.~@ 3500 psi @ 1/4 BPM. After 1~' BBLS acid in formation, rate increased to 1/2 BPM @ 3500 psi. Shut down pump for 2 min. Resumed injection @ 2000 psi @ 2-1/g BPM. Press. declined to 1250 psi @ 2-1/4 BPM. Pumped all acid away & 100 BBLS wtr behind. Final · press, was 10OO psi @ 2-1/4 BPM. Connected wtr injection system to DP & injected @ 330o psi for 2 hrs @ 4.33 BPM. '-Pulled pkr loose & reset above BP. Tested DP to 3500 psi--OK. Retrieved BP & reset @ 8500'. Pressured csg to 2400 psi--bled to 1100 psi in 12 min. Retrieved BP & POH. RIH w/7" BP on DP & set @ 8733'. POH. 4'-21 PBTD 13,585' - Finished in hole w/RTTS pkr & set @ 8,197'. Pumped into liner lap @ 1-1/4 BPM @ 4000 psi. Released tool & spotted 100 sx Class "G" cmt D-Bi, 0.4% R-5. Set tool & sqzd 60 sx cmt into lap. Min. press. 3500 psi, max. & final press. 4000 psi @ 1 BPM. Job complete @ 1:O0 PM 4/20/75. Held 3500 psi on sqze for 2½ hrs. Bled off 2 BBLS. Released pkr & rev.out. POH~ RIH w/8~~'' bit & tagged cmt @ 8,318'. Drld cmt to 8,433' - top of 7" liner. POH. RIH w/ 6" bit. 4-22 PBTD 13,585' - Finished in hole w/6" bit to 8433'. Cleaned out top of ?" liner. RIH to 8?33'. Drld on rtnr & pushed remains to 13,585'. Circ hole clean. POH. RIH w/7" RTTS pkr & set 12',421'. RU Go-International. RIH w/ profile tools. Started injecting into Hemlock Zone @ 3000 psi. Tools failed-- POH. RIH w/profile tools. Injection rate @ 3000 psi - 8500 BPD. 4-23 PBTD 13,585' - Cont'd to run profiles, temperature surveys & tracer surveys. Surveys indicated no communication between Benches 2 and 3, 4 and 3, or 5 and 6. Survey indicated the 2 FIT holes in Bench 3 taking 300 BPD @ 3000 psi. During surveys injected @ rate of 7600 BPD w/3000 psi. Pulled tools out of hole & rigged down Ge-International. RU to lay down DP. Released pkr & POH, laying down DP. 4-24 PBTD 13,585' - Finished laying down DP & DCs. Dropped 1" dia. x 18" long steel bar from Varco Automatic Slips into well on last trip out with DP. Bar is @ PBTD @ 13,585'. RU D-A, RIH w/7" junk basket & gauge ring - 1S,O00' WI~. POH. RIH w/Baker Model F 7" x 4" (BORE).. perm pkr & set @ 12,499' WIN, 12,514' DP. POH & RD Dresser. RU & began running 3-1/2" - 4-1/2" tbg. Tested Baker seal assy to 4000 psi. Running tbg & testing 6000 psi w/Gator Hawk. 4-25 PBTD 13,585' - Finished running tbg & set into Baker Model "F" pkr @ 12,541 (PM) w/seal assy. Closed Hydrill & pressured annulus to 1000 psi - held OK. Released press.-pulled 10 its tbg. Installed Otis b_al ~_ valve ____mendrel & valve w/control line. Reran tbg & spaced out. Insts_l_._!ed tbg hanger w/BP valve. Lauded tbg. Removed BOPE. Inst~ed X-mas tree & tested to 5000 psi - OK. RU to skid rig. Have 5000 # weight set on perm pkr. PBTD 1S,585' - Connected well head to injection system & started injecting. Injected @ rate of 9500 BPD @ 3800 psi. Rig released @ 12:01 AM, 4/25/75. FOR ¥~RATHON OIL COMPANY i ? ' 3W~,t ~c '..,-~.~'>.. DtV'.$1ON OF OIL AND 0>`% A~c~O~AG~ Gyroscopic Directional Multishot TYPE OF SURVEY' ,~,JRVEY DEPTH: FROM 2,225 FT. TO 13,550 ~.A.~F:, Trading Bay Unit ,WELL NO. McArthurRiver COUNTY/PARISH Kenai Peninsula Borough ST^TFAlaska March 27, 1975 SU-3-16967 ~AVZ OF ~R~ JOB NO._ Anchorage, Alaska OFFICE: MARATHON CIL COMPANY TRADING BAY UNIT NELL ~. MCARTHUR RIVER ALASKA NO. D-24A SPERRY-SUN ~ELL S ~VEYING ANCHORAGE, ALASKA COMPUTATION DATE APRIL 3,1975 COMPANY ....................................................... PAGE ..... DATE OF SURVEY M.aRCH 27,19'75 SURWEL GY~OSCOPI C NULTI SHOTS~U_,_RVt~Y.. JOB NUMBER SU3-16967 KELLY BUSHING ELEV. : 106.90.FT. Z_'EB_O AT INC_~_IN_O~ET_E_RAND_. KBE TRUE SUB-SEA M. EASUR~D ..... VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE COURSE DOG-LEG TOTAL INCLINATION DIRECTIGN SEVERITY RECTANGULAR COORDINATES DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/~EST VERTIC&L SECTICX 2200 2040.69 1933.79 2300 2113.29 2006.39, 2400 2185.97 2079.07 2500 2257.22 2150.32 · _ 2600 2325.93 2219.03 2700 2393.15 2286.25 2800 .2q59.5I__2352.6I .... 2900 2525.0~ 2418.1~ 3000 2589.6~ 2482.74 , , 3100 2654.1~ 254.7.2~ 3200 2719.06 2612.16 3300 2784.07 2677.17 3400 2849.15. _2742.25 3500- 2914.74 2807.84 3600 2981.20 2874.30 ~__37~0 3048.00 _2~41.~10 3800 3115.00 3008.10 3900 3182.56 .3075.66 __.40003250.48 _ 3143.58__ 4100 3318.79 3211.89 6200 3387.4§ 3280.54 4300 3456.31 3349.41 4400 3525.38 3418.48 4500 3'594.45 3487.55 4600 3664.14 3557.24 4700 3734.50 3627.60 4800 3805.34 3698.44 4900 3876.%4 .. 3769.8~ 5000 3948.30 3841.39 5100 4020.35 3913.45 __5200___~.09 3.39__3986.49 43 30 43 25 43 21 45 45 47 26 48 5 48 46 49 21 50 I0 49 30 49 32 49 22 49 26 48 35 48 7 48 3 47 49 47 11 47 15 46 35 46 42 46 15 . 46 23 q6 14'' 45 25 45. 9 44 38 ~415 44 22 43 26 42 43 __N_T4~ 0._.~ ........... 0.00 171.Ag_.....H ......~77~19 E N 69.25 E S.26 193.15 N 642.42 E N 68.64 E 0.42 217.83 N 706:52 E N 68.7~ E 2.40 243.32 N 771.87 E N 68.63 E 1.68 269.72 N 839.54 E N 68.24 E 0.71 296.93 N 908.38 E 658.98 725-~ 792. 862.96 934.26 __ N 68 ...... 7__.F__ 0.69__ _32..4.__77__ N 9_7._7.82 E , N 67.91 E 0.59 353.08 N 1047.85 E N 67.85 E 0.81 381.82 N 1118.56 E . .N_67.89._.E 0.67__ 410.._6.1 N__1189.35 E__ N 67.76 E 0.11 439.32 N 1259.78 E N 67.58 E 0.22 468.18 N 1330.07 E __N 67758_...E 0.08 497.14 N 1400.26 E N 67.75 E 0.86 525.83 N 1470.07 E N 67.85 E 0.47 554.06 N 1539.25 E __N6.7.5_.1 E __0..26 582.32 N 1608.09 E 'N 6'7.49 E 0.24 610.73 N 1676.68 E N 67.49 E 0.63 638.95 N 1744.78 E N__.6_7.29__.E 0.17__ 667.17 'N 1812.54 E 10.06.21 '1078.79. 1152.10 .I 2.25..A.,9__, 1298.52 1371.42:., 1588.37 1659.77 1739.93 1801.59 . , N 66.77 E 0.76 695.67 N 18'79.7'8 E N 66.77 E 0.13 724.35 N 1946.59 E __N 66.86_.E_ 0.45 752.89 N 2013.24 E N 67.11 E 0.23 781.17 N 2079.80 E N 67.70 E 0.45 808.95 N 2146.56 E __N 68.39_E 0.95____83.5.?__7__7_N , 2213.08 E N 69.27 E O. 68 861.43 N 2279.34 E N 69.68 E 0.59 886.17 N 2345.43 E N_7.0.