Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
188-157
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/10/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260210 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 224-34T 50283202050000 225044 1/30/2026 AK E-LINE Perf T41349 CLU 11RD 50133205590100 225013 1/24/2026 AK E-LINE Perf T41350 CLU 11RD 50133205590100 225013 1/27/2026 AK E-LINE Plug/Perf T41350 KU 24-07RD2 50133203520200 225126 1/14/2026 AK E-LINE CBL T41351 KU 24-07RD2 50133203520200 225126 1/20/2026 AK E-LINE IPFOF T41351 MPI 2-74 50029237850000 224024 1/25/2026 AK E-LINE Whipstock T41352 MPU 1-36 50029236770000 220047 2/1/2026 AK E-LINE Packer T41353 MPU R-110 50029238260000 225085 10/24/2025 YELLOWJACKET RCBL T41354 NFU 14-25 50231200350000 210111 12/29/2025 YELLOWJACKET CBL T41355 SDI 3-15 50029217510000 187094 1/23/2026 AK E-LINE Whipstock T41356 SRU 214A-27 50133101580100 225133 2/4/2026 YELLOWJACKET SCBL T41357 SRU 231-33 50133101630100 223008 7/31/2025 YELLOWJACKET PLUG-PERF T41358 SRU 242-16 50133204050000 188157 1/24/2026 YELLOWJACKET PLUG-PERF T41359 SU 43-10 50133207390000 225107 1/19/2026 YELLOWJACKET GPT-PLUG- PERF T41360 SU 43-10 50133207390000 225107 12/31/2025 YELLOWJACKET SCBL T41360 Please include current contact information if different from above. SRU 242-16 50133204050000 188157 1/24/2026 YELLOWJACKET PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.10 14:51:05 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 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): 4,860' N/A Casing Collapse Structural Conductor Surface 2,020psi Intermediate Production 5,410psi 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 4,830' See Attached Length N/A; N/A N/A; N/A 4,025' 2,903' 2,537' Swanson River Unit (SRU) 242-1620 AAC 25.055(a) Sterling Undefined Gas 4,002'7" ~810psi Swanson River Sterling/Up Beluga Gas December 30, 2025 3-1/2" 4,830' Perforation Depth MD (ft): See Schematic 3,520psi 90'90' 2,337' Size 90' 2,337' MD 16" 9-5/8" 9.3# / J-55 TVD Burst 4,741' 7,240psi 2,119' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028406, FEDA028077 188-157 50-133-20405-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 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 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: 2025.12.22 17:05:43 - 09'00' Noel Nocas (4361) 325-773 By Grace Christianson at 8:03 am, Dec 23, 2025 TS 12/23/25 10-404 BJM 12/30/25 DSR-12/29/25JLC 12/30/2025 12/30/25 Well Prognosis Well: SRU 242-16 Well Name: SRU 242-16 API Number: 50-133-20405-00-00 Current Status: Shut in Gas Producer Permit to Drill Number: 188-157 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) (907) 564-4506 (O) Maximum Expected BHP: 1048 psi @ 2380 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 810 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.65 psi/ft using 12.5 ppg EMW FIT 9-5/8 shoe (8/22/89) Shallowest Allowable Perf TVD: MPSP / (0.65 - 0.1) = 810 psi / 0.55 = 1473 TVD Top of Sterling / Upper Beluga Gas Pool & PA: 2841 MD / 2490 TVD Recent Well Summary: SRU 242-16 has been perforated up to the top of the Sterling - Upper Beluga Gas Pool / PA. The well was most recently perforated in the Sterling A9 sands in September 2021. The well came on production at ~2.5-3 mmcfd before gradually declining and ceasing to sustain gas production in July 2023. The purpose of this Sundry is to plug and isolate the Sterling Upper Beluga Gas Pool / PA and perforate the Sterling A7 sand. The Sterling A7 interval is above the defined top of the Sterling Upper Beluga Gas Pool / PA. Regulatory The Sterling A7 is a shallower sand above (outside of) the currently permitted Sterling / Upper Beluga Gas Pool defined in CO 716A dated October 19, 2023, governing the Swanson River Field. Rule 2.a. Sterling / Upper Beluga Gas Pool: 2,338 MD 4,609 MD in the SOLDOTNA CK UNIT 341-04 (API No. 501331010900). In the absence of an order establishing units or prescribing spacing, statewide spacing rules apply (20 AAC 25.055.(a): (2) for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 of a property line only if the owner is the same and the landowner is the same on both sides of the line. (4) Inter-well spacing was eliminated via Industry Guidance Bulletin 22-002 dated 10/05/2022. The attached map depicts the anticipated productive interval of the wellbore to be more than 1,500 from a property line with dissimilar owners and landowners, and as such, an exception 20 AAC 25.055 unnecessary. Top: Sterling A7 2,681 MD (2,372 TVD) Bottom: Sterling A7 2,691 MD (2,380 TVD) SRU 12-15 Pad is situated on KPB Parcel No. 02508005, managed by the U.S. Fish & Wildlife Service. Surface operations are granted by Section 1 of Federal OGL A-028406 (SRU Tr. 18), dated September 1, 1956. Well Prognosis Well: SRU 242-16 Procedure: 1. MIRU Eline. 2. PT lubricator to 250 psi low / 2,000 psi high 3. RIH and set 3-1/2 CIBP at + 2727 MD a. Recent slickline diagnostics on 12/5/2025 tagged fill at 2732. 4. Dump bail a minimum of 10 of cement on top of CIBP leaving TTOC at + 2717 MD. a. AOGCC regulation 20 AAC 25.112.(c).(1).(E) requires CIBP to be set within 50 of perforations and a minimum of 25 cement to be dump bailed on top of plug. Hilcorp is requesting a variance to set CIBP greater than 50 above top perforation due to recent fill tag depth above perforations and dump bail 10 of cement on top of plug to ensure room above to perforate planned A7 interval. b. BLM regulation CFR 3172.12.(a).(2).(i) and CFR 3172.12.(a).(2).(iii) requires CIBP to be set within 50 - 100 of perforations and a minimum of 35 cement to be dump bailed on top of plug. Hilcorp is requesting a variance to set CIBP greater than 50 - 100 above top perforation due to recent fill tag depth above perforations and dump bail 10 of cement on top of plug to ensure room above to perforate planned A7 interval. 5. Tag TOC w/ E-line and pressure test CIBP + cement to verify plug placement and integrity for isolation of the Sterling Upper Beluga Gas Pool / PA. a. Provide a minimum of 24 hr notice to AOGCC for witness of tag and pressure test b. If fluid is used for pressure test, pressure test to 2000 psi for 30 min (chart results using a chart recorder or digital crystal gauge). c. If gas is used for pressure test to 2000 psi i. Use a chart recorder or digital crystal gauge monitor for a minimum of 72 hours ii. Criteria for a passing test being a time of 72 hours showing stabilization and less than 2% drop of the maximum test pressure over the 72 hour test period. iii. IA pressure must be monitored over the duration of the test period. iv. 72 hour test will start once pressure stabilizes. 6. RIH and perforate the following sand: Well Sand MD top MD Bottom TVD top TVD bottom Interval SRU 242-16 A7 2,681 2,691 2,372 2,380 10 a. Correlate using log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record tubing pressures before and after perforating run at 5 min, 10 min, and 15 min intervals post perf shot. 7. RDMO and turn well over to production operations. Contingency Procedure: Coiled Tubing Cleanout 1. If throughout the job the current or proposed interval(s) produce sand and / or water that cannot be depressed and pushed away with nitrogen or pad gas, a coil tubing unit may be rigged up to clean out fill or fluid blown down as necessary. a. MIRU Fox CTU, PT BOPE to 250 psi low / 2000 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Variance approved. -bjm If gas is used, apply 2700 psi test pressure to ensure 1500 psi differential across the plug -bjm Well Prognosis Well: SRU 242-16 Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure N2 Operations 5. Map SRU 242-16 Updated BY RPL 12/15/2025 SCHEMATIC Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00-00 1 PBTD = 2,903 MD 2,537 TVD TD = 4,860' MD - 4,025 TVD Original RKB = 26.0' CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8rd 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 2,903 3-1/2 CIBP 9/14/21 3 3,058 3-1/2 CIBP w/ 36 of cement TOC 3,022 9/11/19 4 3,645 3-1/2 CIBP w/ 35 of cement 04-02-19 5 3,796 AD2 Stop @ 3,793, Macco Pack-off @ 3,795, G Stop @ 3,796 6 4,012 AD2 Stop @ 4,015, Macco Pack-off @ 4,013, G Stop @ 4,012 7 4,313 A Stop @ 4,316, Macco Pack-off & G Stop @ 4,313 8 4,734' 3.00" Halliburton Super Seal Float Collar 9 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Baker Shear Out Plug and 1-1/2 gaslift valves PERFORATIONS DETAIL Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-9U 2,848 2853 2,496 2,499 9/18/21 Open A-9L 2,888 2,894 2,525 2,530 9/18/21 Open A-10 2,908 2,928 2,540 2,560 9/12/19 Isolated 9/14/21 A-11 3,078 3,080 2,667 2,668 4/11/19 Isolated 9/11/19 B-0 3,344 3,370 2,865 2,885 7/19/95 Squeezed B-1 3,407' 3,427' 2,912 2,927 7/19/95 Squeezed B-2 3,454' 3,464 2,947 2,955 7/19/95 Squeezed B-3L 3,664 3,671 3,106 3,111 4/12/09 Isolated B-4 3,715 3,725 3,143 3,151 8/28/14 Isolated B-4 3,723' 3,753' 3,150 3,173 7/19/95 Isolated B-5 3,816 3,824 3,221 3,227 8/27/06 Isolated B-6 4,064 4,066 3,410 3,412 8/23/03 Isolated Beluga 4,684 4,696 3,889 3,898 7/24/95 Isolated 8 9 A 7 6 TOF @ 4,092 Fill @ 3,745 5 16 9-5/8 7 Max hole angle = 44 @ 2,100 B-2 B-1 B-0 Calc TOC @ 1,398 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2 Bowen Lift Threads: 3-1/2 8RD WELL DATA A-11 4 TOC @ 3,022 3 A-10 2 A-9 Beluga TOC @ 4,260 B-6 TOC @ 3,967 B-5 TOC @ 3,759 B-4 B-3L TOC @ 3,610 04/02/19 TOC @ 2,590 Fill @ 2732 Updated BY RPL 12/15/2025 SCHEMATIC Proposed Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00-00 1 PBTD = 2,903 MD 2,537 TVD TD = 4,860' MD - 4,025 TVD Original RKB = 26.0' CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8rd 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 + 2,727 3-1/2 CIBP + 10 Cement (Proposed) 3 2,903 3-1/2 CIBP 9/14/21 4 3,058 3-1/2 CIBP w/ 36 of cement TOC 3,022 9/11/19 5 3,645 3-1/2 CIBP w/ 35 of cement 04-02-19 6 3,796 AD2 Stop @ 3,793, Macco Pack-off @ 3,795, G Stop @ 3,796 7 4,012 AD2 Stop @ 4,015, Macco Pack-off @ 4,013, G Stop @ 4,012 8 4,313 A Stop @ 4,316, Macco Pack-off & G Stop @ 4,313 9 4,734' 3.00" Halliburton Super Seal Float Collar 10 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Baker Shear Out Plug and 1-1/2 gaslift valves PERFORATIONS DETAIL Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A7 2,681 2,691 2,372 2,380 Proposed Proposed A-9U 2,848 2853 2,496 2,499 9/18/21 Isolate A-9L 2,888 2,894 2,525 2,530 9/18/21 Isolate A-10 2,908 2,928 2,540 2,560 9/12/19 Isolated 9/14/21 A-11 3,078 3,080 2,667 2,668 4/11/19 Isolated 9/11/19 B-0 3,344 3,370 2,865 2,885 7/19/95 Squeezed B-1 3,407' 3,427' 2,912 2,927 7/19/95 Squeezed B-2 3,454' 3,464 2,947 2,955 7/19/95 Squeezed B-3L 3,664 3,671 3,106 3,111 4/12/09 Isolated B-4 3,715 3,725 3,143 3,151 8/28/14 Isolated B-4 3,723' 3,753' 3,150 3,173 7/19/95 Isolated B-5 3,816 3,824 3,221 3,227 8/27/06 Isolated B-6 4,064 4,066 3,410 3,412 8/23/03 Isolated Beluga 4,684 4,696 3,889 3,898 7/24/95 Isolated 9 10 A 8 7 TOF @ 4,092 Fill @ 3,745 6 16 9-5/8 7 Max hole angle = 44 @ 2,100 B-2 B-1 B-0 Calc TOC @ 1,398 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2 Bowen Lift Threads: 3-1/2 8RD WELL DATA A-11 5 TOC @ 3,022 4 A-10 3 A-9 Beluga TOC @ 4,260 B-6 TOC @ 3,967 B-5 TOC @ 3,759 B-4 B-3L TOC @ 3,610 04/02/19 TOC @ 2,590 Fill @ 2732 A-7 2 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Swanson River Unit BHL Sterling A7Tr. 2 A-028077 Tr. 18 A-028406 Tr. 6 A-028384 Tr. 17 A-028405 SHL 2025-1022_Well_SRU_242-16_ksj Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10/22/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Well Inspection Petroleum Inspector Swanson River Unit 242-16 Hilcorp Alaska LLC PTD 1881570 10/22/25: Travel to Swanson River Unit SRU 242-16 and met with Tad Covault (Hilcorp Lead Operator). Hilcorp sent in notification for a suspended well inspection on 10/17/2025. When I arrived, I asked for suspended well documents and they did not have anything showing it being suspended well. After Tad had talked with field foreman they figured out that SRU-242-16 was not in suspended well status but was a shut in status. They were confused that it required a BLM notification and inspection, not AOGCC. I visually checked the well and surroundings since I was at location and found no issues. All gauges worked and tubing, IA and OA pressures were 0, 120, and 60 psi, respectively. No follow up needed. Attachments: None 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: ______________________ 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: 2,903; Total Depth measured 4,860 feet 3,022 & 3,610 feet true vertical 4,025 feet N/A feet Effective Depth measured 2,903 feet N/A feet true vertical 2,537 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / J-55 4,741' MD 3,933' TVD Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 321-441 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 843 Todd Sidoti, Operations Engineer todd.sidoti@hilcorp.com 907-777-8443Dan Marlowe, ASC Team Operations Manager, 907-283-1329 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 1202,892 0 320 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 90' 2,337' 120 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-157 50-133-20405-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028406, FEDA028077 Swanson River Field / Sterling & Upper Beluga Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Swanson River Unit (SRU) 242-16 measuredPlugs Junk measured N/A Length 90' 2,337' Size Conductor Surface Intermediate 16" 9-5/8" Production Liner 4,830' Casing 90' 2,119' 4,002'4,830'7"5,410psi 3,520psi 7,240psi Burst Collapse 2,020psi t Fra O O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 2:49 pm, Oct 22, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.10.22 12:27:32 -08'00' Dan Marlowe (1267) RBDMS HEW 10/22/2021 DSR-10/25/21SFD 10/25/2021BJM 10/28/21 Updated BY CRR 10-22-21 SCHEMATIC Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00-00 1 PBTD = 2,903’ MD – 2,537’ TVD TD = 4,860' MD - 4,025’ TVD Original RKB = 26.0'CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7” 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8 rd 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26’ 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 2,903 3-1/2” CIBP 9/14/21 3 3,058’ 3-1/2” CIBP w/ 36’ of cement – TOC 3,022’ 9/11/19 4 3,645’ 3-1/2” CIBP w/ 35’ of cement 04-02-19 5 3,796’ “AD2” Stop @ 3,793’, Macco Pack-off @ 3,795’, “G” Stop @ 3,796’ 6 4,012’ “AD2” Stop @ 4,015’, Macco Pack-off @ 4,013’, “G” Stop @ 4,012’ 7 4,313’ “A” Stop @ 4,316’, Macco Pack-off & “G” Stop @ 4,313’ 8 4,734' 3.00" Halliburton Super Seal Float Collar 9 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Baker Shear Out Plug and 1-1/2” gaslift valves PERFORATIONS DETAIL Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-9U 2,848’ 2853’ 2,496’ 2,499’ 9/18/21 Open A-9L 2,888’ 2,894’ 2,525’ 2,530’ 9/18/21 Open A-10 2,908’ 2,928’ 2,540’ 2,560’ 9/12/19 Isolated 9/14/21 A-11 3,078’ 3,080’ 2,667’ 2,668’ 4/11/19 Isolated 9/11/19 B-0 3,344’ 3,370’ 2,865’ 2,885’ 7/19/95 Squeezed B-1 3,407' 3,427' 2,912’ 2,927’ 7/19/95 Squeezed B-2 3,454' 3,464’ 2,947’ 2,955’ 7/19/95 Squeezed B-3L 3,664’ 3,671’ 3,106’ 3,111’ 4/12/09 Isolated B-4 3,715’ 3,725’ 3,143’ 3,151’ 8/28/14 Isolated B-4 3,723' 3,753' 3,150’ 3,173’ 7/19/95 Isolated B-5 3,816’ 3,824’ 3,221’ 3,227’ 8/27/06 Isolated B-6 4,064’ 4,066’ 3,410’ 3,412’ 8/23/03 Isolated Beluga 4,684’ 4,696’ 3,889’ 3,898’ 7/24/95 Isolated 8 9 A TOC @ 4,260’ B-6 7 B-5 6 TOF @ 4,092’ TOC @ 3,967’ B-3L TOC @ 3,759’Fill @ 3,745’ 5 Beluga 16” 9-5/8” 7” Max hole angle = 44q @ 2,100’ B-4 B-2 B-1 B-0 Calc TOC @ 1,398’ Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2” Bowen Lift Threads: 3-1/2” 8RD WELL DATA B-4 A-11 4 TOC @ 3,610’ 04/02/19 TOC @ 3,022’ 3 A-10 2 A-9 A-9U 2,848’ 2853’ 2,496’ 2,499’ 9/18/21 Open A-9L 2,888’ 2,894’ 2,525’ 2,530’ 9/18/21 Open Rig Start Date End Date E-Line 9/14/21 9/18/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 242-16 50-133-20405-00-00 188-157 09/18/2021 - Saturday Crew arrives at SRU. Permits, JSA, Job scope. Before rig up we had to clear some equipment/tanks from around well head. Rig up E-line. PT 250/2,500. RIH W/ 2-3/8" x 6' Razor 5 SPF, 60 degree. Make correlation pass. Send to town, -1' correction, Spot and shoot 2,888'-2,894' W/~850 psi WHP. Good indication, pressure spikes to ~900 psi. POOH Pre: 840psi, shots: 900psi, 5 min: 945psi 10 min:960, 15 min:975. E-line standby for production to flow well. flowing ~1mmcf @ ~905 psi. Town decides to shoot next gun. RIH W/ 2-3/8" x 5' Razor 5 SPF, 60 degree. Make correlation pass. Send to town. -1' correction, Spot and shoot 2,848'- 2,853'. Good indication. WHP stays ~900 psi. POOH. OOH, monitor pressure. Rig down E-line. Slowly increase production to ~3mmcf @ ~880psi monitor for night. E-line crew signs out, leaves facility. 09/14/2021 - Tuesday Crew arrives at facility. TGSM, Permits, JSA. Spot E-line. Begin rig up. PT 250/2,000psi. RIH W/ 2.75'' (3-1/2'') CIBP to 2,885'. Make Correlation Pass. Send to town. No shift required. Spot and set plug at 2,903'. (No cement on plug.). Rig down E-line. Sign out leave facility. Daily Operations: Spot and shoot 2,888'-2,894' W Spot and shoot 2,848'- 2,853'. G Spot and set plug at 2,903'. 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: W hat Regulation or Conservation Order governs well spacing in this pool? W ill planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,860'N/A Casing Collapse Structural Conductor Surface 2,020psi Intermediate Production 5,410psi 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.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 4,025'3,022'2,625'900 3,645', 3,058' Cement / N/A ~1,398' / N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028406, FEDA028077 188-157 50-133-20405-00-00 Swanson River Unit (SRU) 242-16 Swanson River Field / Sterling & Upper Beluga Length Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / J-55 TVD Burst 4,741' 7,240psi MD 3,520psi 90' 2,119' 90' 2,337' 4,002'7" 16" 9-5/8" 90' 2,337' 4,830' Perforation Depth MD (ft): See Attached Schematic 4,830' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 14, 2021 3-1/2" Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:18 pm, Sep 01, 2021 321-441 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.01 12:30:31 -08'00' Taylor Wellman (2143) SFD 9/1/2021 CO 716 and 10-404 DLB 09/01/2021 X DSR-9/9/21BJM 9/9/21 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 15:11:53 -08'00' RBDMS HEW 9/13/2021 Well Prognosis Well: SRU 242-16 Date: 8-31-2021 Well Name: SRU 242-16 API Number: 50-133-20405-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 9/14/21 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 188-157 First Call Engineer: Todd Sidoti (907) 777-8443 (O)(907) 632-4113 (M) Second Call Engineer: Jake Flora (907) 777-8442 (O)(720) 988-5375 (M) AFE Number: Max. Expected BHP: ~1,145 psi @ 2,530’ TVD (Based on normal pressure gradient) Max. Potential Surface Pressure: ~900 psi (Based on expected BHP and gas gradient to surface (0.1 psi/ft)) Brief Well Summary Well Spudded August 1989, TD @ 4860’ MD. Completed in B3, B1, A15, A14. Commingled IP ~6MMCFD. In August 1994 found well full of fill during drift for B3 WSO. Set plug, but didn’t shut off ~150 BPWD. Water increased to ~1000 BWPD by mid-1995. July 1995 workover to clear tubing, replace and cement tubing to shut off Sterling, and perf Beluga. Shot 36-9AX. IP = 1.3MMCFD with no water; rate increased to 3MMCFD in a year. Held steady ~2MMCFD until 2003. Zone produced water starting in 2001. August 2003 encountered fill @ 4350’ MD during recomplete. Seems that 36-9AX prematurely abandoned due to fill. Plugged back 36-9AX, shot B6L. IP = 3.7MMCFD, no water. July 2006 B6 watered out. (500 BWPD production started late 2004.) Cum’d 2.87BCF. August 2006 Plugged back B6L, shot B5. IP = 3MMCFD, no water. Jan 2009 B5 watered out @ 600 BWPD / 300MCFD. April 2009 plugged back B5, shot B2L. IP = 600MCFD, no water. August 2014 shot B3 with B2L still open. IP = 3MM, no water (initially). Two zones followed a nice decline for the next four years. Periodic water production, but never more than 75BWPD. Died @ 500 MCFD with no water. Zone depleted? Tubing pressure <200#. April 2019 plugged back B3/B2L, shot A11. IP = 1.5MM, 600 BWPD. Last five months. Water loaded? Sept 2019 plugged back A11, shot A10. IP = 2.6MM, up to ~1000 BWPD by early 2020. August 2020 A10 declined to ~800MCF with 800 BWPD. Dec 2020 SI so SRU 12-15 could use flowline. This was the worst well in the area and 12-15 was strong. June 2021 brought back online, twinned with 12-15. IP’d ~2.5MMCFD (based on differential production) but then 12-15 started making sand. After battling them a little, decided that two wells did not play together nicely and to SI low-rate 241-16 to give 242-16 a change to unload and produce independently. Came online ~2MMCFD but quickly died. August 2021 found fluid level @ 800’ MD and fill in the well. Now that new flowline installed to TS 2-15, ops able to work to get 242-16 happy. Once sand buster and spool piece issues sorted out, online ~1MMCFD with lots of water and sand. Never able to find stable place to flow well. Facility is very water limited and has no spare pumps; sand from 242-16 puts pumps at risk. Need to SI. Objective Clean out to and plug back A10 and perforate A9. BLM Variance Request Due to the close proximity of perforation intervals, Hilcorp is requesting a variance to BLM Onshore Order #2 Section G, 2, iii. Hilcorp requests to set a CIBP at 2903’ for isolation. Notes Regarding Wellbore Condition x Well is currently producing about 418 MCFD / 1495 BWPD Slickline Well Prognosis Well: SRU 242-16 Date: 8-31-2021 1. 2-3/8” Dummy gun drift and tag to PBTD. 2. Bail sand if necessary to 2,920’ E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH with CIBP and set at 2,903’. 3. Pressure up on well with gas lift to 1000 psi prior to perforating in order to prepare for underbalanced perforating. 4. RIH and perforate the following intervals with 2-3/8” HSD guns loaded at 5 SPF with gas charges: Sand TOP MD BOT MD Total TOP TVD BOT TVD Est Pressure Sterling A9_Mid 2848 2853 5 2496 2499 1128 Sterling A9_Lower 2888 2894 6 2525 2530 1141 a. Final perfs tie-in sheet will be provided in the field for exact perf intervals. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer and Geologist for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. d. All perforations in table above are located in the Sterling/Upper Beluga Gas Pool based on Conservation Order 716.001. 2. RDMO E-line. 3. Turn well over to production. Contingent Procedure: If zone produces water and needs to be isolated 1. RIH with GPT and determine fluid level. 2. Depress fluid into perforations with GL gas. 3. Set CIBP above zone. 4. Dump bail 35’ of cement on plug. Attachments 1.Current Schematic 2.Proposed Schematic Updated BY DMA 09-18-19 SCHEMATIC Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00-00 1 PBTD = 3,022’ MD – 2,625’ TVD TD = 4,860' MD - 4,025’ TVD Original RKB = 26.0' CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7” 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8rd 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26’ 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 3,058’ 3-1/2” CIBP w/ 36’ of cement – TOC 3,022’ 9/11/19 3 3,645’ 3-1/2” CIBP w/ 35’ of cement 04-02-19 4 3,796’ “AD2” Stop @ 3,793’, Macco Pack-off @ 3,795’, “G” Stop @ 3,796’ 5 4,012’ “AD2” Stop @ 4,015’, Macco Pack-off @ 4,013’, “G” Stop @ 4,012’ 6 4,313’ “A” Stop @ 4,316’, Macco Pack-off & “G” Stop @ 4,313’ 7 4,734' 3.00" Halliburton Super Seal Float Collar 8 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Baker Shear Out Plug and 1-1/2” gaslift valves PERFORATIONS DETAIL Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-10 2,908’ 2,928’ 2,540’ 2,560’ 9/12/19 Open A-11 3,078’ 3,080’ 2,667’ 2,668’ 4/11/19 Isolated 9/11/19 B-0 3,344’ 3,370’ 2,865’ 2,885’ 7/19/95 Squeezed B-1 3,407' 3,427' 2,912’ 2,927’ 7/19/95 Squeezed B-2 3,454' 3,464’ 2,947’ 2,955’ 7/19/95 Squeezed B-3L 3,664’ 3,671’ 3,106’ 3,111’ 4/12/09 Isolated B-4 3,715’ 3,725’ 3,143’ 3,151’ 8/28/14 Isolated B-4 3,723' 3,753' 3,150’ 3,173’ 7/19/95 Isolated B-5 3,816’ 3,824’ 3,221’ 3,227’ 8/27/06 Isolated B-6 4,064’ 4,066’ 3,410’ 3,412’ 8/23/03 Isolated Beluga 4,684’ 4,696’ 3,889’ 3,898’ 7/24/95 Isolated 7 8 A TOC @ 4,260’ B-6 6 B-5 5 TOF @ 4,092’ TOC @ 3,967’ B-3L TOC @ 3,759’ Fill @ 3,745’ 4 Beluga 16” 9-5/8” 7” Max hole angle = 44q @ 2,100’ B-4 B-2 B-1 B-0 Calc TOC @ 1,398’ PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2” Bowen Lift Threads: 3-1/2” 8RD WELL DATA B-4 A-11 3 TOC @ 3,610’ 04/02/19 TOC @ 3,022’ 2 A-10 Updated BY TCS 08-31-21 PROPSED SCHEMATIC Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00-00 10 PBTD = 2,903’ MD – 2,537’ TVD TD = 4,860' MD - 4,025’ TVD Original RKB = 26.0' CASING AND TUBING DETAIL Size Wt Grade Conn ID Top Btm 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7” 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8rd 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 10 26’ 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 9 2903’ 3-1/2” CIBP – xx/xx/xx 8 3,058’ 3-1/2” CIBP w/ 36’ of cement – TOC 3,022’ 9/11/19 7 3,645’ 3-1/2” CIBP w/ 35’ of cement 04-02-19 6 3,796’ “AD2” Stop @ 3,793’, Macco Pack-off @ 3,795’, “G” Stop @ 3,796’ 5 4,012’ “AD2” Stop @ 4,015’, Macco Pack-off @ 4,013’, “G” Stop @ 4,012’ 4 4,313’ “A” Stop @ 4,316’, Macco Pack-off & “G” Stop @ 4,313’ 3 4,734' 3.00" Halliburton Super Seal Float Collar 2 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe 1 Unknown Baker Shear Out Plug and 1-1/2” gaslift valves PERFORATIONS DETAIL Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-9U 2848 2853 2496 2499 A-9L 2888 2894 2525 2530 A-10 2,908’ 2,928’ 2,540’ 2,560’ 9/12/19 Open A-11 3,078’ 3,080’ 2,667’ 2,668’ 4/11/19 Isolated 9/11/19 B-0 3,344’ 3,370’ 2,865’ 2,885’ 7/19/95 Squeezed B-1 3,407' 3,427' 2,912’ 2,927’ 7/19/95 Squeezed B-2 3,454' 3,464’ 2,947’ 2,955’ 7/19/95 Squeezed B-3L 3,664’ 3,671’ 3,106’ 3,111’ 4/12/09 Isolated B-4 3,715’ 3,725’ 3,143’ 3,151’ 8/28/14 Isolated B-4 3,723' 3,753' 3,150’ 3,173’ 7/19/95 Isolated B-5 3,816’ 3,824’ 3,221’ 3,227’ 8/27/06 Isolated B-6 4,064’ 4,066’ 3,410’ 3,412’ 8/23/03 Isolated Beluga 4,684’ 4,696’ 3,889’ 3,898’ 7/24/95 Isolated 3 2 1 TOC @ 4,260’ B-6 4 B-5 5 TOF @ 4,092’ TOC @ 3,967’ B-3L TOC @ 3,759’ Fill @ 3,745’ 6 Beluga 16” 9-5/8” 7” Max hole angle = 44q @ 2,100’ B-4 B-2 B-1 B-0 Calc TOC @ 1,398’ PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2” Bowen Lift Threads: 3-1/2” 8RD WELL DATA B-4 A-11 7 TOC @ 3,610’ 04/02/19 TOC @ 3,022’ 8 A-10 9 ... 3 1 Il STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION !..9 n j. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations ✓ Fracture Stimulate Li Pull Tubing Ll Operations shutdown Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casin g ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: `, ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory Ell Service ❑ 188-157 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20405-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406, FEDA028077 Swanson River Unit (SRU) 242-16 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field - Sterling/Upper Beluga Gas 11. Present Well Condition Summary: Total Depth measured 4,860 feet Plugs measured 3,022 & 3,610 feet true vertical 4,025' feet Junk measured N/A feet Effective Depth measured 3,022 feet Packer measured N/A feet true vertical 2,625 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 16" 90' 89' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,830' 7" 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / J-55 4,741' MD 3,933' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 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 0 100 0 Subsequent to operation: 0 1134 0 100 940 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 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 Lj Gas ✓ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-373 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: AMMa rna.hilcoro.com Authorized Signature: "/ �_ Date: d LtS lc Contact Phone: 777-8420 Form 10404 Revised 4/2017(((/ OCT 0 7 2019 Submit Original Only (l /o 7 .,SRBpMs Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Start Date End Date SRU 242-16 E-Line 1 50-133-20405-00 188-157 9/11/19 1 9/12/19 Daily Operations: 09/11/2019- Wednesday Sign in. Mobe to location. Spot Equipment. PTW and JSA. Rig up lubricator. PT to 250 psi low and 1,500 psi high. TP - 950 psi. Field put gas from field gas line to well and it broke over around 1700 psi and well was shut in at 1,100 psi this morning. RIH w/GPT tool and 3.80" gauge ring and tie into pert log. Tagged at 3,079' (pert zone that is open 3,078' to 3,080') and didn't see any fluid level. Run correlation log and send to town. POOH. Town said we were on depth. RIH w/ 2.75" OD CIBP and tie into GPT Log. spotted and set plug at 3,058'. Lost 150 lbs line tension when set. Pick up 30' and go back and tag plug. POOH. Good set. Had 900 psi on tubing when plug was set. RIH w/ 2-1/2" x,30' dump bailer loaded with 6.35 gals of 17 ppg cement (17.5') and dump cement on top of plug. POOH. Good dump. RIH w/ 2-1/2" x 30' dump bailer loaded with 6.35 gals of 17 ppg cement (17.5') and dump cement on top of cement. POOH. Good dump. (35' of cement total). Est TOC - 3,023' and CID - 1630 hrs. Rig down lubricator and secure the well. We will be back around Noon tomorrow to perforate. That would give us 18 hrs on cement and also construction said they would be clear around noon tomorrow. TP - 900 psi. 09/12/2019 - Thursday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. Kinked line picking up tools. R-Head line. Arm gun. PT lubricator to 250 psi low and 1,500 psi high. TP 950 psi. Bleed pressure to 500 psi for perf pressure. RIH w/ 2-3/8" x 20' HC, 5 spf, 60 deg phase and tie into GPT log. Tag cement at 3,022' (36' cement on top of plug). Run correlation log and send to town. Get ok to perf from 2,908' to 2,928' with 500 psi on well. Fired gun and was blown up hole and pressure went from 500 psi to 950 psi in approx. 1 min. Pull on line and felt a few knots in line pull free. Never pulled over what it took to pull out of rope socket. We left approx. 15' of wireline and the tools in well. They pulled bout 500 lbs over watching the line slip by the tools. Rig down lubricator and secure well. Slick line will be out in the morning to fish tools. IThey have to use AKE-Line crane and lubricator. Swanson River Unit Well: SRU242-16 SCHEMATIC Completion Ran: Ran: 4/12/09 PTD: 188-157 mlcu"" llA.kA, ta.r. API: 50-133-20405-00-00 Original RKB = 26.0' CASING AND TUBING DETAIL f Size Wt Grade Coii nn ID Top Btm 16" Conduct. Surf. go- -5/8" 36 1-55 8921" Surf. 2170' 16' _ A_c is 9-5/8', TOC @ �- I Zb N-80 I Buttress 6184" Surf 4830' TUBING DETAIL 9.3 J-55 EUE 8'd 2.992" Surf 4,741' Calc TOC @ 1,398' JEWELRY DETAIL B-0 ` Depth 26' ID 2.992" Item 7-1/16"x3-1/2"FMC ST/Bore Tbg Hanger (EUE Srd)3,058' B-1 e Comments 3-1/2"CIBP w/36'of cement -TOC 3,022' 9/11/193,645' B-2 2,540' 3-1/2"CIBP w/35'of cement 04-02-19 Open 4-11 3 B4 Fill @ 3, TOF IC @ 3,610' 04/02/19 B-3 L B-4 TOC @ 3,759' 4 B-5 TOC @ 3,967' ;I WF B-6 TOC @ 4,260' G I Beluga PFPFr1PATInK1< IICTAII Zone Depth 26' ID 2.992" Item 7-1/16"x3-1/2"FMC ST/Bore Tbg Hanger (EUE Srd)3,058' Btm (W7/19/95Soueezpd e Comments 3-1/2"CIBP w/36'of cement -TOC 3,022' 9/11/193,645' J43,796' 2,540' 3-1/2"CIBP w/35'of cement 04-02-19 Open 4-11 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796'4,012' 2,667' 2,619 "AD2" Stop @ 4,015', Macco Pack -off @ 4013' "G' Stop @ 4,012'4,313' Isolated 9/11/19 B-0 3,344'0' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313'4,734' 2,865' 2,895 3.00" Halliburton Super Seal Float Collar 8 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Squeezed Baker Shear Out Plug and 1-1/2" gaslift valves IC @ 3,610' 04/02/19 B-3 L B-4 TOC @ 3,759' 4 B-5 TOC @ 3,967' ;I WF B-6 TOC @ 4,260' G I Beluga PFPFr1PATInK1< IICTAII Zone Top (MD) D) Top(TVD) Btm (W7/19/95Soueezpd e Comments A-30 2,908'8' 2,540' 2,5/19 Open 4-11 3,078'0' 2,667' 2,619 Isolated 9/11/19 B-0 3,344'0' ;3,671" 2,865' 2,895 Squeezed B-1 3,407'7' 2,912' 2,995 Squeezed B-2 3,454' 4' 2,947' 2,995 Squeezed B -3L 3,664' 3,106' 3,109 IsolatedB-4 3715' 3,725' 3,143' 3,158/28/14 Isolated B-4 3,723' 3,753' 3,150' 3,173' 7/19/95 Isolated B-5 3,816' 3,824' 3,221' 3,227' 8/27/06 Isolated B-6 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated Beluga 4,684' 4,696' 3,889' 3,898' 7/24/95 Isolated 7 i e s' 7" PBTD =3,022' MD -2,625' TVD Max hole angle = 44° @ 2,100' TD = 4,860' MD - 4,025' TVD PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated BY DMA 09-18-19 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 242-16 Permit to Drill Number: 188-157 Sundry Number: 319-373 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this � F of August, 2019. RBDMS / AUG 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0I41JeTOWAVIRM VVED AUG 14 2019 1. Type of Request: Abandon ❑ Plug Perforations Q . 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: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ . Stratigraphic ❑ Service ❑ 188-157 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20405-00-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 716, 716.1 Will planned perforations require a spacing exception? Yeo No I] Swanson River Unit (SRU) 242-16 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406, FEDA028077 Swanson River Field - Sterling/Upper Beluga Gas ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,860' 4,025' 3,610' 3,065' 845 3,610' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 16" 90' 90' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,830' T 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/J-55 4,741' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 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: 8/30/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: CiWO ood hilco .CORI i- �t Contact Phone: 777-8443 2 b 1 `� Authorized Signature: Date: �4 � COMMISSIOWLISE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L✓• Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS AUG 9 2019 t Initial Injection MIT Req'd? Yes E]1 No ❑ `/ cJ Ing Exception Required? Yes ❑ NoC> -� /d Subsequent Form Required: ' APPROVED BY 1 by: COMMISSIONER THE COMMISSION Date: J iii J /1 /L7ti7� Su' 1 5 1J1 Sub in Duplicate and m 10-4�RI vised 4/2017 � Approved applic�n 5�9iWY' 12 it l l�r� the date of approval. �j Atlachments�oupllcate H Hilcorp Alaska, M Well Prognosis Well: SRU 242-16 Date: 8/12/2019 Well Name: SRU 242-16 API Number: 50-133-20405-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 2,928' Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 188-157 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary - 650 psi @ 3,164' TVD 1,100 psi @ 2,560' TVD - 845 psi (Based on static survey 8/18/15) (Based on normal gradient) (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Swanson River 242-16 was drilled as a grassroots gas well in 1989 to target Sterling gas reserves. The well was initially completed with a tubing/packer completion and perforated in the Sterling 130, 131, 132, and 134 sands. A workover in 1995 pulled the existing completion and ran a 3-1/2" tubing string and inside the 7" casing and cemented the tubing string in place. The well was completed in the Beluga in July 1995. A thru-tubing plug was set in August 2003 to isolate the Beluga and the well was perforated in the Sterling B-6 in August 2003. A thru- tubing plug was set in August 2006 to isolate the Sterling B-6 and the well was perforated in the Sterling B-5 in August 2006. A thru-tubing plug was set in April 2009 to isolate the Sterling B-5 and the well was perforated in the Sterling B -3L in April 2009. The Sterling 64 was also added in August 2014. A thru-tubing plug was set in March 2019 to isolate the Sterling 13-3L and the well was perforated in the Sterling A-11 in April 2019. The purpose of this work/sundry is to plugback the open intervals and perforate the Sterling Asand. A -lb Notes Regarding Wellbore Condition • Well is currently shut in. Slickline tagged fill at 3,104' MD. E -line Procedure: 1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 psi Low. a. Tree connection is 3.5" 8RD. 2. RIH with 3-1/2" CIBP and set at 3,058' MD. Dump bail 35' of cement on top. POOH. 3. If needed, RU Slickline Unit to swab fluid below the pert interval. 4. RU 2-3/8" 6 SPF HC wireline guns. 5. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Sterling A-10 2,908' 2,928' 20 6 a. Pressure up tubing to 500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. d. Correlate using SLB PNL/GR/CCL Log (Tie-in loa). e. Use Gamma/CCL/ to correlate. H Ifilwgi Aleska. LL Record tubing pressures before and after each perforating run. 6. RD E -line. 7. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic Well Prognosis Well: SRU 242-16 Date: 8/12/2019 Swanson River Unit Well: SRU242-16 SCHEMATIC Completion Ran: Ran: 4/12/09 PTD: 188-157 t[dcorp Alne4e,1.LC API: 50-133-20405-00-00 Original RKB = 26.0' CASING AND Wt Grade G 8.921 7� 1 25 1 N-80 I Buttress 1 6.184" I Surf. 4,830 - TUBING 830'TUBING DETAIL 3-1/2" 9.3 1-55 EUE 8'a 1 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID I Item 1 26' 2.992" 7-1/16"x3-1/2"FMC ST/Bore Tbg Hanger(EUE8rd) 2 1 3,645'3-1/2"CIBP 4/11/19 w/35'of cement 04-02-19 3 3,796' 2,865' "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4 4,012' 3,407' ° "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 5 4,313' 7/19/95 "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 6 4,734' 3.00" Halliburton Super Seal Float Collar 7 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown 4/12/09 Baker Shear Out Plug and 1-1/2"gaslift valves PERFORATIONS DETAIL Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments 3,078' 3,080' 2,667' 2,668' 4/11/19 Open 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed 3,407' ° 3,427' 2,912' 2,927' 7/19/95 Squeezed 3,454' • 3,464' 2,947' 2,955' 7/19/95 Squeezed 3,664' 3,671' 3,106' 3,111' 4/12/09 Isolated 3,715' • 3,725' 3,143' 3,151' 8/28/14 Isolated 3,723' 3,753' 3,150' 3,173' 1 7/19/95 1 Isolated 3,816' 3,824' 3,221' 3,227' 8/27/06 Isolated 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated r 4,684' 4,696' 3,889' 3,898' 1 7/24/95 Isolated PBTD = 3,610'MD -3,065'TVD Max hole angle=44°@2,100' TD = 4,860' MD - 4,025' TVD PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406/FEDA028077 spud 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated BY DMA 08-12-19 Swanson River Unit Well: SRU2etion 42-16 PROPOSED SCHEMATIC CompPTD: 1188-157Ran: an:4/12/09 Hllmrn Aluekn, LLC API: 50-133-20405-00-00 Original RKB = 26.0' CASING AND TUBING DETAIL Wt Grade I Conn I ID 7" 1 26 1 N-80 I Buttress 1 6184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8'a 1 2.992" Surf 4,741' IFWFI RV IIFTAII No. Depth ID I Item 1 26' 2.992" 7-1/16" x 3-1/2" FMC 5T/Bore Tbg Hanger (EUE 8rd 2 3,058' Proposed 3-1/2" CIBP w/ 35' of cement 3 3,645' 2,667' 3-1/2" CIBP w/ 35' of cement 04-02-19 4 3,796' 3,344' "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 5 4,012' 7/19/95 "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 6 4,313' 2,912' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 7 4,734' 3.00" Halliburton Super Seal Float Collar 8 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown 3,106' Baker Shear Out Plug and 1-1/2" gaslift valves PFRFr1RATInNG nFTAII Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments I 12,908' ±2,928' 12,540' ±2,560' Proposed TBD 3,078' 3,080' 2,667' 2,668' 4/11/19 Isolated 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed 3,407' 3,427' 2,912' 2,927' 7/19/95 Squeezed 3,454' 3,464' 2,947' 2,955' 7/19/95 Squeezed 3,664' 3,671' 3,106' 3,111' 4/12/09 Isolated 3,715' 3,725' 3,143' 3,151' 8/28/14 Isolated 3,723' 3,753' 3,150' 3,173' 7/19/95 Isolated 3,816' 3,824' 3,221' 3,227' 8/27/06 Isolated 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated a 4,684' 4,696' 3,889' 3,898' 7/24/95 Isolated PBTD = 3,023' MD - 2,626' TVD Max hole angle = 440 @ 2,100' TD = 4,860' MD - 4,025' TVD PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406/FEDA028077 Spud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated BY DMA 08-12-19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 3 0 2Q19 r.Ti 2301 1. Operations Abandon LJ Plug Perforations ✓ Fracture Stimulate LJ Pull Tubing Llpeva ions shut oLJ Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Aller Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 188-157 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20405-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406, FEDA028077 Swanson River Unit (SRU) 242-16 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field - Sterling/Upper Beluga Gas 11. Present Well Condition Summary: Total Depth measured 4,860 feet Plugs measured 3,610 feet true vertical 4,025 feet Junk measured N/A feet Effective Depth measured 3,610 feet Packer measured N/A feet true vertical 3,065 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 16" 90' 89' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,830' 7" 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / J-55 4,741' MD 3,933' TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 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 10 0 Subsequent to operation: 0 2015 0 100 920 14. Attachments (required per 20 AAC 25.070, 25.o7t, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-066 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer ✓ Authorized Title: Operations Manager Contact Email: tkramer(hilcoro.com Authorized Signature: Date -3'b Contact Phone: 777-8420 Form 10-404eR vised 4/2017 ,py�y//fin „ 0 S _c3 _/9 RBDWS1L_-' MAY 0 12018 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SRU 242-16 E -Line 50-133-0405-00 188-157 3/29/19 1 4/11/19 Daily Operations: 03/29/2019 - Friday Sign in. Mobe to location. PTW and JSA. The crane truck would not start. Had mechanic out here look at it and thinks it could be starter. AKE-Line mechanic is coming out. The Rig at Beaver Creek called Ed with E -line and needed him to cut drill pipe. So we lost the a -line crew. I have slick line here now (Noon) with mechanic. We are going to drift SRU 213-15 and also SRU 242-16 to find out where we can set the plugs. PTW/JSA. RIG UP SLICKLINE P/T LUB 2,500PSI GOOD TP - 1,900 PSI. RIH W/ 2.8" G -RING TO 3,656'KB TAG W/ TOOL WOULD NOT FALL. POOH. DID NOT SEE FLUID LEVEL. Rig down lubricator and equipment. Told Taylor we need to keep 1,900 psi on well over weekend. 04/02/2019 -Tuesday Sign in. Having trouble starting wireline truck. Charge up batteries on truck. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 2,080 psi. RIH w/ GPT tool and tie into SLB RST log dated Aug, 25 2014. Tagged at 3,649' and found fluid level at 3,250'. POOH. RIH with GPT tool. 2.5" x 10' Bailer with bottom stopped up and tie into GPT log. RIH to 3,200' and wait 5 min to see if fluid would fill bailer up. (To Double check GPT). POOH Bailer was empty. Called town and discussed and decision was made to set plug and cement. RIH with 2.75" CIBP and tie into GPT tool. Set plug at 3,645'. Lost 200 lbs line tension. Picked up 30' and went back down and tagged plug. POOH. Everything look good. TP - 2,000 psi when plug was set. Made up 2.5" x 30' bailer and fill with cement. RIH w/ bailer and tag plug. Dumped cement on top of plug at 3,645'(17.5'). POOH Good dump. RIH w/ 2.5" x 30' bailer and fill with cement. RIH w/ bailer. Dumped cement on top of cement at 3,627.5' (35' total.) Est TOC - 3,610' Cement in place 1820 hrs POOH. Good dump. Rig down lubricator. WOC. 04/11/2019 - Thursday Sign in. Mobe to location. PTW and JSA. Re -headed wireline. then found a high strand and had to do it over. Rigged up lubricator and Tri-plex pump broke down. Waited to get another one out there. Had an O-ring leak. Bled well down from 1,900 psi to 837 psi. while waiting. PT to 250 psi low and 1,500 psi high. RIH w/GPT tool, correlated to SLB RST log dated Aug, 25 2014 and tagged at 3,603'. Found fluid level at 3,200'. POOH. Send to town. RIH w/ 2-3/8 x 2' HC, 6 spf, 60 degree perf gun and tied into RST log. Ran correlation log and send to town. Get ok to pert from 3,078' to 3,080' with 738 psi on tubing. Fired gun and within 2 min pressure was 975 psi, 5 min - 981 psi, 10 and 15 min pressure was still at 981 psi. POOH. All shots fired and gun was dry. Fired gun at 1651 hrs. Had crystal gauges on well. Rig down equipment and turn well over to field. H Iitivnq, Alaska, LLC Original RKB = 26.0' LMCl_X"MAY.."ro CASING AND TUBING DETAIL Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00 Size Wt Grade Conn ID Top Btm 16" 3,080' Conduct. 3,796' Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7" 26 N-80 Buttress 6.184" Surf. 4,830' TUBING DETAIL 3-1/2" 9.3 J-55 EUE 8'a 2.992" Surf 4,741' JEWELRY DETAIL �. Depth ID Item 26' 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 3,645' 3,080' 3-1/2" CIBP w/ 35' of cement 04-02-19 3,796' 4/11/19 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4,012' 3,370' "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 4,313' 7/19/95 "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 4,734' 3.00" Halliburton Super Seal Float Collar 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe Unknown 3,464' Baker Shear Out Plug and 1-1/2"gaslift valves PERFORATIONS DETAIL Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments 3,078' 3,080' 2,667' 2,668' 4/11/19 Open 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed 3,407' 3,427' 2,912' 2,927' 7/19/95 Squeezed 3,454' 3,464' 2,947' 2,955' 7/19/95 Squeezed 3,664' 3,671' 3,106' 3,111' 4/12/09 Isolated 3,715' 3,725' 3,143' 3,151' 8/28/14 Isolated 3,723' 3,753' 3,150' 3,173' 7/19/95 Isolated 3,816' 3,824' 3,221' 3,227' 8/27/06 Isolated 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated 4,684' 4,696' 3,889' 3,898' 7/24/95 Isolated PBTD = 4,780' D - 3,963' TVD Max hole angle = 440 TD = 4,860' M MD - 4,025' TVD own o e evlse PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406 Spud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated BY DMA 04-30-19 Swanson River Unit Well: SRU211 42-16 SCHEMATIC Completion Ran: Ran: 4/12/09 PTD: 188-157 Hilmra Alaska, LLC API: 50-133-20405-00 Original RKB = 26.0' CASING AND TUBING DETAIL B-1 B-2 ti V TUBING DETAIL 3-1/2" 9.3 3-55 1 EUE 8'a 1 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item Calc TOC 26' ' 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 @ 1,,398' 2,667' if 3 3,796' B-0 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4 4,012' 2,885' "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 5 4,313' 3,407' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 6 9-5/8, - Halliburton Super Seal Float Collar •n, L� 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Squeezed Baker Shear Out Plug and 1-1/2"gaslift valves 3,664' 3,671' 3,106' 3,111' 4/12/09 Isolated B-4 f_ 3,725' 3,143' 3,151' 8/28/14 Isolated B-4 3,723' 3,753' 3,150' 3,173' 7/19/95 Isolated B-5 3,816' p 3,221' 3,227' 1 8/27/06 Isolated A-11 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated Beluga 4,684' 4,696' J 3,895' B-0 Isolated B-1 B-2 ti V TUBING DETAIL 3-1/2" 9.3 3-55 1 EUE 8'a 1 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26' 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 3,645' 2,667' 3-1/2" CIBP w/ 35' of cement 04-02-19 3 3,796' B-0 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4 4,012' 2,885' "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 5 4,313' 3,407' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 6 4,734' 3.00" Halliburton Super Seal Float Collar 7 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Squeezed Baker Shear Out Plug and 1-1/2"gaslift valves IC @ 3,610' 04/02/19 B -3L B-4 B-4 �t - Fill @ 3,745'!