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Home My WebLink About161-032Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 21-22 (PTD 161-032) PERF-DRIFT 01-21-2021 Please include current contact information if different from above. Received by the AOGCC 02/16/2021 PTD: 1610320 E-Set: 34702 02/16/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,012 feet 10,970 feet true vertical 11,012 feet 10,922 (fill) feet Effective Depth measured 10,922 feet 10,714 feet true vertical 10,922 feet 10,714 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 10,417' MD/TVD Packers and SSSV (type, measured and true vertical depth)Brown Pkr; N/A 10,714' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email:todd.sidoti@hilcorp.com Contact Phone:777-8443 Senior Engineer:Senior Res. Engineer: Burst 6,340psi 33' 3,008'3,070psi Collapse 1,510psi 3,830psi Casing Structural 22" 11-3/4" Length 33' 3,008' 11,012' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 1,420 Casing Pressure Liner 2 12 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-532 320 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 8 Gas-Mcf 1,320 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 161-032 50-133-10149-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 290735 Swanson River Unit (SRU) 21-22 N/A FEDA 028406 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Hemlock Oil PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"11,012'11,012' WINJ WAG 1 Water-Bbl MD 33' 3,008' 820 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:56 am, Feb 16, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.02.15 11:22:24 -09'00' Taylor Wellman (2143) BJM 2/16/21 RBDMS HEW 2/16/2021 DSR-2/16/21 Rig Start Date End Date E-Line 1/21/21 1/22/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 21-22 50-133-10149-00-00 161-032 01/21/2021 - Thursday AK E-line arrives, complete PTW/JSA. PJSM/discuss job with crew. Rig up E-line. PT 250 psi low/3,000 psi high. RIH W/ 2'' x 30' HSD gun loaded with CONNEX charges, 6 SPF 60 degree phase to 10,193' (gaslift mandrel), pull up hole W/ no over- pull to ~10,000'. RIH then sit down at 10,268' sit down same spot 6 times at diffrent speeds. No overpull. Discuss options with engineer. POOH Decided to run LIB to check for obstruction. Re-head E-line, stand up lubricator. RIH W/ 1-11/16'' weightbar, spangs, 1.75'' weightbar, 1.75'' LIB to 10,712'. Did not leave tubing tail. POOH No obstruction in tubing, no mark on LIB. E-line lay down lubricator for night. Turn well over to production. Plan forward: run 3 guns tomorrow(2'' x 10' each). 01/22/2021 - Friday E-line arrives at location. Complete PTW/JSA. Discuss job scope with crew. Begin rigging up to well. PT 250 psi low/3,000 psi high. Shut well in. RIH w/ 2'' x 10' HSD gun loaded with CONNEX charges, 6 SPF, 60 degree phase. run correlation pass. Send to town. Shift log 10' down. spot gun and perforate 10,783'-10,793' Tubing pressure when guns fired: 275psi, 5 min: 275psi, 10 min:277psi, 15min: 278psi. POOH. OOH W/perf gun. All shots fired. Build next 2'' x 10' gun. RIH w/ 2'' x 10' HSD gun loaded with CONNEX charges, 6 SPF, 60 degree phase. run correlation pass. Send to town. On depth. No shift required. Spot gun and perforate 10,773'-10,783' Tubing pressure when guns fired: 281, 5 min: 281psi, 10 min: 283psi, 15 min: 285psi POOH. OOH w/ perf gun. All shots fired. Build next 2''x10' gun. RIH w/ 2'' x 10' HSD gun loaded with CONNEX charges, 6 SPF, 60 degree phase. Run correlation pass. Send to town. On depth. No shift required. Spot gun and perforate 10,763'-10,773' Tubing pressure when guns fired: 286psi, 5 min: psi, 10 min: psi, 15 min: 287psi. POOH. OOH W/ perf gun. All shots fired. E-line starts rigging down. Turn well over to production. E-line leaves location. Daily Operations: Downhole Revised: 5/08/13 Updated by DMA 01-31-21 SCHEMATIC Swanson River Unit Well: SRU 21-22 Completion Ran: 5/11/2012 PTD# 161-032 API: 50-133-10149-00 TD = 11,012’ PBTD = 10,970’ Max Deviation = 3° @ 6,468’ RKB: 300’ / GL: 285’ AMSL KB – THF: 20.77’ 1 2 7 JEWELERY DETAIL No. Depth ID OD Item 1 21’ 2.441” - Tubing Hanger 2 3,238’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 3 5,803’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 4 7,620’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 5 8,805’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 6 9,641’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 16 7 10,193’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 16 8 10,621’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 20 9 10,669’ 2.313” 3.668” X Nipple 10 10,714’ 2.500” 5.875” AS1-X Mechanical Packer (8k Compression Set) 11 10,718’ 2.441” 3.668” WLEG PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Gun Size Date Comments G2 10,763’ 10,793’ 10,763’ 10,793’ 30’ 6 2” CONNEX 1/22/21 Open WSO 10,800' 10,801' 10,800' 10,801' 1' 5 12/27/61 Open H-1 10,802' 10,816' 10,802' 10,816' 14' 4 12/28/61 Open H-1 10,812’ 10,828’ 10,812’ 10,828’ 16’ 6 3-1/8” HC 5/10/12 Open H-2 10,826' 10,849' 10,826' 10,849' 23' 4 12/31/61 Open H-2 10,836’ 10,860’ 10,836’ 10,860’ 24’ 6 3-1/8” HC 5/10/12 Open H-3 10,879’ 10,909’ 10,879’ 10,909’ 30’ 6 3-1/8” HC 5/09/12 Open H-3 10,890' 10,895' 10,890' 10,895' 5' 4 12/30/61 Open H-5 10,913' 10,922' 10,913' 10,922' 9' 6 3-1/8” HC 5/09/12 Open 22” 33’ 11-3/4” 3,009’ 7” 11,012’ CBL TOC 9,470’ 3 4 WSO 5 H-1 6 H-2 H-3 H-5 9 11 8 10 CASING DETAIL Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22” Conductor - - - Surf. 33’ - Yes Surf. 11-¾” Surface 47 J-55 8RD Surf. 1,481’ 16” 3,030’ 1,500 sx Surf. DV Collar 1,481’ 1,483’ 11-¾” Surface 47 J-55 8RD 1,483’ 3,009’ 500 sx 1,481’ Est 7” Production 29 N-80 BTC Surf. 90’ 9-и” 11,012’ 1,100 sx 5,180’ CBL 23 90’ 4,699’ 29 P-110 LTC 4,699’ 4,706’ 26 N-80 4,706’ 6,636’ 29 6,636’ 7,539’ 29 P-110 7,539’ 7,545’ DV Collar 7,545’ 7,547’ 7” Production 29 P-110 LTC 7,547’ 7,554’ 600 sx 9,470’ CBL 29 N-80 7,554’ 8,464’ 29 P-110 8,464’ 11,012’ TUBING DETAIL Conn ID Cplg OD 2.875” Tubing 6.5 L-80 8RD Surface 10,715’ 2.441” 3.668” CBL TOC 5,180’ SL Tag 10,922’ 1/08/21 DV Collar 7,545’ G2 Open1/22/212” CONNEX6G210,763’10,793’10,763’10,793’30’ 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHUBBBBBBBBBBBBBBBBBBB 2SHUDWRU1DPH&XUUHQW:HOO&ODVV3HUPLWWR'ULOO1XPEHU ([SORUDWRU\'HYHORSPHQW $GGUHVV6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU ,ISHUIRUDWLQJ:HOO1DPHDQG1XPEHU 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ϭ͘Z/,ƚŽƚŽƉŽĨĨŝůůΛϭϬ͕ϴϵϬĂŶĚĨŝƐŚͬďĂŝů͘ Ϯ͘ĂŝůƚŽϭϬ͕ϵϮϮ͛ŽƌĂƐĚĞĞƉĂƐƉŽƐƐŝďůĞ͘ ϯ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶĨŽƌĨůŽǁƚĞƐƚ͘ ͲůŝŶĞWƌŽĐĞĚƵƌĞ ϭ͘D/ZhͲůŝŶĞ͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯ͕ϬϬϬƉƐŝŚŝŐŚ͘ Ϯ͘WĞƌĨŽƌĂƚĞƚŚĞĨŽůůŽǁŝŶŐŝŶƚĞƌǀĂůǁŝƚŚϮ͟,^ŐƵŶƐůŽĂĚĞĚǁŝƚŚKEEyĐŚĂƌŐĞƐĂƚϲ^W&ϲϬĚĞŐƌĞĞ ƉŚĂƐŝŶŐ͗ Per CO 123A, the Tyonek G sands are included in the Hemlock Oil Pool, so there's no downhole commingling issue with this proposed work. DSR-12/22/2020 tĞůůWƌŽŐŶŽƐŝƐ tĞůů͗^ZhϮϭͲϮϮ ĂƚĞ͗ϭϬͬϵͬϮϬϮϬ ^ĂŶĚDdŽƉDŽƚƚŽŵdsdŽƉdsŽƚƚŽŵdŽƚĂů&ŽŽƚĂŐĞ 'ϮϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϯϬ͛ Ă͘WĞƌĨŽƌĂƚĞǁŝƚŚƚŚĞǁĞůůƐŚƵƚŝŶ͕ǁĞǁŝůůŶĞĞĚƚŽŬŝĐŬƚŚĞǁĞůůŽĨĨǁŝƚŚŐĂƐůŝĨƚĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͘ ď͘ŽƌƌĞůĂƚĞƵƐŝŶŐKƉĞŶ,ŽůĞŽƌƌĞůĂƚŝŽŶ>ŽŐƉƌŽǀŝĚĞĚďǇ'ĞŽůŽŐŝƐƚ͘^ĞŶĚƚŚĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐƚŽ 'ĞŽůŽŐŝƐƚ;:ĞĨĨEĞůƐŽŶͿĂŶĚZĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌ;DĞƌĞĚǇƚŚZŝĐŚĂƌĚƐͿĨŽƌĐŽŶĨŝƌŵĂƚŝŽŶ͘ Đ͘/ŶƐƚĂůůƌǇƐƚĂůŐĂƵŐĞƐ;ŽƌǀĞƌŝĨǇWdƐĂƌĞŽƉĞŶƚŽ^ͿďĞĨŽƌĞƉĞƌĨŽƌĂƚŝŶŐ͘ZĞĐŽƌĚĂƚƵďŝŶŐ ^ƵƌĨĂĐĞƉƌĞƐƐƵƌĞďĞĨŽƌĞĞĂĐŚƌƵŶĂŶĚĂĨƚĞƌĞĂĐŚŐƵŶĨŝƌŝŶŐŽĨϱ͕ϭϬ͕ϭϱŵŝŶƌĞĂĚŝŶŐŝŶƚĞƌǀĂůƐ͘ Ě͘dŚĞ'ϮdǇŽŶĞŬ^ĂŶĚŝƐƉĂƌƚŽĨƚŚĞ,ĞŵůŽĐŬKŝůWŐŽǀĞƌŶĞĚďǇŽŶƐĞƌǀĂƚŝŽŶKƌĚĞƌϭϮϯ͘ ϯ͘WKK,͘ZDKĞͲůŝŶĞ͘ ϰ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ ϭ͘ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϯϬ͛ 'ϮdǇŽŶĞŬ^ĂŶĚŝƐƉĂƌƚŽĨƚŚĞ,ĞŵůŽĐŬKŝůWŐŽǀĞƌŶĞĚďǇŽŶƐĞƌǀĂƚŝŽŶKƌĚĞƌϭϮϯ͘ Downhole Revised: 5/08/13 Updated by STP 12/11/13 ACTUAL SCHEMATIC Swanson River Unit Well: SRU 21-22 Completion Ran: 5/11/2012 PTD# 161-032 API: 50-133-10149-00 TD = 11,012’ PBTD = 10,970’ Max Deviation = 3° @ 6,468’ RKB: 300’ / GL: 285’ AMSL KB – THF: 20.77’ 1 2 Jewelry Detail No. Depth ID OD Item 1 21’ 2.441” - Tubing Hanger 2 3,238’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 3 5,803’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 4 7,620’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 5 8,805’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 12 6 9,641’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 16 7 10,193’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 16 8 10,621’ 2.347” 4.750” Gaslift Mandrel, ZSFO-1, Port 20 9 10,669’ 2.313” 3.668” X Nipple 10 10,714’ 2.500” 5.875” AS1-X Mechanical Packer (8k Compression Set) 11 10,718’ 2.441” 3.668” WLEG Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/27/61 WSO 10,800' 10,801' 10,800' 10,801' 1' 5 12/28/61 H-1 10,802' 10,816' 10,802' 10,816' 14' 4 5/10/12 H-1 10,812’ 10,828’ 10,812’ 10,828’ 16’ 6 3-1/8” HC 12/31/61 H-2 10,826' 10,849' 10,826' 10,849' 23' 4 5/10/12 H-2 10,836’ 10,860’ 10,836’ 10,860’ 24’ 6 3-1/8” HC 12/30/61 H-3 10,890' 10,895' 10,890' 10,895' 5' 4 5/09/12 H-3 10,879’ 10,909’ 10,879’ 10,909’ 30’ 6 3-1/8” HC 5/09/12 H-5 10,913' 10,922' 10,913' 10,922' 9' 6 3-1/8” HC 22” 33’ 11-3/4” 3,009’ 7” 11,012’ CBL TOC 9,470’ 3 4 WSO 5 H-1 H-2 H-3 H-5 Casing Detail Size Type Wt Grade Conn Top Btm Hole Cmt Cmt Top 22” Conductor - - - Surf. 33’ - Yes Surf. 11-¾” Surface 47 J-55 8RD Surf. 1,481’ 16” 3,030’ 1,500 sx Surf. DV Collar 1,481’ 1,483’ 11-¾” Surface 47 J-55 8RD 1,483’ 3,009’ 500 sx 1,481’ Est 7” Production 29 N-80 BTC Surf. 90’ 9-и” 11,012’ 1,100 sx 5,180’ CBL 23 90’ 4,699’ 29 P-110 LTC 4,699’ 4,706’ 26 N-80 4,706’ 6,636’ 29 6,636’ 7,539’ 29 P-110 7,539’ 7,545’ DV Collar 7,545’ 7,547’ 7” Production 29 P-110 LTC 7,547’ 7,554’ 600 sx 9,470’ CBL 29 N-80 7,554’ 8,464’ 29 P-110 8,464’ 11,012’ Tubing Detail Conn ID Cplg OD 2.875” Tubing 6.5 L-80 8RD Surface 10,715’ 2.441” 3.668” CBL TOC 5,180’ SL Tag 2.0” GR 10,891’ 5/08/13 DV Collar 7,545’ ŽǁŶŚŽůĞZĞǀŝƐĞĚ͗ϱͬϬϴͬϭϯ hƉĚĂƚĞĚďǇ^dWϭϮͬϭϭͬϭϯ WZKWK^^,Dd/ ^ǁĂŶƐŽŶZŝǀĞƌhŶŝƚ tĞůů͗^ZhϮϭͲϮϮ ŽŵƉůĞƚŝŽŶZĂŶ͗ϱͬϭϭͬϮϬϭϮ WdηϭϲϭͲϬϯϮ W/͗ϱϬͲϭϯϯͲϭϬϭϰϵͲϬϬ dсϭϭ͕ϬϭϮ͛ WdсϭϬ͕ϵϳϬ͛ DĂǆĞǀŝĂƚŝŽŶсϯΣΛϲ͕ϰϲϴ͛ Z<͗ϯϬϬ͛ͬ'>͗Ϯϴϱ͛D^> <ʹd,&͗ϮϬ͘ϳϳ͛ ϭ Ϯ :ĞǁĞůƌǇĞƚĂŝů EŽ͘ĞƉƚŚ/K/ƚĞŵ ϭϮϭ͛Ϯ͘ϰϰϭ͟ͲdƵďŝŶŐ,ĂŶŐĞƌ Ϯϯ͕Ϯϯϴ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϮ ϯϱ͕ϴϬϯ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϮ ϰϳ͕ϲϮϬ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϮ ϱϴ͕ϴϬϱ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϮ ϲϵ͕ϲϰϭ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϲ ϳϭϬ͕ϭϵϯ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϭϲ ϴϭϬ͕ϲϮϭ͛Ϯ͘ϯϰϳ͟ϰ͘ϳϱϬ͟'ĂƐůŝĨƚDĂŶĚƌĞů͕^&KͲϭ͕WŽƌƚϮϬ ϵϭϬ͕ϲϲϵ͛Ϯ͘ϯϭϯ͟ϯ͘ϲϲϴ͟yEŝƉƉůĞ ϭϬϭϬ͕ϳϭϰ͛Ϯ͘ϱϬϬ͟ϱ͘ϴϳϱ͟^ϭͲyDĞĐŚĂŶŝĐĂůWĂĐŬĞƌ;ϴŬŽŵƉƌĞƐƐŝŽŶ^ĞƚͿ ϭϭϭϬ͕ϳϭϴ͛Ϯ͘ϰϰϭ͟ϯ͘ϲϲϴ͟t>' WĞƌĨŽƌĂƚŝŽŶ,ŝƐƚŽƌǇ ĂƚĞŽŶĞdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿŵƚƐƉĨŽŵŵĞŶƚƐ ϭϮͬϮϳͬϲϭt^KϭϬ͕ϴϬϬΖϭϬ͕ϴϬϭΖϭϬ͕ϴϬϬΖϭϬ͕ϴϬϭΖϭΖϱ ϭϮͬϮϴͬϲϭ,ͲϭϭϬ͕ϴϬϮΖϭϬ͕ϴϭϲΖϭϬ͕ϴϬϮΖϭϬ͕ϴϭϲΖϭϰΖϰ ϱͬϭϬͬϭϮ,ͲϭϭϬ͕ϴϭϮ͛ϭϬ͕ϴϮϴ͛ϭϬ͕ϴϭϮ͛ϭϬ͕ϴϮϴ͛ϭϲ͛ϲϯͲϭͬϴ͟, ϭϮͬϯϭͬϲϭ,ͲϮϭϬ͕ϴϮϲΖϭϬ͕ϴϰϵΖϭϬ͕ϴϮϲΖϭϬ͕ϴϰϵΖϮϯΖϰ ϱͬϭϬͬϭϮ,ͲϮϭϬ͕ϴϯϲ͛ϭϬ͕ϴϲϬ͛ϭϬ͕ϴϯϲ͛ϭϬ͕ϴϲϬ͛Ϯϰ͛ϲϯͲϭͬϴ͟, ϭϮͬϯϬͬϲϭ,ͲϯϭϬ͕ϴϵϬΖϭϬ͕ϴϵϱΖϭϬ͕ϴϵϬΖϭϬ͕ϴϵϱΖϱΖϰ ϱͬϬϵͬϭϮ,ͲϯϭϬ͕ϴϳϵ͛ϭϬ͕ϵϬϵ͛ϭϬ͕ϴϳϵ͛ϭϬ͕ϵϬϵ͛ϯϬ͛ϲϯͲϭͬϴ͟, ϱͬϬϵͬϭϮ,ͲϱϭϬ͕ϵϭϯΖϭϬ͕ϵϮϮΖϭϬ͕ϵϭϯΖϭϬ͕ϵϮϮΖϵΖϲϯͲϭͬϴ͟, d'ϮϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϯϬ͛ϲϮ͟KEEy ϮϮ͟ ϯϯ͛ ϭϭͲϯͬϰ͟ ϯ͕ϬϬϵ͛ ϳ͟ ϭϭ͕ϬϭϮ͛ >dK ϵ͕ϰϳϬ͛ ϯ ϰ t^K ϱ ,Ͳϭ ,ͲϮ ,Ͳϯ ,Ͳϱ ĂƐŝŶŐĞƚĂŝů ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶdŽƉƚŵ,ŽůĞŵƚŵƚ dŽƉ ϮϮ͟ŽŶĚƵĐƚŽƌͲͲͲ^ƵƌĨ͘ϯϯ͛ͲzĞƐ^ƵƌĨ͘ ϭϭͲв͟^ƵƌĨĂĐĞϰϳ:ͲϱϱϴZ^ƵƌĨ͘ϭ͕ϰϴϭ͛ϭϲ͟ ϯ͕ϬϯϬ͛ ϭ͕ϱϬϬƐǆ^ƵƌĨ͘sŽůůĂƌϭ͕ϰϴϭ͛ϭ͕ϰϴϯ͛ ϭϭͲв͟^ƵƌĨĂĐĞϰϳ:ͲϱϱϴZϭ͕ϰϴϯ͛ϯ͕ϬϬϵ͛ϱϬϬƐǆϭ͕ϰϴϭ͛Ɛƚ ϳ͟WƌŽĚƵĐƚŝŽŶ ϮϵEͲϴϬ d ^ƵƌĨ͘ϵϬ͛ ϵͲи͟ ϭϭ͕ϬϭϮ͛ ϭ͕ϭϬϬƐǆϱ͕ϭϴϬ͛ > ϮϯϵϬ͛ϰ͕ϲϵϵ͛ ϮϵWͲϭϭϬ >d ϰ͕ϲϵϵ͛ϰ͕ϳϬϲ͛ ϮϲEͲϴϬϰ͕ϳϬϲ͛ϲ͕ϲϯϲ͛ Ϯϵϲ͕ϲϯϲ͛ϳ͕ϱϯϵ͛ ϮϵWͲϭϭϬϳ͕ϱϯϵ͛ϳ͕ϱϰϱ͛ sŽůůĂƌϳ͕ϱϰϱ͛ϳ͕ϱϰϳ͛ ϳ͟WƌŽĚƵĐƚŝŽŶ ϮϵWͲϭϭϬ >d ϳ͕ϱϰϳ͛ϳ͕ϱϱϰ͛ ϲϬϬƐǆϵ͕ϰϳϬ͛ >ϮϵEͲϴϬϳ͕ϱϱϰ͛ϴ͕ϰϲϰ͛ ϮϵWͲϭϭϬϴ͕ϰϲϰ͛ϭϭ͕ϬϭϮ͛ dƵďŝŶŐĞƚĂŝůŽŶŶ/ƉůŐK Ϯ͘ϴϳϱ͟dƵďŝŶŐϲ͘ϱ>ͲϴϬϴZ^ƵƌĨĂĐĞϭϬ͕ϳϭϱ͛Ϯ͘ϰϰϭ͟ϯ͘ϲϲϴ͟ >dK ϱ͕ϭϴϬ͛ ^>dĂŐ Ϯ͘Ϭ͟'Z ϭϬ͕ϴϵϭ͛ ϱͬϬϴͬϭϯ sŽůůĂƌ ϳ͕ϱϰϱ͛ 'Ϯnew perfs attempt to bail fill to 10922 ft d'ϮϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϭϬ͕ϳϲϯ͛ϭϬ͕ϳϵϯ͛ϯϬ͛ϲ Ϯ͟KEEy STATE OF ALASKA ALAI OIL AND GAS CONSERVATION COMMIS 'ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon [j Repair Well Lf Plug Perforations Li Perforate U Other U Replace tubing Performed: Alter Casing ❑ Pull Tubing IS Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ and GLV's Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ , 161 -032 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic Service ❑ 6. API Number: AK 99503 50- 133 - 10149 -00 -00 7. Property Designation (Lease Number): « 8. Well Name and Number: Swanson River Unit FEDA028406 Swanson River Unit (SRU) 21 -22 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Swanson River Field / Hemlock Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,012 feet Plugs measured 10,970 feet true vertical 11,012 feet Junk measured , 10,923 (fill) feet Effective Depth measured 10,923 feet Packer measured 10,714 feet true vertical 10,923 feet true vertical 10,714 feet Casing Length Size MD TVD Burst Collapse ' � JUL 2 4 2[1 Structural � c, Conductor Surface 3,008' 11 -3/4" 3,008' 3,008' 3,070 psi 1,510 psi Intermediate Production 11,012' 7" 11,012' 11,012' 6,340 psi 3,830 psi Liner Perforation depth Measured depth 10,812'- 10,828'; 10,836'- 10,860'; 10,879'- 10,909'; 10,913'- 10,922' feet True Vertical depth 10,812'- 10,828'; 10,836'- 10,860; 10,879' - 10,909'; 10,913'- 10,922' feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# / L -80 10,714' 10,714' 10,714'MD Packers and SSSV (type, measured and true vertical depth) AS -1X N/A RECEIVED 10,714' TVD N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A JUN 0 8 2012 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 20 25 650 1,225 375 2 Subsequent to operation: 20 25 1,000 1,620 375 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development el - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil • El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Phone 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature /". Phone 7 77- b'Yo 5- Date (eN1Z. RSDMS JUN 122012' f' v '-i # 7lzt/ ' 7- Form 10 -404 Revised 11/2011 ` , Ii Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 21 -22: Pull tubing- redesign GLV 50- 133 - 10149 -00 161 -032 4/13/12 5/14/12 Daiy:Operati ns: 04/1/2012 Tuesday RU equipment and test as installed. RU to annular and bleed gas lift gas thru the gas buster while pumping produced water to the tubing, pump appx 72 bbls, well on vaccum. RU pump to Annulus and pump 140 bbls, well went to vaccum. SD pump. Install BPV. Remove tree. Begin NU BOP. 4/18/2012 - Wednesday Prepare for BOP test. Perform function test of BOP (250 psi low - 3,000 psi high), Koomey, choke and fire /gas alarm. Inspector arrived to conduct BOPE test. Several small leaks repaired. Added actuator on kill line. BOP's passed test, need to be replaced. Complete fire /gas system alarms. Replaced and checked by Aurora Well Service. 04/19/2012 - Thursday RU 2 accelerators, 1 hydraulic jar, 2 each 2 -7/8" pup joints and make up to hanger, work jars to free hanger. Pull hanger free at 108K. RU E -line, made GR run to 10,880', log thru assembly. Determine depth to cut 10,742'. POOH. Removed GR, make up radial torch cutter log and correlate at 10,742', Fire cutter. POOH w/E -line. RD equipment. Latch onto tubing pup. PU to 100K, sit down into hanger. PUH to 108K, tubing is free. PUH, removed hanger and thin walled pup joint. PUH w /first full joint. Break out and laid down joint. HU hoses to circulate thru choke. Circulated 450 bbls of produced fluids, recovered oil and gas. 04/20/2012 - Friday Check well, fluid attempting to U -Tube, fluid weights not balanced. Bullheaded down tubing, stablized well. POOH. I aying down tubing string with gas lift mandrels. Stacked on pipe racks. Pulled, laid out, tested and stacked old completions string. Pulled 244 joints of tubing and 6 gas lift mandrels. Installed TIW, closed pipe rams for night. 04/21/2012 - Saturday Pulled completion tubing from well and laid down 96 joints of 2 -7/8" 6.5# tubing and 1 gas lift mandrel, 1 sliding sleeve, 1 Brown safety joint. PU fishing tool string. Overshot (2- 7/8 "), pumped out sub, bumper jar, bowen overshot, 6 drill collars, acc jar, and crossover. Tallied and picked up new 2 -7/8" 6.5# tubing as work string and RIH w /fishing tools. Continued to tally and RIH with new tubing as workstring. 04/22/2012 - Sunday RIH w/ 2 -7/8" 6.5# tubing with BHA to top of Packer. Continued to tally, pick up, and make up work string. RIH w/ 329 Joints of tubing. Placed "90 feet of fill above packer. Removed one joint of tubing, PU TIW. Isolate tubing, move power swivel into position, prepare tanks and equipment to wash fill. SD operations for night. 04/23/2012 - Monday PU power swivel, made all connections, tested system and began circulating DH. Recovered fill (scale). PU joint and washed down. Washed to top of 6 foot pup joint and Brown packer. Latched, pulled 60K over and began jarring. Unable to release packer w/16 turns to right. Began jarring with 60K over, jars hitting good. Continuing to work at jarring packer free. • • 04/24/2012 - Tuesday POOH racking doubles in the derrick. Continued to trip pipe, OOH with BHA assembly, rack drill collars, remove BHA, added packer shoe, extension and added jars. Drilled collars. PU entire assembly. RIH with workstring. Ran 88 double stands in the well, SD for night, Approximate depth with BHA is 5,720.57'. Isolated pipe rams and TIW. 04/25/2012 - Wednesday RIH with BHA assembly and workstring (2 -7/8" 6.5# EUE tubing) on bottom with assembly. PU tubing stripper and install on the annular. Remove stripper, chase threads on Aurora Annular systems. Install power swivel and lower assembly to top of 6' pup joint. Tag top of packer. Begin milling operations on Brown HS -1 -16 packer. Recovered metal shavings. Wash down 2.5' and started HEC sweeps. Continue to mill over packer (mill down - 5'). Packer moving downhole. Chase packer assembly down - 10'. Circulated bottoms up. Added additional joint of tubing and continue to move packer down hole. Total depth from initial tag is 20', 10,755' from top of packer slips. SDFN. 04/26/2012 - Thursday Begin POOH with BHA, packer mill, racking doubles in the derrick. OOH with workstring and BHA. Remove packer shoe mill, remove and replace with BHA. Install new BHA with overshot to latch 2 -7/8" 6' pup on top of Brown HS -1 -16 Packer and RIH with workstring. Top of pup joint, pick up tubing swivel rotated on top of fish. Latch and pulled 120K packer moving up hole, hanging up in collars. Jarred on packer, still hanging up, turned 40 right hand turns and release weight, moving down hole. PUH, still hanging up rig up pumps. Circulating while moving packer up and down tight spot. Shut in for night, plan to rig up power swivel and rotate while PUH. 04/27/2012 - Friday Contacted AOGCC about upcoming BOP test. Jim Regg of AOGCC waived witness. RD tubing swivel and install power swivel. Working packer while rotating to the right. Attempted to move past casing collar. Turning constantly into the packer with no release, jarred up and reset packer into the collar. Jarred until packer is locked in. RU pumps. Circulate well clean, taking returns of fill consisting of scale, heavy oil and other debris. Shut off pump, release overshot. Remove power swivel and begin pulling workstring and BHA. POOH with workstring and BHA. Performed BOP test: 250 psi low / 3,000 psi hi h. 04/28/2012 - Saturday Make up packer mill shoe, and BHA assembly. Tighten all BHA assembly as per specifications, empty trip tank and begin RIH with milling assembly. RIH with BHA. On bottom, pick up power swivel and single joint, tag top of packer 10,755'. Hook up pumps begin circulating fluids, while turning on packer assembl. Mill down 2'. Continue milling down over packer. Milled down 3 additional feet, measurements puts the mill thru the lower slips. Continue to circulate. Top of 6' pup joint is tagging into top of extension crossover. Measurement indicates the lower slips are milled. Stop pumps, begin POOH. 04/29/2012 - Sunday OOH with workstring and BHA. Remove the packer mill and pick up the overshot. Make up the BHA and prepare to RIH. RIH with BHA to fish packer and tail pipe assembly. RIH and tag top of fish, rotate to right, move down hole additional 1'. Engage overshot. PU with additional weight. PU 2 doubles. Shut down for night. 