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Home My WebLink About191-014Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. T40958SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' 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: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,396'8050 & 10851 (fill) Casing Collapse Structural Conductor Surface 1,130psi Intermediate 3,830psi Production 10,490psi Liner 11,160psi 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 Attached Schematic Swanson River Sterling/Upper Beluga Gas 2,187' See Schematic Length 8,701' 2,555' Size Perm Pkr, Liner Top Pk, Baker SC-1L Pkr; N/A 2461', 3879', 9499' MD/ 2461'; 8378'; 9489' TVD; N/A 11,168'3,446'3,446' 13-3/8" 2-7/8" See Attached Schematic Swanson River Unit (SRU) 32A-33CO 716A Same 10,454'5" ~1164 psi 6,340psi 2,730psi September 9, 2025 11,386'1,887' 3-1/2" 11,160' 45'22" 10,566' Perforation Depth MD (ft): 8,701'7"8,701' 2,555' MD 45' 9.2# / L-80 TVD Burst 2,525' 10,140psi 2,555' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028399 191-014 50-133-10164-01-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 10,570psi 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? 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 45' m n P s t 2 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 For: Noel Nocas Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517) Date: 2025.08.26 11:51:05 - 08'00' Chad Helgeson (1517) 325-517 By Grace Christianson at 12:10 pm, Aug 26, 2025 DSR-8/26/25A.Dewhurst 27AUG25 BOP test to 2500 psi X 10-404 BJM 9/2/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.03 08:28:42 -08'00'09/03/25 RBDMS JSB 090425 Well Prognosis Well: SRU 32A-33 Well Name: SRU 32A-33 API Number: 50-133-10164-01-00 Current Status: Gas Producer Permit to Drill Number: 191-014 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: 1506 psi @ 3423’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 1164 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.70 psi/ft using 13.5 ppg EMW FIT (Offset SRU 222-33) Shallowest Allowable Perf TVD: MPSP / (0.70 - 0.1) = 1164 psi / 0.6 = 1940’ TVD *Note: The 13-3/8” shoe was drilled and set in 1960 on well SRU 32A-33 (Original parent wellbore 32-33). There are no records of documented LOT / FIT for the 13-3/8” shoe set at 2555’ MD. For calculations above, Hilcorp is using nearby offset well SRU 222-33. SRU 222-33 was recently drilled in late 2023. 7-5/8” casing was set at 2738’ and a 13.59 ppg EMW FIT was obtained. Top of Applicable Gas Pool / PA: Sterling – Upper Beluga 2295’ MD / 2295’ TVD Well Status: Gas Producer x 336 mcfd / 1489 bwpd / 273 FTP (As of 8/23/2025) Recent Well Summary: SRU 32A-33 is an active gas producer currently open and producing in the B1 and A14 intervals of the Sterling – Upper Beluga Gas Pool / PA. The current perforations were added in September of 2022. Initial production came on between 1.5 – 3 mmfcd before significant water breakthrough occurred in February of 2023. Since, the well has slowly declined and current well production is 336 mcfd / 1489 bwpd / 273 FTP (As of 8/23/2025). The objective of this Sundry is to perform a coil tubing cleanout and add additional perforations in the ST B3 – B8 zones below current open perforations. Most Recent Well work: Slickline Drift & Tag (June 2024) x Tagged at 2750’ x Bailed from 2750’ – 2754’ in (4) 2.5” x 6’ bailer runs Procedure: 1. MIRU Fox CTU, PT BOPE 250 psi low / 2500 psi high a. Provide AOGCC 24hrs notice of BOP test. 2. M/U cleanout nozzle, RIH and tag top of fill (last documented tag was at + 2754’ MD in June 2024) 3. Perform coil tubing cleanout from fill tag depth to ED of + 3,448’. a. Nitrogen may be used during cleanout to aid in hole cleaning and to minimize losses to formation / open perforations. 4. RDMO CTU and MIRU E-line 5. PT E-line lubricator to 250 psi low / 2500 psi high Well Prognosis Well: SRU 32A-33 6. RIH and perforate the following sands: Below are proposed targeted sands in order of testing (bottom/up), but additional sands may be added depending on results of these perfs, between the proposed top and bottom perfs Well Sand MD top MD Bottom TVD top TVD bottom Interval SRU 32A-33 ST B3 +2,936’ +2,942’ +2,936’ +2,942’ +6’ SRU 32A-33 ST B4 +3,003’ +3,009’ +3,003’ +3,009’ +6’ SRU 32A-33 ST B5 +3,041’ +3,051’ +3,041’ +3,051’ +10’ SRU 32A-33 ST B7 +3,326’ +3,333’ +3,326’ +3,333’ +7’ SRU 32A-33 ST B7 +3,335’ +3,343’ +3,335’ +3,343’ +8’ SRU 32A-33 ST B7 +3,354’ +3,364’ +3,354’ +3,364’ +10’ SRU 32A-33 ST B7 +3,370’ +3,380’ +3,370’ +3,380’ +10’ SRU 32A-33 ST B8 +3,393’ +3,399’ +3,393’ +3,399’ +6’ SRU 32A-33 ST B8 +3,413’ +3,423’ +3,413’ +3,423’ +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 each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If necessary, use nitrogen or pad gas throughout operations to pressure up well during perforating or to depress water. 7. RDMO and return well to production. Contingency Procedure: Additional Coiled Tubing Cleanout(s) 1. If throughout the job any current or proposed zones 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 / 2500 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure – N2 Operations Updated by CAH 2-15-23 SRU 32A-33 SCHEMATIC Well SRU 32A-33 PTD:191-014 API: 50-133-10164-01-00 Casing Detail Size Type Wt/ Grade Top Btm CONN / ID 22”Structural -Surface 45’- 13-3/8”Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615”DV Collar 1,023’1,025’ 54.5#, J-55 1,025’2,555’ 7”Intermediate23/26/29#, N-80 Surface 7,916’BTC / 6.184” or greater (see p2) 26#, P-110 7,916’8,036’8RD / 6.276” DV Collar 8,036’8,038’8RD / 6.276” 26#, P-110 8,038’8,701’8RD / 6.276” 5”Liner 18#, N-80 8,379’10,566’FL4S / 4.276” 2-7/8”Liner 6.5#, N-80 9,499’11,386’8RD-Mod / 2.441” Tubing Detail 3-1/2”Prod 9.2#, L-80 Surface 2,525’IBT-M / 2.992” Upper Production String Jewelry Detail #Depth (RKB)Length ID Item 1 26.3’0.62’2.990”Tubing Hanger, 3-1/2” 2 2,412’5.5’2.810”3.5” GLM (Orifice GLV Installed) 3 2,461’6.7’2.990”D&L 3-1/2” x 7” Permanent Packer 4a 2,514’1’2.810”X Nipple 4b 2,525’1’2.991 Mule Shoe 5 3,535’ Spiral bridge plug w/ 20’ cement (8/21/22). Tagged at 3502’ ELMD and added an additional 36’ cement on 9/10/22. Tagged at 3,497’ ELMD and added an additional 45’ cement on 9/15/22. TOC tag on 9/21/22 @ 3,448’ ELMD 6 3,925’--TTBP w/ 60 gals of cement (37’) 4/19/21 TOC @ 3888’ 7 4,273’--Failed TTBP fish 8 5,390’--TTBP w/ 60 gals of cement (37’) 02/24/21 TOC @ 5353’ 9 7,866’1’-CIBP w/ 17bbls of cement (416’) 08/09/17 TOC @ 7450’ 10 8,050’–8,341’122’-122’ ESP assembly: ESP with cut joint of 3-1/2” TOF = 8050’ MD Upper Perforation Data ZONE TOP BTM Comments A-14 2,657’2,663’Perf (9/21/22) B1 2,742’2,747’Perf (9/21/22) B9 3,486’3,500’Perf (8/22/22) Isolated 9/10/22 Up Beluga 3,539’3,547’Perf (4/23/21) Isolated 8/21/22 Up Beluga 3,559’3,563’Perf (4/23/21) Isolated 8/21/22 UB 37-0 3,680’3,693’Perf (4/21/21). Isolated 8/21/22 UB 50-9U 4,834’4,842’Perf (2/27/21) Isolated 4/18/21 UB 50-9L 4,863’4,870’Perf (2/27/21) Isolated 4/18/21 LB 51-7 5,271’5,282’Perf (2/25/21) Isolated 4/18/21 OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2” hole: 1st stage: Shoe cemented with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 1900’ assuming 40% washout. 2nd stage: cemented through DV collar at 1023’ with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 300’ assuming 40% washout. Top Job: Ran 1” pipe to 60’ and cemented with 64 sxs 15.5ppg (13.6 bbls at 1.19 cuft/sxs). Returns to surface. 7” 17-1/2” hole from shoe to 3000’. 12-1/4” hole to 3715’. 10-5/8” hole to TD at 11,385’. 1st stage: Shoe cemented from 11,030’ MD with 650 sxs of 15.4ppg cement. 2nd stage: Cemented through DV collar at 8036’ with 750sxs of 15.4ppg cement (162bbls assuming 1.21 cubic ft / bbl) (full circulation throughout) (32-33 parent – 1960). Volumetrics put ToC at 5400’ or lower. 8/17/17 CBL shows free pipe above 2100’ MD 5”70 bbl 15.6 ppg 2-7/8”18 bbl 15.8 ppg PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” KB-THF: 26.3’ KB 5” @ 10,566’ H-3/H-4 22” H-2 2-7/8” @ 11,386’ TOL at 9,499’ DV Collar @ 1,023’ RKB: 198.3’ KB / GL: 172’ AMSL 1 H-1 G 12 13 14 15 7” TOC 2,100’CBL Tag fill at 10,851’ 9/17/2010 4a/4b 2/3 8 6 A-14 B1 7 7” window at 8,701’ 10 DV Collar @ 8,036’ TOL at 8,379’11 7X 9 Disposal Sand: 2082’ – 2420’ 5 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Fill tagged @ 2,754’ 6-6-24 Updated by CAH 2-15-23 SRU 32A-33 SCHEMATIC Well SRU 32A-33 PTD: 191-014 API: 50-133-10164-01-00 7” Casing Detail Expanded Size Type Wt/ Grade Top Btm CONN / ID 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” Lower Production String Jewelry Detail # Depth (RKB) Length ID OD Item 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Lower Perforation Data ZONE TOP BTM Comments TY 53-0 5,411’ 5,422’ Perf (2/17/21) Isolated 2/24/21 TY 55-5 5,629’ 5,637’ Perf (2/11/21) Isolated 2/24/21 TY 56-9 5,760’ 5,778’ Perf (1/10/21), (2/10/21) Isolated 2/24/21 TY 62-5 6,344’ 6,350’ Perf (2/5/21) Isolated 2/24/21 TY 69-0 7,071’ 7,080’ Perf (2/4/21) Isolated 2/24/21 G 10,698’ 10,724’ Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated 8/9/17 H-1 10,800’ 10,820’ Perf (12/05/95), (5/10/91), (9/17/10) Isolated 8/9/17 H-2 10,835’ 10,854’ Perf (12/05/95), (4/28/91), (9/17/10: 10,835’ – 10,849’) Iso 8/9/17 H-3, H-4 10,900’ 10,912’ Perf (4/23/91) Isolated before 2010… Updated by RPL 8-25-2025 SRU 32A-33 SCHEMATIC (Proposed) Well SRU 32A-33 PTD:191-014 API: 50-133-10164-01-00 Casing Detail Size Type Wt/ Grade Top Btm CONN / ID 22”Structural -Surface 45’- 13-3/8”Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615”DV Collar 1,023’1,025’ 54.5#, J-55 1,025’2,555’ 7”Intermediate23/26/29#, N-80 Surface 7,916’BTC / 6.184” or greater (see p2) 26#, P-110 7,916’8,036’8RD / 6.276” DV Collar 8,036’8,038’8RD / 6.276” 26#, P-110 8,038’8,701’8RD / 6.276” 5”Liner 18#, N-80 8,379’10,566’FL4S / 4.276” 2-7/8”Liner 6.5#, N-80 9,499’11,386’8RD-Mod / 2.441” Tubing Detail 3-1/2”Prod 9.2#, L-80 Surface 2,525’IBT-M / 2.992” Upper Production String Jewelry Detail #Depth (RKB)Length ID Item 1 26.3’0.62’2.990”Tubing Hanger, 3-1/2” 2 2,412’5.5’2.810”3.5” GLM (Orifice GLV Installed) 3 2,461’6.7’2.990”D&L 3-1/2” x 7” Permanent Packer 4a 2,514’1’2.810”X Nipple 4b 2,525’1’2.991 Mule Shoe 5 3,535’ Spiral bridge plug w/ 20’ cement (8/21/22). Tagged at 3502’ ELMD and added an additional 36’ cement on 9/10/22. Tagged at 3,497’ ELMD and added an additional 45’ cement on 9/15/22. TOC tag on 9/21/22 @ 3,448’ ELMD 6 3,925’--TTBP w/ 60 gals of cement (37’) 4/19/21 TOC @ 3888’ 7 4,273’--Failed TTBP fish 8 5,390’--TTBP w/ 60 gals of cement (37’) 02/24/21 TOC @ 5353’ 9 7,866’1’-CIBP w/ 17bbls of cement (416’) 08/09/17 TOC @ 7450’ 10 8,050’–8,341’122’-122’ ESP assembly: ESP with cut joint of 3-1/2” TOF = 8050’ MD Upper Perforation Data ZONE TOP (MD) BTM (MD) Comments A-14 2,657’2,663’Perf (9/21/22) B1 2,742’2,747’Perf (9/21/22) B3 +2,936’+2,942’Proposed B4 +3,003’+3,009’Proposed B5 +3,041’+3,051’Proposed B7 +3,326’+3,333’Proposed B7 +3,335’+3,343’Proposed B7 +3,354’+3,364’Proposed B7 +3,370’+3,380’Proposed B8 +3,393’+3,399’Proposed B8 +3,413’+3,423’Proposed B9 3,486’3,500’Perf (8/22/22) Isolated 9/10/22 Up Beluga 3,539’3,547’Perf (4/23/21) Isolated 8/21/22 Up Beluga 3,559’3,563’Perf (4/23/21) Isolated 8/21/22 UB 37-0 3,680’3,693’Perf (4/21/21). Isolated 8/21/22 UB 50-9U 4,834’4,842’Perf (2/27/21) Isolated 4/18/21 UB 50-9L 4,863’4,870’Perf (2/27/21) Isolated 4/18/21 LB 51-7 5,271’5,282’Perf (2/25/21) Isolated 4/18/21 PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” KB-THF: 26.3’ KB 5” @ 10,566’ H-3/H-4 22” H-2 2-7/8” @ 11,386’ TOL at 9,499’ DV Collar @ 1,023’ RKB: 198.3’ KB / GL: 172’ AMSL 1 H-1 G 12 13 14 15 7” TOC 2,100’CBL Tag fill at 10,851’ 9/17/2010 4a/4b 2/3 8 6 A14 – B1 B3-B8 7 7” window at 8,701’ 10 DV Collar @ 8,036’ TOL at 8,379’11 7X 9 Disposal Sand: 2082’ – 2420’ 5 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Updated by RPL 8-25-2025 SRU 32A-33 SCHEMATIC (Proposed) Well SRU 32A-33 PTD: 191-014 API: 50-133-10164-01-00 OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2” hole: 1st stage: Shoe cemented with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 1900’ assuming 40% washout. 2nd stage: cemented through DV collar at 1023’ with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 300’ assuming 40% washout. Top Job: Ran 1” pipe to 60’ and cemented with 64 sxs 15.5ppg (13.6 bbls at 1.19 cuft/sxs). Returns to surface. 7” 17-1/2” hole from shoe to 3000’. 12-1/4” hole to 3715’. 10-5/8” hole to TD at 11,385’. 1st stage: Shoe cemented from 11,030’ MD with 650 sxs of 15.4ppg cement. 2nd stage: Cemented through DV collar at 8036’ with 750sxs of 15.4ppg cement (162bbls assuming 1.21 cubic ft / bbl) (full circulation throughout) (32-33 parent – 1960). Volumetrics put ToC at 5400’ or lower. 8/17/17 CBL shows free pipe above 2100’ MD 5” 70 bbl 15.6 ppg 2-7/8” 18 bbl 15.8 ppg 7” Casing Detail Expanded Size Type Wt/ Grade Top Btm CONN / ID 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” Lower Production String Jewelry Detail # Depth (RKB) Length ID OD Item 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Lower Perforation Data ZONE TOP BTM Comments TY 53-0 5,411’ 5,422’ Perf (2/17/21) Isolated 2/24/21 TY 55-5 5,629’ 5,637’ Perf (2/11/21) Isolated 2/24/21 TY 56-9 5,760’ 5,778’ Perf (1/10/21), (2/10/21) Isolated 2/24/21 TY 62-5 6,344’ 6,350’ Perf (2/5/21) Isolated 2/24/21 TY 69-0 7,071’ 7,080’ Perf (2/4/21) Isolated 2/24/21 G 10,698’ 10,724’ Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated 8/9/17 H-1 10,800’ 10,820’ Perf (12/05/95), (5/10/91), (9/17/10) Isolated 8/9/17 H-2 10,835’ 10,854’ Perf (12/05/95), (4/28/91), (9/17/10: 10,835’ – 10,849’) Iso 8/9/17 H-3, H-4 10,900’ 10,912’ Perf (4/23/91) Isolated before 2010… 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Donna Ambruz To:AOGCC Permitting (CED sponsored) Cc:Chad Helgeson; Noel Nocas Subject:RE: [EXTERNAL] Sundry_SRU 32A-33 323-102 / Withdrawal Date:Wednesday, March 29, 2023 11:40:18 AM Please withdraw/cancel the above-referenced sundry. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Sent: Thursday, March 2, 2023 12:02 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Sundry_SRU 32A-33 323-102 Samantha Carlisle AOGCC Special Assistant Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1223 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Set Plug 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,396'8050 & 10851 (fill) Casing Collapse Structural Conductor Surface 1,130psi Intermediate 3,830psi Production 10,490psi Liner 11,160psi 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: Contact Email: Contact Phone: 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10,140psi10,454'10,566' 10,570psi11,386'11,160' 2,555' 8,701' Perforation Depth MD (ft): 2,187' 2-7/8"1,887' 5" 7"8,701' 13-3/8"2,555' 6,340psi 2,730psi2,555' 8,701' Length Size Proposed Pools: 45'45' TVD Burst PRESENT WELL CONDITION SUMMARY 11,168'3,446'3,446'~960psi See Schematic 45'22" MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028399 191-014 50-133-10164-01-00 Swanson River Beluga Gas, Hemlock Oil, Sterling/Up Beluga Gas Same CO 716A Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit (SRU) 32A-33 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: 9.2# / L-80 2,525' March 2, 2023 Perm Pkr, Liner Top Pk, Baker SC-1L Pkr; N/A 2461', 3879', 9499' MD/TVD; N/A See Attached Schematic See Attached Schematic 3-1/2" 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: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 m n P s t 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 7:51 am, Feb 17, 2023 323-102 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.02.16 15:47:39 -09'00' Dan Marlowe (1267) 10-407 BJM 3/1/23 DSR-2/22/23SFD 3/1/2023JLC 3/2/2023 3/2/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:27:08 -09'00' RBDMS JSB 030223 Well: SRU 32A-33 Plug Back Date: 2/15/2023 Well Name: SRU 32A-33 API Number: 50-133-10164-01-00 Current Status: SI Gas Producer Permit to Drill Number: 191-014 First Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (720) 988-5375 (C) Max. Expected BHP: ~ 1,234 psi @ 2,742’ TVD (0.45psi/ft to deepest open perfs) Max. Potential Surface Pressure: ~ 960 psi (0.1psi/ft to surface) Brief Well Summary SRU 32A-33 is an online Sterling gas well, flowing between 1.5 and 3 mmscfd of gas, until a significant breakthrough in water (~1,000 bwpd) showed up February 7th. There are 2 Sterling sands open in the well and the upper sand has showed to be the zone making the gas. The purpose of this work is to plug off and isolate the Sterling B1 sand from the Sterling A-14 Sand, which are all in the Sterling/Upper Beluga Pool/PA. Notes Regarding Wellbore Condition x Min ID = 2.810” at 2,514’ MD (3-1/2” X-nipple) x Straight hole at these shallow depths x Recent activity o 2/15/23: SL tagged/bailed fill at 2,766’ o 12/28/22: SL tagged/bailed fill at 2667’ with 2.5” DD bailer o 9/21/22: EL Perforated Sterling B1 and A-14 Sands o 9/10/22: EL set plug over Sterling B9 Sand o 8/22/22: EL Perforated Sterling B9 Sand o 6/30/22: SL bailed to 3605’ MD with a 2.5” x 11’ drivedown bailer E-Line Plug/Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 1500psi high 3. Set expandable bridge plug in 7” casing at ±2,730’ MD 4. Dump bail 35’ cement on top of plug (58 gal) (target ToC = ±2695’ MD) Note: Hilcorp is seeking a BLM variance to set this bridge plug <50’ above top perf, to allow the most ratehole for sand fill. 5. RDMO EL Attachments: 1. Current Well Schematic 2. Proposed Well Schematic o plug off and isolate the Sterling B1 sand f Updated by CAH 2-15-23 SRU 32A-33 SCHEMATIC Well SRU 32A-33 PTD:191-014 API: 50-133-10164-01-00 Casing Detail Size Type Wt/ Grade Top Btm CONN / ID 22”Structural -Surface 45’- 13-3/8”Surface 54.5#, J-55 Surface 1,023’ 8RD/ 12.615”DV Collar 1,023’1,025’ 54.5#, J-55 1,025’2,555’ 7”Intermediate23/26/29#, N-80 Surface 7,916’BTC /6.184”or greater (see p2) 26#, P-110 7,916’8,036’8RD / 6.276” DV Collar 8,036’8,038’8RD / 6.276” 26#, P-110 8,038’8,701’8RD / 6.276” 5”Liner 18#, N-80 8,379’10,566’FL4S / 4.276” 2-7/8”Liner 6.5#, N-80 9,499’11,386’8RD-Mod /2.441” Tubing Detail 3-1/2”Prod 9.2#, L-80 Surface 2,525’IBT-M / 2.992” Upper Production String Jewelry Detail #Depth (RKB)Length ID Item 1 26.3’0.62’2.990”Tubing Hanger, 3-1/2” 2 2,412’5.5’2.810”3.5” GLM (Orifice GLV Installed) 3 2,461’6.7’2.990”D&L 3-1/2” x 7” Permanent Packer 4a 2,514’1’2.810”X Nipple 4b 2,525’1’2.991 Mule Shoe 5 3,535’ Spiral bridge plug w/ 20’ cement (8/21/22). Tagged at 3502’ ELMD and added an additional 36’ cement on 9/10/22. Tagged at 3,497’ ELMD and added an additional 45’ cement on 9/15/22. TOC tag on 9/21/22 @ 3,448’ELMD 6 3,925’--TTBP w/ 60 gals of cement (37’) 4/19/21 TOC @ 3888’ 7 4,273’--Failed TTBP fish 8 5,390’--TTBP w/ 60 gals of cement (37’) 02/24/21 TOC @ 5353’ 9 7,866’1’-CIBP w/ 17bbls of cement (416’) 08/09/17 TOC @ 7450’ 10 8,050’–8,341’122’-122’ ESP assembly: ESP with cut joint of 3-1/2” TOF = 8050’ MD Upper Perforation Data ZONE TOP BTM Comments A-14 2,657’2,663’Perf (9/21/22) B1 2,742’2,747’Perf (9/21/22) B9 3,486’3,500’Perf (8/22/22) Isolated 9/10/22 Up Beluga 3,539’3,547’Perf (4/23/21) Isolated 8/21/22 Up Beluga 3,559’3,563’Perf (4/23/21) Isolated 8/21/22 UB 37-0 3,680’3,693’Perf (4/21/21). Isolated 8/21/22 UB 50-9U 4,834’4,842’Perf (2/27/21) Isolated 4/18/21 UB 50-9L 4,863’4,870’Perf (2/27/21) Isolated 4/18/21 LB 51-7 5,271’5,282’Perf (2/25/21) Isolated 4/18/21 OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2” hole: 1st stage: Shoe cemented with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 1900’ assuming 40% washout. 2nd stage: cemented through DV collar at 1023’ with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 300’ assuming 40% washout. Top Job: Ran 1” pipe to 60’ and cemented with 64 sxs 15.5ppg (13.6 bbls at 1.19 cuft/sxs). Returns to surface. 7” 17-1/2” hole from shoe to 3000’. 12-1/4” hole to 3715’. 10-5/8” hole to TD at 11,385’. 1st stage: Shoe cemented from 11,030’ MD with 650 sxs of 15.4ppg cement. 2nd stage: Cemented through DV collar at 8036’ with 750sxs of 15.4ppg cement (162bbls assuming 1.21 cubic ft / bbl) (full circulation throughout) (32-33 parent – 1960). Volumetrics put ToC at 5400’ or lower. 8/17/17 CBL shows free pipe above 2100’ MD 5”70 bbl 15.6 ppg 2-7/8”18 bbl 15.8 ppg PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” KB-THF: 26.3’ KB 5” @ 10,566’ H-3/H-4 22” H-2 2-7/8” @ 11,386’ TOL at 9,499’ DV Collar @ 1,023’ RKB: 198.3’ KB / GL: 172’AMSL 1 H-1 G 12 13 14 15 7”TOC 2,100’CBL Tag fill at 10,851’ 9/17/2010 4a/4b 2/3 8 6 A-14 B1 7 7” window at 8,701’ 10 DV Collar @ 8,036’ TOL at 8,379’11 7X 9 Disposal Sand: 2082’–2420’ 5 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Fill tagged @ 2,776’ 2-15-23 Updated by CAH 2-15-23 SRU 32A-33 SCHEMATIC Well SRU 32A-33 PTD: 191-014 API: 50-133-10164-01-00 7” Casing Detail Expanded Size Type Wt/ Grade Top Btm CONN / ID 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” Lower Production String Jewelry Detail # Depth (RKB) Length ID OD Item 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Lower Perforation Data ZONE TOP BTM Comments TY 53-0 5,411’ 5,422’ Perf (2/17/21) Isolated 2/24/21 TY 55-5 5,629’ 5,637’ Perf (2/11/21) Isolated 2/24/21 TY 56-9 5,760’ 5,778’ Perf (1/10/21), (2/10/21) Isolated 2/24/21 TY 62-5 6,344’ 6,350’ Perf (2/5/21) Isolated 2/24/21 TY 69-0 7,071’ 7,080’ Perf (2/4/21) Isolated 2/24/21 G 10,698’ 10,724’ Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated 8/9/17 H-1 10,800’ 10,820’ Perf (12/05/95), (5/10/91), (9/17/10) Isolated 8/9/17 H-2 10,835’ 10,854’ Perf (12/05/95), (4/28/91), (9/17/10: 10,835’ – 10,849’) Iso 8/9/17 H-3, H-4 10,900’ 10,912’ Perf (4/23/91) Isolated before 2010… Updated by CAH 2-15-23 SRU 32A-33 PROPOSED SCHEMATIC Well SRU 32A-33 PTD:191-014 API: 50-133-10164-01-00 Casing Detail Size Type Wt/ Grade Top Btm CONN / ID 22”Structural -Surface 45’- 13-3/8”Surface 54.5#, J-55 Surface 1,023’ 8RD/ 12.615”DV Collar 1,023’1,025’ 54.5#, J-55 1,025’2,555’ 7”Intermediate23/26/29#, N-80 Surface 7,916’BTC /6.184”or greater (see p2) 26#, P-110 7,916’8,036’8RD / 6.276” DV Collar 8,036’8,038’8RD / 6.276” 26#, P-110 8,038’8,701’8RD / 6.276” 5”Liner 18#, N-80 8,379’10,566’FL4S / 4.276” 2-7/8”Liner 6.5#, N-80 9,499’11,386’8RD-Mod /2.441” Tubing Detail 3-1/2”Prod 9.2#, L-80 Surface 2,525’IBT-M / 2.992” Upper Production String Jewelry Detail #Depth (RKB)Length ID Item 1 26.3’0.62’2.990”Tubing Hanger, 3-1/2” 2 2,412’5.5’2.810”3.5” GLM (Orifice GLV Installed) 3 2,461’6.7’2.990”D&L 3-1/2” x 7” Permanent Packer 4a 2,514’1’2.810”X Nipple 4b 2,525’1’2.991 Mule Shoe 5 2,730’Spiral Bridge Plug w/ 35’ of cement 5A 3,535’ Spiral bridge plug w/ 20’ cement (8/21/22). Tagged at 3502’ ELMD and added an additional 36’ cement on 9/10/22. Tagged at 3,497’ ELMD and added an additional 45’ cement on 9/15/22. TOC tag on 9/21/22 @ 3,448’ELMD 6 3,925’--TTBP w/ 60 gals of cement (37’) 4/19/21 TOC @ 3888’ 7 4,273’--Failed TTBP fish 8 5,390’--TTBP w/ 60 gals of cement (37’) 02/24/21 TOC @ 5353’ 9 7,866’1’-CIBP w/ 17bbls of cement (416’) 08/09/17 TOC @ 7450’ 10 8,050’–8,341’122’-122’ ESP assembly: ESP with cut joint of 3-1/2” TOF = 8050’ MD Upper Perforation Data ZONE TOP BTM Comments A-14 2,657’2,663’Perf (9/21/22) B1 2,742’2,747’Perf (9/21/22) B9 3,486’3,500’Perf (8/22/22) Isolated 9/10/22 Up Beluga 3,539’3,547’Perf (4/23/21) Isolated 8/21/22 Up Beluga 3,559’3,563’Perf (4/23/21) Isolated 8/21/22 UB 37-0 3,680’3,693’Perf (4/21/21). Isolated 8/21/22 UB 50-9U 4,834’4,842’Perf (2/27/21) Isolated 4/18/21 UB 50-9L 4,863’4,870’Perf (2/27/21) Isolated 4/18/21 LB 51-7 5,271’5,282’Perf (2/25/21) Isolated 4/18/21 OPEN HOLE / CEMENT DETAIL 13-3/8” 17-1/2” hole: 1st stage: Shoe cemented with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 1900’ assuming 40% washout. 2nd stage: cemented through DV collar at 1023’ with 600 sxs 15.5ppg (127bbls at 1.19 cuft/sxs). Volumetric ToC at 300’ assuming 40% washout. Top Job: Ran 1” pipe to 60’ and cemented with 64 sxs 15.5ppg (13.6 bbls at 1.19 cuft/sxs). Returns to surface. 7” 17-1/2” hole from shoe to 3000’. 12-1/4” hole to 3715’. 10-5/8” hole to TD at 11,385’. 1st stage: Shoe cemented from 11,030’ MD with 650 sxs of 15.4ppg cement. 2nd stage: Cemented through DV collar at 8036’ with 750sxs of 15.4ppg cement (162bbls assuming 1.21 cubic ft / bbl) (full circulation throughout) (32-33 parent – 1960). Volumetrics put ToC at 5400’ or lower. 8/17/17 CBL shows free pipe above 2100’ MD 5”70 bbl 15.6 ppg 2-7/8”18 bbl 15.8 ppgPBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” KB-THF: 26.3’ KB 5” @ 10,566’ H-3/H-4 22” H-2 2-7/8” @ 11,386’ TOL at 9,499’ DV Collar @ 1,023’ RKB: 198.3’ KB / GL: 172’AMSL 1 H-1 G 12 13 14 15 7”TOC 2,100’CBL Tag fill at 10,851’ 9/17/2010 4a/4b 2/3 8 6 A-14 B1 7 7” window at 8,701’ 10 DV Collar @ 8,036’ TOL at 8,379’11 7X 9 Disposal Sand: 2082’–2420’ 5A 5 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Fill tagged @ 2,766’ 2-15-23 Updated by CAH 2-15-23 SRU 32A-33 PROPOSED SCHEMATIC Well SRU 32A-33 PTD: 191-014 API: 50-133-10164-01-00 7” Casing Detail Expanded Size Type Wt/ Grade Top Btm CONN / ID 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” Lower Production String Jewelry Detail # Depth (RKB) Length ID OD Item 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Lower Perforation Data ZONE TOP BTM Comments TY 53-0 5,411’ 5,422’ Perf (2/17/21) Isolated 2/24/21 TY 55-5 5,629’ 5,637’ Perf (2/11/21) Isolated 2/24/21 TY 56-9 5,760’ 5,778’ Perf (1/10/21), (2/10/21) Isolated 2/24/21 TY 62-5 6,344’ 6,350’ Perf (2/5/21) Isolated 2/24/21 TY 69-0 7,071’ 7,080’ Perf (2/4/21) Isolated 2/24/21 G 10,698’ 10,724’ Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated 8/9/17 H-1 10,800’ 10,820’ Perf (12/05/95), (5/10/91), (9/17/10) Isolated 8/9/17 H-2 10,835’ 10,854’ Perf (12/05/95), (4/28/91), (9/17/10: 10,835’ – 10,849’) Iso 8/9/17 H-3, H-4 10,900’ 10,912’ Perf (4/23/91) Isolated before 2010… Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SD-06 50133205820000 208160 9/12/2022 Yellowjacket PERF SRU 32A-33 50133101640100 191014 9/21/2022 Yellowjacket PERF KBU 42-06Y 50133206340000 214089 9/26/2022 Yellowjacket GPT-PERF CLU 05RD2 50133204740200 222092 9/29/2022 Yellowjacket PERF SCU 344-33 50133202930100 218054 10/8/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:48 am, Nov 29, 2022 T37313 T37314 T37315 T37316 T37317SRU 32A-33 50133101640100 191014 9/21/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:55:33 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/23/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221123 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PAXTON 6 50133207070000 222054 8/1/2022 Yellowjacket PERF BCU-7A 50133202840100 214060 8/2/2022 Yellowjacket GPT-PERF KBU 43-07Y 50133206250000 214019 8/3/2022 Yellowjacket PERF KBU 22-06Y 50133206500000 215044 8/4/2022 Yellowjacket GPT-PERF SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF HVB 16A 50231200400100 222070 8/23/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/26/2022 Yellowjacket PERF HVB-16A 50231200400100 222070 8/27/2022 Yellowjacket PERF PAXTON 10 50133206910000 220064 8/29/2022 Yellowjacket PERF KALOTSA 4 50133206650000 217063 9/1/2022 Yellowjacket GPT-PERF KALOTSA 4 50133206650000 217063 9/6/2022 Yellowjacket PERF-GPT Please include current contact information if different from above. By Meredith Guhl at 9:26 am, Nov 29, 2022 T37305 T37306 T37306 T37307 T37307 T37308 T37309 T37310 T37311 T37311 T37312SRU 32A-33 50133101640100 191014 8/21/2022 Yellowjacket GPT-PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 09:43:24 -09'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/21/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221121 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 05RD2 50133204740200 222092 10/18/2022 AK E-Line Perf_GPT MGS S MGS Unit 11 50733201040000 168032 10/11/2022 AK E-Line LDL SRU 241-33 50133206630000 217047 8/29/2022 AK E-Line TTBP_Perf SRU 32A-33 50133101640100 191014 9/23/2022 AK E-Line GPT SCU 344-33 50133202930100 218054 9/11/2022 AK E-Line Punch BCU 18RD 50133205840100 222033 9/10/2022 AK E-Line GPT BCU 18RD 50133205840100 222033 9/18/2022 AK E-Line Stim BRU 233-23 50283201360100 222050 11/1/2022 AK E-Line Perf BRU 233-23 50283201360100 222050 9/12/2022 AK E-Line CIBP Please include current contact information if different from above. T37280 T37281 T37282 T37283 T37284 T37285 T37285 T37286 T37286 By Meredith Guhl at 2:54 pm, Nov 21, 2022 SRU 32A-33 50133101640100 191014 9/23/2022 AK E-Line GPT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.21 14:55:38 -09'00' By Anne Prysunka at 2:50 pm, Oct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returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # BRU 212-24 50283200370000 172015 7/27/2022 AK E-Line CIBP BRU 233-27 50283100260000 163002 7/2/2022 AK E-Line PERF HVA B-16 50231200400000 212133 6/23/2022 AK E-Line PLUG/CEMENT KBU 11-08Z 50133206290000 214044 6/22/2022 AK E-Line PERF KBU 33-06X 50133205290000 203183 6/18/2022 AK E-Line PLUG/CEMENT/PUNCH MPU I-17 50029232120000 204098 7/9/2022 Read CALIPER SRU 32A-33 50133101640100 191014 6/20/2022 Halliburton TMD3D-WFL + Report Please include current contact information if different from above. T36794 T36795 T36796 T36797 T36798 T36799 T36800 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.19 09:04:04 -08'00' Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: DATE: 07/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PLUG-CEMENT RECORD 04/17/2021 Please include current contact information if different from above. 07/26/2021 Received By: 37' (6HW By Abby Bell at 10:55 am, Jul 26, 2021 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: 3,888; 5,353; Total Depth measured 11,396 feet 7,450; 10,890 feet true vertical 11,168 feet 8050&10851 (Fill)feet Effective Depth measured 3,888 feet 9,499 feet true vertical 3,888 feet 9,489 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" 9.2# / L-80 2,525' MD 2,525' TVD Perm Pkr; Liner Top Pkr; 2461'; 3879' MD 2461'; 3879' TVD; Packers and SSSV (type, measured and true vertical depth)Baker SC-1L Pkr; N/A 9,499' MD 9489' TVD 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,570psi Burst 10,140psi 2,555' 6,340psi 2,730psi Collapse 1,130psi 3,830psi 11,160psi 10,490psi Casing Structural 22" 13-3/8" 7" Length 45' 2,555' 8,701' 2,187' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,887' 1,000 11,160' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-137 1,128 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-014 50-133-10164-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 9060 Swanson River Unit (SRU) 32A-33 N/A FEDA028399 8,701' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Sterling & Upper Beluga Gas PoolsN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5" 2-7/8" 45' 10,566' 8,700' 10,454' WINJ WAG 0 Water-Bbl MD 45' 2,555' 11,386' 0 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:56 pm, May 19, 2021 gDigitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.19 15:16:56 -08'00' Taylor Wellman (2143) SFD 5/21/2021DSR-5/19/21 RBDMS HEW 5/20/2021 BJM 9/27/21 Rig Start Date End Date 4/17/21 4/23/21 04/20/2021 - Tuesday Crew arrives at location. Permits, JSA, PJSM. Pick up lubricator, PT 250 low/2,500 high. RIH W/ 2-3/8'' X 5' ( 5 SPF) 11 gm / 60 deg phase. Make correlation pass, send to town, make -12' correction. make second correlation pass. Make +1' correction. Spot and shoot 3,688'-3,693' POOH. OOH/ gun was dry. WHP: pre: 1,020, shoot: 1,023, 5 min: 1,025, 10 min: 1,025, 15 min: 1,027. Standby for production to flow well. RIH W/ 2-3/8'' X 10' ( 5 SPF) 11 gm / 60 deg phase. Make correlation pass, send to town, make +3' correction. discuss with geologist correlation. decide correction is correct. Spot and shoot 3,680'-3,690' POOH. OOH/ gun was dry. WHP: pre: 988, shoot: 990, 5 min: 994, 10 min: 994, 15 min:,993. E-line rigs down equipment secures well/turns over to production. Signs out and leaves location. 04/17/2021 - Saturday 04/19/2021 - Monday Crew arrives at facility. JSA, permits, jobscope. Pick up lubricator, rig up to dump cement. RIH with 2.5" x 30' dump bailer for cement run 2. (run 1 was yesterday) tag plug at 3918'. Dump cement, good break. POOH. OOH, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 3 to 3,915'. Dump cement, no break no weight loss. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 4 to 3,914'. Dump cement, squib break, weight bobble. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 5 to 3,913'. Dump cement, squib break weight bobble. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 6 to 3,912'. Dump cement, clean break, weight loss. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 7 to 3,911'. Dump cement, clean break, weight loss. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 8 to 3,910'. Dump cement, clean break, weight loss. POOH. OOH, cement dumped, re-rig bailer for next run. RIH with 2.5" x 30' dump bailer for cement run 9 to 3,909'. Dump cement, clean break, weight loss. POOH. OOH, cement dumped, re-rig bailer for next run. Lay down lubricator for night. secure well. Crew signs out and leaves location. Plan forward is to perforate tomorrow. Crew arrives at facility. Permits, JSA, jobscope. PJSM Rig up E-line. PT 250 low/2,500 high. RIH W/GPT, 2'' x 7' WB, 1-11/16'' LS Setting tool, spiral plug. Make pass for fluid level. (FL 3,993') while RIH noticed temp swing 2,100'-2,300' which is due to proximity to waste water injection well. Continue in hole, tag fill at 4,273' discuss options with town. Got approval from BLM and State to set plug tag depth (~4,273') tag W/ plug, pull up 2' set plug at 4,271'. POOH Plug set. RIH W/ 2.5'' X 25' dump bailer W/beads to ~4,265. good response on fire panel. OOH bailer did not dump. Detonator did detonate. Bottom of bailer packed off with fine mud. Make several attempts to get down and dump beads. could not dump beads. Discuss with town options. Decided to come back tomorrow and tag mud then set plug ~3,900'. 04/18/2021 - Sunday Crew arrives at location. PJSM, jobscope, Permits. Pick up lubricator. PT 250 low/2,500 high. RIH W/GPT, 2'' X 7' WB, 2.5'' drift to tag fill. Get to 4,050' do not tag. Lost communication with tool. POOH data good to see fluid level. (FL @ 3,993'). OOH tools coverd in mud. Call town. Decide to set plug above fluid/mud level ~3,993'. RIH W/ GGR, 2'' x 7' WB, 1-11/16'' LS setting tool, 2.19'' TTSA to set plug ~3,900'. Set plug at 3,925.4'. clean break. OOH plug set. RIH W/ 2-1/2 x 30' dump bailer W/ 6.12 gallons beads. Dump beads at 3,865' good break/weight loss. POOH.RIH W/ 2-1/2" x 30' dump bailer W/ 6.12 gallons cement. Dump cement 3870'. Good break/weight loss. POOH. Cement dumped. Lay down lubricator and secure well for the night. Crew leaves location. