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Home My WebLink About163-007Nolan 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. SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 34-28 SWANSON RIV UNIT 34-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 34-28 50-133-10158-00-00 163-007-0 N SPT1630070 2500 0 2987 2958 2947 0 0 0 0 OTHER P Austin McLeod 12/11/2025 MITT. Sundry 325-673. MITIA on separate report. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:SWANSON RIV UNIT 34-28 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251215123232 BBL Pumped:0.5 BBL Returned:0.4 Friday, January 16, 2026 Page 1 of 1            1-Oil Suspended status; prep for redrill - jbr MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 34-28 SWANSON RIV UNIT 34-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 34-28 50-133-10158-00-00 163-007-0 N SPT1630070 2500 0 0 0 0 0 0 0 0 OTHER P Austin McLeod 12/11/2025 MITIA. Sundry 325-673. MITT on separate report. Attempted to do a CMIT originally. Operator did not know the status of the GLM stations and what they had in them valve wise and it would’ve been a crap shoot jumpering @ surface. They tried to break circulation down the IA with the tubing open (hanger still landed). Shut down the test pump to see what psi they were at. Saw a little dribble out the tubing once IA was almost to test psi. That was the typical squeeze seen on the tubing but since it was open no psi could be built. Just FYI as it looks goofy when testing the IA and tubing doesn’t come up @ all when plugged downhole. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:SWANSON RIV UNIT 34-28 Inspection Date: Tubing OA Packer Depth 0 2640 2622 2615IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251215122420 BBL Pumped:2.5 BBL Returned:2.4 Friday, January 16, 2026 Page 1 of 1          1-Oil Producer; Suspended status; prep for redrill - jbr   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 Other: Rolling BOP Test 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): 10,880' N/A Casing Collapse Structural Conductor Surface 1,510 psi Intermediate Production 3,830 psi 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: Ryan LeMay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 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 See Schematic 10,880' 6,145' Length 7" Brown HS-16-1 Prod Pkr; N/A 10,652'MD/TVD; N/A 10,880' 10,832' 10,832' 22" Swanson River Unit (SRU) 34-28CO 716 & 716.001 Same 10,880'7" ~2500psi Swanson River Tyonek Undef Gas Size December 11, 2025 2-7/8" 10,880' Perforation Depth MD (ft): See Schematic 3,070 psi 34'34' 2,038' 34' 2,038' MD 11-3/4" 6.5# / N-80 TVD Burst 10,755' 6,340 psi 2,038' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028399 163-007 50-133-10158-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 12/11/25 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: Noel Nocas, Operations Manager 907-564-5278 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 m n P s t t N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.12.12 15:15:56 - 09'00' Noel Nocas (4361) 325-757 By Grace Christianson at 3:24 pm, Dec 12, 2025 TS 12/12/25 10-404 BJM 12/12/25 All conditions of approval on sundry 325-757 still apply. JLC 12/15/2025 12/15/25 Rig 401 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 401, WO Program Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with kill weight fluid. Note: Fluid level will fall to a depth that balances with reservoir pressure. Shoot fluid levels as needed. 3) Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger wont pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Fill well with KWF if the fluid is not to surface b) RU SL and set a tubing plug, test to MPSP on the sundry c) ND tree with no BPV Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. d) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads e) For ESP wells - Ensure that cap is on cable penetrator f) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Bryan McLellan (AOGCC bryan.mclellan@alaska.gov) and Mr. Jim Regg (AOGCC - jim.regg@alaska.gov) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) Rig 401 BOP Test Procedure Attachment #1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldnt hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. 4) * Note: A detailed BOP testing procedures will need to be agreed by the AOGCC inspector if they are witnessing the test. The test procedure is at the discretion of the inspectors. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold (PM1), close valves 8,10 &11 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross (K2), open PM1, close valves 5,7 & 9 on choke manifold, open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close manual and super choke / open valves 7 & 9 on choke manifold. Bleed pressure from step b or c recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. Rig 401 BOP Test Procedure Attachment #1 e) Close inside valve (K1) / open outside valve on kill side of mud cross (K2), close valves 2,4 & 6 / open valves 5,7 & 9 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. f) Close valves 1 & 3 / open valves 4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. g) Close HCR (CL2) open valves 2,4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Close inside valve (CL1) / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 11 on choke manifold, close valve 1,2 & 3 / open valve 11 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. j) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record Accumulator Pressure. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read 10 bottles at 2,150 psi). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the electric pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to Auto, not Manual so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Program Change: Rolling BOP Test Summary of Events SRU 34-28 12/10/25: N/U BOP Stack 12/11/25: o Attempt to shell test BOP and pressure leaking by threads of the BPV / TWCV tubing hanger pro le o Received verbal approval from AOGCC ~12:15 hrs to conduct a rolling BOP test to 2500 psi per provided rolling BOP test procedure. The rolling BOP test to 2500 psi was successful, witnessed, and approved by AOGCC rep Austin Mcleod and BLM rep Allie Schoessler. o Performed passing MIT on both tubing, IA, and cement plug in wellbore to 2500 psi for 30 min witnessed and approved by AOGCC rep Austin Mcleod and BLM rep Allie Schoessler. o Performed tubing cut and conducted another MIT on wellbore to 2500 psi for 30 min (passed and charted) to verify tubing cut did not compromise pressure integrity of wellbore. Received approval from Bryan McLellan that since tubing cut did not compromise wellbore integrity and the remainder of program steps are to be completed in tested cased hole, that the rolling BOP test is a su icient test to perform the remainder of well work, and a full BOP test is not further required per the rolling BOP test procedure at ~17:15 hrs on 12/11/2025 via phone call. Page 1/1 Well Name: SRF SRU 034-28 Report Printed: 12/12/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50133101580000 Field Name:Swanson River State/Province:ALASKA Permit to Drill (PTD) #:163007 Sundry #: Rig Name/No: Jobs Actual Start Date:11/21/2025 End Date: Report Number 3 Report Start Date 12/10/2025 Report End Date 12/11/2025 Last 24hr Summary Finish nippling down tree, prep wellhead and hanger . N/u 7" BOP stack. Connect choke, kill, and koomey lines. Function test BOP.R/u work floor. Tarp around stack . Mechanic install new drive on rig. Run and m/u circulating hoses. Continue winterizing. M/u 2-7/8" test joint. Blow air through circulating lines and BOPE to ensure they are clear. Run in test joint and fill BOPE. Report Number 4 Report Start Date 12/11/2025 Report End Date 12/12/2025 Last 24hr Summary Shell tested BOP's 250-5000psi. Leaking off on high. Troubleshoot and leak path at wellhead. Test Gas alarms while troubleshooting. Discussed plan forward with OE and AOGCC to conduct a rolling BOP test. Conducted Rolling BOP test as per procedure. 250psi Low/2500psi High. Preformed Koomey Drawdown test. Test witnessed by AGOCC Inspector Austin McLeod. MIT the Tubing and IA to 2500psi for 30mins with AGOCC and BLM witnessing. BOLD. Steam hanger for 30 minutes. P/u on landing joint, hanger unseats at 56k. R/u e-line. PT lubricator 250/2500psi, good test. RIH w/ 2.063" jet cutter, cut at 4340'. POOH. P/u on pipe, free travel 20k. R/d e-line. Pull hanger to surface and lay down. Fluid pack well. MIT IA to 2500psi charted for 30 minutes, good test. R/u to POOH. Mix corrosion inhibitor in pits. Circulate the well with 1% corrosion inhibited water. Page 40 Version 0.0 November 21, 2025 SRU 214A-27 Drilling Procedure 27.0 Surface Plat (As-Built NAD27 & NAD83) Page 41 Version 0.0 November 21, 2025 SRU 214A-27 Drilling Procedure STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________SWANSON RIV UNIT 34-28 JBR 01/26/2026 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 2-7/8" joint. Rolling test due to hanger threads leaking. Approved by Bryan McLellan. Test Results TEST DATA Rig Rep:Tyson RentonOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens Rig Owner/Rig No.:Hilcorp 401 PTD#:1630070 DATE:12/11/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM251215131313 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 2500 Sundry No: 325-673 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7-1/16"P #1 Rams 1 2-3/8"x3-1/2"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 1 2-1/16"P Kill Line Valves 3 2-1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2500 200 PSI Attained P11 Full Pressure Attained P34 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2000 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P7 #1 Rams P4 #2 Rams P4 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0       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 Other: ___________________ 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): 10,880' N/A Casing Collapse Structural Conductor Surface 1,510 psi Intermediate Production 3,830 psi 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: Ryan LeMay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 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 Noel Nocas, Operations Manager 907-564-5278 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): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028399 163-007 50-133-10158-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 6.5# / N-80 TVD Burst 10,755' 6,340 psi 2,038' 34' 2,038' MD See Schematic 3,070 psi 34'34' 2,038' November 10, 2025 2-7/8" 10,880' Perforation Depth MD (ft): 11-3/4" Swanson River Unit (SRU) 34-28CO 716 & 716.001 Same 10,880'7" ~2500psi Swanson River Tyonek Undef Gas Size See Schematic 10,880' 6,145' Length 7" Brown HS-16-1 Prod Pkr; N/A 10,652'MD/TVD; N/A 10,880' 10,832' 10,832' 22" m n P s t _ N 66 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 9:34 am, Oct 31, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.10.30 15:41:49 - 08'00' Noel Nocas (4361) 325-673 SFD -bjm Provide 24 hrs notice for AOGCC opportunity to witness MIT on existing wellbore to 2500 psi. Suspended well inspection is required within 12 months of approval of this sundry unless the well has been sidetracked before that date. SFD 11/5/2025 X BOP test to 2500 psi. X 11/1/2030 BJM 11/6/25 DSR-11/6/25 10-407 X Plug for Redrill Re-entry of susp well JLC 11/7/2025 11/07/25 Well Prognosis Well: SRU 34-28 02/01/2022 Well Name: SRU 34-28 API Number: 50-133-10158-00 Current Status: Shut In Permit to Drill Number: 163-007 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661)487-0871 (M) Second Call Engineer: Scott Warner (907) 830-8863 (M) Maximum Expected BHP: N/A Well has been plugged and abandoned above perforations. On 10/4/2025 preliminary diagnostics completed and well pressure tested to 2500 psi for 30 min - Good test. Max. Potential Surface Pressure:2500 psi Based on planned MIT test pressure for sidetrack prep. Pool / PA Depths: Tyonek 5,335 MD / TVD Beluga 4,609 MD / TVD Sterling Upper Beluga 2,311 MD / TVD Brief Well Summary - SRU 34-28 was drilled in 1963, targeting the Hemlock oil formation. 34-28 produced 1.6 MMSTB from the Hemlock from 1963-1999. - In 2004, this well was recompleted to the Tyonek formation with a cement packer (IA squeeze) completion. - In December 2005, a through-tubing gravel pack install was attempted, but ultimately unsuccessful due to mechanical issues. - SRU 34-28 remained SI for a few years, coming back online in July 2008 after the Tyonek 62-5L and 62- 5M were isolated and the Tyonek 62-4 perorated. The new perforations did little to redeem production; gas rates never exceeded ~300 MCFD. - SRU 34-28 sat idle between October 2009 September 2014 - As of 2015, the well has been plugged and abandoned up to 4,555 in the 2-7/8 x 7 annulus and 4,410 in the 2-7/8 tubing. The purpose of this Sundry is to prepare the well to be sidetracked. purpose of this Sundry is to prepare the well to be sidetracked Well Prognosis Well: SRU 34-28 02/01/2022 Procedure: 1. Perform MIT on wellbore / existing cement plug to 2500 psi for 30 min. a. Provide AOGCC 24 hours notice to witness MIT. b. Provide BLM 48 hours notice for commencement of operations. c. Use a chart recorder or digital crystal gauge to record MIT pressure test. 2. MIRU E-line and pressure control equipment 3. PT lubricator to 250 psi low / 2,500 psi high 4. RIH and cut tubing at + 4,340 (10-15 above GLM # 7 in schematic) 5. RDMO E-line 6. MIRU 401 workover rig 7. Install TWCV, N/D production tree 8. N/U and pressure test BOPE a. Provide AOGCC 24 hour to witness BOPE test. b. Pressure test 250 psi low / 2500 psi high c. BOP planned to be dressed with 2-3/8 3-1/2 VBRs d. Test with 2-7/8 test joint 9. Pull TWCV 10. Circulate in corrosion inhibited water from cut depth of + 4,340 to surface. 11. Unland hanger and POOH w/ cut 2-7/8 tubing completion from + 4,340 to surface. 12. RU E-line. 13. RIH and set 7 CIBP at + 3075. a. Pressure up to 2500 psi for 30 min. Use a chart recorder or crystal gauge to record CIBP + casing test. b. Dump bail minimum of 35 cement on top of plug leaving TOC at + 3040 c. Planned KOP for sidetrack at + 3020 MD 14. RDMO E-line 15. N/D BOP and N/U dry hole tree. 16. RDMO rig 401. Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Rig 401 BOP Diagram 7-1/16 Planned KOP for sidetrack at + 3020 MD API: 50-133-10158-00 Downhole Revised: 2/03/15 Revised By DMA 09-18-20 Swanson River Unit Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 ACTUAL SCHEMATIC PBTD = 4,410 MD / 4,410 TVD TD = 10,880 MD / 10,880 TVD Max Deviation = 1.5 deg @ 4,345 RKB: 184 / GL: 164 AMSL KB THF: 20.05 1 22 34 11-3/4 2,038 7 10,880 CBL TOC 8,930 H-1 H-2 12 13 14 11 9 5 4 3 2 CBL TOC 2,950 62-4 CC D 19 18 15 17 10 16 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22 Conductor - - - Surf. 34 - Yes Surf. 11-¾ Surface 47 J-55 STC Surf. 2,038 16 2,040 1,400 sx Surf. 7 Production 29 N-80 BTC Surf. 104 9- 10,880 1,100 sx 2,950 CBL 23 104 4,618 26 LTC 4,618 6,016 DV Collar 6,016 6,018 7 Production 26 N-80 LTC 6,018 6,616 700 sx 8,930 CBL 29 6,616 8,495 29 P-110 8,495 10,880 Tubing Detail Conn ID Cplg OD 2.875 Tubing 6.5 N-80 8RD Surface 10,755 2.441 3.668 Jewelry Detail No. Depth Length ID OD Item 1 20.05 1.70 2.441 - Tbg Hngr 2 1,498 12.82 2.867 5.968 3-1/2 Camco MM GLM #12, XO to 2-7/8 3 2,484 12.79 2.867 5.968 3-1/2 Camco MM GLM #11, XO to 2-7/8 4 3,489 12.72 2.867 5.968 3-1/2 Camco MM GLM #10, XO to 2-7/8 5 3,701 12.77 2.867 5.968 3-1/2 Camco MM GLM #9, XO to 2-7/8 6 4,059 13.05 2.867 5.968 3-1/2 Camco MM GLM #8, XO to 2-7/8 7 4,354 13.00 2.867 5.968 3-1/2 Camco MM GLM #7, XO to 2-7/8 8 5,526 13.08 2.867 5.968 3-1/2 Camco MM GLM #6, XO to 2-7/8 (Drift w/ 2.343) 9 6,517 13.05 2.867 5.968 3-1/2 Camco MM GLM #5, XO to 2-7/8 10 6,550 - - 2.180 HES EZ Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411 12.77 2.867 5.968 3-1/2 Camco MM GLM #4, XO to 2-7/8 12 8,146 13.03 2.867 5.968 3-1/2 Camco MM GLM #3, XO to 2-7/8 13 9,387 12.69 2.867 5.968 3-1/2 Camco MM GLM #2, XO to 2-7/8 14 10,598 12.74 2.867 5.968 3-1/2 Camco MM GLM #1, XO to 2-7/8 15 10,643 1.07 2.438 3.688 Brown CC Safety Joint 16 10,652 6.02 2.500 5.875 Brown Retrievable Production Packer, Model HS-16-1 17 10,676 - - 2.180 HES EZ Drill Cmt Retainer (Set on wireline 6/09/04) 18 10,690 0.95 2.250 3.668 CamcoD Profile Nipple, w/ Stuck Plug (Fish) 19 10,755 0.67 2.441 3.688 WLEG Venturi Shoe Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235 6,245 6,235 6,245 10 4 2 PowerJet 7/01/08 62-4 6,244 6,254 6,244 6,254 10 6 Isolated 6/25/04 62-5 6,260 6,270 6,260 6,270 10 6 Isolated 8/22/04 62-5 6,265 6,275 6,265 6,275 10 6 Isolated 6/17/04 Sqz A 6,335 6,345 6,335 6,345 10 4 2 PowerJet 5/11/63 WSO 10,707 10,708 10,707 10,708 1 5 Isolated 5/13/63 H-1 10,716 10,725 10,716 10,725 9 4 Isolated 5/13/63 H-2 10,737 10,762 10,737 10,762 25 4 Isolated 62-5 Sqz A Sqz B 8 7 6 Temp Log TOC 5,470 Cement 6,255 Top of Fill 6,289 Tbg Punch 10,163 Tbg Punch 10,681 Top of Fill 10,738 Damaged GLM 5,526 Cement 6,145 Soft Cement 6,197 Tbg Punch Holes 4,820-4,823 (12) 4,930-4,933 (18) 5,030-5,033 (18) 5,130-5,133 (12) 5,230-5,233 (18) 5,340-5,344 (24) 5,440-5,444 (24) Cement in Tubing (Tagged 2/03/15) 4,410-4,820 Cement in Casing (Estimated) 4,555-4,820 Cement Residue 4,930-5,470 CBL TOC 2,950 CBL TOC 8,930 API: 50-133-10158-00 Downhole Revised: 2/03/15 Revised By RPL 10/27/2025 Swanson River Unit Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 SCHEMATIC Proposed PBTD = 4,410 MD / 4,410 TVD TD = 10,880 MD / 10,880 TVD Max Deviation = 1.5 deg @ 4,345 RKB: 184 / GL: 164 AMSL KB THF: 20.05 22 34 11-3/4 2,038 7 10,880 CBL TOC 8,930 H-1 H-2 7 8 9 6 4 CBL TOC 2,950 62-4 CC D 14 13 10 12 5 11 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22 Conductor - - - Surf. 34 - Yes Surf. 11-¾ Surface 47 J-55 STC Surf. 2,038 16 2,040 1,400 sx Surf. 7 Production 29 N-80 BTC Surf. 104 9- 10,880 1,100 sx 2,950 CBL 23 104 4,618 26 LTC 4,618 6,016 DV Collar 6,016 6,018 7 Production 26 N-80 LTC 6,018 6,616 700 sx 8,930 CBL 29 6,616 8,495 29 P-110 8,495 10,880 Tubing Detail Conn ID Cplg OD 2.875 Tubing 6.5 N-80 8RD + 4,340 10,755 2.441 3.668 Jewelry Detail No. Depth Length ID OD Item 1 + 3,075 7 CIBP + 35 cement (Proposed) 2 4,354 13.00 2.867 5.968 3-1/2 Camco MM GLM #7, XO to 2-7/8 3 5,526 13.08 2.867 5.968 3-1/2 Camco MM GLM #6, XO to 2-7/8 (Drift w/ 2.343) 4 6,517 13.05 2.867 5.968 3-1/2 Camco MM GLM #5, XO to 2-7/8 5 6,550 - - 2.180 HES EZ Drill Cmt Retainer (Set on wireline 6/14/04) 6 7,411 12.77 2.867 5.968 3-1/2 Camco MM GLM #4, XO to 2-7/8 7 8,146 13.03 2.867 5.968 3-1/2 Camco MM GLM #3, XO to 2-7/8 8 9,387 12.69 2.867 5.968 3-1/2 Camco MM GLM #2, XO to 2-7/8 9 10,598 12.74 2.867 5.968 3-1/2 Camco MM GLM #1, XO to 2-7/8 10 10,643 1.07 2.438 3.688 Brown CC Safety Joint 11 10,652 6.02 2.500 5.875 Brown Retrievable Production Packer, Model HS-16-1 12 10,676 - - 2.180 HES EZ Drill Cmt Retainer (Set on wireline 6/09/04) 13 10,690 0.95 2.250 3.668 CamcoD Profile Nipple, w/ Stuck Plug (Fish) 14 10,755 0.67 2.441 3.688 WLEG Venturi Shoe Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235 6,245 6,235 6,245 10 4 2 PowerJet 7/01/08 62-4 6,244 6,254 6,244 6,254 10 6 Isolated 6/25/04 62-5 6,260 6,270 6,260 6,270 10 6 Isolated 8/22/04 62-5 6,265 6,275 6,265 6,275 10 6 Isolated 6/17/04 Sqz A 6,335 6,345 6,335 6,345 10 4 2 PowerJet 5/11/63 WSO 10,707 10,708 10,707 10,708 1 5 Isolated 5/13/63 H-1 10,716 10,725 10,716 10,725 9 4 Isolated 5/13/63 H-2 10,737 10,762 10,737 10,762 25 4 Isolated 62-5 Sqz A Sqz B 3 2 Temp Log TOC 5,470 Cement 6,255 Top of Fill 6,289 Tbg Punch 10,163 Tbg Punch 10,681 Top of Fill 10,738 Damaged GLM 5,526 Cement 6,145 Soft Cement 6,197 Tbg Punch Holes 4,820-4,823 (12) 4,930-4,933 (18) 5,030-5,033 (18) 5,130-5,133 (12) 5,230-5,233 (18) 5,340-5,344 (24) 5,440-5,444 (24) Cement in Tubing (Tagged 2/03/15) 4,410-4,820 Cement in Casing (Estimated) 4,555-4,820 Cement Residue 4,930-5,470 Corrosion inhibited water 1 Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 163-007 SFD 10/31/2025 SRU 34-28 325-673 SFD 10/31/2025 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Lemay To:McLellan, Bryan J (OGC); Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Starns, Ted C (OGC) Subject:[WARNING: UNSCANNABLE EXTRACTION FAILED]RE: [EXTERNAL] [WARNING: ATTACHMENT UNSCANNED] [WARNING: UNSCANNABLE EXTRACTION FAILED]RE: SRU 34-28 (PTD 163-007, Sundry 325-673) - Question Date:Monday, November 3, 2025 12:06:29 PM Attachments:WARNING UNSCANNABLE EXTRACTION FAILEDRE EXTERNAL SRU 34-28 (PTD 163-007) plug for redrill.msg Thanks Bryan for sending the bond log through. Steve 1. The KOP was chosen based on directional plan to have room to hit planned subsurface reservoir targets while minimizing DLS and trying to keep inclination under 70 degrees 2. For timing, we are looking to pick up the workover rig around 12/8-12/9/2025 to perform the sidetrack prep covered under this Sundry submitted. Then the sidetrack itself would currently not be planned to be started until mid to late January of 2026. Please let me know if you have any further questions after reviewing the bond log. Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, November 3, 2025 11:02 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Ryan Lemay <ryan.lemay@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. <ted.starns@alaska.gov> Subject: [EXTERNAL] [WARNING: ATTACHMENT UNSCANNED][WARNING: UNSCANNABLE EXTRACTION FAILED]RE: SRU 34-28 (PTD 163-007, Sundry 325-673) - Question Steve, Ryan sent me the bond log earlier this morning. See attached. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, November 3, 2025 9:39 AM To: Ryan Lemay <ryan.lemay@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: SRU 34-28 (PTD 163-007, Sundry 325-673) - Question Hello Ryan, I'm reviewing Hilcorp Alaska, LLC's Sundry Application for SRU 34-28 and I have a few questions. This is quite an old well, and I'm curious about the quality of the Stage 2 cement across Hilcorp's planned KOP of about 3020' MD. Could you please send me a screenshot of the CBL across that interval that displays Hilcorp's pick for the top of cement at 2950' MD and your interpretation of the quality of bonding across the planned KOP interval? How was this KOP depth determined? When does Hilcorp plan to spud the redrill of this well? Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Reviewed By: P.I. 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Hunt 8/2/2024 2024-0802_Suspend_SRU_34-28_photo_jh Page 2 of 4 2024-0802_Suspend_SRU_34-28_photo_jh Page 3 of 4 Tubing pressure Tubing-Casing Annulus (IA) pressure 2024-0802_Suspend_SRU_34-28_photo_jh Page 4 of 4 Casing-Casing Annulus (OA) pressure Well Cellar 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,880 feet 4,410 feet true vertical 10,880 feet 10,690 (fish) feet Effective Depth measured 4,410 feet 10,652 feet true vertical 4,410 feet 10,652 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / N-80 10,755' MD 10,755' TVD N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)7" Brown HS-16-1Pkr 10,652' MD 10,652' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 34' 2,038' 0 Oil-Bbl measured true vertical Packer 7"10,880' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Tyonek Undef GasN/A measured TVD Tubing Pressure 00 Swanson River Unit (SRU) 34-28 N/A FEDA028399 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 163-007 50-133-10158-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 34' 2,038' 10,880' Conductor Surface Intermediate Production 3,830psi Casing Structural 22" 11-34" Length 10,880' 3,070psi Collapse 1,510psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 6,340psi 34' 2,038' t Fra O 6. A G L PG , R n Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:45 am, Sep 23, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.22 17:01:12 -08'00' Taylor Wellman SFD 9/24/2020 SUSPP DSR-9/24/2020gls 10/21/20 Suspended Well Inspectionn SFD 9/24/2020RBDMS HEW 9/23/2020 KEN June 2020 Suspended Well Inspection Data Well: Swanson Riv Unit 34-28 Surface Location: 660’ FSL, 1,520’ FEL, Sec. 28, T8N, R9W, S.M. Permit to Drill: 163-007 API: 50-133-10158-00-00 AOGCC Inspection Date: 09/04/20 AOGCC Inspector: Lou Laubenstein Hilcorp Representative: Jake Paulk Size Pressure (psi) Tubing 2-7/8” 0 Casing 7” 0 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore API: 50-133-10158-00 Downhole Revised: 2/03/15 Revised By DMA 09-18-20 Swanson River Unit Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 ACTUAL SCHEMATIC PBTD = 4,410’ MD / 4,410’ TVD TD = 10,880’ MD / 10,880’ TVD Max Deviation = 1.5 deg @ 4,345’ RKB: 184’ / GL: 164’ AMSL KB – THF: 20.05’ 1 22” 34’ 11-3/4” 2,038’ 7” 10,880’ CBL TOC 8,930’ H-1 H-2 12 13 14 11 9 5 4 3 2 CBL TOC 2,950’ 62-4 CC D 19 18 15 17 10 16 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22” Conductor - - - Surf. 34’ - Yes Surf. 11-¾” Surface 47 J-55 STC Surf. 2,038’ 16” 2,040’ 1,400 sx Surf. 7” Production 29 N-80 BTC Surf. 104’ 9-з” 10,880’ 1,100 sx 2,950’ CBL 23 104’ 4,618’ 26 LTC 4,618’ 6,016’ DV Collar 6,016’ 6,018’ 7” Production 26 N-80 LTC 6,018’ 6,616’ 700 sx 8,930’ CBL 29 6,616’ 8,495’ 29 P-110 8,495’ 10,880’ Tubing Detail Conn ID Cplg OD 2.875” Tubing 6.5 N-80 8RD Surface 10,755’ 2.441” 3.668” Jewelry Detail No. Depth Length ID OD Item 1 20.05’ 1.70’ 2.441” - Tbg Hngr 2 1,498’ 12.82’ 2.867” 5.968” 3-1/2” Camco MM GLM #12, XO to 2-7/8” 3 2,484’ 12.79’ 2.867” 5.968” 3-1/2” Camco MM GLM #11, XO to 2-7/8” 4 3,489’ 12.72’ 2.867” 5.968” 3-1/2” Camco MM GLM #10, XO to 2-7/8” 5 3,701’ 12.77’ 2.867” 5.968” 3-1/2” Camco MM GLM #9, XO to 2-7/8” 6 4,059’ 13.05’ 2.867” 5.968” 3-1/2” Camco MM GLM #8, XO to 2-7/8” 7 4,354’ 13.00’ 2.867” 5.968” 3-1/2” Camco MM GLM #7, XO to 2-7/8” 8 5,526’ 13.08’ 2.867” 5.968” 3-1/2” Camco MM GLM #6, XO to 2-7/8” (Drift w/ 2.343”) 9 6,517’ 13.05’ 2.867” 5.968” 3-1/2” Camco MM GLM #5, XO to 2-7/8” 10 6,550’ - - 2.180” HES “EZ” Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411’ 12.77’ 2.867” 5.968” 3-1/2” Camco MM GLM #4, XO to 2-7/8” 12 8,146’ 13.03’ 2.867” 5.968” 3-1/2” Camco MM GLM #3, XO to 2-7/8” 13 9,387’ 12.69’ 2.867” 5.968” 3-1/2” Camco MM GLM #2, XO to 2-7/8” 14 10,598’ 12.74’ 2.867” 5.968” 3-1/2” Camco MM GLM #1, XO to 2-7/8” 15 10,643’ 1.07’ 2.438” 3.688” Brown CC Safety Joint 16 10,652’ 6.02’ 2.500” 5.875” Brown Retrievable Production Packer, Model HS-16-1 17 10,676’ - - 2.180” HES “EZ” Drill Cmt Retainer (Set on wireline 6/09/04) 18 10,690’ 0.95’ 2.250” 3.668” Camco“D” Profile Nipple, w/ Stuck Plug (Fish) 19 10,755’ 0.67’ 2.441” 3.688” WLEG Venturi Shoe Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235’ 6,245’ 6,235’ 6,245’ 10’ 4 2” PowerJet 7/01/08 62-4 6,244’ 6,254’ 6,244’ 6,254’ 10’ 6 Isolated 6/25/04 62-5 6,260’ 6,270’ 6,260’ 6,270’ 10’ 6 Isolated 8/22/04 62-5 6,265’ 6,275’ 6,265’ 6,275’ 10’ 6 Isolated 6/17/04 Sqz A 6,335’ 6,345’ 6,335’ 6,345’ 10’ 4 2” PowerJet 5/11/63 WSO 10,707’ 10,708’ 10,707’ 10,708’ 1’ 5 Isolated 5/13/63 H-1 10,716’ 10,725’ 10,716’ 10,725’ 9’ 4 Isolated 5/13/63 H-2 10,737’ 10,762’ 10,737’ 10,762’ 25’ 4 Isolated 62-5 Sqz A Sqz B 8 7 6 Temp Log TOC 5,470’ Cement 6,255’ Top of Fill 6,289’ Tbg Punch 10,163’ Tbg Punch 10,681’ Top of Fill 10,738’ Damaged GLM 5,526’ Cement 6,145’ Soft Cement 6,197’ Tbg Punch Holes 4,820’-4,823’ (12) 4,930’-4,933’ (18) 5,030’-5,033’ (18) 5,130’-5,133’ (12) 5,230’-5,233’ (18) 5,340’-5,344’ (24) 5,440’-5,444’ (24) Cement in Tubing (Tagged 2/03/15) 4,410’-4,820’ Cement in Casing (Estimated) 4,555’-4,820’ Cement Residue 4,930’-5,470’ P Y " Q *! !! ! ! ! ! !!' PP Y " Q Q '' YSRU 34-28 S008N009W SWANSON RIVER FIELD KGSF 7A SRU_34-28 KGSF 1 SRU_41-33 SRU_241-33 KGSF 7AKGSF1 KGSF 7SRU_14B-27SRU_13-27SRU_241-33 SRU 21-33 Pad SRU 34-28 Pad SRU 41-33 Pad SRU 43-28 Pad Sec. 27 Sec. 28 Sec. 34 Sec. 33 0 250 500 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 SWANSON RIVER SRU 34-28 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol'Other "Gas Storage'Oil Q P&A P SHUT-IN Y Suspended Suspended Well Inspection Review Report InspectNo: susLOL200908104802 Date Inspected: 9/4/2020 Inspector: Lou Laubenstein - Type of Inspection: Subsequent Well Name: SWANSON RIV UNIT 34-28 Date AOGCC Notified: 8/25/2020 Permit Number: 1630070 Operator: Nilcorp Alaska, LLC Suspension Approval: Sundry rr 314-498 Operator Rep: Daniel Paulk Suspension Date: 9/24/2014 Wellbore Diagram Avail? ❑� Location Verified? W Photos Taken? ❑� If Verified, Now? GPS - Offshore? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar?O IA: 0 BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition The wellhead was in good condition, there was no signs of leakage or issues. Condition of Cellar The cellar was in good condition with some water present and a very small sheen that was cleaned up. Su: rounding Surface Condition The pad surrounding the wellhead was clear of any debis or contamination. ' Comments Supervisor Comrnents Photos (3) �jbp- l bI (2Azwz. Monday, October 12, 2020 Y qki a i RS rnco .� Qn M O 0) op 06 FIT 00 co 0 oi i�r = C'N f— :r W O� Q U U) 40 > —O 1= M W _j 40'- . .r CM LL —0 Lt1U) LO Q Z-0 W U � Q k u.. a CL w s k U O STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations J Fracture Stimulate ❑ Pull Tubing J Operations shutdown J Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection❑i 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ k 163-007 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 - 50-133-10158-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: FEDA028399• ' Swanson River Unit(SRU)34-28 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A a Swanson River/Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured ' 10,880 feet Plugs measured 4,410 eFC EIVE1 true vertical , 10,880 feet Junk measured 10,690(fish) feet SEP 1 1 2015 Effective Depth measured 10,832 feet Packer measured 10,652 feetOVC true vertical 10,832 feet true vertical 10,652 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070 psi 1,510 psi Intermediate Production 10,880' 7" 10,880' 10,880' 6,340 psi 3,830 psi Liner SCANNED DEC 1 52015 Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/N-80 10,755'MD 10,755'TVD N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) 7"Brown HS-16-1Pkr 10,652'MD 10,652'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development 0 r Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL H Printed and Electronic Fracture Stimulation Data H GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ . SUSP 0 SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Joe Kaiser Email jkaiser@hilcorp.com Printed Name Joe Kaiser Title Operations Engineer Signature i7/11:774.— ge- Phone 907-777-8393 Date ihlis p cf ./7 f�J Form 10-404 Revised 5/2015 ltBDMS l�$EP 15 2015 Submit Original Only ' / 1/;7 _,....-- (� 7 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 Inspector: Jeff Jones Operator: Hilcorp Alaska Well Name: Swanson River Unit 34-28 Oper. Rep: Rick Musgrove PTD No.: 163-007 Oper.Phone: 907-283-2551 Location Verified? Yes Oper.Email: rmusgrove@hilcorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 09/20/14 Date AOGCC Notified: 08/04/15 Sundry No.: 314-677 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 145 OA 0 Condition of Wellhead: Good condition,valves and gauges operable. No visable leaks. Condition of Surrounding Surface Location: Good,clean,gravel pad.Concrete and galvanized culvert well cellar. Follow Up Actions Needed: None Comments: Location verified by well sign. Lat. 60.7501429605345 Long. -150.859908176323 Attachments: REVIEWED BY: Insp.Supry Comm PLB 12/2014 SRU 34-28 Suspended Well Inspection Form • • II ACTUAL SCHEMATIC Swanson River Unit Well: SRU 34-28 nii,.,.nMask.1,.r, Completion Ran: 5/15/1963 API: 50-133-10158-00 PTD: 163-007 RKB:184'/GL:164'AMSL KB-THF:20.05' Casing Detail 22 -}! $- 1 t Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 34' 22" Conductor - - - Surf. 34' - Yes Surf. 11-3/4" Surface 47 J-55 STC Surf. 2,038' 20, 1,400 sx Surf. Il . 2 29 BTC Surf. 104' 7" Production 23 N-80 104' 4,618' 2,950' 1,100 sx 11-3/4".. • 26 LTC 4,618' 6,016' CBL 2,038' `� 3 4... DV Collar 6,016' 6,018'r ti 10,880' 26 6,018' 6,616' CBL TOC , •; 7" Production 29 N-80 LTC 6,616' 8,495' 700sx 8,930' 2,950' • A"; 29 P-110 8,495' 10,880' CBL 4 Tubing Detail Conn ID CplgOD 5 2.875" � Tubing I 6.5 � N-80 � 8RD I Surface 10,755' 2.441" 3.668" +* Cement in Tubine ITa¢aed 2/03/151 Tbg Punch Holes 6 4,410'-4,820' 4,820'-4,823'(12) Cement in Casing(Estimated) 4,930'-4,933'(18) 4,555'-4,820' 5,030'-5,033'(18) WIZ it 7 Damaged --- " 5,130'-5,133'(12) GLM ,,, •;}}i},; -i�. 5,230'-5,233'(18) '- -'^,-""'-.� Cement Residue 5,526' w," ri•:3;r •��--- 5,340'-5,344'(24) '8'13" 4,930'-5,470' 5,440'-5,444'(24) Jewelry Detail ' Temp Log No. Depth Length ID OD Item Cement TOC 1 20.05' 1.70' 2.441" - Tbg Hngr 6,145'-v. � ,, 5,470' 2 1,498' 12.82' 2.867" 5.968" 3-1/2"Camco MM GLM#12,XO to 2-7/8" 3 2,484' 12.79' 2.867" 5.968" _ 3-1/2"Camco MM GLM#11,XO to 2-7/8" Soft ▪y{1f Sqz B 4 3,489' 12.72' 2.867" 5.968" 3-1/2"Camco MM GLM#10,XO to 2-7/8" r•r• Cement��;}tir 62.4 5 3,701' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#9,XO to 2-7/8" 6,197' -.V4.1: 6 4,059' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#8,XO to 2-7/8" Cement.