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Home My WebLink About180-115By Anne Prysunka at 10:07 am, Nov 09, 2022 1 Regg, James B (OGC) From:Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent:Wednesday, November 2, 2022 12:40 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Subject:MIT - SRU 32-33WD - 2022/10/29 Attachments:32-33WD MIT - 2022_10-11 - AOGCC Form.xlsx; 32-33WD MIT - 2022_10-29 - AOGCC Form.xlsx; SRU 32-33WD Schematic 10-12-22.pdf Attached is the official report of the successful AOGCC witnessed MIT-IA, performed on SRU 32-33WD (PTD 1801150) on 10/29/22. Also attached is the official report of the successful MIT-IA performed after setting the packer during the recent RWO on 10/11/2022. The new schematic is attached for your reference. Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 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. 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. Swanson River Unit 32-33WDPTD 1801150  Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1801150 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 1937 BBL Pump 0.5 IA 0 1749 1743 1742 Interval O Test psi 1500 BBL Return 0.5 OA NA NA NA NA Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska LLC Swanson River Field / Swanson River Unit / 32-33 Pad NA Wade Hudgens 10/11/22 Notes: No OA in this well. Pre-injection MIT-IA performed after setting packer per Guidance Bulletin 10-02B. New packer set at 1787' MD / 1787' TVD Notes: Notes: Notes: SRU 32-33WD Form 10-426 (Revised 01/2017)2022-1011_MIT_SRU_32-33WD         J. Regg; 4/7/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 32-33WD SWANSON RIV UNIT 32-33WD Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/21/2022 32-33WD 50-133-20337-00-00 180-115-0 W SPT 1937 1801150 1500 730 730 740 745 OTHER P Kam StJohn 10/29/2022 MIT required on 2 year schedule per sundry 398-080. 30 days after starting Injection, Mono Bore no O/A. Cold diesel test fluid and with triplex pump so no bbls in or returned. Used calibrated Crystal digital gauge. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: SWANSON RIV UNIT 32-33WD Inspection Date: Tubing OA Packer Depth 237 1703 1702 1713IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221029175107 BBL Pumped:BBL Returned: Wednesday, December 21, 2022 Page 1 of 1 MIT required on 2 year schedule per sundry 398-080. 30 days after starting Injection, Mono Bore no O/A. Cold diesel test fluid and with triplex MIT required on 2 year schedule per sundry 398-080. 30 days after starting Injection, Mono Bore no O/A. Cold diesel test fluid and with triplex 1702 1713 740 745 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________SWANSON RIV UNIT 32-33WD JBR 12/09/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 3.5 test joint used for testing. Test Results TEST DATA Rig Rep:Chris HannevoldOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens Rig Owner/Rig No.:Hilcorp 401 PTD#:1801150 DATE:10/9/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopGDC221010105224 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 2.5 MASP: 1020 Sundry No: 322-575 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7 1/16" 5000 P #1 Rams 1 2 3/8"x3.5" V P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 1 2 1/16" 5000 P Kill Line Valves 3 2 1/16" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P2550 200 PSI Attained P15 Full Pressure Attained P36 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2050 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P6 #1 Rams P3 #2 Rams P3 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill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a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y Samantha Carlisle at 9:33 am, Sep 29, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ; ; %23 WHVW WR SVL $$&6)' %-0 '656)' 0,7,$ WR SVL DIWHU ZHOO KDV EHHQ RQ LQMHFWLRQ DW VWDEOH UDWHV 3URYLGH KUV QRWLFH IRU $2*&& RSSRUWXQLW\ WR ZLWQHVV ; 9DULDQFH WR $$&E LV FRQGLWLRQDOO\ DSSURYHG WR VHW SURGXFWLRQ SDFNHU QR VKDOORZHU WKDQ 0'79' DERYH SHUIV *&: Jessie L. 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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:Ryan Rupert To:McLellan, Bryan J (OGC) Cc:Donna Ambruz; Josh Allely - (C); Dan Marlowe; Meredyth Richards; Sarah Frey; Ryan Rupert Subject:RE: [EXTERNAL] SRU 32-33WD (PTD 180-115) 660" radius Date:Thursday, September 29, 2022 10:30:45 AM Attachments:SRF_32-33_pad_660".pdf 32-33WDMap and Log.pdf SRU 32A-33_Offset_Static_temp_Log_and_Schematic(06-05-22).pdf Here’s the documents as requested: 1. Arial 660’ photo 2. Static temp survey from offset producer SRU 32A-33 from 6/5/22 3. Map and log panel of the area I went ahead and just withdrew the prior sundry and submitted a new one with several updates based on what you and I had discussed, packer depth, etc… Please let me know if you need anything else. Thanks! Ryan Rupert Kenai Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, September 29, 2022 8:55 AM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] SRU 32-33WD (PTD 180-115) 660' radius Ryan, Could you send me the areal photo of this well site? Like the one with the 660’ radius you typically include with RWO sundries. I want to get an idea of where this wellsite is located and what’s around it. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual 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. 1200 ftSRU_32-33WDActive InjectionAbandoned InjectionAIO DepthsSRU_14B-27SRU_41-33SRU_32A-33 SEC. 33 8N9W SWANSON RIVER FIELD U S FISH & WILDLIFE SRU 21-33 Pad SRU 32-33 Pad 1-33 TS Source: Esri, Maxar, GeoEye, Earthstar Geographics, CNES/Airbus DS, USDA, USGS, AeroGRID, IGN, and the GIS User Community 150°51'40"W150°51'50"W150°52'0"W150°52'10"W 60°44'45"N60°44'45"N60°44'40"N60°44'40"N60°44'35"N60°44'35"N60°44'30"N60°44'30"N60°44'25"N60°44'25"N60°44'20"N60°44'20"N0 100 200 300 400 Feet 1 inch = 200 feet @ 11x17 Page Size Map Date: 3/22/2021 Document Path: O:\Alaska\GIS\cook_inlet\fields\All_Fields\SSSV_TWellman\mxds\All_Fields_Pad_SRF_660ftBuffer_11x17_TWellman_v01_SRF.mxdSwanson River Field SRU 32-33 Well Pad 660 ft Radius around Well Pad Legend Surface Well Location 660 Foot Buffer Around Well Pad Well Pad Outline KPB Parcels Cook Inlet Oil and Gas Units UNK (Potential Removals) SRF Pipelines UNK Gas Oil Waste Water Fuel Gas SRF Overview This Map No wells on this pad meet the criteria listed in 20 AAC 25.265(d). The 660- foot offset line is drawn from the pad boundary to indicate future wells drilled from this pad will not fall under 20 AAC 25.265(d). Well: Field:06/05/2022Hilcorp SRU 32A-33 Swanson River 50 60 70 80 90 100 0 500 1000 1500 2000 2500 3000 3500 4000 1100 1200 1300 1400 1500 1600 Temperature (Deg. F)MD / TVD Depth (vertical well)Pressure (psia) Pressure Perfs PKR 13 3/8"7" 3 1/2"GLM POOH Press Temperature POOH Temp Pressure-Temperature Profile 1. Well Static (2 days SI) AIO Upper Limit ~1740' MD/TVD Active disposal zone in 32-33WD (~100' away) Report date: 9/29/2022 Updated by CRR 6-8-22 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 4 2,514’1’2.810”X Nipple 5 2,525’1’2.991 Mule Shoe 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 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 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 3/4/5 2 8 6 37-0, UB Upper, UB Lower 7 7” window at 8,701’ 10 DV Collar @ 8,036’ TOL at 8,379’11 7X 9 Disposal Sand: 2082’– 2420’ Expected casing leak in 5” liner at FL4S connection. 13ppg mud to kill well. Updated by CRR 6-8-22 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 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) 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… 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 2022-0902_Well_SRU_32-33WD_gc Page 1 of 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:September 2, 2022 P. I. Supervisor FROM:Guy Cook SUBJECT:Well Inspection Petroleum Inspector SRU 32-33WD Hilcorp Alaska LLC PTD 1801150 9/2/2022: I stopped by Swanson River Unit 32-33WD early this morning on my way back from the BOPE test on the Dolly Varden Platform. You requested the site visit to inspect the wellhead on this shallow disposal well. The following background was forwarded from AOGCC Engineer Bryan McLellan: SRU 32-33WD has a history of shallow water flow outside the surface casing. The well recently failed a MITIA due to tubing leak and we have a sundry application for a tubing RWO that we are reviewing. Upon review of the well, we saw the history of shallow fluid flow copied and pasted below from the wellbore diagram and several shallow perf and squeeze intervals in the surface casing. The well has had a considerably high volume of produced water injected over the years and it is a shallow injection zone at 2100’. So, although the tubing failure is unrelated, we’d like to have a look at the well and observe any signs of fluid flowing outside the casing and get some photos of the cellar before approving this sundry for continued injection. The well was shut in while I was there. No surprise there is water in the cellar since we have had so much rain lately. I saw no movement in the water and no indication of past flow from the well in the cellar. It would be difficult due to the grass and such in the cellar. There was no sheen on the water in and surrounding the well cellar. I didn’t smell anything that would lead me to believe there was anything from the well in the cellar either. While at location I told the Hilcorp operators that approval is required before using the well since it failed a MIT (should remain shut in). I spoke to the control room after returning home and realizing the gauge pressures were not readable. The current pressures are tubing 760 psi and inner annulus (IA) 740 psi. I was told SRU 32-33WD was put on injection to get rid of some water. They couldn’t show me proof of an approval to operate the well while at location but said our office approved injection through September since a rig workover is planned. Attached are pictures of the well sign, well, pressure gauges, and well cellar. Attachments:Photos from AOGCC Engineer Bryan McLellan history of shallow water flow outside the surface casing. 2022-0902_Well_SRU_32-33WD_gcPage 2 of 5 Well Inspection – SRU 32-33WD (PTD 1801150) Photos by AOGCC Inspector G. Cook 9/2/2022 2022-0902_Well_SRU_32-33WD_gcPage 3 of 5 2022-0902_Well_SRU_32-33WD_gcPage 4 of 5 Tubing pressureTubing-casing annulus (IA) pressure 2022-0902_Well_SRU_32-33WD_gcPage 5 of 5 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: SRU 32-33WD (PTD 180-115) TxIA Communication Date:Tuesday, August 23, 2022 11:52:22 AM Attachments:SRU 32-33WD schematic 2022-08-15.pdf SRU 32-33WD TIO.xlsx From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Monday, August 15, 2022 5:28 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: SRU 32-33WD (PTD 180-115) TxIA Communication Mr Wallace SRU 32-33WD is exhibiting TxIA communication. SRU 32-33WD is a Class 2 disposal well that was due this month for its quadrennial MIT-IA. Operations was performing a pre state witnessed pressure test and, at approximately 1400 psi on the IA, the IA pressure equalized with the tubing (~700 psi) indicating we have a well integrity failure. The IA was bled but it immediately pressured back up and matched tubing pressure. The planned MIT-IA test pressure was 1500 psi. Prior to this failure, IA pressure was on average ~400 psi less than tubing pressure and there is no history of bleeds. SRU 32-33WD is responsible for disposing of produced water from Swanson River Field production and it’s injection capacity is necessary to keep Swanson River Field operating at full capacity. The well currently injects an average of 3000 bwpd but can inject anywhere from 500 to 7000 bwpd, Under normal operating conditions, the well injects 24 hours per day. Injection pressure varies from 700 to 900 psi. Attached is a 90 day TIO plot and schematic for your reference. Per our phone conversation, Hilcorp is requesting continued injection for a period no greater than 28 days to diagnose and re-establish well integrity with minimal disruption to Swanson River operations. Given the remote location and low injection pressure, we believe it is safe to operate this well in its current condition for this limited time. Our current plan is as follows: 1. Verify wellhead seals are holding and retest IA if diagnostics indicate leak was through the wellhead. 2. If wellhead work fails to re-establish integrity, proceed with leak depth determination via an LDL and evaluate tubing condition with a caliper. 3. Evaluate data and determine if a thru-tubing fix is warranted or if a tubing swap is necessary. Thank you and please reach out if you have additional questions. Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 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. SCHEMATIC Swanson River Unit SRU 32-33WD PTD: 180-115 API: 50-133-20337-00-00 Primary Y Axis: Pressure [psi] Secondary Y Axis: Rate [BWPD] Date Tubing [PSI]IA [PSI]Water Injection [BWPD] 8/14/2022 757 220 2434 8/13/2022 782 218 2597 8/12/2022 742 223 2894 8/11/2022 741 310 2166 8/10/2022 766 382 2747.48 8/9/2022 780 320 3310.45 8/8/2022 760 220 3436.8 8/7/2022 760 300 3150.96 8/6/2022 744 247 3374.3 8/5/2022 774 210 3529.15 8/4/2022 776 299 3440.79 8/3/2022 776 296 3263.34 8/2/2022 771 282 3537.21 8/1/2022 771 304 3154.77 7/31/2022 771 326 3430.75 7/30/2022 771 351 3411.66 7/29/2022 777 300 3618.71 7/28/2022 753 107 3872.98 7/27/2022 787 203 4204.3 7/26/2022 785 218 3929.84 7/25/2022 766 225 3938.33 7/24/2022 771 262 4503.02 7/23/2022 798 374.5 4498.87 7/22/2022 747 333 2810.46 7/21/2022 790 261 3353.39 7/20/2022 779 245 4264.23 7/19/2022 790 301 4086.93 Date Range: 05/11/2021 - 08/14/2022 Well: SRU 32-33WD Desc: Disposal Permit to drill: 1801150 Admin Approval: N/A API: 50-133-20337-00-00 7/18/2022 775 255 4079.08 7/17/2022 787 265 4347.82 7/16/2022 788 358 4206.21 7/15/2022 787 358 3811.03 7/14/2022 798 347 3911.93 7/13/2022 787 408 3996.47 7/12/2022 804 352 3710.24 7/11/2022 762 322 3292.57 7/10/2022 764 318 3487.41 7/9/2022 765 365 3499.08 7/8/2022 765 340 3645.42 7/7/2022 766 321 3939.79 7/6/2022 769 296 3852.2 7/5/2022 760 280 3767.74 7/4/2022 760 280 3984.4 7/3/2022 780 140 4620.13 7/2/2022 780 145 5074.2 7/1/2022 780 230 4235.26 6/30/2022 770 200 4017.2 6/29/2022 775 250 4160.79 6/28/2022 706 221 3075.18 6/27/2022 786 272 3403.01 6/26/2022 784 250 945.49 6/25/2022 788 221 3552.15 6/24/2022 700 200 2914.86 6/23/2022 698 200 723.16 6/22/2022 784 202 985.26 6/21/2022 800 177 1478.57 6/20/2022 800 213 4569.58 6/19/2022 800 123 2899.22 6/18/2022 820 131 3897.77 6/17/2022 810 75 3859.98 6/16/2022 775 266 2632.58 6/15/2022 790 220 5291.17 6/14/2022 791 200 1744.03 6/13/2022 709 200 4065.19 6/12/2022 827 197 4102.05 6/11/2022 813 195 2166.14 6/10/2022 818 275 4106.51 6/9/2022 725 165 2672.29 6/8/2022 725 165 2097.41 6/7/2022 730 155 1865.7 6/6/2022 775 200 3346.97 6/5/2022 760 150 1755.48 6/4/2022 800 140 2864.27 6/3/2022 770 100 1859 6/2/2022 780 165 2666 6/1/2022 760 185 3551 5/31/2022 730 223 3768.18 5/30/2022 757 227 3751.37 5/29/2022 785 218 3828.01 5/28/2022 809 198 3456.82 5/27/2022 820 198 3249.31 5/26/2022 785 204 3484.24 5/25/2022 728 110 3637.03 5/24/2022 734 220 3096.3 5/23/2022 732 218 4071.18 5/22/2022 834 206 3145.18 5/21/2022 791 144 3915.98 5/20/2022 769 185 3131.91 5/19/2022 745 231 3779.81 5/18/2022 832 179 3545.88 5/17/2022 790 154 3132.99 5/16/2022 818 113 2024.2 5/15/2022 835 138 2629.73 5/14/2022 836 149 4110.32 5/13/2022 810 94 3993.24 5/12/2022 778 138 4122.52 5/11/2022 760 151 3726.76 5/10/2022 750 140 3865.24 5/9/2022 760 40 3293.75 5/8/2022 730 80 3903.84 5/7/2022 730 122 3519.26 5/6/2022 800 430 5241.48 5/5/2022 730 90 3677.13 5/4/2022 790 335 4322.08 5/3/2022 738 143 2136.7 5/2/2022 741 80 2306.49 5/1/2022 820 165 2899.51 4/30/2022 791 195 3293.25 4/29/2022 733 167 3286.06 4/28/2022 771 199 3608.15 4/27/2022 764 173 4096.69 4/26/2022 769 188 3093 4/25/2022 736 156 3020 4/24/2022 780 186 2808 4/23/2022 780 209 3071 4/22/2022 780 155 2982 4/21/2022 790 128 3738.29 4/20/2022 785 228 3093.62 4/19/2022 785 205 3495.88 4/18/2022 765 214 3015.45 4/17/2022 785 284 2028.34 4/16/2022 790 203 1596.94 4/15/2022 775 238 3674.74 4/14/2022 780 220 3742.55 4/13/2022 785 246 3742.55 4/12/2022 800 190 3826.87 4/11/2022 800 65 3817 4/10/2022 760 105 2769 4/9/2022 785 45 2961 4/8/2022 795 80 3263 4/7/2022 790 100 3948 4/6/2022 775 150 3801 4/5/2022 801 152 4243.98 4/4/2022 732 165 3697.53 4/3/2022 732 154 3695.87 4/2/2022 834 167 3825.09 4/1/2022 832 159 3862.93 3/31/2022 811 159 3567.79 3/30/2022 799 155 3693.5 3/29/2022 790 150 2989.21 3/28/2022 760 160 3638.31 3/27/2022 760 160 4303.97 3/26/2022 780 120 3485.98 3/25/2022 790 100 3233.58 3/24/2022 780 200 4286.87 3/23/2022 780 180 3788.78 3/22/2022 750 180 4080.67 3/21/2022 762 140 3591.64 3/20/2022 755 210 3386.02 3/19/2022 760 210 3317.15 3/18/2022 760 208 3789.43 3/17/2022 770 188 3517.24 3/16/2022 760 160 3615.46 3/15/2022 770 140 3344 3/14/2022 790 130 3325 3/13/2022 785 130 3094 3/12/2022 790 130 2766 3/11/2022 780 80 2462 3/10/2022 750 40 1171 3/9/2022 740 40 515 3/8/2022 761 68 974.94 3/7/2022 723 69 1567.38 3/6/2022 782 69 1247.24 3/5/2022 776 69 918.84 3/4/2022 778 68 1168.47 3/3/2022 723 67 1159.56 3/2/2022 755 50 1284.47 3/1/2022 760 50 1606.1 2/28/2022 750 50 1954.84 2/27/2022 740 50 938.88 2/26/2022 740 50 1459.77 2/25/2022 750 60 1557.75 2/24/2022 740 60 1836.2 2/23/2022 740 60 1741.39 2/22/2022 752 62 1664.53 2/21/2022 727 63 1417.42 2/20/2022 727 63 1065.13 2/19/2022 721 69 1519.83 2/18/2022 721 69 1143.18 2/17/2022 721 69 793.34 2/16/2022 738 69 1680.79 2/15/2022 720 30 1080 2/14/2022 730 30 2943 2/13/2022 720 30 2215 2/12/2022 720 25 1864 2/11/2022 730 30 1765 2/10/2022 720 30 1541 2/9/2022 720 30 1600 2/8/2022 719 60 1329.76 2/7/2022 735 57 1640.33 2/6/2022 717 57 2468.22 2/5/2022 719 59 1359.34 2/4/2022 719 60 1839.49 2/3/2022 720 60 1942.03 2/2/2022 722 60 1168.78 2/1/2022 740 20 1803.84 1/31/2022 740 20 1441.04 1/30/2022 750 20 1867.04 1/29/2022 730 30 1646.14 1/28/2022 740 40 1215.71 1/27/2022 720 40 1638.88 1/26/2022 750 40 1861.77 1/25/2022 732 55 1089.37 1/24/2022 760 40 875.78 1/23/2022 760 40 951.8 1/22/2022 760 40 522.16 1/21/2022 760 40 1047.65 1/20/2022 760 40 1137.34 1/19/2022 760 40 2675.95 1/18/2022 760 40 3243 1/17/2022 760 40 3002 1/16/2022 760 90 2159 1/15/2022 770 90 2953 1/14/2022 750 111 2648 1/13/2022 750 102 3230.59 1/12/2022 760 122 3400.15 1/11/2022 750 123 3360.81 1/10/2022 729 93 3267.47 1/9/2022 780 40 2991.82 1/8/2022 750 50 4391.18 1/7/2022 746 50 2996.93 1/6/2022 720 50 1638.65 1/5/2022 772 50 2417.2 1/4/2022 740 25 4867.58 1/3/2022 760 100 1174.14 1/2/2022 760 100 1147.73 1/1/2022 760 100 1604.14 12/31/2021 760 100 3688.06 12/30/2021 780 90 3027.86 12/29/2021 780 20 1779.1 12/28/2021 760 90 2793.07 12/27/2021 765 90 3391.88 12/26/2021 760 90 3245.94 12/25/2021 770 90 2106.72 12/24/2021 770 90 2250.51 12/23/2021 770 90 2175.92 12/22/2021 770 90 2396.79 12/21/2021 760 90 2667.97 12/20/2021 770 90 3013.76 12/19/2021 780 86 2844.59 12/18/2021 765 75 3086.14 12/17/2021 765 70 2863.95 12/16/2021 765 70 2499.76 12/15/2021 785 70 2323.61 12/14/2021 785 70 2190.09 12/13/2021 785 70 2271.86 12/12/2021 770 61 2150.87 12/11/2021 760 82 2420.14 12/10/2021 785 80 2886.36 12/9/2021 775 90 2691.82 12/8/2021 790 86 2736.01 12/7/2021 785 96 2072.54 12/6/2021 750 50 3233.51 12/5/2021 780 80 4903.5 12/4/2021 790 80 2529.94 12/3/2021 780 80 2579.05 12/2/2021 785 80 2581.89 12/1/2021 775 80 5139.19 11/30/2021 795 80 2912 11/29/2021 745 77 2866.22 11/28/2021 867 77 2565.85 11/27/2021 767 86 2331.21 11/26/2021 751 84 3169.58 11/25/2021 815 88 2693.83 11/24/2021 749 77 2629.74 11/23/2021 844 77 2921.3 11/22/2021 760 60 2549.06 11/21/2021 750 67 2576.24 11/20/2021 760 77 1407.15 11/19/2021 755 76 2524.11 11/18/2021 760 81 2765.02 11/17/2021 760 81 2446.89 11/16/2021 780 113 2571 11/15/2021 780 125 2901.15 11/14/2021 790 125 2720.46 11/13/2021 790 144 3317.65 11/12/2021 780 162 3824.14 11/11/2021 785 140 3343.78 11/10/2021 780 130 3023.94 11/9/2021 780 155 3063.21 11/8/2021 750 193 3528.84 11/7/2021 795 173 3192.05 11/6/2021 785 153 2684.49 11/5/2021 780 116 2762.41 11/4/2021 760 68 2223.78 11/3/2021 780 116 1262.26 11/2/2021 780 80 1572.9 11/1/2021 795 152 2560.29 10/31/2021 800 153 2842.37 10/30/2021 756 144 2457.37 10/29/2021 833 154 3007.44 10/28/2021 823 134 3153.7 10/27/2021 732 164 3083.74 10/26/2021 802 209 3667.11 10/25/2021 802 169 3401.16 10/24/2021 751 200 3074.99 10/23/2021 809 172 2949.33 10/22/2021 735 143 2548.55 10/21/2021 755 124 1978.18 10/20/2021 824 138 2060.08 10/19/2021 731 136 1642.05 10/18/2021 739 127 2016.16 10/17/2021 792 142 1783.55 10/16/2021 727 83 1837.28 10/15/2021 824 130 1974.78 10/14/2021 785 150 1836.38 10/13/2021 747 140 3006.22 10/12/2021 729 145 2344.79 10/11/2021 797 139 2205.17 10/10/2021 727 119 2071.65 10/9/2021 729 129 2621.38 10/8/2021 775 119 921.76 10/7/2021 747 138 2263.38 10/6/2021 825 181 2775.49 10/5/2021 737 149 2911.36 10/4/2021 726 118 3584.9 10/3/2021 726 168 3502.67 10/2/2021 785 125 2849.55 10/1/2021 724 122 1844.41 9/30/2021 826 125 2481.31 9/29/2021 826 104 2592.73 9/28/2021 820 150 2600.56 9/27/2021 728 128 2638.02 9/26/2021 757 124 2742.54 9/25/2021 726 129 1743.63 9/24/2021 816 139 2241.39 9/23/2021 725 142 1148.66 9/22/2021 762 125 2655.38 9/21/2021 784 126 2626.71 9/20/2021 765 135 2875.2 9/19/2021 740 136 2919.56 9/18/2021 805 144 2855.37 9/17/2021 780 134 2026.43 9/16/2021 795 105 2441.8 9/15/2021 795 105 1862.18 9/14/2021 795 105 2235.24 9/13/2021 812 143 3203.68 9/12/2021 825 131 1391.68 9/11/2021 825 131 2656.82 9/10/2021 825 126 2793.76 9/9/2021 830 130 2588.37 9/8/2021 830 121 2789.69 9/7/2021 794 124 2678.15 9/6/2021 765 140 3419.6 9/5/2021 760 138 3228.16 9/4/2021 760 138 3251.34 9/3/2021 760 138 3375.87 9/2/2021 770 138 3132.58 9/1/2021 795 138 3091.14 8/31/2021 795 138 3798.09 8/30/2021 795 138 5225.03 8/29/2021 828 130 5180 8/28/2021 810 89 4279.3 8/27/2021 780 69 4395 8/26/2021 795 100 4963.59 8/25/2021 785 119 4313.51 8/24/2021 780 105 3954 8/23/2021 760 170 3468.19 8/22/2021 765 170 3607.08 8/21/2021 760 170 3671.35 8/20/2021 750 170 3479.79 8/19/2021 770 170 3698.25 8/18/2021 780 170 3710.42 8/17/2021 765 172 3622.51 8/16/2021 765 172 3352.23 8/15/2021 743 134 3751.39 8/14/2021 800 146 3430.8 8/13/2021 812 130 3798.41 8/12/2021 811 131 3665.9 8/11/2021 814 159 4320.14 8/10/2021 813 157 3836.91 8/9/2021 780 160 4136.3 8/8/2021 774 185 3415.05 8/7/2021 810 194 3849.93 8/6/2021 811 195 4139.47 8/5/2021 798 127 5739.02 8/4/2021 798 136 6729.06 8/3/2021 810 145 5155.89 8/2/2021 812 117 5523.65 8/1/2021 780 80 6623.91 7/31/2021 795 100 5535.13 7/30/2021 800 75 4306.81 7/29/2021 800 75 3764.62 7/28/2021 800 80 3935.41 7/27/2021 790 100 4385 7/26/2021 795 115 4382.39 7/25/2021 822 114 4392.1 7/24/2021 780 113 4766.81 7/23/2021 815 107 4479.75 7/22/2021 822 107 4465.02 7/21/2021 817 122 3208.2 7/20/2021 815 100 3524.52 7/19/2021 815 106 3133.46 7/18/2021 815 106 5286.99 7/17/2021 793 121 5283.31 7/16/2021 815 105 4734.28 7/15/2021 802 113 4352.42 7/14/2021 770 114 4265.91 7/13/2021 768 95 4638.71 7/12/2021 790 80 3645.97 7/11/2021 800 109 4582 7/10/2021 816 108 3956 7/9/2021 810 115 3722 7/8/2021 800 122 4151 7/7/2021 790 122 4006 7/6/2021 795 122 3871 7/5/2021 790 122 3585.55 7/4/2021 780 60 4358.52 7/3/2021 780 60 3337.32 7/2/2021 760 60 4084.22 7/1/2021 760 60 3937.2 6/30/2021 750 80 5754.8 6/29/2021 760 80 5055.96 6/28/2021 800 100 3572.57 6/27/2021 788 92 3792.98 6/26/2021 780 128 3601.01 6/25/2021 775 150 2655.47 6/24/2021 800 111 3655.3 6/23/2021 785 109 3412.54 6/22/2021 790 112 3866.96 6/21/2021 780 40 3447.24 6/20/2021 760 100 3344.33 6/19/2021 760 100 2937.21 6/18/2021 760 100 3307.67 6/17/2021 760 100 2775.18 6/16/2021 760 100 2607.47 6/15/2021 750 100 3914.01 6/14/2021 800 120 4069.54 6/13/2021 800 127 3597.04 6/12/2021 805 130 3802.4 6/11/2021 810 110 3620.62 6/10/2021 810 112 3288.24 6/9/2021 806 125 3318.89 6/8/2021 790 127 3167.76 6/7/2021 810 100 3970.67 6/6/2021 790 100 3541.26 6/5/2021 785 100 3686.31 6/4/2021 785 100 4294.36 6/3/2021 790 100 3347.12 6/2/2021 790 100 3771.25 6/1/2021 790 80 3595.49 5/31/2021 780 80 2881.49 5/30/2021 800 100 3330.67 5/29/2021 800 100 3131.84 5/28/2021 800 100 3503.82 5/27/2021 800 100 3690.83 5/26/2021 800 200 4077.53 5/25/2021 770 40 3484.13 5/24/2021 750 84 3036.36 5/23/2021 760 78 2827.06 5/22/2021 780 82 3262 5/21/2021 780 78 3281.23 5/20/2021 790 93 3261 5/19/2021 785 96 3336.18 5/18/2021 782 79 2865.26 5/17/2021 800 60 3892.63 5/16/2021 795 107 3588.75 5/15/2021 780 100 3008.26 5/14/2021 800 121 3543.97 5/13/2021 808 138 3847.74 5/12/2021 805 122 3982.22 5/11/2021 813 120 3906.31 • • / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL Area Injection Order 13A.001 Mr. Dave Whitacre Union Oil Company of California P.O. Box 196247 \1 Anchorage, AK 99519 -6247 RE: Area Injection Order 13A Request for Administrative Approval Rule 2: Authorized Injection Strata for Disposal MU Swanson River Field NAKt etc `F - e3c - ctck1 Dear Mr. Whitacre: In accordance with Rule 9 of Area Injection Order ( "AIO ") 13A.000, the Alaska Oil and Gas Conservation Commission (Commission) hereby GRANTS Union Oil Company of California's (Unocal) request for administrative approval revising the authorized injection strata for injection disposal of Class II oil field wastes to the strata that are common to, and correlative with, strata between the measured depths (MD) of 1,745 feet and 3,460 feet in Swanson River Unit (SRU) well No. 32 -33 (SRU 32 -33). FINDINGS 1. Within the Swanson River Field, all aquifers deeper than 1,700 feet below ground surface are exempted per 40 CFR 147.102 (b)(1)(i). 2. Strata receiving Class II injected waste materials are sandstones assigned to the "B- series" of the Pliocene -aged Sterling formation. These stacked, fluvial sandstone strata are typically 10- to 50 -feet thick, rich in volcanic rock fragments, fine -to coarse - grained, fairly to moderately sorted, and display little detrital or authigenic matrix. Well -log correlations indicate local continuity of the sandstone strata is good. 3. Upper confinement for injected waste is provided by a 30- to 50 -foot thick interval of interbedded layers of claystone and siltstone with minor sandstone that lies between 1,695 feet and 1,745 feet MD in SRU 32 -33 (see Figure 1, below). This confining interval is present on well logs and appears to be continuous for a radius of '/2 mile around the active SRU 31 -33WD and SRU 32 -33WD disposal wells. 4. Lower confinement for injected waste is provided by a 115 -foot thick interval that lies between about 3,460 feet and 3,575 feet MD in SRU 32 -33. This interval contains an aggregate thickness of about 55 feet of interbedded claystone, siltstone and coal that will provide an effective bottom seal for the injected fluids. This confining interval appears to be continuous for a radius of 1 /2 mile around SRU 31 -33WD and SRU 32 -33WD. • • 0 AID 13A.001 February 17, 2011 Page 2 of 4 •N0 ke_0c col 150 AIV 50 0,....1 TVD55> J3 1 2000 85 Nl0.sl a t OHY44 200030 - . � — T V O OTCPIOf1 <MD 1600 1500 -1900 800 Confining 1700 °° =-- ..., Interval 1800 900 s°° - 1900 1000 2000 200° -1 800 2100 2100 -'eoo -2000 1 'y 2200 2200 Perforated Intervals in 2300 23 00 2100 SRU 31 -33WD and 2400 2900 __°° SRU 32-33W ` 7 9000 -t— 2500 2500 Y Revised 2400 Disposal 2600 250° Interval =- 2700 2)00 -2500 _r�� 28°0 2800 SPOO -2700 -' 2900 2800 -2800 —. ._ter 3000 300° S. -2900 3100 3100 3200 3200 3000 -3,00 3300 3300 Z) -3200 3400 3400 — 3200 — .--�� -3300 y_ =�S_ Confining 3500 5°0 Interval { 1 _c_.-- __ -3400 .,500 _= .) - -- 5 ..- 3600 �. . Figure 1. SRU 32 -33 Well Log AIO 13A.001 February 17, 2011 P f4 Page To date, approximately 62.3 million barrels of Class II wastes have been injected into wells SRU 21 -33WD, SRU 31 -33WD, SRU 32 -33WD, and SRU 41 -33WD. Wells SRU 21 -33WD and SRU 41 -33WD have been properly plugged and abandoned, but during disposal injection operations these two wells received 2.7 and 3.7 million barrels of waste, respectively. Wells SRU 31 -33WD and SRU 32 -33WD are active injection wells that have received 32.7 and 23.2 million barrels of waste, respectively. 6. The cumulative injected Class II waste volume is estimated to extend radially about 800 feet from SRU 31 -33WD and about 650 feet from SRU 32- 33WD. Waste volumes injected into SRU 31 -33WD and SRU 32 -33WD are likely in communication with each other. 