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 shoot 3,680'-3,690' cement dumped, Dump cement, Dump cement, s Set plug at 3,925.4' set plug at 4,271'. Got approval from BLM and State to set plug tag depth (~4,273') tag W/ plug, Spot and shoot 3,688'-3,693' P Dump cement, Dump cement 3870' Dump cement, c Dump cement, Dump cement, Rig Start Date End Date 4/17/21 4/23/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 04/23/2021- Friday Crew arrives at facility. Permits, JSA, Jobscope. Rig up E-line to well. PT 250low/2500high. Grease pump failed. standby for replacement. RIH with 1-11/16" WB, 1-11/16" GGR, 1-11/16" SS, 2-3/8" x 4' 5SPF (60 deg) 11 gm charges. Make correlation pass, send to town. Make +1' down correction, spot and shoot 3559'-3563'. Good break. POOH. OOH gun dry. WHP Pre: 920, shots: 925, 5 min: 1,050, 10 min: 1,125, 15min: 1,195. Standby for production to flow well. flows down to tank setting pressure. RIH with 1-11/16" WB, 1-11/16" GGR, 1-11/16" SS, 2-3/8" x 8' W/ 5 SPF (60 deg) 11 gm charges. Make correlation pass, send to town. No correction needed, spot and shoot 3,539'-3,547'. Good break. POOH. OOH gun was wet. WHP Pre: 1,110, shots: 1,120, 5 min: 1,190, 10 min: 1,238, 15min: 1,272. Standby for production to flow well. flow back rate dropped to ~1 mmcf @430 psi, WHP and rate increases. seems to stabilize ~2.0 mmcf @ 885 psi E-line released from location. Stage equipment for next perf job on 43B-08. Crew leaves facility. shoot 3,539'-3,547' shoot 3559'-3563' Updated by DMA 05-13-21 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Casing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing Detail 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 3 2,461’ 6.7’ 2.990” D&L 3-1/2” x 7” Permanent Packer 4 2,514’ 1’ 2.810” X Nipple 5 2,525’ 1’ 2.991 Mule Shoe D 3,925’--TTBP w/ 60 gals of cement (37’) 4/19/21 TOC @ 3888’ C 4,273’ - - Failed TTBP fish B 5,390’ - - TTBP w/ 60 gals of cement (37’) 02/24/21 TOC @ 5353’ A 7,866’1’-CIBP w/ 17bbls of cement (416’) 08/09/17 TOC @ 7450’ 6 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 7 8,155’ 1.13’ 2.813” X-Profile Nipple 8 8,309’ 8,309’ - - ESP Cable 9 8,339’ 8,339’ - - Dual Chemical Injection Lines 10 8,219’– 8,341’ 122’ - 5.625”/ 5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Perforation Data ZONE TOP BTM SPF Comments Up Beluga 3,539’ 3,547’ 5 Perf (4/23/21) Up Beluga 3,559’ 3,563’ 5 Perf (4/23/21) UB 37-0 3,680’ 3,693’ 5 Perf (4/21/21) UB 50-9U 4,834’ 4,842’ 5 Perf (2/27/21) Isolated 4/18/21 UB 50-9L 4,863’ 4,870’ 5 Perf (2/27/21) Isolated 4/18/21 LB 51-7 5,271’ 5,282’ 5 Perf (2/25/21) Isolated 4/18/21 TY 53-0 5,411’ 5,422’ 5 Perf (2/17/21) Isolated 2/24/21 TY 55-5 5,629’ 5,637’ 5 Perf (2/11/21) Isolated 2/24/21 TY 56-9 5,760’ 5,778’ 5, 6 Perf (1/10/21), (2/10/21) Isolated 2/24/21 TY 62-5 6,344’ 6,350’ 5 Perf (2/5/21) Isolated 2/24/21 TY 69-0 7,071’ 7,080’ 5 Perf (2/4/21) Isolated 2/24/21 G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated 8/9/17 H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated 8/9/17 H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91), (9/17/10: 10,835’ – 10,849’) Iso 8/9/17 H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated before 2010… PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 6 69-0, 62-5, 56-9, 55-5, KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 10 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 12 13 14 15 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 11 7 X A Tag fill at 10,851’ 9/17/2010 8 9 3 5 4 2 B D 51-7, 50-9L 50-9U 37-0, UB Upper, UB Lower C Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Up Beluga 3,539’3,547’5 Perf (4/23/21) Up Beluga 3,559’3,563’5 Perf (4/23/21) UB 37-0 3,680’3,693’5 Perf (4/21/21)(),, Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD 04/23/2021 Please include current contact information if different from above. PTD: 1910140 E-Set: 35115 05/11/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD 04/20/2021 Please include current contact information if different from above. PTD: 1910140 E-Set: 35114 05/11/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD 02/10/2021 Please include current contact information if different from above. PTD: 1910140 E-Set: 34894 Received by the AOGCC 04/05/2021 04/06/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will 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): 11,396'8,050' Casing Collapse Structural Conductor Surface 1,130psi Intermediate 3,830psi Production 10,490psi Liner 11,160psi 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 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 11,168'5,353'5,353'1,294 10,890', 7,450', 5,353' D&L Permanent Packer ; N/A 2,461' MD / 2,461' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 10,570psi 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 FEDA028399 191-014 50-133-10164-01-00 Swanson River Unit (SRU) 32A-33 Swanson River / Sterling & Upper Beluga Gas Pool Length Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 45' 45' 9.2# / L-80 TVD Burst 2,525' 10,140psi MD 6,340psi 2,730psi2,555' 8,701' 2,555' 10,454'5" 45'22" 13-3/8" 7"8,701' 2,555' 10,566' Perforation Depth MD (ft): 8,701' See Attached Schematic 2,187' 2-7/8" 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: April 1, 2021 11,386'1,887' 3-1/2" 11,160' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:44 am, Mar 17, 2021 321-137 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.16 21:15:19 -08'00' Taylor Wellman (2143) 10-404 CO 716 & SFD 3/23/2021 DSR-3/17/21 SFD 3/23/2021 SFD 3/23/2021 BJM 3/26/21 dts 3/26/2021 3/26/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.03.26 14:57:51 -08'00' RBDMS HEW 3/26/2021 Well Prognosis Well: SRU 32A-33 Date: 3/15/2021 Well Name: SRU 32A-33 API Number: 50-133-10164-01-00 Current Status: Gas Well Leg: Estimated Start Date: 3/1/2021 Rig: E-line Reg. Approval Req’d? Yes: 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 191-014 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907)-632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985)-867-0665 (C) AFE Number: Max. Expected BHP: ~ 1662 psi @ 3677’ TVD Normal hydrostatic at bottom perfs Max. Potential Surface Pressure: ~ 1294 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 32A-33 was sidetracked 1000’ due-east from SRU 32-33 in April 1991, initially targeting Hemlock oil in benches H2, H3, and H4. Shortly after first production, the watered-out H3/H4 interval was plugged back and the H1 was perforated. In early 2001, the G-Zone was first perforated and flowed commingled with H1 and H2. A workover in late 2010 pulled SRU 32A-33’s existing gas lift completion, reperforated all existing zones, and installed an ESP on 3-1/2” tubing. Unfortunately, the rig had to immediately return to install a backup ESP after the original pump failed during start-up. Less than a year later, the ESP failed again and another completion was installed. A few months after that, in late-November 2011, the pump intake pressure and motor temperature suddenly and unexpectedly spiked. During a subsequent attempt to stabilize flow by cycling the well, the intake pressure gauge climbed above 3000 PSI and the well was left SI. After confirming the functionality of the downhole gauges and back-flushing the tubing to clear debris from the pump, suspicions turned to possible connectivity with a high pressure water sand encountered ~1,000’ above the G-Zone during drilling in 1991. Additional research found that the 5” liner across this zone had both a notoriously-weak and significantly de- rated flush joint connection. Repeated instances of rapid casing re-pressurization upon SI and bleed along with fluid to surface on 12/2/2011 strongly indicated communication with the high pressure sand through the pump. SRU 32A-33 was shortly thereafter killed, secured, and suspended. No remedial work was progressed to return the well to production. In 2017, the tubing was cut above the ESP and a CIBP topped with 17bbls of cement was set above the abandoned ESP. In addition, a CBL was ran demonstrating good cement behind the 7” production casing, above the surface casing shoe at 2100’. In January 2021 the well was worked over and a 3-1/2” completion was ran. Tyonek and Beluga Pool perfs have been shot with no commercial gas shows. The objective of this work is to plug back the Lower Beluga and add Upper Beluga and Sterling perforations. Well Condition - Well is currently plugged back @ 5353’MD. Operations 1. Jumper gas lift down tubing in order to push fluid away into existing perforations. E-line 1. MIRU E-Line Unit and pressure control equipment. PT lubricator to 250 psi Low / 2500 psi High. 2. RIH with GPT and vented umbrella plug. Check that fluid level is below plug set depth. 3. Set TTBP at ~4810’. 4. Dump glass beads followed by 35’ of cement. 5. WOC. Check samples. add Upper Beluga and Sterling perforations. Well Prognosis Well: SRU 32A-33 Date: 3/15/2021 6. Perforate the following sand intervals per table below with 2-3/8” HSD guns loaded at 5 SPF. Sand TOP MD BOT MD Total TOP TVD BOT TVD Est Pressure (psi) Sterling A13 2628 2646 18 2628 2646 1188 Sterling A14 2652 2667 15 2652 2667 1199 Sterling B1 2730 2763 33 2730 2763 1234 Sterling B3 2935 2948 13 2935 2948 1327 Sterling B4U 2998 3011 13 2998 3011 1355 Sterling B5 3036 3060 24 3036 3060 1372 Sterling B6U 3200 3215 15 3200 3215 1446 Sterling B8U 3391 3427 36 3391 3427 1533 Sterling B8L 3438 3466 28 3438 3466 1554 Sterling B9U 3482 3503 21 3482 3503 1574 Sterling B9L 3525 3534 9 3525 3534 1593 Upper Beluga 3534 3565 31 3534 3565 1597 UB 36-8U 3568 3586 18 3568 3586 1613 UB 36-9AX 3590 3632 42 3590 3632 1623 UB 37-0 3677 3722 45 3677 3722 1662 a) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. b) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5, 10 and 15 minute intervals. Turn well over to production. Plugback Contingency 1. If perforating an interval results in water production: we will rig up GL and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. Updated by TCS 3-10-21 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 ~2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 3 ~2,461’ 6.7’ 2.990” D&L 3-1/2” x 7” Permanent Packer 4 ~2,514’ 1’ 2.810” X Nipple 5 2,525’ 1’ 2.991 Mule Shoe B 5,390’ - - TTBP w/ 60 gals of cement (37’) 02/24/21 A 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 6 8,103’4.28’2.813”CMU Sliding Sleeve 7 8,155’ 1.13’ 2.813” X-Profile Nipple 8 8,309’ 8,309’ -- ESP Cable 9 8,339’ 8,339’ -- Dual Chemical Injection Lines 10 8,219’ – 8,341’ 122’ -5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ -- Liner Top Packer, Baker SC-1L Packer 13 10,890’ - -1.75” Teledyne Bridge Plug 14 11,319’ - -- Landing Collar 15 11,386’ 10.0’ -- FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM SPF Comments UB 50-9U 4,834’ 4,842’ 6 Perf (2/27/21) UB 50-9L 4,863’ 4,870’ 6 Perf (2/27/21) LB 51-7 5,271’ 5,282’ 6 Perf (2/25/21) TY 53-0 5,411’ 5,422’ 6 Perf (2/17/21) TY 55-5 5,629’ 5,637’ 6 Perf (2/11/21) TY 56-9 5,760’ 5,778’ 6 Perf (1/10/21), (2/10/21) TY 62-5 6,344’ 6,350’ 6 Perf (2/5/21) TY 69-0 7,071’ 7,080’ 6 Perf (2/4/21) G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) Isolated H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 6 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 10 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 12 13 14 15 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 11 7 X A Tag fill at 10,851’ 9/17/2010 8 9 8,084-8,094’ holes punched in tbg to circ kill fluid 3 5 4 2 B Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Directional Data: max hole angle = 34.0° at 11,000’ MD Updated by TCS 3-15-21 SRU 32A-33 Proposed Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 3 2,461’ 6.7’ 2.990” D&L 3-1/2” x 7” Permanent Packer 4 2,514’1’2.810”X Nipple 5 2,525’ 1’ 2.991 Mule Shoe C ~4,810’ - - TTBP w/ 60 gals of cement (37’) x/x/21 B 5,390’ - - TTBP w/ 60 gals of cement (37’) 02/24/21 A 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 6 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 7 8,155’ 1.13’ 2.813” X-Profile Nipple 8 8,309’ 8,309’ - - ESP Cable 9 8,339’ 8,339’ - - Dual Chemical Injection Lines 10 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Perforation Data Listed on Page 2 PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 6 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 10 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 12 13 14 15 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 11 7 X A Tag fill at 10,851’ 9/17/2010 8 9 3 5 4 2 B C Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Perforation Data ZONE TOP BTM SPF Comments Sterling A13 2628 2646 5 Perf (x/x/21) Sterling A14 2652 2667 5 Perf (x/x/21) Sterling B1 2730 2763 5 Perf (x/x/21) Sterling B3 2935 2948 5 Perf (x/x/21) Sterling B4U 2998 3011 5 Perf (x/x/21) Sterling B5 3036 3060 5 Perf (x/x/21) Sterling B6U 3200 3215 5 Perf (x/x/21) Sterling B8U 3391 3427 5 Perf (x/x/21) Sterling B8L 3438 3466 5 Perf (x/x/21) Sterling B9U 3482 3503 5 Perf (x/x/21) Sterling B9L 3525 3534 5 Perf (x/x/21) Upper Beluga 3534 3565 5 Perf (x/x/21) UB 36-8U 3568 3586 5 Perf (x/x/21) UB 36-9AX 3590 3632 5 Perf (x/x/21) UB 37-0 3677 3722 5 Perf (x/x/21) UB 50-9U 4,834’ 4,842’ 5 Perf (2/27/21) Isolated UB 50-9L 4,863’ 4,870’ 5 Perf (2/27/21) Isolated LB 51-7 5,271’ 5,282’ 5 Perf (2/25/21) Isolated TY 53-0 5,411’ 5,422’ 5 Perf (2/17/21) Isolated TY 55-5 5,629’ 5,637’ 5 Perf (2/11/21) Isolated TY 56-9 5,760’ 5,778’ 5, 6 Perf (1/10/21), (2/10/21) Isolated TY 62-5 6,344’ 6,350’ 5 Perf (2/5/21) Isolated TY 69-0 7,071’ 7,080’ 5 Perf (2/4/21) Isolated G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) Isolated H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated 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: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,396 feet 7,450; 10,890 feet true vertical 11,168 feet 10,851 (Fill)feet Effective Depth measured 7,450 feet 9,499 feet true vertical 7,449 feet 9,489 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" 9.2# / L-80 2,525' MD 2,525' TVD Packers and SSSV (type, measured and true vertical depth)Liner Top Packer 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: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 45' 2,555' 11,386' 0 9,499(MD) 9,489(TVD) Oil-Bbl measured true vertical Packer 5" 2-7/8" 45' 10,566' 8,700' 10,454' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field/ Tyonek & Beluga PoolsN/A measured TVD Tubing Pressure 9060 Swanson River Unit (SRU) 32A-33 N/A FEDA028399 8,701' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-014 50-133-10164-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-459 & 321-021 160 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,887' 29 11,160' 0 Representative Daily Average Production or Injection Data 2,555' 8,701' 2,187' Conductor Surface Intermediate Production 11,160psi 10,490psi Casing Structural 22" 13-3/8" 7" Length 45' 6,340psi 2,730psi Collapse 1,130psi 3,830psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,570psi Burst 10,140psi 2,554' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:44 am, Mar 17, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.16 21:12:09 -08'00' Taylor Wellman (2143) DSR-3/17/21 RBDMS HEW 3/18/2021 SFD 3/18/2021BJM 4/26/21 SFD 3/18/2021 Tyonek & Beluga Pools Rig Start Date End Date 12/31/20 2/27/21 12/31/2020 - Thursday PTSM, cont. mobe remaining eq t/pad. Prep well area, lay out felt & liner, spot base beam & rig to well center, spot rig aux eq., install berming, raise & scope mast, secure same. Work l/d pins, test void t/ 3,800 psi good, Check Well, static, install BPV, n/d tree, prep wellhead, install blanking sub, N/U BOPE, install rig floor, r/u accumulator lines. Turn rig over to night watch, install winterization to rig floor, tq. flange bolts on BOPE. cont. winterization. 01/01/2021 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 01/05/2021 - Tuesday PJSM, Blow through surface lines good, r/u McCoy tongs, check well, static,. Run 3-1/2" 9.2#, L-80 IBTM completion as per program, mule shoe, pup, x-Nipple 7" packer, GLM loaded w/dummy valve, 3-1/2" tubing. M/U hanger & landing jt, pump 2 bbls diesel for freeze protect fill annulus, land hanger, RILD pins, placing tubing tail @ 2,531'. Drop ball & rod Pressure up t/3500 psi as per rep, set packer @ 2,467'. R/U test packer & 3-1/2" x 7" annulus t/1,500psi f/30 min good. Blow down lines start prep f/rig move, suck out pits & surface eq. pull landing jt, set BPV. R/D floor, n/d BOPE, install tree & test void 250/5000 good, test tree 250/5,000 good. Cont. RD load trucks for transport t/KDU 13-5. 01/02/2021 - Saturday PTSM, Pressure up accumulator, function test BOPE good, install rig floor stairs, m/u & install test jt. finish rig winterization. Calibrated & tested gas alarms & PVT system. Blow through lines good, fill surface eq. & lines w/test fluid, shell test BOPE t/250/3,000 good. Test BOPE as per Hilcorp & AOGCC requirements, AOGCC witness waived by Jim Regg, BLM witness waived by Quinn Sawyer, tested with 3.5" TJ. R/D test jt, pull blanking sub & BPV, blow down lines, R/U handling eq. install landing jt. Back out L/D pins, pull hanger off seat @ 46k, cont. pull & l/d hanger. Cont. POOH t/4,433' stand back 2,646' 3- 1/2" tubing, Blow down & secure well for night. Night watch rig. 01/04/2021 - Monday PJSM, Service rig, c/o handling eq. P/U BHA # 1- 6 1/8" BIT, 7" scraper, Bit sub, XO = 8.29'. TIH w/ scraper t/2668' up wt 23k, dn wt 23k. POOH f/2668' l/d 3-1/2" tubing, l/d 86 jts, & scraper assy. Prep T/run completion. P/U 3-1/2" completion, m/u mule shoe, p/u x-nipple assy single joint & packer assy, had tong issues with McCoys, sent to shop for repair, stood back completion & secured well for night. Stood back completion & secured well for night. Night watch rig, ( shop repair McCoy tongs & deliver to rig). PJSM, Have skeleton crew on while waiting on weather to warm within Dragon's working parameters for rig, we did take fuel delivery, sorted YJ fishing tools, serviced air compressor, repaired leak on tongs, fueled eq. monitor temps on critical eq. Night watch rig, fuel eq. monitor temps on critical eq. 01/03/2021 - Sunday PJSM, We Have skeleton crew on while waiting on weather to warm within Dragon's working parameters for rig, Temps started trending up, call out rest of crew for 12:00, warm up skate prep backup tongs,. PJSM, Blow through surface lines & eq. good, check well static. POOH f/4,433' l/d 3-1/2" IBT kill string. L/D 142 joints & 1- mule shoe. Secure well, blow down. Night watch rig. Run 3-1/2" 9.2#, L-80 IBTM completion a /U 3-1/2" completion, m/u mule shoe, p/u x-nipple assy single joint & packer assy, had t R/U test packer & 3-1/2" x 7" annulus t/1,500psi f/30 min good. set packer @ 2,467' Rig Start Date End Date 12/31/20 2/27/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 01/10/2021 - Sunday Fill out permits and JSA. discuss job W/involved personnel. Rig up E-line. PT 250 psi low/3,000 psi high. RIH W/ 2-3/8'' x 18' HC, 6 SPF, 60 degree, tie-in CBL log. Run correlation log and send to town. Town said shift log down 28' to shoot. shifted log 28' spot and fire gun from 5,760' - 5,778' W/1,490 psi WHP. After 5 min - 1,502 psi, 10 Min - 1,505 psi, 15 min - 1,506 psi. All shots fired. Gun was dry. Small clumps of fine sand on outside of gun. OOH. Rig down E-line. Turn in permits. 02/04/2021 - Thursday AK E-line arrives at facility. PTW, PJSM, job scope. Rig up E-line. PT 250 psi low/2,500 psi high. RIH W/ 2-3/8''x 9' (5 SPF/60 degree) W/ GEO 11 gm low swell charges. Make correlation pass. Send to town. Shift log up 1' as directed. Spot and shoot Gun at 7,071'-7,080'. POOH. OOH. All shots fired. Gun was damp, but no water in bull plug. Turn well over to production. WHP: guns fired: 1,828 psi.. 5 min: 1836 psi. 10 min: 1838 psi. 15 min: 1,840 psi. Production shut well in at 1,430 psi. RIH W/ GPT to locate fluid level then monitor fluid level while production brings well back on line. found fluid initially at 6,760'. while bleeding down WHP fluid stayed ~6,760'. Also made a couple passes at perfs (7,071'-7,080') to see if we could see any in-flo, no obvious flow, well bleed down to ~150 (edit: 186 on crystal gauge) psi shut well in. POOH. OOH. lay down lubricator/ secure well for the night. E-line Turn in permits. leave location. 01/07/2021 - Thursday Petrospec coiled tubing arrive after SL pulled ball & rod. MIRU. NU BOPE on top xmas tree, spot choke skid and return tank. Close blind/shear ram and test to 250/4,000 psi. Insert 1.75" test rod and close pipe/slip ram, test to 250/4,000 psi. Test out to choke skid, valves, choke. Test accumulator system. AOGCC waived witness of BOP test by Jim Regg. Prep for N2 lift following morning. Depart location. 01/08/2021 - Friday MIRU Fox Energy N2 pump truck. MU injector to BOP's. Test stripper and lubricator to 250/4,000 psi. RIH with 1.75" coiled tubing while pumping N2. Take returns to diffuser tank with wide open choke. Tag at 7,457' ctmd. Wait on bottom for 15 minutes to get N2 above coil. POOH pumping N2. Continue to POOH monitoring fluid returns. Once fluid returns to surface stopped and just N2, close choke and POOH. Recovered 210 bbls of expected 211 bbls. Coil at surface. Trap 2000 psi on well. Fox Energy RDMO. Coil continue to RD. Coil RD Injector, BOPs, and install xmas tree cap/flange. Leave equipment on location for the night. 02/05/2021 - Friday AK E-line arrives at location. PTW, PJSM, jobscope. Stand up lubricator. PU tools. PT 250 psi/2,500 PSI. RIH W/GPT W/ 2- 3/8''x 6' (5 SPF/60 degree) W/ GEO 11 gm low swell charges. Make correlation pass. Send to town. Shift log down 2' as directed. Spot and shoot Gun at 6,344'-6,350'. While POOH make pass from 6,800 up to 6,180 saw temp influx at perfed zone. Fuid level is at 6,710'. Re-log 5,600'-5,900'. OOH. All shots fired. lay down lubricator for night. E-line possibly coming back tomorrow. Turn well over to production. Leave facility. fire gun from 5,760' - 5,778' W shoot Gun at 6,344'-6,350' shoot Gun at 7,071'-7,080'. Rig Start Date End Date 12/31/20 2/27/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 Crew arrives. PTW, PJSM, jobscope. Start equipment, begin rig up. PT 250 psi low/ 2,500 psi high. RIH W/ 2-3/8' 'x 8' HC, 6 SPF, 60 degree phase, W/ 11 gm low swell charges. Make correlation pass. Send to town. No adjustment needed. Spot and shoot (TY 55-5) 5,629'-5,637' POOH. OOH. All shots fired, gun was dry. WHP Pre shoot: 1,800 psi, Shots fired: 1,802 psi, 5 min: 1,803 psi, 10 min: 1,804 psi, 15 min: 1,804 psi. RDMO, turn in permits/JSA. Turn well over to production. 02/17/2021 - Wednesday Crew arrives at location. PTW, PJSM, Mobilize equipment to well. Rig up E-line. Pressure test 250 psi low/2,500 psi high. RIH W/ 1-11/16'' GPT to identify fluid level. FL ~5,840'. Sent fluid pass log to town. Make pass past all previous shot zones. send log to town. POOH. RIH W/ 2-3/8'' x 11' HC, 5 SPF, 60 degree phase, W/ 11 gm low swell charges. Make correlation pass. Send to town. Shift log up 4 ' Spot and shoot (TY 53-0) 5,411'-5,422'. POOH. OOH. Gun is dry. All shots fired. Fine mud hard packed on gun around perf holes . WHP Pre shots: 1,810 psi, shots fired: 1,813 psi, 5 min: 1,813 psi, 10 min: 1,813 psi, 15 min: 1,814 psi. Lay down lubricator for evening. Turn well over to production. Leave location. 02/10/2021 - Wednesday Crew arrives at location. Sign in, PTW, PJSM, job-scope. Begin rig up to well. E-line builds the perf gun for the first run. Snow removal around equipment/well head. RIH W/ 2-1/8'' strip gun loaded W/ shogun charges W/ -45,-22.5,0,22.5,45 degree phasing. Make correlation pass. Send to town. Shift log down 2' as directed. Spot and shoot at 5,760'-5,778'. Run verification pass of perfs (5,760'-5,778') POOH. While POOH. A little stuck in tubing tail (2,525'), ease into 700 pound overpull. Pull free. POOH WHP, Pre shots: 1,857 psi, Shots fired: 1,862 psi, 5 min: 1,865 psi, 10 min: 1,869 psi, 15 min: 1,872 psi. OOH W/ whole carrier / all shots fired. Lay down lubricator for the night. Turn well over to production. Turn in permits. 02/11/2021 - Thursday 02/22/2021 - Monday Crew arrive at facility. Permits, JSA, job scope. PJSM. Rig up AK E-line. PT 250 low/3,250 high. (1.5 x WHP) Make up first tool string and plug. RIH W/GPT, W/TTBP (plug). Run down to fluid level at 5,828'. Run log for fluid level. Pull up for correlation pass. Send to town. Shift log 2' down. Spot and set plug at 5,390'. POOH - WHP: 2150 psi. Crew must maintain same pressure while preforming next runs. RIH W/ 2.5'' x 20' dump bailer W/''beads'' to 5,330'. Appears the bailer dumped. POOH. Bailer failed to dump. Check fire in tools and check detonator. All check out good. Change detonator to new. Discuss plan forward with town. RIH W/ 2.5'' x 20' dump bailer W/''beads'' to 5,330'. Dump ~2' of beads. POOH. Bailer dumped. Re- rig Bailer for cement. Mix cement. Obtain samples of cement every bactch mixed. RIH W/ 2.5'' x 30' dump bailer W/cement to ~5,350'. Does not appear bailer dumped. POOH. OOH. Bailer failed to dump. Lay down tool string. Re-rig entire tool string and bailer with different tools. Pick up tools and bailer. Fighting ice issues with pump to fill bailer with cement. Mix cement. Thaw out pump. RIH W/2.5'' x 30' dump bailer W/cement to ~5,350'. Got good indication bailer dumped and weight loss. POOH. OOH. Bailer dumped. Prepare for next run of cement. RIH W/ 2.5'' x 30' dump bailer W/cement to ~5,350'. Got good indication bailer dumped and weight loss. POOH. OOH. Bailer dumped. Stage equipment for the night. Sign out, turn in permits, Leave location. shoot (TY 53-0) 5,411'-5,422' shoot at 5,760'-5,778' RIH W/2.5'' x 30' dump bailer W/cement to ~5,350'. Got good indication bailer dumped and weight loss. POOH. O shoot (TY 55-5) 5,629'-5,637' P Spot and set plug at 5,390' RIH W/ 2.5'' x 30' dump bailer W/cement to ~5,350'. Got good indication bailer dumped and weight loss. POOH. OOH. Bailer dumped. 'beads'' to 5,330'. Dump ~2' of beads. Rig Start Date End Date 12/31/20 2/27/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 32A-33 50-133-10164-01-00 191-014 02/27/2021 - Saturday Crew arrives, PTW, job scope. PJSM, Begin rig up. PT 250 psi low/ 2,500 psi high. RIH W/ 2-3/8'' x 7' HC W/ 11 gm low swell charges, 5 SPF, 60 deg phase. Make correlation pass. Send to town. Shift +2' (logs down 2') Spot and shoot 4,863'-4,870'. POOH. OOH, all shots fired. Gun was wet. WHP: pre shots: 1,589 psi, shots fired: 1,590 psi, 5min: 1,591 psi, 10 min: 1,592 psi, 15 min: 1,594 psi. RIH W/ 2-3/8'' x 8' HC W/ 11 gm low swell charges, 5 SPF, 60 deg phase. Make correlation pass. Send to town. No correction needed. Spot and shoot 4,834'-4,842'. POOH. All shots fired. Gun was dry. WHP: pre shots: 1,600 psi, shots fired: 1,602 psi, 5min: 1,603 psi, 10 min: 1,604 psi, 15 min: 1,606 psi. Rig down E-line. Mobilize equipment. Turn well over to production. 02/24/2021 - Wednesday Continue from previous day. Rebuilding dump bailer. Check fire, mix cement, prepare for next run. RIH W/ 2-1/2'' x 30' dump bailer to ~5,350'. Dump cement. POOH. OOH. Lay lubricator down and stage equipment until next day. Crew signs out, turn in permit and leave location. 02/25/2021 - Thursday Crew arrives at facility, PTW, JSA, job scope. Rig up E-line. Build/PU perf gun Pressure test 250psi L/2500psi H. RIH W/ 2- 3/8'' x 11' HC, 5 SPF, 60 degree phase, W/ 11 gm low swell charges. Tag TOC at 5,348.7' (NC). Make correlation pass. Send to town. Standby. LIB tag for closing vent on plug was 5,386' subtract 5,348.7' = 37.3'+ of cement on plug. Bleed pressure from 1,800 psi to 1,500 psi. Shift log 1' down, Spot and shoot (LB 51-7) 5,271'-5,282'. POOH WHP Pre shots: 1,507 psi, Shots fired: 1,513 psi, 5 min: 1,523 psi, 10 min: 1,529 psi, 15 min: 1,535 psi. OOH. All shots fired, Gun was damp, no standing water in bull plug, small amount of coarse sand in plug. Turn well over to production. E-line secures well head and lay down lubricator for the night. Operations monitor well, Turn in permits, Sign out/leave facility. 02/23/2021 - Tuesday Start equipment. PTW, JSA. Crew arrives at location. Discuss jobscope with involved personnel. PJSM, rig up E-line. PT 250 psi/low 3,250 psi/high. PU tools. RIH W/ bow spring centralizer W/ 2.75'' LIB. to 5,386'(not correlated). Sit down 2 x to close vent. POOH. Good impression of vent. Vent closed. Rig up bailer for cement. RIH W/ 2-1/2' 'x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Prep for next run. RIH W/ 2-1/2'' x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Slight short in wires through bailer. Rebuild dump bailer. Prep for next run. RIH W/ 2-1/2'' x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Prep for next run. RIH W/ 2-1/2'' x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Prep for next run. RIH W /2- 1/2'' x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Prep for next run. RIH W/ 2-1/2' 'x 30' dump bailer to ~5,350'. Dump cement. POOH. Mix next batch of cement. OOH. Prep for next run. Short through bailer. Rebuild bailer, Mix cement. prep for next run. RIH W/ 2-1/2'' x 30' dump bailer to ~5,350'. Fail to dump cement. POOH. OOH. Check fire in entire tool string, rebuild bailer. Mix cement. shoot (LB 51-7) 5,271'-5,282' s 5,386' subtract 5,348.7' = 37.3'+ of cement on plug. shoot 4,834'-4,842' Tag TOC at 5,348.7' (NC) p bailer to ~5,350'. Dump cement. shoot 4,863'-4,870' RIH W/ 2-1/2' 'x 30' dump bailer to ~5,350'. Dump cement. Updated by TCS 3-10-21 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 ~2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 3 ~2,461’ 6.7’ 2.990” 3-1/2” x 7” Retrievable Packer 4 ~2,514’ 1’ 2.810” X Nipple 5 2,525’ 1’ 2.991 Mule Shoe B 5,390’ - - TTBP w/ 60 gals of cement (37’) 02/24/21 A 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 6 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 7 8,155’ 1.13’ 2.813” X-Profile Nipple 8 8,309’ 8,309’ - - ESP Cable 9 8,339’ 8,339’ - - Dual Chemical Injection Lines 10 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 11 8,379’ - 4.250” - Liner top 12 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 13 10,890’ - - 1.75” Teledyne Bridge Plug 14 11,319’ - - - Landing Collar 15 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM SPF Comments UB 50-9U 4,834’ 4,842’ 6 Perf (2/27/21) UB 50-9L 4,863’ 4,870’ 6 Perf (2/27/21) LB 51-7 5,271’ 5,282’ 6 Perf (2/25/21) TY 53-0 5,411’ 5,422’ 6 Perf (2/17/21) TY 55-5 5,629’ 5,637’ 6 Perf (2/11/21) TY 56-9 5,760’ 5,778’ 6 Perf (1/10/21), (2/10/21) TY 62-5 6,344’ 6,350’ 6 Perf (2/5/21) TY 69-0 7,071’ 7,080’ 6 Perf (2/4/21) G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) Isolated H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 5,353’ MD / 5,353’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 6 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 10 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 12 13 14 15 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 11 7 X A Tag fill at 10,851’ 9/17/2010 8 9 8,084-8,094’ holes punched in tbg to circ kill fluid 3 5 4 2 B Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Directional Data: max hole angle = 34.0° at 11,000’ MD Isolated 2/22/21 Isolated 2/22/21 SFD 3/18/2021 Tyonek Gas Isolated 2/22/21 Hemlock Oil Beluga Gas ZONE TOP BTM SPF Comments UB 50-9U 4,834’4,842’6 Perf (2/27/21) UB 50-9L 4,863’4,870’6 Perf (2/27/21) LB 51-7 5,271’5,282’6 Perf (2/25/21) TY 53-0 5,411’5,422’6 Perf (2/17/21) TY 55-5 5,629’5,637’6 Perf (2/11/21) TY 56-9 5,760’5,778’6 Perf (1/10/21), (2/10/21) TY 62-5 6,344’6,350’6 Perf (2/5/21) TY 69-0 7,071’7,080’6 Perf (2/4/21) Isolated 2/22/21 Isolated 2/22/21 Isolated 2/22/21 ZONE TOP BTM SPF Comments () Isolated 2/22/21 Isolated 2/22/21 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE : 03/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD, TY53-0, FLUID LEVEL PASS 02/17/2021 Please include current contact information if different from above. Received by the AOGCC 03/08/2021 PTD: 1910140 E-Set: 34756 03/09/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE : 03/05/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD 02/04/2021 Please include current contact information if different from above. PTD: 1910140 E-Set: 34755 Received by the AOGCC 03/08/2021 03/09/2021 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: 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? Will 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): 11,396'8,050' Casing Collapse Structural Conductor Surface 1,130psi Intermediate 3,830psi Production 10,490psi Liner 11,160psi 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 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 11,168'7,450'7,449'1,944 10,890', 7,450' N/A ; N/A N/A ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 10,570psi 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 FEDA028399 191-014 50-133-10164-01-00 Swanson River Unit (SRU) 32A-33 Swanson River / Tyonek & Beluga Pools Length Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 45' 45' 9.2# / L-80 TVD Burst 2,525' 10,140psi MD 6,340psi 2,730psi2,555' 8,701' 2,555' 10,454'5" 45' 22" 13-3/8" 7"8,701' 2,555' 10,566' Perforation Depth MD (ft): 8,701' See Attached Schematic 2,187' 2-7/8" 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: January 22, 2021 11,386'1,887' 3-1/2" 11,160' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:43 pm, Jan 13, 2021 321-021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.13 12:12:54 -09'00' Taylor Wellman gls 1/27/21 DLB01/13/2021 Perforate X DSR-1/14/21 N2 10-404 C on Required? Yes 1/28/21 dts 1/27/2021 JLC 1/27/2021 RBDMS HEW 1/29/2021 Well Prognosis Well: SRU 32A-33 Date: 1/12/2021 Well Name: SRU 32A-33 API Number: 50-133-10164-01-00 Current Status: Gas Well Leg: Estimated Start Date: 1/22/2021 Rig: E-line Reg. Approval Req’d? Yes: 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 191-014 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907)-632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985)-867-0665 (C) AFE Number: Max. Expected BHP: ~ 2521 psi @ 5770’ TVD Normal hydrostatic at bottom perfs Max. Potential Surface Pressure: ~ 1944 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 32A-33 was sidetracked 1000’ due-east from SRU 32-33 in April 1991, initially targeting Hemlock oil in benches H2, H3, and H4. Shortly after first production, the watered-out H3/H4 interval was plugged back and the H1 was perforated. In early 2001, the G-Zone was first perforated and flowed commingled with H1 and H2. A workover in late 2010 pulled SRU 32A-33’s existing gas lift completion, reperforated all existing zones, and installed an ESP on 3-1/2” tubing. Unfortunately, the rig had to immediately return to install a backup ESP after the original pump failed during start-up. Less than a year later, the ESP failed again and another completion was installed. A few months after that, in late-November 2011, the pump intake pressure and motor temperature suddenly and unexpectedly spiked. During a subsequent attempt to stabilize flow by cycling the well, the intake pressure gauge climbed above 3000 PSI and the well was left SI. After confirming the functionality of the downhole gauges and back-flushing the tubing to clear debris from the pump, suspicions turned to possible connectivity with a high pressure water sand encountered ~1,000’ above the G-Zone during drilling in 1991. Additional research found that the 5” liner across this zone had both a notoriously-weak and significantly de- rated flush joint connection. Repeated instances of rapid casing re-pressurization upon SI and bleed along with fluid to surface on 12/2/2011 strongly indicated communication with the high pressure sand through the pump. SRU 32A-33 was shortly thereafter killed, secured, and suspended. No remedial work was progressed to return the well to production. In 2017, the tubing was cut above the ESP and a CIBP topped with 17bbls of cement was set above the abandoned ESP. In addition, a CBL was ran demonstrating good cement behind the 7” production casing, above the surface casing shoe at 2100’. In January 2021 the well was worked over and a 3-1/2” completion was ran. The objective of this work is to add perforations to the well in addition to the perforations approved in Sundry 320-459. Well Condition - Well is currently plugged back @ 7450’MD. - Well has been blown down with N2 and perforated from 5760’-5778’ with no gas production. - Fluid level is at 6900’. The objective of this work is to add perforations to the well in addition to the perforations approved in Sundry 320-459. Well Prognosis Well: SRU 32A-33 Date: 1/12/2021 E-line 1) MIRU E-Line Unit and pressure control equipment. PT lubricator to 250 psi Low / 2500 psi High. 2) Perforate the following sand intervals per table below with 2.5” HSD guns loaded at 6 SPF 60 deg phase: Sand MD Top MD Bottom Total Footage TVD Top TVD Bottom TY 54-5 5,500 5,520 20 5,500 5,520 TY 55-4 5,625 5,637 12 5,625 5,637 TY 62-5 6,300 6,360 60 6,300 6,360 TY 69-0 7,065 7,100 35 7,065 7,100 a) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. b) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5, 10 and 15 minute intervals. 