„..----"' 62-5 7 4,354' 13.00' 2.867" 5.968" 3-1/2"Camco MM GLM#7,XO to 2-7/8" 6,255' Sqz A 8 5,526' 13.08' 2.867" 5.968" 3-1/2"Camco MM GLM#6,XO to 2-7/8"(Drift w/2.343") Top of Fill ..*:::;.•:1 9 6,517' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#5,XO to 2-7/8" 6,289' I - ;; 9 10 6,550' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/14/04) At.1, 1,0 11 7,411' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#4,XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2"Camco MM GLM#3,XO to 2-7/8" I Ill 1.1* 13 9,387' 12.69' 2.867" 5.968" 3-1/2"Camco MM GLM#2,XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2"Camco MM GLM#1,XO to 2-7/8" 12 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint CBL TOC 16 10,652' 6.02' 2.500" 5.875" _ Brown Retrievable Production Packer,Model HS-16-1 8,930' 13 ,:i 17 10,676' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/09/04) i ' 18 10,690' 0.95' 2.250" 3.668" Camco"D"Profile Nipple,w/Stuck Plug(Fish) hl 14 19 10,755' 0.67' 2.441" 3.688" WLEG Venturi Shoe Tbg Punch cd I5 . 10,163' L Perforation History :`•"1,' +1' 1--- 16 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2"PowerJet 17 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 Isolated Tbg Punch 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 18 10,681' . 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated r Top of Fill };} H-1 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2"PowerJet 'VI* 19 10,738' j1L?r.11?r▪ 11rti1r11r'tiyr.Syl.��{y.,� 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated r.r.r.r. r r,rH_2 tr1r•1r•:r5•rr1r.tir:::::.ffr rf r.ff \.r..r.:* 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated 7„ 10,880' M.1.1yr 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated TD=10,880' PBTD=10,832' Max Deviation=1.5 deg @ 4,345' Downhole Revised:2/03/15 Revised By STP 3/02/15 • • Nif , SWANSON RIVER UNIT 34-28(SRU34-28) API 50.131,10158,C0-00 'ID 9 163-007 LEASE FED A028399 r BMW SIJRFACE LOCATION ,, SW1/4,SEI/4,SEC 28 TIN R9W,SM,AK * II .• - • 0 • ' 4 At. ,P.• 4„, • t , , • ' • ' - L ';'. , :71 . • . • .,0„.• S Al ON R V wL ELL NO. SRU 34-28 °SW 1 4 SE 1 4 SECTION 28 T(04 R 9W SE' •; r j ik4474, • 11111116' • • • 4 •1';-- ' ', .- '' i H ' . t'r! \ 4M1- iq.y. 1 " .,, ,. s.•:ma,..-'- ..;-7. ;:; ...7.4.,‘ .._,,.. ........ ,..y... .i...„. ...4, .12'1,t7-"Z 4...;',5f- ' li. N "41 - fir, I� ii S ii. . ' i A \ ` /' ; ifi 1 � * �..- , , , f .. - . :',.16'.,:, I j. 1,1 ij z ;, E • SRU 23B-22 • Hilcorp Alaska — Suspended Well Location Quarter Mile Radius Map SRU 41-28 SRU 34-28 0 1 000 2,000 FEET POSTED WELL DATA Well Label • KGSF 7 KGS WELL SYMBOLS ,,O+,' Abandoned Well Dry Hole • • Oil Well Shut-in Well SRU 43-28 D. Suspended Well _ KGSF 2 September 2,2015 CD(t) KcSF7A °SF SRU 31 SRU 223-28 SRU 34-28 • SRU 141 SRU _.._.._---- 2T-33 — 211-33 �r SRU 21 SRU 41-33WD SRU 31-33WD • SRU 32-33WD SRU 32A-33 — SRU 41-33 1J' SRU 32-33 PETRA 9/2/2015 9'.39'.12 AM • S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 Inspector: Jeff Jones Operator: Hilcorp Well Name: SRF 34-28 Oper.Rep: Rick Musgrove PTD No: 163-007 Oper.Phone: 907-283-2551 Location Verified? Yes Oper. Email: musorove( hilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 09/20/14 Date AOGCC Notified: 08/04/15 - Sundry No.: 314-677 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 145 OA 0 ' Condition of Wellhead: Good condition,valves and guages operable,no visible leaks. No flow line connected. - Condition of Surrounding Surface Location: Good,clean gravel pad, Follow Up Actions Needed: None Comments: • Lat/Long taken from well sign Attachments: Photo(1) - REVIEWED BY: Well schematic Insp.Supry , lZ1Z3lrrj Comm SCANNED SEP 0 7 2016 PLB 06/2014 SWI Hilcorp SRF 34-28 8-26-15 JJ.xls • • Suspended Well Inspection—Swanson River Unit 34-28 PTD 1630070 Photo by AOGCC Inspector J. Jones 8/26/2015 m a* ,et,:'. R :. Lit 1 r N 1,) :.. 1"--.• i f--1,. "fly, .�. "fi-aa.:,....-4"- !t.7 E '4 ,4," .., .... ,:...,, , „: L. ,.. ,. . _. ,. ,s.,......., . ,„,..,,,,, ..., ,, ._,,,i,.. _„, _...,.., ;,..„ ,.,,...... 0. t .„...„. 1 ., •........... i „,.. .., .. .; 4, : ..„: „1..„.4. _ .4,4.'''- .,,,,,,,„ .,,proi- -* '').-„ ..t ._P .. P bp,Alille 4,, r C ' litif II* .\. - /_ ;,S , ,S1, ' ` / III . / / / .\ \ \ '\,-\ \\\\\\N .4. \\,s NN,N,,, ,mg 2015-0826_Suspend_SRU_34-28 photo jj.docx Page 1 of 1 • 0 • 11 ACTUAL �^ Swanson River Unit SCHEMATIC Well: SRU 34-28 tlIteoro Al k,..L1.0 Completion Ran: 5/15/1963 API: 50433-10158-00 PTD: 163-007 RKB:184'/GL:164'AMSL KB-THF:20.05' Casing Detail i Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22 aike 22" Conductor Surf. 34' Yes Surf. 34' t, F I1-'/." Surface 47 J-55 STC Surf. 2,038' 2,040' 1,400 sx Surf. 2 29 BTC Surf. 104' 7" Production 23 N-80 104' 4,618' 2,950'1,100 sx 11-3/4" ,' 26 LTC 4,618' 6,016' CBL 2,038' DV Collar 6,016' 6,018' 9 Y. 310,880' 26 N 80 6,018' 6,616' 8,930' CBL TOC 7" Production 29 LTC 6,616' 8,495' 700 sx 2,950' CBL 7, ,, , 'il 4 1 ' 29 P-110 8,495' 10,880' Tubing Detail Conn ID cplgoD OM �-' 2.875" I Tubing I 6.5 I N-80 I 8RD I Surface I 10,755' I l z 2.441" 3.668" 1 5 g Cement in Tubing(Tagged 2/03/15) Tbg Punch Holes 6 4,410'-4,820' 4,820'-4,823'(12) Cement in Casing(Estimated) 4,930'-4,933'(18) ot 4,555'-4,820' 5,030'-5,033'(18) Damaged , 5,130'-5,133'(12) GLM .411,,14$444k-, r,,,,,,r 5,230'-5,233'(18) 5,526' 8, ,,y Cement Residue 5,340'-5,344'(24) i 4,930'-5,470' Jewelry Detail 5,440'-5,444'(24) Temp Log No. Depth Length ID OD Item l'ItlUt...,',-r: 'r:, :„.„a mei ., TOC 1 20.05' 1.70' 2.441" - Tbg Hngr ,i 5,470' 2 1,498' 12.82' 2.867" 5.968" 3-1/2"Camco MM GLM#12,XO to 2-7/8" is 3 2,484' 12.79' 2.867" 5.968" 3-1/2"Camco MM GLM#11,XO to 2-7/8" Soft y' Sqz B 4 3,489' 12.72' 2.867" 5.968" 3-1/2"Camco MM GLM#10,XO to 2-7/8" Cement ' 62-4 5 3,701' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#9,XO to 2-7/8" 6,197' :` "? 6 4,059' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#8,XO to 2-7/8" Cement11r 62-5 7 4,354' 13.00' 2.867" 5.968" 3-1/2"Camco MM GLM#7,XO to 2-7/8" 6,255' Sqz A 8 5,526' 13.08' 2.867" 5.968" 3-1/2"Camco MM GLM#6,XO to 2-7/8"(Drift w/2.343") Top of Fill 9 6,517 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#5,X0 to 2-7/8" 11. 6.289' . 10 6,550' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/14/04) 'v+ 4 .µ 11 7,411' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#4,X0 to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2"Camco MM GLM#3,X0 to 2-7/8" 13 9,387' 12.69' 2.867" 5.968" 3-1/2"Camco MM GLM#2,XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2"Camco MM GLM#1,XO to 2-7/8" ^l1,,,g''' �' 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint CBL TOC H , 16 10,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer,Model HS-16-1 8,930 °; 17 10,676' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/09/04) 41 18 10,690' 0.95' 2.250" 3.668" Camco"D"Profile Nipple,w/Stuck Plug(Fish) 19 10,755' 0.67' 2.441" 3.688" WLEG Venturi Shoe .i';„"6. Tbg Punch rim i5 c'.' 10,163' 10,163' Perforation History fi- 16 Date Zone Tap(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments r=ate �� 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2"Powerlet II4•,i,t; ''7,T-, 177/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 Isolated ,an,. Tbg Punch 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 6' 10,681' ; 11°111 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated Top of Fill H-1 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2"Powerlet 10,738 ti�ti_. H-2 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated ti ti 1 L ti•iiiiitti. �..•.. 'F4: +,•. k'':.�• , 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated ». tititi•..ti.tititititi• 41 1 1.tiiR„iyh.,,ti, a 5/13/63 H-2 10,737 10,762' 10,737 10,762' 25' 4 Isolated 10,880' $IV is TD=10,880' PBTD=10,832' Max Deviation=1.5 deg @ 4,345' Downhole Revised: 2/03/15 Revised By SIP 3/02/15 STATE OF ALASKA • ALA...A OIL AND GAS CONSERVATION COMMI6SION la.Well Status: WELL COMPLETION OR RECOMPLETION REP1b RT AND LOG al ❑ Gas SPLUG ❑ Other 111Abandoned ❑ Suspended ► 20u.AC 25.105 2OMC 25.11 ' Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _0 '. Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Cony(Sus6or 12.Permit to DriN Number: Hilcorp Alaska,LLC Aband.: 2/4/2015 • 163-007/314-677 3.Address: 6.Date Spudded: 13.API Number 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 3/30/1963 50-i310158-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number. Surface: 660'FSL,1530'FEL,Sec 28,T8N,R9W,SM,AK 5/6/1963 Swanson River Unit(SRU)34-28. Top of Productive Horizon: 8.KB(ft above MSL): 184 ' 15.Field/Pool(s): GL(ft above MSL): 164 ' Total Depth: 660'FSL, 1530'FEL,Sec 28,T8N,R9W,SM,AK 9.Plug Back Depth(MD+TVD): Swanson River/Tyonek Undef Gas • • 10,832'MD/10,832'TVD. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 346204.0 • y-2467178.4 ' Zone- 4 • 10,880'MD/10,880'ND. FEDA028399 • TPI: x- y- Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 346204.0 y-2467178.4 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No Q 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) WA 21. Logs Obtained(List al logs here and submit electronic and printed information per 20AAC25.071): 22.Re-driN/Lateral Top Window MC/TVD: N/A 23. CASING,LINER AND CEMENTING RECORD VVT_PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFr. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" Surf 34' Surf 34' 8+97sx 0 11-3/4" J-55 Surf 2,038' Surf 2,038' 16" 1400 sx 0 7" 23-29 N-80 Surf 4,145 Surf 4,145' 10-5/8" 0 4,145' 6,016' 4,145' 6,016 9-5/8" 0 7" 26-29 ' N-80 6,016' 8,495' 6,016' 8,495' 9-5/8" 700+1100 sx 0 P-110 8,495' 10,880' 8,495' 10,880' 24.Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MDfTVD) Size and Number): 2-7/8" 10,755' 10,652'MD/10,652'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVED Was hydraulic used Yes 111 No ❑ • DEPTH INTERVAL(MD) AMOUNTAND KIND OF MATERIALUSED FEB 2 7 2015 Schou) AFT 2 4 201 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate — 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑✓ • Sidewall Cores Acquired? Yes ❑ No❑✓ - If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 10/2012 CONTINUED ON REVE S �2 �' Z - �� Submit original only i2i ►'-z�•/� ,o- v � ' RBDMS MAR 1 3 2015 /6 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes CI No - If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: Operations Summary,Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporhola(a,hilcorp.com Printed Name: Stan Porhola Title: Operations Engineer Signature: itA Phone: 907-777-8412 Date: Z7/LS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Vi Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 34-28 50-133-10158-00 163-007 1/8/15 2/4/15 Daily Operations: 01/08/2015-Thursday Held PJSM and RU Priority E-line on SRU 34-28. MU lubricator,tool string, and 2" x 4'tubing punch. Stab on well. PT lubricator to 250 psi low/2,000 psi high- replace several o-rings,good test. Pump 20 bbls lease water down tubing w/hot oil truck. Tubing full. Replace valve stem packing on 2 tree valves. RIH w/2" x 4'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 800 psi, casing @ 0 psi. Punch tubing from_5,440'-5,444'WLM (24 shots). Positive indication of firing, no change in pressure. Drop below holes and attempt to pump down tubing with no luck, POOH. OOH -all shots fired. Bleed down tubing to zero and pressure up to 1,000 psi on tubing with no communication to / casing. Build another 4'tubing punch. RIH w/2"x 4'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 900 psi, casing @ 0 psi. Punch tubing from 5,340'-5,344'WLM (24 shots). Positive indication of firing, no change in pressure. Drop below holes and attempt to pump down tubing with no luck, POOH. OOH - all shots fired. Bleed down tubing to zero and pressure up to 1,500 psi on tubing with no communication to casing. LD lubricator and secure well. RD Priority. Decision to run another tubing punch. RU Priority. Pump methanol down casing to ensure free. Casing free, pressure up backside to 350 psi with methanol. PT lubricator to 250 psi low/2,000 psi high,good test. RIH w/2"x 3'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 900 psi, casing @ 350 psi. Punch tubing from 5,230'-5,233' WLM (18 shots). Positive indication of firing, no change in pressure. POOH. OOH -all shots fired. Pressure up tubing to 1,500 psi with no communication to casing. Secure well and RD Priority and Pollard for night. 01/09/2015- Friday Held PJSM obtained permit. RU Priority E-line and Pollard Hot Oil truck on SRU 34-28. MU lubricator,tool string, and 2"x 3' tubing punch. Stab on well. PT lubricator to 250 psi low/2,000 psi high,good test. RIH w/2"x 3'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 900 psi,casing @ 350 psi. Punch tubing from 5,130'-5,133' WLM (12 shots). Positive indication of firing, no change in pressure. POOH. OOH -all shots fired. Pressure up tubing to 1,500 psi with no communication to casing. MU 3'tubing punch,troubleshoot tool issues. RIH w/2"x 3'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 900 psi,casing @ 350 psi. Punch tubing from 5,030'-5,033'WLM (18 shots). Positive indication of firing,tubing pressure falling. Bleed off SICP to 0 psi and SITP steady @ 200 psi. POOH. OOH -all shots fired. Pressure up tubing to 1,500 psi with no communication to casing. MU 3'tubing punch. RIH w/2"x 3'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 900 psi,casing @ 0 psi. Punch tubing from 4,930'-4,933'WLM (18 shots). Positive indication of firing,tubing pressure slowly fell to 0 psi, casing pressure unchanged @ 0 psi. POOH. OOH-all shots fired. Pressure up tubing to 1,500 psi with no communication to casing. MU 3'tubing punch. RIH w/2"x 3'tubing punch and correlate to GLM's on well schematic. Verify correlation. Pressure up tubing to 1,030 psi, casing @ 0 psi. Punch tubing from 4,820'-4,823'WLM (12 shots). Positive indication of firing,tubing and casing pressures quickly equalized @ 200 psi. POOH. OOH-all shots fired. Bled down tubing to zero,casing same. Pressure up tubing and casing to 500 psi-good communication. Bled to zero and established circulation,0.5 BPM @ 500 psi. LD lubricator and tool string. Secure well and RD Priority and Pollard. ----------- 01/20/2015-Tuesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 34-28 50-133-10158-00 163-007 1/8/15 2/4/15 Daily Operations: Held Pre Job JSA with SLB and Peak Vac Support. RU SLB Cement Pump Truck and associated equipment. Bled pressure off Tbg/Csg to the Return Tank. Pumped 10bbls of fresh water down the tbg and estabilsh circulations from csg to the return tank. Pre mixed tub with 10bbls of 15.6#cement. Pumped 10bbls of 15.6#cement, pumped a Sbbl fresh water spacer and 20bbls of PW down tbg to spot cement plug. RU SLM iron and RU the Triplex, pumped 50 gals of diesel down tbg for freeze protection. MDMO SLM Cementing and secured well. . 02/03/2015-Tuesday MIRU SL,Test Lub to 1,500psi,test ok. RIH w/ 1.75 sample bailer and tagged cement at 4,400'slm. POOH.Verified cement in sample bailer. RDMO SL. RU the triplex and a chart recorder. Pressured up on tbg to 1,500psi and charted for 30mins,test ok. Bleed off pressure and secured well. 02/04/2015-Wednesday RU the triplex and a chart recorder. Pressured up on casing to 1,500psi and charted for 30mins,test ok. Bleed off pressure and secured well. Swanson River Unit ACTUAL SCHEMATIC Well: SRU 34-28 u i o.o 11„ka,ticCompletion Ran: 5/15/1963 API: 50-133-10158-00 PTD: 163-007 RKB:184'/GL:164'AMSL KB-THF:20.05' Casing Detail 22 J. - 1 L Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22" Conductor - - - Surf. 34' - Yes Surf. 34' • . 11-'%<" Surface 47 J-55 STC Surf. 2,038' 2 040' 1,400 sx Surf. t 2 29 BTC Surf. 104' 7" Production 23 N-80 104' 4,618' 1,100sx 2,950' 11-3/4" • 26 LTC 4,618' 6,016' CBL 2,038' 3 DV Collar 6,016' 6,018'III 10,880' 26 6,018' 6,616' CBL TOC - • 7" Production 29 N 80 LTC 6,616' 8,495' 700 sx 8,930' 2,950' CBL Ifil 4 29 P-110 8,495' 10,880' . Tubing Detail Conn ID Cplg OD ( 5 . 2.875" I Tubing I 6.5 I N-80 I 8RD I Surface I 10,755' I I 2.441" 3.668" Cement in Tubing(Tagged 2/03/15) Tbg Punch Holes ;t =M 6 • 4,410'-4,820' 4,820'-4,823'(12)4g. t,J� . . Cement in Casing(Estimated) 4,930'-4,933'(18) i 4,555'4,820' 5,030'-5,033'(18) ,` (.' Dv".r- Damaged 5,130'-5,133'(12) N° GLM ;1f1ftif1. • .. ti 5,230'-5,233'(18) 5,526' :{:{{{.". ?•r{{{. Cement Residue 5,340'-5,344'(24) r'f' 'f'►Zit • °r 4,930'-5,470'• Jewelry Detail s,440's,444'(24) '' Temp Log No. Depth Length ID OD Item Cement TOC 1 20.05' 1.70' 2.441" - Tbg Hngr 6145' 5,470' 2 1,498' 12.82' 2.867" 5.968" 3-1/2"Camco MM GLM#12,XO to 2-7/8" 62-4 3 2,484' 12.79' 2.867" 5.968" 3-1/2"Camco MM GLM#11,XO to 2-7/8" Soft :ftifti Sqz B 4 3,489' 12.72' 2.867" 5.968" 3-1/2"Camco MM GLM#10,XO to 2-7/8" Cement .rti}ti 5 3,701' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#9,XO to 2-7/8" 6,197' Cement 6,255' };ti . •<62 5 6 4,059' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#8,XO to 2-7/8" 7 4,354' 13.00' 2.867" 5.968" 3-1/2"Camco MM GLM#7,XO to 2-7/8" "'Sqz A 8 5,526' 13.08' 2.867" 5.968" 3-1/2"Camco MM GLM#6,XO to 2-7/8"(Drift w/2.343") Top of Fill • 9,' 9 6,517' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#5,XO to 2-7/8" 6,289' iti;{; �. 10 6,550' 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/14/04) 981/4- )0 11 7,411' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#4,XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2"Camco MM GLM#3,XO to 2-7/8" ( 7,113 9,387' 12.69' 2.867" 5.968" 3-1/2"Camco MM GLM#2,XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2"Camco MM GLM#1,XO to 2-7/8" 112 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint CBL TOC 16 10,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer,Model HS-16-1 8,930' I V 13 17 10,676' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/09/04) 18 10,690' 0.95' 2.250" 3.668" Camco"D"Profile Nipple,w/Stuck Plug(Fish) 1rii 14 . 19 10,755' 0.67' 2.441" 3.688" WLEG Venturi Shoe i Tbg Punch CC 1s 10,163' Perforation History �"p •' 16 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments -� -� '' 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2"PowerJet 3 0 17 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN r , i �, Tbg Punch 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 10,681' +J `°.•l .1;'4dr 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated �' '' H-1 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2"Poweriet Top of Fill "�', f;;; 10,738' rid 19 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated ;tiftirtir::::5 ;.:Ti 3 H-2 r N'.1." ".11f1f1f1'.ti'.17.1. * 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated f.r. 11.1•Pr.r.T.-11: , 7„ -,1.ti.ti.ti.ti.ti.ti.ti.ti.ti.ti 1 }:}}}r}}f?}$f±ig• 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated 10,880' 4,r, ; TD=10,880' PBTD=10,832' Max Deviation=1.5 deg @ 4,345' Downhole Revised: 2/03/15 Revised By STP 2/04/15 • 11 NOON 7-7i 1 18 T \\ OCO _ \ ' 2 --- ! _---1400-'-___ \\ '... r 0— ,�-8JJ -- ` . . a. 60C } ... . 4 n W + 8 M r Z s ---CCZ ..,:_-:iiii-- \ , . /0"/ _ �1N9INt71111= "' VI NOON r. \ - _-600- " , 5- - 5 c: d 1 �------- - . \ ____ . / 0�9: \,`1HJINOIW ...�� C3 -007 Davies, Stephen F (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, February 09, 2015 11:32 AM To: Davies, Stephen F (DOA) Subject: RE: SRU 34-28 (PTD#163-007; Sundry#314-677): Additional Cement Plug Yes, These operations were just completed last week. Both the tubing and annulus were successfully tested. We are putting together the 10-407 for these operations. Stan From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, February 09, 2015 11:09 AM To: Stan Porhola Subject: SRU 34-28 (PTD #163-007; Sundry #314-677): Additional Cement Plug Stan, • Sundry#314-677 authorized Hilcorp to place an additional cement plug in SRU 34-28 to meet BLM requirement by punching holes in the tubing from 5800'to 5804' MD and squeezing cement. I couldn't find any record of a follow-up Sundry Report documenting these operations. Did Hilcorp perform the approved operations? If so, did Hilcorp subsequently pressure test well? Thanks, Steve Davies Senior Petroleum Geologist SCAM° (-.b 2 0201:1 Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 THE STATE GOVERNOR BILL WALKER Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Tyonek Undefined Gas Pool, SRU 34-28 Sundry Number: 314-677 Dear Mr. Porhola: � (c,3 -ooh 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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. DATED this .Z 3 day of December, 2014. Encl. Sincerely, 0400�� Daniel T. Seamount, Jr. Commissioner SCANNED JAN 0 5 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED DEC 19 2014 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ %1 Change Approved Program ❑ Suspend ❑ Plug Perforations ❑� • Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdovn ❑ Re-enter Susp. Wel ❑ Stimulate ❑ After Casing❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development E 1 Stratigraphic ❑ Service ❑ 163-007 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number. 50-133-10158-00 Anchorage, Alaska 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Swanson River Unit (SRU) 34-28 Will planned perforations require a spacing exception? Yes ❑ No ❑r 9. Property Designation (Lease Number): 10. Field/Pool(s): Swanson River / Tyonek Undef Gas Pool FEDA028399 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 1 Junk (measured): 10,880' 10,880' 10,832' 10,832' 6,145' WA Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070 psi 1,510 psi Intermediate Production 10,880' 7" 10,880' 10,880' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / N-80 10,755' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): 7" Brown HS -16-1 Prod Pkr; N/A 10,652'MD[TVD; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory n Stratigrap hic❑ Development n Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/30/14 Oil ❑ Gas Q WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email S Orhola hjlcor .comI Printed Name Stan Porhola Title Operations Engineer Signature Phone 907-777-8412 Date fly COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: n G�✓t GI �r4 fO /$Db S ► 5-, � 1ZCL� � ��t ter, r o ✓c'c� �r✓ ,7 o 474 0- ;Z �rria �� p ! v Pl a rvn 9 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: 1 �% 4v APPROVED BY Z J Z3 Approved by: COMMISSIONER THE COMMISSION Date: 17- / Z Z { ! n. �ia�� ,i�� Submit Form and Form 10-403 (Revised 10/2012) �* jf fi 1 V d■or 12 months from the date of approval. /�. Attachments in Duplicate l[[ 111' ` ll Jn � VV i'1 11/�� ,... ... ,.. , Hilcorp Alaska, U, Well Prognosis Well: SRU 34-28 Date: 12/19/2014 Well Name: SRU 34-28 API Number: 50-133-10158-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: December 301h, 2014 Rig: N/A Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 163-007 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881(M) AFE Number: Current Bottom Hole Pressure: — 2,500 psi @ 6,244' TVD (Flowing survey July 2008) Maximum Expected BHP: ~ 2,500 psi @ 6,244' TVD (Flowing survey July 2008) Max. Allowable Surface Pressure: — 1,876 psi (Based on possible reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Swanson River Unit SRU 34-28 was drilled as a grassroots well in March 1963 to target H-1 and H-2 oil reserves in the upper part of the Hemlock formation. In June 2004, the Hemlock was plugged back and the well completed in the Tyonek gas sands, the Tyonek 62-5 in 2004 and the Tyonek 62-4 in 2008. The well was shut-in and not on production. Cement was dumped across the open perfs in September 2014. A sundry was this work was submitted and approved by the AOGCC. However, no sundry was submitted to the BLM by mistake. The purpose of this work/sundry is to place an additional cement plug in this well per BLM requirements due to not filing a sundry notice with that agency for the previous cement plug dump bailed in the well. Notes Regarding Wellbore Condition • Last tag at 6,180' w/ 2.0" DD bailer on 9/24/14. Slickline Procedure: 1. MIRU Eline, PT Lubricator to 2,000 psi Hi, 250 Low. 2. RIH w/ 1-11/16" tbg punch and punch holes from 5,800'-5,804'. 3. POOH. RD Eline. 4. RU pumping unit. PT lines to 3,000 psi Hi. 5. Mix and pump 7 bbl (100% Excess) of 15.6 ppg cement as 100' balanced plug thru punch holes. 6. Displace cement with 30 bbl of 8.4 ppg lease water. Leave SITP at 100 psi. 7. RD pumping unit. Wait on cement for 48 hours. 8. MIRU Slickline, PT Lubricator to 2,000 psi Hi, 250 Low. 9. RU 1.75" bailer, RIH and tag fill/cement at +/- 5,700'. 10. Pressure test plug to 1,500 psi for 30 min down tubing. Attachments: 1. Actual Schematic 2. Proposed Schematic Hil o p Al -k.. LLC. API: 50-133-10158-00 RKB: 184'/ GL: 164' AMSL KB - TH F: 20.05' 22" 34' 11-3/4" a 2,038' CBLTOC 2,950' Damaged GLM 5,526' New Cement ' 6,145' Soft Cement 6,197' Cement 6,255' Top of Fill 6.289' CBLTOC 8,930' Top of Fill 10,738' CBL TO 5,800' Sqz B 62-4 62-5 Sqz A ACTUAL SCHEMATIC rasinrr nptail Swanson River Unit Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22" Conductor - 2 1,498' Surf. 34' - Yes Surf. 11-W Surface 47 J-55 STC Surf. 2,038'2 16" 0, 1,400 sx Surf. 7" Production 29 N-80 BTC Surf. 104' 10,880' 1,100 sx 2,950' CBL 23 104' 4,618' 26 LTC 4,618' 1 6,016' DV Collar 6,016' 6,018' 7" Production 26 N 80 LTC 6,018' 6,616' 700 sx 8,930' CBL 29 6,616' 8,495' 29 P-110 8,495' 10,880' Tubing Detail Conn ID CpIgOD 2.875" 1 Tubing 6.5 N-80 I 8RD Surface 1 10,755' 2.441" 3.668" Jewelry Detail No. Depth Length ID OD Item 1 20.05' 1.70' 2.441" - Tbg Hngr 2 1,498' 12.82' 2.867" 5.968" 3-1/2" Camco MM GLM #12, XO to 2-7/8" 3 2,484' 12.79' 2.867" 5.968" 3-1/2" Camco MM GLM #11, XO to 2-7/8" 4 3,489' 12.72' 2.867" 5.968" 3-1/2" Camco MM GLM #10, XO to 2-7/8" S 3,701' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #9, XO to 2-7/8" 6 4,059' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #8, XO to 2-7/8" 7 4,354' 13.00' 2.867" 5.968" 3-1/2" Camco MM GLM #7, XO to 2-7/8" 8 5,526' 13.08' 2.867" 5.968" 3-1/2" Camco MM GLM #6, XO to 2-7/8" (Drift w/ 2.343") 9 6,517' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #5, XO to 2-7/8" 10 6,550' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #4, XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 13 9,387' 12.69' 2.867" 5.968" 3-1/2" Camco MM GLM #2, XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2" Camco MM GLM #1, XO to 2-7/8" 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint 16 10,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer, Model HS -16-1 17 10,676 - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/09/04) 18 10,690 0.95' 2.250" 3.668" Camco"D" Profile Nipple, w/ Stuck Plug (Fish) 19 10.755' 1 0.67' 2.441" 3.688" WLEG Venturi Shoe Tbg Punch 10,163' 16 Tbg Punch 10, 681' H-1 H-2 7" A. fr'f'f'f'f'f' 10,880 TD = 10,880' PBTD = 10,832' Max Deviation = 1.S deg @ 4,345' Downhole Revised: 9/24/14 Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2" PowerJet 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2" PowerJet 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated Revised By STP 9/25/14 Hil-, Alaska. LLC API: 50-133-10158-00 RKB: 184'/ GL: 164' AMSL KB - THF: 20.05' 1 22" 11 34' 11-3/4" 2,038' CBL TOC 2,950' Damaged GLM 5,526' Cement 6,145' Soft Cement 6,197' Cement 6,255' Top of Fill 2 t� 4 5 Tbg Punch Holes 5,800' 6 Circ cement 7 bbl 15.6 ppg / s r I PROPOSED SCHEMATIC SWanson Well: River Unit SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 Casing Detail Size Type Wt Grade Conn I Top Btm I Hole Cmt Cmt Top 22" Conductor - 2 1,498' Surf. 34' - Yes Surf. it-%" Surface 47 J-55 STC Surf. 2,038'2 040 1,400 sx Surf. 2.867" 5.968" 29 5 3,701' Surf. 104' 2.867" 5.968" 3-1/2" Camco MM GLM #9, XO to 2-7/8" 7" Production N-80 BTC 5.968" 1,100 sx 2,950' 23 104' 4,618' 26 LTC 4,618' 6,016' 8 5,526' 13.08' 9 10,880 5.968" CBL DV Collar 6,016' 6,018' 13.05' 2.867" 26 N-80 30 6,018' 6,616' - 8 29 6,616' 8,495' 7" Production 12.77' LTC 5.968" 700 sx CBL C0L 29 P-110 8,495' 10,880' 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 13 9,387' 12.69' 2.867" Tubing Detail Conn ID Cplg OD 2.875" 1 Tubing 6.5 1 N-80 1 8 T Surface 1 10,755' IF 2.441" 3.668" 6,289' 9 10 It it 12 CBLT0C CBL TO, 5,800' Sqz B 62-4 62-5 Sqz A Jewelry Detail No. Depth Length ID CID Item 1 20.05' 1.70' 2.441" - Tbg Hngr 2 1,498' 12.82' 2.867" 5.968" 3-1/2" Camco MM GLM #12, XO to 2-7/8" 3 2,484' 12.79' 2.867" 5.968" 3-1/2" Camco MM GLM #11, XO to 2-7/8" 4 3,489' 12.72' 2.867" 5.968" 3-1/2" Camco MM GLM #10, XO to 2-7/8" 5 3,701' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #9, XO to 2-7/8" 6 4,059' 13.05' 1 2.867" 5.968" 3-1/2" Camco MM GLM #8, XO to 2-7/8" 7 4,354' 13.00' 2.867" 5.968" 3-1/2" Camco MM GLM #7, XO to 2-7/8" 8 5,526' 13.08' 2.867" 5.968" 3-1/2" Camco MM GLM #6, XO to 2-7/8" (Drift w/ 2.343") 9 6,517' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #5, XO to 2-7/8" 30 6,550' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #4, XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 13 9,387' 12.69' 2.867" 5.968" 3-1/2" Camco MM GLM #2, XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2" Camco MM GLM #1, XO to 2-7/8" 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint 16 10,652' 6.02 2.500" 5.875" Brown Retrievable Production Packer, Model HS -16-1 17 10,676' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/09/04) 18 1 10,690' 0.95' 2.250" 3.668" Camco"D" Profile Nipple, w/ Stuck Plug (Fish) 19 1 10.755' 0.67' 2.441" 3.688" WLEG Venturi Shoe 8,930' 13 14 Tbg Punch 15 10,163' 16 17 t Tbg Punch 48 10,681' Top of Fill -' r1r1 H-1 10,738' rtirti 19 H-2 r•r•r•r•r•r•r•r•r•r r•r•r•r•r•r•r•r•r•r• r.r.r.r.r.r.r.r.r.. 7„ {.ti.ti.ti.ti.ti 1.1.y.titi. r•r•r•r•r•r•r•r•r•r• {.y.ti.ti.ti.ti 10,880' , r'r•r•r•r•}•r•r•r•r• TD =10,880' PBTD = 10,832' Max Deviation = 1.5 deg @ 4,345' Downhole Proposed Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 30' 4 2" PowerJet 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 30' 4 2" PowerJet 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated Revised By STP 12/19/14 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION rWell StaWEoLLil ❑COMPLETGas r G❑ON OR REl Other ❑ECOMPdLE❑TION Suspended RT AND LOG .Well Class: 20AAC 25.105 20MC 25.110 ' Development ❑, ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _0 2'3./5/ Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp., usp.,or 12.Permit to DriN Number: Hilcorp Alaska,LLC Aband.: 9/24/2014 163-007/314-498 3.Address: 6.Date Spudded: 13.API Number: ill µti 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 3/30/1963 50-Z-10158-00 ' 1'1316 4a.Location of Well(Governmental Section): .7.Date TD Reached: 14.Well Name and Number. Surface: 660'FSL, 1530'FEL,Sec 28,T8N,R9W,SM,AK 5/6/1963 Swanson River Unit(SRU)34-28 Top of Productive Horizon: 8.KB(ft above MSL): 15.Field/Pool(s): GL(ft above MSL): Total Depth: 660'FSL, 1530'FEL,Sec 28,T8N,R9W,SM,AK 9.Plug Back Depth(MD+TVD): Swanson River/Tyonek Undef Gas • 10,832'MD/10,832'ND 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 346204.0 y- 2467178.4 Zone- 4 •10,880'MD/10,880'ND, FEDA028399 ' TPI: x- y- Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 346204.0 y- 2467178.4 Zone- 4 N/A N/A 18.Directional Survey: Yes ❑ No Q 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-driNL.ateral Top Window MC/ND: N/A 23. CASING,LINER AND CEMENTING RECORD WT,PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" Surf 34' Surf 34' 8+97sx 0 11-3/4". J-55 Surf 2,038' Surf 2,038' 16" 1400 sx 0 7" 23-29 N-80 Surf 4,145 Surf 4,145' 10-5/8" 0 4,145' 6,016' 4,145 6,016 9-5/8" 0 7" 26-29 N-80 6,016' 8,495' 6,016' 8,495' 9-5/8" 700+1100 sx 0 P-110 8,495' 10,880' 8,495 10,880' 24.Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/IVO) Size and Number): 2-7/8" - 10,755' 10,652'MD/10,652'TVD RECEIVED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes ElNo 2I DEC 19 2014 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate . 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑., Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. SCANNED r�h .i ; o i5 l I Form 1 07 Revised 10/2012 CONTINUED ON REVERSE Submit original only icl RBDM FEB - 9 2015 2 -3 --15" � .f— ,-1 z `T i5— • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? ❑ Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: Operations Summary,Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporholatc'i.hilcorp.com Printed Name: Stan Porhola / Title: Operations Engineer Signature:�p14_L Phone: 907-777-8412 Date: !2_/(Cf i4 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Hilcorp Alaska, LLC Well Operations Summary 11 Well Name API Number Well Permit Number Start Date End Date SRU 34-28 50-133-10158-00 163-007 9/16/14 9/24/14 Daily Operations: 09/16/2014-Tuesday RU Slickline. PT lubricator to 2,000 psi-test OK. RIH w/2.25"x12' DD bailer.Tag up at 5,540' SLM on GLM. RIH w/2.25"x7' DD bailer.Tag up at 5,540' SLM on GLM. RIH w/2.00"x4' DD bailer. Tag up at 6,239' SLM. RIH w/2.00"x9' dump bailer and dump cement at 6,239' (4 runs, 4 gallons cement total). SDFN. 09/17/2014-Wednesday RU Slickline. PT lubricator to 2,000 psi -test OK. RIH w/2.00"x9' dump bailer and dump cement from 6,229' to 6,208' (7 runs, 8 gallons cement total). SDFN. 09/19/2014- Friday RU Slickline. PT lubricator to 2,000 psi -test OK. RIH w/2.00" DD bailer.Tag up on soft cement down to 6,221' SLM. RIH w/ 2.00"x9' dump bailer and dump cement from 6,195' to 6,186' (4 runs, 4 gallons cement total). SDFN. 09/24/2014-Wednesday RU Slickline. PT lubricator to 2,000 psi -test OK. RIH w/2.00" DD bailer.Tag up on soft cement down to 6,180' SLM. RIH w/ 2.00"x11' dump bailer and dump cement from 6,175'to 6,158' (6 runs, 8 gallons cement total). SDFN. f"`,6, 1 rii/4// • t j,ii .3 c‘w 73N-477 6(51 6L./k , ill Swanson River Unit ACTUAL SCHEMATIC Well: SRU 34-28 ��,.►,.�-�.�: Completion Ran: 5/15/1963 llileorpAPI: 50-133-10158-00 PTD: 163-007 RKB:184'/GL:164'AMSL KB-THF:20.05' Casing Detail 22 J. 1 LL Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22" Conductor - - - Surf. 34' - Yes Surf. 34' - . 11-%<" Surface 47 J-55 STC Surf. 2,038' 2 040' 1,400 sx Surf. 2 29 BTC Surf. 104' 7" Production 23 N-80 104' 4,618' 1,100sx 2,950' 11-3/4" • 26 LTC 4,618' 6,016' CBL 2,038' ' 9�" ( 3 DV Collar 6,016' 6,018' 10,880' 26 6,018' 6,616' CBL TOC 7" Production 29 N 80 LTC 6,616' 8,495' 700 sx 8,930' 2,950' CBL 29 P-110 8,495' 10,880' Tubing Detail Conn ID CpIgOD 9_ 1ti)4 2.875" I Tubing I 6.5 I N-80 ' 8RD I Surface I 10,755' 2.441" 3.668" lls h5 t I 16 : Jewelry Detail Damaged '-' No. Depth Length ID OD Item 'GLM 1ill 7 ?+ 1 20.05' 1.70' 2.441" - Tbg Hngr •.,,:k26' 2 1,498' 12.82' 2.867" 5.968" 3-1/2"Camco MM GLM#12,XO to 2-7/8" -/ r 8 3 2,484' 12.79' 2.867" 5.968" 3-1/2"Camco MM GLM#11,XO to 2-7/8" New 4,..----CBL TOC 4 3,489' _ 12.72' 2.867" 5.968" 3-1/2"Camco MM GLM#10,XO to 2-7/8" ' Cement . 5,800' 5 3,701' _ 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#9,XO to 2-7/8" 6,14 ' • 6 4,059' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#8,XO to 2-7/8" Soft •P:4*, 7 4,354' 13.00' 2.867" 5.968" 3-1/2"Camco MM GLM#7,XO to 2-7/8" •r•r• -'Sqz B _. Cement • •:. 62.4 8 5,526' 13.08' 2.867" 5.968" 3-1/2"Camco MM GLM#6,XO to 2-7/8"(Drift w/2.343")_ 6,197' •%:,. 9 6,517' 13.05' 2.867" 5.968" 3-1/2"Camco MM GLM#5,XO to 2-7/8" Cement - -., 62-5 10 6,550' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/14/04) 6,255' - ',Sqz A 11 7,411' 12.77' 2.867" 5.968" 3-1/2"Camco MM GLM#4,XO to 2-7/8" Top of Fill , - 12 8,146' 13.03' 2.867" 5.968" 3-1/2"Camco MM GLM#3,XO to 2-7/8" 6,289' I ; hl-"::: •T r; 9 13 9,387' 12.69' 2.867" 5.968" 3-1/2"Camco MM GLM#2,XO to 2-7/8" ,y - 10 x 14 10,598' 12.74' 2.867" 5.968" 3-1/2"Camco MM GLM#1,XO to 2-7/8" 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint I h)11 16 10,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer,Model HS-16-1 II % 17 10,676' - - 2.180" HES"EZ"Drill Cmt Retainer(Set on wireline 6/09/04) I I i.12 18 10,690' _ 0.95' 2.250" 3.668" Camco"D"Profile Nipple,w/Stuck Plug(Fish) CBL TOC 19 10,755' 0.67' 2.441" 3.688" WLEG Venturi Shoe 8,930' i 13 `i I h) 14 Tbg Punch cc, 15 10,163' _ I Perforation History 16 Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments c\r 7! J 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2"PowerJet : 17 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN , Tbg Punch ' '' 18 10,681' 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 1_' . 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated Top of Fill (1;1111 j H-1 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2"PowerJet 10,738' 1. i~? 19� H 2 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated ,1:ti:ti:ti.ti.ti.1.1:1:1: •r•r•r•r•r•r•r•r•r•r iti.ti.1.1.1.ti.1.ti.ti.\.�' - r '{:{:{:{:{:{:{:{:{4.141 ' 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated •r.r.r.r.r.r•r.r.r.r.r 7„ I.ti.ti.ti.ti.ti.ti.ti.ti.ti.ti. . . }11{1:4:4:4:4:4::414 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated •-r_r_r_r_r_r_r_r_r_r_r 10,880' ..- _ .ti ,tib TD=10,880' PBTD=10,832' Max Deviation=1.5 deg @ 4,345' Downhole Revised:9/24/14 Revised By STP 9/25/14 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. lfp! - f'1O 7 Well History File # Digital Data Added to LaserFiche File CD's - # - Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Other # Yes No Yes No Yes No Mud Logs # - General Notes or Comments about this file. If any of the infonnation listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-] 433, or email us at: AOGCC_Librarian@admin.state.ak.us THE STATE GOVERNOR SEAN PARNEI L Stan Porhola Operations Engineer S� 0 C I o 2014 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 t r. 3- 0,01 Alaska MR and 'GaC 333 West Seventh Avenue Anchorage, Alaska 99501-3572 fviain: 907.279.1433 Fax: 907.276.7542 Re: Swanson River Field, Tyonek Undefined Gas Pool, Swanson River Unit 34-28 Sundry Number: 314-498 Dear Mr. Porhola: 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, Cathy P. Foerster Chair DATED thisly day of September, 2014. Encl. STATE OF ALASKA APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED SEP 0 2 2014 A0GC0 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ] Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdowt ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing[ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ 163-007 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number. Anchorage, Alaska 99503 50-133-10158-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055fa)(4) Will planned perforations require a spacing exception? Yes ❑ No ❑ Swanson River Unit (SRU) 34-28 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028399 I Swanson River / Tyonek Undef Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 1 Plugs (measured): 1 Junk (measured): 10,880' 10,880' 10,832' 10,832' 6,255' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070 psi 1,510 psi Intermediate Production 10,880' 7" 10,880' 10,8817 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / N-80 10,755' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): 7" Brown HS -16-1 Prod Pkr; N/A 10,657MDrfVD, N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after propsed work: Commencing Operations: 09/08/14 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑✓ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Cortact Stan Porhola Phone: 907-777-8412 Email s orhola hilcor.com Printed Name Stan P rhola Title Operations Engineer Signature Phone 907-777-8412 Date G� L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _ Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9_/J �r iy Form 10-403 (Revise 10/2012 Appr v Mn ska'ld/pr 2 months from the date of a provai�C'MS SEP 1 0 20'4 �I V /-� �... 4��y Submit Form and Attachments in Duplicate Hileorp Alaska, LU Well Prognosis Well: SRU 34-28 Date:9/02/2014 Well Name: SRU 34-28 API Number: 50-133-10158-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: Sept 8th, 2014 Rig: N/A Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 163-007 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure: — 2,500 psi @ 6,244' TVD (Flowing survey July 2008) Maximum Expected BHP: — 2,500 psi @ 6,244' TVD (Flowing survey July 2008) Max. Allowable Surface Pressure: — 1,876 psi (Based on possible reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Swanson River Unit SRU 34-28 was drilled as a grassroots well in March 1963 to target H-1 and H-2 oil reserves in the upper part of the Hemlock formation. In June 2004, the Hemlock was plugged back and the well completed in the Tyonek gas sands, the Tyonek 62-5 in 2004 and the Tyonek 62-4 in 2008. The well is currently shut-in and not on production. The purpose of this work/sundry is to plugback the existing completion. This will remove a non-productive open interval in the Tyonek that is near the proposed SRU 4113-33 gas well. Notes Regarding Wellbore Condition 0 Last tag at 6,255' CTM on 6/25/08. Slickline Procedure: 1. MIRU Slickline, PT Lubricator to 1,500 psi Hi 250 Low. 2. RU 2.0" gauge ring, RIH and tag fill/cement at +/- 6,255'. 3. Dump bail 46' of cement on top of fill, and place TOC 35' above 62-4 sand (12 gallons of cement). 4. Wait on cement for 18 hours. 5. RU 2.00" bailer and tag top of cement. a. Dump additional cement if cement top is below 6,209'. 6. Fill well with lease water. Pressure test plug to 1,600 psi for 30 min. 7. RD Slickline. -i S Sw�k✓� 1 �' Attachments: 1. Actual Schematic 2. Proposed Schematic Hil-p Alaska, LLC API: 50-133-10158-00 22" 34' 11-3/4" 2,038' CBLTOC 2,950' RKB: 184'/ GL: 164' AMSL KB - THF: 20.05' 1 2 3 5 6 ACTUAL SCHEMATIC Swanson River Unit Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22" Conductor - 2 Surf. 34' - Yes Surf. 11-%" Surface 47 J-55 STC Surf. 2,038' 6" 2 1,400 sx Surf. 7" Production 29 N-80 BTC Surf. 104' 104' 4,618' 9 10,880' 1,100sx 2,950' CBL 23 26 LTC 4,618' 6,016' DV Collar 6,016' 6,018' 7" Production 26 N 80 6,018' 6,616' LTC 6,616' 81495' 1 8,495' 10,880' 700 sx gCBL 29 29 P-110 Tubing Detail Conn ID Cplg OD 2.875" 1 Tubing 6.5 1 N-80 I 8RD I Surface 1 10,755' L=1 2.441" 1 3.668" Jewelry Detail No. Depth �16 '4 ID CID Damaged r 20.05' 1.70' 2.441" 7 GLM 2 1,498' 10,681' 2.867" 5.968" 5,526' . Top of Fill 12.79' rLf1 H-1 10,738' 4 rtry 19 12.72' a p� 8 , CBLTOC 3,701' ti.1.1.1.tir•r•r•r•r•r•F•r•r•r• r•r•r•f•r•r•r•r•r•r• 2.867" 1 7„ {.1.1. L.L.1 ti•ti•tiftifti• r•r•r•r•r•r•r•r- ti•ti•ti•L•L•ti ti.ti•1•ti.ti. 5,800' 10,880' •r•r•r•r•r•r•r•r•r•r• 2.867" TD = 10,880' PBTD = 10,832' Max Deviation = 1.5 deg @ 4,345' Downhole Revised: 7/01/08 13.00' 962-5 Sqz B 3-1/2" Camco MM GLM #6, XO to 2-7/8" 8 5,526' 13.08' 62-4 Cement 3-1/2" Camco MM GLM #7, XO to 2-7/8" (Drift w/ 2-1/8") 9 6,517' 13.05' 6,255' 5.968" 3-1/2" Camco MM GLM #8, XO to 2-7/8" 10 Sqz A Top of Fill - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 11 6,289' 12.77' 2.867" .ti.1 9 12 8,146' 13.03' 2.867" 5.968" .101 13 9,387' 12.69' 1J' 5.968" 3-1/2" Camco MM GLM #11, XO to 2-7/8" 14 .12 12.74' CBLTOC 5.968" 3-1/2" Camco MM GLM #12, XO to 2-7/8" 15 10,643' 1.07' 8,930' 3.688" 13 ?. 6.02' 14' 5.875" Brown Retrievable Production Packer, Model HS -16-1 17 10,676' - Tbg Punch 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/09/04) 18 cc I; 10,163' 3.668" Jewelry Detail No. Depth �16 '4 ID CID _ 17 r 20.05' 1.70' 2.441" Tbg Punch Tbg Hngr 2 1,498' 10,681' 2.867" 5.968" 18 3 Top of Fill 12.79' rLf1 H-1 10,738' 4 rtry 19 12.72' a p� r•r•r•r•r•r•r•r•r•r 3-1/2" Camco MM GLM #3, XO to 2-7/8" H-2 3,701' ti.1.1.1.tir•r•r•r•r•r•F•r•r•r• r•r•r•f•r•r•r•r•r•r• 2.867" 1 7„ {.1.1. L.L.1 ti•ti•tiftifti• r•r•r•r•r•r•r•r- ti•ti•ti•L•L•ti ti.ti•1•ti.ti. 6 10,880' •r•r•r•r•r•r•r•r•r•r• 2.867" TD = 10,880' PBTD = 10,832' Max Deviation = 1.5 deg @ 4,345' Downhole Revised: 7/01/08 13.00' Jewelry Detail No. Depth Length ID CID Item 1 20.05' 1.70' 2.441" - Tbg Hngr 2 1,498' 12.82' 2.867" 5.968" 3-1/2" Camco MM GLM #1, XO to 2-7/8" 3 2,484' 12.79' 2.867" 5.968" 3-1/2" Camco MM GLM #2, XO to 2-7/8" 4 3,489' 12.72' 2.867" 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 5 3,701' 1 12.77' 2.867" 1 5.968" 3-1/2" Camco MM GLM #4, XO to 2-7/8" 6 4,059' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #5, XO to 2-7/8" 7 4,354' 13.00' 2.867" 5.968" 3-1/2" Camco MM GLM #6, XO to 2-7/8" 8 5,526' 13.08' 2.867" 5.968" 3-1/2" Camco MM GLM #7, XO to 2-7/8" (Drift w/ 2-1/8") 9 6,517' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #8, XO to 2-7/8" 10 6,550' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #9, XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2" Camco MM GLM #10, XO to 2-7/8" 13 9,387' 12.69' 2.867" 5.968" 3-1/2" Camco MM GLM #11, XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2" Camco MM GLM #12, XO to 2-7/8" 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint 1610,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer, Model HS -16-1 17 10,676' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/09/04) 18 10,690' 0.95' 2.250" 3.668" Camco"D" Profile Nipple, w/ Stuck Plug (Fish) 19 10,755' 0.67' 2.441" 3.688" WLEG Venturi Shoe Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SO Comments 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 30' 4 2" PowerJet 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 30' 6 Isolated 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 30' 6 Isolated 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2" PowerJet 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated Revised By STP 12/10/13 Hil-P Alaeko. LLC API: 50-133-10158-00 RKB: 184'/ GL: 164' AMSL KB -THF: 20.05' 1 22" 34' 2 11-3/4" 2,038' 3 CBLTOC 2,950' 4 Swanson River Unit PROPOSED SCHEMATIC Well: SRU 34-28 Completion Ran: 5/15/1963 PTD: 163-007 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22" Conductor - 7 GLM Surf. 34' - Yes Surf. 11-%" Surface 47 1-55 STC Surf. 2,038' 2,04" 1,400 sx Surf. 7" Production 29 N-80 BTC 1 Surf. 104' 9 10,880' 1,100 sx 2,950' CBL 23 104' 1 4,618' 26 LTC 4,618' 6,016' DV Collar 6,016' 6,018' 7" Production 26 N-80 LTC 6,018' 6,616' 700 sx 8�B L 29 6,616' 8,495' 29 P-110 8,495' 10,880' Tubing Detail Conn ID CpIgOD 2.875" 1 Tubing 6.5 N-80 I 8RD I Surface 10,755'2.441" .12 3.668" y* 16 'k 17 , Tbg Punch 10,681' � to �8 r " .w ! Top of Fill ?{?1 H-1 10,738' ?�?� 1 `� H-2 r•r•r•r•r•r•r•r•r•r• ti•1.ti•ti•♦•L ti•1•ti•1.1• I •r•r•r•r•r•r•r•r•r•r• 7„ r•r•r-r•r•r•r•r-r-r• L.y.1.1.1.ti 10,880' f'r•r•r•f•r.r-r-r-" TD = 10,880' PBTD = 10,832' Max Deviation = 1.5 deg @ 4,345' Downhole Proposed Jewelry Detail No. 5 Length ID 6 s 1 20.05' k 2.441" - i Damaged 2 7 GLM 2.867" 5.968" 5,526' 3 2,484' 12.79' 2.867" 5.968" 3-1/2" Camco MM GLM #2, XO to 2-7/8" 4 8 12.72' CBLTOC 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 5,800' , 3,701' 12.77' Cement 5.968" 3-1/2" Camco MM GLM #4, XO to 2-7/8" 6,209' 4,059' Sqz B 2.867" 5.968" 62-4 Cement 4,354' M 62-5 6,255' 5.968" +Sqz A Top of Fill 5,526' 13.08' 6,289' 9 3-1/2" Camco MM GLM #7, XO to 2-7/8" (Drift w/ 2-1/8") 9 10" 13.05' 2.867" li 3-1/2" Camco MM GLM #8, XO to 2-7/8" 10 .12 - CBLTOC 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 8,930' 13 , 2.867" 14 3-1/2" Camco MM GLM #9, XO to 2-7/8" 12 8,146' Tbg Punch 2.867" CC I 10,163' y* 16 'k 17 , Tbg Punch 10,681' � to �8 r " .w ! Top of Fill ?{?1 H-1 10,738' ?�?� 1 `� H-2 r•r•r•r•r•r•r•r•r•r• ti•1.ti•ti•♦•L ti•1•ti•1.1• I •r•r•r•r•r•r•r•r•r•r• 7„ r•r•r-r•r•r•r•r-r-r• L.y.1.1.1.ti 10,880' f'r•r•r•f•r.r-r-r-" TD = 10,880' PBTD = 10,832' Max Deviation = 1.5 deg @ 4,345' Downhole Proposed Jewelry Detail No. Depth Length ID OD Item 1 20.05' 1.70' 2.441" - Tbg Hngr 2 1,498' 12.82' 2.867" 5.968" 3-1/2" Camco MM GLM #1, XO to 2-7/8" 3 2,484' 12.79' 2.867" 5.968" 3-1/2" Camco MM GLM #2, XO to 2-7/8" 4 3,489' 12.72' 2.867" 5.968" 3-1/2" Camco MM GLM #3, XO to 2-7/8" 5 3,701' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #4, XO to 2-7/8" 6 4,059' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #5, XO to 2-7/8" 7 4,354' 13.00' 2.867" 5.968" 3-1/2" Camco MM GLM #6, XO to 2-7/8" 8 5,526' 13.08' 2.867" 5.968" 3-1/2" Camco MM GLM #7, XO to 2-7/8" (Drift w/ 2-1/8") 9 6,517' 13.05' 2.867" 5.968" 3-1/2" Camco MM GLM #8, XO to 2-7/8" 10 6,550' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/14/04) 11 7,411' 12.77' 2.867" 5.968" 3-1/2" Camco MM GLM #9, XO to 2-7/8" 12 8,146' 13.03' 2.867" 5.968" 3-1/2" Camco MM GLM #10, XO to 2-7/8" 13 9,387' 12.69' 2.867" 5.968" 3-1/2" Camco MM GLM #11, XO to 2-7/8" 14 10,598' 12.74' 2.867" 5.968" 3-1/2" Camco MM GLM #12, XO to 2-7/8" 15 10,643' 1.07' 2.438" 3.688" Brown CC Safety Joint 16 10,652' 6.02' 2.500" 5.875" Brown Retrievable Production Packer, Model HS -16-1 17 10,676' - - 2.180" HES "EZ" Drill Cmt Retainer (Set on wireline 6/09/04) 18 10,690' 0.95' 2.250" 3.668" Camco"D" Profile Nipple, w/ Stuck Plug (Fish) 19 10,755' 0.67' 1 2.441" 3.688" WLEG Venturi Shoe Perforation History Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments 6/19/04 Sqz B 6,235' 6,245' 6,235' 6,245' 10' 4 2" PowerJet 7/01/08 62-4 6,244' 6,254' 6,244' 6,254' 10' 6 OPEN 6/25/04 62-5 6,260' 6,270' 6,260' 6,270' 10' 6 Isolated 8/22/04 62-5 6,265' 6,275' 6,265' 6,275' 10' 6 Isolated 6/17/04 Sqz A 6,335' 6,345' 6,335' 6,345' 10' 4 2" PowerJet 5/11/63 WSO 10,707' 10,708' 10,707' 10,708' 1' 5 Isolated 5/13/63 H-1 10,716' 10,725' 10,716' 10,725' 9' 4 Isolated 5/13/63 H-2 10,737' 10,762' 10,737' 10,762' 25' 4 Isolated Revised By STP 9/02/14 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, September 08, 2014 10:36 AM To: Schwartz, Guy L (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: SRU 34-28 (PTD 163-007) Guy, Future plans for SRU 34-28 (PTD 163-007) are as follows: 1.) Conversion to water disposal in the Sterling -or- 2.) Sidetrack Will add a pressure test of the 7" x 11-3/4" to 1,500 psi to test the cement packer and the tubing. Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, September 03, 2014 12:35 PM To: Stan Porhola Cc: Roby, David S (DOA) Subject: SRU 34-28 (PTD 163-007) Stan, Need justification for suspending the SRU 34-28 in writing. What are the future plans for well ? sidetrack? An email will be fine. Note: added a pressure test of the IA to your procedure to verify the cement packer was competent as well as the tubing. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 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). STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS ~~-~'~ ~- :: n~.. 1. Operations Abandon Repair Well Plug Perforations ~ Stimulate they `" Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate Q - Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory^ 163-007 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-133-1015800-00 7. KB Elevation (ft): 9. Well Name and Number: 20' Swanson River Unit (SRU) 34-28 8. Property Designation: 10. Field/Pool(s): FEDA 028399 [Swanson River Unit] ~ Swanson River / Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,880' - feet Plugs (measured) 6,255' (cement) true vertical 10,880' - feet Junk (measured) N/A Effective Depth measured 6,255' feet true vertical 6,255' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070 psi 1,510 psi Intermediate Production 10,881' 7" 10,881' 10,881' 6,340 psi 3,830 psi Liner Perforation depth: Measured depth: 6,244' - 6,254' t'J~~ri~310~~ ~~ ~ ~ k 2018 l17 B.~ U True Vertical depth: 6,244' - 6,254' Tubing: (size, grade, and measured depth) 2-7/8" N-80 6.4# 10,755' Packers and SSSV (type and measured depth) Brown ret packer Model HS-16-1 @ 10,652' / No SSSV Cement packer @ +/- 5,800' 12. Stimulation or cement squeeze summary: 6,250' - 6,275' squeeze perfs Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Laid in 3.8 bbls cment @ 3500 psi (6,289' - 5,850') and dressed top to 6,160 holding 2150 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 270 34 1460 1550 14. Attachments: 15. Well Class after work: Copies of logs and Surveys Run N!A Exploratory^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-183 Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager ,R ,~ s ~ ~ Signature ~ ~ .~~,~ ~ Phone 263-7657 Date 7/28/2008 Form 10-404 Revised 04/2006 ~ ~ ~ t, F ~ ~' ~ ~--~ ~ Submit Original Only Chevron ~ • Spud 03-30-1963 API # 50-133-10158-00 Swanson River Unit Well # SRU 34-28 RKB =20.0' Casing & Tubing Size Wt Grade ID To Btm 22" Surf 34' 11?/a" 47 J-55 11" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' 7" 29 P-110 6.184" 8,495' 10,881' Tubin 2'/e" 6.4 N-80 2.441" Surf 10,755' Jewelry Item To OD ID Descri tion GLM #1. 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-U2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" Bent Latch ;;~, ., i ~~ ~~_ f~ '~;t ~~in. ,.. i h$8" ;Dint IU,6~Z i_87~' !_` I'kr. Nlc~~.lel li.`rlli-I i IO G~~C~ mc„ T~ rdi ~Icw/stuck Plug i+~ Perforations Zone To Btm Ft SPF Comments S z 6,235 6,245 ]0 6 S z erfs 62.4 6,244 6,254 10 6 Perfs 7/1/08 62.5 6,260 6,275 15 6 S z erfs 6/21/08 S z 6,335 6,345 10 6 S z erfs WSO 10,707 10,708 1 5 WSO H 1 10,716' 10,725 9 4 Covered w/ Cement H2 10,737 10,762 25 4 Covered w/ fill 07-22-08 CVK TD= 10,880' PBTD= 10,832' Max Deviation = 1.3° (a~ 4345' Chevron Chevron -Alaska Daily Operations Summary Well Name SRU 34-28 Field Name SWANSON RIVER, API/UWI 501331015800 Lease/Serial FEDA028399 CHEVNO QA5331 License No./Props... 1630070 Orig KB Elev (ftK6) 180.0 Water Depth (ft) -- _ - ---- - Jobs _ _ _ __ ___ _ Job Cat _ _ Type _ AFE No. _ QC Eng Well Service Completion UWDAK-R8026 ------- Dail O erations - 5/24/2008 00:00 - 5/25/2008 00:00 Operations Summary Rig Up (RU) slickline. Drifted through mandrel # 7 numerous times beating through each time w/largest being 2.275" swedge, 2" dummy gun 2.25" swedge. POOH. 5/25/2008 00:00 - 5/26/2008 00:00 Operations Summary Rig in hole (RIH) slickline. Continued diagnostics on #7 gas lift mandrel. Able to pass 2 1/8" x 18" drift ,Unable to pass cleanly with larger or longer tools. POOH 6/5/2008 00:00 - 6/6/2008 00:00 Operations Summary RU wireline. Drifted tubing with simulated cement retainer. Was able to get through mandrel every time but only after the spangs closed. It would not drift through with out sitting down. Tag bottom at 6,289' RKB WLM (wireline measurement). 6/8/2008 00:00 - 6/9/2008 00:00 Operations Summary Set up for Infectivity test 6/9/2008 00:00 - 6/10/2008 00:00 Operations Summary Kill well with 6% KCL lease water mixture and perform infectivity test 6/13/2008 00:00 - 6/14/2008 00:00 Operations Summary Prepared location with tarps and dunnage 6/14/2008 00:00 - 6/15/2008 00:00 Operations Summary Filled annulus with fluid and ressure tested to 2000 si for 30 minutes ood /bled annulus pressure to +- 25 psi (would not bleed off completely) will monitor annulus pressure in the AM (7" x 2-7/8" annulus pressure as of 04:15 on June 15th, 200 psi) 6/15/2008 00:00 - 6/16/2008 00:00 Operations Summary Monitor Annulus pressure (no change) still @ 200 psi 6/19/2008 00:00 - 6/20/2008 00:00 Operations Summary RU Schlumberger CTU (coil tubing unit), Batch Mixer, Little Monster, Atigun transfer pump, transfered fluids from 43B-08 to 34-28, AOGCC notified with 24hr notice of BOP test on 6/18 and waived by Jeff Jones. BOPE test (good) ,finalized squeeze procedure with town, Mobed equipment from the North Slope and L.A. for clean out. Finalized guns to be utilized for perforating 6/20/2008 00:00 - 6/21/2008 00:00 Operations Summary Demob from SCU 436-8, Mob to SRU 34-28 and spot equipment. 6/21/2008 00:00 - 6/22/Z008 00:00 Operations Summary Cement S ueeze T onek 62-5 sand at 6,289' to 6,160' RKB CTM coil tubin measurement . 6/22/2008 00:00 - 6/23/2008 00:00 Operations Summary Wait on Cement, Clean up Pit liner and misc. on SCU 436-8 Pad 6/23/2008 00:00 - 6/24/2008 00:00 Operations Summary Under ream hard cement from 6 148' RKB CTM to 6 210' RKB CTM / ressure tests ueeze lu to 2150 si for 15 minutes (good Rig up E-line and correlate top of Cement to RST log 6217' 6/24/2008 00:00 - 6/25/2008 00:00 Operations Summary Under- ream hard Cement to 6255.8' RKB CTM BI w ° in rv 11072 psi negative test on sqz perfs. RB CTU for a-line operations 6/25/2008 00:00 - 6/26/2008 00:00 Operations Summary Tag top of Cement at 6255.3', Begin DEMOB of Coil Tubing unit 6/26/2008 00:00 - 6/27/2008 00:00 Operations Summary Demob 6/27/2008 00:00 - 6/28/2008 00:00 Operations Summary Demob I 1 Chevron Chevron -Alaska Daily Operations Summary Well Name SRU 34-28 Field Name SWANSON RIVER, API/UWI 501331015800 Lease/Serial FEDA028399 CHEVNO QA5331 License No./Prope... 1630070 Orig KB Elev (ftK6) 180.0 Water Depth (ft) Dail O rations 6/28/2008 00:00 - 6/29/2008 00:00 Operations Summary Demob 6/29/2008 00:00 - 6/30/2008 00:00 Operations Summary Clean Skim Pit, Hauled Timbers and organized on Tyler Pad. 6/30/2008 00:00 - 7/1 /2008 00:00 Operations Summary Check on equipment and Rig up, test Schlumberger E-Line in preparations for AM perf. 7/1/2008 00:00 - 7/2/2008 00:00 Operations Summary Perforate the T onek 64-2 sand 6244'- 6254') 7/2/2008 00:00 - 7/3/2008 00:00 Operations Summary Finish Demob, Swap contents of Spill conex to new conex, inventory same. ~~'1£VI"ClCi ~ncisco Castro Chevron North~rica Exploration and Production -~!! Technical Assistant 909 W. 9th Avenue ~.. ~~; _ ~ Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE July 7, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 WELL LOG TYPE SCALE LOG DATE INTERVAL RUN n B-LINE CD NOTES -LAS, LOGGED PDS, DLIS GRANITE POINT ST 18742 37 USIT 5" 14-Jun-08 200-9874 PS-1 1 1 LAS, PDS PACKER SETTING SCU 436-08 RECORD 5" 9-Jun-08 5746-5940 2 1 1 PDS COMPLETION SRU 34-28 RECORD 5" 1-Jul-08 5940-6228 1 1 1 PDS TBU K-25 USIT 5" 11-Jun-08 200-6463 PS-1 1 1 PDS,LAS . a,rr.,....... - ~ ~~ -~3~~ >~~ ~ 3 Please acknowledg pt by signing and returning one copy of this transmittal or FAX to 907.263 7828. Received eyf '~ ! ,' ; _ - ~ ~ ~ Date: • Ai,AS1~iA OII. A1~TD GA~5 333 W. 7th AVENUE. SUITE 100 COI~TSERVA"rIO1~T COl~'Il~'II-rlSIO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907).276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 0 ~ ~3J ti Re: Swanson River Field,l~ronek Undefined Gas Pool, SRU 34-28 Sundry Number: 308-183 SCANNED MAY 2 3 2008 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90'7) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely. if it is received. by 4:30 PM on the 23rd day following the date of this letter, or the. next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair ,J DATED thisZ.Z day of May, 2008 Encl. ,,r ~ ~, `~. ~ r v t ~' ,(~ , v' ~O~ STATE OF ALASKA ~ OlT MAY ~0~ i~ ALA OIL AND GAS CONSERVATION COM(~ION,~~ ~ ~ 2O IR,\ 5 APPLICATION FOR SUNDRY APPROV9d~ Oil & Gas Cons. Camm~ian 1. Type of Request: Abandon ^ Suspend. ^ Operational shutdown ^ Perforate 0 ` Waiver Other Alter casing^ .Repair well ^ Plug Perforations ^~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class:. 5. Permit to DriIL Number: Union Oil Company of California Development ^ Exploratory ^ 163-007:- 3. Address: Stratigraphic ^ Service ^ 6. API .Number: P.O. Box 196247, Anchorage, Alaska 9519. 50-1.33-1015800-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ SRU 34-28 ' 9. Property Designation: 10. KB Elevation {ft): 11. Field/Pool(s): Swanson River Unit / FEDA 028399 , 20' Swanson River Unit / T onek Gas 12• PRESENT WELL CONDITION SUMMARY TotafDepth MD (ft): Total Depth TVD (ft): Effeotivebepth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):.. 10880 10880 6328 6328 6328 - 6291 (sand) Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038'. 3,070 psi 1,510 psi' Intermediate Production 10,881 7" 10,881' 10,881' 6,340 psi 3,830 psi. Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6,260' - 6,275' 6,260` - 6,275' 2-7/8" N-80 10,755' Packers and SSSV Type: Brown retpacker Modet HS-16-4 Packers and SSSV MD (ft): 10,652' 1 no SSSV 13. Attachments: .Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 5/28/2008 16. Well Status after proposed work: Commencing Operations:.. Oil ^ Gas. ~ Plugged ^ Abandoned ^ 17. Verbaf ApprovaL• Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenberg Title Drilling Manager Signature ~--_ o Date - ~-~~"' COMMISSION USE ONLY: Conditions of approval: Notify Commission so that a representative may witness Sundry Number. .. ! 83 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~~~~ ~G-5 ~~~w S~ ~~~ . ~-`(. S -Q ~' . , Other. w~-~;~ co ~~ ro~ ccctiv~.Q t~~.~-~~ c~c_cs~ c-~ `-~ ~ ~~c_ ate- ~ ~-~~ Subsequent Form Required: (~~~ S BFL ~Qy ~ 2 ZO~B APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: ~Z/ Form 0-403 Revised 06/2006 U ~' ~ ` I Y ~ ~ Submit in Duplicate 'Cf'1@1i1't31! Swanson River Unit Perforation Data: SRU 34-28 Objective: • Perforate as necessary Tyonek 62.5 sands to accept cemenfinjection • Plug the Tyonek 62.5 Sands w/ cement retainer 8~ Cement • Re-Complete in the Tyonek 62.4 sands • Turn well over to production Procedure: • • Utilize Slick line to change out dummy valve in station # 7 & run memory gauges to determine SIBHP mid pert Tyonek 62.5 • Utilize a pump truck & perform an infectivity test to determine if re-perforating is necessary • Utilize E-line to reperforate the Tyonek 62.5 sands if necessary & set cement retainer above the. TyoneK 62.5 Sand • .Utilize CT to pump cement into the Tyonek 62.5 Sand, lay in 6% KCL water across Tyonek 62.4 interval & blow dovrn the well bore with Nitorgen to prepare the well. for perforating • Utilize E-line to re-complete the well in the Tyonek 62.4 sand by perforating • Turn the well over to production DATE INTERVAL MD INTERVAL TVD INTERVAL SUB SEA Footage DESCRIPTION ONE ... ...TOP BTM TOP BTM TOP BTM Current 6,260' 6,275' 6,260' 6,275' 6,076' 6,091' 15' Current erforations 62.5 ro osed 6,260' 6,275' 6,260' 6,275' 6 076' 6 091'. 15' ro osed/if in'ectivit is low 62.5 ro sed 6,244' 6,255' 6,244' 6,255' 6,060' 6,071' 11' ro osed 62.4 Chevron • • S ud 03-30-1963 P API # 50-133-10158-00 Swanson River Unit Well # SRU 34-28 RKB =20.0' Casina & Tubina Size Wt Grade ID To Btm 22" Surf 34' Il-'/<" 47 J-55 11" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' 7" 29 P-110 6.184" 8,495' 10,881' Tubin 2'/e" 6.4 N-80 2.441" Surf 10,755' Jewelry Item To OD 1D Descri tion 1 GLM # 1 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 2 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 3 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 4 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 5 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 6 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 7 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 8 6517' 5.968" x 5.00" 2.867" Camco MM GLM 3-I/2" x 2-7/8" GLM # 9 741 I' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7!R" GLM # 10 8146' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # l 1 9387' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 12 10,598' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-16-1 4 10,690' Profile Nipple, Camco "D" Nipple w/Stuck Plug 5 10,755' WLEG Venturi Shoe riled to 6291' - 9/4/06 Wellbore Integrity 1. Passed an Active MIT 5/27/99. 1557 si on cs annuli for 30 min. 2. Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi. Within a week injection was at 300 to 400 bpd @ 1100 si 3. Static ressure surve ran on 4/13/01 w/ fluid level at 8457' indicated a BHP of 3,136 sia 10,690' 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GLV leaking. Ran temp survey on 9/17/03. Well passed SI MTT. Found fluid level in tbg @ 1978'. BHP = 2918 psia @ 10,700' 5. Durin RST to on 1/10/04 found fluid level in tb 2081'. In cs fluid level 3394'. 6. Attem t to Ju test failed on 2/24/04. Set lu in "D" ni le. PT well to 1100 si. Bled off to 100 si. Perforations Zone To Btm Ft SPF Comments S z 6235 6245 10 6 S z erfs 62.5 6260 6275 15 6 O en Pertbrations S z 6335 6345 10 6 S z erfs WSO 10,707 10,708 1 5 WSO H1 10,716' 10,725 9 4 Covered w/ Cement H2 10,737 10,762 25 4 Covered w/ fill 03-OS-08 MGB TD= 10,880' PBTD= 10,832' Max Deviation = 1.3° @ 4345' Chevron ~ ~ Spud 03-30-1963 Proposed API # 50-133-10158-00 Swanson River Unit Well # SRU 34-28 RKB =20.0' Casino & Tubina Size Wt Grade ID To Btm 22" Surf 34' 11-3/." 47 J-55 I1" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' 7" 29 P-110 6.184" 8,495' 10,881' Tubin 2'/e" 6.4 N-80 2.441" Surf 10,755' C saoo' °P L 6.244' 62d Sand ~tm (a' 6,254' Jewelry Item To OD ID Descri tion GLM #1. 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #8. 6517' 5.968" x 5.00" 2.867" Camco MM GLM 3-I/2" x 2-78" GLM #9. 7411' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #10. 8146' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #11. 9387' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-16-I 4 10,690' Profile Ni le, Camco "D" Ni le w/Stuck Plu 5 (0,755' WLEG Venturi Shoe Wellbore Integrity 1. Passed an Active MIT 5/27/99. [ 1557 psi on csg annuli for 30 min.] 2. Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi. Within a week injection was at 300 to 400 bpd @ 1100 psi 3. Static pressure survey ran on 4/13/01 w/ fluid level at 8457' indicated a BHP of 3,136 psia @ 10,690' 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GLV leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg @ 1978'. BHP = 2918 psia @ 10,700' 5. During RST log on 1/10/04 found fluid level in tbg @ 2081'. In csg fluid level @ 3394'. 6. Attempt to Jug test failed on 2/24/04. Set plug in "D" nipple. PT well to 1100 psi. Bled off to 100 psi. Perforations Zone To Btm Ft SPF Comments S z 6,235 6,245 10 6 S z erfs 62.4 6,?44 6,254 10 4 Add Pens 62.5 6:260 6,275 IS 6 S z erfs S z 6,335 6,345 10 6 S z erfs WSO 10,707 10,708 1 5 WSO H1 10,716' 10,725 9 4 Covered w/ Cement H2 10,737 10,762 25 4 Covered w/ fill 03-OS-08 MGB TD= 10,880' PBTD= 10,832' Max Deviation = 1.3° @ 4345' / " '3 -o::>-:r e e FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 .