-- .q,/.A% .TOC@ 3,759' 3 B-5 _ OL M, C @ 3,967' I _ e-6 TOF @ I,092' '3`' RMOC 4,260' Beluga PFRFnRATIONS FIFTAII Zone Top (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-11 3,078' 3,080' 2,667' 2,668' 4/11/19 Open B-0 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed B-1 3,407' 3,427' 2,912' 2,927' 7/19/95 Squeezed B-2 3,454' 3,464' 2,947' 2,955' 7/19/95 Squeezed R 3 3,664' 3,671' 3,106' 3,111' 4/12/09 Isolated B-4 3,715' 3,725' 3,143' 3,151' 8/28/14 Isolated B-4 3,723' 3,753' 3,150' 3,173' 7/19/95 Isolated B-5 3,816' 3,824' 1 3,221' 3,227' 1 8/27/06 Isolated B-6 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated Beluga 4,684' 4,696' 3,859' 3,895' 7/24/95 Isolated 7" PBTD=3,630'MD-3,065'TVD Max hole angle =44°@2,100' TD = 4,860' M D - 4,025' TVD PTD'188-157 API: 50-133-20405-00 Lease: FEDA-028406 Spud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" BIRD Updated BY DMA 04-30-19 THE STATE °fALASKA GOVERNOR MIKE. DUNLEAVY Alaska Gil and Gas Conservation Commission Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 242-16 Permit to Drill Number: 188-157 Sundry Number: 319-066 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k o. g ov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioners DATED this _�0 day of February, 2019. RBDMSE"' MAR 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 1 1201S APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑Z • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 • 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: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 188-157 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20405-00 ^e--C� 7. If perforating:/}o7i 8.•Well Name and Number. Z,IZ-�% / What Regulation or Conservation Order governs well spacing in this pool? 20 AA . ) -117, —1. ❑ ❑- 17 Swanson River Unit (SRU) 242-16 Will planned perforations require a spacing exception? Yes No y. 9. Property Designation (Lease Number): 10. Field/Pool(s):req FEDA028406 P�v�a < / Swanson River Field rig Gas 11. /y:1�f PRESENT WELL CONDITION SUMMARY �•' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,860' 4,025' 3,759' 3,177' 885 3,759' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 90• 16" 90' 90' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,839 7" 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3# / J-55 4,741' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A; N/A N/A; N/A 12. Attachments: Proposal Summary Q 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: 2/25/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ $PLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York 777-8345 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tn9SS9 jhllC2M com Contact Phone: 777-8354 Authorized Signature: ' Date: 10 y COMMISSION USE ONLY Conditions of approval: NcW Commission so that a representative may witness Sundry Number: �.� 1nA '1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ u Spacing Exception Required? Yes El No r211SubsequentForm Required: / 6._ 1 0'-( APPROVED BY .a I C/ C 4 Approved by: COMMISSIONER THE COMMISSION Date: t --D 2 �I 19KIJU1V1Zt-Lf—ry MAN U bi 1019 Submit p and Pon10-403 Revised 4/2017 Approved applicatio fir date of approval. achments in Duplicate �AI_ti� Z-,71-14i Well Prognosis Well: SRU 242-16 Date: 2/05/2019 Well Name: SRU 242-16 API Number: 50-133-20405-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: February 25", 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: 3,089' Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 188-157 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: — 650 psi @ 3,164' TVD (Based on static survey 8/18/15) Maximum Expected BHP: — 1,151 psi @ 2,678' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 885 psi (Based on actual reservoir conditions and gas gradient (0.10psi/ft)) Brief Well Summa Swanson River 242-16 was drilled as a grassroots gas well in 1989 to target Sterling gas reserves. The well was initially completed with a tubing/packer completion and perforated in the Sterling 60, 61, 132, and 134 sands. A workover in 1995 pulled the existing completion and ran a 3-1/2" tubing string and inside the 7" casing and cemented the tubing string in place. The well was completed in the Beluga in July 1995. A thru-tubing plug was set in August 2003 to isolate the Beluga and the well was perforated in the Sterling B-6 in August 2003. A thru- tubing plug was set in August 2006 to isolate the Sterling B-6 and the well was perforated in the Sterling B-5 in August 2006. A thru-tubing plug was set in April 2009 to isolate the Sterling B-5 and the well was perforated in the Sterling 13-31- in April 2009. The Sterling 134 was also added in August 2014. The purpose of this work/sundry is to plugback the open intervals and perforate the Sterling A sands. Notes Regarding Wellbore Condition • Well is currently shut in. Slickline tagged fill at 3,648'. E -line Procedure: 1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. a. Tree connection is 3.5" 8RD. 2. RIH with 3-1/2" CIBP and set at±3,645'. Dump bail 35' of cement on top. POOH. 3. RU 2-3/8" 6 SPF HC wireline guns. --------- 4. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Sterling A-10 2,908' 2,928' 20 6 Sterling A-11 3,074' 3,089' 15 6 a. Pressure up tubing to 500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perls tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using SLB PNL/GR/CCL Log (Pending) (Tie-in log). e. Use Gamma/CCL/ to correlate. H Hil... p Alaska, LU f. Record tubing pressures before and after each perforating run. 5. RD E -line. 6. Turn well over to production. E -line Procedure (Contingency): 7. If any zone produces sand and/or water. 8. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. 9. RIH and set 3-1/2" CIBP within 50' above zone. Well Prognosis Well: SRU 242-16 Date: 2/05/2019 10. RU dump bailer. RIH with cement and dump bail 35' of cement on CIBP. POOH. Attachments: 1. As -built Schematic 2. Proposed Schematic 16" Original�'�RKB = 26.0' I T 1 I jA CalcTOC _ y @ 1,398' 95/8' A „ 5Z B0 C P` B-1 B-2 B-4 Fill @ 3, TOF @ 4,092' Js t. B -3L B-4 TOC @ 3,759' t B-5 TOC @ 3,967' 3` B-6 TOC @ 4,260' 4 Beluga 1 4 i� 6 t' SCHEMATIC CASING AND TUBING DETAIL Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00 Size Wt Grade Conn ID Top Btm 16" 2 Conduct. 2,865' "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' Surf. 90' 9-5/8" 36 J-55 4,313' 8.921" Surf. 2,170' 9-5/8" 47 S-95 6 8.681" 2,170' 2,337' 7" 26 N-80 Buttress 6.184" Surf. 4,830' B-4 3,715' 3,725' TUBING DETAIL 3,151' 8/28/14 2-1/2" HC 6 spf/60° Powerlet 3-1/2" 9.3 J-55 EUE 81a 1 2.992" Surf 4,741' JEWELRY DETAIL No. Depth ID Item 1 26' 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 3,796' 2,865' "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 3 4,012' B-1 "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 4 4,313' 2,927' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 5 4,734' 3.00" Halliburton Super Seal Float Collar 6 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown 3,671' Baker Shear Out Plug and 1-1/2"gaslift valves PERFORATIONS DETAIL Zone Top (MD) Stm(MD) Top(TVD) Btm (TVD) Date Comments B-0 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed B-1 3,407' 3,427' 2,912' 2,927' 7/19/95 Squeezed B-2 3,454' 3,464' 2,947' 2,955' 7/19/95 Squeezed B-31- 3,664' 3,671' 3,106' 3,111' 4/12/09 2-1/2" HC 6spf/60° Powerlet B-4 3,715' 3,725' 3,143' 3,151' 8/28/14 2-1/2" HC 6 spf/60° Powerlet B-4 3,723' 3,753' 3,150' 3,173' 7/19/95 Squeezed B-5 3,816' 3,824' 3,221' 3,227' 8/27/06 2-1/2" HC 6 spf/60` Powerlet B-6 4,064' 4,066' 3,410' 3,412' 8/23/03 Isolated Beluga 1 4,684' 1 4,696' 1 3,889' 1 3,898' 1 7/24/9 1 Isolated 7" J 'I. PBTD = 4,780' MD - 3,963' TVD Max hole angle = 44° TD = 4,860' M D - 4,025' TVD Downhole Revised 8/28/14 PTD: 188.157 API: 50-133-20405-00 Lease: FEDA-028406 Saud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated by: DMA 02-05-19 16" 9 5/8"L B-0 BI B 2 B-4 Fill @ 3,745' TOF@, Original RKB = 26.0' 1 PROPOSED SCHEMATIC CASING AND TURING DETAIL Swanson River Unit Well: SRU 242-16 Completion Ran: 4/12/09 PTD: 188-157 API: 50-133-20405-00 Size Wt Grade Conn ID Top Btm 16" Ca lc @ 1,398' Conduct. 3,645' Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 5-95 8.681" 2,170' 2,337- 7' 26 N-80 Buttress 6.184" Surf. 4,830' SLA B -3L B-4 .:. TOC @ 3,759' Y- In 3 B-5 I OC @ 3,967' i -In 4 1 1211211111 B-6 roc @ 4,260' Beluga No. Depth TUBING DETAIL Item 1 3-1/2" 9.3 1-55 EUE 8`a 2.992" Surf 4,741' 2.992" Ca lc @ 1,398' TOC JEWELRY DETAIL 3,645' ±2,540' 3-1/2" CIBP w/ 35' of cement 3 3,796' A-11 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4 SLA B -3L B-4 .:. TOC @ 3,759' Y- In 3 B-5 I OC @ 3,967' i -In 4 1 1211211111 B-6 roc @ 4,260' Beluga No. Depth ID Item 1 26' 2.992" 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE Srd) 2 3,645' ±2,540' 3-1/2" CIBP w/ 35' of cement 3 3,796' A-11 "AD2" Stop @ 3,793', Macco Pack -off @ 3,795', "G" Stop @ 3,796' 4 4,012' ±2,678' "AD2" Stop @ 4,015', Macco Pack -off @ 4,013', "G" Stop @ 4,012' 5 4,313' 3,344' "A" Stop @ 4,316', Macco Pack -off & "G" Stop @ 4,313' 6 4,734' 3.00" Halliburton Super Seal Float Collar 7 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe A Unknown Squeezed Baker Shear Out Plug and 1-1/2" gaslift valves PERFORATIONS DETAIL Zone To (MD) Btm(MD) Top(TVD) Btm (TVD) Date Comments A-30 ±2,908' ±2,928' ±2,540' ±2,560' Proposed TBD A-11 ±3,074' ±3,089' ±2,663' ±2,678' Proposed TBD B-0 3,344' 3,370' 2,865' 2,885' 7/19/95 Squeezed B-1 3,407' 3,427' 2,912' 2,927' 7/19/95 Squeezed B-2 3,454' 3,464' 2,947' 2,955' 7/19/95 Squeezed B-31- 3,664' 3,671' 3,106' 3,111' 4/12/09 2-1/2" HC 6 spf/60° PowerJet B-4 3,715' 3,725' 3,143' 3,151' 8/28/14 2-1/2" HC 6 spf/60' PowerJet B-4 3,723' 3,753' 3,150' 3,173' 7/19/95 Squeezed B-5 3816 3,824' 3,221' 2 3, ' 7/06 2-1/2" HC 6 spf/60° Poweret - 4,0 4,066' 3,410' 1 8//323/03B6 Isolated Beluga 4,684' 1 4,696' 3,889' 3,898' 1 7/24/95 Isolated PBTD=4,780'MD-3,963'TVD Max hole angle =44°@2,100' TD = 4,860' MD - 4,025' TVD Downhole Revised 8/28/14 WELL DATA PTD: 188-157 API: 50-133-20405-00 Lease: FEDA-028406 Spud Date: 8/15/1989 Tree cxn: 3-1/2" Bowen Lift Threads: 3-1/2" 8RD Updated BY DMA 02-05-19 Davies, Stephen F (DOA) From: Taylor Nasse <tnasse@hilcorp.com> Sent: Friday, February 15, 2019 3:32 PM To: Davies, Stephen F (DOA) Cc: Boyer, David L (DOA); Benjamin Siks; Donna Ambruz Subject: RE: [EXTERNAL] SRU 242-16 (PTD 188-157; Sundry 319066) - Question Hi Steve - Our Geologist, Ben Siks, checked and you are correct— CO 716 is the governing spacing regulation for the requested perforations. I think the mistake was a holdover from the previous sundry for this well. If you have any further questions, please feel free to contact me. Thanks, Taylor W. Nasse, PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907) 777-8354 office (907) 903-0341 cell From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, February 12, 2019 2:28 PM To: Taylor Nasse <tnasse@hilcorp.com> Cc: Boyer, David L (DOA) <david.boyer2@alaska.gov> Subject: [EXTERNAL] SRU 242-16 (PTD 188-157; Sundry 319066) - Question Taylor, According to my quick cross-section, Hilcorp's planned perforations in this Sundry Application appear to lie just beneath the top of the Sterling/Upper Beluga Gas Pool as defined in CO 716.001 Rule 2a. If so, CO 716 will govern spacing rather than the statewide regulations of 20 AAC 25.055. Could you please check with the project geologist? Thank you, Steve Davies 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.daviesgalaska.gov. 10,000,000 1,000,000 s C O CL 100,000 LL CU C Q 10,000 R w O o� LL C 1,000 _U B 3 U N 100 3 O t H 20 1 Jan -1985 HILCORP ALASKA LLC, SWANSON RIV UNIT 242-16 (188-157) SWANSON RIVER, STRLG/U BLUG GS Monthly Production Rates I Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Mrs■■_■_■■■■■■■■■■n■■■■■ Produced Gas (MCFM) ■ - Produced Oil (BOPM) W ���f�'�■ ■■■�■ Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 A Produced Gas (MCFM) o GOR Produced Water (BOPM) - Produced Oil (BOPM) 10,000,000 o, 1,000,000 0 O 100,000 0m 0 7 S 10,000 1 - 1 Jan -2020 SPREADSHEET -Prod -Inject Cuwes_W ell_V 117_1881570_SRU_242-16_20190212.xlsx 2/12/2019 Donna Ambruz From: Benjamin Siks Sent: Tuesday, February S, 2019 1:46 PM To: Donna Ambruz; Taylor Nasse Cc: Daniel Taylor Subject: RE: SRU 242-16 Perf Depths Hey Team, Looking at the schematic, a lot of what we proposed had been shot (but it worked!). Below are the two remaining sands to go shoot. There should be no need to update the tops from the previous schematic as these are Sterling A sands (not B). J. I've updated Petra with the correct information. Cheers, Ben From: Donna Ambruz Sent: Tuesday, February 5, 2019 1:30 PM To: Benjamin Siks <bsiks@hilcorp.com>; Taylor Nasse <tnasse@hilcorp.com> Cc: Daniel Taylor <dtaylor@hilcorp.com> Subject: RE: SRU 242-16 Perf Depths I=;a:1410967.10CY1t7i7 From: Benjamin Siks Sent: Tuesday, February 5, 2019 11:38 AM To: Taylor Nasse <tnasse@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Cc: Daniel Taylor <dtaylor@hilcorp.com> Subject: SRU 242-16 Perf Depths Status FORMATION INTERVAL (Status) MD MD TVD TVD Status FORMATION INTERVAL TOP Base TOP BASE Proposed Sterling A10 2908 2928 2540 2560 Proposed Sterling A11 3074 3089 2663 2678 From: Donna Ambruz Sent: Tuesday, February 5, 2019 1:30 PM To: Benjamin Siks <bsiks@hilcorp.com>; Taylor Nasse <tnasse@hilcorp.com> Cc: Daniel Taylor <dtaylor@hilcorp.com> Subject: RE: SRU 242-16 Perf Depths I=;a:1410967.10CY1t7i7 From: Benjamin Siks Sent: Tuesday, February 5, 2019 11:38 AM To: Taylor Nasse <tnasse@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Cc: Daniel Taylor <dtaylor@hilcorp.com> Subject: SRU 242-16 Perf Depths Status FORMATION INTERVAL (Status) MD TOP MD Base ti OF TF • yw 1//y��s. THE STATEAlaska Oil and Gas ti -s �, OfA TTAsK Conservation Commission Wet_= 333 West Seventh Avenue — „Tv-� Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov December 13, 2017 Mr. Chad Helgeson Kenai Operations Manager Hilcorp Alaska LLC P. O. Box 244027 Anchorage, AK 99524-4027 SCANNED 3 ,!r Re: Docket Number: OTH-17-051 Defeated Safety Valve System Swanson River Unit 242-16 (PTD 1881570) Dear Mr. Helgeson: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska LLC (Hilcorp)'s explanation regarding the defeated safety valve system at Swanson River Unit 242-16. Hilcorp's response dated December 11,2017,presented the findings from its internal investigation and "Actions Going Forward"that have been implemented to prevent recurrence of defeated well safety valve systems at Hilcorp-operated wells within Alaska. Those actions address the concerns identified in the violation. The AOGCC does not intend to pursue any further enforcement action regarding the Swanson River Unit 242-16 defeated safety valve system. Sincerely, Hollis S. French Chair, Commissioner cc: AOGCC Inspectors (via email) ......_........ .... ... ._.. • • Hilcorp Alaska, LLC Chad Helgeson Kenai Team Operations Manager RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 DEC 1 1 2017 3800 Centerpoint Drive 100 December 11 2017 Suite � Anchorage,AK 99503 AOGCC Phone: 907/777-8405 Fax: 907/777-8351 Hollis S. French chelgeson@hilcorp.com Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Docket No. OTH-17-051 Defeated Safety Valve Systems Swanson River Unit 242-16 (PTD 1881570) Dear Chair French: We respond to the AOGCC's request dated November 21, 2017, in regards to the Swanson River 242-16 (PTD# 188-157) producing gas well with the safety valve system (SVS) defeated during the 180-day testing cycle. This response includes a written explanation of how the event happened, when it happened and what Hilcorp Alaska, LLC (Hilcorp Alaska)has done or is doing to prevent it from happening again. A. Swanson River Unit 242-16 SRU 242-16 is a gas well producing from the Sterling Pool. Its normal daily production is approximately 550-600 mcfd at 160psi. This well requires soap sticks to be dropped every 2 hrs to keep the well online. When soap sticks are not dropped on this schedule the gas production drops to levels around 100 mcfd within a couple hours. At times the well may be drawn down below the SSV trip pressure (115 psi) to unload the well for 30 min and get the rate back to 550 mcfd. On November 1, 2017, Hilcorp Alaska operators were completing the 180 Day SVS testing with an AOGCC inspector onsite to witness the testing. When the SRU 242-16 SVS was tested the safety valve did not trip, when troubleshooting the failure, a quarter-turn ball valve was found closed, which prevented the hydraulic pressure from venting to the hydraulic reservoir which prevented the safety valve from closing and thus defeating the well safety valve system. B. Investigation Hilcorp Alaska has conducted an investigation of the incident, resulting in the following findings. • • Hollis S.French Docket Number: OTH-17-051 December 11,2017 Page 2 of 5 At approximately 11:00 a.m.on October 27,power was interrupted at Swanson River.1 This power outage shutdown the entire facility for three hours. Operators started bringing wells and production back on line after 2:00 p.m. That night the operator defeated the SVS in order to unload the 242-16 well. During this operation, the operator tagged the defeated valve and tagged the steering wheel in his pickup truck as a reminder. The operator manned the well the entire time the well was in a defeated state. When he left the well, the SVS system was functional with all tags removed and returned to normal. On Saturday, October 28, the well was not flowing at its optimal rate and a different operator unloaded the well at approximately 6:00 p.m. He does not remember if he defeated the SVS at that time and did not flag or tag the well. Hilcorp Alaska assumes this is when the SVS was defeated as the well was not unloaded again between this date and when it was found four days later on November 1. C. Hilcorp Alaska Policy on Defeating Safety Valves When defeating an SVS, Hilcorp Alaska follows AOGCC regulations as seen in Attachment 1, which includes excerpts from existing training slides on blocking, removing or defeating an SVS. Defeating an SVS is an approved practice when performed in accordance with regulatory requirements governing operations during the time the SVS is defeated. For instance, an operator may not leave a pad with a well on production when the SVS is defeated. This rule was violated. D. Hilcorp Alaska Personnel Actions Upon completion of the investigation, Hilcorp Alaska undertook the following personnel actions: 1. Commended the operator who tagged SVS and his truck's steering wheel on October 27 when he defeated it to unload the well, thus assuring his reinstatement of the SVS in full operation before leaving the well. 2. Removed from any operating responsibilities the operator who could not remember if he defeated the SVS and did not tag the SVS when he defeated it to unload the well on October 28. 3. Reprimanded four additional operators with written deficiencies in their employment records. Two of these operators were reprimanded for failure to promptly check the status of their wells shortly after coming on tour. The other two were reprimanded for operating a well with a defeated SVS. These individuals will travel to other Hilcorp Alaska assets to conduct new SVS training where they will discuss what happened,what went wrong, and review the design and inner workings of the SVS. 1 Homer Electric provides Swanson River Field with almost all of the electrical power used to operate the field. Power outages at Swanson River Field are not unusual,given the length of the transmission lines(over 18 miles), the trees on the transmission line right-of-way,and the frequency of winds which impact the line. • Hollis S.French Docket Number: OTH-17-051 December 11,2017 Page 3 of 5 4. Withheld promotions or pay increases for these four operators for three months and such additional time as may be required for them to complete their training of other operators. E. Actions Going Forward 1. All Hilcorp Alaska facilities will review their SVS defeated logs to share practices with other Hilcorp Alaska facilities. Each facility will incorporate good practices from the other facilities. We do not think having one standard log is appropriate for each field, as there are so many different systems in different fields that having one form may not be appropriate for all fields. Swanson River did not have a SVS defeated log kept at the main office for wells, and has now implemented a log similar to what has been used at other facilities. 2. Since the event on November 1, Hilcorp Alaska has refreshed all operations staff that may work or adjust SVS in all Alaska fields on the Hilcorp Alaska SVS training program. 3. For wells that require frequent(once per month)blow down operations requiring defeating the SVS, we are looking for instrumentation that have timers to limit the length of time the valve can be bypassed. If we find a suitable device that will not impact the performance of the SVS, we will work to install these on wells where a SVS may be defeated more than once per month. 4. Hilcorp Alaska treats all safety systems—not just regulated systems such as SVS—as critical to the safety and well-being of our personnel, our equipment, and our environment. We will implement the lessons learned from this incident and apply it to other safety systems as well to ensure that all safety systems at our facilities are being treated with the respect they deserve. Should you have any additional questions, please contact Chad Helgeson (777-8405 or chelgeson@hilcorp.com). Sincerely, HILCORP ALASKA, LLC Chad A. Helgeson Operations Manager Attachment 1 —SVS Training Slides on Defeating SVS cc: Vanessa Hughes Larry Greenstein David S. Wilkins John Barnes Matt Brown • • Hollis S.French • Docket Number: OTH-17-051 December 11,2017 Page 4 of 5 Swanson River Unit 241-16 Defeated Safety Valve System Docket No. OTH-17-051 Hilcorp Alaska Response Attachment 1 SVS Training slides on defeating SVS Blocking, Removing or Defeating SVS I $When required by a tubing workover, well intervention, or by routine well pad or platform operations a SSSV may be temporarily blocked or removed. 265(j) (1). The SSSV must be made operable not later than 14 days after the date that the well is returned to service, and The SSSV must be tested not later than days after installation. 265(j)(1 ). Blocking, Removing or Defeating SVS II When required by a tubing workover, well intervention, or by routine well pad or platform operations a SSV and the sensor may be temporarily removed or defeated. 265(j)(2). The well pad or platform must be continuously manned, the well must be shut-in, until the SSV and sensor are made operable. 265(j)(2) Well pads, platforms, islands, or similar groups of wells are continuously manned if sufficient responsible personnel are physically on-site and manually able to provide a level of protection equivalent to the removed or defeated SVS equipment. 265(j)(2). • Hollis S. French • Docket Number: OTH-17-051 December 11,2017 Page 5 of 5 Tagging a Defeated SVS If a required component of a well's safety valve system is inoperable, removed, or blocked, the well must be tagged, BUT ... 265(m). Tagging is not required during well work activities and continuously manned operational activities that affect a safety valve system. 265(m). The tag must identify the following: (1) the inoperable, removed, or blocked component; (2) the date and reason, if known, that the component was inoperable, removed, or blocked; and (3) the name of the individual completing the tag. 265(m). `N Defeated SVS Example Tag OUT OF SERVICE Defeated Equipment/SVS: O , Other Reason Out of Service: Nate amme: L OF TFj • • 69 I 1/7, THE s THE STATE Alaska Oil and Gas ��.;,"!''�� OKA Conservation Commission fALASConservation 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 • OF ° Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 21, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 0640 0003 5185 6069 Mr. Chad Helgeson Kenai Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-17-051 Defeated Safety Valve System Swanson River Unit 242-16 (PTD 1881570) Dear Mr. Helgeson: On November 1; 2017, an Alaska Oil and Gas Conservation Commission(AOGCC) Inspector witnessed well safety valve system tests in the Swanson River Unit(SRU)that were performed by a Hilcorp Alaska LLC (Hilcorp) representative. The safety valve system on SRU 242-16 was found defeated. Investigation revealed that a quarter-turn valve was closed on the low-pressure pilot control line. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. Hilcorp is reminded that a producing well must be equipped with a functional safety valve system as described in 20 AAC 25.265: - Paragraph(h)(2)requires a performance test following installation, repair, or replacement of a subsurface safety valve; - Paragraph (j)(1) allows the subsurface safety valve to be removed for a tubing workover, well intervention, or routine pad or platform operation. The subsurface safety valve must be tested within five days after installation; - Paragraph (m) establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on SRU 242-16 that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265 —will not be tolerated. Notice of Violation Docket Number: OTH 17-051 November 7,2017 Page 2 of 2 Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written explanation of how this event happened, identify when it happened, and describe what has or will be done in the future to'prevent its recurrence at all Hilcorp-operated fields in Alaska. Failure to comply with this request will be an additional violation. AOGCC has issued notices of violations for defeated safety valves at several fields operated by Hilcorp in Alaska. In each enforcement action, Hilcorp was instructed to describe what has been or will be done in the future to prevent recurrence of defeated safety valve systems. Corrective actions identified by Hilcorp included mechanical.as well as administrative enhancements. The AOGCC is reviewing this violation along with the past commitments made by Hilcorp to implement corrective actions in response to similar defeated safety valve systems. We reserve the right to pursue enforcement action in connection with the defeated safety valve system on SRU 242-16. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Hollis S. French Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. U.S. Postal Servicer CERTIFIED MAIL° RECEIPT Er Domestic Mail Only ED For delivery information,visit our website at www.usps.com -a co Certified Mail Fee __. Ira $ Ui Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ ® 0 Return Receipt(electronic) $ Postmarks CI ❑Certified Mail Restricted Delivery $ Here ® ❑Adult Signature Required ,$ 0 Adult Signature Restricted Delivery$ O Postage $ OTotal Post $ Mr. Chad Helgeson tri Sent To Kenai Operations Manager ra Hilcorp Alaska, LLC a Street and P- P.O. Box 244027 City State, Anchorage, AK 99524-4027 PS Form 3 r r 0,April 2015 PSN 7530-02.000-9047 See Reverse for Instructions SE^'EyER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3. A. Signature / ■ Print your name and address on the reverse �� ❑Agent so that we can return the card to you. X 04i ' 0 Addressee • Attach this card to the back of the mailpiece, B. -eceived. ame) C. Date of Delivery or on the front if space permits. lir' ' r 1. Article Addressed to: . -oi 1 Atilt �Z/ -� t+.4-1 Ss 1 D. Is delivery ad.ress different from item 1? 0 Yes If YES,enter delivery addressbelpv No Mr. Chad Helgeson , ` (I, Kenai Operations Manager 20f1 Hilcorp Alaska, LLC 4100 P.O. Box 244027 "" �� Anchorage, AK 99524-4027 3. Service Type 0 Priority Mail Express® 13E1111 1111111111 111111 II I II "I I IIII II I'll1 O Adult 0 Adult Signature Restricted Delivery ❑Renature 0 gistered Mail Restricted 9590 9402 1823 6104 6486 89 ❑Certified Mail® Delivery ❑Certified Mail Restricted Delivery 0 Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationTM 7015 064® 0003 5285 6 O 6 9 -mired Mail 0 Signature Confirmation 'mired Mall Restricted Delivery Restricted Delivery ,)ver$500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt _ _ ~-~a STATE OF ALASKA 1~~~,I~/~,C~'s.~-~ ~~~ ALAS OIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS MAY ~ 2 ~~~~ ~/~-c~lZVCq s.....~ raAH11Y11$~rQ~{ 1. Operations Abandon Repair Well Plug Perforations ~ - Stimulate _~S~ - 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 ^~ ~ Exploratory^ 188-157- 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-133-20405-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 26' ' Swanson River Unit (SRU) 242-16 - 8. Property Designation: 10. Field/Pool(s): FEDA028406 [Swanson River Field] . Swanson River Field /Sterling Undefined Gas 11. Present Well Condition Summary: Total Depth measured 4,860 feet Plugs (measured) 3,759' (cement) true vertical 4,025 ~ feet Junk (measured) N/A Effective Depth measured 3,759 feet true vertical 3,177 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 16" 90' 89' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,830' 7" 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation depth: Measured depth: 3,664'-3,671' v , True Vertical depth: 3,105'-3,110' Tubing: (size, grade, and measured depth) 3-1/2" 9.3# J-55 4,741' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): 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 bbl 0 0 bbl 0 psi 700 psi Subsequent to operation: 0 bbl 680 0 bbl 0 psi 920 psi 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: 309-038 Contact Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 263-7600 Date 5/7/2009 Form 10-404 Revised 04/2006 ~ t~AV 4 `~ ~C)Q~k Submit Original Only 4 ~. r~ Chevron Chevron -Alaska Weekly Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 242-16 SWANSON RIV UNIT 242-16 FEDA028406 5013320405 IU4698 26.00 - - - -- Jobs ` Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion -Reconfigure Well Abandon Sterling 65 sand and recomplete in the Sterling B3 A2 sand. 4/7/2009 Services Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 242-16 5013320405-00 1881570 Daily Operations 4/7/2009 00:00 - 4/8/2009 00:00 Operations Summary Pressure well to 1800 psi. to attempt to push water away into formation. Small pressure loss seen on tubing. 4/8/2009 00:00 - 4/9/2009 00:00 Operations Summary Pump 10 gals. Methonal and Pressure well to 2225 psi in attempt to push fluid away. Fluid Level machine showed fluid at 1421 '. 4/9/2009 00:00 - 4/10/2009 00:00 Operations Summary RU slickline. Pressure test lubricator to 250psi low/ 2,500psi high. Work 1.75 GR and Drive down bailer to 3834' RKB SLM. RIH w/ 2.7" blind box and saw fuid level at 2,145' RKB SLM. Run 2.9" GR to 3834' RKB. RD slickline. Pressure well to 1700 psi and saw breakover, pushed gas in tubing for 30 minutes, pressure fell to 1290 psi. Well shut in w/ tubing pressure stabilized at 1,110psi. 4/10/2009 00:00 - 4/11/2009 00:00 Operations Summary RU slickline, pressure test to 250psi low/2,500psi high. Run 2.90" GR and tagged fill at 3,834'. Set Macco plug at 3796', Dump bail 41' cement (7 runs). RD slickline. 4/11/2009 00:00 - 4/12/2009 00:00 Operations Summary Monitor Well, Waiting on Cement.Schlumberger brought equipment out and set up. Set up Chart recorder and perform negative test on plug. Tubing bled down to 200 psi. 4/12/2009 00:00 - 4/13/2009 00:00 Operations Summary Tubing pressure 200 psi after 12hr negative test, held. RU slickline, pressure tested lubricator to 250psi lowl2,500psi high. RIH w/ 2.9" GR and tag top of Cement at 3759' RKB SLM (No problems). Confirmed 37' cement on top of plug. Run 2.5"x 10' Dummy gun to 3759' RKB SLM, POOH. RD slickline. 4/13/2009 00:00 - 4/14/2009 00:00 Operations Summary Well pressured up using gas lift line to get well to 10% underbalance pressure of 986psi. Rigged up Schlumberger, Lubricator, Wireline valves and pump-n-sub Pressure test 250 psi low and 2500 psi high, MU 7'x 2.5" Poweryet 6spf, 60deg gun and perforate the 63A2 Bench from 3,664'-3,671' RKB ELM. Pressure climed from 986psi to 1022 psi within 5 minutes. RD Eline unit. Turn well over to Production. Swanson River Field Well #: SRU 242-16 Current Completion as of 4/12/09 Original RKB = 26.0' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 5-95 8.681" 2 170' 2 337' 7 26 N-80 Buttress 6.184" Surf. 4 830' Tubin 3-1/2" 9.3 J-55 EUE 8rd 2.994" Surf 4 741' JEWELRY NO De th ID Item 1. 26' 2.994" 7-1/16" x 3-1/2" FMC ST/Bore Tb Han er EUE 8rd 2. 3,796' "AD2" Stop @ 3793', Macco Pack-off @ 3795', "G" Stop 3796' 3. 4012' "AD2" Stop @ 4015', Macco Pack-off @ 4013', "G" Stop 4012' 4. 4313' "A" Sto 4316' Macco Pack-off & "G" Sto 4313' 5. 4 734' 3.00" Halliburton Su er Seal Float Collar 6. 4 741' 3.00" Halliburton Su er Seal Tubin Float Shoe Perforations Date Zone To BTM Comments 4/12/09 B-3A2 3,664' 3,671' 2-1/2" HC 6 s f/60° PowerJet Char es 8/27/06 B-5 3,816' 3,824' 2-1l2" HC 6 s f/60° PowerJet Char es 8/23/03 B-6 4,064' 4,066' Isolated 7/24/95 Belu a 4,684' 4,696' Isolated 2 912' 2,927' S ueezed 7/19/95 2 947 2 955 S ueezed 7/19/95 3 150 3,173 S ueezed 7/19/95 3,344 3 370 S ueezed 7/19/95 3,407' 3,427' S ueezed 7/19/95 3,454' 3 464' S ueezed 7/19/95 3,723' 3 753' S ueezed 7/19/95 TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Current 5-7-09.D000urrent Wellbore Schematic 5-7-09 REVISED: 5/7/2009 DRAWN BY: CVK ~J u d 0 ~ ~ ~ SARAH PALIN, GOVERNOR ~I[~7~ OIIa ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T51iR~A'I'IOl~T CO1~IIrII551OrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Unocal PO Box 19624? ~~ ~ ~ ~ Anchorage AK 99519 ~ ~, ~~'' Re: Swanson River Field, Sterling Undefined Gas, SRU 242-16 Sundry Number: 309-038 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, Daniel T. Seamount, Jr. ~ Chair r DATED this ~ day of February, 2009 Encl. ,~ ~~~ 11 ,off ~-~' -~ i~ ~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON ~ 200 APPLICATION FOR SUNDRY APPROVAL s~ JAS 20 AAC 25.280 ~" 101: 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ~, aiver 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 Drill Number: Union Oil Company of California Development ^ Exploratory ^ 188-157 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 ^ 50-133-20405-00 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 0 Swanson River Unit SRU 242-16 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028406 Swanson River Unit - 26' ~ Swanson River / Sterlin Undefined Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4,860 ~ 4,025 - 3,967 - 3,336 - 4,012' & 4,313' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 16" 90' 89' Surface 2,337' 9-5/8" 2,337' 2,119' 3,520 psi 2,020 psi Intermediate Production 4,830' 7" 4,830' 4,002' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,816'-3,824' 3,220'-3,226' 3-1/2" 9.3# J-55 4,741' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ . Service ^ 15. Estimated Date for 2/15/2009 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q , Plugged ^ Abandoned ^ 17. Verbal 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 Chris Kanyer 263-7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C P e 276-7600 Date 1/26/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ~ .- 4~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ 's Q Other: ~1 tc`~ ~~~~ ~ ~~v ~~ t~ft1\~ ~~ ~C~ w ~ ~ ~ ~~ ~ ~' ~ \ Subsequent Form Required: ~...~~~ APPROVED BY A d b THE C MMI ION D t pprove y: COMMISSIONER a e: O SS Form 10-403 Revised 06/2006 uF~~G~~AL Submit in Duplicate Chevron • • Swanson River Field Well #: SRU 242-16 Current Completion as of 08/27/06 Original RKB = 26.0' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7 26 N-80 Buttress 6.184" Surf. 4,830' Tubin 3-1/2" 9.3 J-55 EUE 8`d 2.994" Surf 4,741' JEWELRY NO De th ID Item 1. 26' 2.994" 7-l/16" x 3-1/2" FMC ST/Bore Tb Han er EUE 8rd 2. 4,734' 3.00" Halliburton Su er Seal Float Collar 3. 4,741' 3.00" Halliburton Su er Seal Tubin Float Shoe 4. 4313' "A" Sto 4316', Macco Pack-off & "G" Sto 4313' 5. 4012' "82" Stop @ 4015', Macco Pack-off @ 4013', "G" Stop @ 4012' Perforations Date Zone To BTM Comments 8/27/06 B-5 3816 3824 2-1/2" HC 6 s f/60° PowerJet Char es 8/23/03 B-6 4064 4066 Isolated 7/24/95 Belu a 4684 4696 Isolated 2,912' 2,927' S ueezed 7/19/95 2 947 2,955 S ueezed 7/19/95 3 150 3 173 S ueezed 7/19/95 3,344 3,370 S ueezed 7/19/95 3,407' 3,427' S ueezed 7/19/95 3 454' 3,464' S ueezed 7/19/95 3,723' 3 753' S ueezed 7/19/95 TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Current 8-27-06.DOC REVISED: 10/18/2006 DRAWN BY: SLT Chevron ~ • Swanson River Field Proposed Well #: SRU 242-16 Current Completion as of 08/27/06 Original RKB = 26.0' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 5-95 8.681" 2,170' 2 337' 7 26 N-80 Buttress 6.184" Surf. 4,830' Tubin 3-1/2" 9.3 J-55 EUE 8'" 2.994" Surf 4,741' JEWELRY NO De th ID Item 1. 26' 2.994" 7-1/16" x 3-1/2" FMC ST/Bore Tb Han er EUE 8rd 2. 3,794' +/- Slickline lu 3. 4012' "82" Stop @ 4015', Macco Pack-off @ 4013', "G" Stop @ 4012' 4. 4313' "A" Sto 4316', Macco Pack-off & "G" Sto 4313' 5. 4,734' 3.00" Halliburton Su er Seal Float Collar 6. 4,741' 3.00" Halliburton Su er Seal Tubin Float Shoe Perforations Date Zone To BTM Comments New Perf B-3A2 +/-3,667 +/-3,674' 2-1/2" HC 6 s f/60° PowerJet Char es 8/27/06 B-5 3,816' 3,824' 2-1/2" HC 6 s f/60° PowerJet Char es 8/23/03 B-6 4,064' 4,066' Isolated 7/24/95 Belu a 4,684' 4,696' Isolated 2,912' 2,927' S ueezed 7/19/95 2,947 2 955 S ueezed 7/19/95 3,150 3,173 S ueezed 7/19/95 3,344 3 370 S ueezed 7/19/95 3,407' 3 427' S ueezed 7/19/95 3,454' 3 464' S ueezed 7/19/95 3,723' 3,753' S ueezed 7/19/95 TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Proposed 1-21-09.DOCProposed Schematic 1-21-09 REVISED: 1/21/2009 DRAWN BY: CVK Chevron ~ , Swanson River Well #SRU 242-16 1/20/09 OBJECTIVE: • Plug off B-5 open perf and perforate B-3A2 sand. PROCEDURE SUMMARY: 1 Conduct PJSM. RU Slickline lubricator and pressure test 2 RIH with 2-3/4" GR and tag cement at 3,967 (+/-). 4 RIH and set slickline plug at 3,794' (+/-) 6 RIH & tag plug with dump bailer at 3,794' (+/-). Begin Dump bailing 35'-40' cement on top of plug. 8 RD slickline. WOC. 10 Conduct PJSM. RU Slickline lubricator and pressure test 11 RIH with 2-3/4" GR and tag cement at 3,758' (+/-). 12 RIH with 2.5" x 5' dummy gun and tag bottom at 3,758' (+/-). 13 RD slickline 14 Conduct PJSM. RU Eline lubricator and pressure test. 15 RIH with GR/CCL and perf gun and tie-in and perforate the B-3A2 sand. 16 Rig down Eline. Turn well over to production. SRU 242-16 REVISED BY: CVK 1-20-09 Date: January 30, 2009 ~ To: File ; ; From: Jane Williamson Subject: SRU-16 Sterling Und. Gas Chevron requested approval to plug perforations and perforate a new zone. Review of ~~ the production history shows high water with rates averaging around 200 mscfd. `t ~ SS~ ~o~eJ Isolating the lowest zone from the water appears reasonable. /~~ ~~~ I recommend approval of this sundry request. z~-,~ W~Ya RAe (PD) (hhlPo ) 1~ __ - - -. _. _. ~` `_.1 VI r ~ N ~I~ ^ r4~ w~~~V"} ~ ~ti~ ~ ~~u j ~~~ ,~ io 1 1 ai -----..._..__~____------------- T.--~---.-~--------- - --~--- ~sea ee eo s~ sz si sa ss ss s~ ss se zooo m oz a~ oa os as rn ae one · Debra Oudean Technologist Chevron ..............>...~ ~ IIììjiíJ January 15, 2007 To: Chevron North Arne.EXPloration and Production 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: oudeand@chevron.com sCANNED JAN 1 9 2007 AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 9 "~ \ <6~Z~~}~rl~ PERFORATION RECORD 2.5 OMEGA HSD DEPTH DETERMINATION LOG [GR/CCL ABANDONMENT RECORD 2.5 HSD POWERFLOW SQUEEZE PERF DEPTH DETERMINATION LOG 5 INCH 9/17/2006 2000-7701 GAMMA RAY I CCL 501332056100 SCU 42-05X ARRAY INDUCTION I COMP NEUTRONI FORMATION DENSITYI SONIC IMAGER! GR TVD 501332056100 SCU 42-05X PLATFORM EXPRESS.. ARRAY 5 INCH! 7/8/2006 100-8010 INDUCTION DIPOLE SHEAR SONIC TOOL WI GR 501332056100 SCU 42-05X BOREHOLE CALIPER PROFILE W/GR 501332056100SCU 42-05X 6~~~~i:~~ DEPTH 15 INCH 7/16/2006!7000-7810 501332056100 SCU 42-05X DIPOLE SHEAR SONIC TOOL '5INCH 7/8/20062618-8100 W/GR I ~;~L~vS~EAR SONICIMAGER .r/7/8/2006 2618-8040 'IUL TRA-SONIC IMAGING TOOL I 5 INCH '7I15/2006 2600-8000 ' CEMENTEVALUA TION I GR I I CCL I 1188-0157501332040500 SRU 242-16 PERFORATION RECORD 2.5 5 INCH 8/27/2006 3650-3954 1 1 1 1 PDS, PDF I ----'______ ,,',~"~,..~~_~_,.____.,~~~_~=~gIf'!.ERl~I,~~,~,~~~~,~,',~=~,=~"=".~_.~~,~,~~~,=~,~"~,~~"~~""=~~=~~"J ..,tÞ1331- 199-083 501331012501 SCU 21A-09 - I 161-024 501331011400 SCU41-05 161-024 501331011400 SCU 41-05 I 501331011400 SCU 41-05 1501332056100SCU 42-05X 501332056100SCU 42-05X 5 INCH 8/27/200612000-4032 51NCH 1690-7619 1 51NCH 7/8/20062618-8040 o o 7/8/2006. 2618-8040 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. i Received By: I Date: _ STATE OF ALASKA ALAS"IL AND GAS CONSERVATION COMMI.N REPORT OF SUNDRY WELL OPERATIONS .~\aS\\a Rt:, l,; t:.. \ " ,-- nr\ 2;) 2006 \) \.,;0 , commissiört 1. Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator Name: Repair Well Pull Tubing D Opera!. Shutdown D Plug Perforations ./ Perforate New Pool D Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic D Stimulate Other.j Plug backlrecomplete Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 188-157 . 6. API Number: 50-133-20405-00 . 9. Well Name and Number: SRU 242-16 . 10. Field/Pool(s): Swanson River Field / Beluga / Sterling ExploratoryD Service D Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 26 8. Property Designation: Swanson River Production Facility 11. Present Well Condition Summary: Total Depth measured 4860 true vertical 4025 feet feet Plugs (measured) 4313' & 4012' Junk (measured) Effective Depth measured TOC @ 3967 true vertical 3336 feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 90' 16" 2,337' 9-5/8" 4,830' 7" MD TVD Burst Collapse 90' 2,215' 3,520 psi 2,020 psi 4,005' 7,240 psi 5,410 psi 90' 2,337' 4,830' Perforation depth: Measured depth: 3816' - 3824' True Vertical depth: 3220' - 3226' Tubing: (size, grade, and measured depth) 3-1/2" 9.3#, J-55 4741' Packers and SSSV (type and measured depth) NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 1674 240 0 3388 " 0 0 15. Well Class after work: Exploratory D 16. Well Status after work: OilD Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl o o Tubing Pressure 1100 1116 ' 13. Development 0 Service D Summary of Operations WAG D GINJ D WINJ D WDSPL Sundry Number or N/A if C.O. Exempt: 305-385 D Contact Steve Tyler @ 263-7649 Printed Name Tim Brandenbur Signature ~ . Form 10-404 Revised 04/20 tJ {:? ! Title Drilling Manager Phone 263-7657 Date 10/18/2006 ~\L^ ¡ \I j' RBDMS 8Ft 0 ~i 1. 2006 IÞ'Z7·OG. Su mit Original Only ~(~~6 · . SRU 242-16 Primary Job Type Completion Jobs Primary Job Type Completion ::: Daily Operations 8/22/200600:00 - 8/23/200600:00 Operations Summary RU Slickline. RIH w/2.75" GR. Tag fill @ 4092'. RIH set "82" Tbg Stop @ 4015'. RI set MACCO Pack-off @ 4013'. RI set "G" Stop @ 4012'. Pressure test tbg to 18Dq psi for 30 min. RI dump bailed 2 gals of sand @ 4005'. SDFN. .8/23/200600:00 - 8/24/2006 00:00 Operations Summary , RIH w/2.75" GR on slickline. Tag top of sand @ 4008'. Made (6) runs with dump bailer, Dumping cmt on top of sand. SDFN. WOC 8/27/200600:00 - 8/28/200600:00 Operations Summary MIRU Eline. PUMU 2.5" x 10' (loaded 8') 6spf Power Jet charges. RIH tag TOC @ 3967' tied in to GR/CCL log dated July 241995. Bled tbg pressure to 1070 psi. PU perforate Sterling B5 @ 3816' - 3824'. Tbg pressure went to 1150 psi in 10 sec. POOH. RD Eline. .. FINAL REPORT. ::. Original RKB = 26.0' B-S 3967 B-6 4260 TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Current 8-27-06.DOC SIZE WT 16" 9-5/8" 36 8.921" 9-5/8" 47 8,681" 7 26 Buttress 6.184" Tubiu: 3-112 " 9.3 J-55 EUE 8rd 2.994" JEWELRY NO De tit 1. 26' 2. 4,734' 3. 4,741' 4. 4313' 5. 4012' m 2.994" 3.00" 3.00" Date Zone Top BTM Comments 8/27/06 B-S 3816 3824 2-112" HC 6 spf/60oPowerJetCl1arges 8/23/03 B-6 4064 4066 Isolated 7/24/95 Beluga 4684 4696 Isolated 2,912' 2,927' Squeezed 7/19/95 2,947 2,955 Squeezed 7/19/95 3,150 3,173 Squeezed 7/19/95 3,344 3,370 Squeezed 7/19/95 3,407' 3,427' Squeezed 7/19/95 3,454' 3,464' Squeezed 7/19/95 3,723' 3,753' Squeezed 7/19/95 .<1'" e e ~ "r' Lil llL i'l ~ FRANK H. MURKOWSKI, GOVERNOR AIfASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 \ß'6-IS7 Re: SRU 242-16 Sundry Number: 305-385 ~CMNEC C i 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. Please provide at least twenty-four (24) hours 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. DATED thislUay of December, 2005 Encl. · . 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate ~ / Waiver U - erLJ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Plug Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 back/recomplete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [] I 0 188-157 / Exploratory 3. Address: Stratigraphic 0 Service 0 6. API Number: . PO Box 196247, Anchorage, AK 99519 50-133-20405-00 / 7. KB Elevation (ft): 9. Well Name and Number: 26' SRU 242-16 / 8. Property Designation: 10. Field/Pools(s): Swanson River Production Facility Swanson River Field/Beluga 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): IJUnk (measured): 4,860' 4,025' 4,710' 3,909' 4,710' tagged fill at 4,699' MD Casing Length Size MD / TVD Burst Collapse Structural Conductor 90' 16" 90' 90' Surface 2,337' 9-5/8" 2,337' 2,215' 3,520 psi 2,020 psi Intermediate Production 4,830' 7" 4,830' 4,005' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): ITubing Size: ITubing Grade: Tubing MD (ft): 4,064 to 4,696' 3,410 to 3,898' 3-1/2" 9.3#, J-55 4,741' Packers and SSSV Type: n/a Packers and SSSV MD (ft): n/a , 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: / Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development [] Service 0 14. Estimated Date for Q006 15. Well Status after proposed work: Commencing Operations: Oil 0 Gas [] / Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 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. Bra~enburg ".-7 Title Drilling Manager Signature '-.7= ~C:^ ~ Phone 907-276-7600 Date /2 -fl~ 12/9/2005 // /~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: 305- 32S- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: s"~,q"?J¡;d ~ ~ ~. RBDMS SFl DEC 2 2 2005 APPROVED BY Date: 11- .. '¿, z,,.o( ApPCO"d» //JtM COMMISSIONER THE COMMISSION V 'Lf R , r:\-.-- ~ , A STATE OF ALASKA A ALAW\ OIL AND GAS CONSERVATION COM~ON APPLICATION FOR SUNDRY APPROVALS 20 MC 25 280 w<bŒ: (;ft'ift\lf:u DEC 1 5 2005 AlallKa uu <$4 I.:iil Cons. CommissÎor Form 10-403 Revised 07/2005 Submit in Duplicate · · Pressure test plug to psi MIRU Eline. Arm & PU/MU 8' x 2-1/2" RIH Perforate B-5 sand. POOH. RD E ne HSD PJ Omega. 