3) Turn well over to production. Plugback Contingency 1) If perforating an interval results in water production: we will rig up N2 and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. a) Ensure Standard Nitrogen Procedure is reviewed during PJSM. Updated by TCS 1-12-21 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 1A ~2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 1B ~2,461’ 6.7’ 2.990” 3-1/2” x 7” Retrievable Packer 1C ~2,514’ 1’ 2.810” X Nipple 2 2,525’ 1’ 2.991 Mule Shoe 3 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 4 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 5 8,155’ 1.13’ 2.813” X-Profile Nipple 6 8,309’ 8,309’ - - ESP Cable 7 8,339’ 8,339’ - - Dual Chemical Injection Lines 8 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 9 8,379’ - 4.250” - Liner top 10 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 11 10,890’ - - 1.75” Teledyne Bridge Plug 12 11,319’ - - - Landing Collar 13 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM Spf Comments UB 50-6 4,660’ 4,677’ 6 Proposed (Sundry 320-459) UB 50-9U 4,833’ 4,843’ 6 Proposed (Sundry 320-459) UB 50-9L 4,863’ 4,871’ 6 Proposed (Sundry 320-459) LB 51-7 5,271’ 5,283’ 6 Proposed (Sundry 320-459) TY 53-0 5,409’ 5,422’ 6 Proposed (Sundry 320-459) TY 56-9 5,760’ 5,778’ 6 Perf (1/10/21) G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) Isolated H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 7,450’ MD / 7,449’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 4 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 8 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 10 11 12 13 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 9 5 X 3 Tag fill at 10,851’ 9/17/2010 6 7 8,084-8,094’ holes punched in tbg to circ kill fluid 1B 2 1C 1A TOC @ 7,450’ 08/09/17 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Directional Data: max hole angle = 34.0° at 11,000’ MD TY 56-9 5,760’5,778’6 ( Perf (1/10/21)------------------------------------------------------------------------------------------------------------------------------------- isolated perfs Updated by TCS 1-12-21 SRU 32A-33 Proposed Schematic Swanson River Unit Well SRU 32A-33 Completed 1/06/21 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 1A ~2,412’ 5.5’ 2.810” - 3.5” GLM (Dummy GLV Installed) 1B ~2,461’ 6.7’ 2.990” 3-1/2” x 7” Retrievable Packer 1C ~2,514’ 1’ 2.810” X Nipple 2 2,525’ 1’ 2.991 Mule Shoe 3 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 4 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 5 8,155’ 1.13’ 2.813” X-Profile Nipple 6 8,309’ 8,309’ - - ESP Cable 7 8,339’ 8,339’ - - Dual Chemical Injection Lines 8 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 9 8,379’ - 4.250” - Liner top 10 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 11 10,890’ - - 1.75” Teledyne Bridge Plug 12 11,319’ - - - Landing Collar 13 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,525’ IBT-M / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM Spf Comments UB 50-6 4,660’ 4,677’ 6 Proposed (Sundry 320-459) UB 50-9U 4,833’ 4,843’ 6 Proposed (Sundry 320-459) UB 50-9L 4,863’ 4,871’ 6 Proposed (Sundry 320-459) LB 51-7 5,271’ 5,283’ 6 Proposed (Sundry 320-459) TY 53-0 5,409’ 5,422’ 6 Proposed (Sundry 320-459) TY 55-5 5,500’ 5,520’ 6 Proposed TY 55-4 5,625’ 5,637’ 6 Proposed TY 56-9 5,760’ 5,778’ 6 Perf (1/10/21) TY 62-5 6,300’ 6,360’ 6 Proposed TY 69-0 7,065’ 7,100’ 6 Proposed G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) Isolated H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) Isolated H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) Isolated H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 7,450’ MD / 7,449’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 4 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 8 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 10 11 12 13 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 9 5 X 3 Tag fill at 10,851’ 9/17/2010 6 7 8,084-8,094’ holes punched in tbg to circ kill fluid 1B 2 1C 1A TOC @ 7,450’ 08/09/17 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Directional Data: max hole angle = 34.0° at 11,000’ MD TY 55-5 5,500’5,520’6 Proposed TY 55-4 5,625’5,637’6 Proposed TY 62-5 6,300’6,360’6 ( Proposed TY 69-0 7,065’7,100’6 Proposed 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. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 32A-33 (PTD 191-014) PERFORATING RECORD 01/10/2021 Please include current contact information if different from above. PTD: 1910140 E-Set: 34640 Received by the AOGCC 02/02/2021 Abby Bell 02/02/2021 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: 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? Will 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): 11,396'8,050' Casing Collapse Structural Conductor Surface 1,130psi Intermediate 3,830psi Production 10,490psi Liner 11,160psi 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 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 11,168'7,450'7,449'1,944 10,890', 7,450' N/A ; N/A N/A ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 10,570psi 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 FEDA028399 191-014 50-133-10164-01-00 Swanson River Unit (SRU) 32A-33 Swanson River / Tyonek & Beluga Pools Length Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 45' 45' 9.2# / L-80 TVD Burst 7,018' 10,140psi MD 6,340psi 2,730psi2,555' 8,701' 2,555' 10,454'5" 45' 22" 13-3/8" 7"8,701' 2,555' 10,566' Perforation Depth MD (ft): 8,701' See Attached Schematic 2,187' 2-7/8" 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: December 1, 2020 11,386'1,887' 3-1/2" 11,160' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:56 am, Oct 27, 2020 320-459 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.26 23:13:42 -08'00' Taylor Wellman Perforate GAS 10-404 DLB11/12/2020 * 3000 psi BOPE test for rig 401 * 4000 psi BOPE test for CTU Pull Tubingll Tubing DSR-10/27/2020 rig 401/ CTU X gls 11/12/20 X N2 Com m. 11/13/2020 dts 11/13/2020 JLC 11/13/2020 RBDMS HEW 11/13/2020 Well Prognosis Well: SRU 32A-33 Date: 10/19/2020 Well Name: SRU 32A-33 API Number: 50-133-10164-01-00 Current Status: Suspended Leg: Estimated Start Date: 12/1/2020 Rig: HAK 401 Reg. Approval Req’d? Yes: 10-403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 191-014 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907)-632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985)-867-0665 (C) AFE Number: Max. Expected BHP: ~ 2521 psi @ 5770’ TVD Normal hydrostatic at bottom perfs Max. Potential Surface Pressure: ~ 1944 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 32A-33 was sidetracked 1000’ due-east from SRU 32-33 in April 1991, initially targeting Hemlock oil in benches H2, H3, and H4. Shortly after first production, the watered-out H3/H4 interval was plugged back and the H1 was perforated. In early 2001, the G-Zone was first perforated and flowed commingled with H1 and H2. A workover in late 2010 pulled SRU 32A-33’s existing gas lift completion, reperforated all existing zones, and installed an ESP on 3-1/2” tubing. Unfortunately, the rig had to immediately return to install a backup ESP after the original pump failed during start-up. Less than a year later, the ESP failed again and another completion was installed. A few months after that, in late-November 2011, the pump intake pressure and motor temperature suddenly and unexpectedly spiked. During a subsequent attempt to stabilize flow by cycling the well, the intake pressure gauge climbed above 3000 PSI and the well was left SI. After confirming the functionality of the downhole gauges and back-flushing the tubing to clear debris from the pump, suspicions turned to possible connectivity with a high pressure water sand encountered ~1,000’ above the G-Zone during drilling in 1991. Additional research found that the 5” liner across this zone had both a notoriously-weak and significantly de- rated flush joint connection. Repeated instances of rapid casing re-pressurization upon SI and bleed along with fluid to surface on 12/2/2011 strongly indicated communication with the high pressure sand through the pump. SRU 32A-33 was shortly thereafter killed, secured, and suspended. No remedial work was progressed to return the well to production. In 2017, the tubing was cut above the ESP and a CIBP topped with 17bbls of cement was set above the abandoned ESP. In addition, a CBL was ran demonstrating good cement behind the 7” production casing, above the surface casing shoe at 2100’. The current condition of SRU 32A-33’s wellbore makes it a viable candidate for a workover targeting Tyonek, Sterling and Beluga gas sands (~2,631’ MD – 5,778’ MD). The well’s proximity to SRU 241-33, a prolific gas producer; its location high on structure; and strong, stacked gas shows in the SRU 32-33 parent well suggest a high level of success in the development of this gas opportunity. The objective of this work is to pull the 3-1/2” kill string, install a new 3-1/2” completion and perforate the 7” production casing. Well Condition - Well is currently plugged back @ 7450’MD with no open perforations. - A 3-1/2” kill string is installed down to 7018’MD. - Well has been circulated to corrosion inhibited produced water and has a dry hole tree installed. the functionality of the downhole gauges and back-flushing the tubing to clear debris from the pump, suspicions turned to possible connectivity with a high pressure water sand encountered ~1,000’ above the G-Zone during drilling in 1991. After confirming Well is currently plugged back @ 7450’MD with no open perforations. -A 3-1/2” kill string is installed down to 7018’MD. -Well has been circulated to corrosion inhibited produced water and has a dry hole tree installed. In 2017, the tubing was cut abov e the ESP and a CIBP topped with 17bbls of cement was set above the abandoned ESP. In addition, a CBL was ran demonstrating good cement behind the 7” production casing, above the surface casing shoe at 2100’. Well Prognosis Well: SRU 32A-33 Date: 10/19/2020 Procedure Rig 401: 1. MIRU 401 Work over rig. 2. Set TWC. 3. ND dry hole tree, NU BOP and test to 250 psi low & 3000 psi high, annular to 250 psi low & 2500 psi high. a) Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. b) Test rams on 3-1/2” test joint. c) Record accumulator pre-charge pressures and chart tests. d) Submit completed form 10-424 to AOGCC within 5 days of BOPE test. 4. Pull TWC. 5. Stab landing joint into hanger, pull 3-1/2” kill string & LD or rack back depending on condition. a) Kill string is 3-1/2” 9.2# L-80 IBT. 6. PU & RIH with 3-1/2” completion. 7. Land tubing in hanger to position packer at ~2500’. Run in lockdown pins. 8. Drop ball & rod and pressure up to manufacturer’s recommendation to set packer. 9. Pressure test IA to 1500 psi and chart results. 10. Set TWC. 11. ND BOPE/ NU production tree and test to 5000 psi for 30 minutes. 12. Pull TWC. 13. RDMO rig 401. Post-rig SL 1) MIRU SL. 2) Pull ball & rod. Pull RHC plug. 3) RDMO SL. Post-rig Coil 1) MIRU N2 unit, Coiled Tubing Unit and pressure control equipment. PT BOPE to 250 psi Low / 4,000 psi High. a) Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. 2) RIH with coil and blow well dry. Trap 2000 psi on tubing. 3) RDMO N2 and CTU. Post-rig E-line 1) MIRU E-Line Unit and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 2) Perforate the following sand intervals per table below: Sand TOP MD BOT MD Total TOP TVD BOT TVD Pool UB 50-6 4660’ 4677’ 17’ 4660’ 4677’ SRU Beluga UB 50-9U 4833’ 4843’ 10’ 4833’ 4843’ SRU Beluga UB 50-9L 4863’ 4871’ 8’ 4863’ 4871’ SRU Beluga LB 51-7 5271’ 5283’ 12’ 5271’ 5283’ SRU Beluga TY 53-0 5409’ 5422’ 13’ 5409’ 5422’ SRU Tyonek TY 56-9 5759’ 5778’ 19’ 5759’ 5778’ SRU Tyonek MIT-IA 1500 psi 30 min (test casing to `1500 psi before pulling kill string.. 15 min chart ) CBL on 7" indicates TOC at 2100 ft. Spotty cement from 2100 to 4000 ft MD. Good to avg bond below 4000 ft. gls 11/12/20 N2 displace with CTU Review Nitrogen SOP with all onsite personnel before work commences. UB 50-6 4660’ 4677’ 17’4660’4677’SRU Beluga UB 50-9U 4833’ 4843’ 10’4833’4843’SRU Beluga UB 50-9L 4863’ 4871’ 8’4863’4871’SRU Beluga LB 51-7 5271’ 5283’ 12’5271’5283’SRU Beluga TY 53-0 5409’ 5422’ 13’5409’5422’SRU Tyonek TY 56-9 5759’ 5778’ 19’5759’5778’SRU Tyonek ) Well Prognosis Well: SRU 32A-33 Date: 10/19/2020 a) Trap 1500 psi on tubing for the initial TY 56-9 perforations. b) If perforating an interval results in water production: we will rig up N2 and depress fluid into the perforations, set a through-tubing plug and dump bail 35’ of cement before moving uphole. c) Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to Geologist (Jeff Nelson) and Reservoir Engineer (Meredyth Richards) for confirmation. d) Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run at 5, 10 and 15 minute intervals. 3) Turn well over to production. Updated by DMA 09-18-20 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 9/06/11 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 7,018’ 1’ 2.991 4.25 Mule Shoe 3 7,866’ 1’ - 6.276” CIBP w/ 17bbls of cement (416’) 08/09/17 4 8,103’ 4.28’ 2.813” 4.290” CMU Sliding Sleeve 5 8,155’ 1.13’ 2.813” 4.520” X-Profile Nipple 6 8,309’ 8,309’ - - ESP Cable 7 8,339’ 8,339’ - - Dual Chemical Injection Lines 8 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 9 8,379’ - 4.250” - Liner top 10 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 11 10,890’ - - 1.75” Teledyne Bridge Plug 12 11,319’ - - - Landing Collar 13 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 7,018 IBT / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM Spf Comments G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 7,450’ MD / 7,449’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 4 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 8 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 10 11 12 13 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 9 5 X 3 2 Tag fill at 10,851’ 9/17/2010 6 7 8,084-8,094’ holes punched in tbg to circ kill fluid Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. TOC @ 7,450’ 08/09/17 Directional Data: max hole angle = 34.0° at 11,000’ MD 7" CBL indicates TOC at 2100 ft spotty bond from 2100-4000 ft gls 11/12/20 Updated by TCS 10-21-20 SRU 32A-33 Proposed Schematic Swanson River Unit Well SRU 32A-33 Completed 9/06/11 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 1A ~2,500’ 1’ 2.990” 3-1/2” x 7” Retrievable Packer 1B ~2,510’ 1’ 2.810” X Nipple 2 ~2,520’ 1’ 2.991 Mule Shoe 3 7,866’ 1’ - CIBP w/ 17bbls of cement (416’) 08/09/17 4 8,103’ 4.28’ 2.813” CMU Sliding Sleeve 5 8,155’ 1.13’ 2.813” X-Profile Nipple 6 8,309’ 8,309’ - - ESP Cable 7 8,339’ 8,339’ - - Dual Chemical Injection Lines 8 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 9 8,379’ - 4.250” - Liner top 10 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 11 10,890’ - - 1.75” Teledyne Bridge Plug 12 11,319’ - - - Landing Collar 13 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 2,520’ IBT / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM Spf Comments UB 50-6 4,660’ 4,677’ 6 UB 50-9U 4,833’ 4,843’ 6 UB 50-9L 4,863’ 4,871’ 6 LB 51-7 5,271’ 5,283’ 6 TY 53-0 5,409’ 5,422’ 6 TY 56-9 5,759’ 5,778’ 6 G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 7,450’ MD / 7,449’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 4 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 8 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 10 11 12 13 7” TOC 2,100’ (CBL) 5” TOC 8,355’ (CBL) 9 5 X 3 Tag fill at 10,851’ 9/17/2010 6 7 8,084-8,094’ holes punched in tbg to circ kill fluid 1A 2 1B TOC @ 7,450’ 08/09/17 Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Directional Data: max hole angle = 34.0° at 11,000’ MD Coiled Tubing Services Pressure Category 1 BOP Configuration (0-3,500 psi) Client: Hilcorp Date: April 3rd, 2017 Drawn: Chad Barrett Revision: 0 Well Category: CAT I 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip Wellhead 4-1/16" 10K Conventional Stripper 4-1/16" 10K x Wellhead Adapter Flange 5K CO62 x 4-1/16" 10K Flange 5K CO62 Lubricator 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manual 2x2 Valve 2: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manual 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 21 3 4 WH PSI 2" 1502 x 2-1/16 10K Flanged Valve (Manual) 2-1/16 10K x 2-1/16 10K Flanged Valve (Manual) Kill Port Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs Swanson River Field SRU 32A-33 10/20/2020 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. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well SRU 32A-33 (PTD 191-014)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval: Taylor WellmanAsset Team Operations Manager DatePrepared: Todd SidotiFirst Call Operations Engineer Date 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,396 feet 7,866; 10,890 feet true vertical 11,165 feet NA feet Effective Depth measured 7,450 feet 9,499 feet true vertical 7,449 feet 9,489 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" 9.2# / L-80 7,018' MD 7,018' TVD Packers and SSSV (type, measured and true vertical depth)Liner Top Pkr; NA 9,499' MD 9,489' TVD NA; NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 45' 2,555' 11,386' 0 Oil-Bbl measured true vertical Packer 5" 2-7/8" 45' 10,566' 8,700' 10,454' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Hemlock OilN/A measured TVD Tubing Pressure 00 Swanson River Unit (SRU) 32A-33 N/A FEDA028399 8,701' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-094 50-133-10164-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,887' 0 11,160' 0 Representative Daily Average Production or Injection Data 2,555' 8,701' 2,187' Conductor Surface Intermediate Liner 11,160psi 10,490psi Casing Structural 22" 13-3/8" 7" Length 45' 6,340psi 2,730psi Collapse 1,130psi 3,830psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,570psi Burst 10,140psi 2,554' t Fra O 6. A G L PG , R n Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:27 am, Sep 28, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 16:46:09 -08'00' Taylor Wellmangls 10/21/20 RBDMS HEW 10/26/2020 Suspended Well Inspectionn DSR-9/28/2020 SFD 9/29/2020 191-014 SFD 9/29/2020 SUSPP KEN June 2020 Suspended Well Inspection Data Well: SRU 32A-33 Surface Location: 1990’ FNL, 2110’ FEL, Sec. 33, T8N, R9W, SM Permit to Drill: 191-094 API: 50-133-10164-01-00 AOGCC Inspection Date: 09/04/20 AOGCC Inspector: Lou Laubenstein Hilcorp Representative: Jake Paulk Size Pressure (psi) Tubing 2-7/8” 0 Casing 7” 0 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore Updated by DMA 09-18-20 SRU 32A-33 Schematic Swanson River Unit Well SRU 32A-33 Completed 9/06/11 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3’ 0.62’ 2.990” 6.998” Tubing Hanger, 3-1/2” 2 7,018’ 1’ 2.991 4.25 Mule Shoe 3 7,866’ 1’ - 6.276” CIBP w/ 17bbls of cement (416’) 08/09/17 4 8,103’ 4.28’ 2.813” 4.290” CMU Sliding Sleeve 5 8,155’ 1.13’ 2.813” 4.520” X-Profile Nipple 6 8,309’ 8,309’ - - ESP Cable 7 8,339’ 8,339’ - - Dual Chemical Injection Lines 8 8,219’ – 8,341’ 122’ - 5.625”/5.130” Assembly: ESP, 562 series Motors and 513 series Pumps; Intake at 8,288’ 9 8,379’ - 4.250” - Liner top 10 9,499’ 4.33’ - - Liner Top Packer, Baker SC-1L Packer 11 10,890’ - - 1.75” Teledyne Bridge Plug 12 11,319’ - - - Landing Collar 13 11,386’ 10.0’ - - FISH: 10’ BHC/AC logging tool Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22” Structural - Surface 45’ - Cemented 13-3/8” Surface 54.5#, J-55 Surface 1,023’ 8RD / 12.615” 600 sxs 116# (stage 1), 600 sxs 116# (stage 2), 64 sxs 116# (top job) DV Collar 1,023’ 1,025’ 54.5#, J-55 1,025’ 2,555’ 7” Intermediate 29#, N-80 Surface 364’ BTC / 6.184” 650sxs 116# (stage 1), 750sxs 116# (stage 2) 26#, N-80 364’ 1,282’ BTC / 6.276” 23#, N-80 1,282’ 4,687’ BTC / 6.366” 26#, N-80 4,687’ 6,225’ BTC / 6.276” 29#, N-80 6,225’ 7,916’ BTC / 6.184” 26#, P-110 7,916’ 8,036’ 8RD / 6.276” DV Collar 8,036’ 8,038’ 8RD / 6.276” 26#, P-110 8,038’ 8,701’ 8RD / 6.276” 5” Liner 18#, N-80 8,379’ 10,566’ FL4S / 4.276” 70 bbl 15.6 ppg 2-7/8” Liner 6.5#, N-80 9,499’ 11,386’ 8RD-Mod / 2.441” 18 bbl 15.8 ppg Tubing 3-1/2” Prod 9.2#, L-80 Surface 7,018 IBT / 2.992” Cplg OD = 4.250” Perforation Data ZONE TOP BTM Spf Comments G 10,698’ 10,724’ 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) H-1 10,800’ 10,820’ 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) H-2 10,835’ 10,854’ 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835’ – 10,849’) H-3, H-4 10,900’ 10,912’ 1 Perf (4/23/91) Isolated PBTD = 7,450’ MD / 7,449’ TVD TD =11,396’ MD / 11,165’ TVD 13-3/8” @ 2,555’ 4 KB-THF: 26.3’ KB 5” @ 10,566’ 7” window at 8,701’ H-3/H-4 22” @ 45’ H-2 2-7/8” @ 11,386’ TOL at 9,499’ 8 DV Collar @ 1,023’ DV Collar @ 8,036’ RKB: 198.3’ KB / GL: 172’ AMSL TOL at 8,379’ 1 H-1 G 10 11 12 13 Calc TOC 6,175’ CBL TOC 8,355’ 9 5 X 3 2 Tag fill at 10,851’ 9/17/2010 6 7 8,084-8,094’ holes punched in tbg to circ kill fluid Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. TOC @ 7,450’ 08/09/17 Directional Data: max hole angle = 34.0° at 11,000’ MD ' Y ' QQ BY Q Q Q Q Q ' ¶ ' Y ' ' ' * ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! !! ! ! ! Q ' ' ' ' B Y '¶ Q P QY Q QQ ' ¶ ' '' ' * ' Y YSRU 32A-33 S008N009W S007N009W Sec. SWANSON RIVER FIELD SCU_13-34 SRU_24-33 SCU_33-33 SRU_314-27 SRU_314-27PB2 SRU_34-28 SRU_21-33WD SRU_32-33 SRU_32A-33 SCU_34-33 SRU_41-33 SCU_343-33 SRU_21A-34 SCU_44-33 SCU_43A-33 SRU_14B-27 SCU_44B-33 SRU_241-33 SCU_14-34SCU_34-33SRU_24-33SRU_314-27PB2SCU_24-34SCU_33-33SRU_14-33SRU_14A-33SCU_343-33SCU_44-33 SRU_32A-33 SCU_43A-33SRU_211-33 SRU_14B-27SCU_44B-33 S C U _ 3 4 4 - 3 3 SRU_13-27SCU_13-34 SRU_241-33 SCU 14-34 Pad SCU 33-33 Pad SCU 34-33 Pad SCU 43-33 Pad SRU 12-34 Pad SRU 21-33 Pad SRU 23-33 Pad SRU 32-33 Pad SRU 34-28 Pad SRU 41-33 Pad Sec. 27 Sec. 28 Sec. 34 Sec. 33 0 410 820 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 SWANSON RIVER SRU 32A-33 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol'Other*Gas'Oil¶AOil B Dry Q P&A¶P&A OilPSHUT-IN Y Suspended Suspended Well—InspectionReview RoDJrf |nspectNo: susL0L200908105838 Date inspected: 9/4/2020 ' Inspector: LouLau6enstein TypeofInspection Well Name: SVVANBON R|V UNIT 32A'33 ' Permit Number: Number 1910140 - Suspension Approval: Sundry ' # 317'371 ' � Suspension Date: 8/10/2017 LncatiumVehhed7 W |fVerified, Flow? GPS Offshore? El Subsequent Date ADG[ZNotified: 8/25/2820 Operator: Hi|corpAlaska, LLC Operator Rep: Dunie|Pau|k Wellbore D|a�ramAvail?Photos Taken? Well Pressures (psi): TubinEl�: O Fluid in Cellar? |A� � O ' � � BPV|nstaUed? [� OA� 0 VRPiug(u)installed? F� Wellhead Condition The wellhead was in good condition and free from any leaks or othervisable issues. . of Cellar The cellar was in good condition, some water was visable but was clean and without contamination. ' Surrounding Surface Condition The pad surrounding the wellhead was free of any debis or signs of contarmation. Comments � Supervisor Comments Photos (3) attached ^, Monday, October l2'2020 M M a N M r_ D i E C O C 3 N O T' O 00 M 00 LO Q 00 O O O N J O J U) U O Q U) C ,. O U) C O m J K U b o � O ca N Q.. X U O b • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended El 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q ' Exploratory ❑ GINJ ❑ WINJ ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska,LLC Aband.: 8/10/2017 • 191-014/317-311 &317-371 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 3/3/1991 • 50-133-10164-01 • 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 1990'FNL,2110'FEL,Sec.33,T8N, R9W, SM 4 4/8/1991 Swanson River Unit(SRU)32A-33. Top of Productive Interval: 9. Ref Elevations: KB: 198.3' 17. Field/Pool(s): N/A GL: 172' BF: Swanson River/Hemlock Oil - Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1990'FNL, 1133'FEL,Sec.33,T8N, R9W,SM 7,450'MD/7,449'TVD FEDA028399 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 345558.7 • y- 2464371.9 Zone- 4 . 11,396'MD/11,165'TVD• N/A TPI: x- N/A y- N/A Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 346604.8 y- 2464349.6 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes U (attached) No Q 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A RECEIVED AUG 232017 CC 23. CASING, LINER AND CEMENTING RECORD AO v WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 24.Open to production or injection? Yes ❑ No ❑✓ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MDITVD) Size and Number; Date Perfd):p3-1/2" 7,018' 7,866'MD/7,865'TVD SCANNED NOV 2 12017 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0. Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �O Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINIAL only �re7f:/7./7 RBDMS �v AUG 1 5 2017 �g ,.� • • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q . Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary&Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson(777-8405) Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCa.hilcoro.com Authorized / �/f// Contact Phone: 777-8420 Signature: �IJ Date: SA Z 3/(J INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 32A-33 Moncla 401 50-133-10164-01 191-014 7/31/17 8/10/17 07/31/2017-Monday Held PJSM and discussed daily activities to be preformed. Removed flowlines and barriers around wellhead. Off-loaded rig equipment. Leveled and graded containment area. Laid felt and containment. Spotted beam and Moncla 401. Raised derrick and anchored guidelines. Spotted associated rig equipment. Sealed in containment. Cont w/ RU to-do list. Weighted dn kill mud from 12.3 to 11.9. RU communication tower and hooked up dog house. (Rig number 283-2505). SDFN. 08/01/2017-Tuesday Held PJSM and discussed daily activities.SITP 0 psi, SICP 800 psi. MU circulating lines to tbg and 7" production csg. Lined up manifold to pump down csg and take returns up tbg. Rolled over pump and observed pressure build from 800 psi to 1,800 psi. SD pump and bleed to 0 psi. Lined up manifold to pump dn pumd, dn tbg and return up csg. Rolled pump over and broke circulation after 2 bbls pumped. Circulated 350 bbls of 11.9 ppg kill mud. With returns at 11.9 at surface SD pump. Monitored well static. Haul well returns to G&I. Set the BPV and ND the Production Tree. Inspected lift treads, penetrator and hanger. Installed blanking sub with left handed 2-7/8" Acme treads. NU 13-5/8" 5M BOP Stack. 7-1/16" x 13-5/8" adaptor spool, mud cross, double gate 2-3/8" x 3-1/2" flex pipe rams and annular preventer. MU hydraulic accumulator lines to BOP stack. MU Kill/ck lines. Chained the BOP's back to the rig beam. RU floor, handrails and stairway. 08/02/2017=Wednesday Held PJSM and discussed daily activities. PU BOP test equipment. Flooded and circulated manifolds and BOP stack with FW.AOGCC waived witness per Jim Regg. MU 2-7/8" test jt with TIW and !BOP. Shell Tested BOP's 250-3,000psi. With shell test good, performed the BOP test per AOGCC Regs as follows: Annular 250-3,000psi, Rams 250-3,000psi,Valves 250- 3,000psi, Gas Detection and Accumulator Drawdown Test. 1 F/P Annular failed on high test. Cycled and retested good. RD Test equipment. Pulled the BPV and check for flow. Well static. PU/MU 3-1/2" landing jt. While preparing to MU 3-1/2" handling tool the tbg started flowing. BO/LD landing jt and SI the blinds. Opened well to tank and monitored flow. Pit gain over 1hr was 1 bbl. Cut and slip 160' of drill line. Circulated 290 bbls of 11.7 mud with returns from 11.3 to 11.7 ppg mug. SD pump monitored well-csg static, tbg was on a light flow.Total pit gain was .667 bbls. SI well and installed gauges to read SITP and SICP. SDFN. 08/03/2017-Thursday Held PJSM. SITP 0 psi, SICP 175 bbls. Calculated kill mud at 12.1 ppg. Circulated well with present kill fluid while preparing to build new kill mud. Offloaded MI 100 bbl mixing plant and mud products.Spotted tank and hooked up power and circulating lines. Emptied 70 bbls of 11.7 mud from 400 bbl upright tank. Mixed 350 bbbls of 12.1 heavy kill mud and pumped to the 400 bbl upright. Started pumping 12.1 kill mud down tbg returning up csg at 3 BPM. Circulated 290 bbls and 12.1 ppg returns to pit. SD pump. Monitored well slight flow. Hauled off 11.7 ppg from pit and stored in the Johnson tank. Circulated 50 bbls down tbg returns up csg. SD pump. SI overnight. SDFN. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 32A-33 Moncla 401 50-133-10164-01 191-014 7/31/17 8/10/17 Daily Operations: 08/04/2017 - Friday Held PJSM and discussed daily activities. SITP 350psi. Blend off to pit and monitored well-flowing. Calculated new kill weight mud. Cleaned rig pit. Started hauling kill mud from Johnson tank to KGF G&I. New kill weight mud 13.1 ppg. Built kill weight mud in 60 bbl batch and circulated around down tbg up the csg. With 13.1 ppg around SD pump. Monitored well from 1hr to tank-csg static tbg-static. Cont hauling mud from Johnson tank. Set TWC and tested blind rams 250- 3,000psi, charted for 5mins, good test. Pulled TWC and MU 3-1/2" landing jt. BOLDS, latched landing jt and PU on completion string to 120K w no movement. Cont pulling into string to 156K no movement. Slacked off continued working string with no monument. Slacked off and landed hanger. Closed pipe rams and lined up to bullhead down csg. Pumped away 4 bbls and pressure built to 1,800psi. Monitored w/slow leak off. Cont trying to bullhead with no luck. Opened pipe rams and PU on completion string, pulled 156K no movement. Slacked off to hanger. PU and measured pipe stretch, calculation show tbg stuck at 8,300'. Secured well. SDFN. 08/05/2017-Saturday Held PJSM and discussed daily activities. SITP-Opsi. SICP-Opsi. MIRU Pollard EL, Waited on EL part to arrive from town. elf Cleaned and vac out Johnson tank. Cleaned and cleared work areas. Finished RU EL. PU 2K on tbg string and set in slips. Lb, RIH w/3-1/2"jet cutter and set down @ 8,107'. Couldn't work thru. Logged up and cut tbg at 8,050'. POOH. PU 1' on tbg string and set in slips. RIH w/same to 8,050' and cut. POOH. RD EL. PU on pipe to 156K no movement. Slacked off to 130K and set slips, closed bag. RU circulating lines and circulated 70bbls the long way, SD pump. Opened bag and PU to 140K on tbg. Worked string and move up hole 4', cont working string w/ no movement. PU on tbg to 130K and set slips. Closed bag and rev cir 70 bbls. SD pump opened bag, PU on tbg and worked up hole at 100K-140K and moved tbg 8'. With hanger at rig floor set in slips. Cut cable and control lines, BO/LD the tbg hanger. Secured cable and control lines to tbg. Slacked off to neutral weight and closed Pipe rams. SDFN. 08/06/2017 -Sunday Held PJSM and discussed daily activities. SITP Opsi, SICP Opsi. Opened well PU on tbg at 130K (40K over) tbg moved up hole. Closed pipe rams and rev circulated 75bbls at 1.5bpm/1,200psi. SD pump. Opened well and PU on tbg free 83K string weight. Installed 3-1/2" wiper rubber on tongs. L/D 3 3-1/2" IBT pup joints, pull stand and thread cable to spoolers,TOH standing back 3-1/2" IBT completion, Filling hole every 10 stands. Pressure washed cable coming out of hole. After 78 stands OOH, changed out esp cable spool. Continued SOOH w/ 128 stands 1 single and 1 cut jt. Cannon clamps and ESP cable intact. Filled hole and SI well. SDFN. 08/07/2017 - Monday Held PJSM and discussed daily activities. SICP Opsi. Cleaned pits and work areas, MIRU Pollard EL Unit. RIH w/CBL tool to 8,000'. Logged up to 5,000'. POOH. RDMO EL. Sent log to town. Continued cleaning work areas, back hauled Summit equip back to Kenai. PU/MU 7" CIBP and setting tool, TIH w/same on 30 stands of 3-1/2" IBT 9.3#tbg. Set in slips secured well and SDFN. • O • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 32A-33 Moncla 401 50-133-10164-01 191-014 7/31/17 8/10/17 Daily Operations: 08/08/2017-Tuesday Held PJSM and discussed daily activities. SICP Opsi, SITP Opsi. Opened well and continued TIH w/7" CIBP to 7,900'. Attempted to set plug several times with no success. Set pipe in slips and reversed circulated 20bbls. SD pump. Made several more attempts to set plug no luck. PU 1 jt and worked pipe and set the CIBP @ 7,866' KB. Sheared off plug, PU and tagged plug with 15K down. PU 10' and set pipe in slips. Circulated BU. MIRU SLB cementing unit. PT to 3,000psi, good test. Mixed 17bbls of class G 15.8 ppg cement. Pumped 10bbls spacer of FW, 17 bbls of 15.8 ppg cement and 10 bbl FW spacer. Displace cement with 58bbls of 13.1 mud. SD pump. RDMO SLB Cement Unit. TOH slow with 20 stands of 3-1/2". Closed pipe rams MU circulating hoses and reversed circulated BU to rig tank and returned 3 bbls of 15.8 cement. SD pump. Cont TOH standing back 3-1/2" tbg string. Cont TOH standing back 3-1/2" tbg string to surface, LD setting tool. Secured well and SDFN. 08/09/2017-Wednesday Held PJSM, discussed daily ops. SICP Opsi, opened well PU/MU 3-1/2" pup cut with mule shoe on bottom and TIH.Tagged TOC @ 7,450'. Set do 10K cement hard. Calculated 416' of cement of top CIBP @ 7,866'. L/D 1 jt. MU circulating lines and reversed circulated 260 bbls of PW and displaced 260 bbls of 13.1 mud. Cont circulating until returns where clean. SD pump. Closed TIW, and pressured up on IA to 2,000psi, charted for 30mins,good test. Chart is in the rig file. L/D circulating lines. TOH and LD 24 jts of 3-1/2" IBT tbg. PU/MU tbg hanger w/BPV, MU landing jt and landed 3-1/2" kill string at 7,000'. RILDS. Total of 127 jts of 3-1/2" 9.2# L-80 IBT and 3-1/2" mule shoe in the hole. Kill string tally is in the well file. Cleaned and cleared rig floor. SDFN. 08/10/2017 -Thursday Held PJSM and discussed daily activities. Continued cleaning rig and associated equipment. RD handrails, stairs and rig floor. Disconnected accumulator lines and kill/choke lines. ND 13-5/8" BOP stack, tested void, NU dry hole tree. Pulled BPV. RDMO Moncla 401 and associated equipment. Hauled accumulator, pit, generator, mud pump and choke house to Moncla's yard. Moved rig and beam to SCU 12A-04. Cleaned and removed containment. 0 7�TT 1110SRUV 32A-33 Swanson River Well SRU 32A-33 nit Completed 9/06/11 Schematic Hiicor Alaska LLC RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB Casing and Tubing Detail Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ I, 22" Structural Surface 45' Cemented as' ....04. 54.5#,J-55 Surface 1,023' 600 sxs 116#(stage 1), 13-3/8" Surface DV Collar 1,023' 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DV collar I 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) @1,023' 29#, N-80 Surface 364' BTC/6.184" _26#, N-80 364' 1,282' BTC/6.276" m 23#, N-80 1,282' 4,687' BTC/6.366" 13-3/8" 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1), @2,555' 7" 29#, N-80 6,225' 7,916' BTC/6.184" 750sxs 116#(stage 2) 26#, P-110 7,916' 8,036' 8D- "E 8RD/6.276" 0 DV Collar 8,036' 8,038' 8RD/6.276" 26#, P-110 8,038' 8,701' 8RD/6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg Calc TOC N. 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RMod/2.441" 18 bbl 15.8 ppg 6,175' Tubing tA 2 3-1/2" Prod 9.2#, L-80 Surface 6,991' IBT/2.992" Cplg OD=4.250" iTOC o Production String Jewelry Detail • r 4 08/09/17 # Depth(RKB) Length ID OD Item 3 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger,3-1/2" 2 7,018' / 1' 2.991 4.25 Mule Shoe 3 7,866' V 27.30' 6.276" CIBP w/17bbls of cement(416')08/09/17 @8036'DV , 4 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve @ 8,036' 5 8 155' 1.13' 2.813" 4.520" X-Profile Nipple ao e e ;; a,osa-e,osa� ,. holes 6 8,309' 8,309' - - ESP Cable d `w.,, �,,.r punched in 7 8,339' 8,339' - - Dual Chemical Injection Lines C $,tbg to circ kill q, tr fluid Assembly: ESP,562 series Motors and CBL roc 71 '7,:, 8 8,219'— 8,341' 122' - 5.625"/5.130" s 355 is # i ' 513 series Pumps; Intake at 8,288' �' _ _ TOL at 9 9 8,379' - 4.250" - Liner top 8,379' �� . - 10 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 7"window at . 1{. - 11 10,890' - - 1.75" Teledyne Bridge Plug 8,701' t 12 11,319' - - - Landing Collar 13 11,386' 10.0' - - FISH: 10'BHC/AC logging tool t # . • fi I Perforation Data TOL at ' ZONE TOP BTM Spf Comments 9,499' M (:'1,, G 10,698' 10,724' 4,4,4,6 Perf(11/12/03), (3/27/01), (2/25/01), (9/17/10) �,�. 10 H-1 10,800' 10,820' 4,4,6 Perf(12/05/95), (5/10/91), (9/17/10) l-1. Perf(12/05/95), (4/28/91) H-2 10,835' 10,854' 4,4,6 . (9/17/10: 10,835'—10,849') 5"@ 10,566' t' ? H-3, H-4 10,900' 10,912' 1 Perf(4/23/91) Isolated a. to Expected casing leak in 5"liner at ] , /� ' Sc ?.� �\ FL4S connection. 1/`,A�,/,�/,� G 13ppg mud to kill ;.}, well. H-1 .fe /liC4' 7"-------.---' H-1 H-2 y Tag fill at 10,851' _ 9/17/2010 i` 11 H-3/H-4 111 12 2-7/8"@ 11,386' pp_.'. 13 Tn=11 VIA' PRTf=11 319' Directional Data: max hole angle=34.0°at 11,000'MD Updated by DMA 08-17-17 • • Schwartz, Guy L (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday,August 07, 2017 9:44 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer;Wade Hudgens - (C) Subject: SRU 32A-33, PTD 191-014, Sundry# 317-311 Guy, We were able to kill SRU 32A-33 with 13ppg mud on Friday, but we were unable to pull the pump. So we wanted to start the contingency for plugback work. We made 2 cuts at 8,050ft, (1 for pipe and 1 for cable)on Saturday, on Sunday after working the pipe we were able to recover all the pipe and cable, however I do not think we will be able to recover the pump or the rest of the fish._ (The - pump has an OD of 5.625" inside 6.184" Pipe,so we cannot get washover pipe over it). We would like to plug back the well at this point and set it up for a future sidetrack. We haven't been able to get any injection rate into the formation and I do not think that a cement retainer is going to work for this well and therefore would like approval to set a CIBP and cement on top instead of a cement retainer. If you are okay with this idea, I will write up a new procedure and submit a 10-403 for plug for redrill. Feel free to call or send me an email with your thoughts, Thanks Chad Helgeson Operations Manager Kenai Asset Team Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 1 • • OF Tit, Alaska Oil and Gas �`'\1THE STATE �' ��\1//ys ofATT cc Conservation Commission :,-,� - - 333 West Seventh Avenue Anchorage, Alaska 99501-3572 �pR GOVERNOR BILL WALKER Main: 907.279.1433 Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNEDAn ?7 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Swanson River Field,Hemlock Oil Pool,SRU 32A-33 Permit to Drill Number: 191-014 Sundry Number: 317-371 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Commissioner DATED this 17 d y of August, 2017. RBDMS tiN. AUG 2 3 2017 • ‘ VigD STATE OF ALASKA ��`' J 01 ALASKA OIL AND GAS CONSERVATION COMMISSION -,,?.