- ..f"M (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 ~Ct\Ì'\!NfD (: C', <l[i T¡P: {J iiJ L ''I..'U Re: Swanson River Field, Tyonek Oil Pool, SRU 34-28 Sundry Number: 306-148 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this r9. day of May, 2006 Encl. u Chevron ~ October 15, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, AK 99501 Dear Commissioner, • ~~ t(~ 3" ~ 6 After reviewing our well flles, we have come across three separate incidences where a 10-403 was submitted and approved, but a Report of Sundrv Well Operations form 10-404 was not submitted. We apologize for this inconvenience and oversight. We strive to make sure our regulatory filings are correct and submitted in a timely manner. We have taken steps to track our filings with the AOGCC to make sure that this does not happen again. Thank you for your understanding. Sincerely, \ ~'~ ~ ~.'~~'r~..~' ~i i ~ ~ 'r. ! iiti:r ~ , .. ~ . . ~~ ~. Timothy C. Brandenburg ~ Drilling Manager ~ ~0. ~C ~c- a.K~-~ ~ S ~ ~c ~p ~ ~~t~~ ~C-o,~S~~ ~~-\ ~cc,~:~-- `~-c~c ~' ~~~ sT~'' ~~ ~y o~ Attachments: 10-404 for Swanson River Unit 34-28 10-404 for Trading Bay Unit K-13RD2 10-404 for Trading Bay Unit G-03RD2 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS v~,~%~~ " io ~-aP 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Clean out ~ Pertormed: Alter Casing ^ Pull Tubing^ PerForate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ PerForate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ , Exploratory^ 163-007 ~ 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-133-1015800-00 - 7. KB Elevation (ft): 9. Well Name and Number: 20' ~{~r ~f'~ryry~~'y) Swanson River Unit (SRU) 34-28 ~ 8. Property Designation: 10. Field/Pool(s): FEDA 028399 [Swanson River Unit] ~ Swanson River / Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,880' ~ feet Plugs (measured) 6,291' (fill) true vertical 10,880' . feet Junk (measured) N/A Effective Depth measured 6,291' feet true vertical 6,291' feet Casing Length Size MD ND Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070 psi 1,590 psi Intermediate Production 10,881' 7" 10,881' 10,881' 6,340 psi 3,830 psi Liner PerForation depth: Measured depth: 6,260' - 6,275' True Vertical depth: 6,260'-6,275' Tubing: (size, grade, and measured depth) 2-7/8" N-80 6.4# 10,755' ,~ ~~~~, ~~,.. ~ ~u~: ' ~ ~ ~ ,~a ~ ~, -~ Packers and SSSV (type and measured depth) Brown ret packer Model HS-16-1 @ 10,652' / No SSSV Cement packer @ +/- 5,800' ~ ~ " -~ ~ ~ ~-~ ~~ ~ 12. Stimulation or cement squeeze summary: N/A ~~~5~(~ ~1~ ~ ~~1.~ ~,C"~°~. ~~~i3'38S~1il~'~ Intervals treated (measured): ~~t~~t~r~~`s: Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 30 0 Subsequent to operation: 0 0 0 30 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ ~ Service ~ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas Q- WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-148 Contact Steve Tyler Printed Name Timothy C. Brandenburg Title Drilling Manager '' "> _.}. . Signature ~' ~~ ~ ~ ---- :, Phone 263-7657 Date 10/7/2008 Form 10-404 R ed 04/2006 ~ ~~~, ~~ H V ~ ~'?~~~ ~ ~ ~ ~ A ~ Submit Original Only ~ r~ro~ Chevron ~ ~ ~ Spud 03-30-1963 ~ API # 50-133-10158-00 Swanson River Unit Well # SRU 34-28 RKB =20.0' Casina & Tubina Size Wt Grade ID To Btm 22" Surf 34' I1 3~4~~ 47 J-55 11" Surf 2,038' T' 29 N-80 6.184° Surf 104' 7" 23 N-80 6366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' T' 29 N-80 6.184" 6,616' 8,495' 7" 29 P-110 6.184" 8,495' 10,881' Tubin 2'/e" 6.4 N-80 2.441" Surf 10,755' Jewelrv Item To OD ID Descri tion t GLM # l 1498' S.968" x 5.00° 2.86T' Camco MM GLM 3-1/2" x 2-7/8" GLM # 2 2484' S.968" x 5.00" 2.86'1" Camco MM GLM 3-1/2" x 2-7/8" GLM # 3 3489' S.968" x 5.00° 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM # 4 3701' S.968" x 5.00" 2.867° Camco MM GLM 3-1/2" x 2-7/8" GLM # 5 4059' S.968" x 5.00" 2.867" Camco MM GLM 3-l/2" x 2-7/8° GLM # 6 4354' S.968" x 5.00" 2.86T' Camco MM GLM 3-V2" x 2-7/8" GLM # 7 5526' S.968" x 5.00" 2.86T' Camco MM GLM 3-1/2" x 2-7/8" GLM # 8 6~ 17' ;.9Gg'~ x i.00" 2.867" Camco MM GLM 3-U2" x 2-7/8,. GLM # 9 741 1' S.968'~ x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #]0 8146' S.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8° GLM # 11 938T 5.968" x 5.00 2.86T' Camco MM GLM 3-1/2" x 2-7/8" GLM # 12 10,598' S.968" x 5.00~~ 2.867" Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 ]0,652' S.875" 2.5 Brown Retrievable Pkr. Model H~1Crl 4 10,690' Profile Nipple, Camco "D" Nipplew/Stuck Plug 5 10,755' WLEG Venturi Shoe ~iled to 6291' - 9/4/06 Wellbore Intearitv 1. Passed an Active MIT 5/27/99. 1557 si on cs annuli for 30 min. 2. Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi Within a week injection was at 300 to 400 bpd ( 1100 si 3. Static ressure surve ran on 4/13/Ol w/ fluid level at 845T indicated a BHP of3,136 sia 10,690' 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GLV leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg @ 1978'. BHP = 2918 psia @ 10,700' 5. Durin RST lo on 1/10/04 found fluid level in tb 2081'. In cs fluid level 3394'. 6. Attem t to Ju test failed on 2/24/04. Set lu in "D° ni le. PT well to 1100 si. Bled offto 100 si. Perforations Zone To Btm Ft SPF Comments S z 6235 6245 10 6 S z erfs 62.5 6260 6275 I S 6 O en Perforations S z 6335 6345 10 6 S z erfs WSO ]0,707 10,708 1 5 WSO H1 10,716' 10,725 9 4 Covered w/ Cement H2 10,737 10,762 25 4 Covered w/ fill 03-OS-08 MGB TD= 10,880' PBTD= 10,832' Max Deviation = 1.3° (a) 4345' Complete Well Install Coil Tubing Conveyed Gravel Pack 8/28/2006 Services Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 34-28 5013310158-00 1630070 ~ . uR ~ , ~ ~ ~ .;. , _.~ . ; ...~ , f~ ~~., :,, ~ ~~. ~ . N, ~~ . ~~. :, ,,, . , , ~ ,~ t 3 ,, n .h ~ W ~:a 2006 00:00 ~~' t2b06 pk~'tlt~ ~ Operations Summary TP=O psi, PC=30 psi, SC=O psi; Fluid Level within 200' of surFace. Made LIB run and four (4) attempts to latch fish. No Joy. ~ ~. . ,'~ ~, ,:F ,.. -:,~r~ ~/29! ~`~~` ~ O.Ob ~~- 8/30I2006 ~OO:~SI . ~ ~ ~ ~ rF~~ , Operations Summary TP=O psi, PC=30 psi, SC=O psi; Fluid Level within 200' of surface. Bail fill @ 6270'. No Progress. Ran LIB and made four (4) attempts to latch fish. No Joy. 't7006. bQ:00 - 8/31/2006 tl~:Of~ `~x" ~_~ ~ `f r ~~ Operations Summary TP=O psi, PC=30 psi, SC=O psi; Fluid Level @ 193' B' tll from 6272' to 6278'. Formation sand running in with each trip of bailer. Secure operations. RU to inject gas into tbg to drive fluid level down. 9F ~00:00 - 9/4/~OQ~ U~IT'~f ~ k ~ ~ ~ ~^> ~ ~ i ~,~~ ~ ,,: ~ , .~ ~ ,~ ~. ;. Operations Summary TP=2350 psi, PC=30 psi, SC=O psi; Fluid Level is at or below btm perfs @ 6245'. Tag fish w/bailer and LIB @ 6279'. Recovere is . ontinue to airfiTrto br~$~'. ~ ,. r ;, ~ ; ; . ~.r, ~~412006TMOQtQO - 8/5/2006 0Q:00` ~ ti~$; Operations Summary TP=2100 psi, PC=30 psi, SC=O psi; Fluid Level at or below perfs. Bailed fill from 6283' to 6291'. Suspend operations. Unable to procede with plans due to inability to pass throuqh qas lift mandrel. Operations cancelled. pr¡-:f -///~ c;(lt5+0ft, ¿Dc.. I-;J",.,I .r/~P _ STATE OF ALASKA FY' -11~/Ob ALAsWOIL AND GAS CONSERVATION COMMI&N APPLICATION FOR SUNDRY APPROVALS 20 MC 25 280 W0^ sIll '-OO~ ?~A) f/;Þ¡1k~ .~\PQ 2 /.' h'l\ 'I) i'·, "" (, h 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate UW"" '¡';, "'''Wålìté1'EJ· 'ii: 'ó Alter casing D Repair well D Plug Perforations D Stimulate D Time Exf¡j~òh-¡tš}J Through tubing gravel ~/ Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D pack, reperforate 2. Operator Name: 4. Current Well Class: / 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory D 163-007 ,/ 3. Address: Stratigraphic D Service D 6. API Number: / PO Box 196247, Anchorage, AK 99519 50-133-10158-00 7. KB Elevation (ft): 9. Well Name and Number: 20' SRU 34-28 / 8. Property Designation: 10. Field/Pools(s): Swanson River Production Facility Swanson River Field/62-5, Tyonek 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): 10,880' 10,880' 6,550' 6,550' 6,550' Casing Length Size MD / TVD Burst Collapse Structural Conductor 34' 22" 34' 34' Surface 2,038' 11-3/4" 2,038' 2,038' 3,070' psi 1,510' psi Intermediate Production 10,881 ' 7" 10,881 ' 10,881 ' 6,340 psi 3,830 psi Liner Perforation Depth MD (~ ' Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): (,1.1 6,260 to~,762' W6 6,260 to~ 2-7/8" N-80 10,755' Packers and SSSV Type: Brown ret packer Model HS-16-1 Packers and SSSV MD (ft): 10,652' /. 12. Attachments: Description Summary of Proposal l:J 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/7/2006 Oil D Gas 0 / Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature '~¿6 C/ Phone 907-276-7600 Date C-/_ / ð~D~ -V C COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:. Jf.'f...p . t4~ Plug Integrity D BOP Test D Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8Ft MAY {I 3 2006 Subsequent Form Required: to 4- 4-. IApprn""" bY~ APPROVED BY Date: 6' ,. 2r _()'6 COMMISSIONER THE COMMISSION '-"" ~ '-. -- ~ .¡; z.<;:. "" Form 1 0-403 Revised 07/2005 AFE XXXXXX ORIGINAl Submit in Duplicate RKB =20.0' TD= 10,880' PBTD= 10,832' Max Deviation = 1.3" @ 4345' Size 22" 11-%" 47 J-55 1\" T' 29 N-80 6.184" 7" 23 N-80 6.366" 7" 26 N-80 6.276" 7" 29 N-80 6.184" 1" 29 P-II0 6.184" Tubi 2 -;;." 1/4" Item To OD eLM #1. 1498' 5.968" x 5.00" 67" eLM #2. 2484' 5.968" x 5.00" 2.861" eLM #3. 3489' 5.968" x 5.00" 2.867" eLM #4. 3701 ' 5.968" x 5.00" 2.867" eLM #5. 4059' 5.968" x 5.00" 2.867" 4354' 5.968" x 5.00" 2.867" eLM #7. 5526' 5.968" x 5.00" 2.867" eLM #8. 6517' 5.968" x 5.00" 2.867" eLM #9. 7411 ' 5.968" x 5.00" 2.867" eLM #10. 8146' 5.968" x 5.00" 2.867" eLM #11. 9387' 5.968" x 5.00" 2.867" eLM #12. 10,598' 5.968" x 5.00" 2.867" 2 10,643' 3.688" 2.438" 3 10,652' 5.875" 2.5 4 10,690' 5 lO,755 C: \Documents and Settings \dunhade \Local Settings \ Temporary Internet Files \OLK99\SR U _34-28 _Schematic _ 09-20-04 (Z).docl.,pq 9/27/2004 9:58 AM RKB ~20.0' T!)~ 10,880' PBT!)~ 10,832' Max Deviation ~ J.3. @ 4345' Size 22" ll-%" 7" 7" T' 7" 7" Tubin 2 ì'," 1/4" Btm 34' 2,038' 104' 4,618' 6,616' 8,495' 10,881' 47 29 23 26 29 29 J-55 N-80 N-80 N-80 N-80 P-II0 11" 6.184" 6.366" 6276" 6.184" 6.184" To Surf Surf SUlf 104' 4,618' 6,616' 8,495 ' J e 'Ij lIelrv Item TOD OD ID DescriDtion GLM#l. 1498' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" CamcoMM GLM 3-112" x 2-7/8" GLMII3. 3489' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-718" GLMII4. 3701' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2e7/8" GLM #8. 6517' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #9. 7411' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #10. 8146' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #11. 9387' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.867" Cameo MM GLM 3e1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safetv Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. ModelHS':ìh-.l 4 10,690' Profile NiDple, Cameo "D" .". S 10,755' WLEG Venturi Shoe T.T.S. Gravel Paek Packer w/l-1/4" NU Pin &:. 2e1/2"GFishing Neek Mill out extension w/l-1/4" NU 10RDBox x Box Safet Joint wi w/1-1/4" NU JORDPin x Box Crossover Sub wi 1-1/4" Box x I" Pin Blank Tubin w/l" NU lORD Pin x Box "Strataeoil" (2 Jts.) with 2.250" Weld-on Centralizers. wl1" NU lORD Pin x Box Bull Plug w/l" NU lORD .50 1.660 NA Zone Ton Btm Ft SPF Comments Saz 6235 6245 10 6 Saz Derfs 62.5 6260 6275 15 6 Perforations Saz 6335 6345 10 6 Saz Derfs WSO 10,707 10,708 1 5 WSO HI 10,716' 10,725 9 4 P&A H2 10,737 10,762 25 4 P&A C:\Documents and Settìngs \dunhade \Local Settìngs \ Temporary Internet F ìles \0 LK99\SRU _34-28 _Proposed 12/12/2005 11 :46 AM .-Þ e e Swanson River Field Swanson River Unit SRU 34-28 Thru Tbg Gravel Pack Procedure ~ MIRU Slickline. RIH wi Bailers & GR's attempt to CO fill to PBTD. ~ MIRU 1-1/2" CTU. RI CO Fill to PBTD. POOH. ~ MIRU Eline. RIH re-perforate 62-5 sand. POOH. RD. /' ~ PUMU GP Equipment onto CT. RIH. Gravel pack 62-5 sand. Unload well wi N2. POOH. ~ Demobe CT Equipment. ~ MIRU Dyna Coil Unit. RIH wi Capillary coil tubing. RD Demobe. STATE OF ALASKA . ALAe Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS O,rr <j ì ~ t) 1 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U t Pìher1 ~ Reperf Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time E~tension . " Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development [2] Exploratory 0 1~1 ." 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-133-10158-00 7. KB Elevation (ft): 9. Well Name and Number: 20' RKB SRU 34-28 8. Property Designation: 10. Field/Pool(s): Swanson River Unit Swanson RiverlHemlock 11. Present Well Condition Summary: Total Depth measured 10,880' feet Plugs (measured) 6,328' true vertical 10,880' feet Junk (measured) Effective Depth measured 6,328' feet true vertical 6,328' feet Casing Length Size MD TVD Burst Collapse Structu ral Conductor 34' 22" 34' 34' Surface 2,038 11-3/4" 2,038' 2,038' 3,070 psi 1,510 psi Intermediate Production 10,881 7" 10,881' 10,881' 6,340 psi 3,830 psi Liner Perforation depth: Measured depth: 6,260' to 6,275' i)CANNEP Ð~C 1 8 ZfY¡¡: , ~,."I .o~" . & ,.I,j,J True Vertical depth: 6,260' to 6,275' Tubing: (size, grade, and measured depth) 2-7/8", N-80 @ 10,755' Packers and SSSV (type and measured depth) Brown retrievable packer Model HS-16-1 @ 10,652; cemented in place tbg @ 5,400' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft NOVa 1 2005 nla Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: nla 800 metlday nla nla nla Subsequent to operation: nla 800 mcflday nla nla nla 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development [2] Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: OilO Gas [2] WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~Undry Number or NIA if C.O. Exempt: nla Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager ",r" ~:!\ ~ ID-2b-Ð5" Signature / ~ 'V' Phone 907-276-7600 Date J-:' C/ . . Form 10-404 Revised 04/2004 AFE 162509 ORIGINAL Submit Onglnal Only Ñ API# 50-133-10158-00 RKB =20.0' ID= 10,880' PB'ID= 10,832' Max De'liatiQn =1.3°@4345' SRU 34-28 Current dwg 08-25-04 Size 22" 11-%" 7" Rtm 34' 2,038' 104' 4,618' 6,616' 8,495' 10.881' 10,755' 2%" Item Jewel y ID Descri don To OD A B C 6328' 6550' 10,676' HES FasDrì11 Retainer HES Eas Drill Retainer HES Eas Drill Retainer drawn by SLT, revised 10/05 DED e Summary for SRU 34-28 Reperf e 8/22/04 PJSM, rig up Schlumberger and pressure test to 3000 psi. RIH with 10' of 1 11/16" wts, CCL, 10' of 21/8" Spiral EnerJet perf gun. RIH at 80 FPM slowing at gas lift mandrels as not to hang guns in oversize mandrels. Tie with RST log 1-10-04 down to 6290'. Spot perf gun from 6,265 to 6,275' and fire perfs. WHP was 2260 psi and 2275 psi after shot. POOH. RD Schlumberger, all shots fired and had no trouble with GLM at 5,526' SRU 34-28 (162509) reperf morning report summary, CONFIDENTIAL: last revised 10/24/2005, Page 1. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U StimulateU Other ~ Install Capillary Tut Performed: Alter Casing 0 Pull TubingO Perforate New Pool 0 WaiverO Time ExtensionO Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development [2] ExploratoryD 63-0007-0 3. Address: 909 West 9th Ave. Stratigraphic D ServiceD 6. API Number: Anchorage AK 99501 50-133-10158-00 7. KB Elevation (ft): 9. Well Name and Number: 184' SRU 34-28 8. Property Designation: 10. Field/Pool(s): Swanson River Sterling, Alaska Swanson River Field I Tyonek 11. Present Well Condition Summary: Total Depth measured 6550' feet Plugs (measured) 6550' true vertical 6550' feet Junk (measured) none Effective Depth measured 6550' feet true vertical 6550' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 34' 22" 34' 34' 1170 psi Surface 2038' 11 3/4" 47# J-55 2038' 2038' 3070 psi 1510 psi Intermediate Production 10880' 7" 23#,26#,29# N-80 10880' 10880' 6340 psi 3830 psi Liner Perforation depth: Measured depth: 6260'-6270' RECEIVED True Vertical depth: 6260'.6270' OCT () 5 2004 Tubing: (size, grade, and measured depth) 27/8" 6.4# N-80 6550' AI ¡ . 2g (8 O,l & Gas Cons Comm" . . .ISSlon Packers and SSSV (type and measured depth) none - cemented in place tubing @ 5800' Anchorage . . 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Installed a 1/4" duplex stainless steel capillary tube inside the 2 7/8" tubing to inject methanol downhole and prevent hydrate formation during unloading and subs 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1500 0 30 1700 Subsequent to operation: 0 3500 25 30 1900 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run ExploratoryD Development [2] Service D Daily Report of Well Operations 16. Well Status after proposed work: Oil 0 Gas [2] WAG 0 GINJ 0 WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Larry P. Greenstein Printed Name Larry P. G~enstein Title Production Tech Signature ¡:(;;~~n f/ it /J~A A±: Phone 263-7661 Date 10/1/2004 Form 10-404 Revisect64/2004 f'oBFL St:V ~ ~ é:.\JlJ't Submit Original Only IØ)MS UNOCAL8 API# 50-133-10158-00 ~ ~ Swanson River Field Swanson River Unit Well SRU 34-28 Last Completed 5/16/63 Capillary Tube Installed 9-20-041 RKB =20.0' c & b' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I =- ~ @I U :: TD= 10,880' PBTD= 10,832' Max Deviation = 1.3°@4345' T aslng u I n a Size Wt Grade ID Too Htm 22" Surf 34' 11-W' 47 J-55 11" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' 7" 29 P-110 6.184" 8,495' 10,881' Tubin!! 231.' I 6.4 I N-80 2.441" I Surf I 10,755' 1/4" I 0.08 I 2205 SS I 0.18" I Surf I 6,260' J ewe ry Item Top OD ill Description GLM #1. 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #8. 6517' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #9. 7411' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#10. 8146' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #11. 9387' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC SafetY Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-16-1 4 10,690' Profile Nipple, Camco "0" Nipple w/Stuck Plu2 5 10,755' WLEG Venturi Shoe Wellbore Integrity 1. 2. Passed an Active MIT 5/27/99. [1557 psi on csg annuli for 30 min.] Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi. Within a week injection was at 300 to 400 bpd@ 1100 psi Static pressure survey ran on 4/13/0 I w/ fluid level at 8457' indicated a BHP of 3,136 psia @ 10,690' 3. 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GLV leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg@ 1978'. BHP=2918psia@ 10,700' During RST log on 1/10/04 found fluid level in tbg@2081'. In csg fluid level @ 3394'. 5. 6. Attempt to Jug test failed on 2/24/04. Set plug in "0" nipple. PT well to 1100 psi. Bled off to 100 psi. Perforations Zone Top Htm Ft SPF Comments Sqz 6235 6245 10 6 Saz oerfs 62.5 6260 6270 10 6 Perforations Sqz 6335 6345 10 6 Saz oerfs WSO 10,707 10,708 I 5 WSO HI 10,716' 10,725 9 4 Oven H2 10,737 10,762 25 4 Covered w/ fill O:\Gas CFT\Openmind\Swanson\Swanson River Unit\34-28\Schematics\SRU 34-28 Schematic 09-20-04.docLPG 9/27/20049:58 AM I In. 11'&1\11\1 \) Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com ') ¡tea- tJ~ I~ 3 - ðtJ 'i UNOCAL Debra Oudean G & G Technician Date: September 29, 2004 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 ~~~~'Jli.IÐ! SRU ] WELL I, LOG TYPE' " ' " .' ISCALEILOG DATEIINTERVAL LQGGED a-LlNEIFlLMlcD ,,:SRU 23-27 [RESERVOIR SATURATION TOOL SIGMA MODEI51NCH I 8/22/200415250-8350 ....--111f1[ !SRU 34-28 [COMPLETlo.~ R~CORD, -- . 15 INCH I 8/22/2004,16265-6275 - I 11 1 1 SCANNED NO\} 0 8 20D4 :~ïningandr rning one copy of this transmittal or FAX to (907) 263-7828. /~~/of ~,..., Date: ~-~: Winton On our SRU 34-28 well, we have a plug stuck in the liD" profile nipple @ 10,690'. Unocal proposes to leave the plug in the profile nipple and perform the following to Abandon the Hemlock Punch the tbg above the plug. Utilizing a 6' x 1.56" tbg punch gun. Set a cmt retainer, on Eline, between the production pkr @ 10,652' and the tbg punched holes. RI wI CT stab into the retainer. Pump 8 bbls of cement to P&A Hemlock. If there is any question please call. Thanks Workover Foreman I Engineering Tech Unocal Alaska (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 - A B C D / '- F G H I J K l M N 1 STATE OF ALASKA 2 - ALASKA Oil AND GAS CONSERVATION COMMISSION - 3 REPORT OF SUNDRY WELL OPERATIONS 4 I 5 1. Operations Abandon W Suspend W Operation Shutdown D Perforate 0 Waiver W Other ~ ""6 Performed: Alter Casing 0 Repair Well 0 Plug Perforations [J Stimulate [J Time Extension 0 7 Change Approved Program U Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well U Install Capillary Tube -!L 2. Operator Union Oil of Califomia 4. Current Well Class: 5. Permit to Drill Number: 9 Name: aka Unocal Development ~ Exploratory 0 63-0007-0 J.Q. 3. Address: 909 West 9th Ave. Stratigraphic =:J Service 0 6. API Number: 11 Anchorage AK 99501 50-133-10158-00 12 7. KB Elevation (ft): 9. Well Name and Number: 13 184' SRU 34-28 14 s. Property Designation: 10. FieldlPool(s): 15 Swanson River Sterling, Alaska Swanson River Field 1 Tyonek 16 11. Present Well Condition Summary: 17 18 Total Depth measured 6550' feet Plugs (measured) 6550' 19 true vertical 6550' feet Junk (measured) none 20 21 Effective Depth measured 6550' feet 22 true vertical 6550' feet 23 24 Casing Length Size MD TVD Burst Collapse 25 Structural 26 Conductor 34' 22' 34' 34' 1170 psi 27 Surface 203S' 11 3/4' 47# J-55 2038' 203S' 3070 psi 1510 psi 28 Intermediate 29 Production 10SS0' 7' 23#,26#,29# N-SO 10SS0' 10S80' 6340 psi 3830 psi 30 Liner 31 32 Perforation depth: Measured depth: 6,260' to 6,270' RECEIVED 33 n(\T C} 0 '>M\A 34 True Vertical depth: vu " -' -... 6,260' to 6,270' SEP 2 82004 r-- 35 36 Tubing: (size, grade, and measured depth) 27/8' 6.4# N ~, Alaska Oil ~IJ as \"ons. \,,0 37 ""-' Ul, I 38 Packers and SSSV (type and measured depth) none - cemented in place tubing @ 5S00' A charaDe 39 40 12. Stimulation or cement squeeze summary: 41 Intervals treated (measured): 42 43 Treatment descriptions including volumes used and final pressur Installed a 1/4' duplex stainless steel capillary tube inside the 2 7/S' tubing to inject methanol 44 downhole and prevent hydrate formation during unloading and subsequent production. 45 13. Representative Daily Average Production or Injection Data 46 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 47 Prior to well operation: 0 1500 0 30 1700 48 Subsequent to operation: 0 3500 25 30 1930 49 14. Attachments: 15. Well Class after proposed work: 50 Copies of Logs and Surveys Run ExploratoryD Development 0 Service W 51 Daily Report of Well Operations I 16. Well Status after proposed work: 52 OilU Gas l:d WAG -Ou GINJ D WINJ U WDSPL U 53 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 54 55 Contact Larry P. Greenstein 56 57 Printed Name Larry P. Greenstein Title Production Technician 58 # 111" 1/ A 59 Signature Rr,J. II r: .Ã .. ITT. Phone 263-7661 Date 9/24/04 J/ vv , Form 10-404 Revised 12/2003 (""\ n \..C.lMAJ RBDMS SF L SEP j ~ 200~ ORDCAL. API# SO-133-101SS-OO ~ ~ RKB =20.0' k=apillary Tube InstaUed 9-20-041 Swanson River Field Swanson River Unit Well SRU 34-28 Last Completed 5/16/63 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ... '" 0- N (§I t.) 0 ... TD= 10,880' PBTD= 10,832' Max Deviation = 1.3° @4345' c & T b" aslng u In g Size Wt Grade ID TOD Btm 22" Surf 34' II-y." 47 J-55 II" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' 7" 29 polIO 6.184" 8,495' 10,881' Tubine: 2 Ys" I 6.4 N-80 2.441" I Surf I 10,755' 1/4" I 0.08 2205 SS 0.18" I Surf I 6,260' J ewe ry Item Top OD ID Description GLM #1. 1498' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #8. 6517' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #9. 7411' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #10. 8146' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #11. 9387' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.867" Cameo MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-ICr-1 4 10,690' Profile Nipple, Camco "D" Nipple w/Stuck Plu!! 5 10,755' WLEG Venturi Shoe Wellbore Integrity I. 2. Passed an Active MIT 5/27/99. [1557 psi on esg annuli for 30 min.] Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi. Within a week injection was at 300 to 400 bpd@ 1100 psi Static pressure survey ran on 4/13/0 I w/ fluid level at 8457' indicated a BHP 00,136 psia @ 10,690' 3. 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down esg. Found esg in communication with tbg. Suspect GLV leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg@ 1978'. BHP = 2918 psia@ 10,700' During RST log on 1/10/04 found fluid level in tbg@ 2081'. In csg fluid level @ 3394'. 5. 6. Attempt to Jug test failed on 2/24/04. Set plug in "D" nipple. PT well to 1100 psi. Bled off to 100 psi. Perforations Zone TOD Btm Ft SPF Comments SQz 6235 6245 10 6 SQZ perfs 62.5 6260 6270 10 6 Perforations SQZ 6335 6345 10 6 SQZ Perfs WSO 10,707 10,708 I 5 WSO HI 10,716' 10,725 9 4 Open HZ 10,737 10,762 25 4 Covered w/ fill O:\Gas CFT\Openmind\Swanson\Swanson River Unit\34-28\Schematics\SRU 34-28 Schematic 09-20-04,docLPG 9/27120049:58 AM I Ir'\. &&'I&\&ï\1 ~') Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com /63,,-, (Jt) 7 UNOCAL8 "-Alaska Debra A Oudean G & G Technician August 18, 2004 To: Helen Warman 333 W 7th Ave, Suite 100 Anchorage, AK 99501-3539 AOGCC From: Debra Oudean 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Alaska DATA TRANSMITTAL - SRU SCU Transmitting as follows: SCU 42A-05 I COMPLETION RECORD 3 OWEN 3.5 TUBING PATCHES 2" !5 INCH! 6/26/2004! 2200-6060 I 11 1 f 1 I POWERJET 6 SPF, 60 DEGREE PHASED I J I___J_.-.--L-- SCU 42A-05 I COMPLETION RECORD 3.5 WEATHERFORD RETRIEVABLE i 5 INCH! Ii 2000-2200 t 11 1 I. 1 I BRIDGE PLUG ! ¡. ! I ¡ SCU 42A-05 ¡COMPLETION RECORD FAS DRILL BRIDGE PLUG 1.56 TUBING-¡5INCH i 6/16/200417550-10065 --1---1í'---1r'-1 ----- nn__lpU~CHER__._n "n_n_____- .. ----_n_---__.___L___~! . .____1 - .. - . L -_! --- '.__.! ¡SRU 23-27 ¡¡COMPLETION RECORD TUBING PUNCH CEMENT RETAINER ]5 INCH:I 6/2/2004:110980-11142 :L__~L___~L! 1SRU 24-2~.__JlÇg~~_~ÉTION RECORD 2" HSD POWERJETS _..Jl5JNC~JL.~t!~?'Q.~.~II~~~~~~~~~..__...._..JI._.....)JL._~l.)- SRU 24-28 I COMPLETION RECORD 2" HSD POWERJETS, 2.875 FAS Drill 15 INCH i 6/17/200416328-6345 1! 1 i 1 I Retainer ! : I , I SRU24~i8-'----ÎCOMPLE110N RECORD 2" POWERJET HSD, 6SPF, 60 DEGREE ¡5INCHI 6/25/20041549ö-630g---",----c--"------'1r-1f1 ..----.------'.. -_..._J '!:.~~.§-~Q_.._. "'~-"--'''''- .......-..-..-...-..-.....,.... '"'''-'-...-.''''''''' ...-..-..----,...---....--...--........--...J ..._-_......._J ....--.-.....--.....-..J........---.--.,..... .. ... ..-.: -.-,.,-------...' . ,..... -..,..!.-........ SCANNED NO\! 0 5 2004 RECEIVED AUG 1 9 2004 -~'~.~, ;- , .-¡;';J: . .'~ Please acknowled~ reytpt tg :n7. a")1 ret~ng one copy of this transmittal or FAX t~ <¿7) 263l2So¡/ I ReCeiVed' /'10' /f/~ I Date: tV¡tO'Ø ¡Ø 'r ) STATE OF ALASKA '\ ALASKA ùlL AND GAS CONSERVATION COMMIS~ .iN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilD Gas 0 Plugged D Abandoned D 20AAC 25.105 GINJ 0 WINJ D WDSPL D No. of Completions 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 4a. Location of Well (Governmental Section): Surface: 660' Nand 1,530' W of the S.E. corner of Sec. 28, T8N, R9W, SM Top of Productiv Straight Hole Total Depth: 4b. Location of Well (State Base Plane Coordinates): Surface: x- 346,202 y- 2,467,182 TPI: x- 346,202 y- 2,467,182 Total Depth: x- 346,202 y-2,467,182 18. Directional Survey: Yes 0 No 0 (lfl~¡í~;;ì~¡::·I. iÙ"ii'''1 j r In fþ¡T~· ~, j~9.JJ-! i. 1~:¡U1~a} (. ~ . . ~ ,.....-....... -:-'~~-#......~ ~ l~iI"'"'-"'" !'~'"T"'~-:'!II!T'''r-r-,,:' \i""'i"'\\'" 21. Logs Run: Temperature survey Suspended 0 20AAC 25.110 Other 5. Date Comp., Susp., or Aband.: 6/25/04 6. Date Spudded: 7. Date TD Reached: 8. KB Elevation (ft): 20' 9. Plug Back Depth(MD+ TVD): 6,328/6,328 10. Total Depth (MD + TVD): 10,880/10,880 11. Depth Where SSSV Set: 10,652 19. Water Depth, if Offshore: nla feet MSL WAG D 1 b. Well Class: Development 0 ExploratoryD Service D Stratigraphic TestD 12. Permit to Drill Number: ~ ~ ¡hW70 13. API Number: I 50-133-10158-00 14. Well Name and Number: SRU 34-28 15. Field/Pool(s): V Swanson ~;;;::::rt ~ 16:..:'~??~,~y Design~tion: ~ Swanson River -. '- 17. Land Use Permit: 20. Thickness of Permafrost: nla 5CANNED FES 0 ril 2006 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 22" 0' 34' 0' 34' cemented @ 341' 0 11-3/4" 47# J-55 0' 2,038' 0' 2,038' 16" 1 ,400 sx 0 7" 23, 26, 29# N-80, 0' 10,881 0' 10,881' 105/8,97/8, 1,800 sx 0 P-110 95/8 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): Zone Top Btm Ft SPF Comments Sqz 6235 6245 10 6 sqz perfs wi 2", 4spf, PJ 62.5 6260 6270 10 6 Perf wi 2", 6spf, PJ Sqz 6335 6345 10 6 sqz perfs wi 2", 4spf, PJ WSO 10,707 10,708 1 5 WSO H1 10,716' 10,725 9 4 Open H2 10,737 10,762 25 4 Covered wi fill 24. SIZE 2-7/8" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 10,755' 10,652 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6,335 - 6,345 MD 19 bbls I G-Neat 6,235 - 6,245 MD 10 bbls I G-Neat 10,716 - 10,762 MD 16.5 bbls I G-Neat Water-Bbl: Water-Bbl: none NJ6 1 .~ 1_ml~ OR\G\Ni\l 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): June 25, 2004 Flowinç¡ Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: 6/25/2004 24 hrs Test Period ..... 800 mcf/day Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Press. 24-Hour Rate -+ 800 mcf/day 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ? J ru;> I t i1 'J.. "'U... II ).. :>... 7 ~8Fl Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): RECEIVED AUG 1.8 2004 Alaska Oil & Gas Cons. Commission Anchorago Gf 28. GEOLOGIC MARKEF ) ML.. TVD 29. -., FORMATION TESTS Include and briefly suo lize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME RECEIVED AUG 1.8 2004 Alaska Oil & Gas Cons. Commission Anchorage 62-05 Sand 6,244' MD 6,244' TVD 6/25/040.83 mmcflday @ 1149 FTP 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 prin::~a:~: y:;#~ Title: Drilling Manager Phone: 907-276-7600 Date: 8/12/2004 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 RKB =20.0' J b. j ~ ) j ] ] - ~ 'ID= 10,880' PB1D=10,832' Ma x De wa tion = l.:¡O @4345' Currentdwg 06-25-04 Size 22" 1]-%" 47 ]]" Surf 2,038' 7" 29 N-80 6.184" Surf 104' 7'~ 23 N-80 6.366" 104' 4,6]8' T' 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 8,495 ' 7t, P-110 6.184" 8,495' 10,881' I 6.4 I N-80 I 2.441 Surf 10,755' Item GLM #1- GLM #2. GLM #3. GLM #4. GLM #5. GLM #6. GLM#7. GLM #8. GLM #9. GLM#10. GLM #11. GLM #12. 2 3 4 5 A B C ]498' 2484' 3489' 370]' 4059' 4354' 5526' 6517' 7411' 8146' 9387' 10,598' 10,643' 10,652' 10,690' ]0,755' 6328' 6550' 10,676' Depth Top OD 2.867" 2.867" 2,867" 2,867" 2,867" 2.867" 2,867" 2,867" 2,867" 2.867" 2.867" 2,867" 2,438" 2.5 w m 5.968" x 5.00" 5,968" x 5,00" 5,968" x 5,00" 5.968" x 5.00" 5,968" x 5,00" 5,968" x 5.00" 5,968" x 5.00" 5,968" x 5,00" 5,968" x 5.00" 5.968" x 5,00" 5,968" x 5,00" 5.968" x 5.00" 3,688" 5,875" Description Cameo MM GLM 3-112" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-112" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" CameoMM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-]/2" x 2-7/8" Cameo MM GLM 3-]/2" x 2-7/8" Brown CC Safety Joint Brown Retrievable Pkr, Model HS-16-1 Profile Nipp]e, Cameo "D" Nipp]e WLEG Venturi Shoe HES FasDril1 Retainer HES EasyDril1 Retainer HES EasyDril1 Retainer Description Zone P f 0 Top Btm Ft t SPF Comments WSO 10,707 10,708 ] 5 WSO H] 10,7]6' 10,725 9 4 Open H2 10,737 10,762 25 4 Covered w/ fil1 PrQPosed 5/3/2004 SL T >Information >Well >Directional Surveys >F :~~ey ...... S~lect W~II: SRU 34-28_1 .H~I ~I Report Name Well Date Created Position Log SRU 34-28 8/12/2004 Well Name KB Surf X Surf Y (ft) (it) (it) SRU 34-28 INJECTOR - CONVERTED 501331015800 184 346,202 2,467,182 CURRENT STATUS API ,- Interpolate -I MD (ft) o 10,880 TVD (ft) o 10,880 SSTVD (it) 184 -10,696 X. Off Y Off (ft) (ft) o 0 o 0 X. (ft) 346,202 346,202 y (it) 2,467,182 2,467,182 Inc Azimuth (deg) (deg) No Data No Data ) 5/28/04 Held PJSM with Slickline (Pollard) on rigging lubricator. RU wireline lubricator and test to 2,500 psi. RIH with 2.30 gauge ring to 10,690, POOH. RIH, set GL V in #4 mandrel. (Had a hard time setting the valve). POOH, RD slickline equipment 5/29/04 No Operations. Held PJSM, RU Hot Oil to test tubing, pump 90 bbls with no success. It seem that the standing valve may be leaking. (Will get Slickline to pull the standing valve when they finish on 23-27 well) Moved Hot Oil truck to 23-27 5/31/04 No Operations. Move Slickline unit to from 23-27 to 34-28. Held PJSM, and received work pennit. RU Lubricator and equipment. Test to 2500 psi. RIH with SV pulling tool, Tag @ 10,690'. Attempt to pull standing valve, working up and down using jars. (0 psi on tubing, 100 psi on production casing). Jar down on standing valve to close by-pass, Pump down tubing with Pollard truck. Casing pressure increased to 350 psi. Sheared off standing valve, POOH. Bleed casing pressUre to 100 psi, (GAS) RIH with Ponytail to check each GL V, while pumping with Pollard truck. Starting to get back water out the casing valve on the backside. Called Peak to spot tank to take returns into, Spotting tank and liner on pad. POOH with Ponytail, No leaks found in mandrels. RIH with 2.230 solid plug, Pump plug down @ 1 bpm, Plug slowed down at 10422'. This could be where the leak is in the tubing. POOH RIH with "W" circ tool with stop below, set at 10,000' and pressure test tubing to 1,000 psi for 15 min. test good. POOH While POOB the "W" circ tool stuck @ 7,402'. It may be that the rubber element rolled coming through the 3 1/2" x 2 7/8" mandrel causing it to hang. Sheared off of tool and POOH. (Will go in the hole with weight bars and jars in the AM) 6/1/04 No Operations. Held PJSM on rigging up Pollard lubricator and equipment. RU & test lubricator to 1,500 psi. RIH with 2"JDC to 7342' & latch circ plug, Jar up and pull 1600# pulled free. POOH. RIH with 2" SS to pull SV, @ 10,690' Couldn't latch, POOH. RIH with skirted 2" SS JDC to 10,690', the vavle would not equalize. POOH RIH with 2.5 JUS pulling tool to 10,690', Couldn't latch. POOH RD Slickline equipment. (Moved to 43B-08.) 