6 spf, 60° phased gun · · · · · / 1500 ps Bleed pressure to 500 for negative test ncrease to PUMU 2-1/2 Pressure test PUMU 2-1/2" woe for 48 hrs Dump Bailer. Make (1) plug to 1500 psi wI gas Dump Bailer. Make bailer runs bailer run to deposit sand on top of pack-off. Bleed down to original tbg pressure plus to deposit 30' of cmt on pack-off. 1000 · · · RU gas line to tbg. Apply 1300 psi to tbg to blow Ml/Spot and RU Slickline. Test BOPE's / PUMU tbg stop. RIH set @ -4015' on pack-off. 100 psi / POOH. MU & RI wI tbg pack-off. Set on stop tbg dry. Set stop (' SRU 242-16 Work Summary e e Original RKB == 26.0' TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Updated Schematic 08-23-03 Conduct. J-55 8.921 " Surf. 2,170' S-95 8.681" 2,170' 2,337' N-80 Buttress 6.184" Surf. 4,830' 3-112 " 9.3 J-55 EVE 8rd 2.994" Surf 4,741' 1 2 3 4 7-1116" x 3-112" FMC ST/Bore Hanger Halliburton Super Seal Float Collar Halliburton Super Seal Tubing FloatShoe "A" Stop @ 4316', Macco Pack-off & "G" Stop @ 4313' 8/23/03 B-6 4064 4066 2-112" HSD PowerJet, 7/24/95 Beluga 4684 4696 2-112" HC 6 SPF/60deg 2,912' 2,927' Squeezed 7/19/95 2,947 2,955 Squeezed 7/19/95 3,150 3,173 Squeezed 7/19/95 3,344 3,370 Squeezed 7/19/95 3,407' 3,427' Squeezed 7/19/95 3,454' 3,464' Squeezed 7/19/95 3,723' 3,753' Squeezed 7/19/95 REVISED: 4/10103 DRAWN BY: DAS Original RKB == 26.0' TD = 4,860'; PBTD =4,780,' Max hole angle is 44° @ 2,100' SRU 242-16 Proposed 12-06-05 90' 2,170' 2,337' 4,830' Conduct. J-55 S-95 N-80 Buttress 8.921" 8.681" 6.184" J-55 EVE gN 2.994" Surf 4313' REVISED: 12/6/2005 DRAWN BY: DAS about b lank ) ') Steve, A followup to our conversation about SRU Wells today. We have some well pool errors and production allocation isn't correct in our production database or UNOCAL's. We have found some paperwork submitted to us with the wrong pools on the forms and the wrong data was assigned to the wells. We will creat a pool code if the operator indicates production to a new pool. The wells in question are SRU 12-15, SRU 23-22 and SRU 241-16. For each well Bob Crandall would like a discription of the gas pools in the Tyonek, Sterling and Beluga formations. A date or time when these wells produced in specific pool. Illustration of the well with cross sections. We will insert this response into each well file to reduce confusion in the future about these wells and hopefully better explanations will acompany well recompletions and new permits in the future. Steve I :-'> ' - ~JktJ _ r;/ð'V 30') C,Û 86 h ~o J;~:v/..L-L ~ ~JðcJ- ~ &00 tj Be~' ~ ~;11.~ ~¿cJL 1 of 1 11/30/2004 9:35 AM Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCAL(i >.>'~"'.-Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7m Ave, Suite 100 909 W. 9th Avenue Anchorage, AK 99501-3539 Anchorage, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: RU213.10 ~~») 138- tJr1SRU242-16 J 9 J ,- 0 ) i ]SRU 32J\~33 I (ç:3_(X)'1-1~RU 3~-28, J 91../- o<;{5, SRU 41 A-8 COMPLETION RECORD SAFE 1.56 HSD PJ . . .. . ... ... . . . PERF RECORD 111/16 POWER SPIRALS 7.5 SPF , , ' COMPLETION RECORD 111/16 POWER SPIRALS 7.5 'SPF COMPLETION RECORD 2 HSD 6 SPF POWERJET 60 , DEGREE PHASED COMPLETION RECORD 2.5 HSD 6 SPF PJ ¡COMPLETION RECORp ,1.56 HSD PJ 6SPF RESERVOIR SATURATION TOOL_SIGMA MODE ' GAMMÄ RAY eCl 1'.56 POWER JETS 1606 HMX '5INCH RECEIVED ~ ( : Y..l\~\~~\i'\ t~A~~ 1 ~ 200,~ , :'\\...J,n-,\\~ð J-.->-- FEB 2 7 2004 ,t.\Jaska Oil & Gas Cons. Commisekm Þ¡ndwrage of this transmittal or FAX to 907 263-7828. Date: ~~" ~ '~ ~~f"\~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of request Abandon X Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Pull Tubing n Operation Shutdown Plug Perforations Perforate New Pool Perforate X Variance n Stimulate [] Time Extension gl Re-enter Suspended Well [] Annular Disposal [] Other [] 2. Operator Name: Union Oil Company of California/Unocal 3. Address: PO Box 19-0247, Anchorage, AK 995'19 4. Current Well Class Development X Statigraphic [] QQI5. Permit to Drill Number: 88-157 Exploratory 6. APl Number: Service 50-133-20405 7. KB Elevation (ft): 26' 9. Well Name and Number SRU 242-16 10. Field/Pool(s): Swanson River Unit 8. Property Designation: Swanson River Field 11. Present well condition summary Total depth: measured 4,860 Feet true vertical 4,026 Feet Effective depth: measured 4,710 Feet true vertical 3,909 Feet Plugs (measured) CMT Plug at 4,710 MD Junk (measured) Tag fill 4,699' MD Casing Length Size MD TVD Burst Collapse Structural Conductor 90 16" 90 90 n/a n/a Surface 2337 9-5/8" 2,337 2,215 564 2020 Intermediate Production 4830 7" 4,830 4,005 604 5410 Liner Perforation depth: measured 4,684-4,696' true vertical 3,888-3,898' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2, 9.3# ~4,741' 3-1/2 x 7 annulus cemented from 1398-4780' 12. Stimulation or cement squeeze summary Intervals treated (measured) n/a Treatment description including volumes used and final pressure 13 Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl I Prior to well operation I 0 i Subsequent to operation I 0 4. Attachments Daily Report of Well Operations: Casing Pressure Tubing Pressure 11[ 0[420 0 0 1180 15. Well Class after proposed work: [] Exploratory X Development [] Service Oil [] Gas [] WINJ [] WDSLP [] 16. Well Status after proposed work: WAG n GINJ [] 17. I hearby certify that the foregoing is true to the best of my knowledge. Contact: Printed Name: Steve Tyler Signature: .. Sundry Number: Title: Engineering Technician Phone: 907-263-7649 Date: Form 10-404 Revised 2/2003 ORIGINAL UNO(', AL ALASKA RESOUR"" ES WELL SERVICE REPORT Date: Work being done: Supervisor: Wireline Unit Number: Tree Valve Condition Fluid Level if Identified Zero Wireline at: Minimum Tubing ID: Start Tbg. & Csg. PSI 8/20/2003 Dump Cement Glynn Brown Top Kick Tubing Hanger 2.99" Well Number Location: AFE# I Charge Code: Pollard Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: Ending Tbg & Csg PSI Time Operation Details 07:00 Arrive in Field, check in, travel to location 07:15 Safety meeting: Communication 07:30 R/U, P.T. WLV & Lub, discuss job w/Company Man 08:00 Pressure up well to 650 PSI, RIH w/2.75 GR to 4313' KB, POOH 08:45 Cut 25' of wire, test - 21, 21, 20, change up Tool String 09:15 RIH w/13' x 2.25 Dump Bailer to 4300' KB, dump, POOH, repin & reload 10:00 RIH w/same to 4290' KB, dump, POOH, repin & reload 10:45 RIH w/same to 4280' KB, dump, POOH, repin & reload 11:30 RIH w/same to 4280' KB, dump, POOH, repin & reload 12:15 RIH w/same to 4275' KB, dump, POOH, repin & reload 12:50 RIH w/same to 4270' KB, dump, POOH, repin & reload 13:30 RIH w/same to 4260' KB, dump, POOH 14:30 R/D, secure well, wash cement off Tools, fuel equipment, park @ Bull Rail 17:00 Travel to Shop Tool Cost: 2.25 Dump Bailer $150.00 2.75 Gauge Ring $50.00 SRU 242-16 Swanson River AFE # 161194 Barrow/Smith/Calkins 12.98 4313' 26' 2.75" Work String Detail:l(1 1/2" TS) RS, K J, 5' Stem, K J, O J, Spangs, KJ Description of any None tools or debris left in the hole: Brief Summary of Tagged Packoff @ 4313' KB Total Work Dumped 15 gallons of cement on Plug Completed Total Hours Worked 12 Total Tool Cost $ 200.00 Total Hour Cost $ 2,080.00 Ticket Daily Cost: Well Downtime Hr. Shut in Approved by' P-10120 I 2,280.00 12 H2S PPM 0 Day # '1 1 Cumulative Cost:l $ 2,280.00 Wire Test 21, 20 Code: AFE# 161194 8/23/2003 j _. From j To,l Shut dn for crew rest i!i::;,::::ii:,.::::ii::i'ii:.i::::~i;.~'. ~;:?~i~:!!.~::i~:;:':~:,:~ili:?i~iii~:~ Attend simops wi production @ plant go over days plan wi peri: jobs & coil job !?i?:?:ii'iiiiiiii:i:?:i.~ii:;;~i:J~:!?ii!!i?i:::i:.!~::!~ii:;~i~:: Rerf SRU 2'13-'10 (see report) & move to $RU 242-'16 i~'!.:?:.::~.~d.i.;!.~ij!:::~.:.~iE.ii?ii:~::;~:!;~:. Perf safety meeting & chk list P/up 10' gun 2.5" HSD Power Jet hollow carrier w/top 2' loaded, middle 4' blank & btm 4' loaded wi 6spf @ 60 deg phasing Pressure test lubricator 250 / 2200 psi (ok) ::':::.i:.::.:...~::'~;i::.~j:'i';:i:':'i:.ii!:ii;:i:i.:::i~!'~:!i';~:.: Rih & tag fluid level @ 1080' & PBTD @ 4227.8' Pull tie-in pass t/3590' rih & place gun on depth & perf B-6 sand f/4064' t/4066' & b-6 sand f/ L/dn & chk gun (all shots fired correctly) rig/off well & turn well over to production Production began unloading well SlTP= 770 psi, initial numbers after unloading water 2.2mmcfd (~ 990 psi & SWS continued r/dn & clean up, page 1 Swanson River Field Well #: SRU 242~16 Curren~ Completi(m: 8/23/(~3 Original RKB = 26.0' CAS1NG AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 16" Conduct. Surf. 90' %5/8" 36 J-55 8.921" Sure 2,170' %5/8" 47 S-95 8.681" 2,170' 2,337' 7 26 N-80 Buttress 6.184" Sure 4,830' Tubi[~g: 3-1/2" 9.3 3-55 EUE 8'd 2.994" Sorf 4,741' JEWELRY NO Depth ID Item 1 26' 2.994" 7-1/16' x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) 2 4,734' 3.00" tlalliburton Super Seal Float Collar 3 4,741' 3.00" Halliburton Super Seal Tubing Float Shoe 4 4313' "A" Stop (a 4316', Macco Pack-off & "G' Stop (t~ 4313' Perforations Date Zone BTM Comments Top 8/23/03 B-6 4064 4066 2-1/2" HSD PowerJet, 6spf/60 deg 7/24/95 Beluga 4684 4696 2-1/2" HC 6 SPF/60deg 2,912' 2,927' Squeezed 7/19/95 2,947 2,955 Squeezed 7/19/95 3,150 3,173 Squeezed 7/19/95 3,344 3,370 Squeezed 7/I 9/95 3,407' 3,427' Squeezed 7/19/95 3,454' 3,464' Squeezed 7/19/95 3,723' 3,753' Squeezed 7/19/95 Fish/Fil!l lnformatiom A, Tag TOC with GR/CCL (~[ 4~710'; 7/24/95. B. Calculated top o~'cemen~ in ammlus ~s (b~ 1~398'. C. Baker shear oat ph~ and 1-1/2" ~as lift valves, 4,860'; PBTD :4,780,' hole angle is 44: (a 2, ti)0' SRU 242-16 Updated Schematic 08-23-03 REV [SED: 4,.I 0."03 DRAWN BY: [)AS UNO AL ALASKA RESOUR' ES WELL SERVICE REPORT Date: Work being done: Supervisor: Wireline Unit Number: Tree Valve Condition Fluid Level if Identified Zero Wireline at: Minimum Tubing ID: 8/19/2003 Set Plug Glynn Brown Top Kick Tubing Hanger Well Number Location: AFE# I Charge Code Pollard Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: SRU 242-16 Swanson River AFE # 161194 Barrow/Smith/Sparhawk 6.6 4426' 26' 2.99 2.84" Start Tbg. & Csg. PSI Ending Tbg & Csg PSI Time Operation Details 08:00 Arrive in Field, check in, discuss job 08:30 Do Field Orientation, travel to location 09:15 Safety meetin~l:Hand Signals 09:30 Spot equipment, test wire: 21, 21, 21, repack Stuffing Box R/U, P.T. WLV & Lubricator 10:30 RIH w/2.84 GR to 2450', work to 2608', work to 2730, work to 4380', set down in heavy Fluid 4426', POOH, discuss options 12:15 RIH w/3" DD Bailer to 4300' KB, try to set, POOH w/same 14:30 RIH w/3" SB & A-Stop, set @ 4316' KB, POOH 15:15 RIH w/3" GS & Macco Packoff to 4314' KB, set, POOH, Tubing pressure @ 550 16:00 R/U 1/2 Pressure Hose, pressure up Lub to 600 PSI 16:50 RIH w/3" GS & G-Stop to 4313' KB, set, POOH 17:50 R/D, secure well 19:00 Travel to Shop NOTE: G-STOP & PLUG PARTS ON SEPARATE TICKET Tool Cost: 3" SB $100.00 3" GS $200.00 2.85 Gau~le Ring $50.00 Work String Detail:l(1 1/2" TS) RS, K J, 10' Stem, K J, O J, SJ Description of any None tools or debris left in the hole: Brief Summary of Tagged heavy fluid @ 4426 Total Work Set Stops & Macco Plu~l @ 4316 Completed fotal Hours Worked 12 Total Tool Cost $ 350.00 Total Hour Cost $ 2,080.00 Ticket Daily Cost: Well Downtime Hr. Shut in Approved by' P-10116 2,430.00 12 H2S PPM Day # :1 1 Cumulative Cost:I $ 2,430.00 0 Wire Test 21, 21, 21 Code: AFE# 161194 SRU 242-16 P&A and Recompletion Subject: SRU 242-16 P&A and Recompletion Date: Mon, 18 Aug 2003 16:17:22 -0800 From: "Tyler, Steve L" <tylerslHunocal.com> To: "Aubert, Winton w/AOGCC" <winton_aubertHadmin.state.ak.us> CC: "Smetanka, Jeff W" <smetankajHunocal.com>, "Harness, Evan" <eharnessHunocal.com>, "Kn~eger, Philip J -Alaska" <plcruegerHunocal.com> Winton During our prep work for the abandonment of 242-16 Beluga sand, we found top of fill at 4350' SLM. Subsequent attempts to bail this fill proved to be unsuccessful. Unocal proposes to investigate setting the abandonment plug above 4350' instead of the planned depth of 4655'. We'll follow up the results of our P&A and recompletion of the Sterling gas sand in the 10-404 post job report. Please contact me if you have any questions. Thanks Workover Foreman / Engineering Tech Unocal Alaska ~Office: (907) 263-7649 ~Cell: (907) 350-6295 ~Home: (907) 696-1837 !' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator UNOCAL of Alaska 3. Address PO Box 196247 Anchorage AK 99519 4. Location of well at surface 2267 FNL, 971 FWL, Sec 15, T8N, R9W, SM At top of productive interval 2268 FNL, 501 FEL, Sec 16, T8N, R9W, SM At effective depth At total depth 2149 FNL, 1431 FEL, Sec 16, T8N, R9W, SM 5. Type of well: Development: X Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) '26 7. Unit or Property name Soldatna Creek Unit 8. Well number 242-16 ' 9. Permit number 88-157 ~ 10. APl number 50- 133-20405 11. Field/Pool Swanson River Field/Beluga feet 12. Present well condition summary Total depth: measured true vertical 4860 feet Plugs (measured) 4025 feet Effective depth: measured 4710 feet Junk (measured) true vertical 3909 feet Casing Length Size Cemented Structural Conductor 90 16 Surface 2337 9 5/8 756 SX Intermediate Production 4830 7 325 SX Liner Perforation depth: measured 4684-4696 true vertical 3888-3898 Tubing (size, grade, and measured depth) 3 1/2, 9.3#, 4741 Packers and SSSV (type and measured depth) 3 1/2 X 7 annulus cemented from 1398-4780 CMT Plug at 4710 MD Tag fill '4699 MD Measured depth 9O 2337 4830 True vertical depth 90 2215 4005 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for'Comr~encing operation ~/7-26,,~ or ASAP ~' 16. If proposal w I~...~ally approved: Name of approver Date approved 15. Status of well classification as: Oil: Gas: X Service: Suspended: 17. I hereby certify that the fo correct to the best of my knowledge. Signed:/"' n ! ~7,,¢,..t....,~. . Title: Drilling Engineer Date: FOR COMMISSION USE ONLY Conditions of approval: Not~,Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- .~,O'~ Approved by order of the Comn'iiss'i~ner Commissioner Date Form 10-403 Rev 06/15/88 SCANNED AUg 0 8 2.00,3 Op' SUBMIT IN TRIPLICATE SRU 242-16 Proposed Recompletion (7-21-2003) , Objective: Abandon Beluga sand 38-4 at 4684-4696 MD and recomplete in B6 sand at 4064-4066, 4070-4074 MD. j' Procedure: 1. Set Macco tubing packoff assembly with slickline in 3 ½ tubing at 4188 +/- feet. (three runs consisting of lower stop, packoff, upper stop) 2. Pressure test. 3. Dump bail sand on top of packoff assembly. 4. Dump bail 30 feet of cement on top of sand. '/' 5. Pressure test positive and negative and RIH with slickline to confirm cement has set,~l~. 6. Adjust tubing pressure to 1000 psi for 0-250 psi drawdown on B6 sand. /' 7. RIH with eline and make GR/CCL correlation log. 8. RIH and perforate B6 sand at 4064-4066 and 4070-4074 MD. 9. Initiate production testing. Well Schematic: Attached Schedule: Work planned for 7-26-03 or ASAP UNOCAL Swanson River Field Well #: SRU 242-16 Actual Completion: 7/16/03 (Proposed' Recompletion to B6 Zone) Original RKB = 26.0' CASING AND TUBING DETAIL S1ZE WT GRADE CONN ID MD TOP MD BTM. 16" Conduct. Surf. 90' 9-5/8" 36 J-55 8.921" Surf. 2,170' 9-5/8" 47 S-95 8.681" 2,170' 2,337' 7 26 N-80 Buttress 6.184" Surf. 4,830' Tubing: 3-1/2" 9.3 J-55 EUE 8ra 2.994" Surf 4,741' NO Depth ID 1 26' 2.994" 2 4,734' 3.00" 3 4,741' 3.00" JEWELRY item 7-1/16" x 3-1/2" FMC ST/Bore Tbg Hanger (EUE 8rd) Halliburton Super Seal Float Collar Halliburton Super Seal Tubing Float Shoe Date Zone 7/24/95 Beluga Perforations Top BTM Comments 4684 4696 To Be Squeezed 2,912' 2,927' Squeezed 7/19/95 2,947 2,955 Squeezed 7/19/95 3,150 3,173 Squeezed 7/19/95 3,344 3,370 Squeezed 7/19/95 3,407' 3,427' Squeezed 7/19/95 3,454' 3,464' Squeezed 7/19/95 3,723' 3,753' Squeezed 7/19/95 Cement and FH~Information: A. Tag TOC with GR/CCL ~(4,.',.~1/0~7/24/95. B. Calcula/tedTgp of cement in-~i~nulus is ~ 1,398'. C. Fill at(~,69~on 4/4/03 with 2.70 GR TD = 4,860'; PBTD =4,780,' Max hole angle is 44° ~ 2,100' PROPOSED: 7/16/03 DRAWN BY: DEA Unocal Energy Res,_ · I' on 909 West 9th, P.O. ,5,~;-. ,9~ Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCAL Debra Childers Clerk DATA TRANSMITTAL 96- 1 Januaw 11,1996 To: Larry Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas IFrom: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Swanson River 242-16 blueline/sepia Thermal decay time log Granite Point 18742-7RD#2 blueline/sepia Mudlog Granite Point 22-13 RD blueline/sepia Phasor Induction/SoniC/GR Granite Point 22-13 RD blueline/sepia Mudlog Granite Point 22-13 RD tape/listing LIS tape Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received by: Date: STATE OF ALASKA ALASk ,IL AND GAS CONSERVATION COME, ION WELL COMPLETION OR REOOMPLETION RI::PORT AND LOG i. Status of Well Classification of Service Well OIL {~ GAS [~ SUSPENDED ~ ABANDONED~-] SERVICE G 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 88-157/95-124 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 50-133-20405 4. Location of well at surface 9. Unit or Lease Name , , .... .~ ~[ SWANSON RIVER UNIT i 10. Well Number , SRU 242-16 11. Field and Pool . SWANSON RIVER FIELD Tyonek/Hemlock Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 26'I A-028077 22. Type Electric or Other Logs Run 23. CASING, UNER AND CEMENTING RECORD I FT. SE'I-rING DEPTH MDI' CASING SIZE WT. PER GRADE TOP , BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" O' 90' 0 9-5/8" 36/47 J55/S95 26' 2337' 12-1/4" 756 sx 0 7" 26 NSO 26' 4830' 8-1/2" 325 sx 0 3-1/2" 9.3 J55 26' 4743' 6.276" 435 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE ] DEPTH SET (MD) I PACKER SET (MD) 4684'-4696' MD 3867'-3879' TVD 3-1/2" 4741' No packer 6 SPF 2-1/~' Hollow Carrier TBG cemented in place 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 3344-3370 435 sx of premium cmt was used to squeeze 3407-3427 perfs and to cement 3-1/~" tubing in place 3454-3464 3723'-3753' 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 7/29/95I Flowing Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/17/95 24 TEST PERIOD NA 1212' 0 8/64I NA FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 1400 0 24-HOUR RATE NA NA NA NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '"'-- "t D .L. ,.I.I v S EP 20 1995 Alaska O, & Gas Cons, Comm_Jss '. gnchoragt" Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. -- ,. 31. LIST OF ATTACHMENTS Wellbore Diagram, Workover operation daily summary , 32. I hereby certify that the foregoing is true and correct to,~r~e best,~ ~my knowledge Signed O, RUSSELLSCHMIDT T~e DRILLING MANAGER Date ~ _ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 .' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Subrn_er§jble~/~qt~r [rl~ jection, Gas Injection, Shut-in, Other-explain. ~i ['. ,, L~ I '~ ~L) Item 28' If no cores taken, indicate 'none'. S EP 2 0 1995 Alaska Oil & Gas Cons. Commission Spud: 8 18 89 Completed: 8/28/89, Lost Workover: 7'/20/95 SRU 242-16 Swonson River Field APl No.: 50-1,55-2040540 "r~of Hemlock: Ft. MD ~,,~e ~ Perfs: 41 Deqs. Honger: F~C 26.1 - I00.0' 16" OD CgG 99,0-100.0' SHOE 26.1-2170.0'95/8" OD 36.~/fl,l-55 SURF CS(; 2170.0-2535.0' 9 5/8" OD 47.~/fl S-95 SIJ~F CSG ~98.0- ~000.0' CEUEU]' 7/20/95 Cot,~, ~OC 2,.555.0 - 2555.0' SHOE ~.0- ~70.0' ~[[z[ ~ 8..-0, ~, 2~', 8/~ 3407.0- 3427.0' SQUEEZE ~ B-O, 8tlPF', 20', 8/89 34.54.0 - 3464.0' ~EF7F PERFS B-l, 8HPF, llY, 8/89 J72J.O - J75,t.0' SQU~ ~ B-,l, ~PF, ~, 8/89 26.0 - 26.5' HANGER ~C Hgr. ~0.0- 4743,1' CFMEN]' 7/20/95 4741.9 - 4860.0' ~ PLUC 47/9.0 - 4780.0' BAR FISH 1 1/2" Circ Volve W/1 5/8" RK Lotch 26.0 - ,1831.0' 7"0D 26.~/ft J--5.5 UNF. R 26,0-4743.1' 3.500" OD 9.50]/ft 8rd AB Mod 'IgC 4684.0-4696.0' PERFS Belugo 7/24/95 4685.0 - 4696,0' PERFS 7/2q95 47~.9 - 4735,9' FLCOIIAR Howco 4741.9 - 47d,1' FLOAI'SIiO[ Ho, co Ges Well 'rbg. Cemented In Ploce S£P 2 0 1995 Alaska Oil & Gas Cons. Commission Anchorage SCU 242-16 DAY 1 (06/19/95) 9-5/8" (~ 2335' 7" @ 4831' CHECK WELLHEAD PRESSURE: TBG = 840 PSI. ANN = 600 PSI SURF - 100 PSI. CLOSE MASTER VALVE. BLEED OFF WELL HEAD. MASTER HOLDING. REMOVE TREE WING VALVES AND FLOWLINE FROM TOP OF MASTER. INSTALL TREE CAP. SEND TREE TO IISCO FOR INSPECTION. DAY 2 (06/20/95) 9-5/8" ~ 2335' 7" @ 4831' TBG=825 PSI, ANNULUS-555 PSI. PUMP LCM PILL & DISPLACE W/27 BBLS OF LEASE H20. TBG-100 PSI. BUILT TO 510 PSI. DAY 3 (06/21/95) 9-5/8" @ 2335' 7" @ 4831' TBG=400 PSI & ANNULUS=Il0 PSI DAY 4-7 (06/22-24/95) 9-5/8" @ 2335' 7" @ 4831' D.C. $ 0 CUM: $ 0 AFE: $ 255,000 AFE # NO REPORT AVAILABLE. S EP 2 0 ~995 Alaska.Wi.& Gas Cons. Commission ~ 'A~chorage WELL PREP WORK RIG UP HALLIBURTON AND TEST LINES TO 3000 PSI. BLEED CASING PRESSURE TO 0 PSI. AND BULLHEAD 90 BBLS DOWN THE TUBING AT 2 BBLS/MIN AT 600 PSI. PRESSURE BUILT TO 200 PSI. RUN A 2.8" GAUGE RING. RUN, SET AND TEST A PXN PLUG AT 3242' TO 3000 PSI. ATTEMPT TO PULL BK GLM AT 2767' TO CIRCULATE ANNULUS. COULD NOT PULL. R/D WlRELINE AND HALLIBURTON. TUBING PRESSURE 0 PSI, CASING PRESSURE 0 PSI. DAY 2 (07/10/95) CHECK ANNULUS PRESSURES. NOTED 5- 10 PSI OF GAS ON ANNULUS. BLED OFF SAME. PULL BPV. REMOVE TREE M/U 3 1/2" 8RD SUB IN HANGER WITH A CAMERON TYPE H PROFILE. SET 2 WAY CHECK VALVE. NIPPLE UP BOP. R/U SLICKLINE. TEST LUBRICATOR TO 4000 PSI. RIH AND PULL PRONG AND PLUG FROM PX NIPPLE. R/D WlRELINE. TUBING PRESSURE 450 PSI. DAY 3 (07/11/95) MIX A 15 BBL LCM PILL. BULLHEADED INTO FORMATION. PRESSURE BUILT TO 350 PSI. FILL ANNULUS WITH 6 BBLS. MIX A 60 BBL LCM PILL. HOLD 800 PSI AGAINST FORMATION WITH LCM ACROSS PREFS. BLEED OFF PRESSURE. 50 PSI AT SURFACE. R/U COILED TUBING UNIT TO CLEAN OUT THE FILL IN THE CASING BELOW THE TUBING TAIL. PRESSURE TEST THE COILED TUBING BOP'S. RIH WITH JET NETTLE ON THE COILED TUBING AND WASH DOWN DAY 3 (07/12/95) COMPLETED MIXING 275 BBLS OF FLOW VIS COMPLETION FLUID. DISPLACED TUBING AND BEGAN WASHING DOWN FROM 3400'. TAGGED SOLID FILL AT 3417' WASHED DOWN TO 3445'. UNABLE TO WASH DOWN PAST 3445' CTM. POOH WITH COILED TUBING. CHANGED OUT LANDING JOINT. MADE UP 2.25" FLAT BOTTOM MILL ON 2 1/8" BAKER MUD MOTOR AND RIH. CLEANED OUT FROM 3440' TO 3450' AND LOST ALL RETURNS. POOH WITH THE MUD MOTOR. ATTEMPTED TO ESTABLISH ERTURNS AT 2500' WHILE POOH. NO RETURNS. RJU TO PUMP DOWN THE TUBING AND MIXED AN LCM PILL. PUMPED A 60 BBL PILL. DISPLACED WITH 53 BBLS FLOW VIS SEP 20 1995 Alask~ Ull & Gas Gens. Gommission : ~JlCtloraaa WITH NO PRESSURE BUILD UP NOTED. BEGAN MIXING GEL MUD SYSTEM. DAY 4 (07/13/95) ACCEPT RIG AT 06/10/95 @ 00.00 HRS. COMPLETED MIXING 300 BBLS OF GEL MUD. MIXED 50 BBLS LCM PILL. PUMPED PILL AND DISPLACED WITH 28 BBLS GEL MUD. SURFACE TUBING PRESSURE INCREASED TO 375 PSI. R/U COILED TUBING. PRESSURE TESTED COIL TUBING LUBRICATOR TO 4000 PSI. DISPLACED COIL TUBING TO GEL MUD AND BEGAN RIH WITH COILED TUBING. UNABLE TO CLEAN OUT PAST 3447'. POOH WITH WASH NO7?LE. MADE UP BAKER MOTOR ON COILED TUBING AND RIH. CLEANED OUT TO 3750'. LOSSES AT 10- 15 BBLS/HR. POOH CIRCULATING THE WELL CLEAN. PREPARED TO PULL TUBING. TUBING DEAD. CASING AT 40 PSI. ATTEMPT TO BLEED OFF PRESSURE. 2" OIL STREAM OUT OF CASING ANNULUS. SHUT IN WITH A STABILIZED PRESSURE OF 140 PSI. R/U TO PRESSURE TEST CASING SIDE TO 1200 PSI. TESTED OK. BLED DOWN ANNULUS TO ZERO PSI. BACKED OUT TIE DOWN BOLTS. PULLED HANGER OFF SEAT AND FILLED THE ANNULUS. FLUID LEVEL STATIC. PULLED SEALS FROM THE PACKER AND THE HANGER TO THE FLOOR. WELL FLOWING ON ANNULUS SIDE. TUBING ON VACUUM. SHUT IN WELL. 200 PSI ANNULUS, 0 PSI TUBING. STARTED DISPLACING THE ANNULUS TO GEL MUD. DAY 5- 7 (07/14/95- 07/16/95) CONTINUE DISPLACING THE ANNULUS TO GEL MUD MAINTAINING CONSTANT DPP. CHECKED FO FLOW. WELL FLOWING. SHUT WELL IN, 75 PSI BOTH SIDES. BUILT SURFACE VOLUME AND CONDITIONED MUD. WELL PRESSURE BLEED TO 0 PSI BOTH SIDES. FILLED WELL WITH 9 BBLS. CIRCULATED BOTTOMS UP THRU' CHOKE. OPEN WELL OBSERVE. WELL STATIC. PREPARE TO PULL TUBING. PULL TUBING TO SURFACE. REPAIR BOP CONTROLS. RIH WITH DRILLPIPE AND PACKER RELEASE TOOL. RELEASE PACKER AND PULLED UP THE HOLE 90 FT. ANNULUS SIDE FLOWING. SHUT WELL IN. ANNULUS PRESSURE OF 500 PSI NOTED. R/U TO SHOOT PERFS IN DC. MANAGED TO GAIN CIRCULATION WITH THIRD SET OF GUNS RUN IN THE HOLE. CIRCULATED ANNULUS CLEAN. WELL STATIC. POOH WITH PACKER. RIH WITH DRILLPIPE AND BIT TO CLEAN OUT THE~,r~' '- ~ E .~ CASING. TAGGED FILL AT 3710' CLEANED OUT FILL TO 3997'. "... ~ ~ SEp 2 0 1995 Ct/ora9~, Cor~r~i$$io~ DAY 8 (07/17/95) ACCEPT RIG AT 06/10/95 @ 00.00 HRS. CONTINUED TO CLEAN OUT FILL TO 4372'. (MAINLY SAND IN RETURNS). BEGAN PUSHING JUNK AT 4622'. CONTINUED TO CLEAN OUT TO 4712'. UNABLE TO CLEAN OUT PAST 4712'. CONDITIONED MUD TO REDUCE SAND CONTENT. POOH. HOLE STILL TAKING SMALL AMOUNTS OF FLUID. TEST BOP'S. DAY 9 (07/18/95) COMPLETED WEEKLY BOP TEST. M/U BHA #3 WITH JUNK MILL AND JUNK BASKETS. RIH WITH MILL ASSEMBLY TO 3372'. HIT A TIGHT SPOT AT 3372'. PICKED UP THE KELLY TO WORK THRU TIGHT SPOT. CONTINUED TO RIH. CLEAN OUT FROM 4712' TO 4739'. NOTED RUBBER IN RETURNS INDICATING THAT THE WELL HAD BEEN CLEANED OUT TO THE TOP OF THE FLOAT COLLAR. SPOTTED A 600 BBL HIGH VIS PILL ON BOTTOM. POOH LAYING DOWN DRILLPIPE. DAY 10 (07/19/95) ACCEPT RIG AT 06/10/95 @ 00.00 HRS. CONTINUE POOH LAYING DOWN DRILLPIPE. RJU SCHLUMBERGER AND RIH WITH TDT LOG. LOG INTERVAL FROM 4728' TO 1950'. POOH WITH TDT LOG. R/D SCHLUMBERGER. R/U AND RUN 3 1/2" TUBING STRING. DAY 11 (07/20/95) ACCEPT RIG AT 06/10/95 @ 00.00 HRS. CONTINUE RUNNING TUBING STRING. SHOE SET AT 4733.27' TUBING MEASUREMENT (1.57' OFF BOTTOM). CIRCULATE BOTTOMS UP. R/U HALLIBURTON AND START CEMENTING THE 3 112" COMPLETION STRING WITH 30 BBLS LEASE WATER, 20 BBLS FRESH WATER WITH NALCO 3900. PUMP 84 BBLS OF 15.8 PPG CEMENT AS PER RECIPE. DISPLACED WITH 42 BBLS LEASE WATER AND BUMPED PLUG. FULL RETURNS NOTED THROUGHOUT CEMENT JOB. CIP 05.00 HRS. FLOAT VALVE HOLDING. R/D HALLIBURTON. POOH WITH LANDING JOINT. SET BPV. NIPPLE DOWN BOPS. N/U TREE. TEST TREE TO 250 AND 3000 PSI. RELEASE RIG AT 1800 HRS. START RIG MOVE TO 13-4. SE.~ ~0 1995 WELL SRU 242-16 DAY 12 (07/24/95) RU SCHLUMBERGER WLU. NU LUB AND TEST. OK. RIH WITH 2-1/2" HOLLOW CARRIER 6 SPF 60 DEG PERF GUN. PERFORATE THE BELUGA @ 4684'-4696'. POOH WITH HOLLOW CARRIER. RD WLU AND TURN WELL OVER TO PRODUCTION. Gas Cons, ~mmi~io~n WELL SERVICES, INC. 3111 c STREET, SUITE//303 ANCHORAGE, ALASKA 99503 (907) 561-7458 FAX: (907) 563-8347 July 20, 1995 Mr Blair Wondzell PI Supervisor State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr Anchorage AK 99501 Dear Si r: I received a facsimile copy of a memorandum from Mr Dan Williamson, UNOCAL Drilling Superintendent, regarding Alaska Well Services Rig #5 BOP test report dated 7/10/95. To set the record straight, this Rig is not an old Rowan Rig which was in Beluga for several years. It is a Roll'n Alaska Rig and was in Beluga from November, 1988 and completed operations in December, 1988. Because of ice conditions, it was not barged back to Kenai until March, 1989. In the summer of 1993,. we did barge the Rig back to Beluga for approximately 40 days of work, then was barged back to Kenai. Both times the Rig was under contract to ARCO. What concerns me is that if there were any problems concerning any of the BOPE why we were not made aware of them so they could be rectified. We feel that the BOP equipment on a Rig is of utmost importance and strive to keep i t i n top operating condition. In the past we have always complied and rectified any deficiencies the Petroleum Inspectors have encountered. The Rig has been in service, in Alaska, since February, 1987. Why did it take eight (8) years to discover an improper valve on the choke manifold? (schematic of AWS choke manifold enclosed wi th valve in question marked wi th X) Our maintenance program is beyond what the board requires. In 1993 the BOP equipment was inspected and found to be marginal in tolerances. The BOP was replaced with a certified BOP. The annualar was taken in and inspected rebuilt as required and recertified also. In October, 1994, we purchased a new single gate which was required by UNOCAL to have three (3) sets of rams on wells that are worked over. (SRU 242-16 only had two (2) gates on because of height of well head and there was not enough room under the table beams. When the BOP lines were hooked up, the crew inadvertantly hooked up lines that function the gate that was not on, to the gate that was installed) Mr Blair Wondzell July 20, 1995 Page 2 In May, 1995, the BOP's were again dismantled, inspected and recertified prior to commencement of operations for UNOCAL. The choke manifold was pressure tested and repaired as required and a new gas buster was built and installed as per UNOCAL specs. The vacuum degasser was removed because of space on the mud pits and we were under the impression that only water would be used for the work to be performed on the wells at this time. The components of the degasser were inspected, repaired as required and will be installed on July 21, 1995 prior to moving on to the next wel 1. Invoices and documentation of certification will be provided at your request. The Rig activity has not been such that we can justify making the Rig look pretty; however we do keep the equipment in top mechanical condition. Our Company has always strived to be best in what we do. We have not had an LTA since 1989 and hope to add many more years to our record. We did not do this by running junk as implied by Mr Grimaldi. There are also some conflicting observations recorded during the inspection. In one inspection report, Mr Grimaldi rates the drilling rig as OK. In another report, at the same time,, he rates it as poor. I would like to schedule a meetin§ wi th you at your convenience to discuss this further. Please call if you have any questions or comments. Phil Snisarenko Operations Manager kjs Enclosures: Drawing #3348 AWS Rig #5 Choke Manifold AP I RP 53 5m Choke Manifold 2 Inspection Reports cc: Dan Williamson UNOCAL Corporation ALASKA WELL SERVICES RIG #5 46 m MANIFOLD IS DESIGNED WITH 3 1/8" x 5000 SHAFFER TYPE B THROUGH LINE AND SHAFFER 2 1/16" X 5000 TYPE B SIDES. THE CHOKES ARE TRI FLO 3" x 10,000 2" ORIFICE HYD. 2" x 5,000 1" ORIFICE MAN. ¥~W AA DRWG. NO. NWS- 1/87 R£F. DT. NO. 3348 American Petroleum Institute ADJUSTABLE CHOKE--x m _TO PIT AND/OR MUD/GAS SEPARATOR~:VERBOARD W '' ~BLOI,~OUT PREVENTER ~u~,~ / x (~ ~JTACK OUTLET "'~_ FN~E~ i~ ~ ~ TO PII ~uND/OR MUD/~$ SEPARAIOR/O¥[RBOA~D ADJUSTABLE CHOKE-~/' FIG. 3.A.1 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 2M AND 3M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION ADJUSTABLE CHOKE- TO PIT AND/OR SEPARATOR Z'- 2" NOMINAL lARD PREVENTER STACK OUTLET OPTIONAL OPERATED VALVE ~"NOMINAL-- BLEED LINE,To PIT/ = ~'(\OVERBOARD TO PIT AND/OR MUD/GAS SEPARATOR/OTBOARD '~ '~ 2" NOMINAL ~REMOTELY OPERATED OR ADJUSTABLE CHOKE FIG. 3.A.2 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 5M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION / ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, OOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 19, 1995 Mr. G. Russell Schmidt Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 Re: Degasser Variance for Well SRU 242-16, Swanson River Field Dear Mr. Schmidt: This is in response to your July 13, 1995 letter to Commissioner David Johnston and confirms my verbal approval to you on July 17, 1995 regarding a variance to perform remedial work on Swanson River Field well SRU 242-16. We concur work as approved and as outlined in your letter may be safely performed on subject well without the use of a vacuum degasser., Therefore, your requested variance is approved. Sincerely, PI Supervisor cc: Lou Grimaldi abvarsrf G. Russell Schmidt Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL ) Monday, July 17, 1995 Mr. David Johnston AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 VACUUM DEGASSER ON ALASKA WELL SERVICES RIG NO. 5 Dear Commissioner Johnston: On July 13, 1995 Unocal sent a variance request to waive the requirement of a vacuum degasser on Rig No. 5 for well SRU 242-16. This was granted. Unocal also has reviewed the need for the vacuum degasser for future wells in Swanson River and has instructed the contractor to re-install it upon completion of well SRU 242-16. Thank you for your cooperation in this matter. G. Russell Schmidt Drilling Manager CC: Blair Wondzell Lou Gdmaldi GRS/leg RECEIVED JUL '19 'i995 Oil & Gas Cons. Commission Anchorc. :; G. Russell Schmidt Drilling Manager / · UNOCALe Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 JUL 1 7 1995 Oil & Gas Cons. Commission Thursday, July 13, 1995 Mr. David Johnston ICOMM . 'COMa RES ENG SRENG , , NRO ~SR GEOL GEOL ASST 'STAT TECH, ~STAT TE!~'H; -- , , , FILE · : ? ,, i ,~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Variance of Requirement of a Vacuum Degasser For Well SRU 242-16, Swanson River Field Dear Commissioner Johnston, On July 11, 1995, Mr. Lou Grimaldi of AOGCC inspected Alaska Well Services Rig No. 5 which is currently working over Well SRU 242-16. During the inspection Mr. Grimaldi noted deficiencies in a line to the gas buster, a valve, and the need to install a vacuum degasser. The line and valve issues have been rectified. Unocal respectfully requests a variance to the requirement of installing a vacuum degasser to be used for SRU 242-16. This variance is requested for the following reasons: . . . o Well SRU 242-16 is a shallow Iow pressure gas well (see attached schematic), the existing "poor boy" degasser should be adequate to separate the gas from the viscosified brine if gas becomes a problem. The pit volume is 450 bbls, the hole volume to the perfs is only 160 bbls. There should be adequate retention time in the pit to allow for gas break out. Since this is a workover the well can be shut-in at any time and the pits circulated to break out gas. In the recent workovers at Swanson River clear brines or lease water have been used exclusively so the old vacuum degasser was removed to make room for the new 'poor boy' degasser. LETTER COMMISSIONER JOHNSTON JULY 13, 1995 PAGE2 It is understood that this variance is for SRU 242-16 only. As discussed with Mr. Blair Wondzell by Dan VVilliamson, Unocal will review the need for a vacuum degasser for future work at Swanson River and will contact your office concerning this review before the completion of the SRU 242-16. G. Russell Schmidt Drilling Manager cc Dan Williamson DRW/leg MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, Chairman _ DATE: July 10, 1995 THRU: Blair Wondzell, ~ FILE NO: P. !. Supervisor -r~=)',;,~ FROM: Lou Grimaldi, /~'~ SUBJECT: Petroleum Inspector .DOC BOP test AWS rig #122 UNOCAL #SRU 242-16 Swanson river Field PTD #88-157 Monday, July 10, 1995: I witnessed the Initial BOP test on Alaska Well services rig #122 in the Swanson River field. This rig is the old Rowan rig #5 that was used in the Beluga river field for many years. I found the overall condition of the rig to be poor with little or no evidenc, e of regular maintenance. The test went slowly due to incorrectly connected BOP lines. Once this problem was corrected the test was concluded. There was one major failure, this being the isolation valve for the hydraulic choke. The valve had threaded connections and leaked from the grease port when the high pressure test was applied. I also found hammer unions between the choke manifold and gas buster, I required the valve and these non clamped type connections to be removed and replaced with approved equipment. The mud system was of the most basic design with a open trough and exposed pits. There was no vacuum degasser for removing entrained gas. Doug Nienhaus (UNOCAL Rep) informed me that the program called for clear lease water for the initial well work but they would have to gel up the fluid for the cleanout. I required a degasser to be installed before the cleanout was performed. I am not impressed at all with this rig and feel that the drilling company uses the minimum amount of equipment they feel they need to complete the job. As these rigs are brought out of stack a pre-startup inspection should be performed and deficiencies corrected. SUMMARY: I witnessed the Initial BOP test on Alaska Well services rig #12_2 ,~ ~ Test time6 hours. Two failures. ~,; , ~; A. achments: A99JGJCD.XLS ~'~1~ ~ ~ ~ , cc: Dan Williamson (UNOCAL drilling superintendent) ~ ~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlng Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Alaska Well Services Rig No. 122 PTD # Unocal Rep.: SRU 242-16 Rig Rep.: 7" Set @ Location: Sec. X Weekly Other 88-157 DATE: 7/10/95 Rig Ph.# Doug Nienhaus Shane McGeehan 15 T. 8N R. 9W Meridian Seward Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit NV~, Hazard Section None BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig Poor Standing Orders None Quan. 1 Test Pressure P/F 150/3000 P 1 150/3000 P 150/3000 1 150/3000 P 1 150/3000 P 1 150/3000 P 1 150/3000 P 1 150/3000 P MUD SYSTEM: Visual Alarm Trip Tank P F Pit Level Indicators P F Flow Indicator P F Gas Detectors P P H2S Detectors 2* FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 150/3000 1 * 1 150/3000 1 * 1 150~3000 P 1 150/3000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 150/3000 P 30 150/3000 P 1 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: Three Bottles 2200 Average 3,000 I F 2,000 P minutes 36 sec. minutes 3 sec. Remote: X Psig. Number of Failures: 4 ,Test Time: 6.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: 1') Test Kelly valves when picked up and report results to AOGCC. No sample Gas for H2S detectors. Outboard valve on hydraulic choke had threaded connections and leaked, remove and replace with proper valve. No vacuum degasser on mud system, Install one before changing from lease water to gelled fluid. Rig in poor condition! Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspl~l.c(~l~'L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: GJCD.XLS Louis R Grimaldi STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION ~3OPE Test Report OPERATION: Ddg: Workover: X Ddg Contra~oc Al~,ka Well Serv!ce~ Rig ~. ~or: ~- . ~N~ Welt Name: 8RU ~2-14 C~ 8~e: 7 Set ~ T~; tn~da X., Weekly ~er DATE: 7/10195 5 PTD# 88-157 Rig Ph.# Rep,: Doug. Nienhaus Rig Rep.: Shana McC_-~ehan Location:Sec. 15 T. 8N R, 9W Meridian Seward ,, !MISC,. ii'~;PECTiONS: Location C~,~n.: OK P~ ~ L~on none ~i~ O~er P~ OK ,~ndtar Preventer i ~_.?,ams t- Weil Sign OK, Drt, Rig __.OK Hazard Sec, none' Test Pressure P/F 300~000 P ,,, 300/3,000_ P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Ir~ide BOP CHOKE MANIFOLD: No, Valves Quan, 1'. i*- 1 Test Pressure 30013t000 300t3,_0_0_0. _, 300/3,000 300/3,000 Test Pressure p,rF P P/F F i 12 J 30013,000 ~tf¢~ ~ _._. ~ 3 ~00/3,000 '-- No. Flanges 32 J 300/3,(:;)-(~ P , :7~'!"!~'!iR~s '--i 300/~, 000 '. P ~ ManualChokes I 'J Functioned P -!:.:::.'.Ch~~ '-~1 _' 3q.0_~ P-'- , Hydraulic Chokes ~ I :J Functioned i'.':' ' -- I .::'. ~~es -;i-" 30013,000 P ACCUMULATOR SYSTEM: l-'...:,¢i. '~!V~¢e ---~- --~-0~i~-00 i P System Pressure 3,000 i~O~:- · Visual Alarm 200 p~t Attained After Closure d -minutes :~3 'sec. iF,-it'L~~~ors i5 .... Blind Switch Covers: Master:~P Remotei''' P f:':'''5'-. '~'~or ~ -' Nttfln, Btl°$; THREE BOqU-~ ~~}i:;!!!% _2 ,,'ret Hrs,: ,__6.,0: Hours, NkmitSef of valve~ tested 17 Repair or Replacement of Failed ~i~~..~...e;~hin days..:.!Noti~ the !nsi:~Ctor and follow with Wfitt:en or Faxed verification to ~~~C.--.n ~Omc~.e at: Fax No, ~.~7{~12 Inspector North Slope Pager No. 659-3607 or ~,687 .::~~ by the ir,c~pec, iz~r w',~i'.i2 hours plm3~m cOn~ra-t the P. !. Supervisor at: '";~'17:'~:~.~.-,.-.-,..--. ~'~':' ...... " ...... : .... '~ [ ...! '¢~¢'t'/~ ....... ;L' ;:;"~. ..... ';i.'.'?:?':'.:' :.;: ~ ~~,:--' '" ?:'!~'-'., ~ ..... ~~'-'iI''' "' I)%~_,t Keliy valves when pick~<up and fax results in to AOGCC. Improper valve downstream of hvd choke .:;;¢= ..-v,,~?.~-,~.'...~.-;:':: .. ,,,,,_~ .... ----- . '~ . _~o.,- · .... ' ~~'...~fe~_ Te~ H2b; detectors when sample.~.~ ob, rained, ~,~.-'...'."-0~.~:5-'.:.';'. ........... .__.-,- r--z. ' :-::i,:~;-'. '-:,"-:~-"2;;.:~!":,:-:: '...'.' ~i;.. -' STAT~'~¥tTNES$ REQ'alt~'ED? WaNed By: !~. z '.';- · '5'"'~?0~~:~;~ Witnessed By: Louis R , grimaldi :'"..~ 24 HOUR NOTICE GriN YES X NO · ... ;-~'~{t me,. ~z~) ALASKA WELL_SERVICES RIG #5 MANIFOLD IS DESIGNED WITH 3 1/8" xl5000 SHAFFER TYPE B THROUGH LINE AND SHAFFER 2 1/16" X 5000 TYPE B SIDES. THE ~HOKES ARE TRI FLO 3" x 10,000 2" ORIFICE HYD. 2" x 5,000 1" ORIFICE MAN. / VIEW AA DRWG, NO. NWS- 1/87 REF, LIT. NO, 3;548 16 American Petroleum Institute AOJUSTABLE CHOKEm-~ ,.,.,TO PIT ANO/OR MUO/GAS SEPARATOR/OVERBOARD ~BLOV/OUT PREVENTER ~--OPTIONAL ON 2M ~,, FIG. 3.A.1 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 2M AND 3M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION ADJUSTABLE CHOKE -- TO PIT AND/OR SEPAR~ ATO R/OVER~.,~,a, RD '~--' 2" NOMINAL x PREVENTER STACK OUTLET OPTIONAL OPERATED VALVE NOMINAL BLEED LINE TO PiT/ OVERBOARD TO PIT AND/OR MUD/GAS SEPA RATOR/O,~BO/~RD Z~ 2" NOMINAL REMOTELY OPERATED OR ADJUSTABLE CHOKE FIG. 3.A.2 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 5M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION STATE OF ALASKA AL .~KA OIL AND GAS CONSERVATION COb,. .$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Oper~ons shutdown __ Re-enter suspended well__ Alter casingX_ Repair well _ _ Plugging __ Time extension m Stimulate __ Change approved program __ Pull tubing X Vadance __ Perforate X_ Other__ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 4. Location of well at surface 2267' FNL, 971' FWL, Sec. 15, T8N, R9W, SM At top of productive interval 2268' FNL, 501' FEL, Sec. 16, T8N, Rgw, SM At effective depth At total depth 2149' FNL, 1431' FEL, Sec. 16, T8N, R9W, SM 5. Type of Well: Development X Exploratory __ Stmfigraphio __ ORIGINAL 6. Datum elevalJon (DF or KB) 26' 7. Unit or Property name Swanson River Unit 8. Well number 242-16 9. Permit number 10. APl number 50-133-20405 11. Field/Pool SWANSON RIVER HEMLOCK OIL POOL feet 12. Present well condition summary Total depth: measured 4860' feet Plugs (measured) 4780' MD true vertical 4025' feet Effective depth: measured 4780' feet Junk (measured) true vertical 3963' feet Casing Length Size Cemented Measured depth Structural Conductor 90' 16" 90' Surface 2337' 9-5/8" 756 sx 2337' Intermediate Production 4830' 7" 325 sx 4830' Liner Perforation depth: measured 3344'-3370', 3407'-3427', 3454'-3464', 3723'-3753' true vertical 2864'-2884', 2912'-2927', 2947'-2955', 3150'-3173' Tubing (size, grade, and measured depth) 3-1/2" 9.3# @ 3300' Packers and SSSV (type and measured depth) BAKER "FHL' @ 2848' True vertical depth 90' 2215' 4005' RECEIVED JUN 2 ,~ 1995 AIsska, (JJl & Gas Cons. Commission '. ~ch0m? 13. Attachments Description summary of proposal X_ Detailed operations program_ _ BOP sketch _ _ 5. Status of well classification as: 14. Estimated date for commencing operation 7/2/95 16. If proposal was verbally approved Name of approver Date approved Oil__ Gas X_ Suspended __ Service 17. I hereby certify that the forego_ing~js~ue and corrfl~t to t..he,,b,,est of my knowledge. Signed G. RussellSchmid~~Title~ing~" Manager FOR COMMISSION USE ONLY Date 06/16/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test Mechanical Integrity Test__ Approved by the order of the Commission IApproval No.....~ Location clearance ~,',~ '~/~,~ -- -- Subsequent form required 10- _~_C)_'Z__ Approved Copy J:iet~rned / ~- Original Signed By ,.,~_/.~.~/~5'- DaVid W. Johnston ..u, .,, ,,~,..., - -- Date Form 10-403 Rev 06/15/88 SUBMIT Ir~ TRII~LIOATE AFE 752508 RECOMPLETE SRU 242-16 SWANSON RIVER FIELD GENERAL PROCEDURE: Prepare location Kill well by bullheading lease water Move in and rig up the workover rig Install and test BOPE to 3000 psi Release the FHL packer at 2848' (Pull) Circulate lease water POOH and stand back the 3-1/2' tubing Pick up DC's and clean out fill to 4749' w/tubing Run TDT log ETD - 2300' Run and cement 3-1/2" tbg at ETD. TOC at ~1500' Remove BOPE, install ancl test tree to 3000 psi Rig down and move out Replace production lines Achieve drawdown and wireline perforate SRU 242-16 Current Status Spud August 1989 KB elev. 326' Minimum ID = 2.750' OTIS 'XN' profile at 32ST' 9-5/8" @ 23,35' ~ 3-1/2' x 1' K]~VIG GLM 1985' TOC by CBL 2594' 3-1/2' 9.3# J-55 EUE 8rd tbg Chem inj line bnaded to tubing with 67 SS bands ' Camco ~1~ x 1-1~ M~ G~ 27~' B~ker FHL packer 2848; ETO 334T by wireane tag 8-3O.94 'XN' profile 326T Wimline reenuy guide 3300' 3344-70' 3407.27' 3454-64' PB'ro @ 4749' F'~h = 1.1/2' ciro w~v~/1-5/8' I:~ I~tch (27') GRB 9-12.94 SRU 242-16 PROPOSED Spud August 1989 KB elev. 326' 2335' TOC by CBL 2594' PBTD @ 4749' 7' @ 4831' TD @ 4860' TOC in tubing x casing annulus +/- 1500' Potential perf 2908,30' Potential peri 3O80.90' ~. , Polenllal pelf 3_r,85-625* 3723'-53' Potential perf 381640' Potential perf 4060-97~ Fish = 1.1/2" c~rc valve/1-5/lt" Pa< latch GRB 9-12-94 ,/'"" STATE OF ALASKA ~ ALASi,,-~ OIL AND GAS CONSERVATION COMMIt APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend __ Operations shutdown __ Re-enter suspended well__ Alter casing._~_ Repair well _ _ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate X_ Other__ 2. Name of Operator UNION OIL COMPANY OF CAUFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Location of well at surface 2267' FNL, 971' FWL, Sec. 15, TSN, R9W, SM At top of productive interval 2268' FNL, 501' FEL, Sec. 16, T8N, R9W, SM At effective depth 2149' FNL, 1431' FEL, Sec. 16, TSN, R9W, SM At total depth 2149' FNL, 1431' FEL, Sec. 16, T8N, R9W, SM 5. Type of Well: Slm§graphic __ 6. Datum elevation (DF or KB) RKB 345', RKB GL 26' 7. Unit or Property name Swanson River Unit 8. Well number 242-16 9. Permit number 88-157 10. APl number 50-133-20405 11. Field/Pool SWANSON RIVER HEMLOCK OIL POOL feet 12. Present well condition summary Total depth: measured 4860' feet Plugs (measured) None true vertical 4025' feet Effective depth: measured 4749' feet Junk (measured) None true vertical 3932' feet Casing Length Size Cemented Measured depth Structural Conductor 90' 16' Surface 2337' 9-5/8" 756 sx 2337' Intermediate Production 4830' 7" 325 sx 4830' True vertical depth 2129' 3995' Uner Perforation depth: measured 3723'-3753', 3454'-3464', 3407'-3427', 3344'-3370' true vertical 3150'-3173', 2947'-2955', 2912'-2927', 2864'-2884' Tubing (size, grade, and measured depth) 3-1/2' 9.3# J-55 @ 2848' Packers and SSSV (type and measured depth) BAKER "FHL' @ 2848' SEP ?- 1 1994 Gas Cons. Commission Anch0ra~e 13. Attachments Description summary of proposal X__ Detailed operations program_ _ BOP sketch x 14. Estimated date for commencing operation ASAP I5. Status of well classification as: Gas X 16. If proposal was verbally approved Oil _ _ Name of approver Date approved Service 17. I herebyCert~~he. ~~orrect to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Suspended __ Date 09/16/94 Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Location clearance Mechanical Integrity Test__ Subsequent form required 10- _ .... IApproval No. ]mal Signed By W. Johnston Approved by the order of the Comn3jssi_on_ Form 10-403 Rev 06/15/88 ~~7~~ Commissioner Approved CopY Returned Date ~'./'3."t-/'~ ~{ E SUBMIT IN TRIPLICATE 16' @ 100' SRU 242-16 Current Status Spud August 1989 KB elev. 326' Minimum ID -- 2,750" OTIS "XN" profile at 3267' 9-5/8' @ 2335' TOC by CBL 2594' Camco 3-1/2'x 1' KBMG GLM 1985' 3-1/2' 9.3# J-55 EUE 8rd tbg Chem inj line bnaded to tubing with 67 SS bands ETD 3347' by wireline tag 8-30-94 PBTD @ 4749' 7" @ 4831' TD @ 4860' Camco 3-1/2' x 1-1/2' MMG GLM 2790' Baker FHL packer 2848' "XN" profile 3267' Wireline reentry guide 3300' 3344-70' 3407-27' 3454-64' Fish = 1-1/2' circ vaNe/I-5/8" RK latch (27') R£¢EIV£D SEP 2 1 1994 Gas Cons. Commission Anch0r~ GRB 9-12-94 SRU 242-16 PROPOSED Spud August 1989 KB elev. 326' 16" @ 100' 9-5/8" @ 2335' TOC by CBL 2594' "X" profile +/-3000' "X' profile +/- 3400' 'X' profile +/- 3700' "X' profile +/- 4400' PBTD @ 4749' 7" @ 4831' TD @ 4860' TOO in tubing x casing annulus +/- 1500' Potential perf 2cJ08-30' Potential perf 3080-90' 3344-713' 3407-27' Potential perf 3585-625' 3723'-53' Potential perf 3816-40' Potential perf 4060-97' Proposed perf 4685-96' Fish = 1-1/2' circ valve/I-5/8' RK latch (27") RECEIVED SEP 2 1 1994 Oil & Gas Cons. Commission .