//q. 1 APPLICATION FOR SUNDRY APPROVALS liji , s 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 121" /,' ,i7Perforate ❑ Other Stimulate ❑ Pull Tubing IDChange Approved Program Q Plug for Redrill' `� Perforate New Pool ElRe-enterSusp Well 0 Alter Casing El Other: El2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ • 191-014 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10164-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B ❑ Swanson River Unit(SRU)32A-33 • Will planned perforations require a spacing exception? Yes D No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028399 • Swanson River/Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,396' • 11,168' • 10,851' 10,701' 1,488 psi 10,890' 8,050(fish) Casing Length Size MD TVD Burst Collapse Structural 45' 22" 45' 45' Conductor Surface 2,555' 13-3/8" 2,555' 2,554' 2,730psi 1,13opsi Intermediate 8,701' 7" 8,701' 8,700' 6,340psi 3,830P si Liner 2,187' 5" 10,566' 10,454' 10,140psi 10,490psi Liner 1,887' 2-7/8" 11,386' 11,160' 10,570psi 11,160psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80 8,219' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Liner Top Packer;N/A 9,499'MD/9,489'TVD;N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ID Exploratory 0 Stratigraphic 0 Development Q • Service 0 14. Estimated Date for 15.Well Status after proposed work: August 7,2017 Commencing Operations: OIL ❑ WINJ 0 WDSPL 0 Suspended ❑✓ • 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 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: Chad Helgeson 777-8405 Contact Name: Chad Helgeson , Authorized Title: Operations Manager Contact Email: chelaesonehilcorp.com Contact Phone: 777-8405 Authorized Signature: 4/."117/ Date: 3/7/17 USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31-7-371 Plug Integrity r BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: e- /-f/. /'1 / kc—r 'p 1bv—€ Zei 44-c 2---c-: II LAt Wel( ..K.-..? J;11", irA-i e�i,r r..i GO i 414....4.:k. 1 06.-4-1,- , 4C y. //0(e) Post Initial Injection MIT Req'd? Yes No CD Spacing Exception Required? Yes ❑ No Subsequent Form Required: 6-7_ RBDMS L t- AUG 1 3 2017 • Cje APPROVED BY Approved by: iti P l COMMISSIONER THE COMMISSION Date: 8— /7 -4 Submit Form and "to}m 10-403 Revised 4/2017 RritaipNiA alid for 12 months from the date of approval. Aor ttac ments in Du licate • • Well Prognosis Rev1 Well: SRU 32A-33 Hilcorp Alaska,LU Date:8/7/2017 Well Name: SRU 32A-33 API Number: 50-133-10164-01 Current Status: SI Oil Producer Leg: N/A Estimated Start Date: August 7, 2017 Rig: Moncla 401 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: July 10th, 2017 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 191-014 First Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP: 6,219 psi @ 9,200' (9,196' TVD) Calc. from 13ppg mud used to kill well (9,200' MD). Max. Predicted Surface Pressure: 1,488 psi Calc. using a 0.433 psi/ft fluid gradient Brief Well Summary The ESP in the SRU 32A-33 was operating in November, 2011 when it observed a relatively sudden pump intake • pressure spike from 965 psi to over 3,000 psi in a 24 hour period. Diagnostics ran over an 11 day period concluded that the most likely cause was that the FL4S connection of the 5" liner, which was across a known high pressure water interval, had most likely failed. Chevron punched holes in the production tubing and circulated kill weight fluid to balance the well. On Sundry 317-311 it was attempted to pull the ESP and isolate the high pressure water source, however the pump was stuck and would not move. The tubing was cut on 8/5/17 to remove it from the wellbore and the tubing was pulled on 8/6/17. The_purose of this new_procedure is to abandon the open perfs without/ isolating the perfs at the penetrations or within the regulatory required distance to the perfs. The pump has a 5.625" OD inside 7" pipe with a 6.184" ID. There is not enough clearance to washover the pump and recover it. This work scope will set a CIBP at approximately +/- 7,900ft and set (17 bbls) 457 ft of cement on top of the plug. This work will require a variance from BLM for 43CFR3160.III.G.2.i of setting plug within 50ft of open perforations. A variance from 20 AAC 25.112 (c)(1)(C)will also be required for setting plug away from the open perfs due to the junk in the well. Hilcorp believes that plugging this well from the top of the fish/junk will confine freshwater and hydrocarbons to their indigenous strata. Current Well Conditions: 13-5/8" BOPs installed and tested on 8/2/17. Well killed with 13 ppg mud 3-1/2"Tubing was cut at 8,050ft and currently racked in the derrick. WO Rig Procedure extended from sundry#317-311 (step 7): 1. RIH with CIBP on 3-1/2" tubing to 7,900ft and set. 2. PU and tag plug, set 10K down on plug. 3. CIBU 13ppg mud. 4. RU Cementers. Pump 17 bbls of class G cement(457ft)with 10bbI 8.4 ppg fresh water spacers using the displacement method. 5. POOH and LD CIBP setting tool. S Well Prognosis Rev1 Hilcorp Alaska,LL Well: SRU 32A-33 Date:8/7/2017 6. RIH and tag cement(approx. 7,440')with mule shoe on 3-1/2" tubing. Ensure cement has had 12hrs of set time before tagging. N rl Fj 7. Pressure test and chart cement plug to 2,000 psi for 30 min. Kr . v- 8. PU and circulate out 13ppg mud to tank with 8.4 ppg produced water with corrosion inhibitor. 9. POOH with 3-1/2"tubing to 7,000'. Hang off for kill string. 10. RD BOP. NU dry hole tree. 11. RDMO Attachments: 1. Actual Schematic 2. Proposed Schematic C—TA 3. RWO Sundry Revision Change Form SRU 32A-33 Swanson River Well SRU 32A-33 Unit Completed 9/06/11 Actual Well Schematic Hilcor Alaska LLf. RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB ,i Casing and Tubing Detail Size Type Wt/Grade Top Btm CONN/ID Cement/Other n"@ .; J.' 22" Structural Surface 45' Cemented as I 54.5#,J-55 Surface 1,023' 600 sxs 116#(stage 1), " 13-3/8" Surface DV Collar 1,023' 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DV Collar�' I- 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) @1,023'1 ! +, ;4 29#, N-80 Surface 364' BTC/6.184" VI 26#, N-80 364' 1,282' BTC/6.276" m 23#, N-80 1,282' 4,687' BTC/6.366" 13-3/8" i _ -... 2 ,a 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1 2 7" @ ,555' ( g )+ 29#, N-80 6,225' 7,916' BTC/6.184" 75Osxs 116#(stage 2) 26#, P-110 7,916' 8,036' 8RD/6.276" DV Collar 8,036' 8,038' 8RD/6.276" I,,;, .., 3 26#, P-110 8,038' 8,701' 8RD/6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg Calc TOC 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg 6,175' ► Tubing Cr., , 3-1/2" Prod 9.2#, L-80 Surface 8,219' IBT/2.992" Cplg OD=4.250" 4 ,, .• 4 Production String Jewelry Detail # Depth(RKB) Length ID OD Item s 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger;3-1/2" & L 2 3,307' 6.34' 2.867" 5.140"/3.900" GLM,GLMAX-1.ORSL 1.,,i • 3 5,527' 6.34' 2.867" 5.140"/3.900" GLM,GLMAX-1.ORSL Dv Collar • r i' 4 7,485' 6.34' 2.867" 5.140"/3.900" GLM,GLMAX-1.ORSL @ 8,036' t, .•;; 5 8,025'x,031' 5 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve Tag Fill @ :Au,; 6 8,084-8,094' 6 8,155' 1.13' 2.813" 4.520" X-Profile Nipple 8,157' 0IT:PA,, holes 7 8,309' 8,309' - - ESP Cable .'};}:f;}• punched in ♦•5.1•Y CBL TOC 8 •r•r•r•r tbg to circ kill - - Dual Chemical Injection Lines N'}+'ti+f• 9 fluid 8,355' . si.F7'i.r 9 8,219'— 8,341' 122' - 5.625"/5.130" Assembly: ESP,562 series Motors and TOL at �`< �f li," 10 513 series Pumps; Intake at 8,288' 8,376' - sx ," 10 8,379' - 4.250" - Liner top 7"window at 11 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 8,701 -' 12 10,890' - - 1.75" Teledyne Bridge Plug 13 11,319' Landing Collar 14 11,386' 10.0' - - FISH: 10'BHC/AC logging tool ni }ter TOL at I Perforation Data 9'499' F*+' ;r 11 ZONE TOP BTM Spf Comments . ,, G 10,698' 10,724' 4,4,4,6 Perf(11/12/03),(3/27/01), (2/25/01), (9/17/10) f '''' H-1 10,800' 10,820' 4,4,6 Perf(12/05/95), (5/10/91), (9/17/10) koy tet• Perf(12/05/95), (4/28/91) x H-2 10,835' 10,854' 4,4,6 5"@ 10,566' 4 (9/17/10: 10,835'—10,849') H-3, H-4 10,900' 10,912' 1 Perf(4/23/91) Isolated G ,tV.` ti H-1 .il H-2 ; Tag fill at 10,851'. " - 9/17/2010 12 H-3/H-4 jiiivri 13 2-7/8"@ 11,386' 14 TD=11,396' PBTD=11,319' Directional Data: max hole angle=34.0°at 11,000'MD SRU 32A-33 Actual Schematic 07-07-17 Updated by DMA 07-07-17 • Swanson River Unit SRU 32A-33 Well SRU 32A-33 Proposed Schematic - C Completed 9/06/11 Hilcor Alaska LLC RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB Casing and Tubing Detail 1 ,�,. Size Type Wt/Grade Top Btm CONN/ID Cement/Other X45@ 22" Structural - Surface 45' - Cemented g' 54.5#,J-55 Surbace 1,023' 600 sxs 116#(stage 1), w 13-3/8" Surface DV Collar 1,023' 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DV collar I I 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) @ 1,023' z 29#, N-80 Surface 364' BTC/6.184" a• 26#, N-80 364' 1,282' BTC/6.276" A m 23#, N-80 1,282' 4,687' BTC/6.366" 13-3/8" a 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1), @ 2,555' 7" E 29#, N-80 6,225' 7,916' BTC/6.184" 750sxs 116#(stage 2) 26#, P-110 7,916' 8,036' 8RD/6.276" DV Collar 8,036' 8,038' 8RD/6.276" 26#, P-110 8,038' 8,701' 8RD/6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg _ Calc roc 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg 6,175' . - Tubing . 2 3-1/2" Prod 9.2#,L-80 Surface ±7,000' IBT/2.992" Cplg OD=4.250" Production String Jewelry Detail V a <" 7.1.1 # Depth(RKB) Length ID OD Item _ 3 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger,3-1/2" 2 ±7,000' "' 2.991 4.25 Mule Shoe 3 ±7,900' 6.276" CIBP w/17bbls of cement(457) DV Collar • «` @ 8,036' I '. S 8084809x' 5 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve 'r'f:f rt ,�:`..: holes 6 8,155' 1.13' 2.813" 4.520" X-Profile Nipple 7 �r;}}stir punched in 7 $,309' 8,309' ESP Cable 1A:41:r x,tbg to circ kill --tir1r1r~r fluid 8 8,339' 8,339' - - Dual Chemical Injection Lines CBL TOC $ -1r1r1}~r p,' Assembly: ESP,562 series Motors and �~ 7 9 8,219'- 8,341' 122' 5.625"/5.130" 8,355 ................-_a,.___ TOL at mi r ,A 10 513 series Pumps;Intake at 8,288' 8,379' °r' i~ 10 8,379' - 4.250" - Liner top r window at ,P 11 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 8,701' 12 10,890' - 1.75" Teledyne Bridge Plug tt' 13 11,319' - - - Landing Collar 14 11,386' 10.0' - - FISH: 10'BHC/AC logging tool `sA k, TOL at j, 1 ,�r, Perforation Data 9,499' 1 ZONE TOP BTM Spf Comments 11 G 10,698' 10,724' 4,4,4,6 Perf(11/12/03),(3/27/01), (2/25/01), (9/17/10) " H-1 10,800' 10,820' 4,4,6 Perf(12/05/95), (5/10/91), (9/17/10) '� `_ H-2 10,835' 10,854' 4,4,6 Perf(12/05/95), (4/28/91) 5"@ 10,566' `- (9/17/10: 10,835'-10,849') \ Expected casing H-3, H-4 10,900' 10,912' 1 Pert(4/23/91) Isolated leak in 5"liner at FL4S connection. 13ppg mud to kill well. 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Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent:Wednesday,August 09,2017 10:44 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Ted Kramer<tkramer@hilcorp.com>;Wade Hudgens-(C)<whudgens@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: RE:SRU 32A-33, PTD 191-014,Sundry#317-311 Guy, As we discussed on the phone. We pumped 17 bbls of cement yesterday and tagged hard today at 7,450' and set 10K down on the plug. Due to the 23#7" casing in the well, I would like to change the order of steps 7 and 8 in the procedure that was provided for the suspension of the well. 7. Pressure test and chart cement plug to 2,000 psi for 30 min. 8. PU and circulate out 13ppg mud to tank with 8.4 ppg produced water with corrosion inhibitor. We are going to swap the fluid from 13 ppg mud to 8.4 ppg produced water before pressure testing the casing. We will still test to 2,000 psi for 30 min, but will do it with produced water instead of the mud. We will record this change on our RWO Sundry Revision Change Form. Thanks Chad From: Schwartz, Guy L(DOA) (mailto:quy.schwartzt alaska.gov] Sent:Tuesday,August 08, 2017 9:50 AM To: Chad Helgeson Cc:Ted Kramer; Wade Hudgens - (C); Donna Ambruz Subject: RE: SRU 32A-33, PTD 191-014, Sundry# 317-311 1 • • Chad, Verbal approval granted to proceed as outlined in your submitted sundry to sus send well SRU 32A-33. Add notification to witness for the pressure test as mentioned below. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent:Tuesday,August 08,2017 8:45 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Ted Kramer<tkramer@hilcorp.com>;Wade Hudgens-(C)<whudgens@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: RE:SRU 32A-33, PTD 191-014,Sundry#317-311 Guy, Hilcorp is requesting verbal approval to move ahead with the revised procedure we sent yesterday for the SRU 32A-33 where we will set a CIBP and cement above it and suspend the well. We are currently ready to RIH and set the CIBP. As you mentioned we will call for a witness of the pressure test 24hrs before we conduct the pressure test. Chad Helgeson From: Chad Helgeson Sent: Monday,August 07, 2017 3:27 PM To: 'Schwartz, Guy L(DOA)' Cc:Ted Kramer; Wade Hudgens - (C); Donna Ambruz Subject: RE: SRU 32A-33, PTD 191-014, Sundry# 317-311 Guy, Attached is the updated procedure that we briefly discussed this morning for the 32A-33 and is being couriered to your office . Please give me a call if you have any questions on the procedure and we can discuss. We are planning on picking up the CIBP tomorrow morning and start running in the hole. If you see any issues with that or the procedure, please let me know and we will wait to discuss it with you. Chad Helgeson Operations Manager Kenai Asset Team Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 2 • • From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, August 07, 2017 10:03 AM To: Chad Helgeson Cc: Ted Kramer; Wade Hudgens -(C) Subject: RE: SRU 32A-33, PTD 191-014, Sundry # 317-311 Chad, Sent me a new 10-403 to suspend well as we discussed. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Monday,August 07,2017 9:44 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Ted Kramer<tkramer@hilcorp.com>;Wade Hudgens-(C)<whudgens@hilcorp.com> Subject:SRU 32A-33, PTD 191-014,Sundry#317-311 Guy, We were able to kill SRU 32A-33 with 13ppg mud on Friday, but we were unable to pull the pump. So we wanted to start the contingency for plugback work. We made 2 cuts at 8,050ft, (1 for pipe and 1 for cable)on Saturday,on Sunday after working the pipe we were able to recover all the pipe and cable, however I do not think we will be able to recover the pump or the rest of the fish. (The pump has an OD of 5.625" inside 6.184" Pipe,so we cannot get washover pipe over it). We would like to plug back the well at this point and set it up for a future sidetrack. We haven't been able to get any injection rate into the formation and I do not think that a cement retainer is going to work for this well and therefore would like approval to set a CIBP and cement on top instead of a cement retainer. If you are okay with this idea, I will write up a new procedure and submit a 10-403 for plug for redrill. Feel free to call or send me an email with your thoughts, Thanks Chad Helgeson Operations Manager Kenai Asset Team Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 3 PTI) ( (Q/ ° Regg, James B (DOA) From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Thursday, August 3, 2017 4:51 PM To: Regg, James B (DOA) 11 Subject: RE:AOGCC Test Witness Notification Request: BOPE, Moncla 401, SRF 32a-33 The fluid level was 1' below the top of the stack before we pulled the BPV.There was an 15min lapse after pulling the BPV with the bop stack op ne before we MU the landing joint with no noticeable change in the fluid level. But once we screwed into the hanger it slowly started trickling out of the joint. Currently we are circulating the well and still plan to test this afternoon. If something changes I will let know. Thank You, Wade Hudgens Hilcorp WSM Cell 903-331-6711 SCANNED AUG 0 8 20I7, Office 907-283-2505 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 03, 2017 4:01 PM To: Wade Hudgens - (C) Subject: RE: AOGCC Test Witness Notification Request: BOPE, Moncla 401, SRF 32a-33 What was the fluid level after pulling BPV and before installing the landing joint? You do not need to send a BOPE Test report for the test of used BOPE but must maintain test chart in Hilcorp records. Unless I hear otherwise, I am noting in our records that the test was done today, 8/3. Jim Regg Supervisor, Inspections AOGCC 333 w.rh Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. 1 • • From: Wade Hudgens- (C) [mailto:whudgens@hilcorp.com] Sent: Thursday, August 3, 2017 10:15 AM. To: Regg,James B (DOA) <jim.regg{ralaska.gov> Subject: RE: AOGCC Test Witness Notification Request: BOPE, Moncla 401, SRF 32a-33 Thanks Jim, I will get the report written and submitted. Thank You, Wade Hudgens Hilcorp WSM Cell 903-331-6711 Office 907-283-2505 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 03, 2017 10:00 AM To: Wade Hudgens - (C) Subject: RE: AOGCC Test Witness Notification Request: BOPE, Moncla 401, SRF 32a-33 Report is required for use of BOPE in well control; see attached Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Wade Hudgens [mailto:noreply(@formresponse.com] Sent: Wednesday, August 2, 2017 4:05 PM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: AOGCC Test Witness Notification Request: BOPE, Moncla 401, SRF 32a-33 Question Answer Type of Test Requested: BOPE 2 • Pm >7io �4© Regg, James B (DOA) From: Wade Hudgens - (C) <whudgens@hilcorp.com> Sent: Thursday, August 3, 2017 11:41 AMj C 46(3(17 To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) 1 Cc: Chad Helgeson;Ted Kramer Subject: Moncla 401 Reporting BOPE Used to Prevent Flow of Fliud from a Well Use of BOPE to prevent Fluid flowing from Well Date 8/2/17 Time BOP was used 1330hrs Well SRU 32A-33/Location Swanson River/PTD Number 191-014 Rig Name Moncla 401 Operator Contact: Wade Hudgens, whudgens@hilcorp.com, (903)331-6711 After the BOPE Test was performed on August 2"d with the IA open to the tank and no flow from casing, we pulled the BPV. We monitored the Production Tubing with no flow. We MU the Landing Joint to pull the Tubing Hanger and observed the wellbore,fluid started slowly flowing out of the landing joint. We took action and pulled the Landing Joint from the Tubing Hanger and closed t �.lind Rams for well control. After the well was secured,we circulated a well volume (287 bbls) with only .667bb1 gain. We closed in the well for 12hrs to record SI pressure to calculate the correct Kill Mud weight. Thank You, Wade Hudgens Hilcorp WSM Cell 903-331-6711 Office 907-283-2505 1 • • • THE STATE Alaska Oil and Gas „A AsKA Conservation Commission Witt _._ 333 West Seventh Avenue 1/4 15-- 9161*-r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC saws J l 1 I 2 7 201/, 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Swanson River Field,Hemlock Oil Pool, SRU 32A-33 Permit to Drill Number: 191-014 Sundry Number: 317-311 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of July,2017. RBDMS JUL 1 1 2017 • 0RECEIVED • STATE OF ALASKA JUL A �� ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A�G7�,/ ' 20 AAC 25.280 '* ` 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well D Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing Q Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull ESP la 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: • Hilcorp Alaska,LLC Exploratory ❑ Development 2. 191-014 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10164-01 • 7.If perforating: r 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 1 Z5 1•7.-1?" Swanson River Unit(SRU)32A-33 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ • 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028399 • Swanson River/Hemlock Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,396' ' 11,168' • 10,851' 10,701' 1,488 psi 10,890' 10,851'(Fill) Casing Length Size MD TVD Burst Collapse Structural 45' 22" 45' 45' Conductor Surface 2,555' 13-3/8" 2,555' 2,554' 2,730psi 1,130psi Intermediate 8,701' 7" 8,701' 8,700' 6,340psi 3,830psi Liner 2,187' 5" 10,566' 10,454' 10,140psi 10,490psi Liner 1,887' 2-7/8" 11,386' 11,160' 10,570psi 11,160psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80 8,219' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Liner Top Packer;N/A 9,499'MD/9,489'TVD; N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑l Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service 0 14.Estimated Date for 15.Well Status after proposed work: July 30,2017 Commencing Operations: OIL ❑r WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com / Contact Phone: 777-8420 Authorized Signature: „�� Date: 77/1 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \`7 - 3 \ ` Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ''1`' g0 Vq -'‘tiS To • l i'x-', 1 Ru,A.I.>`.,a. c ( ,eQ ---o \,c(1) Vc>i credo- R PI.sCEMe1J A.M?..c vEVN NTL- 20 C- 7 ‘tZt,ti) Post Initial Injection MIT Req'd? Yes 0 No 0 Acyl Spacing Exception Required? Yes ❑ No g/ Subsequent Form Required: ,O RBDMS U L la A,r 1 1 201/ q �w APPROVED BY '^� 4141 1.4211L Approved by: ii MMISSIONER THE COMMISSION Date: 4- l I"(I 1 1 Il� Submit Form and A�. �� 1io `Q-1F�rm 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. ttachments in Duplicate e► _ ,ter/>fp -7.-z,,,--7 • • Well Prognosis Well: SRU 32A-33 Hulcorp Alaska,LL) Date:7/7/2017 Well Name: SRU 32A-33 API Number: 50-133-10164-01 Current Status: SI Oil Producer Leg: N/A Estimated Start Date: July 30, 2017 Rig: Moncla 401 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 191-014 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (C) AFE Number: Maximum Expected BHP: 5,470 psi @ 9,200' (9,196' TVD) Calc. from ESP Gauge to Source of high pressure water flow(9,200' MD). Max. Predicted Surface Pressure: 1,488 psi ✓ Calc. using a 0.433 psi/ft fluid gradient Brief Well Summary The ESP in the SRU 32A-33 was operating in November, 2011 when it observed a relatively sudden pump intake - pressure spike from 965 psi to over 3,000 psi in a 24 hour period. Diagnostics ran over an 11 day period concluded that the most likely cause was that the FL4S connection of the 5" liner, which was across a known high pressure water interval, had most likely failed. Chevron punched holes in the production tubing and circulated kill weight fluid to balance the well. The purpose of this work/sundry is to pull the ESP and attempt to isolate the water flow(believed to be in the 5" liner). This will be accomplished by running seals on 2-7/8" tubing and stabbing into the SC 1L liner top packer at 9,499'. A 7" packer will be ran on the top of the 2-7/8" straddle assembly and it will be set above the 5" liner at 8,379' completing the isolation of the 5" liner. If it proves out that the 5" is parted and/or collapsed, then Hilcorp plans to immediately plug back the well by setting a cement retainer in the 7" casing just above the 5" liner (2,338' above the top perforation). In this contingency, Hilcorp asks for a waiver from 20 AAC 25.112 (c) (D) in that we will be setting our cement retainer — more than 500'above the top perforation. The reason for doing this is that failure analysis performed by Chevron at the time of the well failure, pointed to a failure of the 5" FL4S casing connection. This casing string was originally ran to isolate a known high pressure water flow in the field. • -- Sc �� nL (' If the 5"casing connections are the problem in this section of the well,then it would be prudent to place cement inside and above this casing string to prevent vertical movement of well fluids. Hilcorp would set a retainer and pump a volume of 30 bbls of cement through the retainer(volume of the 5"and 2-7/8" casing down to the bottom exposed perforation at 10,854') using the down squeeze method. 424' feet of cement(16.26 Bbls)would then be placed above the retainer. This would bring cement up across the 7"casing shoe and up into the 7" casing one hundred feet above the DV tool. WO Rig Procedure: 1. MIRU Moncla #401 WO Rig. 2. Kill/bullhead well with 11.5 ppg drilling mud. Insure that the well is dead.✓' 3. Set BPV. ND Tree. 11 • • Well Prognosis Well: SRU 32A-33 Hilcorp Alaska,LL) Date:7/7/2017 4. NU 11" BOPE. Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Test VBR rams on 3-1/2" and 2-7/8"test joints. 5. Pull BPV. Ensure well is fluid filled and dead.,..'" a. Kill well with 11.5 ppg drilling mud (if necessary).✓ 6. RU ESP handling equipment. 7. POOH W/ESP, standing back the 3-1/2"tubing. Lay down the ESP. 8. PU RIH with 7" C/O assembly to the top of the 5" liner at 8,379'. Circ. bottoms up. POOH. 9. PU 7"test packer. RIH to 8,370'. Set same and pressure test 7" casing to 1.000 psi. on chart for 30 min. Release pressure, POOH with test packer. 10. RU E-line. Run CBL from 8,370 to 5,000'. RD E-line. 11. PU 5" casing scraper on 1,200'of 2-3/8"tubing crossed over to 3-1/2". RIH to TOL(2-7/8") at 9,499'. POOH W/same. a. Note: If casing is collapsed or parted,go to step 19. Otherwise,go to step 12. 12. PU RIH with 5" test packer to 9,485'. Set packer and test 5" and 7" (together) casing to 1,000 psi. If holding, chart same for 30 min. POOH W/test packer. If test was good, consult with Operations Engineer. If test failed,go to step 13. 13. PU, RIH with 2-7/8" Seals,Tubing and 7" packer assembly. Stab seals into SC 1L liner top packer at 9,499'. Space out seals, and set 7" packer according to manufactures setting procedure. POOH with workstring. 14. PU 1-1/2" Stinger on bottom of WS. RIH and clean out 2-7/8" liner swapping heavy weight kill fluid for 8.5PPG brine. POOH. 15. PU seals, 3-1/2" production string with GLM's dummied off. RIH W/gas lift string. Stab seals into the 7" packer seal bore at 8,370' +/-. Space out seals. Pressure test back side to 3,000 psi. 16. Hang off well. Set BPV, RD BOP, RU wellhead and test. 17. Turn well over to production. 18. RDMO Pulling unit. Contingency for Plug Back l�s►��aJGa.1-��f w+w Rf A.1ti A Pc''T 1 - amu.-s x`l id1/4Oc2.k-t•L11 LwC c . [2.LI:Z11- -i `� IFIL. S-(1:50-‘4� As i 19. RU E-line. PU RIH with 7" Cement retainer and set same at 8,360'. RD E-line. 20. RIH W/3-1/2:"tubing and stab into the retainer. Establish a pump in rate (PIR). 21. RU Cementers. Pump 30 bbls of cement through the retainer. Sting out of same and place 4.25' of cement on top of the retainer(17 bbls.). 22. PU and reverse out to tank to clean up tubing. WOC. 23. RIH with 3-1/2" tubing and tag top of cement. pczos5„v -x-5-1- c'cti-tic- �i,LG 24. POOH with 3-1/2"tubing to 2,000'. Hang off same for kill string. ,To • ESV I 'Pow_ 25. RD BOP. NU dry hole tree. 26. RDMO WO rig. t-v""' I C TEST I to I n • S 14 • Well Prognosis Well: SRU 32A-33 Hilcorp Alaska,LL) Date:7/7/2017 Attachments: 1. Actual Schematic 2. Proposed Schematic—Producer 3. Proposed Schematic-TA 4. BOPE Schematic 5. Wellhead Diagram 6. Proposed Dry Tree Wellhead Diagram 7. RWO Sundry Revision Change Form Swanson River Unit SRU 32A-33 Well SRU 32A-33 Actual Well Schematic Completed 9/06/11 Hilcor)Alaska LLf. RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB Casing and Tubing Detail Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22 @ t:* : 22" Structural - Surface 45' - Cemented 45 54.5#,J-55 Surface 1,023' 600 sxs 116#(stage 1), 13-3/8" Surface DV Collar 1,023' _ 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DVColla`� l" 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) @ 1023'. t"'' 29#, N-80 Surface 364' BTC/6.184" 26#, N-80 364' 1,282' BTC/6.276" 23# N-80 1,282' 4,687' BTC/6.366" 13-3/8" ; -.. 2 is 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1), @2,555' 7" E 29#, N-80 6,225' _ 7,916' BTC/6.184" 750sxs 116#(stage 2) E' 26#, P-110 7,916' 8,036' 8RD/6.276" DV Collar 8,036' 8,038' 8RD/6.276" 3 26#, P-110 8,038' , 8,701' 8RD/6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg caicTOC 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg 6,175' FA Tubing 3-1/2" Prod 9.2#,L-80 Surface 8,219' IBT/2.992" Cplg OD=4.250" I .... 4ip, Production String Jewelry Detail 4'41 Fl13 # Depth(RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger,3-1/2" • 2 3,307' 6.34' 2.867" 5.140"/3.900" GLM,GLMAX-1.ORSL 4 3 5,527' 6.34' 2.867" 5.140"/3.900" _ GLM,GLMAX-1.ORSL DV Collar 94 4 7,485' 6.34' 2.867" 5.140"/3.900" GLM,GLMAX-1.ORSL @ 8,036' - s 5 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve t,: „ 8,025'-8,031' Tag Fill @ ,:r7„, 6 8,084-8,094' 6 8,155' 1.13' 2.813" 4.520" X-Profile Nipple ''4*.4 8,157' ,;��.,,.. holes ,Yx:*`"� punched in 7 8,309' 8,309' ESP Cable tbg to circ kill 8 8,339' 8,339' - - Dual Chemical Injection Lines CBL TOC 8 4 g fluid Assembly: ESP,562 series Motors and 8,355' ,, 9 8,219'— 8,341' 122' - 5.625"/5.130" TOL at '$2E ►7 10 513 series Pumps; Intake at 8,288' 8,379' < . 10 8,379' - 4.250" - Liner top r window at {, t * 11 9,499' 4.33' _ Liner Top Packer,Baker SC-1L Packer 8,701' .#.; 12 10,890' - - 1.75" Teledyne Bridge Plug ° '` 13 11,319' - - - Landing Collar 7 14 11,386' 10.0' - - FISH: 10'BHC/AC logging tool IA r 1.4 is TOL at ,' Perforation Data 9,499' 0 ;IiZONE TOP BTM Spf Comments ti 11 o G 10,698' 10,724' 4,4,4,6 Perf(11/12/03), (3/27/01), (2/25/01), (9/17/10) f H-1 10,800' 10,820' 4,4,6 , Perf(12/05/95), (5/10/91), (9/17/10) IP Perf(12/05/95), (4/28/91) 5"@ 10,566' k H- 2 10,835' 10,854' 4,4,6 (9/17/10: 10,835'—10,849') H-3, H-4 10,900' 10,912' 1 Perf(4/23/91) Isolated G 8 j H-1 H-2 Tag fill at 10,851' - 9/17/2010 12 H-3/H-4 II 13 2-7/8"@ 11,386' 14 TD=11,396' PBTD=11,319' Directional Data: max hole angle=34.0°at 11,000'MD SRU 32A-33 Actual Schematic 07-07-17 Updated by DMA 07-07-17 Swanson River Unit SRU 32A-33 Well SRU 32A-33 Completed 9/06/11 Proposed Schematic - A Hileor Alaska LI,C RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB Casing and Tubing Detail $ ; Size Type Wt/Grade Top Btm CONN/ID Cement/Other 2@ 6, 22" Structural - Surface 45' - Cemented 45 54.5#,J-55 Surface 1,023' 600 sxs 116#(stage 1), 13-3/8" Surface DV Collar 1,023' 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DV 023 Mr it1, 1r!I „ 2 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) . 29#, N-80 Surface 364' BTC/6.184" Au ,. 26#, N-80 364' 1,282' BTC/6.276" aik a) m 23#, N-80 1,282' 4,687' BTC/6.366" 133/8" ami 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1), @2,555' ,t, 7" 29#, N-80 6,225' 7,916' BTC/6.184" 750sxs 116#(stage 2) 26#, P-110 7,916' 8,036' 8RD/6.276" DV Collar 8,036' 8,038' 8RD/6.276" 26#, P-110 8,038' 8,701' 8RD/6.276" I i 4 S�� 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg Calc TOC _ 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg 6,175' Tubing Li 2-7/8" Prod Surface ±9,499' rii, k. Production String Jewelry Detail # Depth(RKB) Length ID OD Item t4 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger,3-1/2" *"14 2 ±3,307' GLM DV collar 3 ±5,527' GLM @ 8,036' 4 ±7,485' GLM 5 ±8,103' GLM 6 ±8,370' Isolation Packer 7 8,379' - 4.250" - Liner Top CBL TOC 8 9,499' 4.33' - - Liner Top Packer,Baker SC-1L Packer 8,355 6 9 10,890' - - 1.75" Teledyne Bridge Plug TOL at p 7 10 11,319' Landing Collar 8,379' L" . 11 11,386' 10.0' - - FISH: 10'BHC/AC logging tool 7"window at ' gg g 8,701' .t Perforation Data ZONE TOP BTM Spf Comments G 10,698' 10,724' 4,4,4,6 Perf(11/12/03), (3/27/01), (2/25/01), (9/17/10) I H-1 10,800' 10,820' 4,4,6 Perf(12/05/95), (5/10/91), (9/17/10) TOL at _ at Perf(12/05/95), (4/28/91) 9,499' , 8 H-2 10,835' 10,854' 4,4,6 (9/17110: 10,835'-10,849') H-3, H-4 10,900' 10,912' 1 Perf(4/23/91) Isolated 5"@ 10,566' H-1 � H-2 V,' 1''. Tag fill at 10,851' .�- .....4, g 9/17/2010 H-3/H-4 -,; 10 2.7/8"@ 11,386' 'k 11 TD=11,396' PBTD=11,319' Directional Data: max hole angle=34.0°at 11,000'MD SRU 32A-33 PROPOSED Schematic 07-07-17 A Updated by DMA 07-07-17 Swanson River Unit • SRU 32A-33 Well SRU 32A-33 Proposed Schematic - B Completed 9/06/11 IHiieorp Alaska LLC RKB:198.3'KB/GL:172'AMSL KB-THF:26.3'KB Casing and Tubing Detail 1 s it` : Size Type Wt/Grade Top Btm CONN/ID Cement/Other 22"@ . 1 22" Structural - Surface 45' - Cemented ae 54.5#,J-55 Surface 1,023' 600 sxs 116#(stage 1), y- 13-3/8" Surface DV Collar 1,023' 1,025' 8RD/12.615" 600 sxs 116#(stage 2), DV Collar I ■ 54.5#,J-55 1,025' 2,555' 64 sxs 116#(top job) @ 1,023', 29#, N-80 Surface 364' BTC/6.184" 26#, N-80 364' 1,282' BTC/6.276" An m 23#, N-80 1,282' 4,687' BTC/6.366" 13-3/8" '0ai 26#, N-80 4,687' 6,225' BTC/6.276" 650sxs 116#(stage 1), @ 2,555' 7" E 29#, N-80 6,225' 7,916' BTC/6.184" 750sxs 116#(stage 2) E. 26#, P-110 7,916' 8,036' 8RD/6.276" DV Collar 8,036' 8,038' 8RD/6.276" 26#, P-110 8,038' 8,701' 8RD/6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S/4.276" 70 bbl 15.6 ppg Calc TOC 2-7/8" Liner 6.5#, N-80 i 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg 6,175' 1. t,, Tubing VI 3-1/2" Prod 9.2#, L-80 Surface ±2,000 IBT/2.992" Cplg OD=4.250" Production String Jewelry Detail w # Depth(RKB) Length ID OD Item TOC @ 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger,3-1/2" 7935 u 2 ±8,360' Cement Retainer w/425'cement 3 8,379' - 4.250" - Liner top DV @ Collar036' i • •' .• 4 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 5 10,890' - - 1.75" Teledyne Bridge Plug 6 11,319' - - - Landing Collar 7 11,386' 10.0' - - FISH: 10'BHC/AC logging tool CBL TOC p' .. 8,355' ' 2 TOL at V :• IC ',e 3 8,379' i' 7 window at .• Perforation Data 8,701' ZONE TOP BTM Spf Comments G 10,698' 10,724' 4,4,4,6 Perf(11/12/03), (3/27/01), (2/25/01), (9/17/10)Isolated • . I. : K H-1 10,800' • 10,820' . 4,4,6 Perf(12/05/95), (5/10/91), (9/17/10) Isolated • Perf(12/05/95), (4/28/91) Isolated H-2 10,835' 10,854' 4,4,6 (9/17/10: 10,835'-10,849') Isolated iH-3, H-4 10,900' 10,912' 1 Perf(4/23/91) Isolated TOL at ;; 9,499' es rk r., "! 4.' 5"@10,566 :: :I V •'• ,,...1 • G H-1 Tag fill at 10,851' 5 9/17/2010 H-3/H-4 r 6 4 it 2-7/8"@ 11,386' 7 TD=11,396' PBTD=11,319' Directional Data: max hole angle=34.0°at 11,000'MD SRU 32A-33 PROPOSED Schematic 07-07-17 B Contingency Updated by DMA 07-07-17 • Swanson River SRU 32A-33 06/13/17 Hi►rnrp SLi4.a.LLC 1 13-5/8" 5M Annular 2-7/8"- 5" Variables 14 Blinds 14 m 2-1/16" 5M choke and kill valves IN ip • • fiSwanson River SRU 32A-33 Current 05/26/2017 HiItairp: bike,IIA; Swanson River Tubing hanger,Vetco-FTCM-D-H,7 X SRU 32A-33 3'/:IBT-M bottom X 3.725 MCA top, 13 3/8 X A- 3'/z w/3"Type H BPV,VG-100 seal sub top,BIW Kwik Lok feed thru,two continuous control lines,DD material BHTA,Bowen type,3 1/8 5M FE X 3"Bowen top A Valve,swab,VG-M, 3 1/8 5M FE,HWO, , �gt?, Valve,wing,VG-M DD = I' 3 1/8 5M FE,HWO, 1, DD,Qty 2 Valve,wing,VG-M, N. 2 1/16 5M FE,HWO, 1 I a o f ( a a l Valve,upper master,VG-M, ', 3 1/8 5M FE,HWO,DD Valve,master,VG-M, '�' '' 3 1/8 5M FE,HWO,DD `ie,, Adapter,Vetco-ESP,7 1/16 3M FE X all ■ 3 1/8 5M FE,prepped for BIW Kwik mry"j(iJj _ Lok penetrator,2-%chemical lines ��•— . Ground Level life III —' TV Void test good Tbg head attachement,Vetco FTC I' 250/3000psi 1 IT,7 1/16 5M FE X 7 1/16 5M FE, 4/8/2011 special made to 40"in length lit iI Tubing head, Shaffer '-..i i•o-= T55-Ll, 13 5/8 3M X it In 7 1/16 5M w/2-2 1/16 5M SSO, 7"Type 1 secondary � ___ Valve,CIW-F,2 1/16 5M FE, seal in head, no tubing � o ]� OrAlist HWO,Qt 2 y hanger installed `� `f in $ on Void test good Casing head, Shaffer KD, ,' 2 4//20011si 11 13 5/8 3M X 13 3/8 SOW, w/2-2" LPO, 7" KD slips in .— in and packoff assy in head _ Valve,plug,PORockwell,2" ISI : 11111111.I■ i_i �l�.I- L , • • . 11 1 Hilrnrp Aln„ka,l.lA; Swanson River SRU 32A-33 Proposed 06/07/2017 Swanson River Tubing hanger,Vetco-FT-EN,7 X 3 1/2 SRU 32A-33 IBT-M bottom X 3.725 MCA top,w/ 13 3/8 X 7 X 3 1/2 3"Type H BPV,VG-100 seal sub top BHTA, Bowen type,3 1/8 5M FE X 3" Bowen top I ,,, • Valve, master,VG-M, giiiiit 3 1/8 5M FE, HWO, r °t. ° Adapter,Vetco-EN, 7 1/16 5M FE X III �1�-, ,E 3 1/8 5M ..,—� . .._. Ground Level ill Tbg head attachement,Vetco FTC- — ki IT, 7 1/16 5M FE X 7 1/16 5M FE, special made to 40" in length Linni all L Tubing head, Shaffer _,.,441 J m,®, T55-Ll, 13 5/8 3M X i / ii 7 1/16 5M w/2-2 1/16 5M SSO, 7" Type 1 secondary '- �� ' valve,CIW F 2 1/16 5M FE, seal in head, no tubing 1110411) Ili„?.,4HWO,Qty 2 hanger installed = -� - - III / III ii ii ia Casing head, Shaffer KD, _ 13 5/8 3M X 13 3/8 SOW, 1v! . —1 w/2-2" LPO, 7" KD slips Valve, plug, Rockwell, 2" and packoff assy in head MI $iui 01-I LPO, ri ;'.` �5 • 0 c7 — 2a0 / / W2 2 a 0 7 C 22 002 / / 2k ° § / « � E ® n o . $ / § 2 �� >, Ea \ \ 7 \ f a) /'\ ac co m (13 to m 7 3 a \ e $ _ 2 CO e % / 2 � o O 9 Ff 2 J k 0mc - CD .0 I- o > CD (.1 _a / O ci 1:3 $ n e2 U Cn �� ig \ / & so C L511) s 2 E § % _ = eL. 0 2 0 .g . § \ / § . a) \ \ / § th k / / . Cu m = r c \ \ \ o l $ 2 § � % g O < $ § O / kas % \ ¥ U 2 & 9 = .2 2 k .2 k 2 2 © Caml w S 2 \ co C,4 .. . . TI) ZS m , k : P / A 2 92 \ U / / \ / / MO a) U) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~/(~/~ File Nu m ber of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages:. DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] ' Logs-of vadous kinds . [] Other COMMENTS: Scanned' by: Bevedy Diann Nathan Lowell TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl STATE OF ALASKA ALASK IL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate LJ Other U Well Kill Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 191 -014 e. 