6/9/04 No Operations. Simops meeting with production. Wait on Schlumberger. Schlumb arrived on location. Spot equipment. PJSM Ann 6' x 1.56 tbg punch gun. PU same. PT lubricator to 300 low. Leak on pump-in sub. Fixed same. PT Lub to 300 low and 1500 high. No issues. RIH w/ gun. Tag plug in profile nipple. Log up. Correlate to tbg tally. Position gun on depth shot tbg punch hole @ 10,680.6' to 10,686.6' . (1 ') above the stuck SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 1 ) ) plug. POOH. All shots fired. PUMU HES EZ Drill Retainer Pla. Arm setting tool. RIH set retainer @ 10,675.6' (Btm @ 10,677.7'). (3') above top oftbg punch holes. POOH RD and release Schlumberger 6/12/04 No Operations. SIMOPS Meeting wi Production. DS in field. Spot CT Equipment on location, Pull test CTC to 16k. OK. Cont RU and spot equipment utilizing winch truck and loader. Pressure test CTC to 1500 psi. OK. Tested BOPE to 300 psi low and 3500 psi high. OK Secure Injector head. SDFN 6/13/04 No Operations SIMOPS Meeting wi Production. Schlumberger CT Crew on location. PJSM. Start Equipment. Prime pump. PUMU Weight Bar, XO's, Spacer Pipe, Centralizers, HES Stinger. Stab Injector Head. Guy off same. Shell test BOPE to 300 psi (Low) & 3500 psi (High). OK. SITP 0 psi. Open well. RIH (dry) at 100 fpm, slowing down to 30 to 40 fpm going through GLM's. Making weight checks every 1000'. Set down @ 1 0,592' (electronic counter), 10,650' (mechanical counter). #1.2 GLM @ 10,598' MD. PU turn on pump @.5 bpm wi 150 psi. increased rate to 1.25 bpm wi 850 psi. RI set down same spot. Pressure came up to 1700 psi (CT now full). PU sàw 150 psi loss. Continue working CT setting down same spot and seeing pressure differential each time. Became comfortable with being stabbed into retainer. Mixed 16.5 bbls ofG neat @ 15.8 ppg (80 sxs) Start cmt down @ 1.25 bpm wi 1150 psi. decrease rate to 1 bpm wi 2500 psi after 5 bbls away. Continue pumping @ 1 bpm. Start displacement rate.@ 1.5 bpm wi 2300 psi. @ 21 bbls away rate @ 1.5 bpm wi 2500 pS,i. Decrease rate t9 .7 bpm wi 2500 psi. (CT displacement 22 bbls) Stop pumps. Final pressure 2500 psi. Py out of retainer. POOH. 16.5 bbls (80sx) cmt in place. CT BHA at surface. Crane hydraulics contaminated wi diesel. Remedied same. Crane fixed. Unstab injector head. BO BHA. Secure equipment. SDFN. SWITCH TO RECOMPLETION AFE 162509. No Operations Rig up Schlumberger, held safety meeting and pressure test lubricator MU Schlumberger 1.56" perf gun. Gun set down at 10,193'. Attempted to fire gun at 10,163'. Did not fire, pulled tools. Check Schlumberger tools. Line was kinked appro x 180' from rope socket. Cut line and re-headed rope socket. Started in hole with perf gun. 6/14/04 Go in hole with Schlumberger tubing gun (1.56 OD) and punched 41 holes from 10,163 to 10,173'. Go in hole with Haliburton 2 1/8" OD ez-drill squeeze packer and set at 6550' Rig down Schlumberger and secure will. No Operations. Schlumb Coil Crew on location. Chk, start equipment. PJSM. RU hardline fl csg to return tame Tbg 0 psi Csg 0 psi. PU injector head stab same. Circulate CT to return tank. Shell test BOPE to 300 psi (low) & 3500 psi (high). OK. Open well. RIH making wt chks every 2000'. Stab into cement retainer @ 6550'. Start ciculating to fill wellbore. Returns to surface at 90 bbls away. Rate 1 bpm wi 2400 psi. "PT wellbore to 500 psi fl 5 min. OK. Establish circulation rate SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 2 ) ) & pressures. 0.5 bpm @ 600 psi, 0.75 bpm @ 1300 psi, 1.0 bpm @ 2350 psi, 1.25bpm @ 3500 psi, Start mixing 100 bbls of 15.8 ppg cmt (500 sx)". Start cmt down CT @ 0.9 bpm wi 3200 psi. No returns. Decrease rate tl .75 bpm @ 3400 psi after 10 bbls away. 34 bbls away. Returns to surface. Continue pumping @ 0.75 bpm @ 3400 psi. 185 bbls of cmt away (864 sx). Switched to displacement. Cement in place. PU CT 10' above retainer. CBU. Clean Blender. Mix 10 bbls ofHEC polymer. Mix 6 cuft of 20-40 gravel. Pump 10 bbls of sand slurry @ 1.0 bpm wi 2300 psi. Sand slurry @ EOCT. Reduce rate tl 0.5 bpm. Continue pumping while POOH wi CT.· Sand Slurry out of CT. POOH. POOH. Unstab injector head. BO BHA. ND BOPE. RD CT equipment. SDFN. 6/15/04 No Operations. SIMOPS meeting. No Operations. PJSM, Rig up Pollard and test lubricator to 1500 lbs. Run in hole with 2.31 OR and tagged sand at 6497' RKB Rig up tri-temp tool and log down to 6485' and log out of well. Rig down Pollard and secure well. 6/17/04 Rest crews. SIMOP's with production. Schlumberger on 243B-8 location, fire equipment and start Mobe to SRU 34-28. Spot and rig up equipment & hard lines. Berm in equipment with pit liner. Perform BOP test (OK). State waived witness. Test all hard lines to same. Set back injector head and give access to well head for e-line PJSM, rig up Schlumberger, pressure test to 2500 psi RIH with 2" power jet perf gun and shot 41 holes from 6335' to 6345'. Tied in with RST log dated 1-10-04 MU Haliburton fas drill cement retainer 2 1/8" OD,RIH; and set retainer ~t 6328' Rig Schlumberger down and secure well. 6/18/04 No Operations. Attended SIMOP's with production at 05:30 hrs PJSM, MU BHA, pressure test. Spot tiger tank & spot C- Pump brought in from Schlumberger yard. Hauled in MBT of polymer from Schlumberger to use on job. Tag in tree - break head chamfer nozzle - tag again, stab through crossover and vales in tree. Having problem because of lack of being able to use HES centralizer on HES Polished Overshot for Retainer. RIH with coil checking wts, and set down at 2486 in gas lift mandrel. Pick up and try to work thru. No luck Pull out of hole. Add weight bar to lengthen stiffBHA to pass gaslift mandrel and try again - will not pass hanger in tree. Rack back head. Stand back head and secure for standby. Send HES field rep to machine shop to redress tool joint threads so that HES centralizers can be run in BHA Send Schlumberger crew and Peak hands to bed while waiting to get Haliburton tools machined. (we also had Baker modifie a sub into a 2.30 centralizer) Fire up units, MU 20' lub - stab tools with 2.18 HES centralizer. RIH checking weights with no problems. (The 1 " CS Hydrill threads had to be re-cut in the machine shop as some where out of spec.). SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 3 ) ) I . 6/19/04 Continue RIH checking weights every 1000'. Establish circulation rates above Retainer & tag Retainer. Pick up off retainer and finish displacement of coil with lease water brine 8.5#. Set back down on Retainer to start injection rate test. Set down on Retainer 2500#. Pump 0.25 BPM in attempt to establish injection rates into perfs. Perfs requiring greatly higher than expected pressure in inject. As pressure increased we were to slow putting extra coil weight on retainer & at 3200# we got lifted off retainer. Set back down and attempted to inject and had communications with annulus. (suspected damage retainer neck seal. Call town for discussion on bull heading) Call town discuss problem. Perfonn more diagnostics. (Decision made to set down close annulus and bull head for injection rate test.) Injection test perfonned and abnonnally high injection pressure required to inject. At 9 Bbls away at .4 BPM rate over 4000# required to inject and no break over yet. Shut down and monitor pressure leak off. Converse with town about high pressures to inject Mix 20 Bbl cement. Pump cement and displace 19 Bbls of cement in place. Pick up & check Retainer Poppet Check (OK) POOH. Continue to POOH. Set injection head back out of e-lines way & stand down coil crew for rest during e-line operations. Spot e- line. PJSM. Pressure test. Load 10' (4 shots per foot) of2" hollow carrier guns. RIH and set down at 6282'. .Tie in and shoot guns 6235' to 6245'. Had 600# over pull after shooting to start out of hole. Set e-line to' side. Lay down tools and found guns. full of hard cement. (Converse with town on foreward plan.) Decided to not run Retainer and sent e-line to 43B-8 pad. Decided to run another injection test on perfs. Perfonn injection test on surface and find 4150# before establishing injection into perfs again. Plan Foreward made to stand crew down and wait on Braiden Head Squeeze (Coil Crew has been up 17.5 hours .and we plan on working through Squeeze and clean out when starting back up) Rest crew. while planning pump schedule on Braided Head Squeeze, talking with town. Rig up.& stab injector head & pressure test. PJSM go over Braiden Head job with crew RIH and Pawl on level wind of coil spool not working. RIH and fan belt on generator goes. RIH checking weights. Establish circulation rates above perfs. RIH·below perfs and circulate bottoms up to clean hole Mix 10 Bbl cement and lay cement in hole according to schedule. 6/20/04 Finish laying 10 Bbls of cement from 6250' to 4520' in tubing. Pull above cement. Close annulus valve and start to bull head into perfs. Cement would not go into perfs at anticipated surface pressure. 250# over anticipated injection pressure we could get 0.1 to 0.15 BPM to go into perfs. Monitoring pressure by using bull head surface pressure schedule and not seeing any break over in pressure. Shut pumps down once to see if pressure drops as cement goes into perfs (no luck pressure holding fairly constant.) Start 0.1 BPM injection rate again at 300# over surface pressure schedule and not seeing surface pressure drop as fluid gradient decreases with cement being squeezed away. At 4 Bbls of cement squeezed away we were 550# surface pressure over scheduled pressure. Shut down bull head pumping with no decrease in pressure monitored. Talked to town about squeeze and washing 6 Bbls of left over cement out of tubing. Opened annulus increased pumps to 1.25 BPM rate and started washing cement out of hole. Found top of SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 4 ) ) cement at 5000' and cleaned cement out to 5790' before getting to set up to wash out. During wash out we had problems getting through gas lift mandrel at 5526' The 2.0" cement nozzle did not want to clean cement from mandrel. Worked up and down and past mandrel. Cement got harder as we increased depth from there. Made two passes across 5790' to 4520' circulating. Circulated out of hole. CT AS Racked back injector head and secured equipment. Stand down crew for rest. Peak crew cleaned up surface fluids in preparation for Drill-out activities coming next. Fire up equipment. MID new coil connecter (pull test same to 3000#). M/U 2.37" mill and Baker mud motor BHA. Stab injector head PIT and test mud motor on surface. RIH checking pick up weights often and watching for cement stringers. Crew finishing polymer fluid batching on surface. Tag weight loss at mandrel at 5526'. Made several attempts to mill through mandrel at 5526' with motor stalling (unable to feather weight through) Call town and discuss possibility of gas lift valve interference. POOH and change to 2.3 "mill. PIT and test mud motor on surface (OK). RIH and try to pass mandrel 5526' without rotating mill. No luck. Attempt to mill pass mandrel a couple times and stall every time. POOH. Talk to town and call for slickline to diagnose mandrel- gas lift valve problem. Wash tubing on way out of hole in preparation for wireline 6/21/04 No Operations PJSM, rig up wireline lubricator and test RIH with 2" LIB to 5545' and took impression of obstruction. POH, RIH with 2.25" dump bailer and tried to get sample of obstruction at 5545'. POH and bailer empty, RIH with 2.30" GR to 5545'. Could not run below obstruction. POH, RIH with 2.35" tappered swage to 5545'. Beat on obstruction (10 times) POH and swage was missing RIH with 2" JDC to 5545' and latch swage. POH with swage RIH with 1.90" tappered swage down to 5565'. POH Rigged down, secured well and moved to B43-08 No Operations PJSM, rig up wireline lubricator and test RIH with 1.90 LIB with R kickover to 5570. Saw 2 small bumps and 5545' POH RIH with 2" LIB with R kickover tool to 5570'. Saw nothing at 5545'. POH RIH with 2.25" tappered swage and hit lightly at 5545' and went down to 5570'. Worked tools thru 5545' several times RIH with 2.28" tappered swage and swaged thru tight spot at 5545'. Tagged TOC at 5815'. RIH with 2.32" tappered swage and swaged thru tight spot at 5545'. POH. 6/22/04 RIH with 2.35" tappered swage and swaged tight spot at 5545'. Secure well and wait on 2.375" tappered swage, Standby, Rig down and move to SRU 212-27, No Operations PJSM, rig up and pressure test to 1500 psi, RIH with 2.375" tappered swage. Swaged on tight spot. Spudded swage thru tight spot and would have to jar back up thru it. Every ten runs would cut wire and put new head on. It seems tight spot was getting easier to get thru but still would have to jar out of it. 6/23/04 SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 5 ) ) .. . Continuation of Pollard work after working on SRU 212-27. Rig up change tool string to 20' 1 3/4" dummy guns with 2.31 swag on bottom to mimic Baker Mill BHA, RIH through tight spot at 5545' with no problems, Change same to 2.34 swag and run through 5545' several times at different speeds with no problem. NOTE: we should be able to get Baker 2.3" Mill BHA down with no problems. We could not get 2.375" swag through same without jarring In & Out! Many hour were spent yesterday trying to get obstruction open with it. POOH Rig down Move equipment out of Slumberger's way. Send Pollard Wireline home. Coil Mobe from 212-27. Rig hard lines and hydraulics. Run Hippo Tripper through coil to clean Make up Baker coil connector pull test same to 15K Pressure test Blind BOP's. Had well head leak at DSA crossed over to BOP's. Pressure test pipe rams. Had some hydraulic hose connection problems. When found it was made up and everything worked good. Stab off BOP's make up Baker BHA with mud motor and 2.3" 3 bladed cement junk mill. Stab on BOP's and shell test Surface test Baker motor RIH checking pick up weights. Saw a slight loss in weight running through 5547' where bad spot is. Tag cement at 5808' Pick up & start circulation of gel. At 3/4 BPM rate surface pressure 1870 free spin psi. 6/24/04 Feather way into cement 5808'. Milling Cement 30' at a time and back reaming 50' up. Making about 68 FPH Milled to 6293' thru first squeeze perfs, back reamed to 6243', down to 6293' and circulate clean for leak off pressure test Pick up to 6288', close rams and pressure up to 3000 psi. Bled off to 2724 psi in 20 minutes. Bled off pressure and mill cement to 6323', back ream to 6273' and mill to 6325'. Stalled motor 5 times at this depth. Discuss options with town. Dropped 7/16" ball, pressured to 2400 psi and opened circulating sub circulate well clean with lease water and RU nitrogen truck. Displace well with nitrogen and POOH, Blow down nitrogen lines (left 2500 psi on well for perforating) Package up coil equipment in preparation for moving to SCU 42A-5. Looked at Baker mill which showed shoulders worn down from metal munching. (LIB run at a latter date showed a gas lift valve fish neck against the tubing wall. PJSM, rig up Pollard, test lubricator to 2500 psi. 6/25/04 RIH with 20' of2.125" dummy gun and couldn't go past the GLM at 5545' POOH (Pollard Wireline) RIH with 10' of2.125" dummy gun. Tool set down at 5545'. Worked tool down and coming back up thru GLM had 250 Ib overpull. POOH RIH with 5' of 2.125 dummy gun. Tool went thru GLM at 5545' and tagged cement at 6337'. Had 50 Ib overpull back up GLM. POOH RIH with 10' of2" slick wt bar down thru GLM at 5545'. Overpull thru GLM was 220 Ibs. POOH RIH with 2.25" LIB down to 6337". Hit down on obstruction. POOH and did not set any drag at GLM. Rig down and secure well No Operations PJSM, Rig up, test lubricator to 3000 psi RIH with Schlumberger temp and pressure tool and found fluid at 5930'. POOH RIH with 5' of2" 6 spfPower Jet HC perf gun to 5550' (just below GLM). POOH and had 25 lb over pull at GLM RIH with 19' of2" 6 spfPower Jet HC perf gun to 6330'. Logged on depth with RST log 1-10-04 Bled well head pressure to 1850 psi, check with testers and perforated 61 holes from 6260' to SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 6 ) ) 6270'. POOH Rig down and secure well. Well gained 2lbs of pressure when shot. Turn well over to testers Flow test 800 mcfd at 1245 psi tubing pressure hr PBU to 1716 psi. SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 8/12/2004, page 7 ) STATE OF ALASKA ALA\,J...A OIL AND GAS CONSERVATION COM I )ION REPORT OF SUNDRY WELL OPERATIONS 3. Address: PO Box 196247, Anchorage, AK 99519 Operation Shutdown U Plug Perforations D Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic D Perforate U Waiver U Stimulate D Time Extension D Re-enter Suspended Well D ~~.~_t to Dril,1 7~~eor: 07!.t"""'\ D _¿ , Exploratory D ~v I -v \0....:;,) v s.'-""'" Service D 6. API Number: 50-133-1 0158-00 9. Well Name and Number: SRU 34-28 10. Field/Pool(s): Swanson RiverlHemlock Other U 1. Operations Abandon LJ Suspend U Performed: Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Union Oil Company of California Name: 7. KB Elevation (ft): 20' 8. Property Designation: Swanson River Unit 11. Present Well Condition Summary: Effective Depth measured 10,880' feet Plugs (measured) true vertical 10,880' feet Junk (measured) measured 10,738' feet SCANNED FEB (1 1 2005 true vertical 10,738' feet Length Size MD TVD Burst 34' 22" 34' 34' 2,038 11-3/4" 2,038' 2,038' 3,070 psi 10,881 7" 10,881' 10,881' 6,340 psi Collapse Total Depth Casing Structural Conductor Surface Intermediate Production Liner 1,510 psi 3,830 psi Perforation depth: Measured depth: see schematic attached True Vertical depth: Tubing: (size, grade, and measured depth) 2-7/8", N-80 @ 10,775 Packers and SSSV (type and measured depth) Brown retrievable packer Model HS-16-1 @ 10,652 12. Stimulation or cement squeeze summary: Intervals treated (measured): see schematic attached Treatment descriptions including volumes used and final pressure: 13, Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure nla .8 MMCFPD I 0 I 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: OilD Gas 0 WAG D 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations nla o 1,245 psi Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-197 Contact Steve Tyler 907-263-7649 Printed Name Philip J. Krueger Title Drilling Manager Signature "-.¿:/t.:-/ þv¡____ Form '¿04 Revised 12/2003 Phone 907-276-7600 Date 7/27/2004 OR\G\NAL. ~M9r0~1'1 f ~~":;')iH'H'Ì.'1" '~I 1--. ,Jl\/J\., (6 ~" ~)~I}~,\l:¡ ') ) 5/28/04 Held PJSM with Slickline (Pollard) on rigging lubricator. RU wireline lubricator and test to 2,500 psi. RIH with 2.30 gauge ring to 10,690, POOH. RIH, set GL V in #4 mandrel. (Had a hard time setting the valve). POOH, RD slickline equipment 5/29/04 No Operations. Held PJSM, RU Hot Oil to test tubing, pump 90 bbls with no success. It seem that the standing valve may be leaking. (Will get Slickline to pull the standing valve when they finish on 23-27 well) Moved Hot Oil truck to 23-27 5/31/04 No Operations. Move Slickline unit to from 23-27 to 34-28. Held PJSM, and received work pennit. RU Lubricator and equipment. Test to 2500 psi. RIH with SV pulling tool, Tag @ 10,690'. Attempt to pull standing valve, working up and down using jars. (0 psi on tubing, 100 psi on production casing). Jar down on standing valve to close by-pass, Pump down tubing with Pollard truck. Casing pressure increased to 350 psi. Sheared off standing valve, POOH. Bleed casing pressure to 100 psi, (GAS) RIH with Ponytail to check each GL V, while pumping with Pollard truck. Starting to get back water out the casing valve on the backside. Called Peak to spot tank to take returns into, Spotting tank and liner on pad. POOH with Ponytail, No leaks found in mandrels. RIH with 2.230 solid plug, Pump plug down @ 1 bpm, Plug slowed down at 10422'. This could be where the leak is in the tubing. POOH RIH with "W" circ tool with stop below, set at 10,000' and pressure test tubing to 1,000 psi for 15 min. test good. POOH While POOH the "W" circ tool stuck @ 7,402'. It may be that the rubber element rolled coming through the 3 1/2" x 2 7/8" mandrel causing it to hang. Sheared off of tool and POOH. (Will go in the hole with weight bars and jars in the AM) 6/1 104 No Operations. Held PJSM on rigging up Pollard lubricator and equipment. RU & test lubricator to 1,500 psi. RIH with 2"JDC to 7342' & latch circ plug, Jar up and pull 1600# pulled free. POOH. RIH with 2" SS to pull SV, @ 10,690' Couldn't latch, POOH. RIH with skirted 2" SS JDC to 10,690', the vavle would not equalize. POOH RIH with 2.5 JUS pulling tool to 10,690', Couldn't latch. POOH RD Slickline equipment. (Moved to 43B-08.) 6/9/04 No Operations. Simops meeting with production. Wait on Schlumberger. Schlumb arrived on location. Spot equipment. PJSM Ann 6' x 1.56 tbg punch gun. PU same. PT lubricator to 300 low. Leak on pump-in sub. Fixed same. PT Lub to 300 low and 1500 high. No issues. RIH wi gun. Tag plug in profile nipple. Log up. Correlate to tbg tally. Position gun on depth shot tbg punch hole @ 10,680.6' to 10,686.6' . (1 ') above the stuck SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 7/7/2004, page 1 ") ) plug. POOH. All shots fired. PUMU HES EZ Drill Retainer Pkr. Arm setting tool. RIH set retainer @ 10,675.6' (Btm @ 10,677.7'). (3') above top oftbg punch holes. POOH RD and release Schlumberger 6/12/04 No Operations. SIMOPS Meeting wi Production. DS in field. Spot CT Equipment on location, Pull test CTC to 16k. OK. Cont RU and spot equipment utilizing winch truck and loader. Pressure test CTC to 1500 psi. OK. Tested BOPE to 300 psi low and 3500 psi high. OK Secure Injector head. SDFN 6/13/04 No Operations SIMOPS Meeting wi Production. Schlumberger CT Crew on location. PJSM. Start Equipment. Prime pump. PUMU Weight Bar, XO's, Spacer Pipe, Centralizers, HES Stinger. Stab Injector Head. Guy off same. Shell test BOPE to 300 psi (Low) & 3500 psi (High). OK. SITP 0 psi. Open well. RIH (dry) at 100 fpm, slowing down to 30 to 40 fpm going through GLM's. Making weight checks every 1000'. Set down @ 10,592' (electronic counter), 10,650' (mechanical counter). #12 GLM @ 10,598' MD. PU turn on pump @ .5 bpm wi 150 psi. increased rate to 1.25 bpm wi 850 psi. RI set down same spot. Pressure came up to 1700 psi (CT now full). PU saw 150 psi loss. Continue working CT setting down same spot and seeing pressure differential each time. Became comfortable with being stabbed into retainer. Mixed 16.5 bbls ofG neat @ 15.8 ppg (80 sxs) Start cmt down @ 1.25 bpm wi 1150 psi. decrease rate to 1 bpm wi 2500 psi after 5 bbls away. Continue pumping @ 1 bpm. Start displacement rate @ 1.5 bpm wi 2300 psi. @ 21 bbls away rate @ 1.5 bpm wi 2500 psi. Decrease rate to .7 bpm wi 2500 psi. (CT displacement 22 bbls) Stop pumps. Final pressure 2500 psi. PU out of retainer. POOH. 16.5 bbls (80sx) cmt in place. CT BHA at surface. Crane hydraulics contaminated wi diesel. Remedied same. Crane fixed. Unstab injector head. BO BHA. Secure equipment. SDFN. SWITCH TO RECOMPLETION AFE 162509. No Operations Rig up Schlumberger, held safety meeting and pressure test lubricator MU Schlumberger 1.56" perf gun. Gun set down at 10,193'. Attempted to fire gun at 10,163'. Did not fire, pulled tools. Check Schlumberger tools. Line was kinked approx 180' from rope socket. Cut line and re-headed rope socket. Started in hole with perf gun. 6/14/04 Go in hole with Schlumberger tubing gun (1.56 OD) and punched 41 holes from 10,163 to 10,173'. Go in hole with Haliburton 2 1/8" OD ez-drill squeeze packer and set at 6550' Rig down Schlumberger and secure will. No Operations. Schlumb Coil Crew on location. Chk, start equipment. PJSM. RU hardline fl csg to return tanle Tbg 0 psi Csg 0 psi. PU injector head stab same. Circulate CT to return tanle Shell test BOPE to 300 psi (low) & 3500 psi (high). OK. Open well. RIH making wt chks every 2000'. Stab into cement retainer @ 6550'. Start ciculating to fill wellbore. Returns to surface at 90 bbls away. Rate 1 bpm wi 2400 psi. "PT wellbore to 500 psi fl 5 min. OK. Establish circulation rate SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 717/2004, page 2 ) ) & pressures. 0.5 bpm @ 600 psi, 0.75 bpm @ 1300 psi, 1.0 bpm @ 2350 psi, 1.25 bpm @ 3500 psi, Start mixing 100 bbls of 15.8 ppg cmt (500 sx)". Start cmt down CT @ 0.9 bpm wi 3200 psi. No returns. Decrease rate tl .75 bpm @ 3400 psi after 10 bbls away. 34 bbls away. Returns to surface. Continue pumping @ 0.75 bpm @ 3400 psi. 185 bbls of cmt away (864 sx). Switched to displacement. Cement in place. PU CT 10' above retainer. CBU. Clean Blender. Mix 10 bbls ofHEC polymer. Mix 6 cuft of20-40 gravel. PUlnp 10 bbls of sand slurry @ 1.0 bpm wi 2300 psi. Sand slurry @ EOCT. Reduce rate tl 0.5 bpm. Continue pumping while POOH wi CT. Sand Slurry out of CT. POOH. POOH. Unstab injector head. BO BHA. ND BOPE. RD CT equipment. SDFN. 6/15/04 No Operations. SIMOPS meeting. No Operations. PJSM, Rig up Pollard and test lubricator to 1500 Ibs. Run in hole with 2.31 OR and tagged sand at 6497' RKB Rig up tri-temp tool and log down to 6485' and log out of well. Rig down Pollard and secure well. 6/1 7/04 Rest crews. SIMOP's with production. Schlumberger on 243B-8 location, fire equipment and start Mobe to SRU 34-28. Spot and rig up equipment & hard lines. Berm in equipment with pit liner. Perfonn BOP test (OK). State waived witness. Test all hard lines to same. Set back injector head and give access to well head for e-line PJSM, rig up Schlumberger, pressure test to 2500 psi RIH with 2" power jet perf gun and shot 41 holes from 6335' to 6345'. Tied in with RST log dated 1-10-04 MU Haliburton fas drill cement retainer 2 1/8" OD, RIH and set retainer at 6328' Rig Schlumberger down and secure well. 6/18/04 No Operations. Attended SIMOP's with production at 05:30 hrs PJSM, MU BHA, pressure test. Spot tiger tank & spot C-Pump brought in from Schlumberger yard. Hauled in MBT of polymer from Schlumberger to use on job. Tag in tree - break head chamfer nozzle - tag again, stab through crossover and vales in tree. Having problem because of lack of being able to use HES centralizer on HES Polished Overshot for Retainer. RIH with coil checking wts, and set down at 2486 in gas lift mandrel. Pick up and try to work thru. No luck Pull out of hole. Add weight bar to lengthen stiffBHA to pass gaslift mandrel and try again - will not pass hanger in tree. Rack back head. Stand back head and secure for standby. Send HES field rep to machine shop to redress tool joint threads so that HES centralizers can be run in BHA Send Schlumberger crew and Peak hands to bed while waiting to get Haliburton tools machined. (we also had Baker modifie a sub into a 2.30 centralizer) Fire up units, MU 20' lub - stab tools with 2.18 HES centralizer. RIH checking weights with no problems. (The 1" CS Hydrill threads had to be re-cut in the machine shop as some where out of spec.). SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 717/2004, page 3 ") ) 6/19/04 Continue RIH checking weights every 1000'. Establish circulation rates above Retainer & tag Retainer. Pick up off retainer and finish displacement of coil with lease water brine 8.5#. Set back down on Retainer to start injection rate test. Set down on Retainer 2500#. Pump 0.25 BPM in attempt to establish injection rates into perfs. Perfs requiring greatly higher than expected pressure in inject. As pressure increased we were to slow putting extra coil weight on retainer & at 3200# we got lifted off retainer. Set back down and attempted to inject and had communications with annulus. (suspected damage retainer neck seal. Call town for discussion on bull heading) Call town discuss problem. Perfonn more diagnostics. (Decision made to set down close annulus and bull head for injection rate test.) Injection test perfonned and abnonnally high injection pressure required to inject. At 9 Bbls away at .4 BPM rate over 4000# required to inject and no break over yet. Shut down and monitor pressure leak off. Converse with town about high pressures to inject Mix 20 Bbl cement. Pump cement and displace 19 Bbls of cement in place. Pick up & check Retainer Poppet Check (OK) POOH. Continue to POOH. Set injection head back out of e-lines way & stand down coil crew for rest during e-line operations. Spot e- line. PJSM. Pressure test. Load 10' (4 shots per foot) of2" hollow carrier guns. RIH and set down at 6282'. Tie in and shoot guns 6235' to 6245'. Had 600# over pull after shooting to start out of hole. Set e-line to side. Lay down tools and found guns full of hard cement. (Converse with town on foreward plan.) Decided to not run Retainer and sent e-line to 43B-8 pad. Decided to run another injection test on perfs. Perfonn injection test on surface and find 4150# before establishing injection into perfs again. Plan Foreward made to stand crew down and wait on Braiden Head Squeeze (Coil Crew has been up 17.5 hours and we plan on working through Squeeze and clean out when starting back up) Rest crew while planning pump schedule on Braided Head Squeeze, talking with town. Rig up & stab injector head & pressure test. PJSM go over Braiden Head job with crew RIH and Pawl on level wind of coil spool not working. RIH and fan belt on generator goes. RIH checking weights. Establish circulation rates above perfs. RIH below perfs and circulate bottoms up to clean hole Mix 10 Bbl cement and lay cement in hole according to schedule. 6/20104 Finish laying 10 Bbls of cement from 6250' to 4520' in tubing. Pull above cement. Close annulus valve and start to bull head into perfs. Cement would not go into perfs at anticipated surface pressure. 