04/30/2012 - Monday Open pipe rams, check for pressures. Remove TIW and prepare to pull BHA from well. POOH with workstring, BHA, and overshot. PU tubing spear, add BHA and RIH to top of fish. Rotate into the fish, latch and PUH to set spear. Jarring at 60K over Fish will not move up hole. Set down weight and moving down hole. Added two additonal joints. Top of fish at 10,833' MD from rotary. Bottom of fish is located at 10,927' MD. Rotate to release obstruction. PU hole removed 1 joint, continue to pull up hole with 6K overpull. PU slowly, remove 2 joint of tubing, additional weight on spear. Fill casing & tubing with field water. Set TIW. Close pipe rams. Secured well. • • 05/01/2012 - Tuesday Check pressures, remove TIW, open BOPS, Toad trip tank with fluids. Pulling up hole with fish, hanging up at each collar. Unable to jar as the fish will not sit down and moves downhole. Hanging up in collar after pulling 4 stands (249 feet). Work tubing up and down with no success. Pick up tubing swivel and rotate pipe. Rotate tubing, fish dropped off the spear, pull out of hole with work string to pick up piranna mill. OOH with work string and BHA, remove the spear and pick up piranna mill. Begin running back in hole with BHA assembly, shut down for night, secure well, install TIW. 05/02/012 - Wednesday Check pressures, remove TIW, open pipe rams and begin running BHA in hole. On bottom with BHA, pick up power swivel and additional joint of tubing, begin milling operations. Start up rig pumps, pump 3 bbls per min. Pumping produced water, well continues to take fluids without circulating. Mix HEC -10, material is not shearing and mixing properly. Call for additional HEC -10, while attempting to maintain rate, well is taking fluid without returns. Mix more HEC, material is not setting up. Continue to pump fluids, HEC material arrived, mixed 30 bbl pill and_pump away, allow 45 minutes to heal across thief zone. Begin pumping again. Well began to circulate, begin milling operations, fluid circulating with small losses. Mill down 1 foot thru the packer assembly. Mill and circulate with metal shavings recovered on the ditch magnet. Pumped 10 bbl sweep of HEC, well is circulating and cleaning up. Milled total of 2.5 feet thru the bottom portion of Brown HS -1 packer, shut down operations. 05/03/2012 - Thursday Check well pressure, open BOP pipe rams, start rig pumps, and begin circulating fluids. Mix HEC -10 pill to circulate cuttings. Milling on packer, made an additional 1.5' for a total of 4'. Continue to pump 10 bbls sweeps, recovering metal on ditch magnets. Rotating drillers to continue operations while pumping fluids. Continue millin: u • the HS -1 • - • 1 : 4'. Begin POOH with workstring, racking back 100 stands. Notified AOGCC of upcoming test. 05/04/2012 - Friday Check well pressure, fill casing and tubing with 10 bbls of produced fluid. Remove TIW. Begin pulling 67 stands of workstring and BHA. OOH with BHA, Piranha mill is cored and ID indicates 2 -7/8" tubing OD without collar. Prepare BOP for inspection, opening side and clean. Replace BOP side doors. Performed BOP test: 250 psi low / 3,000 psi high, test witnessed by Lou Grimaldi . PU mill control guide. Overshot for 2 -7/8" tubing, and BHA. Begin RIH. RIH with workstring. SD operations. Install "TIW ". Close, pipe rams and install night cap. 05/05/2012 - Saturday RIH with overshot, mill control guide and BHA. Tag top of fish and begin rotating workstring to guide over tubing string. Working string. Overshot dropped down 2.5'. Worked pipe to engage fish. Appears to have latched, overpull on fish, continue working down. Overpull indicating overshot has engaged the tubing. Push down on fish to insure latch. Begin tripping pipe. POOH with workstring. OOH with workstring and BHA. Did not recover fish. Check overshot. Marks indicate over the tubing. Overshot had sand and debris. Fill hole with produced water. Called for slickline to be on location at 6:00 am with impression block. 05/06/2012 - Sunday RU slickline to RIH with imp block. Slickline OOH with impression block. No impression. Possible fill. RD /MO slickline. PU tubing spear and RIH with work string to fish. RIH with work string to spear lower tubing assembly. RIH with workstring and BHA. Tag top of fish, engage pump. Establish circulation. Lower to top of fish work string and wash down 4' into the fish. Pump at 2.5 bbl minute. Turn 4 left hand turns. PU to 120K jars hit. Fish is stuck in fill. Increase pump rate, returns include scale, sand and debris. Jarring at 150K. Fish is moving up hole. Work string up and down 50' to wash away fill bottom out at 10,962'. Continue to work prior to breaking connections. POOH with workstring and fish, racking double stands. Recovered 128' of fish. • • 05/07/2012 - Monday ND stripper head. Mix and pump gel pill, let pill set for 1 hr. Start filling hole with FSW. Pump FSW down well. Trying to get returns pumped 300 bbls. POOH. Well still taking water 12 bbls every 5 stands pumped. 200 bbls pulled out with fish. Lay down same total bbls pumped in well 500 bbls. 05/08/012 - Tuesday Make up 7" scraper and mill, bumper jars and oil jars. RIH with D.C. and tbg. Finish RIH to 10,907'. Make up striper head and wash swivel. POOH with tubing and scraper. RU E -Line. Run PNL Log,. Running PNL Log. 05/09/2012- Wednesday Running PNL Log from 10,911' to 300'. Lay down drill collars and Power Swivel. RU wireline. TIH with 3 -1/8" csg gun. Tag _10,923'._ Perf 10,922' to 10,913' on first run 6 spf 60 deg phase, POOH. RIH w /second run perf 10,909' to 10,879' 6 spf 60 deg phase. 05/10/2012 - Thursday RIH with 3 -1/8" csg gun. Perf 10,836' to 10,860' 6 spf 60 deg phase. POOH. RIH with 3 -1/8" cs: :un. Perf 10 812' to 10 828' 6 spf 60 degihase. POOH. RD E -Line. PU 7" AS1 mechanical packer with 4' pup joint WL entry guide on bottom. Start in hole with 2 -7/8" tubing completion. 05/11/2012 - Friday Finish TIH with completion set packer 10,714' re -entry guide 10,718' 334 jts 2 -7/8" tbg and 7 gas lift mandrels. Set AS -1X Packer at 10,714' with 8,000 compression. Fill casing. Test casing and packer to 1700 psi for 45 minute test, ok. Sent copy of chart to office. Bleed off pressure, make sure no flow back. Set tubing hanger. Screw and hold down pins. Set BPV in tubing hanger. Remove landing. Joint clean off rig floor. RD tongs. Start ND BOPs. NU tree and valves on well head. 05/12/2012 - Saturday RD rig and moving to 23 -15. 05/13/2012 - Sunday Field crew bolt up gas lift and flowlines. Pull BPV, MIRU slickline. PT lubricator 3,000 psi. RIH w/ 2.25 blind box. Tag fluid @ 2,815'. Wlm. RIH w/ 2 -7/8" A2 stop, set @10, 679' KB. Pressure up tubing to get overbalance. RIH w/ 2 -7/8" Daniels KOT. Pull top 5 dummy valves. SDFN. 05/14/2012 - Monday PT lubricator to 3000 psi. Pull bottom 3 DV's. RIH with _6 GLV'S, orifice valve. Pull AD2 stop. RDMO. 05/15/012 - Tuesday Work completed, turned over well to operations. Started production. •nson River ' -1111 1110 Well # SRU 21 -22 As- Built Schematic 5/23/12 PTD: 161 - 032 ASBUILT API: 50 -133- 10149 -00 RKB = 18'Rig Floor to TBG Hgr Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 11 -3/4" Surface 47 J -55 Surface 3,008' 16" 3,008' 1,480' 7" Production 23 N -80 Surface 4,714' 9 -7/8" 11,012' 7,546' 26 N -80 4,714' 6,644' 9 -7/8" 29 N -80 6,644' 8,472' 9 -7/8" F 1 29 P -110 8,472' 11,012' 9 -7/8" L Tubing 2 - 7/8" 6.5 L -80 Surface 10,714' 2 NO. JEWELRY DETAIL WL Depth ID Item Depths (KBI 1 3,238' 2.44 GLV ZSFO 1(52 12) 3,238' 2 5,803' 2.44 GLV-ZSFO-1(S2 12) 5,769' 3 7,620' 2.44 GLV- ZSFO- 1(S212) 7,596' 4 4 8,805' 2.44 GLV- ZSFO- 1(S212) 8,849' 5 9,641' 2.44 GLV-ZSFO-1(S2 16) 9,683' 6 10,193' 2.44 GLV- ZSFO -1(S2 16) 10,242' 5 7 10,621' 2.44 GLV- ZSFO -1(S2 20) 10,648 8 10,669' 2.313 X- Nipple 10,700' 9 10,714' 2.5 AS -1X Mech. 6 Packer 10 10,715' 2.44 WL Entry Guide Perforation Data ! _ ZONE TOP BTM Shot Condition H1 10,812' 10,828' 16 8 H2 10,836' 10,860' 24 Reperf w/ 3-3/8" ae, May 01 spf 60 Deg. II H3 10,879' 10,909' 30 H5 10,913' 10,922' 9 Perf W/ 3 -3/8" guns @ 6 spf 60 Deg. �¢ aE Phase, May 2012 9 10 TOF 010,923' . y -, '� TOC @10,970' TD = 11,012'MD/11,012'TVD Revised by: TDF 6 -5 -2012 9 10 - _ �. 1 / � }'fy � Y �--� �s� �� 1 �� O� ..-;-;: _ ` _,. . �., a\ ti s yam' �' _ ., p` . ` `�_��a�`�� 7.;,: ,-,:'. ,,,'. ' ''..';-'('.;" :',,. : , '''' • ::.' -/ . 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'� � ` .. ... �Altiz3."'r'd F r.""-- ec'"Ri.��','„” 1. ;rffrc;,.r, .C . ,,r`�irr9 /, 1,•'flr.`+r __ _ _ • • ( G 1 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 May 25, 2012 Mr. Stan Golis Operations Manager, Kenai Asset Team Hilcorp Alaska LLC P.O. Box 244027 L JUP 1 .¢ C111 Anchorage, AK 99524 -4027 Re: Missing Kill Line Valve Aurora Well Services Rig #1 Swanson River Unit 21 -22 (PTD 1610320) Dear Mr. Golis: The Alaska Oil and Gas Conservation Commission (AOGCC) has reviewed the explanation from Hilcorp Alaska, LLC (Hlcorp) regarding the missing kill line valve on Aurora Well Services Rig #1 performing workover operations on Swanson River Unit 21 -22. That explanation was provided to the AOGCC letter dated May 8, 2012. The corrective actions that have been implemented for Hilcorp- operated workover rigs in Alaska satisfactorily address the regulatory concerns. The AOGCC encourages Hilcorp to extend these corrective actions to planned drilling activities since it is unclear drilling activities are included after reading Hilcorp's response dated May 15, 2012. The AOGCC does not intend to pursue any further enforcement action regarding the missing kill line valve. Sincerely, Cathy P. Foerster 4.