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 133 - 10164 -01— 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028399 [Swanson River Unit] Swanson River Unit 32A -33 - 9. Field /Pool(s): Swanson River Field/ Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,396 feet Plugs measured 10,890 feet true vertical 11,168 feet Junk measured 10,851 (Fill) feet Effective Depth measured 10,851 feet Packer measured 9,499 feet true vertical 10,701 feet A 441414 jA p t R y rt ical 9,489 feet Casing Length Size MD TVD CC Burst Collapse Structural 45' 22' 45' 45' Conductor Surface 2,555' 13 -3/8" 2,555' 2,554' 2,730psi 1,130psi Intermediate Production 8,701' 7" 8,701' 8,700' 6,340psi 3,830psi Liner 2,187' 5" 10,566' 10,454' 10,140psi 10,490psi Liner 1,887' 2 -7/8" 11,386' 11,160' 10,570psi 11,160psi Perforation depth Measured depth 8.025- 8.031; 8,084' - 8,094'; 10.698- 10.724; 10,800- 10.820; 10.835- 10,854 Feet True Vertical depth 8,025 - 8,031: 8.084' - 8,094';10,567- 10.607; 10.658- 10,675; 10,688- 10.704 Feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 # /L -80 8,21W ¶2T8 r 9,499(MD) RECEIVEQ Packers and SSSV (type, measured and true vertical depth) Liner Top Packer 9,489(TVD) NIA /A 11. Stimulation or cement squeeze summary: N/A JAN 2 7 2012 Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A Alaska Oil & Gas Cons. Commission Anchorage 12. Representative Daily Average Production on a a Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 29 0 696 1,025 psi 240 psi Subsequent to operation: 0 0 0 750 psi 754 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory III Developmental w Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil is ,. Gas U WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager I Signature O 111 Phone 276 -7600 Date 1/25/2012 J -L . / Z- Form 10 -404 Revised 1 �,,,',4,. t. in 2017 Submit Original Only evro • SRU Swanson River Unit Sit V 32A-33 Well SRU 32A -33 '''"■■••••••• Completed 9/06/11 Actual Well Schematic Updated 10/10/11 RKB: 198.3' KB / GL: 172' AMSL KB -THF: 26.3' KB Casing and Tubing Detail i ,, 1 f, ° Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" @ . 22" Structural - Surface 45' - Cemented 45' 54.5 #, J -55 Surface 1,023' 600 sxs 116# (stage 1), 13 -3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600 sxs 116# (stage 2), Dv collar 1 1 54.5 #, J -55 1,025' 2,555' 64 sxs 116# (top job) @ 1,023' 29 #, N -80 Surface 364' BTC / 6.184" d 26 #, N -80 364' 1,282' BTC / 6.276" 23 #, N -80 1,282' 4,687' BTC / 6.366" 13 -3/8" i' M) 2 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), @ 2,555' 7" Surface 29 #, N -80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26 #, P -110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" l r..:.. » 3 26 #, P -110 8,038' 8,701' 8RD / 6.276" 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg • Calc TOC 2 -7/8" Liner 6.5 #, N -80 9,499' 11,386' 8RD -Mod / 2.441" 18 bbl 15.8 ppg 6,175' Ad 1, Tubing 3 -1/2" Prod 1 9.2 #, L -80 1 Surface 1 8,219' 1 IBT / 2.992" 1 Cplg OD = 4.250" ''' i ----- 4 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger, 3 -1/2" 2 3,307' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL 3 5,527' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL Dv Collar ;' 4 7,485' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL @ 8,036'' 5 � 5 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve Tag Fill @ ; f; f; f; r, 6 6 8,155' 1.13' 2.813" 4.520" X- Profile Nipple 8,157' ., T } } f: }. 7 8,309' 8,309' - - ESP Cable . .f . f ..ti f .ti. f . 8 8,339' 8,339' - - Dual Chemical Injection Lines � » ». CBL TOC 8 . } 9 Assembly: ESP, 562 series Motors and 8,355' .:41:::41 , 9 8,219' — 8,341' 122' - 5.625 "/5.130" y' TOL at . 4 10 513 series Pumps; Intake at 8,288' 8,379' ' , 10 8,379' - 4.250" - Liner top 7" window at 4 . 11 9,499' - - - Baker E -22 Anchor Seal Assembly 8,701' kl_' 12 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer . ;y 13 10,890' - - 1.75" Teledyne Bridge Plug ilel 14 11,319' - - - Landing Collar r P. 15 11,386' 10.0' - - FISH: 10' BHC /AC logging tool 9, 99' r L. #' 11 Perforation Data 12 ZONE TOP BTM Spf Comments I. G 10,698' 10,724' 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) N. H -1 10,800' 10,820' 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) 5" @ 10,566' H -2 10,835 10,854' 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835' — 10,849') H -3, H -4 10,900' 10,912' 1 Perf (4/23/91) Isolated G y. H -1 H -2 Tag fill at 10,851' .....1k: ti• 9/17/2010 -� 13 H -3/H -4 ;. 14 2 -7/8" @ 11,386' 4610. .6 15 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A -33 Actual Schematic 10- 10- 11.docx Updated by TDF 1 -25 -2012 ro • Chevron • • 11 10 0 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 32A -33 SWANSON RIV UNIT 32A -33 FEDA028399 5013310164 QA5337 187.00 ;,1.. ,� ` ,., .. 7 . Primary Job Type Job Category Objective Actual Start Date Actual End Date Well Preparation Well 12/13/2011 12/19/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 32A -33 501331016401 1910140 12/13/2011 00:00 - 12/14/2011 00:00 Operations Summary R/U slick -line and P/T lubricator to 250 psi low/ 3,000 psi high. RIH w/ shifting tool and tag fill @ 8,096', POOH. M/U 2.5" bailer and work through to 8,141' POOH. M/U shifting tool and RIH to locate sleeve w/o success. M/U 2.5" bailer and make 5 runs to achieve a depth of 8,157'., POOH. 12/14/2011 00:00 - 12/15/2011 00:00 Operations Summary R/U slick -line and P/T lubricator to 250 psi low /3,000 psi high. P/U 6' tubing punch and RIH, correlate guns on depth @ 8,084' - 8,094' and fire same, POOH, all shots fired and found sand in guns. Attempt to achieve circulation down tubing w/o success. P/U second 6' tubing punch gun and RIH, correlate guns on depth at 8,025' - 8,031' and fire same. POOH all shots fired with sand in guns again. R/D slick -line. 12/15/2011 00:00 - 12/16/2011 00:00 Operations Summary Prepare location for well kill operation. R/U slick -line and P/T lubricator to 250 psi low/ 2500 psi high. RIH with pulling tool and retrieve dummy gas lift valve @ 7,485'. 12/16/2011 00:00 - 12/17/2011 00:00 Operations Summary Confirm communication through GLM, R/D slick -line and secure well. Finish preparing location for well kill operation. Transfer 11.7 ppg NaBr kill weight fluid to rlocation. 12/17/2011 00:00 - 12/18/2011 00:00 Operations Summary R/U fluid pump and lines and P/T to 250 psi low /4,000 psi high. Circulate well down tubing into annulus with 11.7 ppg NaBr brine until 11.7 ppg returns to surface. Bleed off pressure and shut -in well. Monitor well. Turn well over to production. 12/18/2011 00:00 - 12/19/2011 00:00 Operations Summary Freeze Protect annulus & tubing with diesel. RD and demobe equipment. • • Page 1 of 1 Maunder, Thomas E (DOA) From: Kanyer, Christopher V [Chris.Kanyer @chevron.com] Sent: Friday, November 18, 2011 9:40 AM To: Maunder, Thomas E (DOA) Subject: RE: SRU 32A -33 (191 -014) Tom, You are correct, this is a no flow well. Lease water is pumped down the annulus to compensate for pipe displacement and to wash the tubing as we are pulling out of the hole. Let me know if you have any further questions. Chris Kanyer •• Drilling Engineer Wellbore Maintenance Team SLAWNED JAN 5 /tY Office: (907) 263 -7831 CeII: (907) 250 -0374 Chevron North America Exploration and Production Midcontinent /Alaska SBU 3800 Centerpoint Dr, Suite 100 Anchorage, AK 99503 From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Friday, November 18, 2011 9:09 AM To: Kanyer, Christopher V Subject: SRU 32A -33 (191 -014) Chris, Please forward this on as necessary. I am reviewing the 404 submitted documenting the recent ESP workover on this well. In the entry for 9/6 — 9/7 it is noted "Pump lease water down annulus." What was the need to pump lease water? Based on some of the information attached to the sundry, it appears that the normal condition for this well is with the fluid level not at surface even with the pump SD. Is that correct? Thanks in advance, Tom Maunder, PE AOGCC 11/18/2011 STATE OF ALASKA ALASKIIIL AND GAS CONSERVATION COMMISS M.o? , // REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 11 Repair Well 11 Plug Perforations 11 Stimulate 11 Other U Run ESP Completion Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ 191 -014 • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: . 50- 133 - 10164 -01 0 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028399 [Swanson River Unit] Swanson River Unit 32A -33 9. Field /Pool(s): Swanson River Field/ Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,396 feet Plugs measured 10,890 feet true vertical 11,168 feet Junk measured 10,851 (Fill) feet Effective Depth measured 10,851 feet Packer measured 9,499 feet true vertical 10,701 feet true vertical 9,489 feet Casing Length Size MD TVD Burst Collapse Structural 45' 22' 45' 45' Conductor Surface 2,555' 13 -3/8" 2,555' 2,554' 2,730psi 1,130psi Intermediate Production 8,701' 7" 8,701' 8,700' 6,340psi 3,830psi Liner 2,187' 5" 10,566' 10,454' 10,140psi 10,490psi Liner 1,887' 2 -7/8" 11,386' 11,160' 10,570psi 11,160psi Perforation depth Measured depth 10,698- 10,724: 10,800- 10,820: 10,835- 10,854 Feet True Vertical depth 10,567- 10,607: 10,658- 10,675: 10,688- 10,704 Feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 # /L -80 8,219' 8,218' 9,499(MD) Packers and SSSV (type, measured and true vertical depth) Liner Top Packer 9,489(TVD) R C E 1 \E N/A 11. Stimulation or cement squeeze summary: {� 1I OCT 11�� 1 �+ 1 2011 Intervals treated (measured): N/A t 1 Al Treatment descriptions including volumes used and final pressure: N/A 8tk8 011 &Gas Cons. Commission 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 29 0 696 1,000 psi 240 psi Subsequent to operation: 87 143 1,646 160 psi 200 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 ° Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ° U Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 311 -247 Contact Chris Kanyer Phone: 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature � Phone 276 -7600 Date ; p/f c , / i Form 10-404 Revised 10/2010 FIEMMS OCT1,27 1, y ' r Submit Original Only . ' evro • Swanson River Unit SRU 32A -33 Well SRU 32A -33 �.•••""1. Completed 9/06/11 Actual Well Schematic Updated 10/10/11 RKB:19$.3' KB / GL: 172' AMSL KB-THF: 26.3' KB Casing and Tubing Detail J 1 1 Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22 "@ 46' 22" Structural - Surface 45' - Cemented 54.5 #, J -55 Surface 1,023' 600 sxs 116# (stage 1), DV Collar I I 13 -3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600 sxs 116# (stage 2), @1,023' 54.5 #, J -55 1,025' 2,555' 64 sxs 116# (top job) 29 #, N -80 Surface 364' BTC / 6.184" A , 26 #, N -80 364' 1,282' BTC / 6.276" 134/8" 2 23 #, N -80 1,282' 4,687' BTC / 6.366" @ 2,666' 7" Surface 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 29 #, N -80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26 #, P -110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" f , 3 26 #, P -110 8,038' 8,701' 8RD / 6.276" 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg Cale roc 6,176' 2 -7/8" Liner 6.5 #, N -80 9,499' 11,386' 8RD -Mod / 2.441" 18 bbl 15.8 ppg Tubing 3 -1/2" I Prod I 9.2 #, L -80 1 Surface 1 8,219' 1 IBT / 2.992" 1 Cplg OD = 4.250" r t ; ` 4 Production String Jewelry Detail ' ; - - 5 # Depth (RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.998" Tubing Hanger, 3 -1/2" { X 6 2 3,307' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL 7 3 5,527' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL DV Collar @ 8,036' 1 1 ' ' ' ' ii � 4 7,485' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL • 0 J, 5 8,103' 4.28' 2.813" 4.290" CMU Sliding Sleeve 8 ' 6 8,155' 1.13' 2.813" 4.520" X- Profile Nipple 9 7 8,309' 8,309' - - ESP Cable CBLTOC 8 8,339' 8,339' - - Dual Chemical Injection Lines 8,366' 9 8,219' – 8,341' 122' - 5.625 "/5.130" Assembly: ESP, 562 series Motors and TOLat I X $, 10 513 series Pumps; Intake at 8,288' 8,379' 10 8,379' - 4.250" - Liner top 7" window at 11 9,499' - - - Baker E -22 Anchor Seal Assembly 8,701' 12 9,499' 4.33' - - Liner Top Packer, Baker SC -1 L Packer 13 10,890' - - 1.75" Teledyne Bridge Plug 14 11,319' - - - Landing Collar 15 11,386' 10.0' - - FISH: 10' BHC /AC logging tool TOL at 11 1 9,499' Perforation Data 12 ZONE TOP — Spf Comments G 10,698' 10,724 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) .. H -1 10,800' 10,820' 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) 6" @ 10,666' . Perf (12/05/95), (4/28/91) H -2 10,835' 10,854' 4, 4, 6 (9/17/10: 10,835' – 10,849') H -3, H -4 10,900' 10,912' 1 Perf (4/23/91) Isolated G H -1 - * H -2 Tag fill at 10,861' - }r. 13 9/17/ H -3/H -4 ', 14 \ 2 -7/8" @ 11,386' i 5 15 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A -33 Actual Schematic 10- 10- 11.docx Updated by CVK 10 - 10 - 2011 . Chevron • S Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SRU 32A -33 SWANSON RIV UNIT 32A -33 FEDA028399 5013310164 QA5337 187.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 8/31/2011 9/8/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 32A -33 501331016401 1910140 Daily Operations 9/1/2011 00:00 - 9/2/2011 00:00 Operations Summary Move in and rig up Key Energy Rig #3. Bleed gas from tubing and annulus. Install BPV. N/D Tree. N/U BOPE. Notify Jim Regg with AOGCC and Tom Zelenka and Justin Miller with BLM of upcoming BOPE test. 9/2/2011 00:00 - 9/3/2011 00:00 Operations Summary Continue to N/U BOPE. Pull BPV. Run TWC. Test annular to 250 psi low /2,500 psi high. Test remaining BOPE to 250 psi low /3,000 psi high. Test witnessed by Lou Grimaldi with AOGCC. Pull TWC. M/U landing joint to hanger. Pump 100 bbl lease water down annulus and tubing, monitor well. Pull tubing hanger free. Begin to POOH with 3 -1/2" ESP completion. 9/3/2011 00:00 - 9/4/2011 00:00 Operations Summary UD failed ESP Pump. Lost Nexpreme rubber coating of chemical injection lines. RU slickline. 9/4/2011 00:00 - 9/5/2011 00:00 Operations Summary RU lubricator. Run #1 RIH w/ 5.9" Junk Basket to 2,480' SLM. POOH, no recovery. Run #2 to 4,450' SLM. POOH, no recovery. Run #3 to 8,377' SLM. POOH, recover 1 steel band and small amount of rubber coating. Run #4 to 8,377' SLM. POOH, recover 1 cup of rubber coating. Run #5 to 8,377' SLM. POOH, recover 1 cup of rubber coating. Run #6 to 8,377' SLM. POOH, recover 1/3 cup of rubber coating. Run #7 to 8,377' SLM. POOH, recover trace of rubber coating. RIH w/ 3.88" Gauge Ring and Junk Basket to 9,499' SLM. POOH, lost tools downhole. RIH w/ 2.5" Magnet and tag fish at 9,495' SLM. POOH, recover partial fish. Make 3 additional runs, no recovery. RIH w/ 3.5" Magnet to 9,495' SLM. POOH, recover partial fish. RIH w/ 3.5" Magnet to 9,498' SLM. POOH, no recovery. RIH w/ 3.5" Magnet to 9,498'. POOH. Lost magnet. RIH w/ JDU latch tool to 9,498' SLM. POOH, full recovery of fish. RIH w/ 3.88" Junk Basket to 9,499' SLM. POOH. No recovery. RD Slickline. 9/5/2011 00:00 - 9/6/2011 00:00 Operations Summary Rig up to run ESP Pump. Begin to RIH w/ ESP on 3 -1/2" tubing. 9/6/2011 00:00 - 9/7/2011 00:00 Operations Summary Pump lease water down annulus. RIH w/ ESP on 3 -1/2" 9.2 #/ L -80 tubing to 8,341' RKB. MU and land tubing hanger. Set BPV. ND BOPE. NU Tree. Set TWC. Test tree to 250 psi low /3,000 psi high. Pull TWC. Rig down and move Key Energy Rig #3 to SCU 33 -33. 9/7/2011 00:00 - 9/8/2011 00:00 Operations Summary Rig down and move Key Energy Rig #3 to SCU 33 -33. • • k - t SEAN PARNELL, GOVERNOR ALASKA 0114 AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 CONSERVATION PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager O Union Oil Company of California "� P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit 32A -33 Sundry Number: 311 -247 Dear Mr. Brandenburg: o #.Aii AUG i. 6 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, GI Daniel T. Seamount, Jr. i Chair DATED this / day of August, 2011. Encl. D- If , /O // STATE OF ALASKA � , 16 ALASKA OIL AND GAS CONSERVATION COMMISSION i� 0 cello/ Loll APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing El Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Run ESP completion El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory ❑ 191 -014 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-13040161-01 f 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: . . , a . c -, ; F — n property line where ownership or landownership changes: Spacing Exception Required? Yes ;) *; ' p g p q ❑ No 0 Swanson River Unit 32A -33 i ;' 9. Property Designation (Lease Number): 10. Field / Pool(s): (Swanson River Unit) Swa R iver Field / Hemlock Oil Pool 8 ' "' , Jai ay ( FEDA028399 , ( ) c� 1 (.of N,. P¢t 4011U531dt► 11. PRESENT WELL CONDITION SUMMARY titular, d Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,396 11,168 10,851 10,701 10,890' 10,851' (Fill) Casing Length Size MD / TVD Burst Collapse Structural 45' 22" 45' 45 Conductor Surface 2,555' 13 -3/8" 2,555' 2,554' 2,730psi 1,130psi Intermediate Production 8,701' 7" 8,701' 8,700' 6,340psi 3,830psi Liner 2,187' 5" 10,566' 10,454' 10,140psi 10,490psi Liner 1,887' 2 -7/8" 11,386' 11,160' 10,570psi 11,160psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,698 - 10,724, 10,800 10,568- 10,591, 10,658- 10,675, / 10,820, 10,835- 10,854, 10,688- 10,704 3 -1/2" 9.2 #/ L -80 8,155 ■ Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): / Baker SC -1 L Packer and N/A 9,499 (MD)/ 9,489(TVD) and N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El Service ❑ 14. Estimated Date for i 15. Well Status after proposed work: Commencing Operations: 8/23/2,011 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: ' GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone 263 -7640 Printed Name i Timothy C. Brandenburg Title Drilling Manager ''Ik--- Signature X ` Phone 276-7600 Date 8/3/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: , f , Li 7 Plug Integrity ❑ BOP Test [V] Mechanical Integrity Test ❑ Location Clearance ❑ Other: I'S & Bo p E { T o O D Y Li- • Subsequent Form Required: ip q (2 Lt. 0 i . 1 APPROVED BY Approved by it COMMISSIONER THE COMMISSION Date: gi 101 I 1 Form 10 -403 Revised 1/2 +: DMS AUG 1 obi -`' � • 1G1NAL Submit in Duplicate • Chen Swanson River Unit MOO SRU 32A -33 111 0110 7 -11 -2011 Obiective: • Pull failed ESP completion; Run new ESP completion with same 3 -1/2" tubing. Current BHP: 2,830 psi @ 10,580' TVD 5.1ppg EMW (Based on SITP = 800 psi, fluid level at 5,988' and a produced water gradient) Maximum BHP: 2,830 psi @ 10,580' TVD 5.1 ppg EMW (Based on SITP = 800 psi, fluid level at 5,988' and a produced water gradient) Current Water Cut is 95 %. MASPsi (Based on actual reservoir conditions and water cut of 94% (0.432 psi /ft) with added safety factor of 1000' TVD of oil cap) Procedure Summary: 1. MIRU Key Energy Rig #3. 2. Install BPV, ND tree, NU BOPE & test same 250psi low/ 000pst high, test annular to 250psi low/ 1,500psi high, pull BPV. 3. Pump 3% KCI down tubing and annulus. 4. Pull 3 -1/2" production tubing and failed ESP from 8,304'. 5. Re -run 3 -1/2" tubing with new ESP completion to 8,304' ( + / -). 6. Set BPV, ND BOPE, NU Tree. 7. Release Key Energy Rig #3. 8. Return the well to production. 07/11/2011 SP ' evro Swanson River Unit SRU 32A-33 Well SRU 32A -33 '%'"%..i•"'"° Last Completed 10/17/10 Actual Wellbore Schematic Updated 10/17/10 RKB: 198.3' KB / GL: 172' AMSL KB- THF:26.3'KB Casing and Tubing Detail — 1 ,, Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" @ . . 46' 22" Structural - Surface 45' - Cemented 54.5 #, J -55 Surface 1,023' 600 sxs 116# (stage 1), DV Collar ' 13 -3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600 sxs 116# (stage 2), @ 1,023' 54.5 #, J -55 1,025' 2,555' 64 sxs 116# (top job) 29 #, N -80 Surface 364' BTC / 6.184" 26 #, N -80 364' 1,282' BTC / 6.276" 13-3/8" i 2 . 23 #, N -80 1,282' 4,687' BTC / 6.366" @2,656' 7" Surface 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 29 #, N -80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26 #, P -110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" r -- 3 26 #, P -110 8,038' 8,701' 8RD / 6.276" 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg Calc 2 -7/8" Liner 6.5 #, N -80 9,499' 11,386' 8RD -Mod / 2.441" 18 bbl 15.8 ppg Tubing 3 -1/2" 1 Prod 1 9.2 #, L -80 1 Surface 1 8,155' 1 IBT / 2.992" 1 Cplg OD = 4.250" • Production String Jewelry Detail 5 I 4 4 # Depth (RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.990" Tubing Hanger, 3 -1/2" 6 2 3,275' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL 7 3 5,465' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL ovcouar - .r;, @ 8,036' imma■r ' 4 7,484' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL 5 8,039' 4.28' 2.813" 4.290" CMU Sliding Sleeve 8 INIORM 6 8,090' 1.13' 2.813" 4.520" X- Profile Nipple 9 7 8,238' 8,238' - - ESP Cable CBLTOC 8 8,304' 8,304' - - Dual Chemical Injection Lines 8,366' 9 8,155' — 8,304' 149' - 5.130 "/4.56" Assembly: ESP, 456 series Motors and TOLat '. - �� 1 10 513 series Pumps 8,379' 10 8,379' - 4.250" - Liner top 7" window at j 11 9,499' - - - Baker E -22 Anchor Seal Assembly 8,701' 12 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 13 10,890' - - 1.75" Teledyne Bridge Plug 14 11,319' - - - Landing Collar ii 15 11,386' 10.0' - - FISH: 10' BHC /AC logging tool 9, r 11 Perforation Data 12 ZONE TOP BTM Spf Comments L G 10,698' 10,724' 4,4,4,6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) b. H-1 10,800' 10,820' 4,4,6 Perf (12/05/95), (5/10/91), (9/17/10) 6" @ 10,666' H -2 10,835' 10,854' 4, 4, 6 Perf (12/05/95), (4/28/91) (9/17/10: 10,835' — 10,849') H -3, H -4 10,900' 10,912' 1 Perf (4/23/91) Isolated G a H -1 - i H -2 i;: Tag / / 1 Q ' '. - 13 9/17/2010 H-3/H-4 14 2-7/8" @ 11,386' ' 15 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A -33 Actual Well Schematic 10- 17- 10.docx Updated by STP 4 -12 -2011 evro Swanson River Unit SRU 32A -33 Well SRU 32A -33 %.--•......--- PROPOSED SCHEMATIC Proposed 7/11/11 RKB: 198.3' KB / GL: 172' AMSL KB-THF: 26.3' KB Casing and Tubing Detail 1 J.....'? Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" @ • . 46' , 22" Structural - Surface 45' - Cemented 54.5 #, J -55 Surface 1,023' 600 sxs 116# (stage 1), DV Collar I 1 I 13-3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600 sxs 116# (stage 2), @ 1,023' : k ' 54.5 #, J -55 1,025' 2,555' 64 sxs 116# (top job) i 29 #, N -80 Surface 364' BTC / 6.184" 26 #, N-80 364' 1,282' BTC / 6.276" 13-3/8" .�.. 2 23 #, N -80 1,282' 4,687' BTC / 6.366" @2,666' 7" Surface 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 29 #, N -80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26 #, P -110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" i c 3 26 #, P -110 8,038' 8,701' 8RD / 6.276" 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg CaIcTOC 2 -7/8 Liner 6.5 #, N -80 9,499' 11,386' 8RD -Mod / 2.441" 18 bbl 15.8 6,176' _ ppg Tubing 3 -1/2" 1 Prod 1 9.2 #, L -80 1 Surface 1 +/- 8,187' 1 IBT / 2.992" 1 Cplg OD = 4.250" rte.. 4 ' Production String Jewelry Detail O. 5 # Depth (RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.990" Tubing Hanger, 3 -1/2" X ' 6 2 3,275' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL DV Collar ,, 7 ` M 3 5,465' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL @8,036' .1 1 4 7,484' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL 5 +/- 8,071' 4.28' 2.813" 4.290" CMU Sliding Sleeve 8 6 +/- 8,122' 1.13' 2.813" 4.520" X- Profile Nipple 9 7 +/- 8,269' 8,269' - - ESP Cable CBLTOC 8 +/- 8,304' 8,304' - - Dual Chemical Injection Lines 8,366° 9 +/- 8,187' — 118' 5.625 "/5.130" Assembly: ESP, 562 series Motors and TOL at ,. 10 +/- 8,304' 513 series Pumps; Intake at 8,249' 8,379' • ; } �. 10 8 - 4.250" - Liner top 7" window at 11 9,499' - - - Baker E -22 Anchor Seal Assembly 8,701' 12 9,499' 4.33' - - Liner Top Packer, Baker SC-1L Packer 13 10,890' - - 1.75" Teledyne Bridge Plug 14 11,319' - - - Landing Collar 15 11,386' 10.0' - - FISH: 10' BHC /AC logging tool 8, 9 9 h 11 Perforation Data 12 ZONE TOP BTM Spf Comments ` G 10,698' 10,724' 4, 4, 4, 6 Perf (11/12/03), (3/27/01), (2/25/01), (9/17/10) "► H -1 10,800' 10,820' 4, 4, 6 Perf (12/05/95), (5/10/91), (9/17/10) 6" @ 10,666' H -2 10,835' 10,854 4, 4, 6 erf ( 10 0 5/95), (4/ 10,849') �; " 4:4 H -3, H -4 _ 10,900' 10,912' 1 Perf (4/23/91) Isolated i ";'1 ;.1 G to H-1 3," l.' H -2 x Tag Till at 10,861' f 9/17/2010 13 H-3/H-4 XAr e :, r 14 2-7/8" @ 11,386' % dt. 6 15 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0 at 11,000' MD SRU 32A -33 Proposed Schematic 7- 11- 11.docx Updated by STP 7 -11 -2011 Chevron • fts Summary of Key Energy Rio #3 Specifics SRU 32A -33 Replace failed ESP The SRU 32A -33 workover will involve pulling the failed ESP completion, and running a new ESP completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration Rig Model The rig model is a Hopper Hydra- hoist, Back -model GXXTA. Drawworks The drawworks are GXXTA -MD 10x42; w/ Sand Drum 15,000 ft — 9/16" sand line. Derrick The derrick is a 102' tall telescoping double, with 260,000 lb capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a Pipe Wrangler, 45' long, 8.5' wide, 9' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2 -7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 11" Hydril GK. Double gate, 5M, 11" Shaffer LWS w/ blind ram and pipe ram (3 -1/2 ", or 2- 7/8 "x5" VBR rams). Mud Cross, 5M, 11" w/ 2 each 3 -1/8" 5M x 2- 1/16" 5M Double Studded Adapters. BOP Diagram See attached. Accumulator 240 gallon KOOMEY Accumulator System on an enclosed skid unit. Includes 7 functions with manual bypass and remote panel. Sixteen 15 gallon accumulator bottles. 462 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale / shaker is also available that is a 3'x4' Jr. Standard - hydraulic driven. Pumps The primary pump is a National JWS -400 7 "x4.5" Triplex rated to 5,000 psi on an independent skid. A secondary pump is a Gardner Denver PAH 8 "x4.5" Triplex rated to 4,000 psi on an independent skid. The primary pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. The secondary pump will be used in conjunction with the primary pump as needed for increased flow rates and used for fluid disposal in well SCU 43 -04WD (PTD 161 -029). Kill Line Key Energy Rig #3 Specs (SRU 32A-33) rev0.doc 7/07/11 Chevron • • The Kill Line /Circulating Line consists of 2 ", 5,000 psi hose with Unibolt/Hub- flanged connectors. �- Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2- 1/16 ", 5M valves attached to the mud cross with co -flex hose with a Unibolt/Hub- flanged connectors. Choke Line The choke line consists of 2 ", 5,000 psi hose with Unibolt /Hub - flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2- 1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co -flex hose with a Unibolt/Hub- flanged i connectors. Choke Manifold See attached. Choke Return Line /Diffuser Line The diffuser line will consist of 2 ", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Trip Tank A trip tank will be placed adjacent to the rig with the capability of fluid transfer to the circulating system. Gas Detection There will be a gas LEL monitor and a H2S monitor placed at the work platform (rig floor), shale shaker, upper cellar area, and lower cellar area. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 32A-33) rev0.doc 7/07/11 • • • Swanson River 2011 SRU 32A -33 ESP 07/11/2011 Key Stripper head asst' ui'iiriiriirnI 1.77' P 4. 111 111 111 111111 • 0 3.96' Hydril GK 11 -5000 III III III Ill 111 ) Shaffer LWS Blind Ram o 111_ _1- 2-7/8" 2.75' x 5" : — 11" 5000 VBR Ram 10 11111.11111 Choke and Kill lines 2 1/16 5M ili'lil'L11'i1i'III w/ unibolt connections 2.00' p . �/ 1 / 11 1,� I I is 1 �� /.. 1 i 11■11 i '4' j I i ;� II a 11 i i ii 111■I1I 111 111 111 MIL. I .50' Xover spool 11 5M X 11! 111 1 11111 111 7 1/16" 5M lilliluiiillil Tbg head attachement, Vetco III Ground Level FTC -IT, 7 1/16 5M FE X 7 1/16 5M FE, special made to 40" in length • • Chevron Swanson River 2011 Choke Manifold 07/07/2011 Blooey Line To Gas Buster l it III. III li 81 1=5_ I MP' MEW .4.. I I `/ ;...,.:,.; /: 1 ;_ir :,.. - III III �� I► ��1 :°' 0® 1I I e, a - " I 0 0 11 0'- , ra v mip t.• I MIN A111$111 . E. . 0, ' lei Iii nil 4. CommoillW , 00 EMI IA 11 aillM11/111M III l 111 III - \ / III IV . B op 1 et„.:Ncill Ito kfl oil 0 1 o ' , o 000 ® - AL '�r '• `fir '�� 11 UN I I Q � r rip valves 2 1/16 5M on Super Choke ,, r ,,, manifold to w-- O ^�`� Unibolt Connection 0p`�0 - `0 0 1 .� w ( STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations LJ Stimulate LJ Other ,/ ESP Conversion & Performed: Alter Casing ❑ Pull Tubing ❑Q Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Fill Cleanout Change Approved Program ❑ Operat. Shutdown ❑ Perforate [A Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development F±1 Exploratory ❑ 191 -014 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 133 - 10164 -01 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028399 [Swanson River Unit] Swanson Riv Unit (SRU) 32A -33 9. Field /Pool(s): I Swanson River Field / Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,396 feet Plugs measured 10,890 feet true vertical 11,168 feet Junk measured 10,851' (fill) feet Effective Depth measured 10,890 feet Packer measured 9,499 feet true vertical 10,735 feet true vertical 9,489 feet Casing Length Size MD j TVD Burst Collapse Structural Conductor 45' 22" 45' 45' Surface 2,555' 13 -3/8" 2,555' 2,554' 2,730 psi 1,130 psi Intermediate Production 8,701' 7" 8,701' 8,700' 6,340 psi 3,830 psi Liner 2,187' 5" 10,566' 10,454' 10,140 psi 10,490 psi Liner 1,887' 2 -7/8" 11,396' 11,168' 10,570 psi 11,160 psi Perforation depth Measured depth 10,698'- 10,724', 10,800'- 10,820', 10,835' - 10,854 feet / True Vertical depth 10,698'- 10,724', 10,800'- 10,820', 10,835'- 10,854 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" / 9.2# L -80 % 8,155' MD 8,154' TVD Baker SC -1L Liner 9,499' MD �� / Packers and SSSV (type, measured and true vertical depth) To p Packer (9, TVD) il/ 11. Stimulation or cement squeeze summary: Inte rvals treated (measured): � (.0 to ,�� ?p�9 �� + �� S1t4ED NCil UIi 1 Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 380 psi 90 psi Subsequent to operation: 95 300 1505 175 psi 165 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development Q ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil t, Gas LJ WDSPL LJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 1 310-257 Contact Ronnie Santos 263 -7978 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 11/17/2010 i C Form 10-404 Revised 10/2010 t�103D Wtl/��+ S NOV 1 9 20- Submit Original Only Adik Chevron W Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI IChevNo Original RKB (ft) Water Depth (ft) SRU 32A -33 SWANSON RIV UNIT 32A -33 FEDA028399 5013310164 IQA5337 187.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Artificial Lift Revision Major Rig 9/1/2010 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SRU 32A -33 501331016401 1910140 OWWW 0 0010 06 1 0 0 Operations Summary RU slickline, pressure test lubricator 250psi low /2500psi high, pulled /LD tubing patch at 6,675' and ran LIB to top of fill at 10,866'. POOH LIB shows GLV looking up. Rig down slickline unit. Rig up wireline unit. P /test lubricator, pump -n -sub, and wireline valve to 250 psi low /2500 psi high. MU and RIH with 1- 13/16" x 5" jet cutter. Tag fill at 10,849' RKB WLM, pulled up hole and cut tubing at 9,482'RKB WLM. Tool stuck after firing. Pulled out of rope socket. POOH. Top of fish neck at 9,448'. RD and secure well. Operations Summary Rig up slickline unit. Makeup fishing assembly. P /test lubricator to 250 psi low /2500 psi high. RIH to top of fish at 9,462'. Made 4 unsuccessful attempts to catch fish. Decided to leave fish in hole and wait until rig moves on the well. POOH, rig down and secure well. std a 6 6 a;Y Operations Summary Notified AOGCC and BLM on 9/3/2010 09:41 H of upcoming BOPE test. Bill Diel (BLM) waived to witness test at 10:35H and Jim Regg ( AOGCC) waived to witness test at 10:44H. MIRU Key Rig #3 and associated equipment. Kill well with 60 bbls of clean 3% KCL. Install BPV. ND tree. NU BOPE. Test BOPE and related equipment to 250 psi low and 3000 psi high for 5 minutes each test with 2 -7/8" test joint. Change to 2 -3/8" test joint. 9161201a 00;00 91 � Operations Summary Continue BOPE test. Test annular preventer to 250 psi low and 1500 psi high for 5 minutes each test. Pull BPV and install TWC. Test blind rams to 250 psi low and 3000 psi high. MU landing joint to tubing hanger. Circulate hole clean. Unseat tubing hanger free with 10 kips. PU for pipe movement. String parted at 62 kips. Close annular. RU and RIH slickline with 1.75" concave DD bailer. Tag obstruction at 8938'. POOH with DD bailer with small amount of scale and tool face showing metal contact. RIH with mule shoe DD bailer. Tag obstruction at 8947'. POOH DD bailer with no recovery and scuff marks on edges of mule shoe. RIH with 1.72" LIB to obstruction at 8945' and POOH. LD landing joint. POOH LD 2 -7/8" tubing. Operations Summary POOH LD 2 -7/8" and 2 -3/8" tubing GLM and jewelry. Tubing parted at corroded 2 -3/8" pup joint 4" above first 2 -3/8" GLM. Change 2 -3/8" rams to 3 -1/2 ". Install test joint and test 3 -1/2" rams to 250 psi low and 3000 psi high. RIH spear fishing assembly with 2 -7/8" x 3 -1/2" workstring. 1'712010 aa:o0.� s � Operations Summary Continue RIH to top of fish at 8952'. Slack off 8K on fish and pump thru string. Successfully engaged fish and jarred free. POOH with complete recovery. Slickline run failed to recover the jet cutter tool assembly. LIB run indicated 2 -3/8" tubing stub. MU and RIH with overshot to TOF at 9482'. 9812 0.00:o0 45 71 Operations Summary POOH and LD fish (2 -3/8" tubing stub, E- Anchor, seal assembly). WLEG from bottom of seal assembly was LIH. Slickline fishing failed to recoverjet cutter tool assembly but able to retrieve WLEG. Made 6 bailer runs from 10724' to 10748'. 9r9raa�0 ao:oo 9i1o1a0�a ao:oo p� x- � rMk� . �; � , << Operations Summary Ran additional 10 bailer trips from 10748' to 10761'. Ran 6.0" GR to DV collar at 8036' and 5.25" GR/junk basket to 8365' with no obstruction. Made a request for early BOPE test to AOGCC and BLM on 9/9/2010 at 2:15PM. Witness to BOPE test waived by AOGCC inspector Chuck Scheve. Test BOPE to 250 psi low and 3000 psi high. is Aw 91101201o.., .00 41 }t010 0aoa Operations Summary Finish BOPE test. RU to run 2 -3/8" x 1.66" BHA. 02010 00:00 Operations Summary MU and RIH 2 -3/8" x 1.66" CS- Hydril BHA with drag tooth bottom. Continue RIH with 3 -1/2" x 2 -7/8" workstring. Added 605 gals water soluble solvent to active system. Circulate hole clean at 8319'. Continue RIH and tag at 10772'. Spot 55 gals neat water soluble solvent on bottom. Establish pump rates thru string and reverse. Work tool and wash down on fill to 10786'. t1rr2010 oo -,9c ara oa•o Operations Summary Continue washing down and reverse circulating on fill to 10808'. Hole started taking fluid gradually increasing while washing down and reverse circulating on fill to 10846'. Wash down with rotation but no progress. POOH using double pipe displacement with 3 -1/2" and 2 -7/8" workstring. POOH LD 2 -3/8" x 1.66" BHA. No fish recovery. RU slickline for fishing /bailing operations. Operations Summary Run slickline fishing tools and recover LIH jet cutter tool assembly. Ran DD bailer to 10864' RKB with minimal sand recovery. Ran and set packer plug at 9499'. Test plug to 1500 psi for 15 minutes. Spot 673 Ibs of sand mixed with polymer slurry on top of packer plug. PUMU 7" cleanout BHA and RIH. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNO Original RKB (ft) Water Depth (ft) SRU 32A -33 SWANSON RIV UNIT 32A -33 FEDA028399 5013310164 QA5337 187.00 814/2010 00 = 9/ 01 10 00 :00 a T Operations Summary Ceeanout to TOL at 8379'. Circulate hole clean with hivis sweep followed by 3% KCL. POOH LD 7" cleanout tools. PUMU 6" drift BHA and RIH to TOL at 8379'. POOH LD BHA. 9/1$11 ,0110 ' 00:00 , 91116120110 00:00 Operations Summary Install new riser - hanger spool for ESP penetrator. Test new flange connection to 250 psi low and 3000 psi high for 30 minutes. MU and RIH with plug retrieving tool to top of sand at 9440'. Washdown sand to top of packer plug at 9499'. Unexpectedly lost returns immediately after retrieving tool came in contact with the packer plug. Well on vacuum when tool is engaged with plug. 13E1/201...0000 – 9/17(201 "00:00. =: Operations Summary Allow well pressure to equalize. POOH and LD packer plug and retrieving tool. RU slickline and run DD bailer twice. Tag at 10864' RKB. LD 2 -7/8" x 3 -1/2" workstring. r� 0,0 :a ,,,�:. t1 X2010 00:00 = ' Operations Summary LD 3 -1/2" workstring. Test BOPE to 250 psi low and 3000 psi high. Test annular preventer to 250 psi low and 1500 psi high. Test witness waived by AOGCC inspector Chuck Scheve. RU and test wireline lubricator to 250 psi low and 1000 psi high. Re- perforated H2 interval 10835'- 10849' (14 ft), H1 interval 10800'- 10820' (20 ft), and G interval 10698'- 10724'(26 ft) with 6 SPF 60 degree phased hollow carrier guns. Prepare to run ESP. „ 00.