250# over anticipated injection pressure we could get 0.1 to 0.15 BPM to go into perfs. Monitoring pressure by using bull head surface pressure schedule and not seeing any break over in pressure. Shut pumps down once to see if pressure drops as cement goes into perfs (no luck pressure holding fairly constant.) Start 0.1 BPM injection rate again at 300# over surface pressure schedule and not seeing surface pressure drop as fluid gradient decreases with cement being squeezed away. At 4 Bbls of cement squeezed away we were 550# surface pressure over scheduled pressure. Shut down bull head pumping with no decrease in pressure monitored. Talked to town about squeeze and washing 6 Bbls of left over cement out of tubing. Opened annulus increased pumps to 1.25 BPM rate and started washing cement out of hole. Found top of SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 7/7/2004, page 4 ) ) cement at 5000' and cleaned cement out to 5790' before getting to set up to wash out. During wash out we had problems getting through gas lift mandrel at 5526' The 2.0" cement nozzle did not want to clean cement from mandrel. Worked up and down and past mandrel. Cement got harder as we increased depth from there. Made two passes across 5790' to 4520' circulating. Circulated out of hole. CT AS Racked back injector head and secured equipment. Stand down crew for rest. Peak crew cleaned up surface fluids in preparation for Drill-out activities coming next. Fire up equipment. M/U new coil connecter (pull test same to 3000#). M/U 2.3 7" mill and Baker mud motor BHA. Stab injector head PIT and test mud motor on surface. RIH checking pick up weights often and watching for cement stringers. Crew finishing polymer fluid batching on surface. Tag weight loss at mandrel at 5526'. Made several attempts to mill through mandrel at 5526' with motor stalling (unable to feather weight through) Call town and discuss possibility of gas lift valve interference. POOH and change to 2.3" mill. PIT and test mud motor on surface (OK). RIH and try to pass mandrel 5526' without rotating mill. No luck. Attempt to mill pass mandrel a couple times and stall every time. POOH. Talk to town and call for slickline to diagnose mandrel- gas lift valve problem. Wash tubing on way out of hole in preparation for wireline 6/21/04 No Operations PJSM, rig up wireline lubricator and test RIH with 2" LIB to 5545' and took impression of obstruction. POH, RIH with 2.25" dump bailer and tried to get sample of obstruction at 5545'. POH and bailer empty, RIH with 2.30" OR to 5545'. Could not run below obstruction. POH, RIH with 2.35" tappered swage to 5545'. Beat on obstruction (10 times) POH and swage was missing RIH with 2" JDC to 5545' and latch swage. POH with swage RIH with 1.90" tappered swage down to 5565'. POH Rigged down, secured well and moved to B43-08 No Operations PJSM, rig up wireline lubricator and test RIH with 1.90 LIB with R kickover to 5570. Saw 2 small bumps and 5545' POH RIH with 2" LIB with R kickover tool to 5570'. Saw nothing at 5545'. POH RIH with 2.25" tappered swage and hit lightly at 5545' and went down to 5570'. Worked tools thru 5545' several times RIH with 2.28" tappered swage and swaged thru tight spot at 5545'. Tagged TOC at 5815'. RIH with 2.32" tappered swage and swaged thru tight spot at 5545'. POH. 6/22/04 RIH with 2.35" tappered swage and swaged tight spot at 5545'. Secure well and wait on 2.375" tappered swage, Standby, Rig down and move to SRU 212-27, No Operations PJSM, rig up and pressure test to 1500 psi, RIH with 2.375" tappered swage. Swaged on tight spot. Spudded swage thru tight spot and would have to jar back up thru it. Every ten runs would cut wire and put new head on. It seems tight spot was getting easier to get thru but still would have to jar out of it. 6/23/04 SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 7/7/2004, page 5 ) ) Continuation of Pollard work after working on SRU 212-27. Rig up change tool string to 20' 1 3/4" dummy guns with 2.31 swag on bottom to mimic Baker Mill BHA, RIH through tight spot at 5545' with no problems, Change same to 2.34 swag and run through 5545' several times at different speeds with no problem. NOTE: we should be able to get Baker 2.3" Mill BHA down with no problems. We could not get 2.375" swag through same without jarring In & Out! Many hour were spent yesterday trying to get obstruction open with it. POOH Rig down Move equipment out of Slumberger's way. Send Pollard Wireline home. Coil Mobe from 212-27. Rig hard lines and hydraulics. Run Hippo Tripper through coil to clean Make up Baker coil connector pull test same to 15K Pressure test Blind BOP's. Had well head leak at DSA crossed over to BOP's. Pressure test pipe rams. Had some hydraulic hose connection problems. When found it was made up and everything worked good. Stab off BOP's make up Baker BHA with mud motor and 2.3" 3 bladed cement junk mill. Stab on BOP's and shell test Surface test Baker motor RIH checking pick up weights. Saw a slight loss in weight running through 5547' where bad spot is. Tag cement at 5808' Pick up & start circulation of gel. At 3/4 BPM rate surface pressure 1870 free spin psi. 6/24/04 Feather way into cement 5808'. Milling Cement 30' at a time and back reaming 50' up. Making about 68 FPH Milled to 6293' thru first squeeze perfs, back reamed to 6243', down to 6293' and circulate clean for leak off pressure test Pick up to 6288', close rams and pressure up to 3000 psi. Bled off to 2724 psi in 20 minutes. Bled off pressure and mill cement to 6323', back ream to 6273' and mill to 6325'. Stalled motor 5 times at this depth. Discuss options with town. Dropped 7/16" ball, pressured to 2400 psi and opened circulating sub circulate well clean with lease water and RU nitrogen truck. Displace well with nitrogen and POOH, Blow down nitrogen lines (left 2500 psi on well for perforating) Package up coil equipment in preparation for moving to SCU 42A-5. Looked at Baker mill which showed shoulders worn down from metal munching. (LIB run at a latter date showed a gas lift valve fish neck against the tubing wall. PJSM, rig up Pollard, test lubricator to 2500 psi. 6/25/04 RIH with 20' of2.125" dummy gun and couldn't go past the GLM at 5545' POOH (Pollard Wireline) RIH with 10' of2.125" dummy gun. Tool set down at 5545'. Worked tool down and coming back up thru GLM had 250 lb overpull. POOH RIH with 5' of 2.125 dummy gun. Tool went thru GLM at 5545' and tagged cement at 6337'. Had 50 lb overpull back up GLM. POOH RIH with 10' of2" slick wt bar down thru GLM at 5545'. Overpull thru GLM was 220 lbs. POOH RIH with 2.25" LIB down to 6337". Hit down on obstruction. POOH and did not set any drag at GLM. Rig down and secure well No Operations PJSM, Rig up, test lubricator to 3000 psi RIH with Schlumberger temp and pressure tool and found fluid at 5930'. POOH RIH with 5' of2" 6 spfPower Jet HC perf gun to 5550' (just below GLM). POOH and had 25 lb over pull at GLM RIH with 19' of2" 6 spfPower Jet HC perf gun to 6330'. Logged on depth with RST log 1-10-04 Bled well head pressure to 1850 psi, check with testers and perforated 61 holes from 6260' to SRU34-28_AOGCC10-404Summary_AFE162509-162510, last revised 717/2004, page 6 ) ) 6270'. POOH Rig down and secure well. Well gained 2 lbs of pressure when shot. Turn well over to testers Flow test 800 mcfd at 1245 psi tubing pressure hr PBU to 1716 psi. SRU34-28_AOGCC1 0-404Summary_AFE162509-16251 0, last revised 717/2004, page 7 .d 11 ~ 11 11 j] -oJ TD= 16,880' PBTD= 16,832' Max Deviation = 1.3° @4345' SRU 34~28 Proposed dwg 05;03~041 m Top Btm 22" Surf 34' ]] 47 J-55 ] I" Surf 2,038' T' 29 N-80 6184" Surf ]04' 7" 23 N-80 6.366" ]04' 7" 26 N-80 4,618' 6,6]6' 7" 29 N-80 6,]84"' 6,6]6' 8,495' 7"' 29 P- 110 8,495' 10,88]' Tubing 2 y,' 6.4 N-80 I 2.44] Surf 10,755' Item GLM #1. GLM #2. GLM #3. GLM #4. GLM #5. GLM #6. GLM #7. GLM #8. GLM #9. GLM#IO. GLM#U. GLM #12. 2 3 4 5 1498' 2484' 3489' 3701' 4059' 4354' 5526' 65]7' 7411' 8146' 9387' 10,598' 10,643' 10,652' 10,690' 10,755' Top Je OD 5,968" x 5,00" 5,968" x 5,00" 5,968" x 5,00"' 5,968"' x 5,00"' 5.968" x 5,00"' 5,968"' x 5,00" 5,968"' x 5,00" 5.968"' x 5,00"' 5,968"' x 5,00"' 5,968"' x 5,00" 5,968" x 5,00"' 5,968"' x 5,00"' 3,688"' 5,875"' I, Passed an Active M1T 5/27/99, e y Description 2,867" 2,867" 2,867" 2,867" 2.867" 2,867" 2,867" 2,867" 2,867" 2,867" 2,867" 2,867" 2.438" 2.5 Cameo MM GLM 3-1/2"' x 2-7/8"' Cameo MM GLM 3-1/2"' x 2-7/8"' Cameo MM GLM 3-1/2"' x 2-7/8" Cameo MM GLM 3-1/2"' x 2-7/8"' Cameo MM GLM 3-l/2"' x 2-7/8" Cameo MM GLM 3-l/2"' x 2-7/8" Cameo MM GLM 3-112"' x 2-7/8"' Cameo MM GLM 3-112"' x 2-7/8"' Cameo MM GLM 3-]/2"' x 2-7/8"' Cameo MM GLM 3-112" x 2-7/8"' Cameo MM GLM 3-1/2" x 2-7/8" Cameo MM GLM 3-l/2" x 2-7/8" Brown CC Safety Joint Brown Retrievable Ph, Model HS-,l6-] Profile Nipp]e, Cameo "D"' Nipple WLEG Venturi Shoe ty []557 psi on esg annuli tor 30min,] 2, Used for injection in 10/2000, StaI1ed injection @ 1500 bpd @ 800 psi, Within a week injection was at 300 to 400 bpd @ 1100 psi 3, Static pressure survey ran on 4/13/01 w/ fluid level at 8457' indicated a BRP of3,136 psi a @ IO,690' 4, Attempted an active M1T in Sept 2003, Pumped over 400 bbls down csg, Found csg in communication with tbg, Suspect GL V leaking, Ran temp survey on 9/17/03, Well passed Sl MIT. Found fluid level in tbg @ 1978', EHP 29]8 psi a @ 10,700' 5, During RST log on 1/10/04 found fluid level in tbg @ 2081', In csg fluid level @ 3394', 6, Attempt to Jug test failed on 2/24/04, Set plug in "D"' nipple, PT well to I IOO psi, Bled off to 100 psi, Zone WSO HI H2 Top 10,707 10,716' 10,737 o Btm Ft 10,708 1 ]0,725 9 10,762 25 o SPF s Comments 5 4 4 WSO Open Covered w/ fìll Proposed 5/3/2004 34' 22 34' 34' 2,038' 11 3/4" 2,038' 2,038' 10,881' 7 10,881' 10,881' ~ !. Abandon U Alter casing D Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 20' 1. Type of Request: 8. Property Designation: Swanson River Unit 11. Total Depth MD (ft): 10,880' Casing Structural I Total Depth TVD (ft): 10,880' Length Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10,707' to 10,762' Packers and SSSV Type: ,--, STATE OF ALASKA 1"'"'"'\ AlA~r.A Oil AND GAS CONSERVATION COM~I.::iSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: r-"""\ oJ f""'" (.........--r OTJ 5/24(1- Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other 0 Re-enter Suspended Well D P&A and Recomp /' 5. Permit to Drill Number: Exploratory 0 )3-0007-0 ,,/ Service 0 6. API Number: / 50-13Ro;.A8-00 9. Well Name and Number: L CE:: IVED SRU 34-28 / M4 Y 10. Field/Pools(s): ~~ovL þ..~ . 2 0 2004 Swanson River 1 Hemlock 1 Tyonek: aska D/I & Gas C Ðn~ Co,í ~ PRESENT WELL CONDITION SUMMARY Anchor p II' SIan IEffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): ~nk (measured): 10,738' 10,738' Size MD TVD Suspend U Repair well D Pull Tubing D Development Stratigraphic 0 D Burst Collapse 3,070 psi 1,510 psi 6,340 psi 3,830 psi IperfOration Depth TVD (ft): TUbing Size: ITUbing Grade: 10,707' to 10,762' 2-7/8" N-80 Brown Retrievable packer Model HS-16-1 Packers and SSSV MD (ft): 10,652' ITUbing MD (ft): 10,775 12. Attachments: Description Summary of Proposal l.:J Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: ~a. Verbal Approval: 6/2/2004 /' 13. Well Class after proposed work: / Exploratory D Development 0 Service D 15. Well Status after proposed WJk: 0 0 Oil D Gas 0 Plugged Abandoned WAG D GINJ D WINJ 0 WDSPL 0 Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 907-263-7649 Printed Name Steve Tyler Title Acting Drilling Superintendent Signature /. -;;( Æ~ Phone 907-276-7600 Date ~ COMMISSION USE ONLY 5/26/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~. , g 7 Plug Integrity 0 BOP Test 0 Other: Subsequent Form Required: I 0 - 407 Approved by: Or¡&;r.~¡ s¡~[.~(, 6..1 .5;J¡Ï';¡"j ¡t.. I~OiT(¡;:::; Form 10-403 Revised 12/2003 Mechanical Integrity Test D 0 Location Clearance RBDMS efl 1\IM 0 3 1~~~ COMMISSIONER BY ORDER OF THE COMMISSION ~œ s"i~ 0 RIG I ~11:tTIONS ON REVERSE ... ¿ ,r---, 1"'"'"'\ Workover Summary for SRU 34-28: 1. Prep-Work- Conduct a pre-job assessment of location. Manage issues as they are revealed. Complete CT Checklist. Prep-Work- MIT surface wellhead equipment. Prep-Work- RU slickline RIH change out GLV's to Dummies. Jug test tbg. Diagnose any tbg leaks, Remedy same. Prep-Work- Retrieve plug from liD" nipple. RIH wI brush reciprocate fl 10,700' to 10,600'. POOH, RD. // Prep-Work- Eline tbg punch holes at 10,700'. Set cmt retainer @ 10,680'. /' Mobe 1-1/2" Coil Unit to Location. Mobe/Spot Coil Unit & accessory equipment on liner. /' Berm in same. 2. 3, 4. 5, 6, 7. CT - NU 3-1/16" x 4-1/6" 10m adapter flng, Pump-in Sub, Riser & BOP's. Rig up coil tubing unit. RU surface lines. CT - Thread 1-1/2" CT into injector head. MU CTC & test plate. Launch Hip~-Trip, Nerf ball, 1.0" Drift ball. Fill CT. Pull & pressure test CTC. Pressure test BOPE/ CT - MU weight bar(s), cement stinger. Shell test BOPE. CT - RIH stab into cmt retainer. pump~90f cmt to P&A Hemlock. POOH. /' SWITCH TO RECOMPLETION AFE 8. 9. 10. 11. 12. EL - Eline punch holes in tbg @ 10,630'. Set EZ cmt ret @ 6550'. / CT - RIH wI CT. stab into;etainer. Circulate down CT while taking return up tbg x csg annuli. Bring TOC to 5800'. POOH wI CT. CT - Secure well. RD & CT equipment. WL - Slickline temp survey to confirm TOC, WOC fl 72 hrs. /' EL - MIRU Eline. RI perforate sqz holes @ 6335'-6345'. RIH set cmt ret@6325'. /' CT - RU CT. RIH wI cmt stinger on. Stab into retainer @ 6325'. Cmt sqz 6335' - 6345' wI 50 to""'- 100sks. POOH. EL - RU Eline. RI perforate sqz holes @ 6235'-6245', RIH set cmt ret @6220'. /' CT - RU CT. RIH wI cmt stinger on. Stab into retainer@ 6220'. Cmt sqz 6235' - 6245' wI 50 to 100sks. POOH. WOC. CT - RIH wI motorlmill. Mill cmt retainer(s) and CIJlt. Pressure test sqz perfs individually, Continue to drill out to 6500'. CBU / 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. CT - Jet well dry wI N2. POOH. Trap 1200 psi in tbg. RD Demobe CT. EL - RU Eline. RIH Perforate 62.5 sand @ 6262 to 6272 wI 10' x 2" 6spf HC. / Secure operations r ~ It- ~loC1L p~ T 1 ~ UNOCAL8 API# 50-133-10158-00 RKB =20.0' ~ ] ] ] J ~ r--ŒJ J tilt. ~ ~ @t u 0 .... ~ ] J ~ J ~I ]'i1 ~~ ~I ~: ~!1 Î I, TOF ¡l\l ,:¥iJ !I Þ ~ ¡~ ;. Q TD= 10,880' PBTD= 10,832' Max Deviation = 1.30 @4345' SRU 34-28 Actual dwg 05-16-63 ¡CURRENT COMPLETION! Swanson River Field Swanson River Unit Well SRU 34~28 Last Completed 5/16/63 Casing & Tubing Size Wt Grade ID Top Btm 22" Surf 34' ll-y." 47 J-55 II" Surf 2,038' T' 29 N-80 6,184" Surf 104' 7" 23 N-80 6.366" 104' 4,618' 7" 26 N-80 6.276" 4,618' 6,616' 7" 29 N-80 6.184" 6,616' 8,495' T' 29 P-IIO 6.184" 8,495' 10,881' Tubing 21.' I 6.4 I N-80 I 2.441 I Surf I 10,755' Jewelry Item Top OD lD Description GLM #1. 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #8. 6517' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #9. 7411' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#10. 8146' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#l1. 9387' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-16-1 4 10,690' Profile Nipple, Camco "D" Nipple 5 10,755' WLEG Venturi Shoe Wellbore Integrity I. 2. Passed an Active MIT 5/27/99. [1557 psi on csg annuli for 30 min.] Used for injection in 10/2000. Started injection @ 1500 bpd@ 800 psi. Within a week injection was at 300 to 400 bpd @ 1100 psi Static pressure survey ran on 4/13/01 w/ fluid level at 8457' indicated a BHP of3,136 psia @ 10,690' 3. 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GL V leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg@ 1978'. BHP=2918psia@ 10,700' During RST log on 1/10/04 found fluid level in tbg @ 2081'. In csg fluid level @ 3394'. 5. 6. Attempt to Jug test failed on 2/24/04. Set plug in "D" nipple. PT well to 1100 psi. Bled off to 100 psi. Zone WSO HI H2 Perforations Btm Ft SPF 10,708 I 5 10,725 9 4 10,762 25 4 Top 10,707 10,716' 10,737 Comments WSO Open Covered w/ fill Proposed 01/20104 SLT UNOCAL8 API# 50-133-10158-00 RKB =20.0' ~ ] tit. ~ ~ @t ] u ~ ] ] ~ ] ----oJ , ] TOC@5800' TD= 10,880' PBTD= 10,832' Max Deviation = 1.30 @ 4345' SRU 34-28 Proposed dwg 05-03-04 PROPOSED 5/03/04COMPLETlON Swanson River Field Swanson River Unit Well SRU 34~28 Last Completed 5/16/63 Cas i ng & Tu b i n g Size Wt Grade ID Top Btm 22" Surf 34' 11-%" 47 J-55 II" Surf 2,038' T' 29 N-80 6.184" Surf 104' T' 23 N-80 6.366" 104' 4,6l8' 7" 26 N-80 6.276" 4,6l8' 6,616' T' 29 N-80 6.184" 6,616' 8,495' T' 29 P-I10 6.184" 8,495' 10,881' 'tubII):g /2W: I 6.4 I N-80 I 2.441 I Surf I 10,755' Jewel ry Item Top OD lD Description GLM #1. 1498' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #2. 2484' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #3. 3489' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #4. 3701' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #5. 4059' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #6. 4354' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#7. 5526' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #8. 6511' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #9. 7411' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#10. 8146' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM#l1. 9381' 5.968" x 5.00" 2.867" Camco MM GLM 3-1/2" x 2-7/8" GLM #12. 10,598' 5.968" x 5.00" 2.86T' Camco MM GLM 3-1/2" x 2-7/8" 2 10,643' 3.688" 2.438" Brown CC Safety Joint 3 10,652' 5.875" 2.5 Brown Retrievable Pkr. Model HS-16-1 4 10,690' Profile Nipple, Camco "D" Nipple 5 10,755' WLEG Venturi Shoe Wellbore Integrity I. 2. Passed an Active MIT 5/27/99. [1557 psi on csg annuli for 30 min.] Used for injection in 10/2000. Started injection @ 1500 bpd @ 800 psi. Within a week injection was at 300 to 400 bpd@ 1100 psi Static pressure survey ran on 4/13/0 I w/ fluid level at 8451' indicated a BHP of3, 136 psia @ 10,690' 3. 4. Attempted an active MIT in Sept 2003. Pumped over 400 bbls down csg. Found csg in communication with tbg. Suspect GL V leaking. Ran temp survey on 9/17/03. Well passed SI MIT. Found fluid level in tbg@ 1978'. BHP = 2918 psia@ 10,700' During RST log on 1/10/04 found fluid level in tbg @ 2081 '.In csg fluid level @ 3394'. 5. 6. Attempt to Jug test failed on 2/24/04. Set plug in "D" nipple. PT well to 1100 psi. Bled off to 100 psi. Zone Sqz 62.5 Sqz WSO HI H2 Perforations Btm Ft SPF 6245 HI 6 6272 10 6 6345 10 6 10,708 I 5 10,725 9 4 10,762 25 4 Top 6235 6262 6335 10,707 10,716' 10,737 Comments WSO Open Covered w/ fill Proposed 5/3/2004 SL T Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi) '~"'-Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue AnchoraQe, AK 99501-3539 AnchoraQe, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: ~~f ~f~m¡1. ~~~~~tl:I!~ ,.'rf: COMPLETION RECORD SAFE 1.56HSD PJ 51NCH , 11/13/2003i1017~-10450 " " 1,~.." ,1 Jê)J...)LI lPERF 'RECORO'1'1'1i16"powéR SPIRALS 7.5 SPF" 15 INCH 'I 9/16/2003:~018.5 1 1 r 0r1 J:) 4).,/ ~~~PLETION RECORD 111/16 POWER SPIRALS 7.5 51NCH 10/112OO35380-5141 r--f1r /':;;>1-1 L) COMPLETION RECORD 2 HSD 6 SPF POWERJET 60 5 INCH 8/23/2003 3090 3614 1 1 [ 1 c90-'9~II' , ~DEGREE PHASED "". ' '¡ - 'I -- JéìJfLj 138- }ð~SRU 242-16 ~COMPLETION RECORD 2.5 HSD 6 SPF PJ 5 INCH 8/23/200aI1359()-4211 1 11 1 J8JfLj J 91'- 0 ) L.IS~U32A~33" COMPL~TI9N RECORD 1.56 HSD PJ 6SPF 5 INCH 11/12/2003:9360-10815 1 lH JrJL1L, 1~-W~i.JSRU34-~~¡RESERVOI~SATURATIONTOOL_SIGMAMODE '5INCH' I 1/10/2004;14300-7300 I '11. t" '1 JBi-JLj J 9J../-o51.5fsRU 41A-8 fGÃMMA RAY CCL 1.56 POWER JETS 1606 HMX l5îNC¡:¡--l2ï12ï2õõ4r974õ~o590--1 1 ODJ~J..Jl.) RECEIVED 5CAN~eD MAF« 1 @ 2004 FEB 2 7 2004 l-\iaska Oil & Gas Cons. Commision P¡nchorage of this transmittal or FAX to 907 263-7828. Date: ~~" ~ '~ ~ ~ fY\ ~ )'... MAY-28-99 FRI 14:04 UNOCAL ASSET GAS GRP FAX NO. 90726~74 P.02/02 .~ ' ( '"" STATE OF ALASKA ( 7ð':'t1I~' ~'>1 r ALASKA OIL AND GAS CONSERVATION COMMISSION f::"v~ ~6~-.:~r . RE 0 S f:.: G(Qj¡ ~'C..e.(\ . P RT OF UNDRY WELL OPERATIONS PI, -2.'f9..(t-~'JAL¥ "2'2' 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: - Repair we¡¡;- Ot~ X MIT 5. Type of Well: 6. Datum elevation (DF or KB) Development:- 184' Exploratory:- 7. Unit or Property name Stratigraphic: Service:X 2. Name of Operator UNOCAL 3. Address feet Swanson River Unit P.O. Box 196247 Anohorage, Alaska 99519 - 6247 4. Location of well at surface 660' North and 1530' West of the S.E. Corner of Section 28, TaN. R9W, S.M. At top of productive interval Straight Hole At effective depth At total depth 12. Present well oondltion summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermeãate Production Un ar Perforation depth: Length 34' 2038' 10880' measured current: true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) 8. Well number SRU 34-28 9. Permit number/approval number -0 10. API number 50-133-10158-00 11 . AeldlPool Swanson River I Hemlock 1 0880 feet Plugs (measured) 10B80 feet 10832 feet Junk (measured) 10832 feet Size Cemented 2211 Yes 11 3/4" Yes 71 Yes 1 0832' Measured depth ... True vertical depth 34' 2038' 34' 2038' 1 0880' 10880' 10716' -10725', 10737.10762' 10716'.10725', 10737' - 10762' 'J rrrl'!!i~r) " fq, 1'- \i ï'~ r. , "", :"" 'if:"., I!.. ", 2 7/8" 6.5# N-ao from 0.10756' .. . ,. .; 1999 Brown HS. 16 - 1 Pkr @ 10652' -n N/A ß~¡;c;JOrage Treatment description Includfng volumes used and final pressure Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: - I Oil: - Gas: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: 14. Prior to well operation t<8l1 Form 1 O~404 Rev 06/15/ 8ð .for:-:. ReDresentatlve Dallv Averaae Production or Injection Data Oil-BBL Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 30 200 450 1725 190 shut In, ready for InJection. waiting on flbergtass flowline 16. Status of well classification as: suspended:- Service: Water Inlectlon Title: J Mer è"S tCJ ¡Sot) t"e.. /øjQc-febA c~ 40 ¡tJOð f~~ t .. hð/- 10 e¥ct2<2d l"2.00ps-r.. L.~rGeuJ ~/tf9<l SU8MIT IN DUPLICATE C\J C> "- ........... C> c.: OPERATOR: o:::::r r-- co r-- I COMMENTS: ("I') co C\J r-- C> I 34.28 a:> Ó I COMMENTS: :z: :x: <I: I u- 34.28 ' COMMENTS: 0- e:::: ~ tn <I: ~ E- l.tJ tn tn <I: .....J <I: 0 0 :z: =:;. COMMENTS: COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical I nteg ñty Test UNOCAL SWanson River Field Well 34-28 DATE: 1/20/1999- 5/21/99 Du LJ,.,.Jj FIELD I UNIT I PAD: N jl"IIII!~!I;i¡;!18~i : ',' ",,",",',',.." , ,.." ,',,,",".. ','''", -'," iN'" Ii:,I~;!C!l :¡]¡'ict:,! ~:Ii¡ illi 27/8 150 1500 1500 1500 180 1510 1515 Prod. Water Test with bottom gas líft valve pulled and Tbg / Csg Equalized 10,652 . "'..' ,',', ,', : "STÂR" i¡~~:~j"; 14:27 I X 7. 23.00 # N.80 0 Fax # TBG. INJ. FLUID CODeS F::: FRESH WATER tNJ. G ::: GAS INJ. S::: SALT WATER INJ. N ;: NOT INJECTING TEST TYPE: M::: ANNULUS MONITORING P ::: STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL GL YCOl SALT WATER DRILLING MUD OTHER Grad. o.()() 0.00 o.()() o.()() o.()() ("I') C> - - o:::::r e:::: u- a:> a:> I co C\J I >- <I: :E: Distribution: ôrig - We' Rle c - Oper~tor c - Database c - Trip Rpt RIe c - InspeclOr OPERATOR REP SIGNATURE: Kenneth J. Lucas Peak Pump Truck Operator Dave Mc'Grady 5/27/99 - Greg Merle . AOGCC REP SIGNATURE: 4-99 ~28 MIT Jds WEll. TEST: Initial X 4 - Year Workover Other (Rev 9/17/96) -"~,", ,"'" -", lJ.,.J u L.k)¡ c¿ , .. c;r-.. t;)">. Cl' 'r"" c: 0 '(ñ ~ "5 ..) . CJ.) ') t:J) .: (\~ :) (5 ~) ..c: :6 g ò) <C. cÕ ",- 0 ~ &} ~J ) . . TES FORM APPROVED -IE INTERIOR Budget Bureau No. 1004-0135 NAGEMENT Expires: March 31. 1993 5. Lease Designation and Serial No. REPORTS ON WELLS jeepen or reentry to a different reservoir. 6. If Indian. Allottee or Tribe Name .w for such proposals SUBMIT IN TRIPLICA TE 7. If Unit or CA. Agreement Designation 1. Type of Well Swanson Rlverl Oil Gas Soldotna Creek Units (] Well Œ Well 0 Other 8. Wen Name and No. 2. Name of Operator Union Oil Company of California (dba Unocal) 9. API Wejl No. 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 10. fjejd and Pool, or Exploratory Area 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Field Swanson River Unit - - 14 Wells 11. County or Parish, State Soldotna Creek Unit - - 7 Wells Kenai, Alaska ~ '-, 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Œ Notice of Intent 0 Abandonment 0 Recompletion 0 Plugging Back 0 Casing Repair 0 Altering Casing Œ Other Temporarily Abandon 0 Subsequent Report 0 Change of Plans 0 New Construction 0 Non-Routine Fracturing 0 Water Shut-Off 0 Conversion to Injection 0 Dispose Water 0 Final Abandonment (Note: Report resUls of multiple conmpletion on Well I Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (CIeaI1y state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionaJ~ drilled. give subsurilce locations and measured and true wrticaJ depths for all markers and zone pertinent to this work.)* As described in attached letter. Unocal requests that the folbwing wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31 t 1997: Soldotna Creek Unit Swanson River Unit íÞ.2- q SCU 21-8 a SCU 34-9 es,C1-} ~ SRU 212-10 SRU 212-27 ,~l"~ CDJ~'.3SCU34-8 SCU41B-9 Ccð-~Ru12-15 SRU23-27 'E"°-I' . "'"'n .- cÞ~- J SCU243-8 U14-34 OO-ILf4>SRU14,-15 SRU331-27Oðp'r~8 kl::l;t:IVt:D 81-C¡8SCU 13-9 ~J,-.JO SRU41A-15 SRU34-28 lÞ3-,~ (þ I ,. «i5 SRU 43A -15 SRU 43-28 (p (- c C, I'" Y &.f (p~-..3~ SRU 14-22 SRU 21-33WD "~-;l APR 0 1 1!96 8ð-J07 ~17 SRU23-22 SRU24-33ì~-7 (øð ~ ..38 Ala8UOII Gal CaftI, Com~i Ancborage * High GOR well that may be produced intermittently Signed Tille Dennis L Groboske Petroleum Engineer Date 3~6 Approved by Conditions of approval. if any: Tille Date TItfe 18 U.S.C. Section 1001. makes ita crime for any person knowingly and williJlty to make to any department or agency of the United S1ates any false. fictitious or fraucådert statements or represenlations as to any matter within its jurisdction. *See Instruction on Reverse Side Attachment No.1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1 , 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Slowdown ) Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 418-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7 Wells 2 Wells 5 Wells 2 Wells 5 Wells ) I ~h GOR well that may be produced intermittently Q J> .j PJrr¡ .~ ~ ~ n~ '~~J r ~ .w ~ [t!:: ¡-i .... . . l~' ~-, ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarilv Abandoned Status . SCU 34-4 . SCU 43A-4 . SCU 13-4 . SCU 238-3 . SCU 314-3 . SCU 43-9 . SCU 23-15 Recompleted in Tyonek G1 and G2 zones Recompleted in Tyonek G1 and G2 zones Workover to remove tubing fish. Currently producing from Hemlock Returned to full time production Returned to full time production Returned to full time production Returned to full time production Additions to 1996 Temporarilv Abandoned Status . SCU 13-9 Recompleted in Tyonek G2 zone low rate oil producer. kECt:lvED APR 0 1 1996 Alaska 01& Gal ConI. Con\ßUIion Md\Or8QI J{ _/ Unoca' North Amep-\' 011 & Gas Division ' Unocal Corporation ;, 909 West 9th Ave., P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 :D w qð-!t-r""-~~ (,-/ ,~. UNOCAL8 "".þ.~~ b ~ ,.óf7 Alaska Region March 31, 1994 Mr. Joseph A. Dygas Bureau of land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1994 Sundry Notice Request for T A Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (T A) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed T A wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1 , 1994 to March 31,1995. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed T A wells using the same' format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 ~aska OU & Gas Cons. Commission Anchorage ,~4, ....-, Mr. Joseph A. Dygas March 31, 1994 Page 2 , . . As was the case last year, SCU 43-4WD is not included on the proposed T A list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. ~trUIY' Dennis L. 8'rqþ6ske Petroleum Engineer DLG:dma Attachment cc: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC 7:" b~ (),e~c.. ~T 6 <- "}J J'''' () y'" ",;, !c.. /';VI Ie. 11 ~. (Ii r¿ (..:)~/ .t If /;/;e! ~ tA..S Y~i1~ (7Y\- S 'J>:H' eI\ ~ ~ Jl, "'~.l... ß, (ltj-$ sa. ~k ¿fl"...:s ?.I I t¡~~tl/,,~ =¥~ .........~- ' ~ :J> r,~~~ #¿I ~ ~. 9 ,,/ , - , i Attachment No.1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Shut-in Wells during Field Slowdown . ) Shallow Gas Potential Hemlock Future Shallow Gas Producer Rate Potential P & A and 'Hemlock Only' P & A Producers with the Hemlock Abandoned 1 s.-\~ SCU 13-4 lDO- is SRU 212-1 0 bD-3~SCU 14-34 t?2-l ~ SCU 21-8 * Ct>-Il\-to SRU 14-15 Úb -40SCU 34-4 tDl-OS SRU 23-15 hO-l/4SRU 23-27 B\-~~ SCU 13-9 UÙ-'H SRU 34-15 le\~ '22. SCU 341-8 (12.- ~o SRU 41 A-15 SRU 14A-33 (0\ -4:4- SCU 34-9 * SRU 43A-15 ú~-l SRU 34-28 Coz.,..?~ SRU 14-22 B4-It)SCU 238-3* ~<1-t)v SRU 432-15 /9 \- g SRU 43-28 (ÐtH," SRU 23-22 -=1-4--'54 SCU 43A-4 * "'t1..- o""SRU 24-33 eo-lt~ SRU 32-33WD ll[-'~~SRU 212-27 SCU 21 A-4 * (P~"'D\ SCU 243-8 ~-Il(ß SRU 331-27 (O~- 2 SRU 21-33WDbO-22..SRU 12-15 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells ) * High GOR wells that may be produced intermittently RECEIVED APR - 1 1994 Alaska Oil & Gas Cons. Commission Anchorage ~, ~, Attachment 2 Swanson River Field , . . Wells with Temporarily Abandoned Status Change Additions to 1994 TemDorarilv Abandoned Status . SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. . SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 TemDorarilv Abandoned Status . SRU 24A-9: Returned to full time production after workover. . SRU 21-3: Returned to full time production due to commencement of Slowdown in field. . SRU 33-5: Returned to full time production after workover. RECEIVED APR - 1 1994 AI(¡;;Ka 011 & Gas Cons. Commission Anchorage . .. . Form 3160-5 (JUNE 1990) ~ UNITEU, AlES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT <~, FORM APPROVED Budget Bureau No. 1004-0135 fee: March 31, 1993 5. Lease Oeel;nation and Serial No. SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reSeNOlr. Use 8APPUCATlON FOR PERMIT _8 for such proposals SUBMIT IN TRIPLICA TE 1. Type of Well Oil Gas [] Well Œ Well 0 Other 2. Name of Operator 6. If Indian, Allottee or Tribe Name . . . . '. 7. If Unit or CA. Agreement Oeelgnation Swanson Rlverl Soldotna Creek Units 8. Well Name and No. 9. API Well No, 10. FJeld and Pool, or Exploratory Area 12. CHECK APPROPRIATE BOXes) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Œ Notice of Intent 0 Abandonment 0 Recompletlon 0 Plugging Back 0 Casing Repair 0 Altering Casing Œ Other Temporarily Abandon Swanson River Unit - - - 19 wells Soldotna Creek Unit - - - 11 wells 0 Subsequent Report\ 0 Final Abandonment Swanson River Field 11. County or Pariah, State Kenai, Alaska 0 Change of Plans 0 New Construction 0 Non-Routine Fracturing 0 Water Shut-Off 0 Conversion to Injection 0 Dispose Water (Note: Report resUII at multiple conmpIetion on wea or RecompIedon Report and log form. 13. Describe Proposed or Completed Operations (CIe8rty state aI pertinent delails. and giYe per1Inent dat8s. Inducing estimated daI8 at starting any propoeed work. If wen is drecdonaltt drilled, t¡ve aubsuriace locations and measured and true Y8I1IcaI depIh8 for an marker8 and zone pertinent to this work.)* As described In attached letter, Unocal requests that the folbwing wells have a temporarDy abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit S r * SCU 238-3 SCU 243-8 I ~ <5 I SCU 13-4 SCU 341-8 'S I S I * SCU 21A-4 SCU 13-9 ... OIL :5 } SCU 34-4 * SCU 34-9 1 - () I ~ S', * SCU 43A-4 SCU 14-34 S I f "0 I L-* SCU 21-8 *High GOR wells that may be produced intermittently. Title ApprOYed by Conditions of approwl, if any: Title Swanson River Unit s SRU 212-10 /SRU 14-22 S I SRU 43-28 b\.)Sr SRU 14-151-ol'SRu 12-15 S f SRU 14A-33 5 SRU 23-15 s J SRU 23-22<)U$>SRU 24-33 'S\JspSRU 34-15 SI SRU 23-27. '; SRU 32-33WD S' S-I SAU 41A-15J~~SRU 212-27 SRU 21-33WD 1>-0 &J I '5\)SP SRU 43A-15~' SRU 331-27 ,-- 'Sv~ SRU 432-15 <Sf SAU 34-28 í tv:.o ~ 00 w ð1).IL ~JO-':~ K>A-0.J2- hao~~ ~ Date ~1/9'1 RECEIVED hlro ku U7 EnflJneer Date APR - 1 1994 Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and -willillly to make to any department or agency of the United SIa- anv.faJse.didiliau8øns Com' . fraudulert smtements or represenlatbns as to any matter within iIs jurisdcdon. AI~I\"4-11lr & -uCl5l101. mlSSIOr *See Instruction on Reverse Side lißcnorag¡=== -.-~ Alaska Region ,co 'COMM !?OMM I RES ENG r Qa.; - ¡"QrId &.. Q.. It. SR ENG ( . . ~ . SR ENG I 1M /b I.,) . Adtl ,-,c... ~~GÅSST-I- ~ ENGASST . SR GËón ¡¡..",l- ( rf.¡Uem.J GEOL ASSTT -tf,eJ. 41~o ~e.- GEOLASSTT March 24 1993 o.(>f('~.f.:-o.. to ca-r. STAT TECH I , , ~lfl' STATTEÕï.:rr FILE ¡ - t Unocal North America"-" Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 ~3,-O? ~ ~. - tJ it' ...... j¡,-"", UNOCAL8 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in Swanson",River:.Field. '.' - - . . . -,,>~ ,- -.~. Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (fA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed T A wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; Le. April 1 , 1993 to March 31, 1994. These concurrent time periods will greatly simplify future T A Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARGO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. REGEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. commission Anchorage - _.~._-~-,-,- ,'.-...., ~ " ~.--- Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD ,is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. ;¡~7)~o . Dennis L G~:; v,...-- Petroleum Engineer DLG:sr Attachment cc: L. C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company 1 . .. ..:::z=. (!.~Ii::~ #Af. ~Ro6.0S.I:s:- ~E r/IÍs ~Jf<"æ.. c:::::. ~ REcEIVED MAR 2 5 1993 Alaska OiJ & Gas Cons. Commission Anchorage ,t'1" ( ( ~-D7 Form 3160-5 UNITED STATES FORM APPROVED (June 1990) DEPARTMENT OF THE INTERIOR Budget Bureau No. 1004-013~ Expires: March 31.1993 BUREAU OF LAND MANAGEMENT 5. Lease Designation and Serial No. SUNDRY NOTICES AND REPORTS ON WELLS 6. If Indian, Allottee or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT -" for such proposals SUBMIT IN TRIPLICA TE 7. If Unit or CA, Agreement Designation Swanson River/ I. Type of Well Soldotna Creek Units ~Oil œGas 0 Other 8. Well Name and No. Well Well 2. Name of Operator Union Oil Company of California (dba Unocal) 9. API Well NO' 3. Address and Telephone No. P. O. Box 196247, Anchoraqe, Alaska 99519 (907) 276-7600 10. Field and Pool, or Exploratory Area 4. Location of Well (Footage, Sec.. T., R., M.. or Survey Description) Swanson River Field Swanson River Unit ---------- 17 wells II. County or Parish, State Soldotna Creek Unit---------- 14 wells Kenai.. Alaska TYPE OF SUBMISSION CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA 12. ŒJ Notice of Intent TYPE OF ACTION 0 Change of Plans D New Construction 0 Non-Routine Fracturing D Water Shut-Off D Conversion to Injection 0 Dispose Water (Note: Repon resullS of mulliple completion on Well Complelion or Rccomplelion Report and Log [orm,) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details. and give pertinent dates. including estimated date of starting any proposed work. If well is directionaIly drilled. give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.). As described in attached letter, Unocal requests that the following wells have abandoned status for the twelve month period, April 1, 1993 to March 31, 1994: ~'elldJ...,tt., Cr(P',.t"I'" Swanson River Unit I ()"- SCU 21-3 SCU 21-8*/ SCU 23B-3¡/ SCU 243-8v SCU 13-4 /' SCU 341-8~ SCU 21A-4 SCU 13-9/ SCU 34-4 :", , SCU 24A-9" SCU 43A-4J SCU 34-9*~ SCU 33-5 v SCU 14-34 v 0 Subsequent Repon 0 Abandonment 0 Recompletion 0 Plugging Back 0 Casing Repair 0 Altering Casing [X] Other Temporari 1 y 0 Final Abandonment Notice Abandon a temporari ly Swanson River Unit SRU 212-10 '" SRU 14-15' SRU 23-1SV' SRU 34-15 SRU 41A-15V" SRU 43A-15 SRU 432-15 SRU 14-22 v * High GaR wells that may be produced intermittently. Title Petroleum Engineer Approved by Conditions of approval. if any: Title SRU 23-22 ~., SRU 23-27 tI" SRU 212-27;- SRU 331-27 .ttJ!;134~ 28 v ~~~ UÃ:~;- RECE\VED SRU 24-33¥ SRU 32-33WD'" MAR 2 5 1993 . Alaska OH & Gas Cons. comm\SS\(J Anchorage Date 3/¡f'l/93, , . Date *s.e Instruction on Rne.... Side Title 18 U.S.C. Section 1001. makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, ficûûous or fraudulent statements or rcprcseatation5 as 80 8D'f matter within iIs jurisdiction. "'~'~'-"---"-' . -~ -".._.