------ Chair cc: AOGCC Inspectors (via email) ` • • SEAN PARNELL, GOVERNOR L / \ , ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 May 8, 2012 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7009 2250 0004 3911 2838 Mr. Stan Golis Operations Manager, Kenai Asset Team Hilcorp Alaska LLC 14/ 0 P.O. Box 244027 Anchorage, AK 99524 -4027 Re: Notice of Violation — Missing Kill Line Valve Swanson River Unit 21 -22 (P111461.0520) $L N ) Cti 1 s 2012 Dear Mr. Golis: On April 18, 2012 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed the initial performance test of secondary well control equipment on the Aurora Well Services #1 rig being operated by Hilcorp Alaska LLC (Hilcorp). The rig was prepared to begin tubing workover operations on Swanson River Unit 21 -22. Inspection of the equipment in conjunction with the performance test revealed that the kill line — where it connects to the blowout preventer stack — was equipped with a single valve instead of the required two valves. A copy of the AOGCC Inspection report is attached. The kill line valve configuration observed by the AOGCC Inspector is a violation of 20 AAC 25.286(c)(9), which requires secondary well control equipment for tubing workover operations to include "a kill line and a choke line each connected to a flanged or hubbed outlet on a drilling spool or on a BOP body with two full opening valves on each outlet... " (emphasis added) Within 7 days of receipt of this letter (next business day if this falls on a weekend), you are requested to provide the AOGCC with an explanation for this noncompliance and what will be done in the future to prevent its recurrence on Hilcorp- operated drilling and workover rigs. Sincerely, Cathy P oerster Chair, Commissioner V • • s Mr. Stan Golis May 8, 2012 Page 2 of 2 Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC 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. • 0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry 3e--51Z1/1., BOPE Test Report Comm Contractor/Rig No.: Aurora 1 PTD #: 1610320 DATE: 4/18/2012 Inspector Lou Grimaldi Insp Source Operator: HILCORP ALASKA, LLC Operator Rep: Langley Rig Rep: Borenin Inspector Type Operation: WRKOV Rams: Annular: Valves: Inspection No: bopLG120425161751 Type Test: INIT Test Pressure: 250/3000 250/1500 250/3000 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank NA NA System Pressure 2950 P Housekeeping: P Pit Level Indicators NA NA Pressure After Closure 2000 P PTD On Location NA Flow Indicator NA NA 200 PSI Attained 37 P Standing Order Posted P _ Meth Gas Detector P P Full Pressure Attained 183 P Well Sign _P H2S Gas Detector P P Blind Switch Covers: P Drl. Rig P _ MS Misc NA NA Nitgn. Bottles (avg): 4 x 1875 P Hazard Sec. NA ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Q uantit y P/F Quantity Size P/F Quantity P/F y Upper Kelly 0 NA Stripper 0 none NA No. Valves 12 FP Lower Kelly 0 NA Annular Preventer 1 11 P Manual Chokes 1 P Ball Type 1 P #1 Rams 1 2 7/8 P Hydraulic Chokes 1 P Inside BOP 1 P #2 Rams 1 Blind P _ CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA INSIDE REEL VALVES: #6 Rams 0 none NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3 1/8 P Quantity P/F HCR Valves 2 3 1/8 P Inside Reel Valves 0 NA Kill Line Valves 2 3 1/8 FP Check Valve 0 none NA BOP Misc 0 none NA Number of Failures: 2 Test Results Test Time 6.5 Remarks: Missing 2nd valve on Kill side of mud cross, installed HCR and tested OK. Center outlet valve on Choke manifold buffer tank leaked, greased and retested OK. New gas detector system being installed during the test, allowed for the test to be done the following morning. Otherwise test went well. • S 56,{ Z/ - ZZ Regg, James B (DOA) PTh ) 'I0 37,e2 From: Doc Holliday - (C) [rholliday @hilcorp.com] Sent: Tuesday, April 17, 2012 5:42 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Grimaldi, Louis R (DOA) Cc: paullangley @zplenergy.com Subject: BOPE configuration To All, I am sending this email in regards to discrepancies concerning the Sundry Approval for the Aurora rig currently working in the Swanson River Field for Hilcorp. The original Sundry requests covered the Cudd jacking unit that was supposed to perform the well work in Swanson River. Last minute changes moved the Cudd unit to the King Salmon Platform and the Aurora rig was brought to Swanson River. The Cudd unit uses a 7 1/16" x 5m stack versus the 11" x 3m stack used on the Aurora rig. An assumption was made in error that the changes could be rectified on the BOPE test reports submitted after each test. Mr. Paul Langley apologizes for that oversight. The following is a description of the stack configuration currently being used in the Swanson River workover program: Annular preventer: Shafer 11" x 1500 psi rating with 11" x 3m lower connection. Double -gate: Shafer 11" x 3m Model RS, Flanged. sin 10D3 -167. Mud cross: 11" x 3m , flanged w/ [2] 3 1/8" x 5m gate valves and [2] 3 1/8" x 5m HCR controlled gate valves. We have the potential to replace the HCR on the kill side with another 3 1/8" 5m gate valve. There is also a spare 11" x 1500 psi annular preventer on location. I hope this sufficiently answers questions raised, but any other inquiries will be answered promptly. Thank you. Doc Holliday XeMINEDAPR ` 8 2012 Richard 'Doc' Holliday Rig Support 907 - 283 -2520 rholliday @hilcorp.com • • A[LAZIA 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 Stan Golis Operations Manager I 671-- 03 L Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit 21 -22 Sundry Number: 312 -123 Dear Mr. Golis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , / 1 Odx.4414._ Cathy •. Foerster Chair DATED this D day of April, 2012. Encl. III • % STATE OF ALASKA cii ALASKA OIL AND GAS CONSERVATION COMMISSION Is7 APPLICATION FOR SUNDRY APPROVALS �, 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Replace tubing and GLV's 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development Exploratory ❑ 161 -032 3. Address: Stratigraphic ❑ Service ❑ F - Aft-Neer µ ' - '" - 3800 Centerpoint Dr., Suite 100 Anchorage, Alaska 99503 50 1 E D 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Num,ber: property line where ownership or landownership changes: MAP Spacing Exception Required? Yes CI No El Swanson River Unit 21 M 22 1 P,! 2012 9. Property Designation (Lease Number): 10. Field /Pool(s): Swanson River Unit FEDA028406 - Swanson River Field/ Hemlock Oil Pool • ? .,ir s, • -- i, n \ Commission ' 11. PRESENT WELL CONDITION SUMMARY i I Anch ,rarr Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugsi.(measured) :__... ._ ___ JunkImeasured): 11,012 l• 11,012 10,970 10,970 10,970' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3,008' 11 -3/4" 3,008' 3,008' 3,070psi 1,510psi Intermediate Production 11,012' 7" 11,012' 11,012' 6,340psi 3,830psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,802'- 10,816'; 10,828'- 10,802'- 10,816'; 10,828'- 10,849'; 10,868'- 10,895' 10,849'; 10,868'- 10,895' 2 -7/8" 6.5 #/ N -80 10,881 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Brown 2- 7/8 "x7" Packer And N/A 10,748(MD) 10,748(TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Development EI • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/11/2012 Oil © Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Golis Phone: 777 -8356 Printed Name Stan Golis Title Operations Manager Signature C 0 Phone 777 -8300 Date 3/30/2012 COMMISSION USE ONLY n Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 Z" 1 (.✓ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ''\, - `�� 3 060 ies go f ��-sT" Subsequent Form Required: ( ® f o <-( / / APPROVED BY Approved by: / '4{4,7 COMMISSIONER THE COMMISSION Date: q.. -S / 2._ 1 G Form ~ 1' .1 400 08 201L"0 Y e0 0 1 \ Submi ' li t 1��v INAL � Z 4,1) • • ` Swanson River SRU 21 -22 February 29, 2012 Hilcorp Alaska, LLC OBJECTIVE: • Active oil producer. Pull tubing, redesign /rerun GLVs to lift deeper and increase fluid production. / Current BHP: 2500 psi @ 10,802' MD Max Downhole Pressure: 2500 psi @ 10,802' MD (Based on offset well pressure surveys) MASP: 1450 psi (Based on a pressure gradient of 0.1psi per foot of true vertical depth) / PROCEDURE SUMMARY: 1. MIRU pulling unit. Load casing & tubing with FSW. ND xmas tree. NU BOPs. Pressure test BOPs to 25_ 0 psi low /3000 psi high. 2. RU a -line. Make chemical cut @ ( + / -) 10,740' MD. RD a -line unit. 3. POOH while laying down 2 -7/8" production tubing. 4. RIH with overshot. Latch fish. Release Brown HS -16 -1 retrievable packer @ 10,748' MD. POOH. Lay down fish. 5. RU a -line unit. RIH and make required perforating runs to re- perforate ( + / -) 10,802' - 10,816' MD; ( + / -) 10,828'- 10,849' MD; & ( + / -) 10,868'- 10,895' MD. RD e-line unit. 6. RIH with AS -1X packer, GLVs per design and remaining 2 -7/8 ", 6.5 ppf, L -80, EUE T &C ubing. Set packer @ ( + / -) 10,750' MD. 7.rt 7. ND BOPs. NU xmas tree. ..� �,r 8. RDMO workover rig and equipment. 9. Turn well over to production. v e v rec.s. 4'1^, t o C Well Identifier REVISED BY: Initials MM -DD -YYYY • • • ry r .. ,� / -,_- f • : j, 1 1 i seht.ra A ;,:o le•'JAW— .... 0 tom, J ; f 11 II t }. _. } _ . 11 4r its. ,,g -/s/6 8, k) it 1 *--, y w I� :i 41 , n fj , 0..4 1 '� 9 '_•_... _ • t Carrh ab l '4,4 irc/rr /Asse"m j irr/h R,0 �G'o*!s e�- !9.00' x !a #III } a j I - 4.C te* 2 %v T..,b,ng - frte4. 1 . a •\ # k e nn Cosereew NWAfgrook./As,,sem.61y wNhAt011riPe 'U ..r -s . 4 /Jrst 2 /28B.I4•' - • • .164x6•!- etwoo Ili fiffami r /r9'ssers..61 .1440'h RO Pa/P.9 - 1.'100' . ter/,►" 33 Jf.. 2' M•124444 9- ,4'195.`9,7' 6 .vtdr sar Ca . rWarrdsr/sfsse ,r.64 ,t�',Y4 RD/-/3 0' tta . - 29 a& eir"Tubvrlg- 915.23' - ., . • .. • ce36.8/' ( y , t:`A6/f a+rx3/nr/ o¢srcm b/ wi7`h Rd Yalrr /3.Gb' t 61s.ose ' 2 e; dfs. 247146147g Fig 87* .. • Cernro dC4#.H ,aafre /s4sseor4 w,Yb Rarll'afit■ -&W . 1 Z -- ....:- • • C7,t's rsS4` 22 `lt 2f&'Fabng :695.99' 17.9845'r" rrnor enlMarrdrrfAsscnrfi/y Av./h.4'' lfta /re -/...TOO' ' . • . f 3•sst' 92 J1n.24# "12+.6!173- 289U.�G0' - G4rsrng .rr+rxer J/.` ..- R7 K31' -.4 QS' • iJl..8,4 :,xl. rr y _ IP 1'3G 4b" a.-00041 0C .S Gam' ,c .7•rr_se• t'`'.� J 2 �e "r. .txg ,Lz/a • r I -4 - . t$rzwr1 23e:r7 74's-is -/r yc+krr~ -f.40' I)." rasa azr' tits. 2 :c - fb.:ng -6322• . 1 ) � _ awv o ;G7".Y.;c*p/c- ? ` - ,4046' 2Jls: e e1€766A 4'.2.84` • 4 0 I U -huger irenlLN Sh eer -.CO" © 1 -- 478 " . V ! j •\ { wore. 4/1 ia,Gr.7y:s 2 $e'6".5""iV 6veon 8r? AV 2 'CAI' K•' .: r •i.3' a _ ..,C:-V . ,f -t ,*. ... »... ".t..'•. �..