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Home My WebLink About190-152Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 43B-08 (PTD 190-152) PERF 09/08/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/10/2021 By Abby Bell at 9:33 am, Nov 10, 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 10,826 feet 5670, 5765, 10260 feet true vertical 10,820 feet 10,265 (fish) feet Effective Depth measured 5,655 feet 5802, 5872 feet true vertical 5,654 feet 5801, 5871 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3# / N-80 8,914' MD 8,912' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 10,327' MD 10,322' TVD 3-1/2" TTS gravel pkr 5,802' MD, TVD 3-1/2" TTS sump pkr 5,872' MD, TVD Packers and SSSV (type, measured and true vertical depth)Baker D 5"x2-3/8" pkr 10,276' 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 3,820psi 3,070psi 6,340psi Burst Collapse 1,510psi 30' 2,085' 9,387' 5" 9,380' 10,742'10,734' measuredPlugs Junk measured N/A Length 30' 2,085' Size Conductor Surface Intermediate 20" 11-3/4" 7" Production Liner 9,380' 1,757' Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-152 50-133-10121-02-00 N/A 5. Permit to Drill Number:4. Well Class Before Work: FEDA028996 Swanson River Field / Tyonek Gas Pool 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 3. Address: Soldotna Creek Unit (SCU) 43B-08 2. Operator Name:Hilcorp Alaska, LLC measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 00 0 140 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 30' 2,085' 0 Structural TVD 321-404 Sr Pet Eng: 10,190psi Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 125 10,140psi Jake Flora, Operations Engineer jake.flora@hilcorp.com 907-777-8442Dan Marlowe, ASC Team Operations Manager, 907-283-1329 t Fra O O A PG , R 6. A Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 12:35 pm, Nov 05, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.05 11:29:01 -08'00' Dan Marlowe (1267) DSR-11/8/21SFD 11/5/2021BJM 11/9/21 2073' RBDMS HEW 11/5/2021 9378' 2073' SFD Rig Start Date End Date 9/3/21 10/6/21 Crew arrives at location. Permits, JSA. Rig up E-line. RIH W/ 1' X 2-3/8" 5SPF HSC TAGGED BOTTOM @ 5,650' RAN CORRELATION ACROSS PERF INTERVAL AND SENT TO THE ENGINEER LOG WAS FLAT PULLED INTO POSITION AND PERF @ 5,615'-5,625'. RIH W/ 10' x 2-3/8" 5SPF HSC TAGGED @ 5,646' RAN LOG AND SENT IN TO ENGINEER LOG WAS FLAT PULLED INTO POSITION AND PERFORATED @ 5,635'-5,645'. 10/06/2021-Wednesday Evaluating path forward with reservoir engineer. 09/07/2021 - Tuesday 09/03/2021- Friday Crew arrives at location. Permits, JSA. Rig up E-line. RIH W/ 2-3/8” razor (60 degree / 5 SPF) to 5,591'. Sticky pickup. Sit down several times, could not get to depth for perf. POOH. OOH crew rigs down, signs out leaves location. Slick line scheduled for tomorrow to bail. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 43B-08 50-133-10121-02-00 190-152 PERF @ 5,615'-5,625'. PERFORATED @ 5,635'-5,645'. Updated by JMF 11-02-21 SCHEMATIC Swanson River Field SCU 43B-08 API: 50-133-10121-02-00 PTD: 190-152 JEWELRY DETAIL NO. Depth ID OD Item - 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” A 5,670’ CIBP with 15’ of cement – TOC @ 5,655’ (Set 5/4/21) B 5,765’ - - CIBP with 8’ sand and 35’ cement cap - TOC @ ~5,722 (Set 4/9/21) C 5,802’ 1.630 2.720 5011 series TTS GP packer w/snap latch seal assembly 2400# shear D 5,849’ 1.500 2.190 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) E 5,872’ 1.630 2.720 Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” F 8,900’ Fas Drill Cement Retainer 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple G 10,260’ Drillable CIBP H 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG PERFORATION DETAIL (DIL Depths) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Comments TY 57-8 5,615’ 5,625’ 5,615’ 5,625’ 10’ 4 5/6/2021 Re-Perf on 9/7/21 TY 57-8 5,635 5,645’ 5,635 5,645’ 10’ 5 9/7/2021 TY 57-8 5,680’ 5,690’ 5,680’ 5,690’ 10’ 5 4/12/2021 2-1/8” Spiral - Iso 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 11/3/2004 2.5” PJ HC - Iso 5,857’ 5,867’ 5,856' 5,866' 10’ 5 11/27/2004 Spiral Jet - Iso Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 6/13/2004 1.56” Gun - Iso H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Mar ‘01 Temp ISO H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Mar ‘00 Temp ISO 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Dec ‘99 Temp ISO H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Dec ‘99 Temp ISO H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Jul ‘94 Temp ISO H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Dec ‘99 Temp ISO H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Jul ‘94 Temp ISO 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Dec ‘99 Temp ISO 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Dec ‘93 Temp ISO H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Apr ‘91 Temp ISO H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr ‘91 Temp ISO 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Feb 91’ Temp ISO 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Dec ‘93 Temp ISO 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr 91’ Temp ISO CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾” Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL TUBING DETAIL 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ RKB 17.3’ TOC @ 7930’ CBLTD= 10,826’ PBTD= 5,655’ Max Deviation = 5.3q @10,322’ CBL Ratty TOC @9780’CBL Good TOC @10 500’ 1 2 3 4 5 6 Btm @ 6100’ & TOC @ 5570’ CBL Obstruction @ 10,286’ 59-2 TOC @ 5074’ F G C D E B H TY 57-8A Capillary String installed 6/3/2021 3/8” Stainless Steel at 1000’ TY 57-8 5,635 5,645’5,635 5,645’10’5 9/7/2021 ,,,,//// David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: SCU 43B-08 Perf & Plug (PTD 190-152) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW Received By: 08/30/2021 By Abby Bell at 9:10 am, Aug 26, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,826'10,265' Casing Collapse Structural Conductor Surface 1,510psi Intermediate 3,820psi Production Liner 10,190psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: August 30, 2021 10,742'1,757' 3-1/2" ; 2-3/8" 10,734' Perforation Depth MD (ft): 9,069' See Attached Schematic 5" 20" 11-3/4" 30' 7"9,380' 2,073'3,070psi 30' 2,073' 9,067' 30' 2,073' 9.3# / L-80 ; 4.6# / L-80 TVD Burst 8,914' ; 10,327' MD 6,340psi Length Size CO 716 & 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028996 190-152 50-133-10121-02-00 Soldotna Creek Unit (SCU) 43B-08 Swanson River Field / Tyonek Gas Pool COMMISSION USE ONLY Authorized Name: 10,140psi Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 10,820'5,655'5,654'1,955 5670'; 5765'; 10260' Baker Model 'D' 5" x 2-3/8" Permanent Packer ; N/A 10,276' MD / 10,271' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:55 am, Aug 17, 2021 321-404 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.16 15:56:12 -08'00' Taylor Wellman (2143) 10-404 SFD 8/17/2021BJM 8/17/21 9,3789,380 DSR-8/17/21 SFD 8/17/2021 dts 8/18/2021 JLC 8/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.18 11:52:41 -08'00' RBDMS HEW 8/19/2021 Well Prognosis Well: SCU 43B-08 Date: 8/30/2021 Well Name: SCU 43B-08 API Number: 50-133-10121-02-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: 8/30/2021 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 190-152 First Call Engineer: Jake Flora (907) 777-8442 (O)(720) 988-5375 (C) Second Call Engineer: Todd Sidoti (907) 777-8443 (O)(907) 632-4113 (M) AFE Number: Max Expected BHP: ~2543 psi @ 5872’ TVD Based on normal gradient Max Expected WHP: ~1955 psi Based on expected BHP minus 0.1 psi/ft gas gradient History and Objective Per sundry #546431 Hilcorp set a plug at 5765’, dumped 35’ of cement on top and perforated the TY 57-8 sand from 5680-5690’. The sand tested wet and was plugged back. The Tyonek 56-9 was shot from 5615’-5625’ and produced commercial gas until the well had to be shut in due to sand production. Slickline bailed sand and uncovered the perforations. The objective of this job is to re-perforate the 56-9. E-line Procedure: 1. MIRU E-line and pressure control equipment, PT lubricator to 250 psi low & 3000 psi high. 2. Perforate the following with 2-1/8” Shogun Spiral guns loaded at 6 SPF: a.Final perforation intervals will be provided prior to loading guns for exact depths. b.Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Actual Schematic Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt. Tyonek 56-9 +5593’+5658’+5592’+5557’65’ o re-perforate the 56-9. Per Sundry 321-117 - bjm Updated by TCS 06-10-21 SCHEMATIC Swanson River Field SCU 43B-08 API: 50-133-10121-02-00 PTD: 190-152 JEWELRY DETAIL NO. Depth ID OD Item - 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” A 5,670’ CIBP with 15’ of cement – TOC @ 5,655’ (Set 5/4/21) B 5,765’ - - CIBP with 8’ sand and 35’ cement cap - TOC @ ~5,722 (Set 4/9/21) C 5,802’ 1.630 2.720 5011 series TTS GP packer w/snap latch seal assembly 2400# shear D 5,849’ 1.500 2.190 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) E 5,872’ 1.630 2.720 Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” F 8,900’ Fas Drill Cement Retainer 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple G 10,260’ Drillable CIBP H 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG PERFORATION DETAIL (DIL Depths) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Comments TY 57-8 5,615’ 5,625’ 5,615’ 5,625’ 10’ 4 5/6/2021 2-1/8” Spiral - Open TY 57-8 5,680’ 5,690’ 5,680’ 5,690’ 10’ 5 4/12/2021 2-1/8” Spiral - Iso 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 11/3/2004 2.5” PJ HC - Iso 5,857’ 5,867’ 5,856' 5,866' 10’ 5 11/27/2004 Spiral Jet - Iso Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 6/13/2004 1.56” Gun - Iso H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Mar ‘01 Temp ISO H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Mar ‘00 Temp ISO 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Dec ‘99 Temp ISO H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Dec ‘99 Temp ISO H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Jul ‘94 Temp ISO H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Dec ‘99 Temp ISO H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Jul ‘94 Temp ISO 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Dec ‘99 Temp ISO 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Dec ‘93 Temp ISO H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Apr ‘91 Temp ISO H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr ‘91 Temp ISO 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Feb 91’ Temp ISO 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Dec ‘93 Temp ISO 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr 91’ Temp ISO CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾”Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL TUBING DETAIL 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ RKB 17.3’ TOC @ 7930’CBLTD= 10,826’ PBTD= 5,655’ Max Deviation = 5.3qq @10,322’ CBL Ratty TOC @ 9780’CBL Good TOC @10 500’ 1 2 3 4 5 6 Btm @ 6100’& TOC @ 5570’CBL Obstruction @ 10,286’ 59-2 TOC @ 5074’ F G C D E B H TY 57-8 A Capillary String installed 6/3/2021 3/8” Stainless Steel at 1000’ David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: DATE: 07/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 43B-08 (PTD 190-152) PLUG-CEMENT-PERF RECORD 05/04/2021 Please include current contact information if different from above. 07/26/2021 Received By: 37' (6HW By Abby Bell at 10:57 am, Jul 26, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Cap String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,826 feet 5670, 5765, 10260 feet true vertical 10,820 feet 10,265 (fish) feet Effective Depth measured 5,655 feet 5802, 5872 feet true vertical 5,654 feet 5801, 5871 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3# / N-80 8,914' MD 8,912' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 10,327' MD 10,322' TVD 3-1/2" TTS gravel pkr 5,802' MD, TVD 3-1/2" TTS sump pkr 5,872' MD, TVD Packers and SSSV (type, measured and true vertical depth)Baker D 5"x2-3/8" pkr 10,276' 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: Contact Phone:777-8443 WINJ WAG 1,406 Water-Bbl MD 30' 2,085' 10,742' 1 Oil-Bbl measured true vertical Packer 5" 9,298' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Tyonek Undef GasN/A measured TVD Tubing Pressure 1,4804 Soldotna Creek Unit (SCU) 43B-08 N/A FEDA028996 9,300' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-152 50-133-10121-02-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 1,207 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 1,140 Authorized Signature with date: Authorized Name: 1,060 Casing Pressure Liner 1,757' 1,503 10,734' 0 Representative Daily Average Production or Injection Data 30' 2,085' 9,380' Conductor Surface Intermediate Production 10,190psi Casing Structural 20" 11-3/4" 7" Length 6,340psi 3,070psi Collapse 1,510psi 3,820psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,140psi Burst 30' 2,085' t cee Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:25 pm, Jun 18, 2021 gg Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.18 11:39:15 -08'00' Taylor Wellman (2143) RBDMS HEW 6/22/2021 SFD 6/21/2021DSR-6/21/21BJM 10/11/21 Rig Start Date End Date 6/3/21 6/3/21 6/03/2021 - Thursday MIRU Dynacoil unit. PT unit 250 psi low 1,500 psi high. RIH with 3/8" capillary string and set at 1,000'. Remove string from injector and move spool to wellhead. RDMO Dynacoil unit. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 43B-08 50-133-10121-02-00 190-152 Updated by TCS 06-10-21 SCHEMATIC Swanson River Field SCU 43B-08 API: 50-133-10121-02-00 PTD: 190-152 JEWELRY DETAIL NO. Depth ID OD Item - 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” A 5,670’ CIBP with 15’ of cement – TOC @ 5,655’ (Set 5/4/21) B 5,765’ - - CIBP with 8’ sand and 35’ cement cap - TOC @ ~5,722 (Set 4/9/21) C 5,802’ 1.630 2.720 5011 series TTS GP packer w/snap latch seal assembly 2400# shear D 5,849’ 1.500 2.190 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) E 5,872’ 1.630 2.720 Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” F 8,900’ Fas Drill Cement Retainer 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple G 10,260’ Drillable CIBP H 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG PERFORATION DETAIL (DIL Depths) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Comments TY 57-8 5,615’ 5,625’ 5,615’ 5,625’ 10’ 4 5/6/2021 2-1/8” Spiral - Open TY 57-8 5,680’ 5,690’ 5,680’ 5,690’ 10’ 5 4/12/2021 2-1/8” Spiral - Iso 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 11/3/2004 2.5” PJ HC - Iso 5,857’ 5,867’ 5,856' 5,866' 10’ 5 11/27/2004 Spiral Jet - Iso Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 6/13/2004 1.56” Gun - Iso H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Mar ‘01 Temp ISO H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Mar ‘00 Temp ISO 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Dec ‘99 Temp ISO H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Dec ‘99 Temp ISO H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Jul ‘94 Temp ISO H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Dec ‘99 Temp ISO H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Jul ‘94 Temp ISO 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Dec ‘99 Temp ISO 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Dec ‘93 Temp ISO H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Apr ‘91 Temp ISO H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr ‘91 Temp ISO 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Feb 91’ Temp ISO 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Dec ‘93 Temp ISO 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr 91’ Temp ISO CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾” Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL TUBING DETAIL 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ RKB 17.3’ TOC @ 7930’ CBLTD= 10,826’ PBTD= 5,655’ Max Deviation = 5.3qq @10,322’ CBL Ratty TOC @ 9780’CBL Good TOC @10 500’ 1 2 3 4 5 6 Btm @ 6100’& TOC @ 5570’CBL Obstruction @ 10,286’ 59-2 TOC @ 5074’ F G C D E B H TY 57-8 A Capillary String installed 6/3/2021 3/8” Stainless Steel at 1000’ 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,826 feet 5670, 5765, 10260 feet true vertical 10,820 feet 10,265 (fish) feet Effective Depth measured 5,655 feet 5802, 5872 feet true vertical 5,654 feet 5801, 5871 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3# / N-80 8,914' MD 8,912' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.6# / L-80 10,327' MD 10,322' TVD 3-1/2" TTS gravel pkr 5,802' MD, TVD 3-1/2" TTS sump pkr 5,872' MD, TVD Packers and SSSV (type, measured and true vertical depth)Baker D 5"x2-3/8" pkr 10,276' 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: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,140psi Burst 30' 2,085' 6,340psi 3,070psi Collapse 1,510psi 3,820psi 10,190psi Casing Structural 20" 11-3/4" 7" Length 30' 2,085' 9,380' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,757' 880 10,734' 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-117 1,995 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 190-152 50-133-10121-02-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Soldotna Creek Unit (SCU) 43B-08 N/A FEDA028996 9,300' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River Field / Tyonek Undef GasN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5" 9,298' WINJ WAG 0 Water-Bbl MD 30' 2,085' 10,742' 9 t cee Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:56 pm, May 19, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.19 15:12:58 -08'00' Taylor Wellman (2143) Revised depths from Sundry Application received Dec. 9, 1993 34' SFD 5/21/2021 34' 2073'2073' DSR-5/19/21 RBDMS HEW 5/20/2021 9380' 10,826' SFD 5/21/2021 SFD 5/21/2021BJM 10/14/21 Rig Start Date End Date 4/8/21 5/6/21 05/02/2021 - Sunday Crew arrives at facility. Permits, JSA, jobscope. Begin rig up of slickline. Pump 20 gallons methanol prior to stabing on lubricator. PT lubricator 250/2,500. RIH W/ (rigid tool string, 10' 1.75" weight bar, oil jars, long stroke spang jar, 3' weight bar) 2.5" gauge ring to 4' past tubing hanger, sit down. Work down to 80' while pumping methanol. Fall to 2,000'. POOH. RIH W/ 2.5" x 5' DD bailer to 5,712' KB. POOH. Fluid level verified ~ 3,220'. Discuss plan forward with engineer. Slickline rigs down, secures well and moves to another well. 04/08/2021 - Thursday Crew arrives at facility. Permits, JSA, jobscope. TGSM. Begin rig up E-line, PT 250 low/3,000 high. RIH W 2.77'' gauge ring/junk basket. sit down at tubing hanger. POOH. RIH W/ junk basket with no gauge ring, make it past tubing hanger. POOH. RIH W/2.8'' LIB sit down at tubing hanger. POOH. Marks around edge of LIB (restriction on one side). RIH W/2.55'' LIB Pass tubing hanger to 200', POOH. Discuss with town options for a different plug, decided to get a 2.5'' OD CIBP sent out to replace the 2.75'' OD CIBP. RIH W/ GPT and 2.53'' GR. Fluid identified ~2,815', continue RIH to 5,768'. Tag bottom. POOH. RIH W/ 2.5'' CIBP to 5,768'. Make correlation pass. send to town. +8' correction needed. make +8' correction spot and set plug at 5,765'. POOH. OOH plug set. Lay down lubricator for evening due to wind guests over 35 MPH. Crew leaves facility. 05/01/2021 - Saturday Crew arrives at facility. Permits, JSA, discuss job with involved personnel. Rig up E-line to run GPT. PT lubricator. RIH W/ GPT to 4' lightly sit down, pull up fairly sticky. Try several more times sit down same spot. POOH OOH. No Mark's on tapered plug on GPT bottom. Discuss W/town options. Since we are across the tree valves we decide to get slickline out tomorrow. E-line lays down lubricator and stages equipment at edge of pad. E-line signs out and leaves facility. 04/12/2021 - Monday Crew arrives at facility. Permits, JSA, jobscope. Spot equipment. TGSM. Begin to rig up E-line. PT lubricator 250 low/ 3,000 high. RIH W/ 2-1/8'' x 10' shogun spiral strip loaded at 4 SPF/60 deg. Make correlation pass. send to town. +1' correction, spot and shoot 5,680'-5,690' (TY 57-8) ~200 pound weight loss when gun fired. POOH smooth. OOH. All shots fired. Strip carrier intact. Lay down tools, rig down E-line. E-line rigged down. Turn well over to production. WHP: Pre shots fired: 1,207psi, shots: ~1,225 psi, 5 min: 1,231 psi, 10 min: 1,238 psi, 15 min: 1,242 psi. Crew turns in permit, signs out, Leaves facility. 04/09/2021 - Friday Crew arrives at facility. Permits, JSA, jobscope. Stand up lubricator. PT. RIH W/ Dump bailer W/3 gallons sand to 5,760' dump sand. POOH. RIH W/ bailer W/6.24 gallons cement to 5,755' dump cement. POOH. RIH W/ bailer w/ 6.24 gallons cement to 5,745' dump cement. POOH. Rig down E-line. Leave facility. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 43B-08 50-133-10121-02-00 190-152 MITIA to 2100 psi performed 4/7/21. Good test. - bjm Rig Start Date End Date 4/8/21 5/6/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 43B-08 50-133-10121-02-00 190-152 Crew arrives at facility. Permits, JSA, Jobscope. Stand up lubricator. E-line begins to have Electrical issues. Trouble shoot issue. Electrical issue fixed on E-line unit and proven good continuity. PT lubricator 250/3,000. RIH W/ 1-11/16'' tool string W/ 2.5'' CIBP. Make correlation pass. Send to town, zero footage correction needed. Spot and set plug at 5,670'. Good weight loss. POOH. Fluid level ~3,220' weight loss indicated (same as slickline FL tag). OOH, plug set. Rig up Dump bailer for cement. RIH W/ 2.5'' dump bailer W/ 5.2 gallons cement to 5,662'. Dump cement. Good break/weight loss. POOH. OOH cement dumped. Lay down lubricator. E-line crew stages equipment at pad and leaves location. 05/05/2021 - Wednesday Crew arrives at facility. Permits, JSA, jobscope. Strat equipment. Rig up slickline. Production begins to bleed tubing pressure off to T.S. pressure. RIH W/2.7'' gauge ring to 5,680' KB. No obstruction. Tag cement, POOH. OOH. change tools to begin to swab. Production shuts in wing valve. Rig up hard line to bleed remaining pressure to swab/bleed tank. RIH W/ 2 x 3-1/2'' swab mandrels. Start with 200' bite. Work up to 350' bites. Change out swab cups as needed, pulling ~200' fluid out per run. Swab down to ~5,400'KB. Secure well. Rig down slickline. Turn well over to production. 05/06/2021 - Thursday Crew arrives at facility. Permits, JSA, jobscope. Arrive at well site. Start equipment, Begin to rig up E-line. PT 250 low/3,000 high. RIH W/ 2-1/8'' spiral strip, W/ 11gm charges (60 DEG/4 SPF) Make correlation pass. Send to town. shift +1'(shift logs down). Spot and shoot proposed perf 5,605'-5,615'. Good break W/ no weight change. POOH. OOH detonator went off. Gun did not fire, notify town, hot shot new det cord. Standby. Rebuild gun. RIH W/ 2-1/8'' spiral strip, W/ 11gm charges, (60 DEG/4 SPF). Make correlation pass. Send to town. No depth shift required. Geologist changed desired interval from 5,605'-5,615' to 5,615'-5,625'. Spot and shoot. Pressure spike from 1,176 psi. 5 min: 2,085 psi. 10 min: 2,208 psi. 15 min: 2,212 psi POOH. OOH all shots fired, came out with whole carrier. Twisted wire near rope socket. E-line secures well and begins rig down. Turn well over to production. Crew turns in permits/leaves facility. 05/04/2021 - Tuesday o 5,615'-5,625'. Spot and shoot. MITIA to 2000 psi performed on 14-Oct-21. Good test. bjm Spot and set plug at 5,670'. / 5.2 gallons cement to 5,662'. Dump cement. Gun did not fire, Updated by DMA 05-12-21 SCHEMATIC Swanson River Field SCU 43B-08 API: 50-133-10121-02-00 PTD: 190-152 JEWELRY DETAIL NO. Depth ID OD Item - 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” A 5,670’ CIBP with 15’ of cement – TOC @ 5,655’ (Set 5/4/21) B 5,765’ - - CIBP with 8’ sand and 35’ cement cap - TOC @ ~5,722 (Set 4/9/21) C 5,802’ 1.630 2.720 5011 series TTS GP packer w/snap latch seal assembly 2400# shear D 5,849’ 1.500 2.190 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) E 5,872’ 1.630 2.720 Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” F 8,900’ Fas Drill Cement Retainer 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple G 10,260’ Drillable CIBP H 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG PERFORATION DETAIL (DIL Depths) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date Comments TY 57-8 5,615’ 5,625’ 5,615’ 5,625’ 10’ 4 5/6/2021 2-1/8” Spiral - Open TY 57-8 5,680’ 5,690’ 5,680’ 5,690’ 10’ 5 4/12/2021 2-1/8” Spiral - Iso 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 11/3/2004 2.5” PJ HC - Iso 5,857’ 5,867’ 5,856' 5,866' 10’ 5 11/27/2004 Spiral Jet - Iso Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 6/13/2004 1.56” Gun - Iso H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Mar ‘01 Temp ISO H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Mar ‘00 Temp ISO 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Dec ‘99 Temp ISO H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Dec ‘99 Temp ISO H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Jul ‘94 Temp ISO H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Dec ‘99 Temp ISO H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Jul ‘94 Temp ISO 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Dec ‘99 Temp ISO 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Dec ‘93 Temp ISO H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Apr ‘91 Temp ISO H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr ‘91 Temp ISO 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Feb 91’ Temp ISO 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Dec ‘93 Temp ISO 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Apr 91’ Temp ISO CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾” Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL TUBING DETAIL 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ RKB 17.3’ TOC @ 7930’ CBLTD= 10,826’ PBTD= 5,655’ Max Deviation = 5.3qq @10,322’ CBL Ratty TOC @ 9780’CBL Good TOC @10 500’ 1 2 3 4 5 6 Btm @ 6100’ & TOC @ 5570’CBLObstruction @ 10,286’ 59-2 TOC @ 5074’ F G C D E B H TY 57-8 A TY 57-8 5,615’ 5,625’5,615’5,625’10’4 5/6/2021 2-1/8” Spiral - Open TY 57-8 5,680’ 5,690’5,680’ 5,690’10’5 4/12/2021 2-1/8” Spiral - Iso p( )()p( )() 1 Winston, Hugh E (CED) From:Todd Sidoti - (C) <Todd.Sidoti@hilcorp.com> Sent:Tuesday, September 28, 2021 8:53 AM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] SCU 43B-08 (PTD 190-152) 10-404 MITIAs Hi Bryan, I sincerely apologize for my mistake, I had the well mixed up with SCU 42B‐05. We failed to perform a post‐perforating MIT‐IA on SCU 43B‐08. The only MIT‐IA performed on the well was on 4‐7‐21. We should have performed the test per the Sundry and gas production starting on 5‐13‐21. The well is currently off line, I will get a MIT‐IA performed immediately. Ted forwarded me a note on CLU‐01RD. He is no longer with our group and I will follow up with you as soon as I research your request. Thanks, Todd From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Monday, September 27, 2021 4:23 PM To: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com> Subject: RE: [EXTERNAL] SCU 43B‐08 (PTD 190‐152) 10‐404 MITIAs Todd, The attached Sundry 321‐117 had a condition to do an MITIA before and after perforating. Sundry 321‐404 says that the perfs added as part of 321‐117 produced commercial gas until they had to be shut in due to sand production. It’s not making a lot of sense. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com> Sent: Monday, September 27, 2021 2:52 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] SCU 43B‐08 (PTD 190‐152) 10‐404 MITIAs Hi Bryan, 2 No post job MIT‐IA was performed as we never produced hydrocarbon. I can get one performed if you would like, as it does not say in the sundry MIT‐IA before and repeat after production is established. I’m am not sure the way you want to go on that in the future. Thanks, Todd From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Monday, September 27, 2021 2:41 PM To: Todd Sidoti ‐ (C) <Todd.Sidoti@hilcorp.com> Subject: [EXTERNAL] SCU 43B‐08 (PTD 190‐152) 10‐404 MITIAs Hi Todd, The 10‐404 for Sundry 321‐117 did not include the pre or post‐perf MITIA to 2000 psi. Were these done? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 43B-08 (PTD 190-152) PERFORATING RECORD 04/12/2021 Please include current contact information if different from above. PTD: 1901520 E-Set: 35090 Received by the AOGCC 05/04/2021 05/04/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/04/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 43B-08 (PTD 190-152) PERFORATING RECORD 04/09/2021 Please include current contact information if different from above. PTD: 1901520 E-Set: 35089 Received by the AOGCC 05/04/2021 05/04/2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,826'N/A Casing Collapse Structural Conductor Surface 1,510psi Intermediate 3,820psi Production Liner 10,190psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 10,820'8,808'8,806'1,955 N/A Baker Model 'D' 5" x 2-3/8" Permanent Packer ; N/A 10,276' MD / 10,271' TVD ; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 10,140psi Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028996 190-152 50-133-10121-02-00 Soldotna Creek Unit (SCU) 43B-08 Swanson River Field / Tyonek Gas Pool Length Size 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 ; 4.6# / L-80 TVD Burst 8,914' ; 10,327' MD 6,340psi 3,070psi 30' 2,073' 9,067' 30' 2,073' 20" 11-3/4" 30' 7"9,380' 2,073' Perforation Depth MD (ft): 9,069' See Attached Schematic 5" Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: March 15, 2021 10,742'1,757' 3-1/2" ; 2-3/8" 10,734' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:27 pm, Mar 08, 2021 321-117 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.08 11:31:05 -09'00' Taylor Wellman (2143) CO 716 & CO 10-404 DSR-3/8/21 MITIA to 2000 psi before and after adding perforation to verify condition of cement packer above perfs. SFD 3/8/2021 BJM 3/17/21 SFD 3/8/2021Comm. 3/18/21 dts 3/17/2021 JLC 3/18/2021 RBDMS HEW 3/18/2021 Well Prognosis Well: SCU 43B-08 Date: 3/1/2021 Well Name: SCU 43B-08 API Number: 50-133-10121-02-00 Current Status: Shut-in Gas Well Leg: N/A Estimated Start Date: 3/15/2021 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 190-152 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max Expected BHP: ~2543 psi @ 5872’ TVD Based on normal gradient Max Expected WHP: ~1955 psi Based on expected BHP minus 0.1 psi/ft gas gradient Brief Well Summary SCU 43B-08 was drilled in 1991 targeting Hemlock oil. It ultimately produced from H-10, H-9, H-8, H-7, H-6, H-3, and H-1 benches before the Hemlock was abandoned in June 2004. Following abandonment, the Tyonek 61-0 (59-2 on schematic) was shot. While it produced up to 4.1 MMSCFD of gas, sand production forced SI within a year. In June 2008, the 61-0 was gravel packed, restoring access to not only 0.125 BCF of 61-0 reserves but also reserves identified in 57-8 and 56-9. Spotty, declining production continued for the next few years. Another FCO planned in late 2012 was never executed, for unclear reasons; even so, the well came back online, weakly flowing from 61-0 until January 2015. Around this time, fill was tagged ~8,808’ MD, beneath the gravel-packed perfs, suggesting sand control efforts were working well enough. SCU 43B-08 had one last bout of production between June 2015 – December 2016, but rates never exceeded 250 MCFD and with only 120-150# tubing pressure. The well has remained SI, only having cum’d 40% (0.5 BCF) of 61-0’s reserves and none from 57-8 and 56-9. The top of the gravel pack installation on this well is at 5802’ MD with open perforations at 5857’ MD. Hilcorp requests a variance to the 50’ spacing requirement declared in 20 AAC 25.112(c)(1)(E). Our intent is to set the CIBP as close as possible to the top of the gravel pack and dump bail cement on top. Well Work Objectives x Isolate 59-2 sands (5857’ – 5867’ MD) with plug and cement x Perforate 56-9 and 57-8 sands as specified below Notes Regarding Wellbore Condition x SL last tag fill 1/19/21 @ 8826’ with 1.75” Gauge Ring x Shut in since 6/2017 x 7” primary cement job in the 43-08 motherbore was squeezed and has good cement verified by CBL from 6100’-5570’. x A workover was completed in June 2004 cementing the 3.5” x 7” annulus. Cement was pumped through a retainer at 8900’ and overdisplaced with 5 bbls of water. This works out to a 52’ column of cement in place above the CIBP. E-line Procedure: 1. MIRU E-line and pressure control equipment, PT lubricator to 250 psi low & 3000 psi high. 2. RIH with toolstring including GPT, Junk Basket and Gauge Ring. 3. Drift as deep as possible for 3.5” CIBP. 4. Depress fluid level with AL gas into the open perfs from 5857’-5550’. Monitor fluid depth with GPT. 5. RIH with setting tool and 3.5” CIBP. Set CIBP at ~5800’. 6. RIH with dump bailer and dump 10’ of sand on top of CIBP. Pressure test 3.5" x 5.5" annulus to 2000 psi to verify integrity of cement packer before perforating. s completed in June 2004 cementing the 3.5” x 7” annulus. Cement w Planned CIBP set depth is 57' above the existing top perf and 2' above top of the gravel-pack packer. No variance required within same pool. Hilcorp requests a variance to the 50’ spacing requirement declared in 20 AAC 25.112(c)(1)(E). Well Prognosis Well: SCU 43B-08 Date: 3/1/2021 7. RIH with cement dump bailer and dump 35’ (13 gallons) of cement on top of sand plug. 8. Bleed WHP down to 1500 psi. 9. Perforate the following intervals with 2-1/8” Shogun Spiral guns loaded at 6 SPF: a. Final perforation intervals will be provided prior to loading guns for exact depths. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer (Trudi Hallett), and Geologist (Ben Siks) for confirmation. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and 5, 10 & 15 minutes after each perforating run. 10. RD E-line. 11. Turn well over to production. Contingent steps if zone produces water and requires isolation: 1. MIRU N2 unit. a. Ensure that standard nitrogen procedure is reviewed during PJSM. 2. RIH with GPT tool and depress fluid into perfs with N2. 3. RIH and set 3-1/2” CIBP above the zone and dump 35’ of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Standard Nitrogen Procedure Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt. Tyonek 56-9 +5593’ +5658’ +5592’ +5557’ 65’ Tyonek 57-8 +5688’ +5744’ +5687’ +5743’ 56’ MITIA to 2000 psi required to confirm condition of cement packer above new perfs. Swanson River Well SCU 43B-8 Actual Completion 12-07-08 Revised by: STP 9/17/14 ACTUAL SCHEMATIC Top of Fill 8,808’ 1.25” GR 9/17/14 TOC @ 7930’CBLTD= 10,826’PBTD= 10,745’ Max Deviation = 5.3q @10,322’ RKB = 185’CBL RattyTOC @ 9780’CBL GoodTOC @ 10,500’1 2 3 4 5 6Btm @ 6100’&TOC @ 5570’CBLObstruction @ 10,286’ Sand TOC @5074’ A B FISH @ 10,265’ 59-2 TOC @ 7930’CBLTD= 10,826’PBTD= 10,745’ Max Deviation = 5.3q @10,322’ RKB = 185’CBL RattyTOC @ 9780’CBL GoodTOC @ 10,500’1 2 3 4 5 4 5 6Btm @ 6100’&TOC @ 5570’CBLObstruction @ 10,286’ 6Btm @ 6100’&TOC @ 5570’CBLObstruction @ 10,286’ Sand TOC @5074’ A B FISH @ 10,265’ 59-2 Jewelry Detail NO. Depth ID OD Item 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” C. 5,802’ 1.630” 2.720” 5011 series TTS GP packer w/snap latch seal assembly 2400# shear D. 5,849’ 1.500” 2.190” 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) E. 5,872’ 1.630” 2.720” Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG A 8,900’ Fas Drill Cement Retainer B 10,260’ Drillable CIBP 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ PERFORATION HISTORY (DIL Depths) Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments 6/13/2004 Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 1.56” gun 11/3/2004 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 2.5” PJ HC 11/27/2004 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 5 Spiral jet Mar ‘01 H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Temp ISO Mar ‘00 H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Temp ISO Dec ‘99 H3 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Temp ISO Dec ‘99 H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Temp ISO Jul ‘94 H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Temp ISO Dec ‘99 H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Temp ISO Jul ‘94 H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Temp ISO Dec ‘99 H8 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Temp ISO Dec ‘93 H8 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Temp ISO Apr ‘91 H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Temp ISO Apr ‘91 H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Temp ISO Feb 91’ H10 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Temp ISO Dec ‘93 H10 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Temp ISO Apr 91’ H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Temp ISO Casing & Tubing Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾” Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL Tubing 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ E. D. C. RKB 17.3’ Swanson River Field Well SCU 43B-8 Revised by: TCS 2/1/21 PROPOSED SCHEMATIC Jewelry Detail NO. Depth ID OD Item - 18’ - - Tubing Hanger GLM #1 2,371’ 2.867 5.968 GLM, 3-1/2” GLM #2 4,046’ 2.867 5.968 GLM, 3-1/2” GLM #3 5,601’ 2.867 5.968 GLM, 3-1/2” A ~5,800’ - - CIBP with 10’ sand and 35’ cement cap (TOC ~5755) B 5,802’ 1.630 2.720 5011 series TTS GP packer w/snap latch seal assembly 2400# shear C 5,849’ 1.500 2.190 2 PBR’s w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears respectively (400# 20/40 mesh gravel behind pipe) D 5,872’ 1.630 2.720 Sump packer (overall strap sheet available in well file for GP assy) GLM #4 6,807’ 2.867 5.968 GLM, 3-1/2” GLM #5 7,795’ 2.867 5.968 GLM, 3-1/2” GLM #6 8,717’ 2.867 5.968 GLM, 3-1/2” 1 8,914 1.901 3.5 Crossover, 2-3/8” EUE 8rd x 3-1/2” EUE 8rd GLM #7 9,520’ 1.901 4 GLM, 2-3/8” GLM #8 10,229’ 1.901 4 GLM, 2-3/8” 2 10,242’ 1.87 2.5 Baker “X” Nipple 3 10,275’ 1.968 3 E22 Anchor and Seal Assembly 4 10,276’ 2.688 Baker “D” Packer 5” x 2-3/8” w/ MOE & XO 5 10,316’ 1.87 Otis “X” Profile Nipple 6 10,327’ 2 Baker Shear-out Sub w/ WLEG E 8,900’ Fas Drill Cement Retainer F 10,260’ Drillable CIBP 10,265’ Fish & Junk. “W” Circ plug, tbg stop and Lead f/ LIB. Report of “Corkscrewed” Tbg f/ 10,265 to 10,275’ PERFORATION HISTORY (DIL Depths) Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments TBD TY 56-9 ~5593’ ~5658’ ~5592’ ~5557’ 65’ 5 2-1/8” Spiral TBD TY 57-8 ~5688’ ~5744’ ~5687’ ~5743’ 56’ 5 2-1/8” Spiral 6/13/2004 Tbg punch 10,245’ 10,251’ 10,240' 10,246' 6’ 4 1.56” Gun 11/3/2004 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 6 2.5” PJ HC 11/27/2004 59-2 5,857’ 5,867’ 5,856' 5,866' 10’ 5 Spiral Jet Mar ‘01 H1 10,342’ 10,352’ 10,337' 10,347' 10’ 6 Temp ISO Mar ‘00 H3 10,374’ 10,408’ 10,369' 10,403' 34’ 6 Temp ISO Dec ‘99 H3 10,420’ 10,424’ 10,415' 10,419' 4’ 4 Temp ISO Dec ‘99 H4,5 10,447’ 10,480’ 10,442' 10,474' 33’ 4 Temp ISO Jul ‘94 H6 10,498’ 10,520’ 10,492' 10,514' 22’ ? Temp ISO Dec ‘99 H7 10,500’ 10,520’ 10,494' 10,514' 20’ 4 Temp ISO Jul ‘94 H8 10,522’ 10,540’ 10,516' 10,534' 18’ ? Temp ISO Dec ‘99 H8 10,524’ 10,560’ 10,518' 10,554' 36’ 4 Temp ISO Dec ‘93 H8 10,540’ 10,560’ 10,534' 10,554' 20’ 4 Temp ISO Apr ‘91 H9 10,572’ 10,591’ 10,566' 10,585' 19’ 4 Temp ISO Apr ‘91 H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Temp ISO Feb 91’ H10 10,613’ 10,642’ 10,607' 10,636' 29’ 6 Temp ISO Dec ‘93 H10 10,613’ 10,651’ 10,607' 10,645' 38’ 4 Temp ISO Apr 91’ H10 10,651’ 10,664’ 10,645' 10,658' 13’ 4 Temp ISO Casing & Tubing Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor Surf 30’ Yes Surf. 11-¾” Surf Csg 47 J-55 11” Surf 2,073’ 16” 1,300 sx 177’ Calcd 7” Prod Csg 29 N-80 6.184” Surf 302’ 9и” 2200 Sx 7935’ CBL 7” 26 6.276” 302’ 881’ 7” 23 6.366” 881’ 4,549’ 7” 26 6.276” 4,549’ 6,389’ 7” 29 6.184” 6,389’ 8,203’ 7” 29 P-110 6.184” 8,203’ 9,380’ 7” Window. Cut on 7/81 9,,380’ 9,450’ 5” Liner w/ LTP 18 N-80 4.276” 9,069’ 10,742’ 6” 72.5 bbls 10,410’ CBL Tubing 3-½”, EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914’ 2 д”, 8rd & BTC 4.6 N-80 1.995 8914’ 10,327’ RKB 17.3’ TOC @ 7930’ CBL TD= 10,826’ PBTD= 10,745’ Max Deviation = 5.3qq @10,322’ CBL Ratty TOC @ 9780’CBL Good TOC @ 10 500’ 1 2 3 4 5 6 Btm @ 6100’ & TOC @ 5570’ CBL Obstruction @ 10,286’ 59-2 Sand TOC @5074’ E F B C D A STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. tihCEIVED STATE OF ALASKA SEP 2 0 2012 AIIKA OIL AND GAS CONSERVATION COMM SION • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate ❑ Other U Pull Cap String Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Welt El 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Its Exploratory ❑ — 190 -152 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic❑ Service ❑ 6. API Number: Alaska 99503 50- 133 - 10121 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028996 Soldotna Creek Unit (SCU) 43B -08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Swanson River Field / Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,826 feet Plugs measured N/A feet true vertical 10,820 feet Junk measured 6,100' (fill) feet Effective Depth measured 6,100 feet Packer measured 5,802', 5,872' feet true vertical 6,099 feet true vertical 5,801', 5,871' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,085' 11 -3/4" 2,085' 2,085' 3,070 psi 1,510 psi Intermediate 9,380' 7" 9,300' 9,298' 6,340 psi 3,820 psi Production Liner 1,757' 5" 10,742' 10,734' 10,140 psi 10,190 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic MD TVD 3 -1/2" 9.3# / N -80 8,914' 8,912' Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.6# / L -80 10,327' 10,322' 3 -1/2" TTS gravel pack 5,802' MD, TVD 3 -1/2" TTS sump 5,872' MD, TVD Packers and SSSV (type, measured and true vertical depth) Baker D 5 "x2 -3/8" pckrs 10,276' MD, TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A gA ^ p tl 4 2013 SCANNED EIA13 V Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 550 22 180 400 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 ❑ — Gas 0 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: N/A Contact Chad Helgeson Phone: 907 - 777 -8300 Printed Name Chad Helgeson Title Operations Engineer ;4 ,/-� Phone 907 - 777 -8405 Date 9/20/2012 RBQMS SEP 2 1 20g01, , Czs.r z- 0,g4 / /z. Form 10-404 Revised 11/2011 Submit riginal Only • • • �I Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 43B -08 50- 133 - 10121 -02 190 -152 8/13/12 8/13/12 Daily Operations: 8/13/2012 - Monday Pull cap string. Baker arrive on location, JSA and tail gate safety meeting, disconnect surface lines, Deploy and inspect BJDC crane and deck equipment,install counter, zero weight indicator. Lift injector over WH approx. 10 feet. Run all remaining tubing tail through injector. Reduce skate pressure to near 0 psi. Apply 1,500+ psi to skate system to hold tubing. Connect the WPA control line, apply 3,000 psi then open the mini -valve on the pack -off. Remove slips and loosen Rattigan's. Install snubbing guides. Wrap WPA and WHA with absorbents to catch drips. Set counter to Set Depth. Apply sufficient backpressure to the tubing spool. Reduce WPA pressure to near WH pressure, watch for leaks. POOH. String tough to get moving. Monitor MAX pull weights, do not push tubing in -hole to move initially. Tag FCV at surface. Close swab valve fully. Bleed off WH pressure. Rig -down unit. Secure area. • • Swanson River SCHEMATIC Well SCU 43B -8 " Actual Completion 12 -07 -08 Hilcorp Alaska, LLC C a s i n g & T u b i n g RKB 17.3' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor Surf 30' Yes Surf. 11- Surf Csg 47 J -55 11" Surf 2,073' 16" 1,300 sx 177' Calcd 7" 29 6.184" Surf 302' _ 7" 26 6.276" 302' _ 881' 7" 23 N -80 6.366" 881' 4,549' 7935' 7 „ Prod Csg 26 6.276" 4,549' 6,389' 9'/." 2200 Sx CBL A 7" 29 6.184" 6,389' 8,203' 7" 29 P -110 6.184" 8,203' 9,380' 7" Window. Cut on 7/81 9 „380' 9,450' n, 5" I Liner w/ LTP I 18 I N -80 1 4.276" 9,069' 10,742' 6" 72.5 bbls 10,410' CBL I+ Tubing - roc o 7a' 3 -s ", EUE 8rd 9.3 N- 80/L -80 2.992 Surf 8,914' _ 2' ", 8rd & BTC 4.6 N -80 1.995 8914' 10,327' - y - °' Jewelry Detail C. NO. Depth ID OD Item i, 18' - - Tubing Hanger ▪ il! II = ' sand D. GLM #1 2,371' 2.867 5.968 GLM, 3 -1/2" ▪ L`' 1 GLM #2 4,046' 2.867 5.968 GLM, 3 -1/2" GLM #3 5,601' 2.867 5.968 GLM, 3 -1/2" _' E. C. 5,802' 1.630" 2.720" 5011 series TTS GP packer w /snap latch seal assembly 2400# shear x .7 Top of Fill 6,100' 2 PBR's w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears D. 5,849' 1.500" 2.190" respectively (400# 20/40 mesh gravel behind pipe) 19 E. 5,872' 1.630" 2.720" Sump packer (overall strap sheet available in well file for GP assy) __ _ GLM #4 6,807' 2.867 5.968 GLM, 3 - 1/2" GLM #5 7,795' 2.867 5.968 GLM, 3 -1/2" 2 GLM #6 8,717' 2.867 5.968 GLM, 3 -1/2" �� A 1 8,914 1.901 3.5 Crossover, 2 - 3/8" EUE 8rd x 3 - 1/2" EUE 8rd ' _ 1 GLM #7 9,520' 1.901 4 GLM, 2 -3/8" g GLM #8 10,229' 1.901 4 GLM, 2 -3/8" "I 2 10,242' 1.87 2.5 Baker "X" Nipple 3 10,275' 1.968 3 E22 Anchor and Seal Assembly 4 10,276' 2.688 Baker "D" Packer 5" x 2 -3/8" w/ MOE & X0 5 10,316' 1.87 Otis "X" Profile Nipple 6 10,327' 2 Baker Shear -out Sub w/ WLEG A 8,900' Fas Drill Cement Retainer 2 B 10,260' Drillable CIBP 3 Pd, R FISH „ , " '0,265' 10,265' Fish & Junk. "W" Circ plug, tbg stop and Lead f/ LIB. Report of "Corkscrewed" r Tbg f/ 10,265 to 10,275' i c .711. �I 4 6'zT Obstruction PERFORATION HISTORY (DIL Depths) c5::: ascs F . 10,286' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments 6/13/2004 Tbg punch 10,245' 10,251' 10,240' 10,246' 6' 4 1.56" gun e 5 11/3/2004 59 -2 5,857' 5,867' 5,856' 5,866' 10' 6 2.5" PJ HC : °14' f II 11/27/2004 59 -2 5,857' 5,867' 5,856' 5,866' 10' 5 Spiral jet _ Mar '01 H1 10,342' 10,352' 10,337' 10,347' 10' 6 Temp ISO ti ti Mar '00 H3 10,374' 10,408' 10,369' 10,403' 34' 6 Temp 60 - % 6 Dec '99 H3 10,420' 10,424' 10,415' 10,419' 4' 4 Temp ISO Dec '99 H4,5 10,447' 10,480' 10,442' 10,474' 33' 4 Temp ISO o Jul '94 H6 10,498' 10,520' 10,492' 10,514' 22' ? Temp ISO 01 Dec '99 H7 10,500' 10,520' 10,494' 10,514' 20' 4 Temp 60 0 Jul '94 H8 10,522' 10,540' 10,516' 10,534' 18' ? Temp ISO Dec '99 H8 10,524' 10,560' 10,518' 10,554' 36' 4 Temp ISO I Dec '93 H8 10,540 10,560' 10,534' 10,554' 20' 4 Temp 60 Temp H9 10,572' 10,591' 10,566' 10,585' 19' 4 Temp ISO : .,,.,, r „ Apr '91 H10 10,651' 10,664' 10,645' 10,658' 13' 4 Temp ISO Feb 91' H10 10,613' 10,642' 10,607' 10,636' 29' 6 Temp 60 Dec '93 H10 10,613' 10,651' 10,607' 10,645' 38' 4 Temp 60 TD= 10,826' PBTD= 10,745' Apr 91' H10 10,651' 10,664' 10,645' 10,658' 13' 4 Temp ISO Max Deviation = 5.3° @10,322' Revised by: TDF 9/12/12 STATE OF ALASKA ~ ~ ~ ~ ° ~/ ~ i~ U ~ ALA OIL AND GAS CONSERVATION COMM O '~ ~ ~ b 2009 REPORT OF SUNDRY WELL OPERATIC 1. Operations Abandon Repair Well Plug Perforations ther ~ Instal Cap String - Stimulate ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ~(} r~ ^ Waiver ^ ~ ~-TChOE"xf~ sion ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q ' Exploratory^ 190-152 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-133-10121-02 7. KB Elevation (ft): 9. Well Name and Number: 185'MSL Soldotna Creek Unit (SCU) 43B-08 8. Property Designation: 10. Field/Pool(s): FEDA028996 [Soldotna Creek Unit] Swanson Diver / Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured 10,826 - feet Plugs (measured) 8,900' true vertical 10,820 _ feet Junk (measured) 6,000' (fill) Effective Depth measured 8,900 feet true vertical 8,898 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,085' 11-3/4" 2,085' 2,085' 3,070 psi 1,510 psi Intermediate 9,300' 7" 9,300' 9,298' 6,340 psi 3,830 psi Production Liner 1,757' S" 10,742' 10,734' 10,140 psi 10,190 psi Perforation depth: Measured depth: 5,857'-5,867' True Vertical depth: 5,856'-5,866' Tubing: (size, grade, and measured depth) 3-1/2" & 2-3/8" N-80 & L-80 8,914' & 10,327' Packers and SSSV (type and measured depth) 3-1/2" TTS gravel pack, 3-t/2" TTS 5,802', 5,872', sump, Baker D 5"x2-3/8" packers 10,276' / NO SSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 psi 2,225 psi Subsequent to operation: 0 600 0 0 psi 1,130 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development^ ° Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ~` WAG ^ GINJ ^ WINJ ^WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-420 Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager ~ Signature ~ Phone 276-7600 Date 1/5/2009 L_~ / ~ Form 10-404 Revised 0412006 ...~,. Submit Original Only uNOCa~~b • Swanson River Well SCU 43B-8 Actual 12-07-08 Casino & Tubin a Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11?/." Surf Csg 47 J-55 I I" Surf 2,073' 16" 1300 sx 177' Calcd 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7" P d C 23 N-80 6.366" 881' 4549' 9'~ 2200 S 7935' 7„ ro sg 26 6.276" 4549' 6389' x CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' pia 5" Liner w/ LTP 18 N-80 4.276" 9,069' 10,742' 6" 72.5 bbls 10410' CBL Tubin 3-'/ ", EUE 8rd 9.3 N-80/L-80 2.992 Surf 8,914' 2 %", 8rd & BTC 4.6 N-80 1.995 8914' 10,327' '/." (0.25") 0.08 2205 SS 0.18 Surf 5,750 IF.WF,I,RY nF,TAII, D. 'ill 6,000' NO. De th ID OD Item 18' Tubin Han er GLM #1 2 371' 2.867 5.968 GLM 3-1/2" GLM #2 4 046' 2.867 5.968 GLM 3-1/2" GLM #3 5,601' 2.867 5.968 GLM, 3-I/2" C. 5,802' 1.630" 2.720" 501 I series TTS GP acker w/sna latch seal assembl 2400# shear D. 5,849' 1.500" 2.190" 2 PBR's w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears res ectivel 400# 20/40 mesh ravel behod i e F.. 5,872' L630" 2.720" Sum acker overall stra sheet available in well file for GP ass GLM #4 6,807' 2.867 5.968 GLM, 3-1/2" GLM #5 7,795' 2.867 5.968 GLM, 3-1/2" GLM #6 8,717' 2.867 5.968 GLM, 3-1/2" 1. 8,914 1.901 3.50 Crossover, 2-3/8" EUE 8rd x 3-I/2" EUE 3rd GLM #7 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Ni le 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembl 4. 10,276' 2688 Baker "D" Packer 5" x 2-3/8" w/ MOE & XO 5. 10,316' 1.870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Shear-out Sub w/ WLEG A. 8900' Fas Drill Cement Retainer @, 10,260' Drillable CIBP !0,265' Fi.h & Junk. "~~"' Circ Flu tb sto and Lead f/ LIB Rc iort of"Corkscrewed" Tb U 10,265 to 10,275' PF.RF(IRATI(1N HiSTnRY (nll, nenthsl Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" un 11-03-O~t 59-2 5,857' 5,867' 10' 6 2.5" PJ HC 11-27-04 59-2 5,857' 5,867' 10' S S iral 'et Mar `01 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem ISO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 H4,5 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 H8 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 H10 10,651' 10,664' 13' 4 Tem ISO Feb 91' H10 10,613' 10,642' 29' 6 Tem ISO Dec `93 H10 10,613' 10,651' 38' 4 Tem ISO A r 91' H10 10,651' 10,664' 13' 4 Tem ISO SCU 43B-8 Schematic 12-07-08.doc REVISED: 12-07-08 LPG TD= 10,826' PBTD= 10,745' Max Deviation = 5.3° (a~10,322' Chevron . ~ Soldotna Creek Unit Well #SCU 43B-08 12/18/08 Objective: • Install capillary string. Drilling Summary: 11/21/08 RU. Pressure test pack off assembly to 3,000 psi. RIH with'/4" capillary string to 5,750'. Unable to pump down methanol due to unknown plug in capillary string. POOH with cap string.RD. 12/4/08 Cleared plug & tested capillary string. 12/5/08 RU. Pressure test pack off assembly to 3,000 psi. RIH with''/a" capillary string to 5,750'. Tested same. RD. RU. Pressure test pack off assembly to 3,000 psi. POOH w/ cap string to correct crackpressure at nozzle. Recalibrate 12/6108 cracking pressure on nozzle. Pressure tested pack off assembly to 3,000 psi. RIH with'/4" capillary string to 5,750'. RD. SCU 43B-08 REVISED BY: CVK 12-18-08 • ~- ~~ o SARAH PAL1N, GOVERNOR Lsi~C1-711L1 OI~ ~ tioa7 333 W. 7th AVENUE, SUITE 100 COI~SERQA'i`IO1~T COMI~IISSIOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Timothy Brandenburg Drilling Manager Unocal PO Box 196247 t- ~~ ~?