7. Rule 2 of AIOs No. 13 and 13A defines the authorized injection strata as "...those strata which correlate with strata found in well SRU 32 -33 between the measured depths of 2,100 feet and 3,460 feet." The injection strata were defined in accordance with descriptions provided by ARCO Alaska, Inc., operator for the SRU at the time of the original application. 8. Upper confining intervals for the Sterling injection sands are not precisely defined in the original application for AIO 13. The depth of 1,700 feet is referenced in that application and in AIO 13 as being the upper limit for confinement. 9. On May 13, 2010, Unocal requested the Commission revise AIO 13 to conform to the well logs. 10. The Alaska Department of Natural Resources' MapGuide Water Rights GIS System (http: / /magellan.dnr. state .ak.us /dnrwater /default.cfin) shows 10 shallow water wells recorded in the SRU area; the deepest is 262 feet below ground level. All wells are registered to Unocal and dedicated to supporting oil and gas activities; no other registered water wells are within 6 miles of the SRU. 11. Active disposal injection wells SRU 31 -33WD and SRU 32 -33WD recently passed standard mechanical integrity tests. CONCLUSIONS 1. The proposed, revised injection strata that are equivalent to strata between 1,745 and 3,460 feet MD in well SRU 32 -33 are sufficiently thick and laterally continuous and have sufficient reservoir properties to accept additional injected Class II waste fluids. This estimate is based on the temperature -log- determined waste depths of 1,970 feet MD in 1989 and 1,800 feet MD in 2010, assuming uniform filling of the 170 -foot thick interval at 8.1 feet per year, an average porosity of 21.5 %, and piston -like displacement of native formation fluids. 2 ARCO Alaska, Inc., 1987, Swanson River Unit, Area Injection Order Application for AIO 13. Attachment G -2 is hand - annotated with the injection interval between 2,100 feet and 2,422 feet MD. Attachment G -2 is described on page 12 as "an electric log showing the water injection zones in a typical water injection well." However, page 11 states: "Injection within the Sterling is limited to water wet sandstones within the Sterling B series (as recognized by Chevron Stratigraphy) from 2,100' to 3,500'." AIO 13A expanded the definition of the underlying Hemlock Pool, but it did not alter the definition for the Sterling injection sands or address the associated Sterling confining intervals. 3 ARCO Alaska, Inc., 1987, cited above. Subsection 2, states in part: "Even if the immediate confining zone failed, there are several confining zones between the injection interval and 1700'." Finding 4 of AIOs 13 and 13A states: "Adequate confining strata are present below 1700 feet in the Swanson River Field to prevent upward movement of waste fluid from injection zones into non - exempt fresh water sources." AIO 13A.001 February 17, 2011 Page 4 of 4 2. The upper and lower confining intervals designated in the SRU 32 -33 well, confirmed on the well logs submitted in support of the original application, are sufficiently thick and laterally continuous to contain injected waste fluids. 3. There is no evidence that injected waste fluids have migrated or will migrate upward beyond the upper confining layer into non - exempt strata. Underground sources of drinking water will not be affected. 4. The active disposal injection wells have demonstrated mechanical integrity. 5. Revising the authorized injection strata will not promote waste or jeopardize correlative rights, is consistent with the well logs submitted in support of the original application, is based on sound engineering and geoscience principles, and will not result in an increase risk of fluid movement into fresh water. NOW, THEREFORE, IT IS ORDERED THAT the rule governing Class II underground injection operations in the Swanson River Field as described in Rule 2 of Area Injection Order No. 13A be revised as follows: Rule 2 Authorized Injection Strata for Disposal (Revised AIO 13A.001) Within the affected area non - hazardous oil field fluids may be injected for the purpose of disposal into strata defined as those strata that are common to, and correlate with, strata fs ' well SRU 32 -33 between the measured depths of 1,745 feet and 3,460 feet. DONE at Anchorage, Alaska and dated February 17, 2011. <- ` a z , : Zia Daniel T. Seamount, Jr. . No : .n Cath P. Foerster Chair omm s' . er Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Cornrnission an application for reconsideration of the matter detennined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Cornrnission mails, OR 30 days if the Cornrnission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Conunission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Cormmission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Cornrnission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 09, 2010 8:25 AM To: 'Greenstein, Larry P' Subject: RE: SRU 32-33WD (180-115) Thanks Larry. I am doing a file review in conjunction with your AA request and noted that there was a "hole" in the information. My request was to make the file complete or as complete as we can. Thanks again. Tom From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Monday, August 09, 2010 8:23 AM To: Maunder, Thomas E (DOA) Subject: RE: SRU 32-33WD (180-115) ~~.~'~~ ~~ ~`i1"> ~ ~ r~~)1~'°~ Found them in our well files, Tom. Hope they help. Are there some questions about the 32-33WD well?? Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 09, 2010 7:22 AM To: Greenstein, Larry P Subject: SRU 32-33WD (180-115) Larry, was reviewing the file on this well and there appears to be some paperwork, both ours and yours, missing. The well was apparently worked over in August 2002, however I do not find a sundry (403) or the report of operations (404) in the file. There are copies of emails you and I exchanged regarding the sundry or a sundry from October 2001. Can you look at your file and see if what you might have?? Thanks much. Tom Maunder, PE AOGCC 8/9/2010 • ltnocal Carporatlon • P.O. Box 196247 Andmrage, AK 99501 'relephd7e (907i 263-76SQ uNOCa~~ Larry W. Buster AdviS~g i~i~ng Engineer September 3, 2002 Alaska Oil arrd Gas Conservation Commission 333 West 7~` Avenue Anchorage, Alaska 99501 Attn: Commissior>ar Cammy Taylor Re: Sundry Fopow-up Repor# (Form 404) Swanson River Feld Welt SRU 32-33 WD Workover Gommissioner Taylor. Enclosed for your review is the Well workover summary and Surx3ry Notice Follow-up porm 404 for the SRU 32-33 WD well. This water-inaction wail had developed a hole in the tubing several years aga, but was Itept in service wiith the stipulation we ran a #tuid movement log every trnro years. During this workover, we replat:ed the damaged tubing and successfully tested the 7" x 3~-112° tuning annulus to 1500 psi prior to rietuming the well to service, We canlwili conduct a M1T of the casing annulus with a State Inspector present at your convenience. ff there are any questions, please contact myself at 263-7804. Si Larry W. Buster Advising Drilling Engineer Unocal Alaska LBIs Encl. STATE OF ALASKA ALASKA alL AND GAS C~NSERVATIt]N t;C3MMISSION REPORT aF SUNDRY WELL aPERATIC3N5 1.Oparations perfamted: apwatiort shutdawrr _ Stimukta: _ P~girtg: PerforeRe: _ PuH tult~: x Aber rasing: Repay well: allter: 2. Name of Operator 5. Type of Wetl: 9. Datum elevation roF or KB) Urtokt t7ii Co of ~ tlNaCAL) D 177 RT abave fNSL feet 3. Address F~lorstory: w ~ 7. tlrtti or Property narr~ phi _ P.O.6coc 198247 Arch e, AK '!x'4519-6247 S~ioe: x Swann Rh~r Uni! 4. Location of wet at surface Cort~ctor 4121 9. Wall nun~er 1924' FNLS 2D10 FEL Sec. 33, TBN, R9W, 5B & M SRU 32-3'.i WD At top of ptroductive utlenvai 9. Pem~t ra~mberhappmval rraettber Same - Vertic~ t-lok 190.115 At effective dolt 10. APi number Same - l/erticel Hok a0" 133-243:37 At total depth 11. Fkk~Pod Same - Vert[cal Hole Swam Rr+~/Slerfng 12. Pre€~rrt weR oricxt mnttmary Total ckpth: measured 2520' feet Plugs (measured} true vertical 752x' tent EffectWe depth: meastmed 2460' feat Junk {rrx~usd) trrm vertical 2460' feet Cashtg Length Sfae Cemented Msaaur4cE daptit ShvcitXal Tn~ vafiaaa depth Conductor Surtece 80' 10-314" Na 90" 80' ~tennediate Production 2499' 7" 704 sxs 2499' 2498' Liner Perfaation depth: mr:sasured sae attached true vertical see attached 7ubirg {size, grate, and measured depot) 3-117' 9.3~ L~0 HYD 533 t/ 4 -199T Pacta~s and SSSV (typo and measures } Baker sAB 1937' 13. Stimtdatiort ar cement squeeze stxnrrtary none Intervals treated {measured) none Treatment descriptiat ir~kxlirtg volumes used anti flrref pressun: notes 14. Renreser>tffiiue DaNy A-~Etii#4P~ or irtjeetlon Data t]~BBL Gas-Mcf Water-Bbl Cas9ng Pres~re Tub~g Pressure Priorto well operation 330D BWPD 950 ~ 5ubaequent to operation 2700 BUUPD 0 tip i5. Aitachrrterrls: i 6, staff of txe8 r;kssiflcadiort errs: Copk-s of Low and Surveys run: _ Darly R ort of Weli O ns: X O~ Gera S Service; x i 7. i hereby certify that the faregang is true and correr# b the best of my knawkdge: Signed' Tdfe- e4 ~- ~a : w ~ is h I.: ~ ~ Date: ~ ~ Q~p Form 10-404 Rev 4(3115198 "-' '~+ '"" SUBfuf 1T HVV DUPLICATE RBDIIAS AUG 101010 ~ i SRU 32 33 WD Workover Daily Summant Unocal Alaska Drilling Dally Summary Report SRU 32-33 WD 8!19102 to 8128102 8119/02 Accept Nabors Rig 26 from Turn Key Rig Mane. Install BPV and NIQ tn:e. Install double stud adaptor an wellhead. 8120!02 N!U BOPE and test to 3,000 psi high/ 250 psi law. Pull 40 k Ibs over string weight and release 7" FHL Packer. Circulate bottoms up with locatktn water. Pull and lay down 3-112` tubing. 8121/02 Continue to pull 3-112' tubing to where #ie packer is at 757'. Packer hanging up and unable to go up or down. R1U jar and bumper sub at rig floor, bu# unable to knack dawn hole. 8122102 R1U and run a 2-518' chemical cutter and cut tubing at 711'. Circulate bottoms up and pull and ~y dawn c~,t tubing. M/U fishing BHA of overshot and grapple and engage tubing stub. Work to free stuck packer. 8123102 Continue to work fish with na luck. Unable to release overshot. RIU and run back off string shot and back aff below overshot at 720'. POOH with overshot and backed off tubing. RIU 6-1118` bum shoe and 5314° wash pipe. RIH 8124!02 RIH with bum shoe and bum aver packer. Push packer fish to bottom at 2,080'. Circulate bottoms up. - 8125102 POOH with burn shoe. RIH with overshot and grapple and engage packer. Unable to engage fish. PC3OH with overshot. 8126102 RIH with "rolling dog" overshot and engage fish. POOH with packer fish. MIU and RIH with 7" RTTS packer. Set RTTS at 1,953' and test casing to 1,500 psi for 30 minutes (bst 30 psi over 30 mina. POOH with RTTS. 8127102 M1U 6-118" smooth OD mill assembly. Clean out casing fill down to 2,280'. Circulate well clean with lease water and POOH, 8128102 M1U Baker SAB Packer on 3-'112" tubing and RIH. Set packer at 1,93T with RHC drop bar. Pressure up tubing to 3,000 psi far 15 min. and nr-test annulus #0 1,5t~ psi for 30 minutes. N/D BOPE and N!U and test tree to 3,000 psi. Release Rig. -1- Swans,. __ River Field ~~~C~~~ SRU 32-33WD As completed $lZ8102 CASING AND TUBING DETAIL SIZE WT GRADE CflNN TOF. BOTTOM i0-3I4" 0' 90' 7" 23# K-55 {1' 2499' Tubing; 3-112" 9.3 L-80 FIYD 533 0' 1997' NO. JEWE Death LRY AND WELLBORE DETAIL Item 1 0' Rector 7" tbg hgr 3-1l2" BTC 2 l 93b' Baker K Andfor 3 1937' Baker SAB Packer, 3.50" ID 4 I 942' - Baker Mill-out lsxte~ion S 1984' 3-] 2" X nipple, 2.81" ED 6 1997' WLRG, 3.00" 1D .Depth of clean.out with b-1l8"mill assembly = 2,280'. FORATION DATA TD = 24991VID PBTD = 2450' TOP BTM Z ONE SPF 2100' 222$' 4 9185 2234' 2278' 4 9185 2316' 2424' 4 9185 5RU 32-33 WD FinaE Schen~atic.doc 09/03/02 DRAWN 13Y: LWB STATE OF ALASKA ALASKA QIL AND GAS C~NSERVATiQN CUMMiSSIt7N APPLICATION Ft~R SUNDRY APPROVALS 1, Type of Request: Abandon: Suspend: Operation strutdown: _ Re-enter suspended x~l: RepaK well: Plugging: _ T~ e~denston: Sgmtdate: Alter casing: _ Cha approved rogram: Pull11 tubi x Variance: Perforate: Other: 2. Name of Operator 5. Type of wed 8. Datum elevation (f]F or K8) Unipn Oil COmparry of Calif~nia (UNOCAL) Development 172 fit 3. Address ^ Expkxatory: _ 7. Unit or Property narr~ Stratigric: _ P.O. Box 196247 Anchorage, AK 99619.6247 Service: X Swanaon River Una d. Location of well at surface Conductorlr21 8, Well nurr~er 1824' FNL &2010' FEL SEC. 33, TSN, R9{N, SB d. M 5RU 32-33 WD At top of productive interval 9. Permit number . Sams - Ver#iral Hole `~a ""' / ~ At effective doh 10. APi nranber Same -Vertical Nola 60- 133 20337 At total depth 11. F~kf/Pool Same - Vertir~f Hole Swanson River! Star 12. Preserrt wsY aorrd'dian summary Tatai depth: rraeasured 2520 feet Pk~ {measun~ 2450' true vertical 2520 feet Effective depth: measunjd 2450 feet Junk (measured) true vertical 2450 lest Casing Lsngitr Size Cemented Measured depth True vertical depth Struc2urai Conductor SO' 10.314" No 80' 80' f S ur ace Intermediate Producer 2499' T 700 SX 24913' 2499' Liner Perforation depth: rrre~ured 2100'-2228', 2234'-7278', 2318 -2424' bus vertir~l Same - Vertical Hole Tubing (size, grade, and measured depth) 3-112", td-80, 9.Zl1 BTC AB Nod to 2,05T Packers and SSSV (type and measured depth) Bakes FHi_ Retrievable Packer 1997' 13. Atta~emerrts Desrxiption summary of proposal X Deta9ed operatbns progr~n: SOP skrkoh: X Schsmatic~. 14. Esfrrrr~ed ate for corrrmerrcis~ operation 15. Status of wr3ll CEaesifiCatian as: August 19, 2002 iti. if proposal well vly approved: Oil:.~ Gas: ~,,, Suspended: Name ~ approver Gate approved Service: Walser Disposal 17. i hereby certify t 'ng is to the Crest of my knowledge. ~ i ~ Q~ giy title: En inew.r [3ate: e. jr' ~$-1J-~r FOR COMNpSSI~! USE ONLY Conditions of approval: Not~y Commission so represerdative may witness '~'t C' f ~ ~,~,:. ; ~'_: • ~~ ~* - :Y, ~.' ~ ~ 'j• - ~ Approval No ~ ~~ ~ ° Plug integrity BOP Tsst Location clearance '~' ' `~'~ ~ Niedtaniced integrity Test Sut~sequem form required :iU- >t' -. ~ tit ;.. ~'~~-~ ~1.,'+r~.`:. _. .l ~ ti-t.~' ~ 'a. 1~r ~° '~;, ~ - . , ~ /`I d 3' Approved b order of the Commissiwter ~ 11 ~ ~ Commissioner Date ` E,1 4 ; ~' ~ Y.~ 1~ SUBMIT 1N TRIPLICATE Form 10403 Rev 1~t15J88 ~ {'~•: ~ ~ ~ I , _, t RBGiIAS AUG 1~ 0 ZO~q ~-.,: -~ -- • -• • • Proposed Workover Procedure Swanson River Fjeld Well SRU 32-33 WD Augast 2402 1. M1RU Nabors Pulling Unit. 2. install BPV rand N/D Tree. 3. N!U and test BOPE to 3,Q00 psi. 4. M/tT tubing hanger and pu11 to unseat production packer. 5. Pull and L1D tubing and packer. b. Make clean out nui as/if required. ?. Run production packer an 3-112" Hydri1533, 9.3#, L-$0 Tubing. $. Land tubing hanger and set production packer at +/- 1,95d'. 9. Test tubing to 3,OU0 psi. Test tubing x 7" casing annulus to 1,Sp0 psi. l U. N/D Bi~PE and N1U Tree. 11. Test Tree to 3,00 psi. Swanson River Field SRU 32-33WD As completed 312419$ CASING AND TUBING D ETAIL SIZE WT GRADE CONK T OP BOTTOM IL1-314" 0' 90' 7" 23# K-SS 0' 2499' Tubiag: 3-112" 9.2 I~$0 SC BTC AB mod 0' 2057' abing et 400' n tubing at 1,058' JEV NO. __~ t~h 1 0' 2 1967' 3 1997' 4 2046' 5 2057' i tubing ad I975' VELRY AND WELL$ORE DETAIL Item Vetco T' tbg hgr wlxover from 3-I/2" BUE to 3- 1!2" BTC 3-112" X nipple, 2.81'" ID Balser FIiL 1~rievable pkr, 3.00" ID 3-112" X nipple, 2.81 "' ID Shear out sub, 2.992" TD PERFORATION DATA TD = 2499 MD PBTD ~ 2450' T P BTM ZONE SPF 2100' 2228' 4 9185 2234' 2278' 4 9/85 2316' 2424' 4 9185 SRU 32-33WD 3-24-95 Schemadc.doc 08/12102 DRAWN BY: TAB .. , , .. ^7 1 ..f-~' Swanson River Field S.RU 32-33WD Proposed CASING AND TUBING DETAIL SIZE GRADE CONK T+UP BpTTOM 10-314" 0' 40' 7" 23# I~-55 0' 24~' Tabing: 3-112" 9.3 L-80 l3YD 533 0' 2030' JEWELRY AND WELLBQRE DETAIL Np. Depth item 1 0' Recfiar 7" tUg hgt 3-112" BTC 2 1410' 3-112" X nipple, 2.81"' ID 3 1950' Baker 5AB Packer, 4.00" ID 4 1440' 3-112" X nipple, 2.81"' lD 5 2030' WLRG, 2.942" ID PERFORATIUN_DATA TD =?A99 MD PBTD = 2450' TOP BTM ZONE SPF 2100' 2228' 4 9185 2234' 2278' 4 4185 2316' 2424' 4 9185 SRU 32-33WD Proposed Sclzemaric.doc 08/12/02 DRAWN BY: TAB • • (Chevron ' Well: I SRU 31 -33wd I Field: Swanson River 107-27-2010 ' \11-c.\` -%` t. --NP 3 ) 3 w Pressure (psis) 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1000 ■ I • mum - C� I II - Mon a 1100 — - Pressure- Temperature Profile :: 1. Going in hole to 2069 Overlay 11111111111111NI MINI OM - =' i 2. Well Shut-In 1200 — _ l Kr , . ma's : 1 _ _ i e ,g, IN 1300` - - - -- : a ESIMMI:l _ - - I lCSnCm .; = 1400 -- i '•=1 M1111.....1 I - - i II Ii��Q:r� � _ i m► T s ■ I_a m e: SC 1500 1 � �. - ! —Y I 1 1600 _.l . 1700 4 111111111111110111111111011111111 , I I, __IE - Ili-c\ MIN 111111111111111111111111IMIll NNININ1111.1i0111 IIIIIIIIIIIIIIIIIC !NM= al ar�p {� 1800 — = e, ■e, -11:= ME C • 'f Q 1900 NE � �i� il e� = S IIII 111111111111111111 II 71 ""Mill: • zakamsi - � \, —' -mail . t„ (1 , - , ems► _ .��: � AM tee,. 2000 ti I . _ _ i. - • �■� �c . =__. omill1� i 114% 111 111Mir...7,11111111 I 2100 i I 1 ■ 1 1 _. 50 55 60 65 70 75 80 85 90 95 100 Temperature (Deg. F) I - Perfs x PKR —10 3/4" r —2 7/8" 51/2" 1st Pass Temp — 7 - 25 - 10 Temp —30 min Pass Temp 1 hr Pass Temp 2 hr Pass Temp — 4 - 15 - 10 Temp i Report date: 8/2/2010 • Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 19, 2010 12:26 PM To: 'Greenstein, Larry P' Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham); Davies, Stephen F (DOA) Subject: RE: AIO 13 A request for Administrative Approval Larry, et al, I need to request some additional information regarding your request. q 9 9Y q 1. Can you provide a structure map? The map should likely be centered on the SRU 31 -33WD well with a 1 mile radius. Any wells within that radius should be listed. 2. You provided a crossection. Can you provide the relative distances between the wells at the top of the exempted aquifer (1700'), 2100' and 2400'? 3. Have there been any calculations /studies regarding the volumetrics and fill for this disposal area? 4. Are you aware of any temperature logs from wells other than 31 -33WD? 5. Of the wells that may be identified in (1) above, what wells could temperature logs be run in? Thanks in advance, Tom Maunder, PE From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, May 17, 2010 10:49 AM To: Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham) Subject: RE: A1O 13 A request for Administrative Approval You got it, Tom. This is'the static log, after a 12 hr shut -in, of warm water going into warm ground. Very little delta between injection temp and rock temp. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, May 17, 2010 10:42 AM To: Greenstein, Larry P Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham) Subject: RE: A1O 13 A request for Administrative Approval Larry, I thought I remembered a temperature log. I'd appreciate if you could send that information. Please attach to the message trail. Tom From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, May 17, 2010 10:40 AM To: Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham) Subject: RE: A1O 13 A request for Administrative Approval Tom, 5/20/2010 Page 2 of 2 • • We have done a number of temp logs recently, but all were offshore waterflood wells. The only recent disposal well temp log at Swanson, on SRU 31 -33WD, I brought to you for our discussion and will be glad to send to you electronically if you would like. The MITs have been intact on the two continuous disposal wells at Swanson for the last 8 years, so no other logs have been run recently. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, May 17, 2010 10:03 AM To: Greenstein, Larry P Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham) Subject: RE: AIO 13 A request for Administrative Approval Larry, I was more thinking of anything done recently. I thought I understood that there might have been some more recent surveys done in these wells as Swanson, but I may have confused that with such logs in other wells. Tom From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Monday, May 17, 2010 10:01 AM To: Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA); Winslow, Paul M; Eastham, Kevin (KEastham) Subject: RE: AIO 13 A request for Administrative Approval Tom, Are you talking about any and all historic temp logs or only ones that have been run recently ?? SRU 32 -33WD did get a WO in 2002 and we had run some Water Flo logs to prove up on MIT prior to the WO. There were some temp logs run in the 80's that I showed you, but 1 don't know whether you got copies at the time. Don't know if we have any extra copies, but we'll look. Larry From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Monday, May 17, 2010 9:51 AM To: Winslow, Paul M; Greenstein, Larry P Cc: Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: AIO 13 A request for Administrative Approval Paul and Larry, Have there been any temperature logs run in the disposal wells affected by this AA at Swanson? If so, it would be appreciated if you could provide them. Call or message with any questions. Tom Maunder, PE AOGCC 5/20/2010 1 Chevron Paul Winslow Chevron North America Petroleum Engineer Advisor Exploration and Production MidContinent/Alaska P.O. Box 196247 Anchorage, 99519-6247 Tel el 907 7 7 263 7629 Fax 907 263 7828 RECEIVED PWinslow @chevron.com MAY 13 2010 May 13, 2010 RAM &Gas Cons. Wormsso Anctiolve Commissioner Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501 -3509 AREA INJECTION ORDER NO. 13A REQUEST FOR ADMINISTRATIVE APPROVAL REGARDING RULE 2: AUTHORIZED INJECTION STRATA FOR DISPOSAL SWANSON RIVER FIELD Dear Chair Seamount: Union Oil Company of California ( "Union ") requests administrative approval under Rule 9: Administrative Relief of Area Injection Order No. 13A to amend Rule 2: Authorized Injection Strata for Disposal in Swanson River Field. Rule 2 currently authorizes the disposal of non - hazardous oil field fluids into strata which correlates between the measured depths of 2,100 feet and 3,460 feet in the Swanson River Unit well SRU 32 -33. Union believes that the 3,460 foot depth provides adequate basal confinement of injected fluids but, based on well log interpretation, does not believe the 2,100 foot depth provides confinement from upward migration of injected fluids. The current top of authorized injection strata (2,100 feet MD) is in the middle of a permeable Upper Sterling sandstone, and in Union's interpretation, does not offer vertical confinement of injected fluids in the current water disposal wells. Therefore, Union proposes the top of the authorized injection strata be amended to 1,745 feet MD/TVD ( -1,558 feet TVDSS) as correlated in the Swanson River Unit well SRU 32 -33. To support this request, Union submits the following information and documentation as attachments: 1. Well Log of SRU 32 -33 (1,600 feet — 2,200 feet MD) (attached), 2. SRU 32A -33 Well Schematic (Equivalent to SRU 32 -33 at Rule 2 disposal depths), and 3. Upper Sterling cross section showing the %2 mile radius regional extent of the upward confining interval. The proposed amended top depth of 1,745 feet MD/TVD is based on three criteria. First, the proposed injection strata depth remains distinctly below the top of the exempted aquifers which, per 40 CFR 147.102(b)(1)(i) for Class II injection activities, is at a depth of 1,700 feet. Second, the proposed depth corresponds to the top of a permeable Upper Sterling sandstone and the base of what appears to be an adequate confining strata, 45 feet thick. Third, Union interprets this confining strata to be present in all wellbores within a'/ mile radius of our current water disposal wells, as demonstrated in Attachment 3. Rule 2 currently reads: "Within the affected area non - hazardous oil field fluids may be injected for the purpose of disposal into strata defined as those strata which correlate with strata found in the Swanson River Unit well SRU 32 -33 between the measured depths of 2,100 feet and 3,460 feet." Under Rule 9: MidContinent /Alaska Chevron North America Exploration and Production www.chevron.com • • Commissioner Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission May 13, 2010 Page 2 Administrative Relief, Union suggests the following language be used to amend Rule 2: "...in the Swanson River Unit well SRU 32 -33 between the measured depths of 1,745 feet and 3,460 feet." Union believes that the proposed amendment to Rule 2 would adequately prevent the upward movement of waste fluid from the injection zones into non - exempt fresh water sources. If you have any questions or would like to review any additional information, please contact myself (907/263 -7629) or Kevin Eastham (907/263 -7959) at your earliest convenience. Thank you for your consideration in this matter. Sincerely, G Paul M. Winslow Petroleum Engineer Advisor Attachments MidContinent /Alaska Chevron North America Exploration and Production www.chevron.com • evro SRU 32A-33 Well SRU 32A -33 4../... Last Completed 4/15/91 Actual Welibore Schematic Updated 7/05/08 RKB: 201.6' KB / GL: 172' AMSL KB- THF:29.6' KB Casing and Tubing Detail J 1 . 2 L Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 22 "@ • 22" Structural - Surface 45' - Cemented as 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), DV Collar I 1 54.5 #, J -55 1,025' 2,555' 64 sx 116# (top job) 1 29 #, N -80 Surface 364' BTC / 6.184" 26 #, N -80 364' 1,282' BTC / 6.276" 4 23 #, N -80 1,282' 4,687' BTC / 6.366" 13.3/8" =1 3 26 #, N -80 4,687' 6,225' BTC / 6.276" 650sxs 116# (stage 1), @z,sss' 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" 4 5" Liner 18 #, N -80 8,379' 10,566' FL4S / 4.276" 70 bbl 15.6 ppg Ca lc 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 1 s 2 -7/8" Prod 6.5 #, N -80 Surface 8,910' 8RD -Mod / 2.441" Cplg OD = 3.668" 1 1 2 -3/8" Prod 4.7 #, N -80 8,910' 9,499' 8RD -Mod /1.995" Cplg OD = 3.063" 6 Production String Jewelry Detail # Depth (RKB) Length ID OD Item 1 29.6' 1.9' 2.992" 4.500" Tubing Hanger, 3 -1/2" L• 7 2 31.5' ? 2.441" 4.500" X -Over 3 -1/2" x 2 -7/8" DV Collar GLM, Camco Model MMGP 2 -7/8" x 1 -1/2" @ ° 3 4,021' ? 2.441" 5.500" (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 6,712' 15' 0.875" 2.441" Tubing patch, set 7/5/08 cBL TOC G- stop /packoff /spacer /packoff/AD -2 stop 8,355' GLM, Camco Model MMGP 2 -7/8" x 1 -1/2" roL \`' 8 6 7,281' ? 2.441" 5.500' (Drift = 2.347 ") [Gaslift valve installed] 8,379' • ,'. 2.441" 5.500" GLM, Camco Model MMGP 2 -7/8" x 1 -1/2" 7" window at .. 9 7 8,359' (Drift = 2.347 ") [Gaslift valve installed] 8,701' 8 8,379' ? 4.250" 6.276" Liner top x 10 ° .. 9 8,818' ? 2.313" 3.668" Sliding Sleeve, 2.313" Min ID $ 1 0 8,878' ? 2.313" 3.668" X- Profile, 2.313" Min ID 11 11 8,910' ? 1.960" 3.668" X -Over 2 -7/8" 8RD -Mod B x 2 -3/8" 8RD -Mod P 12 • 12 8,962' ? 1.995" 3.870" GLM, TMPDX Teledyne 2 -3/8" x 1" (1.901" Drift) 13 9,466' ? 1.995" 3.870" GLM, TMPDX Teledyne 2 -3/8" x 1" (1.901" Drift) 13 14 9,499' ? ? ? Baker E -22 Anchor Seal Assembly TOL at 14 15 9,499' 4.33' ? ? Liner Top Packer, Baker SC-1L Packer 9 �, I 15 16 10,890' - - 1.75" Teledyne Bridge Plug 17 11,319' - - - Landing Collar 18 11,386' 10.0' - - FISH: 10' BHC /AC logging tool d N. 5" @ 10,566' Perforation Data G ZONE TOP BTM Spf Comments I G 10,698' 10,724' 4,4,4 Perf (11/12/03), (3/27/01), (2/25/01) J H -1 10,800' 10,820' 4,4 Perf (12/05/95), (5/10/91) H -1 H -2 10,835' 10,854' 4,4 Perf (12/05/95), (4/28/91) Ha • : H -3,H -4 10,900' 10,912' 1 Perf (4/23/91) Tag Fill ;,.: 10,863' SLM 16 7/02/08 H-3/H-4 _, 17 2 -7/8" @11,386' 1 18 TD = 11,396' PBTD = 11,319' Directional Data: max hole angle = 34.0° at 11,000' MD SRU 32A -33 Actual WBD 7- 05- 08.doc Updated by STP 3 -30 -10 i urJV 1 vl L • • Fleckenstein, Robert J (DOA) From: Greenstein, Larry P [Greensteinlp@chevrori.com] Sent: Monday, June 09, 2008 1:31 PM To: Fleckenstein, Robert J (DOA) Subject: RE: PKRTVD Project ~~ g° ~ "S Attachments: An-19 Dec84 Schem Updated.doc; GP 24-13RD Final 10-4-97.DOC; D114DrawingSchematic1985-08-25.PDF; SRU 32-33WD schematic 8-28-02.doc Here is what I based our depths on Bab. Please let me know if these will suffice to update your records. Thanks Larry From: Greenstein, Larry P Sent: Thursday, June 05, 2008 10:20 AM To: 'Fleckenstein, Robert J (DOA)' ~~~~~~ SUN ~ ~. 