- :'ti4C•- ..! t.tn. r •i`.:r: ".: y:.. .ti.,•�a zt a, . .V'"a.Yn�::tr 7. ••. •' " iCa ^:Y.'• :d S...• '..G U'•�s` . » • • II Swanson River SRU 21 -22 BOPE 03/02/2012 1l 1.,,.1..1:,.A.,. 1.1.t. Swanson River SRU 21 -22 113/4X7X27/8 v � 1114111 t it um 111 lit lit u Annular Preventer 7 1/16 5M sop 111 111 111 111 lit 7 1/16 5M ,6' - - -- ° Pipe rams t,...0 Blind rams 4. 111 111 111 111 11 E 1 r i . ) r�` �� O I ► 2 1 /16 5M w/ 2" Unibolt i di lit 111111 lit • connections for choke and kill hoses iii 111 111 111 111 Ground Level lil 111 111 111 lit 111 1 111 6 N Co i mill C3 I Il i i. • Bm. lit 111 - Uii ICI � �I i[ l 1 • i. l er Or Page 1 of 2 • • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, July 26, 2010 11:16 AM To: Myers, Chris S Subject: RE: Swanson River Update #5 Thank you; no problem with recovered fluids going to Class II disposal well. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~ ~ ~ 1 ~., ` .~ \ ~ From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Monday, July 26, 2010 11:15 AM To: Regg, James B (DOA) Subject: Re: Swanson River Update #5 Yes, the lines are in field gathering lines - ----- -- h~~.rc~ii'1Tid' ~.~4~1~._ ~ ~J ~1°~+ Sent from my BlackBerry Wireless Device From: Regg, James B (DOA) <jim.regg@alaska.gov> To: Myers, Chris S Sent: Mon Jul 26 14:00:14 2010 Subject: RE: Swanson River Update #5 Reports indicate recovered liquids were being sent to the fields Class II injection well for disposal. Are the pipelines in question upstream of any custody transfer (non-transportation; gathering lines or production support only)? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Sunday, July 25, 2010 9:11 PM To: tzelenka@blm.gov; claire_caldes@fws.gov; Dewandel, Shannon S (DEC); Russell, Steve A (DEC); Pexton, Scott R (DEC); rees.david@epa.gov; Catalano@circac.org; Regg, James B (DOA) Cc: Myers, Chris S Subject: Swanson River Update #5 To All, This is the fifth situation status report for the Swanson River 21-27 crude release. Please 7/26/2010 Page 1 of 2 Maunder, Thomas E (DOA) From: Myers, Chris S [myersc@chevron.com] Sent: Thursday, July 22, 2010 11:29 AM To: Maunder, Thomas E (DOA) Cc: Regg, James 6 (DOA) Subject: RE: Swanson River Update #1.xlsx Tom, Jim Wells 21-27 and 21-22 remain shut in until we can excavate the lines and determine the cause of failure. It will be several more days. The two wells make about 1000 bbls of water and 70 bbls of oil per day. Chris S. Myers Operations Superintendent MidContinent/Alaska SBU Chevron North America Exploration and Production Co. 3800 Centerpoint Dr. suite 100 Anchorage, Alaska 99503 Tel 907 263 7654 Fax 907 263 7847 Mobile 907 398 9955 myersc@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 22, 2010 11:08 AM To: Myers, Chris S Cc: Regg, James B (DOA) Subject: FW: Swanson River Update #i.xlsx Chris, Thanks for the information. Greg did call me the other night. indicated that 2 wells were SI due to this event. What wells were SI? Thanks, Tom Maunder, PE AOGCC Jim should be the primary contact here. Greg From: Myers, Chris S [mailto:myersc@chevron.com] Sent: Thursday, July 22, 2010 10:37 AM To: Maunder, Thomas E (DOA) Subject: FW: Swanson River Update #l.xlsx Tom, Greg Merle indicated that you wanted to be included on these updates. Here is yesterdays and I will send you the next one later tonight. Give myself or Greg a call if you need anything else. Thanks, Chris S. Myers Operations Superintendent MidContinent/Alaska SBU 7/26/2010 l ~ S ill or Release - Information U date Pa e 1 of 2 Status Update No 1 Status Update Date June 21, 2010 at 1800 Next Update: June 22 Initial Release Date and Time July 20, 2010 at 1700 Incident Name Swanson River Field Pad 21-27 Crude Oil Release Responsible Party Union Oil Company of California Location 40 feet from Pad 21-27, Swanson River Field, Kenai, Alaska. Latitude/Longitude Lat: 60 deg 45 minutes 38.4 seconds Long: 150 deg 50 minutes 28.2 seconds Release Controlled and Removed? Release controlled. Ongoing spill response and cleanup. Company Contact Chris Myers @ 907-253-5515 or 907-398-9955 (cell) Onsite Incident Comander Contact: Greg Merle @ 907-283-2543 (office) HES Contact Chris Holden @ 907-263-7364 or 907-223-3117 (cell) Current Weather Conditions; Clear, 60 degrees, light wind Initial Volume Released (Estimate) 15 bbls and unknown square footage Current Volume Released? Approximately 15 bbls as of this re ort eriod Source of Leak Buried crude oil pipeline in ROW. Buried 6' deep. Incident Potential Incident is under control and can be handled with available resources. CISPRI and full ICS resources are not required and have not been activated. Short Description of Initial Event A contract crew performing a power pole survey discovered crude oil stained ground along the powerline route near Pad Discovery: 21-27 at Swanson River Field (SRF). No bubbling or indication of active leak was observed. The pipelines in the area were shut in and swept of fluid with gas. The two wells that service the pipelines in the area were shutdown. There was no active leak observed and no gas was observed at the site when the line that was suspected of leaking was evacuated. After sweeping the line with gas, the line was shutin and 132# of gas pressurre was maintained on the line over night. The line was manually depressurized in the early afternoon. There are 3 other pipelines within the area of the leak: 2 natural gas lines and one crude oil line. Other inactive lines are also in the area. Investigation is ongoing to determine the source of the leak. The hydrocarbon leak was wthin a natural drainage to a culvert (250 yards downgradient) that goes under the road. Sheen was reported along the natural drainage but no sheen was observed on either side of culvert. Sorbent booms are in place at the culvert. Drainage area consists of dense grass and some standing water. Source Controlled? Yes, source has been isolated. Suspect pipeline was isolated, evacuated and depressured. Impacts to Soil and Water? Soil: Yes, impacted off pad soil. Water: No. Evidence to date does not indicate impacts to water bodies or Swanson River Current area impacted by release Impacted Area: Off-pad soil and vegetiation (as of this report period) Square Footage: approximately 2000 SF of surface area. Location: About 40 feet north of the entrance to 21-27 well pad. Significant Change in Impact Area or No. this is the first report. Volume Since Last Update? Potential Human Health Impact or None based on current information. Community Related Issues? Wildlife or Resource Impacts? No wildlife impacts observed. No adjacent water bodies appear to have been impacted. Discharge is 0.81 miles from Swanson River. Remedial action to Date Source conrolled. Spill area was identrfied and staked. No soil or water have been excavated to date. Some grass has been cleared to better assess the impacted area. Material Recovered (soil, water)? Soil: No soil removed to date. How much (gallons, yd)? Dewatering: No water has been removed to date Recovered Material Disposal Location Soil: No soil removed to date. Any soil removed will be disposed of at offsde approved facility (ASR, Emerald). Permission has been received for temporary storage on 21-27 well pad. Water: No water removed to date. Any oil contaminated water will be disposed Class II produced water disposal well at the facility. Agency Contacts; Claire Caldes - USFWS @ 907-262-7021 Emait: Claire_Caldes@fws.gov Tom Zelenka -BLM @ 907-267-1469 Email: Tzelenka@blm.gov Sinda Wolfsen -BLM @ 907-267-1441 Email: Swolfsen@blm.gov Scott Pexton -ADEC 907-269-7680 Email: scott.pexton@alaska.gov Shannon DeWandel -ADEC @ (907) 269-7541 Email: shannon.dewandel@alaska.gov r~ ~~ Spill or Release -Information Update Page 2 of 2 Status Update No 1 Status Update Date June 21, 2010 at 1800 Initial Release Date and Time July 20, 2010 at 1700 Incident Name Swanson River Field Pad 21-27 Crude Oil Release Key Actions Since Last Reporting Period Action 1: Comments (general): See above Action 2: Removal Action Status: See above Action 3: Leak Identification Status: Leak area will be excavated as soon as contaminated material has been removed. Action 4: Remediation: Surface Water Sampling: 3rd-Party company is collecting a downgradient water sample to verify that there are no hydrocarbon impacts. Analytical samples will be submitted on rush-turn (48 hours). Sample results will be reported in update as they are received. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Enginiedng December 27, 1991 Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 22 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 $~r~lry. 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: 1, rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC 1 1991 Alaska Oil & Gas Cons. Comm'tssien Anchorage Mr. J. A. Dygas Page 2 December 27, 1991 Shut-in wells until field b!owdown, 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 year's TA list were moved into this category. Attachment 2 gives a brief expl. anation 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, $CU 23B-3, SCU 43A-4, SCU 13-9, $RU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, $RU 21-15 and SRU 314-27, have been removed from the Previous TA List. Attachment 3 is a list Of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call PIyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4107. Sincerely, J. C. W inn Acting Regional Engineer JTZ:jlg:0025 Attachment L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation Rrr..CEI / o Alaska Oil a Gas Cons. Com~$s'~o~ Anchorage ORIGINAl. Form 31~,0-5 (November 1983) (Formerly 9~331) UNITED STATES .umzT m (OUier lultlqJetloaa o~ D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON LLS not ~ t~l~ form for pm~l~ to dr~l or to d~a or ~lul b~ck ~ I ~e~at rmrvolr. U~ '~P~CATION ~R PERMIT--" for such ~&) oft, ~ G~lr. r. ~ OTIH 2. NAMB O! OPIIATOI 3. AODIILI& DIP OPHATOI 4. r. OC&TION OF ~'E:.r. (Report Ioc~tiofl cieiriy iud ~ &eCOrd&n~ wt~h tn~ State requlrementLe See &lBo II)lee 1T below.) Form approved. Budget Bureau No. 1004-0135 ExDires August 31. 1985 t II) IlOIil. 