- $/19/201Q 00.00 Operations Summary PUMU ESP assembly with jewelry and RIH with 3 -1/2" 9.2# L -80 IBT tubing. 9!1.912010 00 :00 = 9%20/3010 00:00 MV T- Operations Summary Land 3 -1/2" ESP completion with bottom of assembly at 8336'. ND BOPE. 9/20/2010 00:00 - 9/211204 0 00:00' Operations Summary NU and test tree to 250 psi low and 3000 psi high for 30 minutes. Turnover well to production and release rig. 10/1` 3121 tE111�0 Operations Summary Prep location for key rig. MIRU Key Rig #3 and associated equipment. Shutdown ESP. Bleed down well. 0/14/2010 6 0 301161201:0 -`, Operations Summary MIRU slickline. Pressure test lubricator to 2500 psi. Set PX plug and prong in x- nipple. Shift sliding sleeve open. Pump 52 bbls 3% KCL down tubing to confirm sliding sleeve is open. Operations Summary ND tree. NU BOPE. RU floor. Test annular preventer to 250 psi low and 1500 psi high. Test all other BOPE to 250 psi low and 3000 psi high. BOPE test witness waived by Jim Regg of AOGCC and Tom Zelenka of BLM. Pump 100 bbls 3% KCL down annulus and monitor well. PU and LD tubing hanger. POOH and standback 3 -1/2" tubing. Test at penetrator splice is good. Test at cable above splice at 1669' is good. Test at cable below mid splice is good. Pumps, intake separator, and seal protectors rotate free. No trash in intake. Test on top motor section indicates "grounded ". 10N612010.00 :00 .1011r 12. ; 000.00 .x.: �,�" a , Operations Summary Bottom motor section tested good. Seal protectors were almost out of oil and the remaining oil was very dirty. Rerun completion with new top and bottom seal protectors, new top and bottom motors, new MLE, and new flat pack. Rerun x- nipple and run new sliding sleeve. rll'2`01Oo 812Q 0000 p h ° #,, r Operations Summary Land 3 -1/2" 9.2# L -80 IBT ESP completion at 8,304' RKB and run electrical tests. ND BOPE. NU and shell test tree to 250/5000 psi. RD equipment. 1,0118/2010 00;00. 1011912010 00:06 Operations Summary Turnover well to production. Startup ESP. RD and demob rig. 10/19120/0 OOc00A1 x k Operations Summary Finish demobe off location. I I evro IRW - - SRU 32A -33 Actual Wellbore Schematic RKB:198.3' KB / GL: 172' AMSL KB- THF:26.3' KB Casing and Tubing Detail 1 Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22" @ 46' 22" Structural Surface 45' - Cemented 54.5# J-55 Surface 1,023' 600 sxs 116# , sta e 1 ( 9 ) Dv collar 13 -3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600 sxs 116# (stage 2), @ 1,023 y,, 54.5 #, J -55 1,025' 2,555' 64 sxs 116# (top job) 29 #, N -80 Surface 364' BTC / 6.184" 26 #, N -80 364' 1,282' BTC / 6.276" 13.318" 2A 23 #, N -80 1,282' 4,687' BTC 16.366" @2,666' 7" Surface 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 29 #, N -80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26 #, P -110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" L . 26 26 #, P -110 8,038' 8,701' 8RD / 6.276" 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg 6,,176176' ' ca 2 -7/8" Liner 6.5 #, N -80 9,499' 11,386' 8RD-Mod/2.441" 18 bbl 15.8 ppg Tubing 3 -1/2" Prod 1 9.2 #, L -80 Surface 8,155' IBT / 2.992" Cpig OD = 4.250" 2 C Production String Jewelry Detail 3 # Depth (RKB) Length ID OD Item 1 26.3' 0.62' 2.990" 6.990" Tubing Hanger, 3 -1/2" X 4 2A 3,275' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL DyCollar 2B 5,465' 6.34' 2.867" 5.140 "/3.900" GLM, GLMAX- 1.ORSL @8,036' 2C 7,484' 6.34' 2.867" 5.140 "13.900" GLM, GLMAX- 1.ORSL 3 8,039' 4.28' 2.813" 4.290" CMU Sliding Sleeve 4 8,090' 1.13' 2.813" 4.520" X- Profile Nipple s Assembly: ESP, 456 series Motors and 5 8,155' — 8,304' 149' 5.130 "/4.56" CBL TOC 513 series Pumps 8,366' 6 8,379' - 4.250" Liner to TOL at 6 7 9,499' - - - Baker E -22 Anchor Seal Assembl 8,379' 8 9,499' 4.33' - - Liner Top Packer, Baker SC -1 L Packer 7" window at 9 10,890' 1.75" Teledyne Bridge Plu 8,701' 10 11,319' - Landing Collar 11 11,386' 10.0' FISH: 10' BHC /AC logging tool Perforation Data TOL at 7 ZONE TOP BTM S f Comments 9,499' G 10,698' 10,724' 4, 4, 4, 6 Perf (111/12103), 3/27/01 2125/01 9/17/10 $ H -1 10,800' 10,820' 4, 4, 6 Perf (12/05/95), 5/10/91 9/17/10 H -2 10,835' 10,854' 4, 4, 6 Perf (12/05/95), (4/28/91) 9/17/10: 1 835'— 10,849' 6" @ 10,566' H 3, H -4 1 10,900' 10,912' 1 1 Perf 4/23/91 G H -1 H -2 Tag Till at 10,861' 9 9/1712010 H -3/H -4 10 2.718" @11,386" 11 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A-33 Recompleted WBD 10 -17 -10 ESP docx Updated by RMS 10 -17 -2010 Chevron Francesco Castro Chevron North Ame i a Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcastro @chevron.com DATE October 21, 2010 To: AOGCC Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 r°t&t. xy .",.��`" ' ' r k ", ' y ,. 7 #'s -'" - WEL i SRU 32A -33 PERFORATION RECORD 9/17/2010 10698 -10849 X X SCU 34 -08 2.25" TUBING CUTTER 8/3/2010 10000 -10310 X X i �0c ;1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to— 263 7828. Received By: Date: �r • ~~Q~~ 0~ l~~Q~~{Q /~..o...«~o~a.ow Timothy C. Brandenburg ®~ " 1 Drilling Manager ~`.. ' 1 Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: Swanson River Field, Hemlock Oil Pool, SRU 32A-33 Sundry Number: 310-257 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '~~~ Daniel T. Seamount, Jr. Chair DATED this day of August, 2010. Encl. 5-~`~ ~~ ~~~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ' ~~- APPLICATION FOR SUNDRY APPROVA ,.,.,~ . 20 AAC 25.280 •. ~ ~+ ° _i F~ ~;~~ ~'(?''~~)"NISSIOfI 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ * lA~~ved Program ^ Suspend ^ Plug Perforations ^ Perforate ^~ _ Pull Tubing ~' Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ ESP Conversion 8 Fill Cleanout 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^~ Exploratory ^ 191-014 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10164-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ Swanson Riv Unit (SRU) 32A-33 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028399 [Swanson River Unit] ~ i Swanson River Field /Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,396 11,168 10,890 10,735 10,890' 10,850' (fill) Casing Length Size MD ND Burst Collapse Structural Conductor 45' 22" 45' 45' Surtace 2,555' 13-3/8" 2,555' 2,554' 2,730 psi 1,130 psi Intermediate Production 8,701' 7" 8,701' 8,700' 6,340 psi 3,830 psi Liner 2,187' 5" 10,566' 10,454' 10,140 psi 10,490 psi Liner 1,887' 2-7/8" 11,396' 11,168' 10,570 psi 11,160 psi Pertoration Depth MD (ft): ~ Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): / 10,698'-10,724', 10,800'- 10,568'-10,591', 10,658'- 10,820', 10,835'-10,854', 10,675', 10,688'-10,704', 2-7/8" x 2-3/8" 6.5# N-80 x 4.7# N-80 Surf-8,910' x 8,910'-9,499' 10,900'-10,912' 10,743'-10,753' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): / Baker SC-1 L Liner Top Packer / N/A 9,499'MD (9,489'ND) / N/A 12. Attachments: Description Summary of Proposal ^~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development Q - Service ^ 14. Estimated Date for 8/ /2010 15. Well Status after proposed work: Commencing Operations: ~ Oil ^~ - Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: N/A WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C. one 276-7600 Date 8/18/2010 COMMISSION USE ONLY Sund Numb l tif th tiv it diti f N C i i t t C er: 3'V ~'C7~/~ ry : omm on so a represen e may w ness on ons o approva o y ss a a Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: " ~',~ S~ ~0 ~ E -l p ~v 00 O [D S.~ . Subsequent Form Required: [ ~ . 4 p t, f . APPROVED BY D t ~ ~/~! ~-~ Approved by: COMMISSIONER THE COMMISSION a e: , ~-~"~ ~•-•„ n~u~fL~UIU Form 10-403 Revised 12/2009 y~^ ~ (~ ~ (1 ~ (~ I ~ ~ Subm' 'n Dupl' t~O Chevron • • Swanson River Unit Well #SRU 32A-33 8/12/10 OBJECTIVE: • Pull existing gaslift completion, cleanout 7" casing, install new tubing spool, re-perforate existing zones and run new ESP completion. PROCEDURE SUMMARY: 1. RU Slickline. Pressure test lubricator 250psi low/2500psi high. 2. RIH and bail fill to bridge plug at 10,890' (+/-). ~ 3. RU Eline. Pressure test lubricator 250psi lowl2500psi high. 4. RIH and cut 2-3/8" tubing at 9,480' (+/-). 5. MIRU Key Energy Rig #3. ~-~" 6. Install BPV, ND tree, NU BOPE & test same 250psi low/ ,000 i high, pull BPV. ~ 7. Pump 3% KCI down tubing and annulus. Pull cut 2-7/8" x 2-3/8" production tubing from 9,480' (+/-) 8, Change out 2-3/8" pipe rams and install 3-1/2" pipe rams. Test same 250psi low/ 3,000 psi high. 9. RIH ar}d'pull cut 2-3/8" tubing and fish seal assembly out of packer at 9,499'. 10. S packer plu in packer at 9,499' (+/-). Test plug to 1,500 psi. 11. Scrape 7" casing to 5" liner top depth of 8,379'. 12. ND BOPE. NU new tubing spool. NU BOPE. Shell test to 250psi low/3000psi high. ~ 13. Pull packer plug. 14. RIH w/ 3-1/2" x 2-7/8" workstring and tag up on packer at 9,499' RKB. 15. RIH and reperforate existing zones: H-2 (+/-10,835' to +/-10,854' RKB), H-1 (+/-10,800' to +/-10,820' RKB), and G zone (+/-10,698' to +/-10,724' RKB). 16. POOH and L/D 3-1/2" x 2-7/8" workstring. 17. Run 3-1/2" tubing ESP completion to 8,350' (+/-). / 18. Set BPV, ND BOPE, NU Tree. 19. Release Key Energy Rig #3. 20. Return the well to production. Current BHP: 2,830 psi @ 10,580' TVD Max Downhole Pressure: 2,830 psi @ 10,580' TVD (Based on SITP = 800 psi, fluid level at 5,988' and a produced water gradient) MASP: 1,772 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth). ~ SRU 32A-33 Operation Summary 8-12-10.doc REVISED BY: STP 8/12/10 zr' ~ 45' DV Collar ~ 1,023'; t 133/8" ~ 2,5~, Calc TOC s,17s DV Collar 8,035' CBL TOC e,3ss TOLat 8,379' T' window at 8,701' H-1 H-2 Tag Fill 10,850' SLM ~ 1/14/10 H3M-0 Casing and Tubing Detail Size Type WU Grade Top Btm CONN / ID Cement /Other 22" Structural - Surface 45' - Cemented 54.5#, J-55 Surface 1,023' 600sxs 116# (stage 1), 13-3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600sxs 116# (stage 2), 54.5#, J-55 1,025' 2,555' 64 sx 116# (top job) 29#, N-80 Surface 364' BTC / 6.184" 26#, N-80 364' 1,282' BTC / 6.276" 23#, N-80 1,282' 4,687' BTC / 6.366" " 26#, N-80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 7 Surface 29#, N-80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26#, P-110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" 26#, P-110 8,038' 8,701' 8RD / 6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod / 2.441" 18 bbl 15.8 Tubing 2-7/8" Prod 6.5#, N-80 Surface 8,910' 8RD-Mod / 2.441" C I OD = 3.668" 2-3/8" Prod 4.7#, N-80 8,910' 9,499' 8RD-Mod /1.995" C I OD = 3.063" Production Strin Jewel Det ail # De th RKB Len th ID OD Item 1 29.6' 1.9' 2.992" 4.500" Tubin Han er, 3-1/2" 2 31.5' - 2.441" 4.500" X-Over 3-1/2" x 2-7/8" 3 4,021' - 2.441" 5.500" GLM, Camco Model MMGP 2-7/8" x 1-1l2" Drift = 2.347" Gaslift valve installed 4 6,193' - 2.441" 5.500" GLM, Camco Model MMGP 2-7/8" x 1-1/2" Drift = 2.347" Gaslift valve installed 5 6,675' 52' 0.875" 2.441" Tubing patch, set 5/21/10 G-sto /ackoff/s acer/ ackoff/AD-2 sto 6 7,281' - 2.441" 5.500" GLM, Camco Model MMGP 2-7/8" x 1-1/2" Drift = 2.347" Gaslift valve installed 7 8,359' - 2.441" 5.500" GLM, Camco Model MMGP 2-7/8" x 1-1l2" Drift = 2.347" Gaslift valve installed 8 8,379' - 4.250" 6.276" Liner to 9 8,818' - 2.313" 3.668" Slidin Sleeve, 2.313" Min ID 10 8,878' - 2.313" 3.668" X-Profile, 2.313" Min ID 11 8,910' - 1.960" 3.668" X-Over 2-7/8" 8RD-Mod B x 2-3/8" 8RD-Mod P 12 8,962' - 1.995" 3.870" GLM, TMPDX Teled ne 2-3/8" x 1" 1.901" Drift 13 9,466' - 1.995" 3.870" GLM, TMPDX Teled ne 2-3/8" x 1" 1.901" Drift 14 9,499' - - - Baker E-22 Anchor Seal Assembl 15 9,499' 4.33' - - Liner To Packer, Baker SC-1 L Packer 16 10,890' - - 1.75" Teled ne Brid a Plu 17 11,319' - - - Landin Collar 18 11,386' 10.0' - - FISH: 10' BHC/AC to in tool Perforation Data ZONE TOP BTM S f Comments G 10,698' 10,724' 4,4,4 Perf 11!12/03 , 3/27/01 , 2/25/01 H-1 10,800' 10,820' 4,4 Perf 12/05/95 , 5/10/91 H-2 10,835' 10,854' 4,4 Perf 12/05/95 , 4/28/91 H-3,H-4 10,900' 10,912' 1 Perf 4/23/91 2-718" ~ 11,386'+ +~.'~~.'' 18 TD=11,396' PBTD=11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A-33 Actual WBD 5-21-10 doc UDdated by STP 5-21-10 RKB: 2D7.6' KB / GL: 17T AMSL KB-THF: 29.G KB KB-THF: 29.8' KB 1 - zr' ~ ~,4 . 45' DV Collar ~ 1A23' 133/8" 2 2,5~, 3 Calc TOC ~ ,~ 6,179 ~+ q _ ~ DV Collar ~ a,o39 CBL TOC 8,355' TO L at _ :, 9 8,379' T' window at 8,701' lULat ~ }; 10 9,497 a' 11 s" ~ 10,557 G 13 Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement /Other 22" Structural - Surface 45' - Cemented 54.5#, J-55 Surface 1,023' 600sxs 116# (stage 1), 13-3/8" Surface DV Collar 1,023' 1,025' 8RD / 12.615" 600sxs 116# (stage 2), 54.5#, J-55 1,025' 2,555' 64 sx 116# (top job) 29#, N-80 Surface 364' BTC / 6.184" 26#, N-80 364' 1,282' BTC / 6.276" 23#, N-80 1,282' 4,687' BTC / 6.366" " 26#, N-80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), 7 Surface 29#, N-80 6,225' 7,916' BTC / 6.184" 750sxs 116# (stage 2) 26#, P-110 7,916' 8,036' 8RD / 6.276" DV Collar 8,036' 8,038' 8RD / 6.276" 26#, P-110 8,038' 8,701' 8RD / 6.276" 5" Liner 18#, N-80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 2-7/8" Liner 6.5#, N-80 9,499' 11,386' 8RD-Mod / 2.441" 18 bbl 15.8 Tubing 3-1 /2" Prod 9.2#, L-80 Surface 8,200' IBT / 2.992" C I OD = 4.250" Production Strin Jewel Det ail # De th RKB Len th ID OD Item 1 +/- 29.6' +/- 2.0' 2.992" 4.250" Tubin Han er, 3-1 /2" 2 +/- 3,000' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 3 +/- 4,600' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL Drift = 2.867" 4 +/- 6,200' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL (Drift = 2.867" 5 +/- 7,800' +/- 6.0' 2.992" 5.140" GLM, GLMAX-1.ORSL (Drift = 2.867" 6 +/- 8,110' +/- 6.0' 2.813" 4.250" XD Slidin Sleeve, 2.813" Min ID 7 +/- 8,160' +/- 1.0' 2.720" 4.250" XN-Profile, 2.720" No-Go ID 8 +/- 8,200' 150' - 5.133" ESP, 456 series Motors and 513 series Pumps 9 8,379' - 4.250" - Liner to 10 9,499' - - - Baker E-22 Anchor Seal Assembl 11 9,499' 4.33' - - Liner To Packer, Baker SC-1 L Packer 12 10,890' - - 1.75" Teled ne Brid a Plu 13 11,319' - - - Landin Collar 14 11,386' 10.0' - - FISH: 10' BHC/AC to in tool Perforation Data ZONE TOP BTM S f Comments G 10,698' 10,724' 4,4,4 Perf 11/12/03 , 3/27/01 , 2/25/01 G +/-10,698' +/-10,724' 6 Pro osed H-1 10,800' 10,820' 4,4 Perf 12/05/95 , 5/10/91 H-1 +l-10,800' +/-10,820' 6 Pro osed H-2 10,835' 10,854' 4,4 Perf 12/05/95 , 4/28/91 +a ? ~^~ a~F' ~/-10.$54' 6 Pro osed H-3.H-4 10.900' 10,912' 1 Perf 4/23/91 2-718"11,388"~ 14 TD =11,396' PBTD =11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A-33 Proposed WBD 8-12-10 ESP doc Updated by STP 8-12-10 Chevron • • Summary of Key Energy Rig #3 Specifics SRU 32A-33 Workover The SRU 32A-33 workover is to pull the existing gaslift completion, cleanout the 7" casing, isolate the well and install a new spool on the existing wellhead, re-perforate the existing zones and run a new ESP completion. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Confis~uration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft - 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Hydril Single gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-3/8", 2-7/8", or 3-1/2" rams) and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Eight 15 gallon accumulator bottles. 200 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line Key Energy Rig #3 Specs (SRU 32A 33) rev0.doc 7/01/10 Chevron i The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a i single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SRU 32A 33) rev0.doc 7/01/10 Ch_ evron BOPE Diagram SRU 32A-33 Workover 8/12/2010 nular preventer, Hyd . 7 1/16 5M Flanged 3.08' I haffer Chasovoy 7 1/16 5 Plpe Ram 9.00' 0.94' stdd X 7 1y5M stdd I 1.04' haffer Chasovoy 7 1116 5 Plpe Ram stdd X 7 1 5M stdd 2.27' Q• i Blind Ram O• Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M X 2 1/16 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M 1.67' Unibolt HCR Unibolt ~~ Swanson River 2010 Choke Manifold 08/12/2010 Blooey Line To Gas Buster ~ Unibolt Connection 0 a ~` e e Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com March 16, 2006 Steve McMains AOGCC 333 W. ¡th Avenue, Ste. 100 Anchorage, Alaska 99501 Re: Outstanding Sundries Dear Mr. McMains, We have conducted an internal audit of regulatory filings for 2003 and 2004. As a result, several projects were found to have outstanding sundries. We have researched the work and have prepared the sundries to close out the projects left uncompleted. The list of projects includes the following: 2003 Grayling, G-12RD3, Reperforate Grayling, G-24, Reperforate Monopod, A-15RD2, Perforate Steel head, M-01, Repair Casing Patch Steelhead, M-05, Perforate Swanson River, SCU 32-04, Reperforate (3 Sundries) ,1- Swanson River, SRU 12-15, Recomplete c> , ï Swanson River, SRU 32A-33, Reperforate ~ \ q \ - 2004 Happy Valley, HV-A02, Coil Tubing Clean Out In order to assure that we do not have any such gaps in the future, we have implemented a database to track all drilling related AOGCC filling requirements. Please contact me directly at 263-7657 if you have any questions about these filings. Sincerely, Z::fß G Timothy C. Brandenburg Drilling Manager Attachments Cc: Well Files TB:sk Union Oil Company of California I A Chevron Company http://www.chevron.com .. _ STATE OF ALASKA . ALASWOIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate Ld Other ~ Reperforate Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryO 191-014 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-133-10164-01 7. KB Elevation (ft): 9. Well Name and Number: 15' SRU 32A-33 8. Property Designation: 10. Field/Pool(s): Swanson River Field Swanson River Field/Hemlock 11. Present Well Condition Summary: Total Depth measured 11,396 feet Plugs (measured) 10,890' true vertical 11,168 feet Junk (measured) Effective Depth measured 10,890' feet true vertical 10,735' feet Casing Length Size MD TVD Burst Collapse Conductor 30' 22" 30 30' Surface 2,540' 13-3/8" 2,540' 2,539' 2,730 psi 1 ,130 psi Intermediate Production 8,685' 7" 8,685' 8,684' 6,340 psi 3,830 psi Liner 2,187' 5" 10,566' 10,454' 10,140 psi 10,490 psi Liner 1,887' 2-7/8" 11,386' 11 ,160' Perforation depth: Measured depth: 10,698' to 10,912' True Vertical depth: 10,568' to 10,753' Tubing: (size, grade, and measured depth) 2-7/8",6.5#, N-80 @ 8,911'; 2-3/8", 4.7#, N-80 @ 9,499' Packers and SSSV (type and measured depth) 5" x 7" liner top packer @ 8,379'; Baker SC-IL Packer @ 9,499'; 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 100 0 617 1,640 psi 290 Subsequent to operation: 137 0 845 1,620 psi 450 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I ~Undry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager r?--~7é'^ c::;/ (~\ Date l.:- z ( - c;.G,. Signature < Phone 907-276-7600 Form 1 0-404 R~ 04/2004 ¿.-/ AFE 161531 RBDMS BFl MAR 1 i"j zoOO, Submit Original Only 4 .. e e 11/12/03 MIRU/PJSM. Pressure tested to 2200 psi. RIH with hydraulic jars, CCL, and 10 foot gun. TP @ 290#, CP @ 1500#. Tied in with Atlas CBL (4-20-91) and tubing tail and short joints, no problem. Fired gun and perf 10,714- 10,724 (10 feet). Logged up and POOH. No problem. RIH with hydraulic jars, CCL, and 10 foot gun. TP @ 390#, CP@ 1500#. Tied in. Fired gun and perf 10,704 - 10,714 (10 feet). Logged up and POOH. No problem. RIH with jars, CCL, and 10 foot gun loaded for 6 feet. TP @ 390#. Tied in. Fired gun and perf 10,698 - 10,704' ( 6 feet). TP@ 420#. Logged up and POOH. No problem. POOH. RD/MO. SRU 32A-33, 161531 morning report summary, CONFIDENTIAL: last revised 1/23/2006, Page 1. Well Name: SRU 32A-33 Unocal Alaska Field: Swanson River Soldotna Creek API: 50-133-10164-01 191-014 Well Status: Oil RKB: 15' TO/TVO: 11,396'/11,168' PBTD/PBTVO: 11,319'/11,101 3 Cas!n Detail Size Wt Type 22" ctor 13-3/8" 54.4# Surface 4 7" 23-29 Production Casing 5" 18# iner 2-7/8" 6.5# 5 Tub!n Detail Size Wt Grade Top (FT) Btm (H) 2-7/8" 6.5# N-80 0.00 8,911 6 2-3/8" 4.7# N-80 8,912.00 9,499. Jewel Detail Type 1. Tubing Hanger 3-1/2" 2. X-Over 3-1/2" x 2-7/8" 3. Cameo Model MMGP GLM 2-7/8" x 1-1/2" 4. Cameo Model MMGP GLM 2-7/8" x 1-1/2" 5. Cameo Model MMGP GLM 2-7/8" x 1-1/2" 6. Cameo Model MMGP GLM 2-7/8" x 1-1/2" 8,339' 8 7. 5" x 7" Liner Top Packer 8,379' 8.2-7/8" Baker Sliding Sleeve, ID 2.313" 8,875' X 9 9.2-7/8" X Nipple, ID 2.313" 8,877' 10. X-Over 2-7/8" x 2-3/8",101.960" 8,910' XO 10 3/8" x 1" 8,950' 9,454' 9,498' 11 9,499' 9,509' 15. Bridge Plug (set 5/10/91) 10,890' 12 16. Baker-Brown Type Landing Collar 11,319' Baker-Brown Type Float Collar 11,352' 13 Baker-Brown Type Float Shoe 11,384' 17. Fish Below 5" Shoe 10' BHC/AC Logging Tool 11,396' 14 Perforation Detail 3/01,11/03 6 G-Zone Open 10,698.00 10,70400 6.00 3/01,11/03 6 G-Zone Open 10,704 10,714.00 10.00 3/01,11/03 6 G-Zone Open 10,714. 10,724.00 10.00 May-91 4 H1 Open 10,800.00 10,820.00 20.00 Apr-91 4 H2 Open 10,835.00 10,854.00 19.00 Apr-91 1 3,H4 Below BP 10,900.00 10,912.00 12.00 ILast Revised: 11/23/2006 I Revised By: IDED Unocal Alaska 909 W 9th Ave Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 Email: oudeand@unocal.com UNOCALi) .,c-.'-Alaska Debra A Oudean G & G Technician February 26, 2004 DATA TRANSMITTAL To: From: Lisa Weepie Debra Oudean 333 W 7tn Ave, Suite 100 909 W. 9th Avenue Anchoraqe, AK 99501-3539 Anchoraqe, AK 99519-6247 AOGCC Unocal Alaska Transmitting as follows: , COMPLETION RECORD SAFE 1.56 HSD PJ : 5 INCH .. . . . . ... ....... . PERF RECORD 111/16 POWER SPIRALS 7.5 SPF 5 INCH J &:{J-Œ :~~~PlETION RECORD 111/16 POWER SPIRALS 7.5 FH . ~ ~I }~RU 213-1 0 ~~~~r~~E~G6RD 2 HSD 6 SPF POWERJET im ¡SINGH 8/2312003 3090-3614 188 - Jð T SRU 242-1SlcOMPLETION RECORD 2.5 ~SD 6 SPF PJ ~ , 8/23/2003 3590-4211 . ] <:] r~ 0 ) i SRU 32~-33 ~OMPLETION RECORD,1.56 HSD PJ 6~,PF".. 5 INCH .." ' , 11/1,212003: 9369-10815 I ù:é5-CO'i-1SRY 34-28RESERVOIR SATURATI()N TOO~_SIGMJ\ MODE, ,I? INCH, '1,,1/10/2004;14300-7300 , J 9'-1- o~ SRU 41A:a-GAMMA RAY GGl 1.56 POWER JETS 1606 HMX SiNGH. 2I1212OO4fg7 40-10590 .:~- I!~~', 4i~l~~i {t¥.{~~dr 11/13/2003; 1O,1.?5~10450,' ,,{, 1,: .., 1 IdL)Lj 9/16/2003: 5016-5018.5 1 0' , ~~J c;? 4.L.j 1 0/1 12003 ¡ 5380-5141 1 . ~î j J ;;?t-J L) f- 1 1 J()tfLj 1 1 1 )tJ .L./~ 1 1, 1 Jr)LJL I. , .1 1 : ' , 1 J () J-I L, 1; r 1 If).'-J'J RECEIVED sct\NNEC' MAr~ 1 Qj 2004 FEB 2 7 2004 l-\laska Oil & Gas Cons. Commisioo. Þ¡nchorage of this transmittal or FAX to 907 263-7828. Date: ~<::--., '" \:.J. \~ ~~ -m ~ J"'.. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager September 7, 2001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn' Mr. Tom Maunder Subject: Swanson River unit Well SRU 32A-33 APl No. 50-133-10164-01 10-404 Perforate G-Zone Dear Mr. Maunder: Please find enclosed in duplicate Form 10-404 for the perforation of the G-Zone in well SRU 32A-33. The following intervals were perforated on 3/27/01: Bench Top Bottom Feet G 10,698 10,724 26 If you have any questions, please contact Ralph Holman at 263-7838. Dan Williamson Drilling Manager /~laska Oil & Gas Cons, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown: Stimulate: Plugging: ~ Perforate: X Pull tubing: Alter casing: Repair well: Other: 2, Name of Operator Union Oil of California (Unocal) 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth At total depth 1990' FNL, 1133' FEL, Sec. 33, T8N, R9W, SM 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: 6. Datum elevation (DF or KB) RKB: 198', GL 172' 7. Unit or Property name Swanson River Unit 8. Well number SRU 32A-33 feet 9. Permit number/approval number 91-14 10. APl number 50-133-10164-01 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total depth: measured 11396 true vertical 11165 feet Plugs (measured) feet 10890' (Bridge plug) Effective depth: measured 11319 true vertical 11098 feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 30' 22" Driven 30' 2540' 13-3/8" Yes 2540' 8685' 7" Yes 8685' 2187' 5" 325 sx 8379'-10566' measured 10698-10724,10800-10820,10835-10854,10900-10912 true vertical 10569-10592,10656-10673,10686-10702,10741-10751 Tubing (size, grade, and measured depth) 2-7/8" 8911' MD; 2-3/8" from 8912'-9499' MD, 2-7/8" liner from 9499'-11386' MD Packers and SSSV (type and measured depth) Liner top packer @ 8379' MD, Baker "SC-IL" packer @ 9499' MD True vertical depth 30' 2540' 8685' 8379'-1O453' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure 57 30 767 1700 230 20 536 1690 Tubing Pressure 270 34O 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: 16. Status of well classification as: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Form 10-404 Rev 06/15/88 Title: ORIGINAL SUBMIT IN DUPLICATE ON OR BEFORE. E E C:LORlkMlqLM,DOC M~R-06-~8 FRI 16'14 UNOOAL ~SSET G~$ GRP FA× NO. 90726~-~'a74 ' STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well--?' Other!'' P, 0]/09 X (MIT) 2, Name of Operator UNOCAL 3. Address P.O. Box 196247 Anchorage, Alaska 99519 - 6247 5. Type of Well: Development: Exploratory: Stratigraphlc: Service: X 4. Location of well at surface 1874' FNL, 2010' FEL, SEC. 33, T8N, Rgw, SB & M At too of productive interval Same - vertical hole At effective depth Same - vertical I~ole 6. Datum elevation (DF or KB) RKB: 172' feet 7. Unit or Property name Swanson River Unit At total depth Same - vertical hole 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface Intermediate Production 2499' Liner Perforation depth: measured 2520' 2520' 2450' 2450' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 10 3/4" No 7" 700 sx ~ 2499' 2100'-2228', 2234'-2278', 2316'-2424' 8. Well number SRU 32-33 WD 9. Permit nu..mber/ApprmLal number ! (,,c~ ~,-'- ~' 10. APIAumber 50-133-20337 , ,, 11. Field/Pool Swanson River / Sterling 2499' 2499' true vertical Same - vertical hole Tubing (size, grade, and measured depth) 3 1/2" EUE, 9.2# N-80 to 2056' Packers and SSSV (type and measured depth) Baker FH Pkr @ 2000' 13. Stimulation or cement squeeze summary 14, Inter~als treated (measured) Treatment description including volumes used and final pressure Representative Daily Avera.qe .Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7000 900 940 Subsequent to operation 7100 900 960 15. Attachments: Copies of Logs and Surveys run: Report Dally Report of Well Operations: 16, Status of well classification Oil: Gas: Suspended: Service: Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed'. ~-:~-~ ~ q[ ~ Title: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE l~AR-06-98 FRI 16:14 UN00AL ASSET GAS GRP UNOCAL WELL SERVICE RE NO, 90726~7.~74 P, 02/09 Wireline Company: Schlumberger IContractor Supervisor: Rachel Wal~h . . Work BeincJ Donei ..... WFL ............. IFill Taq.0~-d at present Operati.on~: ........ Rig!dldow~......D~...~e Oun Type, Size.., SPF, I~has.e[ ..... UNOCAL_ Supervisor: Lam~ Mcallister/Larry ,G, ,?stie.n [Rep o'~'t"#:. 1 of ' ......... iiii i iii IEj IIIII IIII I I I II I--I IIIIIII I II TIME FROM TO HOURS DETAILS OF OPERATION I I I ~II II Il-- I 9:00 11:45 2:45 I~u SWs [Baker tank & ~hoke mani~_!_d..~l_r~_on wellhead_l~LedU~..,'o_~ ............................ 0:00 Pr~.~re T~t Lubflmt~r ~. Cho~e ManK~td 2riO0 P~ - Ok - .__1..,1..:,~__ ......... 12:00 ...... 0:15 ,J. Rill w/WFL Toot~ to 250'RKB ~annj_e~_n..g...w/!~.p~ I.t Pr... ~ annul~?..p__~__k ................... .... ..~&iP~--. .... ,__1~:.30~ ..... 3:30 ,_..A~t~l~ T,o~! ~..250' t~ rrm~:~g~? _~/.~.., 2,__.~A. 1._~up_-_68.4.1~ - choke~k rat~_& Re-activate ............................ _..~ ,0.j...O0 ! 0.3 f~.~ - RIH to 1000' & meaAAV'___s._-...N.o...n,?~.~ ~tl~~e 1000' -._~R!_H &_..~[ Fil.__l, .......... ...................... 0__:,1:}0 ..... 2156'RKB - Pul~_up_~_.2.0_2_0'_.~.._t~_be_l..,.o~,_E~.} & Look for Up Chan~ ~ Nonez.,P..~ul~u.~_.to ................. .............................. o:oo ~ 1'o~ .~ ?5o'. ,~:r, ~3o', & 7oo'. ^xr, ,~ ~t ~ ~~.~ ............................... ~,o,:~ ..... ~,,n ?oo' & ..-~._5..~...~._.~ _~.1.6. :.1.,5.._. 0:45 Shut/In A~nnulu~ & Rill & Activate T.T._o~I._~.~.:.P_/. & ~4~1980' to ioek for 0,t~0 Uplcha~etin~[: None - Pu~up to 700' & Aclivato lo I~k for~_k. ................ ..................... .~ ....... 0:~0 None ...~_.9~.~ ....... 2_o.:.~ .... ~:3o ..Rj.~._o~ & mo.~o~ 0.-00 o:o0 0:00 0:00 0.'~ 0:00 0:00 .......................... .~ 0:0~ 0:00 i i,i i iii i i i iiii1~1. ,..i ii ..,.,. ,., ,i,,~.. ,.,. i i i i . . COSTS VEND°R''' SERVICE DALLY VENDOR $ERVICE DALLY I I · I11 I I I I I III II ..s...w..9. ............................. .W.~.,,n,..o_w_L.~. ................. !..s,~ .......................................................... AFE AMOUNT: Sg,gO0 DAILY TOTAL: S$,$~4 __ El I J I II II I CUMULATIVE; i,~ll 111 IIIIll I I ,, I J i I II I iiiii III, IIII I I II III I I I SERVICE COMPANY ..... ~E~VI~ ,E, PEtRFORMEO SERVICE ORDI~R NO. ..s_.w._s ...................................................................... .W....~r.EJ~..L...~ .......................................... I I III IIII I II III I Il! III ~IAR-06-98 FRI 16:15 UNOO(~L ASSET GAS GRP FAX NO. 90726,~.~74 P. 03/09 I i i i i i i i i i i i i i__ ii ij[~l i i i i i LOGGING TOOL STRING SKETCH i i i i i ii iii ii i ii ii illllll ii _ i i ~ i ii i ii I iii i i EQF1, 1 11116" OD CALU, 1 11/16" OD ATTB, 1 11/16" OD TDTP, I 11/16" OD TDBN, I 11/16" OD MH-22 Head CCL 37.0 F 31.0 F 30.2 F 29.3 F GR 21.3 F HV 19.8 F 19.7 F RF2 7.4 F RN2 6.9 F 0.7 F TOOL ZERO COMPANY WELL FIELD TOTAL TOOL STRING LENGTH IS 38.7 F. TOTAL TOOL STRING WEIGHT IS 253. LB IN AIR. i i i Ii I I II ii I I i i i II i ! i I i i illl i Union Oil Company of California $CHL, FR 2156,0 F SCHL. TD 215er0 F SRU 32-33WD DRLR. TD Swanson River Unit BOROUGH Kenai STATE Alaska Elev; KB DF GL Water Flow Log I'IAR-06-98 FRI 16: 16 UNOCAL ASSET G,qS GRP FAX NO, 90726a.7..a74 P, 04/09 WFL ADVISOR WFL Interpretation SRU 32-33 WD Company : UNOCAL Field : SWANSON RIVER Logging Date : 08-Feb-1998 Processing Date : 2-MAR-1998 Analyst : Rob North Reference : 98011 Schlumberger GeoQuest Interpretation & Computing Services 500 West International Airport Road Anchorage, Alaska 99518 (907) 562-7669 11RR-06-98 FRI 16:16 UNOCAL UNOO~.~j~.~tSSET G~t$ GRP FRX NO, ?, 05/09 Log Date: 08-Feb-1998 SWANSON HI~EIt SHU 32-55 WD WFL Interpretation Summary A TDT-WFL Survey was run on 8-Feb-1998 to check the Mechanical Integrity of the tubulars under injecting conditions. The tool was run in the up-flow configuration with the annulus open and returning approximately 1200 bpd to the surface. The up-flow survey was then repeated with the annulus closed. The tool was then changed to the down-flow configuration and a down-flow survey was completed. Summary of Findings: Tubing leak between 700 and 750 feet. Small tubing leak at or just above the packer at 2000 feet. Packer at 2000 feet is NC)T leaking. Casing integrity is good. No casing leaks detected. Deepest reading at 2040 feet shows NO upward channeling of injected fluids, WFL Discussion: With the tubing to 7" annulus open during injection the well was returning -1200 bpd to the sudace. This flow rate was substantially higher on the first station at 250 feet (-2500 bpd) but was lowered for the rest of the survey. A small amount of the up flow (-100 bpd) originates from the tubing at or just above the packer at 2000 feet. The majority of the annular flow (-1100bpd) is coming from a tubing leak between 700 and 750 feet. No flow was seen coming up past the packer at 2000 feet. With the tubing to 7" annulus closed no up flow was seen in the well. This indicates the casing integrity is good between the packer and the surface. The absence of any up flow at 2040 feet on this survey also indicates no water is channeling up from the perforations in the casing to open hole annulus. The down flow survey saw NO evidence of annular down flow in the well. Attached is a plot of the WFL results along with tabular listings of the interpretation results and field recordings. II II II II II II UNOOP~L RSSET GR$ GRP FRX NO, 90726~,~-~q,74 P, 08/09 i II[II I II I I I II IIII I UNOCAL, SRO 32-33WD, Swanson River Unit, WFL, 8-Feb-98, (9801 I) 0 0 0 0.0 ~0.0 0~0 250.0 0,0 250.0 O~) C~) IbP~) · '.' ' :rt' III II II 1~0 C~r~ L~.~' I .. , . ' ' ::: p Annular rate increased at surface J 600 ~ ' ;'::J'::'." , ................. ..... : 700 " . ,/, " ,.,,, ,~ ..:': '-' '.'.. :i: ' I T,~., L.k ~,,.,,?,~- 7~o,. ,, · 900 :'; "' · '..: ..... · 1100 .: ...:..:" '"". · ii:: " :::: ~ . '. No UpRow w/ annulus shut-in · t300 -: ':' 1400 ':' ' · ...... !:'-: :':' .. : :.:. 16o0 :.: .. .:. · .v .. ·:.. :. ,:, ~ ~nnular DownFIow 1700 " . . .: ,, o. t800 " " '.'. .... .. 1gO0 :': .: . ',,:. :':.:; ;:.. :' · ,:. " ' :::: < Sm~Jt Tubing leak at pack~ 20()0 ,..'' i .... I~ ~ , ~,, ,Li ! i I I,,..I'll' 2200 ' 2~00 ['.', · . 2400 ........... -'. MflR-06-98 FRI t 6:17 UNOCAL UNOO~L ~SSET G~S GRP F~IX NO, 9072~74 ?, 07/09 Log Date: 08-Feb-1998 SWANSON R1ArER SRU 32-33 WD Job Results: Unocal Water Flow Log we~l #: SRU 32-33 WD 2 3 12 13 14 11 4 5 10 9 OD ,,, , ........... WFL Tool 1.69 - .............. Tubing 3,5 2.992 ,,, 7' Casing ? 6.368 .i~i~ ~ing 2,992 ........ ] :~9 .... e.~ lUb~ ' 7' ann. 6.366 3.5 39.66 ,,, ,, 7'- OH ann. 8.5 7 3Z55 Unocal SRU 32-33 WD WFL FPM Mode 250 too last too ta~l 68.4 Up Flow 250 too fast 10.3 ? tip Flow 500 too last 28 29.7 Up Flow 600 leo fast 30.6 33.2 Up Flow 700 too fast 33.2 31.9 Up Flow 750 2.3 0 0 Up Flow 1000 0 0 0 Up Flow 1000 ?? 3.S 0 Up Flow 1990 2.3 0 0 Up Flow 2020 0 0 0 Up Flow Cae Flowing Csg Flowing Csg Flowing Csg Rowing Csg Flowing Csg Rowing Csg Rowing Csg Flowing Csg Flowing Csg Flowing · approx. detector fpm limits 1 lt. t-30 2 It. 2-60 6fl. 7-180. 15 It, 16-450 20 ft. 22-600 I lntubt.g.! tbg-7' I 7'-OH.; 584 270~ 2228 88 40~ 335 253 1176 967 281 1211 gg6 272 1263 1038 20 91 75 0 0 0 30 138 114 20 91 0 0 0 0 R~utts Indicate lub!.n~ leak baleen 700' & 750', smaller leak right above the p?cker, no channelling 18 7o0 o 0 o Up Flow Csg Shut-in 0 0 O 17 1980 ?? 0 0 Up Row Csg Shut-in 0 0 0 16 2040 0 0 0 Up Flow Csg Shul4n 0 0 0 Results,,,,,, ,, ,indi=ale,, no casin~ leak,above..,, p,_acker ..... depth~ confirmed no ............ channelling behind.casing above 2040' 21 500 0 0 0 Down Flow Csg Shul-in 0 0 O 22 900 0 0 0 Down Flow Csg Shut-in 0 0 0 23 1950 0 0 0 Down Flow Csg Shul-in 0 0 0 Results confirmed no casing leak abovepa~r depth Job Summary: 1 ) The tubing is leaking bolwaen 700'-750' 2) The tubing is leaking right ~} the packer 0 2000' 3) ThQ casing is intact - no leaks documented 4) 'There were no channels documented behind the casing above 2040' Commenls annular rate too high 2500 bpd lowered annular rote annular rate (oo low increased annular rate 2,3 eslimatecl flow detected NQ Interpretation Ii Ii Ii ['1~R-06-98 FRI 16: ~ 7 UNOCAL UNOO~L ~SSET G~S GR? F~× NO. 9072B,?-7.874 P. 08/09 Log Date z 0B-Feb-1998 SWANSON RIVER SRU aZ-3:S WD iii L I I iiiiii Job Results: Unocal Well #: SRU 32-33 WD OD ID [ WFL Tool 1,69 . Tubing 3.5 2.992 7' Casing 7 6.366 Flow Areas O.D, I,D. bpcl/lpm inside tubtr~ 2.gg2 1.69 8.53 tubing - 7' ann. 6,366 3.5 39.59 T.. OH ann. 8.5 7 32.55 Unocal SRU 32.33 WD WFL I FPM [ ~,',io.,~1 !' I 2' I ,s, l~o~o 2 250 too fast too fast 68.4 3 250 t~o fast 10.3 ? 4 1000 0 0 0 5 1000 ?? 3.5 o 9 2020 0 0 0 10 1990 2.3 0 0 11 750 2.3 0 0 12 500 too fast 28 29.7 13 600 too lasi 30,6 33.2 14 700 too fast 33.2 31.9 IRsmams Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Up Flow Csg Flowing Csg Flowing Csg Flowing C$g Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing approx, detector fpm Iimils 1 ft. 1-30 2 ft. 2-60 · 16450 20 ff. 22.600 J BPD intu~r~ [ {b~l- 7: I f' o~,' 584 2708 2226 88 408 335 0 0 0 30 139 114 0 0 0 20 91 0 20 91 75 253 1176 987 261 1211 996 272 1263 1038 Resull$ 16 17 t8 Results 21 . 22 23 Results Indicate tubing !,eak between 7,0q' & 7r50', mailer leak ri~hl above ~he pa. cker. no channellinc~ 2040 0 0 0 Up Flow Csg ,Shut-in 0 0 0 1980 ?? 0 0 Up Flow Csg Shut-in 0 0 0 700 0 0 0 Up Flow Csg ShUt-Lq 0 O U indicate no, casin~ !eak above Packer depth, conlir.m.e, ,d no channelling ,b.._ehind casing above ,2,,040.1- 500 0 0 O Down Flow Csg Shut-in 0 0 0l gOO 0 0 0 Down Flow Csg Shut-in 0 0 0 1950 0 O O Down Flow Csg Shut-in 0 0 0 confirmed no casing leak above p ,a,cker dep!