20~~ Subject: RE: PKRTVD Project Will do Bob I'm at 263-7661, but 1've been gone the last two days, so l'm just catching up now. I'll get the back up data to you as soon as I can. The 1680360 GRANITE PT ST 18742 25 is getting the MIT done the same way a bunch of other Anna wells are, which is by using temperature surveys to confirm every other year where the wafer is being injected. Sorry for the delay in getting back with you. Larry From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Wednesday, June 04, 2008 10:15 AM To: Greenstein, Larry P Cc: Regg, James B (DOA) Subject: PKRTVD Project Larry, I have reconciled all the PKRTVD differences except for the following wells. Please send me your paperwork on these wells that verify your data. 1680060 GRANITE PT ST 18742 19 =__> An-19 1750660 S MGS UNIT 14 =__> Di-14 1801150 SWANSON RIV UNIT 32-33WD =__> SRU 32-33WD 1801160 GRANITE PT ST 24-13RD =__> GPP 24-13RD If 1680360 GRANITE PT ST 18742 25 does not have a packer in the well what are you testing against? Thanks, 6/9/2008 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 boh. fleckcnste rl(cLalaska.~ov~ ~'~ 6/9/2008 • • Fleckenstein, Robert J (DOA) From: Regg, James B (DOA) Sent: Thursday, May 29, 2008 1:46 PM To: Fleckenstein, Robert J (DOA) Subject: FW: UNOCAL PKRMC & PKRTVD Spreadsheet Attachments: UNOCAL PKRMD & PKRTVD.xIs • This attachment may reflect the changes since you spoke with him yesterday - I have not checked. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Greenstein, Larry P [mailto:Greensteinlp@chevron.com] Sent: Thursday, May 29, 2008 9:59 AM To: Regg, James 6 (DOA) Subject: FW: UNOCAL PKRMC & PKRTVD Spreadsheet Hi Jim, Since your name is on the letter I got from Commissioner Foerster, I wanted you to get the packer depth reconciliation spreadsheet. f like using the color coded version just because it focuses me on the more problematic wells. Cleared four more wells since I sent this to Bab yesterday. The TVD ca(c on G-29RD was recalculated and now matches yours and the An-19, D-14 RD & D-29RD wells have been confirmed by schematic to be those few feet off from your depths. There are a lot of small differences in depths that won't make any difference in the required test pressure for an MET (coded yellow). And a few that had some clear reasons why our depths didn't match {coded purple}. The two blue colored wells are the only ones where our depths just don`t seem to match up with yours without anything to explain why except maybe just some sort of typo. Let me know if you would like to discuss any of these or anything else further. You don't need a formal respanse letter back on this, do you?? i assumed the data attached to this e-mail would suffice. Thanks Larry From: Greenstein, Larry P Sent: Wednesday, May 28, 2008 10:21 AM To: 'Fleckenstein, Robert ] (DOA)' Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Here you go Bob. Lots of updates seem to be coming out of this. Didn't worry about differences of a few pounds on the required test pressure calc as this doesn`t change the pressure test for the MIT. 6/3/2008 Hope this helps. Larry 1 UYV \. L V1 J • From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Tuesday, May 06, 2008 3:21 PM To: Greenstein, Larry P Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Larry, Attached is a revised sheet for you to use. I have added 3 columns for your use. Thanks, BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and. Gas Conservation Conunission Office: 907-793-1242 Fax:907-276-7542 TPtease ~~flfe e~eti~- r.<~~a.i~ <~t~f?>.~s: bob lleckensteinrz,al~zska.~ov From: Greenstein; Larry P [mailto:Greensteinlp@chevron.com] Sent: Monday, May 05, 2008 3:28 PM To: Fleckenstein, Robert J (DOA) Cc: Regg, James B (DOA); McMains, Stephen E (DOA) Subject: RE: UNOCAL PKRMC & PKRTVD Spreadsheet Thanks Bob (and Steve), An electronic copy will make it easier for me to make updates and corrections. Larry From: Fleckenstein, Robert J (DOA) [mailto:bob.fleckenstein@alaska.gov] Sent: Monday, May 05, 2008 3:26 PM To: Greenstein, Larry P Cc: Regg, James B (DOA) Subject: UNOCAL PKRMC & PKRTVD Spreadsheet Attached is the data you requested. BobF Robert J. Fleckenstein Statistical Technician II 6/3/2008 rage s or ~ Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 bol~.t~Ieclterlstc~i~'-:~ a?~iska.C7ov 6/3/2008 ~ ~ ~ 8'c~ ire Swanso~iver Field V N Q CA ~® SRU 32-33WD As completed 8/28/Q2 CASING AND TUBING DETAIL SIZE VVT GRADE CONK TOP BOTTOM 10-3/4" 0' 90' 7" 23# K-55 0' 2499' Tubing: 3-1/2" 9.3 L-80 HYD 533 0' 1997' NO. JEWELRY AND WELLBORE DETAIL Depth Item 1 0' Rector 7" tbg hgr 3-1/2" BTC 2 1936' Baker K Anchor 3 1937' Baker SAB Packer, 3.50" 1D 4 1942' Baker Mill-out Extension 5 1984' 3-1/2" X nipple, 2.81" ID 6 1997' WLRG, 3.00" ID Depth. of clean-out with 6-1/8" mill assembly = 2,280'. PERFORATION DATA TD = 2499 MD PBTD = 2450' TOP BTM ZONE SPF 2100' 2228' 4 9/85 2234' 2278' 4 9/85 2316' 2424' 4 9/85 SRU 32-33WD schematic 8-28-02.doc 06/09/08 DRAWN BY: LWB MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -D f ¡ ¡_oJ ¡ Uw; ,\¿ø " , ( f{ DATE: Friday, September 01, 2006 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA 32-33WD SWANSON RIV UNIT 32-33WD / \ \5 \Côô FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv J'þ?- Comm NON-CONFIDENTIAL Well Name: SWANSON RIV UNIT 32-33WD API Well Number 50-133-20337-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG06090 I 074349 Permit Number: 180-115-0 Inspection Date: 8/28/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 32-33WD Type Inj. i W TVD 1937 IA ! 30 1560 1500 I 1550 1520 1520 P.T. 1801150 TypeTest I SPT Test psi 1500 OA Interval REQVAR P/F P Tubing 800 800 800 800 800 800 Notes No OA on this well, After IS minutes IA had dropped to minimum test pressure due to leaking bleeder valve, Repressured fA to 1550, / " ~ÇMU~ED SE? 0 8 lDDu Friday, September 0 1,2006 Page I of I 32-33 WID MIT . . «32-33 MIT 06.xls» «32-33 w-d chart.pdt» «WSR 32-33 MIT 06.doc» \glì~ \ ,S- Mr. Regg, We would also like to schedule a witness of the MIT for disposal well 32-33 WID for next week. Please let me know if someomeone is available. Thanks, SCANNED SEP 052006 .> Greg Merle Content-Description: 32-33 MIT 06.xls MIT Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: 32-33 w-d chart.pdf w-d chart.pd Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: WSR 32-33 MIT 06.doc 32-33 MIT Content-Type: application/msword Content-Encoding: base64 1 of 1 8/24/20063:41 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: UNOCAL Swanson River Field/Swanson River Unit! 32-33 WID Pad 08/22/06 Walgenbach Packer Depth Pretest Initial 15 Min. 30 Min. Well I 32-33 WID I Type Inj. I H2O/Diesel TVD I 1,937' Tubing 850 850 850 850 Interval I 4 P.T.D.I 180-115 I Typetest I p Test psi I 1500 Casing 0 1550 1550 1550 P/FI P Notes: OA NA NA NA NA Weill I Type Inj. I TVD I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA weill I Type Inj.1 TVD I Tubing I ntervall P.T.D.I I Type test I Test psil Casing P/F Notes: OA weill I Type Inj.1 TVD Tubing Interval P.T.D.I I Type test I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I p.T.D.1 I Type test I Test psi I Casing p/FI Notes: OA TYPE INJ Codes D = Drilling Waist G=Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 32-33 MIT 06-2.xls UrecAL ALASKA RESOURiiS WELL SERVICE REPORT Date: R/??In~ Well Number: ~?~~ wIn Wireline Company: Location: SRF Work Being Done: PreMIT AFE # I PO #: Present Operations: 5/1 Wireline Crew: UNOCAL Supervisor: Walaenbach Total Wireline Miles: Wireline Unit Number: Max Depth (KB): Zero Wireline at: Well KB: Minimum Tubina ID Max Tool Strina OD Time Operation Details T.P. P.C. 1:40 P 850 0 Start pumping diesel down the production casing 1:45 850 1550 2:00 850 1550 2:15 850 1550 2:30 850 1550 2:45 850 1550 End of test Work String Detail: I Description of any tools or debris left in the hole: Brief Summary of I Total Work Completed: Ticket #: I I Day#: I Dailv Cost: I 1650.00 I Cumulative Cost: I Well Downtime Hr.n/A H2S PPM I ~ ".",- ""'~'.--"'-'-'-' .,~------_._--~-..~--,---~ 9 ---. '0 . ""...,-"-''''---= ,- .- / -, ,- 8 .' 1 AUG 3 0 20Dz ~HART NO. HO HP-4000-~ __ OH~RT PUT ON 0 T~KEN OFF REHA!~'Ks ~0 EtD~d 6 L;99-gLL-LOB ~T,:~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL ~ SWANSON RIVER FIELD -UNIT 051994 FEBRUARY 2002 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.c_ 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER ., FIELD.~ DAYS 7. 8. 9. 10. 1'1. 12. 13. 14. a. & POOL u~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) SRU 21-33WD 133-10162-00 5 772036 8 0 0 0 0 0 0 0 0 0 SRU 31-33WD 133-20336-00 5 772036 9 28 1,000 924 0 0 3,289 0 92,091 0 sro 3~.-33wo 133-20337-00 s ??~-03s 9 ~.8 ?60 71~- 900 ?8? 3,20? 0 89,802 0 I hereby certif)ft~hat the foregoing is true and correct to the best of my knowledge 15. Signed Title ACCT. SUPERVISOR Date 12-MAR-2002 TOTAL 181,893 0 Form 10-406 Rev 07/27/99 ~SfJANNEIi3 ~IAR 1 0 2_003 Submit in Duplicate MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill ~--2~ :~5 DATE: November 8, 2002 Commissioner SUBJECT: Mechanical Integrity Test THRU: Tom Maunder Unocal Petroleum Engineer t~-I,...,,-©-~. SWanson River SRU 32,33 WD FROM: Lou Gdmaldi Swanson River Unit Petroleum Inspector Swanson River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 32-33 WD I Type Inj. I WD I T.V.D. I 1937 I TubingI~oI~oI~oI~0 I lntervall I P.T.D;I 180-115 ITyPetestI P ITestpsil 1500 I Casingl 1500I lS00 I lS00'I lS00I P/FI P Notes: Initial test, well 'was I~ft pressured up from pretest performed earlier we"l 32'33WD Imype'nj'l WD I~.v.~.l 1937 Imub,ngI 780 I 780 } 780 I I'nte"va'l P'T'D'I '180-115 ITyl~etestl P ImestpsiI 1500 I Casingl 1600I 1100I 1100I I P/F I P Notes: Lowered Annulus pressure 500 psi and observed for 15 minutes (+) "OK" Type INJ. Fluid Codes F -- FRESH WATER INJ. ® -- GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4-- Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) I arrived Swanson River and after meeting with Bruce I-Iirschberger (Lead Operator) we proceeded to the well SRU 32- 33 WD. This well had been worked over this year and had not had a witnessed MIT. The well had been tested earlier today and still had 1500 psi on the annulus. The gage was bled offto check zero and the annulus was presured up an additional 100 psi to 1600 psi. I observed the well in this condition for thirty minutes with no loss of pressure. I requested the annulus pressure be bled offS00 psi to 1100 psi. I observed the well in this condition for fifteen minutes with no change. The well showed good casing integrity and I approved it for continued injection. M.I.T.'s performed: One Attachments: None Number of Failures: None Total Time during tests: 2 Hours cc: SCANNED JAN g A 2003 MIT report form 5/12/00 L.G. 021108-MIT SRU 32-33WD LG 1 .xls 11/12/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 0'51994 NOVEMBER 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5._ 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER [u: FIELD DAYS 7. 8. ' ' · 9. 10. 11. 12. 13. 14. n & POOL ~ IN MAX AVERAGE MAX AVERAGE. LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (I~ICF) (BBL) (MCF) sro 21-33WD 133-10162-00 4 ??2036 8 0 0 0 0 0 0 0 0 SRO 31-33WD 133-20336-00 5 772036 9 30 9?5 , 943 0 0 3',516 0 105,481 SRO 32-33WD 133-20337-00 5 772036 9 30 750 719 980 818 3,622 0 108,653 · ,RECEIVED DEC 1 Na~ a(~l& Gas C0ns. Cx I hereby certify-that th® foregoing i,s true and correct to the best of my knowledge t 5. Signed Title ACCT. SUPERVISOR Date 12-DEC-2001 TOTAL 214,134 Form 10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 OCTOBER 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.~ 6. TUBING PRESSURE CASIN~ PRES$1)RE DAILY AVERAGE INJECTION TQTAL MONTHLY INJE(~TION WELL APl NUMBER u~ FIELD~ DAYS 7. 8. 9. 10. 11. 12. 13. 14. a. & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO $0- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (aBE) (MCF) SRO 21-33WD 133-10162-00 4 772036 8 0 0 0 0 0 0 0 0 0 SRU 31-33WD 133-20336-00 5 772036 9 31 1,000 958 90 14 3,667 0 113,663 0 SRU 32-33WD 133-20337-00 5 ??2036 9 31 760 731 850 805 3,805 0 117,960 0 I hereby certify that the foregoing is true and correct to the best of my knowledge 15. Signed ~f~ ?~ (i[~ ,~.~'~'~ . Title ACCT. SUPERVISOR Date 19-NOV-2001 TOTAL 231,623 0 I Form 10-406 Rev 07127199 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 SEPTEMBER 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5._ 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER tu FIELD DAYS i7. 8. " 9. 10. tl. t2.. 13. 14. n & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (aBE) (MCF) (BBL) (MCF) SRO7 31-33WD 133-20336-00 5 772036 9 30 1,0'00 968 85 33 3,722 0 111,672 0 SRU 32-33WD 133-20337-00 5 772036 9 30 780 742 880 819 3,749 0 112,457 0 , I hereby certify/t~at the foregoing is true and correct to the best of my knowledge 15. Signed _.~/_./~~'~ (~ Z~P~-/ ' · · Title ACCOUNTING SUPERVISOR Date 11-0CT-2001 TOTAL 224,129 0 Form 10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 T,T~OC3LT, SW3.1~TSON RI¥]gR FIELD -UI~TIT 051994 AUGUST 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.00: 6. TUBING PRESSURE CASING PRE$~URE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER [u FIELD E: DAYS 7. 8. 9. t0. 11. 12. 13, t4. a. & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO $0- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) Igc. o' 3'1-33w0 133-20336-00 5 '7?2036 9 3:!. z, ooo 986 180 88 3,882 0 3.20,330 0 Sl~O 32-33WD :[33-20337-00 5 772036 9 3:[ 920 745 840 83.6 4,:[06 0 3.27,2'/7 0 RF__CEI IED ..... SEP 2 .t ZOI]l tlaska Oil & Gas Con~ Commission Anchorag I hereby certi at the foregoi g is true and correct to the best of my knowledge 15. Signed ~ Title ACCOONTING SUPERVISOR Date 17-SEP-2001 TOTAL 247,607 · 0 Form10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 JULY 2001 , Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5._c 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER tu FIELD.~ DAYS 7. 8. 9. 10. 11. 12. 13. 14. =. & POOL ~ IN MAX' AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) sro 31-33WD 133-20336-00 5 772036 9 31 1,100 .991 230 153 4,015 0 124,462 SRO 32-33WD 133-20337-00 5 772036 9 31 760 '731 900 833 4,337 0 134,452 RECEI VED AUG i 6 ~001 Ala;ka 0il & Gas Con,, Commission Anchorag I hereby ce~ify~~e forego iR, g is true and correct to the best of my knowledge 15. Signed ALEJA DE~ITO Tit~e ACCOIIRTIN~ SUPERVISOR Date 13 -AU~-2001 TOTAL 258,914 Form10-406 Rev 07127199 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 JUNE 2001 Name of Operator ' Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.~ 6. TUBING PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHL~' INJECTION WELL APl NUMBER m FIELD~ DAYS i7. 8. 9. 10. 11. 12. 13. 14. =. &POOL ~ IN MAX AVERAGE MAX AVERAGE .LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (aBE) (MCF) (aBE) (MCF) SRU 31-33WD 133-20336-00 5 772036 9 30 1,100 982 200 77 4:,010 0 120,310 0 SRU 32-33WD 133-2033'7-00 5 7'72036 9 30 980 764: 980 805 4:,364: 0 130,926 0 REC z iVED JUL ~ ~ ~1 ~.~o~ ~Je ,' hereby ce~if~at the forc~;~i~ is true and correct to the best of my knowledge 15. Signed Title ACCT. SUPERVISOR Date 10-JUL-2001 TOTAL 251,236 0 Form 10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL swANsoN 'RIVER FIELD -UNIT 051994 MAY 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5._o 6.' TUBING.PRESSURE CASING PRESSURE DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL AP! NUMBER uJ FIELD~ DAYS 7. 8. 9. 10. tt. t2. 13. 14. n & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ opER PSIG PSIG PSIG PSIG (aBE) (MCF) (BBL) (MCF) SRO 31-33WD 133-20336-00 5 772036 9 31 980 950 950 34 3,843. 0 119,118 0 SRU 32-33WD 133-20337-00 5 772036 9 31 900 756 840 810 4,172 ~ 0 129,333 0 \ Ant ~orage Commission , I hereby cert~forego~q~gis t.ru.e an_d correct to the best of my knowledge 15. · Signed ALE~A J ~VIT~ Title ACCT. SUPERVISOR Date 11-~TON-200Z TOTAL 248,¢Sl 0 , Form 10-406 Rev 07127199 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 " APRIL 2001 · Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5. 6. TUBING PRESSURE CASING PRESSURE DALLY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER ,,, FIELD DAYS 7. 8. 9. 10. 11. 12. 13. 14. =. & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG~ · ~ (BBL) (MCF) (BBL) (MCF) SRU 31-33WD 133-20336-00 5 772036 9 30 950 932 0 0 3,950 0 118,514 0 SRU 32-33WD 133-20337-00 5 772036 9 30 820 760 890 806 3,876 0 116,287 0 · · Signed Title ACCT. SUPERVISOR Date 09-MAY-2001 TOTAL 234,801 0 Form 10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 UNOCAL SWANSON RIVER FIELD -UNIT 051994 MARCH 2001 Name of Operator Field and Pool Month and Year of Injection 1. 2. 3. 4. 5.~ 6. TUBING PRESSURE CASING PRESSURE DALLY AVERAGE INJECTION TOTAL MONTHLY INJECTION WELL APl NUMBER uJ FIELD =. & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (BBL) (MCF) SRG 3[-33WD 133-20336-00 5 7'72036 9 31 950 915 0 0 3,77~ 0 11'7,000 0 SRU 32-33WD 133-20337-00 5 772036 9 31 780 707 800 781 3,911 0 121,229 0 . I hereby certify th_at the foregoing i~ true and correct to the be~t of my knowledge 15. Signed Title ACCT. SUPERVISOR Date 10-APR-2001 TOTAL 238,229 0 ,.,. Form 10-406 Rev 07~27~99 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 T3~NOCAJL SWAZqSO~ :R/:V~I~ ~'~ZELD -O'lqIT 051994 JA_NT3~ ' 2001 '"Name of Operator , Field and Pool Month and Year of Injection , · 1. 2. ' .... 3. 4. 5.¢~'6. ,TUBING"I~ESSURi= ..... .,CASING PRE.S,,SUR~= ........ DA~i[~ AVERAGE INJECTION" TQTAL MONTHLY INJE'.~:ION FIELD Om DAYS 7. 8. 9. 1'~l'.' t~'. ...... 12. 13. 14. ' ..... WELL APINUMBER nm & POOL ~ IN MAX AVERAGE MAX AVERAGE LIQUID GAS LIQUID, GAS NO 50- ~ CODE ~ OPER PSIG PSIG PSIG PSIG (BBL) (MCF) (aBE) (MCF) ,~RU 31-33WD 133-20336-00 5 772036 9 31 950 913 0 0 3,999 0 123,957 SRU 32-'33WD 133-20337-00 5 772036 9 31 860 826 850 801 3,704 0 114,828 RECEIVE B 1 6 Alaska Oil & Gas Cons. Cornmissl~ n ~nchorage '"1 hereby certify~t the fore~oi~g.i!';crue and"~ 'orrec, ,o the best of my knowledge ", 15. ' .... . ,, Title AccT. ~O~.RVI~O~ .... Date 12-~'~.~-2001, .... TOTAL 238,7ss , , , , , , , , , , · Form10-406 Rev 07127/99 Submit in Duplicate 32-33 WD 5"w~n~n I~Ner D~posa! wel! Subject: RE: 32-33 WD Swanson River Disposal Well Date: Thu, 4 Oct 2001 16:00:33 -0700 From: "Greenstein, Larry P" <greensteinlp@unocal.com> To: "q'om Maunder'" <tom_maunder@admin.state.ak. us> Sounds great Tom..Thanks. ----Original Message .... From: Tom Maunder [mailto:tom maunder~admin.state.ak, usl Sent: Thursday, October 04, 2001 2:26 PM To: Greenstein, Larry P Subject: Re: 32-33 WD Swanson River Disposal Well Larry, The approval is on my desk and I just need to have a chance to add the final touches and get it out. Tom "Greenstein, Larry P" wrote: > Tom, > Here is the variance report for 32-33 WD for September. All looks well. > Any word get on finding the approved and signed off sundry for this well?? > > Larry > Name: 32_.33WD. xl$ > 32_$$WD.xi$ Type: EXCEl. File (application/msoxceO > Encoding: base64 I of I 10/4101 4:42 PM ;.lZ-.~ WU ;~wanson i~lver iJisposal Well Subject: 32-33 WD Swanson River Disposal Well Date: Wed, 26 Sep 2001 14:21:08-0700 From: "Greenstein, Larry P" <greensteinlp@unocal.com> To: '"Tom Maunder @ AOGCC'" <tom_maunder@admin.state.ak.us> Tom, Sorry for the delay. Here is the Variance report for 32-33 WD for August. Per the attached note which Chris forwarded to me, did you locate the signed sundry for this well?? Also wanted to inform you that a tubing pull workover for this well has been added to the 2002 wellwork budget with a regulatory compliance justification. Let's see how the money holds out for getting this work done. Larry -mOriginal Message ..... From: Ruff, Christopher A Sent: Monday, August 06, 2001 5:14 PM To: Greenstein, Larry P Subject: 32-33 WD Swanson River Disposal Well ..... Original Message .... From: Tom Maunder [maiito:tom maunder~'~,admin.state.ak, us] Sent: Monday, August 06, 2001 5:01 PM To: Chris Ruff Subject: Swanson River Disposal Well Chris, Thanks for your call. I am checking on where the WFL report and sundry are for the Subject well. In the course of this work, Bob Crandall and I did meet with Larry and examined the WFL. Our conclusion was that the log indicated 2 tubing leaks. One leak was substantially larger than the other as evidenced by the detection response time. It was our conclusion that the log indicated that the produced water was confined within the wellbore and that the goal of demonstrating wellbOre integrity was accomplished. ! indicated to Larry, at that time, that disposal operations could continue and that I would forward the sundry and attached WFL to the Commissioners recommending approval. I do apologize that the signed sundry has not been returned. I will locate the document package and get the copy off to you. Ir~ the interim, I confirm that your disposal operations may continue. At no time since the receipt of the WFL was Unocal ever advised to the contrary. I also want to acknowledge Unocal's consideration of working over the well to restore complete integrity. We both are aware of the importance of the continued operation of this well to the production at Swanson River. Our reasoning in requesting that a workover be considered is that the well does conduct fluid through drinking water aquifers. If 1 of 2 10/4/01 4:42 PM 32-33 WD Swanson River Disposal the casing were to develop a leak, there is a risk of potential aquifer contamination which would be a very serious matter. We believe that it is prudent for Unocal to evaluate opportunities to workover the well and apprise the Commission of that analysis. It is possible that a maintenance shutdown might afford an opportunity to accomplish some work without requiring a field shutdown. It might also be possible to deploy a tubing patch to repair the larger leak. Please give me a call and we can discuss. Tom Maunder, PE Petroleum Engineer AOGCC ~32. 33WD.xis 32_33WO.xls ] Name:Type: EXCEL File (application/msexcel)] Encoding: base64 2 of 2 1014101 4:42 PM Unocal Alaska Resouru~ 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661 Fax (907) 263-7874 Larry P. Greenstein Production Technician UNOCALe May 4, 2001 Tom Maunder, State of Alaska AOGCC P.O. Box 196900 Anchorage, Alaska 99519-6900 RECEIVED MAY 1 8 Z001 Naska Oil & Gas Cons. Commission Dear Tom, SUBJECT: Request Approval to ContinUe Injection in Swanson River Unit 32-33WD Enclosed is a copy of the Water Flow Log and final Schlumberger report on the MIT logging done on SRU 32-33WD in January, 2001. Unocal is requesting a variance to continue water disposal in this well. Similar to the WFL done in 1998, no leakage around the packer was detected and no water was found channeling up from the perforated zones towards any potential USDW. Please call me at 263-7661 if there are any questions. Sincerely Larry P. Greenstein Concurrence: Tom Maunder Schlumberger WFL Advisor WFL Interpretation Company Field Well Date Logged Date Processed Reference Number APl Number Log Analyst : UNOCAL : Swanson River : SRU 32-33WD : 22-JAN-2001 : 25-APR-2001 : 21195 : 50-133-20337-00 : Douglas Hupp Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 (907) 273-1700 RECEIVED MAY Alaska Oil & ~ ~:)ns. Commiss~un interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting ~trom any interpretation made by any of our officers, agents or employees, These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current~ ~price schedule, UNOCAL Job Number 21 195 · 1, Introduction Well SRU 32-33WD Field Swanson River A TDT Water Flow Log (WFL)survey was run on UNOCAL's well SRU 32-33 WD on 22-JAN-2001 to check the mechanical integrity of the tubulars under injecting conditions. The TDT tool was run in the up flow configuration (near, far, and gamma ray detectors above the minitron neutron generator)with the casing- tubing annulus both flowing and shut-in. The annular flow rate was varied from 360 BPD to 1800 BPD for the initial stations and shut-in for the final stations. The well was on injection at a rate of 3300 BWPD during this operation. 2. Main Results With the annulus flowing, an upward annular water velocity of 24.9 FPM was measured at the 400 ft station using the gamma ray detector. This was the only definitive fluid velocity measured during this survey. Figure 1 displays the WFL station chart from this depth. This station was recorded with the annulus flowing at 1800 BPD. This fluid flow is believed to be inside the tubing - 7" casing annulus. Water Flow Log - (~iR Detector Measured 6R ^ _ ro Flow Background Background Time (secs) Figure 1 WFL Station at 400 it Well SRU 32-33WD UNOCAL Field Swanson River Job Number 21195 A questionable fluid velocity was measured at 1975 ft with the annulus shut-in on the far detector. This measurement is questionable because the detection peak is very small (See Figure 2)and was not identified with either the near or gamma ray detectors. If this measurement reflects water flow, it is estimated to be an upward velocity of 7.2 fpm. Possible water flow at 1975 ft would be an isolated event as none of the WFL stations between this depth and 400 ft indicated flow. Water Flow Log - Far Detector Time (secs) Figure 2 WFL Station at 1975 ft The station located at 2020 ft did not identify water flow indicating that the packer at 1997 ft to 2003 ft is not leaking. This lack of flow also indicates there is no channeling of fluid in the cemented 7 in - open hole annulus. All WFL stations between 1925 ft and 600 ft indicate no upward water flow indicating no channeling of fluid in the cemented 7 in - open hole annulus or flow in the 3.5 in - 7 in annulus. The WFL results are presented in Section 3 and Section 4 contains a listing of the calculated flow rates based on measured WFL velocities. Also attached are a well schematic, Electric Line Daily Operations Report, and Electric Line Procedure. UNOCAL Job Number 21195 Well SRU 32-33WD Field Swanson River 3. WFllog Plot MD "I : 3600 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 SFU :32~3:::'.ND 'li~¡'eIiSketc¡-' DATA .ASCII Load 0 + () - +2000 Up 1"10'11'.' Tbg-]" Annulu:!i #2 Annulu::1; Open Hole # Tubing #1 #1 ¡f§ DATA .ASCII Load , -. ~~ () ~~2000 l r L r F UNOCAL Job Number 21195 4. WFL Tabular Results Well SRU 32-33WD Field Swanson River Velocity Calculations .... Velocity (FPM] Up Hole Flow Rate (BPD) Station Velocity for 7"-OH Annulus Flow Depth Near Far GR Calculations In tubing Tbg-7" Annulus Comment (FPM) Annulus Rate (BPD) ,, , iTubing - 7" Annulus Flowing , , 700 NFD NFD NFD NFD NFD NFD NFD 360 600 NFD NFD NFD NFD NFD NFD NFD 360/675 400 NFD Partial Peak 24.9 24.9 212.397 985.791 810.495 1800 1750 NFD NFD NFD NFD NFD NFD NFD 1800 1950 NFD NFD NFD NFD NFD NFD NFD 1800 2020 NFD NFD NFD NFD NFD NFD NFD 1800 800 NFD NFD NFD NFD NFD NFD NFD 1800 700 NFD NFD NFD NFD NFD NFD NFD 1800 600 NFD NFD NFD NFD NFD NFD NFD 1800 Tubin~l - 7" Annulus Shut-in 1975 NFD 7.2? NFD NFD NFD NFD NFD 0 Questionable velocity seen on the far detector 1475 NFD NFD NFD NFD NFD NFD NFD 0 1625 NFD NFD NFD NFD NFD NFD NFD 0 1750 NFD NFD NFD NFD NFD NFD NFD 0 1875 NFD NFD NFD NFD NFD NFD NFD 0 1925 NFD NFD NFD NFD NFD NFD NFD 0 NFD = No flow detected Partial Peak = Tail section of velocity peak appears at start of record Comp. leted: 5/29/81. Lost Workover: 3]24/95 Swanson River Field APl 'No.: 50-133- 205.37-00 k. Angle @ Perrs: 0 Degs. Hanger: VEl'CO GI~Y 1ILO - 1~' 7.0~' O0 2,9~2'* tO I-I~ER Vetco ~'oy l"lgr. 18.8- I9.3'CR~R3 I/?'BE. x .t I/F'IITC. 24,,ff).0 - 2499.0' CEMENT PI.U(; 0.0 - 2499.0' T'0~ 2,T.()OJ/I~ !(-55 SURF 2499.0 - 2499.0' KB ELL'V: 18' PE~: 'rD: 2520' 2006.5- 18.8 - 1967.,1 - 1996.8 - 19197.t - 2045.8 - 2055.4 - 2056.4 - 2100.0 - 3)01.9' CR~R .~ t/? IORO. x .,1 I/2' BTC. 205~.4' ,1.500"01) 9..20~/fl N-80 1968.7' ..t.957" eO 2.81" ID I'I~PLE OU~ "X"' ', 1997.1' 2047,2' 21:)56.4' 20~7.0' 222&0' C~ ,T I/2' 10~. x 3 1/2'" 8're; . 5368" O0 &OOP ID REIRV. P,A~I(ER 3.9;~7' OD 2.81' ID NIPPLE 01~ cRossov~ :~ V2" mc. x 3 V2" EUF_ 4.250" OD 2.992" le SHF..ARSUB Bo~ ~r....-Oul W/Boll SeQ!" PEF~ ,~, ~28', ~/'~9/8~, 9/8,~ '22:3,4.0 - 2278.0' PDiF5 ,Pd. IPF, 44', 8/19/81, 9/85 2316.0 - 2424.0' PERIS 4111~', 106", 8/19/81, 9/85 ~. I wote,- DisPOsol Well y :?_..-'. ,. ,F Well: SRU 32-33 **-' '' Date: 1123/01 I ii i ii iii i i i ii i E-line Company: Schlumberoj.e_r Perforating Gun L..0st Time ~E-line Co. Engr: Joe Dalebout ........ Type: E-line (Hrs.) 0:00 UNOCAL Supv: ._R.a.l.ph Holman Size: Other (Hrs.) ~IMork Being Done: WFL Shots/R: I Pre,se,nt,,,Operation:WF Phasing: Fill Tagged ,at (MD,): ............ L-U-P FROM TO HOURS .... DETAIl'S" OF (~PERATION ...... i ii i i! iiii i ii i iiii iii i ii i P' 8:00 11 :Od :~?od' Schlumberger on location. Change out tree connection, flU. P 11:00 13:20 2:20 F'~"~re test lubncator to~~nng lea~i~"~', ay--~'W~Tu'~ncator an~ ~' ...... ~ ""'T~-~" 13:50 ~)"~'~4~)m ~"~-~p~ t~g. ...... F 14:30 14:51 0:21 '~T~'O'~~ ~ ~ r~t'~'~-~'. Fi~~~-al)~t e-~'~'~-B-P'-~-'. ----P .... 14:51 15:45 0:54 ~'~i~0~~ no flow. Record 7 more ~:'~,, no flow. '---'is ..... -~T~t'~ .... T~.""O""!~ .......... 0:~0 .... ~et Minitron 600' ecord S~y-d~, no flow. 'T' '-'1"~":0~ 17:10 1:05 I'~'-cr~'~"'~-~ ~']b'~'~~l~i' "' P 17:10 T"7.'---30 ..... ~!20 ....... Set~'~i~Tlb'~-. ~[~"~'~~-~'~'"~-~~~~~g. ' P 17:3o ~7.-~!~- '--'6!:~S ........ Saai~l'E~'~T?~FF6c-6;Z~-~-~,,no~~'CkYate .... iS- 17:55 1 e: 10'~.. 1'i~-'-- ...... 'is--- -iis:'Ffb'- '-fE~' ........... ~i-~5~ ~etin,ton e2020', record "---P~ lS:50 19:05 0:15 '"'--~ 19:05 19:35 ~..~ ....Sef ~'T~'on~'~-~0rd 8cyCles,~ n0~fi0w~:'~h~ in annulus. - .......... = P 19:55 .... '~!iO .......... O~i~ ........... ~'"--P .......... 2-d~'~--' 20:45 ~..'1".~ ~T~~-[, no flow. ~'---~ ....... 20:45 21:00 "~!¥~ ......... ~S~t-'~i~~~'~, record a cycles, no Fow. - ~-F 21:00 21:15 0:15 ........ ~ .............. O: 00 0:00 0:00 0:00 0:00 0:00 .... 0:00 0:00 ............................................. 0:00 0:00 0:00 ................. 0:00 0:00 ........ t-- ...... 0:00 ...... ~ ......... 0:00 TOTAL 16:00 NOTE: USE A'rrACHMENT TOOLSTRG.XLS TO DESCRIBE TOOLSTRING. iii i ii i iii ! i i i i NOTES '" SERVI~E ..... COST ..... im j i i i i i m Electrmc4ine: ; $6,834 ; S,ck-..o: ! ! Helicopters: ( Boata: ~ , , $35 , Catering: ' ' Supervision (Contract): 1 't Other:.Other:' Car rental ! .... .$.9_6_ .... Other: i | Other: ~ ............ I I I I II ! ! m AFE No: i 147254 ~.FE Amount: , ! E-line Prey. Cum: )' $0 E-line Total Cum: ..Da_i/~ Total: Prey. Total Cum: t Total Cumulative: , $6,965 $6,965 ! iml m ELECTRIC LINE PROCEDURE Well: SRU 32-33WD Facility: Swanson River Unit Field: Swanson River Field API #: 50-133-20337-00 AFE #: 147254 Operation: WFL UNOCAL ) Status: Tubing: Tubing tail: Casing: WH Connection: Min. ID/Depth: ETD/Date: THF to RKB: Max. Hole Angle: Contacts: Name Office 3-1/2", 9.2#, N-80 2057' 7", 23#, K-55 2.81" in X nipple at 1967' & 2045' 18' 0 deg. Home Cell Pager Larry Greenstein o/&3-7661 Don Byme 7835 Dan Williamson 7677 Ralph Holman 7838 243-3667 696-1583 250-2712 268-5035 248-7558 223-2926 268-5582 563-6923 229-3199 Slickline procedure (gauge run) 1. Pressure test lubricator (Follow procedure in step m). 2. RIH with 2.7" gauge ring. 3. Rig down SRU 32-33WD WFL 11-00.doc Ralph P. Holman 01/17/01 Page I II. IlL IV. Hold safety meeting with production, drilling and Schlumberger personnel. 1. Establish that the tree valves are not leaking. 2. Establish tag out procedure for wellhead valves while wireline is in the well. Establish whom Schlumberger is to contact for pressure test and to operate wellhead valves. 4. Note: A pump-in sub with a valve is required below the wireline BOP's. o If well has a SSSV, ensure that it is pumped up to 3000 psi and blocked in the open position. . The Unocal on-site foreman and the Schlumberger engineer will discuss the following tie-in information: · Gamma ray character and collar spacing. · Verify that there is enough data to ensure an accurate tie-in. · Required logging depths and potential wellbore problems that may prevent obtaining logs of sufficient quality at those depths. · A call will be made to the on-call supervisor or engineer of a reasonable doubt exists that the correlation is accurate. Pressure test lubricator with methanol to 500 PSI for a low pressure test and check for leaks. Then, test to 2500 PSI or 500 PSI above shut-in tubing pressure, whichever is greater and check for leaks. Electric line procedure - WFL log (Follow attached procedure by Larry Greenstein): Objective: Status: Correlation Log: Preoared By: Pro,.c,edure: Prior to logging To perform a Mechanical Integrity Test (MIT) on this well with a Water Flow Log (WFL) and verify that the well is not affecting the fresh water aquifers. 7400 BPD 980 tubing press 940 casing press No log available - Use center of Packer depth @ 2000' Larry P. Greenstein To be executed by Drilling (1) Rig up slickline and tag fill with a 2.7" gauge ring. (2) Notify AOGCC and BLM 24 hours prior to logging. Mechanical Integrity Test (MIT): Water Flow Log ,(WFL) SRU 32-33WD WFL 11-00.doc Ralph P. Holman 01/17/01 Page 2 (~) Rig up to flow the tubing/casing annulus to a Baker tank. Place a valve, suitable to choke back well bore fluids, on the annulus flowback line. (A minimum of 250 BPD or a maximum of 500 BPD flowing back to surface is needed.) (2) Pressure test all applicable surface equipment to 4000 psi. (3) (4) (5) (6) (7) (8) (9) Increase injection pressure to 1100# and stabilize the injection rate. Record injection rates and pressures during the survey every hour. RU Shlumberger unit, BOP's and lubricator. Pressure test to'4,000 psi. MU a 1-11/16" TDT/WFL/GR tool in the up-flow mode. The WFL tool will have.gamma ray detectors at these distances, 1 fi, 2 fi and 15 fi, above the neutron generator (based on expected water velocities). Check equipment to be sure that it is working with all pieces screwed together. Establish and stabilize annulus flow at 250 - 500 BPD. RIH taking WFL measurements at the following depths. 700 800 1750 1950 2050 Use the neutron generator aS the depth reference, not the bottom of the tool. Use a 10 second burst time and stack 6-8 data sets at each WFL measured depth. It will take about 15 minutes at each depth to acquire the WFL data. Additional WFL measurements will be taken between the last depth that indicates water flow in the annulus and the next depth that does not indicate water flow in the annulus, unless this occurs at the packer, (a) Take a WFL measurement midway between these two depths. If there is water flow, take the next WFL measurement midway between this depth and the no flow depth. If there is no flow, take the next WFL measurement midway between this depth and the next flowing depth. Continue to cut the distance in half until the communication is located. Close the casing valve. Do not shut-in the master valve and cut the e-line. Take a WFL measurement @ 1975' to determine if there is water flowing in the annulus above the packer. If there is water flowing in the annulus, Continue to take measurements every 500 fi up the well, until there is no longer any water flowing. Then repeat the procedure in step 7 to locate the hole in the 7" casing. SRU 32-33WD WFL 11-00.doc Ralph P. Holman Page 3 01/17/01 If there is no water flowing ~n the annulus, Take a second measurement 50 fl above the first measurement to verify the first measurement. (10) If there is no water flowing in the annulus, or once step 9 has been completed, RII-I to gently tag fill and log out of hole to perform tie-in. (11) RD SRU 32~33WD WFL 1 l~00.doc Ralph P. Holman Page 4 01/17/01 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: X (MIT) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: RKB: 172' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, Alaska 99519 - 6247 Service: X Swanson River Unit 4. Location of well at surface REC~...iIv'ED 8. Well number 1874' FNL, 2010' FEL, SEC. 33, T8N, R9W, SB & M SRU 32-33 WD At top of productive interval 9. Permit number/approval numbe, r Same - vertical hole ~A¥ ~- '8 ZOO1 gO- t~" / ~,~1, ~'-0"~,,~ At effective depth 10. APl number Same - vertical hole At total depth Alaska Oil & C.-.-.-.-.-.-.-.-.-~ CoilS. CoI~1011 11. Field/Pool50' 133-20337 Same - vertical hole AlldlOrage Swanson River / Sterling 12. Present well condition summary Total depth: measured 2520' feet Plugs (measured) 2450' true vertical 2520' feet Effective depth: measured 2450' feet Junk (measured) true vertical 2450' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 90' 10 3/4" No 90' 90' Surface Intermediate Production 2400' 7" 700 sx @ 2499' 2499' 2499' Liner Perforation depth: measured 2100'-2228', 2234'-2278', 2316'-2424 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 Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3300 900 940 Subsequent to operation 3300 900 960 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Report Daily Report of Well Operations: X Oil: Gas: Suspended: Service: Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed:~~~ Title: /~//~ j/~/~~"~' Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ti¢t¥-! ]-98 I"ION 02:52 Pti ¢tOC,:,r"'"--, F,q,',{ NO, g0¢~,76 7542 _~R-28--98 THU 16:43 UN.AL RSSET G~S GRP Ft~X. NO. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P, 03 P, Ol Alter ¢.si~.' - Rep~-~'"'well: Plugging: ~Time extension: C~nge a~mv~ ~rogram: Pu~ing: ._ Vance: Pe~o~: ~her: ~- MIT I I;~w,; iI .......... UNOCAL ow~t~nt:~ RKO: t72' .. ,._ ~eet, ~. A~dmss'~ - ' " - ......... - " ExpleratoW:~ '-¢,'O~r'~e~ na~e' Stmt~taphiC: ~ P.O. 60X 106247 An~omge, AK 99519 - ~47 ~ewi~:-- 'Swanson R~er Unit . ...... . .. ~.~,., ~ ....... ,, :: ...... _ ..., ECEIVED Same - ve~l ho~ ....... ~... Sm~ - ve~ical hole 5~13~2~37 At total de~th i~'m~i~ol .... '"" ' ': .... ' Sam~.- venical ~e ~a ~l & ¢~ ~l, ~~ . . ~e~ River I ~terllng .: - __ , ,, ~ ..[ ..... i ii i, ._ 12. Pm~mnt well ~nd~on su~ Total demh: mea~ 2520' ~et P~gs (~u~) 2450, tree ~gi~l 2520' feet Effeaive ~Dth: . measured 24~ f~t Junk (masUr~) true venial 245~ Casing LenCh Si~e Coasted Measure degffi Trna vefl(~l depth S~ufat Ce,dado[ 80' 10 314" No 8o' Inte~ed~te Pmdu~ion 2499' T' 7~ ~x ~ 2499' 24~' 2499' Liner PROration dept~: measu~ 2100L2228', 22~'-2278'. 2316'-2424' Tublng (,~e, g.de, and measu.d aleph) 3 1~" EUE, g,2* N-e0 to Z05~ ~AR ~ G 1998 :' Ps.kern and SSSV (~ anO measured d~) Baker FH Pkr ~ 20~' _ . ........ _~ Git & i'3.~,~,~,~: - - '-- ~,~uo, ~=~'~,ro~M:~"' d~m,,,-~.., p~.~:~ ........ ,o~,k~~a~e "'" "~'~; Estimated date for ~mmen~"g' ap, ration -15. St,tus of W~ll'~;ss~ll~ as~ .... Feb~ a.~908 16. If'~ro°~ ~ Ve~al~, aPproVed: ........ 0~:~ Gas: ~. 17, I bemby'~'~ t~i {he fo~'~ing ~ tm'~'ana cowe~ to the'~{-0~ my ' ' .................. ~OR CoM~ss~O~ use ONLY, ~hd,uon. ola.',: .o. Comm,..,o~,~ 'Pm"~t." ~~. ....... ' ........ lAPPr~'' NO;~¢'~'~ ~:' Me~an~l Int~ Test~ - -~U~e~ent fo~ ~u~d ~o. ~ Approves ~ o~e~ of ~e Commissioner ·, _. . . ~ ..... , ....... - ..... ~- ..~ .............. n~,n.W .{nhnst~n Camm~sioner ..... O;te Approved Copy n=t. rned JRN-22-2001 I'ION 10:3'7 RI'1 U~L ~LRSKR NO. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Ul 1. Type of Request: Abandon: Suspend: ' ~peralion shutdown:. Re-enter suspenc~ed well: Alter casing: Repair well:. Plugging: Time extension: Stimulate: Change approved'--'programi Puli tubing: VarianCe: Perforate'-'~' Other: --~'- MIT 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development:. RKB: 172' feet -3. Address ' Exploratory,. 7. Unit or Property name Stratlgraphtc: P.O. Box 196247 Anchorage, AK 99519 - 6247 sewlca:-~" Swanson River Unit ~. Location of well at surface ' 8, Well numbe~ ' ' 1874' FNL, 2010' FEL, SEC. 33, T8N, RgW, SB & M SRU 32-33 WD At top of productive interval - 9. ~ermit number ' Same- vertical hole ~.~'~.~ ,.. ~ ~ ~ At effeotlve depth 10. APl number ' Same - vertical hole 50-133-20337 At total depth 11, Field/Pool Same. vertical hole Swanson River / Sterlin~ 12. Present well condition summary ' " Total depth: measured 2520' feet Plugs (measured) 2450' true vertical 2520' feet Effective depth: measured 2450' feet Junk (measu,,d)ORiGiNAL true verUcal 2450' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80" 10 3/4' No 80' 80' Surface Intermediate Production 2409' 7" 700 sx @ 2499' 2499' 2499' Liner PerforaUon depth: m,asured 2100'-2228', 2234'-2278', 2316'-2424 R E C E IV E D tr.e vet,ca, hole JAN 2 2 2001 Tubing (size, grade, and measured depth) 3 I/2" EUE, 9.2# N-80 to 2056' Alaska 0il & Gas Cons. ¢0mmissi0n Peckers and SSSV (type and measured depth) Baker FH Pkr @ 2000' Anchorage 13. Attachem~nts Desoription summary of proPosal:_~X Detailed operations Program.: X ~OP sketch: 14. Estimated da~e for commencing operation 15. Status ~f well' classification aa: ' _ Janua~ 23, 2001 16. If prOposal Well ~erbally approved: ' Oi1:__._ Gas: ~ Suspended:~ Name of appear ' ., Date approved Sen/Ice: 1-7., i~ereby ~i.tify ~at the forg~olng~ls ~.~Tand correpl to the be~t of my knoWr~dae.~i.~'1 'Wa!er' Disp'°sal ' ' , FoR COMMISSION USE ON~ Conditions of approval. Notify Commission so rePreaentaUVe may witness I Approval No. Plug integfily BOP Test Location clearance L~...~!,-- ~),~ u Mechanical lnte-"-~rily Test..L~_.' Subsequent form required I0-_. ' ~ 1~ I.~ ORIGINAL SIGNED BY J. M. Heusser ............ '"_ ..... O.,ommlsdoner, Date Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Post-It'" brand fax transmitlal memo 7671 I # of pages · Deer. ,,.'J .-... ,, '~ ~ Com~ ~IL-~I~L'~"~JL'/I ! ! ..... SUBMIT IN TRIPLICATE JAN-22-2001 lION 10:37 AlI UN~gO~,L ALASKA ! FAX NO, U/ ELECTRIC LINE PROCEDURE Well: SRU 32-33WD Facility: Swanson River Unit Field: Swanson River Field API #: 50-133-20337-00 AFE #: 147254 Operation: WFL UNOCAL ) Status: Tubing: Tubing tail: Casing: WH Connection: Min. ID/Depth: ETD/Date: THF to RKB: Max. Hole Angle: 3-1/2", 9.2#, N-80 2057' 7", 23#, K-55 2.81" in X nipple at 1967' & 2045' 18' 0 deg. Contacts: Name... ,_ Office ,,. Larry Greenstein 7661 Don Byme 7835 Dan Williamson 7677 Ralph Holman 7838 Hgn!e C.ell .Pa~er 243-3667 696-1583 250-2712 268-5035 248-7558 223-2926 268-5582 563-6923 229-3199 Slickline procedure (gauge run) 1. Pressure test lubricator (Follow procedure in step lJI). 2. RIH with 2,7" gauge ring, 3. Rig down RECEIVED JAN 2 2 2001 Alaska 011 & Gas Cons. Commission Anchorage SRU 32-33WD WFL 11-00.doc Ralph P. Holman 01/19/01 Page I JAN-22-2001 MON 10:37 AM U~)I~;~L ALASKA FAX NO, 8U'~3 (U (4 II. III. IV. Hold safety meeting with production, drilling and Schlumberger personnel. 1. Establish that the tree valves are not leaking. 2. Establish tag out procedure for wellhead valves while wireline is in the well. . Establish whom Schlumberger is to contact for pressure test and to operate wellhead valves. 4. Note: A pump-in sub with a valve is required below the wireline BOP's. , If well has a SSSV, ensure that it is pumped up to 3000 psi and blocked in the open position. The Unocal on-site foreman and the Schlumberger engineer will discuss the following tie-in information: Gamma ray character and collar spacing. Verify that there is enough data to ensure an accurate tie-in. Required logging depths and potential wellbore problems that may prevent obtaining logs of sufficient quality at those depths. A call will be made to the on-call supervisor or engineer of a reasonable doubt exists that the correlation is accurate. Pressure test lubricator with methanol to 500 PSI for a Iow pressure test and check for leaks. Then, test to 2500 PSI or 500 PSI above shut-in tubing pressure, whichever is greater and check for leaks. Electric line procedure - WFL log (Follow attached procedure by Larry Greenstein): u~ Obiective: Status: Correlation _Lol~: Prepared By: Procedure: Prior to logging To perform a Mechanical Integrity Test (MIT) on this well with a Water Flow Log (WFL) and verify that the well is not affecting the fresh water aquifers. 7400 BPD 980 tubing press 940 casing press No log available - Use center of Packer depth @ 2000' Larry P. Greenstein To be executed by Drilling (1) Rig up slickline and tag fill with a 2.7" gauge ring. (2) Notify AOGCC and BLM 24 hours prior to logging. Mechanical Integrity Test. (MIT): Water Flow Log (WFL) SRU 32-33WD WFL 11-00.doc Ralph P. Holman 01/19/01 RECEIVED JAN 22 2001 Alaska 011 & Gas Cons. Commission Anchorage Page 2 JthN-22-2001 I'ION 10:38 lhI"l U~L RLttSKfl NO, 90~3 7~74 F. Uq (1) Rig up to flow the tubing/casing annulus to a Baker tank. Place a valve, suitable to choke back well bore fluids, on the annulus flowback line. (A minimum of 250 BPD or a maximum of 500 BPD flowing back to surface is needed.) (2) Pressure test all applicable surface equipment to 4000 psi. (3) Increase injection pressure to 1100# and stabilize the injection rate. Record injection rates and pressures during the survey every hour. (4) RU Shlumberger unit, BOP's and lubricator. Pressure test to 4,000 psi. MU a 1.-11/16" TDT/WFIdGR tool in the up-flow mode. The WFL tool will have gamma ray detectors at these distances, I ft, 2 ft and 15 ft., above the neutron generator (based on expected water velocities). Check equipment to be sure that it is working with all pieces screwed together. (5) Establish and stabilize annulus flow at 250 - 500 BPD. (6) RIH taking WFL measurements at the following depths. 700 800 1750 1950 2050 Use the neutron generator as the depth reference, not the bottom of the tool. Use a 10 second burst time and stack 6-8 data sets at each WFL measured depth. It will take about 15 minutes at each depth to acquire the WFL data. (7) Additional WFL measurements will be taken between the last depth that indicates water flow in the annulus and the next depth that does not indicate water flow in the annulus, unless this occurs at the packer. (a) Take a WFL measurement midway between these two depths. If there is water flow, take the next WFL measurement midway between this depth and the no flow depth. If there is no flow, take the next WFL measurement midway between this depth and the next flowing depth. Continue to cut the distance in half until the communication is located. (8) Close the casing valve. Do not shut-in the master valve and cut the e-line. (9) Take a WFL measurement @ 1975' to determine if there is water flowing in the annulus above the packer. If there is water flowing in the annulus, Continue to take measurements every 500 ft up the well, until there is no longer any water flowing. Then repeat the procedure in step 7 to locate the hole in the 7" casing. SRU 32-33WD WFL 11-00,doe Ralph P. Holman Page 3 ~ ~ JRN-22-2001 liON 10:38 ~,. NO, 90,,~,-~3 "(874 If there is no water flowing in the annulus, Take a second measurement 50 ft above the first measurement to verify the first measurement. (10) If there is no water flowing in the annulus, or once step 9 has been completed, RIll to gently tag fill and log out of hole to perform tie-in. (1 l) RD 1~. Ub RECEIVED JAN 2 2 2001 Alaska 011 & Gas Cons. Commission Anchorage SRU 32-33WD WFL I l-O0.doc Ralph P. Holman 01t19/01 Page 4 Spud: 5 25 8.1 , Completed: 5/29/'.81 .' Lost Workover: 57'24/95 SRU 52-55WD Swanson River Field AP1 No.: 50-155-20557-00 0,0 - 90.0' 10 3/4" OD CSG Driven 90,0 - 90.0' SHOE 0.0 - 2499.0' 7" OD 2&OO#/ft K-55 SURF CS6 2450.0 - 2499.0' CEMENT PLUG 2499.0 - 2499_0' SHOE KB ELD/: I72' PBTD: 2450' TO: 2499' Top of In act on Zone: Ft. Angle @ Perf's: 0 Decks. Hanger: VETCO GRAY 18.0 - 18.8' ZOO" OD 2.992" 1D HANGER Vetco Gray Hgt. 18,8 - 19,3' CROSSOVER 3 1/2" EUE.. x 3 1/2" BTC. 18.8 - 2056.4' 3,500" OD 9,20#/ft N-80 TBG I967.5 1996.8 1997.3 2005.5 2045.8 2055.4 2056.4 2100.0 - 1968.7' 3.937" OD 2.81" ID NIPPLE Offs "X" - 1997.3' CROSSOVER 5 1/2" 10RD. x 5 1/2" BTC. - 2003.5' 5.968" OD 3.00" ID RETRV. PACKER Baker FHL Pkr. W/40K Sheer - 2003.9' CROSSOVER 3 1/2" I ORD. x 3 1/2" BTC. - 20¢7.2' 3.957" OD 2.8i" ID NIPPLE Otis "X" - 2056.4' CROSSO'~R 3 1/2" BTC. x 3 i/2" EUE. - 2057.0' 4.250" OD 2.992" ID SHEARSUB Baker Shear-Out W/Bell Se~t - 2228.0' ?£RFS 4HPF, 128', 8/i9/8!, 9/85 ;~,,,~.v - .,z/o.u PERFS 4HPF, 44, 8/]9 81, 9/85 I Water Disposal Well MEMORANDUM STATE OF ALASKA TO: Well Files 31-33WD (80-114) and 32-33WD (80-115) FROM: Wendy Mahan DATE: April 13, 2000 RE: Unocal request to inject nonhazardous ethylene glycol waste into Class II well(s) at Swanson River Field I spoke to Laura Hammond on April 10th, 1 1th and 13th regarding Unocal's request to dispose of 6-10,000 gallons of ethylene glycol and flush water generated in the Swanson River Field (SRF). According to Laura, there are 12 1000 Btu heaters at well pads or tank settings at SRF. The heaters heat flow lines (oil out) or gas lift lines (gas down) to wellheads at oil producing wells. The heaters are natural gas fired and provide a heated ethylene glycol bath surrounding the flowlines. The glycol bath is necessary to reduce hydrate formation/freezing in the flowlines. The heater systems currently hold approximately 3,000 gallons of nonhazardous ethylene glycol. An additional 3-6,000 gallons of water must be used to flush the lines once the glycol is drained. Unocal originally planned to send the ethylene glycol portion of the waste to a commercial facility for recycling but was told that the glycol had degraded to the point that it was no longer usable. The only Class I disposal wells in Alaska are located on the North Slope. Transporting the waste for disposal on the North Slope would create an additional spill risk as well as unnecessary air pollution and fuel usage. Unocal could also store the waste indefinitely and use it for make-up water when drilling activities resume. Storing the waste indefinitely while awaiting disposal also creates an additional spill risk. The Commission authorized the Class II injection of this "associated" waste as the most environmentally beneficial solution. I notified Laura of the Commissioners decision on April 13, 2000. [Fwd: ethylene glycol and flush water disposal] Subject: [Fwd: ethylene glycol and flush water disposal] Date: Thu, 13 Apr 2000 15:41:57-0800 From: Wendy Mahan <Wendy_Mahan~admin.stat¢.ak.us> Organization: doa-aogcc To: Camille Oechsli <cammy_oechsli~admin.state.ak.us> Cammy, I accidentally left you off of this email. Subject: ethylene glycol and flush water disposal Date: Thu, 13 Apr 2000 15:40:45-0800 From: Wendy Mahan <Wendy_Mahan~admin.state.ak.us> Organization: doa-aogcc To: lhammond~unocal.com, Robert Christenson <robert_christenson~admin.state.ak.us>, Dan Seamount <dan_seamount~admin.state.ak.us> Laura, Unocal has requested to dispose of 6-10,000 gallons of ethylene glycol and flush water generated in the Swanson River Field (SRF) into two Class II disposal wells, 31-33WD and 32-33WD. According to my previous conversations with you, there are 12 1000 Btu heaters at well pads or tank settings at SRF. The heaters heat flow lines (oil out) or gas lift lines (gas down) to wellheads at oil producing wells. The heaters are natural gas fired and provide a heated ethylene glycol bath surrounding the flowlines. The glycol bath is necessary to reduce hydrate formation/freezing in the flowlines. The heater systems currently hold approximately 3,000 gallons of nonhazardous ethylene glycol. An additional 3-6,000 gallons of water will be necessary to flush the lines once the glycol is drained. Unocal originally planned to send the ethylene glycol portion of the waste to a commercial facility for recycling but was told that the glycol had degraded to the point that it was no longer usable. The only Class I disposal wells in Alaska are located on the North Slope. Transporting the waste for disposal on the North Slope would create an additional spill risk as well as unnecessary air pollution and fuel usage. Unocal could also store the waste indefinitely and use it for make-up water when drilling activities resume. Storing the waste indefinitely while awaiting disposal also creates an additional spill risk. The Commissioners discussed the situation and determined that Class II injection of this nonhazardous "associated" waste is the most environmentally beneficial solution. Please feel free to call me if you have any further questions, WendyMahan Natural Resource Manager 4/13/00 4:09 PM ]I,¢,R-26-98 THU 16:43 UNO~C~ ¢155ET 6¢1S GRP FClX NO. 9072~7874 STATE OF ALASKA ' " ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P. OI 11 Typ~ of RequeSt: "Abandon: Suspend: -- operation shutdown! .... Re.~nter suspended well: Alter casing:'?- Repair Well: Plugging: ~Time extension: Stimula~, Change approved--'~rogram: Pull tu--~ing: Varian"'-'~: Perforate:'" Other: -'X'- MIT . , ....... . . i · :1 i .... 2. Name of Operator 5, Type of well: 6. Datum elevation (DF or KB) UNOCAL oevelopment: RKB: 172' feet ~. Address' ...... Exploratory: ~ 7'.' Unit ~)r '~roperty name ......... . Stratigraphic: P.O. Box 196247 Anchorage, AK 99519- 6247 Service: X Swanson River Unit ~. Location of'will at sUrfac~ ........... 8. Well number ............. 1874' FNL, 2010' FEL,'SEC. 33, TSN, R9W, SB & M SRU 32-33 WD At top of productive interval ti. Be, r~j3~t '~uml~, ~;., ........... Same - vertical hole:~'/(.~ "- [ {ll,.~ ,, At effective depth 101 APl number Same - vertical hole 50-135-20337 .. . At total depth 11. Field/Pool , Sa.m,e.-,mVertical hole Swanson River I Sterling 12. Present welt conditi~'~ s'um~nary ...................... Total depth: measured 2520' feet Plugs (measured) 2450' true vertical 2520' feet .Effective depth: measured 2450' feet Junk (measured) true vertical 2450' feet Casing Length Size Cemented Measured depth True vedical depth Structural Conductor 80' 10 3/4" No 80' 80' Surface Intermediate Production 2499' 7" 700 SX (~ 2499' 2499' 2499' Liner Perforation depth: measUred 2100'-2228', 2234'-2278', 2316'-2424' true vertical Same - vertical hole RECEIVED Tubing (size, grade, and measured depth) 3 1t2" EUE, cJ,2# N-80 to 2058' MAR 2 r~ '~998 Packers and SSSV (type and measured depth) Baker FH Pkr {~ 2000' ~,,~ pit & Gas Cons. Commission :Ii, Attac'h~ments ........ Descripti°n'~ummary of proposal: X.~ "Detsiled"operations ~rogrsm: X .... ' --- BOP ske~cho.._rage I~=.,~e.s-r ~~¢~,- '7"0 f'~,-,'r,~u~. 14, Estimated date for commencing operation 15. Status of well classificatl'0n as: .. . February 8,1998 16, If proposal well verbally approved: - Oil:~ Gas: ...--. Suspended:_.... Name of approver Date approved Service: ..Water, Disposal ....... 1~. I hereby'~:ertif~ that the foregoing is true and correct to the' 'l~est of my' I~nowled~e. ' .......... """" FOR COMMISSIOI~I USE ONLY C°nditi°n' °f approva': N'b'ifY c°mmi"i°n '° repre'e'ntative ~laY '~tneS'Plug integrity__ BOP Test Location clearance ..... IAPPr'~V'i N°'~OIC~-- ~:~)0 Mechanical Integrity Test .-.-- '"'~ubsequent form required 10- - Appmv,e,d by order of the Commissioner .. n~uirl W .Inhnston commissioner oat? . ..... x.~ .~r. ~ .... ..: .......... , Post-it' Fax Note 7671 lOa{;~'.~ Z. I~-~}-'"~,- ] -[ ' '" SUBMIT IN TRIPLIC: ~TE Approved Copy Z~Leturned MC, R-26-98 THU 11:42 UNOCAL ¢,SSET Gets GRP ' I. JNO~3AL WELl: SERVICE RE FP, X NO. 9072637874 Y, U;"/U~ Wireltne Company: ............ Schlumberge[. {Contractor Supervisor: Rachel Welah !Work Being Done.:. . WFL .... J.F!!l Tagged al (MD}: Present Operation.s: .... .R. Ig'.d/down. Done Gun Type, SizeI S..P.F.; Phase: .... u,OCAL ~...~,.o,: u,,~ ~ca~,st.r~w~..s,.. ' l%,,r.~."i'.,,.i.,, '~ o, · ~ ",, ,",'," -- ' -'-':': ::"- : ::-"':%':'" -~'-' ' ..'. ' .'7 ~ .~ :::7: ;:~: ._ ,,~::- :"~:. ' ....... '.:':'. ,':'.' ' ' .. ' ~'ROM 'r,o, ..... ,,ou.~S ..... D~'rA~LS O~: ?':~T~O,N ...... .,._~.;m_ ....... '~.._J:_,,~ ............ ~_:4~ _. ~S~S.J,~ak.r tank & ~o~. ~.,~.L~,~r_~:~L~_up_,:~v,~Jh,,~ ~pr .~, _.u~_._,,..,) ................... -:- ....... .. 0!00 P. re~reT :~...t :!~Ut~d _cator & :C~hoke__M.antfold 2500 Pal. Ok- ._~1,1.~ ..... 12,..,.;.~.~ ..... 0:15.....L- RIH w/w FL T_~_~_.to.2.~_RK~J.nl.ec~__..LW/~~ Pr..- now a..ulu, to ~k 12:oo 15:3o ._ 3:3o.. ~tvate T~ .~_2~__~m..?:^??~__~;_~;__.&_.:!??p~. ~..rpm~ ~oke/bk rate & Re-aoUv.te --.--O. LO~- ...... !.0_.'_3_~m ' RIH te 1000' & maas AV*I - N~n,.e I~.Lnd!ca_~_ng~t~g :leak abov~e !00(7 -_RIH ~_TL,a_ g.,FIl__l' ....... 0!~ ._. betw.e. 7OO' & ?~ 15:30 1{]:15 .0:~ ......... Shut/~.~nu~u~ & RIH & Activat. T~ ~ 2q,4.0_'~,.,?~u_ &..~:~ :~ b k~k f~r ............... 0;O0 _. Up/_.,;ha~n?~e!~L- N~ne- Pulltu~ to 70<3' & Ac~ltvate 1o leek~l~l~, k~ ............................ o~_ ........... None ..~1.,~:1_5_ ..... 1~.7.',.~._... 1:15 POOH & Chanl~e tool around to l~, for down/channelin~ 17:30 19:00__ ..... 1:30 RIH & Activate ~..~._!..!..!..!..!~[~500_~_~~_.~ ~,down/;hanne{inll~- POOH lg:oO 20:3o 1:3o ~[~ &_.m~ve/out 0:00 ........... ; ........... 0:00 O:oo 0:00 ~.w.,..,...,~,,I .... ~ ................................ ..~ ....................... , .... ..........................o:oo O:00 O;OO ......... 0:00 TOTAL: 11:30 I~IOTE: USE/4 TTACI. f;~fENT TOOLSTRG, XL$ TO DE2CRfE~E ' ~ · ~:7 ,, ~,,~ ' ',:',' ';',"';~'~'.';,;,;,':::7:: : · ~:'-":: ' I"..'.':.'".'_' . '"'. '"'.'..' ~ -. ~ '---. ' :..: ..... ;; COSTS .. "",..,,o, :' ....... ' "!"",F.,.,.,,'i:":, ...... D,,,,..,. ,s,_w..s,. ..................... ..W...