~chora~e GRB 9-12-94 PROPOSED WORKOVER PROCEDURE SWANSON RIVER UNIT 242-16 . . . , , . . 10. 11. Prepare location. Kill well by bullheading lease water down robing. Move in and rig up workover rig. Nipple down tree, nipple up and test BOP to 3,000 psi. Release Baker "FHL" packer at 2,848' and circulate well clean with lease water. POOH with packer and stand back 3-1/2" robing. RIH with bit and drill collars on 3-1/2" robing and clean out to 4,749'. POOH. RIH with 3-1/2" robing and cement in place with TOC at 1,500'+/-. Nipple down BOP and nipple up and test tree to 3,000 psi. Rig down and move out service rig. Replace production lines. Achieve drawdown and wireline perforate Beluga. RECEIVED SEP 2 1 1994 Aiaska Oil & Gas Cons. Commission Anchor~j~ FILL UP LINE ANNULAR BOP 11" 3,500 psi FLOW LINE KILL LINE 3" 5,OO0 psi PIPE RAMS 11" 5,000 psi BLIND RAMS 11" 5,000 psi DRILLING SPOOL 11" 5,000 psi CHOKE LINE HCR I I 3" 5,000 psi PIPE RAMS 11" 5,000 psi BOP STACK 11,, 5,000 psi RECEIVED SEP 2 1 1994 Aiaska Oi~ & Gas Cons. Commission Anchor~.~i~ 5,000# CHOKE MANIFOLD Manual Choke 2" 5,000# o o ~ o O O O O o o To BOP o o = LO Od OJ = 2" 5,000-If 3" 5,000-fl' 11 3" 5,000# 0 0 0 5,000# Hyd. Choke 3" 10,000# I I 2" 5,000-If · , APPLICP ION FOR SUNDRY APPROVALS 1. Type of request: A,ba.,~don .__ Cu.~pend __ Operations shutdown __ Re-ent[. ~spended well__ Alter casing__ Repair well __ Plugging X_ Time extension __ Stimulate __ Change approved program Pull tubing Variance __ Perforate Other__ 2. Name of Operator 5. TyPe of Well: 6. Datum elevaUon (DF or KB) Unocal Development X_ KB: 345' Exploratory __ feet 3. Address Strafigraphk= __ 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Servk~ __ Swanson River Unit 4. Location of well at surface 8. Well number 2267' FNL, 971' FWL, Sec. 15, T8N, R9W, SM SRU 242-16 At top of productive interval 9. Permit number 2268' FNL, 501' FEL, Sec. 16, T8N, R9W, SM 88-0157-0 At effective depth 10. APl number 50-133-20405-00 At total depth 11. Field/Pool 2149' FNL, 1430' FEL, Sec. 16, T8N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 4860 feet Plugs (measured) true vertical 4025 feetORIGINAL Effective depth: measured 4780 feet Junk (measured) true vertical 3963 feet Casing Length Size Cemented Measured depth True vertical depth Structural 90' 16" Driven 90' 90 Conductor Surface Intermediate 2337' 9' 756 sx 2337' 2119' Production Liner 4830' 7" 325 sx 4830' 3995' Perforation depth: measured 3723-3753, 3454-3464, 3407-3427, 3344-3370 true vertical 3149-3172, 2948-2955, 2912-2927, 2865-2885 R ~ C E I V ~ D Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 3300' S[P - 7 ~994 Packers and SSSV (type and measured depth) Baker 'FHL' pkr. (iD 2848' A~a$~ Oil & Gas Cons, Commission ~n~horage 13. Attachments Description summary of proposal X_ Detailed operations programX__ BOP sketch __ Questions? Call Dave Whitacre @ 263-7616 14. Estimated date for commencing operation 15. Status of well classir~ation as: August 30, 1994 16. If proposal was verbally approved Oil __ Gas X_ Suspended __ Blair Wondzell 8/26/94 Name of approver Date approved Service 17. ! hereby ce _r~..~ ~t, hat the foregoing is true and correct to the best of my knowledge. Signed Title J/~ I, l ~ /'~, Date -"- FOR COMMISS~iON"'USE O~N~Y v/ ~' ~ Conditions of approval: Notify Commission so repreSentative may Witness I Approval No. Plug Integrity __ BOP Test_ Location clearance _i ?~'"' '~' ~'f '~ Mechanical Integrity Test__ Subsequent form required 10- t/c)Lf Original Signea Wy Approved by the order of the Commission David W. Johnston Commissioner Date ~" ~I;'/~ y Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPUCATE Oil & Gas Divis;on Unocal Corporation .~_.... P.O. Box 190247 Anchorage, Alaska 99519-.? Telephone (907) 276-7600 UNOCAL Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 27, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent to set a through tubing plug in well SRU 242-1 6 at approximately 3550' to shut offwater production from the lower interval at 3723'-3753'. PROCEDURE TO SE "P IN SRU WELL NO. 242-16 August'26, 19~4 Dave Whitacre 263-7616 2, , , . , . 10. 11. 12. 13. Review procedure with Schlumberger crew. Shut-in well (both tubing and fiowline valves) Pick up PosiSet bridge plug and setting tool in lubricator and nipple up to wellhead. Test lubricator to 500 psi above maximum anticipated surface pressure. Open robing valve and RIH w/BP to ETD of approx. 3550'. Reference collar locator on Schlumberger Dual Burst Thermal Decay Log dated April 26, 1991. Pull up 10' and set BP. POOH w/setting tool. Dump 10' cement plug (approx. 16 gallons) on top of BP with wireline bailer. POOH w/bailer and rig down Schlumberger. Leave well shut-in hrs. Open up well and flow at same choke setting as before job. Monitor gas production, water production, and tubing pressure until stabilized. After well is stabilized, open choke in 1/64th increments. Closely monitor well performance at~er each choke adjustment. Oil & Gas Cons. Commission Anchorago ,Spud Date: 8/18/89 --'-:3riginal RKB:, 326'. "op of Hemlock: /%-~mpletion Date: 8/28/89 ,.anger Type' FMC Max. Hole Angle: 43° Workover: NA tanger' Angle @ Perfs · 41° All Depths are RKB MD to Top of Equipment. 1 b Jewelry I 1985' 2 2790' 3 2848' 4 3267' 5 3300' 6 3300' Camco 3 1/2" x 1" KBMG GLM Camco 3 1/2' x I 1/2" MMG GLM Baker 7" FHL Packer Otis "XN" Nipple Baker 3 1/2" Sheamut Sub w/Re-entry Guide Tubing Tail Minimum ID: 2.750" ~ 3267' (Otis" 'XN' Nipplei Casing and Tubing 16' 0 100' 9 5/8" 36# 'J-55 0 2170' 9 5/8" 36# J-55 0 2170' 9 5/8" 47# S-95 2170' 2335' 7" 26# J-55 0 4831' 3-1/2' 9.3# J-55 0 3300' Perforation Data JJ:ttC.[Y,~ Zone FT ~ Date 3344'-3370" BO 26' 8 8/89 3407'-3427' BO' 20' 8 8/89 3454'-3464' B 1 10' 8 8/89 3723'-3753' B4 30' 8 8/89 PBTD = 4749' TD = 4860' Description Conductor Surface Casing Surface Casing Sudace Casing Production Casing Tubing Well SRU 242-16 By: JLB 4/11/90 SEP - 7 1994 ,~. ~a uit & Gas Cons. C0mmi5',. ~,nchorage ARCO ALASKA INC. Cook Inlet Engineering #540 TRANSMISSION COMMISSIONER COMPANY: AOCK2C DATE: 5/24/91 FROM: Victoria Fer~uson 'coMPANY: ARCO Alaska, Inc ~l J. NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia rape & , Line FoldedlRolled Mylar ilistin~ SRU 32A-33 PFC LOG 1 1 ACBL 1 1 SRU 242-16 DUAL BURST THERM DEC 1 1 TBU K_' 19 VERTIL~ 1 1 ' ' 'SEGMENTED BOND LOG I 1 , ' ' ', ' · , ,, - % ,IdW~' Renan reciept to ARCO AI.~SKA, Inc. ATTN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: ARCO Alaska, Inc. Post Office Box 100380 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering February 22, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SRU 242-16 Dear Mr. Chatterton: An initial four-point back-pressure test was performed on SRU 242-16 on November 1, 1989. An absolute open flow potential of 45,950 MCFD has been calculated for this well. The following data is attached: 1. Copy of test data 2. Worksheet for calculation of static column wellhead pressures (Pw) - Form BPT 3 3. Gas Well Open Flow Potential Test Report - Form BPT 5 4. Back-Pressure Curve The test was conducted in accordance with the provisions detailed in the "Manual of Back-Pressure Testing of Gas Wells" with one exception. The spread of flow rate data as specified by the percentage of the well's shut-in pressure was not obtained due to concerns of sand and water production at the higher flow rates. However, a sufficient spread of flow rate data was obtained to accurately determine the absolute open flow potential for this well. If you have any questions, please contact Stacy Strickland at 263-4914. Sincerely, T. Wellman Interim Manager TW:SLS:ch:0019 Attachments cc." S. W. Ohnimus A. R. Kukla UNOCAL Corporation Marathon Oil Company ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Attachment #1 · SRU 242-16 FOUR POINT BACKPRESSURE TEST DATA ................. ~o ~s:z~ 0 I/~. ~ ~ 0 /o~. ~ 0 0 .,~r-,~ ~ ..... ' ............... ' ........... ~ ~oz ~r~-~ ' .~.:,~ I~ //~z.~ 4~ 2.~ /. 4o ,o~ .~ ~1 /~ /,/40, / o ....................... ~r~,u ~ ~f~ ~ ' ................ sr~,,~ ~~' ,, , ,, ,, n n~ ....... ....... i i i ii i1~ i ~ i i __. ii lie ii i ii il ii i i i i i i ii ii i ii ii i i ~ i m I i ii I I ii . _ . . '.'~ .' ' '; ' '" - .. , :' , , i i i , [ i i Attachment//2 llOlli ~IE~T F011 CAL~~ OF STATIC O]LUlM Il/LINE,q) · ~,~iTG" Fr O..OO~IG~7 ~ll 1575 Pa-(~7~ T¢, 33~. LiNE I'* ~,91 Z'~ ~-';~1 :~,~ +~ I~ ~ Z~~l I~ ~1 Z~ ~ 4 T 5Zi ~zl 5Z~ ~ZZ 5Z~ ~z~ ~Z3 . 6 ~ ~o~ ~5 .447 ~G 44~ 4~o 4~o ~ ~ .~.~oo ~,s~. ~.sz~ s. 5~% $.514 3.5o~ 3.504 9 IW~ 5. I~O ~.IZ4 O. lZ4 O. 164 O. IZ4 O~lZ4 O. I Z~ .... F~,m B SHEET FOIl CAL~TKB OF STATIC I;I~UI~ lYELU-IEAD PRESSURES L ~3oo ti Z.~33' .... L,M I.IG5 ~ 0.5'5-/ ~W:Z)2 o.o-~ Pcr Q,-/3 Tcr 33C,, ii ii LIIqE I ~' -~-h~l, I ~ 5.'544 _ 4 T 5g~ 5 Z o,~z o. 9 I~s O. I Z~ o. I --, 13 Fc - F,~ ~.'66f 14 F~ ~o.4~ ~'o.4~ _ i6F~~Fc~~ i~.~ ~ Tr ~ .~ I.~& : ~ z o. ~ o,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1 a. TEST: INITIAL ANNUAL SPECIAL lb. TYPE TEST MULTIPOINT ~ OTHER STABILIZED [] NON STABILIZED ~] -- CONSTANT TIME '_]' ISOCHRONAL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 88-157 3. Address 8. APl Number P. O. Box 100360 Anchoraqe, AK 99510-0360 5o- 133-20405-00 4, Location of Well Surface 2267' FNL, 971' FWL, Sec. Top of Producing Interval 2271' FNL, 463' FEL, Sec. 15, T8N, R9W, SB&M 16, T8N, R9W, SB&M 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. 344' RKB I A-028077 12. CompletionDate8/29/89 113.T°talDepth4860' MD 114'PlugbackT'D'4749' MD 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. 7" 26# 6.276 4831' 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 3-1/2" 9.3~ 2.992 3300' 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 242-16 11. Field and Pool Swanson River Field, Sterling 15. Type Completion (Describe) Single Completion Gas Producer Perforations: From To 3344 - 3370 34O7 - 3427 3454 - 3464 3723 - 3753 2848' I .... I 0.557 22. Producing thru: Reservoir Temp. o F. Mean Annual Temp. o F. Barometric Pressure (Pa), psia Tbg.~ Csg.~ 75°F 0 3300' 33°F 14.65 psia 23. Length of flow channel (L)I Vertical Depth 'M)' Ga.' °<~O- ' "~= I ~'~ I "rover I U,t,,ru, *~P~ 3300' 2833' 1.557 i .07 i .31 -- 3" -- IFlange F 24. Flew Data Tubing D~ta Casing Dat~ I Prover Choke Meter Meter Duration of Pressure Diff. Temp. Pressure Temp. Pressure Temp. Line X Orifice Flow No. Size (in.) Size (in.) psig Re~ud. ing o F. ps i a o F. psig ° F. Hr. ~. 3.068 x 1.75 163 1.40 73 1113 46 N/A N/A 1 2. 3.068 x 1.75 175 3.30 104 1098 48 N/A N/A 1 3. 3,068 x 1.75 170 4.75 101 1086 50 N/A N/A 1 4. 3.068 x 1.75 196 6.25 ! 78 .1065 52 N/A N/A 1 l Basic Coefficient I ~ Static Flow Temp. Gravity Super Comp. (24-Hour) Read i n.g Factor Factor Factor Rate of Flow Q, Mcfd No. Fb or Fp * huPu Pu Ft F,~ Fpv ~. 79. 147 10.85 7.75 0.988 1.340 : 1.011 1149 79 147 26.24 7.95 0.960 ~ , a. I · i 1..340 i 1.010 I 2698 ~3. I 79.147 37.05 7.80 I 0.963 ' 1.340 1.009 : 3818 4. 79. 147 52.50 8.40 0.983 i 1,340 1.013 5544 * ncludes Meter Constant (M) = 4.899 i ' · for Separator for Flowing i Temperature ~ Tr Z GasI Fluid i Pr T i Gg No. It. 0.26 533.0 ! 1.59 0.978 2. 0.28 564.0 ~ i 1.68 0.981 3'i 0'27 561.0 i 1'67 0.982 Critica~Pres.,ure 673 psia 4. I 0.31 538.0I 1.60 0.975 Critical Temperature 1336° R. Form 10-421 CONTINUED ON REVERSE SIDE ~ '~ y~ ~]) Submi[ in duplicate Pc 1121 Pc2 1256.6 pf pf2 No. Pt 1. 1113 2. 1098 3. 1086 4. 1065 . 25. IPt 1238.8 1205.6 1179.4 1134.2 AOF (Mcfd) 45,950 Remarks: pc2 , pt2 i Pw 17.8 51.0 77.2 ! 122.4 Pw2 1239.4 1209.3 1186.8 1149.9 pc2 . pw2 17.2 47.3 69.8 106.7 Ps Ps2 pf2 . ps2 n 0.861 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~l,z~ .Title AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-x,/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-V"l/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air-1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia F lowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility .factor, dimensionless Recommended procedures for tests and-calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Attachment//4 ~.. 104 7 SRU 242-16 Four Point Back Pressure Test 11/1/89 9 8 7 6 5 102 10 1,000 3 4 5 6 7 8 910 10,000 3 4 5 6 7 8 910 100,000 3 4 5 6 7 6 91S Q (MCFD) '~' ?~" STATE OF ALASKA "-~'~ I ~ N ! 9 I · ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-157 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 133-20405 9. Unit or Lease Name Swanson River Unit 10. Well Number 242-16 11. Field and Pool Swanson River Field 4. Location of well at surface 2267' FNL, 971' FWL, Sec.15~ T8N, Rgw, SM At Top Producing Interval 2268' FNL, 501' FEL, Sec.16, T8N, Rgw, 5H At Total Depth 2149' FNL, 1431' FEL, Sec.16, T8N, R9W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 345', RKB-GL 26' [ A-028996 Hemlock Oi 1 Pool 12. Date Spudded 113. DateT.D. Reached I 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore I16. No. of Completions 08/17/89 I 08/23/89 I°~//~ ~/~'? ~ I N/A feet MSL Ij 1 4860'MD 402S'TVDI 4780'MD+3963'TVD I YES [~ NO [] [ None feet MD I N/A 22. Type Electric or Other Logs Run DIL-GR-SP, CDL-CN-GR-CAL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTIN( DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 12-1/4' 8-1/?~ 16" 9-5/8" 7" 422 sx 12.5 C1 G= 334 82_5 sx C1 G 25. TUBING RECORD SIZE sx 15.8 C1 G 26. 3-1/2" 36# =47~ 2~# .~ J-55;S-9_~ .I-55 DEPTH SET (MD) PACKER SET (MD) 3300 ' MD 28~.~- ' MD Surf Surf Surf 90' 2337 ' 4830' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 3723 ' -3753 ' ,3454 ' -3464 ' ,3407 ' -3427 ' ,3344' -3370'MD 3150 ' -3173 ' , 2947 ' -2955 ' ,2912 ' -2927 ' ,2864 ' -2884 'TV[ 3-3/4"perfs ~8 spf ACID, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT & KIND OF MATERIAL USED DEPTH INTERVAL (MD) 27. PRODUCTION TEST Date First Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. 28. WATER-BBL ICHOKESIZE IGAS'OILRATIO WATER-BBL lOlL GRAVITY-APl (corr) IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOR lei L-BBL GAS-MCF TESTPERIOD e [ CALCULATED i~ I OIL-BBL GAS-MCF 24-HOUR RATE '1~ j CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None Form 10~107 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RECEIVED. OCT 2 6 ]9 g Alaska 0il & Gas Cons. C0mmissi0~ Anchorage Submit in duplicate.~ NAME B-3 Sand Top B-4 Sand Top B-5 Sand Top B-6 Sand Top Beluga Top GEOLOGIC MARKERs --tOPS' MEAS. DEPTH TRUE VERT. DEPTH 3585 3719 3816 4070 4455 3,046 3,147 3,221 3,414 3,711 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of esch phase. 31. LIST OF ATTACHMENTS Summary of Operations, Gyro 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: if this well is completed for separate prodUction from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' if no cores taken, indicate "none" Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Dali) Initr~ctlenl: Prepare and submit the "lhllill Rtport" on the first Wednesday after a well is spudded or workover operations ere Itmled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District }County, perish or borough ARCO ALASKA INC. ~ SWANSON RIVER Field ILeax Or Unit SWANSON RIVER UNIT ] ADL A-O28996 f Auth. Or W.O. no. ~Title PO:)6366 ) DRILLING ISfet~K IWell no. SRU 242-161 Operator ARCO Spudded or W.O. begun IDate ]Hour SPUD I 08/17/89I 14:30 Date and depth as o! 8:00 a.m. 08/17/89 ( 1) TD: 0'( 0 SUPV:BS 08/18/89 (2) TD: 544'( 544 SUPV:BS 08/19/89 (3) TD: 2036'( 1492] SUPV:BS 08/20/89 (4) TD: 2346'( 310 SUPV:BS 08/21/89 (5) TD: 2346'( O SUPV:BS 08/22/89 (6) TD: 2798'( 452 SUPV:BS Complete record for each day re~ed GRACE 154 IARCO W.I. 48.4864 Prior status if a W.O. BUILD SPUD MUD MW: 0.0 VIS: 0 ACCEPT RIG AT 1200 HR 8/16/89. R/U DIV~RTER SYSTEM AND 10" LINES. MIX SPUD MUD. HAVING TROUBLE WITH ELECTRICAL SWITCH ON ACCUNULATOR UNIT. DAILY:S142,534 CUM:$142,534 ETD:S142,534 EFC:$1,310,000 DRILLING SURFACE HOLE MW: 9.0 VIS:117 MIX SPUD MUD. FUNCTION TEST DIVERTER SYSTEM AND SERVICE LEAKING DIVERTER VALVe. SPUD AT 1430HR 8/17/89. DRILL 12-1/4" HOLE TO 494' CIRCULATE AND CONDITION HOLE. DROP SINGLE SHOT SURVEY. POOH, PIPE TIGHT, CIRCULATE PIPE FREE. WORK ON PUMP 91. CIRCULATE HOLE CLEAN. POOH, RETRIEVE SURVEY. P/UA BOTTOM HOLE ASSEMBLY ~2. TRIP IN HOLE. MAGNETIC SURVEY WITH MWD. ORIENT 2 DEGREE BENT SOB. DRILL FROM494' TO 544. DAILY:S32,852 CUM:$175,386 ETD:S175,386 EFC:$1,310,000 DRILING MW: 9.2 VIS: 40 DRILL 12-1/4" HOLE FROM 544 TO 1677 WITH 2 DEGREE KICK OFF ASSEMBLY. POOH AND CHANGE BHA. L/D NAVIDRILL AND TRIP IN HOLE. TIGHT SPOTS FROM 500' TO BOTTOM. DRILL FROM 1677 TO 2036 M~D SURVEYS EACH CONNECTION. DAILY:S25,185 CUM:$200,571 ETD:S200,571 EFC:$1,310,000 R/O TO DO TOP JOB 9-5/8"~ 2337' MW: 9.2 VIS: 42 DRILL FROM 2036 TO 2067. CBU, POOH AND P/O BIT %2 AND ADDED STABILIZER. TRIP IN HOLE, WASH AND REAM LAST 45' TO BOTTOM. DRILL TO 2346'. CBU, SHORT TRIP TO HWT AND POOH SLM. L/D BHA. R/U AND RUN 4 JTS 9.625" 47# S-95 AND 57 JTS 36~ J-55 CASING TO 2,337'. CIRCULATE AND RECIPROCATE PIPE WHILE RIGGING UP BJ TITAN. CEMENT CASING WITH 422 SACKS OF 12.5 PPG LEAD AND 344 SX 15.8 PPG TAIL CEMENT. BUMP PLUG WITH 1750 PSI. CEMENT IN PLACE AT 0530HR 8/20/89. FLOATS HELD. NO CEMBNT RETURNS TO SURFACE. R/U UP FOR TOP JOB. DAILY:S25,317 CUM:$225,888 ETD:S225,888 EFC:$1,310,000 TESTING BOPE 9-5/8"@ 2337' MW: 9.0 VIS: 31 ND DIVERTER AND PERFORMED 58 SK TOP JOB. INSTALLED STARTER HEAD AND NU BOP STACK. DAILY:S89,129 CUM:$315,017 ETD:S315,017 EFC:$1,310,000 POH 9-5/8"@ 2337' MW: 9.1 VIS: 36 TESTED BOPE. TESTED CSG TO 2000 PSI, OK. DRILLED OUT TO 2356' AND PERFORMED PIT = 12.5 PPG EMW. DRILLED AND SURV'D TO PD. POH. DAILY:S29,032 CUM:$344,049 ETD:S344,049 EFC:$1,310,000 OCT 2 ]937 Anchorage INumber all el they are dally well history forms con~cutlv~ly prepared for each wtll. ARCO Oil and Gas Company,~,'~' Daily Well History--lnterinl Inllructionl: This form is used during drilling or wOrkover operations. If testing, coring, or perforating, show formalion name in describing work pedormed. Number all drill stem teats sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlel'll~l' sheels until final completion. Report olficial or representative test on "Finll" form. 1) Submit "Interim" sheets when tilled out but not less frequently then every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting ol oil strin§ until completion. District Field ARCO ALASKA INC. ICounty or Parish SWANSON RIVER Lease or Unit ~ell no. / ADL A-028996 SRU 242-1~ SWANSON RIVER UNIT Date and depth ae of 8:00 a.m. 08/23/89 ( 7) TD: 3955'( 115 SUPV:BES 08/24/89 (8) TD: 4860'( 90 SUPV:BES 08/25/89 (9) TD: 4860'( SUPV:BES 08/26/89 (10) TD: 4860 PB: 4780 SUPV:RWS 08/27/89 (11) TD: 4860 PB= 4780 SUPV:RWS 08/28/89 (12) TD: 4860 PB: 4780 SUPV:RWS 08/29/89 (13) TD: 4860 PB: 4780 SUPV:RWS Complete record for each day while drilling or workover in progress GRACE i54 DRILLING 9-5/8"@ 2337' MW: 9.2 VIS: 36 CO MWD. DRILLED TO 2580'. CIRC WHILE WO GYRO. POOH. GYRO SURV'D SURFACE CSG AND VERIFIED THAT MWD IS OK. GIH AND DRILLED TO PD. DAILY:S42,348 CUM:$386,397 ETD:S344,049 EFC:$1,352,348 POOH TO LOG 9-5/8"@ 2337' MW: 9.5 VIS: 36 DRILLED TO 4112'. TFNB. DRILLED TO TD @ 4860'. PREPARE TO LOG. DAILY:S18,190 CUM:$404,587 ETD:S404,587 EFC:$1,310,000 POOH LAYING DOWN DP 9-5/8"@ 2337' MW: 9.6 VIS: 38 FPOH. RU ATLAS AND RUN OH LOGS. GIH AND CONDITION FOR CSG. POOH AND LD DP. DAILY:S48,694 CUM:$453,281 ETD:S453,281 EFC:$1,310,000 INSTALLING CSG PACKOFF 9-5/8"@ 2337' MW: 9.6 NaCl POOH AND LD DP. RU AND RUN 7" 269 N-80 BTC CSG TO TD. CMT CSG W/325 SX CLASS 'G' BLEND. CIP @ 0030 HRS 8-26-89. FLOATS HELD. ND STACK AND INSTALL SLIPS. CUT CASING AND INSTALL PACKOFF. DAILY:S115,130 CUM:$568,411 ETD:S568,411 EFC:$1,310,000 PREP TO PERFORATE 9-5/8"@ 2337' MW: 9.6 NaCl NU TBG SPOOL AND TEST. TEST BOPE. RU AND RUN CASED HOLE LOGS AND GYRO. RU TO PERFORATE. DAILY:S27,220 CUM:$595,631 ETD:S595,631 EFC:$1,310,000 RUNNING COMPLETION 9-5/8"@ 2337' MW: 9.6 NaCl EVALUATE PDK-100 FOR PERF DEPTHS. PERFORATE WELL AND RD ATLAS. RUN 3-1/2" ASSY. GALLED TOP THREADS ON TBG HGR. WO NEW HANGER FROM FMC. DAILY:S68,530 CUM:$664,161 ETD:S664,161 EFC:$1,310,000 RIG RELEASED 9-5/8"@ 2337' MW: 9.6 NaCl REC'D NEW TBG HGR AND MU SAME. SET PKR AND SHEARED PBR. TESTED TBG TO 2500 PSI. OK. NU TREE AND TESTED SAME. OK. RELEASED RIG @ 2000 HRS, 8-28-89. DAILY:S75,696 CUM:$739,857 ETD:S739,863 EFC:$1,309,994 The above ia correct Sig na~,.~.~ ~ For form preparatio~nd distribution see Procedures Ma~tu~ Section 10, Drilling, Pages 86 ~ 87 / / ~ v I AR3B-459-2-B INumber all daily well history forms consecutively ae Ihey are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or ~old. · 'Final Rel~orr' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when In official lest il not required upon completion, report completion and representative test data in blocks provided. The "Final Rep~rt" form may be used for reporling the entire operation ii space is available. IAccounting coat center code ARCO ALASKA INC. I SWANSON. RIVER ILease or Unit ]Well no. SWANSON RIVER UNIT I ADL A-028996 SRO 242-~6 Title DRILLING Field Aulh. or W.O. no. ~a~)63 66 Operator ARCO Spudded or W.O. begun SPUD Date and del)th as of 8:00 a.m_ 08/30/89 (14) TD: 4860 PB: 4780 SUPV:RWS IA.R.Co. W.I. 48.4864 Date 08/17/89 Complete record for each day reported GRACE 154 I otal number of wells (active or inactive) on this Dst center prior to plugging anti I bandonment of this well I our ]Prior etatue If a W.O. 14:30 FINAL REPORT 9-5/8"@ 2337' MW: 9.6 NeC1 FREEZE PROTECTED 7" X 9-5/8" ANNULUS WITH 4-1/2" BBLS DIESEL. DAILY:S7,365 CUM:$747,222 ETD:S747,222 EFC:$1,310,000 OidTO I New TD 1PB Depth Released rig IDste [Kind of rig Classifications (oil, gas, etc.) Producing method IType completion (single, dual, etc.) Official reservoir name(s) Potential test date Wall no. Date Reservoir Producing Interval OII or galTest time Production Oil on tell Gel per day Pump size, SPM X length Choke size T.P. C.P. Water % (]OR Gravity Allowable Effective date corrected Tho lbOve il correct s[gnatu¢~.(.~_l' ~ ,Date/' / _la _ For form pmpar~ and distribu o~.n. 0 -- ' see Procedures I~l~ual, Section 10, Drilling, Plgea 86"and 87. AR3B-459-3-C Number ill dally will hi,toP/ forml conlecutlvely i~ they are prepared for each well. jPage no. Dl~d~ ot Atianlfc~kgdlekiC~ap OR'- INAL October 12, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. BO90082/B090086 Well: SRU-242-16 Field: Swanson River Survey Date: 8-22/8-26/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures cc: Judy Boegler, Arco Alaska 1 copy, 1 diskette 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 ° Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. SRU-242-16 SWANSON RIVER ALASKA COMPUTATION DATE: 8/28/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 100 100.00 20O 200.0O 300 300.00 400 400.00 -345.00 -245.00 -145.00 -45.00 55.00 DATE OF SURVEY: 8-22/8-26-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: BO90082/BO90086 KELLY BUSHING ELEV. = 345.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 0 N .00 E .00 0 9 S 65.20 E . 15 0 3 S 67.70 E .09 0 6 N 32.00 E .12 0 5 N 40.10 E .03 .00 .00 .00 .05S .12E -.12 .13S .29E -.29 .07S .39E -.39 .07N .49E -.48 500 500.00 600 599.82 700 699.12 800 797.82 900 895.77 155.00 254.82 354.12 452.82 550.77 0 40 S 84.30 W .75 5 31 S 64.50 W 4.89 7 58 S 73.50 W 2.66 10 33 S 85.50 W 3.22 12 35 S 82.80 W 2.10 .07N .05W .06 2.06S 4.99W 4.88 6.10S 15.98W 15.66 8.79S 31.76W 31.29 10.87S 51.71W 51.12 1000 993.09 1100 1089.43 1200 1184.48 1300 1277.92 1400 1369.64 648.09 744.43 839.48 932.92 1024.64 13 57 S 87.60 W 1.76 17 6 S 88.00 W 3.14 19 4 S 86.60 W 2.02 22 36 S 86.20 W 3.53 24 19 S 85.90 W 1.73 12 13 15 17 2O .74S 74.58W 73.86 .76S 101.33W 100.53 .24S 132.33W 131.42 .48S 167.82W 166.76 .23S 207.54W 206.30 1500 1459.64 !600 1548.01 1700 1634.65 1800 1718.53 1900 1798.74 1114.64 1203.01 1289.65 1373.53 1453.74 27 19 S 86.90 W 3.02 28 29 S 86.00 W 1.24 31 24 S 87.60 W 3.03 34 32 S 88.70 W 3.19 38 46 S 89.50 W 4.26 22 25 28 30 31 .95S 251.01W 249.58 .85S 297.72W 296.09 .61S 347.56W 345.73 .34S 401.95W 399.97 .26S 461.62W 459.53 2000 1874.87 2100 1947.88 2200 2019.89 2300 2092.41 2400 2165.55 1529.87 1602.88 1674.89 1747.41 1820.55 42 2 S 89.80 W 3.29 44 8 S 89.90 W 2.09 43 43 N 89.80 W .46 43 17 N 89.50 W .48 42 42 N 89.20 W .63 31 31 31 31 30 .65S 526.44W 524.25 .83S 594.75W 592.47 .77S 664.13W 661.77 .35S 732.98W 730.56 .57S 801.18W 798.71 2500 2238.93 2600 2312.35 2700 2386.06 2800 2459.94 2900 2533.98 1893.93 1967.35 2041.06 2114.94 2188.98 42 52 N 88.90 W .27 42 38 N 88.60 W .31 42 23 N 88.10 W .42 42 21 N 87.50 W .41 42 5 N 87.50 W .26 29 27 26 23 20 .45S 869.10W 866.61 .97S 936.98W 934.47 .02S 1004.53W 1002.04 .43S 1071.87W 1069.43 .50S 1139.02W 1136.64 3000 2608.37 3100 2682.94 3200 2757.42 3300 2831.92 3400 2906.67 2263.37 2337.94 2412.42 2486.92 2561.67 41 46 N 87.20 W .39 41 47 N 87.00 W .14 41 55 N 86.30 W .49 41 45 N 86.00 W .26 41 29 N 85.70 W .34 17 14 10 5 .41S 1205.78W 1203.47 .04S 1272.32W 1270.10 .14S 1338.94W 1336.82 .66S 1405.50W 1403.52 .86S 1471.75W 1469.93 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. SRU-242-16 SWANSON RIVER ALASKA COMPUTATION DATE: 8/28/89 DATE OF SURVEY: 8-22/8-26~ '~9 BOSS GYROSCOPIC SURVEY JOB NUMBER: BO90082/B090086 KELLY BUSHING ELEV. = 345.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 2981.73 2636.73 41 12 N 85.10 W .49 3600 3056.98 2711.98 41 11 N 84.80 W .20 3700 3132.47 2787.47 40 45 N 84.30 W .54 3800 3208.33 2863.33 40 33 N 83.80 W .38 3900 3284.40 2939.40 40 24 N 83.40 W .31 4.44N 1537.60W 1535.96 10.24N 1603.21W 1601.78 16.47N 1668.49W 1667.28 23.22N 1733.29W 1732.34 30.45N 1797.81W 1797.13 4000 3360.76 3015.76 40 1 N 82.70 W .58 4100 3437.50 3092.50 39 43 N 82.50 W .33 4200 3514.60 3169.60 39 22 N 82.40 W .37 4300 3591.81 3246.81 39 32 N 82.30 W .19 4400 3668.98 3323.98 39 26 N 81.80 W .34 38.27N 1861.90W 1861.53 46.52N 1925.48W 1925.44 54.89N 1988.60W 1988.90 63.35N 2051.59W 2052.23 72.15N 2114.58W 2115.57 4500 3746.27 3401.27 39 19 N 80.90 W .58 4550 3784.98 3439.98 39 13 N 80.80 W .22 4600 3823.71 3478.71 39 13 N 80.80 W .04 4700 3901.17 3556.17 39 13 N 80.80 W .02 4800 3978.63 3633.63 39 13 N 80.80 W .02 81.69N 2177.30W 2178.69 86.72N 2208.55W 2210.15 91.78N 2239.77W 2241.57 101.89N 2302.20W 2304.42 l12.00N 2364.63W 2367.27 4860 4025.11 3680.11 39 13 N 80.80 W .03 118.07N 2402.08W 2404.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2404.98 FEET AT NORTH 87 DEG. 11 MIN. WEST AT MD = 4860 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 272.81 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. SRU-242-16 SWANSON RIVER ALASKA COMPUTATION DATE: 8/28/89 DATE OF SURVEY: 8-22/8-26-89 JOB NUMBER: BO90082/BO90086 KELLY BUSHING ELEV. = 345.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -345.00 1000 993.09 648.09 2000 1874.87 1529.87 3000 2608.37 2263.37 4000 3360.76 3015.76 .00 .00 .00 12.74 S 74.58 W 6.91 6.91 31.65 S 526.44 W 125.13 118.22 17.41 S 1205.78 W 391.63 266.50 38.27 N 1861.90 W 639.24 247.61 4860 4025.11 3680.11 118.07 N 2402.08 W 834.89 195.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. SRU-242-16 SWANSON RIVER ALASKA COMPUTATION DATE: 8/28/89 DATE OF SURVEY: 8-22/8-26-89 JOB NUMBER: BO90082/B090086 KELLY BUSHING ELEV. = 345.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -345 45 45.00 -300 145 145.00 -200 245 245.00 -100 345 345.00 .00 .00 .00 .00 .00 .00 .00 .00 .00 S .01 E .00 .00 .10 S .22 E .00 .00 .14 S .33 E .00 .00 .00 N .43 E .00 .00 445 445.00 545 545.00 645 645.00 746 745.00 848 845.00 100 200 300 400 500 .00 .00 .00 .00 .00 .12 N .50 E .00 .00 .40 S 1.37 W .03 .03 .92 S 9.43 W .44 .41 .64 S 22.70 W 1.39 .96 .53 S 40.67 W 3.02 1.63 950 945.00 1053 1045.00 1158 1145.00 1264 1245.00 1372 1345.00 6OO 700 8OO 900 1000 .00 .00 .00 .00 .00 12 13 14 16 19 .16 S 62.76 W 5 .29 S 88.31 W 8 .44 S 118.74 W 13 .62 S 154.59 W 19 .43 S 196.43 W 27 .47 2.45 .70 3.23 .24 4.54 .51 6.27 .96 8.45 1483 1445.00 1596 1545.00 1712 1645.00 1832 1745.00 1960 1845.00 1100 1200 1300 1400 1500 .00 .00 .00 .00 .00 22 25 28 30 31 .53 S 243.55 W 38 .74 S 296.09 W 51 .86 S 353.95 W 67 .72 S 420.67 W 87 .53 S 500.11 W 115 .56 10.60 .57 13.01 .17 15.59 .43 20.26 .18 27.75 2095 1945.00 2234 2045.00 2372 2145.00 2508 2245.00 2644 2345.00 1600.00 1700.00 1800.00 1900.00 2000.00 31 31 30 29 27 .82 S 591.95 W 150 .68 S 688.15 W 189 .84 S 782.22 W 227 .34 S 874.74 W 263 .22 S 967.02 W 299 .99 35.81 .75 38.76 .04 37.30 .28 36.24 .37 36.09 2779 2445.00 2914 2545.00 3049 2645.00 3183 2745.00 3317 2845.00 2100 2200 2300 2400 2500 .00 .00 .00 .00 .00 24 20 15 10 4 .03 $ 1058.27 W 334 .07 S 1148.97 W 369 .80 S 1238.46 W 404 .86 S 1327.80 W 438 .85 S 1417.15 W 472 .79 35.41 .85 35.06 .11 34.26 .31 34.19 .54 34.24 3451 2945.00 3584 3045.00 3716 3145.00 3848 3245.00 3979 3345.00 2600.00 2700.00 2800.00 2900.00 3000.00 1 9 17 26 36 .72 N 1505.52 W 506 .29 N 1592.77 W 539 .54 N 1679.23 W 571 .63 N 1764.47 W 603 .58 N 1848.77 W 634 .15 33.61 .09 32.93 .54 32.45 .25 31.72 .42 31.17 RECEIVED OCT 2 6 :.~o,,. Oi; o~ (;-'as Cons. Comm]ssiol] Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. SRU-242-16 SWANSON RIVER ALASKA COMPUTATION DATE: 8/28/89 DATE OF SURVEY: 8-22/8-26-89 JOB NUMBER: BO90082/B090086 KELLY BUSHING ELEV. = 345.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4109 3445.00 3100.00 4239 3545.00 3200.00 4368 3645.00 3300.00 4498 3745.00 3400.00 4627 3845.00 3500.00 4756 3945.00 3600.00 4860 4025.11 3680.11 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 47.34 N 1931.66 W 664.75 30.34 58.19 N 2013.32 W 694.32 29.56 69.33 N 2095.06 W 723.95 29.63 81.52 N 2176.27 W 753.35 29.40 94.56 N 2256.92 W 782.48 29.13 107.61 N 2337.52 W 811.58 29.10 118.07 N 2402.08 W 834.89 23.31 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. DATE OF SURVEY: 8-22/8-26-89 SRU-242-16 SWANSON RIVER JOB NUMBER: BO90082/BO90086 ALASKA KELLY BUSHING ELEV. = 345.00 FT. COMPUTATION DATE: 8/28/89 OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 2337 2119.34 1774.34 31.12 S 3585 3045.69 2700.69 9.34 N 3719 3146.87 2801.87 17.70 N 3816 3220.49 2875.49 24.34 N 4070 3414.43 3069.43 44.02 N 758.36 W 9 5/8" CSG 1593.37 W B-3 SANDS 1680.83 W B-4 SANDS 1743.64 W B-5 SANDS 1906.47 W B-6 SANDS 4455 3711.46 3366.46 77.18 N 4550 3784.98 3439.98 86.72 N 4780 3963.14 3618.14 109.98 N 4830 4001.87 3656.87 115.03 N 4860 4025.11 3680.11 118.07 N 2149.15 W BELUGA 2208.55 W SURVEY DEPTH 2352.14 W PBTD 2383.36 W 7" CSG 2402.08 W TD SPERI~;'-SUN DRLG.'~'SVCS. 8RU-24.2-16 SWANSON RIVER ALASKA 8-22/8-26-89 HORTZONTAL PROJECTTON FINISH SCALE START TVD = IS 500 TVD =0 4025. 11 FEET/IN if .8000 '- oobo ,sbo 2oho 15b0 1OhO DEPARTURE 56o ,2500 ,2000 1500 100o .500 mmmmmmmmmmmmmmmmmme ARCO ALASKA, INC. SRU-242-16 STRATIGRAPHIC SUMMARY MEASURED ....... MARKER ....... DEPTH ........ TVD ........ BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 2267FNL 971FWL SEC 15 T08N R09W 9 5/8" CSG 2337 2119.34 1774.34 31.12S 758.36W B-3 SANDS 3585 3045.69 2700.69 9.34N 1593.37W B-4 SANDS 3719 3146.87 2801.87 17.70N 1680.83W B-5 SANDS 3816 3220.49 2875.49 24.34N 1743.64W B-6 SANDS 4070 3414.43 3069.43 44.02N 1906.47W BELUGA 4455 3711.46 3366.46 77.18N 2149.15W PBTD 4780 3963.14 3618.14 109.98N 2352.14W 7" CSG 4830 4001.87 3656.87 115.03N 2383.36W TD 4860 4025.11 3680.11 118.07N 2402.08W mmmmmmmmmmmm ,mmmmmmmmmmmmm mmmmmmmmmmmmmmmmmm~ COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE ,mmmmmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~ DATE OF SURVEY: 8-22/8-26-89 COMPUTATION DATE: 8/28/89 JOB NUMBER: BO90082/BO90086 KELLY BUSHING ELEV. = 345.00 FT. SPERR~':-SUN DRLG. '~SVCS. VERTTCAL PROJECTION SRU-242-16 SWANSON RIVER ALASKA 8-22/8-26-89 START FINISH TVD = SCALE IS 1000 TVD =0 4.025. 11 FEET/IN 1,1 1000 2000 8000 40O0 SO00 6000 7000 4860L ~obo ~obo soho ~obo VERTICAL SECTION DIRECTION = O. O0 soho ! 6030 ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSM1TrAL #349 TO: John Boyle FROM: Tom Wellman COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: Sept. 6, 1989 WELL NAME: SRU 242-16 Transmitted herewith are the following Blue Sepia Sepia Line Folded Rolled MTlar Ta~e DIFL 2" &5" 1 1 I BHC 2" & 5" 1 1 [CZD/CN 2" & 5" 1 1 ACBL/V/S 1 1 EPILOG-GAS ID 1 1 EPII~OG-INTERPR. RESULTS 1 1 - PDK-100 1 1 GA!~@dA RAY SRU 3 !-33WD ! Receipt Acknowledgement: Date: ATTN: Judy Boegler ATO Post Office Box 100360 Anchorage, AK 99510-036~}L~ ARCO Alaska, Inc/'-"'" Post Office ,__x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 20, 1989 Mr. C. V. Chatterton Chairman, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501-3192 Dear Mr. Chatterton' Please make note in your files that the actual surface location for ARCO's SRU 242-16 well is as follows' Surface Location' 2267 FNL, 971 FVVL, Sec. 15, T8N, R9W, SM. Also please find the attached BOP sketch showing the upgraded BOP stack which is actually being used on the well. If you or your staff have any questions or need any further information please contact Jim Zernell at 263-4107. Sincerely, Patrick J. ^rchey ^rea Drilling Fngineer cc: J. T. Zernell File JTZ/MAC ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C 13-5/8' ,3000 PSI BOP STA,_.;; DIAGRAM ACCUMULATOR CAPACITY TEST I I PI PE RAMS I ¢ I I I BLI ND RAMS I SPOOL I I, ( PIPERAMS I I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 3,500 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PiPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 3,500 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 3,500 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 3,500 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 12. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BLIND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPMENT 5000 PSI RATED December 29, 1988 Telecopy: (907)276-7542 Mr. P. J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Swanson River Unit 242-16 ARCO Alaska, Inc. Permit No. 88-157 Sur. Loc. 2243'FNL, 948'FWL, Sec. 15, TSN, R9W, SM. Btmhole Loc. 2254'FNL, 1492'FEL, Sec. 16, TSN, R9W, SM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly Mpurs, Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf ~ ~' Enclosure cc: Department of FiSh & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. LamOreaux STATE OF ALASKA '~"., ALASKA L..,_ AND GAS CONSERVATION C(. MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~1 lb. Type of well. Exploratory ,.~ Stratigraphic Test Re-Entry ~ DeepenQI Service C Developement Gas ,,~ Single Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, lng, GL = ~1~ feet Swanson River Field 3. Address 6. Property Designation Sterl lng Gas P.O. Box 100360, Anchorage, AK 99510 Swanson River Field Pool "B" 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 2o AAC 25.025~ 2243' FNL, 948' FWL, Sec. 15, TSN, Rgw, SM Swanson River Unit Statewide At top of productive interval 8. Well number Number SRU 242-16 -650607 2250' FNL, 550' FEL of Sec. 16, T8N, R9W, SM At total depth 9. Approximate spud date Amount 2254' FNL, 1492' FEL, Sec. 16, TSN, Rgw SM February, 1989 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (ME)and TVD) property line ~840 feet 114' (on surface) feet 7900 4900'ND/4000'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.0~S Kickoff depth 500 feet 43° Maximum hole angle 0 Maximum surface 1245# psig At total depth O'VD) BHP=3450'TVD ~s,g 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade iCoupling Length MD TVD MD TVD (include stage data) 16" X-52 Weld ~lO' 30' ~O' 11o' 110' To surface 12-1/¥ 9-5/8" 36 J-55 BTC ~.~?1 ' 29' 29' 2300' 2100' ~20 ~ Cl 'G' 8-1/2" 7" 26 J-55 BTC 4~72 28' 28' 4900' 4000' 400 sx C1 'G' 19. TO be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~% F~ Surface Intermediate '.~} ~.:i :i-; Production Liner A,~S',~.~.: dli .;.'.:: Perforation depth: measured true vertical 20. Attachments Filing fee .,~ Property plat ~ BOP Sketch .'X] Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot .~ Refraction analysis D Seabed report ~ 20 AAC 25.050 requirements - 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engineer ~ Title Date Signed · Commission Use Only ~'u~/u~,~ Permit Number I APl number I Approval date I See cover letter 8~'1~'? 50--1:~3- ;~O~/O5' 12/29/88 for other requirements Conditions of approval Samples required ~ Yes !~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures C Yes ~ No Directional survey required ~!~ Yes ~ No Other:Requo ired work~r~re.~7OP~2~~ ,.~///,, ~ /~//'~1~~ comlOM; I% 15M by order of /~/~ A_proved by missioner the commission Date Subm~ riplicate I I I I I I PROPOSED SRU- 242- I I 18 19' I I-.., IO I I ~ I Icu I ~ I I 978' i I I IT9N T8N 12 I I 27 I 26 I I ~5.~=J. ~. I 24 III : SCALE = I MILE CERTIFICATE OF SURVEYOR I hereby ce'rtify thor ! om properly registered ond licensed to proctice Iond surveying in the Store of AIosko ond thor this plot represents o Iocofion survey mode by' me or under my supervision, ond thor oil dimensions ond other detoils ore correct. Dote SURVEYOR I)R~P o~rD LOCATION SRU- 242-16 Located ia Sec. 15 Alaska Surv.yed for ARCO ALASKA INC. RO. BOX 100:560 ANCHORAGE~ AK. 99~10-0:~:~0 Surveyed by R.C. DAVIS 8~ ASSOC. LAND & MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH.~AK. 99516 ANNULAR PREVENTER PIPE RAMS BLIND RAI'I$ 11. 12. 13. ACCUMULATOR CAPACITY TE~T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIO FLUID. 2. A,~URE THAT AC:CIUMULATOR PRE,,q~URE 13 3000 P:51 WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OB,SERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADO REPORT. THE ACCEPTABLE LOWER LIMIT' IS 45 SECONDS CLOSING TIME AND 1200 PS1 REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUO WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN ~REW$ IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRE~URE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES. IF ANY. WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLCLSE BLIND RAMS AND TEST TO 5000 PSi FOR 10 MINUTES. BLEED TO ZERO P 10. OPEN BLIND RAMS AND RECOVER TEST PLUO. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY ODCKS AND IN,SIDE BOP TO 5000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. DM MARCH 9, 1987 . NOTE' DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE RISER IFLOWLINE II 2000 PSI / 10" BALL VALVE 10" BALL VALVE i 5 -; :'" ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES, THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE 'FROM 20AAC25.035 10" VENT LINES I I I I I-- I I I mmmmmmmmmmm RIG MODULES I NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES mmmmmmmmmmmmm JG 7127/87 SRU 242-16 Drilling Procedure ARCO Alaska, Inc., as operator proposes to drill a shallow dry sands gas well designated SRU 242-16. The well will be located approximately 2243 FNL 948 ~MTL Sec 15, T8N, R9W, SM. 1. After location construction, drive 80' MD/TVD of 16" conductor. 2. Move and rig up a drilling rig similar to Grace Rig #154. 3. Nipple up 20" 2000# WP diverter and lines. Function test same. 4. Drill 12¼" hole to ±2~00' TVD. 5. Run 9-5/8" casing and cement witheR0 sx of Class G, to bring cement to surface. 6. Install casing head and nipple up 5000# WP BOP. 7. Test BOP equipment. Notify AOGCC and BLM 24 hours in advance of BOP test. 8. Drill out 9-5/8" float collar and test casing. 9. Drill out 9-5/8" shoe and 10' of new 8½" hole. 10. Circulate and condition mud and perform leak off test. 11. Drill 8~" hole to TD. 12. Log open hole. 13. Run 7" casing and cement with 400 sx of Class G. adjusted to caliper log. 14. Run a cement evaluation log. Run a gyro to give a continuous directional survey. 15. Complete the well with 3½" tubing. Note: Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level on location will be pumped down the sur- face/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with cement upon completion of the fluid disposal. SR/176 - #1 ARCO ALASKA, Ino. SRU 242-16 Proposed Swanson River Field, Kenal, Alaska 500 _ 1000 _ 1500 _ 2000_ 2500_ 3000_ 3500_ 4000_ 4500 0 SURFACE KOP TVD=500 TMD=500 DEP=O 15 . BUILD 2.5 DEG 20 PER lOO FT 35 4O EOC TVD"2071 TI'ID=2231 DEP=623 TVD=2121 THD=2300 DEP=671 _ N~ET TVD~3000 THD=3507 DEP~i498 AVERAGE ANGLE TD / 7' CSG PT ' TVD=4000 THD=4881 DEP=2440 500 ! 000 1 500 2000 2500 VERTICAL SECTION SCALE 1 IN. m 500 FEET ~ MEST-EAST ' ~000 ~500 i ' 2000 ~1500 1000 500 , ,, , ~ r~n£T TVD- SO0o DEP" ~ i ' ,. ,~ , ....... ~ ......... ., =;'- . ; :, : , - -. = = : z : 4 -::' . , , 100_.0 .. N ....... ~ :..F. NL,.. ~5507 fa'El, TD LOCATIO ~ 8EO. 16., TSN,. Rg~ ..... i ' :2254~' FNL, 1492' FEL SEC. 16. · ........ . ....... . .... S .89 DEG 44 M:IN W 1498' .LTO TAROET) ~ SURFAC~ SRU 242-16 Drilling Fluid Program Density PV Spud to 9-5/8" Surface .Casing 8.4-9.0 15-30 Drill Out TO TD 9.0-9.5 8-15 YP 20-40 10-15 Viscosity Initial Gel 50-100 5-15 35-45 3-5 10 Minute Gel 15-30 8-15 Filtrate API 2O 8-12 pH % Solids 8-9 10+ 8-9 6-10 Drilling Fluid System Dual tandem shale shaker Mud cleaner Centrifuge Degasser Pit level indicator (visual and audio alarm) Trip tank Fluid flow sensor Fluid agitators Drilling fluid practices will be in accordance with the appropriate regu- lations stated in 20AAC25.033. Maximum anticipated surface pressure is calculated using a surface casing leak off of 12.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows maximum surface pressure of 1080 psi. Since formation breakdown would occur before a surface pressure of 3000 psi could be reached, ARCO Alaska, Inc. proposes to test our BOP equipment to 3000 psi. SR/176 ih II ISUCTION PUMP ---- I suc~ I ICHARG£ i IPUMP I UP _ DESILTER DESANDER i CUTTINOI O ARCO Alaska, Inc. Post Office Box- 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 6, 1988 Mr. Joe Dygas Bureau of Land Management Division of Mineral Resources 6881 Abbott Loop Road Anchorage, Ak 99501-2599 Mr. John Wharam Alaska 'Department of Natural Resources P.O. Box 7034 Anchorage, Alaska 99510-7034 CO RE Re: ARCO Alaska Inc., Swanson River, Shallow Gas well, SRU 242-16 Dear Sirs: ARCO Alaska, Inc. proposes to drill a shallow gas well in Sec 16, T 8 N, R 9 W, Seward Meridian, approximately 4 miles north of the field. Compressor Plant. This well will be drilled from USF&WS surface property into BLM, Oil and Gas Lease, #A-028406. The well is scheduled to be drilled beginning approximately February 1, 1989 with drilling and testing operations requiring less than one hundred days to complete. At that time, the well will be converted to a gas producer in accordance with BLM and AOGCC requirements. The solid drilling waste will be disposed of in accordance with ADEC regulations at the Central Disposal Site. A temporary water use request will be obtained from L&WM. Waste liquids generated during the drilling activities will be injected either in the well annulus or in one of the field injection wells. Enclosed with this notification is a copy of the "Plan of Operations" and "Coastal Project Questionnaire". If you have any questions or detect a need for additional permits or other authorizations regarding this planned gas well, please call me at 265-6176. Sincerely, Peter N. Hellstrom Permit Coordinator PNH: es:ill PNH/12/004 Enc. Plan of Operations CZM Questionnaire RECEI VED DEC .1. ]988 Alaska,Oil & Gas Cons. CommisslOt~ ' ~i.' ~nch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Mr. Joe Dygas and Mr. John Wharam December 6, 1988 Page 2 CC: Robert Flint, ADEC, Anchorage Les Leatherberry, ADEC, Soldotna Lonnie Smith, AOGCC, Anchorage Bob Richey, USF&WS, Soldotna Jane Gabler, KPB, Soldotna Hank Baij, COE, Anchorage Patty Bielawski, DGC, Anchorage Yes Will your project result in the development of a currently unpermitted facility for the disposa[~ of domestic or industrial solid waste? 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than 10,000 barrels of such products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need a permit or approval from the Alaska Department of Environmental Conservation (DEC), Continue to the next section. If you answered YES to any of these questions, contact the DEC Regional Office for information and application forms, Based on your discussion with DEC, please list (below) the approval type needed and date submitted. /~,ooroval Tyoe Date Submitted (or intend to submit) Drillinq Waste Notice Dec. 88 Waste Water Injection Dec. 88 If you are not applying for DEC permits, indicate reason below' a. (DEC contact) told me on approvals or permits were required on this project. ~,___ b. Other. (date) that no DEC CERTI F ICATION STATEMENT T-he information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alask Coastal Management Program. Signature of Applicant or Agent Date Peter N. Hellstrom To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5of5 2. Is your project located in a State Game Refuge, Critical Habitat Area, or State Game Sanctuary.~ 3. Does your project include the construction and operation of a salmon hatchery? 4. Does your project affect or is it related to a previously permitted salmon hatchery? I"-1 5. Does your project include the construction of a shellfish or sea vegetable farm? r'-"l if you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Fish and Game (DFG). Continue to the next section, If you answered YES to any of the questions under 1 or 2, contact the Regional DFG Habitat Division Office for information and application forms, If you answered YES to questions 3, 4, or 5, contact the DFG Private Nonprofit Hatchery Office at the F.R,E,D division headquarters for information and application forms, Based on your discussion with DFG, please list (below) the approval type needed and date submitted. APProval Tyoe Date Submit, i~ed (or intend to submit) If you are not applying for DFG permits, indicate reason below' ~a. (DFG contact) told me on approvals or permits were required on this project. (date) that no DFG .______ b. Other DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS !. Wilt a discharge of wastewater from industrial or commercial operations occur? (See =2 in "Federal Permits" section.) Yes 1 your project generate air emissions from the following: Diesel generators totaling more than 10,000 hp? Other fossil fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or 100,000,000 btu/hr? Asphalt plant? Incinerator burning more than 1000 pounds per hour? Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4. Will you be processing 'seafood? 5. Will food service be provided to the public or workers? 6. Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? No 4of5 If you answered YES to ANY questions in this section, contact DNR to identify and obtain necessary application forms. Based on your discussion with DNR, please list (below) the approval type needed and date submitted. AD~roval Type Date Submitted (or intend to submit) Temporary Water Use Dec, 88 Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below' a, (DNR contact) told me on, approvals or permits were required on this project. b. Other. Yes (date) that no DNR DEPARTMENT OF FISH AND GAME APPROVALS 1. Will you be working inastream, river, orlake? (This includes running water or on ice, within the active floodplain, on islands, the face of the banks, or the stream tideflats down to mean Iow tide.) Name of stream or river: Name of lake: If you answered "no," proceed to question =2. If "yes," will you be doing any of the following? a. Building a dam, river training structure, or instream impoundment? b. Using the water? c. Diverting or altering the natural channel stream? d. Blocking or damming the stream, (temporarily or permanently)? e. Changing the flow of the water or changing the bed? f. Pumping water out of the stream or lake? g. Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream with tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? Yes Yes F1 F-1 1. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n, Constructing a weir? o. Other in-stream structure not mentioned above? 3of5 rq No No No 2. Have you applied for or do ~,ou intend to apply for a U.S. Environment~ Protection Agency National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right and describe below. (Note: Any wastewaterdischarge requires an NPDES permit.) 3. Have you applied for or do you intend to apply for permits from any other federal agency? If yes, please list below. Aaencv BLM COE Yes No AoDroval TyQe Date Submitted (or intend to submii;) Lease Ooeration Dec. 88 Wetland Determination Dec. 88 I')FPARTMFNT OF NATllPAI PF.SC)tIRC. F% APPRtqVAI S 1. Is the proposed project on state-owned land or will you need to cross state lands for access? 2. Is any portion of your project placed below the ordinary high water line of a stream, river, lake, or other water body? 3. Will you be dredging? If yes, location of dredging is' Townshil~ Range Meridian~ Section Yes · Location of disposal site for dredged materials: Townshil~ Range Meridian~ Section 4. Will you be filling with rock, sand, or gravel? If yes, amount_? · Location of source: Township Range Meridian · Location of area to be filledl'ownship Range Meridian~ 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount? · Location of source:Township Range Meridian~ Other Materials · If yes, what material? (Peat, building stone, silt, overburden, etc.) · Location of source: Townshi~q Range Meridian 5. Are you planning to use any fresh water? · If yes, amount (gallons per day)? 10,000 · Source? ,G'~n~nd w~frr 7. Will you be building or altering a dam? 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will you be exploring for or extracting minerals on state-owned land? I 1. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? 13. Will you be investigating or removing historical or archaeological resources on state-owned land? Section Section Section Section Yes Yes Yes No No No 14. Will the project be located in a unit of the Alaska State Park System? If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Natural Resources (DNR). Continue to the next section. 2of5 Coastal Questionnaire and Certification Statement Project Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. AppLICANT INFORMATION 1. ARCO Alaska. Inc. Name of Applicant P.O. Box 100360 Address Anchoraqe, AK 99510-0360 City/State/Zip Code (907) Phone PROJECT INFORMATION Peter N. Hellstrom 2. Contact Person P.O. Box 100360 Address Anchorage, AK 99510-0360 City/State/Zip Code (907) 265-6176 Phone 1. Provide a brief description of your project and ALL associated facilities (caretaker facilities, etc.) Drill, develop, and produce a shallow gas well within the Swanson River Field (SRU 242-16). Starting Date for Project 1 Feb 89 pROJECT LOCATION Ending Date for Project 30 Jun 89 1 Please give location of project. (Include nearest Community or identifiable body of land or water.) Swanson River Field~ Kenai National Wildlife Refuqe~ Kenai Peninsula~ Alaska Township 8N Range 9W MeridianSeward Section 15 Aliquot Parts USGS Map 2. Is the project on: State Land ~ (please mark with ~ ) XX Federal Land~ Private Land 3. Project is located in which region of the state (see attached map): Northern~ Southcentral XX Southeast- Municipal Land PERMIT APPROVALS 1. Do you currently have any State or federal approvals for this project? If yes, please listbelow ~ (Note: Approval means permit or any other form of authorization.) Approval Type Solid Waste disposal, ADEC Approval ~ 8623-BA004 Expiration Date August 31, 1991 Area Injection Order, AOGCC Number 13 Non expiring FEDERAL APPROVALS Yes No 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, r-I rs-I or wetlands*? I^l *If you are uncertain whether your proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 753-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free 1-800-478-2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) I~! I~! permit? Please indicate at right and describe below. CZMA: 88:005 l of 5 ARCO Alaska Inc., Temporary Water Use December 5, 1988 SRU 242-16 Enclosure C CZM Questionaire ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION APPROX. 950' FWL, 2285' F NL SEC. 16, T 8 N, R 9 W, SEWARD MERIDIAN DEC 1 :.! 1988 ~las~,Oil & Gas Cons. Commission '-'~!?- ~mchorage SRU 242-16 This Plan of Operation describes pad construction and other activities necessary in drilling a single shallow gas well named SRU 242-16. ARCO Alaska, Inc., (ARCO) will act as the Operator for the well and be responsible for all site surface and subsurface activities. Most drilling support and related services will be supplied by companies based out of Kenai or Soldotna, Alaska. The drilling and testing activities should last from February 1, 1989 to mid-April, 1989. This plan addresses the gas well from site preparation, drilling, and gas production through well plugging and abandonment, including surface restoration. It provides an overview of all activities associated with site development and has been developed to describe the activities that will occur at the site. It does not provide all details associated with the site activities. In the event of a determination that additional wells are needed, a plan or plans for the drilling and development of the additional well(s) will be submitted to the appropriate governmental representatives. 1. Existinz Roads All activities will originate from existing Swanson River field roads and pads, see Exhibit A for the site location maps. 2. Access Access will be by use of the existing road. No up-grade of this existing road is needed. 3. Location of Provosed Well Exhibit A shows the relative surface location of well site and the immediate area. There are approximately 12 existing oiI or gas wells within a two mile radius of the proposed location. The nearest oil or gas well site is located approximately 100 feet to the east. Water wells have been developed within two miles of the site. These wells are associated with past drilling activities within the field and are located at each existing drill site within the field. The location of all water wells in the area are on file in the Anchorage office of the Alaska Department of Environmental Conservation. 4. Well Site Layout The proposed layout of the drill site is shown in Exhibit A. Smoothing of the surface area and addition of gravel (to create a new drill site) is planned. The gravel is needed to accommodate the rig and provide a foundation for well work that might be needed in the future. Because of the shallow depth and the targeted bottom hole location, it has been determined that the well can not be drilled from an existing pad. Therefore, expansion of an existing well pad is being proposed. The attached drawing (Exhibit A) reflects the current plans for the well site layout. Page # 2 a. Pad location and design - The drill site pad size will be approximately 150 feet by 350 feet as indicated in the drawings. Smoothing and leveling of the surface area is planned. The temporary diverter pit will then be excavated. The drill pad will be designed such that the natural drainage of the pad area is towards this sump (Exhibit A), if used. This will ensure that material stays within the site and will prevent extraneous fluids, i.e. surface water, from entering the drill site area. b. Diverter Pit - The basic design of the diverter pit is shown in the attached drawing (Exhibit A). The pit will be approximately 8' wide x 30' long x 4' deep. The sidewall slope for the pit will be approximately 2:1. The pit will be made impermeable by the use of a synthetic liner. This pit will be used only in an emergency (i.e. if the well is put on diverter for safety reasons). The cross section of the drilling location is shown in Exhibit A. .. Turnouts: No road turnouts will be required. Drainage/Culverts' It is not planned to install permanent culverts. Surfacing Material; Fill material or gravel to be obtained from the location or purchased from an approved site will be used to uP-grade the drill site. No concrete or asphalt surfacing will be needed at the site. Gates· A gate or access control device is not needed at this site. Road Maintenance: The newly constructed pad will be maintained to insure acceptable access at all times. The obligation to maintain the pad, under this Plan of Operation, will cease when the gas and .associated support vehicles are no longer required (i.e. if the well is abandoned or suspended and approved clean-up activities and/or restoration are completed). No special road maintenance is anticipated for this project. Location and Type of Water Supply. Fresh water is needed for drilling operations. The primary source of water will be from the water well on drill site 12-15. If the drill site 12-15 well is unacceptable another existing well in the immediate area will be used. Water will not be taken from rivers or surface lakes in the area. Page # 3 , 8~ Approximately 10,000 gallons (250 bbls) of water per day will be required for drilling operations. Total maximum anticipated water usage is estimated at 0.5 million gallons (12,000 bbls). Potable water, used for washing and drinking, will be provided, as necessary, from existing sources within the field. Source of Construction Mgterials Existing native soils and gravel (only as needed) will be utilized for pad construction. The source of construction gravel will be "re-use" of existing gravel that is no longer necessary for field operations. Methods for Handlin~ Waste Disr>osal -- a. Solid non-burnable waste' This type of waste will be handled via contract with a local refuse company. A large enclosed container will be delivered to location and emptied/exchanged as necessary. b. Solid burnable waste' This type of waste will also be handled via contract with a local refuse company. c. Camp waste water disposal' A rig camp will not be utilized. However, additional personnel will be employed within the field and will increase the amount of "camp waste" that will be generated at the main camp facility within the field. This waste will be handled by existing systems. Disposal of Drilling Wastes: During normal well operations, drilling wastes consist of the following: drill cuttings, drill mud, cement, and wash down water. These wastes, non- hazardous fluids generated from well operations, will be conveyed to a metal "cuttings box". During drilling and at the end of the project, any pumpable liquids will either be transporied to the "Oil Skimming Facility" and injected through existing facilities or pumped down the the well just drilled. Liquid waste disposal via underground injection is allowed by authority of either the AOGCC "Permit to Drill" or ADEC "Waste Water Disposal Permit". The "S.olid Waste" that accumulates in the cuttings box during the project will be transported to the Swanson River Field, Central Disposal Site (CDS) and discarded by burial. These wastes will be contained in the lined pit that is permitted and open, and will therefore not pose any hazard to potential drinking water sources in the area. The cuttings box will be a welded steel container approximately 5 feet high and 10 by 20 feet on the sides. This container will be located on a pit liner next to the rig shale shakers. Liquids in the cuttings box will be periodically pumped back to the rig mud pits and reused with the active mud system. The solids that accumulate will be periodically removed by back-hoe and loaded into a water tight transport tank. These tanks will be hauled by truck to the Central Disposal Site for disposal. The cuttings box and surrounding area will be protected by a pit liner. Rig mats will be placed on top of the liner for liner protection and for back-hoe Page # 4 support. This liner-area will be cOntained by a berm to prevent the release or migration of fluids. - The-total volume of waste fluids (i.e. drilling mud and the liquid phase of the cuttings discharge) from this source is estimated as 5,000 barrels. Either the casing annulus or field waste water disposal system will be available for fluids disposal at this well. It is possible that liquid waste will be transported to the "Oil Skimming Facility" and be injected through existing facilities. The available annulus would be between the 9-5/8" x 7" casing strings. The 7" string will be set at the base of the Sterling formation at approximately 3,700 feet TVD (4800 MD). The Sterling, "B" Sands is interbedded with sandstones, claystones, and siltstones. See Exhibit C for a more complete description of the geologic formation, hydrology, and schematic of the well. After evaluating the open hole logs, the placement of the top of the cement should give an open annulus to downsqueeze or pump unwanted water based drilling fluids. Exhibit D contains a simplified well schematic. a..Reserve Pit Design; A reserve pit will not be used during this project. The temporary diverter pit design, which will be used only for safety reasons, was described above. b. Wastes: Drill cuttings come from the well bore being drilled. These solids, consisting mainly of clay and silt, are circulated from the bottom of the well to the surface where mechanical equipment separates and conveys the solids to the cuttings box. The "solids control" equipment typically comprises of shale shakers, desander, desilter, conveyor belt and mud cleaner. These pieces of equipment separate the liquid phase from the drill cuttings; the overall goal is to discharge as little liquid-phase of the mud along with the solids as possible. It is estimated that about 1,000 bbls of drill cuttings will be generated during the project. The well depth is anticipated to be 4,800 feet. Normally, the drill cuttings discharges to the cuttings box are coated with drill mud. In addition, occasionally some drill mud is discharged to the cuttings box when the "solids control equipment" is overloaded. During the course of the project, it is estimated that about 3,450 bbls of mud will be discharged to the cuttings box. The drilling mud proposed for this well is a fresh water base with additives to maintain certain theological and density properties. Tabulated below is a list of possible materials to be used and their application in the mud system. These additives and their concentrations are included on the EPA approved mud list for OCS drilling, Exhibit B. Oil based muds will not be used at this well site. Additiv~ Auulication - - Barite Bentonite clays and extenders Chrome free lignosulfonate Caustic soda Weighing agent Viscosifier Dispersant/thinner pH control Page # 5 Soda ash (sodium carbonate) Bicarbonate of soda Polyanionic cellulose polymers Aluminum stearate Biodegradable lubricant Sodium carboxymethycellulose Lime Calcium removal/pH control Calcium removal/pH control Filtrate control/shale inhibition Defoamer Torque and drag reduction Filtrate control pH control/shale inhibition Occasionally fresh water is used to wash down the "solid control equipment" as well as other rig mechanical equipment; this "gray" water would be collected and either absorbed in the mud system or discharged. Attempts will be made to minimize this "wash down" water amount and at the same time allow for a safe and clean working environment. Additional amounts of water are used to wash the drill cuttings before analyzing them for geoscience purposes. Approximately 500 barrels of this water will discharged to the cuttings box during the life of the project. This waste fluid will be disposed of by injection. In drilling operations, cement is used to grout the steel casings in the well bore and, therefore, seal the steel pipe to the formation rock. This will prevent the sub-surface migration of fluids. It is estimated that, at the most, about 50 bbls of cement would be discharged to the cuttings box and transported to the CDS for disposal. Hydrocarbons, mostly in the form of diesel fuel and hydraulic oil, are used to run the rig equipment and machinery. These fuels and occasional lubricants and greases should all be in containers and are transferred, through secure hoses under strict supervision, so that spillage is avoided. Very little, if any, hydrocarbon should find its way to the cuttings box. c. Diverter Pit Closure; At the end of the project, and in the remote chance that solids and any non- pumpable liquid waste might be in the diverter pit, these wastes shall be removed and disposed of at the CDS. The liner will be removed and the temporary pit will then be closed by removal of the liner and back filling the pit with the native loess'which was excavated during pit construction. A site visit during the first, third and fifth year is planned to inspect the integrity of the restoration and to perform any remedial work that might be needed for site stabilization. 9. Disposal of Produced Fluids - Oily Wastes: When testing the well, the gas hydrocarbons will be processed through existing oilfield test separators existing at the installed facilities. Therefore, on-site liquid hydrocarbon generation is not anticipated. Other hydrocarbon liquids from the site will be trucked from the location and added to the Oil Skimming Facility. Any such liquid hydrocarbons will become a part of the field production. The liquid-free gas will be metered and added to the 150# gas system. Page # 6 10. Ancillary Facilities: All equipment necessary for drilling and formation evaluation will stay either on the drill site or at the existing production facility pads. No special aircraft landing or service facilities will be necessary. Because rig and support personnel will either return home or stay in local hotels in the area, no rig camp or camp kitchen facilities are planned to be utilized on site. 11. Plo, n for Site Closure: Upon completion of drilling and testing/evaluation operations, all residual muds, will be removed and abandoned at the Central Disposal Site. Other debris or solid waste will be hauled to an approved disposal site. The well will be converted to a producer according to Alaska Oil and Gas Conservation Commission regulations. Post-development site visits will be conducted during the first, third and fifth summer following drilling and site abandonment operations to verify the integrity of the closure method, and to remove any remaining litter. 12. Wildlife Access: The wastes to be discharged to the Cuttings box or diverter pit should hold no attraction for wildlife and therefore secondary impacts to wildlife are not a significant factor. Personnel will be instructed not to feed, harass or hunt wildlife on site. 13. Safety Hazards: The only site safety concern probable would be the potential for a vehicle running into the cuttings box. This possibility is remote due to cuttings box siting, away from the access route to the location. It is common knowledge to those employed in these operations-where the box is located and the associated traffic restrictions. The fact that the'"public" will not be allowed access to the site also minimizes the potential for a safety violation. The gas generation concern associated with well drilling and testing will be addressed by access controls which exist at installed equipment locations and which apply to the drilling activities. 14. ~;pill Contingency: a. An approved spill control package will be kept on-site at all times for use in controlling accidental discharge of fuels and lubricants. Absorbent materials for controlling any accidental discharge of fuel or lubricants will be on-site at all times, with a back-up supply at the Swanson River Field and ARCO's Kenai warehouse facilities. In addition, an SPCC plan will be prepared and retained at the drilling location. b. Fire, Safety and medical emergencies will be handled through available resources at Soldotna and Kenai, Alaska. Page # 7 c. Well control problems will be handled in a manner commonly accepted as safe oilfield practice utilizing the diverter, diverter pit, blow out preventer, and other resources as necessary. 15. Communication and Supervision: An ARCO representative will be on site at all times during drilling and well testing operations. The following people are designated as contacts. Name Title Company Ph0n¢ # Bret Allard Operations Manager ARCO 283-7144 Keith Bullard Drilling Superintendent ARCO 263-4609 Doug Stoltz Drilling Superintendent ARCO 263-4111 Jeff Kewin Regional Drilling Engineer ARCO 263-4970 Pat Archey Area Drilling Engineer ARCO 263-4622 Scott Sigurdson Sr. Drilling Engineer ARCO 265-6986 ARCO 24 hour Security switchboard 276-1215 16. Development Drilling and Production Plan of Operation: If the well, to be drilled according to the Plan of Operation, is successful and a commercial gas volume is defined; the gas will be tied in to the existing 150# gas gathering system at Tank Setting (TS) 2-15. This will minimize facility investments, surface disturbance, and result in the most cost effective method of production. To accomplish this, approximately 450 feet of buried four inch pipeline will be installed between the well head and TS 2-15. At the tank setting, the gas will be routed to a separate water knock-out vessel and gas metering facilities. After metering, the gas will be combined and mixed with the existing 150# gas production at the Tank Setting. This gas becomes a part of the existing gas gathering system which is routed to the Compressor Plant. To prevent hydrate formation in the well methanol will be injected. Facilities to accomplish injection will include an injection line, pump, and a 500 gallon methanol storage tank. The pump and tank will be located at TS 2-15, within existing buildings. A small diameter injection line (less than one inch) will be buried with the gas production pipeline to carry the methanol to the well head. Surface restoration of these facilities, following abandonment of the field, will be addressed by the field abandonment plan that is approved by the appropriate agencies (USF&WS, BLM, and AOGCC). Page # 8 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION NoVember 29, 1988 Exhibit A Maps and Drawings I I I I I I I I I I I I I / Jl I_ I ~-' ~//5 //~~_: ~~~~ , ~ /~~ --'~-'; ALASKA VICINI~ MAP COOK INLET VICINI~ II ~ I II ~ I ~ I I I II I I I L I ~~~ t' 'X~THIS PROJECT ~ % ~_ - .~ , ~~ ' ~ ~ ~ ~, ', PROPOSED ,~' ~ ~'~ ~' ~ C~ PAD EXP~SION ~ ~ ~ ~ ~ ~ o ~~_ ~ K~ ~EN~NSU~ eo~ou~ ~~ ,~ ~ . . S~E IN MILES ' - ~DHc~ b: ~co A~ ~NC, A4.03,588001 R0 i i I ii 18 17 16 19 20 21 RIVER UNIT TSN, ROW T7N, Rgw 7 I I ~ o_ _. ,~ SCAL£ ,N FEET , SRU 242-16 F PROPOSED 18 17 .~ 16 15 14 PADEXPANSION / SOLDOTNA ~ KENAI PENINSULA BOROUGH CREEK UNIT STATE OF ALASKA Appllc_~don_by ARCO ALASKA INC. Sheet ;Z of 5: Oot~: DEC '88 I A4.0,.,x588002 RO SRU 242-16 12-15 ~SRU 432-15 SC, ALE IN FEET I SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ALASKA Appllc~on b_b_b~: ARCO ALASKA INC. Sheet ,~ of5 o~.: DEC '88 I RO GAS FLARE SRU 242-16 INJECTION TANK 12-15 --SRU 432-15 VALVL -- lo(r ~.~4.E IN FEET SWANSON RIVER UNIT 242-16 ~--12- 15 432 - 1,5 S.~L! 242 - 16 PROPOSED DR!LLSITE LAYOUT KEN~.I PENINSULA BOROUGH SI'fl'r'E OF ALASKA FOR ARCO ALASKA INC. 700 "G" Stree! A nchoroge, ~.leska R.C. DAVIS 8~ ASSOC, A PIPE RACKS g , DIVERTE~iPIT ' CU'i=i'INGS TANK ii 135' 160' 350' A 55' 150' SCALE 1"'. 40' 6" MATTING ~ BOARDS SECTION _1 /~ OlVERTER PIT (4' DEEP) A-A: DURING OPERATION SECTION A-A: AFTER RECLAIMATION LINER FILL ~TERLAL ~TtVE SOILS WASTE DRILLING CU1TING"S EMPTY PIT NOTE ALL EXCAVATED PITS ARE PLANNED TO HAVE A :SIDE SLOPE OF 2:1. SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ALAS~ Appliccl:ion oy: ARCO ALASKA INC, S~e~ 4. of5 Date'. DEC '88 A4035~004 RO ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit B Generic Muds and Additives EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes all earlier versions. Updated versions are available, from EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) 1. Seawater/Freshwater/Potassium/ Polymer Mud KC 1 50 Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed 2. Lignosulfonate Mud Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Lime 2 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed 3. Lime Mud Lime 20 Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Components Maximum Allowable Concentration (lb/bbl) 4~ Nondispersed Mud Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As needed 5. Spud Mud Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or FreshwaterAs needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. The following additives have been approved by EPA in Alaska. Not all of these additives will necessarily be used during drilling of the SRU 242-16 well. Product Name Generic Description Maximum Allowable Concentration (lb/bbl) Aktaflo-S Aqueous solution of non-ionic 3 modified phenol (equivalent of DMS) Aluminum stearate 0.2 Ammonium nitrate 200 mg/l nitrate or 0.05 lb/bbl Agua-Spot Sulfonated vegetable ester formulation 1% by volume Bara Brine Defoam Dimethyl polysiloxane in an 0.1 aqueous emulsion Ben-Ex Vinyl acetate/maleic anhydride 1 copolymer Bit Lube II Fatty acid esters and alkyl phenolic sulfides in a solvent base Calcium carbide As needed Cellophane flakes Chemtrol-X Con Det Polymer treated humate Water solution of anionic surfactants As needed 0.4 D-D Blend of surfactants 0.5 DMS Aqueous solution of nonionic 3 modified phenol Desco CF Chrome-free organic mud thinner containing sulfo- methylated tannin 0.5 Duovis Xanthan gum Durcncx - Lignite/resin blend Flakes of silicate mineral mica -- 45 Product Name Gelex Glass beads LD-8 Lube-106 Lubri-Sal MD (IMCO) Milchem MD Mil-Gard Nut hulls, crushed granular-- Phosphoric acid esters and -- triethanolamine Plastic spheres -- Poly RX Resinex Selec-Floc Sodium chloride Sodium nitrate Sodium polyphosphate Soltex Sulf-X ES Therma Check Generic Description Sodium polyacrylate and polyacrylamide Aluminum stearate in propoxylated oleylalcohol Oleates in mixed alcohols 2 Maximum Allowable Concentration (lb/bbl) 8 10 gal/1500 bbl Vegetable ester formulation 2.0% (by volume) Fatty acid ester Ethoxylated alcohol formulation Basic zinc carbonate 0.25 0.04 gal/bbl or 0.3 lb/bbl As needed As needed 0.4 Polymer treated humate 4 Reacted phenol-formaldehyde- 4 urea resin containing no free phenol, urea, or formaldehyde High molecular weight poly- 0.25 acrylamide polymer packaged in light mineral oil 50,000 mg/1 chloride 200 mg/l nitrate or 0.05 lb/bbl 0.5 Sulfonated asphalt residuum 6 Zinc oxide As needed Sulfono-acrylamide copolymer Product Name Therma Thin Torq-Trim II Generic Description Maximum Allowable Concentration (lb/bbl) Polycarboxylic acid salt Liquid triglycerides in vegetable 6 oil Vegetable plus polymer -- fibers, flakes, and granules VG-69 XC Polymer xo2 Zinc carbonate and lime -- 50 Organophilic clay Xanthan gum polymer Ammonium bisulfite 12 0.5 As needed ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit C Geologic and Hydrologic Description SRU 242-16 SURFACE LOCATION GENERAL INFORMATION T000granhv and Geogranhv The area proposed for the surface location of the SRU 242-16 Well falls geographically on the Kenai Lowlands sub-province of the Cook Inlet Basin. This lowland is bordered on the west by Cook Inlet, on the north by Turnagain Arm and on the east by' the Kenai Mountains (Karlstrom, 1964). This area is further subdivided by topography and geology. The area north of the Kasilof River falls into the Nikishka Lowland sub-unit. The topography of the Kenai Lowland and the Nikishka Lowland unit is the result of repeated Pleistocene glaciations. In the immediate area of the proposed surface location, the topography is dominated by large broad terraces and rolling hills composed of till formed by complex morainal deposits of Eklutna age (90,000 to 110,000 years before present). Filling the lows between morainal ridges are extensive areas of muskeg, swamp and lakes. The greatest relief near the proposed surface location is approximately 175 feet, this is the difference in elevation between the surface location and local base level, the Swanson River. The unconsolidated sediments which overlie .the Tertiary bedrock are composed of deposits of glacial,-fluvial, lacustrine and estuarine origin. Tills are poorly sorted, drift is composed of mixed tills, outwash deposits and lacustrine sediments. Outwash plain deposits are materials deposited in front_ of glaciers. They are composed of well sorted sand and gravel. Abandoned channel deposits are composed of fluvial sands and gravels entrenched in older sedimentary deposits. At approximately 100 feet below the surface, there is an extensive layer of clay and silt that Karlstrom (1964) suggests was deposited in a large proglacial lake. This layer of fine-grained sediments forms an aquitard between an upper unconfined acquifer and an upper confined acquifer. The total thickness of these unconsolidated sediments in and about the surface location is approximately 500 feet as witnessed in the SRU 23-15 and 211-15 wells. Climate Climate on the Cook Inlet/Kenai Lowland is intermediate between the dry, cold continental type of interior Alaska and the wet and mild maritime climate'of the Gulf of Alaska (Sub-polar marine). The Kenai Lowland falls in the precipitation shadow of the Kenai Mountains. The National Weather Service has maintained a weather station at Kenai since 1944. The mean annual rainfall for the Kenai area is about 19 inches. Most of the recorded precipitation falls during the last three months of the calendar year and is stored as ice and snow. Snowfall is heavy during the winter months, generally starting in late October and continuing until late April. Temperatures rarely go below -20OF in the winter and the average summer temperature is approximately 50 - 60°F. Surface Hvdrolog? and Groundwater Systems Surface waters of the Kenai Lowlands fall into the following categories: lakes, streams, and swamps. Surface drainage is not well integrated over this broad area, which reflects on its glacial origin. Streams tend to meander aimlessly, always seeking base level. Lakes, marshes and muskeg make up more than one-third of the total Kenai Lowlands surface. Two lakes, Tustumena and Skilak, occupy glacially scoured and moraine dammed troughs and are drained, respectively by the Kasilof and Kenai rivers. Water falling to the land surface as precipitation flows overland into lakes and streams and infiltrates into the soils. Of the water that infiltrates, some returns to the atmosphere by evaporation and transpiration, and some percolates down to the water table where it recharges the unconfined acquifer. Ground water in the unconfined acquifer flows towards streams and toward springs on the coastal bluffs where it discharges. Ground water in the unconfined acquifer leaks downward through the clay units to recharge the deeper confined acquifers. Ground water in the confined acquifers flows toward the coast and discharges under Cook Inlet. Lakes in the Nikiski area are recharged by precipitation and by ground water inflow. Lakes lose water to evaporation, to ground water outflow, and to outlet streams. ARCO Alaska, Inc. P.O. B°x 100360 Anchorage' AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit D Well Schematic I _11 Ii _ il i I I PROPOSED WELLBOREDIAGRAM ii i ii i 16" CONDUCTOR · 80' 9-5/8" SURFACE CASING · 2000' CEMENTED TO SURFACE 7" CASING ,~ :l: 4.800' CEMENTED TO 500' ABOVE THE 'B' GAS SANDS APPROXIMATE SURFACE LOCATION' 2285' FNL, 950' FWL, SEC.15, TSN-RgW, SM I Jl I I SRU 242-16 PROPOSED WELLBORE DIAGRAM KENN PENINSULA BOROUGH STATE OF ALASKA ,N~pllc~d_'en b_.y: ARCO ALASKA INC. s~eet ~ of5 oo~: DEC '88 ' ' ARCO Alaska Inc., Waste Water Disposal Notification December 5, 1988 SRU 242-16 Enclosure B Formation Information ARCO Alaska Inc., Waste Water Disposal Notification December 5, 1988 SRU 242-16 1. Well Designation/Name: SRU 242-16 Location/Map - see Exhibit A of the Plan of Operation, Enclosure A. 2. List of materials: Description: Volume: Source: - Only those authorized by Appendix A, II, B. of permit # 8740- DB002. - The mud system to be used for the well is described as OCS generic mud, see Enclosure A. The additives to be used are include in this exhibit. The estimated volume should not exceed those volumes provided in Enclosure A. - As specified by the permit, the fluids will be limited to those generated by the exploratory well activities. Hazardous waste will not be injected. 3. Total volume injected: - Less than 10,000 barrels. 4. Zone description: - A complete or detailed description of the zone is not available to ARCO. What is known that is not confidential is contained in the Plan of Operation, Enclosure A. The depth of these zones will be verified when the logs are available. 5. Depth of Injection: - At or below 3,700 feet, TVD. 6. Start/stop dates: - The earliest date to begin injection is February 1, 1989. Injection should be competed by May 30, 1988. 7. Well schematic: See Exhibit E, Enclosure A. 8. Sealing method: A cement plug(s) will be set at various depths within the well as needed to comply with existing AOGCC regulations. Any shallow (less than 400 feet) ground water aquifers will be isolated from the well when the surface casing is cemented in place. At a minimum, cement plugs are also placed above and below any hydrocarbon zone(s) and from 100 feet below the casing shoe to 100 feet above it. AOGCC requirements state that plug placement must be physically verified by an AOGCC witness. 9. Production date: - The latest gas production date for this well is expected to be July 25, 1989. SRU 242-16 SURFACE LOCATION GENERAL INFORMATION Tonoeranhv and Geoeraohv _ - _ -- The area proposed for the surface location of the SRU 242-16 Well falls geographically on the Kenai Lowlands sub-province of the Cook Inlet Basin. This lowland is bordered on the west by Cook Inlet, on the north by Turnagain Arm and on the east by the Kenai Mountains (Karlstrom, 1964). This area is further subdivided by topography and geology. The area north of the Kasilof River falls into the Nikishka Lowland gub-unit (see Figure 1). The topography of the Kenai Lowland and the Nikishka Lowland unit is the result of repeated Pleistocene glaciations. In the immediate area of the proposed surface location, the topography is dominated by large broad terraces and rolling hills composed of till formed by complex morainal deposits of Eklutna age (90,000 to 110,000 years before present) (see Figure 2). Filling the lows between morainal ridges are extensive areas of muskeg, swamp and lakes. The greatest relief near the proposed surface location is approximately 175 feet; this is the difference in elevation between the surface location and local base level, the Swanson River. The unconsolidated sediments which overlie the-Tertiary bedrock are composed of deposits of glacial, fluvial, lacustrine and estuarine origin. Tills are poorly sorted, drift is composed of mixed tills, outwash deposits and lacustrine sediments. Outwash plain deposits are materials deposited in front of glaciers. They are composed of well sorted sand and gravel. Abandoned channel deposits are composed of fluvial sands and gravels entrenched in older sedimentary deposits. At approximately 100 feet belOw the surface, there is an extensive layer of clay and silt that Karlstrom (1964) suggests was deposited in a large proglacial lake. This layer of fine-grained sediments forms an aquitard between an upper unconfined acquifer and an upper confined acquifer (see Figure 4). The total thickness of these unconsolidated sediments in and about the surface location is approximately 500 feet as witnessed in the SRU 23-15 and 211-15 wells. 2 Climate Climate on the Cook Inlet/Kenai Lowland is intermediate between the dry, cold continental type of interior Alaska and the wet and mild maritime climate of the Gulf of Alaska (sub-polar marine). The Kenai Lowland falls in the precipitation shadow of the Kenai Mountains. The National Weather Service has maintained a weather station at Kenai since 1944 (see Figure 3). The mean annual rainfall for the Kenai area is about 19 inches. Most of the recorded precipitation falls during the last three months of the calendar year and is stored as ice and snow. Snowfall is heavy during the winter months, generally starting in late October and continuing until late April. Temperatures rarely go below -20°F in the winter and the average summer temperature is approximately 50 - 60OF. Surface Hydrology and Groundwater Systems Surface waters of the Kenai Lowlands fall. into the following categories: lakes, streams, and swamps. Surface drainage is not well integrated over this broad area, which reflects on its glacial origin. Streams tend to meander aimlessly, always seeking base level. Lakes, marshes and muskeg make up more than one-third of the total Kenai Lowlands surface. Two lakes, Tustumena and Skilak, occupy glacially scoured and moraine dammed troughs and are drained, respectively by the Kasilof and Kenai rivers. Figure 4 depicts the hydrologic setting for the Nikski area. Water falling to the land surface as precipitation flows overland into lakes and streams and infiltrates into the soils. Of the water that infiltrates, some returns to the atmosphere by evaporation and transpiration, and some percolates down to the water table where it recharges the unconfined acquifer. Ground water in the unconfined acquifer flows towards streams and toward springs on the coastal bluffs where it discharges. Ground water in the unconfined acquifer leaks downward through the clay units to recharge the deeper confined acquifers. Ground water in the confined acquifers flows toward the coast and discharges under Cook Inlet. Lakes in the Nikiski area are recharged by precipitation and by ground water inflow. Lakes lose water to evaporation, to ground water outflow, and to outlet streams. STERLING The topmost section of the Sterling represents the transition from fresh to brackish water. This occurs within 60 feet of the top of the Sterling Formation Rw values were calculated throughout the Sterling Formation. Though shaliness has some adverse effects on these calculations, I think the results were quite consistent. Rw seems to be within the range of .265 ohm meters to .235 ohm meters at 75°F (22 kppm to 26 kppm NaCI). I would not doubt some minor variations may occur areally, or with depth. The upper Sterling is a clean sand/shale sequence. These "sands" seemed to be composed of varying amounts of quartz and some other heavy mineral, probably one of the micas. There seems to also be a correlation between the gamma ray and this heavy mineral. I suspect a possible micaceous mineral to be the heavy component. This portion of the section is characterized on logs by good SP deflection, and low resistivities in sands. Porosities from sonic range from 34 to 36 percent, decreasing slightly with depth. Modem logs indicate a much reduced amount of heavy mineral, and slightly more .. shale in the sands. The most significant feature is an increase in resistivity. I suspect this may be due to a very silty or fine-grained texture to the sands. This middle Sterling is characterized by reduced SP deflection, and resistivities greater 10 ohm meters in the sands. Shale was calculated at 10 percent to 20 percent and sonic porosities range from 32 to 37 percent, though effective porosities are 28 to 33 percent. The puzzling aspect is that the shalier sands appear more resistive, whole the pure shales read 4 ohm meters. Reduced SP may reflect reduced permeability due to silt as well as shale content. In the lower Sterling, the sequence becomes a classic sand/shale sequence. The heavy mineral is gone, and SP and GR' begin to roughly correlate as shale indicators. The sands exhibit shale content as high as 25 percent, and sonic porosities range from 28 to 35 percent, though effective porosities are from 22 to 32 percent. Resistivities also drop below 10 ohm meters in this interval. On logs, this zone is characterized by SP deflections greater than the middle Sterling, though potentially quite variable, and resistivities below 10 ohm meters. RECOMMENDATIONS Based on inspection of the 211-15 and 23-15 wells and log analysis, it appears that th entire Sterling Formation section is suitable for annulus injection. The most prospective sands begin at approximately 2000 feet MD and should be completely separate from the uppermost producing interval at or near 3000 feet. The sands are highly porous and have a wide lateral extent as well as good clay/siltstone beds that isolate the individual sands. The sands in the lower Sterling should probably not be used as injection zones based on their proximity to the producing zone and their thin bedded nature. In summary, most of the Sterling Formation would be suitable for annulus injection but owing to the shallow TD projected for this well, it is recommend that any annulus injection be restricted to the upper Sterling beginning at about 2000 feet MD. This level would assure that injection fluids would remain isolated from the producing horizon as well as the fresh water/brackish water transition zone at approximately 500 feet MD. 152' 151o LKEETI~ M' Susi Riuer !49° ,s! Luke LONE RIDGE PT. Ty, ..'k ~ ,~ ..~. ,' ~ NORTH GRANITE FORELAND PT PT. WORONZOF. FIRE /,~ ISLAND~../ PT POSSESSION , 00~ KENAI 8RU 42-18 O D LO ON EAST ' FORELAND · WEST ~,c~ FORELAND NIk,..,h ka PEN IN S ULA ~n41 11 1~LGIN LAND I_ Kasilol FIGURE I.-44ap showing physiographic units of upper Cook Inlet region, Alaska. I ~~.~0 MILES 0 L_~ KILOMETE,.~ · ~:X DI,.,AN ATIO N predominant sedlulram-nxm-b~ I~n ~ndm-lain by 3-0 oe mm"u f~ 04 I~at and silt Well-dm~'~l I~w~lL~ f~eu~d ~nt t~ ttntlx ~ indudinl ~lluvitl and I~-ustnne ~-,~ kn~m tmq"~sm, a~ flat s~n~r~ly d~ft.e~ve: W'eil..d~ned ~uner~lr forum m of ~r ~S,T~,F Mth su'~n~ linea; elemenu in end. l&ter~, and inMrlobate mol~nes, a.u Major ~ and st~ siol~m, including hilts ~long t'r~nt of Kena~ ~4ount. az~ 30¸ 2~ --. -- -- Ave~a~ Preeipit. ation I I I I I I I I I I ' · I I I. I I I , ' I I I I I I. · · sm. ~ I I I I I I · · I I I I I I · I I I I I I IJ 0 ~,, t.l,~,,I ,,,, I , ,, II,,,~ I,,, ,] i.l.~, W&TE:R YEAR Precipitation a~ Kermi aJzpor~. (Data provided Depamnent of Commerce, National Weather Service) 4 ~ EVAI'OIATION TIANiPIRATION ~ubmmtn~ PII. ECil'ITATIOH GROUND-WATIit. FLOW ., . Os~)mflMd Aqdfer OIOUNi)-WATII FLOW ,.. Lit AIr,.AGI GIOUNi)-WATEI FLOW · · Loww Colbed Aqulfw TAILS i)1 IIILTIAI"I Oll LIAI[AOI LgAKAOg flchenmtic diapum of the hydrologic setting o! the l%likiski area. ARCO Alaska Inc., Waste Water Disposal Notification December 5, 1988 SRU 242-16 Enclosure C CZM Questionaire Coastal Project Questionnaire and Certification Statement Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. APPLICANT INFORMATION 1. ARCO Alaska. Inc. Name of Applicant p~Q, Box 100360 Address Anchoraqe, AK 995 10-0360 City/State/Zip Code (907) Phone PROdECT INFORMATION , Peter N. Hellstrom Contact Person P.O. Box 100360 Address Anchorage, AK 9,.951 0-0360 City/State/Zip Code (907) 265-6176 Phone i 1. Provide a brief description of your project and ALL associated facilities (caretaker facilities, etc.) Drill, develop, and produce a shallow gas well within the Swanson River Field (SRU 242-16). Starting Date for Project 1 Feb 89 Ending Date for Project 30 Jun 89 PROJECT LOCATION 1. Please give location of project. (Include nearest community or identifiable body of land or water.) Swanson River Fieldl Kenai National Wildlife Refu.qe~ Kenai Peninsulal Alaska Township 8 N Range 9W MeridianSeward Section 1S Aliquot Parts USGSMap~ 2. Is the project on: State Land (please mark with ¥' ) XX Federal Land Private Land Municipal Land. 3. Project is located in which region of the state (see attached map): Northern Southcentral XX. Southeast PERMIT APPROVALS .... v~ 1, Do you currently have any State or redera~ aoprovals for this project? If yes, please list belowl~i (Note: Approval means permit or any other form of authorization.) ADoroval Type Solid Waste disposal, ADEC Area Injection Order, AOGCC ADDrOVa] ~ 8623-BA004 Number 13 ExDiration Date August 31, 1991 Non expiring No FEDERAL APPROVALS , Yes No 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, r---1 r~ or wetlands*? I! *If you are uncertain whether your proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 753-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free 1-800-478-2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) I--! F'I permit? please indicate at right and describe below. CZMA:88:005 l of 5 2. Have you applied for or do you intend to apply for a U.S. Environmental Protection Agency Yes National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right i~i and describe below. (Note: Any wastewater discharge requires an NPDES permit.) 3. Have you applied for or do you intend to apply for permits from any other federal agency? I~l If yes, please list below. Adencv BLM COE ADorQy~l Type Lease Operation Wetland Determination No Date Submitted (or intend to submii;) Dec. 88 Dec. 88 rlFDAI~TMFkIT (3F klATIII~AI RF.SQIII~CFS APPROVAl S 1. Is the proposed project on state-owned land or will you need to cross state lands for access? · 2. Is any portion of your project Placed below the ordinary high water line of a stream, river, lake, or other water body? 3. Will you be dredging? If yes, location of dredging is: Township Range Meridian~ Section · Location of disposal site for dredged materials: Township Range Meridian.~ Section 4. Will you be filling with rock, sand, or gravel? If yes, amount? · Location of source: Townshir) Range Meridian · Location of area to be filleaTownship Range Meridian 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount?. · Location of source:Township Range Meridian ~ Other Materials · If yes, what material? (Peat, building stone, silt, overburden, etc.) · Location of source: Township Range Meridian.~ 6. Are you planning to use any fresh water? 10,000 · If yes, amount (gallons per day)? · Source? Grmmd w~tpr Section Section Section Section 7. Will you be building or altering a dam? Yes Yes Yes Yes No No No 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will You be exploring for or extracting minerals on state-owned land? 1 I. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? F-1 13. Will you be investigating or removing historical or archaeological resources on state-owned land? 14. Will the project be located in a unit of the Alaska State Park System? E] If you answered NO to all questions In thls section, you do not need an approval from the Alaska Department of Natural Resources (DNR). Continue to the next section, 2of5 If you answered YES to ANY questions in this section, contact DNR to identify and oDtain necessary application forms. Based on your discussion with DNR, please list (below) the approval type needed and date submitted, ADoroval Type Date Submitted (or intend t~ submit) Temporary Water Use Dec. 88 Yes Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below: a. (DNR contact) told me on approvals or permits were required on this project. b. Other. DEPARTMENT OF Ft:~H AND GArdE APPROVALS 1, Will you be working inastream, river, orlake? (This includes running water or on ice, Yes within the active floodplain, on islands, the face of the banks, or the stream tideflats down r"-! to mean low tide.) Name of stream or river: Name of lake: If you answered "no," proceed to question =2. If "yes," will you be doing any of the following? Yes a. Building a dam, river training structure, or instre~m impoundment? b. Using the water? I~! c. Diverting or altering the natural channel stream? I l d. Blocking or damming the stream, (temporarily or permanently)? e. Changing the flow of the water or changing the bed? I~l f. pumping water out of the stream or lake? r~l g.Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream'with tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? 1. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n. Constructing a weir? o. Other in-stream structure not mentioned above? 3of5 (date) that no DNR No No No 2. Is your project located in a State Game Refuge, Critical Habitat Area, or State Game Sanctuary.~ 3. Does your project include the construction and operation of a salmon hatchery? F--'l 4. Does your project affect or is it related to a previously permitted salmon hatchery? O 5. Does your project include the construction of a shellfish or sea vegetable farm? r-'l If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Fish and Game (DFG). Continue to the next section. If you answered YES to any of the questions under 1 or 2, contact the Regional DFG Habitat Division Office for information and application forms. If you answered YES to questions 3, 4, or 5, contact the DFG Private Nonprofit Hatchery Office at the F.R.E.D division headquarters for information and application forms. Based on your discussion with DFG, please list (below) the approval type needed and date submitted. Aoorov~l Tyoe Date Submitted (or intend to submit) If you are not applying for DFG permits, indicate reason below: -------a. (DFG contact) told me on approvals or permits were required on this project. (date) that no DFG ~. b. Other DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS 1. Will a discharge of wastewater from industrial or commercial operations occur? (See '2 in "Federal Permits" section.) Yes 2. Will your project generate air emissions from the following: a. Diesel generators totaling more than 10,000 hp? b. Other fossil fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or 100,000,000 btu/hr? c. Asphalt plant? d. Incinerator burning more than 1000 pounds per hour? e. Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4. Will you be processing seafood? 5. Will food service be provided to the public or workers? 6. Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? No 4of5 Yes 8. Will your project result in the development of a currently unpermitted facility for the disposal-'i of domestic or industrial solid waste? 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than 10,000 barrels of such products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need a permit or approval from the Alaska Department of Environmental Conservation (DEC). Continue to the next section, If you answered YES to any of these questions, contact the DEC Regional Office for information and application forms. Based on your discussion with DEC, please list (below) the approval type needed and date submitted. Ai;)Droval Type ~)ste Submitted (or intend to submit) Drillincj Waste Notice Dec. 88 Waste Water Injection Dec. 88 No If you are not applying for DEC permits, indicate reason below: ,__~__.a. (DEC contact) told me on approvals or permits were required on this project. ~.b. Other. . (date) that no DEC CERTIFICATION STATEMENT The information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alask Coastal Management Program. Signature of Appiicant or Agent Date Peter N. Hellstrom To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5of5 ARCO Alaska Inc., Waste Water Disposal Notification December 5, 1988 SRU 242-16 Enclosure C CZM Questionaire Coastal ,, Project Questionnaire and Certification Statement Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. APPLICANT INFORMATION 1. ARCO Alaska. Inc. Name of Applicant P,O, Box 100360 Address Anchoraqe, AK 9951 0-0360 City/State/Zip Code (9971 Phone PROJECT I NFORMR.TION , Peter N. Hellstrom Contact Person P.O, Box 100360 Address Anchorage, AK 99510-0360 City/State/Zip Code (907) 265-6176 Phone 1. Provide a brief description of your project and ALL associated facilities (caretaker facilities, etc.) Drill, develoo, and produce a shallow gas well within the Swanson River Field (SRU 242- 16). Starting Date for Project I Feb 89 _Ending Date for Project 30. Jun 89 . PRO~IECT LOCATION 1. Please give location of project. (Include nearest community or identifiable body of land or water.) Swanson River Field~ Kenai National Wildlife Refu,qe~ Kenai Peninsula~ Alaska Township 8 N Range 9W MeridianSeward Section 15 Aliquot Parts USGS Map 2. Is the project on: (please mark with,l) State Land Federal Land XX Private Land Municipal Land 3. Project is located in which region of the state (see attached map): Northern Southcentral XX Southeas't.~ PERMIT APPROVALS 1. Do you currently have any State or federal approvals for this project? If yes, please list belowiA! (Note: Approval means permit or any other form of authorization.) Aooroval Tvoe Solid Waste disposal, ADEC Area Injection Order, AOGCC /~ODrOVal ~ 8623-BA004 Number 13 Expiration Dat~ August 31, 1991 Non expiring No FEDERAL APPROV^L~ Yes No 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, or wetlands*? i~i *If you are uncertain whether your proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 753-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free 1-800-478-2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) I~1 ~ permit? Please indicate at right and describe below. CZMA:88:005 l of 5 2. Have you applied for or do you intend to apply for a U.S. Environmental Protection Agency National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right and describe below. (Note: Any wastewater discharge requires an NPDES permit.) , Yes No Have you applied for or do you intend to apply for permits from any other federal agency? ~ If yes, please list below. Agency ADorg¥~I1 Type Date Submitted (or intend to submit) BLM Lease Ooeration Dec. 88 COE Wetland Determination Dec. 88 F1FDAI~THFNT ~lr NATllI~AI ~r.s~llRr. F.% APPRQVAI ,~ 1. Is the proposed project on state-owned land or will you need to cross state lands for access? Yes 2. Is any portion of your project placed below the ordinary high water line of a stream, river, lake, or other water body? III 3. Will you be dredging? If yes, location of dredging is: Tow nShil~ Range Meridian Section Iii · Location of disposal site for dredged materials: Township Range Meridian~ Section 4. Will you be filling with rock, sand, or gravel? If yes, amount? · Location of source: Township Range Meridian~ · Location of area to be filleoTownship Range Meridian 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount? · Location of'source:Township Range Meridian Other Materials · If yes, what material? (Peat, building stone, silt, overburden, etc.) · Location of source: Township Range . Meridian~ 6. Are you planning to use any fresh water? · If yes, amount (gallons per day)? 10,000 · Source? I~rnJlnrl wafPr Section 7. Will you be building or altering a dam? Section Section Section Yes Yes Yes No No No 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will you be exploring for or extracting minerals on state-owned land? 11. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? 13. Will you be investigating or removing historical or archaeological resources on state-owned land? 14. Will the project be located in a unit of the Alaska State Park System? F1 If you answered NO to all questions In this section, you do not need an approval from the Alaska Department of Natural Resources (DNR). Continue to the next section, 2of5 If you answered YES to ANY questions in this section, contact DNR to identify and obtain necessary application forms. Based on your discussion with DNR, please list (below) the approval type needed and date submitted. AoDroy~II Tyoe Date Submitted (or intend to submit) Temporary Water Use Dec, 88 Yes No Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below: .... a. (DNR contact) told me on approvals or permits were required on this project. b. Other. DEPARTMENT OF FISH AND (~AME APPROVALS 1, Will you be working in astream, river, or lake? (This includes running water or on ice, Yes No within the active floodplain, on islands, the face of the banks, or the stream tideflats down I-'-! F~I to mean low tide.) Name of stream or river: Name of lake: , If you answered "no," proceed to question =2. If "yes," will you be doing any of the following') ' Yes No a. Building adam, river training structure, or instream impoundment? I I b. Using the water? I-'-I i-"-i c. Diverting or altering the natural channel stream? I I I I d. Blocking or damming the stream, (temporarily or permanently)? l--I e, Changing the flow of the water or changing the bed? [--I f. Pumping water out of the stream or lake? I--I I'--I g,Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of I~! any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream with tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? (date) that no DNR i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? 1. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n. Constructing a weir? o. Other in-stream structure not mentioned above? 3of5 2. Is your project located in a State Game Refuge, critical Habitat Area, or State Game Sanctuary 3. Does your project include the construction and operation of a salmon hatchery? 4. Does your project affect or is it related to a previously permitted salmon hatchery? 5. Does your project include the construction of a shellfish or sea vegei~able farm? If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Fish and Game (DFG). Continue to the next section. If you answered YES to any of the queStions under 1 or 2, contact the Regional DFG Habitat Division Office for information and application forms. If you answered YES to questions 3, 4, or 5, contact the DFG Private Nonprofit Hatchery Office at the F.R.E.D division headquarters for information and application forms. Based on your discussion with DFG, please list (below) the approval type needed and date submitted. Approval TvDe Date Submitted (or intend to submit) If you are not applying for DFG permits, indicate reason below: ---------a. (DFG contact) told me on approvals or permits were reqUired on this project. (date) that no DFG ._.___ b. Other. DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS 1. Will a discharge of wastewater from industrial or commercial operations occur? (See ~2 in "Federal Permits" section.) Yes 2. Wil a. b. 1 your project generate air emissions from the following: Diesel generators totaling more than 10,000 hp? Other fossil fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or 100,000,000 btu/hr? Asphalt plant? Incinerator burning more than 1000 pounds per hour? Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4. Will you be processing seafood? 5, Will food service be provided to the public or workers? 6. Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? No 4of5 Yes 8, Will your project result in the development of a currently unpermitted facility for the disposals'I of domestic or industrial solid waste? 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than 10,000 barrels of SUCh products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need a permit or approval from the Alaska Department of Environmental Conservation (DEC), Continue to the next section, If you answered YES to any of these questions, contact the DEC Regional Office for information and application forms, Based on your discussion with DEC, please list (below) the approval type needed and date submitted. AoDroval TYPe Date Submitted (or intend to submit) Drillinq Waste Notice Dec. 88 Waste Water Injection Dec. 88 No If you are not applying for DEC permits, indicate reason below: a, (DEC contact) told me on approvals or permits were required on this project. ___.__ b, Other, (date) that no DEC CERTIFI CATION STATEMENT The information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alask: Coastal Management Program. Signature of Applicant or Agent Date Peter N. Hellstrom To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5of5 ARCO Alaska, In© - Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6335 David A. Heatwole Vice President December 6, 1988 Mr. Robert Flint Ak Dept. of Environmental Conservation 3601 "C" Street, Suite 1350 Anchorage, Alaska 99503 Re: ARCO Alaska Inc., Swanson River, SRU 242-16, Drilling Waste Disposal RES ENG ~) -~R ENG SR_ ENG___.~ ENG ENG Eo-L- GEOL ~--~S~ ~-'~ Dear Mr. Flint: ARCO Alaska, Inc., (ARCO) plans to drill a shallow gas well (SRU 242-16) beginning on or before February 1, 1989. It is also planned, depending on various drilling and well testing considerations, that all activities should be completed by late April 30, 1989. The well surface location will be approximately 350' FWL, 2285' FNL of Section 15, T 8 N, R 9 W, Seward Meridian. This letter provides the information, available to ARCO, on the drilling mud handling system that will be utilized to contain, transport, and dispose of the waste mud generated during the project. By review of the enclosures to this letter, you will notice that the spent mud will not be "stored" but that it will be contained, transported, and disposed of at the Swanson River Field, Central Disposal Site. We believe this disposal action will be in full compliance with the new Solid Waste regulations and the permit that has been issued for the disposal area. However, we provide this notice with' the associated enclosures to insure that ADEC has all information necessary and therefore, insure compliance with existing regulations. It is requested that ADEC provide written confh-mation of receipt of this letter and also confh'm that additional mud handling notifications are not required for fields that have permitted central disposal sites; Swanson River and Beluga River. Should you have any questions about this letter or desire additional information, please contact Peter N. Hellstrom at 265-6176 in Anchorage. Sincerely, Dhv/c[ A. Heatwole DAH:es:rll PNH/12/302 Enc. Plan of Operations CZM Questionnaire -.. R. ECEI.VED DEC 1 lgc g Alaska Oil & Gas Cons..Commission ~'~" Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6007-C Mr. Robert Flint December 6, 1988 Page 2 Henry Friedman, ADEC, Anchorage Les ~atherberry, .AD. EC, Soldoma Lo~eS~;~AOGCC, Anchorage Jane Gabler, KPB, Soldoma Julie Howe, ADEC, Anchorage Joe Dygas, BLM, Anchorage Bob Richey, USF&WS, Soldoma Hank Baij, COE, Anchorage Patty Bielawski, DGC, Anchorage RECEIVED AJaska.Oil & Gas Cons..Commission ~ ~nchorage ARCO Alaska Inc., Drilling Waste Disposal December 5, 1988 SRU 242-16 Enclosure A Plan Of Operations gn~hora~e ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION APPROX. 950' FWL, 2285' FNL SEC. 16, T 8 N, R 9 W, SEWARD MERID~ SRU 242-16 This Plan of Operation describes pad construction and other activities necessary in drilling a .single shallow gas well named SRU 242-16. ARCO Alaska, Inc., (ARCO) will act as the Operator for the Well and be responsible for all site surface and subsurface activities. Most drilling support and related services will be supplied by companies based out of Kenai or Soldotna, Alaska. The drilling and testing activities should last from February 1, 1989 to mid-April, 1989. This plan addresses the gas well from site preparation, drilling, and gas production through well plugging and abandonment, including surface restoration. It provides an overview of all activities associated with site development and has been developed to describe the activities that will occur at the site. It does not provide all details associated with the site activities. In the event of a determination that additional wells are needed, a plan or plans for the drilling and development of the additional well(s) will be submitted to the appropriate governmental representatives. 1. Existine Roads -- All activities will originate from existing Swanson River field roads and pads, see Exhibit A for the site location maps. 2. Access Access will be by use of the existing road. No up-grade of this existing road is needed. 3. Location of Proposed Well - Exhibit A shows the relative surface location of well site and the immediate area. There are approximately 12 existing oil or gas wells within a two mile radius of the proposed location. The nearest oil or gas well site is located approximately 100 feet to the east. Water wells have been developed within two miles of the site. These wells are associated with past drilling activities within the field and are located at each existing drill site within the field. The location of all water wells in the area are on file in the Anchorage office of the Alaska Department of Environmental Conservation. 4. Well Site Layout The proposed layout of the drill site is shown in Exhibit A. Smoothing of the surface area and addition of gravel (to create a new drill site) is planned. The gravel is needed to accommodate the rig and provide a foundation for well work that might be needed in the future. Because of the shallow depth and the targeted bottom hole location, it has been determined that the well can not be drilled from an existing pad. Therefore, expansion of an existing well pad is being proposed. The attached drawing (Exhibit A) reflects the current plans for the well site layout. Page # 2 a. Pad location and design - The drill site pad size will be approximately feet by 350 feet as indicated in the drawings. Smoothing and leveling of the surface area is planned. The temporary diverter pit will then be excavated. The drill pad will be designed such that the natural drainage of the pad area is towards this sump (Exhibit A), if used. This will ensure that material stays within the site and will prevent extraneous fluids, i.e. surface water, from entering the drill site area. b. Diverter Pit - The basic design of the diverter pit is shown in the attached drawing (Exhibit A). The pit will be approximately 8' wide x 30' long x 4' deep. The sidewall slope for the pit will be approximately 2:1. The pit will be made impermeable by the use of a synthetic liner. This pit will be used only in an emergency (i.e. if the well is put on diverter for safety reasons). The cross section of the drilling location is shown in Exhibit A. , Turnouts: No road turnouts will be required. Drainage/Culverts' -- It is not planned to install permanent culverts. Surfacing Material' Fill material or gravel to be obtained from the location or purchased from an approved site will be used to up-grade the drill site. No concrete or asphalt surfacing will be needed at the site. Gates' A gate or access control device is not needed at this site. Road Maintenance; The newly constructed pad will be maintained to insure acceptable access at all times. The obligation to maintain the pad, under this Plan of Operation, will cease when the gas and associated support vehicles are no longer required (i.e. if the well is abandoned or suspended and approved clean-up activities and/or restoration are completed). No special road maintenance is anticipated for this project. Location and Type of Water Supply Fresh water is needed for drilling operations. The primary source of water will be from the water well on drill site 12-15. If the drill site 12-15 well is unacceptable another existing well in the immediate area will be used. Water will not be taken from rivers or surface lakes in the area. Page # 3 6. 7~ . Approximately I0,000 gallons (250 bbls) of water per day will be required for drilling operations. Total maximum anticipated water usage is estimated at 0.5 million gallons (12,000 bbls). Potable water, used for washing and drinking, will be provided, as necessary, from existing sources within the field. Source of Construction Materials Existing native soils and gravel (only as needed) will be utilized for pad construction. The source of construction gravel will be "re-use" of existing gravel that is no longer necessary for field operations. Methods for Handlin~ Waste Disoosal -- a. Solid non-burnable w~$te; This type of waste will be handled via contract with a local refuse company. A large enclosed container will be delivered to location and emptied/exchanged as necessary. b. Solid burnable waste: This type of waste will also be handled via contract with a local refuse company. c. Camo waste water disposal' A rig camp will not be utilized. However, additional personnel will be employed within the field and will increase the amount of "camp waste" that will be generated at the main camp facility within the field. This waste will be handled by existing systems. Disposal of Drilling Wastes: During normal well operations, drilling wastes consist of the following: drill cuttings, drill mud, cement, and wash down water. These wastes, non- hazardous fluids generated from well operations, will be conveyed to a metal "cuttings box". During drilling and at the end of the project, any pumpable liquids will either be transported to the "Oil Skimming Facility" and injected through existing facilities or pumped down the the well just drilled. Liquid waste disposal via underground injection is allowed by authority of either the AOGCC "Permit to Drill" or ADEC "Waste Water Disposal Permit". The "Solid Waste" that accumulates in the cuttings box during the project will be transported to thc Swanson River Field, Central Disposal Site (CDS) and discarded by burial. These wastes will be contained in the lined pit that is permitted and open, and will therefore not pose any hazard to potential ~rinking water sources in thc area. The cuttings box will be a welded steel container approximately 5 feet high and 10 by 20 feet on the sides. This container will be located on a pit liner next to the rig shale shakers. Liquids in the cuttings box will be periodically pumped back to the rig mud pits and reused with the active mud system. The solids that accumulate will be periodically removed by back-hoe and loaded into a water tight transport tank. These tanks will be hauled by truck to the Central Disposal Site for disposal. Thc cuttings box and surrounding area will be protected by a pit liner. Rig mats will be placed on top of the liner for liner protection and for back-hoe Page # 4 support. This liner area will be contained by a berm to prevent the release or migration of fluids. The total volume of waste fluids (i.e. drilling mud and the liquid phase of the cuttings discharge) from this source is estimated as 5,000 barrels. Either the casing annulus or field waste water disposal system will be available for fluids disposal at this well. It is possible that liquid waste will be transported to the "Oil Skimming Facility" and be injected through existing facilities. The available annulus would be between the 9-5/8" x 7" casing strings. The 7" string will be set at the base of the Sterling formation at approximately 3,700 feet TVD (4800 MD). The Sterling, "B" Sands is interbedded with sandstones, claystones, and siltstones. See Exhibit C for a more complete description of the geologic formation, hydrology, and schematic of the well. After evaluating the open hole logs, the placement of the top of the cement should give an open annulus to downsqueeze or pump unwanted water based drilling fluids. Exhibit D contains a simplified well schematic. a. Reserve Pit Design: A reserve pit will not be used during this project. The temporary diverter pit design, which will be used only for safety reasons, was described above. b. Wastes: Drill cuttings come from the well bore being drilled. These solids, consisting mainly of clay and silt, are circulated from the bottom of the well to the surface where mechanical equipment separates and conveys the solids to the cuttings box. The "solids control" equipment typically comprises of shale shakers, desander, desilter, conveyor belt and mud cleaner. These pieces of equipment separate the liquid phase from the drill cuttings; the overall goal is to discharge as little liquid phase of the mud along with the solids as possible. It is estimated that about 1,000 bbls of drill cuttings will be generated during the project. The well depth is anticipated to be 4,800 feet. Normally, the drill cuttings discharges to the cuttings box are coated with drill mud. In addition, occasionally some drill mud is discharged to the cuttings box when the "solids control equipment" is overloaded. During the course of the project, it is estimated that about 3,450 bbls of mud will be discharged to the cuttings box. The drilling mud proposed for this well is a fresh water base with additives to maintain certain theological and density properties. Tabulated below is a list of possible materials to be used and their application in the mud system. These additives and their concentrations are included on the EPA approved mud list for OCS drilling, Exhibit B. Oil based muds will not be used at this well site. Additiw Application Barite Bentonite clays and extenders Chrome free lignosulfonate Caustic soda Weighing agent Viscosifier Dispersant/thinner pH control Page # 5 Soda ash (sodium carbonate) Bicarbonate of soda Polyanionic cellulose polymers Aluminum stearate Biodegradable lubricant Sodium carboxymethycellulose Lime Calcium removal/pH control Calcium removal/pH control Filtrate control/shale inhibition Defoamer Torque and drag reduction Filtrate control pH control/shale inhibition Occasionally fresh water is used to wash down the "solid control equipment" as well as other rig mechanical equipment; this "gray" water would be collected and either absorbed in the mud system or discharged. Attempts will be made to minimize this "wash down" water amount and at the same time allow for a safe and clean working environment. Additional amounts of water are used to wash the drill cuttings before analyzing them for geoscience purposes. Approximately 500 barrels of this water will discharged to the cuttings box during the life of the project. This waste fluid will be disposed of by injection. In drilling operations, cement is used to grout the steel casings in the well bore and, therefore, seal the steel pipe to the formation rock. This will prevent the sub-surface migration of fluids. It is estimated that, at the most, about 50 bbls of cement would be discharged to the cuttings box and transported to the CDS for disposal. Hydrocarbons, mostly in the form of diesel fuel and hydraulic oil, are used to run the rig equipment and machinery. These fuels and occasional lubricants and greases should all be in containers and are transferred, through secure hoses under strict supervision, so that spillage is avoided. Very little, if any, hydrocarbon should find its way to the cuttings box. c. Diverter Pit Closure; At the end of the project, and in the remote chance that solids and any non- pumpable liquid waste might be in the diverter pit, these wastes shall be removed and disposed of at the CDS. The liner will be removed and the temporary pit will then be closed by removal of the liner and back filling the pit with the native loess'which was excavated during pit construction. A site visit during the first, third and fifth year is planned to inspect the integrity of the restoration and to perform any remedial work that might be needed for site stabilization. 9. Disposal of Produced Fluids - Oily Wastes: When testing the well, the gas hydrocarbons will be processed through existing oilfield test separators existing at the installed facilities. Therefore, on-site liquid hydrocarbon generation is not anticipated. Other hydrocarbon liquids from the site will be trucked from the location and added to the Oil Skimming Facility. Any such liquid hydrocarbons will become a part of the field production. The liquid-free gas will be metered and added to the 150# gas system. Page'# 6 10. Ancillary Facilities: All equipment necessary for drilling and formation evaluation will stay either on the drill site or at the existing production facility pads. No special aircraft landing or service facilities will be necessary. Because rig and support personnel will either return home or stay in local hotels in the area, no rig camp or camp kitchen facilities are planned to be utilized on site. 11. Plan for Site Closure: Upon completion of drilling and testing/evaluation operations, all residual muds, will be removed and abandoned at the Central Disposal Site. Other debris or solid waste will be hauled to an approved disposal site. The well will be converted to a producer according to Alaska Oil and Gas Conservation Commission regulations. Post-development site visits will be conducted during the first, third and fifth summer following drilling and site abandonment operations to verify the integrity of the closure method, and to remove any remaining litter. 12. Wildlife Access: The wastes to be discharged to the cuttings box or diverter pit should hold no attraction for wildlife and therefore secondary impacts to wildlife are not a significant factor. Personnel will be instructed not to feed, harass or hunt wildlife on site. 13. Safety Hazards: The only site safety concern probable, would be the potential for a vehicle running into the cuttings box. This possibility is remote due to cuttings box siting, away from the access 'route to the location. It is common knowledge to those employed in these operations where the box is located and the associated traffic restrictions. The fact that the "public" will not be allowed access to the site also minimizes the potential for a safety violation. The gas generation concern associated with well drilling and testing will be addressed by access controls which exist at installed equipment locations and which apply to the drilling activities. 14. Spill Contingency; a. An approved spill control package will be kept on-site at all times for use in controlling accidental discharge of fuels and lubricants. Absorbent materials for controlling any accidental discharge of fuel or lubricants will be on-site at all times, with a back-up supply at the Swanson River Field and ARCO's Kenai warehouse facilities. In addition, an SPCC plan will be prepared and retained at the drilling location. b. Fire, Safety and medical emergencies will be handled through available resources at Soldotna and Kenai, Alaska. Page # 7 c. Well control problems will be handled in a manner commonly accepted as safe oilfield practice utilizing the diverter, diverter pit, blow out preventer, and other resources as necessary. 15. Communication and Sunervision: An ARCO representative will be on site at all times during drilling and well testing operations. The following people are designated as contacts. Na~ Title Company Phone # Bret Allard Operations Manager ARCO 283-7144 Keith Bullard Drilling Superintendent ARCO 263-4609 Doug Stoltz Drilling Superintendent ARCO 263-4111 Jeff Kewin Regional Drilling Engineer ARCO 263-4970 Pat Archey Area Drilling Engineer ARCO 263-4622 Scott Sigurdson Sr. Drilling Engineer ARCO 265-6986 ARCO 24 hOur Security switchboard 276-1215 16. Develoument Drillin~ and Production Plan of Oueration: _ -- If the well, to be drilled according to the Plan of Operation, is successful and a commercial gas volume is defined; the gas will be tied in to the existing 150# gas gathering system at Tank Setting (TS) 2-15. This will minimize facility investments, surface disturbance, and result in the most cost effective method of production. To accomplish this, approximately 450 feet of buried four inch pipeline will be installed between the well head and TS 2-15. At the tank setting, the gas will be routed to a separate water knock-out vessel and gas metering facilities. After metering, the gas will be combined and mixed with the existing 150# gas production at the Tank Setting. This gas becomes a part of the existing gas gathering system which is routed to. the Compressor Plant. To prevent hydrate formation in the well methanol will be injected. Facilities to accomplish injection will include an injection line, pump, and a 500 gallon methanol storage tank. The pump and tank will be located at TS 2-15, within existing buildings. A small diameter injection line (less .than one inch) will be buried with the gas production pipeline to carry the methanol to the well head. Surface restoration of these facilities, following abandonment of thc ficld, will be addressed by the field abandonment plan that is approved by the appropriate agencies (USF&WS, BLM, and AOGCC). Page # 8 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION November 29, 1988 Exhibit A Maps and Drawings 185'188' 17 Fairb, na! SWANSON RIVER UNIT Sewo~ ALASKA VICINITY MAP COOK INLET VICINITY 3WANSON RIVER PROJECT .SCALE IN MILl SRU 24.2-16 PROPOSED PAD EXPANSION KENN PENINSULA BOROUGH STATE OF ALAS~ ARCO ALASKA iNC. 0~.~ RO II L, SRU 242-'16 F ' PROPOSE:D 18 17 ' ~ ~ ~ ~. PAD EXPANSION SOLDOTNA _~ ...j KEN~ PENINSULA CREEK UNIT STATE OF ALASKA Appllca~l~on ~y: ARCO ALASKA INC. Sh~t ;Z of_ Oa~. DEC A4035BBO02 RO SRU 242-16 12-15 ~ SRU 4.32-15 100' 0 100' SCALE IN SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ~ Appllccfdo~~ ARCO ALASKA INC. ,~ of 5 o=~. DEC '8~1 ~88003 RO II I I I I II I I I I I I I I iii I ii i I i i i ii i i i i i i i ii i i SRU 242-16 .J GAS FLARE.~ INJECTION TANK 12-15 --SRU 4-32-15 VALVL -- 100' SC,,~LE IN FEET SWANSON RIVER UNIT '-'~-- 12 - 15 -15 S.~U 242- 16 PROPOSED DR!LLSITE LAYOUT KENAI PENINSULA BOROUGH STA'rE OF ALASKA FOR ARCO ALASKA INC. 700 "G" Slreel A nchoroge, A DIVERTER PIT L DIVERTER[:~iPIT ' PiPE RACKS 135' 10' CU'i'~NGS TANK III I 350' A 160' :RIG 55' 150' SCALE 1": 40' SECTION A-A: DURING 61' ~ OIVE:RTER PIT (¢' DEEP) I OPF~^IIO~ SECTION I A-A: AFTER RECLAIMATION LINER FILL MATERIAL NATIVE SOILS ~ WASTE DRILLING CU1TINGS r-~ EMPTY PIT NOTE ALL EXCAVATED PITS ARE PLANNED TO HAVE A SlOE SLOPE OF 2:1. SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF' ALASKA Applicetion b~v: ARCO ALASKA INC. Sheet, 4. of5 O~.e: ~ A4035~8004. RO ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit B Generic Muds and Additives EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes all earlier versions. Updated versions are available, from EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) 1. Seawater/Freshwater/Potassium/ Polymer Mud KC 1 5O Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed 2. Lignosulfonate Mud Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Lime 2 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed 3. Lime Mud Lime 20 Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Components Maximum Allowable Concentration (lb/bbl) e Nondispersed Mud Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As needed 5. Spud Mud Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or FreshwaterAs needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. The following additives have been approved by EPA in Alaska. Not all of these additives will necessarily be used during drilling of the SRU 242-16 well. Product Name Generic Description Maximum Allowable Concentration (lb/bbl) Aktaflo-S Aqueous solution of non-ionic 3 modified phenol (equivalent of DMS) Aluminum stearate 0.2 Ammonium nitrate 200 mg/l nitrate or 0.05 lb/bbl Agua-Spot Sulfonated vegetable ester formulation 1% by volume Bara Brine Defoam Dimethyl polysiloxane in an 0.1 aqueous emulsion Ben-Ex Vinyl acetate/maleic anhydride 1 copolymer Bit Lube II Fatty acid esters and alkyl phenolic sulfides in a solvent base Calcium carbide As needed Cellophane flakes As needed Chemtrol-X Polymer treated humate Con Det Water solution of anionic surfactants 0.4 D-D Blend of surfactants 0.5 DMS Aqueous solution of nonionic 3 modified phenol Desco CF Duovis Chrome-free organic mud thinner containing sulfo- methylated tannin Xanthan gum 0.5 Durenex Lignite/resin blend Flakes of silicate mineral mica -- 45 Product Name Gelex Glass beads LD-8 Lube-106 Lubri-Sal MD (IMCO) Milchem MD Generic Descrit~tion Sodium polyacrylate and polyacrylamide Aluminum stearate in propoxylated oleylalcohol Oleates in mixed alcohols 2 Maximum Allowable Concentration (lb/bbl) 8 10 gal/1500 bbl Vegetable ester formulation 2.0% (by volume) Fatty acid ester EthoxYlated alcohol formulation Mil-Gard Nut hulls, crushed granular-- Phosphoric acid esters and -- triethanolamine Plastic spheres - - Poly RX Resinex Selec-Floc Sodium chloride Sodium nitrate Sodium polyphosphate Soltex Sulf-X ES Therma Check Basic zinc carbonate 0.25 0.04 gal/bbl or 0.3 lb/bbl As needed As needed 0.4 Polymer treated humate 4 Reacted phenol-formaldehyde- 4 urea resin containing no free phenol,, urea, or formaldehyde High molecular weight poly- 0.25 acrylamide polymer packaged in light mineral oil 50,000 mg/l chloride 200 mg/l nitrate or 0.05 lb/bbl 0.5 Sulfonated asphalt residuum 6 Zinc oxide As needed Sulfono-acrylamide copolymer 1 Product Nam~ Therma Thin Torq-Trim II Generic Descrivtion Maximum Allowable Concentration (lb/bbl) _ Polycarboxylic acid salt Liquid triglycerides in vegetable 6 oil Vegetable plus polymer -- fibers, flakes, and granu!es VG-69 XC Polymer xo2 Zinc carbonate and lime -- 50 Organophilic clay Xanthan gum polymer Ammonium bisulfite 12 0.5 As needed ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit C Geologic and Hydrologic Description SRU 242-16 SURFACE LOCATION GENERAL INFORMATION Tot~ograt~hv and Geogra_0hv The area proposed for the surface location of the SRU 242-16 Well falls geographically on the Kenai Lowlands sub-province of the Cook Inlet Basin. This lowland ~is bordered on the west by Cook Inlet, on the north by Turnagain Arm and on the east by the Kenai Mountains (Karlstrom, 1964). This area is further subdivided by topography and geology. The area north of the Kasilof River falls into the Nikishka Lowland sub-unit. The topography of the Kenai Lowland and the Nikishka Lowland unit is the result of repeated Pleistocene glaciations. In the immediate area of the proposed surface location, the topography is dominated by large broad terraces and rolling hills composed of till formed by complex morainal deposits of Eklutna age (90,000 to 110,000 years before present). Filling the lows between morainal ridges are extensive areas of muskeg, swamp and lakes. The greatest relief near the proposed surface location is approximately 175 feet, this is the difference in elevation between the surface location and local base level, the Swanson River. The unconsolidated sediments which overlie the Tertiary bedrock are composed of deposits of glacial, fluvial, lacustrine and estuarine origin. Tills are poorly sorted, drift is composed of mixed tills, outwash deposits and lacustrine sediments. Outwash plain deposits are materials deposited in front of glaciers. They are composed of well sorted sand and gravel. Abandoned channel deposits are composed of fluvial sands and gravels entrenched in older sedimentary deposits. At approximately 100 feet below the surface, there is an extensive layer of clay and silt that Karlstrom (1964) suggests was deposited in a large proglacial lake. This layer of fine-grained sediments forms an aquitard between an upper unconfined acquifer and an upper confined acquifer. The total thickness of these unconsolidated sediments in and about the surface location is approximately 500 feet as witnessed in the SRU 23-15 and 211-15 wells. Climate Climate on the Cook Inlet/Kenai Lowland is intermediate between the dry, cold continental type of interior Alaska and the wet and mild maritime climate, of the Gulf of Alaska (sub-polar marine). The Kenai Lowland falls in the precipitation shadow of the Kenai Mountains. The National Weather Service has maintained a weather station at Kenai since 1944. The mean annual rainfall for the Kenai area is about 19 inches. Most of the recorded precipitation falls during the last three months of the calendar year and is stored as ice and snow. Snowfall is heavy during the winter months, generally starting in late October and continuing until late April. Temperatures rarely go below -20OF in the winter and the average summer temperature is approximately 50 - 60OF. Surface Hydrology and Groundwater Systems Surface waters of the Kenai Lowlands fall into the following categories: lakes, streams, and swamps. Surface drainage is not well integrated over this broad area, which reflects on its glacial origin. Streams tend to meander aimlessly, always seeking base level. Lakes, marshes and muskeg make up more than one-third of the total Kenai Lowlands surface. Two lakes, Tustumena and Skilak, occupy glacially scoured and moraine dammed troughs and are drained, respectively by the Kasilof and Kenai rivers. Water falling to the 'land surface as precipitation flows overland into lakes and streams, and infiltrates into the soils. Of the water that infiltrates, some returns to the atmosphere by evaporation and transpiration, and some percolates down to the water table where it recharges the unconfined acquifer. Ground water in the unconfined acquifer flows towards streams and toward springs on the coastal bluffs where it discharges. Ground water in the unconfined acquifer leaks downward through the clay units to recharge the deeper confined acquifers. Ground water in the confined acquifers flows toward the coast and discharges under Cook Inlet. Lakes in' the Nikiski area are recharged by precipitation and by ground water inflow. Lakes lose water to evaporation, to ground water outflow, and to outlet streams. ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit D Well Schematic I I - . . iii I I I PROPOSED WELLBORE DIAGRAM ! .'."'.-I :~.:~ '~:;.'i 77.'1 7'1 L 16" CONDUCTOR · 80' g-5/8" SURFACE CASING · 2000' CEMENTED TO SURFACE 7" CASING · :t: 4800' CEMENTED TO 500' ABOVE THE 'B' GAS SANDS APPROXIMATE SURFACE LOCATION' 2285' FNL, 950' FWL, SEC, 15, TSN-R9W, SM SRU 242-16 PROPOSED WELLBORE DIAGRAM KENAI PENINSULA BOROUGH STATE OF ALASKA Application by: ARCO ALASKA INC. Sheet 5 of5 O~t,: DEC '88 " A40~Si~x)S' RO ARCO Alaska Inc., Drilling Waste Disposal December 5, 1988 SRU 242-16 Enclosure B CZM Questionaire Coastal Project Questionnaire and Certification Statement Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. /~PPLI CANT INFORMATION 1. ARCO Alaska. Inc. Name of Applicant P,O, I~ox 100360 Address Anchoraqe, AK 99510-0360 City/State/Zip Code (907) Phone Peter N. Hellstrom 2. Contact Person P.O. Box 100360 Address Anchorage, AK 9951 0-0360 City/State/Zip Code (907) 265-6176 Phone PROdECT INFORMATION 1. Provide a brief description of your project and ALL associated facilities (caretaker facilities, etc.) Drill, develop, and produce a shallow gas well within the Swanson River Field (SRU 242-16). . Starting Date for Project 1 Feb 89 Ending Date for Project 30 Jun 89 PRO~IECT LOCATION 1. Please give location of project. (Include nearest community or identifiable body of land or water.) SwansOn River Field~ Kenai National Wildlife Refuqe~ Kenai Peninsular Alaska Township 8N Range 9W MeridianSeward Section 15~ Aliquot Parts 2. Is the project on: (please mark with ~/) State Land Federal Land XX Private Land Municipal Land USGS Map~ 3. Project is located in which region of the state (see attached map): Northern Southcentral XX Southeast.~ PERMIT APPROVALS j No 1. Do you currently have any State or federal approvals for this project? If yes, please list below I-"i (Note: Approval means permit or any other form of authorization.) ADDrOVal TVDe Solid Waste disposal, ADEC ADDroval ~ 8623-BA004 Expiration Date August 31, 1991 Area Injection Order, AOGCC Number 13 Non expiring FEDERAL APPROVALS 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, Yes No or wetlands*? I-'-I ~ *If you are uncertain whether your proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 753-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free !-800-478-2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) I--I I~l permit? Please indicate at right and describe below. CZMA: 88: 005 1 of 5 2. Have you applied for or a~ you intend to apply for a U.S. Environme~,~al Protection Agency Yes National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right F-i and describe below. (Note: Any wastewaterdischarge requires anNPDES permit.) 3. Have you applied for or do you intend to apply for permits from any other federal agency? If yes, please list below. Aaenc~ BLM COE No AoDroval TvDe Lease Operation Wetland Determination Date Submitted (or intend to submit) Dec. 88 Dec. 88 I')FDARTMFNT QF NATllDAI RF%C)IIRC..F.$ AppDc)VAI S, 1. Is the proposed project on state-owned land or will you need to cross state lands for access? 2. Is any portion of your project placed below the ordinary high water line of a stream, river, lake, or other water body? 3. Will you be dredging? If yes, location of dredging is: Township . Range~Meridian~ Section Yes · Location of disposal site for dredged materials: Township RangP Meridian Section , 4. Will you be filling with rock, sand, or gravel? If yes, amount? · Location of source: Township Range Meridian · Location of area to be filleoTownshiD Range Meridian~ 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount? · Location of source:Township Range. , Meridian Other Materials · If yes, what material? (Peat, building stone, silt, overburden, etc.) · Location of source: Township Range Meridian~ 6. Are you planning to use any fresh water? · If yes, amount (gallons per day)? 10,000 · Source? ,Grnllnd WafPF 7. Will you be building or altering a dam? 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will you be exploring for or extracting minerals on state-owned land? I 1. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? Section Section Section Section Yes Yes Yes No No No 13. Will you be investigating or removing historical or archaeological resources on state-owned land? 14. Will the project be located in a unit of the Alaska State Park System? If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Natural Resources(DNR). Continue to the next section, 2of5 If you answered YES to ANY questions in thls section, contact DNR to identify and oDtaln necessary application forms. Based on your discusSion with DNR, please list (below) the approval type needed and date submitted. ADoroval Tvoe Bate Submitted (or intend to submit) Temporary Water Use Dec. 88 Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below: a. (DNR contact) told me on approvals or permits were required on this project. b. Other. DFpARTMENT OF FISH AND GAME APPROVALS 1. Will you be working in astream, river, or lake? (This includes running water or on ice, within the active floodplain, on islands, the face of the banks, or the stream tideflats down to mean low tide.) Name of Stream or river: Name of lake: If you answered "no," proceed to question ~2. If "yes," will you be doing any of the following? a. Building a dam, riVer training structure, or instream impoundment? b. Using the water? c. Diverting or altering the natural channel stream? d. Blocking or damming the stream, (temporarily or permanently)? e. Changing the flow of the water or changing the bed? f. Pumping water out of the stream or lake? g. Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream With tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? 1. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n. Constructing a weir? o. Other in-stream structure not mentioned above? 3of$ Yes (date) that no DNR Yes Yes No No No 2. Is your project located in a State Game Refuge, Critical Habitat Area, or State Game Sanctuary.~ 3. Does your project include the construction and operation of a salmon hatchery? I~ 4. Does your project affect or is it related to a previously permitted salmon hatchery? 