__2_._F 0.45 910.29 N__2411._16 E N 70.63 E 0.4~ 933.81 N 2476.93 E N 71.92 E 1.29 956.08 N 2542.60 E N 72.75 E 0..~1 976.80_N .... 26Q.7_.67 E 1871.g0 )- 2011.16 '. 208~.ql 2218.82 2287.76 2356.32 2424 .62 2560.35 2627.9~' 2.6_9_4. MARATHCN OIL CONPANY TRADING BAY UNIT~_.WELL_NO..__D~29.A_ MCARTHUR RIVER ALASKA, SPERRY-SU,'q 14ELL ~'~RVEYI~,'G CONPANY ................................................... A~CHORAG.. ALASKA .- ~ATE OF SURVEY MARCH 27t1975 · CONPUTAT_I ON DATE SURWEL_ GYF<OSCOP_I C__MUL_T.I SHOT__SUBVEY_ APRIL 3f1975 JOB NUNB:~R $U3-16967 - KELLY BUSHING Z E,_R, 0 _A_T_IN_C_LI N_0_M_E3_E R__A ND__K_ B E TRUE SUB-SEA _.M EA § U.,.R ED_ .... VERT I.CAL ...... ¥ E R._T_ .I,~._AL INC DEPTH DEPTH DEPTH D COURSE COURSE DOG-LEG TOTAL LI.~,~.~.T.~I O~D,!,B ECT I oN__S EV_E R I TY.._.R E C_T ANGU L AB _C.~qRQ.IN_A.T~ E S V ERT !_C_Ak _ EG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 5300 4166.99 5400 4240.87, 4133.9~ 5500 4314.74 4207-84 ,~5600 4388.31 4281..~..1 5700 4461.35 4354.45 5800 4533.91 4427.01 42__30__N 7_3_..32 E O..b~ 42 15 N 73.70 E 0.36 1015.69 N 2737-04 E 2827.54' 42' 30 N 74.56 E 0.63 1034.12 N 280P. 87 E 2893.93 42 46__N 75,.60._E 0._75 .... 1..0.5_1.55 N__2_867_:_31 E · 2960,-"'~ _ 43 23 N 76. 8 E 0.69 1068.26 N 2933.5J'-'E 3-02~-',~ 43 35 N 77.93 E 1.28 1083.73 N 3000.58 E 3096.71 5900 _4606.15 .4R99.25 6000 4678.49 4571.59 6100 4751.27 4644.37 ~.6200 : .,,_4824-22 4717..32_~ 6300 4897.30 4790.40 6400 4971.14 . 4864.24 , 650.0 5Q4 5.46__ 4938.5.6__ 6600 5120.30 5013.40 6700 5196.05 5089.15 6800__5272.20 __5165...30 6900 5349.0i 5242.II 7000. 5425.72 5318.82 7100 ..... 5501.64 7200 5577.36 5470.46 7300 5653.18 5546.28 __74_00 5729.22 5622.?_~2 7500 5805.54 5698.64 7600 5881.96 5775.06 77 00___595 8._55 5851_. 65__ 7800 6035.18 5928.28 7900 6111.26 6004.36 ~8000 .. 6187.02 .6080.12 8100 6262.57 6155.67 8200 6337.97 6231.07 ~8300_____6412.97 6306.07 4.3 55 N__79.29_E ' 0.99_1097.3_8_N 43 24 N 80.30 E 0.86 1199.61 N 43 12 N 80.74 E 0.36 - 1120.91 N 43 6 N 81.51_E 0.53__1 131.46 N__ 43 0 N 81.72 E 0.17 1141.41 N 3339.05 E 41 48 N 83. 3 E 1.49 1150.37 N 3405.87 E 42 _ 1.1__N 83......9...4__E 0,._-/2 .1_15.7_~:96 N__3472.,.3__4__E .... 40 55 N 84.56 E 1.33 1164.61 N 3538.33 E 40 35 N 84.58 E 0.33 1.170.78 N 3603.31 E 40 1_4.. N_85_.25__E . 0.56._. 1176.53__N 3_667.88 E 23 N 84.25 E 1.06 1182.38 N 3731.63 E 26 N 85.63 E 1.37 1188.03 N 3795.53 E 46__N_85...__79_ E .0._35__1192_.90 N .... 3860.~._~E'...' 40 48 N 84.~8 E 0.59 1198.21 N 392.5.52 E 40 35 N 84.98 E 0.23 1203.97 N 40 25 N 85_.. 8_.,E O. 18 1209_,.60 N ' 40 5 N 84.61 E 0.45 1215.41 N 40 15 N 84.98 E 0.29 1221.26 N 39 47 N_8_5:_4_C) E 0.54 1226,65 N 40 10 N 85.58 E 0.40 1231.70 N 40 45 N 86.26 E 0.73 1236.32 N 40 _~ 45 N_86.78_E 0.34__1240.28_N 41 7 N 87.17 E 0.45 1243.73 N 41 0 N 87.85 E 0.46 1246.59 N . 41 49 .... N._88.14 E 0.94 .... 1248.90 N__ 39 4O 40__ 306_8.36 F 316 5 ,_Sb,.__ 3136.30 E 3234.39 3203.95 E 3302.84 327..1 ,..52__E. . 33 7 I.. 14__ 3439.34 3506.73 3_5_~ 3_ 3639, 95 3705.22 ........ · 3_ 7'7.0.. 03_. 3834.05 3~98.19 ~9_S..3 ._2~___ 4028.. ~j 3990.47 E' · 4093.,~ 405'5_',-.!_7_2 E .'?':' 415_8..6__6~ 4119.52 E 4223.27 4183.75 E 4287.76 4 _2.__4_7_ ,~ .~..j-_E43_5.2.__05 431I.~7 E 4416.28 4376.'59 E 4481.1~ 4507.i7 E 4611.77 4572.79 E 4677.34 4638, 89__E_ -. Z~743.. 32 MARATHCN CIL CONPANY .__TRADING BAY UNIT WELL_.NO..__D_-.24A__ MCARTHUR RIVER ALASKA SPERRY-SUN ANCHORAbr_, ALASKA COMPUTATION DATF APRIL 3,1975 URVEY It:!G_.CONPANY ................................................... PAGE..]_ 3 .. DATE .OF SURVEY M/~RCH 27,1975 SUR',REL GYaOSCCRIC... M, UL.TI SHOT...SUR_]%'E~. JOB NUMBER SU3-16967 · KELLY BUSHING ELEV. = 106.90 FT. ZERO AT INCLINONETER ~ND KBE TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE CaURSE DOG-LEG TOTAL __I NC L I._NAT.~I Q~!__D I.R ECT! ON.__S. EVER.I TK R E_C.]AN GUL ARC.O_9_R.D INfi..T_E S VERT I C_A_L_ DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 8400 6487.73 6380.83 8500 6562.27 6455.37 8600 6635.77 6528.87 8700 6709.57 ,,. 6602-.6~ _ 8800 6785.17 6678.27 8900 6859.57 6752-67 9000 .... 6931.~6 .6824.56_ 9100 7002.38 6895.48 9200 7072.32 6965.42 9300 7141.10 703.4.20 9400 7208.17 7101.27 9500 7274.64 7167.74 9600 , 7342.04 7235~._14__ 9700 7410.46 7303.56 9800 7479.57 7372.67 9900 7547.15 7440.25 10000 7613.45 7506.55 10100 7680.91 7574.01 ~.10200 7749.74__ .7642.84 I0~00 7818.78 7711.88 10400 7887.99 7781.08 10500 7958.40 7851'.50 , 10600 8029.48 7922.58 10700 8099.61 7992.71 __10800 8169.23 8062..,_33 10900 8239.37 8132.47 11000 8311.13. 8204.23 __lllO0 8384.79 .82~7...8.9 11200 8458.41 8351.51 11400 8603.89 8496.99 _]1600 8747.85 8640.95 __411 .... 25 __N 88.36__E ....... 42 11 N 85.34 E 43 12 N 85.22 E 41 40 N 82.67 E 40 10 N 76.35 E 4. 43 40 N 74.98 E 3. .44 ...... 24._ N_.76.94_F 1. 45 15 N 79.87 E 2. 46 0 N 83.29 E 2. 47 5 N 85.65 E 2. 48 40 N 87.60 E 2. 48 0 N 89.85 E 1. 47 ..... 1.5_ S .... 89: 0 E 1. 46 24 S 88.42 E O. 46 10 S 87.91 E O. 48. 47 S__8~7.57 E __2. 48 10' S 88.22 E O. 47 0 S 84.88 E 2. 0.42 ..... 1250.93_N ._4705.27__5 2.15 125~.60 N 477.1.80 E 1.02 1260.18 N 4839.37 E 2.3Q. . 1267...28_N ., 40 1279.13 N 4970.79 E 61 1295.70 N 5035.49 E 5.~ , _1312. 55_N. 5102..91_F 23 1326.70 N 5171.95 E 55 1337.15 N 5242.62 E 02~1~44.13 N 5314 . 85_E__, 14 134'8.48 N 5388.88 80 1350.15 N 5463.54 13 ...... 1_349,60 N__55_3 7_.__4. 1 95 1347.96 N 5610.32 44 1345.65 N 5682,56 62 1342.74 N 5756.19 78 1339.99 N 5831.00 72 1335.56 N 5904.67 4809_.55 _ 4876.10 5076.5,5 5142.6.3 5211. 5281.57 5352.95 5425:5_ L 5499.59 5574.0Z 5_64 5719.78 5791.39 5938.45 6011.27 46 0 ..... S_ 8_4. 6__E 46 40 S 82.75 E 45 45 S 81.46 E 44 43 S 80.83 E --. 44 41 ' S 80.55 E 46 15 S 81. 9 E 4 5 30 S 79 -_7_6E 45 25 S 79.88 E 42 52 S 77.81 E 42 , 15 $_~7.~5_E 42 55 S 77.8I ~E 43 45 S 79.84 E 44 1_.0_ S 79 ?