~.~,~9.?_L.~. .... .!..%~.~. ....................................................................................... ,._..,~....~... ~,..,, , ,,,, __ : ,::.: --- ..,...,..,,,~,,..,.,.....+,--.--,,.... ,---.-~,..~..--.~.....,..,.,..,--.,., ~..__ ........ ,,.,....,.,..,4.o.,,,., ....... ..,,,.~.--,,,...~. AFE AMOUNT: $~1~900 DALLY TOTAL: i CUMULATIV;: :!-'T::: : :':' .... ~ ~ ......... . . :~ j ~ .;:.::,........ ,~.. ~,. !_ ......... : ' ...... SERVICE <3..OMPANY ................ SERVICE PERFORMEO SERVICE ORDER _ . . . ?.. .., . ,. sw8 ............. _W.....t..._r.~J_~.._L_~ ..................................................... R,E. CEtV ' I ILIll IIIII II I I Illl I II I II III I IIIII I I IIII MAR 26 1998 D Naska 0ii & Gas Cons. C0mmisston Anchorage I'I~R-26-98 THU 11',43 UNOO~L ~SSET 6~S G. RP t"SX NO, UU-(;,'U3(UO~ r,u~/uu -" III II IIII I II i iiiiii ..... -'~'- ~--~w:T '" ' .~OGGING TOOL STRING ..... -SKETCH ............................................... EQFi, I 11/16" OD CALU, I 11/16" OD ATTB, 1 11/16" OD TDTP, 1 I1/16" OD TDBN, I 11/16" OD MH-22 Head CCL GR HV RF2 RN2 37.0 F 31.0 F 30.2 F 29.3 F 21.3 F 19.8 F 19.7 F 7.4 F 6.9 F 0.7 F TOOL ZERO COMPANY WELL FIELD TOTAL TOOL STRING LENGTH IS 38.7 F. TOTAL ,.T.Q..O.,.L, ....... S.T,,,,R,I. NG ,W~..,,.,I..GHT IS 253. LB IN AIR. .............................................. - --1 , , , 1:111 .. i Union Oil Company of California SRU 32-33WD Swanson River Unit BOROUGH Kenai STATE Alaska $CHL, FR 2156,0F SCHL. TO 2156,0F ORLR, TO Elev: KB DF GL HRR-26-98 THU 1:43 UNOOflL RSSET GhS GRP F'RX NO, 1-', uq/uo 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 tteference : 98011 Schlumberger GeoQuest Interpretation & Computing Services 500 West International Airport Road Anchorage, Alaska 99518 (907) 582-7669 RECEIVED MAR 26 1998 Alaltka 011 & Gas Cons. Commission Anchorage HflR-26-98 THU 11:44 UNOCAL UNOCAL aSSET GaS Gift-' l-.'Bl,X, NU, BU {iUd ~'U lq. r. u~/uo Log Date; 0~-Eeb-1998 SWANSON RIVER ~RU ~2-33 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 NOT 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 surface. 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. Altached is a plot of the WFL results along with tabular listings of the interpretation results and field recordings. RECEIVED MAR 2-6 1998 Alaska 0il & Gas l;~a'l~, ~ il II II II II II IIRR-26.98 THU 11 ;44 UNOCAL ,qSSET GftS GRP I~'AX NO, UU'f;.'U~fU(~ r, 00/00 I I I I I ~, II UNOCAL, SRU 32-33WD, Swanson River Unit, WFL, 8-Feb-gS, (980~ 1) o 0 O 0.0 ~.0 0.0 2~.0 0,0 ~.0 - , ,,,,,,:,.~ ........... :::~ "' ........ ".. :' 'A~ ' " I ,,::: ..:. :.::.....- . . Annular r~e in~eas~ at 3~ ·" · ~ '-'::"':' TM ....... ~ ... '.?. ,...~..;~..: ... ,,, . 7. :.'L" .. ::-~ '?..'~ ' ~ · :, ':-;.- :"i. ~;.-..." Tu~ngL~k~n7~-~ 8~ ....... · '.~ ....". , ~ ' .. ~ :.'~. ~ ............... ~., .. --..,'... ~:....?. ~ ':'~ ~ :'.:... :~.:'.. :-.:: ., ~.. · :.:':' ~:~:::::'(:'. .:. :':..':: :~?' :'. No UpR~ w/ annuls ~-~ 1~oo ': ::" :::: ' - :~ ..... ,. . . .:. .... ..,~:,: ~-....:~ ~.~.':: (.. .... .: ........... 2~. "...~ ~.~'..: ,"::,.:' .. 2'~: ? " /.. .~ ¥' :'..- .~, ?. :2:: .~' ~ ':' · .':' ~" :"' ":-"':' ,7 17~ ,v . -: ' ,:,: .... . ~':'. . ¥:: .v M,' :. ':. ~,, . ..... 1~ ~:::: . .. '. ,:,":: - ;~', -,..... , ' : ~ ~'2' .'~... : .. .~ -. . · · . .: · ,:~ ) %%'. . .~ ~' ~ - '~, 2 .':. ...... ~ ,...:...~'/:". )' ..:::.'::...':'?:~: ~ ............................. "'""'.' :",. "' ' MAR 26 ]998 Naska 0il & Gas Cons. Commisswr~ Anch0m?, ~R-26-98 THU l 1:45 UNOCAL i iiiii LII I UNOChL ASSET GAS GRP , Lol~ Date = 08.Feb-1998 SWANSON' RIV'ER SRU 32-83 WD .... I Ill II[llllllllllll Il I Ill I IllS Water Flow Log Job Reoults: Unocal Well #: SRU 32-33 WD OD ID WFL Tool 1.69 - TUbing 3.5 2.992 7' Casing 7 6~386 ' Flow Areas O.D. I.D. b~pm inside tub~ 2.992 1,69 8~63 tubing - 7' ann, 6.366 3,5 39.59 7" - OH ann. 8.5 7 32.65 , , . Unocal SRU 32-33 WD WFL ..... I i'. FPM .............. i.. J n~ # I ~ I .... ~ '. i I, 2'. ! is~ luo~e 2 250 too fast too fast 68.4 Up Flow 3 250 too fast 10.3 ? Up Flow 12 500 too fast 28 29.7 Up Flow 13 600 too last 30,6 33.2 Up Flow 14 700 too last 33,2 31,6 Up Flow 11 750 2.3 0 0 Up Row 4 1000 0 0 0 Up Flow 5 1000 ?? 3,5 0 Up Flow 10 ! 990 2,3 0 0 Up Flow 9 2020 0 0 0 Up Flow I' approx. detector"i fpm limits 1 ft, 1-30 2 it. 2,.60 6 ft. 7-180 15 ft, 16-450 20 fl, 22-600 I BP0 ...... , ,: :" ............... IRemarks ,I in tuu"g I t~; 7' 1..?'- oH Csg FIo~ng 584 2708 222 Ceg Flowing 88 40~ 335 Csg Flowing 263 1176 967 Csg Flowing 261 1211 996 Csg FI owl ng 272 1263 1038 Csg Flowing 20 91 75 Csg Flowing 0 0 0 Csg Flowing 30 130 114 Csg Flowing 20 gl 0 Csg Flowing 0 0 0 Results indicate tubing leek'between 700:& 7~0:, smaller leak dght above the packer, no channelling 18 700 0 0 0 Up Flow Csg Shut-in 0 0 0 17 1980 ?? 0 0 Up Flow Csg Shut-in 0 0 0 16 2040 0 0 0 Up Flow Csg Shut-in 0 0 0 Results indicate no Ca~?i.fl.,~ leek above packer depth, confirmed no ~annefling behind casing above 2040' 21 500 0 0 0 Down Flow Csg Shut-in 0 0 0 22 900 0 0 0 Down Flow Csg Shut,in 0 0 O 23 1950 0 0 0 Down Flow Csg Shut-in 0 0 0 Resulls confirmed nq.c. asing leak above pecker depth . Job Summary: 1) The tubing is leaking between 700'-750' 2) The tubing is leaking right O the packer O 2000' 3) The casing is inlacl - no leaks documoflled 4) There were no channels documented behind the casing above 2040' Comments annular rate too high 2500 blXl lowered annular rate annular rate too Iow increased annular rata 2.3 estimated Ilow detected NO Interpreta~ion ~aR-26-98 THU lt:4b ,? UNOCAL __ UNOOAL A55~'1' Ufl6 UKV I~R~ NU, ~JU/~'0~IL)Iv, r, vo/vo , ~W.~N~OI~I H.I~F~H. ~iRU 22-35 WI) IIi1[11 -- ii i i i! . . iiiii Job Results: Unocal Well if: SRU 32-33 WD OD ID WFL Tool 1 .......... 7' Ca.~!ng 7 6.366 Flow Areas O.D. I.D: . .bpd/fpm ......... , i~slde tubing 2.992 1.69 8.53 t, ubln~l - 7' ann. 6.366 3.$ . _39.59 7' - OH ann. 5.5 7 32.55 ,,, Unocal SRU 32-33 WD _.WFL approx. det~r f~m limits I fl, 1-30 2 fl, 2-60 6fl, 7-180 15it, 16-450 20 lt. 22.600 .... I FPM t 1' ' BPD m~* ~ i 'DePth I t' I 2, I .... ts' lmod, IRamarks '! i.t. bi.g I tho. 7' ! ~;: OH too fast too fast 68.4 Up Flow Csg Rowing 584 2708 2226 2 25O 3 250 4 1000 5 1000 9 2O2O 10 1990 11 750 12 5(30 13 6(30 14 700 Results 16 17 18 too last 10.3 ? Up Flow 0 0 0 Up Flow ?? 3,6 0 Up Flow 0 0 0 Up Flow 2.3 0 0 Up Flow 2.3 0 0 Up Flow too fast 28 29.7 Up Row too last 30.6 33,2 Up Flow Csg Rowing Csg Rowing Csg Flowing Csg Flowing Csg Rowing Csg Flowing Csg Flowing Csg Flowing 88 40,6 336 0 0 O 30 136 114 0 0 0 20 91 0 20 61 76 253 1176 967 261 1211 996 too fast 33.2 31.9 Up Row Csg Flowing 272 1263 1038 indicate t~blng leak between 700.' & 750', smaller leak. rig, h, ,t, a~ve tho packer, no c,h~n.e!li.ng 2040 0 0 0 Up FieW 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-in 0 0 0 Results indicate no casi?~ leak above packer deplh, confirmed no channelling behind casing above 2040' I . "~11 : ~ ~: ~ r iiii . I I Iii ~ Il ~" 21 . $00 0 0 0 Down Flow Csg Shut-In. 0 0 ' 0 22 900 0 0 0 Down Flow Csg Shut-in 0 0 0 23 1950 0 0 0 Down Flow Csg Shut-in 0 0 0 Results confirmed no casing leak _above. pacl~?r.,depth Job Summary: 1) The tubing is leaking between 700'-750' 2) The tubing is leaking right O the packer O 2000' 3) The casing is intact · no leaks documented 4) There were no channels documented behind the casing above 2040' Comments annular rate too high 2500 bpd lowered annular rate annular rate too Iow increased annular rate 2,3 estimated flow detected NQ Field Recording rlflK-U~-~U t'K! Id;lq i,' OPeratio n~" p-~rfomled: UHUUflL FI~;::Jh.I IjH~ I~KI' I~H~ I~IU, ~UI/OJlI~/u~ ?~'~', STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown: Stimulate: Pull tubing: Alter casing: 2, Name of Operator UNOCAL 3. Address P.O. Box 196247 Anchorage, Alaska 99519 - 6247 4. Location of well at surface 1874' FNL, 2010' FEL, SEC. 33, TSN, RgW, SB & M At top of productive interval Same - vertical hole At effective depth Same - vertical hole At total depth Same - vertical hole feet feet 12. Present well condition summary Total depth: measured 2520' true vertical 2520' r, UI/UO PlUgging: Perforate: Repair welt Other:' X,, (M~T)_ ...... i'-5, Type of Well: 6, ~l'[~m elevation (DF or KB) Development: RKB: 172' . feet __ Exploratory: -. ..... 7. Unit or Property name Stratigraphlc: Servtce:~ Swanson River Unit SRU 32-33 WD R E C E IV E D ...... nUmber .... 10. APl number 50-133-20337 ~{~\R C~ ~ 1998 ~1. r~eld/.ool Swanson River Alaska 0ii & Gas Cons. C0mr:;iss~o)'i Plugs (measur~hch0ra~50' Effective depth: measured 2450, true vertical 2450' feet Junk (measured) Casing Length Structural Conductor 80' Surfaoe Intermediate Production 2499' Liner Perforation depth: measured Size 10 314" Cemented Measured depth True vertical depth 7" 700 sx ~ 2499' 2100'-2228', 2234'-2278~, 2316'-2424' 2499' true vertical Same - vertical hole Tubing (size, grade, and measured depth) 3 1/2" EUE, 9.2# N-80 to 2056' 0 R J G Packers and SSSV (type and measured depth) Baker FH Pkr ~ 2000'. ......................... Post-it' Fax Note L~ :: LO/iS, ............................................ · . 7671 13, Stimulation or cement squeeze summary Intervals treated (measured) Co,IDept, Treatment description including volumes used and final pressure '~ ~ ,,- 14. Representative.Daily Ave!;a~e Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Fax # Tubing Pressure Prior to well operation 7000 900 940 Subsequent to operation 7100 900 960 16. Attaohments: Copies of Logs and Surveys run: R,~ort Dally Report of Well Operations: X 16. Status of well classification as: Oi1: Gas: Suspended: Service: Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: /~_~)~. c ~[ ~ Title: Form 10404 Rev 0gl15/88 SUBMIT tN DUPLICATE rlflK-Ul~-~ l"K J. I i::j; I q URUIjflL fl~;51:. 1 I~H~ LfKI-' UNO'CAL WELL SERVICE RE IT Wireline ComF,an¥: ...... Sohlumbe[ge[ .... [Contractor $'~per~i. sor: Rachel Wabh Work Being Done;. WFL IFi, Ta~ed a~_[~O~: , , ~rese~t Operations: , , R~'.dld~ ~ Gun Type, Size, SPF, Phase: UNOCAL Supe~lsor: ~ M~atli~rl ~r~ Or~n eport 1 of I~L I Ill I I I IIII I III II II. I IIIII TIME ' FRQM TO HOURS DE~AILS OF OPE~I~N ..................... ~;~ ....... :Pr~e T~t Lub~r & Ch~e Ma~ 2~ P~ - Ok - 0:~ ~n 7~ & 7~ 0:~ ~on~ 0~ 0:~ 0:~ 0~ ~ ............ 0:ffi .......................... ~ ..... 0:~ .............................. 0:~ COSTS ......................... A~B AMOUNT: CUMULATIVE; I'lf:tK-U§-~JU 1~ K I ]. ti: 1. b UFIUUflL fl:5:Skl Hfl;5 ~JKI" t' fl~ [~u, ~u r I I I I II ij II __ I I - -' .I I j I i i II · LOOGING TOOL STRING SKETCH .......................... ....... . ........................... , ,,, , , , [, U,D/ i ii i i i i iii] i i i1 ii ] ilL. iiiiii ..~ . EQF1, 1 11/16" 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 BOROUGH TOTAL TOOL STRING LENGTH IS 38.7 F. TOTAL TOOL STRING WEIGHT IS 253. LB IN AIR. ..................... ,!I,~:,?I, " ' ' ,. ~ I I I II ...... i1.1~ ii $¢HL. Fn ~l~e,o F Union Oil Oompany of Oalifornia SCHL TD ~I~D.O F SRU 32-33WD Swanson River Unit DRLR. TD Elev: KB DF Kenai STATE Alaska GL I'II-IK-IJD-UU F K 1 10; 10 UI~ILJI,,;HL HDD". 1 ~THD ~I'KF F MA Dig. UU I,"UO I 0 I WFL ADVISOR WFL Interpretation SRU 32-33 WD Company : UNOCAL Field : SWANSON RI-VEl{ Logging Date : 08-Feb-1998 Processing Date : 2-MAR-1998 Analyst : Rob North Reference : 98011 Schlumberger GeoQuest Interpretation & Computing Services 500 West International Airport I{oad Anchorage, Alaska 99518 (90~) MRR-06-98 F'R 1 16: 16 UNOCAL UNOGAL A88~'1' Gfl~ GRE Lo~ Dal;e ~ 08-Feb-Z99S SWANSON RIV]~R SRU $~-8~ WD iiii iii i i II I II IIII . . I I I 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 NOT 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 surface. 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 (-1 lOObpd) 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 rlflK-UU-VU l~Kl IU;IU U~UUHI H;5;Shl ~JH;~ VKK l"H/~ l~lU, uu(/oo(o(,~ r, vv/w UNOCAL, SRV 32-33WD, Swanson River Unit, WFL, 8.,Feb-ge, (9801 I) o o o Up ~nul. OpMI Up AmmI.Clo~ed Dram Tub. x ?irt o.o aooo.o o.o 2~.o o,o · :' . .... 0 Annular rate increased at suri'ace I 800 .. . [:::: :':N°~'annular DownFIow I : i I 2300 i ' 240O Mflg-Ol~-88 Fi I 1 ~: l'/ UNOCAL Log Date: OS-Feb-legS SWANSO~ ~BR S~U 82-88 WD I I II II II I II1~1 II IIIII I I I II I . II,Jill II Job Results: Unocal Water Flow Log Well #: SRU 32-33 WD OD ID .. WFL Tool 1:69 , ,Tubing. 3,5, ....... 2.992 7' Casing 7 6.368 Flow Areas O.13. I.D, bpd/lpm inside tubing 2,992 1,69 ' 8.53 , , t,u, bing. 7' ann' 6.366 7' - OH ann. 8.5 7 32.55 Unocal SRU 32-33 WD WFL :: , , approx. detector fpm limits 1 It. 1.30 2 It, 2-60 6 ft. 7-180. 15 ft, 16-450 20 lt. 22-600 .... ;l~*l 0aP*hi...r ..I 2'....[ ts'..., lU.ode . In,re,rko, l ln?(~.l t~-7' I ?'-OH 2 3 12 13 14 11 4 5 10 9 Results 16 17 16 Results 21 23 Results 250 too fast too fast 66.4 Up Flow 250 too fast 10.3 ? Up Flow 500 too fast 28 26.7 Up Flow 600 loc fast 30.6 33.2 Up Flow 700 too fast 33,2 31.g Up Row 750 2.3 0 0 Up Flow 1000 0 0 0 Up Row 1000 ?? 3.~ 0 Up Flow 1990 2.3 0 0 Up Flow 2020 0 0 0 Up Flow Cae Flowing 584 2708 2226 Csg Flowing 88 40~ 335 Csg Flowing 253 1176 967 Csg Flow~g 281 12t 1 996 Csg Flowing 272 t263 1038 Csg Flowing 20 91 76 Csg Rowing 0 0 0 Csg Flowing 30 139 114 Csg Flowing 20 91 0 Csg Flowing 0 0 0 indicate tubing leak between 700' & 750', smaller leak right above the packer, no channelling 700 o o 0 UPFfw '" ' ....... Csg Shut-in 0 0 0 1980 ?? 0 0 Up Row Csg Shut-in 0 0 0 2040 0 0 0 Up Flow Cog Shutdn 0 0 0 indicate no casing leak above packer depth, oonlinned no channelling behind casing above 2040' 500 0 0 0 ....... Do~vn Flow Csg Sh~i:~'" 0 0 O 900 0 0 0 Down Flow Csg Shut-in 0 0 0 lgSO 0 0 0 Down Flow Csg Shut-in 0 0 0 confirmed no casing leak above p~ck,,e,r ,depth Job Summary: 1) The tubing is leaking between 700'.750' 2) The tubing is leaking right O the packer O 2000' 3) The casing is intact.- no leaks documented 4) Them were no channels documented behind the casing above 2040' Commenla annular rate too high 2500 bpd lowered annular ate annular rate too low inerealed annular rate ;La estimated flow detected NQ Interpretation UNOCAL U~U~flL fl~l ~H~ bKY I"HA llg. UU{~"OOIO~ I. uu/uu Log Date i .:0~,-/'eb-1998 SWANSON HXVER SRU 3~-~S WD . JlJ JJ[ [ I J2 II II1 I II I I I IIIIII II I . I I . Job Results: Unocal Well #: SRU 32-33 WD OD ID wF'~L Tool ' '1.8, - 7" Casing 7 6.366 Flow Areas O,D, I,D. bpd/lpm "inside tubtn9 '21992 " 1.69 8.53 tubing - 7' ann. 6,366 3.5 39,59 7' - OH ann. 8,5 7 1 32,55 Unocal SRU 32-33 WD WFL FPM 2 250 too fast too fast 3 250 too fast 10,3' 4 1000 0 0 5 1000 ?? 3,5 9 2020 0 0 lO 1990 2,3 0 11 750 2.3 0 12 500 too fast 28 13 600 too fast 30,6 14 700 too fast 33.2 68.4 Up Flow ? Up Flow 0 Up Flow 0 Up Flow 0 Up Flow 0 Up Flow 0 Up Flow 2g.? Up Flow 33,2 Up Flow 31.9 Up Flow app~x, -d'~tector I fpm limits 1 ~t, 1-30 2 It, 2-60 6 It, 7-180 t6 :. 16-t50 20 , 22.600 .... Remarks Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing Csg Flowing BPD 584 2706 2226 88 408 335 0 0 0 30 13g 114 0 0 0 20 91 o 20 91 75 253 111'6 967 261 1211 996 27'2 1263 1038 Results indicate tubing leak between 700' & 750', smaller leak fight above the packer, no channelling ....... ,tmh I I · 11 rill IIL / I~ 16 2040 0 0 0 Up Flow Csg Shut-in 0 0 17 1980 ?? 0 0 Up Flow Csg Shut-in 0 0 18 700 0 0 0 Up Flow Csg Shut-ilq 0 0 Res~.!lts indicate no casing leak above packer depth, oonfi_r_m, qd no ..o. han.._n?!li_.ng .b..ehind casing above 2040!~ 21 . ~00 0 0 c~ ,r Down Fiew csg Shut,in. 0 0 22 900 0 0 0 Down Flow Csg Shut-in 0 0 23 1950 0 0 O Down Flow Gag Shut-in 0 0 Results confirmed no casing leak. above packer, dap!h,, ......... Job Summon/: 1) The tubing Is leaking between 700'-750' 2) The tubing is leaking dght O the packer @ 2000' 3) The casing is intact · no leaks documented 4) There were no channels documented behind the casing above 2040' Comments annular rate too high 2500 bpd lowered annular rate annular rate too Iow Increased annular rats 2,3 estimated flow detected NO Field Recording Spud: 5 25 81 Completed: 5/29~81. _ Lost Workover: 3?24/95 SRU 52-35WO Swanson River Field APl No.: 50-15~-20557-00 0.0- 90.0' 10 3/4" OD CS(; Driven 90.0 - 90.0' SHOE .. 0.0 - 2499.0' 7" OD 23.00~/ft K-55 SURF CS(:; 2450.0 - 2499.0' CEMENT PLUG 2499.0 - 2499.0' SHOE KB ELEV: 172' PBll): 2450' TD: 2499' Top of In ect on Zone: Ft. Angle @ Perf's: 0 Degs. Honger: VE-[CO GRAY 18.0 - 18.8' 7.00" OD 2.992" ID HANGER Vetco Gray Hgr. 18.8 - 19.3' CROSSOVER 3 1/2" EUE.. x 3 1/2" BTC. 18.8 - 2056.4' 3.5D0" OD 9.2Dt~/tt N-80 TBG 1967.3 - 1996.8 - t997.3 - 2003.5 - 2045.8 - 2055.4 - 2056.4 - 2100.0 - 1968.7' 3.937" OD 2.81" ID NIPPLE Otis "X" 1997.3' CROSSOVER 3 1/2" lORD. x 3 1/2" BTC. 2DD3.5' 5.968" OD 3.00" iD RETRV. PACKER Boker FHL Pkr. W/40K Sheor 2003.9' CROSSOVER 3 1/2" lORD. x 3 1/2" BI'C. 2047.2' 3.937" OD 2.81" ID NIPPLE Otis "X" 2056.4' CROSSOVER 3 1/2" BTC. x 3 1/2" EUE. 2057.0' 4.250" OD 2.992" ID SHEARSUB Boker Sheor-Out ~V/Boll Seo[ 2228.0' PERFS 4HPF, 128', 8/19/81, 9/85 2234.0 - 2278.0' PERFS 4HPF, 44', 8/19/81, 9/85 231§.0 - 2424.0' PERFS 4HPF, 108', 8/19/8I, 9/85 Woter Disposol Well ! Unocal North Americar/-~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL June 6,1995 Alaska Region Mr. Blair Wonzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wonzell: With reference to a conversation I had with Joan Miller, Ms. Miller expressed concern over an open 10-403 Sundry, Approval No. 93-321, for SRU 32-33 WD (Swanson River Field). In November of 1993, plans were to work over SRU 32-33 WD water disposal well. This work was postponed. Unocal worked over the well in March 1995 under Sundry, Approval No. 95-049. A 10-404 Report of Sundry Well Operations was submitted on 4~25~95 to report on this work. Unocal is hereby sending the 10-404 Report of Sundry Well Operations showing cancellation of work permitted under Approval No. 93-321. This should close out all the sundries for SRU 32- 33 WD. We apologize for any confusion we may have caused you. If you have any questions, please call me (i~ 263-7676. Sincerely, G. Russell Schmidt Drilling Manager GRS/leg ~-~../--,, STATE OF ALASKA .,-."--,, AI.A~ OIL AND GAS CONSERVATION COMIV,~ !ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutd°Wn __ Stimulate Pull tubing _ _ Alter oasing__ __ Plugging _ _ Perforate _ _ Repair well _ _ Pull tubing _ _ OtherX_ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Development Exploratory __ .Stratigraphic__ Service X Location of well at surface 187' South & 2010' West of NE Corner of Sec. 33, T8N, R9W, SB & M 6, Datum elevation (DF or KB) 172' GL 7, Unit or Property name Swanson River Field 8. Well number SRU 32-33WD feet At top of productive interval Same At effective depth Same At total depth Same ORIGINAL 9. Permit number/approval number 80 - 115/93 -321 10. APl number 50-133-20337 11. Field/Pool Sterling 12. Present well condition summary Total depth: measured true vertical 2520 feet 2520 feet Plugs (measured) 2450 Effective depth: measured true vertical 2450 feet Junk (measured) 2450 feet Casing Structural Conductor Surface Length Size Cemented Measured depth True vertical depth 80' 10-3/4" No 80' 80' Intermediate Production Liner Perforation depth: 2499'. 7" 700 sx@2499' 2499' 2499' measured 2100'-2228'; 2234'-2278'; 2316'-2424' true vertical 2100'-2228'; 2234'-2278'; 2316'-2424' Tubing (size, grade, and measured depth) 3-1/2" 9.3# to 2019' R£¢EIV£D 13. Packers and SSSV (type and measured depth) Baker FH Packer @ 2019' Work proposed and approved per approval number 93-321 cancelled. JUN 1 4 1995 Stimulation or cement squeeze summary Alaska Oil & Gas Cons. Commission Intervals treated (measured) N/A Anch0r~ ;~ Treatment description including volumes used and final pressure N/A 14. Prior to Well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A N/A Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations x _ Oil_ _ Gas _ _ Suspended _ _ 17.1 hereby certify that the fei ~g ,~l~'u~ ~d c.o~ ~:~/Uo the best of my knowledge. Signed G, Russell Schmidt ~~-V~Title Drilling Manager Form 10-404 Rev 06/15/88 Service Salt Water Disposal Date 6/12/95 SUBMIT IN DUPLICATE ,~'~-~ STATE oF ALASKA ~ ,,_ .,~KA OIL AND GAS CONSERVATION CC, ..... ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing _ _ AJter easing Plugging _ _ Perforate _ _ Repair well X_ Pull tubing _ _ Other_ _ 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of Well: Oevek>pment _ Exploraton~ __ Stratigraphic__ Service X_ Stimulate Location of well at surface 1875' South & 2010' West of NE Corner of Sec. 33, T8N, R9W, Si3 & M At top of productive interval Same At effective depth Same At total depth Same RECEIVED 12. Present well condition summary Total depth: measured true vertical Alaska Oil & Gas Cons. Commission 2520 feet 2520 feet 6. Datum elevation (DF or KB) 172' GL 7. Unit or Property name Swanson River Field feet 8. Well number SRU 32-33 W~ 9. Permit number/approval number 80 - 115/95 -O49 10. APl number 50-133-20337 11. Field/Pool Sterling Plugs (measured) 2450 Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2450 feet Junk (measured) 2450 feet Size Cemented Measured depth True vertical depth 10-3/4" Driven 80' 80' Intermediate Production 2499' 7' 700sx@2499' 2499' 2499' Liner Perforation depth: measured 2100'-2228'; 2234'-2278'; 2316'-2424' true vertical 2100'-2228'; 2234'-2278'; 2316'-2424' Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 Butt w/AB mod @ 2057' Packers and SSSV (type and measured depth) Baker FHL Packer ~ ~ ' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including VOlumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut in 6363 95 Tubing Pressure 790 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run__ I Daily Report of Well Operations x Oil Gas Suspended _ _ Signed G. Russell Schmidt-'Ha-b~_~~,~-v~'"~itlet ~' ~ wt-~'--~ Drilling Manager Form 10-404 Rev 06/15/88 / - Service Water Disposal _ Date 4/25/95 -SU~B-I~IIT IN DUPUCATE Spud: 5 25 8i C~)mp. leted: 5/29/81, Lds[ Workover: 3/24/95 SRU 52-55WD SwonsOn River Field APl No.: .50-153-20357-00 0.0 - 90.0' lO 3/4" OD CSG Driven 90.0 - 90.0' SHOE 2450.0 - 2499.0' CEMEN'i' PLUG 2499.0 - 2499.0' SHOE KB ELD/: 18' PB!D: 2450' TD: 2520' Top of tn edon Zone: Ft, Angle @ Peff's: 0 Hanger: VETCO ~el~ 18.8- 2056.4' 5.500" OD 9.20t,/H N-80 TBG 18.0 - 18.8' 7.00" OD 2.992" ID H,~OER Vetco gr~/Hgr. 18.8- 19.3' CROSSOVER 3 1/2" EUE. x 3 1/2" BIC. ~a~'-, ', - ,q~:o-,,-,,~,?,, ,n NIPPLE ~is "×" .,,,;,,,, ,..,,,;,,., ,,.,,.,,, OD 2.g1" ,,, , 1996.8 - i997.5' CRO~OV[R 5 1/2" lORD. x 51/2" BIC. 1~7.5 - 2005.5' 5.~" OD 5,00" ID REIRV, PAC~ BoRer FHL Pkr..!/~ Shear 2005.5- 2005.9' CROSSOVER 51/2" lORD, x 51/2" BTC. 20.56.4 - 2057.0, 4.250" OD 2.992" ID SH~RSUB Boker Sheor-Oul W/Boll ~t z2 4.o - 2 8.o' PERFS ,,HPF, /ss 2516.0-24-24.0' PERFS 4HPF, 108', 8/19/81, 9/85 RECEIVED MAY - 5 1995 Alaska Oil & Gas Cons. Commission Anchora ~' Wa(er Disposal Well SCU 32-33 WATER DISPOSAL DAY 1 (3/17/95) 10-3/4" @ 80' 7" @ 2499' LEASE H20 D.C. $ 28,620 CUM: $ 28,620 AFE: $ 190,000 AFE #752504 U.O. 100% WO REPAIR PKR LEAK TIME REQ'D: 4 DAYS COMPLETE TURNKEY MI/RU. INSPECTED RIG. ACCEPTED RIG @ 1800 HRS. MARCH 21, 1995. RU TO 7" CSG & 3-1/2" TBG. PREP TO CIRC WELL THRU PACKER LEAK @ 2086. WELL COMPLETELY DEAD. CIRC LEASE H20 @ 800 PSI 3 BPM. DAY 2 (3/18/95) 10-3/4" @ 80' 7" @ 2499' LEASE H20 RU HOWCO. TEST LUB. TO 1500 PSI. RIH SET TBG STOP @ 2000'. TEST TBG TO 1400 PSI. RECOVER PLUG. SET PLUG @ 25'. ND TREE. NU BOPE. ATTEMPT TO TEST STACI~ GETTING FLUID BYPASS. RECEIVED PERMISSION FROM BLM TO DELAY FULL STACK TEST. RIG ON DOWNTIME. PULLED PRK LOOSE 14K OVER STRING WT. R/U TO PULL 3-1/2" BUTT TBG. DAY 3 (3/19/95) 10-3/4" @ 80' 7" @ 2499' LEASE WATER CONT POOH W/OLD COMPLETION. INSTALL TEST PLUG. TEST BOP'S REPAIR SEVERAL LEAKS. RIH W/6" BIT ON 3-1/2" DP. CLEAN OUT FILL FROM 2191' TO 2450'. POOH L/D DP. RECEIVED MAY - 5 1995 Alaska 0ii & Gas Cons. Commission Anchora ~P DAY 4 (3/20~95) 10-3/4" @ 80' 7" @ 2499' LEASE WATER FINISH RUNNING COMPLETION, DISPLACE WELL W/INHIBITED PACKER FLUID AND FREEZE PROTECT W/DIESEL SET PACKER. PERFORM MECHANICAL INTREGRITY TEST TO 1500 PSI FOR 30 MINS. PERFORM INJECTION TEST 2.6 BPM ~ 700 PSI. AOGCC & BLM BOTH WAIVED WITNESSING. MIT. NID STACK. NIU TREE, TEST TREE TO 3000 PSI. RELEASE ALASKA WELL SERVICES RIG #5 AT 2000 HRS ON MARCH 24, 1995. FINAL REPORT. ,6 H0N 12:35 UNUUAL - i~NUMUKHUl: rnn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMraleSION APPLICATION FOR SUNDRY APPROVALS 1. Type or requss{: ^ban~'~ _ _ ' Sus'pemJ"~_ ' bperat/one ,hutdown ~_ Re-enter ,U,l~nded well_... --Alter cuing..__ Repair well _. RuggJng __ ' Time extortion,._ 8t~mulate -.. Change approved program -~ Pull tubing X Vmianoe Pjd'ornte ..... 2'"~. Name of Operato~;' _U~NION oIL ,OOMPA,N.y OF GAL!?ORNIA [UNOCAL).. ,,t. Address P.O. BOX 196247 ANCHORAGE, AK 99519 ,, 5. Type of Well: F. xelo~tory --. SuatiSt~phle .-.. 6.-D'~tum elevation (DF'O~· KB) 7. Unit or Property name Swanson River Unit .. feet 4, L0cation of well at surface 1874' FNL, 2010' FEL, SEC, 33, TSN, RSW, SB&M At top of procluctive Interval Same - vertical hole At effect]va depth At total depth Same -- vertical hole 12. present well condltion summary Total depth: measured 2820' true vertical 2520' feet feet Plugs (measured) 8. Well number SRU 32-33 WD 9, Permit number -//5- hO. APl nU~nber I.50--133-20337 8ter~ln.g 2450 Effective depth: measured 2450 true vertical 2450 feet teat Junk (measured) Casing Length Size StructuraJ Conductor 80' 10--3/4" Surface Intermediate Production 2499' 7" Liner Perforation clepth: measured 2100'-2228' Cemented Measured depth true vertical True vertical depth Driven 80' 80' Tubing (size, grade, and measured depth) 3-1J2" EUE, N-80 to 2064' MO Packers and SS~V (type and measured depth) Baker FH Pkt @ 2010' MD 2499' 2499' RECEtVEg Alaska 0il & Gas Cons. 13. Attachments Description summary of proposal x _ Detailed operations program_ _ BOP sketch x _ 14. Estimated date for commencing operation !15. March 20, 1995 16. If proposal was verbally approved O11 _ _ Gas _ _ Name of approver Date approved Sen/Ice _ W,.aler Dis[x3sa_l "17. I hereby certify that the fo~o~g is ~l ~O~~e besl of my kno~edge. Sl~ned <3. Russell Schmidt/~{,,.~17 Drllflnc] Mana_qer . '- " FOR, COMMISSION USE ONLY Conditions of approval: Notify CommL~ston so representative may witness Plug Integrity BOP me~t Looatiorl clearance Mechanical Int'~rity Test.;~'~ ~-'~bsequent form required 1-'~- _~__ Status of well classification as; Suspended __ Approved by the 0rd~r of the Comm!sslo~ Form 10-403 Rev 06/15/88 Date 03/07/95 J Approval 'No. Approved Copy ORIEL SIGNED aY l~etu rq,ed.~ RUSSELL A, DOUGLA'S~' .... ~//~ /~ SUBMIT I~ TRIPLICATE d6~ HON 12:35 UNOO~L - ~NOHOR~GE NO, r', uo/u ! Top o£Fill ~} 2,1B7' SIM Swsmoa River Field SRU ~2-33W1) Ezlst~t Completion Work-over Pase: 1 i! i ..... ! .- -- i 3.1/2" Tubin~ Baker Mod FHL Packer ~ 2,026 3-1/2 Tubing x.o @ 2o~s' S-Nippl~ ~ 2,059' Pup $oint 3.1/2' Tubing Tail ~ 2,064' ?¢ds ~ 2100'-2228' Peds ~ 2234'.2278' Perf~ ~ 2316'*2424' ETD ~ 2,4~0' 29# CSG (~ 2499' TD ~ 2520' RECEIVED Alaska Oil & Gas Gons. MWD WBD.DOC . 4~ , 7, , 10. 11. 12. 13. Page: ! Swanson River Field SRU 32-33 WD Work-over: Packer Leak . . . ~ , ,. _ .Ill I Il I I I -- I [ Il Il I - -- Il II MIRU the workover rig. RU Slicklme. Set a tubing plug ~ -~ 2,000'. Pressure t~st Tubing. Verify that the well is dea~d. Install 7" 5000 psi BOPE and test to a000 psi. Attach to the 3-1/2' tubing ami pull with +/- 40,000 #. ~ should r~leaso tho packer, if this falls, rotate to tho right at~d attempt to r~lease tl~ packer. POOH and inspect the tubiog. If the tubing is reusable, use it for both the work string and comp{~ion string. RIH and clean out fill from 21715' - 2210'. Make gauge ring and junk basket nm. RIH with a new packer and the 3-1/2" ir!jection string. Iustall a tubing plug just below Iho pazker and pressure up to set file packer, Test the casing to 3000 psi for 30 mmuu:s. Install BPV and remove the BOPE, Install the tr~¢ and tes~ to 3000 psi. Release tho xvell to prodUction. Tim~: 4 days RECEIVED Alaska 0il & Gas Cons. MWD 3233PRO,DOC Sw.