~~~~' ~~`; ~ ~ ~~~~ ~ ~~ Anchorage AK 99519 Re: Swanson River Field, Tyonek Undefined Gas Pool, SCU 43B-08 Sundry Number: 308-420 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Conunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, y oerster Commissioner DATED this ~ day of November, 2008 Cath . F Encl. 8 8 ~ ; n-.. ., STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS ~n aac ~~ ~Rn . ; . /~/9-0~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Waiver ^ Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^" Install Cap String Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 190-152 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196247 Anchorage, Alaska 99519 50-133-10121-02 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Soldotna Creek Unit SCU 43B-08 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028996 Soldotna Creek Unit 185' MSL - Swanson River / T onek Undef Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,826' ~ 10,820' ~ 8,900' 8,898' 8,900' fi115,403' Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,085' 11-3/4" 2,085' 2,085' 3,070 psi 1,510 psi Intermediate 9,300' 7" 9,300' 9,298' 6,340 psi 3,830 psi Production Liner 1,757' S" 10,742' 10,734' 10,140 psi 10,190 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,857' to 5,867' 5,856' to 5,866' 3-1/2" & 2-3/8" N-80 & L-80 8,914' & 10,327' Packers and SSSV Type: 3-1/2" TTS gravel pack pkr / 3-1/2" TTS sump Packers and SSSV MD (ft): 5,802', 5,872', 10,276' / No SSSV packer / Baker D Packer 5" x 2-3/8" 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ ~ Service ^ 15. Estimated Date for 11/20/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ - Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenberg Title Drilling Manager Signature ~ on 276-7600 Date ~r (~ ~ ~~~ ~~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ g• ~~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: I ~,,_ ~ j,~ l APPROVED BY Approved by: ~i~~~~---- COMMISSIONER THE COMMISSION Date: ~~ ~ - ~ ~/ l ~ R ~ C ~ ~ A L ~. ~~ ~~ ~~ } ~~~ Form 10-403 Revised 06/2006 ~3 Submit in Duplicate • Swanson River Well SCU 43B-8 V N 0 CA~ 76 Actual 06-20-08 C a s i n o & T u b i n a Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11?/." Surf Csg 47 J-55 I I" Surf 2,073' 16" 1300 sx 177 Calculated 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7" Pr d C 23 N-80 6.366" 881' 4549' 9 '/ " 2200 S 7935' 7„ o sg 26 6.276" 4549' 6389' - a x CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' 5„ Liner w/ LTP 18 N-80 4.276" 9,069' 10,742' 6" 72.5 bbls 10'110 CI3l. Tubio 3-'/", EUE 8rd 9.3 N-80/I: 80 2.992 Surf 8914' 2 %", 8rd & BTC 4.6 N-80 1.995 8914' 10,327' JEWELRY DETAIL D. Fill 6,000' NO. De th ID OD Item 18' Tubin Han er GLM kl 2,371' 2.867 5.968 GLM 3-1/2" GLM N2 4 046' 2.867 5.968 GLM 3-1/2" GL11 #3 5,60]' 2.867 5.968 GLM, 3-I/2" C. 5 802' 1.630" 2.720" 501 I series TTS GP acker w/sna latch seal assembl 2400# shear D. 5,849' 1.500" 2.190" 2 PBR's w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears res eclivel 400# 20/40 mesh ravel behind i e E. 5,872' 1.630" 2.720" Sum acker overall stra sheet available in well file for GP ass GLM #4 6,807' 2.867 5968 GLM, 3-1/Y' GLM #5 7,795' 2.867 5.968 GLM, 3-I/2" GLM #6 8,717' 2.867 5.968 GLM, 3-1/2" I. 8,914 1.901 3.50 Crossover, 2-3/8" EUE 8rd x 3-1/2" EUE 8rd CLM #7 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1.901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Ni le 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembl 4. 10,276' 2.688 Baker "D" Packer 5" x 2-3/8" w/ MOE & XO 5. 10,316' 1.870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Shear-out Sub w/ WLEG ~, 8900' Fos Drill Cement Retainer g, 10,260' DrillableClBP 10 265' Fi>h & .link. "~'," ('irc lu , tb sto i and Lcad f/ L1B Re curt of °Curk.'crewed" Tb f/ 10,265 to IU,275' PERFORATION HISTORY DIL De the Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" un 11-03-04 59-2 5,857' S 867' 10' 6 2.5" PJ HC 11-27-04 59-2 5,857' S 867' 10' S S iral 'et Mar `O1 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem ISO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 H4,5 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 H8 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 H10 10,651' 10,664' 13' 4 Tem ISO Feb 91' H10 10,613' 10,642' 29' 6 Tem ISO Dec `93 H10 10,613' 10,651' 38' 4 Tem ISO A r 91' H10 10,651' 10,664' 13' 4 Tem ISO SCU 43B-8 Schematic 07-07-08.doc REVISED: 07-07-08 MGB TD= 10,826' PBTD= 10,745' Max Deviation = 5.3° (a~10,322' Swanson River Well SCU 43B-8 uNO~~` 76 Proposed Casing & Tubin p RKB 17.3' Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11 '/." Surf Csg 47 J-55 1 I" Surf 2,073' 16" 1300 sx Calculated 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7" P d C 23 N-80 6.366" 881' 4549' " 7935' 7„ ro sg 26 6.276" 4549' 6389' 9-/e 2200 Sx CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' 5„ Liner w/ LTP 18 N-80 4.276" 9,069' 10,742' 6" 72.5 bbls 10,410' CBI. Tubin 3-''/z" EUE 8rd 9.3 N-802-80 2.992 Surf 8914' 2 %", 8rd & BTC 4.6 N-80 L995 8914' 10,327' JEWELRY DETAIL D. NO. De th ID OD Item 18' Tubin Han er GLM #l 2,371' 2.867 5.968 GLM 3-1/2" GLM #2 4 046' 2.867 5.968 GLM 3-1/2" GLM #3 x,601' 2.817 5.968 GLM, 3-I/2" F. 5,700' 14" 25" Ca it tube from surface to ~-5 700' w/check valve & Wt bar C. 5,802' 1.630" 2.720" 501 I series TTS GP acker w/sna latch seal assembl 2400# shear D. 5,849' 1.500" 2.190" 2 PBR's w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears res ectivel 400# 20/40 mesh ravel behind i e E. 5,872' 1.630" 2.720" Sum acker overall stra sheet available in well file for GP ass GLM #4 6,807' 2.867 5.968 GLM, 3-I/2" GLM #5 7,795' 2.867 5.968 GLM, 3-1/2" GLM #6 8,717' 2.867 5.968 GLM, 3-I/2° 1. 8,914 1.901 380 Crossover, 2-3/8" EUE 3rd x 3-I/2" EUE 8rd GLM #7 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1.901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Ni le 3. 1Q275' 1.968 3.00 E32 Anchor and Seal Assembl 4. 10,2 7 G 2.688 Baker "D" Packer ~" t 2-3/8" w/ MOE & XO 5. 10,316' L870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Shear-out Sub w/ WLEG ,4, 8900' Fas Driii Cement Retainer B, 10,260' Drillable CIBP 10,265' Fish & Junk. "W" Circ lu tb sto and Lead (/ LIB He port of "Corkscrewed" Tb f/ 10 265 to 10 275' PERFORATION HISTORY (DIL Depths) Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" un l 1-03-04 59-2 5,857' 5,867' 10' 6 2.5" PJ HC 1 I-27-04 59-2 5,857' 5,867' 10' S S iral 'et Mar `O1 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem [SO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 H4,5 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 H8 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 H10 10,651' 10,664' 13' 4 Tem ISO Feb 91' H 10 10,613' 10,642' 29' 6 Tem ISO Dec `93 H10 10,613' 10,651' 38' 4 Tem ISO A r 91' H10 10,651' 10,664' 13' 4 Tem ISO SCU 43B-8_Schematic 11-19-08~roposed.doc REVISED: 06-30-08 MGB TD= 10,826' PBTD= 10,745' Max Deviation = 5.3° (a~10,322' Soldotna Creek Unit Operational procdure: 43B-08 Objective: • Install a 1/4" capilary tube for chemical injection purposes Procedure: • MIRU BJ Dyna Coil unit • MU BHA consisting of capilary connector, check valve, knuckle joint, weight bar • Stab on well head and pressure test surface equipment and capilary tube to +-3,000 psi • Displace capilary tube with methanol • Open well and run in the hole to +-5,700' • Hang off capilary tube on the surface and PT pack off to +-3,000 psi • Rig down BJ Dyna Coil unit • Hook up surface pump to surface end of capilary tube and set methanol injection pump • Turn well over to production -7 ~ STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM ON °~: ~. .~~~~ ~ ~ Zt~~~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Oj~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate Q ~ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q ~ Exploratory^ 190-152 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-133-10121-02 ' 7. KB Elevation (ft): 9. Well Name and Number: 185' MSL' Soldotna Creek Unit (SCU) 436-08 ' 8. Property Designation: 10. Field/Pool(s): Soldotna Creek Unit FEDA028996- Swanson River / Tyonek Undef Gas' 11. Present Well Condition Summary: Total Depth measured 10,826 ~ feet Plugs (measured) 8,00' true vertical 10,819 - feet Junk (measured) 6,000' (fill) ~~ JV~L ~ 2~~~ . Effective Depth measured 6,000 feet true vertical 5,999 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,085' 11-3/4" 2,085' 2,085' 3,070 psi 1,510 psi Intermediate 9,300' 7" 9,300' 9,298' 6,340 psi 3,830 psi Production Liner 1,757' 5" 10,742' 10,734' 10,140 psi 10,190 psi Perforation depth: Measured depth: 5,857' - 5,867' True Vertical depth: 5,856' - 5,866' Tubing: (size, grade, and measured depth) 3-1/2" & 2-3/8" N-80 9.3#& L-80 4.6# 8,914' & 10,327' Packers and SSSV (type and measured depth) Baker D Paker 5"x2-3/8" 10,327' & No SSV [Cemented anulus to 5074') 12. Stimulation or cement squeeze summary: See attached Daily Operations Summary Intervals treated (measured): V~ Cc. ~ ~ h~S V~fi ~ ~ c'Q~ ~l CC Treatment descriptions including volumes used and final pressure: ..~ \'t~«C` (, ~ _ ~ ~ /~('a~ t ~ ~ ~j y 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 2000 0 1700 2200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas Q WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 308-186 Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature .- C`' , r Phone 276-7600 Date 7/9/2008 ..~ Form 10-404 Revised 04/2006 R~GINAL S~i~~~~~~~oo~ ~tl,~ Submit Original Only • • Swanson River Well SCU 43B-8 V N ~ CA~ 76 Actual 06-20-08 Casing 8r Tubing Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11-%." Surf Csg 47 J-55 I l" Surf 2,073' 16" 1300 sx 177' Calculated 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7" P d C 23 N-80 6.366" 881' 4549' 9 ~ 2200 S 7935' 7„ ro sg 26 6.276" 4549' 6389' - x CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' 5„ Liner w/LTP 18 N-80 4.276" 9,069' 10,742' 6" 728 bbls 10,410' CBL Tubin 3-%z" EUE 8rd 9.3 N-80/L-80 2.992 Surf 8914' 2'/" 8rd & BTC 4.6 N-80 1.995 8914' 10 327' JEWELRY DETAIL D. Fill 6,000' \O. De th ID OD Item 18' Tubin Han er GLM #1 2,371' 2.867 5.968 GLM 3-1/2" GLM #2 4 046' 2.867 5.968 GLM 3-1/2" CL11 #3 5,601' 2.867 5.968 GLM, 3-I/2~~ C. 5,802' 1.630" 2.720" 501 I series TTS GP acker w/sna latch seal assembl 2400# shear U. 5,849' 1.500" 2.190" 2 PBR's w/2 GP screens & snap latch seal assemblies 4800 & 7200 # shears res ectivel 400# 20/40 mesh ravel behind i e E. 5,872' 1.630" 2.720" Sum acker overall stra sheet available in well file for GP ass GLM #4 6,807' 2.867 5968 GLM, 3-I/2" GLM #5 7,795' 2.867 5.963 GLM, 3-I/2" CLM #6 8,717' 2.867 59(18 GLM, 3-1/2" 1. 8,914 L901 3.50 Crossover, 2-3/8" El1E 8rd x 3-I/2" EUE 8rd CLM #7 9.520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1.901 -1.00 GLM, 2-3/8" 2 10,242' 1.870 280 Baker "X" Ni >>le 3. 10.275' 1.968 3.00 t22 Anchor and Seal Assembly 4. IQ27G 2.688 Baker "D~~ I'zcker ~" y ~ ~~8" w! MOE & XO 5. 10,316' 1.870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Sheaz-out Sub w/ WLEG A, 8900' Fas Drill Cement Retainer g, 10,260' DrillableClBP 10,265' Fish & .hmk. "~~° (irc ilu ~, tb sto and Lead f/ LIR Re wr[ of "Corkxrcwcd" Tb° f/ 10,265 to 10,275' PERFORATION HISTORY (DIL Depths) Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" un I1-03-04 59-2 5,857' 5,867' 10' 6 2.5" P.1 HC 11-27-04 59-2 5,857' 5,867' 10' S S iral 'et Mar `O1 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem ISO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 H4,5 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 H8 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 H10 10,651' 10,664' 13' 4 Tem ISO Feb 91' H10 10,613' 10,642' 29' 6 Tem ISO Dec `93 H10 10,613' 10,651' 38' 4 Tem ISO A r 91' H10 10,651' 10,664' 13' 4 Tem ISO SCU 43B-8 Schematic 07-07-08.doc REVISED: 07-07-08 MGB TD= 10,826' PBTD= 10,745' Max Deviation = 5.3° (n~10,322' Chevron Chevron -Alaska Daily Operations Summary Well Name SCU 43B-8 Field Name API/UWI 501331012102 Lease/Serial FEDA028996 CHEVNO QA5265 License No./Prope... 1901520 Orig KB Elev (ftK6) 178.0 Water Depth (ft) -- Jobs Job Cat Type AFE No. __ ____ _ QC Eng Workover Workover UWDAK-R8038 - __ - _ __ Daily Operations - 5/27/2008 00:00 - 5/28/2008 00:00 Operations Summary Drift Tubing to 5520' with 2.75" GR and retrieve Fluid sample 10' from bottom. 6/3/2008 00:00 - 6/4/2008 00:00 Operations Summary Prep location w/coil tubing support equipment 6/4/2008 00:00 - 6/5/2008 00:00 Operations Summary Rig up Coil Tubing and tanks for Mixing brine. Mix 400 barrels of brine. Contacted AOGCC for 24 Hr notice for BOPE test which was wiaved by John Crisp. 6/5/2008 00:00 - 6/6/2008 00:00 Operations Summary Operational, stand down, Coil Plugged 6/8/2008 00:00 - 6/7/2008 00:00 Operations Summary Operations stand down meeting in Anc. office. 6/7/2008 00:00 - 6/8/2008 00:00 Operations Summary Change out Coil tubing reel and PT BOP's and surface iron. AOGCC witness waived by John Crisp. 6/8/2008 00:00 - 6/9/2008 00:00 Operations Summary Clean out fll fro 6/9/2008 00:00 - 6/10/2008 00:00 Operations Summary Tag fill at 6022 RKB SLM, pull chemical injection valve in mandrel # 2, install dummy valve in same & PT casing to 1500 psi for 2 hours, Set TTS Sump packer @ 5872', install Screen and blank assembly into same w/ top of screens @ 5838' & blank pipe top @ 5815' 6/10/2008 00:00 - 6/11/2008 00:00 Operations Summary Ran TTS gravel pack packer assembly, set same, no communication with formation, communication between coil and production tubing. Unable to ravel ack, POOH with setting assembly, RB CTU SDFN. Will fish packer out of well tomorrow 6/11/2008 00:00 - 6/12/2008 00:00 Operations Summary Pulled TTS Gravel pack packer, missing one element. fished for element. 6/12/2008 00:00 - 6/13/2008 00:00 Operations Summary Set plug in screen assembly and test for Sand bridge / no bridge / ood in'ectivi .Fish Rubber seal from failed Packer that was pulled from Well. 6/13/2008 00:00 - 6/14/2008 00:00 Operations Summary Correspond with TTS engineers, Test TTS Swivel and Disconnect to 5000 psi. 6/14/2008 00:00 - 6/15/2008 00:00 Operations Summary standing by waiting on TTS gravel pack pack packer 6/15/2008 00:00 - 6/16/2008 00:00 Operations Summary Inventoried hardline basket, circulated tanks with friction reducer, prep location and surface equipment. Contacted AOGCC for 24 Hr notice for BOPE test tomorrow, which was waived by Jim Regg. 6/16/2008 00:00 - 6/17/2008 00:00 Operations Summary Pressure test BOP's and make up TTS packer and tools, stab on well and PT 250 low 4000 high. AOGCC witness waived by Jim Regg. 6/17/2008 00:00 - 6/18/2008 00:00 Operations Summary Install top of Gravel Pack Packer Assembly and gravel pack the Tyonek 59-2 sand @ 5802' - 5827'. 6/18/2008 00:00 - 6/19/2008 00:00 Operations Summary Change out Dummy Valve with chemical injection valve. Recover 75 bbls of 6% KCL water from production tubing CheVrOr~ Cisc® Castr® Chevron ivorrh ~rica Exploration and Production . Technical Assistant 909 W. 9th Avenue ~ Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE July 7, 2008 To: AOGCC Mahnken, Christine R ~~~~~ ~U~ ~ ZQfl~ 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ©-!~ ~ /~ `~~a~ HELL LGG TYPE SCALE LOG DATE INTER'/AL RUN # B-LINE CD NOTES -LAS, LOGGED PDS, DLIS GRANITE POINT ST 18742 37 USIT 5" 14-Jun-08 200-9874 PS-1 1 1 LAS, PDS PACKER SETTING SCU 43B-08 RECORD 5" 9-Jun-08 5746-5940 2 1 1 PDS COMPLETION SRU 34-28 RECORD 5" 1-Jul-OS 5940-6228 1 1 1 PDS TBU K-25 USIT 5" 11-Jun-08 200-6463 PS-1 1 1 PDS,LAS Please acknowled Received By by signing and returning one copy of this transmittal or fAX to 907.-263 7828. __- ~~ ~ Date: • • - - SARAH PALfN, GOVERPIOR ~y ~~~t~g~T n®~j ~r ~T 333 W 7th AVENUE, SUITE 100 L®1®~g~!~QAal®A`~ i.®~~-7~~1~ ANCHORAGE.A~ASKA 99501-3539 °d PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 995 Re: Swanson River, Tyonek Undefined Pool, Soldotna Creek Unit 43B-08 Sundry Number: 308-186 L ~~~~~ JuN ~ ~ 2008 ~b ~' ~ J Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval- relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30. PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~, _. .- ,~~ ~---: - .z.~.~ =~_ . F Daniel T. Seamount, Jr. Chair ~` DATED this - day of May, 2008 Encl. T-~~C,:C.I v ~u STATE OF ALASKA MAY 2 2 "Z~08 AL~ OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAI~}~ska Oil & Gas Cans. Commission 20 AAC 25260 A r.nhnr7lip 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Q Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ e'jr".~~ j Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ~ ~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ . 190-152 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196247 Anchorage, Alaska 99519 50-133-10121-02 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Soldotna Creek Unit 43B-08 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): G'7"' Soldotna Creek Unit FE,dA Oa~996 185' MSL Swanson River / Tyonek 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,826' 10,820' 8,900' 8,898' 8,900' fill 5,403' Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,085' 11-3/4" 2,085' 2,085' 3,070 psi 1,510 psi Intermediate 9,300' 7" 9,300' 9,298' 6,340 psi 3,830 psi Production Liner 1,757' 5" 10742' 10734' 10,140 psi 10,190 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,857' to 5,867' 5,856' to 5,866' 3-1/2" & 2-3/8" N-80 & L-80 8,914' & 10,327' Packers and SSSV Type: Baker D Packer 5" x 2-3/8" Packers and SSSV MD (ft): 10,276' / No SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 Service 15. Estimated Date for 5/28/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas Q Plugged ^ Abandoned ^ 17. Verbal Approval: Dater WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marcus Barbee 263-7605 Printed Name Timothy C. Brandenberg Title Drilling Manager Signature ~ r. Phone 276-7600 Date T:.w 13 r~p ~.~.r.` ~ `J Z Z O ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~_ Plug Integrity [] BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~® FS`i M'~, h`<'~~~ V~^. ~~~ ~ S~ Subsequent Form Required: { ~ APPROVED BY r~ ~ ~ ~ Approved by: COMMISSIONER THE COMMISSION Date: „]r f L~ ~ v - Form 10-403 Revised 0 ~ 1 ~ ~ ~ ~ ~ Submit in Duplicate 6 Chevron Soldotna Creek Unit Perforation Data: 43B-08 Objective: • Clean fill out of well bore to a depth below bottom perforation • Re-perforate tyonek 59-2 sand as necessary for good injectivity • Gravel pack the Tyonek 59-2 sand to refusal • Turn well over to production Procedure: • Utilize Slick line to drift the production tubing to sand top & take fluid sample from mid pert • Utilize CT to clean out sand from the production tubing to refusal below 6,000' & perform injectivity test from mid pert • Utilize E-Line to re-perforate Tyonek 59-2 sand as necessary to achieve good injectivity /decision to re-pert based on injectivity test • Utilize Slick line to drift the production tubing with a simulated sump packer • Utilize E-Line to tie in and set Sump packer below bottom perforation • Utilize Slick line to install gravel pack screens into sump packer • Utilize CT to install Gravel pack packer and gravel pack the Tyonek 59-2 sands to refusal, then prep well for production w/nitrogen • Turn well over to production DATE INTERVAL MD INTERVAL TVD INTERVAL SUB SEA Footage DESCRIPTION ONE TOP BTM TOP BTM TOP BTM Current 5,857' 5,867' 5,856' 5,866' 5,671' 5,681' 10' Current perforations 59.2 ro osed 5, 857' S, 867' S, 856' S, 866' S, 671' S, 681' 10' ro osed / if in "ectivit is low 59.2 • '~'" , • Swanson River Well SCU 43B-8 UNOCAL 16 Current Status 03-10-08 C a r i n a & T u h i n a RKB = 185' Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11-'/<" SurfCsg 47 J-55 11" Surf 2,073' 16" 1300 sx 177 Calculated 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7 P d C 23 N-80 6.366" 881' 4549' " 9 ''/ 2200 S 7935' 7" ro sg 26 6.276" 4549' 6389' - a x CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' ~.~4ti:U~ti=i`~+ 5„ Liner w/ LTP 18 N-80 4.276" 9,069' 10,742' 6" 72.5 bbls 10'410 CBI. Tubin 3-%:", EUE 8rd 9.3 N-80/L-80 2.992 Surf 8914' f7 ys~ ~ 4{` ~ ~'. ,_. 2 %", 8rd & BTC 4.6 N-80 1.995 8914' 10,327' ! r"~ y tc~ ' ~ "asp `~- ra .TF,WF.i,RY DETAii. NO. De th ID OD Item 18' - Tubin Han er GLM #1 2 371' 2.867 5.968 GLM 3-1/2" GLM #2 4 046' 2.867 5.968 GLM 3-1/2" Live Valve no indication what e GLM #3 5,601' 2.867 5.968 GLM. 3-112" GLM #4 6,807' 2.867 5.968 GLM, 3-1/2" CLM #5 7,795' 2.867 5.968 GLM, 3-I/2" GLM #6 8,717' 2.867 5.968 GLM, 3-I/2" 1. 8,914 1.901 3.50 Crossover, 2-318" EUE 8rd x 3-I/2" EUE 8rd GLM #7 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1.901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Ni le 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembl 4. 10,276' 2.688 Baker "D" Packer 5" x 2-3/8" wf MOE & XO 5. 10,316' 1.870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Sheaz-out Sub w/ WLEG A. 8900' Fas Drill Cement Retainer $, 10,260' Drillable CIBP 10 265' Fish & Junk. "W" Circ lu tb sto and Lead f/ LIB Re ort of "Corkscrewed" Tb f/ 10 265 to 10 275' PF.RFnRATTnN HiST(1RY (T)TT, ilenthcl Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" 06-20-04 59-2 5 857' S 867' 10' 6 2.5" PJ HC 11-03-04 59-2 5 857' S 867' 10' 6 2.5" PJ HC 11-27-04 59-2 5 857' S 867' 10' 6 2.5" PJ HC Mar `O1 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem ISO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 84,5 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 H8 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 810 10,651' 10,664' 13' 4 Tem ISO Feb 91' 810 10,613' 10,642' 29' 6 Tem ISO Dec `93 810 10,613' 10,651' 38' 4 Tem ISO A r 91' 810 10,651' 10,664' 13' 4 Tem ISO 43B-8 Current Schematic 03-07-08.doc REVISED: 9/15/04 by SLT 03-07-08 MGB TD=10,826' PBTD=10,745' Max Deviation = 5.3° @10,322' Swanson River Well SCU 43B-8 UNOCAL 76 Proposed Casing & Tubin g Size T e Wt Grade ID To Btm Hole Cmt Cmt To 20" Conductor Surf 30' Yes Surf. 11?/0" SurfCsg 47 J-55 11" Surf 2,073' 16" 1300sx 777 Calculated 7" 29 6.184" Surf 302' 7" 26 6.276" 302' 881' 7" Prod Cs 23 N-80 6.366" 881' 4549' '/ " 9 2200 S 7935' 7„ g 26 6.276" 4549' 6389' a - x CBL 7" 29 6.184" 6389' 8203' 7" 29 P-110 6.184" 8203' 9380' 7" Window. Cut on 7/81 9,380' 9450' 3;~-F;~~.? ~ .R 5„ Lmer w/ LTP 18 N-80 4.276" 9,069' 10,742' 6" 72.5 bbls 1Q410' CBL Tubin 3-%:", EUE Srd 9.3 N-80/L-80 2.992 Surf 8914' ~~w 2'/", Srd & BTC 4.6 N-80 1.995 8914' 10,327' '~=c JEWELRY DETAIL NO. De th ID OD Item 18' Tubin Han er GLM #1 2 71' 2.867 5.968 GLM 3-1/2" GLM #2 4 046' 2.867 5.968 GLM 3-1/2" GLM #3 5.601' 2.867 5.968 GLM, 3-112" E. 5,824' 1.38 2.992 5011 series TTS GP acker D. 5 827' 1.29 1.92 GP screens C. 5,847' Xx 2.992 Sum aaker GLM #4 6,807' 2.867 5.968 GLM, 3-1/2" GLM #5 7,795' 2.867 5.968 GLM, 3-1/2" GLM #6 8,717' 2.867 5.968 GLM, 3-1/2" 1. 8,914 1.901 3.50 Crossover, 2-3/8" EUE Srd x 3-1/2" EUE Srd GLM #7 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8 10,229' 1.901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Ni le 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembl 4. 10,276' 2.688 Baker "D" Packer 5" x 2-3/8" w/ MOE & XO 5. 10,316' 1.870 Otis "X" Profile Ni le 6. 10,327' 2.00 Baker Shear-out Sub w/ WLEG ,4, 8900' Fas Drill Cemen[ Retainer $, 10,260' Drillable CIBP 10 265' Fish & Junk. "W" Circ lu tb sto and Lead f/ LIB Re ort of "Corkscrewed" Tb f/ 10,265 to 10 275' PERFORATION HISTORY DIL De the Date Zone Top Btm Amt SPF Comments 06-13-04 Tb unch 10,245' 10,251' 6' 4 1.56" ??-??-?? 59-2 5,857' 5,867' 10' 6 2.5" PJ HC 06-20-04 59-2 5,857' 5,867' 10' 6 2.5" PJ HC 11-03-04 59-2 5,857' S 867' 10' 6 2.5" PJ HC 11-27-04 59-2 5,857' 5,867' 10' S S iral 'et Mar `O1 H1 10,342' 10,352' 10' 6 Tem ISO Mar `00 H3 10,374' 10,408' 34' 6 Tem ISO Dec `99 H3 10,420' 10,424' 4' 4 Tem ISO Dec `99 H4,S 10,447' 10,480' 33' 4 Tem ISO Jul `94 H6 10,498' 10,520' 22' ? Tem ISO Dec `99 H7 10,500' 10,520' 20' 4 Tem ISO Jul `94 HS 10,522' 10,540' 18' ? Tem ISO Dec `99 H8 10,524' 10,560' 36' 4 Tem ISO Dec `93 H8 10,540' 10,560' 20' 4 Tem ISO A r `91 H9 10,572' 10,591' 19' 4 Tem ISO A r `91 H10 10,651' 10,664' 13' 4 Tem ISO Feb 91' H10 10,613' 10,642' 29' 6 Tem ISO Dec `93 H10 10,613' 10,651' 38' 4 Tem ISO A r 91' H10 10,651' 10,664' 13' 4 Tem ISO 43B-8 Proposed Schematic 03-10-08.doc REVISED: 03-10-08 MGB TD=10,826' PBTD=10,745' Max Deviation = 5.3° @10,322' ) ) ..J Unocal Alaska 909 W. 9th A venue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unoca1.com /f;dJ - 02- c¡ (Ie¡ () - /¿-~ /7ò--1'f1 UNOCALe Debra Oudean G & G Technician Date: March 10, 2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SCAi\U\JED JUN 1 7 20œj . , . , , . LOG ' . iNTERVAL 'B· " .. WELL, ' VEND9R . . . LOG TYPE' , SCALE DATE' LOGGED LINE FILM CD NOTES ./ --" .,,_. . . .. ....-.. ~._... ~'--' . "" .. ....".." -~ .... . --. --.. -_. -. . '-"~'"'''''''' -.- --. "... .... "" '."- ., ...-...."... --...-'- ...." ..- .-... .--..-..... ......-.. .. .--.- .__." .... "'--' I ... '-"-"'~-" ,j t~¿~--~~~~~-r~~:~:~:;~~~~:~~~~6£~~~~tTT6p-GÜÑs ----·---r:--:~~~ 11~~~~~~: I;~~~~~~Ò-'-I---h-+[---fr-- j Iscu 312'{)9 . Schlu;'berg~r ~g~LEilON RECORD INFLATABLE BRIDGE 5 INCH 11/17f200Ú300-7400 I . 111\ 0 NO CD .I ¡scü·à1-2--õ9·----ls~¡,ïü~b;rge-rlcoMPi~ET'õNR·ËCÒÃÕ-i'HSÒ-POWERJET6 SPF-'lilfJCHrI2à),200~1r:,ì90~nnF: l-" 11'11 '11 - , ¡ ,...."nr-,-..r"'\r-r-nl'^,.........·.... STATE OF ALASKA \ ALf .~ OIL AND GAS CONSERVATION COM...&SION REPORT OF SUNDRY WELL OPERATIONS Total Depth measured 10,826' feet true vertical 10,820' feet Effective Depth measured 8,900' feet true vertical 8,898' feet Casing Length Size MD Structu ral Conductor 30' 20" 30' Surface 2,085' 11-3/4" 2,085' Intermediate 9,300' 7" 9,300' Production Liner 1,757' 5" Perforation depth: Measured depth: 5,857 to 10,664' 1. Operations Abandon U Repair Well U Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 185' 8. Property Designation: Soldotna Creek Unit 11. Present Well Condition Summary: True Vertical depth: 5,856 to 10,646' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 1 8 2005 Stimulate U \ (!)ther . ~J: RßRerforate,~ Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 90-152 Service 0 6. API Number: 50-133-10121-02 9. Well Name and Number: SCU 43B-08 10. Field/Pool(s): Swanson River/Hemlock Plug Perforations U Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 . .:.;~ [Jr, Plugs (measured) 8,900' Junk (measured) TVD Burst Collapse 3,070 psi 1,510 psi 6,340 PSI 3,830 PSI 10,140 psi 10,190 psi 30' 2,085' 9,378' 10,742' 10,7~4' . 