_57 E 1.16 1328,.58 N__59_76.87 E 60~2-,}__5_ 1.16 1320.27 N 6048.72 E 615i 1.30 1310.36 N 6120.22 E 6223.0~ 1.12 1299.43 N__6190.36 E 6'291:~__~__ 0.20 1288.05 N 6259.78 E 6359.54 1.61 1276.69 N 6330.14 E 6428.35 1-21 1264.75 N 6..40Q. 92E 64 97_._5_0 O.I3 I252.I6 N 6471.07 E 6565.97 2.92 1238.7I N 6539.39 E 6632.53 0:69 1224._17 N~6605_..q~_E 6.696_.__72 O. 73 1 209.62 N 6671 . 52 E 6760.94 O. 81 1 183.04 N 6806.14 E 6892. O~ 0.23 II~_8_.23 N 6942.73 E 702_5.__~3~? ~ARATHCN OIL COMPANY TRADING. BAY UNIT_WELL MCARTHUR RIVER ALASKA SPERRY-SUN ~-;ELL "'RVEYING COMPANY ANCHORAGt, ALASKA COMPUTATION DATE APRIL 3t 1975 DATE OF SURVEY MARCH 27,1975' SURWEL._GYRG_S_CO_P_!._C_[qULT_ISHOT SURVE JOB NUMBER SUB-16967 ' KELLY BUSHING ELEV. : 105.90 FT. ZERO AT INCLINOMETER AND KBE____ .~EASbRED DEPTH TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ERTI C A..k. VEB_I' I.C._A L I]N_C..L I _N A.]!..ON____D. I ~E C Z.IO.~. .... SEVERITY ..... RE.C TA. NGULA R CO DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH ORDINATES EAST/WEST VERT SECTION ..... !.18_00 120O0 12200 12q00 12600 12800 _~.13000 13209 13400 8.891,05 878'4,15 44 23 $ .7_8:_..8_0E _.0,29 .!.1~2',.0.3N ~ 9034.21 8927~31, 44 12 S 77-60 E 0.43 1103.z~7 N 9175.87 9068.97 45 36 S 78.95 E 0.84 1074.81 N 931_~,56 9207.66 46__35 S 78.._13 E ~0.o.57 lg.~.6_,17__._N__ 9453.63 9346.,73 45 18 S 77. 6 E 0.74 1015.31 N 9594.06 9487.16 45 30 S 77.12 E 0'10 ~83.50 N 9733.83 9626._92 4._5 50 . ,S _7.6.66._E O. 23 9873.17 9766.27 45 50 S 78.12 E 0.52 919.73 N I0013-72 9906.82 4~+ 52 S 76.59 E 0.72 888.60 N 1011.9.44_ 10012.54 ~ 5.3_0._ S. 7_6 ._9.5_. E __0.45 864.. 2~ N .... ...... 13550 F 7216.57 E 7354':, 78 E 7495 ._gg_ E 7636.35 E 7775. I5 E 7.9_ lb_..~ 8_ E 8054,~7 E 8193.29 E .82_9_6, 8.7_E 7_1_ 5_~,_05 _ 7292.06 7426.. ~ 7700.44 7835,20 79.Z0 ...~2___ 8106./.1 .. 8241.26 8_3_zt I ..]' ~__ HORIZONTAL DISPLACEMENT = 8~41.76 FEET AT NORTH, 84 DEG. 3 MIN. EAST AT MD = 13550 THE CALCULATION PROCE · DURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS CF CURVATURE -.; METHOD. / SPERRY-SUN L'ELL ~' '~VEYI.~,~G .COFiPANY. ANCHORAGE, ALASKA MARATHCN CIL COMPANY' TRADING ,.BAY..UNIT._ WELL_NO.,_Dr24A COMPUTATION DATE MCARTHUR RIVER APRIL 3·1975 ALASKA ALASKA _PAGE__.5 DATE OF SURVEY MARCH 27t1975 SURWEL]GY:~.OS.COP_IC._F',ULTI S,HO_T $_UBVE-~:- JOB NUMBER SU3-16967 .- KELLY BUSHING ELEV. = 106.90 FT. ZERO_A_T INC. LINO.,~iETE_R &NO,_.K.E]E .... KELLY BUSHING ELEV. = 106.90 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUD-_.SEA T.O'r_~, L_ ..... MEASURED VERTICAL VERTICAl= RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECT ION -" 2200 2040.69 1933.79 171.49 N- 577.1<:) E 15(9.31. 3200 2719o06 2612.16 439.32 N ------1259. 78 E "'- 480.93 ~21.62 4200 .3387.44. 3280.54 724.35 ._ N__-~_~ 1946.59......E~ ....... 812 55 331.61 5200 '4093.39 3986.49 976.80 N Z 2607.67 E~/ 1106:60 294.05 .. _7200_ _5577.36____5470..46 1198121_N. ~925152._E_ _ ._1622.63,."- 246._86 8200 ].8 z.02 9200 7072.32 6965.4.2 .... - ...... i33-7-,I5 N/':-, 5242.,62'-"E .............: 2127.67 265-65 .___1.0200_ '7,749.74 , .,%6.42,84 1328.58 N~--'~_ 5976. 87 E ~/"'~ 2450.25 322.57 11200 8q58.ql 8351.51 1209.62 N~P:;'--'6671.-52' E ~/--27ql.58 291.32 12200 9175.87 9068.9'7' 1074.81 N '---.---/3m~q--,,--7-e'-'E- ...... 3024.13 282.5% . 13200___9873.17 97.66.2..7 919..7..3 N__ 8054._47._ E ~__3326.82 30.2 ._69 13550 10119.44- 10012.54 864.25 N' 8296.87 E 3430.5.5 103.72 ,. IHE_CALCULATI_ON_.RR_OCEDURES.AB.E__B_A,SED ON__T_HE__USE_OF~.HREE___D.IM_ENSIONAL_g,_A~_!.U_S CF_C..UR_V_A_T_UR~_~_ TE_T_H_O_I~o . ......................................................... SPERRY-SUN NELL 'IRVEYING ..CONPANY ~NCHgRA~,.~ ALASKA MARATHCN OIL CO~'~PANY _TRADING_.B~.Y UNI.T_NELL__N.O.. D-24A COMPUTATION_...DA~E ~CARTHUR RIVER APRIL 3,197~ ALASKA' _P_ASE._=~ DATE OF SURVEY MARCH 27,1975 SURWEL G_¥ROS¢.OR!_C_ NU. LTI SH.O..T__S.U_R.V. EX JOB NUMBER SU3-16967 KELLY PUSHING ELEV. = 106.90 FTo. ZERO AT _I~_C. LINONETER AND ~_B_E INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES IqD-TVD QEPTH DEPTH DEPTH NORTH/SOUTH E A S_T./._KE_.S__']' .. D_ I__F_F_ E R EN C E__ 2200 2040.69 1933.79 171.49 N 577.19 E ~21.53 __2006.90 I_g_OQ?QO 1.62__.__4_0 N__54_6...Z~5 E 2291 2106.90 2000.00 191.06 N 636.75 E 2428 2206.90 2100.00 225.02 N 724.92. E 2571. ~ 2306.90 ....... 220Q.00 262...I.7__N ..... 820.2.~ ...E 2720 2406.90 2300.00 302.61 N 922.60 E 2872 2506.90 2400.00 345.13 N 1028.2T E , , 3026 .. 3181 3335 3_488 3638 3787 3935 4082 4228 4373 4517 4660 2606.90 '2500..00 .389.62_N 1137.72_.E 2706.90 2600.00 ~33.92 N 1246.58 E 2806.90 2700.00 478.33 N 1354.66 E ~2906.90__ 2800.00 522_,~6 N__1_~_61_,84 E 3006.90 2900.00 564.86 N 1565.79 E 3106.90 3000.00 $07.30 N I668.4I E __.3206.90__3100.00 6~9.9!__N ,. 1~69.05.._E 3306.90 3200.00 690.71N 1868.23 E 3406.90 3300.00 732.49 N 1965.56 E 3506..90 3.400..00_ ~Z3...62_N.__.2.061..94_F 3606.90 3500.00 813.88 N 2158.58 E 3706.90 3600.00 851.6I N 2253.39 E 159.31 1.5.6. _-.!. 2 184.29 221.87 2 6_q ._96 313.67 365.24 420..03 474.35 528.14 5.81_..~2.3 631.58 681.02 728.90 775.79 821.46 8 66....3.0 911.o8 953.96 VERTICAL CORRECT ION -1_2.78 .37.76 37.58 43 ..08 48.70 - 51.57 ..... 5.~..79. 54.~ 53.79 53.09 50.35 49.43 46.89 45.66 44.84 44.77 42.87 -IARATHON OIL COMPANY ;RADING.BAY UN[T_.WELL_ NO,__D~2~A 4CARTHUR RIVER ~LASKA SPERRY-SUN WELL S' VEYING COMPANY ANCHORAGE, ALASKA COMPUTATION DATE .. APRIL 3~1975 °AG: 7 ,, DATE DF SURVEY M.~RCH 27,1975 ' SURWEL ~YR.OSCO~I_C_.MULTI SHOT JOB NUMBER SU3-16967 KELLY BUSHING ELEV. : 106.90 FT, ZERO AT INC__LI_,~O~E_T_E_R ___AN.D G_BE . INTERPOLATED VALUES FOR'EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUD-SEA -~EASURED VERTICAL VERTICAL .'}EPTH DE..p.T_H __ DEPTH .... 4802 3806. 4942 .. 3906. 5081 4006.90 5218 4106.90 ~535~4206.90_ 54 56 57 59 6O 89 4306. 25 4406. 62~~506. O1 4606. 39 4706. 90 3700.00 90_ _.3~00..00 3900.00 4000.00 4100.00 90 4200.00 90 4300.00 90 4400.00~ 90 4500.00 90 4600.00 61 63 6447 __6582 6714 6845 6975.. 