'ILLOTTll OI TIIII IAMB UNIT AOIIIMIN! IliMI Soldotna Creek/Swanson I'Amid Ol [JAil IAMB WILL fO. 10. ,IILO &ND POQg,, OB WILDCAT AC lUr~ice Swanson River Unit Soldotna Creek Unit 19 wells 13 wells I16. BL'eYAVIONI (Show whether or. rt. mt. eta.) Swanson River Field 11. ~. ~.L,M. OR ILL L I ID I~IVBY Kenai Alaska la. Check. Approm,ate Box To Indicate Nature o1: Notice, Report, or Other Data lOtlCl Of INTBll'~IO# ~: - 3dCLTIPLll COMPI.RTE IUIIIqUIIIT Ill'OH ~e': IEPAII'WI~ CflANGB PC*~a (Other) , ~ . ~-ompteUon or ~omptefloa M~fl In4 ~ fo~.) 1~. D~3CIiB~ I'RObBED OR COMPLETED OPEIATIO~ (Clearly 8tare ~tl ~rtinp.~ detail~. ~nd =lye ~rttneuC dl~ ~n~lud.~.mfl~8~ ~M ~.o~ ~; p~ worL If ~1 h di~n~ d~U~ five o~m ~uns and meam, r~ &nd t~e veru~ aepm roe ~ m~eu ina Mum ~. nan; m ~ ~L) · As decribed in the attached memo, ARCO Alaska, [nc. requests that the following wells have a temporarily abandoned status: 5oldotna ~ Unit Swanson River Unit SCU 23B-3 SCL/21-8 * SRU 212-10 SCU 12A-4 SCL/ 341-8 SRU 14-15 SCU 13-4 SCU 13-9 SRU 23-15 SCU 21A-4 SCU 24A-9 SRU 34-15 SCL/ 34-4 SCU 34-9 SRU 211-15 SCU 43A-4 SCU 14-34 SRU 41A-15 SC'TI33-5 SRU 43A-i5 SRU 432-15 SRU 14-22 SRU 21-22 SRU 23-22 SRU 23-27 SRU 212-27 SRU 331-27 SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33 SRU 32-33W'D * -High GOR wells that may be produced intermittently. 18. I hereby ee, gt~Y~zAt-the fo, refolaf ia trde and correct sxG~'so .. "Z~.-2/~'"--'--"-- RECEIVE£ DEC I 1991 Alaska 0ii & Gas Cons. Commi. TZ?T.]~ Actinq Reqional En_qineer OA~l . (Thin spite for Federal or State DaCe uae) APPROVED BY CONDITIONS OIP APPROVAL, lB* AN~: TITL~ DATB 'Se. Inmucfions on Reverse Side 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 scU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SCU 341-8 SRU 21-22 SRU 34-28 SRU 43-28 SRU 32-33WD SRU 212-10 SRU 211-15 SRU 23-15 sRu 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SRU 24-33 ca SCU 14-34 SRU 23-27 SRU 14A-33 m r-fl 11 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:~ :::::::::::::::::::::::::::::::::: ::::::::.'::::::::: ::::::::::::." :::::::' :~' '.' :' :' :' :' :' :' ~:' :' :° :' :': ':':':':':':'~: 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) eec 1 1991 Alaska Oil & Gas Cons. Con]miss Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43^4: Sh'ut-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, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. I · · 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 · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 5 1 1991 Alaska Oil &(]as Cor~$, t;ummissio~, Anchoraae ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A.. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, A1 aska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories- 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB. JWR- ch: 0006 Attachment cc: C.V. Chatterton, Chairman ' Alaska Oil & Gas Conservation Commission Form 3160--5 (November 1983) (Formerly 9--331) UNITED STATES (O~her lustrucUO-R on re* DEPARTMENT OF THE INTERIOR ,.se-,do) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drUI or to deepen or plug bsck to · dl~erent reservoir. Use "APPLICATION FOR PERMIT--" for such propoemlL) o~L ~ GAS ~ OTHER WELL WELL .~. NAMB Or OPERATOR ARCO Alaska, Inc. 3. ADDRESS OF OPBBATOR P. O. Box 100360 Anchorage- AK 4. LOCATION OF WELL (Report location clearly and i~ ·6cord·nee with any State ~qulrementJ.e See also space 17 below.) At ss. rises Soldotm Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 1~. FIItMIT NO. IS. ILIVATIONS (SHOW whether Dr. rE. aB. eta.) Form approved. Budget Bureau No. t004--0135 Expires August 31, 1985 fi*. LitAOB DBIION&'L*ION AND IBBIA~ Re. O. Ir INitiAl, &LL4Y~'rIit Oil VIlli NAMg ?. UNIT CreekYSwanson River Unit 0. Wmr'r- MO. 10. I'IBLD AND POOr-., Sit WILl)CAT Swanson River Field 11. omC., ~** L, X~ Sit ELK. AMD IUBVBY Sit AIBA Kenai Alaska Check Appropriate Box To Indicate Nature of Notice, Repo~t, or Other Data No'fica or INTENTIOIe TO: OUBIB4JUBI~ Bm~O~ SI' .* tPRACTUIE TREAT MULTIPLE COMPI.ETE FBAC'Jr~YRB TRBATMmNT . ALTBIIIIIO CAiIINO SHOOT OS ACIDIZB ABANDON® SHOO, lNG OR ACIDI~INO ABANDONMBIITe REPAIR WELL CHANGE PLAN~ (Other) (No~·: Report results of multiple eompleUon on Well (Other) T~111porar-i ly a~lridorl .~ Completion or Reeompletion Rapers and Leg for~.) 17. ~)~s~R~Ur~ r~O?OStO OR CO.~IPLETEO OPERATION8 (Clearly state ~tll p~,rtlnent details, and give pertinent dates, Including estimated date of st&gL;sE In, proposed work. If well ia direct·easily drilled, give sttburface locations and measured and true vertical deptk, for all mltrkerl ·nd I~ne~ perU* neat to t~is work.) * As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-IO SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU21A-4 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. [ hereby certlf~Z._t~tt the for. ageing i~/'~ae and correct ,~/,/ 2 / i/., / / .. TITLE Regional Engineer (This space for Federal or State offie~ use) APPROVED BI CONDITIONS OF APPROVAL, IJ' TITLE DATa *See InslmctJons on Rayne Side Title 18 U.S.C. Section lO0l makes it a crime for any person knowingly and willfully to make to any department or ·gency of the TABLE I Wel 1 s under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future UtilitS 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243 -8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 RECEIVED STANDARD OIL COMPANY OF Division of Mines and Minerals C A L I F 0 R N A~s& Dept. of Natural Resource~ WESTERN OPERA T IONS, INC. Anchorage, Alaska Mr. M. H, Soyster, Regional Supervisor United States Geologic.al Survey P. O. Box 259 ~A~nchorage, Alaska ~~~ D. D. Bruce, Chief- Petroleum Branch State Department of Natural Resources P. O. Box 148 Anchorage, Alaska Gentlemen: CONFIDiENTIAL Ne enclose herewith the following information and well data for Your files and information: Yours very truly, STANDARD OIL COMPANY OF CAlIFORNiA Western Operations, Inc. C. V. CHATTERTON :~'~ SUBMIT IN DUP ATE* STATE OF ALASKA (Seeothorm- st ructions on reverse side; OIL AND GAS CONSERVATION COMMITTEE i ii WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ~,. T¥~, or w*,~,L., o,,, E~ ~ ~ ~ W ELL %¥ ELL DR ~ Other b. TYPE OF' COMPLETION: W E[,I, OVER EN BACK RESVR. Other __ 2. NAME OF 0PERATOI% 3. XDDaZSS 0r OPERATOR 4. LOCATION 0~' WELL (Report location clearly and in accordance with any State requirements)* At surface 5. APl NUM]g~CAL CODE 6. LEASE DE~GNA~ON A-ND SERIAL NO. 7. IF INDIA.N, ALLOTTEE OR TRIBE NA/VLE 8. UNIT,FA/llVI OR LF_akSE NAME 9. WELL NO. 10. FIELD AND POOL, OR WlLDCA. T i1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) At top prod. interval reported below At total depth 12. PERMIT NO. 18/ TOTAL DEPTH, NLD & TVD~lg. PLUG, B~C'K MD & TVD~), IF i~ULT~PLE CO1VLPL., 21. -- ~: I HOW iVI~Y* ROTARY TOOLS ;: 22, PRODUCING INTERVAL(S), OF THIS COMPL~TIO.N--TOP, BOTTOM, NAME (MD AND TVD)' 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN I RT, GR, ~L'TC)*ll7. ELEV. CASINGHEAD ! INTERVALS DRILLED BY ! CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE ~ , , C~SI~4G SIZE ] WEIGHT, LB/PT [ 7' . . i ii iii ii CASING RECORD (Report all strings set in well) DEPTH~[~i~r iSET (M.D) HOLE/& SIZE ! ~l~ CEMLNTING RECOPJ) i ANIOUNT PULLED 26. LINER lq~EC OtTD S!Z]D I TOP (MD) 13OTTOM (MD) l SliCKS CEMEN~T* i SIZE SCi[EEN (~ D) i TUBING REC OF~D DEPTIt SE/' (MD) ~ PACKER SET (MD) 28, PERFORATIONS OPEiN TO Pt~'ODUC4PION' iintcrval, size and number) 29. ACID, SHOT, ]FJ~AC~ 0'RE, CE~,IENT SQUECZi~, ETC. D~i INT~V.~ (MD) ] AMOUNF z'~D I'i!ND OF ~AIEF~AL US~ P~ODUCTION 30. : DATE FIRST PI%ODUCTION [i Fp~OD'ucT1oN MEIHO'D (Fiowi'og, gaJ li£[, parnping--size and type of pump) DATE OF TI;ST, HOURS TESTZD : ' lCHOXE SIZE TPROD'N FOiK OIL--~BEL. VeELL STATUS (Producing or G~kS---iv~CF. WATER,--BBL. [ GAS-OIL ILkTIO 1 WATER--BBL. I OIL GRAVITY-APl ~ ,,,,, , i 1 ITEST WITNESSED BY PLO%V, TUBING I~SS. M. '~,sPosnuo.~ or FJAS;I2qG PRESSURE [CALCUT~TED OIL--BBL. : t24-HOUR RATE GAS (Sold, u's"'ed for fuel, vented, etc.) ,il GAS--MCF. 1 '" 33. I hereby certify that the. foregoing and attached information 1~ complete and correct as determined from'all-available record,~ , T-~-'"r- , ,, *(See Instructions and Spaces For Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucir~,9 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately productcl. (See instruction for items 20 and 22 above). :~IARY O~' FORMATION T,~S'I'S iNcLUDIN(; INTERVA~ TESTED, I'HE~iJRE DATA ~ ~COVERI~ OF OIL, GAS, 35. G~GIC MARK~ WAT~ AND MUD NA~ MEAS. . AND I)E~I'~Cq'EI) SllOWS O~ _ . OillGIN - COMPLETION REPORT - NEW WELL STANDARD OIL CQMPAN~ OF CAL. IFOENIA - WESTERN OPERATIONS INC. - OPERATOR _ u I i ., ii ~ I · ILl il ii iii kl . II I_ · J I I I,,, i,,! I I~ L J I AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Swsnson River Unit LAND OFFICE: Anchorage LEASE NO. A-028406 WELL NO.: SRU 21-22 SEC. 22 T. 8N, R. 9W~ Seward B & M LOCATION: 730' South & 2050' East from NW corner of Section 22 ELEVATION: 300' K.B. DATE: April 17, 1962 DRILLED BY: Rowan Drilling Company, Rig #29 DATE COMMENCED DRILLING DATE COMPIE TED DRILLING November 14, 1961 January 3, 1962 DATE OF INITIAL PRODUCTION: Jsnuary 10, 1962 PRODUCTION: Daily Average.....368 B/~D Oil... '. 364 B/D Water....... 4 B/D Gas...... 34 MCF/D Gravity...,. 32.4° TP.....1240 psi Bean.....8/64" i. ij ' ILIll, l] ' I';,II" '1 II SUMMARY TOTAL DEPTH: 11.~012' PLUGS: 10,970' - 11,012' JUNK: None CASING: 22'1 conductor cemented at 33' 11 3/4" casing cemented at 3009' with 2000' sacks cement. _First .s. ta. ge around shoe with 500 sacks. ~econd.stage through DV collar at 1481' with 1500 sacks cement. 7" casing cemented at 11,012' with 17OO sacks cement.. First stage around shoe with 600 sacks. Second stage through DV collar at 7554' with 1100 sacks cement. WELL RECORD INVENTORY Fi e 1 d: _ Swanson Kid. er. _ Location .. _TSN -.RgW, Sec.. Operator & Well Name Standard Oil Co. - ' ' ii iii i i ...... Unic ..#21-22. _ 1. Drilling Permit: 2. Survey Plat: 3. Monthly Reports (P-3): 4. Compl.etion Report (P-7): 5. Well History: 6. Other: 7. Mi s cel 1 aneous: 8. Deviation Survey(s): 9. Well Logs: Total Pages: _(1 ) ... T~'[, . (2) SL (3)_ cD)[. ~( 5 ) CBND (6) 1~ (7) (8) _ (9)., (!