-~on l~er Field SRU 32.33~D Proposed Completion Work-over lo-~14" @ 3,,1/2" EUA Tubing Baker Mod FH Pa~r @ 2,000' 1 JT of 3.1/2 IZUg Tubing X-Nipple ~ 2,032' @ 2,45o' 7" 29# CSO ~ 2499' '1'32) @ 2520' 3-1/2" Pup Joint 3-1/2" Tubing Tail @ 2,050' Peris @ 2100'.2228' Perfm ~ 2234'-2278' Perfs ~ 2316'-2424' MWD WBDPI.IX~ ~3-95 HON 12:37 UNOCAL- ANCHOR~IdE FAX NO. 9072637884 P, 06/07 FILL UP LINE FLOW LINE ANNULAR BOP 11" 3,500 psi KILL LINE 3" 5,000 psi R E C E I,V E D I' PIPE RAMS 11" 5,000 psi BLIND RAMS 11" 5,000 psi DRILLING SPOOL 11" 5,OOO psi AlaSka Oil & Gas Cons. Anchorag6 CHOKE LINE HCR ~]- 3" 5,000 psi D 5,000# CHOKE MANIFOLD Manual Choke 2" 5,000# 3' 5,000# 3" 5,000-,'¢ 2" 5,000-//' 3" 5,000# O Hyd. Choke 3" 10,000# 2" 5,000# Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCAL March 31, 1994 .//5 Re: Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 Ataska Oil & Gas Cons. Commission Anchorage ( Mr. Joseph A. Dygas March 31, 1994 Page 2 . . . As was the case last year, SCU 43-4WD is not included on the proposed T A list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. j;;trulV, Dennis L. r ske Petroleum Engineer DLG:dma Attachment cc: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC 7.: /;~ ~c~~ ~T 6 Co I1jJf'C~/ ~!r- ,1;(/1 Ie. (f ~ ~ (Itf e ~~/ j, ~ /;/;cf .... lA..S y1?, r/ J a-n- s u:J" '" ~ tIV'- Jll V~Il... \~'.I j},'("j$ sa. ~£ L3<1-~ ?.' ,----=-~ {{ "t~.{1 /" ~ ----..........-. ~ :Y ../ #¿ ~ ~. 9 Attachment No. I Swanson River Field Proposed Temporarily Abandoned Wells' Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for ~ / , II i I ' iiiiii I I ii i i Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A -/~-t~ SCU 13-4 u~--I~ SRU 212-10 (~:)~SCU 34-4 L0(-o~ SRU 23-15 [e~-'~.,SCU 341-8 ~.-~o SRU 41A-15 (~--'l SRU 34-28 ~z,-~ SRU 14-22 ~-l~ SRU 43-28 ~-['~ SRU 23-22 ~o'~[[~ SRU 32-33WD/~I-~%SRU 212-27 (~--b~ SCU 243-8 ~o-l~ SRU 331-27 (a~_- 2- SRU 21-33WDa0~Z~SRU 12-15 Ioo-~&SCU 14-34 &o-q~/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' R)-IU~b SRU 14-15 SCU 13-9 (to-u~t SRU 34-15 SCU 34-9' SRU 43A-15 SCU 23B-3' %~-bb SRU 432-15 SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED , PR - 1 994 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change .Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3: · SRU 33-5' Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover. to RECEIVED tPR - 1 1994 ~s~a oIl & Gas Cons. Commission Anchorage Form 3160- 5 (JUNE 1990) UNITE,., ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPECATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas [] Well [] Well r-1 Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- - 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expire~: Maroh 31~ 1993 5. LeaSe Deelgnatlon and Serial No. 6. If Indian, Allottee or Tribe Name · ,. 7. If Unit or CA, Agreement Deeignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field ' 11. County or Perish, State Kenai, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION !-~ Notice of Intent El Subsequent Repo~ E] Final Abandonment r-] Abandonmem r-I Change of Plans !-] Recompletion r"] New Construction !'-] Plugging Back i-I Non-Routine Fracturing [-'i Casing Repair E! Water Shut-Off r"! Altering Casing El Conversion to Injection ~ Other Temporarily Abandon r'] Dispose Water Complelio~ or ~ Repo~ and Log form.) 13. Describe Proposed or Completed Operations (Clearly slateail perUnentdelaib, and glve pedirmnt ~,lndu(ing estimated dateo~stmtlngany P~'OPoeed wodc if ~ is direcUonal¥ drilled, give subsurface Iocatl(xm and measured and t;ue YmiGal del~h8 for all markem and zone pMIlnent to IMI work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit ,~ ~' * SCU 23B-3 ~ I SCU 13-4 <JI *SCU21A-4 :5 1 SCU 34-4 5' 1 * SCU 43A-4 /' -o//_-* SCU 21-8 SCU 243-8 SCU 341-8 SCU 13-9 * SCU 34-9 SCU 14-34 *High GOR wells that may be produced Intermittently. Swanson River Unit ~l SRU 212-10 ./'SRU 14-22 $ I SRU 43-28 ~os~ SRU 14-15//-~/~RU 12-15 S I SRU 14A-33 .~ SRU 23-15 ~J SRU 23-22<~-u.<~pSRU 24-33 ~u~I:,SRU 34-15:51 SRU 23-27. · SRU 32-33WD ~ ! SRU 41A-15J~SRU 212-27 SRU 21-33VVD ~ SRU 43A-15G~ SRU 331-27 ~ v~ SRU 432-15 ~ Z SFlU 34-28 ' - - and~ate~ (This space for Federal use) co~cr~ions o~ approval, if any: RECEIVED APR - 1 1994 T~e 18 U.S.C. SecUon 1001. makes it a crime for any person knowingly and willfully to make to any department or agency od' the United Sla~f~.~fl$. C0mmissio~ .fm_u~_,__~t. ~m_t_.,~nents or ~ '_~ms as to any me__~__m'_ within ils ju~cktion. *See Instruction on Reverse Side AuGhorag8 STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION CC, ,IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon __ Suspend __ Alter casing__ Repair Well X Change approved program __ 2. Name of Operator Union Oil Company of California dba Unocal 3. Address P.O. Box 196274 Anchorage, Alaska 99519-6247 Operations shutdown __ Re-enter suspended wail__ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate__ Other__ 6. Datum elevation (DF or KB) 5, Type of Well: Oevelopment --- Exploratory __ Stratigraphic 4. Location of well at surface 1875' South and 2010' West of NE Corner of Section 33, T8N, R9W, SB&M. 172' G.L. 7. Unit or Property name Swanson River Field 8. Well number SRU 32-33WD, feet At top of productive interval Same as above. At effective depth Same as above. At total depth Same as above. ORIGINAL 9. Permit number 10. APl number 50-133-20337 11. Field/Pool Sterling 12. Present well condition summary Total depth: measured 2520 true vertical 2520 feet feet Plugs (measured) 2450 Effective depth: measured 2450 true vertical 2450 feet Junk (measured) feet Casing Length Structural Conductor 80' Surface Intermediate Production 2,499' Liner Perforation depth: measured Size Cemented 10-3/4" No 7" 700sx @ 2,499' 2,100'-2,228'; 2,234-2,278'; 2,316'-2,424' true vertical 2,100'-2,228'; 2,234-2,278'; 2,316'-2,424' Tubing (size, grade, and measured depth) 3-1/2", 9.3# to 2,019' Packers and SSSV (type and measured depth) Baker "FH" Packer @ 2,019' 13. Attachments Measured depth True vertical depth 80' 80' 2,499' 2,499' RECEIVED NOV Alaska 0ii & Gas Cons. Commission Anchorage Description summary of ProPOsal X__ Detailed operations program__ BOP sketch X 14. Estimated date for commencing operation Jl 5. Status of well classification as: December 15, 1993 16. If proPOsal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Salt Water Disposal Well _ 17' I her "~' ce7 t~'ai(~ f°~g~nc~~nd c°rrect t° the'~ ' ~ ~,.t(,.L.,~C.,, best of my knowledge. Signed /~, I.-.'-,J¢¢u',-& J~-v,~--..c.,vJ~ Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Mechanical Integrity Test~/,~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance _ -- Subsequent form required 10- Original Signed By Oa,/Jd W.-Johnston JApproval No~:;;~._ .~. 2./ Approved Copy Returned [/- ~y....~. "~ CommissiS.n_er' D~i~ ~//-,. ~./'~-.~ I SUBMIT IN TI~,PE(~ATE Swanson River Field SRU 32-33WD Workover Proce&we I II III IIIII 1. Rig up electric line and jet cut tubing O 2,000'. 2. Kill Well. Set BPV 4. Nipple down tree and nipple up B.O.P. Test B.O.P. to 5,000 psi. 5. POOH with tubing and fish top packer. 5 5 RIH with completion string Pressure test tubing/casing annulus to 1,500 psi. 5 10. In~all BPV; nipple down B.O.P. Nipple up tree; pressure test to s,0oo psi. Release Rig. RECEIVED t~OV ~ 8 199,~ Oil & Gas Cons. Commission A~chorage SWANSON RIVER FIELD WELL # SRU 32-33 WD PROPOSE~ 11/16/93 10-3/4" ~ 80' 3-1/2" DSS HTC IPC N-80 TUBING 7" K-55 ETD AT 2450' 7" ~SING AT 2499' BAKER "SAB'3" PACKER ~ 2000' "X" TYPE PROFILE PEEFO~T~N$ 2100'-222,8' PERFORATIONS 2234'-2278' PERFORATIONS 2316'-2424' RECEIVED TD AT 2520' NOV 0ii & Gas Cons. Commission Anchorage · · o TOP PLUG Z4SO' ~9. asao' .' · WOIIKOV~R RECEIVED NOV 1 8 Oil & Gas Cons. Commission Anchorage. SRU 32-33 W.-D.':. CASING & TUBING DETAIL .i l!~.. SE:CTION $$ T. BNq IIl. tW.' SId:- · ,,.,4, ..,,.- · . .:-r~~.' "4bi '~ "'"".' H :-U S.A.'-tNC.-'..<',~ Contract Exhibit E OPTION I FILL-UP KILL LINE ( 3 FLOW 1 ANNULAR BOP 10" 3000 psi I I PIPE RAMS 10" 5000 psi BLIND RdMS 10" 5000 psi [~] | DRILLIN~ t ~ SPOOL ~ :~> u/~~0" 5000 p~~ 3" 5000 psi t~ I1 3" 5000 . I 10" 5000 psi I CHOKE psi LINE~ BOP STACK 10" 5000 psi RECEIVED NOV 1 8 0il & 6as Cons. Commission Anchorage Alaska Region Unocal North Americp'-~ Oil & Gas Division Unocal Co. ration P.O, Box ~190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) March 24, 1993 COMa .... ~OMM COMa II RES ENG "~,1~ ~-R ENG SE ENG I'- ENG--AssT-'I' _ ~NG ASST SR GEOL -G-ECL ASSTI ¥3EOL ASSTI ~TAT TECHI -~TAT TEC'H ~,-~--! FILE -- Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S~ans0~,_..~.~iver:~EielcL Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to complY with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment I lists the .proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIV'ED MAR 2,5 199; Alaska Oil & Gas Cons. Com~tSSiOn Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the prOposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED Alaska 0il & Gas Cons. C0mmissio~ :Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name SUBMIT IN TRIPLICATE I. Type of Well IX']Oil Gas Well rX] O Other Well 2. Name of Operator Union 0il Company of California (dba Unocal) 3. Address and Telephone No. P. 0. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit 17 wells Soldotna Creek Unit 14 wells (907) 276-7600 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. !0. Field and Pool, or Exploratory Area Swanson River Field I I. County or Parish, State Kenai, Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA [-~ Notice of Intent I-"] Subsequent Report ~='=] Fi~ Abandonment Notice {~{ Abandonment r"'] Recompletion O Plugging Back g C. asing Repair f~ Al~rinS Casing [[] O~r Temporari 1 y Abandon O Change of Plans O New Construction O Non-Routine Fracturing O Water Shut-Off O Conversion to Injection D Dispose Water {Note: Report resuhsof multiple¢ompletionon Well Completion or Recompletion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit Swanson River Unit SCU 21-3 SCU 21-8*/°~ SRU 212-10 SCU 23B-3!/ SCU 243-8~ SRU 14-15' SCU 13-4 ~ SCU 341-8~ SRU 23-15 SCU 21A-4 SCU 13-9/ SRU 34-15 . SCU 34-4 y SCU 24A-9~ SRU 41A-15 SCU 43A-4 SCU 34-9'g SRU 43A-15 SCU 33-5~ SCU 14-34v' SRU 432-15 SRU 14-22 SRU 23-22~' SRU 23-27 ~ SRU 212-27~ SRU 331-27 SRU 34-28~ SRU 43-28 v SRU 14A-33~ RECEIVED AR25199 Naska 0ii & Gas Cons. ~0~m~,or * High G0R wells that may be produced intermittently. 14. I bereby certify that~f°reg°ing~l~'e/~J~- 'c°~rrec~t'.')~ ~ Petroleum Engineer . - ,,/?/ ./ ~ ~ for F~ or S~ o~) Anch0raga Approved by Title Date Conditions of approval, if any: Tide 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any deparUnent or agency of the United States any false, fictitious or fraudulent statements · See Instruction on Rs~erae Side Attachment No. 1 Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Shallow Gas Potential Hemlock Future Shallow Gas Producer Rate Potential P & An~ and 'Hemlock Only' P & A Producers with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8' SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33(2~ 5 Wells {1! Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 (2~ Scheduled 'Hemlock Only' P & A in March-April, 1993. ' High GOR wells that may be produced intermittently. t ECEiVED Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. · SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: · SRU 12A-4: · SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECE[VE.D MAR Alaska Oil & Gas Cons. 6ommiSs~,o~' Anchorage ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 cOMM do~ J Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject:. 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: · Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEO ~ 1 199t Alaska Oil & Gas Cons. CommiSSiOn Anchorage Mr, J. A. Dygas Page 2 December 27, 1991 Shut-in wells until field bloWdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in 'which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye,ar's TA list were moved into this category. Attachment 2 .gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J[ C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment CC:. L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation Alaska Oil 8, Gas Cons. Com~ss'~o~ Anchorage Form 3160-$ (November 1983) (Formerly 9.--331) UNITED STATES (Othee lutraeflon~ oB D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON ~LLS not ~ tbl8 ~orm for pm~is to drUI or to d~a or plug beck ~ · ~Eenat tmtvolr. UM -~P~CATZON ~R PERMIT~" for .u~ Il&ill ARCO Alaska, Inc. 3. AOOn~tl O]j Offnn& P.O.Box 100360 Anchoraqe,.. AK 99510 · t. cocA?toIl of wmcf, (Report Ioeatloa clearly end Ia ACCOrdance with tn7 Sta~e requlze~--entLe See also space IT below.) Form approved. Budget Bureau No. 1004-013:5 Expires Auipast 31. 198S ~. LI411 O#lO.ql&'r/OII SlID llfl~L ]JO. O. I1' llOlil, ALLO~II OI Tllll NiMI Soldotna Creek/Swanson Rv I. fi&SM OB L~&II l&ill O. WBLL Iio. 10. IIILI i~ID POOr,, Ot WILIM:&~ At Swanson River Unit 19wells Soldotna Creek Unit ...... 13 wells I Swanson River Field .. Kenai Alaska 16. O~eck Apl:~op-ate Box To Indicate Nature oF Notice, Report, or Other Data · (Othe,) TemporarY Abandon "1-'~. Di;SCIial; I'ROP~BIO OI COMPLEX~D OPBRATiON~ (Clearly state all ~rtlnf, t detalia, and give ~rtlnent dat~ ln~ud~ mflml~ ~M ~.l~ HF p~ worL 'H ~i b di~Uo~ d~U~ give o~~ ~uns and meaour~ mad t~e yertl~ de~ foe ~ medea ina Mum ~m- As d~ in the attached memo, ARCO Alaska, Inc. r~uests that the following wells, have a temporarily abandoned status: $oldotna Creek Unit SCU 2315-3 SCI3 21-8 * SCU 12A-4 SCU 341-8 SCU .13-4 SCU I3-9 SCU 21A-4 SCU 24A-9 SCU 34-4 SCU 34-9 SCU 43A-4 SCU I4-34 SCU 33-5 Swanson River Unit SRU 212-10 SRU 21-22 SRU 14-15 SRU 23-22 SRU 23-15 SRU 23-27 SRU 34-15 SRU 212-27 SRU 211-15 SRU 331-27 SRU 41A-15 SRU 34-28 SRU 43A-~5 SRU 43-28 SRU 432-15 SRU 14A-33 SRO 32-33WD DEC 3 1 1991 ~1,, ,_ '~,,=S~a O# & Gas Cons. Con]mi. ..... ,vj a!~~ * -High GaR wells that may be produced intermittently. 18. I hereby certif~t-the foregoing Is trde and correct TITLE Actinq Reqional Eqqineeroa~ (Thio spice for Feasts& or State oace uae) APPROVED BY CONDITIONS OIP APPROVAL. IJ' ~: TITLE D&TB · t- _ m .... -, ..... O ..... Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A SCU 12A-4 SRU 212-10 SCU 14-34 SCU 13-4 SRU 211-15 SRU 23-27 SCU 21A-4 SRU 23-15 SRU 14A-33 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 32-33WD / .~..-/ .......... ~ rn Wells 9 Wel~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i~:i:~:~:i:~:i:i:i:i:i:i:~:~:i:i:!:i:i:i::~..:~:~:i:i:i:i:i:!:i:!:i:i:~i~:i:..`.~:i:i:~:~:i:i:i:i:i~:i:~:i~i:~:i:~:i:i:i:i:i:i:~:i:~:i:i~i:i:i:i::~:i:~:i:i:~:i:i:i:i:i:i:i~i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:~:i:i:i:~;i:~:i:i:i~.:i:!::;i:i:i~i~i:i:i:i:i:i::;~:i:i:i:i::.!:i:i..i:i:i..~i SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) DEC 3 1 lgg! Alaska Oil & (~as Cons. Commissi~. Anchorage Added to 1992 Temp.0.rari!y Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, maybe produced intermittently, otherwise shut-in until blowdown. · SCU 12A4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, $RU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 SwanSon River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCL/ 434WD: This water/mud disposal well is a standby well and is only, used on an 'as needed' basis. RECEIVED DEC 3 1 199l ~/aska Oil & (Jas Cons. uommJssio~, Anchoraae ARCO Alaska, Inc. Post Office b,.x 100260 Anchorage. -.' ias~,a ~95 ;.0-0360 Te,ecnc?e ~07 2-~. ' Z'.' ~ December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Mana~ment 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice'requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of-Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted fi.om the temporarily abandoned status (Reft your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment CC: :C. V. Chatterton, Chairman AOGCC A. R. Kukla, Marathon Oil Company S.W. 'Ohnimus, UNOCAL Corporation RECEIVED D C2 1989 Alaska 0il & Gas Cons. Commissic Anchorage FQrm 3160--5 (Novmnirmr 1983) (Formerly 9-331) TED STATES RTMENT (o~m ,.~.., o. rs. DEPA OF THE INTERIOR BUREAU OF LAND MANAGEkiENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ thio rom toe protx)~lo to drill or to deepen or plug b~et to · 41forsat rswrvolr. Uso -AppLICATION IPOR PERMIT--" for sums 9rOlm~m.) I. N&BII Of OPRB.&TOI ARCO Alaska, Inc. 3. &DDLS81 of OPBIA~"OR Post Off i'ce Box 100360 Anchroage, AK 99510 4. r. OCATZO~ 0f ~'ELZ, (ltetmrt locattoa clearly and tn accord&a~ with Ray scar~ requirement&* Form approved. Budget Bunma [qo. 1004--013S Exl)tna August 31. t9~5 ?. [;III AOUIMBaV N&&IB oldotna_.CreekZwanson Htv~r units XO. fVeLD &HD POOL, OS WILOC&'r See also space 17 below.) At surface Soldotna Creek Unit - 11 wells Swanson River Unit - 20 wells jIS. IL,SY&TIONS ($ho1 wbetiXr DP. rr, GL I~d.) .~w~nSOn I~iv,~ Field Kenai I Alaska Check Aoproo-ote Box To lndicote Notun of Notice, Report, or Othr Dca NO~ICB Of I~qTI#TIOII TO: ?SIT wA'rn ,B,~, ~ ,C~ OB &~TIR C.,Sl~G 8~T OI ACID~ J~J Ai&N~N° (Other) Temporar i [ y abandon I7. u~.sr~ln£ ['~Of*OStD aa CO.~IPLgTED 0PEaAT10.~S (Clearly state all p4, rttue. C detail,, and ~tve pertinent' dates, Ineludllq~ estimated data of itm*tlz~ &ur ~roi2°=cd work. If weft is dirKtion&Zl), drilled, give subiurYm kzestiuas ~nd aeRo, red and true vertical deptlm to~ ALI Barters ud ~oal pent- aertG *.o dais work-) · As described in the attached memo, ARCO Alaska, Inc. requests* that thc following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 31A-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVEC Alaslca OJJ & Gas Co~$. Anchorage 18. Z here. cerUry r. lz~t tile fore~oU~ ts r~de and correct Cook Inlet Enginerring Manag~z~ /z-z~-~ (Thio ipi~ for APPROVED BT CONDITIONS Of APpROVA/~ I~ ANY: TITL~ DATB "See Inm'Ktiom on Renne Side Title 18 U.S.C. Section lOOt, makes it a came for any person kflo~mgly and willfully to make to any department or agency of the United States day false, f~ctttzous or frauduien,, statements or representa~on$ aa to iffy matter wtthtn tis Jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate Potential Wells being evaluated for P&A/Future Utility Wells SI for Inefficient Production Wells SI until Blowdown 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 L4. 3 ..... 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 ._ SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Teml/orarily Abandoned Status: S. CU 21A-4' Well is temporarily abandoned due to inefficient pro~d~_ (high GOR). ~ SRU 32-33 W D): Well is temporarily abandoned due to annulus ~..communication./.~roblems. Removed from 'Temporarily Abqnd~,ped Status: $CU .243-8' production. This shallow sands gas well has been returned SCU 13-9' A workover is planned for this well which will enable this well to be returned to an active status. .SRU .21,2-10,: This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. SRU 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED D[C2 1989 Alaska Oil & Gas Cons. Commission /~chorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* ~,CU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned Alaska Oil & ~as Cons. Commi · AnChOrage For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures February 7, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notice for SRU 32-33WD Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perform a mechanical integrity test on SRU 32-33WD. This test will be conducted as per Rule 6 of the Swanson River Field Area Injection Order No. 13. To verify integrity, we' propose to pressure test the tubing x production casing annulus to 1,500 psi. If SRU 32-33WD passes this test, we plan to return this shut-in well to water injection. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Carol Baker at 263-4643. Sincerely, T. S. McCorkle TSM:CMB:ch:0013 cc: G. ~ Graham A. R. Kukla UNOCAL Corporation Marathon Oil Company RECEIVED FEB 1 AlaSk~ Oil & Gas Cons, Commission Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6279 STATE OF ALASKA ~ AL,-,,.,KA OIL AND GAS CONSERVATION COMMI,.,,.ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate Change approved program __ Pull tubing __ Variance __ Perforate __ O'~'r X__ M I T 2. ,N,.,a~m,.,e cftC, per,ator /~I~L,U /~ I aSKS, I nc. 3. Address 4. Location of well at surface 1874' FNL, 2010' FEL, Sec. At top of productive interval Straight hole At effective depth Attotal depth 12. Present well condition summary Total depth: measured 5. Type of Well: Development Exploratory Stratigraphic ~ Service pt 33, T8N, Rgw, SB&M 6. Datum elevation (DF or KB) 7. Unit or Property name Swanson River Field 8. W~?jur~r 33WD 9. Permit number feet 252O Effective depth: Casing Conductor · Production ~:~X Perforation depth: true vertical measured true vertical Length 252O 245O feet feet 2450 feet Plugs (measured) feet Junk (measured) 10. APl number 50-- 133-20337 11. Field/Pool Stet I ing Size Cemented Measured depth True vertical depth 80 ' 10-3/4" dr i yen 80 ' 80 ' 2499 ' 7" yes 2499 ' 2499 ' , measured 2100 - 2228' MD, 2234 - 2278' MD, 2316 - 2424' MD true vertical Tubing (size, grade, and measured depth) 3-1/2" EUE N-80, tbg to 2019' Packers and SSSV .(type an¢ measured depth) Baker 'FH' pkr e 2019' MD MD FEB 1 Al~tska 0it & 6as Cop,:, C0mmissio~ AnnhnmnP. Detailed cperations program ~ BOP ske~h 13. Attachments Description summary of proposal X_.. 14. Estimated date for commencing operation February, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Service Gas __ Suspended Water Disposal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢,~./~~ Title Cook Inlet Engineering Mgr. FOR COMMISSION UsE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ B(~P/Test __ Location clearance __ Mechanical Integrity Test (,,~.. Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissioner LONNIE C. SMITH .... ~;urnmissioner I Approval No. ~ .-- / Oc~- Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SRU 32-33 WD Mechanical Integrity Test SR 27 Objective: To verify the mechanical integrity of SRU 32-33WD (per AOGCC regulations) prior to returning this well to injection. Well Data: Tubing: Liner: Capacitln Current Pressures: 3-1/2" EUE to 2,019' MD 7", K-55, 23# Tbg x PC = .0275 Bbl/ft. Tbg=0psi; PC=0psi Note: Verify that Sundry has been approved prior to performing test. Procedure: 1. Shoot FL's on the PC and tubing. Calculate needed load volume for annulus. 2. Hook up a two pen recorder to the well to record tubing and PC pressures during test. 3. Load the annulus, as needed, using inhibited lease water and topping with lease crude. Do not exceed a 2,000 psi surface treating pressure during pump in. Monitor rates and PC and tubing pressures throughout job. Bleed off PC pressure as needed. NOTE: 48 hours prior to initiating pressure testing, contact the AOGCC (279-1433) and the BLM (267-1240) informing them that the test will be conducted as per Rule 6 of the Swanson River Field Area Injection Order No. 13. 4. Pressure up PC to 1,500 psi. Hold for 30 minutes. Note initial and final pressures on PC and tubing. 5. When testing is complete, bleed-off PC pressure without producing liqUid. 6. If the pressure test was successful (i.e., did not bleed off more than 150 psi in 30 minutes), return well to water injection. . Carefully monitor PC pressure as well is returned to injection to verify that there is no annulus communication. ~ ~ C E IV [ ~ ARCO Alaska Inc. is a subsklla='y of Atlantic Richfield Con. any AR3B-~OO1-A FEB 1 ,~ '""" . ^lasl.,:a 0ii a .'.~::,::, Cor',~. Commission Anchoiaga E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead : : t,ee' TOP PLUG 24S0' · ' WOItCOV~R f~-d~ " SR U 3Z- 33 W.~.'. CASING & TUBING DETAIL '~ ._'.. SECTION 33 T. 8Nq R. BW.' S~ . ,. ~ '- o .. ~,. :,.=-~ .-..~..~:.~.~ · -.'.¥..rur.e~d ':_',, · STATE Of ALASKA ALA~_ A OIL AND GAS CONSERVATION CON ;SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. Feet 3. Address 6. Unit or Property name Post Office Box 100360 Anchorage, AK 99510 Swanson River Field 4. Location of wellatsurface Sec. 33, T8N, R9W At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical See attached schematic feet Plugs (measured) feet 7. Well number SRU .Z~- 33WD 8. Approval number 7-795 9. APl number ~ ~:~ ~.~ ~ 7 50-- 133-D~Yt6~O 10. Pool Ster I ina Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True Vertical depth true vertical RECEIVED Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) JAN 2 2 ~,laska 0il & Gas Cons. Commission Anchorage , 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 R~i~] 12-1-85 Title Manager, Cook Inlet Engineering Date Submit SUBSEQUENT REPORT PRESSURE TEST SRU 32-33WD Attached is the Well Service Report which documents the production casing pressure test on water disposal well SRU 32-33WD. The well was tested on 10/28/87 in accordance with Rule 6 of the AOGCC Area Injection Order to a test pressure of 1500 psi. The SRU 32-33WD did not meet the criteria of Rule 6 which states that there cannot be more than a 10% decline in the test pressure over a 30 minute period. Repairs were completed and the well was retested on 12/16/87. The SRU 32-33WD held 1500 psi (within 10%) for 30 minutes. RECEIVED JAN 2 2 Alaska 0il & Ga8 Cons. Commission Anchorage ~! RECEIVED Alaska Oil & Gas Cons. Co[llf'nlssJol~ Anchorage I ' · · ILO0' i ~o · I o I I · I I . b · , Ills TOP PLUG 2450* 2520' . .. ~. .... ~ - . . . CASING 8, TUBING DETAIL S£CTION 33 T. 8N., R. SW.' SM,~_- . .. ,?...-... :..~,~; -::,,-q~: .-..'.:'_.l~,,e,,~,/.; :'.,, ~, , .':'.;,,k':'~-'.~;:.~ ~ JAN-12-~88 11:~9 ID~ANSON ARCO Alaska, Inc. ,~,ul~ldl~,~ Ot~ AttAnli¢ I:lichfi~ld COmpany WELL J PBDT CONTRACTOR RE'--~IARKS TEL N0:1383~, JFIELD-DISTRICT-$TATE IOPERATION AT R£F~RT TIME ~629 P02 ......... WELL SERVICE REPORT DAYS f"[- ~"E-6K' +HIS BLOCK IF SUMMARY CONTINUED.ON BACK ..... -'"~- ~ ' -- ] ....... ~'- -; '.-;-:-'- ~ ' .... i ........ KI:LEI V EtJ ... Alaska Oil & Gas' [;ohs: Uomm]~slon Anr. hnm?. AIASKA OIL AND GAS CONSERVATION ~SSION MECHANICAL ~TY TEST Date: /~- /~-. ~7 Company: .... *P *I TY~E OF PKR CASING TBG REQ TBG , TIb~. TIME TIME W~3. *S --- ANNULUS TVD SIZE/WT/~E SIZE TEST CSG TBG TBG 113G C~ ~I'! ~I FI.IJID 1~ PRESS PRESS' CSG CSG CSG , PRESS PRESS i. PRESS I I I I I I I , I I . I I Il Ill '. " ' ." ', .... ' ' · i i i Il I I I I I I I I I I Il I II II , , · i II II I II II II I [ I - -- II I -- II I II III I Ell I I I II I II -- I II -- I . II II II I I II · I I I[ II I II I I I I . II i ~ .... . ,, ~ ~ i i i i ~11 ! i ii . i i i i i I ~ .... - - '~ ~ po ~ ji ............ Il~ ~ ~ I I I I I ' ~ i ii i i ii ii ii i , ) - ~ i I ii i Ill *TUBI~ IN3ECTION FIMID: P - PRODUCE WATER INJ S - SALT WA/IR INJ M - MISCIBLE IN3ECTION I - IR3ECTIN~ N-NOT ~ .. :. ~,:, , !'..i D.EWS. 06 ' ANNULAR ~: DIESEL GLYCOL SALT WATER DRILLING MUD · , ~42, , 20 A~,C 25.030 (a) 20/%~,C 2.5.412(c) 20 AAC 25.252(d) · .. .. , · . . · .. ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering LOG TRANSMITTAL ADDRESS' ~/~F~ ~ ~-~ DATE: , //--/7-~-,~ ~ WELL: ~'5½~ ~ ~J~c~ Please find the following logs enclosed' Log ~'£ ~ ~'~--~_~ . . . ~ ~-~~ ~-,_~,. ?~s~.~ . / * / . . /./ . ~ ~,. ~-~ *~*~* ~ ~~ ~ ~,,~,~ . /. ~ . Blue *** Sepia *** Line Folded Rolled Mylar Tape Receipt Acknowledgment- Return Receipt to' Pos t Offi ce ~k~it &~'as~°ns' commissio~ Anqhorage, AK 99510 Anchorage ~'"'% STATE OF ALASKA ,""~. ALA,._ ~ OIL AND GAS CONSERVATION CO~,, ,SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post 0ffice Box 100360 4. Location of well"at surface Sec. 33, TSN, Rgw, and Sec. At top of productive interval At effective depth At total depth Anchorage, AK 99510 4, T7N, R9W 5. Datum elevation (DF or KB) 6. Unit or Property name Swanson River Field 7. Well number SRU 32-33WD SRU 31-33WD, SCU 43-4WD 8. Approval number Feet 7-795 /,~.~ 9. APl number,4 .50--133-20336-00, 133-10111 10. Pool Stet I i ng 11. Present wellcondition summary See attached schematic Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Measured depth True Vertical depth I ECEIIfED NOV 1 9 1557 · aska Oil & Gas Cons. Commissior~ Anchorage 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best'of my knowledge ~,,,~/,,~-. ¢-c~-? .... ~7 Signed/4~.~/~'.~.._ _--, -v~~'-'"--~,.,. --,..