7106 7239 76 . 4806'.90 .~700,00 13 4906.90 4800°00 5006.90 4900.00 5106.90 __5.000..00 5206.90 5100.00 5306.90 5200.00 5406.907 5300.00 5506.90 5400.00 5606.90 5500.00 " TOTAL RECTANGULAR COORDINATES MD-TVD VER1 ICAL .... ~.OBT._H ~_SOU_I._H .....EAS ?/WE S.T~. D_ l F_ F E B_ENC_E_ . C_O_R B.~.~_T_!.QN 886.71 N 2346.87 E 995.28 41.32 920.33 N__2438.78 E__ 1035.20 39.92 952.12 N 2530.49 E 107~.57 39.36 980.50 N 2619.57 E 1111.47 36.90 1007.01 .N ....... 2707.41_E ........ 1147.19 _35-71 I032.20 N 279q.94 E II~2.46 35.26 1055.83 N 2883.97 E 1218.42 35.95 1078.35_N ...... 2975.43. F _!255.80. 37_. 3.8 1097.51 N 3069.07 E 1294.1~ 38.33 1114.14 N 3162.78 E 1332.19 38.05 112.9.07___N. _ 3255.48 E 1369.36 3_7...17 1142.70 N 3347.90 E 1406.22 36.85 II54.2i N 3437.65 E I4qI.08 34.86 .1163.51 N__3526.77_.._E__ 147_5.36 3_~_:27 II71.66 N' 3612.56 E I507.37 32.0I ~I78.99 N 3697.08 E I538.52 31.I~ 1186.o81 N__37_79.54 E __1568.37 '29.85 1193.23 N 3864.94' E 1600.03 31.66 1200.49 N 3950.92 'E 1632.11 32.08 · f ~-~ARATHON OIL COMPANY T~ADI.N G_.BAY_ _UNIT WELL ,N_g~ MCARTHUR RIVER .. ~LASKA SPERRY.~SUN WE'LL S ANCHORAGE, V EY I NG_...COMPANY ALASKA · D-24 A C 0 M P~.U ..l'_ A.T... I O.N_ D A.T E APRIL 3,1975 DATE OF SURVEY MARCH 27,1975 S UR W E L_G_YRO. S..CO P I C MULTI.SHOT JOB NUHBER . SU3-16967 '~" · KELLY BUSHING ELEV. : 106.90 FT, ZERO AT INC_LIN_O}!E_TER AND KBE ....... INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~qEASURED DEPTH 7370 !501. 7632 7762 8026 8158 8291 .... 8425 8560 ~~6~6 . 8828 8965 9106 9249 9398 9548 . 9694 9839 TRUE VERTICAL DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES ~D-TVD DEPTH NORTH/SOUTH EAS]J~T DIFFERENCE 5706.90 5600.00 1207.97 N 4036,22 E 1663.77 5806..90 5.7.0j]_._00 1_215_._5_! N__4!..20.._.6_5 E 1_6_g_~,86 - . , 5906.90 5800.00 1223.10 N 4204.78 E 1725.76 6.006.90 5900.00 1229,86 N 4288.07 E 1756.09 6106.90.. 6.000_.0_0 . 12_36_..0_7 N 43_72 ...... 8_~ E 17_87_,_3.~ 6206.90 6100.00 1241.2Z~ N 4458.85 E 1819.33 6306.90 6200,00 1245.57 N z~545.80 E 1851.92 6406.90. 6300.00 . . 1.248.~2_N 4633.46._. ~: 1884.9.5 6506.90 6400.00 125'1.41 N 4722.18 E 1918.66 6606.90 6500.00 1257.92 N 4812.35 E 1953.48 67.06_._9_0 6_6.00._00 1.2.~6_.,_9_~N q_9_04..09 _E 1989_,.5.1 6806.90 6700.00 1283.62 N 4988.95 E 2021.7'/ 6906.90 6800.00 1307.11 N 5079.48 E 2058.72 7006._9Q 6900..Q0 132.7.50 N__5.176._43 E 2099.5.0 7106.90 7000.00 1341.20 N' 5278.33 E 21~2.97 7206.90 7100.00 1348.42 N 5387.43 E 2191.17 730.6.9_0 7200._00 135.0 1.8___N 5499.29 E 22.41.2.~ 7406.90 7300.00 1348.07 N 5606.58 E 2287.93 7506.90 7400.00 1344.56 N 5711.52 E 2332.93 VE RI I C AL CORRECT IO_N 31.65 / 31.08 30.90 30.32 3_1..2_4,, -32.00 32.58 33.._02 ' 33.70 - 34.82 3.6_ 32.25 36.94 40._78 43.46 48.20 50_.._0_6 46.68 45.00 i MARATHON OIL COMPANY TRADI NGBAY_UNI T WELL__ MCARTHUR RIVER ALASK,~ NO. D-24A SEE R.R. Y_,_S_U M __W. EL __.S_UR V EY.I N G_CO ~! P:A NY "m I ANCHORAGE, ALASKA COMPUTATION DATE .APRIL 3,1975 DATE OF 'SURVEY MARCH 27,1975 SU_R_.WE_L.....G.y_,SO_S_C_DPI._C_~!._UL_T_[SHOT SU?, ,JOB NUMB"R:- SU3-16967 KELLY BUSHING ELEV. = 106.90 ZERO AT INCLINOMETER AND KBE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERTICAL.-' VERTICAL DEPTH DEpT_.H 'DE.P~TI-:!_.. TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL N.O._RT H,/_S o U_~,H._E .AST/W,E S_T. .....D!FF,.ERENC E ..... .C~ R R_EC__T_I ON 9990 7606.90 7500,.00 1340.21 N 10138 7706.90 7600.00 1333.08 N 10282 7806.90 7700.00 1321.86 N 10427 7906.90 7800.00 1307.47 N 10568 , ,.8006.90 .... 7900.00 ,.1291.72_N 10710 8106.90 8000.00 1275.~51 N 10853 8206.90 8100.00 1257.95 N 10994_ _.8306.90___8200.00 1239.54_N ... 11129 8406.90 8300.00 1219.77 N 11266 8506.90 8400.00 1200.10 N 11404 8606.90__.8500..00 1,182.5_3._..N 11542 8706.90 8600.00 1165.43 N 11682 8806.90 8700.00 1147.85 N .118228906.90 8800.00 1_129.0.2 11961 9006.90 8900.00 1109.18 N 12101 9106.90 9000.00 1088.31 N 12244 . 9206.90 9100.00 1068.73. N., 12388 9306.90 9200.00 1047.84 N 12533 9406.90 9300.00 1025.89 N 5823.69 E 2383.27 50.33 5932.43 E 2431.20 47.92 6036.22 E 2475.77 44.57 6139.41 E 2520.20 44.42 6237,74,,._E _2561,33 4,1.12 6337.66 E 2603.64 42-30 6438.62 E 2646.83 43.19 6535.51 .... E ......... 2687.30 .40 6625.03 E 2722.97 35.66 6715.58 E 2759.30 36.33 6808.98 E 2797.27 3_7__..96 6903.61 E 2836.00 38.73 6999.14 E 2875.41 39.41 7095.08 E 2915.27 39 ._85 7190.63 E 2955.00 39.73 7285.66 E 2994.52 39.52 __7385.88 F__ 3037.45 4.2,.92. 7488.06 E 3081.95 44.49 7590.32 E . 3126.66 44.71 MARATHCN OIL COMPANY TRADINGB.AY__UNIT WELL_._N.D.,_ D-24A MCARTHUR RIVER ALASKA S~ERR.Y=~UN.._~EL. SURVEYING COM~ANY ANCHORAGE, ALASKA C gM PUT_A.T..I ON.__DA T E APRIL 3,1975 P~_G_F._. DATE OF SURVEY MARCH 27,1975 S U.R_WE L__G .Y._,~O_S_ .C 0 P I C_..M.,UL_T_I_SH 0 T JOB NUMBER SU3-I6967 KELLY BUSHING ELEV. = 106.90 F ZERO AT INCLINOHETER Al,ID KBE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED ~O E P_TH TRUE VERTICAL DEPTH 12675 9506.g0 I2818 9606.90 . . IEg6I 9706.g0 13 lOZ~ 9806.90 13248 . 9906.90 13390 10006,90 13532 10106.90 13550 10119.4Z+ SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD __ DEPTH __NORTH/SOUTH EAST/WEST DI FFERENC_E ......... 9400.00 1003.26 N 7688.81 E 3168.83 __ 9500_..00 980.~..59 N 7_787.89_E ......... 3.2.11.. ~,.1 9600.00 957.44 N 7887.50 E 3254.45 9700.00 933.78 N 7987.70 E 3297.97 9800.00 912.58 N__ 8088.45_.E .......... 3341.50 9900.00 890.18 N 8186.68 E 3383.47 10000.00 867.14 N 8284.42 E 3425.19 10012.54 86_4.25 N 82 96...87....E ........3.4..30.. 55 VERTICAL C 0.~ .R.EC_T...I ON · 42.16 42.._58 43.03 43.52 63.52 41.96 41.72 5.35 ._. THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN .THE__NEAREST 20 FOO~_,...MD .... {FR_OM_.RADIUS .... OF CURVATURE) POINTS ' Ticket FLUID SAMPLE DATA Date 12-28-76 Number 838794 '?~ Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job OPEN HOLE TEST District ANCHORAGE ~, cc. Oil cc. Water Tester C.H. BOATMAN Witness B. STEVENS cc. Mud Drilling 03 Tot. Liquid cc. Contracto~p^RKER DR! LL !NG COMP^NY PW , Gravity ° APl @ °F. E q U I P M E N T & H O L E D A T A CO Gas/Oil Ratio cu. ft./bbl. Formation Tested Z RESISTIVITY CHLORIDE Elevation 106 ' K.B. Ft. , CONTENT Net Productive Interval Ft. ..~ Recovery Water @ °F. ppm All Depths Measured From 106' Kelly Bushing Recovery Mud @~°F. ppm Total Depth 8497' Brid.qe Plug Ft. Recovery Mud Filtrate @ °F. ppm Main Hole/Casing Size7" Mud Pit Sample @ °F. ppm Drill Collar Length 275' I.D. 2 3/8" Mud Pit Sample Filtrate @ °F. ppm Drill Pipe Length8087'I.D.2.764" Packer Depth(s) 8380 ' .Ft. Mud Weight vis cp Depth Tester Valve 8~J(~' .. Ft. TYPE AMOUNT Depth Back Surface Bubble Bottom Cushion Ft. Pres· Valve 8356 ' Choke Hose Choke 5/8n Recovered 20 Feetof drilling water. ~ ~-~ · Recovered Feet of Recovered Feet of o i-- Recovered Feet of ~ rtl Recovered Feet of Remarks Opened tool' with a very weak blow for 5 minutes - dead remainder of 15 minute test. Closed tool for 30 minutes. Reopened tool for a 60 minute second flow period with no blow at bubble hose. Closed tool for 120 minutes. m Gouge No. 3636 Gouge No. 3637 Gauge'No, ' ' z TEMPERATURE . TIME ~.~ Oepth: 8367 ~t. Oepth: 8392 Ft. Oepth: Ft. 24 Hour Clock 24Hour Clock Hour Clock Tool A.M. Est. 1~0 *F. BlankedOff no BlankedOff yes BlankedOff ' Opened 104 P.M;,, Opened A.M. cz Actual °F. Pressures Pressures Pressures Bypass 451 P.M. -r' Field Office Field Office Field Office RepOrted Computed Initial Hydrostatic 2881 2875 2888 2876 Minutes Minutes ~-~o Initial 18 24 24 34 i~.c Flow i~ Final 18 24 24 31 17 Closed in 147 1 36 148 141 30 r- ~c.e~: Flow Initial 18 31 24 45 ~ Final 18 35 24 41 60 aosedin .238 256 258 260 120 Initial .O'O ~ o Flow ., ~'~- Final Closed in Final Hydrostatic 2881 2875 2888 2876 -- FORMATION TEST DATA .~,TICKET NO. 83879~, Drill Pipe or Tubing .- ............... Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. Hydraulic Jar .................... VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly ................... O.D. I.D. 11 2.25" 2.764" 2 3/8" 3 1/2" 2.5" 3.88" 87" 3.88" .62" 3.88" 3" 3.88" 1.25" 3.88" .75" 5.75" 2.55" 2.4" ~,~)~mx. P. er. fs ................. 2 ~7/8" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ....................... Anchor Pipe Safety Joint ............ 3.88" Packer Assembly ................... Distributor ........................ ' Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................... Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... ,,,.,,-,,,,,,o ,, ,,.,.^. I='C31 !i PMI='IXIT DATA LENGTH DEPTH I 8087' 275' 4.69' 6.51' 5.8' 4.58' 5.04' 3.24' 4.34' 8.82' 5.06' 8356' 8362' 8367' 8380' 8392' 8497' ,,,, 96676 7SC e/74~ TIME Horizontal Line Equal to 1000 NOMENCLATURE b -. Approximate Radius of Investigation ........................ Feet b~ -- Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio ........... : ................................ E! -- Elevation .............................................. Feet GD -- B.T. Gauge Depth (From Surface Reference) ................... Feet h -- Interval Tested ......................................... Feet h, -- Net Pay Thickness ....................................... Feet K -- Permeability ........................................... md K~ -- Permeability (From Net Pay Zone h,) ........................ md m -- Slope Extrapolated Pressure Plot (Psi2/cycle Gas) .............. psi/cycle OFt ~---Maximum Indicated Flow Rate .......... ' .................. MCF/D OF2 '--Minimum Indicated Flow Rate ............................ MCF/D OF:~ '- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF4 -- Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D Ps -- Extrapolated Static Pressure ............................... Psig. P F -- Final Flow Pressure ...................................... Psig. Pot -- Potentiometric Surface (Fresh Water') ...................... Feet e ----- Average Adjusted Production Rate During Test ................ bbls/day Q, -- Theoretical Production w/Damage Removed .................. bbls/day Q9 --Measured Gas Production Rate ............................ MCF/D R -- Corrected Recovery ...................................... bbls r,~ -- Radius of Well Bore ...................................... Feet t -- Flow Time ............................................. Minutes t o --- Total Flow Time ......................................... Minutes T -- Temperature Rankine .................... ~ ............... °R Z '-- Compressibility Factor ....................................... ~ -- Viscosity Gas or Liquid ................................... CP Lo~I -- Common Log * Pofenf~omefr~c Surface Reference fo Rotary Table When Elevation Not Given, Fresh Water Corrected to I00~ F. Drill Pipe or Tubing ................ Reversing Sub ...................... Water CuShion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly .- ..... Dual CIP Valve ....... ' ............ Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ............... Extension Joint AP Running Case .................. Hydroullc Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly .................... O.D. I.D. 11 2.25" 2. 764" 2 3/8" , 2.5" 87" .62" 3" 1.25" .75" 2.55" 2.4" .. 3 1/2" 3.88" 3.88" 3.88" · 3.88" 3.88" 5.75" ~>~mx. P. er. fs. · _2_?7/8" Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... 3,88" Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ ' Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................... Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... I IL.I~I- I LENGTH DEPTH I 8087' 275' 4.69' 6.51' 5.8' 4.58' 5.04' 3.24' 4.34' 8.82' 5.06' 8356' 8362' 8367' 8380' 8392' 8497' ~ l"orm ~o. P--4 1~'. 