0,. SCANNED fEB Z 3 20 5 2-3/8"; 3-1/2" N-80; L-80, N-80 10,327'; 8,914' Baker D Packer 5" x 2-3/8" @10,276' Prior to well operation: 38 Subsequent to operation: 0 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 33 19 880 500 0 2150 15. Well Class after proposed work: Exploratory n Development fYl 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl x Contact Steve Tyler 263-7649 Printed Name Nein Magee Signature ~ fkQxfl<3~ Form 10-404 Revised 04/2004 Tubing Pressure 720 1950 Service n GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: n/a Title Acting Drilling Manager Phone 907-276-7600 Date a../ f7/~s OR\ RBDMS BFl FEB 2 2 2005 ~ \. :'. ¡ ./ \, t II\'JKL. Submit Original Only JEWELRY DETAIL NO. Depth ID OD Item 18' Tubing Hanger GLM #1. 2,371' 2.867 5.968 GLM, 3-112" GLM #2. 4,046' 2.867 5.968 GLM, 3-112" GLM #3. 5,601' 2.867 5.968 GLM, 3-1/2" GLM #4. 6,807' 2.867 5.968 GLM, 3-112" GLM #5. 7,795' 2.867 5.968 GLM, 3-112" GLM #6. 8,717' 2.867 5.968 GLM, 3-112" 1. 8,914 1.901 3.50 Crossover, 2-3/8" EVE 8rd x 3-112" EVE 8rd G L M #7. 9,520' 1.901 4.00 GLM, 2-3/8" GLM #8. 10,229' 1.901 4.00 GLM, 2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Nipple 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembly 4. 10,276' 2.688 Baker "D" Packer 5" x 2-3/8" wi MOE & XO 5. 10,316' 1.870 Otis "X" Profile Nipple 6. 10,327' 2.00 Baker Shear-out Sub wi WLEG A. 8900' Fas Drill Cement Retainer B. 10,260' Drillable CIBP 10,265' Fish & Junk. "W" Circ plug, tbg stop and Lead fl LIB Report of "Corkscrewed" Tbg fll 0,265 to 10,275' PERFORATION HISTORY (DIL Depths) InterwJ. AI.nm ntte Zíœ Tq> Btm Ant spf Connmts 6'2WM 59-2 5,PSl' s¡m 10' 6 25", 6spf, PJIlC l1/3/M Reperl' 5,PSl' 5,867' 10' 6 25",6spf, PJIlC 11127/M Reperl' 5,PSl' 5,867' 10' 5 25", sprat Jet smp &13/M Th2Pmrl 10,245' 10,251' 6' 4 1.56" Qm Nhr-Ol Hl 10,342' 10,352' l(J 6 Tenp IsolatiæPIqn;ed :MIr-OO ID 10,374 10,4Œ :w 6 Tenp IsolatiæPIqn;ed llir99 ID 10,42(J 10,424 4' 4 Tenp IsolatiæPIqn;ed llir99 Ht-,5 10,447 10,4ID 33' 4 Tenp IsolatiæPIqn;ed Jul-94 H5 10,498' 10,520 22 ? Tenp IsolatiæPIqn;ed llir99 H7 10,500 10,520 2(J 4 Tenp IsolatiæPIqn;ed Jul-94 m 10,522 10,540' 18' ? Tenp IsolatiæPIqn;ed llir99 m 10,524 1O,5ro' 36 4 Tenp IsolatiæPIqn;ed llir93 m 10,540' 1O,5ro' 2(J 4 Tenp IsolatiæPIqn;ed A¡r-91 IÐ 10,572' 10,591' 19 4 Tenp Isolatiæ PIqn;ed A¡r-91 HlO 10,651' 10,664' 13' 4 Tenp IsolatiæPIqn;ed Ftb-91 HlO 10,613' 10,642' 29 6 Tenp IsolatiæPIqn;ed REVISED: 9/15/04 by SL T 02/14/05 by CRW ) UNOCALe RKB = 185' Casing & Tubing Grade ID Top Btm Surf 30' Size 20" Type Conductor Wt ~. - ~l".' ~ , - -t 11-%" SurfCsg 47 29 ~ 23 ~ 29 29 J-55 11 " 6.184" 6.276" 6.366" 6.276" 6.184" 6.184" Surf 2,073' 7" 7" 7" 7" 7" 7" 7" Window. Cut on 7/81 I Liner Toe @5074' 5" wi L TP Tubin~ 3-W', EVE 8rd 2 %", 8rd & BTC Surf 302' 881 ' 4549' 6389' 8203' 9,380' 9,069' 302' 881 ' 4549' 6389' 8203' 9380' 9450' 10,742' ~ Prod Csg N-80 P-110 118 I I 9.3 I N-80/L-80 I 2.992 4.6 N-80 1.995 N-80 14.276" ... 11:1 U ~ I Surf 8914' I 8914' 10,327' @ u ~ «S ,§., E ,;; fg¡ a=~- ¡ @ ,~(~ ]~~i.:..i... ¡ 0 ' u¡" ,.' ¡f;"l , ~ do ~ i~~ ift.-$'~' ~~; , :'.':~~ . ;1_-:--- - _:_:_: :-:-~ Obstruction @ 10,286' 6 ~ TD= 10,826' PBTD= 8,900' Max Deviation = 5.3° @10,322' 43B-8 Final Recompletion 2-05 ) Swanson River Well SCD 43B-8 As Completed on 6/20/04 Hole Cmt Cmt Top Yes Surf 16" 1300 sx 177' Calculated 9-1'.' 2200 Sx 7935' CBL 6" 72.5 bbls ~ 6/1/04 ) ) PJSM. RU Slickline lubricator and equipment. Test to 1500 psi. Pump 6 bbls of Xylene down tubing with tri-plex pump. RIH with 2.81 GR to 1024', POOH. RD. 6/2/04 PJSM. RU Slickline lubricator and equipment. Test lubricator to 1500 psi, RIH with 3 1/2" wirebrush and brush while pumping diesel. Tagged asphaltines @ 1030'. Continue working brush and pumping diesel. Worked down to 1360'. RD. SDFN. 6/3/04 PJSM Test lubricator to 1500 psi. RIH with 3 1/2" wirebrush to 1360', pump and work down to 1420'. POOH. RIH with 2.80 GR to 1420', would not pass. POOH. Pump PAO-33 mixed with diesel. Flow well. Shut well in and RIH 2.85 GR to 1462'. Continue in hole to 8901', POOH. RIH with 1.85 GR to 10,265', POOH. RD. 6/4/04 PJSM, RU and test Slickline lubricator to 1500 psi. RIH wI 2" Daniels KOT with 1 1/4" JDC to GLM #810229' pull GLV. RIH with same pull GLV at 9516'. RIH with 31/2"om-1 kot with 1 5/8" JDS to and pull GLV at 8712',7791', 6800',5598',4039', and 2363'. RD Slickline. 6/5/04 PJSM. RU Slickline, Test lubricator to 1500 psi. RIH, set dummys in all GL Vs. 6/12104 RU/PT pump truck, choke valves and Johnson tank for operations. 6/13/04 RU Schlumberger. PJSM. Pressure test lubricator to 2500 psLRU Weatherford bridge plug (1.75 OD) and set plug at 10,260'. Fill tubing with 28~6 barrels water. WIH with Schlumberger 1.56" OD perf gun and perfed 25 holes from 10,245' to 10,251'. MU Halliburton 2.56" OD fast drill cement retainer and set retainer at 8900'. RD Schlumberger. 6/15/04 PJSM. RU. BOP Test (State Waived Witness). Test Hard Lines, Test Blind Rams and Pipe Rams 250# Low Pressure and 3500# High Pressure All Tested OK. 6/16/04 PJSM. RU Stab Injector Head. Perform low pressure and high pressure test on stripper head and clean tanks. RIH checking coil pickup weights every 1000' and tag on retainer at 8883'. Circulate until returns up production casing to tank and check circulation rates at 1.25, 1.0, .75 and .5 BPM. Pump 125 bbls 15.8# G-neat cement. Pump displacement volume of 27 bbls through coil and 2 3/8" tubing between retainer at 8900' and perforations at 10145'. PU off retainer and check float in retainer (OK). Circulate bottoms up 58 bbls coil by tubing annulus. POOH to 4500' continue to CBU 23 more bbls. Pump N2 and unload tubing from 4500' to surface. POOH to surface. Pump N2 and put 2000# nitrogen cap on tubing top 4500'. Close all well head valves and secure well head. 6/17/04 SCU 43B-08 morning report summary, CONFIDENTIAL: last revised 2/17/2005 Page 1 v PJsM: RU slickline and pressure ~v)t to 2500 psi. MU 2.25 GR and RIH. Tagg",)upat 8898'. RIH with tri-temp tool and logged from 4000' to 8886' and back to 4000'. RDPollard and secure well. Found fluid level @ 4060'. Found roc 5074'. 6/18104 Rig up PTS equipment for 6-20-02 test and pressure test all equipment. Found several leaks and fix during hydro test. 6/20/04 PJSM, Rig up Schlumberger, load perf gun (10', 2.5"OD, 6 spf Power Jet HC), pressure test to 2500 psi. RIH, tied in to GR/CCL log dated 6-13-04 and spotted perf gun from 5857' to 5867'. Bled tubing down to 1426 psi and fired gun. Gained 189 Ibs first minute. POOH. RD Schlumberger and turned well over to PTS. Unload well with rate increasing from 2.5 to 3.4 MM/D on choke at 10/64. Prod 17.9 Bbl completion fluids. Flow test with rate pushing 5 MM/D. TP at 2240 psi. CP at 50 psi. No fluids. Dry gas. Shut in. Pressure built from 2240 to 2334 in1 minute. Fluid level 80 feet above perfs. Flow test with rate building to 5.6 MM/D. TP declining to 2150. No fluids. SI. Disconnect PTS and prep to move to next well with PTS. Well to operations for production connection. PTS on standby for next well. 6/21/04 Shot fluid level. Fluid at 5680'. PJSM, rig up, test lubricator to 3000 psi. RIH with 2" bailer to 5858' and obtained fluid sample across perfs. POH RIH with 2" bailer to 8884' and collected sample. 16' of fill above bridge plug. (Sand) RD Pollard and secure well. 11/3/04 PJSM. RU pressure test lubricator 300# low and 3000# high (OK). Well has 2140 psi tubing pressure. RIH with 10' of 2.5" HSD Powerjet, 6SPF, 60° deg. Phase correlating to GR/CCL Log dated 6/13/04. Made position pass and tied CCL into Gas. lift valve # 4 at 6810' W/L. Using CCL and correlating to GR/CCL log (6/13/04) pulled up and positioned 10', 2.5" HSD Powerjet guns across existing perfs at 5857' to 5867' (Reperforate 59-2 Sands). Fired guns and had good indication they shot, no increase in tubing pressure identified. POOH inspect guns all 61 .' shots fired. RD. Flow test well. . 11/26/04 PJSM, RU, PT lubricator to 3000 psi. RIH WI 2.75 GR to 8862' KB (WLM)POOH. OOH WI GR, make up dummy guns (10' spent 2.5" guns). RIH WI 2.5" dummy guns to 8860' KB (WLM), POOH no excessive PU weight. Fluid level at 5400'. OOH WI dummy guns RD. 11/27104 PJSM. RU lubricator. Arm guns, NU and test lubricator to 3000 psi. RIH W 10' of 2.5" spiral jet strip gun. 9EnJetPH-DP 2.13in, PJ, HMX, 5SPF to 6100', SWS GR-CCL Log 6-13-04, Perforate from 5857' to 5867' guns fired at 16:00 hrs. POOH. RD, and secure well. SCU 43B-08 morning report summary, CONFIDENTIAL: last revised 2/17/2005 Page 2 ') ) Unocal Alaska 909 W. 9lh A venue Anchorage, AK 99501 Te1e: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com Í,Ik~ ~5r \~:V ,t Î UNOCAL Debra Oudean G & G Technician Date: November 29, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 '. INTERVAL B·, ' WELL LOG TYPE ,S~ALE LOG DATE LOGGED LINE CD .Ð'I..ot>t 1KG'8'F'~7Ä" ,""" PERFÒÄATING RECÓÃÖ"'3"3/8'HSO"GÙN' "","''''''''..,,'' . """''''''''''''''''lS'''INCH 1""'Ú)i24/~iÓö416"Újó-'fi456"" ""'I'" '''1''''''']'''1''''; ./ 1's'Clj"'24Ä~ò'5""'lPLÜG"'sËT"'Äï~(:;ÖFiD"'2"'7¡8"'H'Aï~ijBÜRTÒ~.iï~Z'siJ ,...., 15 INCH I' 0/21/200.t 19635-9635 I 1 11 j I qo / lSCÙ24Á:Ö5-ISQUËEZEF)E~FORÃ TI6';iRgëoRD2HSÖ 2096Pj 6~pC-]5iNCH - "¡ '-{OI29i200;¡ ]7626--7800-]--i---1-1J ~~~~~:~~~~~!~1it~~~~~~~~~~~~~~iN~§:=_~:=:~=:'-~=:=:_"~1~;~6~---1-~~~~~~I~~~~~~~Fl'=:FlP ICQ(J looOZ,1J1sCU.2!2-09 J~OMPLETION RE(;OR~_~ HSD POWERJE_!._.___",.___I,~~~J~1/2/2004~O~6340_.."J_~_I_~J - '.f: J jscu 32-08 i COMPLETION RECORD 2_5 HSD POWERET 6 SPF 60 ¡ 5 INCH . 10/3/2004110200-10565 1 1! ~~~~ 5 ~ ¡SëU43B:081~~~~~~~~~SR~CORÒ 2_5HSD POWERJETS . . '15 INCH '¡ -i 1Ï3I2004]5857 -5867 .., {11 i ~ ~ ~tf:;~;:;_~5--I¡~tbl~~~i~~~~;:;:~A;;;c~O_~:~S~:~~~:_--_!I:i~~i:H]-~::~~~;I:;;:;~~-~-----I---~-:J-~-1 1/~/f)øjJSRU 32A-15 COMPLETION RECORD 2 HSD POWERJET 6SPF 60 5 INCH 9/30/2004 7280-7600 1 1 !I -, ï - {) r I DEGREE PHASED . ~:,:~32A:15··~~~J~~~t~ÃE~~g~I~~~~~;~~~~-ET6SPF 5 INêH··"":·_'~~~~~~~~-683Õ:73;¡5'··'-"~:~-'··iJ '\ P" - ,; ')rj ["I ¡ì \SCA,NNEr ,c, ,~. H .~ ~; (..'.i 'J' Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: /~~~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilU Gasl:J Plugged 0 Abandoned 0 Suspended 0 WAGD 1 b. Well Class: 20AAC25.105 20AAC 25.110 Development 0 Exploratory 0 GINJD WINJD WDSPLD No. of Completions Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., s~r I(ft.., 12. Permit to Drill Number: Union Oil Company of California Aband.: 4 90-0152-0 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10121-02 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2150 S, 0515 E, Sec. 08 T7N 009W SCU 43B-08 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 2150 S, 0515 E, Sec. 08 T7N 009W 185 Total Depth: 9. Plug Back Depth(MD+ TVD): Swanson River UniU 2311 S, 0417 E, Sec 08 T7N 009W 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 341,807 y- 2,452,885 10,826/10,819' Swanson River Unit TPI: x- y- 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- y- 10,2761 nla 18. Directional Survey: Yes ~No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL nla 21. Logs Run: Temperature survey 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 0 30' 0 30' yes surf 11-314" 47# J-55 0 2,073 0 2,073' 19" 1,300 sx; 177' calculated 7" 23,26,29 N-80, P-110 0 9,450 0 9,537' see schematic 2,200 sx; 7,935' CBL 5" 18# N-80 9,069 10,742 9067 10,735' 6" 72.5 bbls; 10,410' CBL 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE I DEPTH SET (MD) PACKER SET (MD) see attached schematic see attached schematic 10,276' I 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): nla Flow Date of Test: IHours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: /GaS-Oil Ratio: see reverse side Test Period .... Flow Tubing Icasing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ..... 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". SEP2~) 7f\f\.4 none ~ RBDMS Sf L .. ~-" , RECEIVED \ I: ~. ORIGINAL SEP 1 6 2004 ~ [- ..' Ailltltlil nil & Gas Cans. Commission Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Anchorage 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 59-2 Sand 5,857' MD 5,856' TVD 59-2 Sand Perf 5,857 to 5,867 MD 6/21/04; Flow test #1 (5 hrs): unloaded 17.1 bbls completion fluid Shut-in #1 (1 hr): 2,334 psis sitp, 5,780' F.L. Flow test #2 (3 hrs): 5.6 xxId @ 2,150 psis FTP Shut-in #2 (4 days/20hrs): 2,360 psis SITP RECEIVED SEP 1 6 2004 A'aska on & Gas Cons. Commission Anchorage 30. List of Attachments: schematic, directional survey, daily summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: Philip J. Krueaer Title: Drilling Manager ~,.//-. ~ Phone: 907-276-7600 Date: 9/15/2004 Signature: ..r~ / / ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR\G\NAL UNOCAL8 Swanson River Well SeD 43B-8 As Completed on 6/20/04 RKB = 185' Size T e 20" Conductor 11-0/.," SurfCsg Wt Cas in Grade ID 30' Hole Cmt Cmt To Yes Surf. 1300 sx 177' 16" Calculated 47 J-55 II" Surf 2,073' 302' 881' 4549' 6389' 8203' 9380' 9450' 9-? " 2200 Sx 7935' CBL .¡ e 10,742' ~ @ ~ o¡ ~ @ e Iõ SIJ-Z Sand NO, Oeoth ID 00 Item 18' - Tubinn Hanner GL'\<1 #1. 2371' 2.867 5.968 GLM 3-1/2" GLM #2. 4046' 2.867 5.968 GLM 3-1/2" GLM #3. 5601' 2.867 5.968 GLM 3-1/2" GLM #4. 6 807' 2.867 5.968 GLM 3-1/2" GLM #5. 7795' 2.867 5.968 GLM 3-1/2" GLM#6. 8717' 2.867 5.968 GLM 3-1/2" 1. 8914 1.901 3.50 Crossover 2-3/8" EVE 8rd x 3 -1/2" EVE 8rd GLI\1 #7. 9520' 1.901 4.00 GLM 2-3/8" GLM #8. 10229' 1.901 4.00 GLM 2-3/8" 2. 10242' 1.870 2.50 Baker "X" Ninnle 3. 10275' 1.968 3.00 E22 Anchor and Seal Assemblv 4. 10276' 2.688 Baker "V' Packer 5" x 2-3/8" wi MOE & XO 5. 10111\' 1.870 Otis "X" Prnfilp Ninnlp 6. 10.127' 2.00 Bohr Shear-out <:..h wi WLEG A. 8900' Fao Drill Cement Retainer 8, 10260' Drillable CIBP 10265' Fish & Junk. "W" Cire "Iun Ibn 010" and Lead fl LIB Renort of "Corkoerewed" Tb2 f/lO,265 to 10,275' JEWELRY DETAIL ~ ~ @ is .. 6 PERFORATION HISTORY lOlL DeDths) Interval Attorn, Date Zone Ton 8tm Amt sof Comments 6120104 59-2 5J157' 5867' 10' 6 2.5" 6snf PJ HC "I1UY 10UI;' 1011;1' 1\' A C"" roo.. Mar-OI HI 10342' 10352' 10' 6 T~ Isolation i>rnnn<pd Mar -00 H3 10374' 10408' 34' 6 T~ Isolation ~ Dec-99 H1 10420' 10424' 4' 4 T"- IMlotion i>rnnn<ed -0;;;:--99 H4- 10447' 104RO' 11' 4 Ternn l""lation Prnnn<Pn Jul=<M H6 10498' 10 -20' 22' ? TPmn l""lotinn Prnnn<Pd Dec-99 H7 10500' 10520' 20' 4 Ternn Isolation Prnnn<ed Jul-94 H8 10522' 10540' 18' ? Temn Isolation Pronosed Dec-99 H8 10524' 10560' 36' 4 Tern.. Isolation Po-nnnsed Dec-93 H8 10540' 10560' 20' 4 T~ Isolation Pr~"d Anr-91 H9 10572' 10591' 19' 4 Temn Isolation Pronnsed A;;;91 HIO 10651' 10 664' 13' 4 Temn lsolation~ Feb-91 HIO 10 613' 10.642' 20' 6 T Pmn Isolation Pr"""""d n..-_01 HlO 10 613' 10.651' 38' 4 T~ lo..lotion i>rnnn<ed Anr-91 HlO 10651' 10664' 13' 4 Ternn Isolation Pr~"d ~ J~ ''is e.. TD= 10,/126' PBTD=10,745' Max Deviation = 5.3" @10,322' 43B-8 Final Recompletion 6-04 REVISED: 9/15/04 by SLT 6/1/04 No Operations Held PJSM, Discuss job. RU Slickline lubricator and equipment. Test to 1500 psi. Pump 6 bbls of Xylene down tubing with tri-plex pump. RIH with 2.81 GR to 1024', very sticky POOH (Asphaltines on gauge ring) RD secure well. Will move slickline to 23-27 in the AM. 6/2/04 No Operations Held PJSM with Slickline, RU Slickline lubricator and equipment. Test lubricator to 1500 psi, RIH with 31/2" wirebrush & brush while pumping diesel. Tagged Asphaltines @ 1030', Continue working brush and pumping diesel. Worked down to 1360' Rig down - Secure well. Will continue in the AM 6/3/04 No Operations Held PJSM with Slickline, Discuss forward plans. Test lubricator to 1500 psi. RIH with 3 1/2" wirebrush to 1360', pump and work down to 1420', Couldn't make any hole. POOH RiH with 2.80 GR to 1420', would not pass. POOH. Pump PAO-33 mixed with diesel. Flow well. Shut well in & RIH 2.85 GR to 1462', set down working tools, Continue in hole to 8901', POOH RIH with 1.85 GR to 10,265', POOH. RD Slickline will continue in the AM 6/4/4 No Operations Held PJSM, RU and test Slickline lubricator to 1500 psi RIH w/2" Daniels KOT with 1 1/4" JDC to GLM #8 10229' pull GLV. RIH with same pull GLV at 9516'. RIH with 31/2" om-1 kot with 1 5/8" JDS to and pull GLV at 8712',7791 ',6800',5598',4039',and 2363'. RD Slickline equipment. Will set dummy's in the AM 6/5/4 No Operations Held PJSM with Pollard, RU Slickline, Test lubricator to 1500 psi. RIH, set dummys in all GL V's will jug test tbg in the AM. 6/12/04 No Operations Went to SIMOPS meeting Waiting on equip from coil mobe Rig up pump truck, choke valves and johnson tank Pump lease water down back side to fill casing for pressure test. Pumped 121 barrells. Put 1000 psi on back side and held it for 15 min. Pressure test good Rigged pump truck, choke lines and johnson tank down. 6/13/04 No Operations Went to SIMOPS Meeting Wait on Schlumberger to arrive RU Schlumberger, held safety meeting and pressure test lub to 2500 psi RU Weatherford bridge plug (1.75 00) and set plug at 10,260' Fill tubing with 28.6 barrels water Went in hole with Schlumberger 1.56" 00 perf gun and perfed 25 holes from 10,245' to 10,251' MU Haliburton 2.56" 00 fast drill cement retainer and set retainer at 8900'. Rig down Schlumberger 6/15/04 No Activity SIMOPS with production on all the days projects. Roustabouts start pulling equipment from 34- 28 pad Mobe equipment from 34-28 to 43B-8. Peak, Schlumberger and WBI wench truck (PJSM on Rig Up) (BOP Test - State Waived Witness) Test Hard Lines, Test Blind Rams and Pipe Rams 250# Low Pressure and 3500# High Pressure All Tested OK Sent Schlumberger home after finishing rig up, Peak hauled water too 500 bbl Tiger Tank and worked on Berm's Stand down for rest. Peak crew working on equipment. Peak moved Johnson tank to 212-27. Production using blow down tank on 43A-4 tonight to bleed off casing 6/16/04 SDFR SIMOP'S with production Schlumberger arrive on location Hold PJSM with Schlumberger and Peak. Check all calculations & capacities and go over program. Make up tools and Stab Injector Head Perform low pressure and high pressure test on striper head and clean tanks RIH checking coil pickup weights every 1000' and tag on Retainer at 8883' coil tubing measurement Circulate until returns up production casing to CONFIDENTAL - SCU-43B-08_AOGCC10-407Summary_AFE162571 , last revised 9/16/2004, page 1 tank and check circulation rates at 1.25, 1.0, .75 and .5 BPM. Batch mixing cement during this time. Pump 125 Bbls 15.8# G-neat cement (catching samples and checking weights of same) Pump displacement volume of 27 Bbls through coil and 2 3/8" tubing between Retainer at 8900' and perforations at 10145' Pick up off Retainer and check float in retainer (Good OK) Check bad valves in cement pump and find trash under suction valve seat. Circulate Bottoms up 58 Bbls coil by tubing annulus POOH to 4500' continue to CBU 23 more Bbls while doing so Finish nitrogen cool down and test nitrogen lines Found leak on nitrogen unit warmed up fixed discharge side connection and cooled back down and re-test. Pump N2 and unload tubing from 4500' to surface POOH to surface Pump N2 and put 2000# nitrogen cap on tubing top 4500' (Close all well head valves and secure well head) Stand back injector head, bust down hard lines and prepare equipment for MOBE to SRU 34-28 (Stand down crews for rest until 08:00 hrs tomorrow) 6/17104 No operations PJSM, rig up pollard slickline and pressure test to 2500 psi MU 2.25 GR and RIH. Tagged up at 8898' RIH with tri-temp tool and logged from 4000' to 8886' and back to 4000' Rig Pollard down and secure well. Found fluid level @ 4060'. Found TOC 5074' 6/18/04 No Operations Field Orientation with production for one hour. Good operations meeting with production, drilling and PTS. Rig up PTS equipment for 6-20-02 test and pressure test all equipment. Found several leaks and fix during hydro test Need to unload Hydro water prior to bringing well on Lined PTS supervisor out on field ticket needs for end of day cost Plan hand over to gas team field rep (Don Andrus for reporting) We will support in T-Pak moves and well knowledge during project testing. 6/20104 Attend SIMOPS Meeting Waiting on PTS to blow down test lines PJSM, Rig up Schlumberger, load perf gun (10', 2.5"OD, 6 spf Power Jet HC), pressure test to 2500 psi RIH, tied in to GR/CCL log dated 6-13-04 and spotted perf gun from 5857' to 5867' Checked with PTS and Don Andrews. Bled tubing down to 1426 psi and fired gun. Gained 1891bs first minute. POOH Rigged Schlumberger down and turned well over to PTS. (BA) Unload well with rate incresing from 2.5 to 3.4 MM/D on choke at 10/64. Prod 17.9 Bbl completion fluids. Flow test with rate pushing 5 MM/D. PTS metering problems. TP at 2240 psi. CP at 50 psi. No fluids. Dry gas. Shut in. Pressure built from 2240 to 2334 in 1 minute. Fluid level 80 feet above perfs. Flow test with rate building to 5.6 MM/D. TP declining to 2150. No fluids. S. I. Disconnect PTS and prep to move to next well with PTS. Well to operations for production connection. PTS on standby for next well. 6/21/04 No Operations. Shot fluid level. Fluid at 5680'. Wait on slickline unit to move from SRU 34-28 to 43B-48. PJSM, rig up, test lubricator to 3000 psi. RIH with 2" bailer to 5858' and obtained fluid sample across perfs. POH. RIH with 2" bailer to 8884' and collected sample. 16' of fill above bridge plug. (Sand). Rig down Pollard and secure well CONFIDENTAL - SCU-43B-O8_AOGCC10-407Summary-AFE162571 , last revised 9/16/2004, page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Suspend U Operation Shutdown U Perforate W WaiverU Other U Performed: Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill;~ber: - ¿ø Name: Development 0 Exploratory 0 Q6-ð1~!.6 ~/~~ J 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic 0 Service 0 6. API Number: 50-133-10121-02 7. KB Elevation (ft): 9. Well Name and Number: 185' SCU 43B-08 8. Property Designation: 10. Field/Pool(s): Soldotna Creek Unit Swanson River Unit 11. Present Well Condition Summary: Total Depth measured 10,826' feet Plugs (measured) true vertical 10,819' feet Junk (measured) Effective Depth measured 10,745' feet true vertical 10,738' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 2,073' 11-3/4" 2,073' 2,073' 3,070 psi 1,510 psi Intermediate Production 9,450' 7" 9,540' 9,537' 6,340 psi 3,830 psi Liner 1,673' 5" 10,742' 10,735' 10,140 psi 10,490 psi Perforation depth: Measured depth: see schematic attached True Vertical depth: Tubing: (size, grade, and measured depth) 2-3/8",3-1/2"; N-80, L-80; 8,914'; 10,327'; Packers and SSSV (type and measured depth) Baker "D" Packer @ 10,276' 12. Stimulation or cement squeeze summary: JUt "l JrJO4 Intervals treated (measured): see schematic attached. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure I Tubing Pressure Prior to well operation: n/a Subsequent to operation: n/a .6 MMCFPD 0 0 I 1,910psi 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 304-205 Contact Steve Tyler 263-7649 Printed Name Phil J. Krueger Title Drilling Manager Signature ~ £,. //- - Phone 907-276-7600 Date 7/27/2004 / r , Form 1 0&'04 Revised 12/2003 n QJ h , ~,' .1\ , IJII)MS SF L JUl2\t I UNOCALe Swanson River Well SCU 438-8 As Completed on 9/18/02 RKB = 185' Cas i n Size T e Wt Grade ID Hole Cmt Cmt To 20" Conductor Yes Surf. 11-%" SurfCsg 47 J-55 II" Surf 2,073' 16" 1300 sx 177' Calculated 29 6.184" Surf 302' 26 6.276" 302' 881' Prod Csg 23 N-80 6.366" 881' 4549' 9-Y," 2200 Sx 7935' 26 6.276" 4549' 6389' CHL 29 6.184" 6389' 8203' 29 polIO 6.184" 8203' 9380' 9,380' 9450' 9,069' 10,742' .J .. u " ~ '" ~. ~ u ¡: .¡ ~ ". E ,¡ 5\1-2 Son. JEWELRY DETAIL .J .. u ~ NO. Depth ID OD Item 18' - - TubinQ HanQer GLM #1. 2,371' 2.867 5.968 GLM,3-1/2" GLM #2. 4,046' 2.867 5.968 GLM,3-1/2" GLM #3. 5,60]' 2.867 5.968 GLM,3-1/2" GLM #4. 6,807' 2.867 5.968 GLM,3-1/2" GLM #5. 7,795' 2.867 5.968 GLM, 3-1/2" GLM #6. 8,717' 2.867 5.968 GLM, 3-1/2" 1. 8,914 1.90] 3.50 Crossover, 2-3/8" EVE 8rd x 3-1/2" EVE 8rd GLM #7. 9,520' 1.90] 4.00 GLM, 2-3/8" GLM #8. ]0,229' 1.901 4.00 GLM,2-3/8" 2. 10,242' 1.870 2.50 Baker "X" Nipple 3. 10,275' 1.968 3.00 E22 Anchor and Seal Assembly 4. 10,276' 2.688 Baker "0" Packer 5" x 2-3/8" wi MOE & XO 5. 10,3]6' 1.870 Otis "X" Profile Nipple 6. 