- Title Manager, Cook Inlet Engineer ng Date Form 10-404 Rev. 12-1-85 Submit i(~ Dul~licate SUBSEQUENT REPORT PRESSURE TESTS SRU 31-33WD, SRU 32-33WD, AND SCU 43-4WD Attached are three (3) Well Service Reports which document the production casing pressure tests on water disposal wells SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD. The wells were tested in accordance with Rule 6 of the AOGCC Area Injection Order to a test pressure of 1500 psi. The SRU 32-33WD did not meet the criteria of Rule 6 which states that there cannot be more than a 10% decline in the test pressure over a 30 minute period. This well is currently shut-in pending work on the tubing hanger which is the source of the leak. Repairs should be completed by the end of December at which time you will be notified of the production casing retest. The SRU 31-33WD and SCU 43-4WD held 1500 psi (within 10%) for 30 minutes. NOV .~ 9 l,.g~ 7 Alaska Oil & Gas Cons. Commission Anchorage WELL ARCO Alaska, Inc. TEL NO: I ~9J5 P05 Suosl(ltlry of Atla~Itc ~tcl'ttlet(l Coffipa*'~y WELL SERVICE REPORT C;ONTRACTOR REMARKS CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ? / / OCT-2_?-' 8'7 ~3: 2/'-'"'~'~;'' ..4NSON ~o.. 3160-s UNITED STATES (Novme~ L983) cro~.fl~ ~-32~ D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTIC~ AND REPOR~ ON ~L~ (~ eot ~ ~ tom foe pm~l to d~l or to d~ or pi~f ~ ~_ Om .,~p~ON ~R pERMIT--" for ~ ~ Water Dis ells NAMB Of OPB~B ~C0 A~as~a, ~c- Form approved. Budget Bureau No. 1004001 Expires, Au~st 31, lg8S Swanson River Unit, 8. ~m OB ~ HO. t0. e~J~ AHD I~OL, OB WILO~&T Swanson River Field -~l. II~. ~-, L~ arq Om B&L ~lo ~UUVB! OB Sec. 33, T8N, R9W, and TTN, R9W Sec · 4 Kenai ~ska Id. Check Apj~oPflate Box To Indicate Nature o~ Notice, Repod, or Other Data iUBSMUBI~ ~ a~: Tga'r WATIB I~U''~I'¢)1~ POLL OI ALTAR C.%aiNO FR&CTUSB TatA~ HULTIPLm COMPI.KTB J*R&C'T~BB ~A~MI~ . 8H~T OB ACCel ABAN~Ne 8l~lMO OB ACk.lBO AB~MM~ Completion or ~mpte~n senti (Otbe~) . ~. ~E~(-R[~ I,RqP~SED OS CO~IPLE~EO OPERATIO~ (C~earlF state sll ~FtlueuC details, and ~ive ~rttneut data tnciudl~ pr~os~ worL xr wal ~ ~i~o~ d~a~ wive s~~ t~ns ~nd meaour~ and t~e verti~ dept~ row ~ m~e~ ~ Mnm ~m- nent ~ ~ ~r~) · The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annuli in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. The pressure testing is expected to be completed by the end of October,-1987. ~cr%o ! 1~4. [ hereOy c~tttZ~ ~ correct SXG~r~D ~~..~~~1TL~ Re ional En ±neet R CEIVEi) RE:.,',... Division of iV, ine. ra: ~.:~ urce~JOV i 0 !9~7 ~ -~'~',-~ Oil & Gas Cons. Commission ..: ~,ch0rage U.S. r,c,,,,,rn .... t ofthe ~n!erior Bure,:u o: .~.,'~ ~..:~.~.~. eat · / CHIEF, BRANCH OF LEASE C,;;Z;~/~.. ':'.:'.~ OCT 0 ? 1967 APPROVED BY aden es 1,4 ~, &- , CONDITIONS Or '~P~'O~t'A~ ~ ~r'~': ',. ,~J~OT/'~ SUBJECT TO THE A.TTA CIfED B~ ~U~EMENTS ~ I~~ on R~ ~ ~ F~'m No. ~~ Title IS U.$.C. Section t00l, makes Lt a crime for any person knowmgly and willfully to make to any department or ageticy of the .................. ;..,,M,,t.flt qtatemertts or reoresefltatioflS al to any matter wtth£n its jurisdiction. SRU 31-33WD Pressure Test Production Casing PROCI~IDURI!I 1. Rec~l~i pt~sstn~ on the robing and Imxlu~on casing. The mrface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5~7: FL--O' at 0 psi). Monitor all presstues. NOTE: 48 hours prior to initiating presmwe testing pmcedm~ contact tim AOC-CC at 279-1433 and the BLM at 267-1240' and inform them that a pressure test will be conducted as per Rule 6 of Swanson River N'mid Area Injection Order N~ 13. Install two pen recorder to monit~ robing and PC tnessmes during the test. Presmn~ production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final presmmm on PC and tubing. 5. The pressure test was successful if the prodcutiou casing pressure did not decrease more than 150 psi (10%) over :30 minutes. If successful, return to injection. NOXl - ,..... ~,t.~st~ Oi~ & ~ss Co~s. 6o~misston j. ~. 4. ~" N~, ! SQ01 Oil & Gas ConS. Commission lilt lilt 1114 T.O. SRU' 31- 33 W.-C CASING & TUBING DE;TA~ SECTIO# $$ T. IN., R. Iw. ". II SRU 32-33WD Pressure Test Production Casing PROCEDURE 1. Record.presstwes an the tubing and production casing. The mrface casing is cemented. 2. Shoot fluid level in the PC for pump-in voltunetrics (8/5/87: FL=O' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 1000 psi surface pressure during pump-in. Monitor all ~ NOTE: 48 ho~rs prior to initiating tnessm~ testing ~ure, contact the ACK]CC at 279-1433 and th~ BLM at 267-1240, and inform them tl~__t a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. 5. Install two pen recorder to monitor the PC and tubing pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting inithl and final ~ on PC and tubing. 6. The pmssm~ test was succe.ssful if the production casing pressure did not decrease mm~ than 150psi (10%) over 30 minutes. If successful, return to injec~on. SRU 32- 33 ~- CASING 8 TUBING DET SECTION 33 T. SN~ R. gW · -.' "" ;.....'5".£ .Me*"" "emi d~&&dlmm~ *·l ~ ii · SCU 43-4WD Pressure Test Production Casing pROCEDURE 1. Record pressm~ on the tubing, ~n casin~ nnd surfnce casing. 2. Blow down t~ SC, recording ~ pressures. 3. Shoot fluid level in the SC for pump-in volumetrics (8/5/87: ~' at 0 psi; ann-iht volume=0.0464 bbls/ft). Lond tim SC with lease water containing 1.0 gal/1000 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. If fluid level is the same then 19 bbis is required In fill the SC annulus. Do not exceed 300 psi surface pressure during pump-in. Monilor nH pressu~s. 5. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL=O' at 0 psi). 6. If necessary, load the PC with lease crude. Do not exceed_ 2000 psi surface pressure during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure ~g Inocedure, contact the AOC~C at 279-1433 and tim BLM at 267-1240, and inform them that a pressure test will be conducted as pet Rule 6 of Swanson River Field Area Injection Order No. 13. NOTE: During pressure tests of the tubing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify , . Pressure test PC/SC pack, off to 3000 psi. 'Install two pen recorder to monitor the PC and tubing press~ during the test. Pte.sml~ production casing to 1500 psi with lease water. Hold for 30 minutes, noting ~ and final pressures on PC and tubing. The pressure test was ~_~essful if the production casing pressure did not decrease more than 150 psi (10%) over 30 minutes. If successful return to injection. ARCO 11 u i ORIGINAL K. B. · 15 4 ' OTIS "S# NIPPLE, POSITION I 2..~B" 6.,,I N-BO Srd EUE TUBING xo, Si2' ~ ' " I? BAKER FH PACKER 2~B' OTIS 'S' NIPPLE ,POSITION I I JT. Z~8' 4.?w'N-BO Srd EUE TUBING-Zd~& 23/B' Srd £UE SHEAR SUB 3030' ~00' 4~11 ' S207' PBTO 8RIDG~ PLUG TO . 6660' i CHEVRON U.~. ii SCU 43'4~ TUBING SECTION 4, TTN, RgW~ ~ SWANSON RIVER F DISPOSAL WE/. REQUIRF/~NTS WELL NOS. SRU 31-33WD SRU 32-33WD SCU 43-4WD 1. Follow the procedures outlined in the approved Sundry Notice for well Nos. SRU 31-33WD, SRU 32-33WD, AND SCU 43-4WD. 2. Notify the Chief, Branch of Lease Operations, 48 hours prior to initiating the operations. PHONE: 267-1220 (office) 248-3010 or 344-0336 (after hours) OFFICE HOURS: 7:30 a.m. to 4:00 p.m., M-F, except holidays 3. Submit a revised Sundry Notice for approval prior to deviating from this approved plan. 4. Undesirable events are subject to the requirements of NTL-3A. 5. Ail activity shall take place within the confines of the perimeter of the existing pad. Any required activity off the pad will require prior approval by the Fish and Wildlife Service - Kenai Refuge Manager. 6. Any solid and/or liquid wastes resulting from the proposed activity shall be properly disposed of in an approved disposal facility within the field. 7. Within 30 days of completing the approved plan, please submit the results of the pressure tests on form No. 3160-5. ARCo Alaska, In¢~''~. Post Office ..,,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering October 9, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached for your approval is three disposal wells at the Injection Order No. 13. The copied on our earlier application H. F. Blacker Regional Engineer a Sundry Notice for approval to pressure test Swanson River Field in accordance with Area Alaska Oil & Gas Conservation Commission was to the Bureau of Land Management. Enclosures TW/0116 RECEIVED OCT 1 1987 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,'~"/~" STATE Of ALASKA ':~-~-~ AL~.,..,,(A OIL AND GAS CONSERVATION COdy, Iv. jlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate .1~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface Sec. 33, T8N, R9W, and Sec. At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical 4, T7N, R9W Swanson River unit - 2 wells Soldotna Creek Unit - 1 well 5. Datum elevation (DF or KB) feet 6. ~lnit or Pro,~e. rty na.m.e.. Se!de_~-.a Cre~_!c Unit 7. Well number SRU 32-33WD, SRU 31-33WD~ SCU 43-4WD 8. Permit number 9. APl number 133-10164-00 50-- 13.'3-20336-00,133-10111--;.. 10. Pool ' Swanson River feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface I n termed late Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth [heAO~C~bas ~su~d Ar~a IDj~~ti~D~Qrde! No..13 .applic~ble.~p Swanson iver ~me±~, ezzecnive march ~o, iw~/. in or~er'no comp±y wzcn Rule · No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annuli in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. measured The pressure testing is expected to be completed by the end of true vertical OctOber, 1987. RECEIVED Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) OCT 1 1987 Alaska 0, & Gas Cons. Commission Apnhnr~.,ne 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is .true and correct to the best of my knowledge Signed ~//~k-~, /C _~/~~_ i/ti'tie Regional Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved by Form 10-403 Commissioner )0 .o. 7- by order of the commission Date//~) -/~ -~' Submit in triplicate SRU 32-33WD Pressure Test Production Casing I~ROCEDURE 1. Record pressures on the tubing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL=0' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 1000 psi surface pressure during pump-in. Monitor ~I1 pressures. NOTE: 48 hours prior to initiating pressure testing procedure, contact the AOGCC at 2'/9-1433 and the BLM at 26'/-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. 5. Install two pen recorder to monitor the PC and tubing pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final pressures on PC and tubing. 6. The pressure test was successful if the production casing pressure did not decrease more than 150 psi (10%) over 30 minutes. If successful, return to injection. R , !CEIVED ARCO Alaska Inc. is a su~klimy of Atlantic Richfield Con13any AR3B-6001 -A Alaska 0,, (~ Gas Cons. Commission Anchorage REC:IVED ~/' ~..../ : - ~.. Naska Oil & ~s Oons. Commission TOP PLUG 2450' T.D. · WORKOVER hq SRU 32'33 W.-O~ CASING & TUBING DETAIL SECTION 3:3 T. eN., R. gw.' SM ' .. ,~-:':'. '.- ~-..,.-"-= e~_.~:'.~,:~ · '..'.,'--.l~U~.f~A'; ,, f., · .-',,,A ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TO: ~_~.-~ _. _ ' FROM: COMPANY' -~Z~ ~_._.~_~ ~./ COMPANY: DATE: .~/.qjj ~g ? WELL NAME: Transmitted herewith are the fol lowing: PLEASE NOTE: BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy OCT. 0 2 19B7 · .__. mnmm|B81O~l Alaska Oit & 88,8~horqO~,, .... Recei pt Acknowledgment' Date: Return Receipt to' ARCO Alaska, Inc. AT.TN: Judy Boegler ATO.-.~?o~ Poll Office Box 100360 Anchorage, AK 99510 Form 3160--5 (November 1983) (Formerly 9--331) ~,,qlTED STATES SUBMIT IN '1 LICATB° (Other Instrueu~,dS on re- DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e thio form for proposals to drUI or to deepen or plug back to a ~ll~erent rflervolr. U~ "APPLICATION FOR PERMIT--" for ouch prolMMalt) OrL [~- GAS [~] STABS WELL wELL X 2. NAMa OF arEa&TaU ARCO AlaskaL Inc. 3. ADDIaII Or OPBRATOu Water Disposal Wells Post Office Box 100360 Anchorage, Alaska 99510 LOCATION or WELL (Report location clearly and in accordance with any State requt;ementm, e See also 8pace 17 below.) At ourfae~ Swanson River~Unit - 2 wells Soldotna Creek Unit - 1 well 14. PgRMIT NO. I15. E,--VAT~ONS (Show whet~r Dr, ri, oB, eta.) Form approved. l~udget Bureau No. 1004-0t35 Expires August 31, 1985 §, LB&OB DBalON&TION AND aBIIAL MO. ~. ID' INDIAW, ALLOTTBI 0U TRIBE NAME ?. U#I~ AOBBIMINT Nd, MB Swanson River Uni_t, 0. WELL MO. 10. J*IBLD AND POOL; OB WILDCAT Swanson River Pield ][1. 8B~,, T,, I., Mq OB aLE. AMD Sec. 33, TaN, R9W, and Sec. 4, T7N, R9W Kenai Alaska Check Appropriate Box To Indicate Nature of Notice, Res)off, or Other Data NO'I*ICB O1' INTSNTION TO: TESTWATSB SHUT-OrB* PCLL Om ALTER C.%SI~O FRACTURE TREAT ~IULTIPLB COMPI.RTE FRA~URB 8~OOT OR ACID,S ABANDONS 8H~INO OR ACIDIZINO R~PAIR WELL CHANGE PLANS (Other) (NOTS: Re~rt r~ulM of mMtlplo ~mpleflon on (Other) X Pressure Test Completion or R~mpletlon Rein and ~g fao.) Ut:M('Rlflg I'flOI'OSED 08 CO~fPLETED 0PERATIONM (Clenrly state all p~rtluent details, and ~lve ~rttnent dateL tncludl~ ~Gmat~ date of_o~fln~ proposed work. If w~l h di~tion~y drill~, five s~e l~tions and meaour~ and ~rue vertical dept~ for MI markers and Mn~ ~rU- neat ~ ~is wor~) ' mUBaBqUBW'f IBI'OB~ O~: ALTaBIMO CAIIIINdO · The AOGCC has issued Area Injection Order No. 13, applicable to Swanson River Field, effective March 16, 1987. In order to comply with Rule No. 6 which pertains to the demonstration of mechanical integrity in the tubing/production casing annulus, the production casing annuli in the SRU 31-33WD, SRU 32-33WD, and SCU 43-4WD will be pressure tested to 1500 psi. The attached procedures outline the steps that will be taken to conduct the test. The pressure testing is expected to be completed by the end of October, 1987. 1~. [ hereby certify t.J~ the forego~Jf~ is tr'de/~bd correct (This space for Federal or State ames u~e) APPROVED BY CONDITIONS OF APPROVAL, /~ ANY: TITLE Regional Engineer DATE *See Insh'uctions on Reverse Side Title 18 U.S.C. Section 100l, makes it a crime for any person knowingl}' and willfully to make to any department or agency of the .............. r..t-- r:.,;, .... e ,~. trrmt,,-h,l;-nt qtnt~ments or representatiOnS aS to any matter within its jurisdiction. SRU 32.33WD Pressure Test Production Casing PROCEDURE 1. Record pressures on the tubing and production casing. The surface casing is cemented. 2. Shoot fluid level in the PC for pump-in volumetrics (8/5/87: FL--O' at 0 psi). 3. If necessary, load the PC with lease crude. Do not exceed 11300 psi surface pressure during pump-in. Monitor all pressures. NOTE: 48 hours prior to initiating pressure testing procedure, contact the AOOCC nt 279-1433 and the BLM at 267-1240, and inform them thnt a pressure test will be conducted as per Rule 6 of Swanson River Field Area Injection Order No. 13. 5, Install two pen recorder to monitor the PC and tubing pressures during the test. Pressure production casing to 1500 psi with lease water. Hold for 30 minutes, noting initial and final pressures on PC and tubing. 6. The pressure test was successful if the production casing pressure did not decrease more than 150 psi (10%) over 30 minutes. If successful, return to injeclion. ARCO Alaska ~. Is a sul~idlaty o~ Atlantic Richfield Company AR3B-6OO1-A WORKOVE'R fO SR U :52- ~3 w.-D. CASING ~ TUBING DE:TAIL SECTION 33 T. 8N., R. gw.' SiM . . .; -.. -_...,..,..; '-.':,':. ~I4I'vD n,;' :J.'fl' e ...... '~-" ''''¥ · I '.:411t~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering September 2, 1987 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr, Wondzell' This letter is to inform you of the naming convention for the Swanson River water disposal wells. We will be using these names in future correspondence and notices. The monthly injection report will be reissued from March, 1987 to include information on the disposal wells as you requested through Mr. Ronzio. Well Name API Number Old Name SRU 21-33WD 133-10162 SRU 221-33 SRU 41-33WD 133-10167 SRU 31-33WD 133-20336 SRU 32-33WD 133-10164 SCU 43-4 WD 133-10111 SCU 243-4 If you have any questions, please give me a call at 263-4299. H. F. Blacker Regional Engineer HFB'MLE'ch'O034 cc' Joseph A. Dygas, Bureau of Land Management D. Gann/J. Renfrow SRF J. D. Hales ATO 704 R. H. Larson KI W. M. Peirce ATO 1390 E. A. Raleigh ATO 700 G. S. Ronzio ATO 2020 T. Wellman ATO 1396 RECEIVED SEP o 9 J~,6! Naska 0il & Gas I~on;. Gomml~loff Anchorage STATE OF ALASKA ?~ ALASKA OIL AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-115 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 5o-133-20337 OTHER Water Disposal 4. Location of Well 1875'S & 2010'W of NE Corner Section 33, TSN, R9W, S.B.&,? 5. Elevation in feet (indicate KB, DF, etc.) G.L. = I72' I 6. Lease Designation and Serial No. A-028399 12. 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 32-33 WD 11. Field and Pool Swanson River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). After starting injection, annulus pressure increases until it matches tubing pressure. We intend to do the following: 1. Move in and rig up the workover rig. 2. Bleed off pressure, and kill the well as required. 3. Nipple down the tree, and nipple up the BOP's. 4. Test the rams, manifold and valves to 3000 PSI. Test the annular to 1500 PSI. 5. Pull out of the hole with the tubing. 6. Mill over the packer set at 2048'. ~ frei V~D 7. Clean out to PBTD of 2450'. 9. Nipple dOwn the BOP's and nipple up the tree. 10. Test the annulus to 1000 PSI for 30 minutes. & nchorago SSlor~ 14. I hereby certify that the f/qregoing is true and correct to the best of my knowledge. Signed .... Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by ORIG:NA1. St,GN[D B'f IAR~Y W. KIGLEI lleturned, By Order of COMMISSIONER the Commission Date /~---~~__ Form 10403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Chevron Inc? P.O. Box 107839, Ancho,dge, AK 99510 · Phone (907) 786-6600 J.l. Weaver Area Operations Superintendent Production Department :' octOber 11, 1985 Well SCU 32-33 WD Sw .ansonR,iver Field~ ~ U.S. Environmental Protection Agency Region 10 Attn: Mail Stop 409 ~¥~., 1200 Sixth Avenue Seattle, Washington 98101 Dear Sirs: On October 1, 1985, it was discovered that there was pressure on the tubing-easing annulus that approximately equaled the tubing pressure of +750 psi. The annulus was then bled down to 0 psi and shut-in to observe the pressure while injecting. The annulus pressure built, up to the tubing pressure in a few hours, indicating communication between the tubing and the tubing-easing annulus. The well was then shut-in and annulus bled to 0 psi. On October 2, 1985, Mr. Harold Scott of your office was verbally notified of the situation by Ms. Christine Creed of our office. Investigation by the field personnel of the pressure communication found that the tubing hanger appeared to be leaking. The bolts securing the tubing hanger were tightened and the annulus retested to 1000 psi. The annulus held the 1000 psi for over 30 minutes. On October 7, 1985, the well was returned to injection and the annulus pressure monitored. The annulus pressure remained at 0 psi for several days, then began to build up. On October 10, 1985, it was observed that the pressure on the annulus had built up to tubing pressure, the annulus was bled off and then shut-in. The pressure quickly built up to the tubing pressure. It is believed that the tubing or the packer is leaking. The well was shut-in and the annulus pressure bled to 0 psi. . · The well is currently being evaluated to determine the most economical action for correcting this situation. This would involve pulling and testing the tubing string and replacing the existing packer. This work will be~ done with the rig currently working in Swanson River and will begin some time in November, pending U.S. Environmental Protection Agency October 11, 1985 Page 2 approvals. Chevron U.S.A. Inc. would like to emphasize that there is no question as to the integrity of the casing, however, the wen will remain shut-in until the proposed work is completed. If there are any questions concerning this work, please contact Mr. J.B. Logan or Ms. C.D. Creed at (907)786-6600. ~yours, · Weaver a Operations Superintendent JBL:mw Attachments Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 bec: M.R. Brennan C.D. Creed RECEIVI D ocr 6 ^las~a Oil & Gas Cons. Commission Anchorage Chevron Chevron U.S.A. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area Operations Super~n~enden! Production Department August 15, 1985 Integrity Tests SRU 31-33 W.D. and SRU 32-33 W.D. Swanson River Field~ Alaska , U.S. Environmental Protection Agency Region 10 Attn: Mail Stop 409 1200 Sixth Avenue - Seattle, Washington 98101 Dear Sirs: Please find attached the results of the pressure integrity tests on the Swanson River Water Disposal Wells SRU 31-33 W.D. and SRU 32-33 W.D. This includes a summary of each test and a copy of the pressure chart recorder. These tests were performed on August 6, 1985 and were witnessed by the following people: Name Organization Harold Hedland AOOCC Debra Gates EPA Jerry Opatz EPA Joe Dygas BLM Joe Ru~ell BLM Dan Marlowe Chevron USA Bud Kloppenburg Chevron USA Jim Logan Chevron USA The pressure test on SRU 32-33 W.D., which was recently worked over, was successful. The casing annulus held a pressure of 950 psig for over 30 minutes. Due to the type of pump being used for the test, we were' unable to achieve 1000 psig exactly. However, since the test pressure of 950 psig is higher than the normal operating pressure of 800-850 psig, it was accepted by the EPA representa- tives on site. The pressure test on SRU 31-33 W.D. was not successful as the casing annulus would not hold pressure. We believe that this was due to cement squeeze holes in the casing which are not sealing. These holes, which range in depth from 100' to 430', were originally shot for cement squeeze work to isolate shallow gas zones. A copy of the casing and tubing detail, along with the completion report showing the cementing detail, are shown in Attachment #1. The depth of these holes and the U.S. Environmental Protection Agency AugUst 15, 1985 Page 2 type of formations behind the casing make it difficult to repair these holes to where they are a pressure seal. This does not, however, affect the integrity of the well. The radioactive survey completed in 1983 and the fact that there is a pressure differential of 850 psig between the tubing and the casing indicate that the well is in sound condition. A copy of the radioactive tracer survey for this well is also shown in Attachment #1. Daily monitoring of the casing and tubing pressure along with the injection rate will flag any deviation from the current condition of the well. Consequently, if any abnormality is noted, the well will be shut in and the problem located. At that time, it would then be determined if remedial action is necessary. In addition, the governing agency would be informed as per the permit conditions. If there are any questions concerning these tests, .please contact our representa- tives in AnChorage, either Christine D. Creed or James B. Logan at (907)786-6600. :JBL:mw Attachments ~rS, (J. L. Weaver Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SRU ATTACHME'NT # 2 32-33 INTEGRITY TEST SWANSON RIVER FIELD Tubing Casing INITIAL CONDITIONS Pressure: 0 ps~g (Wel I Shut in) Pressure: 0 psig (Annulus ful I) Start pressur.ing 'at 12:]3 annulus annul pREsSuRE TEST us using Sal tz pump truck and lease water psig and.shut in follows: P.M. on 8-6-85. valve, Annulus p Pressured to 920 ressure reacted as Elapse d Time 5 min. 0 m~n 4 min 9 min 4 9 mln 4 min Pressure 915 915 92O 93O 94O 95O 95O (psig) Test completed at 12:47 P.M, and equipment rigged down. Annulus· pressure test successful. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHERX~ Water Disposal 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 80-115 3. Address 8. APl Number P.O. 'Box 107839, Anchorage, AK 99510 50- 133-20337 4. Location of Well At Surface 1875'S & 2010'W of NE Corner Section 33, T8N, R9W, SB&M 5. Elevation in feet (indicate KB, DF, etc.) O.L. = 172' 12. I 6 . Lease Designation and Serial No. A-028399 9. Unit or Lease Name Swanson River Unit 10. Well Number SRU 32-33 WD 11. Field and Pool Swanson River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed worE, for Abandonment see 20 AAC :25.105-170), Began operations at 10:00 A.M. 8/2/85. Nippled up the 10"-- 5000 PSI double ram preventers. Made up landing joint in tubing hanger. Attempted to test BOP's and could not fill BOP's due to communication between annulus and tubing. Pulled tubing hanger 15" before taking weight, and attempted to release anchor from packer. Pipe pulled free, and recovered 764' of tubing. Ran in hole with work string and screwed onto top of fish.' Released anchor, and pulled out of the hole with the anchor and seal assembly. Redressed the seal assembly and ran~the hole with the seal assembly on 3½" 9.2# N-80 BTC tubing. Tested tubing in the hole internally to 3000 PSI. Landed tubing with 2½' of seals above and 1½' of seals below packer. Tested the packer to 1000 PSI. Nippled down the BOPE and nippled up the tree. Operations. completed at 10:00 A.M. 8/5/85. RECEIVED AUG 2 1 ]985 Alaska Oil & Gas Cons. CommJssjoD Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , . · Title Area Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM TO: TERU z FROM: stat of Alaska Com~ssioner Harold J. Hedluud ~~ Senior Petroleum Engineer APR 1 ,,5 2003 TELEPHONE NO: SUBJECT: Mechanical Integrity Tests, UIC Emergency Permits, S~anson River Field Tuesday, Augus..t 6, 1985: I witnessed mechanical integrity tests on two wells for which UIC Emergency PermAt Numbers AK-2D0098-E and AK-2D0099-E have been issued. Other witnesses of these tests included Deborah Gates and Jerry Opatz with EPA, Joseph Dygas and Joseph Russell with BLM and H.G. Kloppenburg and J.B. Logan with Chevron. The first well to be tested was SRU 31-33 WD. Water was being injected through fiberglass tubing set in a packer. Tubing pressure was 730 PSI with no pressure on the annulus. annulus was pressured up to 300 PSI but the pressure fell off rapidly to about 150 PSI in one minute. When SRU 31-33WD was completed in 1981, 7 in. casing was set at 24.50 ft. and was cemented to surface. A poor cement job was obtained and numerous holes were perforated between 100 ft. and 430 ft. and squeezed with cement. The casing was perforated between 2100 ~t. and 2383 ft. Three and one-half inch fiberglass tubing was run and set in a packer at 2050 ft. The injected water is apparently all' being disposed of through the perforations below the packer since there was no pressure on the annulus. It appears that the perforations between 100 ft. and 430 ft. were not completely squeezed off and allowed the annulus pressure to fall off. Steps to repair the casing were not determined at this time. The second well to be tested was SRTJ 32-33WD. The three and one-half inch_fiberglass tubing which was installed when this well was completed in 1981 had just been replaced w~th three and one-half inc~ steel tubing. Water was not being injected due to the water lines being disconnected.. The annulus was Pressured up to 925 PSI whiCh slowly fell-off to 920 PSI and then gradually increased to 950 PSI after 35 minutes. While the pump and teSt equipment was being moved to the second · well, We inspected the water disposal facilities and the other disposal wells® A workover ri bein. g rigged up on well SRU 243-4 to ~rk over the well an~ was run tubi6g and packer. In summarY, I witnessed a successful mechanical integrity test on SRU 32-33WD and an unsuccessful test on SRU 31-33WD. 02-00IA(Rev. 10/79) . ~ ~ STATE OF ALASKA /~'~ ALASKA OIL AND GAS CONSERVATION CO,v~MISSION $1...IN_nRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER'KI Water Disposal 2. Name of Operator Chevron U.S.A. Inc. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of Well 1875' S & 2010' W of NE Corner Section 33, T8N, Rgw, SB&M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 80-115 8. APl Number 50-133-20337 9, Unit or Lease Name Swanson River Unit GL = 172' A-028399 10. Well Number SRO 32=33 WD 11. Field and Pool Swanson River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) ________.__ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). While attempting to pressure test tubing/casing annulus, noticed that there was pressure on annulus. While injecting, both casing and tubing pressures were equivalent. We intend to do the following: 1. Shut well in and shut in offset injection wells that dispose in the same zones. 2. Move in and rig up workover rig. 3. Bleed off well pressure. Kill well as required. 4. Nipple down the tree and nipple up the double ram 6" - 3000 PSI BOP's. Test the BOP's to 1500 PSI. 5. Pull out of the hole with the producing string and inspect and repair as required. 