5'1-70 STATE Or ALASKA OIL AND GAS CONSERVATION COMMII-I'EE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS Hemlock Water Injection NAME OF OP~%ATOR *Union Oil Company of California SUBMIT IN DUPLICATE 3. AD~¥tESS OF OPEl:tATaR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL 20 At Surface: 755' N & 1214' E of the SW corner, Sec. 6 T8N, R13W, SM - Conductor 12, Leg A-1 n Proposed Hemlock Zone: AP1 NUiV~ERlCAL ~ODE 50-133-20225-01 12,558' ~iD, 9500' TVD, Distance out 7789' @ N80°E. LEASE DESIGNATION AND SEMIAL NO. ADL-18729 IF INDIA~, ALOTTEE O]{ TRIBE NAME 8. L~,'IT FARM OR LEASE NA~ME Trading Bay Unit 9 WELL NO D-24A (33-5), ~'lJ~ A_ND POOL, OR WILDCAT HcArthur River F±eld, Hemlock SEC , T., R., M.. {'~T'T*OM HO1.E oamcTn~ 2230' N & 560' W of SE namer Sec. 5, T8N, .R13W, SM P~IT ~O. 74-64 13. REPORT TOTAL DKPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PEH~OHATIONS, TESTS AND HESULTS FISHING JOB~ JLrNK IN HOLE AND SIDE-T1R~CKED HOLE A~D AX~Y OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS TRADING BAY UNIT WELL D-24A - WATER INJECTION - APRIL~ 1975: 4/1-4/4 Finished cement squeezing by squeezing above Bench 1 with 100 sacks through perfs from 12,675' to 12,680'. Drilled out retainers & cleaned out to 13,585' PBTD. 4/5-4/6 Ran Wireline Formation Interval Test Tool to monitor pressures & fluids on Benches 1 through 6. 4/7-4/20 Perforated & treated Hemlock Benches as follows: Bench No. Perforations Acid Stimulation 1 12,695'-12,705' 2 12,753'-12,864' 3 No Perfs 4 13,033'-13,216' 5 13,259'-13,451' 6 13,486'-13,516' None 1200 gals 2-1/2% HC1 + 800 gals 12-6 UMA 15,800 gals 2-1/2% HC1 + 9,600 gals 12-6UMA 15,800 gals 2-1/2% HCi+ 9,600 gals 12-6UMA 1000 gals. 2-1/2% HCl + 400 gals 12-6 UMA 4/21-4/22 Repaired the 7" liner lap leak by squeezing with 100 sacks of cement. Drilled & cleaned out to 13,585'. 4/23-4/25 Set a permanent packer at 12,499' on wireline & ran 3-1/2" OD & 4-1/2" OD tubing. 4/26 Began injecting water at 9,500 BPD at 3,800 psi into Hemlock & released rig to move to drill Well D-27. *Mar, at~ Oil Comoany --- Sub-Operatnr _ 14. I hereby ~rti~y that the f~'~g~ is~ t~-ue ~ ~ , / /T4~ P ~]]n~4n~ N~E ~-~o~ ~n t~i~~r~uired for ~ calendar ~th~ regardless of the status of operations, and must ~ flied in dupll~t, with the oil an4 gas conlervatbn commiflee bythe 15~ of the suo~ding mn~, ~le~ otherwise directed. No. P.--4 $- I-?0 STATE OF' AJ.A.~KA susMrr IN m~LICA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O~L.,LL ['"] ~*".'-LL [--'] O?"Z" Hemlock Water Injection 2. NAM.~- OF OP~I~ATOR *Union 0il Company of California 3. ADSRZSS O~' oPm~roa AP1 NI.TMEHICAL CODE 50-133-20225-01 LEASE DESIGNATION AND SE1RIAL NO. ADL-18729 ? IF INDIA~, ALO-f iEl~ O1~ TRIBE NAME 8. L~IT FARM OR LEASE NAME Trading .Ba7 Unit g WELL NO 909 West Ninth Avenue, Anchorase~ Alaska 99501 LOCATION OF WI~!-Y-L l0 At Surface: 755' N & 1214' E of the SW corner, Sec. 6 T8N, R13W, SM- Conductor 12, Leg A-1 Proposed Hemlock Zone: 12,558' MD, 9500' TVD, Distance out 7789' @ N80°E D-24A (33-5) FIlL. r) A_ND POOL, OR WILDCAT McArthur River Field, Hemlock I1 SEC., T., R., M. (BO~I'OM ltOLE o~ 2230'N & 560'W of SE corner Sec. 5, T8N, R13W, SM 12. PERMIT 74-64 '13, REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PERFOHATIONS, TESTS ~ RESULTS FISHING JOB~ JUNK IN HOLE AND SIDE-TRACKED HOLE A2~D ANY OTI-IER SIGNIFICANT CHANGES IN HOLE CONDITIONS. TRADING BAY UNIT WELL D-24A - WATER INJECTION - MARCH~ 1975: Continued drilling 8-1/2" sidetracked hole to a total depth of 13,600'. Unable to log open hole; could not get below 9,115' with logging tools. Ran 7", 29#, N-80, X-line casing from 8,433' to 13,600'. Cemented with 50 sacks ll#/gallon Class "G" Neat ahead of 900 sacks Class "G", 1% D-31, 0.4%, R-5, 15.5# slurry. Had good returns while cementing. Ran CBL/VDL/GR logs. The Cement Bond Log indicated generally poor bonding, and the well is currently undergoing block squeezing to improve bonding. Block squeezing has been completed between Benches 3 and 4 and between Benches 2 and 3. *Marathon 0il Company -- 14. I he.by ~y~t the ~ego~e N~E ~Report on this fo~ is required for/~ calendar ~thT regardless of the status of operations, and must ~ filed ~n dupli~te with the oil and gas conlervoflon oommiflee byfhe 15~ of the &uoo~ding mn~, ~leK Otherwise directed. ]Pm'm ~o. P,.EV. $- I-?0 STATE Ot-- ALAS~ OIL AND GAS CONSERVATION COMMI'I-rEE SuBMrT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP1 NUMERICAL CODE 50-133-20225-01 6 LEASE DESIGNATION AND SERIAL NO. ADL-18729 O,Lw~LL [] G,SW,.LL ~-] OrZZ' Hemlock Water Injection 2. NAME OF OPERATOR ~Union Oil Company of California ~,, 3. ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchora~e~ Alaska 99501 At Surface: 755' N & 1214' E of the SW corner, Sec. 6 T8N, R13W, SM - Conductor 12, Leg A-1 Proposed Hemlock Zone: 12,558' MD, 9500' TVD, Distance out 7789' @ N80°E 8. I,,~IT FA.R~ OFt LEASE lqA.ME Trading Bay Unit 9 WELL NO D-24A (33-5) 10 FI~J.,D AND POOL, OR WILDCAT McArthur River Field~ Hemlock OB,mCTrV~ 2230' N & 560' W of SE corner Sec. 5, T8N, R13W, SM 1~. PIERMIT N'O. 74-64 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFORATIONS, TESTS A.N'D RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE A_ND ANY OTHER SIGNIFICA-NT CH-~GES IN HOLE CONDITIONS TRADING BAY UNIT WELL D-24A - WATER INJECTION - FEBRUARY~ 1975: 2/1-10 Recovered approximately 1/4 of roller reamer pin with magnet. Drilled 12-1/4" hole to 9,821'. Dropped survey. Pipe stuck while surveying & circulating. After attempting to work pipe free, rigged up Dia-Log & ran free point. Attempted to backoff at 8,852'. Pipe backed off at 8,510'. A second backoff occurred at 8,813' (top of Dailey jars). Re- covered all drill pipe & 7 joints of heavy wall. Top of fish at 8,825'. Ran 214 joints of 9-5/8", 47#, N-80 & P-il0 casing with shoe at 8,627'. A 180-sack cement plug was then placed on top of the fish and drilled out to 8,723'. A second cement plug was placed from 8,723' to approxi- mately 8,440'. 