_o) .... · _ 22,._S.M. ............ No. Pages_ i i i' _ i i ii I ,,, PERFORATIONS: 5 - ~' holes at 4 ' ~" holes/foot 4 - ~~'' holes/~foot 4-~" holes/foot 10)800' ~ 10,802 ' - 10,816' 10,826' - 10,849' 10,868' - 10,895' WELL S ~URVEYS: le Schlumberger Induction Electrical log, interval 100' - 2998'-- 2e· Schlumberger Sonic' log~ interval ~ ~ 100 ~ - 2988' 3. Schlumberger Induction Electrical log, interval 3009' - 11014'-' 4. Schlumberger Sonic log, interval 3009' - 11010' 5e Schlumberger Microlog - Caliper, interval 3600 ' - 4100' & 10513 ' - 11013' 6. Schlumberger Cement Bond log, interval 5000' - 10962f 7. Schlumberger Neutron-Collar log, interval 9966' - 10966' DRILL STEM TESTS: HCT #1 on 5 - ½" holes at HCT #2 of perf' d interval HCT #3 of perf'd interval lO,8OO, (w.s.o.) lO, 802 ' - 10816 ' 10,890' - 10895 ' COMPLETION REPORT SWANSON RIVER UNIT 21-22 SECTION 22, T8N, R9W~ Seward B & M ~-TA~DA~D" '0~ COMPanY OF CALIFORNIA"-"W~ 0' '~'I' , ~OPERATOR Page 1. Spudded at 7:00 A.M., November 14, 1961 Drilled 124!'' hole 0 - 1300' ~Ngv. em~er 15~. 196.1.. Drilled 12¼" hole l~OOt - 1600' Opened 12~~'' hole to 17½" 0 - 1250' 0ve,mber 16,, Opened 12¼" hole to 17½" 1250' - 1600' Drilled 16" hole 1600' - 3030t Nqvember 17, 1961 Reamed 16" hole 1528' - 3030' 1502 Re~med 1300'~ Drilled 300 ' Drilled 1250 Opened 350' Opened 1430 ' Drilled 69-74 pcf mud 72-75 pcf mud 77-80 pcf mud Ran Schlumberger Induction Electrical log 2998 t - 100 t. Ran t Schlumberger Sonic log, 2988 ~ - 100 ~. N~v. ember 18..~ 1961 Ran 73 joints, ll 3/4" casing and cemented at 3009' in 2 stages with 2000 sacks cement~ using Halliburton power equipment. Used 1 top and I bottom rubber plug. 1st stage around shoe with 500 sacks of cement. Pumped 50 bblse of water ahead, mixed 500 sacks cement in 37 m_ins, using Halliburton truck, displaced in 24 rains, using rig pumps. Average slurry weight ll6~. Bumped plug with 1800 psi. Full circulation. COMPLETION REPORT SWANS C~ RIVER UNIT 21-22 SECTION 22~ TSN~ R9W~ Seward B & M STrAnD "OIL COMPANY OF' CALIFORNIA - W. O. I. - OP~HATO~ Page 2nd stage through DV at ~481'. Dropped DVbomb, opened DV ports in l0 mins. Pumped 50 bbls. of water ahead, mixed 1500 sacks of cement in 60 mins. using Halliburton truck, displaced in 14 mins. using rig pumps. Average slurry weight 116#. Closed DV ports with 1800 psi. Full circulation. Cement in place at 9:15 A-M. CASING DETAIL: 36 joints or 1457.36' DV Collar 2.00 37 joints or 1525.99 ' Casing in hole 2985.35 Below K.B. 23.50 Cemented at 3008~85 11 3/4", 47# 8R, J-55 (Top at 1481' ) 11 3/4" 47#, 8R, J-55, equipped with Baker shoe and float collar. Installed BOPE and tested with 2000: psi. Drilled out DV collar at 1481'. November !9~ 1961 Tested DV with 2000 psi, O.K. Drilled out cement 1480' - 1690 '. out~ float collar and shoe, 2960' - 3006'. Cleaned out to 3030'. Drilled 10 5/8" hole 3030' - 4157 ' 1127' Drilled Drilled 65-66 pcf mud November 20 -. 23~ 196,1 Drilled 9 7/8" h°le (hole size change) 4157' - 6480' 2323 ' Drilled Changed over to lime base mud at 6400' 62-75 pcf mud .N..q,v. emher ,24,.- Decemb.e,r 20~, 1961,, Drills d 9 7/8" hole 6480' - 10920' 4440' Drilled 75-96 pcf mud COMPLETION REPORT SWANSON RIVER UNIT 21-22 SECTION 22, T8N, R9W, Seward B & M ~TAEDARD OIL' c'OMPANY OF CALIFoRNiK~'' W~,6.i'. '.~' 6P]JR3JTO~ Page 3. D_ecember.. 21, .!9..6~1 Drilled 9 7/8" hole. 10920' - 10984' 64' Drilled Lost circulation at 10.984'. Lost apProximately 300 bbls. fluid. Mixed in lost circulation material and regained circulation. Drilled 9 7/8" hole. 10984' - 11,O12 ' T.D. 28' Drilled Conditioned mud to run logs. 96-97 pcf mud Dec. ember 22,..1961 Ran Schlumberger InduCtion ElectricaI log, 11014' - 3009'. Ran Schlumberger SoniC log, 11010' - 3009'. Ran Schlumberger Microlog-Caliper 11013' - 10513 ' and 4100' - 3600 '. Ran Schlumberger Continous Dipmeter 11011' - 3009'. 96 pcf mud December 23.,~ 196~ Circulated. Ran 264 joints 7" casing. 96 pcf mud December 24., 1.9.61 Cemented 7" casing at 11012' in 2 stages with 1700 sacks cement treated with O.3%HR-4 using Halliburton power equipment. Used l top ~ubber plug. 1st stage around shoe with 600 sacks cement. Pumped 50 bbls. of water ahead, mixed 600 sacks of cement in 20 mins. using Halliburton truck, displaced in 40 rains, using rig pumps. Average slurry weight ll7#. Bumped plug with 2500 psi. Full circulation. COMPLETION REPORT SWANSON RIVER UNIT 21-22 S_ECTION ..22,....1.T ,.8 .N.' ,R 9 W, Seward B & M STANDARD OIL COMPANY OF CALIFORNI~ ' W'O.I. - OPERATOR Page 4. 2nd stage through DV at 7554'. Dropped DV bomb, opened DV ports in 40 mins. Pumpgd 50 bbls. of water ahead, mixed 1100 sacks of cement in 30 mins. using Halliburton truck, displaced in 25 mins. using rig pumps. Average slurry weight 117#. Closed DV ports with 2500 psi. Full circulation. Cement in place at 4:00 A.M. Hookload weight of casing: before cementing 230,000 after cementing before lsnding casing 228~000 at time of landing casing 210,000 CASING DETAIL: Top 3 Next 109 1 45 21 1 1 21 51 1 10 joints or 111.87' 7" 29~ BT N-80 joints or 4608.57' 7" 23# BT N-80 crossover 6.87 ' 29# P-IlO joints or 1929.98' 26~ L8R N-80 joints 902.96 ' 2~9~ L8R N-80 crossover 6.80 ' 29# P-110 DV collar 2.00' (Top at 7554' ) Crossover 6.73' 29# P-IlO joints 909.48' 29# LSR N-80 joints 2105.42' 29# L8R P-110 marker joint 14.35' 29# L8R P-/lC joints 428.54' 29# L8R P-110 ll 3 . 57 ' Cut and recovered -35.16 ' Total casing in hole K.B. to Ldg. Head 22.16' Casing landed at Drilled depth 11012. CO ' Correction: ....... 5'57' Tested secondary packoff with 3500 psi - O.K. Tested shut-off with 15OO psi for 30 mins. - O.K. December 25, 19,,61 Christmas Day off. D.e...ce. mber .26,. !961 Tested BOPE with 2000~ psi - O.K. Picked up 3½" drill pipe. Drilled out DV at 7554'. Tested DV'with 2000~ psi - O.K. Drilled out Baffle plate at 10929'". COMPLETION REPCRT SWANSON RIVER UNIT 21-22 SECTION 22, TSN, R9W, Seward B & M S-TANDA~ O~~-CO~PANY OF cALIFcRN~' W~'0. I: "2" OPERATOR Page 5. December 27,. 19~! Drilled cement 10929' - 10970'. Circulated and conditioned mud. Ran Schlumberger Cement Bond log 10962' - 5000'. Ran Schlumberger Neutron Collar log 10966' - 9966'. Shot 5 - ½" holes at 10800' for HOT #1. .December HCT .#1 on 5 - ½" holes at 10800'. Tool .assembly: 2 outside BT recorders 4' of perf'd tail pipe, 7" type "C" Hookwall packer, VR safety joint, hydraulic jars, 1 inside BT,'recorder, hydrospring tester and TC valve. Ran on 3½" drill pipe. Used. 2700' of water cushion. Set packer at 10755' with 17' of tail to 10772'. Opened tester at 8:50 A.M. for 63 mins. flow test. Weak blow to dead in 15 mins. Shut in tool at 9:53 for 60 mins. FSI pressure. Pulled packer loOse at 10:53 A.M. Recovered 30' net rise, normal drilling fluid.. Final PreSsure Data: ~epth Gau~e Top inside 10742 ' Top outside 10764 ' IH ISI IF FF FSI FH 6503 - 1332 1332 1641- Chart time expired 6553 - 1334 1331 Chart time ex- pired. Bottom outside 10768' 6556 - 1332 1332 W. SoO. - O.K, Shot 4 - ½" holes/foot 10802' - 10816' for HCT #2. 2552 6556 December, ,29 - 31,, ,,19...6.1 __ HCT #2 of the interval 10802' - 10816'. Tool assembly: 2 outside BT recorders, 4' of perf'd tail pipe, 7" type "C" Hookwallpacker, VRsafety joint, hydraulic jars, 2 inside BT recorders, hydrospring teste~, 1OO' of 4 5/8" drill collarsand TCadJustable valve. Ran on 3½" drill pipe Used 2700' of water cushion. Set packer at 10745' with l7' of tail to 10762'. Opened tester at 2:O4A.M. for 2 mins, pressure release. Shut in tester at 2~06 A.M, for 32 mins. ~I pressure period. Opened tool to surface at 5:05 A.M. for 70m ins. flow test. Shit in tool at 6:15 A.M. for 70 mins. flow test. Shut in tool at 6:15 A..~ o 7:05 P.M. (Sump filled up.) Pulled packer loose at 7:05 P.M. COMPLETION REPORT SWANSON RIVER UNIT 21-22 SECTION 22, T8N, R9W~ Seward B & M OF - 0" '- 0P T'0 Page 6. Samples and cuts as follows: ~ Tim.e, Total Cut Water Emulsion S & M ~ ~J :. :.~ 11 !. ,, 1. 12: 30 A.M. 4.0% 0.1% 1.5% 2.4% 2. 1:30 A.M. 1.0% 0.2% 0.,7% 0.1% 3. 2:30 A.M. 1.2% 0.6% 0.4% 0.2% Shut in tool at 2:35 A.M. Started.backscuttle at 2:45 A.M. Samples and cuts as follows: ", :1.'', 2:55 A.M. 3.6% 1.5% 0.7% 1.4% 2. 3:10 A.M. 3.4% 0.7% 1.0% 1.7% 3. 3:25 A.M. 6.0% 1.3% 1.3% 3.4% 4. 3:40 A.M. 10.0% 0.8% 7.2% 2.0% Water tested 16.7 ohm/m at 70°F, - fresh water, turned to tank at 8:15 P.M. Opened ¼" subsurface bean to 3/8" subsurface bean. Back scuttle flow turned to mud at 3:45 A.M. Pulled packer loose at 3:55 A.M. Final pressure data: Depth Gauge Top inside 10728 ' 6446 Bottom inside 10732 ' 6453 Top outside 10754' 6449 Bottom outside 10758' 6529 5325* - 3416 5338* - 3416 5424 197~ 3444 5410 1998- 5333 4909 6424 4909 6424 4981 6422 Chart time expired Shot 4 - ½" holes.foot 10890' - 10895' for HCT #3. HCT #3 of the interval 10890' - 10895'. Tool assembly: 2 outside BT re- corders, 4' of perf'd tail pipe, .7" type "C" Hookwall packer, VR safety joint, hydraulic jars, 2 inside BT recorders, hydrospring tester,llOO' of 4 5/8" drill collars and TC adjustable valve. Rsn on 10730' of 3~" drill pipe. Used 2892' of water cushion. Set packer at 10857' with 7' of tail to 10864'. Opened tester at 3:25 A.M. for 2 mins pressure release. Shut in tester at 3:27 A.M. for 43 mins. ISI pressure period. Opened tool to surface at 4:10 A.M. for 35 mins. flow test. Shut in tool at 10:05 A~M. for 65 rains. FSI pressure. Pulled packer loose at 11:10 A.M. Oil and gas to surface at 5:15 A.M. at a rate of 1000 B/D oil and 75 MCF/D gas. Turned to tank at 6:05 A.M. Cuts: Total .5% (.2% water, .3% S&M). 