6. Run the~producing string and internally test the tubing to 1500 PSI. 7. Space out and stab into the packer. Test the packer to 1000 PSI. 8. Latch anchor and land tubing with 8000 LBS tension. 9. Nipple down the BOP's and nipple up the tree. Test the annulus to 1000 PSI. 10. Rig down and move off the workover riI. , 14. I hereby cer~h7reTg is true and correct to the best of my knowledge. Signed ,~'~. ~ ~~~ .~ Title Area Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by. 91tll~tliAL Siili£9 BT' tO,qfllE C. SMITIt COMMISSIONER Approved Cop~ Returned By Order of the Commission Submit "intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Chevron Chevron U.SA. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area Operations Superintendent Production Department July 29, 1985 Well SRI] 32-33 W.D. Swanson River Fieldt Alaska U.S. Environmental Protection Agency. Region 10 Attention: Mail Stop 409 1200 Sixth Avenue Seattle, Washington 98101 Gentlemen: On July 23, 1985, it was discovered that there was communication between the tubing and the tubing-easing annulus in waste water injector well SRU 32-33 WD. This letter is written as follow-up to verbal notification given by Mr. J.B. Logan of Chevron U.S.A. to your Harold Scott on July 24, 1985, per Permit No. AK-2D0099-E Section C.5. The well is currently shut in. The communication was found while preparing for the required pressure testing of the tubing-casing annulus. Pressure was noted on the casing annulus. This pressure matched the injecting tubing pressure of the well. The well was shut in and the pressure dropped to zero. We believe that there was a failure in the tubing or the packer which resulted in the pre~ure communication. There is no reason to believe at this time that there is any problem with the casing itself. We propose moving a workover rig on the well and repairing the problem, then pressure testing the tubing-easing annulus to 1000 Psi as per the permit conditions. The repair work on this well is scheduled to begin on or about August 1, 1985. If there are any questions, please contact Mr. J.B. Logan of our office (907)786-6600. Sincerely yours, j. L. Weaver JBL:mw cc: Alaska Oil and Gas Conservation Commission 4nOhn ~ uf',=?9~' ~Ol'~,r/./l~$100 ! · RECEIVED REMARKS ON OTHER INC. BOX 7-839 SIDE, THIS SNk'~T 'ANCHORAGE, ALASKA 99510 TYPE AP_ - 2048'. WORKOVER 8.20.81 TUBING HANGER 3¥? ., ,i 3~2 3.71 O.D. 3.02" I.D. 2000'~W.R STAR FIBERGLASS H.P. THREADED RUE B RD. .- TOP OF PACKER .BAKER MODE[: F,I (wIRE LINE MEASUREMENT) SEAL ASSLY. WITHIN PACKER .. CASING SECTION 7 - 20-8:5 · I 32-33 w.O, TUBING DETAIL 33 T. 8N., R.9W. SM CHEVRON U.S.A. INC. TRANSMITTAL ~D ACKNO~rLEDCEMENT OF DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FI)- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueltne PLEAS~CHECKAND ADVISE IMMEDIATELY. ../ REMARKS ON OTHER SIOE, THIS SHE'ET ~6~T u.s.a, mc. / BOX 7-~39 AI,,I(~ORAGE, ALASKA 99510 Chevron Chevron U.S.A. Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 /~ O~cC fire.. E,,,,%',.,,,..~, ,~c COMPLE'TION REPORT AREA: Swanson River Field Kenai Peninsula, Alaska PROPERTY: Swanson River Unit WELL NO: SBU 32-33 WP LOCATION AT SURFACE: LOCATION AT TOTAL DEPTH: ELEVATION: 171 'GL DATE: 6/23/83 LAND OFFICE: Anchorage LEASE NO: A-028399 AP! NO: 50-133-20337 1874' South & 2010' West from NE Corner Section 33 T.8N., R.9W.SM Same /.- BY: ~. ,' AREA SUPERVISOR T. L. PERRYMAN WORK PERFORMED BY: R.L. 's Oilfield Service ', DATE COMMENCED WORK: August 17, 1981 ' DATE COMPLETED WORK: August 20, 1981 PLACED ON PRODUCIION: TOTAL DEPTH: 2520' EFFECTIVE DEPTH: 2450' CASING: TUBING: SUMMARY PERFORATIONS: '. 10-3/4" Conductor driven to 80' 7" 29#, unknown grade cemented at 2499' 2425' 2316' 2278' - 2234' 2228' - 2100' 3-1/2" Star Fiberglass w/ 3-1/2" EUE 8rd thread to 2048' .A. Ugust 17, 1981 Rigged up 40 ton Linkbelt crane owned by D. Toloff and under contract to R. L's. Oilfield Service. Made clean out run with 6" bit and 7" casing scraper to 2450' (PBTD). Displaced hole with fresh water. POOH 30 j ts. AugUst 18 and 19, 1981 Finished POOH, rigged up Gearhart, and perforated the following intervals using 4" HSC casing guns: 2425' - 2316' 2278' - 2234' 2228' - 2100' 4CJPF 1/2" holes 4CJPF 1/2" holes 4CJPF 1/2" holes Ran in hole w/Baker 7" Model E1 retainer production packer (413-06-8540) and set at 2048' with Gearhart wireline. Started running tubing. August 20, 1981 Finished running tubing, tubing detail: Gray type A2 tbg. hanger 7" x 3-1/2" 1 jt. 3-1/2" Star Fiberglass pup jt. 66 jts. 3-1/2"/ 3.71" ODX3.02" ID 2000# WP Star Fibergals~S-H.P. EUE 8rd tubing 1 - Baker tubing anchor.for F-1 pkr 1.00' 5.87' 2039.38' 2.00' Latched into packer at 2048', landed tubing in 8800 lbs tension (24 inches of stretch, tubing tensile strength - 20,000 lbs.) Nippled up Gray tree and rigged down crane. Turned well over to production foreman. DIRECTIONAL SURVEY WELL #SRU 32-33 W.D. Depth 2520' Angle 3/4° 5/28/81 · ···DEPT.: · PLACE: 'i -. · .. .i::iTItE FOLLOWING IS A. LIST OF I~TER. IAL ENCLOSED HEREIN. -. · . .. FD- Folded R - Rolled S.- Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. -\\ ~.\ \ .. · '. RECEIVED BY ": *: ';' ','~" :"-'~ELL' ~RVEY Pro-'312 iiELL NO..,-~'~L/' L,~/~- ~,2-,,T~'. ~IITY,oF' /~/7'~/' '' * CI'i'Y OF · TINCT. NO. ' LOT I10. FI ELD 1::3 PRELII~I#ARY i' ELEVATION: GROUND~ I* ' CO~ICRETE HAT DERRICK FLOOR "'"-'~AT I 011 ., I~OCATION COORDINATES DES I GNATI ON :'-, · & ['T E R . A T E -O R' S U R V E Y. E D I~OVE CATION STATION SEARING DISTANCE ' 81NE ' I ~.C081NE · NORTH SOUTH . .. EAST . YEST ... ' . · . . ..>:,~,.: · -- '" .... :' :',.-:" ', .. "- .: .'. ..... ',,.:' '.:: .:.~,. : ,, -.::. ::! ,:'ii:: ' ' ....... ..':' ', ..-: '-'.. · ' .. ' ........ .-:.,?~ ' .., .., ,:. - .: . . , ·. -' ? · ;. , - :,._ . . ,, ' , ' .' : - ,., , ,' . , : ~, , '~ . ~. - '.'. "-'' "' '-:01 . .... ' , : :...' . - . . · ' , , ' . · -?. ..... .;.~,..,.~,. - , , ..,.., ., .... · . · · ....: · . , ----' ....... :':'. :"'- ^ncherag~ .. -... . . -- . .. : .',..-';'~.. , , :...' ' " .'. ...... ;. . ...~ '! ....... ' ~:~' . . . . .i~. ' -,' -':..?';:' ' , " - . - · '. : , ' ' . .... '.' .... ". · Receipt o.f the · C'~ ~. ~'; ~ ~' ' following material ,~whi ch was transmitted via /-~"/~ :" is hereby acknOwledged' QUANT I TY DESCRIPTION .: Copy YES sent tg~ sender so _.. ALASKA OIL AND CAS CONSERVATION COMMISSION June 17, 1982 /. ,r ., 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE(907) 279,-1433 · Mr. T. L. Perryman .Chevron USA, Inc. P.O. Box 7-8'39 Anchorage, Alaska~ 99510 Dear Mr. Perryman: We wish to thank you for the material forwarded to the Commission in response to our letter of April 21, 1982. However, all of the requested material was not received at that time or during the subsequent interval. Again we wish to bring to your attention that ~he following required material has not yet been received: We 1 1 Beluga River U. #214-35 Completion Date 3/7/81 Mi s sin~ Material -Samples (dry ditch cuttings ) -Mud Log-Directional Survey-DST/Prod. Tast Reports-Digitized E. Log Tape Soldotna Cr. U. #21-4A 3/7/81 -Certified Survey Plat -Digitized E. Log Tape Soldotna Cr. U. #42-5A 10/5/81 -Digitized E. Log Tape Soldotna Cr. U. #41-9A ,. S%~nson Riv. U. #31-33WD sWanson Riv. U.. #32-33WD 6/2/81 5/29/81 5/29/81 -Digitized E. Log Tape -Inclination Survey -Digitized E. Log Tape -Well History -Certified Survey Plat -Inclination Survey -Digitized E. Log Tape Please submit the above material at your earliest convenience since you remain in violation of Title 20, Chapter 25 of the Alaska Administration Code. Very truly .yours, Harry W. Kugler Commissioner HWK/WVA/glh COMPI_FI'ION REPORT - NEW WELL AREA: Swanson River Field Kenai Peninsula, Alaska 'L LAND OFF I CE: Ancho rage':' PROPERTY: Swanson River Unit LEASE NO: A-028399 WELL NO: SRU 32-33 WD API NO: 50-133-20337 LOCATION AT SURFACE: 1874' South & ,2010' West from NE Corner Section 33 T.8N., R.9W. '. SM LOCATION AT TOTAL DEPTH: ELEVATION: 171 ' GL DATE: June, 1981 Same Tom L. Perryman AREA SUPERVISOR DRILLED I~Y: Brinkerhoff Rig #60 DATE CO~NCED ~ WORK: DATE COMPLETED ~ WORK: RETURNED TO PRODUCTION: May 25, 1981 May 29, 1981 TOTAL DEPTH: 2520 EFFECTIVE DEPTH: 2 CAS I NG: SLMVlARY PLUGS: 10 3/4" Conductor at 80' 7" Cement at 2499' 2450' - 2520' LO6S: Schlumberger DUAL INDUCTION LATERLOG: 94' .to 2516' DIL WI/H LINEAR CORRELATION: 94' to 2516' FORMAT!ON DENS ITY COMPENSATED NEUTRON: 5-28-81 5-28-81 94' to 2516' 5-28-81 94' to 2516' 5-28-81 GO Gearhart-Owen CEMENT BOND LOG WITH SEISMIC 48' to 2435' ~2~--81 SPECTRUM & NEUTRON': CEMENT 'BOND LOG WITH G~IA RAY 48' to 2435' 7-10-81 AND NEUTRON LOG: 5~ May 24, 1981 Completed location and drove Id '.3/4" conductor to 90'. t May 25, 1981 Moved Brinkerhoff Rig 960 onto locat±on and completed rigging up. Installed Hydrit', diverter lines and prepared mud. Total elapse time 15 hours. Spudded at 9:00 PM. 9.8 pcf mud May 26, 1981 Drilled 9 7/8" hole to 976'. 72 pcf mud May 27, 1981 Drilling 976' to 1630' 72 pcf mud May 28, 1981 Circulated 1530' to 1630' drilled to 2100' pulled up to drill collars, circulated and drilled 9 7/8" hole to 25-20' and c~rculated. Pulled out of and prepared to run Schlumberger. Ran Dual Induction Laterlog from 94' to 2516'. Ran DIL with Linear Correlation from 94' to 2516', Formation Density Log from 94' to 2510' and Compensated Neutron from 94' to 2510'. Completed log runs and cleaned out hole. 78 pcf mud May 29, 1981 (-2520') Rigged up and ran 7" casing float collar at 2455' cemented at 2499' with 700 sacks. Pulled out of hole, p~ck up Hydril cut 7" casing off and nippled up Hydril. Ran into hole w~th 6" b±t and 7" scraper drill out cement from 2410' to 2450' ¢~rculated and pulled out of hole. Cleaned · mud tanks, repaired leak ~n stand p~pe. Released rig at 12:00 noon. J. W. WILSON RECEIVED Oil & Gas Cons. Commissio~ ~chomge _July 8, 1981 Crew moved onto location and prepared well for Gearhart logging. .July 9, 1981 Gearhart rigged up and ran a Cement Bond Log from 0' to 2435', ran Cement Bond Log with Gamma Ray and Neutron from 0' to 2435' andi~ran Cement Bond Log with Seismic Spectrum and Neutron from 0' to 2435' completed logging and rigged down. Move logging equipment to SCU-31-33 WD location. Crew shut down well. TYPE A2 TUBING HANGER ,2" ' I ~' l~ ,120 d.P. 4-~/2 HJF .~'~;' 3.71" O.D. 3.02" I.D. ZOO0~W.P. STAR FIBERGLASS H.P. THREADED EUE 6 Ro. __ Z048'. a,oo' aaa'. 2234' 23,e~. TOP PLUG TOP OF PACKER BAKER MODE[: F,I (WIRE LINE MEASUREMENT) SEAL ASSLY. WITHIN PACKER 2450' SRU CAS lNG ~ SECTION CHEVERON II 32 -33 w,o. TUBING DETAIL T. 8 N.,R.gW. SM · . U.S.A. INC. L 7-1o-81 5-z8-8~ /:3/ectsc ccc/c~io~ led, j.e +cans m; Urq i o4' -t-he c~6oac r~,med. e~c(osed enue [ope. -'t - Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 April 21, 1982 Beluga River Unit-%214-35 (2r~ notice; see attached copy of 10/8/81 lettar) 3/7/sl -Ceze~-!_eied Surly Plat -Directional Survey -DST or Prod. Test ~ -Digit/zed E. Log Tape Soldotna Ct. tkuLt 921-4A ~11 History -Certlf~ Survey Plat -Digitized E. Log Tape Soldotna Ct. Unit S42-5A Soldotna Ct. Unit #44-8A -Well Ittstnry Soldotna Ct. unit S41-9A 6/2/81 -~geL% History -Elec. Logs -Digitized E. Log Tape Swanson River bY~t #31-33WD 5/29/81 -Incl~mtic~ Survey -Digitized E. Log Tape -Certified Survey Plat -Inclination Surv~, -Digitized E. Log Tape Please ~t the above material at l~xzr earliest convenience since you are now in violation of Title 20, .(2u~ 25 of th~ Alaska Adm/nistrative Code. ./:::.~ i/,.'.--:-'. / / SY o,RD~ OF THE COMNI1SS[O~,t o. TRANSHITTAL AND ACKNO~ffbEDGEb~NT OF RECEIPT OF HATERIAL - (ALASKA) 'THE' FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. CHECK AND ADVISE I~ffD~DIATELY. .... RUNS . . · · · INDUCTION ELECTRICAL LOG DUAL INDUCTION BOREHOLE CO~flPENSATED SONIC BOREHOLE COHP. SONIC w/caliper BOREIiOLE CObflP. SONIC w/gamraa BOREHOLE TELEVIEkq~R CONTINUOUS DIPI'fl~TER- High Res. CDH- POLlq40C PLOT CEmeNT BOND LOC CASING COLLAR LOG - Perf~. Rec. COMPENSATED FORI.[ATION DEN. COMPENSATED NEUTRON FOF&~TION ANALYSIS LOC FOP~£~TION DENSITY LOC F F FOPd.[ATION TESTER FOR>5%TION FACTOR F F GBJ-fffl~ RAY .- CA~DIA RAY - NEUTRON GA>iliA RAY COLLAR LOG MICRO LOG MICROLATEROLOG MUD LOG NEUTRON LOG PROXIMITY MICROLOG RWA ~O,'.fPARIsON PLOT SANDSTONE ANALYSIS SAFu%BAND SIDEWALL NEUTRON POROSITY SONIC TEIiP ERATURE LOG CO,~fl~LET ION REt'ORT DIRECTIONAL SURVEY CORE DATA SAIb\B,M~D TABULAR LISTING PLEASE SEPIA Received and checked by: BLUELINE · / 11;' F r i:: I Vi:: n --'--' ' =" ~- i~y:_- AllG ? i !98! Alaska 0il & ~as Cons. Commission Anchorag.e · I I I0O goo : ·f~"~ ,,~?~ STATE OF,~ ALASKA ;~--;~ , I1~ I ~ I/~/j~ WELL COMPLETION OR REGOMi Lgi,u. REPORT AND LOG l il~Status of Well Water Di sposa l Classification of Service Well ~ .~ . Confidential OIL [] GAS [] SUSP~'NDE© [] 'ABANDONED [] SERVICE [] 2. Nameof'Operator ' " 7.'PermitNumber Chevron USA ]:nc,, 80-115 ,3. Address 8. APl Number P,0, Box 7-839 Anchorage, Ak, 99510 5o-133-20337 4. Location of well at surface 9. Unit or Lease Name 1950'S,2200W, of NE corner, Sec. 33, T8N, R9W, SB+M. Swanson River Unit At Top Producing Interval 10. Well Number Same gRII ~?- At Total De..pth 1 1. Field and Pool ' same Swanson Ri ver Fi el d . 5. 'Elevat'i0n in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 172'GL A-028399 12. Date sPudded ' 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ,15. Water Depth, ifoffsh0re ,16. No". of Completi'on's 5-25-81 5-28-81 5-29-81I Ifeet MSL 1 i T, T0taIDepth{MD+TVD) 18. Plug Back Depth (MD+-I-VD) 19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 2499, 2450, YES [] NO J~ feet MD None ... 22. Type Electric or Other Logs Run "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 10 '3/4" - CondUct)r 90' Driven ' ' . . '" 7" 23# K-55 5u,,~ 2~99' 9 7/8" 700 Sx Class "G" .... I , 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) None ' 26. ACID, FRACTUREi CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MA'~'ERIALUSED . . 27. PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD FioTM q'ubing Casing pressure CALcuI~ATED -~'i 61E-BBL' GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. '' ~ ~ ~::'~ 24-HODR RATEII~,. 28. " "' ' ':'~ ~ ': ' ~ ' C~R'E DATA· ' , ~'Briefdescripti°n°flith°l°gY'p°r°sity'fractures'apparentdipsandpresence°f °il' gas °r water' Submit c°re chips' , ~ ~ . -.. ~ . . ~ · .JUN-~I~31 A ~,,,. 0il & Gas Cons. Commission · Form 10-407 Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. tST OF ATTACHMENTS 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed(.~' ~' ~~~//~~'~_./m~N~.-'/' Title Area ODer SuDt T.L. Perryman Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lan~s 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..~n 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 too!. 111 ,("I '\ t Check Form for tinely canpliance with our regulations. ~ O~rator, Well NëUœ and Numœr s6LV\. ~L~11l.VD Reports and Materials to be received by: t -;¿?-?J Da.te I RE\1Uired Completion Re¡:úrt Yes Well History Yes Samples I ~~ I I - If6 Mud Log Core Chips ¡ c----... ¡ ¡ ¡ ~ ¡ .------.- ¡ Core Description 1M Production Test RefOrts Logs Run Yes ,-'" ,-~. "'-";"."... -~..f'- ._- - '-". '.":¥( [/ [)i¡Jitized Log Lata ¿ ;~. '. ",,.,ø';¡¡""""'. . .d' ".....¡ ~.... ."..-...... ""W""'''''''''~'''''~'. ,.' ......,JI' \,...-"':;~""--' ~. I ! Date Received I r I i I Remarks ~ Ifv-- ?'I 2 ó f /; I ------- 0 ~? íl L 0 I~ ------.-- 0 ~~. - ;L. l&l'€. oK () -. Of (j ~ ~ I--~ \ ~Pr h1../ ',~~~ I - ~_1J -,gól-. - ' /-'~ STATE OF ALASKA ALASKA/ :,'AND GAS CONSERVATION C~ .VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well IX] Workover operation [] 2. Name of operator 7. Permit No, Chevron USA Inc. 80-115 3. Address 8. APl u P.O. Box 7-839 Anchorage, AK 99510 5o_1~'-"~2b(~337 4'L°cati°n°fV~50'S,220~, of NE corner, Sec.33, T8N, R9W, SB+M 9. Unit or Lease Name ~t ~u~f~ Swanson River Unit 10. Well No. SRU 32-33WD 11. Field and Pool Swanson River Field A-028399 For the Month of May ,19. 81 ., 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks SpuddOd 5-25-81'/DRLD. 9 7/8" hole to 2499' 5-28-81 13. Casing or liner run and quantities of cement, results of pressure tests Drove 10 3/4" casing to 90', Run 7" casing w/FC at 2455'+ shoe at 2499'. Cement to surface w/700' sacks Class "G", Landed casin§ R.I.H. w/6" Bit. Tagged CMT. at 2410'. DRLD. CMT. to 2450'. P.O.H. lay~d down D.P. Nippled Down. Released Rig 5-29-81 14. Coring resume and brief description 15. Logs run and depth where run GR 2522'-94~ , FDC CNL GR w/Caliper 2512-94 16. DST data, perforating data, shows of H2S, miscellaneous data RECEiVE~" JUN - 4 1981 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Reporl~ 6~ fhisrt~f~',yslltL~l~laired f'~or each calenda; month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate November 12, Hr. R. g. Hagee Area' Engtneer Om vron U, <5. A., Inc. ~. P.O. Box- 7-839 ~oraga, Alaska 9.9510 S~Ject: S~ans~ Ri~ ~1 t S~ 31-33 ~D $~nson River ~tt SRU ~-33 gD/ Dear ~-. Ma~e: The AP:[ numbers asstgned to the l~sted wells on the permtt to dr111 forms ~e~e erroneous and need ~ be corrected. SRU 31-33 WD ts ass!gned AP:[ number 50-133-20336. SRU 32-33 WD ts assigned AP:[ nu~er 50-133-20337. We apologize for any Inconvenience thls may have caused. JALIge October 8, 1980 Mr. R. W. Magee Area Engineer Chevron U.S.A. Inc. P. O. Box .7-839 An~.~orage, Aiaska 99510 Ret Swanson River Unit SRU 32-33 WD Chevron U.S.A. Inc. Permit No. 80-115 Sur. Loc.~ 1950~S, 2200~W of NE cr Sec. 33, TSN, R9W, SBM. Bottomhole Loc. ~ S A M E Dear Mr. Magee~ Enclosed is the approved application for permit to drill the above referenced well. This permit to drill and complete does not constitute approval for disposal of fluids, such permit m~st be obtained ~rom the Alaska Department of Environmental Conservation. Well samples and a mud log are not r~uired. A directional survey is not required. If' available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code}. Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ..? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. W. Magee -2- Swanson River Unit SRU 32-33 WD October 8, 1980 commencing operations you may be contacted by a representative of the Department of EnvirOnmental Conservation. Pursuant to AS '38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in-scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like.to be notified so that a repre- sentative of the commission may be present to witness testing of' blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, H~le H. X~iiton Chat~ of 'BY O'~9~R OF TH~ CO~SSION Alaska 0il & Gas Conse~at~on Co~ission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmenta! Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. STATE OF ALASKA ALASKA G.'- AND GAS CONSERVATION COi...,'llSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [~ STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator CHEVRON U.S.A. INC. 3, Address P. 0. Box 7-839 Anchorage, Alaska 99510 4. Location ofwellat surface 1950' south and 2200' west of NE corner of Sec. 33, T8N, R9W, SB&M At top of proposed producing interval same At total depth same 5. Elevation in feet (indicate KB, DF etc.) 172' GL 6. Lease designation and serial no. A-028399 9. Unit or lease name Swanson River Unit 10. Well number SRU 32-33 WD 11. Field and pool Swanson River Field 12. Bond information (see 20 AAC 25.025) Type nationwi de Surety and/or number SL 6205862 13. Distance and direction from nearest town 16.5 miles N..of Kenani"es 16. Proposed depth (MD & TVD) 2450' feet 14. Distance to nearest property or lease line 1900 feet 17, Number of acres in lease 1120 Amount $150,000 15. Distance to nearest drilling or completed well SRll 32-33 18. Approximate spud date 10/80 19. If deviated (see 20 AAC 25.050) . · 120. Anticipated pressures 0 ' psig@~Surface KICK OFF POINT NA feet. MAXIMUM HOLE ANGLE oI (see 20 AAC 25.035 (c) (2) 1_030 psig@L ?~-_-~0 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Ho Casing Weight le 1~,,3/4 23# 22. Describe proposed program: Grade lC CASING AND LINER I >upling T&C Length 2450' M D TOP TV D I 0 MD BOTTOM TVD 12450 (include stage data) Driven 700 sx single.s We propose to dril SRU 32-33 WD for the purpose of waste water disposal attached program. '~, i~~!.: ".~ per the 23. I hereby c~he foregoing is true and correct to the best of my knowledge The space below for Commission use f Area Engineer CONDITIONS OF APPROVAL DATE Samples required Mud log required [qYES ~O []YES ~NO Permit number Approval date g'o'-/ I,.f , 0/08/80 APPROVED BY~ Directional Survey required APl number :YES ~'NO 50--/3~- ~-- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSl ON ER DATE by order of the Commission October 8, 1980. Form 10-401 Submit in triplicate le 2. 3. 4. 5, '6. 7. 8. PROGRAM Drive 10 3/4" conductor to + 80'. Install 10", 2000 psi diverter. Drill 9 7/8" hole to 2450'. Condition mud for logs. Run Dual-Induction Focused log and Compensated Densilog-Compensated Neutron-Gamma Ray log from 2450' to shoe of surface casing. a. Obtain 1/2 gallon sample of drilling fluid prior to pulling out for log. b. Use 10 MV SP, 0-50 ohm-meters scale on linear DIFL, 0-60% porosity scale, and 0-100 API units on GR. Run and cement 7", 23#, K-55, LT&C casing at 2450' as follows: a. Use float shoe and float collar, float collar' to be one joint above shoe. b. Install centralizers 10' above shoe, on top of shoe joint, and on every other joint for first 10 joints. c. Cement in single stage with sufficient Class "G" cement with 2% calcium chloride to obtain returns to surface. (Estimate 800 cu. ft. required including 20% excess.) d. Displace wi th lease water. WOC 4 hours. Land casing and install tubing head. RIH, locate top of cement. Perforate casing and run packer and fiberglass injection string per supplementary program to be issued by Area Engineer. BLOWOUT PREVENTION REQUIREMENTS: A. 10", 2000 psi diverter system installed on conductor. B. Surface holes for surrounding oil wells drilled with 76-82 pcf mud and no BOP, did not encounter shallow gas above 3400'. 0 Surface Casing Max. Mud Well No. Depth, Ft. Wt.., PCF SRU 41-33 3025 81 SRU 34-28 2038 76 SCU 33-33 3400 80 SRU 32,33 3000 82 Static reservoir pressure in proposed injection interval is 1030 psi at 2450'. An 80 pcf mud will over balance formation pressure by 330 psi at 2450'. LOST CIRCULATION' None anticipated, however, LCM should be kept on hand at all times. DRILLING FLUID' Lightly treated native clay base, 78-80 pcf. No fluid loss or solids concentration requirements. Viscosity and gel strength as required for efficient hole cleaning, pH' 8.5-9.5. FIGURE i11-1 DIVERTER-PREVENTER HOOKUP FILL-UP LINE TO MUD-GAS SEPARATOR I FLOW LINE VALVE VALVE (~ EXTEND LINES I IN 'DIFFERENT 'DIRECTIONS TO ,~U LAB DIVERTER · .. _ ~ ___J DRILLING ,~ : I, SP0 0 L ENSURE DOWNWIND DIVERSl0N VALVE DRIVE PIPE OR CONDUCTOR .... CASING NOTE: ALL LINES AND VALVES SHALL MEET ALL .. REGULATIONS THAT APPLY. (SEE PAGE I11-1, A.I.a) SRU 32-33WD PROPOSAL FOR WATER DISPOSAL Pertinent data concerning this proposal · 1. Formation water quality: approximately 4200 ppm TDS (Fig 1). 2. SRF waste water: approximately 21,100 ppm TDS (Fig. 2). 3. Total water production at SRF' approximately 10500 bwpd, maximum. 4. Proposed injection interval' Upper Sterling sand, Kenai formation, between 2100' and 2450' (.see attached structure contour map AA-155 and cross sections A-A' and B-B'). 5. Estimated injection pressure' less than 1000 psig, surface. 6. Estimated injection rate' 5250 bwpd overage, 10500 bwpd maximum. 0 Chemical treatment' A. At waste water plant, 12 gal./day of Magna "B" acrylic aldehyde bacteri aci de. Be At 1-4 tank setting, 12 gal./day of Cronox 607 water soluble amine salt corrosion inhibitor. C, At 1-33 tank setting, 5 gal./day of at Colnox 164W-50 organic phosphanate scale inhibitor. Be Injection interval monitoring' Periodic radioactive tracer surveys will be run to ensure that injected water is confined to the proper interval. 'CF EYJJEAL & GEOLOGICAL LA O ATOR!E$ OF ALAS'XA, P C. -- 'p~i4-1276 TELEPHONE (907)-279-4014 ANCHORAGE INDUSTRIAL CENTER Anchorage, Alaska 99509 274-3364 5633 B Street Soldotna Creek Unit Alaska WATER ANALYSIS REPORT DAT~ June 26, 1980 LOCATION FOiRS/ATION XNT~RVAT, BA~PL~ FRO~- Produced Water 20109 4073-2 " Samole taken June 16t 1980 ~m~2 ~ co~cLu~zoN~' ' Salinitsf_as NaC1 ~_~ 5525 95 2470 4O 240.34 s~ ...... 2.43 CNN~ ........ 123.25 ~~ ..... 3.29 B~~ ..... -- H~4ro=k~,~ ..... 369.31 T~ A=~ 21098 ' 8p*~A~'!.= ~h~, @ ~°~.: 20663 O I~~'' .... 5.9 - c ~L~-~ .... ~')~Cl o~~~, m:(/l ....... O~ p~I .......... 5 12200 0 1535 0.10 344.04 25.17 369.31 -- N~ M~ '": WELt NO. Se, U 221-33 COMPANY $ YAHOARD OIL LOCATION A L .", -~ K A '' SAMPLE SOURCE ZONE CO O~L WATER B/D GAS MCF/D OIL GRAVITY METHOD 109 1536 ~'"~'~P L E DATE I, . ORT DATE LABORATORY S~PLED BY ANALYST 854 RADICALS sr, u~u:,, C ~LC I Ut4 M .~ -"..; '~ E .S I U H SULFAYE CA '~ BO'~A rE BICARBUNAFE ' TO [AL PARTS PER MIt[ION 1293.4 98.2 ° 76.9 ' 2.7 ~866.3 O. '. 902.~ 6~39.9 O. E,'~U!VAL~-N[ SALT = £HLD, RIN[fY = L7g.72 REACTING VALUE ~Quiv. e~,~ Mit[i~ 56.26 4.90 6.33 0.06 52.64 O. .. 14.79 . 134.97 · -215.0 G/G,' RESISTIVITY =-L.450 OHH-NET'ER G/G~ SPECIFIC'GRAVITY :1.0045, PH = 7.9/ II¥ORU(;EN SULFIDE ABSENt REACTING VALL~E 41.68 · 3.63 '4.69 0.04 " 39.00 O- ' 10.96. 100.00 AT 77 DEG F TAB1L'IFY AT 1.00° F. -J-/,.20 No+K TICKELL GRAPH Ca+ Mg+ Bo+ $r ' % REACTinG VALUE · STANDARD OIL CO. of C~LI£,W.O I.,Opor S~onson River Unil 221-33 CO:) '~' ' K ' X HCO3 ~.~,~v. ~o~ b~ ~,.,.,, co,. s~.~ ~.~.~.s.~.~'~.. ~ .. / o,,. .560'S.~ 2110'E. Surfoco Loco~ion CI SIGNED. R Company CHECK LIST FOR NEW %~LL PERMITS I_te~_ ~ove Date (3) A~d_n.(~-._/<~ 4-~ 1. Is the permit fee attached ................................... ....... 2. Is well to be located in a defined pool ............................. Yes 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. 5. Is well located proper distance frcm other wells .................... 6. Is sufficient undedicated acreage available in this pool ............ Lease & Well No. ~ No Remarks 7. Is well to be deviated ............................................. 8. Is operator the only affected party ................................. ~. 9. Can permit be approved before ten-day wait .......................... /~_~ . .... 10. Does operator have a bond in force ........ 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ...................... .................. ~ __ (4) Casg. .~ 14. Is enough cement used to circulate on conductor and surface ......... '~ ~o-7-~ 15. Will cement tie in surface and intermediate or production strings ... ~ __ 16. Will cement cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... ~ 18. Will all casing give adequate safety in collapse, tension and burst.. _? .... ( 5 )B OPE ~ 19. Does BOPE have sufficient pressure rating - Test to Approval Reccmmended: ~o0'0 psig .. ? Additional Requirements: Engin~9~in9: rev: 03/05/80 Well Histo.ry 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. ,o 3 4 } 5 7 ,') 8 9 10 ~2 ~3 ~5 22 25 *'** MSP 086 BEC~TSC5 HAVING EXTENDED TASK NAME HS/82.2~gl.22:3 =52 HAS 13 DATA STRINGS LISTED BELOW I , G R F 0 N 1. N S P '7 ~ o ~ 8 255 ~., 5 ~ i~ o 5 ~ - 99 ~ 25 B 2 :~ .¢ o q ? ~ 8 S L M L I S 22 3822 ~ ~ I CALIFDN1 MSP 7~,, ~-¢ 2%5~o5¢ ~o5~ -'99! 25~ 2~,,,5.325 8 SLMLIS ~23822~ t NPHIFONi MSF 7a,,,~ g 255;.~°5¢ ~.58 -99 25¢: '75,,769t] 8 SLI~LIS 2238:228~ ,JO8 BECWTSC5 WITH CHRGE NO. S'7~,~95 STEP NO,., ~ ON STEM C~.~ A'T 22:52:8 USING 52~X/ 8~2,K BYTES MEMORY *** 28 ,) 29 3O 33 34 3~ ,48 46 )47 42 4'3! 4,4,I '1 4 ,,3 5 ? ~2 ) ~7 ~8 20 2~ )23 24 25 ) ~ 28 ) 2~ 3O ~6:~: .19 *** HSP JOB: BECMTSC~ HAVT.G EXTE"DED TASK NAHE HAS 15 DATA STRINGS LISTED 4 TRACE DATA STRINGS ~, ~ ... . . . . . . .., . .. ., , . . . .. . . . . ,. ., .... ... . . . , . . . , . . 9 :! SPDIL1 ~SP 74~.o ~ 255~.5~ B.5~ -12! i,,118 -9.1 671 8 SL~LZS I ILODIL 1 ~SP T~$g9 255g.Sg g. 5~ 2* 6121 872~7~2 8 SLRLi:S ~ IL~DIL.I ~SP 7~ge 255~.5~ a. 5g 5- 357 99999~ 8 SLNLIS 1 LLBI H 7, 8'g *** S g *** *'***'* HSP dOB BEC:MTSC~ HAVING TASK NAHE '*** d~B BECMT.SC~I ~ilTH CHRGE NO:,, S?~g95 .9 H: 'ED 33- 34 STEP NO. ~ ON SYSTE)I CI3~ AT 22.'27=58 USING 52~/ 152K BYTES NEROR¥ *** 36 48 37 ' ....................................................... ~ : ............... -- ...................... - - .... ~: ........ ]49j - 50 )38 ~ 5~ 39 __ 52 61 62