2/11-28 Drilled out cement plug from 8,460' to 8,645'. Kicked off plug at 8,645' and drilled & surveyed to 10,212'. At this depth the hole angle had dropped to such an extent that it was necessary to plug back and redrill to correct the angle. Placed cement plug from 9,200' to 8,823'. Kicked off plug at 8,823' & drilling sidetracked 8-1/2" hole below 9,500' at month's end. *Marat~n 0il Company-- Sub-Operator 14. I hereby certii[y//11~at the iOre~g/ng, iF~ue_~z~_d eOrre~ ' . ' " ,,~mm ~/x~,"'/~7.4~-,_~~ Dist. Drl~. Su~t, .,~ 3/14/75 , , ~/ Jlm ~. oallendar - - ,, ~--Re~ort on lhie f~ it required for .~ch calendar ~thl regordle,, of t~e m/otu$ of operotio,~, and mu~t ~ filed i, dupli~te ~ith the oil and gas conservation commiflee bythe IS~ of the suocNdifl9 mfl~, ~le~ otherwise directed. l'~rm No. }'--4 lq..EV, $- I-?0 STATE O¥ ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE £~[ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,~ ~] ~*" [~] OT,~E,~ Hemlock Water Injector W£LL wELL 2. NAME OF OPE. P. ATOR Union Oil Company of California * 3. ADDRESS OF OPERATOR 909 West Ninth Ave., P. O. Box 6247, Anchorage, Ak.99502 LOCATION OF WELL At surface: 755' N & 1214' E of the SW corner, Sec. 6, T8N, R13W, S.M. Conductor 12, Leg A-1 Proposed Hemlock Zone: 12,558'MD, 9500'TVD, Distance out ~789' @ N80 °E 5 APl NUMERICAL CODE 50-133-20225-01 6 LEASE DES;GNA?ION AND SEHIAL NO ADL-l$729 7 IF INDIAN[ ALOTTEE OR TRIBE NAME 8. L.~IT F.k.r~l OR LEASE NAME Trading Bay Unit 9 WEL,L NO State D-24A (33-5) 10 FIFI.r~ A.%'D POOL OR WILDCAT McArthur River Field, t-[em].ock SEC.. T.. R...~, (i, orrbx, ,o,.~. 2230'N & 560'W of SE corner, Sec. 5,TSN,R13W, S.M. 1~. PERMIT NO. 74-64 13.REPORT TOTAL Di~:~TIt AT F~ND OF MON'I24. Ct{ANGF~ IN HOLESIZE. CASING AN~D C~IENTING JOBS INCLUDING DEPTH SET ANq2~ VOLL.'A/IY-q USED. PEILFORATIONS. T~iSTS ANqD PLESULTS. FISHING JOBS. JI/NK L~/ HoL~E A.ND SlDE-TI~ACKED HOLE A~N'D ANY OTIiER SIGNIFICANT CI-LkNGF-.S IN HOLE CONDITIONS. TRADING BAY UNIT 'WELL D-24A -, WATER INJECTION - JAlqUAEY ~ 197~: 1/1-6 Continued milling window in 13-3/8" csg. Milled from 2,110' to 2,180'. 1/7-17 Spotted 200 sxs cmt from 2191' to 1980'. Drld out cmt to 2,110'. RIH with Dyna- drill with 2° bent sub and kicked off @ 2,110'. Drld 12-1/4" hole to 2,190' and laid down Dyna-drill. Drld and surveyed 12-1/4" hole from 2,190' to 4,803'. Changed mud to polymer type due to extreme ice condition limiting boat operations. Drld and surveyed 12-1/4" hole from 4,803' to 6,853'. 1/18-27 While pulling out of hole blade stabilizer hung on 13-3/8" csg ~ 2100'. Worked stabi']izer into csg by rotation. Lost 1 blade of stabilizerin hole that was not recovered. Drld and surveyed 12-1/4" hole from 6,853' to 8,463'. RIH w/Dyna-drill with 2° bent ~ub and drld to 8~491'. Laid down Dyna-drill. Drld and surveyed 12-1/4" hole from 8,491' to 9,003'. 1/28-31 RIH with drilling assembly and found pin on bottom. Drilled one ft. POt{. RIH w/magnet and recovered roller reamer pin. Drld and surveyed ~; hole from 9~O04' to 9~505'. POH and laid down 3 - 8" drill collars. Left one roller reamer pin in hole. RIH w/magnet and fished for pin. No recovery. RIH w/12{-" bit and chased pin to bottom. POH. *Marathon Oil Co., Sub-Operator sm~z~ ~-_'.~-a~--.nrus Distric.t Drlg. Supt. ,~.~ 2/12/75'// /~ / d',~ ~. ~ _ . , , , ' ~--Report on this form is required for each calender month,~ regardless of Ihe status of operations, and must be filed In duplicate vdftt the oil and gat coneervatlon committee byfhe I~th of Iha succeeding month,unlets otherwiee directed, l,'~w~ ~To. 1P--4 REV. STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN DUPLICA'I']~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUiViEPACAL CODE 50-133-20225-01 LEASE DESIGNATION AND SERIAL NO. ADL-18729 1. ~ IF INDIA)~. AL(DA lEE OR TRIBE NAME O,L i''-] ~'" J--] or,,--. Hemlock Water Injector WELL WELL 2. NAME OF OP~:LATOR 8,L~.'IT FAP. M OH LEASE NA.ME Union Oi'l Company of California * Trading Bay Unit ADDRESS O1~' 'OPERA. TOR 909 West Ninth Ave.~ P. 0. Box 6247, Anch0ra~e~ Ak. 99502 LOCATION OF WELL At surface: 755'N & 1214" E of the SW corner, Sec. 6, T8N, RiBW, S.M. Conductor 12, Leg A-1 Proposed Hemlock Zone: 12,558'MD, 9500'VD, Distance out 7789' @ N80°E g WELL KO State D-24A (33- 5) i0 FIELD A_~D POOL. OR WILDCAT McArthur River Field~ Hemlock n SEC., T., a., 1925' N & 8500 ~E of s~f. loc. or 2230'N_&569'~~_.cgr~r, 1~. P~IT NO 74-64 13. REPORT TOTAL DEPTH AT END OF MONTH, CPI3~'qGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFOHATIONS. 'rESTS ANT) RESULTS FISHING JOB~ JUi~K IN HOLE AND SIDE-TRACKED HOLE A/~D ~Y OTHER SIGNIFICANT ~GES IN HOLE CONDITIONS 12/21-26 Rigging up 12/27-31 13-3/8" casing previously set @2,545'. RIH to 2225' and swedged on casing. RU Dresser-Atlas & ran CBL to 2225'; log showed good bonding. Milled window in 13-3/8" csg from 2100' to 2110'. * Marathon Oil CompS-Sub-Operator S~aN~m ~ ~"~ ~;;~/~~ =TU~ Dist. Drlg. Supt. DA~E 1/10/75 / -,'m K, I:~ll~d~r ~TE--Report on this form Is required for ~ calender ~th~ regardless of the status of operation,, and muir ~ flied l" dupll~/e wlt~ the oil and gas conservatbn commiflfl bythe 15~ of the suoc~ding mn~. ~le~ otherwise directed. JAY S. HAMHOND, ~gVERNOR Dece~er 6, 1974 Re: Trading Bay Dnit State D-24A (33-5) Union Oil Co. of Calif., Operator Permit No. 74-64 Mr. Robert T. Anderson District Land f,~nager Union Oil Co. of Calif. 909 W. 9th Avenue Anchorage, Alaska 99501 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well ,~on or about December 16, 1974 at a location from the Dolly ~arden Platform. Well samples, core chips a))d a mud log are not required. A directional survey is requir~d. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70} and by the Federal Water ~otlution Control Act, as Prior to c~Fmi~g operations you may be contacted by a representative of the Department of E~vironmentat Cons~vation. Pursuant to AS 38.40, Local Hire U~der State Leases, tJ~e Alaska Department of Labor is betn~ notified of the issuance of this permit to drill. Very ~truly yoursj Homer k. Bur~ell Chai~n Alaska Oil and ~s Conservatio~ ~ittee Department of Enviror~.~.ental Co~servation w/o encl. Department of Labor, $~rvisor, Labor Law Compliance Division w/o encl. l~rm I0-- 401 ll~V. I -I--71 ][1. TYP~ OF WORK SUBMIT IN THIPLI¢. (Other instructions on reverse side} STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN ~ __ DRILL or, °'" r-I W~:LL W~LL 2. NAME OF OPEH3kTOR DEEPEN ttem J ock oT~=J Water n i ectgr. ZONI/: Union Oil Compa. ny of California 3. ADDR~ ~ 909 West 9th Avenue~ P. O. Box 6247, .Anchoraqe, Alaska- ggS02 _ 4. LOCATION OF WELL At surface Conductor 12_ Leg A-l, 755LN & 121.4'E' of the SW corner, Section.~6r.~' ~SN, R13W, S.M : At proposeo zone ~* ' Ilemlock Oil Pool 12,558'MD, 9500'VD~ Distance out 7789.',~.. 80°E 13. DISTANCE IN MILES AND DIRECTION F~OM NEAREST TOWN OR POST OFFICE' 21 miles Northwest of Ke. nair Alaska l~. ~OND ~NFO~U~^T~ON: Un i ted Pac i f i c Co. TYPESta t ewi de Surety and/or I%~O, B-55502 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. (Al~o to nearest drig. unit. ii any) 854' - Bottom of Hole 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR, FT. 2100' from D-4 ~o. or AC~S ~N ~i~X'SE · 3085 J ig. PROPOSED DE~PTH 13669' TaD 10,300' 'T~D API #50-133-20225-01 LEASE DESIGNATION AND SERIAL NO, ALL-J8729 IF INDIAN. ~TT1ZE O1{ TIt2BE NAM~ II, UNIT FARM OR LEASE NAA4E TRADLNG BAY UHIT 9, WELL NO. STATE D-24A (33-5) 10. FIEL.D AND POOl.. OR WILDCAT McART~iUR RIVER FI EL[) IlEMLOCK SEC., T.. R., M., CBO'FTOM HOLE OBJECTIVE~I 925~& 8~O01E of surface loc. 2230'I'1 & 560'W of SE corner., Seg.~k5: ~TSII; RI'3W, S.M NO. ACRES ASSIGNED TO THiS WELL 160 20. ROTARY OR CABLE TOOLS ROTARY 21. ELEVATIONS (Show whether DF, RT. C-R. etc. i 22. APPROX, DATE WORK WILL START* 12/16/74 106' KB,above. MSL. . PROPOSED CASING AND CEMENTING PROGRAM SIZEOFHOLE rSIZEOFCASi-N~G~ WEIGHT PER FOOT "~'RAD~ .... S~SO D~ ~ ~" ' i 'y of cern,at -17-1/2" 13-3/8" ~ 2,'~'b0' ..... Previ~'ly"set p'ropo~'e8 wi~d°w from 2000' ' 2~7'0'"' '(185 sx.""~ .12-1/4'I' ' 9-5/8" 47~ ~'-.80 4.7~" DV"Collar.~ 600O' .)~t ~t'~]y]l, O0.O ,12=1/~,' ... q-~/8,' .. 4~ ' ~P-ll( ~600' w/4% GEL. &.330. sx. G neat lP-t/4" q-q/R" A7~ ~'~O q.8OO' l~q ~x. "G" w/.~?J .GEL & 150 .s.x.. m~ ~ ~ 12-1 ~ . ,, q-E/ ' 47~ P-Il[ ]1.000' neat .cut,' bY I -~ q ':. .... 8-1/2" 7" Liner 29~ ' N-80 10,800' - 13,669' 600 sx. "G" neat CMT. X-Line , . : i ' [ " ' -. . ,. in D-lO & D-24, 4750'-7600' MD or 4000' - * Run 47# P-IlO csg :across-zones that'damaged csg. 6000' TVD. * Marathon Oil Company - Suboperator - Dolly Varden Platform IN ABO%FE SPAC1g DESCRIBe: I~ROPOSET) PP. OGRANI: If proposal is to deepen give c~m on present productive zone and proposed new pro'duct~ve zone..lf__p_r_o_pg_s~.l is to grill or aeepen du-ect_jonally, give pertinent. ~lata' on s%i0suriace I~tiol~ and rne&aured and true 'Veriical depths. Give bloC;t0-ut p~ev-e_nter' program. 24, I hereby certify that the Foregoing is True and Correct S~_GN~r~ ...... ,~ D^~November 27, 1974 ~ District Land Manager (This space /or State office use) CONDITIONS OF APPROVAL. 1F AN-Y: SAMPLE~ AND CORE CItlPS REQUlI~CD J ~,.~D ~o'a ~ ~~'~: $ Y~ ~o J,, a m ~uo SEE TRANSMITTAL LETTER DI~ION~ SURVEY R~~ A.P.L ~C~ COD~ , ~ O/ ~~'~--~:~ __ - fi' , ..... ~ ~ ~'S '~" Pecemb~r.[6, .. lm9~4........ .~ .... ~. Chairm~n',~] ~ ~.~ December 6, 1974 PLAN OF PROCEDURE' 1. Skid rig over Conductor #12, Leg A-1 and rig up. Sidetrack ]',.ole in 13-3/8" csg. @ -,' 2000'. Dri~.l 12-1/4" d~_recc~on~.,1 hole to + ll,000' ~,~3 4. Run 9-5/8" csg. to 11,000' a~d cement as required.' · S. Drill 8-1/2'" directional hole to 13,669' 6. Rrm required logs. 7. Rrm 7" liner from 10,800' to 13,669' m~d cement as required. 8. Reconplete well as }Ie~pgock Injector. EST IkVkTED TOTAL. Redrill Fifl',y-s/x (56) Days ~ven%¥-six ~26) Days ' // ! \ ~ ~-~o x",, ',, '", 4!' , ./ _ ~ /D-20/ / ~ "- (12X-5) D-2~ i .. ~ D.,~ "._.~s / / b ..',(~-s) ~~. ' ~- -o~%~'¢ ~,~/ . - .. ~ H ~op. T/H D'2 4 i ' ~ ~ ~P~ ' .////.~......~' . ' ,v, ,,,oo.-, ,,. ,,, . ////,~ /' ~ . _~ ....o--,-~o ~.~ II// ,'~ ,." / ~ ~ -- ~ · TvO ~o,~oo DOLLY VARDE · D-17 -- ~_____ (44- s)-e '-~ D-33 (14X-5) (;'2-7) D-9 42-7) '\D- 14 (44 -7) 18 D-22 33X-18) I:)-8 (.24-8) '~":- 4 ~ '-D-lO (24-5) ~'""~"' I (44 -5) ' D-8 RD. _ · U-M ADL 18729 N PPSS ADL 17,579 .\ b D-14RD (I-I- 17) J7 ~(12X-17). · ~)2'4~(t 17) ! N UNION WELL LOCATION MAP MARATHON SUB-OPERATOR TRADING BAY STATE UNIT D-24 A (33- 5 ) 0 2000 SCALE: I": 2000' ~ NOV, 21,1974 iiiii i i i ii ii I CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1 Is well to be loCated in a defined pool ................. /F~K 2. DO statewide rules apply ....................... ~ /~( 3. Is a registered survey plat attached ................. 4. Is well located proper distance from property line ........ 5. s well located proper distance from other wells .......... 6. ts sufficient undedicated acreage available in this pool ....... x, ea~ 7. Is well to be deviated .............. ~ 8. Is operator the only affected party ............ Y~_ 9. Can permit be approved before ten-day wait ...... 10. 12. Is enough cement used to circulate on conductor and surface . l~k_~ii~ill cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ....... 15. Will surface casing cover all fresh water zones ........ 16. Will surface csg. internal burst equal .5 psi/ft, to next string . . 17. Will all casing give adequate safety in collapse and tenSion . . . 18. Does BOPE have sufficient pressure rating ..... Additional Requirements: Does operator have a bond in force ............. x/~J~-. Is conductor string provided .................... ~ Approval Recommended: ?mt' ~ OKG KLV~ JAL ~~ HWK ~-~ LCS HHH = .... JCM ....