~ Job Summa~/: 1 ) The tubing ts leaking betwee~ 700'-750' 2) The tubing is leaking right @ the packer @ 2000' 3) The casing is intact- no teaks documented 4) There were no channels documented behind the casing above 2040' Comments annular rate too high 2500 bpd Iowerecl annular rate :annular rate too Iow Increased annular rate 2.3 estimated flow detected NQ Field Recording Spud: 5 25 81 Completed: 5/29/81. Lost Workover: 3/24/95 SRU 32-33WD Swanson River Field APl No.: 50-133-20337-00 Top of in ect on, Zone: FI:. Angle @ Perf s: 0 Degs. Hanger: VD'CO (;;RAY 0.0- 90.0' 10 3/4" OD CSG Driven 90.0 - 90.0' SHOE 18.0 - 18.8' 7.00" OD 2.992" ID HANGER Vetco Gray Hgr. 18.8 - 19.3' CROSSOVER 3' 1/2" EUE.. × 3 1/2" BIC. 18.8 - 2056.4' 3,500" OD 9.20Ji//fl N-BO TBG 0.0 - 2499,0' 7" OD 2,~.OOt~/ft K-55 SURF CSG 2450.0 - 2499.0' CEMENT PLUG 2499.0 - 2499.0' SHOE KB ELEV: 172' PB11): 2450' TD: 2499' 1967.3 - 1968.7' 3.937" OD 2.8t" ID NIPPLE Otis "X" 1996.8 - t997.3 - 2003.5 - 2045.8 - 2055.4 - 2056.4 - 2100.0 - 1997.3' CROSSOVER 3 1/2" 10RD. × 3 1/2" BTC. 2003.5' 5.968" OD 3.00" ID RETRV. PACKER Baker FHL Pkr. W/40K Shear 2003.9' CROSSOVER 3 1/2" lORD. x 3 1/2" BTC. 2047.2' 3.937" OD 2.81" ID NIPPLE Otis "X" 2056.4' CROSSOVER ,~ 1/2" BTC. x 5 1/2" EUE. 2057.0' 4.250" OD 2,992" ID SHEARSUB Baker Shear-Out W/Boll Seat 2228.0' PERFS 4HPF, 128', 8/19/81, 9/85 2234.0 - 2278.0' PERFS 4HPF, 44', 8/19/81, 9/85 2316.0 - 2424.0' PERFS 4HPF, 108', 8/19/81, 9/85 IWater Disposal Well Z 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing After casing Repair well Pull tubing X Other 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519- 6247 4. Location of well at surface 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth At total depth 1990' FNL, 1133' FEL, Sec. 33, T8N, R9W, SM 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) RKB 198' GL 172' 7. Unit or Property name Swanson River Unit 8. Well number SRU 32.A-33 9. Permit number 91-14 10. APl number 50-133-10164-01 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,396 feet Plugs (measured) 10,890' (Bridge Plug) 11,165 feet Effective depth: measured 11,319' feet Junk (measured) true vertical 11,098' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 22" Driven 30' 30' Surface 2540' 13-3/8" Yes 2540' 2540 Intermediate 8685' 7" Yes 8685' 8685' Production Liner 2187' 5" 325 sx 8379'-10566' 8379'-10453' Perforation depth: measured 10800'-10820'; 10835'-10854'; 10900'-10912' true vertical 10656'-10673'; 10686'-10702'; 10741 '-10751' Tubing (size, grade, and measured depth) 2-7/8" to 8911' MD; 2-3/8" from 8912'-9499' MD, 2-7/8" liner from 9499'-11386'MD Packers and SSSV (type and measured depth) Liner top packer @ 8379' MD, Baker "SC-1L" packer @ 9499' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Data Prior to well operation 240 75 682 1820 Subsequent to operation 140 255 768 1800 Tubing Pressure 5O0 7OO 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations I16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the forf~)iq0 is tru¢~c~c0r~ect t~tT~ best of my knowledge. 'gnd G. Russell Schmidt tt~<~?m~V.~.~Title Drilling Manager Form 10-404 Rev 06/15~88 Date ~{;:3i ~~ SUBMIT IN DUPLICATE Unocal Energy Resourr~"'~'iV~-'"q 909 West 9th, P.O. Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 263-7828 UNOCALe Debra Childers Clerk DATA TRANSMITTAL 96-4 February 13, 1996 To: Larry Grant 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items. SRU 32A-33 ,.//BLUELINE / SEPIA 12/5/95 PERFORATING RECORD SMGS #3 BLACKLINE / SEPIA 12/28/95 COMPLETION RECORD .SMGS #3 ~,,'BLUELINE / FILM 1/9/96 COMPLETION RECORD GP 42-23 RD c'"BLUELINE / SEPIA 12/27/95 BRIDGE PLUG SETTING RECORD GP 42-23 RD BLUELINE / SEPIA 12/29/95 MUDLOG - FORMATION SCU 43-4 ~ BLUELINE / SEPIA 12/21/95 PERFORATING RECORD SCU 343-33 u /BLUELINE / SEPIA 12/5/95 COMPLETION RECORD SCU 321-9 ~, /BLUELINE / SEPIA 12/21/95 PERFORATING RECORD Please acknowledge reoeipt by signing and retuming one copy of this transmittal or~_~_..~~ ~ Alaska Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL March 4, 1996 Mr. David Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Commissioner Johnston' Re: Swanson River Unit- Well SRU 32A-33 APl Number 50-133-10164-01 This is to inform you that on December 5, 1995, Unocal reperforated the following intervals in SRU 32A-33 in the Swanson River Unit. BENCH TOP (MD) BOTTOM (MD) FEET HB 1 10,800 10,819 19 HB2 10,835 10,848 13 Total 32 Very truly yours, · G. Russell Schmidt Drilling Manager Attachment STATE OF ALASKA ; ALHoKA OIL AND GAS CONSERVATION COI,,,vIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~1 GAS E~ SUSPENDED r--] ABANDONED E~ SERVICEr"--] ORIGINAL 2 Name of Operator 7 Permit Number ARCO Alaska, Inc ............ 91-14 , 3 Address 8 APl Number P.O. Box 100360, Anchora~le,,AK 99510-0360 50-133-10164-01 4 Location of well at surface 9 Ur~it or Lease Name 1990' FNL, 2110' FEL, SEC 33, T8N, RDE SM '~"---'""'-" At Top Producing Interval ~¢,~[,~Ti0~ I LOC.~~ i SWANSON RIVER UNIT ! ~:i~ 10 Well Number 1963' FNL, 1370' FEL, SEC 33, T8N, RDW SM ~../~/'~~ f~ S~'f~--, SRU 32A-33 At Total Depth ~j¢(::,~,~l~! IR. H; ~l 11 Field and Pool 1990' FNL, 1133' FEL, SEC 33, TSN, RDE, SM ~.;~,-.-~ ~~[ SWANSON RIVER FIELD 5 Elevation in feet (indicate KB, DF. etc.) I' 6 L~ST~ Des~gn-i~'~ and Serial No. HEMOLOCK OIL POOL RKB 187' GL 172'I A-028399 12 Date Spudded 13 Daie T.D. Reached .... i4 Date comP., suspl or Aband. I 15 Water Depth, if offshore ' J16 No. of Completions 3/3/91. 4/8/91. --4¢'2'2/eJ1'! NA . . . feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11396' MD & 11165'TVD 11319' MD & 11098' TVD YES ['~ NO E~ NONE feet MD 0' APPROX 22 Type Electric or Other Logs Run IEL/CN/BHC-AL/GR/GYRO/CBL/CCL ,, 23 CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" SURF 30' TO SURFACE 13-3/8" 54.5# "J-55 ' SURF ' 2540' 17-f/2" 1200 SX CMT 7" 23/26/29 # N-80/P-110 SURF 8701', 10-5/8" 1400 SX CMT , , , 5" 18# ' N-80 I ' 8379, 10566' 6" 325 SX PREMIUM 2-7/8" 6.5# N-80I ' 9499' 11386' 4-1/8"' 85 SX LONESTAR ...... 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2]7/8'', 6.5# 9499' 9499' 10800'-10820' MD W/1-11/16" @ 4 SPF 10686'-10702' TVD 10835'-10854' MD W/1-11/16" @ 4 SPF 10656'-10673' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, FTC 10900°-10912, MD W/1-11/16" @ 1 SPF 10721'-10731' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , ...... , , 27 PRODUCTION TEST Date First Production eth0d of Operation (Flowing, gas lift, etc.) 9/18~90. . DateofTest Hours Tested PRODUCTION FOR OIL-BBL ' ' GAs-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL G/~s-McF ' WATER-BBL OIL GRAvITY-APl (corr) Press. 1500 PSI 24-HOUR RATE ~ "~ ........ cORE DA-I:A J~'"E ~'~ Brief description of lithology, porosity, fractures, appareni d'i'ps and'presence of oil, gas or water. Submit core chips. S i*SRU :32-33 PLUGBACKED @ 8701' AND SIDETRACKED TO A NEW BOTTOM-HOLE LOCATION AS 32A-33. Alaska 0il & 6as 0ohs. 6ommission Anchorage , , , , ......... 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 SUMMARY OF DAILY OPERATIONS 32. I hereby certify that the foregoing is true and cor~t to the best of my knowledge "' I ii- ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. MaY 15, 1991 Mr. Jim Zernell ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ORIGINAL Re: Level Rotor Gyroscopic Survey Job No: AK-LB-10044 Well: 32A-33 Field: Swanson River Survey Date: 4/20/91 Operator: D. Harger Dear Mr. Zernell: Please find enclosed two copies of our Level Rotor Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Region Manager Enclosures 5631 SilveradoWay, Suite G · Anchorage, Alaska99518 · (907)563-3256 · Fax (907)563-7252 A Baroid Company ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 32-33 / 32A-33 KENAI SWANSON RIVER UNIT SWANSON RIVER FIELD DAILY OPERATIONS RECLFIVFD A-028399 50-133-10164 91-14 PAGE: 1 ACCEPT: 02/26/91 14:00 SPUD: 03/03/91 01:30 P~ELEASE: 04/15/91 18:00 OPERATION: P&A,DRILL,COMP,PERF RIG: GRACE 154 AFE: AD7176 WI: 48.4864 02/27/91 ( 1) TD:10938' (10938) SUPV:EB 02/28/91 (2) TD:10938' ( SUPV:EB o) 03/01/91 ( 3) TD:10938' ( SUPV:EB 0) 03/02/91 ( 4) TD: 9994'( SUPV:EB o) 03/03/91 ( 5) TD: 8685'( SUPV:EB o) 03/04/91 ( 6) TD: 8719' ( 34) SUPV:RS 03/05/91 (7) TD: 8721'( SUPV:RS 2) NU BOPE MW: 0.0 VIS: 0 FINISH RIGGING UP,KILL WELL, SET PLUG IN X NIPPLE,ND TREE,NU BOPE DAILY:S98,171 CUM:$98,171 ETD:S98,171 EFC:$2,200,200 CIRC OUT GAS MW: 8.3 VIS: 0 NU 13-5/8" 5000# BOP STACK, TEST SAME, RU SLICKLINE UNIT, RIH & PULL PRONG, SHEAR OFF PX PLUG & POOH, BULLHEAD 20 BBLS WATER DOWN TUBING INTO FORMATION, RD SLICKLINE UNIT, PULL TBG HANGER & LD LANDING JT, CIRC OUT GAS AT 6 BPM, 1000 PSI, 5 BPH LOSS TO FORMATION. DAILY:S27,311 CUM:$125,482 ETD:S125,482 EFC:$2,200,200 POOH MW: 8.3 VIS: 0 CIRC OUT GAS, POOH, LD COMPLETION STRING, TEST KELLY COCKS & FLOOR SAFETY VALVES, SET WEAR RING, PU 3-1/2" DRILL PIPE & TIH W/ 7" CSG SCRAPER TO 10372', CBU, NO GAS, SOME ASPHALTENES, POOH. DAILY:S23,567 CUM:$149,049 ETD:S149,049 EFC:$2,200,200 POOH MW:10.5 VIS: 72 POOH, LD CSG SCRAPER, RUN ATLAS CBT, TIH W/ HOWCO CMT RETAINER, CIRC, SET RETAINER @ 10353, TEST CSG TO 3000 PSI, MIX & PUMP 100 SX MATRIX CMT AND 75 SX CLASS G CMT, SQUEEZE THRU RETAINER INTO GRAVEL PACK COMPLETION, FINAL PRES 4200 PSI, SPOT 14 BBLS CLASS G ABOVE RETAINER, EST TOC 9994', POH 6 STANDS SLOW, REV OUT, MIX 10.5 MUD IN PITS, POH TO 9000', DISPLACE WELL TO 10.5 PPG MUD, TOH. DAILY:S66,198 CUM:$215,247 ETD:S215,247 EFC:$2,200,200 TIH MW:10.5 VIS: 96 POH, LD HOWCO RUNNING TOOL, RUN GUAGE RING ON ATLAS WL, TIH & SET TIW WHIP- STOCK PKR AT 8700', TOH, RIH W/ TIW STINGER & SPERRY MULTISHOT GYRO, STING IN, ALL STINGER LUGS SHEARED, RD ATLAS, PU AND ORIENT PACKSTOCK, TIH W/ WHIPSTOCK & STARTER MILL, LATCH IN & SHEAR OFF, TOP OF WHIPSTOCK @ 8685' MILL 1.5' W/ STARTER MILL, TOH, CHG MILLS. DAILY:S63,134 CUM:$278,381 ETD:S278,381 EFC:$2,200,200 OPENING WINDOW IN CSG MW:10.5 VIS: 81 RIH W/ WINDOW MILL & WATERMELON MILL,CUT WINDOW 8689-8698, 24~ILL QUIT, TOH, CHG OUT FLEX JT & WINDOW MILL, TIH,CUT DRLG LINE,CUT WINDOW 8698-8701,DRLG NEW HOLE 8701-8719,CIRC BTMS UP,CHK FOR FLOW, TOH, LD FLEX JOINT,PU MILL, STRING MILL, & WATERMELON MILL, TIH, OPEN WINDOW. DAILY:S20,000 CUM:$298,381 ETD:S298,381 EFC:$2,200,200 DRLG W/ MOTOR MW:10.6 VIS: 44 REAM WINDOW 8689-8719,SLUG PIPE,TOH, LD MILLS,MU BIT & NB STAB, TIH, REAM THRU WINDOW 8689-8719,DO LEAKOFF TEST TO 14.5 PPG EMW, HELD OK, RUN GYRO, TOH, SERVICE RIG, PU BHA, TEST MUD MOTOR & MWD,TIH, PU KELLY & CIRC,CHG OUT LEAKING SWIVEL PACKING, PROGRAM MWD & ORIENT TOOL FACE, DRLG W/ MUD MOTOR 8719-8721. DAILY:S28,735 CUM:$327,116 ETD:S327,116 EFC:$2,200,200 RECE[V[ WELL: 32-33/32A-33 OPERATION: P&A, DRILL,COMP,PERF RIG: GRACE 154 03/06/9t ( 8) TD: 8735' ( 14) SUPV:WH 03/07/91 ( 9) TD: 8735'( SUPV:WH o) 03/08/91 (10) TD: 8780' ( 45) SUPV:WH 03/09/91 (11) TD: 8804' ( 24) SUPV:WH 03/10/91 (12) TD: 8907' ( 103) SUPV:WH 03/11/91 (13) TD: 9006'( 99) SUPV:WH 03/12/91 (14) TD: 9142' ( 136) SUPV:WH 03/13/91 (15) TD: 9254' ( 112) SUPV:WH 03/14/91 (16) TD: 9348' ( 94) SUPV:WH 03/15/91 (17) TD: 9491' ( 143) SUPV:WH -. 03/16/91 (18) TD: 9568' ( 77) SUPV:WH Alaska Oii .& Gas Cons. Com[~issiof~ PAGE: 2 LAY DOWN 2-3/8" TBG MW:Z0.6 VIS: 45 DRILL W/ MOTOR & BENT SUB 8721-8735,COULD NOT MAINTAIN TOOL FACE DUE TO BIT SLIDING ALONG OLD 7" CASING, POOH,PU 18 JTS 2-3/8" TBG & TIH, RU HOWCO,MIX & PUMP 5 BBLS WATER, 13 BBLS 17.0 PPG CLASS G CMT,2 BBLS WATER, DISPLACE W/ 55 BBLS MUD TO BALANCE POINT, PULL 4 STANDS,REVERSE OUT,ATTEMPT TO SQUEEZE W/ 2000 PSI, PUT NO CEMENT AWAY, SHUT IN W/ 1000 PSI,WOC, POOH W/ 2-7/8" TBG. DAILY:S39,704 CUM:$366,820 ETD:S366,820 EFC:$2,200,200 DRLG CMT MW:10.5 VIS: 43 TEST BOPE,PU BIT AND RIH, TAG SOFT CMT,CIRC, POH, PU MILL AND RIH,DRLG SOFT CMT, WOC,DRLG SOFT CMT,WOC, DRLG SOFT CMT DAILY:S34,687 CUM:$401,507 ETD:S401,507 EFC:$2,200,200 DRLG MW:10.5 VIS: 39 DRLG CMT F/8694 T/8707,CIRC AND COND MUD, BIT TRIP,SLIDE DRILL W/ STEERABLE MOTOR F/8707 T/ 8780 DAILY:S29,159 CUM:$430,666 ETD:S401,507 EFC:$2,229,359 DRLG MW:10.5 VIS: 44 DRLD F/ 8780 T/ 8798,POH, RIH CIRC, RUN GYRO,POH LD BIT AND STAB, PU STEERABLE MOTOR AND RIH, C&S DRLG LINE,RIH,DRLD F/8798 T/8804 DAILY:S41,872 CUM:$472,538 ETD:S472,538 EFC:$2,200,200 DRLG SLIDE DRLG T/8875,ROTARY DRLD T/8907 MW:10.5 VIS: 42 DAILY:S34,394 CUM:$506,932 ETD:S506,932 EFC:$2,200,200 DRLG MW:10.5 VIS: 41 DRLD F/8907 T/8970,SHORT TRIP INTO WINDOW, DRLD T/9006 DAILY:S40,169 CUM:$547,101 ETD:S547,101 EFC:$2,200,200 DRLG MW:10.5 VIS: 41 DRLD F/9006 T/9096,SHORT TRIP INTO CASING, DRLD F/9096 T/9142 DAILY:S33,243 CUM:$580,344 ETD:S580,344 EFC:$2,200,200 CIRC AND RAISE WT MW:12.7 VIS: 47 DRLD F/ 9142 T/ 9155,WELL FLOWING-CIRC, RAISE WT TO 10.8,DRLD T/9173,CIRC AND RAISED WT T/ ll.5,DRLD T/9231,RAISED WT T/12.5,SHORT TRIP INTO CASING, DRLD F/ 9231 T/9254,RAISED WT T! 12.7,MWD FAILED, POH, HOLE NOT TAKING RIGHT VOLUME, RIH TO BOTTOM, CIRC AND RAISE WT T/ 13 DAILY:S47,737 CUM:$628,081 ETD:S628,081 EFC:$2,200,200 ~RLG MW:13.0 VIS: 45 CIRC AND RAISE MUT WT TO 13,POH, CO BHA, RIH, SLIDE DRILL T/9348 DAILY:S36,619 CUM:$664,700 ETD:S664,700 EFC:$2,200,200 DRLG MW:13.0 VIS: 45 ROTARY DRILL F/9348 T/9394,SLIDE DRILL T/9460,SHORT TRIP (HOLE IN GOOD COND) SLIDE DRILL T/9491 DAILY:S32,164 CUM:$696,864 ETD:S696,864 EFC:$2,200,200 DRILLING MW:13.0 VIS: 48 SLIDE DRILL F/9491 T/9562,POH CO BI{A, TEST BOPE,RIH, RE~/Vl F/9264 T/9562,DRfD T/9568 DAILY:S45,331 CUM:$742,195 ETD:S742,195 EFC:$2,200,200 WELL: 32-33/32A-33 OPERATION: P&A, DRILL, COMP,PERF RIG: GRACE 154 PAGE: 3 03/17/91 (19) TD: 9671' ( 103) SUPV:WH 03/18/91 (20) TD: 9728' ( 57) SUPV: WH 03/19/91 (21) TD: 9817' ( 89) SUPV:WH 03/20/91 (22) TD: 9910' ( 93) SUPV:WH 03/21/91 (23) TD: 9962' ( 52) SUPV:WH 03/22/91 (24) TD:10107' ( 145) SUPV:EB 03/23/91 (25) TD:10184' ( 77) SUPV:EB 03/24/91 (26) TD:10345' ( 161) SUPV:EB 03/25/91 (27) TD:10566' ( 221) SUPV:EB 03/26/91 (28) TD:10566' ( SUPV:EB o) 03/27/91 (29) TD:10566' ( SUPV:EB o) CHANGE OUT SEAL IN HYDRIL MW:13.1 VIS: 46 DRLD F/9568 T/9671,MWD FAILED,POH, CO SEAL IN HYDRIL DAILY:S33,231 CUM:$775,426 ETD:S775,426 EFC:$2,200,200 SLIDE DRLG MW:12.9 VIS: 47 FINISH CO SEAL IN HYDRIL,RIH,DRLD F/9671 T/9701,POH CO BHA RIH, S&C DRLG LINE FINISH RIH, SLIDE DRLD F/ 9701 T/9728 DAILY:S25,373 CUM:$800,799 ETD:S800,799 EFC:$2,200,200 DRLG MW:13.0 VIS: 48 DRLD F/9728 T/9802,SHORT TRIP,DRLD T/9817 DAILY:S39,412 CUM:$840,211 ETD:S840,211 EFC:$2,200,200 DRLG MW:13.0 VIS: 52 DRLD F/9817 T/9903,SHORT TRIP,DRLD T/9910 DAILY:S34,355 CUM:$874,566 ETD:S874,566 EFC:$2,200,200 DRLG MW:12.9 VIS: 51 DRLD W/MOTOR T/9962,POH C O BHA, RIH,ORIENT, SET BIT PATTERN DRLG DAILY:S37,250 CUM:$911,816 ETD:S911,816 EFC:$2,200,200 CBU DRLD F/9962 T/10107,CBU MW:13.0 VIS: 52 DAILY:S37,168 CUM:$948,984 ETD:S948,984 EFC:$2,200,200 POH MW:13.0 VIS: 48 MONITOR HOLE(STABLE),POH, TEST BOPE, RIH W/ BIT#12,DRLG F/10107 T/10126, CHANGE OUT SWIVEL PACKING, DRLD T/10184,POH DAILY:S29,034 CUM:$978,018 ETD:S978,018 EFC:$2,200,200 DRLG POH, RIH,DRLD F/10184 T/10345 MW:13.0 VIS: 50 DAILY:S30,259 CUM:$1,008,277 ETD:S1,008,277 EFC:$2,200,200 SHORT TRIP MW:13.0 VIS: 48 DRLD F/10345 T/10450,SHORT TRIP,DRLD T/10566,CBU, POH DAILY:S26,867 CUM:$1,035,144 ETD:S1,035,144 EFC:$2,200,200 RUNNING 5" CASING MW:13.0 VIS: 53 SHORT TRIP TO 7" CSG WINDOW, NORMAL, TIH, NO FILL, CIRC & COND MUD, TOH, RU ATLAS, RUN GR/CALIPER LOG, RIG DOWN ATLAS, T~H TO 8600', CDL, SERVICE RIG, CONT TIH, WASH TO BTM, NO FILL, CIRC & COND MUD, DROP RABBIT, TOH SLOW TO WINDOW, MONITOR HOLE, TOH, RIG CSG CREWS, PU & RUN 5" 18# N80 FL4S CSG. DAILY:S48,876 CUM:$1,084,020 ETD:S1,084,020 EFC:$2,200,200 NU BOPE 5"@10566' MW:13.0 VIS: 58 RIH W/ 5"LINER AND HANGER, CIRC, CEMENT 5" LINER, CIP 1700HRS RELEASE SETTING TOOL AND SET LINER TOP PACKER, REVERSE OUT 14 BBLS CEMENT, TEST PACKER OK, POH LD TOOLS,TIH W/ BHA AND STORM PACKER AND SET,ND BOPE AND TBG HEAD TO CHANGE OUT SEALS,TEST SEALS OK, NU BOPE DAILY:S99,646 CUM:$1,183,666 ETD:S1,183,666 EFC:$2,200,200 WELL: 32-33/32A-33 OPERATION: P&A, DRILL, COMP,PERF RIG: GRACE 154 PAGE: 4 03/28/91 (30) TD:10566' ( SUPV:EB 03/29/91 (31) TD:10566' ( SUPV:EB 03/30/91 (32) TD:10568' ( SUPV:EB 0) 0) 2) 03/31/91 (33) TD:t0620' ( 52) SUPV:EB 04/01/91 (34) TD:10795' ( 175) SUPV:EB 04/02/91 (35) TD:10890' ( 95) SUPV:EB 04/03/91 (36) TD:10940' ( 50) SUPV:EB 04/04/91 (37) TD:l1021' ( 81) SUPV:WH 04/05/91 (38) TD:ll147' ( 126) SUPV:WH 04/06/91 (39) TD:lll91' ( 44) SUPV:WH PU BHA 5"@10566' MW:12.8 VIS: 55 FINISH NU BOPE,TEST BOPE,RETRIEVE STORM PACKER, TIH TOL@8379 NO CMT, POH, LDDP, PU 3.12" DC, RIH TO TOL, POH LD CSG SCRAPER, CO BHA, PREPARE TO RIH DAILY:S31,737 CUM:$1,215,403 ETD:S1,215,403 EFC:$2,200,200 DRLG CEMENT 5"@10566' MW:12.2 VIS: 41 TIH TO 8370, WASH FR/ 8370-8430, CONT TIH TO 10403, WASH & REAM CMT STRINGERS TO 10448, DRLG SOFT CONTAMINATED CMT TO 10483, DRILL PLUGS & LANDING COLLAR AT 10484, HARD CMT TO 10485-10523, DRILL FLOAT COLLAR & CMT 10523-10528, PUMP PILL & TOH, INSPECT MILL, STRAP & PU 9-3-1/8" DC'S & NEW BHA, TIH TO 10513, SLIP DRLG LINE, SERVICE RIG. DAILY:S29,342 CUM:$1,244,745 ETD:S1,244,745 EFC:$2,200,200 DRILLING 5"@10566' MW: 9.8 VIS: 44 DRLG HARD CMT 10528-10553, TEST CSG TO 3000 PSI, BUILD & DISPLACE WELL TO 9.9 PPG POTASSIUM NITRATE MUD SYSTEM, DRILL CMT 10553-10565, DRILL ON FLOAT SHOE, PUMP SLUG, TOH, SERVICE RIG, TIH W/ MILL, DRILL FLOAT SHOE & NEW HOLE TO 10568. DAILY:S26,143 CUM:$1,270,888 ETD:S1,270,888 EFC:$2,200,200 TRIP IN HOLE 5"@10566' MW:10.1 VIS: 42 DRILLING W/ CMT MILL 10568-10570, PUMP SLUG, TOH, PU MOTOR, TIH, DRILL 10570- 10575, CIRC & TEST FORMATION 13.0 PPG EMW, DRILL 10575-10620, MOTOR QUIT, TOH, PULLED 60 STANDS, WELL STARTED TO FLOW, TIH TO 10586, CIRC WELL TO 10.1 PPG, BTMS UP CUT TO 9.7 PPG, MOMITOR WELL 15 MIN, STABLE, TOH, MOTOR LOCKED UP, PU ROTARY BHA, FUNCTION TEST BOP'S, CHG BITS & TIH. DAILY:S23,405 CUM:$1,294,293 ETD:S1,294,293 EFC:$2,200,200 DRILLING 5"@10566' MW:10.1 VIS: 40 TIH TO SHOE AT 10566, CUT DRLG LINE, DRILL AHEAD 10620-10795. DAILY:S26,635 CUM:$1,320,928 ETD:S1,320,928 EFC:$2,200,200 DRILLING 5"@10566' MW:10.1 VIS: 43 DRILLING 10795-10805, SHORT TRIP TO SHOE, NO PROBLEM, SERVICE RIG, TIH, DRILLING 10805-10890. DAILY:S32,657 CUM:$1,353,585 ETD:S1,353,585 EFC:$2,200,200 DRILLING 5"@10566' MW:10.1 VIS: 41 DRILLING 10890-10900, SHORT TRIP TO SHOE, NO PROBLEMS, SERVICE RIG, TIH, DRILLING 10900-10924, TOH FOR BIT, NORMAL DRAG, TEST BOP'S, CHANGE BIT & TIH, NO FILL, DRILLING 10924-10940, HIGH ROTARY TORQUE. DAILY:S27,552 CUM:$1,381,137 ETD:S1,381,137 EFC:$2,200,200 · ~RILLING 5"@10566' MW:10.1 VIS: 43 DRILLING 10940-10995, SHORT TRIP (HOLE IN GOOD CONDITION), DRILLING 10995- 11021. DAILY:S20,644 CUM:$1,401,781 ETD:S1,401,602 EFC:$2,200,379 DRILLING 5"@10566' MW:10.0 VIS: 44 DRILL 11021-11131, SHORT TRIP, SERVICE RIG, HOLE IN GOOD CONDITION, DRILL 11131-11147. DAILY:S20,295 CUM:$1,422,076 ETD:S1,422,076 EFC:$2,200,200 RIH 5"@10566' MW:10.0 VIS: 46 DRLD F/ 11147 T/ll186,BIT TRIP,DRLD T/lll91,BIT TRIP,PU ECONOMILL AND RIH DAILY:S26,254 CUM:$1,448,330 ETD:S1,448,330 EFC:$2,200,200 WELL: 32-33/32A-33 OPERATION: P&A, DRILL, COMP,PERF RIG: GRACE 154 PAGE: 5 04/07/91 (40) TD:11254'( 63) SUPV:WH 04/08/91 (41) TD:l1381' ( 127) SUPV:WH 04/09/91 (42) TD:11396' ( 15) SUPV:WH 04/10/91 (43) TD:11396' ( SUPV:WH 0) 04/11/91 (44) TD:11396' ( SUPV:WH 0) 04/12/91 (45) TD:11396' ( SUPV:WH 0) 04/13/91 (46) TD:11386' ( SUPV:WH 0) DRLG 5"@10566' MW:10.0 VIS: 45 FIN RIH,DRLD W/ MILL T/l1204,?OH LD MILL, RIH W/ BIT#20,C&S DRLG LINE, RIH T/ lll91,REAM TO ll204,DRLD T/ 11254 DAILY:S21,700 CUM:$1,470,030 ETD:S1,470,030 EFC:$2,200,200 DRLG 5"@10566' MW:10.0 VIS: 48 DRLD F/11254 T/l1339, SHORT TRIP,SERVICE RIG, DRLD T/11369, CHANGED OUT SWIVEL PACKING, DRLD T/11381 DAILY:S20,677 CUM:$1,490,707 ETD:S1,490,707 EFC:$2,200,200 RIH 5"@10566' MW:10.0 V/S: 45 DRLD F/ 11381 T/l1396,SHORT TRIP, CIRC,POH, RU DRESSER TO LOG TIGHT SPOT @ 10690,POH W/ LOGS,RIH W/ BIT TO CONDITION HOLE. DAILY:S20,608 CUM:$1,511,315 ETD:S1,511,315 EFC:$2,200,200 POH W/FISH 5"@10566' MW: 9.8 VIS: 47 FIN RIH TIGHT @ ll177T/l1271,CIRC, POH, RUN GAMMA RAY/ACOUSTIC STUCK TOOL ON REPEAT PASS, PULL OUT OF ROPE SOCKET, WO FISHING TOOLS,RIH W/ OVERSHOT, LATCK ON POOH, RETRIEVED HALF OF THE FISH DAILY:S28,618 CUM:$1,539,933 ETD:S1,539,933 EFC:$2,200,200 LAY DOWN DRILL PIPE 5"@10566' MW: 9.7 VIS: 58 FINISH POOH, RECOVERED 22' OF FISH, ACCOUSTIC TOOL PARTED LEAVING 10' OF TOOL INHOLE, REDRESS 3-5/8" OVERSHOT W/ 2-3/4" SPIRAL GRAPPLE, RIH TO SHOE, CUT DRILLING LINE, FINISH RIH TO TO 11054', ATTEMPT TO LATCH FISH, COULD NOT, PUSH FISH TO BOTTOM, TOP OF FISH 11386', POOH, NO FISH, LAY DOWN TRISTATE TOOLS, PICK UP BIT, TIH TO 11386', CIRC & COND MUD, PULL OUT TO SHOE, START LAYING DOWN 3-1/2" DRILL PIPE TO RUN 2-7/8" LINER. DAILY:S21,407 CUM:$1,561,340 ETD:S1,561,340 EFC:$2,200,200 RUN 2-7/8" LINER 5"@10566' MW: 9.7 VIS: 45 FINISH POH, LD 3-1/2" & 2-7/8" DP, INSTALL 2-7/8" RAMS & PULL WEAR BUSHING, TEST BOPE, RU & RUN 2-7/8" 6.5#/FT N80 8RD ABMOD LINER W/ 2-7/8" WORKSTRING. DAILY:S21,596 CUM:$1,582,936 ETD:S1,582,936 EFC:$2,200,200 RIH W/ RTTS 5"@10566' MW: 9.7 VIS: 0 FINISH RIH W/ LINER AND WORK STRING, CIRC HOLE, HOLE PACKING OFF,CMT 2-7/8" LINER, SET BAKER SC-IL PACKER, ROTATE OFF OF PACKER, REVERSE CIRC, POH W/ WORK STRING, PU RTTS AND RIH DAILY:S59,822 CUM:$1,642,758 ETD:S1,642,758 EFC:$2,200,200 WELL: 32-33/32; 3 OPERATION: P&A, DRILL, COMP, PERF RIG: GRACE 154 PAGE: 6 04/14/91 (47) TD:11386 PB:l1319 SUPV:WH 04/15/91 (48) TD:11386 PB:l1319 SUPV:WH 04/16/91 (49) TD:11386 PB:l1319 SUPV:WH 04/22/91 (50) TD: 0 ?B:11319 SUPV:WH 04/23/91 (51) TD: 0 PB:l1319 SUPV:WH RUNNING PROD STRING 2-7/8"@11386' MW: 9.7 NaCl FIN RIH W/ RTTS,TEST LINER TOP W/ 3000 PSI, PERFORM NEGATIVE PRESSURE TEST ON LINER LAP, OK, CIRC AND FILTER BRINE, POH LD WORK STRING AND RTTS,RU & RUN PROD STRING. DAILY:S30,048 CUM:$1,672,806 ETD:S1,672,806 EFC:$2,200,200 ND BOPE 2-7/8"@11386' MW: 9.7 NaC1 RUN 2 7/8" COMPLETION, SPACE OUT TBG, MU TBG HANGER, THREADS WERE GALLED, HAVE NEW THREADS CUT, INSTALL TBG HANGER, LATCH INTO SEAL ASSEMBLY, RI LDS,RIH W/ SLICKLINE TO LANDING COLLAR, TEST SEALS AND TUBING, OK, SET X PLUG AND BPV, ND BOPE DAILY:S65,978 CUM:$1,738,784 ETD:S1,738,784 EFC:$2,200,200 RIG RELEASED 2-7/8"@11386' MW: 9.7 NaC1 ND BOPE,NU TREE AND TEST,DISPLACE TUBING WITH CRUDE, SET BPV FINISH CLEANING PITS, RIG RELEASED @ 1800HRS, 15-APR-91 DAILY:S15,299 CUM:$1,754,083 ETD:S1,754,083 EFC:$2,200,200 SECURE WELL 2-7/8"@11386' MW: 9.7 NaC1 RU PRECISION WIRELINE & RUN GAUGE RING TO 11,316', MU SPERRY SUN GYRO, RIH TAKING SHOTS EVERY 500' TO 8500' THEN EVERY 100' F/8500'-11250', POH CHECKING SHOTS EVERY 1000', RD PRECISION & SPERRY, RU ATLAS & RUN CBL/GR/CCL, RD ATLAS SECURE WELL DAILY:S40,000 CUM:$1,794,083 ETD:S1,794,083 EFC:$2,200,2000 SECURE WELL 2-7/8"@11386' MW: 9.7 NaC1 RU ATLAS, RIH W/i-ii/16" @ 1 SPF & PERF F/10900'-10912', POH & RD, SECURE WELL DAILY:S20,000 CUM:$1,814,083 ETD:S1,814,083 EFC:$2,200,200 SIGNATURE: ~ ~ DRI LLING~UPERINTE~T DATE: SPERRY-SUN DRILLING SERVIC~ ANCHORAGE ALASKA PAGE ARCO ALASKA 32A-33 SWANSON RIVER ALASKA 'COMPUTATION DATE: 4/22/91 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE INCLN DIRECTION DG MN DEGREES DG/ 0 .00 -172.00 500 499.98 327.98 1000 999.93 827.93 1500 1499.90 1327.90 2000 1999.88 1827.88 DATE OF SURVEY: 4/20/91 LEVEL ROTOR GYROSCOPIC SURVEY JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER DLS TOTAL RECTANGULAR COORDINATES 100 NORTH/SOUTH EAST/WEST 0 0 N .00 E .00 0 45 S 21.96 E .15 0 50 S 1.00 E .06 0 25 S 13.18 E .09 0 30 N 67.15 E .14 VERT. SECT. .00 .00 .00 3.03S 1.22E 1.21 9.73S 2.51E 2.46 15.17S 2.99E 2.91 16.09S 5.42E 5.34 2500 2499.86 2327.86 3000 2999.84 2827.84 3500 3499.83 3327.83 4000 3999.81 3827.81 4500 4499.79 4327.79 0 35 S 52.72 W .22 0 25 S 39.60 E .15 0 20 S 39.12 W .10 0 30 S 10.91 W .05 0 40 N 71.74 E .20 16.81S 5.38E 5.29 19.77S 4.49E 4.39 22.32S 4.71E 4.60 25.61S 3.36E 3.24 26.84S 5.71E 5.58 5000 4999.77 4827.77 5500 5499.75 5327.75 6000 5999.72 5827.72 6500 6499.68 6327.68 7000 6999.57 6827.57 0 20 N 55.56 E .07 0 35 N 50.58 E .05 0 35 N 73.71 E .05 0 55 N 46.96 E .09 1 25 N 48.33 E .10 25.09S 9.70E 9.58 22 . 62S 12 . 91E 12 . 80 20.26S 17 . 37E 17.27 16.81S 22.77E 22.68 9.97S 30.31E 30.26 7500 7499.37 7327.37 8000 7999.19 7827.19 8500 8499.09 8327.09 8600 8599.08 8427.08 8700 8699.05 8527.05 1 45 N 63.25 E .11 1 20 N 54.79 E .09 0 50 N 80.43 E .14 1 5 N 65.77 E .35 1 45 S 55.87 E 1.50 2.42S 41.75E 41.73 4.38N 53.34E 53.36 8.36N 61.73E 61.77 8.88N 63.32E 63.37 8.41N 65.45E 65.49 8800 8798.84 8626.84 8900 8898.32 8726.32 9000 8997.62 8825.62 9100 9096.84 8924.84 9200 9195.98 9023.98 5 20 S 56.61 E 3.59 6 20 S 72.09 E 1.86 7 10 S 83.89 E 1.61 7 10 N 87.33 E 1.09 7 50 N 84.43 E .77 4.99N 70.60E 70.63 .73N 79.74E 79.75 1.63S 91.20E 91.19 2.00S 103.63E 103.62 1.05S 116.65E 116.65 9300 9294.83 9122.83 9400 9393.04 9221.04 9500 9490.03 9318.03 9600 9585.60 9413.60 9700 9680.33 9508.33 9 30 N 82.71 E 1.68 12 10 N 84.01 E 2.68 15 55 N 84.10 E 3.75 18 15 N 85.25 E 2.36 19 5 N 87.54 E 1.11 .66N 131.63E 131.63 2.81N 150.30E 150.31 5.32N 174.43E 174.45 8.02N 203.67E 203.71 10.02N 235.61E 235.66 9800 9774.13 9602.13 9900 9866.14 9694.14 10000 9956.33 9784.33 10100 10045.56 9873.56 10200 10134.22 9962.22 21 25 N 87.59 E 2.33 24 40 N 89.72 E 3~35 26 30 N 88.59 E 1.90 27 10 N 88.68 E .67 27 55 N 86.78 E 1.16 11.49N 270.19E 270.24 12.36N 309.31E 309.37 13.01N 352.48E 352.54 14.09N 397.61E 397.67 15.93N 443.80E 443.88 SPERRY-SUN DRILLING SERVICe.. ANCHORAGE ALASKA PAGE 2 ARCO ALASKA 32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE OF SURVEY: 4/20/91 LEVEL ROTOR GYROSCOPIC SURVEY JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 10300 10222.07 10050.07 29 10 N 86.65 E 1.25 10400 10309.17 10137.17 29 40 N 86.74 E .50 10500 10395.74 10223.74 30 25 N 87.97 E .97 10600 10481.83 10309.83 30 45 N 88.13 E .34 10700 10568.67 10396.67 28 40 N 89.71 E 2.23 18.67N 491.50E 491.59 21.50N 540.54E 540.64 23.80N 590.54E 590.65 25.53N 641.39E 641.51 26.49N 690.93E 691.05 10800 10655.84 10483.84 30 0 N 89.83 E 1.33 10900 10741.02 10569.02 33 10 S 86.76 E 3.63 11000 10824.33 10652.33 34 0 S 85.42 E 1.11 11100 10908.22 10736.22 31 55 S 83.79 E 2.26 11200 10993.98 10821.98 30 0 S 79.99 E 2.74 26.68N 739.91E 740.04 25.21N 792.24E 792.36 21.43N 847.42E 847.52 16.34N 901.57E 901.64 9.13N 952.48E 952.51 11250 11037.50 10865.50 29 0 S 80.13 E 2.00 4.88N 976.73E 976.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 976.74 FEET AT NORTH 89 DEG. 42 MIN. EAST AT MD = 11250 VERTICAL SECTION RELATIVE TO WELL HEAD TUBING HEAD VERTICAL SECTION COMPUTED ALONG 89.71 DEG. SPERRY-SUN DRILLING SERVIC~.~ ANCHORAGE ALASKA PAGE 3 ARCO ALASKA 32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE OF SURVEY: 4/20/91' JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -172.00 1000 999.93 827.93 2000 1999.88 1827.88 3000 2999.84 2827.84 4000 3999.81 3827.81 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 9.73 S 2.51 E .07 .07 16.09 S 5.42 E .12 .05 19.77 S 4.49 E .16 .04 25.61 S 3.36 E .19 .02 5000 4999.77 4827.77 6000 5999.72 5827.72 7000 6999.57 6827.57 8000 7999.19 7827.19 9000 8997.62 8825.62 25.09 S 9.70 E .23 .05 20.26 S 17.37 E .28 .04 9.97 S 30.31 E .43 .15 4.38 N 53.34 E .81 .38 1.63 S 91.20 E 2.38 1.57 10000 9956.33 9784.33 11000 10824.33 10652.33 11250 11037.50 10865.50 13.01 N 352.48 E 43.67 41.29 21.43 N 847.42 E 175.67 132.00 4.88 N 976.73 E 212.50 36.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA -32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE OF SURVEY: 4/20/91 JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER INTERi~,OLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 0 .00 -172.00 .00 .00 .00 72 72.00 -100.00 .00 .00 .00 172 172.00 .00 .00 .00 .00 272 272.00 100.00 .27 S .11 E .00 372 372.00 200.00 1.48 S .60 E .01 472 472.00 300.00 2.70 S 1.09 E .02 572 572.00 400.00 3.91 S 1.58 E .03 672 672.00 500.00 5.12 S 2.07 E .04 772 772.00 600.00 6.39 S 2.45 E .05 872 872.00 700.00 7.86 S 2.48 E .06 VERTICAL CORRECTION .00 .00 .00 .01 .01 .01 .01 .01 .01 972 972.00 800.00 9.32 S 2.50 E .07 1072 1072.00 900.00 10.79 S 2.53 E .08 1172 1172.00 1000.00 12.26 S 2.56 E .09 1272 1272.00 1100.00 13.56 S 2.61 E .10 1372 1372.00 1200.00 14.26 S 2.78 E .10 .01 .01 .01 .01 .00 1472 1472.00 1300.00 14.97 S 2.94 E .10 1572 1572.00 1400.00 15.68 S 3.11 E .10 1672 1672.00 1500.00 16.39 S 3.28 E .11 1772 1772.00 1600.00 16.87 S 3.58 E .11 1872 1872.00 1700.00 16.53 S 4.39 E .11 .00 .00 .00 .00 .00 1972 1972.00 1800.00 16.19 S 5.19 E .12 2072 2072.00 1900.00 15.85 S 6.00 E .12 2172 2172.00 2000.00 15.51 S 6.80 E .13 2272 2272.00 2100.00 15.39 S 7.24 E .13 2372 2372.00 2200.00 16.01 S 6.43 E .14 .00 .00 .00 .00 .01 2472 2472.00 2300.00 16.63 S 5.61 E .14 2572 2572.00 2400.00 17,26 S 4.79 E .15 2672 2672.00 2500.00 17.88 S 3.97 E .15 2772 2772.00 2600.00 18.49 S 3.43 E .16 2872 2872.00 2700.00 19.05 S 3.90 E .16 .01 .00 .01 .00 .00 2972 2972.00 2800.00 19.61 S 4.36 E .16 3072 3072.00 2900.00 20.17 S 4.82 E .16 3172 3172.O0 3000.00 20.73 S 5.29 E .17 3272 3272.00 3100.00 21.27 S 5.57 E .17 3372 3372.00 3~00.00 21.73 S 5.19 E .17 .00 .00 .00 .00 .00 SPERRY-SUN DRILLING SERVICEb ANCHORAGE ALASKA PAGE ARCO ALASKA 32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE OF SURVEY: 4/20/91 JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3472 3472.00 3572 3572.00 3672 3672.00 3772 3772.00 3872 3872.00 3300.00 3400.00 3500.00 3600.00 3700.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 22.19 S 4.82 E 22.65 S 4.44 E 23.11 S 4.07 E 23.66 S 3.74 E 24.52 S 3.57 E MD-TVD VERTICAL DIFFERENCE CORRECTION · 17 .00 · 17 .00 .18 .00 · 18 .00 · 18 .00 3972 3972.00 4072 4072.00 4172 4172.00 4272 4272.00 4372 4372.00 3800 3900 4000 4100 4200 .00 .00 .00 .00 .00 25.38 S 3.41 E 26.23 S 3.24 E 27.09 S 3.08 E 27.68 S 3.20 E 27.31 S 4.30 E · 19 .00 .19 .00 .19 .00 .20 .00 .20 .01 4472 4472.00 4572 4572.00 4672 4672.00 4772 4772.00 4872 4872.00 4972 4972.00 5072 5072.00 5172 5172.00 5272 5272.00 5372 5372.00 4300.00 26.95 S 5.41 E 4400.00 26.58 S 6.51 E 4500.00 26.22 S 7.62 E 4600.00 25.86 S 8.59 E 4700.00 25.52-S 9.08 E 4800.00 25.19 S 9.57 E 4900.00 24.85 S 10.06 E 5000.00 24.52 S 10.54 E 5100.00 24.11 S 11.10 E 5200.00 23.46 S 11.90 E .21 .01 .22 .01 .23 .01 .23 .01 .23 .00 .23 .00 .24 .00 .24 .00 .24 .00 .25 .00 5472 5472.00 5572 5572.00 5672 5672.00 5772 5772.00 5872 5872.00 5300.00 22.80 S 12.69 E 5400.00 22.15 S 13.49 E 5500.00 21.49 S 14.28 E 5600.00 20.92 S 15.12 E 5700.00 20.63 S 16.11 E .25 .00 .26 .01 .26 .01 .27 .00 .27 .00 5972 5972.00 6072 6072.00 6172 6172.00 6272 6272.00 6372 6372.00 58OO 5900 6000 6100 6200 .00 .00 .00 .00 .00 20.34 S 17.10 E 20.05 S 18.09 E 19.77 S 19.08 E 19.30 S 20.11 E 18.21 S 21.28 E .28 .01 .28 .01 .29 .01 .29 .01 .31 .01 6472 6472.00 6572 6572.00 6672 6672.00 6772 6772.00 6872 6872.00 6300 6400 6500 6600 .00 .00 .00 .00 .00 17.11 S 22.45 E 16.02 S 23.62 E 14.93 S 24.78 E 13.71 S 26.11 E 12.07 S 27.95 E .32 .01 .33 .01 .35 .01 .36 .02 .39 .03 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA 32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE OF SURVEY: 4/20/91 JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 6972 6972.00 6800.00 7072 7072.00 6900.00 7172 7172.00 7000.00 7272 7272.00 7100.00 7372 7372.00 7200.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 10.42 S 29.80 E 8.78 S 31.65 E 7.13 S 33.50 E 5.55 S 35.54 E '4.17 S 38.27 E MD-TVD VERTICAL DIFFERENCE CORRECTION .42 .03 .45 ' .03 .49 .03 .52 .03 .57 .05 7472 7472.00 7300.00 7572 7572.00 7400.00 7672 7672.00 7500.00 7772 7772.00 7600.00 7872 7872.00 7700.00 2.80 S 41.00 E 1.42 S 43.73 E .05 S 46.46 E 1.32 N 49.00 E 2.67 N 50.91 E .61 .05 .66 .05 .71 .05 .75 .04 .78 .03 7972 7972.00 8072 8072.00 8172 8172.00 8272 8272.00 8372 8372.00 8472 8472.00 8572 8572.00 8672 8672.00 8773. 8772.00 8873 8872.00 7800.00 7900.00 80OO.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 4.02 N 52.82 E 5.37 N 54.73 E 6.71 N 56.64 E 7.81 N 58.45 E 8.05 N 59.89 E 8.30 N 61.34 E 8.66 N 62.85 E 8.87 N 64.77 E 6.23 N 68.73 E 1.63 N 76.96 E .80 .03 .83 .03 .86 .03 .88 .02 .89 .01 .90 .01 .92 .01 .94 .02 1.07 .13 1.52 .46 8974 8972.00 9074 9072.00 9175 9172.00 9276 9272.00 9378 9372.00 8800.00 8900.00 9000.00 9100.00 9200.00 1.29 S 88.00 E 2.15 S 100.51 E' 1.37 S 113.37 E .17 N 127.84 E 2.34 N 145.90 E 2.18 .66 2.96 .79 3.79 .83 4.85 1.06 6.50 1.65 9481 9472.00 9585 9572.00 9691 9672.00 9797 9772.00 9906 9872.00 9300.00 9400.00 9500.00 9600.00 9700.00 4.80 N 169.44 E 7.65 N 199.20 E 9.90 N 232.73 E 11.46 N 269.35 E 12.37 N 312.00 E 9.28 2.78 13.68 4.40 19.18 5.50 25.71 6.53 34.44 8.74 10017 9972.00 10129 10072.00 10242 10172.00 10357 10272.00 10472 10372.00 9800.00 9900.00 10000.00 10100.00 10200.00 13.20 N 360.29 E 14.40 N 411.17 E 17.05 N 463.82 E 20.29 N 519.41 E 23.31 N 576.61 E 45.51 11.07 57.72 12.21 70.77 13.05 85.22 14.46 100.47 15.25 SPERRY-SUN DRILLING SERVIC,.- ANCHORAGE ALASKA PAGE 7 ARCO ALASKA 32A-33 SWANSON RIVER ALASKA COMPUTATION DATE: 4/22/91 DATE'OF SURVEY: 4/20/91 JOB NUMBER: AK-LB-10044 KELLY BUSHING ELEV. = 172.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10588 10472.00 10300.00 10703 10572.00 10400.00 10818 10672.00 10500.00 10937 10772.00 10600.00 11057 10872.00 10700.00 25.34 N 635.55 E 116.56 16.09 26.50 N 692.75 E 131.79 15.23 26.65 N 749.36 E 146.71 14.92 24.07 N 812.45 E 165.00 18.29 18.77 N 879.08 E 185.29 20.29 11174 10972.00 10800.00 11250 11037.50 10865.50 11.24 N 939.83 E 202.55 17.26 4.88 N 976.73 E 212.50 9.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 32~-33 SNRNSON RI~VER ~L9SKF~ u,/20/91. SPERR'i -SUN DR f LL l' N5 5ElaV i CE5 HOB ~F ZON Tt:::IL PROJECTION STP:IRT TVD = 0.00 FINISH TVD = 1.1037.50 SCRLE iS 200 FEET/iN rio0 9OO 700 ~:3 s°o 300 100 -100 SSaS 2, tO - DEPF::IRTURE HOFI[ZONTRL B'ISPLFICEMENI' 'IS 976.7~ t200 ER5T 32R-33 SNRNSON RIVER RLRSKR L~/20/9I SPERFi'r -SUN BFI 1~ LL'rN6 SEFIV ICES VFB1- I CFtL PRSJFCT ~ START TVD = 0.00 FINISH TVD = 11037.S0 SCALE IS 2000 FEET/IN 0 2000- u,000- 6000- 8000- I0000 - 10~7.5 12000 11250 2odo VFRT I C~L SECT I CN 97§.7~ FEET RT N 89 OEO l~3 MEN E 4odo $~OS 2. lO b: lb]O04~ AOGCC GEOLOGICAL MATERIALS INYENTORY LIST PERMIT.~ ¢j ~ _ IL~ WELL NAME ,'~"u,.~V'~ COMPLETION DATE ~. /~ ~| CO. CONTACT ....... Cl~eck'off Or ii~t ~at~n as' it' is. recei¥~d.*list 're~:~iVed date for 40z~ i~' not required list as NR 407"I I~]q,',," 'd~lii~9 hi~to* ,,,~ " SU~ I/"1 " . . , well iests' 0 I core dCscriptio4 cored intcwal~ core analyMs d~ ditch intc~als ,,, diflital data _ .... i ~ t _] i j ~ ii ~1 . ]llllJ .i i i i ii i i iJi i ii ii iii iiii i i ii i i iiii i .i ........................... ,, ............................. ,,,, ,,,,,, ....... LOG' TYPE * RUN INTERVAES SCALE NO. ,(to the nearest foot) i (inch/100'1 ~ ............. , , , ,,,1 i i , i i IL I,1111 III II IIIII ~11~1 i i . ARCO Alaska, Inc. Post Office Box -,00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering August 29, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SRU 32A-33 Dear Mr. Smith: From 4/28/91 thru 5/10/91 ARCO Alaska, Inc. succesfully completed perforating SRU 32A-33 H1 and H2 Sands (10,800'-10,820',10,835'- 10,854'). A bridge plug was also set at 10,890' MD. Please refer to the attached submittal of the Subsequent Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, T. Wellman TW:DRH:czm:0125 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown~ Stimulate Plugging X Perforate X ' ~'~ ~, Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing Other 2. Name of Operator ARCO AlaSka, Inc. 3. Address P.O. Box I O0360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory .... Stratigraphic __ Service 4. Location of well at surface 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth At total depth 1990' FNL, 1133' FEL, Sec.33, T8N, Rgw, SM 6. Datum elevation (DF or KB) RKB 198' GL 172' 7. Unit or Property name Swanson River Unit 8. Well number SRU 32A-33 9. Permit number/approval number 91-14 10. APl number 50-133-10164-01 11. Field/Pool Swanson River/ Hemlock 12. Present well condition summary Total Depth: measured true vertical 11396' 11165' feet Plugs (measured) feet 10890' (Bridge Plug) Effective depth: measured 11319' true vertical 11098' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Current: Current: Length Size Cemented Measured depth 30' 22" Driven 30' MD 2540' 13-3/8" Yes 2540' MD 8685' 7" Yes 8685' MD 2187' 5" 325 sx 8379'- 10566' MD measured 10800' - 10820', 10835' - 10854', 10900'- 10912' MD true vertical 10656' - 10673', 10686' - 10702', 10741'- 1075 I' TVD Tubing (size, grade, and measured depth) 2-7/8" to 8911' MD; 2-3/8" from 8912'-9499' MD, 2-7/8" Liner from 9499'-1 Packers and SSSV (type and measured depth) Packers: Liner Top Packer @ 8379' MD, Baker "SC-IL" Packer @ 9499' MD True vertical depth 30' TVD 2540' TVD 8685' TVD 8379'- 10453' TVD CEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/ ~laska Oil & ~ea$ Co~$. Commission Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 850 1000 400 Subsequent to operation 800 3000 1 1 O0 1200 600 15. Attachments Copies of Logs and Surveys run~ Daily Report of Well Operations ~ 16. Status of well classification as: Oil ~ Gas Suspended~ Service.~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~/~---~., Title Cook Inlet Regional Engineer, Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MAY-ii-'91 08:0? ID/~'~!ANSON RIVER TEL NO: 2651 ~-~ ~595 PO1 ARCO Alaska, In(:. (~ gube4dJv of Atl.ntl(= R~ehf~eM ~ · WELl. IPBDT ..('~//.~ZA_-~_~ . ~:)NTI=mCTO,~ lilI~MAINK~ T . · V ."'~--_.=.._ J_ .. ! WELL SERVICE REPORT IFIELD · DIi¥HiCT* hYATt. I DAY~ DATE ._c,.,.=.,,.,~ ~,,~.~ _,~",-,,.,, ! _. OPERATION AT INEF~T TIME .T_UtX,d(.. l:M,'-tt INlitea..__'Th plfA.-ce--d-"~lZ/Jl/___- /--'-~-'~q iii --. - - - - - -- e- --,~-- ...... ~w ~ - . -- _. ,, , . ....... /l~.,,dJ A ~.