10,327' 2.00 Baker Shear-out Sub wi WLEG A. 8900' Fas Drill Cement Retainer B. 10,270' Retrievable or Drillable Bridge Plug wi 10' ofsand ;,; u 0 .. O"'rud;on @10,286' ~ ~ ~ 6 PERFORATION HISTORY (DIL Depths) Interval Accum. Date Zone Top Btm Amt spf Conunents 59-2 5832' 5.842' 10' 6 TbI! Puocl 10.245' 10251' 6' 4 Prooosed Mar-O] H] 10,342' 10,352' ]0' 6 Teß1) Isolation Proposed Mar -00 H3 10,374' 10,408' 34' 6 Teß1) Isolation Proposed Dec-99 H3 10,420' 10,424' 4' 4 Teß1) Isolation Proposed Dec-99 H4,5 10,447' 10,480' 33' 4 Teß1) Isolation Proposed Jul-94 H6 10,498' 10,520' 22' ? Teß1) Isolation Proposed Dec-99 H7 10,500' ]0,520' 20' 4 Teß1) Isolation Proposed Jul-94 H8 10,522' ]0,540' 18' ? Teß1) Isolation Proposed Dec-99 H8 10,524' ] 0,560' 36' 4 Teß1) Isolation Proposed Dec-93 H8 ]0,540' 10,560' 20' 4 Terq¡ Isolation Proposed Apr-91 H9 10,572' ]0,591' 19' 4 Terq¡ Isolation Proposed Apr-91 HIO 10,651' 10,664' 13' 4 Terq¡ Isolation Proposed Feb-91 HIO 10,613' 10,642' 29' 6 Tenw Isolation Proposed Dec-93 HIO 10,613' 10,651' 38' 4 Tenw Isolation Proposed Apr-91 HIO 10,651' 10,664' \3' 4 Temp Isolation Proposed g , ~. ]@ -:u ;0 "'.. TO: 10,826' PBTD= 10,745' Max Deviation = 5.3° @10,322' 43B-8 Proposed Schematic 4-041 REVISED: 7/7/04 by SLT 6/1/04 No Operations. Held PJSM, Discuss job. RU Slickline lubricator and equipment. Test to 1500 psi. Pump 6 bbls of Xylene down tubing with tri-plex pump. RIH with 2.81 GR to 1024', very sticky POOH (Asphaltines on gauge ring). RD secure well. Will move slickline to 23-27 in the AM. 6/2/04 No Operations. Held PJSM with Slickline, RU Slickline lubricator and equipment. Test lubricator to 1500 psi, RIH with 3 1/2" wirebrush & brush while pumping diesel. Tagged Asphaltines @ 1030', Continue working brush and pumping diesel. Worked down to 1360'. Rig down - Secure well. Will continue in the AM 6/3/04 No Operations. Held PJSM with Slickline, Discuss forward plans. Test lubricator to 1500 psi. RIH with 3 1/2" wirebrush to 1360', pump and work down to 1420', Couldn't make any hole. POOH. RiH with 2.80 GR to 1420', would not pass. POOH. Pump PAO-33 mixed with diesel. Flow well. Shut well in & RIH 2.85 GR to 1462', set down working tools, Continue in hole to 8901', POOH. RIH with 1.85 GR to 10,265', POOH. RD Slickline will continue in the AM. 6/4/04 No Operations. Held PJSM, RU and test Slickline lubricator to 1500 psi. RIH w/2" Daniels KOT with 1 1/4" JDC to GLM #8 10229' pull GL V. RIH with same pull GL Vat 9516'. RIH with 3 1/2" om-1 kot with 1 5/8" JDS to and pull GLV at 8712',7791 ',6800',5598',4039',and 2363'. RD Slickline equipment. Will set dummys in the AM. 6/5/04 No Operations. Held PJSM with Pollard, RU Slickline, Test lubricator to 1500 psi. RIH, set dummys in all GL V's will jug test tbg in the AM. 6/12/04 No Operations. Went to SIMOPS meeting. Waiting on equip from coil mobe. Rig up pump truck, choke valves and johnson tame Pump lease water down back side to fill casing for pressure test. Pumped 121 barrells. Put 1000 psi on back side and held it for 15 min. Pressure test good. Rigged pump truck, choke lines andjohnson tank down. 6/13104 43B-08_AOGCC10-404Summary-AFE162571 , last revised 7/7/2004, page 1 No Operations. Went to SIMOPS Meeting. Wait on Schlumberger to arrive. RU Schlumberger, held safety meeting and pressure test lub to 2500 psi. RU Weatherford bridge plug (1.75 aD) and set plug at 10,260'. Fill tubing with 28.6 barrels water. Went in hole with Schlumberger 1.56" OD perf gun and perfed 25 holes from 10,245' to 10,251'. MU Haliburton 2.56" OD fast drill cement retainer and set retainer at 8900'. Rig down Schlumberger 6/15/04 No Activity. SIMOPS with production on all the days projects. Roustabouts start pulling equipment from 34-28 pad. Mobe equipment from 34-28 to 43B-8. Peak, Schlumberger and WBI wench truck (PJSM on Rig Up). (BOP Test - State Waived Witness) Test Hard Lines, Test Blind Rams and Pipe Rams 250# Low Pressure and 3500# High Pressure All Tested OK. Sent Schlumberger home after finishing rig up, Peak hauled water too 500 bbl Tiger Tank and worked on Benn's. Stand down for rest. Peak crew working on equipment. Peak moved Johnson tank to 212-27. Production using blow down tank on 43A-4 tonight to bleed off casing 6/16/04 SDFR. SIMOP'S with production. Schlumberger arrive on location Hold PJSM with Schlumberger and Peak. Check all calculations & capacities and go over program. Make up tools and Stab Injector Head. Perfonn low pressure and high pressure test on striper head and clean tanks. RIH checking coil pickup weights every 1000' and tag on Retainer at 8883' coil tubing measurement. Circulate until returns up production casing to tank and check circulation rates at 1.25, 1.0, .75 and .5 BPM. Batch mixing cement during this time. Pump 125 Bbls 15.8# G-neat cement (catching samples and checking weights of same). Pump displacement volume of27 Bbls through coil and 23/8" tubing between Retainer at 8900' and perforations at 1 0 145'. Pick up off Retainer and check float in retainer (Good OK) Check bad valves in cement pump and find trash under suction valve seat. Circulate Bottoms up 58 Bbls coil by tubing annulus. POOH to 4500' continue to CBU 23 more Bbls while doing so. Finish nitrogen cool down and test nitrogen lines. Found leak on nitrogen unit warmed up fixed discharge side connection and cooled back down and re-test. Pump N2 and unload tubing from 4500' to surface. POOH to surface. Pump N2 and put 2000# nitrogen cap on tubing top 4500' (Close all well head valves and secure well head). Stand back injector head, bust down hard lines and prepare equipment for MOBE to SRU 34-28 (Stand down crews for rest until 08:00 ills tomorrow) 6/17/04 No operations. PJSM, rig up pollard slickline and pressure test to 2500 psi. MU 2.25 GR and RIH. Tagged up at 8898'. RIH with tri-temp tool and logged from 4000' to 8886' and back to 4000'. Rig Pollard down and secure well. Found fluid level @ 4060'. Found TOC 5074' 6/18/04 43B-OB_AOGCC10-404SummarLAFE162571, last revised 7/7/2004, page 2 No Operations. Field Orientation with production for one hour. Good operations meeting with production, drilling and PTS. Rig up PTS equipment for 6-20-02 test and pressure test all equipment. Found several leaks and fix during hydro test. Need to unload Hydro water prior to bringing well on. Lined PTS supervisor out on field ticket needs for end of day cost. Plan hand over to gas team field rep (Don Andrus for reporting) We will support in T -Pak moves and well knowledge during project testing. 6/20/04 Attend SIMOPS Meeting. Waiting on PTS to blow down test lines. PJSM, Rig up Schlumberger, load perf gun (10', 2.5"OD, 6 spfPower Jet HC ), pressure test to 2500 psi. RIH, tied in to GR/CCL log dated 6-13-04 and spotted perf gun from 5857' to 5867'. Checked with PTS and Don Andrews. Bled tubing down to 1426 psi and fired gun. Gained 189 lbs first minute. POOH. Rigged ScWumberger down and turned well over to PTS. (BA). Unload well with rate incresing from 2.5 to 3.4 MMID on choke at 10/64. Prod 17.9 Bbl completion fluids. Flow test with rate pushing 5 MMID. PTS metering problems. TP at 2240 psi. CP at 50 psi. No fluids. Dry gas. Shut in. Pressure built from 2240 to 2334 in 1 minute. Fluid level 80 feet above perfs. Flow test with rate building to 5.6 MM/D. TP declining to 2150. No fluids. S.L Disconnect PTS and prep to move to next well with PTS. Well to operations for production connection. PTS on standby for next well. 6/21/04 No Operations. Shot fluid level. Fluid at 5680'. Wait on slickline unit to move from SRU 34-28 to 43B-48. PJSM, rig up, test lubricator to 3000 psi. RIH with 2" bailer to 5858' and obtained fluid sample across perfs. POH. RIH with 2" bailer to 8884' and collected sample. 16' of fill above bridge plug. (Sand). Rig down Pollard and secure well. 43B-08_AOGCC10-404Summary-AFE162571 , last revised 7/7/2004, page 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class:/ Development 0 Exploratory D Stratigraphic 0 Service D 6. API Number: 0 50-133-10121-02/ .. Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 185' 1. Type of Request: 8. Property Designation: Soldotna Creek Unit 11. Total Depth MD (ft): 10,826' Total Depth TVD (ft): 10,819' Length Casing Structural Conductor 30' 2,073' Surface Intermediate 9. Well Name and Number: SCU 43B-08 / 10. Field/poOIS(S):?,60",.,L p.:.~W Swanson River, He'h1locklTyonek PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10,745' 10,738' Size MD Suspend U Repair well 0 Pull Tubing 0 11-3/4" 9,450' 7" 1,673' 5" IperfOration Depth TVD (ft): 10,336 to 10,658 Baker "D" Packer Production Liner Perforation Depth MD (ft): 10,342 to 10,664' Packers and SSSV Type: 20" 12. Attachments; Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Date: 075 {,f/ / 1-- Perforate U Stimulate 0 Waiver U Annular Dispos. U Time Extension 0 Other 0 Plug Back and Recomplete 5. Permit tr Number: 90-0152-0 Junk (measured): TVD Burst Collapse 30' 2,073' 30' 2,073' 3,070 psi 1,510 psi 9,537' 10,735' ITUbing Grade: N-80, L-80 Packers and SSSV MD (ft): 9,540' 10,742' ITUbing Size: 2-3/8", 3-1/2" 6,340 psi 3,830 psi 10,140 psi 10,490 psi Tubing MD (ft): 8,914'; 10,327' 10,276' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 6/11/2004 Oil 0 Gas 0/ Plugged WAG 0 GINJ 0 WINJ 0 /' Service 0 0 0 Abandoned WDSPL 0 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Steve Tyler Title Acting Drilling Manager Signature ¿ ;/. /L-- Phone 907-263-7649 Date /' - COMMISSION USE ONLY Steve Tyler 907-263-7649 , 5/28/2004 Conditions of approval: Notify Commission so that a representative may witness SUndryNUmber: (:all .;;<05 Plug Integrity 0 BOP Test 0 Other: Subsequent Form Required; I 0 - 4-O 1 0 0 RECEIVED JUN 01 2004 Alaska Oil & Gas Cons. Commission Anchorage Mechanical Integrity Test Location Clearance «ØJIS Bfl !U" 0 ~ 1~~~ Approved by: Or¡ç)nzi Signee: Gj J~r;i, \~. NO¡¡¡i::n Form 10-403 Revised 12/2003 BY ORDER OF . I. j COMMISSIONER THE COMMISSION Date: (ÍJ / / jó ¿j INSTRUCTIONS ON REVERSE 0 RIG' N A L Submit in DuPlicatej¿: ~ - - Workover Summary 43B-O8 . MIRV slickline unit. Gauge 3-112'~ wi 2.85" GR. Gauge 2-3/8" tbg wi 1.85" GR. Tag obstruction @ 10,286'. -7f: . RIH wi bailer(s). remove obstruction @ 10,286'. RI tag f/ fill. . CO GL V's to Dummy valves. . MIT tbg string. ~ /' . RIH wi 3-112" brush to XO. RI wi 2-3/8" brush to EOT. RD slickline. . MIRV Eline. RIH set CIBP @ 10,270'. Dump bail 1 0' of sand on BP. Pressure test tbg. . Rill punch tbg wi 6' x 1.56" gun @ 10,240'. Fill wellbore. Establish circulation. . Rill set Fas Drill cmt retainer @ 8,900'. RD Eline. . MIRV CT. RIH wi stinger and stab into retainer @ 8900'. Establish circulation pressure anær . Mix/pum 3 bls of cement down CT while taking return out tbg x csg annuli. f1 L ; Over disp e CT wi lease water by 5 bbls. PU above retainer. CBV. jU-t vv-- v- (This will place TOC in annuli @ 5000' wi no emt in 2-318" tbg below retainer) w~/r'~' . Jet tbg dry wi N2. POOH. RD CT. . RV Slickline. RIH wi memory temp survey tool to confirm TOC. RD. /' . WOC for 72 ills. . RU Eline. Rill perforate TYOneGand @ 5832' to 5842'. RD Eline /' . Turn well over to testing. ( ,..¡ '" " 0 0 '" ð s ;¡ ,..¡ '" " ~ @ U 0 .... I 0 0 '" J; ¡¡¡O V.... 6 TD= 10,826' PBTD= 10,745' Max Deviation = 5.3° @10,322' Size Type b.. 20" Conductor II-%" SurfCsg :. 7" 7" 7" 7" 7" 7" 7" Window. Cut on 7/81 I Liner w/LTP Prod Csg 5" Tubing 3-W', EUE 8rd 2 %", 8rd & BTC I 4/61 3/62 5/74 2/86 10/89 4 1/91 9/02 Ob,truction @ 10,286' 2003 12/03 FISH #1 FISH #2 43B-8 Final Recompletion - 820021 CasinQ & Tu b n 9 Wt ID Top Btm Surf 30' 47 J-55 II" 2,073' 29 6.184" Surf 302' 26 6.276" 302' 881' 23 N-80 6.366" 881' 4549' 26 6.276" 4549' 6389' 29 6.184" 6389' 8203' 29 P-IIO 6.184" 8203' 9380' 9,380' 9450' I 18 N-80 I 4.276" 9,069' 10,742' I 9.3 N-80/L-80 I 2.992 I Surf I 8914' 4.6 N-80 1.995 8914' 10,327' JEWELRY DETAIL Depth m OD Item 18' Tubing Hanger 2,371' 2.867 5.968 GLM, 3-1/2" 4,046' 2.867 5.968 GLM,3-1/2" 5,601' 2.867 5.968 GLM,3-1/2" 6,807' 2.867 5.968 GLM,3-1/2" 7,795' 2.867 5.968 GLM,3-1/2" 8,717' 2.867 5.968 GLM,3-1/2" 8,914 1.901 3.50 Crossover, 2-3/8" EUE 8rd x 3-1/2" EUE 8rd 9,520' 1.901 4.00 GLM, 2-3/8" 10,229' 1.901 4.00 GLM, 2-3/8" 10,242' 1.870 2.50 Baker "X" Nipple 10,275' 1.968 3.00 E22 Anchor and Seal Assembly 10,276' 2.688 Baker "D" Packer 5" x 2-3/8" wi MOE & XO 10,316' 1.870 Otis "X" Profile Nipple 10,327' 2.00 Baker Shear-out Sub wi WLEG )'/0. 1. 2, 3. 4. 5. 6. Date Zone Mar,O! Hl Mar,oo H3 Dev99 H3 Dec-99 H4,5 Jul-94 H6 Dec"99 H7 Jo1-94 H8 Dec-99 H8 Dec-93 H8 Apr-91 H9 Apr-91 HIO Feb-91 HIO Dec-93 HIO Apr-91 HlO Total Interval: Swanson River Well SeD 43B-8 As Completed on 9/18/02 Hole Cmt Cmt Top Yes Surf. 16" 1300 sx 177' Calculated 9-18" 7935' CBL Brief History Originally drilled & completed as a Hemlock producer. WO to isolate shallow gas "D" sands. (5) cement squeezes w/l, 175 sX RD f01llJd 7" breached @6002', 5772',5670',5550'. (4) cmt sqzs wi 550 sx. PT to 2500 psi. WO found 7" csg breach 5670' to 6007'. Sqzd w/27 sx of emt. Found 5" liner bad £110523' to 10530'. A several inch long piece of csg was recovered in mill. WO f01llJd 5" liner collapsed @ 10,695'. Found slight leak @ liner lap. Found 7" csg breach £I 5592' to 6200'. (2) Sqz's wi 350 sx (5 bbls sqzd). PT csg t! 2500 psi. wi slight leak (lost 75 psi in Ilmin.). GP. RD PT 7" t! 2000 psi. completed wi 5" liner as a Hemlock H-I 0 producer. PT csg anm¡li & liner top pkr t! 2500 psi. Added H8 & H9 in 4/91 WO Tbg Change out. No pressure after WOo Slickline work. Unable to get deeper than 10,258;..T¡tgged hard wi 1.3" tapered swedge. Had to work through multiple asphaltine indnc~d restrictions. / Slickline 2.85" GR to 6000'. Ran bombs to 1~,268'/All GLM's had GLV's II' Strip Gun. '>/ 1.25" LIB. PERFORATION HISTORY (DIL Depths) Interval I Accum. Top Btm Amt spf Comments 10,342' 10,352' 10' 6 10,374' 10,408' 34' 6 10,420' 10,424' 4' 4 10,447' w,480' 33' 4 10,498' 10,520' 22' 10,500' 10,520' 20' 10,522' 10,540' 18' 10,524' 10,560' 36' 10,540' 10,5!i0' 20' W,572' 10,591' 19' 10,651' 10,664' 13' 10,613' 10,642' 29' 10,613' 10,651' 38' 10,651' 10,664' 13' 322' Total Open: 309 2200 Sx 6" 10,410' CBL 72.5 bbls 4 4 4 4 4 6 4 4 reperf Add Add Initial completion reperf Add REVISED: 4/15/04 by SL T Swanson River Well SCU 43B-8 As Completed on91l8/0Z Proppsed Completipn sin 9 Tu b i n 9 Wt Grade ID Btm Surf 30' 47 J-55 II" Surf 2,073' 29 6.184" Surf 302' 26 6.276" 302' 881' 23 N-80 6.366" 881' 4549' 26 6.276" 4549' 6389' 29 6.184" 6389' 8203' 29 P-IIO 6.184" 8203' 9380' 9,380' 9450' I 18 N-80 I 4.276" 9,069' 10,742' I 9.3 N-80/L-80 I 2.992 I Surf I 8914' 4.6 N-80 1.995 8914' 10,327' RKB = 185' Size Tr~e 20" Conductor 11-%" SurfCsg 7" 7" 7" Prod Csg 7" 7" 7" 7" Window. Cut on 7/81 Liner wlLTP Hole Cmt Cmt Top Yes Surf. 16" 1300 sx 177' Calculated 9-18" 2200 Sx 7935' CBL II b.. :. 10,410' CBL 6" 72.5 bbls Tubing 3-W', EUE 8rd 2 'Is", 8rd & BTC 59-2 Sand JEWELRY DETAIL m OD Item Tubing Hanger GLM,3-1/2" GLM, 3-1/2" GLM,3-1/2" GLM,3-1/2" GLM,3-1/2" GLM, 3-1/2" Crossover, 2-3/8" EUE 8rd x 3-1/2" EUE 8rd GLM, 2-3/8" GLM, 2-3/8" Baker "X" Nipple E22 Anchor and Seal Assembly Baker "D" Packer 5" x 2-3/8" wi MOE & XO Otis "X" Profile Nipple Baker Shear-out Sub wi WLEG Fas Drill Cemeut Retainer NO. Depth 18' 2,371' 4,046' 5,601' 6,807' 7,795' 8,717' 8,914 9,520' 10,229' 10,242' 10,275' 10,276' 10,316' 10,327' 8900' 2.867 2.867 2.867 2.867 2.867 2.867 1.901 1.901 1.901 1.870 1.968 2.688 1.870 2.00 5.968 5.968 5.968 5.968 5.968 5.968 3.50 4.00 4.00 2.50 3.00 1. 2. 3. 4. 5. 6. A. B. 10,270' Retrievable or Drillable Bridge Plug wi 10' of sand Ob,truction @ 10,286' P E RFORAT ION H IS T ORY ( D IL D ep th S) Interval Accum. Date Zone 'f()P Btm Amt spf Comments 59.2 5,832' 5,842' 10' 6 Proposed Tb; Punch 10,245' 10,251' 6' 4 Proposed Mar-Ol HI 10,342' 10,352' 10' 6 Temp Isolation Proposed Mar-oo H3 10,374' 10,408' 34' 6 T~mp Isolation Proposed Dec-99 H3 10,420' 10,424' 4' 4 Temp Isolation Proposed Dec.99 H4,5 10,447' ] 0,480' 33' 4 Temp Isolation Pr9Poscd Jul-94 H6 10,498' 10,520' 22' Temp Isolation Pr9posed Dec-99 H7 10,500' 10,520' 20' 4 Temp Isolation Proposed Jul-94 H8 10,522' 10,540' 18' Temp 1solation Proposed Dec-99 H8 10,524' 10,560' 36' 4 Temp Isolation Proposed Dec-93 H8 10,540' 10,560' 20' 4 Temp Isolation Proposed Apr-91 H9 10,572' 10,591' 19' 4 Temp Isolation Proposed Apr,91 HlO ]0,651' 10,664' ]3' 4 Temp Isolation Proposed Feb-91 H1O 10,613' 10,642' 29' 6 Temp Isolation Proposed Dec-93 H1O 10,pI3' 10,651' 38' 4 Temp Isolation Proposed Apr-91 HlO 10,651' 10,664' 13' 4 Temp Isolation Proposed 6 g ~ g ;;¡, ~C' ~o u¡.. ~ ~ TD= 10,826' PBTD= 10,745' Max Deviation = 5.30 @10,322' 43B-8 Proposed Schematic 4-041 REVISED: 4/15/04 by SL T STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: X Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: - 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X RZKB: 178',SL: 152' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, Alaska 99519-6247 Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 2150' FSL, 515' FEL, Sec. 8, TTN, R9W, SM SCU 43B-8 At top of productive interval 9. Permit numbedapproval number %', J 90-0152 At effective depth '~.~ 10. APl number 50-133-10121-02 At total depth 11. Field/Pool 2292' FSL, 455' FEL, Sec. 8, TTN, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10826' feet Plugs (measured) true vertical t 0820' feet Effective depth: measured 10745' feet Junk (measured) true vertical 10739' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 20" Drive 30' 30' Surface 2085' 11-3/4" 1300 sxs 2085' 2085' Intermediate 9300' 7" 2200 sxs 9300' 9378' Production Liner 1757' 5" 72.5 bbls 9069' - 10,742' 9067' - 10,734' Perforation depth: measured 10420-10424, 10447-10480, 10500-10520, 10524-10560, 10572-10591,10613-10642, 10651-10664 true vertical 1041 4-10418, 10443-10475, 10495-10515, 10519-10555, 10566-10585, 10602-10636, 10644-10646 Tubing (size, grade, and measured depth) 3-1/2". 9.3#/9.2#, N-80/L-80 tbg to 8914' 2-3/8" 4.6# N-80/L-80, 8914'- 10275' Packers and SSSV (type and measured depth) Baker Mod "D" @ 10276' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 0 0 Prior to well operation Subsequent to operation 62 1790 30 1050 320 15. Attachments: ...... .16. Status of well classification as: Copies of Logs and Surveys run:~ R E~eCi~. J V E JJ) Daily Report of Well Operations: X Oil: X Gas: Suspended: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: OCT 2 8 2002 Signed Title: d'~-~ ^~ 1", [ J:j ~ : (~'-'~ (. Dm a~/4~,,~.~... !'~!0\' 0 b 20{'12 Form 3160n5 (September 2001) ' UNF STATES DEPARTMEN'~ OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to re.enter an abandoned well. Use Form 3160-3 (APD) for such proposals. FORM APPROVED OMB No. 1004-0135 Expires: January 31, 2004 5. Lease Serial No. A-028996 6. If Indian, Allottee or Tribe Name 1. Type of Well [~ Oil Well [~ Gas Well ['-I Other 2. Name of Operator Union Oil Company of Califolmia (UBOCAL) 3a. Address P. O. Box 196247, Anchorage, AK 99519-6247 4. Location of Well (Footage, Sec., T, R., M., or Survey Description) 2150' FSL & 515' FEL, Sec. 8, T7N, R9W, SM 3b. Phone No. (include area code) (907) 276-7600 7. If Unit or CA/Agreement, Name and/or No. Soldotna Creek Unit 8. Well Name and No. SCU 43B-8 9. API Well No. 50-133-10121-02 10. Field and Pool, or Exploratory Area Swanson River/Tyonek 11. County or Parish, State Kenai Peninula Borough~ Alaska 12. CHECK APPROPRIATE BOX(ES) TO iNDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION I--I Notice of Intent [~ Subsequent Report [~ Final Abandonment Notice [~ Acidize [~1 Deepen [Z] Production(Start/Resume) [Z] Water Shut-Off [~] Alter Casing [~ Fracture Treat [~ Reclamation [~ Well Integrity [--I Casing Repair [~ New Construction [~ Recomplete [~ Other Recovered tbg fish [~ Change Plans [--1 Plug and Abandon [~ Temporarily Abandon & reran completion & Gas I-'Il Convert to Injection [~ Plug Back I~ Water Disposal Lift Mandre Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereof If the proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA. Required subsequent reports shall be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed once testing has been completed. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed, and the operator has determined that the site is ready for £mal inspection.) On September 14, 2002, a Pulling Unit was rigged up on well. Roated 2-3/8" tubing anchor out of the Production Packer at 10,276'. Pulled existing 3-1/2" x 2-3/8" tubing string and reran same with Gas Lift Mandrels. Released rig at 0600 September 18, 2002. 14. 1 hereby certify that the foregoing is true and correct Name (PrintedlTyped) Larry W. Buster Title Advising Drilling Engineer Signature Date Approved by (Signature) Conditions of approval, if any, are attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title.to those rights in the subject lease which would entitle the applicant to conduct operations thereon. Name I (Printed/TypedJ Title Office Date Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, make it a crime for an3, person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. (Continued on next page) SCU 43B-8 WD Workover Daily Summary Unocal Alaska Drilling Daily Summary Report SCU 43B-8 9/14/02 to 9/18/02 9/14/02 Accept Nabors Rig 126. Install BPV, N/D tree & NU BOPs.. 9/15/O2 BOPs tested to 3,000 psi high/250 psi Iow. RU to pull 3-1/2" tbg. Worked pipe to a max pull of 96k. Pipe free & wt dropped to 74k. Fluid at 3600'. POOH to 3241', standing back 3-1/2". Pipe pulled wet. Attempted to pump through tbg w/o success. POOH w/wet pipe. 9/16~O2 POOH to XO. Changed out handling equip, to 2-3/8". POOH w/wet pipe. Laying down 2-3/8" tbg. RIH w/Sand Line. Tagged tbg plug +/- 32 jts down in 2-3/8". Cont POOH to plug. Tbg dry below plug. Finished POOH tbg & anchor. LD remainder 2-3/8". Begin running in hole with new 2-3/8" tbg production assembly. PU GLMs. 9/17/02 Cont RIH w/2-3/8" tbg. Changed over to 3-1/2" handling tools. RIH w/3-1/2" tbg & GLMs. Circ from 10246' to 10276'. Tagged pkr. Spaced out tbg string w/pup its & landed same. Installed 3" BPV. RD. ND BOP & NU tree. 9/18/02 Completed NU tree. RD & released rig at 0600 9/18/02. Moving to Well SCU 21B- 16. UNOCAL SIZE 18" 11-3/4" 7" 5" (liner) Tubing 3-1/2" 2-3/8" Swanson River Well SCU 43B-8 Actual Completion CASING AND TUBING DETAIL GRADE CONN ID TOP 47 29 18 - Surface J-55 Surface N-80 BTC Surface N-80 BTC 9,069' 9.3#/9.2# 4.7# N-80/L-80 EUE 8rd Surface N-80/L-80 BTC/EUE 8rd 8,914' BTM. 30' 2,085' 9,300' 10,742' 8,914' 10,275' NO. Depth ID JEWELRY DETAIL OD item 1 18' - - 2 1,582' - 3 2,371' 4 4,046' 5 5,601' 2.992 3.500 6 6,807' 2.992 3.500 7 7,795' 2.867 5.968 8 8,717' 2.867 5.968 9 8,914 2.867 5.968 10 8,915' 2.992 3.500 11 9,519' 2.440 2.875 12 9,520' 2.347 4.500 13 9,527' 2.440 2.875 14 10,228' 2.440 2.875 15 10,229' 2.347 4.500 16 10,242' 2.347 4.500 17 10,275' 2.875 3.00 Tubing Hanger Crossover, 3-1/2" EUE 8rd x 3-1/2" BTC GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" Crossover, 2-3/8" EUE 8rd x 3-1/2" EUE 8rd Crossover, 2-3/8" BTC x 2-3/8" EUE 8rd Crossover, 2/3/8 EUE 8rd x 2-3/8" BTC GLM, 2-3/8" Crossover, 2-3/8" BTC x 2-3/8" EUE 8rd Crossover, 2/3/8" EUE 8rd x 2-3/8" BTC GLM, 2-3/8" Baker "X" Nipple E22 Anchor and Seal Assembly 17 NO. Depth Item Notes 43B-8 Final Recompletion Schematic.doc PERFORATION HISTORY (DIL Depth) Interval Accum. Date Zone Top I Btm Amt spf Comments Dec-99 [ H3 10,420' 10,424' 4' 4 Dec-99 [ H4,5 10,447' 10,480' 33' 4 Dec-99 H7 10,500' 10,520' 20' 4 Dec-99 H8 10,524' 10,560' 36' 4 Apr-91 H9 10,572' 10,591' 19' 4 Add Feb-91 H10 10,613' i 10,642' 29' 6 Initial completion Apr-91 H10 10,651'I 10,664' 13' 4 Add PBTD -- 10,7745' TD = 10,790' DRAWN BY: lwb REVISED: 8/20/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tul~ing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Unocal Corporation Development: X RKB: 178', SL: 152' feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 Stratigraphic: Soldotna Creek Unit ~ Service: 4. Location of well at surface v' .,(' ,./" 8. Well number 2150' FSL, 515' FEL, Sec. 8, T7N, R9W, SM SCU 43B-8 At top of productive interval 9. Permit num. b~rt 90-0152 v At effective depth 10. APl number 50- 133-10121-02 At total depth 11. Field/Pool 2292' FSL, 455' FEL, Sec. 8, T7N, R9W, SM Swanson River/Hemlock ~ 2. Present well condition summary Total depth: measured 10826 feet '/ ,.j, Plugs (measured) 9979' true vertical 1 O82O feet Effective depth: measured 10745 feet Junk (measured) true vertical 10739 feet ,~i~ ~i~: i'"" Casing Length Size Cemented Measured depth ,i. :-,True'vertical depth Structural Conductor 30' 20" Drive 30' 30' Surface 2085' 11-3/4" 1300 sxs 2085' 2085' Intermediate 9300' 7" 2200 sxs 9300' 9378' Production Liner 1757' 5" 72.5 bbls 9069' - 10,742' 9067' - 10,734' Perforation depth: measured 10420-10424, 10447-10480, 10500-10520, 10524-10560, 10572-10591, 10613-10642, 10651-10664 true vertical 10414-10418, 10443-10475, 10495-10515, 10519-10555, 10566-10585, 10602-10636, 10644-10646 Tubing (size, grade, and measured depth) 3-1/2". 9.3~ @ 8967', 2-3/8", 4.7#, N-80 from 8967' - 10327' Packers and SSSV (type and measured depth) Baker Mod "D" @ t0276' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 15-Sep-02 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver /~ / Date approved Service: 17. ' hereby c~orego~orrect to the best of my knowledge. Signed~_._~ I k~.~J,J~ Title: Drilling Engineer Date:Oo "~ FOR COMMISSION USE ONLY Conditions of approval: Not!~ Commission so representative may witness .'~ ~'C~.. %\ ~:~ ~ Approval No. Plug integrity '/,,. BOP Test X' Locat,on cle~;nce ,~,~.~.z , , Mechanical Integrity Test Subsequent form required 10- L(..(~~ .Approved by order of the Commissioner Cammy Oecflsli Taylor Commissioner Date ' Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE BOPE Variances Unocal Swanson River Unit August - September 2002 In order to operate Nabor's Well Service Rig 26 in Alaska, Unocal requires several variances to the requirements at 20 AAC 25.285. This approval is specific to the wells listed below. Due to the specific well type or work performed in advance, the chance to encounter hydrocarbons that can flow to surface is remote. Work on other well types using these specific waivers is not approved. SRU 32-33 WD WO SCU 13-34 WO SCU 33-33 WO SCU 24A-5 WO ~ SCU 43B-8 WO SCU 21 B-16 WO SRU 32A-15 WO - Replace Tubing/Packer - Replace Rod Pump - Repair Rod Pump - Install additional gas lift -Abandon Hemlock (?) Recomplete in Tyonek 4~- - Abandon Hemlock and recomplete in Tyonek - Replace corkscrewed tubing Unocal requested an exception to 20 AAC 25.066 to allow using a single LEL gas meter. Gas detection must comply with 25.066 for methane and H2S detectors (if necessary). This request is denied. Unocal proposed using high-pressure line(s) and hose with 1502 threaded connections which requires an exception to 20 AAC 25.285 (c) (9) and (e) (6). The waiver request is approved as provided by 20 AAC 25.285 (e) (6). With regard to the actual lines, hose (flexible, continuous) may be used. Steel pipe and traditional chicksan may not be employed. All of the valves Unocal plans to employ are manual. 