5. Does your project include the construction of a shellfish or sea vegetable farm? If you answered NO to all questions in this section, you do not need an approval from the AlasKa Department of Fish and Game (DFG). Continue to the next section, If you answered YES to any of the questions under 1 or 2, contact the Regional DFG Habitat Division Office for information and application forms, If you answered YES to questions 3, 4, or 5, contact the DFG Private Nonprofit Hatchery Office at the F,R,E,D division headquarters for information and apl~licatlon forms, Based on your discussion with DFG, please list (below) the approval type needed and date submitted. AoDroval Tvoe Date Submitted (or intend to submit) If you are not applying for DFG permits, indicate reason below: , a. (DFG contact) told me on approvals or permits were required on this project. b. Other DEPARTrdENT OF ENVIR(2NI'IENTAL CONSERVATION APpROVAI.~ 1. Will a discharge of wastewater from industrial or commercial operations occur? (See =2 in "Federal Permits" section.) 2. Will your project generate air emissions from the following: a. Diesel generators totaling more than 10,000 hp? b. Other fossil fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or l O0,O00,O00 btu/hr? c. Asphalt plant? d. Incinerator burning more than 1000 pounds per hour? e. Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4, Will you be processing seafood? 5. Will food service be provided to the public or workers? 5, Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? (date) that no DFG Yes No 4of5. Yes 8. Will your project result in the development of a currently unpermitted facility for the disposal---I of domestic or industrial solid waste? 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than 10,000 barrels of such products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need a permit or approval from the Alaska Department of Environmental Conservation (DEC). Continue to the next section. If you answered YES to anY of these questions, contact the DEC Regional Office for information and application forms. Based on your discussion with DEC, please list (below) the approval type needed and date submitted. Aooroval Tvoe Date Submitted (or intend to submit) Drillinq Waste Notice Dec. 88 Waste Water Injection Dec. 88 No If you are not applying for DEC permits, indicate reason below: ~a. (DEC contact) told me on approvals or permits were required on this project. ~ b. Other. (date) that no DEC CERTIFICATION STATEMENT The information contained herein is true and Complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alask Coastal Management Program. Signature of Applicant or Agent Date Peter N. Hellstrom ~mml To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5of5 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 6, 1988 Mr. Bill Wright ENG SR GEOL Department of Natural Resources ~_GEOL ~-S--~- [ Land and Water Management P.O. Box 107001 AT TECHt Anchorage, AK 99510,700t [ ~-TAT'TECH Re: ARCO Alaska Inc., Swanson River, SRU 242-16, Temporary W~ Dear Mr. Wright: ARCO Alaska Inc., is planning to drill a shallow gas well (SRU 242-16) within the Swanson River field, on the northern portion of the Kenai Peninsula, beginning approximately February 1, 1989. As a part of the gas well development activities, we plan to utilize the water well on Drill Site 12-15 and use ground water from a depth of approximately 100 feet as the sole source of drilling make-up water. The existing water well completion date was prior to 1970. The anticipated use duration will be less than six months. The enclosed maps describe the surface location. The gas well drilling and testing activities well last less than seventy five days and we anticipate the daily water use to be approximately 10,000 gallons per day. By this temporary use notification, we request Land and Water Management approval to use up to 0.5 million gallons. I understand that the information contained in this letter is all that may be required in order for you to process this request. You will also find the requisite check for $50.00. If you desire additional information in order to grant the desired temporary water use approval, please contact me at 265-6176. Sincerely, Peter N. Hellstrom Permit Coordinator PNH/es:fll PNH/12/301 Enc Plan of OperatiOns $50.00 check, payable to State of Alaska CZM Questionnaire Joe Dygas, BLM, Anchorage Robert Flint, ADEC, Anchorage Les Leatherberry, ADEC, Soldotna Lonnie Smith, AOCK2C, Anchorage Bob Richey, USF&WS, Soldotna Jane Gabler, KPB, Soldotna Hank Baij, COE, Anchorage Patty Bielawski, DGC, Anchorage ., . RECEIVED Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldC0mpany ARCO Alaska Inc., Temporary Water Use December 5, 1988 SRU 242-16 Enclosure A Plan Of Operations RE¢[IVED DEC 1 ,? 1988 Alaska Oil & I~as Cons. Commissior~ ' : ~chorage ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION APPROX. 950' FWL, 2285' FNL SEC. 16, T 8 N, R 9 W, SEWARD MERIDIAN RECEIVED DEC 1 ;,.' 1988 SRU 242-16 Alas.ks,Oil i Gas Cons. C.om~issiori · ,-. ~ . i,'~ ~ . . . .. ~,.. ~chorage :' This Plan of Operation describes pad construction and other acuvmes necessary in drilling a single shallow gas well named SRU 242-16. ARCO Alaska, Inc., (ARCO) will act as the Operator for the well and be responsible for all site surface and subsurface activities. Most drilling support and related services will be supplied by companies based out of Kenai or Soldotna, Alaska. The drilling and testing activities should last from February 1, 1989 to mid-April, 1989. This plan addresses the gas well from site preparation, drilling, and gas production through Well plugging and abandonment, including surface restoration. It provides an overview of all activities associated with site development and has been developed to describe the activities that will occUr at the site. It does not provide all details associated with the site activities. In the event of a determination that additional wells are needed, a plan or plans for the drilling and development of the additional well(s) will be submitted to the appropriate governmental representatives. . l~:dsting Roads All activities will originate from existing Swanson River field roads and pads, see Exhibit A for the site location maps. 2. Access Access will be by use of the existing road. No up-grade of this existing road is needed. 3. Location of Prooosed Well Exhibit A shows the relative surface location of well site and the immediate area. There arc approximately 12 existing oil or gas wells within a two mile radius of the proposed location. Thc nearest oil or gas well site is located approximately 100 feet to the east. Water wells have been developed within two miles of thc site. These wells arc associated with past drilling activities within the field and arc located at each existing drill site within thc field. Thc location of all water wells in thc area are on file in thc Anchorage office of the Alaska Department of Environmental Conservation. 4. W¢I Site Layout The proposed layout of the drill site is shown in Exhibit A. Smoothing of the surface area and addition of gravel (to create a new drill site) is planned. The gravel is needed to accommodate the rig and provide a foundation for well work that might be needed in the future. Because of the Shallow depth and the targeted bottom hole location, it has been determined that thc well can not be drilled from an existing pad. Therefore, expansion of an existing well pad is being proposed. Thc attached drawing (Exhibit A) reflects the current plans for thc well site layout. Page # 2 a. Pad location and design - The drill site pad size will be approximately 150 feet by 350 feet as indicated in the drawings. Smoothing and leveling of the surface area is planned. The temporary diverter pit will then be excavated. The drill pad will be designed such that the natural drainage of the pad area is towards this sump (Exhibit A), if used. This will ensure that material stays within the site and will prevent extraneous fluids, i.e. surface water, from entering the drill site area. b. Diverter Pit - The basic design of the diverter pit is shown in the attached drawing (Exhibit A). The pit will be approximately 8' wide x 30' long x 4' deep. The sidewall slope for the pit will be approximately 2:1. The pit will be made impermeable by the use of a synthetic liner. This pit will be used only in an emergency (i.e. if the well is put on diverter for safety reasons). The cross section of the drilling location is shown in Exhibit A. 5. Turnouts: No road turnouts will be required. prainage/Culverts' It is not planned to install permanent culverts. Surfacing Material' Fill material or gravel to be obtained from the location or purchased from an approved site will be used to up-grade the drill site. No concrete or asphalt surfacing will be needed at the site. Gates: A gate or access control device is not needed at this site. Roa~l. Maintenange; The newly constructed pad will be maintained to insure acceptable access at all times. The obligation to maintain the pad, under this Plan of Operation, will cease when the gas and associated support vehicles are no longer required (i.e. if the well is abandoned or suspended and approved clean-up activities and/or restoration are completed). No special road maintenance is anticipated for this project. Location and Type of Water Supply Fresh water is needed for drilling operations. The primary source of water will be from the water well on drill site 12-15. If the drill site 12-15 well is unacceptable another existing well in the immediate area will be used. Water will not be taken from rivers or surface lakes in the area. Page # 3 0 . . Approximately 10,000 gallons (250 bbls) of water per day will be required for drilling operations. Total maximum anticipated water usage is estimated at 0.5 million gallons (12,000 bbls). Potable water, used for washing and drinking, will be provided, as necessary, from existing sources within the field. Source of Construction Materials EXisting native soils and gravel (only as needed) will be utilized for pad construction. The source of construction gravel will be "re-use" of existing gravel that is no longer necessary for field operations. Methods for Handlin~ Waste Disr>osal a. Solid non-burnable wi~$te; This type of waste will be handled via contract with a local refuse company. A large enclosed container will be delivered to location and emptied/exchanged as necessary. b. Solid ,burnable waste; This type of waste will also be handled via contract with a local refuse company. c. Camo waste water disposal' A rig camp will not be utilized. However, additional personnel will be employed within the field and will increase the amount of "camp waste" that Will be generated at the main camp facility within the field. This waste will be handled by existing systems. Disposal of Drilling Wastes: During normal well operations, drilling wastes consist of the following: drill cuttings, drill mud, cement, and wash down water. These wastes, non- hazardous fluids generated from well operations, will be conveyed to a metal "cuttings box". During drilling and at the end of the project, any pumpable liquids will either be transported to. the "Oil Skimming Facility" and injected through existing facilities or pumped down the the well just drilled. Liquid waste disposal via underground injection is allowed by authority of either the AOOCC "Permit to Drill" or ADEC "Waste Water Disposal Permit". The "Solid Waste" that accumulates in the cuttings box during the project will be transported to the Swanson River Field, Central Disposal Site (CDS) and discarded by burial. These wastes will be contained in the lined pit that is permitted and open, and will therefore not pose any hazard to potential drinking water sources in the area. The cuttings box will'be a welded steel container approximately 5 feet high and 10 by 20 feet on the sides. This container will be located on a pit liner next to the rig shale shakers. Liquids in the cuttings box will be periodically pumped back to the rig mud pits and reused with the active mud system. The solids that accumulate will be periodically removed by back-hoe and loaded into a water tight transport tank. These tanks will be hauled by truck to the Central Disposal Site for disposal. The cuttings box and surrounding area will be protected by a pit liner. Rig mats will be placed on top of the liner for liner protection and for back-hoe Page # 4 support. This liner area will be contained by a berm to prevent the release or migration of fluids. The total volume of waste fluids (i.e. drilling mud and the liquid phase of the cuttings discharge) from this source is estimated as 5,000 barrels. Either the casing annulus or field waste water disposal system will be available for fluids disposal at this well. It is possible that liquid waste will be transported to the "Oil Skimming Facility" and be injected through existing facilities. The available annulus would be between the 9-5/8" x 7" casing strings. The 7" string will be set at the base of the Sterling formation at approximately 3,700 feet TVD (4800 MD). The Sterling, "B" Sands is interbedded with sandstones, claystones, and siltstones. See Exhibit C for a more complete description of the geologic formation, hydrology, and schematic of the well. After evaluating the open hole logs, the placement of the top of the cement should give an open annulus to downsqueeze or pump unwanted water based drilling fluids. Exhibit D contains a simplified well schematic. a. Reserve Pit Design: A reserve pit will not be used during this project. The temporary diverter pit design, which will be used only for safety reasons, was described above. b. Wastes: Drill cuttings come from the well bore being drilled. These solids, consisting mainly of clay and silt, are circulated from the bottom of the well to the surface where mechanical equipment separates and conveys the solids to the cuttings box. The "solids control" equipment typically comprises of shale shakers, desander, desilter, conveyor belt and mud cleaner. These pieces of equipment separate the liquid phase from the drill cuttings; the overall goal is to discharge as little liquid phase of the mud along with the solids as possible. It is estimated that about 1,000 bbls of drill cuttings will be generated during the project. The well depth is anticipated to be 4,800 feet. Normally, the drill cuttings discharges to the cuttings box are coated with drill mud. In addition, occasionally some drill mud is discharged to the cuttings box when the "solids control equipment" is overloaded. During the course of the project, it is estimated that about 3,450 bbls of mud will be discharged to the cuttings box. The drilling mud proposed for this well is a fresh water base with additives to maintain certain rheological and density properties. Tabulated below is a list of possible materials to be used and their application in the mud system. These additives and their concentrations are included on the EPA approved mud list for OCS drilling, Exhibit B. Oil based muds will not be used at this well site. Additi¥~ Aut~lication - - Barite Bentonite clays and extenders Chrome free lignosulfonate Caustic soda Weighing agent Viscosifier Dispersant/thinner pH control Page # 5 Soda ash (sodium carbonate) Bicarbonate of soda Polyanionic cellulose polymers Aluminum stearate Biodegradable lubricant Sodium carboxymethycellulose Lime Calcium removal/pH control Calcium removal/pH control Filtrate control/shale inhibition Defoamer Torque and drag reduction Filtrate control pH control/shale inhibition Occasionally fresh water is used to wash down the "solid control equipment" as well as other rig mechanical equipment; this "gray" water would be collected and either absorbed in the mud system or discharged. Attempts will be made to minimize this "wash down" water amount and at the same time allow for a safe and clean working environment. Additional amounts of water are used to wash the drill cuttings before analyzing them for geoscience purposes. Approximately 500 barrels of this water will discharged to the cuttings box during the life of the project. This waste fluid will be disposed of by injection. In drilling operations, cement is used to grout the steel casings in the well bore and, therefore, seal the steel pipe to the formation rock. This will prevent the sub-surface migration of fluids. It is estimated that, at the most, about 50 bbls of cement would be discharged to the cuttings box and transported to the CDS for disposal. Hydrocarbons, mostly in the form of diesel fuel and hydraulic oil, are used to run the rig equipment and machinery. These fuels and occasional lubricants and greases should all be in containers and arc transferred, through secure hoses under strict supervision, so that spillage is avoided. Very little, if any, hydrocarbon should find its way to the cuttings box. c. Diverter Pit Clos~r~; At the end of the project, and in the remote chance that solids and any non- pumpable liquid waste might be in the diverter pit, these wastes shall be removed and disposed of at the CDS. The liner will be removed and the temporary pit will then be closed by removal of the liner and back filling the pit with the native loess which was excavated during pit construction. A site visit during the first, third and fifth year is planned to inspect the integrity of the restoration and to perform any remedial work that might be needed for site stabilization. 9. Disposal of Produced Fluids - 0ily Wastes: When testing thc well, thc gas hydrocarbons will be processed through existing oilficld test separators existing at thc installed facilities. Therefore, on-site liquid hydrocarbon generation is not anticipated. Other hydrocarbon liquids from thc site will be trucked from thc location and added to thc Oil Skimming Facility. Any such liquid hydrocarbons will become a part of the field production. The liquid-free gas will be metered and added to thc 150# gas system. Page # 6 10. Ancillary Facilities: All equipment necessary for drilling and formation evaluation will stay either on the drill site or at the existing production facility pads. No special aircraft landing or service facilities will be necessary. Because rig and support personnel will either return home or stay in local hotels in the area, no rig camp or camp kitchen facilities are planned to be utilized on site. 11. Plan for Site Closure: Upon completion of drilling and testing/evaluation operations, all residual muds, will be removed and abandoned at the Central Disposal Site. Other debris or solid waste will be hauled to an approved disposal site. The well will be converted to a producer according to Alaska Oil and Gas Conservation Commission regulations. Post-development site visits will be conducted during the first, third and fifth summer following drilling and site abandonment operations to verify the integrity of the closure method, and to remove any remaining litter. 12. Wildlife Access: The wastes to be discharged to the cuttings box or diverter pit should hold no attraction for wildlife and therefore secondary impacts to wildlife are not a significant factor. Personnel will be instructed not to feed, harass or hunt wildlife on site. 13. Safety 'Hazards: The only site safety concern probable would be the potential for a vehicle running into the cuttings box. This possibility is remote due to cuttings box siting, away from the access route to the location. It is common knowledge to those employed in these operations where the box is located and the associated traffic restrictions. The fact that the "public" will not be allowed access to the site also minimizes the potential for a safety violation. The gas generation concern associated with well drilling and testing will be addressed by access controls which exist at installed equipment locations and which apply to the drilling activities. 14. St>ill Contingency: - a. An approved spill control package will be kept on-site at all times for use in controlling accidental discharge of fuels and lubricants. Absorbent materials for controlling any accidental discharge of fuel or lubricants will be on-site at all times, with a back-up supply at the Swanson River Field and ARCO's Kenai warehouse facilities. In addition, an SPCC plan will be prepared and retained at the drilling location. b. Fire, Safety and medical emergencies will be handled through available resources at Soldotna and Kenai, Alaska. Page # 7 c. Well control problems will be handled in a manner commonly accepted as safe oilfield practice utilizing the diverter, diverter pit, blow out preventer, and other resources as necessary. 15. Communication and Su~)ervision: An ARCO representative will be on site at all times during drilling and well testing operations. The following people are designated as contacts. Name Title Company Phone # - Bret Allard Operations Manager ARCO 283-7144 Keith Bullard Drilling Superintendent ARCO 263-4609 Doug Stoltz Drilling Superintendent ARCO 263-4111 Jeff Kewin Regional Drilling Engineer ARCO 263-4970 Pat Archey Area Drilling Engineer ARCO 263-4622 Scott Sigurdson Sr. Drilling Engineer ARCO 265-6986 ARCO 24 hour Security switchboard 276-1215 16. Develo~)ment Drilline and Production Plan of O~eration: _ _ If the well, to be drilled according to the Plan of Operation, is successful and a commercial gas volume is defined; the gas will be tied in to the existing 150# gas gathering system at Tank Setting (TS) 2-15. This will minimize facility investments, surface disturbance, and result in the most cost effective method of production. To accomplish this, approximately 450 feet of buried four inch pipeline will be installed between the well head and TS 2-15. At the tank setting, the gas will be routed to a separate water knock-out vessel and gas metering facilities. After metering, the gas will be Combined and mixed with the existing 150# gas production at thc Tank Setting. This gas becomes a part of thc existing gas gathering system which is routed to the Compressor Plant. To prevent hydrate formation in thc well methanol will be injected. Facilities to accomplish injection will include an injection line, pump, and a 500 gallon methanol storage tank. The pump and tank will be located at TS 2-15, within existing buildings. A small diameter injection line (less than one inch) will be buried with the gas production pipeline to carry the methanol to the well head. Surface rc-storation of these facilities, following abandonment of thc field, will be addressed by thc field abandonment plan that is approved by the appropriate agencies (USF&WS, BLM, and AOGCC). Page # 8 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION November 29, 1988 Exhibit A Maps and Drawings ° 78' I~S'iG0'155°IS0'14S'140°13S°130° 12S' ALASKA VICINI~ MAP COOK INLET VICINITY .-,,,'~'~ SWANSON RIVER UNIT IS PROJECT ~'~~d~LEs- IApplication Sheet 1 of ~Y: SRU 24.2-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STALE OF ALASKA ARCO ALASKA INC. Oc~e: ~ RO 18 19 5O SRU 31 TSN, Rgw TTN, RgW 242-16 17 2O 29 SWANSON RIVER UNIT 16 21 28 11 ?5 23 27 26 35 7O 5000 I 0 5000 i I SC, ALE IN FEET 18 17 SOLDOTNA CREEK UNIT 16 15 14 SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ALASKA A~pll¢_~tion ~_y: ARCO ALASKA INC. zof5 ~DEC '88 A4055~2 RO SRU 242- t 6 12-15 ~ SRU 432-15 100' 0 100' SCALE IN FEET SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ALASKA " Applic~]_o~ ~y: ARCO ALASKA INC. Sheet ~ of5 Dc~.:. DEC '88 _ RO i I i I 30 -29 26 ' RIVER UNIT %/ TSN, Rgw: TTN, RgW 7 , ] sRu 242-16 -' ~ PROPOSED ~ ~z ~s ~ P~ EXPANSION CREEK UNIT ~plic~ ~: ~ ~ I~. s~t~ o~ DEC '88 A40,S588(X)2 RO i i i i i ii i i i i i ii i ~,?~' '.?~' !~S'~61~'15~'1.5~'[4S'~,40° 135~3~' ~2S' , ALASKA VICINI~ MAP COOK INLET VICINI~ i i I I I I ~ ~- ~+' q~ PAD EXP~SiON ~ ...... STA~ OF A~KA ~ Sh.~ 1 o~ 5 0~' OEC 88 , ~,, , ~ ,.~.. , -,~ A403588001 RO ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION November 29, 1988 Exhibit A Maps' and Drawings c. Well control problems will be handled in a manner commonly accepted as safe oilfield practice utilizing the diverter, diverter pit, blow out preventer, and other resources as necessary. 15. Communication and Supervision; An ARCO representative will be on site at all times during drilling and well testing operations. The following people are designated as contacts. Name Title Company Phone # Bret Allard Operations Manager ARCO 283-7144 Keith Bullard Drilling Superintendent ARCO 263-4609 Doug Stoltz Drilling Superintendent ARCO 263-4111 Jeff Kewin Regional Drilling Engineer ARCO 263-4970 Pat Archey Area Drilling Engineer ARCO 263-4622 Scott Sigurdson Sr. Drilling Engineer ARCO 265-6986 ARCO 24 hour Security switchboard 276-1215 16. Develovment Drillin~ and Production Plan of Overation: If the well, to be drilled according to the Plan of Operation, is successful and a commercial gas volume is defined; the gas will be tied in to the existing 150# gas gathering system at Tank Setting (TS) 2-15, This will minimize facility investments, surface disturbance, and result in the most cost effective method of production. To accomplish this, approximately 450 feet of buried four inch pipeline will be installed between the well head and TS 2-15. At the tank setting, the gas will be routed to a separate water knock-out vessel and gas metering facilities. After metering, the gas will be combined and mixed with the existing 150# gas production at the Tank Setting. This gas becomes a part of the existing gas gathering system which is routed to the Compressor Plant. To prevent hydrate formation in the well methanol will be injected. Facilities to accomplish injection will include an injection line, pump, and a 500 gallon methanol storage tank. The pump and tank will be located at TS 2-15, within existing buildings. A small diameter injection line (less-than one inch) will be buried with the gas production pipeline to carry the methanol to the well head. Surface restoration of these facilities, following abandonment of the field, will be addressed by the field abandonment plan that is approved by the appropriate agencies (USF&WS, BLM, and AOGCC). Page # 8 10. Ancillary Facilities: All equipment necessary for drilling and formation evaluation will stay either on the drill site or at the existing production facility pads. No special aircraft landing or service facilities will be necessary. Because rig and support personnel will either return home or stay in local hotels in the area, no rig 'camp or camp kitchen facilities are planned to be utilized on site. 11. Plan for Site Closure: Upon completion of drilling and testing/evaluation operations, all residual muds, will be removed and abandoned at the Central Disposal Site. Other debris or solid waste will be hauled to an approved disposal site. The well will be converted to a producer according to Alaska Oil and Gas Conservation Commission regulations. Post-development site visits will be conducted during the first, third and fifth summer following drilling and site abandonment operations to verify the integrity of the closure method, and to remove any remaining litter. 12. Wildlife Access: ~The wastes to be discharged to the cuttings box or diverter pit should hold no attraction for wildlife and therefore secondary impacts to wildlife are not a significant factor. Personnel will be instructed not to feed, harass or hunt wildlife on site. 13. Safety Hazards: The only site safety concern probable would be the potential for a vehicle running into the cuttings box. This possibility is remote due to cuttings box siting, away from the access route to the location. It is common knowledge to those employed in these operations where the box is located and the associated traffic restrictions. The fact that the "public" will not be allowed access to the site also minimizes the potential for a safety violation. The gas generation concern associated with well drilling and testing will be addressed by access controls which exist at installed equipment locations and which apply to the drilling activities. 14. Soill Contingency: - a. An approved spill control package wilI be kept on-site at all times for use in controlling accidental discharge of fuels and lubricants. Absorbent materials for controlling any accidental discharge of fuel or lubricants will be on-site at all times, with a back-up supply at the Swanson River Field and ARCO's Kenai warehouse facilities. In addition, an SPCC plan will be prepared and retained at the drilling location. b. Fire, Safety and medical emergencies will be handled through available resources at Soldotna and Kenai, Alaska. Page # 7 Soda ash (sodium carbonate) Bicarbonate of soda Polyanionic cellulose polymers Aluminum stearate Biodegradable lubricant Sodium carboxymethycellulose Lime Calcium removal/pH control Calcium removal/pH control Filtrate control/shale inhibition Defoamer Torque and drag reduction Filtrate control pH control/shale inhibition Occasionally fresh water is used to wash down the "solid control equipment" as well as other rig mechanical equipment; this "gray" water would be collected and either absorbed in the mud system or discharged. Attempts will be made to minimize this "wash down" water amount and at the same time allow for a safe and clean working environment. Additional amounts of water are used to wash the drill cuttings before analyzing them for geoscience purposes. Approximately 500 barrels of this water will discharged to the cuttings box during the life of the project. This waste fluid will be disposed of by injection. In drilling operations, cement is used to grout the steel casings in the well bore and, therefore, seal the steel pipe to the formation rock. This will prevent the sub-surface migration of fluids. It is estimated that, at the most, about 50 bbls of cement would be discharged to the cuttings box and transported to the CDS for disposal. Hydrocarbons, mostly in the form of diesel fuel and hydraulic oil, are used to run the rig equipment and machinery. These fuels and occasional lubricants and greases should all be in containers and are transferred, through secure hoses under strict supervision, so that spillage is avoided. Very little, if any, hydrocarbon should find its way to the cuttings box. c. Diverter Pit Closure: At the end of the project, and in the remote chance that solids and any non- pumpable liquid waste might be in the diverter pit, these wastes shall be removed and disposed of at the CDS. The liner will be removed and the temporary pit will then be closed by removal of the liner and back filling the pit with the native loess'which was excavated during pit construction. A site visit during the first, third and fifth year is planned to inspect the integrity of the restoration and to perform any remedial work that might be needed for site stabilization. 9. Disposal of Produced Fluids - Oily Wastes: When testing the well, the gas hydrocarbons will be processed through existing oilfield test separators existing at the installed facilities. Therefore, on-site liquid hydrocarbon generation is not anticipated. Other hydrocarbon liquids from the site will be trucked from the location and added to the Oil Skimming Facility. Any such liquid hydrocarbons will become a part of the field production. The liquid-free gas will be metered and added to the 150# gas system. Page # 6 support. This liner area will be contained by a berm to prevent the release or migration of fluids. The total volume of waste fluids (i.e. drilling mud and the liquid phase of the cuttings discharge) from this source is estimated as 5,000 barrels. Either the casing annulus or field waste water disposal system will be available for fluids disposal at this well. It is possible that liquid waste will be transported to the "Oil Skimming Facility" and be injected through existing facilities. The available annulus would be between the 9-5/8" x 7" casing strings. The 7" string will be set at the base of the Sterling formation at approximately 3,700 feet TVD (4800 MD). The Sterling, "B" Sands is interbedded with sandstones, claystones, and siltstones. See Exhibit C for a more complete description of the geologic formation, hydrology, and schematic of the well. After evaluating the open hole logs, the placement of the top of the cement should give an open annulus to downsqueeze or pump unwanted .water based drilling fluids. Exhibit D contains a simplified well schematic. a. Reserve Pit Design: A reserve pit will not be used during this project. The temporary diverter pit design, which will be used only for safety reasons, was described above. b. Wastes: Drill cuttings come from the well bore being drilled. These solids, consisting mainly of clay and silt, are circulated from the bottom of the well to the surface where mechanical equipment separates and conveys the solids to the cuttings box. The "solids control" equipment typically comprises of shale shakers, desander, desilter, conveyor belt and mud cleaner. These pieces of equipment separate the liquid phase from the drill cuttings; the overall goal is to discharge as little liquid phase of the mud along with the solids as possible. It is estimated that about 1,000 bbls of drill cuttings will be generated during the project. The well depth is anticipated to be 4,800 feet. Normally, the drill cuttings discharges to the cuttings box are coated with drill mud. In addition, occasionally some drill mud is discharged to thc cuttings box when thc "solids control equipment" is overloaded. During the course of thc project, it is estimated that about 3,450 bbls of mud will bc discharged to the cuttings box. Thc drilling mud proposed for this well is a fresh water base with. additives to maintain certain rheological and density properties. Tabulated below is a list of possible materials to be used and their application in the mud system. These additives and their concentrations are included on thc EPA approved mud list for OCS drilling, Exhibit B. Oil based muds will not be used at this well site. Additive Aoolication - - Barite Bentonite clays and extenders Chrome free lignosulfonate Caustic soda Weighing agent Viscosifier Dispersant/thinner pH control Page # 5 , , , Approximately 10,000 gallons (250 bbls) of water per day will be required for drilling operations. Total maximum anticipated water usage is estimated at 0.5 million gallons (12,000 bbls). Potable water, used for washing and drinking, will be provided, as necessary, from existing sources within the field. Source of Construction Materials Existing native soils and gravel (only as needed) will be utilized for pad construction. The source of construction gravel will be "re-use" of existing gravel that is no longer necessary for field operations. Methods for Handling Waste Disposal a. Solid non-burnable waste: This type of waste will be handled via contract with a local refuse company. A large enclosed container will be delivered to location and emptied/exchanged as necessary. b. Solid burnable waste: This type of waste will also be handled via contract with a local refuse company. c. Camo waste water dis_vosal; A rig camp will not be utilized. However, additional personnel will be employed within the field and will increase the amount of "camp waste" that will be generated at the main camp facility within the field. This waste will be handled by existing systems. Disposal of Drilling Wastes: During normal well operations, drilling wastes consist of the following: drill cuttings, drill mud, cement, and wash down water. These wastes, non- hazardous fluids generated from well operations, will be conveyed to a metal "cuttings box". During drilling and at the end of the project, any pumpable liquids will either be transported to the "Oil Skimming Facility" and injected through existing facilities or pumped down the the well just drilled. Liquid waste disposal via underground injection is allowed by authority of either the AOGCC "Permit to Drill" or ADEC "Waste Water Disposal Permit". The "Solid Waste" that accumulates in the cuttings box during the project will be transported to the Swanson River Field, Central Disposal Site (CDS) and discarded by burial. These wastes will be contained in the lined pit that is permitted and open, and will therefore not pose any hazard to potential drinking water sources in the area. The cuttings box will be a welded steel container approximately 5 feet high and 10 by 20 feet on the sides. This container will be located on a pit liner next to the fig shale shakers. Liquids in the cuttings box will be periodically pumped back to the rig mud pits and reused with the active mud system. The solids that accumulate will be periodically removed by back-hoe and loaded into a water tight transport tank. These tanks will be hauled by truck to the Central Disposal Site for disposal. The cuttings box and surrounding area will be protected by a pit liner. Rig mats will be placed on top of the liner for liner protection and for back-hoe Page # 4 a. Pad location and design - The drill site pad size will be approximately 150 feet by 350 feet as indicated in the drawings. Smoothing and leveling of the surface area is planned. The temporary diverter pit will then be excavated. The drill pad will be designed such that the natural drainage of the pad area is towards this sump (Exhibit A), if used. This will ensure that material stays within the site and will prevent extraneous fluids, i.e. surface water, from entering the drill site area. b. Diverter Pit - The basic design of the diverter pit is shown in the attached drawing (Exhibit A). The pit will be approximately 8' wide x 30' long x 4' deep. The sidewall slope for the pit will be approximately 2:1. The pit will be made impermeable by the use of a synthetic liner. This pit will be used only in an emergency (i.e. if the well is put on diverter for safety reasons). The cross section of the drilling location is shown in Exhibit A. Turnouts' No road turnouts will be required. Drainage/Culverts' -- It is not planned to install permanent culverts. Surfacing Material; Fill material or gravel to be obtained from the location or purchased from an approved site will be used to up-grade the drill site. No concrete or asphalt surfacing will be needed at the site. Gates: A gate or access control device is not needed at this site. Road Maintenance; Thc newly constructed pad will be maintained to insure acceptable access at all times. The obligation to maintain thc pad, under this Plan of Operation, will cease when the gas and associated support vehicles are no longer required (i.e. if the well is abandoned or suspended and approved clean-up activities and/or restoration arc completed). No special road maintenance is anticipated for this project. Location and Type of Water Supply Fresh water is needed for drilling operations. The primary source of water will be from thc water well on drill site 12-15. If the drill site 12-15 well is unacceptable another existing well in thc immediate area will be used. Water will not bc taken from rivers or surface lakes in thc area. Page # 3 SRU 2~2-16 This Plan of Operation describes pad construction and other activities necessary in drilling a single shallow gas well named SRU 242-16. ARCO Alaska, Inc., (ARCO) will act as the Operator for the well and be responsible for all site surface and subsurface activities. Most drilling support and related services will be supplied by companies based out of Kenai or Soldotna, Alaska. The drilling and testing activities should last from February 1, 1989 to mid-April, 1989. This plan addresses the gas well from site preparation, drilling, and gas production through well plugging and abandonment, including surface restoration. It provides an overview of all activities associated with site development and has been developed to describe the activities that will occur at the site. It does not provide all details associated with the site activities. In the event of a determination that additional wells are needed, a plan or plans for the drilling and development of the additional well(s) will be submitted to the appropriate governmental representatives. 1. Existing Roads Ail activities will originate from existing Swanson River field roads and pads, see Exhibit A for the site location maps. 2. Access Access will be by use of the existing road. No up-grade of this existing road is needed. 3. Location of Proposed Well Exhibit A shows the relative surface location of well site and the immediate area. There are approximately '12 existing oil or gas wells within a two mile radius of the proposed location. The nearest oil or gas well site is located approximately 100 feet to the east. Water wells have been developed within two miles of the site. These wells are associated with past drilling activities within the field and are located at each existing drill site within the field. The location of all water wells in the area are on file in the Anchorage office of the Alaska Department of Environmental Conservation. 4. Well Site Layout The proposed layout of the drill site is shown in Exhibit A. Smoothing of the surface area and addition of gravel (to create a new drill site) is planned. The gravel is needed to accommodate the rig and provide a foundation for well work that might be needed in the future. Because of the shallow depth and the targeted bottom hole location, it has been determined that the well can not be drilled from an existing pad. Therefore, expansion of an existing well pad is being proposed. The attached drawing (Exhibit A) reflects the current plans for the well site layout. Page # 2 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT sHALLoW GAS WELL SRU 242-16 PLAN OF OPERATION APPROX. 950' FWL, 2285' FNL SEC. 16, T 8 N, R 9 W, SEWARD MERIDIAN ARCO Alaska Inc., Operations Notification December 5, 1988 SRU 242-16 Enclosure A Plan Of Operations ARCO Alaska Inc., Temporary Water Use December 5, 1988 SRU 242-16 EnclosUre B Check ARCO Alaska, Inc. {~ Date December 8, 1988 To the order of: State of Alaska Dept. of Natural Resources Land & Water Management 4420 Airport Way Fairbanks, AK 99701 89-5 1252 Anchorage, Alaska CA305338 Void after 90 days ""v*50.00' Regular Account National Bank of Alaska Anchorage, Alaska ,,' 50 5 5 3a[i'i~ ~: ~ 25 2000 5 ?1: ,' 0 ~,,, ? S,,, 0 0 ?,,, 0,' I II I i I PROPOSED WELLBORE DIAGRAM 16" CONDUCTOR · 80' 9-5/8" SURFACE CASING · 2000' CEMENTED TO SURFACE 7" CASING · :i: 4800' CEMENTED TO 500' ABOVE THE 'B' GAS SANDS APPROXIMATE SURFACE LOCATION: 2285' FNL, 950' F'WL, SEC, 15, TSN-RgW, SM I II I SRU 242-16 PROPOSED WELLBORE DIAGRAM KENAJ PENINSULA BOROUGH STATE OF ALA,.~KA N)pllc_~lon by: ARCO AI.J~KA INC. Sheet_.~ of__.~ oot,: DEC ' A40'3588005 R0 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit D Well Schematic Surface Hydrology and Groundwater Systems Surface waters of the Kenai Lowlands fall into the following categories: lakes, streams, and swamps. Surface drainage is not well integrated over this broad area, which reflects on its glacial origin. Streams tend to meander aimlessly, always seeking base level. Lakes, marshes and muskeg make up more than one-third of the total Kenai Lowlands surface. Two lakes, Tustumena and Skilak, occupy glacially scoured and moraine dammed troughs and are drained, respectively by the Kasilof and Kenai rivers. Water falling to the land surface as precipitation flows overland into lakes and streams and infiltrates into the soils. Of the water that infiltrates, some returns to the atmosphere by evaporation and transpiration, and some percolates down to the water table where it recharges the unconfined acquifer. Ground water in the unconfined acquifer flows towards streams and toward springs on the coastal bluffs where it discharges. Ground water in the unconfined acquifer leaks downward through the clay units to recharge the deeper confined acquifers. Ground water in the confined acquifers flows toward the coast and discharges under Cook Inlet. Lakes in the Nikiski area are recharged by precipitation and by ground water inflow. Lakes lose water to evaporation, to ground water outflow, and to outlet streams. SRU 242-16 SURFACE LOCATION GENERAL INFORMATION Tooo~raohv and Geoera~h¥ The area proposed for the surface location of the SRU 242-16 Well falls geographically on the Kenai Lowlands sub-province of the Cook Inlet Basin. This lowland is bordered on the west by Cook Inlet, on the north by Turnagain Arm and on the east by the Kenai Mountains (Karlstrom, 1964). This area is further subdivided by topography and geology. The area north of the Kasilof River falls into the Nikishka Lowland sub-unit. The topography of the Kenai Lowland and the Nikishka Lowland unit is the result of repeated Pleistocene glaciations. In the immediate area of the proposed surface location, the topography is dominated by large broad terraces and rolling hills composed of till formed by complex morainal deposits of Eklutna age (90,000 to 110,000 years before present). Filling the lows between morainal ridges are extensive areas of muskeg, swamp and lakes. The greatest relief near the proposed surface location is approximately 175 feet, this is the difference in elevation between the surface location and local base level, the Swanson River. The unconsolidated sediments which overlie the Tertiary bedrock are composed of deposits of glacial, fluvial, lacustrine and estuarine origin. Tills are poorly sorted, drift is composed of mixed tills, outwash deposits and lacustrine sediments. Outwash plain deposits are materials deposited in front of glaciers. They are composed of well sorted sand and gravel. Abandoned channel deposits are composed of fluvial sands and gravels entrenched in older sedimentary deposits. At approximately 100 feet below the surface, there is an extensive layer of clay and silt that Karlstrom (1964) suggests was deposited in a large proglacial lake. This layer of fine-grained sediments forms an aquitard between an upper unconfined acquifer and an upper confined acquifer. The total thickness of these unconsolidated sediments in and about the surface location is approximately 500 feet as witnessed in the SRU 23-15 and 211-15 wells. Climate Climate on the Cook Inlet/Kenai Lowland is intermediate between the dry, cold continental type of interior Alaska and the wet and mild maritime climate of the Gulf of Alaska (sub-polar marine). The Kenai Lowland falls in the precipitation shadow of the Kenai Mountains. The National Weather Service has maintained a weather station at Kenai since 1944. The mean annual rainfall for the Kenai area is about 19 inches. Most of the recorded precipitation falls during the last three months of the calendar year and is stored as ice and snow. Snowfall is heavy during the winter months, generally starting in late October and continuing until late April. Temperatures rarely go below -20oF in the winter and the average summer temperature is approximately 50 - 60OF. ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF opERATION December 5, 1988 Exhibit C Geologic and Hydrologic Description Product Name Therma Thin Torq-Trim II Vegetable plus polymer fibers, flakes, and granules VG-69 XC Polymer xo2 Zinc carbonate and lime Maximum Allowable Generic Description Concentration (lb/bbl} Polycarboxylic acid salt 4 Liquid triglycerides in vegetable 6 oil -- 50 Organophilic clay Xanthan gum polymer Ammonium bisulfite 12 0.5 As needed 4 Product Name Gelex Glass beads LD-8 Lube-106 Lubri-Sal MD (IMCO) Milchem MD Mil-Gard Nut hulls, crushed granular-- Phosphoric acid esters and -- triethanolamine Plastic spheres -- Poly RX Resinex Selec-Floc Sodium chloride Sodium nitrate Sodium polyphosphate Soltex Sulf-X ES Therma Check Generic Descrimion Sodium polyacrylate and polyacrylamide Aluminum stearate in propoxylated oleylalcohol Oleates in mixed alcohols 2 Maximum Allowable Concentration (Ib/bbl) 8 10 gal/1500 bbl Vegetable ester formulation 2.0% (by volume) Fatty acid ester Ethoxylated alcohol formulation Basic zinc carbonate 0.25 0.04 gal/bbl or 0.3 lb/bbl As needed As needed 0.4 Polymer treated humate 4 Reacted phenol-formaldehyde- 4 urea resin containing no free phenol, urea, or formaldehyde High molecular weight poly- 0.25 acrylamide polymer packaged in light mineral oil 50,000 mg/1 chloride 200 mg/1 nitrate or 0.05 lb/bbl 0.5 Sulfonated asphalt residuum 6 Zinc oxide As needed Sulfono-acrylamide copolymer The following additives have been approved bY EPA in Alaska. Not all of these additives will necessarily be used during drilling of the SRU 242-16 well. Product Name Generic Descriotion - Maximum Allowable Concentration (lb/bbl] Aktaflo-S Aqueous solution of non-ionic 3 modified phenol (equivalent of DMS) Aluminum stearate 0.2 Ammonium nitrate 200 mg/l nitrate or 0.05 lb/bbl Agua-Spot Sulfonated vegetable ester formulation 1% by volume Bara Brine Defoam Dimethyl polysiloxane in an 0.1 aqueous emulsion Ben-Ex Vinyl acetate/maleic anhydride 1 copolymer Bit Lube II Fatty acid esters and alkyl phenolic sulfides in a solvent base Calcium carbide As needed Cellophane flakes Chemtrol-X Polymer' treated humate As needed Con Det Water solution of anionic surfactants 0.4 D-D Blend of surfactants 0.5 DMS Aqueous solution of nonionic 3 modified phenol Desco CF Chrome-free organic mud thinner containing sulfo- methylated tannin 0.5 Duovis Xanthan gum Durenex Lignite/resin blend Flakes of silicate mineral mica -- 45 EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes all earlier versions. Updated versions are available, from EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) 1. Seawater/Freshwater/Potassium/ Polymer Mud KC 1 50 Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed 2. Lignosulfonate Mud Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Lime 2 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed 3. Lime Mud Lime 20 Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Components Maximum Allowable Concentration (lb/bbl) , Nondispersed Mud Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As needed 5. Spud Mud Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or FreshwaterAs needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit B Generic Muds and Additives 6" MATT'ING.m, SECTION A-A: DURING OPERATION 61' 1 SECTION A-A: AFTER RECLAIMATION LINER FILL MATERLAL NATIVE SOILS WASTE DRILLING CUTTINGS EMPTY PIT NOTE ALL EXCAVATED PITS ARE PLANNED TO HAVE A SIDE SLOPE OF 2:1, SRU 242-16 PROPOSED PAD EXPANSION KENAI PENINSULA BOROUGH STATE OF ALASKA Application by: ARCO ALASKA INC. SI'~e% & of5 Dote: DEC '88 A4,03588004. R0 A PIPE RACKS '8' DIVpIT ~ DiV CUTTINGS TANK RIG 135' 160' A 350' ,e- 30'~ 46'---~ 150' 55' SCALE 1".' 40' ~--12- 15 4.52 - 15 S.~LI 242- 16 PROPOSED DR!LLSITE LAYOUT KENAI PENINSULA BOROUGH SIAIE OF ALASKA FOR ARCO ALASKA INC. ?00 "G" Slreel A nchorage~ ~.la~ka SRU 242-1 6 12-15 432-15 100' 0 SC, N.E IN FEET II I II I I I SRU 242-16 PROPOSED PAD EXPANSION KENN PENINSULA BOROUGH STATE OF AL,~KA Applic~_on b.b~: ARCO AL~KA INC. Shaet ~ of Ec II I II II ii II I I II iii II I I iii j I II iiiii ii II! II ii i i i i i iL i i iiii ii i i i i i i GAS FLARE: ..~ SRU 242-16 ./ INJECTION TANK --SRU 12-15 4.~2-15 VALVE SOILE IN FEET SWANSON RIVER UNIT 242-16 '~-'- 12- 15 4.52 - 15 S.~U 242- 16 PROPOSED DR)LLSITE LAYOUT KENAI PENINSULA BOROUGH SLATE OF ALASKA FOR ARCO ALASKA INC. 700"G" Street A nchoroge~ .M~ska R.C. DAVIS 8~ ASSOC. 14 87C Snowshoe Lane Anchorage, Alaska 99516 A DIVERTERI PIT 1 PIPE RACKS 135' A CUTTINGS 3 5 0' TANK 160' RIG 55' 150' "-- SCALE 1": 40' SECTION A-A: AFTER RECLAIMATION LINER FILL MATERI~I. NATNE SOILS WASTE DRILLING CUTRNGS EMPTY PIT I NOTE ALL EXCAVATED PITS ARE PLANNED TO HAVE A SIDE SLOPE OF 2:1. SRU 242-16 PROPOSED PAD EXPANSION KENN PENINSULA BOROUGH STATE OF ALASKA Application by: ARCO ALASKA INC. Sheet a, of5 Date: ~ A40.~58800~ RO ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit B Generic Muds and Additives EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes ail earlier versions. Updated versions are available, from EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) 1. Seawater/Freshwater/Potassium/ Polymer Mud KC 1 50 Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed 2. Lignosulfonate Mud Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome~ Treated 10 Caustic 5 Lime 2 Barite 575 Drilled Solids _ 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed 3. Lime Mud Lime 20 Bentonite* 50 Lignosul£onate, 'Chrome or Ferrochrome 15 Lignite, Untreated or Chr°me- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Components Maximum Allowable Concentration (lb/bbl) 4, Nondispersed Mud Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As needed 5. Spud Mud Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or FreshwaterAs needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. The following additives have been approved by EPA in Alaska. Not all of these additives will necessarily be used during drilling of the SRU 242-16 well. Product Name Generic Descrit~tion Maximum Allowable Concentration (lb/bbl) Aktaflo-S Aqueous solution of non-ionic 3 modified phenol (equivalent of DMS) Aluminum stearate 0.2 Ammonium nitrate 200 mg/l nitrate or 0.05 lb/bbl Agua-Spot Sulfonated vegetable ester formulation 1% by volume Bara Brine Defoam Dimethyl polysiloxane in an 0.1 aqueous emulsion Ben-Ex Vinyl acetate/maleic anhydride 1 copolymer Bit Lube II Fatty acid esters and alkyl phenolic sulfides in a solvent base Calcium carbide As needed Cellophane flakes As needed Chemtrol-X Polymer treated humate Con Det Water solution of anionic surfactants 0.4 D-D Blend of surfactants 0.5 DMS Aqueous solution of nonionic 3 modified phenol Desco CF Chrome-free organic mud thinner containing sulfo- methylated tannin 0.5 Duovis Xanthan gum Durenex Lignite/resin blend Flakes of silicate mineral mica -- 45 Product Name Gelex Glass beads LD-8 Lube-106 Lubri-Sal MD (IMCO) Milchem MD Mil-Gard Nut hulls, crushed granular-- Phosphoric acid esters and -- triethanolamine Plastic spheres - - poly RX Resinex Selec-Floc Sodium chloride Sodium nitrate Sodium polyphosphate Soltex Sulf-X ES Therma Check Generic Descrimion - Sodium polyacrylate and 1 polyacrylamide Aluminum stearate in propoxylated oleylalcohol Oleates in mixed alcohols 2 Maximum Allowable Concentration (lb/bbl} 8 10 gal/1500 bbl Vegetable ester formulation 2.0% (by volume) Fatty acid ester 0.25 Ethoxylated alcohol 0.04 gal/bbl or formulation 0.3 lb/bbl Basic zinc carbonate As needed As needed 0.4 Polymer treated humate 4 Reacted phenol-formaldehyde- 4 urea resin containing no free phenol, urea, or formaldehyde High molecular weight poly- 0.25 acrylamide polymer packaged in light mineral oil 50,000 mg/l chloride 200 mg/l nitrate or 0.05 lb/bbl 0.5 Sulfonated asphalt residuum 6 Zinc oxide As needed Sulfono-aCrylamide copolymer 1 Product Name Therma Thin Torq-Trim II Generic Description Maximum Allowable Concentration (lb/b~l) Polycarboxylic acid salt Liquid triglycerides in vegetable 6 oil Vegetable plus polymer -- fibers, flakes, and granules VG-69 XC Polymer xo2 Zinc carbonate and lime -- 50 Organophilic clay Xanthan gum polymer Ammonium bisulfite 12 0.5 As needed ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF oPERATION December 5, 1988 Exhibit C Geologic and Hydrologic Description SRU 242-16 SURFACE LOCATION GENERAL INFORMATION Tonoeraohv and Geo_~raoh_y The area proposed for the surface location of the SRU 242-16 Well falls geographically on the Kenai Lowlands sub-province of the Cook Inlet Basin. This lowland is bordered on the west by Cook Inlet, on the north by Turnagain Arm and on the east by the Kenai Mountains (Karlstrom, 1964). This area is further subdivided by topography and geology. The area north of the Kasilof River falls into the Nikishka Lowland sub-unit. The topography of the Kenai Lowland and the Nikishka Lowland unit is the result of repeated Pleistocene glaciations. In the immediate area of the proposed surface location, the topography is dominated by large broad terraces and rolling hills composed of till formed by complex morainal deposits of Eklutna age (90,000 to 110,000 years before present). Filling the lows between morainal ridges are extensive areas of muskeg, swamp and lakes. The greatest relief near the proposed surface location is approximately 175 feet, this is the difference in elevation between the surface location and local base level, the Swanson River. The unconsolidated sediments which overlie .the Tertiary bedrock are composed of deposits of glacial, fluvial, lacustrine and estuarine origin. Tills are poorly sorted, drift is composed of mixed tills, outwash deposits and lacustrine sediments. Outwash plain deposits are materials deposited in front of glaciers. They are composed of well sorted sand and gravel. Abandoned channel deposits are composed of fluvial sands and gravels entrenched in older sedimentary deposits. At approximately 100 feet below the-surface, there is an extensive layer of clay and silt that Karlstrom (I964) suggests was deposited in a large proglacial lake. This layer of fine-grained sediments forms an aquitard between an upper unconfined acquifer and an upper confined acquifer. The total thickness of these unconsolidated sediments in and about the surface location is approximately 500 feet as witnessed in the SRU 23-15 and 211-15 wells. Climate Climate on the Cook Inlet/Kenai Lowland is intermediate between the dry, cold continental type of. interior Alaska and the wet and mild maritime climate of the Gulf of Alaska (sub-polar marine). The Kenai Lowland falls in the precipitation shadow of the Kenai Mountains. The National Weather Service has maintained a weather station at Kenai since 1944. The mean annual rainfall for the Kenai area is about 19 inches. Most of the recorded precipitation falls during the last three months of the calendar year and is stored as ice and snow. Snowfall is heavy during the winter months, generally starting in late October and continuing until late April. Temperatures rarely go below -20oF in the winter and the average summer temperature is approximately 50 60OF. Surface Hydrology and Groundwater Sv,qtemn Surface waters of the Kenai Lowlands fall into the following categories: lakes, streams, and swamps. Surface drainage is not well integrated over this broad area, which reflects on its glacial origin. Streams tend to meander aimlessly, always seeking base level. Lakes, marshes and muskeg make up more than one-third of the total Kenai Lowlands surface. Two lakes, Tustumena and Skilak, occupy glacially scoured and moraine dammed troughs and are drained, respectively by the Kasilof and Kenai rivers. Water falling to the land surface as precipitation flows overland into lakes and streams and infiltrates into the soils. Of the water that infiltrates, some returns to the atmosphere by evaporation and transpiration, and some percolates down to the water table where it recharges the unconfined acquifer. Ground water in the unconfined acquifer flows towards streams and toward springs on the coastal bluffs where it discharges. Ground water in the unconfined acquifer leaks downward through the clay units to recharge the deeper confined acquifers. Ground water in the confined acquifers flows toward the coast and discharges under Cook Inlet. Lakes in the Nikiski area are recharged by precipitation and by ground water inflow. Lakes lose water to evaporation, to ground water outflow, and to outlet streams. ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 SWANSON RIVER UNIT SHALLOW GAS WELL SRU 242-16 PLAN OF OPERATION December 5, 1988 Exhibit D Well Schematic PROPOSED WELLBORE DIAGRAM 16" CONDUCTOR · 80' 9-5/8" SURFACE CASING e 2000' CEMENTED TO SURFACE 7" CASING · :i: ¢800' CEMENTED TO 500' ABOVE THE 'B' CAS SANDS APPROXIMATE SURFACE LOCATION. 2285' FNL, 950' FWL, SEC. 15, TSN-RgW, SM i i SRU 242-16 PROPOSED WELLBORE DIAGRAM KENAI PENINSULA 8OROUGH STATE: OF ALASKA Applica~i_'on b_y: ARCO ALASKA INC. Sheet ,,'3 of5 O<~u~: DEC '88 ' ' ' A~,.o~h~ RO ARCO Alaska Inc., Operations Notification December 5, 1988 SRU 242-16 Enclosure B CZM Questionaire ~Coastal Project Questionnaire and Certification Statement ,) Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. APPLICANT INFORMATION 1. ARCO Alaska. Inc. Name of Applicant P,O, DoX 100360 Address Anchoraqe~ AK 9951 0-0360 City/State/Zip Code (907) Phone PROJECT INFORMATION , Peter N. Hellstrom Contact Person P.O. Box 100360 Address Anchorage, AK 99510-0360 City/State/Zip Code (907) 265-6 176 Phone 1. Provide a brief descriptiOn of your project and ALL associated facilities (caretaker facilities, etc.) Drill, develop, and produce a shallow gas well within the Swanson River Field (SRU 242-16). Starting Date for Project 1 Feb 89 Ending Date for Project 30 Jun 89 PROJECT LOCATION 1. Please give location of project. (InClude nearest community or identifiable body of land or water.) Swanson River Field~ Kenai National Wildlife Refuqe~ Kenai Peninsula~ Alaska Township 8N Range 9W Meridian.Sewar.d Section . 15 Aliquot Parts 2. 'Is the project on: (please mark with ~) State Land~ Federal Land XX Private Land Municipal Land 3. Project is located in which region of the state (see attached map): Northern Southcentral XX Southeast~ PERMIT APPROVAL,5 1. Do you currently have any State or federal approvals for this project? If yes, please list below (Note: Approval means permit or any other form of authorization.) USGS Map Aoorova] Tyoe Solid Waste disposal, ADEC ADorova} ~ 8623-BA004 Expiration Date August 31, 1991 Area Injection Order, AOGCC Number 13 Non expiring FEDERAL APPROVALS , · Yes No 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, I---! ~ or wetlands*? *If you are uncertain whether yoUr proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 75.7-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free 1-800-478-2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) I--i I~! permit? please indicate at right and describe below. CZMA: 88: 005 1 of 5 :2. Have you applied for or do you intend to apply for a U.S. Environmental Protection Agency Yes National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right i-'l and describe below. (Note: Any wastewater discharge requires an NPDES permit.) 3. Have you applied for or do you intend to apply for permits from any other federal agency? ~ If yes, please list below. Agency BLM COE Aooroval Tyoe Lease Ooeration Wetland Determination Date Submitted (or intend to submit) Dec. 88 Dec. 88 i')FDAI~TI'IFNT OF NATIII~AI RF%OIlI~CF_c; APPROVAl .~ 1. Is the proposed project on state-owned land or will you need to cross state lands for access? 2. Is any portion of your project placed below the ordinary high water line of a stream, river, lake, or other water body? 3. Will you be dredging? If yes, location of dredging is: Townshil~ Range~Meridian~ Section · Location of disposal site for dredged materials: Townshil~ RangP Meridian~ Section 4. Will you be filling with rock, sand, or gravel? If yes, amount? · Location of source: Townshila Range Meridian · Location of area to be filledl'ownship Range Meridian 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount? · Location of source:Township Range Meridian Other Materials · If yes, what material? (Peat, building stone, silt, overburden, etc.) · Location of source: Townshii~ Range Meridian 6. Are you planning to use any fresh water? · If yes, amount (gallons per day)? 10,000 · Source? Grmlnd wRt.~r 7. Will you be building or altering a dam? 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting coal? 10. Will you be exploring for or extracting minerals on state-owned land? 11. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? Section Section Section Section Yes Yes Yes No No No 13. Will you be investigating or removing historical or archaeological resources on state-owned land? 14. Will the project be located in a unit of the Alaska State Park System? If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Natural Resources(DNR), Continue to the next section, 2of5 If you answered yEs to ANY questions in this section, contact DNR to identify and obtain necessary appilcatlon forms. Based on your discussion with DNR, please list (below) the approval type needed and date submitted. Aoorova] Tvoe Date Submitted (or intend to submit) , T.emporary Water Use Dec. 88 , , , Yes No Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below' a. (DNR contact) told me on. ' approvals or permits were required on this project. . b. Other. DEPARTMENT OF FISH AND GAME APPROVALS 1. Will you be working inastream, river, orlake? (This includes running water or on ice, Yes No within the active floodplain, on islands, the face of the banks, or the stream tideflats down I--! to mean low tide.) Name of stream or river: Name of lake' If you answered "no," proceed to question =2. If "yes," will you be doing any of the following? Yes No a. Building a dam, river training structure, or instream impoundment? I i I ! b. Using the water? I-"! F-! c. Diverting or altering the natural channel stream? I~ I~l d. Blocking or damming the stream, (temporarily or permanently)? I'-'l I--i e. Changing the flow of the water or changing the bed? I---I f. pumping water out of the stream or lake? r-'] I"-! g.Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream with tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? (date) that no DNR i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? 1. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n. Constructing a weir? o. Other in-stream structure not mentioned above? 3of5 E] E] 2. is your project located in a State Game Refuge, Critical Habitat Area, or State Game Sanctuary.~ 3. Does your project include the construction and operation of a salmon hatchery? 4. Does your project affect or is it related to a previously permitted salmon hatchery? 5. Does your project include the construction of a shellfish or sea vegetable farm? If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Fish and Game (DFG), Continue to the next section, If you answered YES to any of the questions under 1 or 2, contact the Regional DFG Habitat Division Office for information and application forms. If you answered YES to questions 3, 4, or 5, contact the DFG Private Nonprofit Hatchery Office at the F,R,E,D division headquarters for Information and application forms, Based on your discussion with DFG, please list (below) the approval type needed and date submitted. Aooroval Tvoe Date Submitted (or intend to submit) If you are not applying for DFG permits, indicate reason below: --------a. (DFG contact) told me on approvals or permits were required on this project. (date) that no DFG _..._.__ b. Other DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS 1. Will a discharge of wastewater from industrial or commercial operations occur? (See =2 in "Federal Permits" section.) Yes 2. Wil a. b. 1 your project generate air emissions from the following: Diesel generators totaling more than 10,000 hp? Other fossil fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or 100,000,000 btu/hr? Asphalt plant? Incinerator burning more than 1000 pounds per hour? Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4. Will you be processing seafood? 5. Will food service be provided to the public or workers? 5. Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? No 4of5 Yes 8. Will Your project result in the development of a currently unpermitted facility for the disposa~l of domestic or industrial solid waste? 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than_l 0,000 barrels of such products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need a permit or approval from the Alaska Department of Environmental Conservation (DEC). Continue to the next section. If you answered YES to any of these questions, contact the DEC Regional Office for information and application forms. Based on your discussion with DEC, please list (below) the approval type needed and date submitted. APPrOVal Tvoe Date Subrflitt~d (or intend to submit) Drillinq Waste Notice Dec. 88 Waste Water Injection Dec. 88 No If you are not applying for DEC permits, indicate reason below: a. (DEC contact) told me on approvals or permits were required on this project. b. Other. (date') that no DEC CERTI FI CATION STATEMENT The information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alask Coastal Management Program. Signature of Applicant or Agent Date Peter N. HeIlstrom To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5of5 ARCO Alaska, InC ; Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6335 David A. Heatwole Vice President December 5, 1988 Mr. Robert Flint Ak Dept. of Environmental Conservation 3601 "C" Street, Suite 1350 Anchorage, Alaska 99503 Re: ARCO Alaska Inc., Swanson River, SRU 242-16, Waste Water Disposal, Permit Application Dear Mr. Flint: ARCO' Alaska, Inc. (ARCO) plans to drill a shallow gas well (SRU 242-16) beginning on or before February 1, 1989. It is also planned, depending on various drilling and well testing considerations, that all activities should be completed by late April, 1989. The well bottom hole location will be approximately 350' FEL, 2250' FNL of Section 16, T 8 N, R 9 W, Seward Meridian. This letter provides the information, available to ARCO, on the injection zone formation. We request that ADEC issue written approval for the planned fluid disposal by injection activities that are needed to dispose of the liquid wastes in the most environmentally sound manner. We plan to spud the well as soon as all necessary permits have been obtained and will be on location approximately seventy five days, drilling and testing. See Appendix A, Plan of Operations, for additional information about the development plan. The drilling waste (solid and liquids) will consist of used mud and formation cuttings which will be confined to a "cuttings box" and be disposed of in the 'Central Disposal Site. All fluid waste, generated during the drilling and testing, will be injected down hole upon the completion of all drilling activities. Appendix B, entitled Additional Formation Information, contains a description of the injection zone. It is estimated that approximately 5,000 barrels of drilling waste fluid will be injected. There are no residents in the area of the proposed site. ARCO is aware of applicable local ordinances, zoning requirements, and those concerns described in the Coastal Zone Management Questionnaire, Appendix C. If you have any questions, please call me at 265-6176. Sincerely, D'. A. Heatwole PNH/12/005 t~ Enc. Plan of Operations Formation Information CZM Questionnaire REEE'IV:-ED DEC 1 1988 Gas ConS.,CommlSa10n ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3B--6007-C Mr. Robert F~ ~ December 6, 1988 Page 2 CC: Henry Friedman, ADEC, Anchorage Les Leathcrberry, ADEC, Soldotna Lonnie Smith, AOGCC, Anchorage Jane Gabler, KPB, Soldotna Julie Howe, ADEC, Anchorage Joe Dygas, BLM, Anchorage Bob Richey, USF&WS, Soldotna Hank Baij, COE, Anchorage Patty Bielawski, DGC, Anchorage RE EiWED DEC 1 ''-~ 1988 Rlas~ 0ii & Gas Con~, ~Comr/llS~I~ ~ .,,~;.~ ~chorage~--i,. ARCO Alaska Inc., Waste Water Disposal Notification December 5, 1988 SRU 242-16 Enclosure A Plan Of Operations (9 =~ru 13) I0. (10 :d 13) 12. 13. (4) ~ ~-4"~,~.f~,x (14 :hr~ 22) (23 :hr~ 28) (29 :hr~ 3I) Company -~C) Lease & We1! No. ~ YES NO Is =he perm/= faa a=:ached ...................................... , .... ~-- --- ,,,, 2. Is well =o be Iota=ad in a defined pool ............................. ~._ ,. 3. Is well loca=ad proper dls=anca from proparr7 1/ne .................. 4. Is well loca=ad proper dis=anco from o=har wells .................... 5. Is sufflcian= unded!ca=ed acreage available in =his pool ............ 6. Is well =o be doric=ad and is wellbore pla= included .' .............. 7. Is opera=or =he only alfa=nad part7 .................... '. ........... 8. Can permi= be approved before fir=aah-day.wain ...................... 14. I$. 16. 17. 18. 19. 20. 2i. · 22. Does operator have a bond in force .................................. _~ Ts a conserve=ion order needed ...................................... Is admff~is=ra=ive approval needed ................................... Is :~e lease ::be= appropriate ..................................... ~ Does =ha well have a u~qua ~e ~d :~ber ........................ ~ Is conduc=or s~r~g provided ' ~ ee eee*eeeeeeeeeeeeeee eeeeeeeeeeeeeeeeeee , ,, Wi~ surface casing pro=ac: ~I~ zones reasonably ~ec:ad =o se~e as ~ under~ound source of dr~g wa=ar ..................... ~ , ,,,,, Is enough camen~ used =o =irc:lane o= condu==o= ~d surface ......... ~ W~I =amen= =la ~ surface ~d ~=a~edia~e or produc=ion s~gs ... Wi~ careen= cover ail ~o~ produc=ive hot. ohS ..................... ~ ,,, Wi~ ~1 casing give adequate s~a~ ~ collapse, tension ~d burs=.. ,~ Is this we~ ~o be ~c~d off from ~ ~s=~g wei!bora ............. Is old we~bore ab~do~en=, procedure ~c!uded on 1~403 ............ ' Is adequate wellbore separa=io~, proposed ............................ ~ 23. 24. 25. 26. 27. 28. 29. 30. 3I. Is a dtver:er sysuam required ....................................... Is =he drilling fluid program schema=i= and lis= of equipmen= adequaua Are ne=essa=7 diagrams and des=rip=ions of diver:ar and BOPE a=~ached. Does BOPE have sufflcian= pressure ra=/ng -Tes= =o Does =he choke man/fold comp. l/ w/API P,P-53 (t~ay Sa) .... ' ............. Is =he presence of H25 Ecs probable ................................. e'~io a=o and S=razigraph/c wells: Are dace presen=ad on po=mn:Iai over~rassure zones? ................. ~ ~ Are seismic analysis daua presen=ad on shallow gas zones ............ If an offshore loc., are s=rvey resul=s of seabed conditions present__ ~: Eugineerln~: ....- C ~ .... LC$ ......... B~J j' v: 08/11/88 01i 32. Addi=±onal raquir~menus ............................................. , · POOL i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. PROGRAM: LISCAN REVISION: 5.1 Start of execution: Thu 31 AUG $? 5:16o ~*** RE=L HE~DER **** L~- ~.S 8.9126108 ATLAS 01 LIS CUSTOMER FORMAT TAPE **** TAPE HEADER **** LIS 89/26/08 3946 01 :POK-IO0 : MAiN AND REPEAT ?? PART NUMBSR: W5790-mE32 FILE # 1 MAIN .001 **** FILE HEADER **** 1024 CN : aRCO ALASKA INC. W,N : SRU 242-16 FN : S~ANSON RI:VER COUN : KENAI STAT : ALASK * FORMAT RECORD (TYPE# 64) ONE DEPTH PER 'FRAME TaPE DEPTH UNIT : FT 19 CURVES : NAME I CCL 2 SPD 3 LS 4 SS CODE SAMPLE# UNIT 58 1 VOLT ,~$ 1 FT 68 1 CTS 68 1 CTS BYTES 4 4 6 GElS 68 1 CTS 4 7 G2 6,8 1 CTS 4 9 MON 68 1 CTS 4 10 MSD ~8 1 CTS 4 11 SG~ .68 1 DIM 4 12 CSS ,~8 1 CTS ~ 1 3 ZSS 65 I STS z, 1~ BKL 58 1 CTS 4. 15 BKS 68 1 CTS 4 16 RATO 6,8 I DIM 4 1? RICS .~8 I DIM 4 18 RIN 68 1 DIM ~, 1~ RBOR 68 1 DIM 4 , DATA RECORD DEPTH G1 MSD BKS (TYPE# CCL GElS SGMA RATO O) 966 BYTES * SPD G2 CSS RIOS LS GR ISS RIN SS MON BKL REOR 4632,000 0,0000000 0.0000000 0,0000000 300.0000 0,0000000 0.0000000 0.0000000 0,0000000 0,0000000 0,0000000 -10.00000 400.0000 0.0000000 0.0000000 5.000000 0.0000000 0,0000000 0,0000000 -1.000000 4532,000 9947.309 0.2020720 339,1260 4432,000 11455.33 0,1801433 306.6931 0.0000000 148427.t 23.95802 23.06322 0,0000000 149166.8 21,60310 20.85991 14,99850 2175.567 26734.98 12.31593 16,76250 2824.324 28056.65 12.15256 1789,454 62,74530 332444,9 8.571371 2068,725 43,07283 335897,1 8.556362 411 62.73 2014.485 109.1160 1.557734 43271,56 2015,142 110.6810 1,554166 4332,000 10147,4'8 0,3269209 311,589! 0,0000000 151591.3 22,35191 22.24834 14.99850 2369.184 27008,23 12.82786 1837.530 25,62018 343252,8 8.542303 40924,66 2025.121 65,51399 1,598076 4232,000 6171.609 0.4534429 302,7961 0.0000000 138628.9 29.00821 25.64061 14.99850 974.6169 22292,91 14.28801 1303.336 37,68750 318994.8 8.744312 33454.87 2027,178 72,63701 1.609223 4132.000 10939,67 0,3215093 350,1.670 0.0000000 138811,7 19.91612 19,93863 14,99850 3014,974 25839.42 12.31955 I 943,076 29.03174 322529.9 8.374487 38728,69 2025,365 68,48399 1,597069 4032.000 6166.043 0.6073157 0,0000000 133464,8 25,86479 15,76260 1139,307 20953.65 1238,227 38,44084 318621,0 30307,66 2024,610 56.40201 3932.000 10475.35 0.161901? 299.0781 3832.000 13541.17 0.2172760 384.7300 3732.000 12157.21 0.3374289 349.3430 3632.000 7710.148 0.3680642 270.8511 3532.000 10617,2,7 0.2601433 323,3340 3432.000 7696.453 0.5247858 283.9990 33.32.000 10387.61 0.4223333 355.2070 3232.000 9312.137 0.2253726 348.4231 3132.000 10986.81 0.1480768 363.4099 3032.000 10781.64 0.1945921 371.4609 2932.000 15299.06 0.2598673 0.0000000 141462.9 20.51451 20.64973 0.~000000 148673.4 17.4455~ 15.63425 0.0000000 149353.3 18.76494 17.04587 0.0000000 130859.8 24.53392 22.10042 0,0000000 139063,1 20,018£3 20.31525 0,0000000 136688.2 24.34534 22,68916 0.0000000 1 4'2989.1 20.74414 19,73315 0.0000000 138444.3 21.45020 20.80983 0.0000000 139639.8 19.88684 19.86034 0,0000000 1405'20,8 20,24908 19.60207 0.0000000 156447.9 16.10748. 15.99840 2763.284 25472.54 12.87406 15.99840 4317.711 28464.08 12.13732 1 5.99840 3597.563 27667.19 12.53574 15.99840 1550.445 22294.00 13.49093 16.65331 2~:57.1 81 25349.74 I 2..~.4618 16.10760 1556.2'01 22842.29 13.86493 16.88910 2679.154 25653.09 12.79515 16.99831 23t6.956 24200.71 12.62890 16.99831 3016.475 25647.44 12.64252 17.76241 2836.321 25517.23 12.62583 17.99R'20 5320.910 30707,22 1828.251 27.56474 327448.8 8.501394 2635.528 28.36104 345689.9 7.826486 2380.111 31.66202 338995.2 8.001495 1524.569 23.51839 302~67.9 8.117872 1849.132 28.31528 329'517.9 $.452333 1502.359 31.32773 316945.5 8.439373 1939.390 28.92143 326551.4 8.253477 1718.631 26.95795 317858.4 8.151306 1912.521 27.40724 324865.6 8.363115 1921.942 33.15771 325226.7 8.3e2248 3223.510 35.16869 S57075,0 37760.31 2023.Tz, 1 72.13899 1.614153 41248.65 2022.503 92.91101 1.654908 40649.51 ~028.935 75.27000 1.626120 .33706.92 2018.Z91 43.40001 1.645877 37542.5~ ~U24 685 60 ..... '~1500 1. 632824 3404~.21 2020.090 81.89001 1.633292 38294.94 2020. 923 76.31 302 1.612976 35653.19 2021.458 64.20500 I .5907Z2 38041.17 2020.987 73.36902 1.621631 37649.70 2021.7'76 73.63000 1.641800 44334,04 201 7.431 ~" ;* "~, ~00 0 2832.000 I 7 ~ ii, 3r~7 ! 3. 1516.159 29.75206 310564.9 340:3.23 2026.532 99.19501 1.6~2333 £7 32. 9:~97.35 ~ 3.352426:~ 3?7.3230 ·.,..."O O 00 C ,::' 14.01 54,3 2t .21704 20.55364 1 ?:. 99Sl ! 2457 0 ,"'~'~ 22; 91 0 · 5 5 13,1o6'04 1786.$67 30.~4670 321694.8 5.390472 36857.61 Z021 .66 ~ 80.44.101 1.651356 2632.000 10931.50 0.5711402 302.6951 0,00O0003 137887,0 19,44678 19.62701 16.9~g31 3115,765 25428.86 12.67030 1917.677 21.90283 321530.8 8.241985 37597.31 2021.086 73.55901 1.609652 2532,000 10881.30 0,1550625 332,7180 0,0000000 140027,7 19,81386 19,48822 16,99831 2938,941 25538,19 12,70706 1929,798 22.18950 326578,3 8,380455 37606,20 2030.61 5 85.29500 I .617717 2432.000 13641,52 0,3120708 338.4099 0.0000000 136357,8 19,35661 19.39870 16,99831 3007,744 25019.63 12.77861 1892,578 22,78299 319913.1 8,089634 36719,98 2031.627 83.47801 1,610904 2332,000 9086.500 0.1916873 266.0420 0.0000000 135756.4 21.95825 19.95526 16,99831 2241,615 23709,13 14,72222 1 742,350 24,41090 311217,6 8,460304 34804,30 2026,400 66.73999 1,706065 2232,000 5324.008 0.2191972 225,7480 0.0000000 131621.0 23.10077 24.10066 17,03400 1232,106 18996,02 .1 6.51 254 1035,'771 14,84862 322243,1 9.078213 24880.02 2024,729 65.02301 1.797316 2132,000 4430,055 0.3596273 274,1899 0,0000000 131601.6 28.13214 24,84566 17.59200 779,7361 18584,86 16,98563 995,5649 22,21097 314045,3 8.923996 24695 2021.723 67.00801 1.775039 2032.000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0.0000000 0,0000000 0,0000000 0,0000000 -8,000000 1259.874 15,14438 0',0000000 5,000000 0.0000000 0.0000000 39.99600 -1.000000 TOTAL DATA RECORDS ' STARTI:NG TAPE DEPTH = FILE TRAILER **** 439 4632.00 ENDING T~PE DEPTH = 2000.00 FILE # 2 **** ~ILE HEADER **** 1024 FORMAT ONE DEP TAPE DE RECORD (TYPE# 04) TH PER FRAME PTH UNIT : FT 19 CURVES : NAME CODE S4MP 1 CCL O8 1 2 SPD 68 1 3 LS 68 1 4 SS 68 1 5 G1 68 1 6 GElS 68 1 7 G2 68 1 8 GR 68 1 9 MON 68 1 10 HSD 68 1 11 SGMA 68 1 12 CSS 68 1 13 ISS 68 1 14 BKL 68 1 15 B~S 68 1 16 RATO 68 1 17 ~ICS 68 1 18 RIN 68 1 lO RBOR 68 1 LE# UNIT BYTES VOLT & mT 4 CTS 4 CTS 4 CTS 4 CTS 4 CTS 4 API 4 CTS 4 CTS ~ DIM 4 CTS ~ CTS 4 CTS 4 CTS 4 DIM 4 DIM 4 DIM 4 DIM 4 D4T~ DEPTH G1 MSD BKS RECORD (TYPE# CCL GElS SGMA RATO O) 966 BYTES * SPD G2 CSS RIC:S LS GR ISS R IN SS MON BKL RBOR 4636.000 0.0000000 0.0000000 0.0000000 300,0000 0.0000000 0,0000000 0,0000000 0,0000000 0.0000000 0.0000000 -10.00000 400,0000 0.0000000 0.0000000 5.000000 0.0000000 0.0000000 0.0000000 -1.000000 4536.000 8423.469 0.2518997 313,9341 0.0000000 148914.5 25,13284 24.28293 16.99831 1696.243 25421.25 13.36979 1584.567 52.62410 33777Z.6 8.922552 38539.91 2007.118 109.6020 I ,606153 4436.000 12062.01 0.¢580~40 340.4580 0.0000000 t53537.1 20.96460 21.72038 16.99831 3055.993 291 O0,43 11,68302 2069.224 37,88545 339975.7 8,038904 4491 7.28 '2012.171 93.27400 I .534525 TOTAL OATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 42 4,536.00 ENDING TAPE DEPTH : 4388,00 **** TriPE TR&ZLER **** LIS 89/26/08 3946 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 491 **** REEL TRAILER **** LIS 8912§108 ATLAS' 01 TOTAL RECORDS IN THiS LOGICAL REEL : 492 TOTAL RECORDS IN THIS PHYSICAL REEL: 492 End of execution: T~u 31 AUG 89 ?:41p Eiapsecl. ex~e:cut±on ~±me = 2 ho'u'r$, ** m±nutes, ** seconds. SYSTEM RETURN CODE = 0 PROGRAM: LISCAN REVISION: 5.1 ~ART NUMBER: WS790-PE32 Start of execution: Thu 31 AUG 8'9 3:570 **** REEL HEADER **** LIS 89124105 ATLAS 01 'LIS CUSTOMER FORMAT TAPE." **** TAPE HEADER **** LIS 89/24/08 3'945 01 DIFL,BHC~'Z!DL,CN: MAIN AND REPEAT FILE # 1 MN-D~B.O01 **** FILE HEADER **** 1024 CN : ARCO ALASKA !NC. WN : SRUi 242-16 FN : SWANSON RIVER COUN : KENAi STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 15 CURVES : NAME !LO CHT GR RiLM CODE SAMPLE# UNIT 68 I MMMO 68 1 LB 68 1 APl 68 1 OHMM BYTES 4 4 4 4 6 RFOC 68 1 OHMM 7 SPD 68 1 CT 8 TTEN 68 I LBS 9 CAL 68 1 INCH 10 SP 6~ I MV 11 dC 65 I US/F 12 T2R2 68 1 US 13 T2R1 68 1 US 14 T1R2 68 1 US 15 T1 R1 68 1 US * DATA RECORD DEPTH RILD .SP TlR1 4892,000 0,2000000 -160,0000 350.0000 4792,000 11,81811 -8t,44710 535,3750 4692,000 35,05167 -91,41945 594,1 250 4592,000 3,243170 -60,88535 551,6250 4492,000 8,999783 -96,42700 600,4375 4392,000 7,303158 -79,28841 568,9375 4292,000 10,90221 -65,94456 525,2500 4192,000 9,01811~ -60,40555 578,1250 4092,000 1~.5,52889 -87,20113 744,8125 (TYPE# O) CILD RFOC ~C 0,0000000 0,2000000 50,00000 84,61588 12,99492 106,6905 28,52931 62,69141 119,4632 308,3403 4,685498 .113,2126 111,1138 10,78890 124,1304 t36,9271 8,572525 115,8005 91,72452 12,09545 104,1006 110,8879 8,249971 115,4166 64.39610 17,08966 t 49. 941 9 966 5Y TE S * CHT SPD T2R2 0,0000000 0.0000000 350.0000 -1149~,85 28.40340 530,1250 -11498,85 25,40930 585,5625 -11498,85 28.40340 5z, 3,3750 -11498,85 25,39780 593,3125 -11498.85 26,00330 565,3750 -11498,85 26,59111 520.1250 -1149.$,85 26,43341 571,9375 -11498,85 13,99860 740,3125 GR TTEN T2R1 0.0000000 1000.000 450.0000 55.05018 2030,260 734,7500 44,25809 2067,542 833,5625 53,59279 2017,370 777,8125 51,18736 1907,708 838,9375 49,86115 1985,085 796.4375 55,52975 1922,388 732,4375 47. 69675 1780.834 800.5000 52,32619 1781,587 1111,000 RILM CAL TlR2 0,2000000 6.000000 450.0000 12,20088 -11,424100 741,6875 47.2075.3 -1,658501 843,3750 3,384357 -1,689099 786,5000 9,755409 -1,3t8200 843,0625 8,295221 -1,746000 798,4375 11,99292 -0,9927001 73'8,875 0 8.700830 -0,9964001 804.7500 16.91031 -0,9964001 1t31,688 3992.000 7.623816 -74.~6056 579.6875 3~92.003 9.260931 -105.7845 610.5625 3792.0C0 5.246514 -67.74802 609.1250 3692.000 17.27928 -66.73711 642.3750 3592.000 21.68076 -106.011? 807.0000 3492.000 11.48319 -99,97112 708,0000 3392.000 17.13264 -91.34113 669,7500 3292.000 18.13535 -66.11313 625.5625 3192.000 11.01200 -100,3848 614.5000 3092.000 26.43074 -126.9793 772.0625 2992.000 1,9,27533 -125.0663 645,6875 2,892.00,3 16.69640 -121.2127 746 2792.000 17.68768 -132,3324 638.8125 131.1679 7.784108 116.3480 107.9505 12.68213 I 2,~. 6402 t90.6027 7.095117 125.2/~85 57.87279 40.77255 13.7.4655 46.1 2384 30. 34993 191.5192 :,87. 08380 18.47772 146,.6112 58.36812 16.21 94.8 146.4646 55.1 4093 34.01772 131.1605 90.80930 10.62953 129.4933 37.83473 31.79645 237'2994 51,87979 21.99554 137.5010 59.89319 21., 90378 168.3560 56.53653 '1 9.33.177 134.1313 - 11 49 ~. 85 27.99130 573.0000 -11 ~,98. ,~5 27.99721 60~.6250 -11498.85 23.oQ760 5;0.3750 -11498.$5 15.55650 637.0000 -11498.85 15.96270 786.5625 -1149~85 1~.99840 700.0625 -11498,85 16.39870 665.7500 -11495.85 16,40460 615.2500 -11498,85 16.99831 59'9,75 O0 -11498,85 16.99831 779.5000 -11498.85 17.44020 639,1 875 -11498.85 16.96260 744.7500 -11498.85 17.44020 635.0625 50.96548 1700.368 831.0000 4C.22490 1632.722 $62.~250 56.68452 1716.323 ~51.2500 38.13109 1653.267 908.6250 51.12375 1519.786 1148.000 57.62769 1534,746 962.0000 54.69897 1469.150 982,00,00 33.19746 1465.404 878.3750 57.43056 1422,677 $50.0O00 53.02979 1363.720 1244.250 51.16544 1273.636 912.7500 56.29240 1354.726 1048.500 44.95209 1179.366 909,2500 8.063204 -1.109300 837.31 25 10.05257 -1.000000 866.1250 5.359469 -0.3416000 860.875O 17.12207 -1.231000 916.1250 24.98456 -1 1142.625 I 1.1 2632 -1.030400 968.8750 17.10507 -0.9964001 984.0000 17.56932 -0.7460001 885,3750 11 . 7321 1 -1 . 003700 866.2500 29.75327 -1.000000 1258.375 20.16777 1.160501 919,4375 15.09085 1.366899 1056.563 1 ?'3. ,82697 1. 749,600 912.7.500 1 2. 691 25 1 3. 849?5 17. 44020 -1 25.61 20 1 25. 8179 61 9.0625 626.0625 1178. 533 2.002.400 88 7. 3750 898. 5625 2592.000 68,69713 -11498.85 45 · 1 7484 I 6. 3341 $ 1 4. 55665 15. 65036 17 ·96251 11 57. 380 I · 996401 -1 31 . 21 44 I 30 · 7291 61 $. 25 O0 883 · 5000 ,~91 . 3750 624.8125 2492.000 76. 5811 5 -11 498.85 47.41 797 14 . 36123 1 3.05804 1 3. 42084 1 9,96230 I I 85. 459 2. 006001 -1 29.9923 I 26.7138 600. 8750 871 .31 25 878.1 25 0 608.6250 2392. 000 54.1 2796 -1 lZ, 98.85 46 · 1 5770 19. 73232 1 8. 47475 20,21 251 20.40421 11 09.218 1 · 421 400 -1 56. 0619 1 35,5951 649. 2500 91 9·4375 926. 0625 658.1250 2292.000 0.0000000 O.O00OO00 29.99017 0.2000000 0.2000000 0,2000000 0.0000000 1000,000 6.000000 -160.0000 70.05571 327.4375 479.8125 470.8125 338.7500 TOTAL DATA RECORDS : STARTING TAPE DEPTH : FILE TRAILER **** 35O 4892. O0 ENDING TAPE DEPTH = 2268.00 FILE # 2 RP-D~B. 002 **** FILE HEADER **** 1024 FORMAT RECORD (TYPE~ 64) ONE :DEPTH PER FRAME TAPE DEPTH UNIT : FT 1¸5 CURVES : NAME CODE I C!LO 68 2 CHT 68 3 GR 68 4 R I L M 68 5 R ILD 6 B 6 RFOC 68 7 S P D 68 8 TTEN 68 9 CAL 68 10 SP 68 1 I ~ C 68 1 2 T2R2 68 13 T2R1 68 I 4 T'I R2 68 15 TlR1 68 SAM PLE# UNIT 1 MMHO I LB 1 1 OHMM I OHMM t OHMM I FT 1 LBS 1 IN:CH I M'V I US/F I US I US 1 US I US BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * D.~,T~ RECORD (TYPE~ O) 96b BYTES * DEPTH CILD CHT GR RILM R ILD RFOC SmD TT EN CAL SP kC T2R2 T2R1 T1RZ TlR1 4878,000 0,0000000 0,0300000 0,0000000 0,2080000 0.2000000 0,2000000 0.0000000 1000.000 5,000000 -160,0000 5O,O00OO 350,0030 450,0000 450,0000 350.0000 4778.800 116,91d9 -11498,85 57,38649 8.882879 8,553080 10,95233 29,99701 2101.15¢ -2,241700 -57,48285 109.7193 551.1250 770,2500 782,1250 560.0000 4678,000 181,6702 -11498,85 63,78038 5,546733 5.504481 6.41289~ 29.99701 2080.014 -1.765599 -37.30032 118.1642 580.5625 821.6875 825.8750 589.8750 578,000 231,7961 . -11498,.85 55,65437 4,404426 4,31 41 37 4,909441 30. 99690 2060, 514 -0,8604001 -55.01620 I 24. 1899 574. I 250 833.31 25 840. 0000 593.8125 TOT,&L~DATA RECORDS : STARTING TAPE DEPTH = **** $ILE TRAILER **** 53 4878,00 ENDING TAPE DEPTH 4486,00 FILE # 3 **** FILE MN-~DL,O03 HEADER 1024 FORMAT RECORD (T'YPE~ 64,) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 2O CURVES : NAME CODE SAMP 1 CAL 68 1 2 C N 68 1 3 C NC 68 1 4 G,R 68 1 5 SSD 68 1 6 SSN 68 1 7 LSN 68 1 8 'ZCOR 68 1 9 ZD E N 68 1 L E # UNiT iNCH PCT PCT API CTS CTS CTS GMC C GM. CC BYTES 4 4 4 ,, lU ~'~ ~ 11 TTEN 12 HR01 13 HRD2 14 SFT2 15 SHR 16 CHT 17 mE 18 PORZ 20 DEV 68 1 LBS 4 68 I CTS 4 68 1 CT$ 4 68 1 CTS 4 68 I L~ 4 65 1 B~R~ 4 68 I PCT 4 68 I OEG 4 68 I DEG 4 * DaTA RECORD (TYmE= O) 101~ BYTES * DEPTH CAL CN CNC GR SSD SSN LSN ZCOR ZDEN SmD TTEN HRD1 HRD2 SFT2 SHR CHT PE PORZ RB DE~V 4804.000 0.0000000 0.0000000 0.0000000 0.0000000 4704,000 8525,762 22,99770 0,5984300 368,0442 4604,000 9378,60~ 22,99770 0,5989391 368,0442 4504.000 8718'281 22,99770 0,5971709 368.0442 4404,000 8773,906 21,99780 0,6520051 368,0442 4304.000 8252,828 21,99780 .0,6073450 368,0442 4204,000 7975,898 21,76201 0,6071861 368,04~2 4104,000 6,000000 0,0000000 1000,000 0,0000000 8,640818 142.6260 2031,308 -11498,85 $,640818 132.9881 1982.068 -11498,85 8,600655 163,4977 1974,784 -11498,85 8,604483 168,6205 2008.259 -11498,85 9,0&0676 150,3037 2009,285 -11498.85 9,151024 163,3085 t966,781 '-11498,85 8.731337 0,0000000 0.0000000 O,O000000 0,0000000 36.05912 37,75070 1433,402 3,040573 41.90878 32,12990 2003.206 3,140514 28,19882 50,89391 1775,057 2,720535 30,00584 50,34671 1816,0'84 2,347204 36,67433 39.36720 1410,219 2,791437 34,33580 44,61050 1145.420 2,742028 35.40230 0.0000000 -0.1000000 0.0000000 0,0000000 40.06912 O, 32451 06E-01' 1788,751 16,71925 45,90878 0,2829786E-01 2482,646 27,73634 32.19882 0,1070964E-01 2224,750 29,49411 34,00584 0.3608479E-01 2199,569 28,24013 40,67433 0,5039835E-01 1748,480 18.91093 38,33580 0,2123717E-01 1458,041 17.80956 39.40230 0,0000000 2.000000 0.0000000 0.0000000 6:2,42775 2,374.132 1191,068 -1,555345 59,86308 2,192350 1713,476 -1.555345 48,49463 2',163347 1572,232 -1,555345 47.94472 2,184038 1545,669 -1,555345 47,38072 2,337969 1206,389 -1,555345 45.95412 2,356142 1008,975 -1,5553~5 56.49361 2~.9977C) 0.6837691 368.0442 4004.000 8842.004 24.76170 0.6038560 368.0442 3904,000 9227,258 24,10680 0,6217g02 368.0442 3804,000 13352.20 23,99760 0,8245460 368,0442 3704,060 9334,801 24,99750 0,6098471 368,0442 3604,000 9170,809 25,99741 0,6369470 368,0442 3504,000 8910,938 25,99741 0,6012731 368.04:42 3404,000 934!,762 26,10660 0,6132340 368.0442 3304,000 9390,996 24,99750 0,6326491 368,0442 3204,000 9589,938 24,g9750 0,5875959 368,0442 3104,000 8795,47'7 25,99741 0,5940990 368.0442 3004.000 1793,091 -11498,85 $.84ag02 153.2198 1661,559 -11498,85 8,742859 162,1385 1615,994 -11498,85 9,355103 118.4168 1810,506 -11498,85 8,877012 174,8162 1790,837 -11498,85 8,844902 !84,7696 1557,363 -11498,85 8,844902 158,8634 1603,439 -11498,85 $,893513 158,1060 1504.638 -11498,85 9,627001 146,4182 1645,754 -11498,85 9,788450 118,3428 1495,219 -11498,85 $,742859 160,3424 1387,253 -11498,85 8.716942 1746.243 2,647773 37,68605 39.45502 1869,466 2.644492 32,96898 45.47911 2035,673 2,322243 47,89676 26,57561 7366,219 2,511814 25,60037 58,06131 2128,812 2,633924 23,42245 65,09351 .2220,819 2.594201 31,25795 46,15741 1973,844 2,.804939 31,87180 45.34850 1298,868 2,898176 36.,72081 38,31 900 2058,358 2,675810 53,68208 25,08459 2217,466 3,299610 31,94655 45,91870 1850,553 2,813908 29,90071 2145,464 24.76259 41.68605 O. 2529330E-01 i317.451 30.56874 36.96898 0,2764724E-01 2506,898 31,32318 51 .89676 -0,7112193E-01 9281.508 50,52560 29,6003'7 O, 1047706E-01 2597,088 33.73811 ?.7.42245 0,9106483E-0.2 2667,664 34,69104 35,25795 0,9765893E-02 2445,379 34,50615 3J5,87180 0,1237363E-01 2849,625 34,66891 40,72081 0,31982.44E-01 2481.,919 33,65079 57,68208 0,4756048E-01 2756,949 32,84645 35,94655 0,1354759E-01 2280,230 30,57867 33.90071 ~.~1~1~ 1469.992 -1,555345 39.7?200 2,145616 1554,452 -1.555345 45.28880 2.1 33167 1756,719 -1 ,555345 53,23918 I ,816327 6734,926 -1 ,555345 52,48166 2,093321 1776,028 -1 ,555345 48,02948 ?.,077598 1892,105 -1 ,555345 50,50804 2,080648 1646,268 -1,555345 56,19252 2,077963 1964,335 -1,555345 51 ,92061 2,094761 1742,256 -1 ,555345 57,62927 2,108033 1905,486 -1,555345 47.44958 2.145452 1586.628 -1,555345 51.13930 25.99741 1321.085 1951.704 2439.403 0.5996549 -11495.85 2.$00983 32.05569 368,0442 2904. 000 9,622776 52. 55605 56,55605 101 23.32 117. 401 2 25 , 1 4070 O. 44617422-01 26.23320 I 456.35t 2405. 192 2996.963 O. 5866691 -11 498.85 2. 748546 32. 2811 3 368,0442 28 04. 000 $ o 946939 29. 72600 33 . 72600 8872.328 1 62.4729 48,$1 641 O. 22532252-01 27. 99721 I 303. 025 1 982 . 054 2464. 257 0 · 59141 40 -11498,85 2 . 757246 31 . ,~9322 368.0442 2704. 000 10,01 028 43. 671 02 47. 671 02 9472. 332 120,3 213 28. 39340 O. 2079 2002-01 27.2331 I 1451.91 3 2201 . 387 2694. 394 O, 5969080 -11 498.85 2. $z, 5207 35. 24771 368.0442 26,94.000 8,844902 35 , 41 568 39,41 568 $832,441 155 o 0083 41 . 50821 O. 1 661 7482-01 28. 88791 1206,952 1 973.91 0 2456. 016 O. 5752000 -11498,85 3.0501 90 34. 30385 368.0442 2504. 000 8,94619'4 30,1 2535 34.12535 9201,906 1 46,0234 43,48390 O, 38273812-02 28. 9971 0 1141.726 2209.626 2782.432 O. 5758051 -11 498,85 2 · 885808 34,63307 368.0442 2404.000 9,048981 32.09882 36.09882 8759,508 156.2317 44.60101 0.10959572-01 28,99710 1187.625 1895,566 2370,73'3 0.5672070 -11498,85 3.036348 30.86137 · 368.0442 1632.776 -1.555345 52.13274 2.117361 1963.641 -1.555345 46.87141 2.123762 1709.512 -1.555345 55.03397 2.068413 1808.685 -1.555345 39,80289 2.083986 1650.005 -t.555345 43,55649 2.078554 1829.418 -1,555345 41.97052 2.140787 1599.039 -1.555345 2304.000 6,000000 74,76913 78,76913 29.07811 0.0000000 99.52881 18,34610 -0.1000000 2.000000 0.0000000 1000.000 0.0000000 0.0000000 0,0000000 0o0000000 0.0000000 0,0000000 0.0000000 0.0000000 0,0000000 TOTAL DATA, RECORDS : 419 STARTING TAPE DEPTH : 4804.00 FILE TRAILER **** ENDING TAPE DEPTH 2292,00 FILE # 4 **** ~iLE HEADER **** RP-~DL.O04 1024 ONE TAP DEPTH PER FRAME = OEOTH UNIT : FT CURVES : NAME CODE I CAL 68 Z CN 68 3 CNC 4 GR 68 5 SSO 68 6 SSN 68 7 LSN 68 ~ ZCOR 68 9 ZDEN 68 0 SPO 68 I TTEN 68 2 HRD1 68 3 HRD2 68 4 SFT2 66 5 SHR 68 6 CHT 68 7 PE 68 8 PORZ 68 9 RB 68 0 DEV 68 SAM PLE; UNIT BYTES 1 INCH 4 1 PCT 4 I PCT 4 1 AP! 4 1 CTS 4 I CTS 4 1 CTS 4 I GMCC 4 I GHCC 4 1 FT 4 I LBS 4 I CTS 4 1 CTS 4 I CTS 4 I DIM 4 I LB 4 1 BARN 4 I PCT 4 1 DEG 4 I DEG 4 * DATA RECORD DEPTH SSO SPD SHR DEV 4874.000 0.0000000 0.0000000 0.0000000 0,0000000 4774.000 7797,500 22,99770 0.5625741 368,0442 4674,000 8253,926 22,99770 0,5710800 368,0442 4574.000 10053.59 22.34280 0.6538250 368.0442 4474.000 O.OOOO0O0 0.0000000 (T YP E # CAL SSN TTEN CHT 6,000000 0.0000000 1000.000 0.0000000 8,749052 157,8094 2152,965 -11498,85 8,699951 140,1294 2064,499 -11498,85 8,529369 110,9144 .2082,333 -11498,85 ,, 6.000000 0.0000000 1000.000 O) 1014 BYTES * CN LSN HRD1 PE 0.0000000 0.0000000 0.0000000 0.0000000 35,87750 41..91090 1244,895 3,135590 39,27365 35.18361 1409,744 3.072945 51.28493 24.03900 216!,453 2.320705 0.0000000 0.0000000 0.0000000 CNC ZCOR HRD2 PO R Z 0.0000000 -0.1000000 0.0000000 0,0000000 39,87750 0,1547246E-01 1598,444 17,99994 · 43,27365 0,3808276E-01 1774.16'7 21.63858 55.28493 0.1052147 2710.228 32.53833 0.0000000 -0.1000000 0.0000000 GR Z~ D E N SFT2 RB 0,0000000 2.000000 0,0000000 0.0000000 56,68414 2,353001 1058,272 -1,555345 64,78854 2,292963 1148,764 -1,555345 48,95349 2,113117 1815,181 -1,555345 47.10068 2,000000 0.0000000 O.O000OOO TOTAL DATA RECORDS : STARTING TAPE DEPTH : **** mILE TRAILER 69 4374.00 ENDING TAPE DEPTH = 4466.00 **** TAPE TRAILER **** LIS 89/24/08 3945 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 909 **** REEL TRAILER **** LiS 89/24/08 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 910 TOTAL RECORDS IN THIS PHYSICAL REEL: 910 End o ¢ e:~(,ec n: Thu 31 AUG 89 ~+: 14p Ela:ps:ed e~ecw~£:cn ~ime = 17 minute:s, 12.0 seconds. SYSTEM RETURN CODE = 0