~.~ """--'---"'-"~--'~.' '. -.". ._.~-,._.",w,..-..~.... "'-"."-"'-"".~-''''-'''-' "." ~_.." "'-""."-".' , f - , Attachment NO.1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1 , 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-In Wells until the Field Blowdown ) Shallow Gas Potential Hemlock Future Shallow Gas Producer Rate Potential P & AI,. and 'Hemlock Only' P & A Producers with the Hemlock Abandoned SCU 13-4 SRU 212-10 SCU 14-34 SCU 21-8. SRU 14-15 SCU 21A-4 SRU 23-15 SRU 23-27 SCU 13-9 SRU 34-15 SCU 34-4 SRU 41A-15 SRU 14A-33 SCU 24A-9 SRU 43A-15 SCU 43A-4 SRU 14-22 SCU 34-9. SRU 432-15 SCU 33-5 SRU 23-22 SCU 238-3. SRU 24-33(21 SRU 341-8 SRU 212-27 SRU 34-28 SRU 331-27 SRU 43-28 SCU 32-33WD ) SCU 243-8 SCU 21-3 11 Wells 7 Wells 3 Wells 5 Wells 5 Wells (1) Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 (2) Scheduled 'Hemlock Only' P & A in March-April, 1993. . High GOR wells that may be produced intermittently. RECEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. Commission }\nchoraga ¡....-...... ~ ¡II- Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status . SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. . SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status . SRU 21-22: . SRU 12A-4: . SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR 2 5 1993 Alaska Oil & Gas Cons. Lornm\sSlú': Anchorage r', UNITED STATES 8UBKIT Of ftIPLIC~ft. DEPARTMENT OF THE INTERIOR ~~~e:.~~truUOD' OD "" BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS c 110 not.... Ibla tor. tor proPOQ18 10 cSrUl or to dH~D or plue bact to a cUff'feat 'eNnol, U. "APPLICATION FOR PERJilIT-" tor IUcla propoaal..) . Form 3160-5 (November 1983) (FormerlY 9.,..331) 1. OIL ~ GA. ~ .CLL I:a ..1.1. L4 2.. "A..8 0.. OPCD.-roD 0'1'." AReo Alaska, Inc. 3. AOOa&88 or OP...-ro8 P.o. Box 100360 Anchoraae, AK 99510 ,f. LOCATIO" 0.. wCLL (Report l~tloa clearJl aDd aD a<:cordaDt.'t' .Ub aDI State requlrelDeDta.- See al80 apaC'fl 17 Mlo..) ~t audac. -... Swanson River Unit------- 19wells Soldotna Creek Unit------13 wells U. .""1'1' !fO. \15. C~VAnONS (Sbow wbether Dr. aT. G8. Ñ.) ~ (~ ORIGINAL Form approved. Budlet Bure.u No. 1004-01 J S Expires Au~st 31. 1985 ~. &.8... D8810"AftO. All. '''UI. .0. e. ... I.DI.., ALLOft.. oa TUa. ".XI T. U8rr .0..'X.llor ...xa - Soldotna Creek/Swanson Rv 8. .... oa La.., 1I..a t. .au.o. 10. '1.1.0 .lfD POOL. oa .11oDC.or Swanson River Field n-.- 88C..~.. ... II.. oa 8IoIt. ~ 8Va..~ oa ..... ------« It. COG.'r~ 08 '''1..'11. .AU Kenai Alaska Chec!c Appropriate Box To Indicate Nature of Notice, Report, or Other Data 1~ "one. 0.. IlfftRflO. 'to: 8088"°811'1' 880- -: TE8T ..ua ..OToO'" ~ peLL 0& .LTC. C.'SI:'tO ~ ..T.a '.OToOr. § ...,.I&IJIO ".... ...~.. -.... - "<L~I'L8 cou..... - ...crvu -.......... - ...- c..- 8Rocn' 0& .elDaa - """DON- - 8BOO'I'III0 O. ACIDISINO .."DO...n- aCPAla ..I.L . CH.NG. PL.:oI8 (Otber) - ( Nou: aeport relala of .altlplo ...JI.uoa 08 w, - - cOtber) Temporary Abandon J , ('~tnplet1oD or R~o¡¡¡plet1oD "port aDd Loc fora.) 11. 0~S(".18C, 1'.OroS&O 0& CO)IPLCTCD OP&."TIO~t: (Cleol'.' .Ialf' 411 p4'rtlafout d.talb. and :IYt pertlDent datH, IDelud", .tt..q.j data of IWt1a8 ..,. proPØMd work. If ..I ia cliNCtioaa1b driUed. .ive .Ù8W'Íace Iocaûuas and ID.Ullrtd and true ytrttc:al de,. tor aU ..den ... ..a. ,.ru- nea& to da18 wort.) - ' As decribed in the attached memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit sa¡ 23B-3 SCU 12A-4 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SCU 21-8 . SCU 341-8 SCU 13-9 SCU 24A-9 SCU 34-9 SCU 14-34 SRU 212-10 SRU 14-15 SRU 23-15 SRU 34-15 SRU 211-15 SRU 41A-15 SRU 43A-15 SRU 432-15 SRU 14-22 . -High GOR wells that may be produced intermittently. 18. 1 berebl cutUr'QIat ..tbe toreco~ t. (r,¡e and correct /~ \, SIGNED .' V { 6... .J '4'"-- SRU 21-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33WD RECEIVED DEe 3 1 1991 Alaska Oil & Gas Cons. Commis 4ij~R8ra9ø I 'J.j:l? I~ I TITLE Actinq Reqional E~qineer D~T8 (Thta .pace for Federal or State oace U8) APPROVED BY CONDITIONS or .PPKOV.u.. ø AH1': TITLE *See Instructionl on Rev... Si- D~T8 Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Rate Potential Shut-in Wells under Evaluation for Shallow Gas Potential and 'Hemlock Only' P & A P&A :~::::::::::::::::::::::::::::::::::i:::::::::::::::::::::::::::::::::::::;:;:::::::::::::::;:::::::;:::::::::::::::::::::::::;:::::::::::::::::::::::::::;:::::::::::::::::::::;:::::::::::::::::::::::::::::::;:::::::::::;::::::::=::::::::::::;:::;:::::::::;:;:::::::::;:::::~::::::::::::::::::::::::::::::;:::::::::::::::;::::::::::::::::::::::::::::::;::~:::::::;::::: seu 12A-4 seu 13-4 seu 21A-4 seu 34-4 seu 43A-4 seu 33-5 seu 341-8 SRU 21-22 SRU 34-28 SRU 43-28 SRU 32-33WD SRU 212-10 SRU 211-15 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SRU 24-33 » Iü en Š- f? ;0 ;; g ,." ~~ C) () ::T en (.co.I ....... On ... ÏiJO -- - (Q::3 CDCJ'J- < . CD ~ (0 m 3 .... ã. CJ ,:::;:::::;;;;;:;:i;;:;;;:;~:i:i:,::::;i;,;,:i:i:,:i:i:,;i:,:,;,:i:;;i:,:,:i;;::;,:,:,:,:';i:,;,:i:,:::i:,:,:':,:,:i:::,:i:,:,:::,:,:::,:,:,:i:,:i:,:,:,:,:it»:,:i:i:i:i:i:::,:::i:i:,:i:::,:i:,:,:::i:::i:;:':':::::i:':::,:;:::::,:i:::,:;:,:;:,:,:,:i:i:i:i:i:i:::i:i:i:i:;:,:,:i:i:i:,:i:,:::i:,:i:i:,:i:i:,:,:i:,:i:,:::i:::i:,:,:i:i:::,:i:,:::i:,:i:,:,:i:,:,:,:i:i:: 11 Wells 9 WeIŠ. 3 Wells seu 14-34 SRU 23...27 SRU 14A-33 .. -High GOR weUs that may be produced intermittently. Shut-in Wells'until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned :::::::::::::::::::::::::::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::::::::::::::~:::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:;::;:::::::: seu 21-8 It seu 13-9 seu 24A-9 seu 34-9 seD 238-3 It ) SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 ), ::::::::::::::::::::::::::~:::::::::::~:::::~:~:::::::::::::::::::~:~:::::::::::::~:::::::::~::~~::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~::::::::::::~:::::::::::::::::::::::::::::::::::::~::::::::::::::::::::::::: 5 Wells 4 Wells For: Temporarily Abandonment Sundry 12/27/91. ~ { , '.--...... { Attachment 2 RECEIVED Swanson River Field DEe 31 199J Wells with Temporarily Abandoned Status Change Alaska Oil & Gas Cons. Commiss (Based on 1991's TA Status; our letter 12/28/90) Anchorage Added to 1992 Temporarily Abandoned Status: . seu 23B-3 &: seu 21-8: . . seu 12A-4: . SCU 43A-4: . seu 13-9: . SRU 212-10 &: SRU 212-27: . . SRU 21-22: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. ' High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. High GOR well, shut-in until field blowdown. High water rate shallow fuel gas well, current! y not economic to produce based on current fuel gas needs. Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status . SRU 21-15 &: SRU 314-27: . Wells are scheduled for full P &: A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the T A List for 1992. I~ /~, AttacþmenU Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: . SRU 21-15 & SRU 314-27: Wells are scheduled for P & A in first quarter 1992. . Wells that are used seasonally . SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. liommissiol' Anchoraa9 . ' ~, -----, Cook Inlet Engineering C".OM~A''''-~,- COMM-~ , tOMM ,~¡ 'RES ENG ~\ SR ENG i -sFfEÑG ~ ENG ASST \ 'ENG ASST \ SR GEO~ ~EOL A iG~~~~ STAT TE~ tFAT T. ECH \ \, FILE ~\ ~ ~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 2761215 December 27, 1991 Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office !k>x 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 '< wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected "to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment llists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: 1. 2. 3. rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only' abandonment. RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. Commission Anchorage ( .. (~-" (~' Mr. J. A. Dygas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4. 5. Hemlock producers, and wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above isa new addition to this year's T A listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye~'s TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned Lìst (Ref: our letter of 12/28/90). Eight wells, seu 12A-4, seu 21-8, seu 23B-3, seu 43A-4, seu 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 T A listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is seu 43-4WD, a standby water disposal well which is only used seasonally. H you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerel y, ,~ ~- .¡J.ú vJ~"'- J. C. Winn Acting Regional Engineer cc L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation RECE\VED DE.C ~ 1 199\ Alaska Oil & Gas Cons. commiSSion Anchorage JTZ:jlg:002S Attachment <~ ~ ARCa Alaska, Inc: ' Post Office 8ux ~OO360 Anc~oragt?, 41ôSKd 995 ~ 0-.)360 ,~. ':..)Cl< ;n'e¡ ~~¿.v ',,""_.'.[:;:; cë:~~r'Jj ¡:ü: S-Ë ~'J G . S 0~:~~,~- ,fML , ~~~-~Ì"~~'-~ !É~\ÏG~~?U-¡ ¡ t:=~I."'" ^""~~I \,. .::~ ..~ .''''','' ,..'-~ v , ! SR GECL \ SCÓL I\S.Š-r-\ \~~~~~--~~~~TlW \ S~~~~5gH~. c::",... ,~. T T ...-,-.\ \ ¡ '.J " t:,\Ja I F!LE \ I. ' :- ~¡~chcn¿~.)~ :-S .. 2: 5 =:-:g;neer:!"g December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1 . Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984» and 3/30/89 (3180 (984) and our letter 12/28/88)- In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, ~w~ Tom Wellman TW:SLS:jt:OOI6 Attachment cc: C. V. Chatterton, Chainnan AOGCC A. R. Kukla, Marathon Oil Company S.W. Ohnimus, UNOCAL Corporation REcEIVED DEC291989 Alaska OU & Gas Cons. Commlssi(U Anchorage 4~'~ J :'.-lSI(d "r:' ':>d '::"_'J'iC,i,:'. -_!':'-~~r':...:~~¡.:'ìf:e'(~'':'';:'"O;:;,1,""'I" -, . ~, ,~ Form ap1'l"Oved. ITED ' STATES IUBMft DI 'to. id~'1'88 .r OF THE INTERIOR ~=-:a.:.~ 08 N- ------ -- ...-.--- ~.. .7a~ 5. L8A8II o""..ftO. ... 88UL ... F LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS t. ~ IIID..., ALL0'ft88 08 ftIa. "AX. (Do not UIt t"" fo,. for VO~I. to drill or to deepea or pia. bee. to a 416,..c """°11'. U."AI CATION roR PERMIT-" for."" D~) 1. 1. u.n AOU.-..7 II.M. ort. (]J GA. ŒJ ~aRCreekÙ 't "C1.t. .. 8U. 0'1'..8 W Iver nt s 2. If.... or OPC"~. 8. r... 08 La... If... ARCO Alaska, Inc. 3. ADDU" O. OP."~. i. "8010 .0. Post Office Box 100360 Anchroaae. AK 99510 t. LOC4TIOlf O. \\'&1.1. (Report locaUoa c:learl1 aad to ac:c:ordaac. ..ith &A1 State reqaireaaeDta,8 10. .Ia... 4zeO POOL, 01 "'ILÞC4T See also .paCt' I1tt.lo..) Â t lurtaee ~w::!nC:f"In ~i"ør I=iølrf Soldotna Creek Unit - 11 we I Is 11. 180.. T.. ... ... o. u.K. AD ....T O. .... Swanson River Unit - 20 we I Is 14. ..8a.. n' HO. 15. .~YAT10N. (Sba. ...b8tåer Dr. ft. aa. 8t&.) 12. eoa.7Y 08 '&&...111. nAn Kenai Alaska l~ Checlc Appropriate Bo. To Indicate Nature of Notice, Report, or Other D.ea IIOI'IC. I). UfUlt7l0lftO: .U88MG'811'1' 880ft, - : TC8T ....'1'.. ..u~'" ~ Pf:LL oa 4LT8&, C.\.I~O ~ "'A7., ..U'I'-O'" § ....I8Df. ...... ra"CTU88 n.AT ~Vt.=IPL8 CO)lPu~ft - r'ACtUU ""A7..n - ßt'881.. CUI". 8ROO'I' oa 4CIDØ8 - .8.HDQN8 - ..oor.... 08 .CID..... ....00..8ft8 REP..a ..LL CHAlfce PL.:CS (Other) .' - ,( Non: ReDOn rt881t11 01 .alUtle -,..uo. 0. "tII !Othu) T emporar I I y abandon ~ ("01ll1l18t108 or KHOGlpleaoa 8eõort aca W. tona.) 11. la.srllUJE 1'1\0('051:0 0& CO~fÞL&Ta:D OPca"TIO~r, (Cl~:U"11 Itat~ 1111 PfÞrttDPut d~t.ib. and ;1.. pttrttDeat ciat... i.claca.. .u.ated date of ltarUq 1.87 :.copu::cd work. It weU ia directioD8Ü7 driUed. cive lUMudace Iocatiuna I1nd lDe.."red ADd true "ertSeaI depdla tN aU ..den aM ... peru. nen' to tlaia work.) . As described in the attached memo, ARCa Alaska, Inc. requests that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit seD 13-3 seD 13-4 seD 21A-4 seD 34-4 seD 24-5 seD 33-5 seD 33-8 seD 341-8 SRU 34-10 SRU 14-15 SRU 21-15 SRU 211-15 seu 34-9 SCU 31A-16 seu 14-34 SRU 31-15 SRU 34-15 SRU 41A-15 SRD 43A-15 SRU 432-15 SRU 23-22 SRU 312-22 SRU 23-27 SRU 314-27 SRU 331-27 DEe 2 91Q89 SRU 34-28 . v SRU 43-28 Alaska all & Gas Cons. Commi SRU 14A-33 Anchorage SRU 24-33 SRU 32-33WD SRU 12-34 RECEIVEr la. ¡hueòT certU7 tbat tb. torecoiDc is tr,¡e &Ad c:orreeC SIGIŒD ~ W~ Iz-z'-~9 (Thie apace for Federal or Stateo8ea Q88) TITLE Cook Inlet Enginerring Mñna~ APPROVED BY CONDITIONS or ~PP.01' AI.. ø .un': TITLB *See 1..-.cti0ftl Oft R8Y818 Side DATIl Title 18 U.S.C. Section 1001, makes ita crime (or any person kno.ingly and willfully to make to any department or agency of the Uniteå States .ny f.lse, :ic:u.ttous or fraudulent statements or representations as to any matter w\th\n ItS ,urisc1iction. Wells under Evaluation Rate Potential 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 > m ~ ;:0 -. t:) r; n-¡ l'T1 ~Ci)o n g.~ N m ~ ~..o - ¡U::s a--a < cg sn to C") 00 m ~ <0 0 3. m (/). õ ~ TEMPORARILY ABANDONED WELLS IN SRF Wells being evaluated for P&A/future Vtility 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31 A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 Wells SI for Inefficient Production 21 A-4 33-5 34-10 43-28 24-33 Wens SI until Blowdown ) 43A-15 314-27 331-27 ) For: Temporarily Abandonment of 12/29/89 .' ~\ ~- SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Ü A~, Status: A1Ided to Tem1)orar y seD 21 A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRD 32-33 W D : Well is temporarily abandoned due to annulus communication problems. Ü A~ Status: Femove<LJrom Tempor:Jr y seD 243-8: production. This shallow sands gas well has been returned seD, 13-9: A workover is planned for this well which will enable this well to be returned to an active status. S R D 212-10: This shallow sands gas well has been returned to production. SR D 23-15: This gas-lifted well has been returned to production. SRD 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED DEC291989 Alaska OU & Gas Cons. Commission Anchorage For: Temporary Abandonment Sundry of 1 2 / 2 9 / 8 9 ~ .i' ~, ~ SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* seu 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned statB f£ E I V f D DEC29]OD Alaska Oil & G vd9 A' as Cons. rtom . . nChorage8 \II mIssion For: Temporary Abandonment Sundry of 12/29/89 . ,"'....,......'-"".- ._,v--"''''''''''!'''-....._.....,....,.....--------_. ~ ~""- Form approved. Form 3160-5 U ~ ITED STATES SUBMIT 1M Tþ..&,LICATlle {November 1983) DEPARTMENT OF THE I NTERIOR ~~~e:'d~).tneUoD' OD fto . - . (Formerly 9-331) G. LaA'. DI.IOllf&ftOIl AIID ..aUL 110. BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS 8. ø' IRDIAII, ALLOfta. oa ftl.' RAXI (Do not 11It tbll form for Prm"all to drUl ()r to deepeD or pine bact to a dUfereDt reHrYolr. U.. "APP CATION FOR PERIIIT-" for 8ucb propoealL) 1. T. URn' AOI""I.~ MAK. OIL 8 GAS B Soldotné3 Creek/Swanson River Uni WI:LL weLL OTBE' 2. IU... or opeaATOI 8. r... oa LaA'. IIA.a ARCO Alaska.. Inc. 3. ADDae.. or OP.IATO. 8. ".u. 110. P. O. Box 100360 AnchnrRgp, AK qq~10-01~O 10. rlaLD AIID POOL. oa W.LDCA~ 4. LOCATION or WELL (Report locaUoD de.rly aDd In accordaDce wltb aDY State requlremeDu.- See Also SPAt:.- 17 ~Iow.) At .~rfaee Swanson River Field 11. 880.. '1'.. L. II.. oa 8La. üID Soldotna Creek Unit - 15 8UaY.T oa AU. Swanson River Unit - 22 wells H. PEUUT NO. I iI. .....noH' (Show ........ ... "';... ....) 12. COUII~T oa ...I.SIIL nAT. Kenai Ala~ka t 18. Check Appropriate Box To 'ndicate Nature of Notice, Report, or Other Data NOTlca or rNT.N~IOM TO: .u"8Q"n lUII'Oa.. -: TEST WATEI SBU'I'-orr ~ PCLL oa ALTER c.\sr"o WA'I'la 8BUT-orr § a..Alant. W8LL ~ ..RACTUal: TaEA~ - )IUL,¡,rPLE CO!\fPI.r.TfJ - r.ACTO.a 'I'8'A'I'IIIII'1' - . unalllO CA.III. - 8HOOT oa Acrorza - A8ANOON- - SBOOTIIIO 01. ACIDIZIII. A.AMDO"lIall~. - REPAIR WELL CHANGE PLANS (Otber) . - (NOTa: Report re.altl of multlpl. eoapleUoD OD Well (Otber) CompletloD or ReeompletloD BepOrt IDd Loe form.) 11. Ot:SCRIUE 'ROPOSEO OR CO~PUTEO OPEI\ATIO~r. (Clearly state nil pf'rtlof'lIt detallH. and ;Ive pertlneDt datH. IDclndlq etltfmated date of IwttDe aD7 proposed work. If well is directioDa1ly driUed. .ive subauñaee loeatioDS and meunred ADd true nrtlc:al deptH for all marker. aDd _Dee perU- nent to this work.) - As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SCU 13-3 SCUI2A-4 SCU 13-4 SCU323-4 SCU43A-4 SCU 24-5 SCU 33-5 SCU341-8 SCU243-8 SCU 13-9 SCUI2A-IO SCU343-33 SCU 14-34 SCU 14-3 SCU23B-3 sell 34-4 SCU21A-4 SWANSON RIVER UNIT SRU212-10 SRU 34-10 SRU 14-15 SRU 21-15 SRU 31-15 SRU 432-15 SRU 34-15 SRU41A-15 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRUI4A-33 SRU 24-33 SRU 12-34 SRU 21-34 v.itt\~~\) , - ,n\\ , I\\jG '¿ ( ~;.. t'^t\a CO'(f\'(f\\'fl!Þ\On .~ &. GaS VU\1~. ~as~ O~ ~(;"ota\\' 18. [ bereby ce~~at ~,e lorecolng 7trae aDd corred ~ ~ £7t~~~f SIGNEQ- II ;/ /" TITLE Regional Engiueer (Tbl. .pace for Federal or State odlee aee) APPROVED BY CONDITIONS OF APPROVAL, U' ANY: TITLE D.t.TII -8 b l ~ "7 I / .' D.t.TII *Se. Instruction. on R.v.... Sid. Title 18 U.S.C. Section 1001, makes it a crime for any person knowing!)' and willfully to make to any department or agency of the United States ¡'In~' f¡¡lse, fictihous or fraudulent statements or representations as to any matter within itS jurisdiction. Wells under Evaluation for Rate Potential TABLE 1 Wells being Evaluated for P&A/Future Utility 41A-15 23-22 23-27 34..28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 ~ \ -,d ~ ~ ~ ~ G> rt' -;1! t'J, ~ ~ ~ -. t-f\ ~~ ,- .-4 ã rp I~ ~ c:P~ - % ~. YA- ~ 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells S1 for Inefficient Production 12A-4 43A-4 24-33 12A-IO 34-10 14-15 21-22 21A-4 '1".. , Wells SI until Blowdown 43A-15 314-27 331-27 343-33 ) ) ~\ -~ ARca Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907276 1215 August 19, 1987 C('\~'~~ Cook Inlet/New Ventures Engineering n. :ì ~; , p ...,~.) ~ Joseph A. Dygas, Branch Chief United States Bureau of land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: ~~ ~~ Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a p~riod of 12 months. This sundry is fbeing submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, ¿~', ~. "( ./ / ~..,L. /7 " . / (.. -->/' I>~ ~_vL..t'--...~, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB:JWR:ch:0006 V.it't\~'t\) ~\.\G ¿ ( \~.~ I . . GaS (;O\\s. (;O¡\\\\\\SS\O\\ Nas~ 0\\ &. ~t"n()t'ð.r¡,e Attachment C. V. Chatterton, Chairman / Alaska Oil & Gas Conservation Commission cc: ARca Alaska, Inc IS 3 Sub<;'diilrY of At!ðntlcR,chf1eldCompany --- ,,\ . ,~ .>""" ~~, .-jd% K ~~ ~ "f)) Jtv1 I I ï I I I i ; UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Conservation Division Alaska Region 800 "A" Street, Suite 201 Ancho~age, Alaska 99501 June 18, 1980 F, L E ; S. R fA 34- - 2- '3 I sAV\ -+1-311#1 ! Mr. C.F. Kirkvold Chevron U.S.A., Inc. P.o. Box 7-839 Anchorage, Alaska 99510 .>"<~-~~ Re: Request for a permit to dispose produced water i~RU #34~2~ Swanson Ri \Ter Pooli,ng Unit, Alaska Gentlemen: The subject request for permit to dispose produced water 11 3/4-7" annulus and out the shoe of the 11 3/4" casing in SRU #34-28 is hereby approved for a period of 15 days through June 30, 1980. In the event use of this well is water disposal after June 30, 1980, an application under have to be submitted and approval obtained. down the at 2038' from June 16 desired for NTL-2B will Based on past experience with wells #41-33 and #41W33, we are no longer in favor of dispos~ng salt water down the annulus of any produc~ng oil or gas well. We prefer to have a separate disposal well cased into the receiv~ng formation with the water injected through tubing set in a packer located just above the casing shoe (for open hole completion) or perforations. Sincerely, I!~/II~J¿ Harold J. Hedlund Acting Deputy Conservation Manager for Onsþore Minerals j).1, f,':.' i'~' L r (, . C;\/F !,!(J U 1 9 1.980 AI:ska Oil 8~ ('. ArwhUff.:li,i'J /;,,'''; .. -'4 /""""', ~.', r 1 ¡¡ i . II i f\ \ : ¡ ¡ L \ Ii ¡ I -~ ' I'. ( í' \ t- ..) ,.1 ,-- JA Y S. HAMMOND, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION June 19, 1980 3001 PORCUPINE DRIVE-ANCHORAGE, ALASKA 99501 Mr. C. F. Kirkvold Area Operations Superintenden Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re: River Field, Dear Mr. Kirkvold: Enclosed are approved copies of the Sundry Notices you submitted on June 16, 1980 to Mr. Harry Kugler. You will notice the approvals apply only to the physical mechanics to protect the fresh water sources and/or the safe oil producing capability of each well. Approval for disposal or injection of fluids into any zone other,.than "a hydrocarbon bearing formation" must be obtained from either US Geological Survey and/or US Environmental Protec- tion Agency or Alaska Departmeneof Environmental Conservation. From the history of tubular failures due to corrosion associated with your disposal systems we have concluded that: 1. The use of any oil or gas well for long term annular injection/disposal should be discontinued. 2. Disposal wells should be properly designed and upgraded or replaced so as to provide protection of fresh water sources and allow normal monitoring of casing intergrity. 3. Failed casing in wells such as SRU 41-33 and 41-33WI should be repaired or replaced prior to further production operations in those" wells. ive~y tru~;ty ~:urs, ~r r J ,.-- ~ .':......'" "v//- ,~ C o~~ ð < ~~>tL Lonn~e C'. Sm~ th Commissioner Enclosure .-; I 7. UNIT AGREEMENT NAME-- t; l\.' Ü :.: '':'~' : ~ ~ ';- SWANSON ~I-VER UNIT - ~ k 8. FARM OR LEASE NAME:' r; ~ ~ è.. !>.' ;. - ~ C"~. - SWANSON RÏVER UNìT =-~ £T 9. WELL NO. .g E ~ ~ .~ ;; e. ~ SRU 34-2BF 1'1 ë; r; .~ ? ë:- 10. FIELD OR WI[DèÀT~AMÉ~ ~ ~ f: o£~,< iÞ ::.""'- SWANSON <RIVER ..J :::-, ~~ 11. SEC., T., R., M~ bR:BLK.~ND SÙRV£Y OR AREA g ~ èÞ Ë" ~ ::;¡ ë;; = ~ ~"O It' èÐ ~ ~~ SEC. 28 'taN' R9W SB&M5::l ~ 12. COUNTY ORJ>ÃRïSH13;T. STATE='\. ~ ~ =- ~ h. - (.".,..::) KENAI ~ ~ g :: R ALAS.I{A~" 14 API NO ~ ¿; è ~ tI' C'- '." fJ ;¡ . . :l.C~:-a. ~ ~~C'..o 50 - 13.~--~jO IS S ~~. ~:: 15. ElEVATIONS~(~HQW DF;:; KQB~¥,ÄÑ'ò WD) 184 I KB~ 3 S :=. =';;- 1;, == ~ .- {"'\.c> :-- !:" -' - r" ("'\ tñ ::: 0 ~;' ~ Cr 0 ~ N , :=o~~r.-" '~D \Þ, '- -:¡ cJ~"~'vc:>UI' ":"N~O g ONsHÒRf ~IST. Off/iEEE" (\)~ ~' "':"3g,g =.. £c~c:r t. 0 ll' N C '" r' - (NOTE: Report resultS 'óf multiplgcom'j,letiøn:-'or zone ch~nge on~riri M30."\i'\8l ~ ::;à. Í\¡ - ,JUN ::>~ .u 1:1 - l! ~ ::> 8 è Õ ~ ?, t s ~ ~ g :~ CONSEÍN;t, nON q}Vl SJ9N: 2 ~ u. S. ~fQ(°ß'CA~ SU~~ i ; ANC80JAGE. A!AS~,A¿- 0 f -r""pIo- ~ . Q.rr 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detail~~ ~ñd give~pertiñe'!lt dates. including estimated date of starting any proposed work. If well is directionally drilled.giv.e:subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.). t.'1 g ~ g. ~ ~ ~~) :- ~ ~~R~~ ~ ~g.~~ ~:(J~~ 0 ~:'ë-£ casing inJ'ection.~ eWe' have~snu"L"1n :..'oJ v" c -1r, '.0 'to dispose of thE[- Þfoauced:wa'tê'~.:.c ~ k~ ~ ~ ~. ~ (~ ~. ~ ~ 1\1..0 oJ -:: =-- Co :;, c: .:1 =-- :7J lÞ ~ ....; = ::::.(JJ L ~ ,,-, c- g. -:3 ~ <':J ~ S ö'~ -C-o; ~ ~ ~:- teL. ~ ~ ~ ~, g. E' .. ~ 5 ~ c£., So~=-~ '8 ~~~;;: .r,;:.!J ::... C ~ . oJ U' - :... ~ injectti6~ int~rval~: 3 ~ HU~ it HH ~Set @'o:=- ,: _.~ .-:: Ft. 9. 3 ~ ~; t: u ~ ;:: (\1" .0 '':' .:>, .... r. g, c. - ~ .-, t:T f' oJ r: r ~ - Juh'ë. q 6 r ~i 980~. :,' -' - - :-:~ C" t.:... -.. ..:. -- ~ .. '... . . ¡ ~ . 'Form 9-331 Dec. 1973 ~, UNITI:.... STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY .. .. SUNDRY NOTICES AND REPORTS ON WEllS (Do not use this form for proposals to drill or to deepen or plug back to 8 different reservoir. Use Form 9-331-C for such proposals.) 1. oil 0 well gas well 0 other WATER DISPOSAL 2. NAME OF OPERATOR CHEVRON U.S.A. INC. 3. ADDRESS OF OPERATOR P.O. BOX 7-839~ ANCHORAGE~ ALASKA 99510 4. LOCATION OF WELL (REPORT LOCATION CLEARLY. See space 17 below.) . AT SURFACE: 660 IN & 1530'~' W - FROM S :E.CORNER AT TOP PROD. INTERVAL: OF SEC. 28 AT TOTAL DEPTH: STRAIGHT HOLE 16. CHECK APPROPRIATE BOX TO INDICATE NATURE OF NOTICE, REPOR~ OR OTHER DATA REQUEST FO~ APPROVAL TO. TEST WATER SHUT-OFF 0 FRACTURE TREAT 0 SHOOT OR ACIDIZE 0 REPAIR WELL 0 PULL OR ALTER CASING 0 MULTIPLE COMPLETE 0 CHANGE ZONES 0 ABANDON. n (other) CONVERT TO WAStE SUBSEQUENT REPORT OF: 0 0 0 0 0 0 0 WATER DI90SAL Propose to convert SRU 34-28 to annular + 2,300 BOPD- because of our inability Attached for your information are: Form Approved. Budget Bureau No. 42-R1424 ~,~ S ~ C ¿.; ~;- 5' i\'.c.,f;" 0 5C'0'> A-02839,9 - t. :-: =- 6. IF INDIAN. ALLOTTËE ORtrRIBENAME ~ f~<" t ~ õ ~. ~ ........ " ~ LE " . ~ 0 ~ ~ '.... 1. 2. 3. 4. 5. 6. Surfac~ location sketch. Mechanical detail of SRU 34-28 Cross-section wells SRU 34-28 and SRU 41-33 Produced water analysis E-Log (1" = 50') from surface through proposed E-Log (1" = 100'-) from surface to T. D. Subsurface Safety Valve: Manu. and Type EnEjneer DATE ~ . _I C '~~.i= :.:; ë ~::. i: r /f¿, (Th'IS sp"" Federal or Sta'te office use) :J r -.. r. ;. - -...... ',' -~ ' --0""'" ----"- ~ ..J- ~ ~ '. ,~~gëólS-.:l~i: APPROVED BY " '" ,IITLE Act1ng- Deputy rma- UI'\1-;- - '- ~: ... :', ;.~. : ~ ~. CONDITIONS OF APPROVA IF ANY: ' servat.ion Manager for Onshore Mtn..~;¥s ~ ::' ~.¿. ~ ;: , ~;~~~ !~ ~t~: APPROVAL SUBJECT TO ATTACHED REQUIREMENTS 0. !>. \~' ì:§.~ ~ ~.~ Š t ;.. Þq-t'~ r ..-- .See Instructions on Reverse Side ' < ê ~;J í 91980 Oil ¿~ I,', '; t~nGnUf íi!:¡t:j .., Form 1 o-40~ REV. 1-1()-..73 :t.... Submit "Intentions" In Triplicate 8& "Subsequent Reports" In Duplicate ...-....... ~~ .. . ~\ 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.) A-028399 ¿ :JvJ 15 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 50-133-10158 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN. ALLOTTEE OR TRIBE NAME SRU 34-28 10. FIELD AND POOL, OR WILDCAT 1. OIL 0 GAS 0 WELL WELL. OTHER 2. NAME OF OPERATOR Water Disposal 8. UNIT. FARM OR LEAS~NAME SWANSON RIVER UNIT CHEVRON U.S.A. INC. 3. ADDRESS OF OPERATOR P. O. BOX 7-839, ANCHORAGE, ALASKA 99510 4. LOCATION OF WELL Atsurface 660' N & 1530' W. from S. E. Corner of See. 28 9. WELL NO. SEC. 28 T8N, R9W SB&M 13. ELEVATIONS (Show whether DF. RT, GR. ete.) 12. PERMIT NO. 184' K.B. 63-7 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 14. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ WATER SHUT-OFF § REPAIRING WELL ~ FR, ACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAI R WELL CHANGE PLANS (Other) (Other) Convert to Water DisDosal (NOTE: Report results of multiple completion on Well Completion or Recompletlon 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. Propqse to convert SRU 34-28 to Annular Casing Injection. We have shut-in + 2,300 BOPD because of our inability to dispose of the produced water. Attached for yo~r information are: l. 2. 3. 4. 5. 6. Surface location sketch. Mechanical detail of SRU 34-28 Cross section of wells SRU 34-28 and SRU 41-33 Produced water analysis. E-log (1" = 50') from surface through proposed E-log (1" = 100') from surface to T.D- injection interval. ** Verbal approval to"'canmence above 'WOrk was given by Blair ~ndzell on June 16, 1980. Approval is for mechanical details a, nly, to prot, ect fresh water ~, ere,'" ;mP\ ~~ r¥1teg- rity of the oil well and for a ~riod of time not to exceed 6' IOOnt tTr:abtM: 'Slitv'ey to be run within 30 days of initial injection. Operator to obtain approval fran USGS and/or EPA or DEC for disposal of the produced water into the propq~1 t~e\9aQ.be Carmission may only approve "salt water...........be disposed of by" rnjection into hydrocarbon bearing fonnation(s) ....... II 20AAC 25.250 page 22). & I. ' '.," y,,\,,;',((dÎ Alaska 0\\ . v 1 Anct1íJI alae TITLE Area En~ineer DATE T11nl'> 1 h 19RO COMMISSIONER. ~--- ---.r--'-"'_'---_,~.----:--_,,------ -- - DATE , --If-8ð F ~fOVtId Copy ~.. Returned _left ?/f~" #'~ì'~ See Instructions On Reverse Side ;--\ ~ Page 2. PERFORATING BECOBD: 5 - 1u hóles at 10,707' 4 - In hóles/foot. 1.0,716 - 10,725' 4 - 2ft holes/foot 10,737 - 10,762' WELL SURVEYS: 1. Schlumberger Induction - Electrica.l log 35 - 1981' & 2039 - 10,880' 2. Schlumberger Sonic log 2039 - 10,880' 3. Schlumberger Microlog~Caliper 9883 - 10,880' 4. Schlumberger Formation Density log 9800 - 10,880' 5. Schlumberger Continuous Dipmeter 2040 - 10,850' 6. Schlumberger Cement Bond log 200 - 10,823' 7. Schlumberger Gamma Ray-Neutron log 9828 - 10,828' 8. Schlumberger Casing Collar log & Perforating Record DRILL STEM TESTS: BCT 1/=1 at 10,707' (wao) RCT'#2, interval 10,157 - 10,762' ,~ -, ,"-" COMPLETION REPORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPEMTIONS, mc. ~ OPEMTOB Page 3. March 30,1963 Spudded at 11:00 P.M. Drilled 16" hole to 45'. March 31, 1963 Drilled 16" hole to 58'. Lost circulation around cellar and through mouse hole. Cemented mouse hole with 8 sacks cement. Drilled 16" hole to 79'. Circulated around cellar. Cemented with 97 sacks through 7" casing hung at 29'. Cement,,~returns to surface around cellar. Stood cemented. April 1, 1963 Drilled out cement and cleaned out to 791. Drilled 16" hole to 1512'. 74 pcf mud April 2, 1963 Drilled 16" hole to 2040 r . Ran Schlumberger Induction - Electrical log 35 - 1981'.. Reamed 16" hole to 660'. April 3, 1963 Reamed 16" hole to 2040'. Ran 11 3/4" ca.sing. Cementing detail: Cemented 11 3/4" casing at 2038' in a single stage with 1400 sacks of cement using Halliburton power equipment. Used one top plug. Pumped 50 bbls. of water ahead, mixed 1400 sacks of cement in 55 mins. using Halliburton, displaced in 15 mins. using rig pumps. Average slurry weight 116/1=. Bumped plug with 2000 psi. Full circulation. CASING DETAIL Above K.B. Cut -and recovered X.B. to top of casing 51 joints 11 3/4", 47#, J-55, s8R, R3 including shoe and float collar Casing cemented at - 4.481 f:24~~' 20. . 20l¡.52' 203 .00' April 4, 1963 Landed casing and installed BOPE. Drilled out cement and shoe at 20381. Drilled 10 5/8" hole to 2400'. 74 pcf mud A~ri1 5, 1963 Drilled 10 5/8" hole to 3793'. 71 - 80 pef mud April 6, 1963 Dr11led 10 5/8" ho1e to 3876 I a.nd 9 7 /8" to 4145 1 . 77 - 79 pcf mud /'\ 0 COMPLETION Rt!:PORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 We, Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. -:n OP]::RATOR Page 4. April 7 - 21, 1963 Drilled 9 5/8" hole to 8550'. Increased mud weight to 96# pet when drilling at 6700'. 79 - 96 pet mud April 22, 1963 Ran Schlumberger Induction- Electrical log 8549 - 2039' and Sonic log 8545 - 2039'. Drilled 9 5/8" ho1e to 8638'. 97 - 99 pet mud April 23 - May 5, 1963 Drilled 9 5/8" hole to 10,863'. 96 - 99 pet mud May 6, 1963 Drilled 9 5/8" hole to 10,880' T.D. Circulated and conditioned mud. Ran Induction - Electrical log 10,880' - 85491, Sonic log 10,880' - 8545' and Microlog- Caliper 10,880' - 9883'. Conditioned hole. 99 - 100 pcf' mud May 7, 1963 Ran Formation Density log 10,880 - 98001, and Continuous Dipmeter 10,850 - 2040 t . Circulated and conditioned mud. 99 - 100 pcf' mud May 8, 1963 Ran and cemented 7" casing. Cementing detail:: Cementéd 7ft casing at 10,880 I in two stages with 1800 sacks ot cement treated with 0.5~ HR-4 using Halliburton power equipment. Used 1 top and 1 bottom rubber plug. 1st stage around shoe with 700 sacks ot cement. Pumped 50 bbls. of water ahead, mixed cement in 40 mins. uSing Halliburton truck, displaced in 38 mins. using rig pumps. Average slurry weight 116#. Bumped plug with 2000 psi. Full circulation. 2nd stage through DV at 6016 I (top) . Dropped DV bomb, opened DV ports in 30 mins. Pumped 50 bbls. of water ahead, mixed 1100 sacks of' cement in 55 mins. using Halliburton truck, displaced in 24 mins. using rig pumps. Average slurry weight 116#. Closed DV ports with 2500 psi. Full circulation. Cement in place at 11:30 P.M. Hookload weight of casing before cementing - 210,000#, atter cementing before landing casing - 190,000#. 0, "'\ COMPLETION P~ORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M . STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR CASING DETAIL Above K.B. Cut and recovered K.B. to top of casing 125 21' 3 joints 7", 29#, N-80 BT R3 = -42:91' 107 joints 7", 23#, N-80 BT R3 Crossover, BT to 26/1 LBR 33 joints 7", 26#, N-80 LBR B3 DV collar 14 joints 7", 26#, N-80 L8B R3 46 joints 7", 29=/1=, N-80 L8R R3 50 joints 7", 29#, P-I10 L8R R3 Marker joint 6 joints 7", 291/=, P-110 LBB 8R including shoe and float collar Casing cemented at May 9, 1963 Page 5. K..B. Depth - 21.38' 42.91' 21.53' 82.30' 4513.94' 8.33' 1390.30' 2.13' 597.58' 1879.16' 2111.50' 14.38' '.... 