20 AAC 25.285 (9) (C) requires that the outer choke valve must be a hydraulic valve. For the planned application with calculated pressures likely well below 2000 psi, this is acceptable and the waiver is approved as provided by 20 AAC 25.285 (h). The choke manifold does not have a bypass line per 20 AAC 25.285 (9) (D). The request for waiver should be approved as provided by 20 AAC 25.285 (h). Your approval of these recommendations is requested. I propose that a copy of this document with the appropriate well identified be attached to the workover Sundries as they are processed. A copy of this document is included as an attachment to the sundry approval for the respective well work. SCANNED OCT Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Larry W. Buster Advising Ddlling Engineer Wednesday, August 22, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: CommissionerCammy Taylor Re: Sundry Notice (Form 10-403) Swanson River Field Well SCU 43B-8 Commissioner Taylor: Enclosed for your review and approval is the Sundry Notice for upcoming work on the SCU 43B-8 Well. The well history and our plan forward is documented in the attached sheets. In summary, we plan to attempt to recover a fish in the existing 2-3/8" tubing string which is blocking Hemlock Oil Production. If we are unable to recover the fish on our first try, the remaining useful life in the existing Hemlock completion doesn't justify us undertaking an extended fishing operation. Therefore, if unsuccessful in recovering the existing tubing string/fish, we propose to abandon the existing Hemlock Completion and re-complete the 43B-8 Well as a Tyonek Gas Zone Completion. We are undertaking this work utilizing the recently mobilized Nabors Pulling Unit and expect this well work to begin approximately September 15, 2002. If there are any questions, please contact myself at 263-7804. LB/s Enclosure Advising Drilling Engineer Unocal Alaska $CANNEC OCT 0 ~ 2002 Proposed Workover Procedure Swanson River Field Well SCU 43B-8 August 2002 Well Background: 1. Well is currently completed as a Hemlock Zone producer (as per attached schematic) . In February 2002, the well loaded up and quit producing. Attempts were made to place a gas lift valve into the existing mandrel at 10,262'. However, it was determined by wireline that the tubing was corkscrewed and tools could not get to the lower mandrel. Therefore, the decision was made to punch a hole in the 2- 3/8" tubing as a gas lift injection port. Since the tubing/casing annulus was full of fluid and the tubing would not hold a column of fluid (underpressured producing formation) - a tubing plug was set to hold a column of fluid prior to punching the tubing. The tubing was successfully punched at 9954', but we were unsuccessful in retrieving the tubing plug at 9979'. The well has been off production since then. Workover Concept: . Our first intention is to try and initiate Hemlock Production by recovering the tubing string and removing the tubing plug. If we are successful in this, we would re-run an identical completion. Note: We are concerned with our ability to rotate the existing 2-3/8" tubing anchor out of the production packer. The economics of the project won't allow us to undertake a fishing operation to recover the tubing plug, therefore if we can't recover the tubing by rotating off the anchor, our intention would be to go directly into the abandonment program. . If we are unsuccessful in recovering the tubing string, we intend to abandon the existing completed interval and re-complete the well as a gas well in the Tyonek Gas Sands. Proposed Program: 1. MIRU Nabors Pulling Unit. 2. Pressure test casing to 2,000 psi 3. Install BPV and N/D Tree. 4. N/U and test BOPE to 3,000 psi. 5. M/U tubing hanger pull hanger off seat and attempt to rotate the 2-3/8" tubing anchor out of the Production Packer at 10,276'. Proposed Workover Procedure Swanson River Field Well SCU 43B-8 August 2002 Page 2 of 2 If successful in recovering the anchor: 6. Pull the tubing out of the hole. 7. M/U a GLM 3-1/2" x 2-7/8" completion string and run same. 8. Space out and snap tubing anchor back into the existing production packer. 9. N/D BOPE and NAJ Tree. 10. Test Tree to 3,000 psi. If unsuccessful in recovering the anchor: . . 8. 9. 10. Set production packer. 11. N/D BOPE and N/U Tree. 12. Test Tree to 3,000 psi. RIH with 2-3/8" tubing jet cutter to 9,300' and cut 2-3/8" tubing. Using the tubing as a work string, spot a 400' balanced cement plug from 9,300' across the liner lap to 8,900'. Pull above the top of cement and circulate clean. POOH and test casing and cement plug to 2,000 psi. RAJ and run 3-1/2" tubing c/w hydraulic set production packer to +/- 5580'. Arco ,alaska Inc.- Swanson River ,-leld ~- SCU 43B-8 APl#: 50-133-10121-02 Well Type: Producer Spud Date: 5/74 Completion Date: 2/21/91 Last Work0ver: · Original RKB: 18' Hanger Type: Shaffer Hanger: Shaffer top of Hemlook:lO,3S~'MD Max. Hole Angle: 1° Angle @Hemlook: Oo All Depths are RKB MD to Top of Equipment. 4 5 7 8 9 Jewelry I 2021' 2 8967' 3 10,262' 4 10,267 6 10,273" 6 10,276' 7 10,282' 6 10,282' 9 10,316' 10 10,327' GLM Canx~ MMG 3-1/2" x 1.1/2" RD Dummy w/BK Latch X-Over 3-1/2" x 2-,I/8' GLM 'TMPOX 23/8" x 1" w/Dunm~ BK.2 Latch Otl,~ Nim4e 2-3/a" Baker "DE" Packer 5" x 2-3/8" w/Andxa' 2.688 I.D. Mill out Extension w/ X-Over o~a -x- Nk3p~ Baker ,Shear out SubiWlreih~e. Re-entry ,2.00 I.D. / ./ ~Ca.lng and Tubing // .~,1 ~ ~rmdm ::~ ~ D.,crlotlan / ~ 2o" . o 30' ~or P~ ~ ~ 11-3/4" 47~ J-55 0 2085' ~d~ C~ 2~ 7" 29~ ~0 . 0 9300' Pm~n C~I~ ~ 5" 18~ ~0 9069' 10,742' Liner ~1~" 9.~ Mk~ 0 896~ Tubi~ 2 ~" 4.7~ ~ 896~ 10,32~ Tub~ Perforation Daltm 10,6'13'-10,642 H10 29' 6 2/21191 Initial Completion $CANNEP gOT p z.~ 2002 PBTD . 10,745' TO . 10,790' Well SCU 43B-8 __ JLB 2/25/91 'UNOCAL ) 43B-8 Abandonment Schematic.doc II SIZE Swanson River Well SCU 43B-8 Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN ID 18" - 11-3/4" 47 J-55 7" 29 N-80 BTC 5" (liner) ! 8 N-80 BTC TOP BTM. Tubing 2-3/8" 4.7 N-80 EUE 8rd Mod. Surface Surface Surface 9,069' 30' 2,085' 9,300' 10,742' 10,327' NO~. 1 Depth 9979' 10262' 10267' 10273' 10276' 9,650' 9,651' ID 2.0 JEWELRY DETAIL OD Item FISH - Tubing Slip Stop and W Circulating Plug (blanked) with !.75" Lead from LIB on top. - TMPOX 2-3/8" x 1" GLM w/dummy. Otis 2-3/8 .... X" Nipple Baker mod E-22 Locator Seal Assy. Baker Mod. D Packer c/w anchor & Mill Out Ext. Otis 2-3/8 .... X" Nipple Baker Shear out Sub w/WLRG NO. Depth I +/- 9300' II +/- 8900' Item Notes 2-3/8" Tubing Cut Cement Plug in 5" casing, across liner top and into 7" casing. PERFORATION HISTORY (D1L Depth) Interval Accum. Date Zone Top Btm Amt spf Comments Dee-99 H3 10,420' 10,424' 4' 4 Dec-99 H4,5 10,447' 10,480' 33' 4 Dec-99 H7 10,500' 10,520'. 20' 4 Dec-99 H8 10,524' 10,560' 36' 4 Apr-91 H9 10,572' 10,591' 19' 4 Add Feb-91 H 10 10,613' 10,642' 29' 6 initial completion Apr-91 H10 10,651' 10,664' 13' 4 Add PBTD = 10,7745' TD = 10,790' SCANNED OCT DRAWN BY: lwb REVISED: 8/20/02 'UNOCALe SIZE II Swanson River Well SCU 43B-8 Proposed Re-Completion CASING AND TUBING DETAIL GRADE CONN ID 18" - - l 1-3/4" 47 J-55 - 7" 29 N-80 BTC 5" (liner) 18 N-80 BTC TOP BTM. Tubing 3-1/2" 9.2 L-80 BTC-Imp Surface 30' Surface 2,085' Surface 9,300' 9,069' 10,742' Surface 5600' NO. Depth ID JEWELRY DETAIL OD Item I 2000' 2 5580' 3 5590' 4 5600' Chemical Injection Madrel BOT "SAB" 7" x 3-1/2" Production Packer w/Anchor BOT 3-1/2 .... X" Nipple BOT Shear out Sub w/WLRG NO. Depth Item Notes I +/- 9300' 2-3/8" Tubing Cm II +/- 8900' Cement Plug in 5" casing, across liner top and into 7" casing. PROPOSED PERFORATION ZONES Interval Aecum. Date Zone Top Btm Amt spf Comments 56-9 5,620' 5,628' 8' Proposed 56-9 5,634' 5,639' 5' Proposed 58-1 5,708' 5,760' 52' Proposed 59-2 5,812' 5,821' 9' Proposed PBTD-- 10,7745' TD = 10,790' 43B-8 Recompletion Schematic.doc DRAWN BY: lwb REVISED: 8/20/02 1502 TI-ID . 1502 THO · .. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager Wednesday, March 29, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 43B-8 APl No. 50-133-10121-02 10-404 Perforate H1 & 3 benches Dear Mr. Christensen: 15--"2_ Please find enclosed in duplicate Form 10-404 for the perforation of the H 1 & 3 benches in well SCU 43B-8, The following intervals were perforated on 3/16/00: Bench Top Bottom Feet H1 10,342 10,352 10 H3 10,374 10,408 34 Total: 44 10 2000 Alaska Oil & Gas C~ms. Comm~ion If you have any questions, please contact Ralph Holman at 263-7838. Sincerely, Dan Williamson Drilling Manager .--. STATE OF ALASKA ALASKA O,,_ AND GAS CONSERVATION ,_ .)MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X RKB: 168', GL: 152' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 2150' FSL, 515' FEL, Sec. 8, T7N, R9W, SM SCU 43B-8 At top of productive interval 9. Permit number/approval number 2278' FSL, 484' FEL, Sec. 8, T7N, R9W, SM 90-0152 At effective depth 10. APl number 2289' FSL, 459' FEL, Sec. 8, TTN, R9W, SM 50-133-10121-02 At total depth 11. Field/Pool 2292' FSL, 455' FEL, Sec. 8, TTN, R9W, SM Swanson River/hemlock 12. Present well condition summary Total depth: measured 10826 feet Plugs (measured) true vertical 10820 feet Effective depth: measured 10745 feet Junk (measured) true vertical 10739 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 34' 20" Driven 34' 34' Surface 2073' 11-3/4" 1300 sx 2073' 2073' Intermediate 9380' 7" 2200 sx 9380' 9378' Production Liner 1757' 5" 72.5 bbls. 9069'-10826' 9067'-10824' Perforation depth: measured 10342-10352, 10374-10408, 10420-10424, 10447-10480, 10498-10520, 10522-10554, 10572-10591, 10609-10642, 10651-10664 true vertical 10336-10346, 10368-10402, 10414-10418, 10441-10473, 10491-10513, 10515-10547, 10565-10584, 10602-10635, 10644-10657 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, @ 8967'; 2-3/8", 4.7#, N-80 from 8967'-10327' Packers and SSSV (type and measured depth) Baker "DB" @ 10276' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) ORIGINAL Treatment description including volumes used and final pressure AJlc~0ra~ 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 44 4090 13 0 740 Subsequent to operation 35 5920 22 0 650 - 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~)'~,"'~/~ ~)~~.~(/~~/-~~///~-~4 / Title: /~.~"///~..~ //~..~i~: Date: .~//~.~/,/.~ ¢.--....~". Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOEAL Dan Williamson Drilling Manager Tuesday, March 28, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 43B-8 APl No. 50-133-10121-02 10-404 Perforate H3, 4, 5, 7 & H8 benches Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H3, 4, 5, 7 & H8 benches in well SCU 43B-8. 'i The following intervals were perforated on 12/15/99: Bench Top Bottom Feet H3 10,420 10,424 4 H4, 5 10,447 10,480 33 H7 10,500 10,520 20 H8 10,524 10,540 16 Total: 73 ORIGINAL RECEIVED ap~ 10 2000 If you have any questions, please contact Ralph Holman at 263-7838.Al~0il&GasC~s.~m~n Anchorage Sincerely, Dan Williamson Drilling Manager STATE OF ALASKA -- ALASKA OIL AND GAS CONSERVATION t.;OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X RKB: 168', GL: 152' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 2150' FSL, 515' FEL, Sec. 8, T7N, R9W, SM SCU 43B-8 At top of productive interval 9. Permit number/approval number 2284' FSL, 483' FEL, Sec. 8, T7N, R9W, SM 90-0152 At effective depth 10. APl number 2289' FSL, 459' FEL, Sec. 8, T7N, R9W, SM 50-133-10121-02 At total depth 11. Field/Pool 2292' FSL, 455' FEL, Sec. 8, T7N, R9W, SM Swanson River/hemlock 12. Present well condition summary Total depth: measured 10826 feet Plugs (measured) true vertical 10820 feet Effective depth: measured 10745 feet Junk (measured) true vertical 10739 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 34' 20" Driven 34' 34' Surface 2073' 11-3/4" 1300 sx 2073' 2073' Intermediate 9380' 7" 2200 sx 9380' 9378' Production Liner 1757' 5" 72.5 bbls. 9069'-10826' 9067'-10824' Perforation depth: measured 10420-10424, 10447-10480, 10498-10520, 10522-10554, 10572-10591, 10609-10642, 10651-10664 true vertical 10414-10418, 10441-10473, 10491-10513, 10515-10547, 10565-10584, 10602-10635, 10644-10657 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, @ 8967'; 2-3/8", 4.7#, N-80 from 8967'-10327' Packers and SSSV (type and measured depth) Baker"DB"@ 10~' RECEIVED 13. Stimulation or cement squeeze summary ,~p~ 'JO 2000 Intervals treated (measured) ORIGINAL Atari 0il & Gas Cons. Commis~on Treatment description including volumes used and final pressure Arll~lOfal~ 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 34 524 7 0 225 Subsequent to operation 44 4090 13 0 740 --- 1'5. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: ~ Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to theb~s~ of my knowledge: Si g n ed :~~/4~"¢ ~_ ~(~¢_ ~ ~~~_~/////'/~~_/ Title: //~%//~/~'~' ~~/~. Date: ,/ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALASKA AL~' AOILAND GAS CONSERVATION )MMISSION REPOi £ OF SUNDRY WELL Or ERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing __ Alter casing__ __ Plugging m Perforate X_ Repair well m Pull tubing __ Other__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, R9W, SM At top of productive interval At effective depth At total depth 2292' FSL, 455' FEL, Sec. 8, T7N, R9W, SM 5. Type of Well: Development X_ Exploratory __ Strafigraphic __ 6. Datum elevation (DF or KB) RKB: 178', GL: 152' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 43B-8 feet 9. Permit number/approval number 90-0152 10. APl number 50-133-10121-02 11. Field/Pool Swanson River/Hemlock 12. Present well cOndition summary Total depth: measured true vertical 10826 10820 feet Plugs (measured) feet Effective depth: measured 10745 true vertical 10739 Casing Structural Conductor Surface Intermediate Production Liner Length 34' 2073' 9380' 1757' Perforation depth: measured feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20" Driven 34' 34' 11-3/4' 1300 sx 2073' 2073' 7' 2200 sx 9380' 9378' 5" 72.5 bbls. 9069'-10826' 9067'-10824' 10498-10520,10522-10554,10572-10591,10609-10642,10651-10664 true vertical 10491-10513, 10515-10547, 10565-10584, 10602-10635, 10644-10657 Tubing (size, grade, and measured depth) 3-1/2", 9.3# (iD 8967'; 2-3/8", 4.7#, N-80 from 8967'-10327' Packers and SSSV (type and measured depth) Baker "DB' @ 10276' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR 20 1995 Uit & Gas Cons. Commission Anch0ra! ~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 107 11658 7 0 206 13201 9 0 Tubing Pressure 2100 225O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_ Gas __ Suspended __ Service 7. I here~3~ certify that the foregoing is true and correct to the best of my knowledge. · '~ ! _ ; . . Form 10'-404 Rev 06/15/88 Date SUBMIT IN DUPLIOATE Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 November 15, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: On July 1, 1994 the following intervals were perforated in well SCU 43B-8 (API 50-133-10121-02) in the Swanson River Field: BENCH TOP (MD) BOTrOM (MD) H6 10,498 10,520 22 H8 10,522 10,540 18 TOTAL 40 FEET RECEIVED / PR 2 0 199,5 Alas~ (J~l & Gas Cons. Commission Anchora,~ - ~5 1A I I:: Ul- ALA;::)I',,A ALASK/~'~L AND GAS CONSERVATION CO~"--~ISSION APPLICA. ION FOR SUNDRY AF, ROYALS 1. TTpe of request: Abandon Suspend Operations shutdown Re-enter suspended well Alter casing__ Repair well Change approved program __ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, R9W, SM At top of productive Interval At effective depth At total depth 2292' FSL, 455' FEL, Sec. 8, 'i'7N, R9W, SM 12. Present well condition summary Total depth: measured true vertical 10826 10820 Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate X_ Other__ J5. Type of Well: Development X_ Exploratory __ Stratigraphic __ 6. Datum elevation (DF or KB) RKB: 178', GL 152' RECEIVED JUN -,~ 1994 Al~.ska Oil & Gas Cons. Commission Anch0ra~e feet 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 43B-8 9. Permit number 90 -0152 10. APl number 50-133-10121-02 11. Field/Pool feet Plugs (measured) feet Swanson River/Hemlock Effective depth: measured 10745 true vertical 10739 feet Junk (measured) feet Casing Length Structural Conductor 34' Surface 2073' Intermediate 9380' Production Liner 1757' Perforation depth: measured Size Cemented Measured depth True vertical depth 20' Driven 34' 34' 11-3/4" 1300 sx 2073' 2073' 7" 2200 sx 9380' 9378' 5" 72.5 bbls. 9069'- 10826' 10541-10554, 10572-10591,10609-10642, 10651-10664 9067'-10824' true vertlcal 10536-10549, 10567-10586, 10604-10637, 10646-10659 Tubing (size, grade, and measured depth) 3-1/2', 9.3# @ 8967'; 2-3/8', 4.7#, N-80 from 8967' - 10327' Packers and SSSV (type and measured depth) Baker 'DB' @ 10276' 13. Attachments Description summary of proposal __ Detailed operations prograrn,~__ BOP sketch 14. Estimated date for commencing operation ~15. 12/15/93 16. If proposal was verbally approved Oil X_ Gas Name of approver Date approved Service 17' I her~' ~. i.~e f{~e/Tq)°~ and c°rrect t° the best °f mY kn°wledge' Sign e d ,,C~. [Cu,~ ,,/~_~..~ Title'"~ ~,.t, LLt j~ (~ '['~ ~ C~ FOR COMMISSION USE ONLY Status of well classifk:ation as: Suspended Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required 10- IApproval No. ..Approved by the order of the Commission Original Signed By David W. Johnston Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned Date ~//,~t/~' '7' SUBMIT IN TRIPLICATE ~U I,"03 lO Iq May i9, l!~!)d Swanson River WeU $CU 4313-8 Perforating Procedure Obtain a well test. ! = e Load tubin§ wi~ crude if ne, c~ssary. Hold r~'ety me, ting with appropriatc I~rsonnel. Pig up electric line unit. (A pumi~-in s~b is relluire~t on lubricator) Pre.ute test iubri~tar to 3500 pM for fivc minutu$. Shut down all welding and radio uansmissions. RIH and perforate intervals aa instructed by Unoc~ representative. (When gun is 200' below surfak, wading and radio uansmt~ons may r~ume.) POOH. (When gun is 200' below surfaco, shut down all welding and radio transmissions.) P. epeat steps 5,6 snd 7 ss needed to pert0rate the l~oilowing intcntats: _BENCH ............ MEASURED ._~_.,, TVD ............ FEET H6 104.9 8- i0~20 10493-10~ 15 22 H8 I0~22-i0540 10517-10533 18 TOTAL 40 . .~-. STATE OF ALASKA --- ' - ALASt-' ~>IL AND GAS CONSERVATION C' ~AISSION '~- APPLIC 'FION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Operations shutdown Re-enter suspended well Alter casmg__ Repaur well __ Pluggmng __ lime extension __ Stimulate __ Change approved program Pull tubing Variance Perforate X Other 2. Name of Operator m 15. T--~-pe of Well: M 6.-D-atum e'leva-~n (DF or Unocal I Development X_ RKB: 178', GL 152' · feet 3. Address J Stmagmphk= q 7. Unit or Property name P .O. Box 196247 Anchorage, Alaska 99519-6247 I service Soldotna Creek Unit Location of well at surface 2150' FSL, 515' FEL, Sec. 8, l'TN, R9W, SM At top of productive interval At effective depth At total depth 2292' FSL, 455' FEL, Sec. 8, T7N, R9W, SM 8. Well number SCU 43B-8 9. Permit number 90-0152 10. APl number 50-133-10121-02 11. Field/Pool Swan ~ n_RIv...e rJ, H I~ ~ I1;)~ 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 34' 2073' 9380' 1757' Perforation depth: measured 10826 10820 10745 1O739 feet feet feet feet Plugs (measured) Junk (measured) Size Cemented N I:LI- IV bL) DEC -9 199) Aiaska 0il & Gas Cons. Commission Anchorage Measured depth True vertical depth 20' Driven 11-3/4' 1300 sx 7' 2200 sx 34' 34' 2073' 2073' 9380' 9378' 5' 72.5 bbls. 9069'- 10826' 10572-10591, 10613-10642, 10651-10664 9067'-10824' true vertical 10567-10586, 10608-10637, 10646-10659 Tubing (size, grade, and measured depth) 3-1/2', 9.3# @ 8967'; 2-3/8', 4.7#, N-80 from 8967' - 10327' Packers and SSSV (type and measured depth) Baker 'DB" @ 10276' 13. Attachments Description summary of proposal m Detailed operations programX__ BOP sketch 14. Estimated date for commencing operation )15. 12/15/93 16. If proposal was verbally approved Oil X_ Gas Name of approver Date approved Service 17. I h~y ~ t~/~r/e~o~~nd correct to~he best of my knowledge. Signed Z'~ ~.--4/¢¢~05/..,v%~ T'rtle t~L~J~i,L/,.,t~--x ~k~(~CAC~g-.- FOR COMMISSION USE ONLY Status of well classification as: Suspended Date Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test Location clearance Mechanical Integrity Test~ Subsequent form required 10- Approved by the order of the Commission Original Signed By David W. Johnston Form 10-403 Rev 06/15/88 I Appro_val N~O~ ..,Jp~oved Copy. Returned Commissioner -Date / SUBMIT IN TRIPUCATE December 8, 1993 Swanson River Well SCU 43B-8 Perforating Procedure 1. Obtain a well test. 2. Load robing with crude if necessary. 3. Hold safety meeting with appropriate personnel. 4. Rig up electric line unit. (A pump-in sub is required on lubricator) 5. Pressure test lubricator to 3500 psi for five minutes. 6. Shut down all welding and radio transmissions. . RIH and perforate intervals as instructed by Unocal representative. (When gun is 200' below surface, welding and radio transmissions may resume.) , POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 9. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TVD FEET H10 10613-10651 10608-10646 38 TOTAL 38 D£C -9 ~9~ Alaska Oil & (]as Cons. Commission Anchora[le STATE OF ALASKA "'J :~ '" '''~ ~ j'~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR RI=COMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well *OIL E~] GAS [~] SUSPENDED F'~ ABANDONED [--] SERVICE E~ · SIDETRACK 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-152 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-133-10121-02 4 Location of well at sudace 2150' FSL, 515' FEL, SEC 8, T7N, Rgw, SM At Top Pr~ucing Inte~al 2310' FSL, 421' FEL, SEC 8, ~N, R9W, SM 231 ~ FSk, 417' F~k, SEC 8, ~, ~OW, SM ~' ....... '~ 5 Elevation in feet (indicate KB, DF, etc.) RKB 178', 152' GL 12 Date Spudded 02/02/91. 17 Total Depth (MD+TVD) 0,826' MD, 10,820' TVD 6 Lease Designation and Serial No. A-028996 22 Type Electric or Other Logs Run 13 Date T.D. Reached 02/1 6/91. 18 Plug Back Depth (MD+TVD) 10,742'MD, 10,736' TVD DateComp., Susp. or Aband. I 02/22/91. Directional Survey 20 9 Unit or Lease Name SWANSON RIVER UNIT 10 Well Number 1 Field and Poo~ ~/'~' SWANSON RIVER FIELD HEMLOCK OIL POOL 15 WaterNADepth, if offshore feet MSL 16 No. Completions Depth where SSSV sel 21 Thickness of permafrost NA feet MD NA DI L/BHC-AL/C DL/CNL/G R/S P/CAL/PKD IO0/CBL/GYRO /,/--6 I CASING SIZE WT. PER FT. I GRADEI TOP * 20" I I SURF * 11-3/4" 47# SURF * 7" 23#, 26#, 29# SURF Note: 7' Plugged back to 9451' and sidetracked as 43B-8 5"(liner) I 9069' 24 Perforations open to Production (MD+TVD of Top and B(2tom and interval, size and number) 10613'-10642' MD 3-3/8" @ 6 SPF 10607'-10636' TVD CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I BO'FrOM HOLE SIZE I CEMENTING RECORD AMOUNT PULLED 42' 2,081' 10,886' 1O826' *Previous csg corrected to new RKB of 178' 16" I 1300 SX 9-7/8" I 2200 SX 345 sx 25 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2"x 2-3/8" 10237' 10276' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 Date First Production Date of Test Hours Tested Flow Tubing Press. Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift. etc.) IPRODUCTION FOR TEST PERIOD .. CALCULATED 24-HOUR RATE ,~- OIL-BBL GAS-MCF WATER-BBL OIL-BBL GAS-MCF 28 CORE DATA WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONT~NUEDONREVERSE~DE JU!".I 1 ? Aiask~ 0il & Gas Cons. 6,orr~i,$¢0r~ Submit in duplicate 29. 