9:30 A.M. to 10:00 A.M. gauge: 1200 B/D rate. Final Pressure Data: Depth ,Gauge ~ ISI IF._ FF FS!. F~ Top inside 10844 6341 5253 3636 4452 5215 6341 Bottom inside 10844 6416 5276 3664 4466 5231 6416 Top outside 10864 6463 5325 3759 4523 5294 6463 Bottom outside 10870 6423 5347 3791 4524 5294 6423 COMPLETION REPORT SWANSON RIVER UNIT 21-22 SECTION 22, T8N, R9W, Seward B & M sTA~ARD O~ C'O~PA~ OF CALIFORNIA "j'W, '0. i'-' OPER~T6~ Page 7. Jet perforated 4 - ½" holes/foot using Alternate Crack Jets & No Plug 10890' - 10868' and 10849' - 10826 '. , Laid down 3½" drill pipe. Picked up aud started running 2 7/8" tubing. Ran a total of 341 joints of 2 7/8" tubing. Tubing. ~etai,,1..: K.B. to tubing hanger Landing flange and nipple 47 joints 2 7/8" 6.5# 8Rd N-80 Camco MM mandrel & pup joint 45 joints 2 7/8" 6.5# 8Rd N-80 Camco MM mandrel & pup joint 41 joints 2 7/8" 6.5~ 8Rd N-80 Camco MM mandrel & pup joint 33 joints 2 7/8" 6.5~ 8Rd N-80 Camco MM mandrel & pup joint 29 joints 2 7/8" 6.5# 8Rd N-80 Camco MM mm drel & pup joint 26 joints 2 7/8" 6.5# 8Rd N-80 Camco MM mandrel & pup joint 22 joints 2 7/8" 6.5# 8Rd N-80 Camco MM mandrel & pup Joint 92 joints 2 7/8" 6.5# 8Rd N-80 Camco sleeve valve I joint 2 7/8" 6.5# 8Rd N-80 Brown CC safety joint Brown HS-16-1 packer 2 joints 2 7/8" 6.5~ 8Rd N-80 Camco "D" nipple 2 joints 2 7/8" 6.5# 8Rd N-80 Venturi shoe K.B- .D..ePth 20.77' 20,77 3.01 23,78 1515.21 1538.99 13, 1551.99 1424,48 2976.47 13. 2989.47 1288.14 4267.61 13. 429o.61 lO37.97 5328.58 13. 5341.58 915.23 6256.81 13. 6269.81 819.87 7089.68 13. 71o2.68 695.99 7798.67 13. 7811.67 2890.40 10702.07 2.62 10704.69 31.71 10736.40 11,22 10747.62 6, 10753.62 63,22 10816.84 .96 10817.80 62,84 10880.64 .66 1o881.30 Tubing landed at 10881,30 ' Landed tubing. Removed BOPE.~ Installed x-mas tree and tested with 5000 psi for 15 mins.- O.K. Commenced displacing mud with oil at 2:30 P.M. Pumped 50 bbls. of water ahead, followed by 450 bbls. of crude oil. Stopped circulating at 7:00 P.M. Started flowing to trap at 7:30 P.M. Representative flow rate and cuts as follows: COMPLETION REPORT SWANSON Rr~ER UNIT 21-22 SECTION 22, T8N, R9W, Seward B & M STAND~RD OIL COMPANY C~ CALIFORNIA- W.. O. I.~ OPERATOR Page 8. FLOW RATES: ,, BEAN TBG. CSG. TRAP FLOW PERIOD OIL GAS SIZE PRESS . PRESS. PRESS. 1. 1 hrs. 1080 B~ 70 MCF/D 16/~64 800 800 40 2. 1 hrs. 736B/D 45 MCF/D 12/64 1020 1000 40 %TOTAL CUT % WATER ~, EMULSION % SAND & MUD CORR. GRAVITY 1. 1.4 0.8 0.6 trace 31.0 2. 0.8 0.4 0.4 trace 31.7 Shut in well at 11:00 P.M. Shut in pressures; Tbg. press. 1500 psi, Csg. press. 1480 psi. Produced estimated 240 bbls. formation oil. Flowed 200 bhls. to tank and estimated 40 bbls. to sump. Installed cosasco plug. Rig released 5:00 A.M. January 2, 1962. COMPLETION REPORT SWANSON RIVER UNI~ 21-22 SECTION 22~ T8N~ R9W~ Seward B & M STANDARD 0IL COMPA~Y oF'CALIFORNIA -W,0'i. "'OPERA'TOi~ DEVIATION DATA Page 9. Depth Degrees 100' OO15' 808 ' 0o45 ' 1581' 0o30 ' 2990 ' 0o30 ' 4116 ' OO 4360 ' 0o30 ' 4607' l°45' 485 ' lO3O, 5295' 2o3O' 5830' 1°10' 6222 ' 2o45 ' 6468 ' 3°00' 6600' 2°00' 6934' 2°00' 7050' 2°O0' 7305' 1°10' 7614 ' l°30 ' 7800 ' l°30 ' 8180' l°30' 8440 ' l°30 f 8761' l°15' 9071' 2o00 l 9460 ' l°30 ' 9690 ' 2 °00 ' 9940' l°30' 10622 ' l°30 ~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAl. SURVEY LESSEE'$ MONTHLY REPORT OF OPERATIONS State ....... A~_~_~a ................. ~o~ty ................................. F~eld ...... SwaT[son Tl~e followi~ is a correct report of operatio~,.s and prodz~et:io~ (incl,.~ii,.~ ,:!ri[lin~ ar, d producin~ wells) for tl~e mo,.t1, of ...... J~ry .................... ZO_~2.. Sg~~~ .~~ . .O~1 .Zee~*'~ ~aa,~ .......... r. O. Box 7-839 ......................... Com.pan.~~~ ~.~ ........ P~one .......... ~o_~_~_~Z,_6201 ............................................ .:t~e~' s title --'Di~t-.-' ~u~ri~d AND CC: ~ .,~d~nded 3h~ Joints 2 7/8 t~bi~ at lO,Sgl'.~ Tubing equipped ,A~:h Ve~t~i sho~' Camco "D" ni~,~ta~ Bro~ HS-1f-!~packer (at 10,7h7') s~ety joint, Cm¢o sleeve v~lve ~d 7 ~mo ~ a/[ mandrels at 78:L1~ 7iO2~ 6270~ i<]h2~' h291, 2~85 ~ ~d 1S[2. Rem&veal BO~, installed x-,ass t~eo Dis~[~ced ~d with oil ~d fl~ tested~wello aepre- se]~tatiVe rates:': ylowperiod 1 h(,~: 736 B/n oil, 12{64" ~ean. Tubing ~r~ss~e 102( psi, ca~ing pre,sure 1~O psi, tr~¢ pr~ss~e 4o ~si. tm*~ cut, 0.8% (o.h% w., o,4~ E.) Corr. gr~vityl31.7 API.~ Shut~ ~ Dressmes: Tubi~ 15OO ~si~ casing 1480 Dsi. a~ rel~a~ed Janu,.ry 3,;~ 1¢6~. 1 ' { Ala~a O~ & G~ Co Co - Do D. ],race Ohi~ - G~O'. S~rds i' ~ Uni~ - C. Eo iS~th ~ ~~ , Fil~s: ?rodu~g I [ g~lCration NoTE.--There were ........................................ runs or sales of oil; .................................................. M cu. ft. of gas sold; .............................................. runs or ss.las of gasoline during the month. (Write "no" where applicable.) No~E..--Report on this form is required for each calendar month, regardless of tho status o[ opcrauions, and must be filed in duphcate with the supervisor by the 6th of the succeeding month, unl~ otherwise directed by the supervisor. Form 9-3~9 (January UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL suRvEY LESSEE'S MONTHLY REPORT OF OPERATIONS 2:2 State ........... ~l._a_s_ ~_~ ............ County _K_~--n~-~i_._~pinsula ..... Field ...... .S",~'~SOn ~ve~_ The fo~lozvin~ is a correct report of operation, s and produetio~ (i/;(,Iu,li~,:2 .frillin~ a~d prod~cinE wells) for tke month of ....... ~q~r ..................... , Ag.~} ....... ~p~..R~ger 'Unit _ ST~ XRD_ O~~ OF CALIFORN IA .~gent'~ address ........ P. O._ ~B~_.7.83R ............................ compa.y~ ~ ~.r~i~ ~. ....... Phone .......................... _~~_a~_.7:~:791 ............................... Z~ent s t~tle D~u~r%c~_S~r~ter~e_a~ TwP. R~N'GE NO I Pao;uc~ BA~ELS O~ O~ GR'AVITY CU. FT. OF OAS GASOLINE WATER (Ir (I~ drillin¢, d,pth: if nhut down, . ~ - . ~ . (In tb0~m]ds) ~ECOgERED fl0110, SO state) dau, nad r~uh of l~t for an¢ see~ 5~o~ D.V.',ag 7,546~ w/ll00 sacks. D~lled ou~ D.go ~ tested ~/200~- 0.:[o DrSll~C out cem~n~ to 19,970!. ~ ' CBS 10,~67- ~~' ~d NOL 10,96; - 9,9707. Shot ~5 - ~" holes at 101802 4 10,8~6' ~r HCr ~2. ' --] --- · Hag HCT !#2 on perf~rate~ interval I0,802 -! 10,816 ~ j Used 2,700 ScS packer at 10,~5'. 132 min. III. Opened tool ~d flowed oil to sump, at,{200 - 250 ~/D~ $5 MCF/D r~,te. Total cut lj2% (006% W, 0°4% E, 0.~% S ~ M),. Pree[sures~ IH 6432 psi, ISI 5351 ps~, IF 2155 psi, ~ ~ '' " M P ' Alf, FF 3428~ FSi 5322 psi, ~'~. 6405 pSilo '.erfo~ated 4 ~ holes per foot 005% S ~ ~). ~es,~es, IH 6431 I. si, ISI~5322 psi, IF 3585 osi, FFl~73 ~psi, ~I 5~70 PSi, ~ 6431 psi. P~rf0rate~ for La~ d~ d~ll ..... ' .......... tubin~ ' n NoTr.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or-sal~ of gasoline during the month. (Write "no" where applicable.) NOTE. Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the suoeeoding month, un/ess otherwise directed by the supervisor. Form 9-829 (January 19,50) t6--2576a--!t U S ']uYY. R*~ar P,,1,1~TtNa OFFICI~ UNITED 'STAT~ ~.~ o~ac~ .... .~ DEPARTMENT OF THE INTERIOR ~ GEOLOGICAL SURVEY UNIT ........... LESSEE'S MONTHLY REPORT OF OPERATIONS State Alaska Cou.~tyK_e_.n__a.~_P.A_r~._.~.a_ ..... Field Swansor: Hiver The, fol~owi~ is a correct report of operatio~,s a~,d prod~ctio~ {'i-~:cluJi~'~g drillit,~ arid prod~ciz,~ wells)for the moz~th of Nove~er . '9 61 S~anson ~iver Unit ,,~ - __{ .... {~1 ........... 22 8N ~ SR 2!-~2 (26) ,ml Sp~dded}Nove~er ~, 19kl. ~rill~d 12~" h~le OX- 1,600{o ~i ~ned i21" hole ~o 17~' O- 1,'255'o. ~er~d 124" to 16" ~ ~,OO8! with 2,0~0 sae~s ~nt ~n two stages$ ls~ arced sb~ w/SO0 sacks?2nd t4ro~h D.V; ~ 1,48~' w/1,500 sacks cemento In4t~l~d DO~ ~ teSt~d t~ 2,00(~ - O.Kol Drilled out cement ~hD.V~ ~ 1.480'J Te's~e~ D.V~ C~.ll~ ,Vo_ ,. ' I , I ' I I ' BEC 14 1961 I ~ [ PeSo/cum Branch J D~idon of Mines and Minerals } Alaska De.t. oF ~'ot,,ral Resources { { eot ~oSoC.S. H. S~ter (2) ~ichJ'ield - C W. ~er~, R. r.. ~t ;er ~. C. E.{ S~t~ ) ~lo~att~ NoTm.--There were ....................................... runs or sales of off; ............................................... M cu. ft. of gas sold; ............................................. runs or sal~s of gasoline during the month. (Write "ac" where applioable.) NoT~.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the'succeeding month, unless otherwise dh~cted by the supervisor. Form ~-.~1 n~ (Feb. 19~1) (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT Of ThE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL NOTICE OF INTENTION 'TOCHANGE PLANS NOTICE OF INTEN]ION TO TEST WATER SHUT-OFF NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL NOTICE OF INTENTION TO SHOOT OR ACIDIZE NOTICE OF INTENTION TO PULL OR ALTER CAEING NOTICE OF INTENTION TO ABANDON WELL SUBSEQUENT REPORT OF WATER 5HUT-OFF SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING SUBSFQUENT REPORT OF ALTERING CASING SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR SUBSEQUENT HEPORT OF ABANDONMENT SUPPLE'MENTARY WELL HISTORY (INDICATE ABO~E BY CHECK MARK NATURE OF REPORT NOTICE. ()R OTHER DA/Al Well No. 8EU 21-22is located ~ ft. from ~1[~ line and 1.980 ft. from :~ line of sec. ~W~ ~ ~ ~J ~c, (4 ~c'. and ~,~,. No ~a_ R~ver Ke,nnJ. pen.l, ns~lA AZaska The elevation of the ~above sea level is 310 ft. DETAILS OF WORK (State nimea of and expected depth, to ob~.ective sands; show ~i~s weights, and lenltha ~ pro~ caan~l I~t~te muddi,I ,)~. ~men~ inS points, and all other imp~tant pro~ w~) 1. Drill to 3OO0' Log & Cemant 11 3/4" ca~ing in 2 ste~. to surface. 2. Install & teat CLsos IH ~lo~ut Preventloa ~nt. 3. Drill ai~a~ to appmximatel~ 11050', Los Obtain requisi~e wter s~ut-offs. 5. 8electivel~ Jet perforate attractive 6. ~ 2 7/8" tubin~ & oon~lete. I un--stand that this plan of wor~ must r~cmve approva! in ~'ttin~ by tho G~olo~ical ~urvev I~for. operations may b~ commtne~d. Company S~~ Oil O0mi~F of Oaliformi~, wester~ op~er~.~tlon~,' !~_nc. _ .... Address L.O. ~ox_ 7-~3~ ............ ._A~. _m .1~__ Title Dist. Supt., A~sk~ NO±U]±_LV,H3 'A pou:~!$ leU!2pO · aMpal~aomt .,O.u ~o ~soq aq% -azd se~ 1.xoc[a.x sIt[1 leql pue :l~oda.x s!ql a~[etu ol ,~tredtuoo pies ,~q pa~..zoqlne ute I leql pTXe '(~uedtuoo) (ouoz 2u!onpoad ~ou po~oodxo puc ouoz 2u!onpoad %uoso.~d 2ulA!2 'ouop oq ol >I-~o~ oql.~oSOp Xgol.zq ':/o~q 2n[d .to uodoop ol uol~o!idd~ u~ s! s!tI1 ~I) puoq ~o snl~S sso-,pp¥ atu~eN :posm3qoand u~oq~, tuo-,~ 'POII!.~p SllO-~ o~iotu ~o ouo q]?A poem~qoand 'osm~o[ iii :-,toAaob~e:l siq] oh ~U!ll!-'P ao u! po~OldtUoo 'lie~ sitI1 2u!PnlOu! 'osm~Ol uo Slle.~ $o aoqtunbl l.,ul~ I[IAa ~l.~o.~,~ olmzp 'xoJddV SlOOl olq~o ao (punoa~) uoll~AalfE · - uoa. vuMao u0 XNva~o0 ao a~vt¢ ~"I"IIH(I O,L NlOI-~I,~OI~IctcI¥