21.53' 103.83' 4617.77' 4626.10' 6016.40' 6018.53' 6616.11' 8495.27' 10,606.77' 10,621.15' 258.85' 10,880.00 10,880.00' Landed casing, installed tubing head and reinstalled BOPE. Drilled out DV at 6016' and tested with 2500 psi - OK. May 10, 1963 Drilled out cement to 10,832' /J Circulated and conditioned mud. Ran Cement Bond log 10,823 - 200 r, and GamuaRay Neutron log 10,828 - 9828 t . May 11, 1963 99 pcf mud Ran Schlumberger Ca.rrier gun and shot 5 - ~" holes at 10,707'. RCT #1, WSO test at 10,707'. Tool assembly: 2 outside BT recorders, 3' of 2fT8" perf'd tail pipe, 7" type "C" hookWal1 packer, VB safety joint, hydraulic jars, 2 inside BT recordersi hydro spring tester w/J¿tI bean and dual closed in valve. Ran on 10,638' of 32" IF drill pipe. Used 3600' of water cushion. Set packer at 10,8581 with 16' of tail to 10,674' at 8:45 A.M. Opened tester at 8:48 A.M. for 5 mins. pressure release. Immedia.te faint blow of air throughout. Shut in tester at 8:53 A.M. for 30 mins. ISI pressure period. Opened tool to surface at 9:23 A.M. for 61 inins. flow test. Shut in tool at 10:24 A.M. for 30 mns. FBI pressure. Pulled packer loose at 10:54 A.M. Dead throughout fløw test. Recovered 25' net rise, all 9B pcf drilling fluid. Final. Pressure Data: Depth Gauge ...!!L IS1 IF FF FBI FH --- -- Top inside 10,641' 7456 2143 1648 1646 1920 7119 Bottom inside 10,645' 7476 2144 1643 1632 1897 7369 Top outside 10,666' 7534 2162 1663 1663 1928 7433 Bottom outside 10,670t 7534 2144 1654 1659 2038 7395 Conclusion: Charts indicate tool functioned OK. WSO - OK. r\ ,~ COMPLETION REPORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INO. - OPERATOR May 12, 1963 Page 6. Circulated and conditioned mud. Shot 4 - i" hOles/toot 10,757 - 10,762'. Ban tester and made up water cushion. Unable to set packer. Pulled and found small piece of metal in slip arm on packer. May 13, 1963 Reran tester. RCT of the interval 10 757 - 10 762'. Tool assembly: 2 outside BT recordere 3 t of 2 7 perf" d tail pipe, 7 t~e "clt hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders i hydro spring tester wit" bean and dual closed in valve. Ran on 10,698' of 32''' IF drill pipe. Used 3132' of water cushion. Set packer at 10,718' with 16' of tail to 10,734' at 4:41 A.M. Opened tester at 4:43 A.M. for 3 mins. pressure release. Immediate weak blow of air increasing to strong when shut-in. Shut in tester at 4:46 A.M. for 1 hr. 9 :min. ISI pressure period. Opened tool to surface at 5: 55 A.M. for 9 hrs. 40 mine. flow test. Shut in tool at 3:35 P.M. for 2 hr. 1 mins. FBI pressure and backscuttled out oil. Pulled packer loose at 5: 36 P.M. Immediate moderate blow of air increasing to strong. Used 3/4" bean in Shaffer adjustable at surface. Water cushion to surface at 6:50 A.M. (55 mins.) becoming dirty and muddy till oil to surtace at 7: 25 A.M. (90 mins.). Turned from sump to tank. at 1: 55 A.M. Turned through trap at 8:00 A.M. Began gauging and sampling at 8:30 A.M. Well flowed at a rate of 950 B/D oil through 3/4" bean. Flowing pressure 123# psi. Cuts: o. 3;' total (0.1% water O. 2'1ø emulsion, and trace sand and mud)t Gravity 33.9OAPI. Eackscutt1ed and took samples. Final Pressure Data: DepthGauge ..!!L !ê.L..1!.. -1!... ~-Æ!.. Top inside 10,701' 6432 4689 2100 3588 4634 6432 Bottom inside 10,705' 6430 4711 2062 3575 4651 6422 Top outside 10,726' 6484 4727 2057 3616 4669 6484 :Bottom outside 10,730' 6467 4718 2247 3591 4659 6437 Pulled tester and shot 4 - t" holes per foot 10,137 - 10,757' and 10,716 - 10,72 Ma:y 14, 196~ Ran 6ft reamer to 10, 770t. Circulated and conditioned mud. Pulled and ran open ended drill pipe. Laid down drill pipe. May 15 & 16, 1963 Ran a total of' 336 joints 2 7/8", 6.5#, lV-SO EUE 8R Rg2 tubing equipped with packer and mandrels. 86 pct mud r\ ~ COMPLETION REPORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M --~- ~ - - - - ~ - STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR TUBING DETAIL K.B. to donut Donut and pup joint 47 Joints 2 7/8" tubing Cameo MM mandrel w/RD (#1) 31 joints 2 7/8" tubing Cameo MM mandrel VI /RD (#2) 22 Joints 2 7/8 It tubing Cameo MM mandrel w/BD (#3) 16 joints 2 7/8 ft tubing Cameo MM mandrel w/RD (#4) 11 joints 2 7/8ft tubing Cameo MM mandrel w/RD (#5) 9 joints 2 7/8 n tubing Cameo MM mandrel w/RD (#6) 37 joints 2 7/8" tubing Cameo MM mandrel w/RD (#7) 31 joints 2 7/8" tubing Cameo MM mandrel wJIID (#8) 28 joints 2 7/8ft tubing Cameo MM mandrel w /RD (#9) 23 joints 2 7/8u tubing Cameo MM ma.ndrel w /RD (#10) 39 joints 2 7/8ft tubing Cameo MM mandrel'w/RD (#11) 38 joints 2 7/8ft tubing Cameo MM mandrel w/OEV (#12) 1 joint 2 7/811 tubing Brown CC safety joint One 2 7/8" pup joint Brown 2 7/8" X 7" HS-16-1 packer 1 join-t 2 7/8" tubing Cameo liD" nipple 2 joints 2 7/8" tubing Venturi shoe tubing landed at 20.05' 1.70' 1476.39' 12.82' 937.07' 12.79' 692.31' 12.72' 500.04' 12.77' 344.06' 13.05' 282.56' 13.00' 1158.80' 13.08' 977.85' 13.05' 880.50' 12.77' 722.43 13.03' 1227.86' 12.69' 1198.74' 12.74' 31.96' L07' 8.07' 6.02' 31.54' .95' 63.74' .67' 10,754.89' Page 7. K.B. Depth 21.75' 1498.14' 1510.96' 2484.03' 2496.~ 3489.13' 3201.85' 3701.89 ' 3414.66' 4058.72' 4071.77' 4354.33' 4367.33' 5526.13' 5539.21' 6517.06' 6530.11' 7410.61' 7423.38' 8145.81' 8158.84' 9386.70' 9399.39' 10598.13' 10610.87 ' 10642.83' 10643.90' 10651.97' 10657.99' 10689.53' 10690.48' 10754.22' 10754.89' Removed BOPE. Completion detail: Installed x-mas tree and tested with 5000 psi for 17 mins. Held OK. Commenced displacing mud with oil at 10: 10 P.M. (May 15) Pumped 32 bbls. of water ahea.d, fQllowed by 410 bbls. of crude oil. Stopped circulating at 2:50 A.M. (May 16). Formation oil to surface a.t 3:00 A.M. Flowed oil to sump until 7:05 A.M. Set packer at 10,652' and started floWing to trap at 7: 10 A.M. Re:presentati ve flow rate and cuts as follows: FLOW RATES BEAN TBG. CSG. TRAP FLOW PERIOD OIL GAS SIZE PRESS. PRESS. PRESS. 1. 1 Hr. 141.6 BID 296 MCFjD 64/64" 100 0 75# 2. 1 Hr. 516 BID 169 MCF/D 18/64" 350 0 75# 3. 1 Hr. 288 BID 134 MCF/D 12/~4" 600 0 75# r\ .~ COMPIETION REPORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M STANDABD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR Page 8. TIME iTOTAL CUT c¡bWATER ~ION ~ & MUD CORR. GBA VITY 1. 9=30 AM' 5.2 4.0 1.2 0 34.80 API 2. 10:15 AM 2.6 2.2 0.4 0 3. 11:00 AM 1.6 1.4 0.2 0 4. 11:30 AM 1.0 0.8 0.2 0 Shut well in at 1:30 P.M. Shut in pressures: tubing pressure 1000 psi, casing pressure 0 psi. Produced estimated 118 bbls. formation oil.. Flowed 102 bbls. to tank and estimated 20 bb1s. to sump. Installed Cosasco plug. Released rig at 6:00 P.M., May 16, '1963. 51PA '/ø.lb3 S. R. HANSEN SRH:pb /-'\ ...... /' "\ COMPLETION REPORT SWANSON RIVER UNIT 34-28 Section 28, T. 8 N., R. 9 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. -. OPERATOR DEVIATION DATA Depth 450' 1670 t 2040' 3170' 3856' 4009' 4100' 4345' 4715' 5360' 6020' 6200' 6540' 6940' 7037' 7224' 7500' 7740' 7933' 8080' 8270' 8737' 8930' 9096' Degrees 0°15' 0°30' 0°30' 0°45' 1°15 ' 0°30' 0°45' 1°30' <:)°30' 0°15' 1°15' 0°45' 1°00' 0°45' 1°00' 1°00' 0°45' 1°15 ' 0°30' 1°00' 0°45' 1 °15 ' 0°45' 0°15' Chevron === ,~ '-.. -, Chevron U.S.A. Inc. P.O. Box 7-839, Anchorage, A K 99510 . Phone (907) 279-9666 c. F. Kirkvold Area Operations Superintendent Production Department June 16, 1980 REQUEST FOR A PERMIT TO DISPOSE OF PRODUCED WATER IN SRU 34-28 - SWANSON RIVER FIELD Mr. Harry Kugler Commissioner of State Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Kugler: Chevron U.S.A. Inc., as operator of the Swanson River Oil Field, requests your approval to dispose of produced water from the Swanson River Field in well SRU 34-28. We are proposing to dispose of the produced water in well SRU 34-28 by injecting down the 11-3/4 x 7", annulus and out the shoe of the 11-3/4" at 2038 feet. As can be seen from the attached cross-section, we will be injecting into the next sand above the one we have been injecting into for the past several years in SCU 41-33. We currently have all of the SRU wells shut-in. This results in a loss of + 2300 BOPD. We are also attempting to workover well SRU 41-33WD. This is ~n old disposal well that plugged up and stopped taking water. It is doubtful if well SRU 41-33WD will be able to take the required 6-10,000 B/D of produced water even if the workover is successful. We are presently working on a plan to drill disposal wells in the general area of the 1-33 tank setting. However, this will not solve our immediate problem of produced wäter disposal. Attached for your information are: RECF1\/CD , d) ~ 1 1 G 1Qao 1. 2. 3. 4. 5. 6. Surface location sketch. Mechanical detail of well SRU Cross-section wells SRU 34-28 Produced water analysis. E-Iog (1"=.50') from surface E-Iog (1"=100') from surface A\:;.S\<3 (hi i~,' , knQ\WI j¡\~~ through proposed injection interval. to T.D. 34-28. and SRU 41-33. ",' ;:~,;',\cn Your rapid approval of a permit to dispose of produced water in SRU 34-28 would be greatly appreciated. :RWM:sj Vèry;;ty YO~ c. F. K~ 100 Years Helping to Create the Future Attachments ",....-. :";."'~¡..~~ ..-I-,ßO-.:,":", ':~~3~,::'~~',:' / J '~;:/' 29 ,"'1' 32 t7ç¡-- : 'V;:;. i /---, 1 I I I I , . I ! -----------~~---~-7 I I, I' I I I I I I I /~, :23-22 )( , , I I I I h ~ I ! I I I 4I'';:t> 4- 21,27 . A-028~39 .s. 0 Co f/z - /? 0 Co/'p. f/~ 11.27 /" "''' +H'21..hnd, 27 28 .)-ze . ;' ,~,~, 27" : ,. -27 - - i I ! SRLI. J'4-¿>~ ""-f--- 1410' , 'g 1\ \¡) - - '- -- --'---//--- f--- ~b; , \.1'" .I-)~ ''''1 --- - -- .-- - - ------- 221 - 3'3 ~ ~1-34 0 )2,H . 12. 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I'<r -- -r " -, -¡-- .¡...,- r- -- ~ '-""¡J-'-- ~r-- ~ '=-,-.-- --' r ~ VI, --- -- r.-- -...,... r:! ,---;-- " - . -- -r-r - ~ L --;"'1 ----- -- 1- "-- -1- ..:: ---+- -rli- '1-'=1'-=--""-1H --.- -, J - ~ -¡-, r-~- 1---- c- -r-r-- ~ ~ = . -r-...-,- ,~ I-C---I-~-~- 1- ---- -r-..- - r- ~ - - 0 - '-' - -,r-r--=- - -t -.-- 1- ...-,-- - ;::: - - c---o---- - . r -r--; -C----J- "'-r --r-~ -0---- - -~.- . '-, rl c-...,- - - 00 -r- -ro-¡- r-, -+- - -- - ,- ~ -.-i ;:: ~- - - - c---..J - - = ""--0----.- - c- -+- c- -- " .- - ,~r-.--o----~ ---r;::~r--r - .-~- ~~ ~ ' -c- - ~f'-- -,rry -+- -rr-r.-- ! ,--+-- '~Ef - -c- ,; r- r' r-. j - - ,r-jt--;-'j -.. - . 1- rJ-,-;::: ;:::: r- r:-- c- -.- 'i..= 1-.- --,- - r-r--r-- - - - I'>r- ,,---- - ,..- -.---- - - PI' ,--- .&10- :"-r-r- --r-c-- - I-- - - -r-,- - ~-...,-- - ""..- --r-~r--c-. -c- ~--- . - -,.,.. - '~"" =::-=- - - ,-r-t-r-rt= :L -r- -~,- 8 1- ,.... J_" E t- -= -h- '" =- -, -;= , rrr-rr-.-' .. ~I~!~ L....:::+- bÎ~~/~< ~¡~, ~ ~ ~t~å ~~ ;?";;~ LJ" 'î'~ ::= :=~, '=:=- -t_~ - , ~~:.- , . :.::. L - '= --'.w-j J --:¡; .-3"z1 ."-~., = -,.-- " "" - ~. - t---r:: tt '-" ç J/ U / / r -c ~= ~ =;:;-' ¡::~ cr~11f 7?êh - II -, t-J::¡ ,~, ,- ~,~tI " . I.,,~ - -r- r--,- r- ;-- - -¡-,- r-r-r---:- r- "- LI l r-r.:-.... . . - . L "'4"-"""~~~~~''''.~--"'.:"'''oI'..~ , , . , .... CHEMICAl~: GEOLOGICAL lABORA'~RIES OF ALASKA, INC. , ~ TELEPHONE ~907) 279- 4014 P.O.BOX 4- 1276 ANCHORAGE, ALASKA 99509 4649 BUSINESS PARK BLVD. VV.l.t\TER AI\JALYSIS REPOR'ì A 1 as ka DATJL.i!anUary 27, 1978 LAD no 7246-8 LOCATION- FORUATION IMTERV AL- SAUPLIk FROM.... Wa ter Samp1 e .. op~r~TOF Chevron~ U.S.A. ,œLL no SCU vIa ter SamJtl.g PIELD Soldotn,a' Creek COUNTY, 6T A TR. nEl!APJ:S t: CONCLUSIons. Stabi1 ity index = -0.7 @ 25°C *Iron (Fe)mq/1 -----Total = 97, Soluble = 5 NO WELL NO. LISTED ~ ~,.,/l ~/l ArJona ~p,/l ~/l - - ~ - . . - . - 6442 -A 280.24 8u1fa~ -. - - - - 8 o. 17 ~ ... -. 140 3.58 ~_..__..- 1 3000 366.60 Ccldtm1 - - . - . - 1800 89.82 Cu~te -... - . 0 76 6.25 800 - -~-1-3. 1 2 ~t.cm-_....- BIcu~ta - - - - .. Irca * -- H~'t!roxide - - - . . . - - . . . . Tœ:1 ~~ - - . - 379.89 Tota1 An1o::w .. -. 379 .89 --~~- T~.cl &-~ ~~ ~1 .. - .. - - 21729 UcCI cq;dYclcut, c.::Ii . .. - .. .. .. - 21664 O~-n:I pH .. - - .. .. .. .. .. .. .. 5 . 6 s~ rds~ @ ó69P.: 0 b--::uvec. #...... ~ ..... 0.32 0.32 c!:m-~ ~~ (J &mp10 c bovo de-"..criqed V/ATER ANALYSIS IJATTERli ~ .MEQ ~ Unit Nn . Cl 100 Na 111i11rHi H-H+H.t ¡~ I II If IIIII ¡ 11 I [HI 11JtH~ Cl .,' ,....-, Cs mi~ i I I ¡ I ¡ H I h;.,+- !} HC03 1 0 Ca I n H H 11111111 ¡ 11111 i ! H Ii III 1IIIIIIIIIIIIIIIlill H co 3 J R'~;'j I.!r:. , , ., ", . , " :¡fffffimmTTnW~ SO~ 10 - I~g SO.. Fa Rftttllllllll!; II J , J ! I !'~HJlW II ! II ! II ¡ 11lli.llJ CO 3 10 Fe CO, (ft. t'Ù.M b ~ ~ ..... Nt.. r.. 8!Ñ U) )lOT:: !.fÚl=lf~ p8I' ~ Ueqf1= 1f~ qrúT8l.eau pee U.. ~ c:ItJøri6e ~:~.., D~ . a~ ~ &.. ...... -;.t'.~~~~~~-~;:~':~ "~~+-.,. CHEMICAr-~ GEOLOGICAL lABORt(~RIES OF ALASKA, INC. TÐ... EPHONE 1907) 279- 4014 P.O.BOX 4- 1276 ' ANCHORAGE, ALASKA 99509 4649 BUSINESS PARK BLVD. WATER ANALYSIS REP01<'f opnp.hTOF Chevron, U.S.A. DATJt January 27, 1978 LAD NO 7246:..7 ",roLL ~O SRU Hater Sample LOCATION- FIELD Swanson 'River FORUATION COUNTY INTERVAT GThT~ A 1 as ka SAUPLK FRO!cl ,.Wa ter ,Samp I e rmUAr..I:B t:: CONCLUßIOl1ß. Stability Index = + 0.4 @ 25°C *Iron (Fe) mq/l ----Total = 5, Soluble = <, NO WELL NU~1BER LISTED ~ EE!.! ~/l ArJOM ~/l ~ -t. - ~ - . . .. - - 4720 .- 205.27 8tûfa~ - - - . . - 51 1 .06 ~ .. - - - ,106 2.71 ~_...._- 15500 437 .10 Cak:h::n - - . - -. 4ROO 239.52 Cubo=te -. - - . 0 ~_.... 46 3.78 BIc:-.rbooate - . - . . 800 13.12 Irca - - - ." . - - * --- Hydro:dde -.... Tctn1 Catiœa .. - - 451.28 TotaJ AnIona .... 451.28 - ..--.-..... 'þ Tot'J ~ ~ mdl .. - . - 25613 lJcCl ~d\'8lct, m:vl . - - - - - . 25219 O~ pH -. - - . - . - - - 6 . 4 8~ ~ e ~.J!.: Ob~ . - - . ~1("fl.1;. ted .. - . 0.27 0.27 o=.~ oJ:m..~ Sampla Qbove de"'vCn"bed V{ATER APlALYSIS PATTERN Scdo n!EQ p:a- Unit ø Nn :.l ,- Cl 200 Na Cl CJ -- HCO~ 20 Ca HC03 ;.+ v 11r: -, ~ ~> so.. 20 l.fg 80.$ Fa C03 20 Fe CO. (If. n1at ill ~ ~ ~ Ka. ~ ~ U) )f on: ltc/I = tf~ p8' ~ 1teqf1 = Ha=cr- ~ain1eet8 I*' Uw Ioöaa c:Woride ~:~~ D\oIÙep . H~ ~ ".... r J IT. '_'c'. )~, t~ - , < ~ SCHWMBERGER COMPANY STANDARD OIL COMPANY OF CALI FCRN I A ~~. ë UJ ...J > i 'z >-= >-J...O Z Z~~~ ~ I COUNTY KENAI ::> ~ u ~ :E. 8~ 9 ~ 8 I STATE 'ALASKA WEll S'I1ANSON RIVER UN IT - NO. 34-28 .- FIELD'S WANS ON RIVER lOCATION 2S..8N-9W - II II " .. - - -..- -~-'~ /~ Other Surveys SL ML COM FDL Location of Well @ Elevation: K.B.:184 D.F.: or G_L.: 163~ 7 FILING No. I @ OF @ of @ of @ of @ of CC 30 min. - L- @ of @ of @ ~ of @ of ,@ of CC 30 min. P IOFh . 1IJ 0:: 1IJ J: 0 .J 0 I&. ,'~~.JIí, ... , , ~ p z o¡:~ ,g. REMARKS 'C.Pt' Used(' --- ; S.O. = 'lfU '" ~ '-- -'-- - '- ..-- ~ - ~I Cartridge No.~ Panel No. 325 Sonde No:. .17 I IPan~ I No ~ 29B ~ 32.S ll.l 288 ~-3 325 III 60 , ! I RESISTIVITY CONDUCTIVI ohms. m2/m niillimhos/ m = ohl 16/ NORMAL. ,INDUCTION 0 f 5 500 I 0 , 5001 I SPONT ANEOUS.POTENTIAL millivolts -I~I+ r--- - INDUCTION 0 sc r-----------------L---------------.-----' 0 ' 50e .....---------------------1.- --~ - -= -- I-~~~ t -1- I '- - . !- -, J - - I - I I 1-- - , 1- 0 0 0 0 N 0 0 .. . I 0 ()I 1 1 I 1 I __I Jr'" a_- -- "-' '-'0 £ d -> 0 -0 1.0 0 co r--r- -..-- 0 ........... I - ¿ I - { - . - ~ ~~ c;;" t::> -it - 0 IJ 0 Ir- r-- 0 ,.> <- - ") <'---- - ~ ~ ~ -,-- h . \ 0 0 ....,!Þ tD 0 cr.. . - . --- -- 1- 1- c::- --> ¿ > - ) - ..- --... "" 4 . r---- ~ í""-- IF ~ )~' '''''''þ .... !~ "> -] : 4" . ~ " ~ "'\ < ~\ 4 ) '\ < J ) - \- - I \' - l-J ;--' . - . -- - J- ~ 0 0 ~ 0 0 0 '-../ , ~ :111 t- ~.~.~~-... ' 7¡/O~d '~ 0 0 Q '-J ~ r (I r ~ ~ ~ t J ¡ ~ I ---> 5" ! <... 0 'z .., 0 ~ ~ í . ":) l... /~ ') I " I ~ ~/ 0 t:.. ~ - Q It c:::: -' -- \ - D - ;;. " - ) c::::::: --/ c:::~ ~ -...~ \ ; .J <: '"' - <. <: --- ~ <--' '-> <: , <::-- --- ' ... - ' ~ ¿ ~ c~ ..~ 1. , ....--1 /: ~-'-- ~~~- J -, 0 0 m 0 0 0 - . ~ . .J' ~' --.,.* ~;/O Sd .- \" '~ :> --- co I -- ' - ,- --,~ I I If - I ~ ( ~ - > I <..~ <. '--- ) "') - - 0 ,0 i- { - ~ - - , ( - . ~~ - i 1- LJ - - <~ ~ c:::::: '.--' 0 0 ' ~ - < ! -' / .-- - c~ - i.--- '" - " - < - 1- ~ 1- J I ~ I , - 1. - < -, <;;1' - .-D - \ - -,t.....--'" ~ / - ~ ,- .-f ~ ~ <þ <c;' ~ ") - U - 1-' <::::- - ~-- . IV I '\ )1 I ~ I .- .', 0 0 10 0 0 ~ 0 ,.... . , , . ,"j" \ .....-~ .),i-) r<> (\I 0 0 ('IJ (\J <. _..~ -. - &_- ..w w- - ----- -.-.- 0 0 -" 0 -(\1- 0 0 Q2 0 (') .. '-'- -\J . , " !j~O , d r) ~ ..-~ . ~:-~ ~.,;,-~ ,t. ,<.~.,",:~ 'j"'" .'-' ... -. , -'''....".;'' - ..-.., ~~r..:.. ,,""., ...-<~..-.:,!.... .,' "",...~. . . . . ¡--.." I ~, J ! ~:.J1 ~i1 WElL S..,ANSON RIV::R UNIT ~!OI NO. 34-28 I it) $1 ~q FIELD SWANSON RIVER @ .I ~ ~~J lOCATION 28-8N-9W Ô )0 Elnction. K.a..~ - ~ ~ ~~" ~ COUNTY ~F.HAI I ~G,",¡n;:'[ §¡¡:g~ 8 I STATE A1.AS.IA FILING No.~ ë ~ . -- ...--.-. -- ,Ci> "f --~ -0; Ci> Of of of CC 30 Olin, I .~O I~Q ~ SPOHT ÀNE OUS.POTENTIÅL millivolts I f RESISTIVITY I oh~s. m'/m -- ¡ 16" NOIMAL 10 , 5 51 0 I &OC 'INDUCTION ~ i 0 . i 0 -I~I+ 1- ~,,'-,----"'- ~ --- :~ ~ -V ~ - - '- v -or -'" ~~-~ !f 0 ~ ~ ~ I ~ ~~ ~ 0 ~ .~ =c L.1 i 1 T T-r-1 -L- ~ - ¡..."o<L-L- -J--J-- -- _LL t-~I-~ ..:... '\.. ----- -:-,L- ----- u: --- - -,>"'- - - - -- --~- - -- - ,- --- '- -t- L --- --- ' ,- '- -- - - '--~ - '- ..... '-- - - ----= '- --- '- - .=1- ,- - -- '-- ---- '--~ - --J-- '--'- - . -- -- - '- .-:- - '-- -- '- ~ -I- -- '- - -~ ~ '- ~ "-- -- '-- -- - - '--- j - '-- J -- '-- ...... --- :== -~ -- '-- - :-- ... 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Õ - þ-' ,- .- .. . - T r , § J J \, - ~- f-. -" -, .~ ~. ---.- ,- - -, .. - f- , I -....;;...... " I ~ I .J I;" ~ Õ .l "l::: - - 8 '( IT -- '" þ .4<' ,¿, - "~I-- .~ -f-IJ "- - ... ~ :,., _I_t. ~ Ill<- r. - - .-('1 o~ .j( '~j .-' > ;~ - - J j I\. " I Ii: -.. ~ .~ ....... I r"" ..- ç ,;..., ...v ( ) :~ v ð ( l ,r;:, ). ~ --- =- 0 ~ '\. \. ~ """ I~ < f '- r: '. - t;:::. . ~ ... ,J C. K .. v -¡., . - - It' L'" ,,,\-- r ? ....L "'"'--I-- , ~ r I I , ~ I, 0 ", ¡ 0 ~L - -. SPONT ANEOUS.POTENTlAl 0 RESISTIVITY 100 millivolts ~ 0 ohms. m1/m 50 PluQ: IO,8öO'-IO,832' T.D, 10.880' 5'27'63 I . I i " STANDARD 01 ~ CO, of CALI F., W.O. I., Oper. SWANSON RIVER UNIT 34.28 Elev. 184' K.B. Fr. S.w. Cor. Sec. 28 T 8N.,R.9W"S.B.ßM. 660' N. & 1530' W. Surface Location Janu~1t.y 1, 1'64 Hr. C.V. Cbatterton D18tri~t Superintendent Standard Oil Co.pany of PO lox7.ß3" AL1chorage A,laak.,a Call1forl11a Dear Mr. Chatterton; Acbeck of OU't' r~ec():rclsi.l\dicata.ati,}at aneleet'ric log bas not been subm:J.tted fortbe folloWin¡ developœel,'},t, well8: sau 34...,28 ¡CU21...16 Very tru.ly yours, T'nœas R. l~Ja'rsh.Qllþ Jr. TIM:: l~p . l~ -, - ....".,.., "»>, ....'..'i<'-~~;"'I?r.i~:. ~. Budge~ lJu¡:'t\!ul;No. 42- R~d.6.,< ' " \ APOrovaluptMl2-31-tiQ. ' L.AND OFHcr,AnohQ.t.&._~. "'-.-' LEASE N\1MB£R .A.~,2J'J.99n. ''''.''- UNIT -~~VËD ,- ,,' LESSEE'S..MONTHLY REPORT OF OPERATI&}\fSage, Alaska , II TN la 1963 Stat,;; __A.f!.~J.c~_._..,------_. ' . 06U#ÎY'J~~~~--~!~~~~~~~,--- Field -~!!~~~~--~!!!~.,._---_._._".,. -, _.. ...w,_.. The followìng is.a COl'l'~ct.repart of' opel'a.tions ,and producUon (includi~,i¡Mlltfn~~~arphMmei~ well.) 107 the mon t h "I ------ -._-_:__._}Jl~-Y-___-, 19(,1- ,(>w§!!'!!! Q!+~BßIlfì!r.:i-~;~!()~atë~~ ..1~ent's addrC8.(~ -_J).. _9...~~~,t.'l~~¿9._-,_.,.__.. _P,-___._..n--.-.p'--- Cornpan!J\ie8J.8Jta;:~~on.'-,,,,-<, ' ---______n- - _n_~c~Qrl1i....__A~71!- n ,--- - Si¡!n,'d- (g f~~-; , '" -- ~r" Phone ---.,.... ..---.. -- .-æQJ.dwgy--_1.42fJ.1_~__--------------------------_. A~ene 8 tÚi~J ~_!I__r1tt .-'!a;r.!n_t.~n~_Il~- --.. -_.._.. ='---1--:;CC:;':CU'IU"-"'- , ¡,..~- ....'¡" 'T "..' ,',,'. , ',' GAL~N;;i-1B:;;;LS;";' .:~ ,-- rŒ~RKS ;.- -:; . ~EC',ANf) 'l'WP,' RA'N,"GB I ~EL,L,I D. S,.D"",A,'"R,.,R"ti3"" , ,.rn,'..."....,.,,',OIL. ",' O",p.',.1,',",'1TY" CU,' ~T. o~ G~8 , OA8úLlNß W ATBR <,Il"',,',"',..'.r.'..(,',,",.f""fdì", UII,ncr. d, el,th; .il8hut down, CMIN: U or ~ No. PaODUOICD' " ' .. (In tnousands) nXCOVF.BJ:P none, so $U.t(\y. at. MIld ~':'~i ~M:!.)r 1(."'°1100 '-'l~--' "I" , ' ._----¡-'-~.._._----_. '.' --.-- 28 8N 19W' I sw sœ ImRÞIT "'..2 36 ,I I, ,<., SW, ì 1 1,1 I D"r"~,led.',",.Þ/.8" ,,','.....,.'.,.'.,.,.,h ou, ',' ',t, O,"3JO" '880,' ., t' 109, S, ., Ie, em, ent ",:"','"',,7,',,.,,," casing at BE. ¡ J.L¡,1880' ,th 700 8.Ck.~rOUnd shoe and UO aaole." ough DV oollar I at b019' ~,'Lan4.d asi ' and reins ailed B PE. Dr ed out DV at , ¡ 60~1~ 'an~tesWd 11th 2 ao p8i. . Ole dou.t t ,,10,832 I . I !' ¡" ,'. ' ,i' I I RCBL -.nd JCt. ot, ive tll hol;s at 10 707' . ',HOT #1, wao I ok. Srot t~ t hOla/toot 10, y'571-10, 62.. , troT #2. )fin. I ¡ ho s 401ll1nu~s ow t~øt. lPloqil clean i1 at a roxiDlate1¡ 9,0 I I B , ona .3/4" bean To11al cut O.3~ (0.2% . + ~.l, .). Corr I I g~it¡ 3.,0 ~¡.t Pre~ur.81 IH16420, I 14700,,12028, rF 3622, I I FS~ 465'~ and PH 6 20 p,io I conhitiOh.d,.'", ho:t,. t 10,*°1., Shot I four f.~.'hOleS/£#,"\",lO,751'-lO,137' I and!-lO, 7e5. -10, 716. ~n bit and þcraper 0 10,77. t i' I ' ' , ¡ Ra2~1~i tuÞ*ng'Wn~ed tubihg .t 10,7$ '. Remo d. BOPE and iI1ß¡ all.rX-ma$ t e. iIIplaced 1d with ~il and t. tested well. IR",',8P¡re8,en,',~,',a, tiv,e, "'.'".,.,£1,,, O"",r,a.t, ="1,, h,our ,f' low p.r~od.28, B~B/,D oil, 134 M, CFy'D gar. 2' ,1/",6".,'".,4' b. sn't.-, P. 600 Pg , 1.6% otal cut (1.4% water. O.2¡ Em.) t Oo-rf"ect d gr ty 34.8 I API. S ut in ? . 1000 psi. ¡ I ¡Rig! rel, ...sed at 6. ' P. . .May 16, 11963. ¡I' ' f I , I co , tJ .~ .<3.5.,,- H. H. 5 18ter I FiShl& Wildltte Sertice - I I St~t., - T.. R. Mars aU J B. HakU.. Ri.,q,hf' "i91d."".. -. , ~w, ,. erry Fuer ~ . R. tter athon- orgeowards U on - H. M Lian , I _1'1 UNITED STATES D£PARTMENT OF THE INTERIOR , GEOLOGICAL SURVEY ~--' --., ..... NOTE.-There were u_..______m____--------------------- runs or sales of oil; --------u_--------,--"-------------'-------- M cu. ft. of ps sold; -----------------------------------____--_n- runs or saleß of gasoline during the month. (Write uno'l where applicable.) NOTH.-Report on this form is required for each calendar month, regardle~s of the sbtus of opera.tions, and mu..~t be tiled in duplicate with the supervisor by thé 6th of t.he succéCding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) . tð-~576&'f1 u. !\.GOVlRHMI!I'IT PRI!HINIJ O'''CE ~" UNITED, STATES D&!PARTMENT OF ,THE 'INTERIOR GEOLOGICAL SURVEY . ~~\1"V\ , DudgcL,ß(.lI"'..~u:r-; Q. 42-1¡;85/).6. ApPfovalexpirllS 12':31""00. ~~ L~¡~D OFFIG~ ,- .~~hO~~~ ,~lJ LEASE ~;UMSEfL.- .~.02~399 ,--' UNIT -~.~_I1.8~n.. ~v4!r"UlÙt -- LESSEE'S MONrrHLY REPORT OF OPERATIONS State ., .. .~J..as~~.._.,-- County JS@~i__~~~~y._¡a ---- .Field - _.u, ---$wa,~~_o~~!~r- 1'he follOll'infl is a correct report: of operations and production (includin~ drillinf! and producing wellsj for the nlOnl It oj' '--H_--..__.__.__j.~r<:~L_____, J9__~.3, ,- ...-.,.- S!àDS°n R1 ver Un! t - ....' "'--"" .r1~entt~ addre88 -- -:p. Q. Bø.~LI--83&m---- p----_.- - .--- C07npany ST~ .O~ .CQ.~ ,.0' CAJ,IJ\.. WOI , ~. '... ----..---....--m-..----- ..._--- ...Anchoraø.__-~,ka- ..- pu -_u---- Signed.. )C."V. cÍlAftlR'l'Otf Phone -------.-----.__,...BB 7...62.Q1---._-----~..--_-----___m_--- umO_- m - .1fjent's title - D:I..etr1c_tSuperinwÐ48at-- 16"ihole ! i to 79.'. I I I i I I .1 í ¡ i ! I I I I I I I ,I i 'I ! U.$.G.~. -f" B. Soys~r (2) StJJ,te - T. . Marabal U.,...,.,.,.,."S. ,ish. Wildl11'e ~..serv1ce B1~hf~ ld -R. R, R1t~er Ie. W. Per MI.,rEL,..,.,.,..',. ';1. n - ,¡;eOl'ge - So'ltards Unto. - B. )1. L1an Files .. P~uc1ng ~trat1on I I cc: ! I I , L ! I Dri1fLing I I ¡ I I ! I I 1 J. B. ~18 ItEÇE\V[Ð ..", ! Î I I Petroleum 8ronch : I 'D1v'~ton of Mines 0' \inerat. \ rAla~a Dept. of Nalu.., .e......... I I -----.. '.- ---- APR ~ ~ 1963 ;, ; i ~ ~ .------ NOTE.-There were --------_--____m_.____------.....---- runs or sales of oil; ----------------..--.....-...--....--.------ M cu. ft. of gas sold; _m______-~--___---_--n__.__------------"-- runs or sal~ of gasoline during the month. (Write "no" where a!Jplicable.) NOTE.-Report on this form is required f6r each calendar month, regardless of the status of operations, and must be filed'~ duplicate with the supervisor by the 6th 'of the. succeeding month, unless otherwise directed by the supervisor, Form 9-329 (January 1950) 16-25766-'8 v' ¡, ¡¡OV£R~o\IIN~ "It!hTI..,, OFFICE \ \ F\)r~1\ P-Î ~ /"" SUBMIT IN D'l ,.éATE- (SN' oth¡>r In- ;~'~~~'~~~~d~~ I 5. API NUMERICAL CODE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Ø"'I']-'./A 6. LEASE DESIGNATION AND SERIAL NO. la, TYP1: WELL COMPLETION OR RECOMPLETION REPORT AND LOG * OIL 0 ~AS 0 w~;LI, WELL DRY 0 Other situ 3I-&e 7. IF INDIAN, ALLOTTEE OR TRiBE NAME b, TYPE OF COMPLETION: :-òEW 0 WELL WORK 0 OYER ~~EP- 0 prx<.; 0 DACK IlIFF. 0 P.ESVR, Other 8. UNIT,FARM OR LEASE NAME 2, NAME OF OPERATOR 9. WELL NO. 3, AODRESS OF OPERATOR 10. FIELD AND POOL, OR WILDCAT 4, LOCA TIO:-; O~- W ELL -(Report-'ocatiOn clearly and in accordance with anll SJate requirement8)- At surface 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) At top prod. interval reported below At total depth 12, PERMIT NO, 9. PLUG,: BACK 16. ELEVATIONS (DF, RKB, R'f, GR, ~C).'17, ELEV. CASINGHEAD 13, DATE SPUDDED 114. DÃTET.t>.REAêHED 115. DATECOMP SUSP,OR ABAND. MD & T\TD 21. ROTARY TOOLS INTER\' ALS DRILLED BY r CAIH.E TOOLS '0832., 22. PRODUCING INTERVAL(S), OF THI;:> COMPLETION-TOP, BOTTOM, NAME (MD AND TVD)* 23. WAS DIRECTIONAL ; SURVEY MADE 24, TYPE ELECTRIC AND OTHER LOGS, RUN 25, CASING RECORD (Report all strings set in wtõH) CASL:.~G SIZE WEIGHT, LB/FT, J GRADE DEPTH SET (MD) HOLE SIZE CE"fL~TlNG RECOHD A:'.fOUNT PULLED 11iiIt 7 ,.1Itð cr"h ,... . 26 LINER RECORD 27. TUBING REGORD SIZE TOP (MD) BOTTOM (:i.VID) SACKS CKHENT* SCIŒEN Ci.vm} SIZE DEPTH SET (MD) ; PACKER SET (l\1D) , . , &7. 1(7~" - 28, PERFORATIONS OP'[;N TO PRODUCTION (Interval, size and number) 2:.1, ACID, SLOT, F;,A::::l URE, CE.i\ŒNT SQUr:~ZE, ETC, ~«lr-'."/~ DEPTH II{TERVAL (MD) Al'dOUN r AND KIND OF MA1E:::lAL USED 10 r'-In-""'" /0717-/6171 DATE OF TEST, PRODUCTION 30. CHO:-<:E SIZE GAS--MCF. WELL STATUS (Producing or :';i1uL-in) DATE FIRST prWDUCTION PRODUCTION MEIHOD (Flowing, g;:,¡" lift, pumping-size and type of pump) FLÒW, TUBING PRES.S. PROD'N FOR TEST P~'RIOD ---. CASING PRESSURE ¡CALCULATED 'OlL-BBL. 21-HOUR RATE . OIL-BDL. GAS-OIL IL\.TIO GAS-MCF. 31. DISPOSITION OF GAS (Sold, uBed for fuel, vented, etc.) 32. LIST OF ATTACH!\IENTS /f éì3, I hereby certify that tbe foregoing and attached information is complete and correct as determined from all ava!lnblr record8 SIGNED .--,D f 6 8"'''°" ~-.,£ "'(See Instructions and Spaces for Additional Data on Reverse Side) TITLE DA TE -1b:-1-k-'3-, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion rppoft èr.d log on all types of lan:Js and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments Items 20, and 22:: If this well is completed for separate prcduction from ¡,nore than one :nterval zone (multiple completion), so state Irì item 20, and in ite'lì :)2 show the prc.Jucl;1Cl intErval, Or Intervals, top(s), bottom(s) and name (s) (if any) for only the intervdl reported in item 30 Submit a sep¿Hate report (paCJe) on this form, adequately identified, for each addilior1òl i!ltel vòl to be seperately rroduce-;i, show- ing the aooitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul.:J show the details of any mul- tiple stage cementing and the location of the cemen ting 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), -_'"...""~ .,';.-, :;; :,:y OF FORMATION TESTS INCLl/DINe; INTErtVAL TESTED, PHESSURE DATA AND RECOVERIES OF OIL. GAS, 35 GOOLOGIC MARKERS WATER AND MUD ---'~''''''''~",'''~'C''''';;'''-~''''''''''-'~''-''''~''''''''' NAME !\IEAS. DEPTIi TRUE V1I:RT, D!:PTH - '" 3/1, émiE DATA, A~lvl'ÃCIl BRIEF DESCRIPITIONS OF LITHOLOGY, POROSITY, FHACTURF.s, APPARENT DIPS AND DETECTED SIIOWS OF 011., GAS on WATEH, ,~ ,~ , 'éfO RIG I N A L úfjJ:r- COMPLETION REPORT - NEW WELL S'rANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPEBATIONS, INe. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area., Alaska. LAND OFFICE: Anchorage Lease No. A-028399 PROPERTY: Swanson R1 ver Unit WELL NO: SRU 34-28 Section 28, Township 8 North, Range 9 West, Seward B&M LOCATION: Surface: 660' North and 1530' West from Southea.st Corner of Section 28. ELEVATION: 184' K.B. DATE: July 3, 1963 BY: ë7"V. DRILIED BY: Rowan Drilling CompaDY, Rig #29 DATE COMMENCED DRILLING: March 30, 1963 DATE OOMPLft.ED DBILLIIiG: . May 16, 1963 DATE OF INITIAL PRODUCTION: May 27, 1963 PRODUCTION: Daily Average 351 BID Oil 350 BID Water 1 BID Gas 61 MCF/D Flowing Gravity TP Bean 34.1° API 500 psi 12/64" SUMMARY TOTAL DEPTH: 10,880 I PLUGS: 10,832 - 10,8801 JUNK: None CASING: 22" cemente~ at 34' 11 3/4" cemented at 20381 7" cemented at 10,8801 -~,~ "'o_~..".. -.., '~""" -"-,.... RtcaVfD" JUt 17 1963 PetrO/eUtn Bron~h Orv,.lon of Mrn.. ond Minerol, ~ Dep,. of Noturor Re,ourCIW ~ '-...., R~a.ease Date 6-16-65 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch Sec. 28 T. ~ ID! 9W R. S. . Meridian Permit No. 63-7 Issued 3-14-63 Operator Standard Oil Co. of Ca1:Uit>cation (Surface) 1530' FEL & 660' FSL, Sec. 28. Lease No. A-02899 or Owner Swanson. &1 ver Un! t INDIVIDUAL WELL RECORD Loc. (Bottom) Well No. 34-28 Spud Date 3-30-63 Suspended Area Swanson Rive~ Drilling ceased 5-16-63 Abandoned Total Depth 1Q#880' Elevation 1 Ria.' 1C. ~. Completed (F-GL-P) 5-21-63 IP ill BID, Grav 34.1 0 API Cut 0.3 % Gas 61 MCF/D, Bean \2 /64 CP Casing: Size Depth Sx Cmt Perf: psi, TP 500 psi .. Plugs I 10,880'-10,832' 22" 34' 10,716" -10.725" 4-%"/ ft. 11 3/4" 2038 ' 1400 10,737' -10,762,' . 4-~tll ft. 1100 DV @ 6016' 7" 10t880' 700 @ shoe - G!OLOGIC FORMATIONS -. Surface , Lowest Teste<\ Name PRODUCTIVE HORIZONS Depth Contents Year Jan Feb Mar AEr WELL STATUS May June July Aug Sept Oct Nov Dee Remarks: Cnnt-r.AC"t:or. Rowan Drilling Company 'fcr 4J:l @ lQ,707' (5 in holes) W..S..O.. HC! #2 10,757'-10,762'. 950 BID rate - 3/4" bean - T.P. 123 psi. 0.3% - 33.9°API . I " .'~' ,...-... WELL RECORD INVENTORY Field: Swanson River Unit loca ti on T8N-R9W~ Sec. 28, S.M. OPI'I'O' , W." Name. Standard Oil Co. Unit ~J34-28 No. Pages 1. Drilling Pe~it: 2. Survey Plat: 3. Month 1y Reports (P-3) : . 4.. Completion Report (P-7) f 5. Well H1stor,y: I ~ 6. Other: L Individual Well Record 7. M1sce11aneous: Total Pages: u ,8. Deviation Survey(s): 9. Well Logs: ill (2) ill ill ill ill ill m ill llitl SL IEL CDM FDL CBND CCL & PR '. . '. " , , . . ¡ ." , . .,,:....... ".'~~ ....~. ..- -&'.." ....) . . . .. -,:, ...'..' ''''.. ,;J (Feb. lJlSl) (suBMIT IN TRIPLICATE) UN ITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTIC~ OF INTE~ ION .TO CHANG~ PLANS ....................... I ...... ~J~E~JE~'T ~ OF ~i0~rli~N~ O~ ~.IDIZIN~ ............... I ..... ................... ~ ................................. ~ ...................................................................... ~ .......... ~. -.,., .... .f-..-I [. ......... (IND~..ATI[ AAOV[ BY Cl4I;CK MARK NA3NJJQE Odr REPOI~T. N43rTICL O~ OTI413q D~TA) SRU Approx. Well No. _~[~.-._2_8_ ....... is located ..____~._ .... ~t. ~rom__ {S}11} line and __!3_~___. ~t. from [~} line d ~c. s...,_.L___~..£__j_~_~_~;.__~_~,. ~ ~. 8 N.~ ~. ~. w. s~~ ~ ~ ~ n., ~ s.. No.) ...... ~ ............ f~$ ...... ' ................................ .~_~pp_..~j_~.n ................. _~A__~c~n~ ........................ A~s~ ............................. (F~) (~y ~ ~i~) (S~ m T~i~) K.B. ~ e]evat~ ~ ~ ~~ve ~ level is .... ~__ ~. Ap~xlmtely DETAI I~ OF WORK lng ~n~ 2. Ins~ll & test Class III Blowout P~ntion Equip~nt. 3. ~lll ~ 10,~0' (est. T.D.), log & ce~nt 7" ~sing. 4. ~cti~ly jet pe~o~te att~ctive ~s & test as neccssa~. 5. ~ 2 7/8" tubing eq~p~d ~th ~cker .. R C IVED' Petroleum Branch Division of~ 'Mines and Minerals ~usk. a _1:)~ ~~~ourc Title ~~,~=iat~~ i]_~,,ks Dist. APPLICATION `EOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL. DEEPEN ❑ PLUG BACK ❑� N^MF. OF COMPANY OR OPERATOR DATE MAR a I'M tamftrd Oil Con Address 0`�f^� P• r Box 7-8 of CaLitorniap Westem iterations, Inc. _ City 'State Anchorage., AUsla�t ! DESCRIPTION OF NVELL AND LEASE Name of lease — number Elevation (ground) ...._.,_ 'IWell S son "028' 8_ 160 # r= Zvell location (give footage from section lines) Section—township—range or block & Survey Approx. 1530' Wo & 6601 * of 8,SR Corner of ?=j• See. 28,j T8X,0 i W, Sevard B . Field & reservoir (If wildcat, so state) County _Sv"soa River Field mlo* Reservoir I Kenai Peninsula Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location to property or lease line: Distance from proposed location to nearest drilling, completed or applied—for well on the same lease: 53U feet « feet Proposed depth. Rot-ary or cable tools Approx. date work will start ', aro`I I �_ — I App=* Aril 5,, 1963 — — _ Number of acres in lease _ _ _ Number of wells on lease, including,* this well, � — completed in or drillings to this reservoir: 16'res' — 6 If lease, purchased with one or more._._....._._---_.._._......__.._....___.___._._._— Name _ ........---......_._........__._.__...._...._._..-_-_.-- Address wells drilled, from whom purchased: Status of bond p -None Kemarks: (If this is an application to deepen or plug back, briefly describe work to be done, givingpresent. producing zone and expected new producing zone) N CERTIFICATE: I, the undersigned, state that I am the ` 6 of the Wes—t=opeati 1W (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Signature "" R CakTUMIN Permit Number: Approval Date: d1v r-. Approved By: 4/41 Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958