~ ..... ' .................... ~ -- · ~ ~, ~lr'~"' ~ll~ ~""- {:~ 'CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK /'~'-"t ,Mot /u/.-~*~l ~u/- ~AY"~ .w..~.~. J T..,p. I c.,,, F... I Visibility J W~nd v.,. '"-' i~w~' ~_ "' ~-, -- '" ----"-- .... APR-29-~gl ~4:59 I, ARCO Alaska, Inc. WELL SERVICE REPORT j. z~, ~,/ C, ONTI::LACrO~ REMARK8 IgToo- D?/~' FIEI. D - DISTRICT. ST~i tOPERATJDN AT REPORT TiME ~ 5ud. s i · ['-]-" CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Wlltltl' J 'ram~_ i e~kl,I ~.~ I ~-,",-".,.--' ' ' ' ........ r =%' . Arc' Alaska Inc. - Swanson Well- SRU 32A-33 APl#: 50-133-20337-01 Spud Date: 12/60 Completion Date: 4/14/~1 STK RKB: 29'(TBG HD) Original RKB' 15' (TBG HD) Top of Hemlock:lo,659 TVD Max. Hole Angle: 34° Field Well Type: Producer Last Workover: Hanger Type' Schaffer Angle @ Hemlock' 30° Ail Depths are RKB MD to Top of Equipment. Jewelry I 29' 2 29.65' 3 4006' 4 6178' 5 7266' 6 8339' 7 8379' 8 8875' 9 8877' 10 8910' 11 8950' 12 9454' 13 9498' 14 9499' 9509' 9510' 15 10,890' 16 11,319' 11,352' 11,384' 17 11,396' Tubing Hanger 3-1/2" X-Over 3-1/2" x 2-7/8" Camco Model MMGP GLM 2-7/8" x 1-1/2" Camco Model MMGP GLM 2-7/8" x 1-1/2" Camco Model MMGP GLM 2-7/8" x 1-1/2" Camco Model MMGP GLM 2-7/8" x 1-1/2" 5" x 7" Uner Top Packer 2-7~8" Baker Sliding Sleeve, ID 2.313" 2 -7/8" "X" Nipple, ID 2.313" X- Over 2 -7/8" x 2 -3/8" ID 1.960" GLM TMPDX Teledyne 2-3/8" x 1" GLM TMPDX Teledyne 2-3/8" x 1" Baker E22 Anchor Seal Assembly Baker "SC-IL" Packer (As a Uner Top/Production Packer) Baker Mill-out Extension Baker X-Over Bridge Plug (Set 5/10/91) Baker-Brown Type Landing Collar Baker-Brown Type Float Collar Baker-Brown Type Float Shoe Fish Below 5" Shoe 10' BHC/AC Logging Tool H1 H2 H3/4 8 9 10 11 12 13 14 15 16 17 PBTD = TD= 11,319' 11,396' Casing and Tubing Size Weight Grade Top Bottom Descriotion 22" 13 -3/8" 7" # 2-7/8" 2-7/8" 2-3/8" 0 30' Conductor Pipe 54.5# J-55 0 2540' Suface Casing 29# N-80 0 349' Production Casing 26# N-80 349' 1268' 23# N-80 1268' 4672' 26# N-80 4672' 6210' 29# N-80 6210' 7901' 26# P-110 7901' 8685' Whipstock @ 8,685' 18# N-80 8379' 10,566' Liner 6.5# N-80 9499' 11,386' Liner 6.5# N-80 0 8911' Tubing 4.7# N-80 8912' 9499' Tubing Perforation Data Interval Zone F T SPF Date Comments 10,900-912' H3/H4 12 I 4/22/91 Below B.P. 10,835'-854' H2 19 4 4/28/91 Open 10,800'-820' H1 20 4 5/10/91 Open Well SRU 32A-33 By: JLB 8/29/91 revised I~ ~' SR Te N PR · IT?N 6 I' iPOSED SIDETRi CK I I0 ORIGINA I II I 12 15 I I 22 I 25 I SCALE: I"= I MILE I I CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a proposed drilling location. Dimensions and other details furnished by Arco Alaska Inc. Surveyor PROPOSED SIDETRACK SRU- :52 A - 3:5 Locoted In Sec.$3 t T. 8 N.t R.9 W.t S.M.t Alaska for ARCO ALASKA INC. RO. BOX 100560 ANCHORASEt AK. 99510-0560 by R.C. DAVIS 8~ ASSOC. LAND. 8 MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH.~AK.99516 ARCO ALAS~ INC. Cook Inlet Engineering #540 TRANSMISSION TO:. COMMISSIONER COMPANY: AOGCC DATE: 5/24/91 FROM: Victoria Fer~mson COMPANY: ARCO Alaska, Inc WF.I.I. NAME: Listed Below Transmitted herewith axe the following - Blue Sepia Sepia rape & Line Folded Rolled Mylar listing SRU 32A-33 PFC LOG 1 1 ACBL 1 1 SRU 242-16 DUAL BURST THERM DEC 1 1 TBU K- 19 VERTILOG 1 1 SEGMENTED BOND LOG 1 1 Receipt Acknowledgement: Return reciept to ARco ALASKA, Inc, ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: ARCO Alaska, Inc. Post Office Box lu0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Weliman Regional Engineer Cook Inlet Engineering May 3, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to plug back the H3/4 interval and perforate the Hi interval in SRU 32A-33. We propose to perforate 20' of the HI sand (10,800'- 10,820' MD) using 1 11/16" perforating guns @ 4 spf. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Jim Zernell at 263-4107. Sincerely, T. Wellman Regional Engineer TW:jkw:czm:0065 Attachment cc: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED MAY - 9 t991 Alas~ Oil & Gas Cons. Gomn~iss~Oa Anch. rag STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend__ Alter casing __ Repair well Change approved program __ 2. Name of Operator ARCO Alaska, Inc,, 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown _ Plugging X Pull tubing __ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1990' FNL, 2110' FEL, Sec. 33, T8N, Rgw, SM At top of productive interval At effective depth At total depth 1990' FNL, 1133' FEL, Sec. 33, T8N, R9W, SM Re-enter suspended well __ Time extension Stimulate Variance_ Perforate X Other__ 6. Datum elevation (DF or KB) RKB 198', GL 172' 7. Unit or Property name Swanson River Unit 8. Well number sRU 32A-33 9. Permit number 91-14 10. APl number 50-133-10164-01 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total Depth: measured true vertical 11,396' feet Plugs (measured) 11,1 65' feet Effective depth: measured 11,319' feet Junk (measured) true vertical 1 1,098' feet Casing Length Size Cemented Measured depth Structural Conductor 30' 22" Driven 30' MD Surface 2540' 1 3-3/8" yes 2540' MD Intermediate 8685' 7" yes 8685' MD Production Liner 21 87' 5" 325 sx 8379'-10566' MD Perforation depth: measured Current: 10835'-10854', 10900'-10912' MD Proposed: 10800'-10820' MD true vertical Current: 10686'-10702', 10741'-10751' TVD Proposed: 10656'-10673 ' TVD Tubing (size, grade, and measured depth 2-7/8" to 8911' MD; 2-3/8" from 8912'-9499' Packers and SSSV (type and measured depth) Packers: True vertical depth 30' TVD 2540' TVD 8685' TVD 8379'-10453' TVD RECEIVED MAY - 9 t991 MD; 2-7/8" Liner from 9499'-11386'/ll~J~ Oil & Gas Cons. Corem Liner Top Packer @ 8379' MD; Baker "SC-IL" Packer @ 9499' MD Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: oi~ _.X_ C=as Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)-[4~~-~.-~--~ Title Cook Inlet Recjional En~r. FOR COMMISSION USE ONLY Date 5'~ ~-~':) / Conditions of approval: Plug integrity BOP Test Mechanical Integrity Test__ Notify Commission so representative may witness Location clearance Subsequent form require 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission IApproval No. I "Commissioner Date~.~ -" J~ '" ~'~// ~si0n Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE E-Line BOPE's Grease Head/ Hydraulic Packoff ~-- Lubricator Extension RECEIVED · UA? - 9 ~99~ 41as~.Oii & Gas Cons. Commission ~chorage Manual Rams Swab Valve Double Mastez Valves III Wellhead Attachment #1 SRU 32A-33 Procedure to Plua Back H3/4 and Perforate the H1 _ SR ### Objective: Plug back the H3/4 and perforate the H1 sand. W~ll Data: All measurements are from RKB, unless otherwise noted. 2-7/8" tubing to 8,910' and 2-3/8" tubing from 8,910' to 9,499' 2-7/8" liner from 9,499' to 11,386' Restriction(s)- Min Restriction 2-3/8" 4.7# Tubing: Drift Dia. = 1.901" Baker Sliding Sleeve @ 8,818': Min Dia. -- 2.313" Otis 'X' Nipple @ 8,878' Min Dia: = 2.313" X/O 2-7/8" x 2-3/8" @ 8,912': Min Dia. = 1.960" Baker Locator/Seal Assembly @ 9,499': Min Dia. = 2.00" PBTD - 11,319' Current Status: Well currently perforated with I SPF in the H3/H4 from 10,900°-912. and 4 SPF in the H2 from 10,835'-10,854'. Procedure: . Hold pre-job safety meeting. Verify with the Anchorage office that Sundry approval has been received from the AOGCC. Shut in well 6-8 hours before perforating. To reduce the risk of sticking the perf guns in the 2-7/8" liner the well will not to be shot underbalanced. Load the tubing with lease crude if necessary. 2. Make a 1.75" gauge ring run to PBTD. . RIH with Maria 'Wide Range' Bridge Plug on E-line and tie into CCL from CBL (4/20/91). Set at 10,890' above the H3/4 perforations. Log off of BP with CCL to verify setting depth. Note: The maximum ID that the BP can be set in is 2.441"which is equal to the tube of 2-7/8", 6.5# tubing, therefore it is imperative that the plug is not set in a collar. . RIH with 1-11/16" perf guns with CCL and perforate the H1 as shown below. CCL should be tied back to open hole Induction Electrolog Run # 2 (4/9/91) via the GR/CCL from the CBL (4/20/91) and the original H3/H4 perforating runs. Induction Electrolog (Run #2 4/9/91) Footaae Sand SPF Run #1 10,800'-820 20' H1 4 Note: Guns should be oriented 90° from bottom with 0° Phasing. Approx. H1 and H2 Mid-perf TVD = 10,683' (from Sperry Sun Gyro). Estimated BHP 4,000_+ psi (from SRU 32-33 BHP survey prior to sidetr_ac_k)~ RECE IV L) MAY - 9 t991 Alaska Oil & Gas Cons. CommiSS'toa Anchorage SRU 32A-33 Plug H3/4 and Perf HI. Page 2. Company Gun Ty.oe GunS~e ~ Hole Dia.* Western Atlas Jumbo Jet III 1 - 1 1/1 6" 5.84" 0.24" Schlumberger Hyperdome 1 - 1 1/1 6" 4.63" 0.28" Halliburton Logging Services does not offer 1-11/16" perf guns in Alaska. * APl test data in Berea Sandstone. 4. POOH with guns and verify that all shots were fired. 5. Return well to production. Gauge well for 24 hours after RTP and on days 3, 7 and 9. RECEIVED MAY - 9 Alaska 0ii & Gas Cons. Commissio[~ Anchorage ARCO ALASKA INC. Cook Inlet Engineering #533 TRANSMISSION COMMISSIONER COMPANY: AOGCC DATE: 4/29/91 FROM: Victoria Fer[~uson COMPANY: ARCO Alaska, Inc WELL NAME: SRU 32A-33 Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled Mylar lisfin$ BHC ACOUSTILOG 1 1 COMP NEUTRON 1 1 COMP NEUTRON 1 1 BOREHOLE PROFll~E 1 1 4-ARM CALIPER 1 1 INDUCTION ELECTOLOG 1 1 Receipt Acknowledgement:~ ~J/~ Return reciept to ARCO ALASKA, Inc. ATTN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: RECEIVED Alaska Oil & Gas Cons. Anchorage ARCO ALASKA INC. Cook Inlet E8gineering #530 TRANSMISSION T~ COMMISSIONER COMPANY: AOGCC DATE: 4/18/91 Transmitted herewith are the following FROM: Victoria Ferguson COMPANY: ARCO Alaska, Inc WELL NAME: Listed below SCU 43B-8 PDK-100 GR CCL SEGMENTED BOND LOG SRU 32A-33 ACBL VDL/SIGN/GR Remm reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: ALASKA OIL AND GAS CONSERVATION COMMISSION February 5, 1991 WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Swanson River Field, SRU 32A-33 ARCO Alaska, Inc. Permit No. 91-14 Sur. Loc. 1990'FNL, 2110'FEL, Sec. 33, TSN, R9W, SM Btmhole Loc. 1990'FNL, lll0'FEL, Sec. 33, TSN, R9W, SM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, '~~Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill _ Redrill ~/lb. Type of Well Exploratory __ Stratigraphic Test ~ Development Oil .~. Re-Entry X Deepen~'~°~'4 Service _ Development Gas __ Single Zone w Multiple Zone__ ?_. Name of Operator 5~Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 187 feet Swanson River Field 3. Address 6. Property Designation /~7..~,~/~./~ ~<~ / /,~ P. O. Box 100360, Anchorage, AK 99510-0360 A-028399 4. Location of well at sudace 7. Unit or pro~Hy Name 11. Type Bond (see 20 AAC 25.025) 1990' FNL, 2110' FEL, Sec.33, T8N, R9W, SM ~wanson River Field Statewide At toP of produ~ive interval 8. Well number Number SRU 32A-33 gU630610 At total depth 9. Approximate spud date Amount 1990' FNL, 1110' FEL, Sec.33, T8N, R9W, SM. 02-10-91 $200,000 12. Distance to nearest 13. Distan~ to nearest well 14. Number of a~es in pro~y 15. Pr~s~ depth (MD a~ TVD) property line SRU 32-33 WD 11483' MD SCU ~ 650 feet 153' ~ sruHa~ feet 2560 11300' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 8300'feet M~imum hole an~le 22 o Maximum sudace 1663 psig At total ~pth (TVD) 3362 psig 18. Casing program ~ Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~ Weight Grade Couplin~ Length ~ ~D ~ ~D (include sta~e data~ existin~7", ~3/26/29 N-80 BTC sectio3 mill horn 83~)0' to 8~50' 6" 5" 1 8~ N-80 FL4S 2600' 8000' 8000 10600', 10500' 250ex Class G , 4.13" 2-7/8" 6.5~ N-80 EUE8rd 1200' 1030~ 1020( 11483" 11300' 100ex Class G 19. To be completed for Redrill, Re-entry, and Deepen O~rations. Present well condition summary Total depth: measured 11386 feet Plugs (measured) 32-33 will be P&Aat 8300', true vertical 11386 feet 32A-33 will ~ side tracked rom 32-33 Effective depth: measured feet Junk (me~ured true vertical feet Casing Length Size Cemented Measured depth True Ve~ical depth Intermediate ProductionJAN 3 d 1991 Liner Perforation depth: measured ~aS~0~~ ~G~S 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Dive,er Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed repo~ ~0 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and corr~t to the best of my knowl~ge Si~ned ~~ ~~Commission useTitleonly Area Drillin~ Engineer Date ~/,/~ so-/~X -/~/~ ~-~/ 0 2 / 0 5 / 91 other requirements Conditions of ~pproval Samples required ~Y e s ~ N o Mud Icg required~ Y e s N o Hydrogen sulfide measures~ Yes ~ N o Directional su~ey required ~Yes ~ N o Required working pressure for BOPE ~ 2M; ~ 3 M' ~ 5 M' ~ 1 0 M' ~ I 5 M Other: b~~ ~~ -" by order of Approved Commissioner the commission Date & Form 10-401 Rev. 7-24-89.,,~ in triplicate SRU 32A-33 General Procedure PRE-RIG WORK · 2. 1 e Rig up a Precision slickline unit and run a gauge ring to the top of any fill. Clean out to bottom if necessary with SLU. Install dummy valves in the GLM's and a circulating valve in the lower most mandrel. Rig down SLU. RU Howco and circulate the well with lease water. Monitor the well to make sure it is dead. Release Howco. Rig up Atlas Wireline and set a 3.5" retainer above the gravel pack packer (10370'). Perforate the 3.5" tubing above the retainer. RD AWS. RU CTU. RIH and close the annulus to establish an injection rate into the GP. Perform a squeeze into the gravel pack with Howco Matrix cement. Tail the Matrix cement into the 3.5" blank pipe and gravel pack with Class G cement. Open up the annulus and set a plug in the 3.5" by 7" annulus and in the 3.5" tubing. POH with CTU. Pressure test plug before rigging down the CTU. RD and release. Rig up AWS and RIH and tag TOC with a sinker bar. RIH with a tubing cutter and cut the tubing above the TOC. RD and release the unit. Si Prepare the location for the rig. MIRU Grace Rig #154. Alaska 0il 8, G~s (;o~s. ~°~ssl°~ · · Install BPV in tubing hanger, ND tree, NU BOPE, and test same. Prepare to pull out of the hole with the remaining completion assembly. e Test casing to 3000 psi. If the test is good, POH. While pulling out of the hole, stop at 9000' and displace casing w/Hi-Vis 12.5 ppg mud suitable for section milling. If the casing does not test, finish pulling out of the hole and call the drilling superintendent for further instructions. , RU AWS and PU TIW SS-WS whipstock packer for 7" 29# casing and RIH. Set the SS-WS at 8300'. POH with WL and RIH with a gyro and determine the orientation of the SS-WS. 5. GIH w/ a Greatland pack stock for 7" casing. . Side track well out of window with 1000' displacement (+50') to the East of the current bottom hole location. Build 2 o/ 100 ft to 22° and hold to TD. Drill well to top of G sand +10,500' TVD (10,601' MD). 7. Make conditioning trip for running 5" liner. 8. POOH. Lay down drill pipe. , RIH with a Baker 5" 18# liner w/ pkr and cement same. Make sure that the float/shoe equipment is drillable. 10. Clean out to top of liner and test same to 3000 psi. Drill out 10' and perform leak-off test. 11. Decrease mud weight to 10.0-10.5 ppg. Drill 4-1/8" hole to +11,300' TVD (11,483'MD). 12. Log open hole and make any additional necessary rat hole on the conditioning trip prior to running 2-7/8" tubing section. 13. Run 2-7/8" tubing and cement in place from 9800' to TD. 14. Clean out to top of tubing and test same to 3,000 psi. 15. Clean out inside of liner and retest to 3,000 psi. 16. Run cased hole logs 17. Run completion assembly. 18. ND BOP's, NU tree, and test same. 19. Displace to lease crude. 20. RD and MO rig. 21. Perforate with through tubing guns. 22. Turn well over to Production Supervisor. Opsa. LandDipectional Dpilling. ~..~'. A, KB 0 ON OE KOP BUILD 2.00/S00 8300 ON O E C) E~ OF 2.00 BUZ~ 94,7 ON 2,5E D) TARGET/B~ ,,~3 ON iO00E PLAN V'TEN ARCO ALASKA. INC. SRU 32-33 CLOSURE ..... : t000 ft N 90.00 E 'DECLINATION.: 0.00 E ~ SCALE ....... : I irlch = 200 feet DRANN ....... : 0i/09/91 700 600 500 400 300 2OO ~ t00 " 0 & 3oo 400 5OO 600 700 lO0 0 tO0 <- NEST ' EAST -> 9o.,)o 200 300 400 500 600 700 800 900 iO00 iLO0 Grea'~ ~mnd Directional Drillin~ <KB> o 65O i300 ~ I i950 , 2600 3250 39Q0 4550 §200 ---~ 5850 6500 7t50 7800 B 8450 I~ gto0f 9750 i0400 ii050 itTO0 650 VERTICAL SECTION VIEW ARCO ALASKA. INC. SRU 32-33 Sect ion at: N 90.00 E TVD Scale.: ! inch = i300 feet Dep Scale.: 1 inch: 1300 feet Drawn .....: 01/09/9i Harken IUentificatton HD TVD SECTN INCLN ~) KB 0 0 0 0.00 B) KOP BUILD 2.00/t00 8300 8300 0 0.00 C) END OF 2.00 BUILD 94i7 9388 2t5 22.33 D) TARGET/BHL ii483 ii300 tO00 22.33 65O t300 2950 2600 3250 3900 4550 5200 5850 6500 Section Departure C~PLETICN REPORT SWANS~ RIVER UNIT 32-33 Section 33~ T. 8 N.~ R. 9 W.; Seward B &,M STANDARD OIL CO. OF CALIFORNIA, W.O.I. - OPERATOR Page 16. Depth 2844 ' 3700' 3960' 4190' 4534' 5251' 5647' 6065' 6239' 6453' 652~' 6627' 7111' 7770' 8336' 9176' De~rees OO 30' 0° 30' 1° O' O° 30' OO 45' lO 15' lO O' 0° 45' 0° 45' OO 15' lO O' 0° 45' 1° O' OO 45' lO O' 1° O' 1° O' SRU 32-33 WELLBORE SCHEMATIC ,~_ 22"@ 30' ~,,~_~ 13-3/8" @ 2540' .,~.,,~.~ Top of SRU 32-33 5" Liner @ 8000' Anchor Stock set @ 8300' Top of Cement @ +/-10,100' 7-5/8" Retainer @ 10,400' TeL 2.875" @ 9800' ~5" Shoe@10600' Fish Detail SRU 32-33 Abandoned Wellbore Note: PBTD@ 0,938' ~.,,--"" 1 1,03 0' TD od 4-1/8" hole = 11483' = Cement All depths are measured, corrected to RKB=164', G.L.=138',RKB-G.L.=26' (Original RKB-G.U=I 7') 6 5 4 3 iI 13 5/8" 5000 Pc, BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUMC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE ~ME, 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 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5(XX) PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5(XX) PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1, 11' - 3000 PSI CASING HEAD 2. 11" - 3(X)0 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 3. 13-5/8' - 5000 PSI PIPE RAMS 4. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 5. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 6. 13-5/8' - 5000 PSI ANNULAR jt 01/14/91 GRACE 154 WeLL pm)IfiL! ii i ! ARCO ALASKA~" i#c S~AI~ ALASKA i COMPLETION Of:TAIL 1. Tubing, $-1/2' 9d1' H-BO ABI'~ S?C (4./- ~oc:~') 2. GLrl, 3-1/2' ~ Io~". w/ I-I/2" ck valve. ' 3. ~d" Otis'X' nipple, ABrl~ 4. Locator tubing seal asseemblg, Baker model 'S-22, w/ additional Seal units to allow for I0' of seal movemer ~3. Gravel packer. 7' Baker SC I- L ( 70-32 ) Gravel pack extentlon. Baker 80-32 with lower extentlon tO accomodatt I0' Of sial movement. "7. Saftg Joint, Baker model 'GP', .3-1/2' NU lOrd. 8. $-I/2' 9 2' N-BO NU lOrd Olank pipe w/weld( blade centralizers for 7' 2g" csg. g. · - .3- I/2' 9 2' N-80 NU I Oral .012 gage elakerwald screen w/welded blade centralizers f/7" 29e csg. I0. O-Ring seal sub' Baker. 3-1/2' NU lOrd 2.5' ID. I I. I0' - 3-1/2' telltale screen. 12. Baker model '$' snap latch Including 2, B0-32 seal uni~ 1:3. Sump packer, 8oker model 'D' (B4-:32) ~ MR e -*/r~- 7(g 0 I~ '"°"'" ='""'"""'""'1 q~- _~~~.~i~... SWANSON RIVER. ! I~ =" FIELD- ' ~,'....._,,,,, , ,,, / ...... _', --~.__._~:-_-_-_-_"_~---_~ . ,,,~./_,I_~/-- .......... ', I \.- -~-- ?,'- I ,~ ~l i ..m" ,,.,,3.~~ CENTRAL FAULT · ~.,. ~ .,,,. ,,ct, / '."" :~,, . ' ,..~.~,/ ]_T_.~~ '~ ~ ~~ .,:'..,' : " ~, ../ / ~ ,,.~----~_..' ./ /; I ' -'"' ''"-"" '.,,.~.:~,.~.." ~:'.~/'"J'"*'~"- I .. t8 ~ ,,..,.. . ..,,""' I ~,~ ...:, i i ~: : ..... ~ ' I ; '~' I )41 I ~ 314 ~ i..~; I i ~ ~.' ,~i~. ~ ?' ;..;, .- ~ : ~ ~ -,- ~I / · ~ ..... ~ -5''~,- [~ --~ .... -/ ' i .,.,o ~ t\ t I .. 1_.,~ ~, ? ' ' ' '~ "" ' ~ / / I/ optio~ # l ~ / : ..r." ...:" _..' / ~~..'~--~.:---~j~...~' j 8/ ,,,-..~, /.~..'~' ~' ~ i ~x ~-.'-'"',' 1 ., .,u,,~. i~ ~/~ // ,~,S 3._. _m. ? :&_'.:~. ~.-- .-- --~L~_.--. --. --. q,. -- ,-- . ,,~. '1 / ./~// .~.~': $OLDOT~A eRE [ K \ r /i ' .,-r,._.~' ..~' I. .~,~ / \ ~ ~ \ I ?' ;'*! I ...' ".,,., .~....,. SCU 32A-33 Drillinq Fluids Proqram Sidetrack Point to +/-10500' At Total Depth Density Funnel Viscosity PV YP Initial Gels 10 minute Gels Fluid Loss pH % Solids 12.5 45-50 20-30 15-20 2-10 5-20 5-10 8.5-9.5 6-10 10.0 38-46 12-18 8-12 2-10 5-20 4-8 8.5-9.5 8-12 Drillina Fluid System - Dual tandem shale - Mud cleaner - Centrifuge - Degasser - Pit level indicators - Trip tank - Fluid flow sensor - Fluid agitators shakers (visual and audio alarm) AOILAND GAS CONSERVATION COMM!' ON APPLICATION FOR SUNDRY APPROVALS 1. Ty~e of REquest: Abandon ~X 2. Name of Operator Alter casing _ Change approved program _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Repair well _ Plugging .3_ Time extension _ Stimulate _~ Pull tubing .JL. Variance _ Perforate _ Other_ 6, Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At top of productive Interval 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At effective depth 1990' FNL, 2110' FEL, Sec. 33, T8N, R9W, SM At total depth 1990' FNL, 2110' FEL~ Sec. 33~ T8N~ R9W~ SM 12. Present well condition summary Total Depth: measured 1 1 3 true vertical 1 1 3 8 6 feet Plugs (measured) 8 6 feet None Effective depth: measured 1 0 941 feet Junk (measured) tma~ verttcaJ~ 1,~9.4,1~ feet~, ~ Casing Length Size Cemented Structural Conductor 30 ' 2 2 ': To Surface Surface 2540 ' 13.38" 1200 Sx in Intermediate 2 stages Production 11030 ' 7" 1400 Sx in Liner 2 stages Perforation depth: measured RKB 187 7, Unit or Property name Swanson River Field feet 8.', Well number SRU 32-33 9.. Permit number 7-488 10. APl number so-133-10164 11, Field/Pool Swanson River Field RE£EIVED ;lAN o 1991 Uoasur~~~~ca~depth : 30 ' 30 ' 2540 ' ' 2540 ' . 11030 ' '11030 ' 13. P & A well to perform a sidetrack 1000' due east of present 14. Estimated date for commencing operation 15, · February, 1991 16. If proposal was verbally approved Name of approver Date approved 10566 '-10582 ', 10590 '- 10600 ', 10648 '- 10660 ', 10680 °- 10720 10725 '- 10745 ', 10748 '- 10750 true vertical 10566 '-10582 ', 10590 '- 10600 ', 10648 '- 10660 ', 10680 '- 10720 10725 '- 10745 ', 10748 '- 10750 Tubing (size, grade, and measured depth) 3.5" N80/J-55 TUBING WITH TAIL @ 10772' wlm Packers and SSSV (type and measured depth) 70 B2-40 SCIL pkr @ 10371 '; sump pkr @ 10772' wlm Attachments Description summary of proposal JL. Detailed operation program _ BOP sketch BHL {Wellbore schematic attached). Status of well classification as: Oil Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, / FOR COMMIsSiO~ USI~ ONI.~ Conditions of approval: Notify Commission so representative may witness / Plug integrity_ Mechanical Integrity Test BOP Test N Location clearance m Subsequent form require 10- IApproval No. I Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE . JDATE (3) Admin '('9 ~-hru /13)"" 10. /- (10 and 13) 12. 13. (4) Casg ~z~.~.~/~f ~-I-V,,! (14 thru 22) (5) UOPE ~L~./~Z ~-~-v~ (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. Company Ak=~_O_ . . .... - v Lease & Well No. /~/PZ ,,5f- O 2~.~ ~ ~/~ YES NO .... REMARKSJ Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3..Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. (6) OTHER 29. /~2~t~u 31) 30. 31. Eng~' neering: (6) Add: Geology: DWJ ~ C Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ ,, Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... __ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ -~ Is adequate wellbore separation proposed ............................ ~/~ Is a diverter system required ....................................... ,,, Is the drilling fluid program schematic and list of equipment adequate/~f Are necessary diagrams and descriptions of di~ar~a~ £n_ BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. rev: 11/30/90 6.011 O 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ,, INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, r, Additional Remarks: 7~;.~ ..c_z ¢ 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: 5.2 PART NUMBER: W5790-MICRO Start of execution: Wed 17 APR 91 9:52a **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 1 LIS o 001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI : ALASKA * COMMENT RECORD * FILE = CN-GR LOG UP: 11400 - 10510 FT. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 13 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CN 68 1 % 4 2 CNC 68 1 % 4 3 CNRA 68 1 DIM 4 4 COND 68 1 MMHO 4 5 GR 68 1. API 4 6 LSN 68 1 CPS 4 7 RT 68 1 OHMM 4 8 SN 68 1 OHMM 4 9 SP 68 1 MV 4 10 SPD 68 1 F/MN 4 11 SSN 68 1 CPS 4 12 TEN 68 1 LBF 4 13 TTEN 68 1 LBF 4 * DATA RECORD DEPTH GR SPD 11400.000 -999.2500 -999.2500 11350.000 12807626 30.99690 11300.000 288.5134 31.59650 11250.000 351.5029 31.39720 11200.000 401.7993 31.59061 11150.000 0.0000000E+00 30.99690 11100.000 61.27690 31.99680 11050.000 102.5676 31.99680 11000.000 63.88153 31.99680 (TYPE# CN LSN SSN -999.2500 -999.2500 -999.2500 12.83707 239.3237 469.7583 11.84625 251.9407 474.3110 18.67482 176.7515 429.8081 12.34729 262.4243 504.7043 11.54578 188.9045 351.0286 13.61446 260.3022 527.2708 14.55074 190.3714 399.9729 12.41544 240.4196 463.7104 0) 1014 BYTES * CNC RT TEN -999.2500 -999.2500 -999.2500 21.88148 4.89'2245 439.5146 20.66461 5.814908 134.8926 28.92177 3.099137 109.6899 21.28076 4.566443 50.45432 20.29433 6.580891 -13.35137 22.83177 3.432608 -38.54590 23.97108 5.683255 -42.39073 21.36444 6.088572 -48.79298 CNRA SN TTEN -999.2500 -999.2500 -999.2500 1.000000 7.572955 3894.980 1.000000 11.50560 3872.453 1.000000 6.099047 3941.765 1.000000 11.87300 3985.438 1.000000 10.34865 3953.365 1.000000 9.675438 3932.243 1.000000 11.21560 3904.184 1.000000 11.90540 3860.245 COND SP -999.2500 -999.2500 204.4051 40.06810 171.9718 38.95528 322. 6704 35.98021 218.9888 33.29576 151.9551 57.59584 291.3237 32.09473 175.9555 38.69406 164.2421 31.51480 10950.000 11.12108 19.76996 1.000000 127.6518 60.67509 32.03250 10900.000 70.53958 32.43280 10850.000 74.21626 32.39709 10800.000 90.22670 32.56070 10750.000 59.95897 32.99670 10700.000 55.01691 33.03241 315.2795 574.9714 12.43323 231.6132 447.0586 14.31087 213.1647 443.7476 11.90886 235.3719 444.3135 16.39580 154.0876 346.5745 16.07608 180.1954 400.6746 7.833810 -48.91042 21.38628 11.40340 -52.77811 23.67975 13.82759 -27.51894 20.74170 9.567841 -35.47636 26.19960 6.151851 -48.12320 25.81503 1.854209 -53.51163 17.21448 3844.492 1.000000 19.41493 3813.405 1.000000 22.41919 3815.796 1.000000 19.43767 3814.700 1.000000 8.021082 3786.702 1.000000 8.220858 3756.792 10650.000 0.8437567 6.723798 1.000000 105.7191 34.30621 1.872434 9.640732 34.59030 31.67171 267.7502 3704.739 10600.000 1.948493 8.159042 1.000000 58.95129 25.52071 1.902498 8.496639 32.99670 26.33549 78.94191 3682.203 10550.000 1.298839 7.315988 1.000000 48.47456 20.65570 2.353130 0.1006963 33.59630 20.00861 1.071160 3657.336 31.45660 87.69312 35.38026 72.31920 29.67668 104.5168 54.82150 162.5527 62.98932 539.3135 48.29686 534.0642 65.50754 525.6248 64.23248 424.9658 33.84361 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 99 11400.00 ENDING TAPE DEPTH = 10510.00 **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI : ALASKA * COMMENT RECORD * FILE = CN-GR LOG DOWN: 10680 - 11380 FT. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 13 CURVES : NAME 1 CN 68 2 CNC 68 3 CNRA 68 4 COND 68 5 GR 68 6 LSN 68 7 RT 68 8 SN 68 9 SP 68 10 SPD 68 11 SSN 68 12 TEN 68 13 TTEN 68 CODE SAMPLE# UNIT 1 % 1 % 1 DIM 1 MM_HO 1 API 1 CPS 1 OHMM 1 OHMM 1 MV i F/MN 1 CPS 1 LBF 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH CN CNC CNRA GR LSN RT SN SPD SSN TEN TTEN 11380.00.0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 COND SP -999.2500 -999.2500 11330.000 141.3663 29.99701 11280.000 82.95665 30.34200 11230.000 487.7917 29.99701 11180.000 157.6900 29.99701 11130.000 461.3601 28.99710 11080.000 389.5239 30.10620 11030.000 466.3784 30.88770 10980.000 398.6699 30.23280 10930.000 290.6851 29.99701 10880.000 412.3467 30.23280 10830.000 494.3665 29.99701 10780.000 395.7256 30.23280 10730.000 435.2219 29.99701 10680.000 -999.2500 -999.2500 11.62648 227.7458 424.6978 11.40509 209.4665 386.8423 10.58551 276.7180 492.5605 10.71759 280.6604 502.6047 10.28143 118.7321 208.3920 10.77327 258.6047 464.2827 11.69612 235.5926 440.6626 12.96616 104.4947 206.1982 11.78999 246.1065 462.2039 11.69260 226.9820 424.4922 6.173120 155.5596 219.6828 12.07944 205.6774 391.1035 8.258636 339.6460 539.4382 -999.2500 -999.2500 -999.2500 20.39384 4.854955 -17.78149 20. 12076 8.834223 -20.64606 19.10704 2.148464 -11.90476 19.27069 4.614531 -9.045689 18.72981 8.253679 -8.353947 19.33966 4.407375 -16.46756 20.47968 5.569360 -17.90778 22.03957 12.18836 -26.65120 20.59534 7.851608 -17.98859 20.47534 6.606534 -23.13181 13.57451 9.046070 -31.08102 20.95158 8.153896 -11.42774 16.20522 10000.00 -55.08179 -999.2500 -999.2500 -999.2500 1.000000 7.758607 2664.923 1.000000 16.20204 2641.889 1.000000 5.829077 2653.795 1.000000 11.66492 2659.262 1.000000 19.13869 2640.366 1.000000 9.926540 2635.842 1.000000 10.64418 2637.022 1.000000 30.80788 2624.842 1.000000 15.78788 2616.864 1.000000 15.55480 2622.260 1.000000 12.77693 2603.506 1.000000 10.20893 2624.381 1.000000 -0.1208883E-02 2608.465 -999.2500 -999.2500 -999.2500 205.9752 33.67024 113.1961 64.05527 465.4487 23.21332 216.7068 24.66002 121.1581 57.22456 226.8924 37.91682 179.5539 33.79816 82.04549 53.21568 127.3624 40.51653 151.3653 27.82379 110.5452 59.74101 122.6407 72.36952 -1.386819 66.49667 -999.2500 -999.2500 TOTAL DATA RECORDS : 78 STARTING TAPE DEPTH = 11380.00 ENDING TAPE DEPTH = 10680.00 **** FILE TRAILER **** **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI : ALASKA * COMMENT RECORD * FILE = MAIN PASS IEL/BHC: 10190 - 11160 FT. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 13 CURVES :~ NAME CODE SAMPLE# UNIT BYTES 1 A1R1 68 1 MV 4 2 A1R2 68 1 MV 4 3 A2R1 68 1 MV 4 4 A2R2 68 1 MV 4 5 AC 68 1 US/F 4 6 ACQ 68 1 DIM 4 7 CAL 68 1 IN 4 8 GR 68 1 API 4 9 PORA 68 1 % 4 10 SP 68 1 MV 4 11 SPD 68 1 F/MN 4 12 TEN 68 1 LBF 4 13 TTEN 68 1 LBF 4 * DATA RECORD DEPTH AC SP 11160.000 -999.2500 -999.2500 11110.000 67.55269 0.0000000E+00 11060.000 77.07765 0.9190137 11010.000 77.50021 0.8175952 10960.000 81.76796 0.6899832 10910.000 85.58742 0.8704823 10860.000 86.28088 0.9636291 10810.000 82.69287 1.236433 10760.000 81.55579 1.315575 10710.000 80.48497 1.797500 (TYPE# A1R1 ACQ SPD -999.2500 -999.2500 -999.2500 201.2230 0.0000000E+00 31.99680 153. 1870 0. 0000000E+00 31.99680 240.7131 0.0000000E+00 31.99680 368.7625 0.0000000E+00 31.99680 207.6177 0.0000000E+00 31.99680 112.5018 0.0000000E+00 31.99680 246.7905 0.0000000E+00 31.76100 177.3367 0.0000000E+00 31.99680 269.2549 0.0000000E+00 31.99680 0) 1014 BYTES * A1R2 CAL TEN -999.2500 -999.2500 -999.2500 103.4987 -2.484839 321.0759 93.81160 -2.495809 139.6052 79.06456 -2.487042 36.97758 138.7174 -2.489024 -20.84399 39.84431 -2.486300 -24.97432 34.85246 -2.490824 -14.22032 105.3690 -2.496252 i25.4523 68.95085 -2.490565 -61.64659 160.2532 -2.492603 -60.97345 A2R1 GR' TTEN -999.2500 -999.2500 -999.2500 98.38786 68.20972 3819.394 77.93779 66.00433 3883.948 57.38330 121.5208 3893.113 108.5395 57.79927 3854.886 30.66922 68.77792 3838.221 19.26605 65.65242 3861.699 103.0866 74.14409 4005.975 82.49683 68.06395 3826.030 119.7178 61.35524 3780.708 A2R2 PORA -999.2500 -999.2500 193.4232 9.028231 149.7516 16.16303 194.8192 16.47956 278.1301 19.67637 221.6580 22.53739 86.24112 23.05684 272.9319 20.36919 234.4727 19.51744 272.9866 18. 71533 10660.000 395.2288 207.8873 73.46527 204.7827 376.9011 1.471380 10610.000 66.76302 2.117810 10560.000 96.80113 1.139260 10510.000 94.70628 0.3528728 10460.000 59.38350 1.385177 10410.000 54.20969 0.9875778 10360.000 55.25270 1.449117 10310.000 55.30310 1.377282 10260.000 53.73442 1.083104 10210.000 50.00000 0.4266219 5.000000 36.74310 384.5994 1.000000 29.99701 25.44209 0.0000000E+00 30.99690 44.10472 3.000000 30.65190 131.3510 0.0000000E+00 30.99690 64.49358 .0000000E+00 30.10620 124.4880 0.0000000E+00 37.88701 71.29109 .0000000E+00 38.99609 49.59665 0.0000000E+00 38.99609 0.0000000E+00 0.0000000E+00 0.0000000E+00 -2.483435 72.64397 117.4671 -2.488291 5.435102 33.36963 -2.489094 -33.85988 29.77029 -2.480551 -35.87990 21.58241 -2.488814 -30.56894 24.37465 -2.489303 -29.08784 43.09329 -2.493358 -6.566039 22.69110 -2.469403 -31.69833 19.32304 -2.496353 -88.34081 0.0000000E+00 -2.4.88997 0.0000000E+00 72.77385 3753.365 123.5272 49.22926 3735.196 28.90138 51.40080 3697.692 25.66452 45.39520 3691.523 23.11917 39.08600 3668.508 21.68491 38.36041 3669.125 51.55862 38.20515 3684.971 20.61995 42.10854 3644.939 19.17755 43.60114 3581.161 0.0000000E+00 0.0000000E+00 3000.000 240.7499 216.5395 8.436716 42.95393 30.93718 33.44160 29.36800 129.6067 2.908988 81.42110 -0.9665271 125.0290 -0.1852428 69.77327 -0.1474902 57.01865 -1.322531 0.0000000E+00 -4.119850 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 108 11160.00 ENDING TAPE DEPTH = 10190.00 **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 4 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI : ALASKA * COMMENT RECORD * FILE = REPEAT IEL/BHC: 10980 - 11010 FT. * FORMAT RECORD (TYPE# 64) ONE. DEPTH PER FRAME TAPE DEPTH UNIT : F 11 CURVES : NAME 1 A1R1 68 2 A1R2 68 3 A2R1 68 4 A2R2 68 5 AC 68 6 CAL 68 7 GR 68 8 SP 68 9 SPD 68 10 TEN 68 11 TTEN 68 CODE SAMPLE# UNIT BYTES 1 MV 4 1 MV 4 1 MV 4 1 MV 4 1 US/F 4 1 IN 4 1 API 4 1 MV 4 1 F/MN 4 1 LBF 4 1 LBF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH A1R1 A1R2 AC CAL GR TEN TTEN A2R1 SP A2R2 SPD 11010.000 -999.2.500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : 3 STARTING TAPE DEPTH = 11010.00 ENDING TAPE DEPTH = 10980.00 **** FILE TRAILER **** **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 5 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI : ALASKA * COMMENT RECORD * ***NOTE*** 4-ARM CAL LOGGED ON 3/25/91. FILE = MAIN PASS: 4-ARM CAL (8630 - 10580 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 4 CURVES : NAME 1 C13 2 C24 3 CAL 4 GR CODE SAMPLE# UNIT BYTES 68 1 IN 4 68 1 IN 4 68 1 IN 4 68 1 API 4 * DATA RECORD DEPTH (TYPE# 0) 1006 BYTES * C13 C24 CAL GR 10580.000 -999.2500 -999.2500 -999.2500 -999.2500 10530.000 6.353710 6.261255 6.307483 46.10075 10480.000 6.499819 6.403279 6.451550 63.26405 10430.000 6.716316 6.690756 6.703536 61.91820 10380.000 6.673161 6.451043 6.562102 41.07950 10330.000 6.799236 6.404143 6.601690 46.43680 10280.000 6.911930 6.770607 6.841269 62.70381 10230.000 6.490608 7.101085 6.795847 42.70833 10180.000 6.876347 6.995034 6.935691 62.02374 10130.000 7.346265 6.448883 6.897574 55.53481 10080.000 7.323558 6.391411 ~6.857485 61.66853 10030.000 6.705980 6.378795 6.542388 37.44153 9980.000 7.700409 6.112652 6.906530 59.40683 9930.000 7.905809 6.104518 7.005164 48.35832 9880.000 7.202336 6.215119 6.708728 47.20874 9830.000 7.737832 6.053723 6.895778 63.35049 9780.000 9730.000 9680.000 9630.000 9580.000 9530.000 9480.000 9430.000 9380.000 9330.000 9280.000 9230.000 9180.000 9130.000 9080.000 9030.000 8980.000 8930.000 7.489292 6.389686 7.274920 6.543815 7.332430 6.472566 9.746922 7.070457 8.856964 7.081768 7.777270 8.116039 7.143222 7.778717 8.419436 10. 62136 7.363441 10.00727 6.849338 6.976812 7.767698 7.852484 8. 191345 7.606666 6.663943 6.849005 6.800596 6.996519 7.871454 8.096310 7.154037 8.573696 6.999104 7.077435 8.588804 6.517658 7.169315 6.683249 7.521309 7 · 198150 7.761889 7.039616 8.205429 6.959731 7.828780 7.039144. 7.824363 8.106178 7.148629 8.176208 7.709270 8.849396 7.976123 8.262466 63.89301 38.21689 38.88646 52.81398 56.27054 41.09737 18.09451 32.29919 57.69881 41.23155 56.75516 38.21114 39.07448 51.90163 58.55438 61.81282 68.40715 71.27682 8880.000 7.054398 9.493134 8.273766 57.95630 8830.000 7.577599 9.342260 8.459930 57.57500 8780.000 8.153126 8.331429 8.242279 39.67059 8730.000 8.571051 7.539298 8.055176 41.16873 8680.000 6.633985 6.362987 6.498486 22.34920 8630.000 -999.2500 -999.'2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 79 10580.00 ENDING TAPE DEPTH = 8630.00 **** REEL HEADER **** LIS 91/ 4/17 AWS 01 **** TAPE HEADER **** LIS 91/ 4/17 01 FILE # 6 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN : ARCO ALASKA INC. : SRU 32A-33 : SWANSON RIVER UNIT : KENAI STAT : ALASKA * COMMENT RECORD * FILE = REPEAT PASS: 4-ARM CAL (10320 - 10580 FT.) * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 4 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 C13 68 1 IN 4 2 C24 68 1 IN 4 3 CAL 68 1 IN 4 4 GR 68 1 API 4 * DATA RECORD DEPTH (TYPE# 0) 1006 BYTES * C13 C24 CAL GR 10580.000 -999.2500 -999.2500 -999.2500 -999.2500 10530.000 6.464553 6.172650 6.318602 40.67357 10480.000 6.636749 6.277271 6.457010 64.27719 10430.000 6.583541 6.745694 6.664618 62.59819 10380.000 6.720502 6.476398 6.598451 40.81227 10330.000 0.0000000E+00 0.0000000E+00 4.000000 0.0000000E+00 TOTAL DATA RECORDS : 11 STARTING TAPE DEPTH = 10580.00 ENDING TAPE DEPTH = 10320.00 **** FILE TRAILER **** **** TAPE TRAILER **** LIS 91/ 4/17 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 421 **** REEL TRAILER **** LIS 91/ 4/17 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : TOTAL RECORDS IN THIS PHYSICAL REEL: End of execution: Wed 17 APR 91 9:53a Elapsed execution time = 54.66 seconds. SYSTEM RETURN CODE = 0 422 422