130. ~A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH FORMATION TESTS Include interval tested, pressure data, all fluids recoverd and gravity, GOR, and time of each phase. IN/A 31. LISTOF A-FTACHMENTS REPORT OF DALLY OPERATIONS, GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this welt should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain, ARCO ALASKA INC. DAILY OPERATIONS WELL: SCU 43B-8 PAGE i BOROUGH: FIELD: UNIT: LEASE: API: WELL: PERMIT: KENAI SWANSON RIVER FIELD SOLDOTNA CREEK UNIT A-028996 50-133-10121-02 SCU 43B-8 APPROVAL: 90-152 AFE: AD7150 WI: 48.4864 RECEIVED Aias~a Oii & "'" uao Cons, CornraissiOn Anchorage ACCEPT: 01/25/91 SPUD: 02/02/91 RELEASE: 02/22/91 OPERATION: SIDETRACK RIG: GRACE 154 01/25/91 ( 1) TD: 0'( SUPV:EB 01/26/91 ( 2) TD: 0'( SUPV:EB 01/27/91 ( 3) TD: 0' ( SUPV: EB 01/28/91 (4) TD: 0'( SUPV:EB 01/29/91 (5) TD: 0'( SUPV:EB 0) 0) 0) 0) 0) TEST BOPE MW: 0.0 VIS: 0 RIG UP GRACE 154,ACCEPT RIG @ 18:00, CHECK CSG PRESS(0PSI) ND TREE AND NU ADAPTER FLANGE AND BOPE, TESTING BOPE DAILY:S155,063 CUM:$155,063 ETD:S155,063 EFC:$1,390,000 RD CSG TOOLS MW: 9.6 VIS: 0 TEST HYDRILL & BOPE, BOLDS, PULL BAKER 15' S-22 LOCATOR SEAL ASSY F/PKR W 93K ANNULUS FULL, LD LANDING JT, HANGER & PUP JT, CBU @ 10130', GAS BUBBLE TO SURFACE, CLOSE RAMS & CIRC TO 9.6 PPG, MONITOR WELL-STATIC, POOH, LD COMP STRING & JEWELRY. DAILY:S21,589 CUM:$176,652 ETD:S176,652 EFC:$1,390,000 PU CSG SCRAPERS MW: 9.6 VIS: 0 RD GBR TBG TOOLS & CLEAR FLOOR, SET TEST PLUG & TEST UPPER & LOWER KELLY COCKS FLOOR SAFETY VALVE & INSIDE BOP TO 250/4500 PSI, RIH W/BAKER PKR RETRIEVING TOOL TO 10,100' AND WASH TO PKR @ 10,151', SHEAR RELEASE ON PKR, CONT TO PU SHEAR RELEASE ON SAFETY JOINT W/24K, ATTEMP TO CIRC, RELEASE TOOL, CBU, SMALL GAS BUBBLE TO SURFACE, CIRC TO 9.6 PPG, RE-ENGAGE TOOL, ATTEMPT TO CIRC, POOH SLOW TO 7" CSG, CBU-NORMAL, POOH, LD PKR & TAIL PIPE W/SAFETY JOINT, SET WEAR RING & MU 5" CSG SCRAPER. DAILY:S32,246 CUM:$208,898 ETD:S208,898 EFC:$1,390,000 PREPARE TO SPOT BALANCED PLUG MW: 9.6 VIS: 0 FIN SETTING WEAR PLUG, PU & TIH W/5" & 7" TANDEM CSG SCRAPERS TO TBG STUMP @ 10,178' DPM W/7" SCP @ 9600', CBU-NORMAL, POOH LD 18 JTS 2-7/8" DP, RU AWLS & RUN VERTILOG IN 7" F/9500' TO SURF, REPEAT F/6100' TO 5000', RD ATLAS, MU HOWCO 5" CMT RETAINER & RIH TO 9997', SET RETAINER & PRESS TEST BACKSIDE TO 2000 PSI, RU HOWCO & TEST LINES TO 5000 PSI, ATTEMPT TO ESTABLISH RATE, PUMP 1.25 BBL, PRESS @ 4100 PSI, CIRC. DAILY:S36,146 CUM:$245,044 ETD:S245,044 EFC:$1,390,000 TIH MW:10.0 VIS:100 CIRC & BATCH MIX CMT, PUMP 10 BBLS H20 & 75 SX G CMT BLENDED W/.l% HR-5 & .3% CFR-3 MIXED @ 15.8 PPG, DISPLACE & BALANCE PLUG W/2.6 BBLS H20 & 62.5 BBLS NACL, 9.6# BRINE HOLDING 500 PSI BACKPRESSURE ON CHOKE. POOH SLOW 9400', REV OUT DRILL STRING, CHAIN OUT OF HOLE, LD 15 JTS DP & ST BACK 2-7/8" TBG PU 15 4-3/4" DC & TIH, PREPARE 10.0 PPG HI-VIS MUD, TAG UP ON FIRM CMT @ 9470', DISPLACE HOLE W/50 BBLS H20 & HI VIS WINDOW MUD, POOH, PU 7" MILL & TIH. DAILY:S50,483 CUM:$295,527 ETD:S295,527 EFC:$1,390,000 ARCO ALASKA INC. WELL: SCU 43B-8 OPERATION: SIDETRACK RIG: GRACE 154 01/30/91 ( 6) TD: 0'( SUPV:EB 0) 01/31/91 ( 7) TD: 0'( SUPV:EB o) 02/01/91 ( 8) TD: 0'( SUPV:EB o) 02/02/91 (9) TD: 9385' (9385) SUPV:EB 02/03/91 (10) TD: 9436' ( 51) SUPV:EB 02/04/91 (11) TD: 9530' ( 94) SUPV:EB 02/05/91 (12) TD: 9642' ( 112) SUPV:EB 02/06/91 (13) .TD: 9790' ( 148) SUPV:EB 02/07/91 (14) TD: 9853' ( 63) SUPV:WH 02/08/91 (15) TD: 9899' ( 46) SUPV:WH DAILY OPERATIONS R C IV D PAGE: 2 Aiask~ 0il & 6~s Cons. oomrCSS~On Anchorage CUT DRLG LINE MW:10.0 VIS:120 TIH W/MILL, TAG CMT @ 9470', POOH 90', MILL 7" CSG F/9380'-9450' & PUMP 300 VIS SWEEP, CBU, MONITOR HOLE, STABLE, POOH, INSPECT MILL, NORMAL HOLE FILL W WEAR PATTERN ON CUTTER ARMS INCONCLUSIVE, INTEGRITY OF COMPLETE CUT QUESTION- ABLE, CHANGE OUT MILL, TIH TO VERIFY POSITIVE 70' WINDOW, SLIP & CUT DRLG LINE DAILY:S27,870 CUM:$323,397 ETD:S323,397 EFC:$1,390,000 WOC MW:10.4 VIS: 52 REAMED F/ 9380 T/ 9450,CBU, POH, TIH W/ BIT AND WORK INTO STUMP,POH, TIH W/ TBG STINGER TO 9465,RIG UP HOWCO AND BATCH MIX CEMENT,PUMPED 75 SX CMT AND SET BALANCED PLUG, POH 4 STDS AND REVERSE OUT, SHUT IN WELL WITH 2000 PSI, HOLDING PRESS ON WELL AND WOC DAILY:S47,800 CUM:$371,197 ETD:S371,197 EFC:$1,390,000 RIH MW:10.4 VIS: 47 WOC, POH,WORK ON BOPE, TEST BOPE,RIH, STOP AND CIRC AT 4000' DAILY: $24,818 CUM: $396,015 ETD: $396,015 EFC: $1, 390, 000 GYRO AND ORIENT MW:10.0 VIS: 46 RIH, TAG CMT @ 9183,DRILL HARD CMT F/9183 T/9385,CIRC, POH LD BHA, PU STEERABLE SYSTEM, RIH, S&C DRLG LINE, RIH, RUN GYRO AND ORIENT 'DAILY:S28,079 CUM:$424,094 ETD:S424,094 EFC:$1,390,000 TIH MW:10.0 VIS: 53 ORIENT TOOL FACE, SIDETRACK OFF OF CMT PLUG, DRILLED FROM 9385 T/9436,MWD SURVEY AND POH,BHA CHANGE,RIH DAILY:S48,114 CUM:$472,208 ETD:S472,208 EFC:$1,390,000 RUN GYRO MW:10.0 VIS: 45 RIH, ORIENT TOOL AND WASH F/9388 T/9436,DRLD W/ STEERABLE TO 9460,TEST FORMATION TO 14.2PPG, (OK),CONT. DRLG TO 9464,REAM KICK OFF SECTION, CONT DRLG T/9530,RUN GYRO DAILY:S33,454 CUM:$505,662 ETD:S505,662 EFC:$1,390,000 DRLG MW:10.0 VIS: 45 DRILL F/9530 T/9591,RUN GYRO, SHORT TRIP,DRILL F/9591 T/9626 REPAIR MUD LINE, DRILL F/9626 T/9642 DAILY:S33,320 CUM:$538,982 ETD:S538,982 EFC:$1,390,000 DRLG MW:10.0 VIS: 47 DRLD F/9642 T/9686,SHORT TRIP,DRLD F/9686 T/9790 DAILY: $40,641 CUM: $579,623 ETD: $579,623 EFC: $1, 390, 000 DRLG MW:10.0 VIS: 46 DRLD T/ 9799,SHORT TRIP TO WINDOW, RIG SERV.,DRLD T/9831 SLIDE TO 9844,DRLD T/9853 DAILY:S32,722 CUM:$612,345 ETD:S612,345 EFC:$1,390,000 C O BATTERIES MW:10.0 VIS: 46 DRLD T/ 9876, SHORT TRIP,DRLD T/9899,POH, TEST BOPE,PU MUD MOTOR, CHANGE OUT BATTERY PACK DAILY:S28,390 CUM:$640,735 ETD:S640,735 EFC:$1,390,000 ARCO ALASKA INC. WELL: OPERATION: RIG: SCU 43B-8 SIDETRACK GRACE 154 02/09/91 (16) TD:10016' ( 117) SUPV:WH 02/10/91 (17) TD:10131' ( 115) SUPV:WH ,~iaska Oil & Gas Cons, Commission DRLG MW:10.1 VIS: FIN CO BATTERIES IN MWD,RIH,DRLD T/10016 46 DAILY:S28,888 CUM:$669,623 ETD:S669,623 EFC:$1,390,000 POOH MW:10.1 VIS: 48 SLIDE DRLG F/10023 T/10054,SHORT TRIP,DRLD T/10131,POH PAGE: DAILY:S30,193 CUM:$699,816 ETD:S699,816 EFC:$1,390,000 02/11/91 (18) TD:10225' ( 94) SUPV:WH DRLG MW:10.3 VIS: 46 FIN POH, LD MOTOR, BIT PLUGGED OFF W/ PIECE OF RUBBER FROM MUD MOTOR, CHECKED MWD CO BHA, RIH,WASH 28' TO BOTTOM, NO FILL,DRLD F/10131 T/10225 DAILY:S37,000 CUM:$736,816 ETD:S736,816 EFC:$1,390,000 02/12/91 (19) TD:10373' ( 148) SUPV:WH DRLG MW:10.4 VIS: 48 DRLD T/10272,SHORT TRIP AND SERVICE RIG,DRLD T/10373 DAILY:S31,195 CUM:$768,011 ETD:S768,011 EFC:$1,390,000 02/13/91 (20) TD:10500' ( 127) SUPV:WH DRLG MW:10.4 VIS: 47 DRLD T/10383,DROP SURVEY, POH, LD BHA, C&S DRLG LINE,RIH,WASHED 19' TO BOTTOM NO FILL, DRLD T/10500 DAILY:S33,922 CUM:$801,933 ETD:S801,933 EFC:$1,390,000 02/14/91 (21) TD:10592' ( 92) SUPV:WH DRLG MW:10.4 VIS: 48 DRLD F/10500 T/10510,BIT TRIP,DRLG F/10510 T/10592 DAILY:S27,280 CUM:$829,213 ETD:S829,213 EFC:$1,390,000 02/15/91 (22) TD:10686' ( 94) SUPV:WH DRLG MW:10.4 VIS: 50 DRLG T/10615,DROP SURVEY POH, TEST BOPE, RIH,DRLD T/10686. DAILY: $29,984 CUM: $859,197 ETD: $859,197 EFC: $1, 390, 000 02/16/91 (23) TD: 10766' ( 80) SUPV: WH 02/17/91 (24) TD:10826' ( 60) SUPV:WH DRLG MW:10.4 VIS: 48 DRLD T/10736, SHORT TRIP,DRLD T/10766. DAILY: $23,835 CUM: $883,032 ETD: $883,032 EFC: $1, 390, 000 LOGGING OPEN HOLE MW:10.5 VIS: 47 DRLD T/10826,CIRC HOLE CLEAN, DROP SURVEY AND POH, LOG OPEN HOLE DAILY:S22,044 CUM:$905,076 ETD:S905,076 EFC:$1,390,000 02/18/91 (25) TD:10826' ( SUPV:WH 02/19/91 TD:10826 PB:10742 SUPV:WH (26) o) CBU 5"@10826' MW:10.5 VIS: 46 LOGGING, BIT RUN TO 10826,S&C DRLG LINE,POH,RIG UP AND RUN 5"18# LINER, BREAK CIRC, RIG UP TO CEMENT. DAILY:S42,989 CUM:$948,065 ETD:S948,065 EFC:$1,390,000 CIRCULATING 5"@10826' MW:10.5 WBM CIRC AND COND FOR CMT JOB,CMTD LINER W/72.5 BBLS OF CLASS G CMT,BUMPED PLUG, SET HANGER AND LINER TOP PACKER, REVERSE CIRC, POH,PU 6"BIT AND SCRAPER AND RIH TO LINER TOP,CBU, POH PU 3"DC'$ AND RIH AND TAGGED CMT @ 10723,DRLD CMT T/10742 TEST LINER TO 1900PSI,OK, CIRC AND FILTER BRINE DAILY:S66,475 CUM:$1,014,540 ETD:S1,014,540 EFC:$1,390,000 ARCO ALASKA INC. DAILY OPERATIONS WELL: SCU 43B-8 OPERATION: SIDETRACK RIG: GRACE 154 PAGE: 4 02/20/91 (27) TD:10826 PB:10742 SUPV:WH 02/21/91 (28) TD:10826 PB:10742 SUPV:EB 02/22/91 (29) TD:10826 PB:10742 SUPV:EB 02/23/91 (30) TD:10826 PB:10742 SUPV:EB RUNNING CASED HOLE LOGS 5"@10826' MW: 9.5 NaC1 CLEAN PITS AND FILTER BRINE,DISPLACE WELL WITH BRINE,FILTER BRINE,POH LD DC AND SCRAPER, RU AWS AND RUN PRODUCTION LOGS. DAILY: $25,630 CUM:$1,040,170 ETD:S1,040,170 EFC:$1,390,000 WO GLM 5"@10826' MW: 9.5 NaCl FINISH RUNNING SBT,RUN GYRO, RUN GUAGE RING, PERF 10613 TO 10642,WELL STABLE MU BAKER MOD D PERM PACKER AND 2 3/8 TAIL ASSY AND RIH AND SET ON WIRELINE SET PACKER @ 10246 AND TAIL @10300,RD WIRELINE, RU TO RUN COMPLETION STRING, TRIED TO RABBIT GLM, WOULD NOT GO, WAIT ON PROPER GLM. DAILY:S84,669 CUM:$1,124,839 ETD:S124,839 EFC:$2,390,000 NU TREE 5"@10826' MW: 9.5 NaC1 WO GLM, RUN TBG COMPLETION, SPACE OUT AND LAND TBG, PRESS TEST TUBING, BO LANDING JT, INSTALL BPV, ND BOP,NU TREE DAILY:S32,631 CUM:$1,157,470 ETD:S1,157,470 EFC:$1,390,000 RIG RELEASED 5"@10826' MW: 9.5 NaC1 FINISH NU XMAS TREE, TEST SAME,CLEAN PITS,RELEASE RIG DAILY:S98,357 CUM:$1,255,827 ETD:S1,255,827 EFC:$1,390,000 SIGNATURE: DATE: t i GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY 43B-8 WELL NAME SWANSON RIVER UNIT LOCATION AL191D8 MWD 02/28/91 JOB NUMBER TOM DUNN TYPE SURVEY DIRECTIONAL SUPERVISOR DATE NAME TITLE SIGNATURE DEPTH INTERVAL 9350 FT. 10826 FT. FROM TO 01/31/91 02/16/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. RECEIVED Alaska Oii,~" Ga.,,~ Cons. Cornrn~,ssiOn Anchorage ~AT LAND DIRECTIONAL DRILLING, ient .... : ARCO Ar~SKA, INC. eld ..... : SWANSON RIVER UNIT 11 ...... : SCU 43B-8 =tion a~: S,89.50,E gineer..: TOM DUNN INC. MEAS INCLN DEPTH ANGLE BKB 0 0.00 0.0 100 0.50 100.0 200 0.50 200.0 300 0.00 300.0 400 0.00 400.0 VERTICAL-DEPTHS SUB-SEA -180.0 -80.0 20.0 120.0 220.0 RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 0.0 S 0.00 W 0.1 S 32.00 E 0.6 S 30.00 E 0.7 S 0.00 W 0.7 S 0.00 W 500 0.50 500.0 320.0 0.4 600 0.25 600.0 420.0 0.3 700 0.25 700.0 520.0 0.1 800 0.25 800.0 620.0 -0.0 900 0.50 900.0 720.0 -0.2 1000 0.50 1000.0 820.0 .. ,1100 0.25 1100.0 920.0 ~ 0.25 1200.0 1020.0 1~' .O 0.00 1300.0 1120.0 1400 0.00 1400.0 1220.0 1500 0.25 1500.0 1600 0.25 1600.0 1700 1.25 1700.0 1800 2.75 1799.9 1900 2.00 1899.8 1320.0 1420.0 1520.0 1619.9 1719.8 1999.8 1819.8 1/SINGLE SHOT 2000 1.50 -0.3 -0.5 -0.8 -0.9 -0.9 -0.9 -1.2 -1.5 -2.6 -4.2 -5.2 03/01/91 Computation...: RADIUS OF CURVATURE Survey Date...: 02/16/91 RKB Elevation.: 180.00 ft Reference - ..ee.~ Magnetic Dcln.: 24.00 E r~ey~Codes: U43BSD) RELATIVE-COORDINATES FROM-WELL-HEAD 0.0 N 0.0 E 0.4 S 0.1 E 1.2 S 0.6 E 1.6 S 0.7 E 1.6 S 0.7 E CLOSURE DL DISTNCE BEARING /100 0.0 N 90.00 E 0.00 0.4 S 16.00 E 0.50 1.3 S 26.06 E 0.00 1.7 S 23.30 E 0.50 1.7 S 23.30 E 0.O0 N 10.00 W 1.6 S 0.4 E N 14.00 W 1.0 S 0.3 E N 20.00 W 0.5 S 0.1 E N 22.00 W 0.1 S 0.0 W N 11.00 W 0.5 N 0.2 W 1.7 S 13.59 E 0.50 1.0 S 14.64 E 0.25 0.6 S 12.81 E 0.O0 0.1 S 12.91 W 0.00 0.5 N 24.08 W 0.25 N 4.O0 W N 30.O0 W N 53.00 W N 0.00 E N 0.00 E 1.4 N 0.3 W 2.O N O.5 W 2.3 N 0.8 W 2.5 N 0.9 W 2.5 N 0.9 W 1.4 N 13.78 W 0.O0 2.0 N 14.80 W 0.25 2.4 N 19.39 W 0.O0 2.6 N 19.96 W 0.25 2.6 N 19.96 W 0.O0 N 8.00 W S 5.00 W S 15.00 W S 24.00 W S 22.00 W 2.7N 0.9W 2.7N 1.2W 1.4N 1.4W 1.9S 2.6W 5.7S 4.2W 2.9 N 18.75 W 0.25 3.0 N 24.27 W 0.O0 2.0 N 45.70 W 1.00 3.2 S 54.20 W 1.50 7.1 S 36.58 W 0.75 S 20.00 W 8.5S 5.3W 10.1 S 31.90 W 0.50 ~ 438-8 Page 2 03/01/91 RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS DEPTH ANGLE BKB SUB-SEA ~'00 1.00 2099.7 1919.7 t ~0 1.00 2199.7 2019.7 · ~-2300 0.50 2299.7 2119.7 2400 0.75 2399.7 2219.7 2500 0.75 2499.7 2319.7 SECTION DISTNCE -6.1 -6.9 -7.7 -8.5 -9.7 DIRECTION BEARING S 28.00 W S 29.00 W S 47.00 W S 44.00 W N 84.00 W RELAT I VE- COORD I NAT E S FROM-WELL-HEAD DI STNCE 10.5 S 6.2 W 12.2 12.1 S 7.0 W 14.0 13.1 S 7.8 W 15.3 13.9 S 8.6 W 16.3 14.3 S 9.8 W 17.3 CLOSURE BEARING S 30.50 W S 30.25 W S 30.91 W S 31.87 W S 34.46 W DL /lOO 0.50 0.00 0.50 0.25 0.01 2600 0.75 2599.7 2419.7 2700 1.25 2699.7 2519.7 2800 1.00 2799.7 2619.7 2900 0.75 2899.7 2719.7 3000 1.25 2999.6 2819.6 3100 1.00 3099.6 2919.6 3200 0.50 3199.6 3019.6 3300 0.50 3299.6 3119.6 3400 0.75 3399.6 3219.6 3500 0.75 3499.6 3319.6 -11 -12 -14 -15 -16 -18 -19 -19 -20 -20 .0 N 76.00 W .5 N 46.00 W .1 N 66.00 W .4 N 45.00 W .5 N 36.00 W .0 N 63.00 W .1 N 49.00 W .8 N 68.00 W .5 N 12.00 W .9 N 21.00 W 14.1 S 11.1 W 13.2 S 12.6 W 12.1 S 14.2 W 11.3 S 15.5 W 10.0 S 16.6 W 8.7 S 18.1 W 8.0 S 19.2 W 7.5 S 19.9 W 6.7 S 20.6 W 5.4 S 21.0 W 17.9 18.3 18.7 19.1 19.4 20.1 20.8 21.3 21.6 21.7 S 38.27 W S 43.61 W S 49.52 W S 53.92 W S 59.07 W S 64.34 W S 67.45 W S 69.35 W S 71.97 W S 75.43 W 0.O0 o.5O 0.25 0.25 O.5O 0.25 0.50 0.00 0.25 0.00 3600 0.75 3599.6 3419.6 ~ 9 0.50 3699.6 3519.6 30',~ O. 50 3799.6 3619.6 3900 0.50 3899.6 3719.6 4000 0.50 3999.6 3819.6 4100 0.50 4099.6 3919.6 4200 0.50 4199.6 4019.6 4300 0.00 4299.6 4119.6 4400 0.00 4399.6 4219.6 4500 0.50 4499.6 4319.6 4600 -21.2 N 8.00 W -21.7 N 41.00 W -22.0 N 5.00 E -21.8 N 14.00 E -21.6 N 13.00 E -21.4 N 16.00 E -21.3 N 4.00 E -21.3 N 0.00 E -21.3 N 0.00 E -21.2 N 7.00 E 0.50 4599.6 4419.6 -21.2 N 2.00 E 4.2 S 21.3 W 3.2 S 21.7 W 2.4 S 22.0 W 1.5 S 21.8 W 0.7 S 21.6 W 0.2 N 21.4 W 1.0 N 21.3 W 1.5 N 21.3 W 1.5 N 21.3 W 1.9 N 21.2 W 2.8 N 21.2 W 21.7 22.0 22.1 21.9 21.7 21.4 21.3 21.3 21.3 21.3 21.3 S 78.88 W S 81.61 W S 83.78 W S 85.98 W S 88.18 W N 89.58 W N 87.27 W N 86.10 W N 86.10 W N 84.92 W N 82.58 W 0.00 0.25 0.O0 0.00 0.O0 0.O0 0.O0 0.50 0.O0 0.5O 0.00 u~vey Codes: 1/SINGLE SHOT ,~; 43B-8 Page 3 03/01/91 RECORD OF SURVEY MEA$ INCLN VERTICAL-DEPTHS DEPTH ANGLE BKB SUB-SEA 4700 0.75 4699.5 4519.5 4800 0.00 4799.5 4619.5 ~.~90 0.50 4899.5 4719.5 i, 0 0.75 4999.5 4819.5 5100 0.25 5099.5 4919.5 5200 5300 5400 5500 5600 SECTION DIRECTION DISTNCE BEARING -21.6 N 44.00 W -21.8 N 0.00 E -22.0 N 47.00 W -22.7 N 36.00 W -23.4 N 74.00 W 0.50 5199.5 5019.5 -24.0 N 48.00 W 0.50 5299.5 5119.5 -24.2 N 16.00 E 0.50 5399.5 5219.5 -24.5 N 50.00 W 0.50 5499.5 5319.5 -25.1 N 48.00 W 0.75 5599.5 5419.5 -25.6 N 5.00 W 5700 0.75 5699.5 5519.5 -25.6 5800 1.00 5799.5 5619.5 -25.3 5900 1.00 5899.5 5719.5 -25.0 6000 1.50 5999.5 5819.5 -24.8 6100 1.75 6099.4 5919.4 -25.2 N 12.00 E N 12.00 E N 8.00 E N 2.00 E N 19.00 W RELATIVE-COORDINATES FROM-WELL-HEAD 3.7 N 21.5 W 4.3 N 21.8 W 4.7 N 22.0 W 5.5 N 22.7 W 6.0 N 23.4 W 6.3 N 23.9 W 7.1 N 24.2 W 7.9 N 24.4 W 8.5 N 25.1 W 9.5 N 25.5 W 10.8 N 25.5 W 12.3 N 25.1 W 14.0 N 24.8 W 16.1 N 24.7 W 18.9 N 25.1 W CLOSURE DISTNCE BEARING 21.9 N 80.13 W 22.2 N 78.74 W 22.5 N 77.85 W 23.3 N 76.26 W 24.1 N 75.52 W 24.8 N 75.15 W 25.2 N 73.53 W 25.7 N 71.99 W 26.5 N 71.26 W 27.2 N 69.68 W 27.6 N 67.09 W 28.0 N 64.02 W 28.5 N 60.65 W 29.5 N 56.78 W 31.4 N 52.94 W /1oo 0.25 0.75 0.50 0.25 0.50 0.25 0.00 0.01 0.00 0.25 0.00 0.25 0.00 0.50 0.25 6200 2.00 6199.4 6019.4 -26.4 6300 2.50 6299.3 6119.3 -27.5 64n0 2.25 6399.2 6219.2 -28.1 6~ 2.25 6499.1 6319.1 -28.9 66~0 2.25 6599.0 6419.0 --29.4 6700 2.25 6699.0 6519.0 -29.7 6800 2.25 6798.9 6618.9 -30.3 6900 2.25 6898.8 6718.8 -31.0 7000 1.75 6998.7 6818.7 -31.2 7100 1.50 7098.7 6918.7 -31.0 7200 1.75 7198.7 7018.7 -30.7 N 21.00 W N 11. O0 W N 5.00 W N 16.00 W N 0.00 E N 7.00 W N 8.00 W N 12.00 W N 4.00 E N 6.00 E N 8.00 E 22.0 N 26.2 W 25.8 N 27.3 W 29.9 N 27.8 W 33.7 N 28.6 W 37.6 N 29.1 W 41.5 N 29.3 W 45.4 N 29.9 W 49.3 N 30.5 W 52.8 N 30.8 W 55.6 N 30.5 W 58.4 N 30.2 W 34.2 N 49.96 W 37.5 N 46.61 W 40.8 N 42.98 W 44.2 N 40.25 W 47.6 N 37.74 W 50.8 N 35.25 W 54.4 N 33.32 W 58.0 N 31.79 W 61.1 N 30.27 W 63.4 N 28.79 W 65.7 N 27.34 W 0.25 0.50 0.25 0.02 0.02 0.01 0.00 0.01 0.50 O.25 0.25 Trey Codes: · 1/SINGLE SHOT ~ 43B-8 Page 4 03/01/91 RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DEPTH ANGLE BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 7300 2.00 7298.6 7118.6 -30.8 N 10.00 W 61.7 N 30.2 W 68.7 N 26.13 W 0.25 7400 1.75 7398.6 7218.6 -31.4 N 11.00 W 64.9 N 30.8 W 71.8 N 25.43 W 0.25 --'~ '0 I 75 7498 5 7318 5 -31 7 N 1 00 E 67 9 N 31 i W 74 7 N 24 61 W 0 O1 ~ ' · · . . . . . · . ~-J0 1.25 7598.5 7418.5 -31.9 N 10.00 W 70.5 N 31.3 W 77.2 N 23.95 W 0.50 7700 1.00 7698.5 7518.5 -32.2 N 3.00 W 72.5 N 31.5 W 79.0 N 23.52 W 0.25 7800 1.25 7798.4 7618.4 -32.3 N 4.00 W 74.4 N 31.7 W 80.9 N 23.04 W 0.25 7900 1.00 7898.4 7718.4 -32.5 N 4.00 W 76.4 N 31.8 W 82.7 N 22.60 W 0.25 8000 1.25 7998.4 7818.4 -32.7 N 7.00 W 78.3 N 32.0 W 84.6 N 22.21 W 0.25 8100 1.50 8098.4 7918.4 -33.2 N 16.00 W 80.7 N 32.5 W 87.0 N 21.92 W 0.25 8200 1.25 8198.3 8018.3 -33.7 N 10.00 W 83.0 N 33.0 W 89.3 N 21.68 W 0.25 8300 1.50 8298.3 8118.3 -34.1 N 9.00 W 85.4 N 33.4 W 91.7 N 21.36 W 0.25 8400 1.25 8398.3 8218.3 -34.6 N 14.00 W 87.7 N 33.9 W 94.0 N 21.11 W 0.25 8500 1.25 8498.3 8318.3 -35.2 N 15.00 W 89.8 N 34.4 W 96.2 N 20.96 W 0.00 8600 1.25 8598.2 8418.2 -35.9 N 19.00 W 91.9 N 35.1 W 98.4 N 20.87 W 0.00 8700 1.25 8698.2 8518.2 -36.7 N 23.00 W 94.0 N 35.8 W 100.6 N 20.88 W 0.00 8800 2.00 8798.2 8618.2 -37.5 N 10.00 W 96.7 N 36.6 W 103.4 N 20.76 W 0.75 8900 2.00 8898.1 8718.1 -38.1 N 5.00 W 101.0 N 37.2 W 107.6 N 20.22 W 1.00 9~TM 2.25 8998.0 8818.0 -38.4 N 2.00 W 105.6 N 37.5 W 112.0 N 19.55 W 0.75 9~ J 2.00 9097.9 8917.9 -38.5 N 0.00 E 109.3 N 37.6 W 115.6 N 18.97 W 0.25 9200 1.75 9197.8 9017.8 -38.8 N 8.00 W 112.5 N 37.8 W 118.7 N 18.56 W 0.25 9300 2.25 9297.8 9117.8 -39.1 N 3.00 W 116.0 N 38.1 W 122.1 N 18.19 W 0.50 ERPOLATED STATION FROM SCU 43A-8 SINGLE SHOT SURVEY AND TIE-IN FOR SCU 43B-8 SIDETRACK AT 9350 MD 9350 2.25 9347.7 9167.7 -39.2 N 1.00 W 118.0 N 9440 2.50 9437.7 9257.7 -37.2 N 74.30 E 120.8 N 9505 4.20 9502.6 9322.6 -33.4 S 87.00 E 121.2 N 38.2 W 124.0 N 17.94 W 0.01 36.1 W 126.0 N 16.65 W 0.32 32.4 W 125.4 N 14.95 W 2.62 r~ey Codes: 1/SINGLE SHOT 3/MWD 7/GYRO N/INTERPOLATED U 43B-8 Page 5 03/01/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 9568 3.90 9=31 4.00 ! ,'4 4.00 9/57 4.30 9844 4.50 VERTICAL-DEPTHS BKB SUB-SEA 9565.4 9385.4 9628.2 9448.2 9691.1 9511.1 9753.9 9573.9 9840.7 9660.7 SECTION DIRECTION DISTNCE BEARING -29.0 N 76.60 E -24.7 S 89.10 E -20.3 N 79.70 E -15.9 N 71.90 E -9.7 N 68.40 E RELATIVE-COORDINATES FROM-WELL-HEAD 121.6 N 27.9 W 122.1 N 23.6 W 122.4 N 19.3 W 123.5 N 14.9 W 125.8 N 8.6 W CLOSURE DISTNCE BEARING 124.8 N 12.94 W 124.3 N 10.96 W 123.9 N 8.95 W 124.4 N 6.86 W 126.1 N 3.90 W /lOO 0.49 0.19 0.09 0.48 0.23 9906 10063 10198 10262 10322 4.40 9902.5 9722.5 4.50 10059.0 9879.0 4.30 10193.6 10013.6 4.50 10257.4 10077.4 4.80 10317.2 10137.2 10595 10788 10826 3.50 10589.5 10409.5 3.50 10782.1 10602.1 3.50 10820.1 10640.1 -5.1 N 80.50 E 6.9 N 76.70 E 17.0 N 78.30 E 21.7 N 76.50 E 26.4 N 76.00 E 45.9 N 85.00 E 56.8 N 56.00 E 58.7 N 56.00 E 127.1N 3.9 W 129.5 N 8.0 E 131.7 N 18.1 E 132.8 N 22.9 E 134.0 N 27.6 E 137.2 N 47.1 E 141.1 N 58.1 E 142.4 N 60.0 E 127.1 N 1.78 W 129.7 N 3.53 E 133.0 N 7.82 E 134.8 N 9.78 E 136.8 N 11.65 E 145.1 N 18.94 E 152.6 N 22.37 E 154.5 N 22.85 E 0.20 0.07 0.15 0.31 0.50 0.48 0.06 0.00 arvey Codes: 1/SINGLE SHOT 3/MWD X/EXTRAPOLATED ~ 43B-8 Page 6 03/01/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL BSEA MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES ~ DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD -100 80 0.40 80 0 0 S 32.00 E 0.26 S 0.08 E 0 180 0.50 180 0 0 S 30.40 E 1.01 S 0.48 E ..~f 280 0.10 280 0 0 S 6.00 E 1.56 S 0.70 E 2', 380 0.00 380 0 0 S 0.00 W 1.58 S 0.68 E 300 480 0.40 480 0 0 N 10.00 W 1.59 S 0.49 E 400 580 0.30 580 0 0 N 13.20 W 1.06 S 0.28 E 500 680 0.25 680 0 0 N 18.80 W 0.63 S 0.15 E 600 780 0.25 780 0 0 N 21.60 W 0.22 S 0.00 E 700 880 0.45 880 0 0 N 13.20 W 0.33 N 0.18 W 800 980 0.50 980 0 0 N 5.40 W 1.18 N 0.32 W 900 1080 0.30 1080 0 0 N 24.81 W 1.89 N 0.47 W ~000 1180 0.25 1180 0 0 N 48.40 W 2.24 N 0.74 W ~100 1280 0.05 1280 0 0 N 10.59 W 2.47 N 0.92 W ~200 1380 0.00 1380 0 0 N 0.00 E 2.49 N 0.90 W L300 1480 0.20 1480 0 0 N 8.00 W 2.62 N 0.91 W [400 1580 0.25 1580 0 0 S 38.36 W 2.77 N 1.18 W '~00 1680 1.05 1680 0 0 S 13.00 W 1.80 N 1.36 W .' 1780 2.45 1780 0 0 S 22.21 W 1.04 S 2.27 W [7 1880 2.15 1880 0 0 S 22.40 W 5.03 S 3.96 W LB00 1980 1.60 1980 0 0 S 20.40 W 8.04 S 5.14 W L900 2080 1.10 2080 0 0 S 26.42 W 10.22 S 6.04 W ~000 2180 1.00 2180 0 0 S 28.80 W 11.77 S 6.87 W ~100 2280 0.60 2280 0 0 S 43.45 W 12.97 S 7.70 W 2200 2380 0.70 2380 0 0 S 44.59 W 13.68 S 8.44 W ~300 2480 0.75 2480 0 0 S 85.75 W 14.30 S 9.55 W !400 2580 0.75 2580 0 0 N 77.58 W 14.13 S 10.84 W U 43B-8 DATA INTERPOLATED FOR 100 Page FT SUBSEA INTERVAL o3/ol/91 BSEA MEAS INCLN TVD MD-TVD VERT PTH DEPTH ANGLE BKB DIFF CRRT 2500 2680 1.15 2680 0 0 '~0a 2780 1.05 2780 0 0 ~( 2880 0.80 2880 0 0 2800 2980 1.15 2980 0 0 2900 3080 1.05 3080 0 0 DIRECTION BEARING N 51.91 W N 62.07 W N 49.13 W N 37.77 W N 57.70 W RELATIVE COORDINATES FROM WELL HEAD 13.49 S 12.28 W 12.29 S 13.90 W 11.46 S 15.28 W 10.28 S 16.36 W 8.86 S 17.78 W 3000 3180 0.60 3180 0 t100 3280 0.50 3280 0 t200 3380 0.70 3380 0 ~300 3480 0.75 3480 0 9400 3580 0.75 3580 0 0 N 51.75 W 0 N 64.27 W 0 N 22.98 W 0 N 19.24 W 0 N 10.55 W 8.08 S 19.03 W 7.57 S 19.75 W 6.93 S 20.50 W 5.69 S 20.87 W 4.44 S 21.24 W 1500 3680 0.55 3680 0 1600 3780 0.50 3780 0 ~700 3880 0.50 3880 0 1800 3980 0,50 3980 0 1900 4080 0.50 4080 0 0 N 34.54 W 0 N 4.00 W 0 N 12.24 E 0 N 13.20 E 0 N 15.41 E 3.34 S 21.61 W 2.57 S 21.99 W 1.70 S 21.89 W 0.85 S 21.68 W 0.01 S 21.47 W ~000 4180 0.50 4180 0 '~00 4280 0.10 4280 0 4380 0.00 4380 0 [3 ~ 4480 0.40 4480 0 1400 4580 0.50 4580 0 0 N 6.35 E 0 N 0.78 E 0 N 0.00 E 0 N 7.00 E 0 N 2.98 E 0.84 N 21.29 W 1.43 N 21.26 W 1.45 N 21.26 W 1.73 N 21.24 W 2.58 N 21.17 W ~500 4680 0.70 4680 ~600 4780 0.15 4780 ~700 4880 0.40 4880 ;800 4980 0.70 4980 ~900 5080 0.35 5080 0 N 35.01 W 0 N 8.60 W 0 N 47.00 W 0 N 38.15 W 0 N 66.58 W 3.55 N 21.40 W 4.30 N 21.82 W 4.59 N 21.89 W 5.35 N 22.52 W 6.02 N 23.27 W i000 5180 0.45 5180 0 0 N 53.08 W 6.25 N 23.81 W :U 43B-8 Page 8 03/01/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL ~SEA MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES ~ DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD 5100 5280 0.50 5280 0 0 N 3.50 E 6.98 N 24.20 W -~m~ 5380 0.50 5380 0 0 N 37.12 W 7.81 N 24.29 W ~," 5480 0.50 5480 0 0 N 48.39 W 8.39 N .24.94 W 5400 5580 0.70 5580 0 0 N 13.39 W 9.22 N 25.49 W 5500 5680 0.75 5680 0 0 N 8.68 E 10.51 N 25.51 W 5600 5781 0.95 5780 i 0 N 12.00 E 11.93 N 25.22 W 5700 5881 1.00 5880 1 0 N 8.78 E 13.64 N 24.90 W 5800 5981 1.40 5980 1 0 N 3.17 E 15.65 N 24.68 W 5900 6081 1.70 6080 1 0 N 14.92 W 18.37 N 24.91 W SO00 6181 1.95 6180 1 0 N 20.61 W 21.39 N 25.95 W 5100 6281 2.40 6280 i 0 N 12.93 W 24.97 N 27.10 W 5200 6381 2.30 6380 I 0 N 6.15 W 29.12 N 27.78 W 5300 6481 2.25 6480 1 0 N 13.90 W 33.01 N 28.37 W 5400 6581 2.25 6580 1 0 N 3.05 W 36.86 N 29.09 W ~500 6681 2.25 6680 1 0 N 5.67 W 40.79 N 29.27 W ~600 6781 2.25 6780 i 0 N 7.81 W 44.68 N 29.76 W '~00 6881 2.25 6880 I 0 N 11.25 W 48.56 N 30.39 W . 6981 1.84 6980 1 0 N 1.00 E 52.17 N 30.82 W i9 7081 1.55 7080 1 0 N 5.63 E 55.08 N 30.59 W ~000 7181 1.70 7180 1 0 N 7.63 E 57.84 N 30.27 W '100 7281 1.95 7280 I 0 N 6.65 W 61.02 N 30.16 W '200 7381 1.80 7380 I 0 N 10.81 W 64.30 N 30.74 W '300 7481 1.75 7480 I 0 N 1.22 W 67.34 N 31.11 W '400 7582 1.34 7580 2 0 N 7.97 W 70.10 N 31.24 W '500 7682 1.05 7680 2 0 N 4.29 W 72.13 N 31.52 W 600 7782 1.20 7780 2 0 N 3.82 W 74.03 N 31.63 W .'U 43B-8 Page 9 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 03/01/91 ~SEA MEAS INCLN ~ DEPTH ANGLE 7700 7882 1.05 '-'~00 7982 1.20 "0~ 8082 1.45 8 ~ 8182 1.30 8100 8282 1.45 TVD BKB DIFF 7880 2 7980 2 8080 2 8180 2 8280 2 MD-TVD VERT DIRECTION RELATIVE COORDINATES CRRT BEARING 0 N 4.0O W 0 N 6.45 W 0 N 14.35 W 0 N 11.10 W 0 N 9.18 W FROM WELL HEAD 76.05 N 31.77 W 77.94 N 31.94 W 80.22 N 32.34 W 82.62 N 32.93 W 84.92 N 33.32 W 8200 8382 1.30 8300 8482 1.25 B400 8582 1.25 B500 8682 1.25 8600 8782 1.86 8380 2 8480 2 8580 2 8680 2 8780 2 0 N 13.09 W 87.34 N 33.78 W 0 N 14.82 W 89.46 N 34.32 W 0 N 18.27 W 91.56 N 34.93 W 0 N 22.27 W 93.60 N 35.69 W 0 N 12.36 W 96.08 N 36.51 W ~700 8882 2.82 3800 8982 2.38 3900 9082 2.04 )000 9182 1.79 )100 9282 2.16 8880 2 8980 2 9080 2 9180 2 9280 2 0 N 5.90 W 100.09 N 37.12 W 0 N 2.54 W 104.85 N 37.47 W 0 N 0.36 W 108.65 N 37.56 W 0 N 6.57 W 112.00 N 37.71 W 0 N 3.89 W 115.34 N 38.08 W ~200 9382 2.34 '~00 9482 3.61 .~'~ 9583 3.92 ~50~ 9683 4.00 ~600 9783 4.36 9380 2 9480 2 9580 3 9680 3 9780 3 ~700 9883 4.44 9880 ~800 9984 4.45 9980 ~900 10084 4.47 10080 ~000 10184 4.32 10180 ~100 10285 4.61 10280 0 N 26.01 E 0 N 31.72 E 0 S 3.70 E 0 S 18.11 W 0 N 70.85 E 0 N 76.10 E 0 N 78.62 E 0 N 76.95 E 0 N 78.14 E 0 N 76.31 E 119.23 N 37.91 W 122.09 N 34.36 W 121.06 N 27.24 W 119.52 N 21.83 W 124.16 N 12.98 W 126.73 N 5.65 W 128.17 N 1.95 E 129.87 N 9.59 E 131.52 N 17.10 E 133.23 N 24.64 E '200 10385 4.50 10380 0 N 78.08 E 135.10 N 32.59 E ~ 43B-8 Page 10 03/01/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL BSEA MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES PTH DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD 0300 10485 4.02 10480 5 0 N 81.38 E 136.42 N 39.93 E · "00 10585 3.55 10580 5 0 N 84.69 E 137.17 N 46.50 E ~ 10686 3.50 10680 6 0 N 71.38 E 138.35 N 52.49 E 06~i 10786 3.50 10780 6 0 N 56.32 E 141.03 N 57.96 E .~U 43B-8 Page 11 03/01/91 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 "-i 0 0.00 0 -180 0 N 0.00 E 0 N 0 E 0 N 90.00 E 0.0 I ~0 0.50 1000 820 -0 N 4.00 W i N 0 W 1 N 13.78 W 0.0 2000 1.50 2000 1820 -5 S 20.00 W 9 S 5 W 10 S 31.90 W 0.5 3000 1.25 3000 2820 -17 N 36.00 W 10 S 17 W 19 S 59.07 W 0.5 4000 0.50 4000 3820 -22 N 13.00 E 1 S 22 W 22 S 88.18 W 0.0 5000 0.75 5000 4820 -23 N 36.00 W 6 N 23 W 6000 1.50 5999 5819 -25 N 2.00 E 16 N 25 W 7000 1.75 6999 6819 -31N 4.00 E 53 N 31 W 8000 1.25 7998 7818 -33 N 7.00 W 78 N 32 W 9000 2.25 8998 8818 -38 N 2.00 W 106 N 37 W 23 N 76.26 W 0.3 29 N 56.78 W 0.5 61 N 30.27 W 0.5 85 N 22.21 W 0.3 112 N 19.55 W 0.8 10000 4.46 9996 9816 2 N 78.22 E 128 N 3 E 128 N 1.42 E 0.1 Great Land DireckYonal Dpilling. £nc. 6§0 ' t300 ~.- 1 i950 ~- E600 3250 3900 4550 5200 T 5850 6500 7t50 7800 8450 9t00 g750 10400 ii050 85O ii700 VERTICAL SECTION VIEW [ARCO ALASKA. INC, { J SCU 43B-8 Section at: S 89.50 E , ! TVD Scale · ! inch = 1300 feet I i Dep Scale · i inch = 1300 feet i Dpa~n .... · 03/0t/9t ~eker Identification i~ TYO SECTN INOJ~ ~ BJ 9IDETRAO( KOP 0 0 0 0.00 g~O 9348 -3g 2.~ ~ C) m , i0826 iOIr20 59 3.50 ~ 65O i300 i950 2600 3;~50 3900 4550 5;~00 5e50 6500 Section Departure 9t00 [ ~-- i 9~00 ~ - ' 9400 9500 9600 9700 98OO 9900 T ioooo V D io~oo 10200 t0300 SCU 43k~8 i0400 iO§O0 10700 ~----- VERTICAL SECTION VIEW ARCO ALASKA. INC. SCU 43E-B Section at: S 89.50 E TVD Scale.: i inch =200 feet Dap Scale.: ! inch = 200 feet Drawn ..... : 03/01/9! Marker Idm~t!flcm~!on I~ T~9 SECTN INCLN A) SID~ KOP 93511 9348 -39 2.25 t BJ TD i08~li lOB20 59 3.50 'i S~ ~B-B iOBO0 i · ' B t00 0 I ; -, t00 200 300 400 500 600 700 800 900 lO00 Sect ion Departure .. Op~ L an~ Ol?e£ b.f ~ne g zZF'././././'n.<g . . )larked IdenCiflcltton 113 N/-q KB 0 ON OE SIDETRA~ KI]P g3~ ~1 TD t08~ t~ N 60 E PLAN VIEW ARCO ALASKA, INC. SCU 438-8 CLOSURE ..... : 155 ft N 22.84 E DECLINATION.: 24.00 E SCALE ....... : ! inch = 30 feet DRAWN ....... : 03JO1/§! 180 i- t65 j { i50 j 1 tO§ 9O 75 ~ 6O 3O ' i5 " 0 v 9o sau 4SA-a :1 I t I 75 6O 45 30 t5 0 t5 <- NEST ' FAST -> 3O 45 60 75 9O AOGCC GEOLOGICAL MATERIALS iNYENTORY LiST PERMIT # qO - J~"'Z..- WELL NAME L%~.., COMPLETION DATE ~. I 7_,"'/_. /~ t. CO, CONTACT check off or list data as it is rcccived.*list received date for 407, if not reouired list as NR drillin~ histo~' surv'ev well tests core dcscriDtim cored intervals core analysis dry ditch intervals ital data ! , ! 10] 11] 12] 14] 18.1 RUN NO. I INTERVALS [to thc nearest footJ SCALE j Jinchll§O'J j o0o -.' ^0GCC GEOLOGIC~.L MATERIALS INVENTORY LIST ~ ( check off or list data as it is received ] 'd,z ! 6/;1/~ drillinu histnw~' ~"~"Y l ~w. Ii test~ I ~r~ desrirtion~' cored iote~als core anal~is d~ ditch int~als digital data I I I , ' LOG TY6E ' RUN INTERVALS SC/ILE NO. ,, , 12) 1~] I ,, ARCO Alaska, Inc. Post Office B~,~. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 0 P, I Gr f'N A L April 7, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 43B-8 Dear Mr. Smith: On July 31, 1991 ARCO Alaska, Inc. successfully completed the perforation of SCU 43B-8 H8, H9 and H10 sands. The intervals shot were from 10540'-10560',' 10572'-10591' and 10651'-10664' respectively. Please refer to the attached Well Service Reports and submittal of the Subsequent Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zemell at 263-4107. Sincerely, Acting Regional Engineer TW:DRH:czm:0130 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation Alaska Oi[ & Gas Cons. Coll~missiu~': 'Anchorage ARCO Ale~a, Ir~c. Is a Sub~.idlary of Atlantic RlchfleJd Company STATE OF ALASKA ALAsI~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging ~ Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 1003 60, Anchorage, AK 99510 4. Location of well at surface Z150' FSL, 515' FEL, Sec. 8, T7N, Rgw, SM At top of productive interval At effective depth At total depth 2292' FSL~ 455' FEL~ Sec. 8~ T7N~ Rgw~ SM 2. Present well condition summary Total Depth: measured 10826' true vertical 10820' 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB178' GL152' 7, Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 43B-8 9. Permit number/approval number ~1-217//F~-,-;~ --~' 10. APl number so-133-101 21-02 1 1. Field/Pool Swanson River-Hemlock feet feet Plugs (measured) Effective depth: measured 10745' feet true vertical 10739' feet Junk (measured) 13. Casing Length Size Cemented Structural Conductor 34' Z0" Driven Surface 2073' 11-3/4" 1300 sx Intermediate 9380' 7" 2200 sx Production Liner 1757' 5" 72.5 bbis Perforation depth: measured Measureddepth ~ueverticaldepth 34' 34' 2073' 2073' 9380' 9378' 9069'-10826' 9067'-10824' Current: 10540'-10560', 10572'-10591 ',10613'-10642',10651 '-10664' MD true vertical Current: 10535'-10555',10567'-10586',10608'-10637',10646'-10659' TVD Tubing (size, grade, and measured depth) 3-1/2" @ 8967' MD; 2-3/8" from 8967'-10327' MD Packers and SSSV (type and measured depth) Packers: Baker Model 'DB' Packer @ 10276' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons, G0mr~'tss~OO 14. ReDre~¢l~l;~ti¥~ Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 250 272 16,427 10 0 17~862 8 0 16, Status of well classification as: Oil X Gas Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~/¢<~-~/~-/A___~, c~.,,L~._ Title Cook Inlet Re~lional En!]ineer Form 10-404 Rev 06/15/88 2025 2100 Service ___ Date SUBMIT IN DUPLICATE 05:55 ! ;ANSON RIUER ARCO Alaska, Inc. ~~'y of Atl~tk~ FU~fl~d C, Oml~y IPBD? _ _ _ TEL NO: DISTRICT- STAT~.~ lOP'RATION AT REPORT TIME ~311 P01 WELL SERVICE REPOt. /3__'_2.0 ' t--J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ... i m ! ....... ! ....... ARCO Alaska, Inc. Subsidiary Of Atlantic Ri¢t~ftetc~ Comoan¥ CONTRACTOR REMARKS iPIBDT WELL SERVICE REPORT tFIF_LO ' DISTRICT. STATE JOPERATION AT REPORT TJlVlJ~ DAYS . -$1.?/ .~0 _7':00-" ~T - ?~:$o Lo 9 .rko,,/. /o ~"¥o .- /os&o {Z] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK "~ I --~*~ I__l__ 1 lll--al...lll~--. [JJIJla'-I Arco ,ell- scu 43B-8 APl#' 50-133-10121-02 Spud Date: 5/74 Completion Date: 2/21/91 Original RKB- 18' Hanger Type' Shaffer Top of Hemlock:10,352'UD Max. Hole Angle' 1° ,~ska Inc. - Swanson Rive, ~eld Well Type: Producer Last Workover: Hanger' Shaffer Angle @Hemlock' 0 All Depths are RKB MD to Top of Equipment. H8 H9 HIO 10 Jewelry I 2021' 2 8967' 3 10,262' 4 10,267 5 10,273' 6 10,276' 7 10,282' 8 10,282' 9 10,316' 10 10,327' GLM Camco MMG 3-1/2" x 1-1/2" RD Dummy w/BK Latch X-Over 3-1/2" x 2-3/8" GLM TMPOX 2-3/8" x 1" w/Dummy BK-2 Latch Otis "X" Nipple 2-3/8" 1.875 LD. Baker E-22 Locator Seal Assembly Baker "DB" Packer 5" x 2-3/8" w/Anchor 2.688 I.D. Mill out Extension X-Over Otis "XN" Nipple 1.791 I.D. Baker Shear out Sub/Wireline Re-entry 2.00 I.D. Casing and Tubing Size Weloht Grade 20" 11-3/4" 47# J-55 7" 29# N-80 5" 18# N-80 3-1/2" 9.3# Mixed 2 3/8" 4.7# N-80 Bottom Descri_otion 0 30' Conductor Pipe 0 2085' Sudace Casing 0 9300' Production Casing 9069' 10,742' Liner 0 8967' Tubing 8967' 10,327' Tubing Perforation Data Interval CDIL) Zone FT SPF 10,540'-10560' H8 20' 4/6 10,572'-10,591' H9 19' 8 10,613'-10,642' H10 29' 6 10,643'- 10,651' H10 8' 4 10,651'-10,664' H10 13' 4/8 Date Comments 8/1/91 ADD 7/25/91 Reperf 2/21/91 Initial Completion 7/25/91 ADD 7/25/91 Repeal PBTD = 10,745' TD --10,790' Well scu 43B-8 JLB 1/6/92 Rev. ARCO Alaska, Inc. Post Office Bo^ ,u0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Bnlet Engineering INAL March 13, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Subsequent Report for SCU 43B-8 Dear Mr. Smith: On April 27, 1991 ARCO Alaska, Inc. successfully completed the perforation of SCU 43B-8 H9 and H10 sands. The intervals shot were from 10572'- 10591' and 10651'- 10664' respectively. Please refer to the attached submittal of the Subsequent Report for details of this operation. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, J. c. winn Acting Regional Engineer JCW:DRH:czm:0122 Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED MAR 1 6 1992 Alaska Oil & Gas Cons. Anchorage ARCO ~ Inc. is a Substdlar~ of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY INELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate Plugging ~ Perforate X Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing ~ Other Z. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2150' FSL, 51 5' FEL, Sec. 8, T7N, RgE, SM At top of productive interval At effective depth At total depth 2292' FSL~ 455' FEL, Sec. 8~ T7N~ RgE~ SM 1Z. Present well condition summary Total Depth: measured 108;::)6' true vertical 10820' 5. Type of Well: Development Exploratory Stratigraphic Service feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 178' GL 15Z' 7. Unit or Property name Soldotna Creek Unit 8. Well number 5cu 43B-8 9. Permit number/approval number 90-152 / 91-156 10, APl number 50-1 33-101 21-02 1 1. Field/Pool Swanson River-Hemlock Effective depth: measured 10745' feet true vertical 10739' feet Junk (measured) 13. Casing Length Size Cemented Structural Conductor 34' Z0" Driven Surface 2073' 11-3/4" 1300 sx Intermediate 9380' 7" 2200 sx Production Liner 1757' 5" 72.5 bbls Perforation depth: measured Current: 10572'-10591 ',10613'-10642', 10651 '-10664' MD true vertical Current: 10567'-10586',10608'-10637',10646'-10659' TVD Tubing (size, grade, and measured depth) 3-1/Z" @ 8967' MD; Z-3/8" from 8967'-10327' MD Packers and SSSV (type and measured depth) Packers: Baker Model 'DB' Packer @ 10276' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A Measured depth 34' 2073' 9380' 9069'-108Z6' Trueverticaldepth 34' Z073' 9378' 9067'-108Z4' RECEIVED MAR 1 Alaska 0il & Gas Cons. Anch0raga 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In_iection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 251 1 6,944 6 0 2000 364 17~787 4 0 2150 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations ~ 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 //~ ~-¢'A'~ ~'5~'~1e Cook Inlet Regional Engineer Date ~ / /,~ /'~ Z.. SUBMIT IN DUPLICATE , ~ I:lPR-~'gl ;~5:4,.3 I *ql, EON RIUER TEL N0:26.~ tt~"~ I=~1 ARCO Alaska, Inc. ~ul~llary of Atlatttlo Rtc~hflMd OOtlll;~ltly WELL, CONTRACTOR WELL SERVICE REPORT I-FIELD. DISTRICT. STATE ~-~_,,.,,_~,,,, ,~,,,_~,,/-,~_,_~ .... Iq: t \ .... .~, .i/il :1~ ~8,~ b~li$, buIIlfrlJSSJOf~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK .- ARCO Alaska-, Inc. CONTRACTOR ~/~/ REMARKS 1'7:oo I~ELL SERVICE REPORT PBDT ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK _Weather [ Temp, I Chill Fiotm'! Vlilblllty. l Wind VeL ~ Arc¢ aska Inc. - Swanson Riv~ ield ,~ell- $CU 43B-8 APl#: 50-133-10121-02 Well Type: Producer Spud Date: 5/74 Completion Date: 2/21/91 Last Workover: Original RKB: 18' Hanger Type: Shaffer Hanger: Shaffer Top of Hemlock:10,352'UD Max. Hole Angle: 1° Angle @Hemlock: o All Depths are RKB MD to Top of Equipment. H9 HIO 4 5 7 8 9 10 Jewelry I 2021' 2 8967' 3 10 262' 4 10 267 5 10 273' 6 10 276' 7 10 282' 8 10 282' 9 10316' 10 10 327' GLM Camco MMG 3-1/2" x 1-1/2" RD Dummy w/BK Latch X-Over 3-1/2" x 2-3/8" GLM TMPOX 2-3/8" x 1" w/Dummy BK-2 Latch Otis "X" Nipple 2-3/8" 1.875 LD. Baker E-22 Locator Seal Assembly Baker "DB" Packer 5" x 2-3/8" w/Anchor 2.688 LD. Mill out Extension X-Over Otis "XN" Nipple 1.791 I.D. Baker Shear out Sub/Wireline Re-entry 2.00 I.D. Casing and Tubing Size Weight Grade Bottom Description 20" 0 11-3/4" 47# J-55 0 7" 29# N-80 0 5" 18# N-80 9069' 3-1/2" 9.3# Mixed 0 2 3/8" 4.7# N-80 8967' Perforation Data Interval Zone FT SPF 10,572'-10,591' H9 19' 4 10,613'-10,642' H10 29' 6 10,651'-10,664' H10 13' 4 30' Conductor Pipe 2085' Surface Casing 9300' Production Casing 10,742' Liner 8967' Tubing 10,327' Tubing Date Comments 4-91 ADD 2/21/91 Initial Completion 4-91 ADD PBTD = 10,745' TD =10,790' MAR 1 6 ~99~ Alaska Oil & Gas Cons. c ..... Anchorage Well SCU 43B-8 JLB 7/17/91 Rev. ARCO Alaska, Inc. Post Office E~ 100360 Anchorage, Alaska 9954 Telepho.~e 907 276 ORIGIN/ July 18, 1991 Mr. L Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H8, H9 and H10 Sands in Swanson River Field producer well SCU 43B-8. We propose to add 20' of new perforations in the lower H8 Sand, reperforate 19' of the H9 Sand, and reperforate 13' of the lower H10 Sand with 1-11/16" strip guns. With your approval, we would like to begin this work as soon as possible. If you have any questions please contact Murray Hamilton at 263-4384. Sincerely, / !;J T. Wellman Regional Engineer Cook Inlet Engineering TW:MOH:czm:0110 Attachment Mr. W. Watson Mr. B.C. Dehn SCU 43B-8 Well Files Marathon Oil Company UNOCAL Corporation ARCO ~ Inc. is a Subsidtar7 of Afl~n~c Rlchtle~l Company STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend m Alter casing __ Repair well Change approved program __ Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate_ Pull tubing __ Variance _ Perforate ~( Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK . 99510 Location of well at surface 2150' FSL, 515' FEL, Sec. 8, T7N, R9E, SM At top of productive interval At effective depth At total depth 2292' FSL, 455' FEL, Sec. 8, T7N, RgE, SM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) RKB 178'. GL 152' 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 43B-8 9. Permit number 10. APl number 50-133-10121-02 11. Field/Pool Swanson River/Hemlock feet 12. Present well condition summary Total Depth: measured true vertical 10,826' feet Plugs (measured) 1 0,820' feet Effective depth: measured 10,745' feet Junk (measured) true vertical 1 0,739' feet Casing Length Size Cemented Structural Conductor 3 4' 2 0" D rive n Surface 2073' 1 1-3/4" 1300 sx Intermediate 9380' 7" 2200 sx Production Liner 1 757' 5" 72.5 bbls Perforation depth: measured Current: 10572-10591' ; 10613-10642' ; true vertical Current: 10567-10586'; 10608-10637' ; 10646-10659' TVD Tubing (size, grade, and measured depth 3-1/2" @ 8967' MD; 2-3/8" from 8967'-10327' MD Packers and SSSV (type and measured depth) Packers: Baker Model 'DB' Packer @ 10276' 10651-10664' MD Measured depth 34' MD 2073' MD 9380' MD 9069'-10826' MD True vertical depth 34' TVD 2073' TVD 9378' TVD 9067'-10824' TVD 13. Attachments Description summary of proposal X Detailed operation program _ ~0-(:~OPl~'¢ketch X 14. Estimated date for commencing operation July 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~]ned / - ~.cr.~,~.~_. Title Cook Inlet Regional Em:jr. FOR COMMISSION USE ONLY Date -7//~//? / Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- ~ 7 Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C Commissioner Approved C.opy IAppr°val N °¢/.....~(?/'Z I SUBMIT IN TRIPLICATE SUMMARY OF PROPOSED WELL OPERATIONS WELL SCU 43B-8 (July 1991) 1. RU E-line unit and lubricator. 2. Perforate the following intervals: Run No. Bench Interval (MD-DIL) 1 H10 10651-10664' 2 H9 10572-105~!:_ 3 H8 ., 10540-10__5_6~v~ Note: Lubricator will be pressure tested to 3500 psi. Lenmh SPF 13 4 19 4 20 4 3. RD E-line unit and lubricator. ~Ve;!- SCU 43B-8 Spud Date: 5/74 Original RKB: 18' Top of Hemlock:lO,352' MD Max. Hole Angle: Arc(, · Jaska Inc. - Swanson Rive. APl#: 50-133-10121-02 Completion Date' 2/21/91 Hanger Type: Shaffer 1° ·.ield Well Type: Producer Last Workover: Hanger' Shaffer Angle @Hemlock' o All Depths are RKB MD to Top of Equipment. Jewelry I 2021' 2 8967' 3 10,262' 4 10,267 5 10,273' 6 10,276' 7 10,282' 8 10,282' 9 10,316' 1 0 10,327' GLM Camco MMG 3-1/2" x 1-1/2" RD Dummy w/BK Latch X-Over 3-1/2" x 2-3/8" GLM TMPOX 2-3/8" x 1" w/Dummy BK-2 Latch Otis "X" Nipple 2-3/8" 1.875 I.D. Baker E-22 Locator Seal Assembly Baker "DB" Packer 5" x 2-3/8" w/Anchor 2.688 I.D. Mill out Extension X-Over Otis "XN" Nipple i.791 I.D. Baker Shear out Sub/Wireline Re-entry 2.00 I.D. Casing and Tubing Size Weight Grade Bottom Descrl_Dtion 20" 0 11-3/4" 47# J-55 0 7" 29# N-80 0 5" 18# N-80 9069' 3-1/2" 9.3# Mixed 0 2 3/8" 4.7# N-80 8967' Perforation Data Interval Zone FT SPF 10,572'-10,591' H9 19' 4 10,613'-10,642' H10 29' 6 10,651'-10,664' H10 13' 4 30' Conductor Pipe 2085' Surface Casing 9300' Production Casing 10,742' Liner 8967' Tubing 10,327' Tubing 4-91 ADD 2/21/91 Initial Completion 4-91 ADD 5 6 7 8 H9 HIO 10 PBTD -- 10,745' TD --10,790' Well SCU 43B-8 JLB 7/17/91 Rev, E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead MOH 6/1/91 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4304 Tom Wellman Regional Engineer Cook Inlet Engineering May 17, 1991 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached is an Application for Sundry Approval to perforate the H9 and H10 intervals in SCU 43B-8. We propose to perforate 19' of the H9 sand (10,572'-10,591' MD) and 13' of the H10 sand (10,651'-10,664' MD) using 1 11/16" perforating guns @ 4 spf. Verbal approval was previously obtained from Mike Minder and the work commenced April 26, 1991. If you have any questions please contact David A. Pursell at 263-4258. Sincerely, T. Wellman Regional Engineer TW:jkw:0062 Attachment cc: Mr. A~ 1~ Kukla Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED k4^¥ 2 3 991 Alaska .Oil & Gas Cons. Commission ;~nchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend__ Operation Shutdown __ Re-enter suspended well 2. Name of Operator Alter casing __ Change approved program __ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Repair well Pull tubing __ 5. Type of Well: Development Exploratory Stratigraphic Service _ Plugging_ Time extension _ Stimulate_ Variance_ Perforate X Other__ _ 6. Datum elevation (DF or KB) RKB 178'. GL 152' 7. Unit or Property name Soldotna Creek Unit feet 4. Location of weil at surface 2150' FSL, 515' FEL, Sec. 8, T7N, R9E, SM At top of productive interval At effective depth At total depth 2292' FSL, 455' FEL, Sec. 8, T7N, RgE, SM 8. Well number SCU 43B-8 9. Permit number 90-152 10. APl number 50-1 33-1 01 21 11. Field/Pool Swanson River/Hemlock 12. 13. Present well condition summary Total Depth: measured true vertical 10,826' 10,820' feet Plugs (measured) feet Effective dePth: measured 10,745' feet Junk (measured) true vertical 1 0,7 3 9' feet Casing Length Size Structural Conductor 34' 2 0" Surface 2073' 1 1-3/4" Intermediate 9380' 7" Production Uner 1 757' 5" Perforation depth: measured Current: 10613'-10642' MD Proposed: true vertical Current: 10608'-10637' TVD Proposed: Tubing (size, grade, and measured depth 3-1/2" @ 8967' MD; 2-3/8" from 8967'-10327' MD Packers and SSSV (type and measured depth) Packers: Baker Model 'DB' Packer @ 10276' Attachments Cemented Driven 1300 sx 2200 sx 72.5 bbls Measured depth True vertical depth 34' MD 34' TVD 2073' MD 2073' TVD 9380' MD 9378' TVD 9069'-10826' MD Description summary of proposal 10572'-10591'; 10651'-10664' MD 10567'-10586'; 10646'-10659' TVD 9067'-10824' TVD RECEIVED MAY ;3 1991 Alaska 0il & Gas Cons. C0mmiss~ ~n~'hnran~ Detailed operation program _ BOI~ "~G~'~.~. 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver /c/l,/d.~__. ,/t~d~f'~ Date approved 15. Status of well classification as: o, _.X_ ~as. Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned '/~'~'~----~ Title Cook Inlet Regional Engr. FOR COMMISSION USE ONLY Date 5/Zo/'~ / Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Approved b)~ the order of the Commission Form 10-403 Rev 5/03/89 Subsequent form require 10- Approvea Copy Returned 407 Commissioner IApproval No. ORIGINAL SIGNED BY LONNIF r'- e,.,,-,u... SUBMIT IN TRIPLICATE · E-Line BOPE's Grease Heact/ Hydraulic Packoff ~-. Lubricator Extension Manual Rams Swab Valve Double Maste~ Valves Wellhead Well SCU 43B-8 Perforation Procedure Objective Perforate H9/H10 Sand in order to increase oil production. Current Status SCU 43B-8 is producing. Minimum Restriction: 'XN' profile at 10,316' MD (ID = 1.791") Pressures: FTP 2010 psi PC 10 psi SC 0 psi Procedure · Prior to Perforating 1. RU slickline and tag with 1.7" gauge ring. 2. Shoot fluid level in tubing to verify liquid level is several hundred feet above perforated interval. Load tubing with crude ff necessary. 3. Contact Anchorage office to verify sundry approval before proceeding. · Perforatinq ! ~ 1. MIRU E-L~ Unit. Pressure test lubricator. 2, RIH w/ Perf gun/GR/CCL. Tie-in to perf the following intervals: Interval Run No. (PDK- lr00--2-~~) Footage fit) Sand SPF Phasing 1 ~. ...... 10,651-664 13 H10 4 0° 2 '~ .... 10.572~- 1 19 Ha 4 0° Confirm that all shots have fired. 3. POOH. RD E-Line Unit. 4. RTP on current choke setting. perforation. Test well on days 1,3, 5 following re- RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 6 7 SCU 45B. PROPOSE D SI I I · ], · ~?' I 33 FS~L 9' 34 I0 15 I I I II 12 14 I$ SCALE: I"= I MILE CERTIFICATE Of SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a proposed drilling location. Dimensions and other details furnished by Arco Alaska Inc. Lmte Surveyor PROPOSED SIDETRACK $CU -45B-8 Located in Sec. 8! T. TN.1R.9 W.~ S.M.~ Alaska for ARCO ALASKA INC. , P.O. BOX100560 ANCHORAGE! AK. 99510-0360 by - R.C. DAVIS & ASSOC. LAND ~ MINERAL SURVEYORS 14870 SNOWSHOE LANE ANCH~AK.99516 ARCO ALASKA INC. Cook Inlet Engineering #522 TRANSMISSION TO:. COMMISSIONER FROM: Victoria Ferguson COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: 3/22/91 WEIJJ NAME: SCU 43B-8 Transmitted herewith are the following ~ -' [~[ ~L Blue Sepia Sepia rape & Line Folded Rolled Mylar listing COMP. NEUTRON 1 1 BHC ACOUSTILOG 1 1 4-ARM CALIPER LOG 1 1 DUAL INDUCI1ON FOCUSED 1 1 COMP. Z-DENSITY 1 1 ~,, Receipt Acknowledgement: /~ Return reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' RECEIVED MAR 2 Date: Alaska Oil & 6as Cons, Comrnissio~ Anchorage ARCO ALASKA INC. Cook Inlet Engineering #510 TRANSMISSION TO:. COMMISSIONER FROM: Victoria Ferguson COMPANY: AOGCC DATE: 3/8/91 COMPANY: ARCO Alaska, Inc WELL NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia l'ape & Line Folded Rolled M~,lar listin~ SCU 43B-8 PDK- 100/GR/CCL 1 Alaska Oil &AnchoraGaS Cons.e Cqrnrnission R~eipt Ac~owl~gement: ~~ Re~ r~iept m ~CO ~S~, hc. A~: Judy ~~ ATO 1390A Post ~fice Box 1~3~ ~chomge, ~ 99510-03~' Date: ARCO ALASKA INC. Cook Inlet Engineering #499 TRANSMISSION TO:. COMMISSIONER COMPANY: AOGCC DATE: 2/20/91 FROM: Victoria Ferguson COMPANY: ARCO Alaska, Inc WEI~I~ NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Roiled Mylar listin~ SCU 24A-5 PDK-100 1 1 SCU 43B-8 Vertilog . 1 1 SZDL/CN/GR/DIFL/AC 1 R~eipt Acknowledgement: ~,.~ ~ ~ ~.)~.~~ Return reciept to ARCO ALASKA, Inc. ATI~: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: Telecopy No. (907) 276-7542 November i6, 1990 A IW McBride Area Drilling Engr ARCO Alaska, Inc P 0 Box 100360 Anchorage, AK 99510-0360 Re: Soldotna Creek Unit 43B-8 ARCO Alaska, inc Pea-mit # 90-152 Surf Loc 2150'FSL, 5!5'FEL, Sec 8, T7N, R9W, SM Btmhoie Loc 2250'FSL, 415'FEL, Sec 8, T7N, R9W, SM Dear Mr McBride: Enclosed is the approved application !or permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until ali. other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, . , ~/Lonnie C gSmith Core. is s loner BY ORDER OF THE CO~R~iSSiON jo encl C~ Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl "~ · STATE OF ALASKA ' A[.A~,~ OIL AND GAS CONSERVATION COMMI'-w,ON PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill ~ Redrill __ I lb. Type of Well Exploratory~ Stratigraphic Test ~ Development Oil Re-Entry X Deepen :XI Service __ Development Gas ~ Single Zone __ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 170'. Pad GL 152' feet Swanson River Field 3. Address 6. Property Designation Hemlock Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 A-028996 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2150' FSL, 515' FEL, Sec. 8, T7N, Rgw, SM Soldotna Creek Statewide At top of productive interval 8. Well number Number 2250' FSL, 415' FEL, Sec. 8, T7N, Rgw, SM SCU 43B-8 #UG30610 At total depth 9. Approximate spud date Amount 2250' FSL, 415' FEL, Sec. 8, T7N, R9W, SM December 15, 1990 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line SOU SCU 33A-8 10,800' MD 1250'feet approx 600'feet 3,6 4 0 10,789' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9350 'feet Maximum hole angle 5° IVaximum surface 3920 psI~ At total depth ~I'VD) 5000 psl~l !18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casino,1 Wei~lht Grade Couplin~l Len~lth IVD TVD IVD ~ TVD linclude stac, le dataI existin(7" 33.7# N-80 Sect on Mil from~ 6'/~ 5" ~3,~'.0# N-80 1750' 9050' 10800' 1~.~ Sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 43A-8 Total depth: measured 10,790' feet Plugs (measured) 43A-8 will be P&A @ 9500' true vedical 10,779' feet 43B-8 will be sidetracked from 43A-8 Effective depth: measured 10,745' feet Junk (measured ~,~ true vertical 10,735' feet Casing Length Size Cemented Measured depth True~' .~lflical . ConductorStructural 20" Driven 34' 34' -,-,o.~;..~?~, O'~.O- Surface 2,051' 1 1-3/4" 1300 Sxs Class G 3,390' '~.~,. "z2~,,,~ 3,390 .. C'~. Intermediate 1 0,860' 7" 2200 Sxs Class G 1 0,565' 1 0,365' Production-~ ~ ...?I~,~. Liner 1,171' 5" 117 Sxs Class G 9619'-10790' 9617'-10779" Perforation depth: measured 10728'-10717', 10714'-10708', 10702'-10688', 10678'-10646', 106~-10613' 10601'-10584', 10576'-10567', 10556'-10531', 10523'-10514' true vertical 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program X Drilling fluid program _ Time vs depth plot ~ Refraction analysis ~ Seabed report ~20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~//'~'~/~ ,~. ~~I~ CommissionTitle Area Drilling] En~ineeruse Only Date //~ ~/~(:~/ Per~t Number I 5AOPI- 7--~b~ I Approval d~.t~_ I See cover letter for c_/~{~) -//~,. "/~) ,/2. ! - 4~ ~ / ]- ~ / 9 0 other recluirements Conditions of approval Samples required .~Y e s ~ N o Mud Icg required Ye s ~ N o Hydrogen sulfide measures Yes ~ N o Directional survey required ~'Ye-;- N o Required working pressure for BOP'~E __2M; /~'--~-3M' ~ 5M' _ 10M; __ I 5"~' Other: / ~-, t -/ Approved by ~ ' Commissioner the commission Date / SCU 43B-8 Sidetrack and Redrill Summary The following general procedure outlines the planned work to sidetrack and redrill the SCU 43A-8 as SCU 43B-8 and complete the well in the Hemlock formation as a non-gravel packed single completion. The procedure includes the cutting of approximately a 70 foot section in the 7 "casing at +9350' and then sidetracking from the original wellbore using conventional methods. The well will then be redrilled to a total measured depth of approximately 10,800'. The new wellbore is planned for a minimum step out to the east/northeast. Except for the sidetrack out of the old wellbore, this well will be essentially a straight hole with as low an angle as possible through the Hemlock. Following the re-drill and open hole logs a 5" liner will be run and cemented in place. The well will then be completed as a non-gravel packed single completion in the Hemlock formation. Actual completion procedures will be determined after cased hole logs have been run and evaluated. Please note that the new well is renamed as SCU 43B-8 and will be referred to as such in the future. SCU 43B-8 General Procedure 1. Install BPV in tubing hanger. 2. Move in and rig up Grace Rig //154. 3. Pull BPV. Bleed off pressure in tubing and casing annulus. 0 Kill well by bullheading 9.2 ppg NaC1 kill weight brine down tubing. RU slickline and set plug in Otis 'X' Nipple @ 10,133'. Pull valve from GLM @ 10,092'. Circulate kill weight brine down tubing up annulus. Pull plug in Otis 'X' Nipple. RD slickline. . Ensure well is dead, install BPV, ND tree, NU BOPE, pull BPV. Install test plug and test BOPE to 5000 psi. Pull test plug. , Stab into Shaffer tubing hanger with a joint of 3-1/2" EUE 8rd tubing and pull present completion assembly. LD all tubing and accessories. . PU cement retainer for 5" 18# casing and RIH. Set retainer at + 10,10ft. Test retainer with 10,000# string weight and 3000 psi on backside. Squeeze + 75 sacks class G cement below retainer and spot an additional 75 sacks cement on top of retainer to put TOC @ + 9,500'. 1 POOH 10 stands and reverse out any excess cement. Finish POOIk 9. Make 6" bit and scraper run to TOC. POOH. 10. Test casing to 2500 psi for 30 minutes. If casing does not test, RIH with retrievable packer w/bypass and isolate casing leak interval. POOH. If casing tests, skip to step #12. 11. PU and RIH with a 7" drillable bridge plug on drill pipe and set below leaking interval. Shear off bridge plug and spot a balfinced cement plug of sufficient volume to put th top of cement + 250' above top of leaking interval. POOH 150' above TOC and brad,nh,ad squeeze 6-8 bbls cement into leaking interval. POOH. Drill out cement to bridge plug. Test casing and repeat procedure if necessary. If casing tests, drill up bridge plug and make bit run to PBTD. 12. Displace casing w/ 10 ppg Hi-Vis mud suitable for section milling. 13. GIH w/ Tri-State Metal Muncher section mill for 7" casing. 14. Cut 70' section f/+ 9,350' - 9,420'. POOH. 15. GIH open ended and spot a 65 sack balanced densified cement plug on top of existing cement so that TOC is 200' above the top of section. POOH 7 stands and squeeze 2 to 3 bbls cement into the formation if possible. Open preventers and POOH. 16. GIH w/ 6" bit and dress off kick-off plug to 10' below top of casing section. POOH. 17. Side track well out of section with 100' displacement (+ 50') to the East/Northeast from the current bottom hole location keeping angle as low as practical. Redrill well to + 10,800' TVD. 18. Log open hole and make any additional necessary rat hole on the conditioning trip prior to running casing. 19. Run 5" production liner and cement same. 20. Clean out to TOL and test same to 2500 psi. 21. Clean out inside of liner and retest to 2500 psi. 22. Run cased hole logs 23. Perforate w/ TCP. POOH and LD drill pipe. 24. Run completion assembly. 25. ND BOP's, NU tree, and test same. 26. Displace to lease crude. 27. RD and MO rig. Turn well over to Production Supervisor. Arcr - laska Inc. - Swanson River Well- SCU 43A-8 APl.' 50-133-10121-01 VV.,I Type'SI Producer Spud Date: 5/74 ; Completion Date: 5/17/74 Last Workover: 1-1/5/89 Original RKB' 18' Hanger Type: Shaffer Hanger' Shaffer 'Top of Hemlock:10,352' MDMax. Hole Angle: 1° Angle @Hemlock' 0° All Depths are RKB MD to Top of Equipment. Jewelry 1 1999' 2 3940' 3 9559' 4 10092' 5 10133' 6 10151' 7 10174' .8__ 10174. 9 10453' _ 1'0 10,678' 11 10,692' K-BUG Mandrel w/'E' Dummy BK2 Latch K-BUG Mandrel w/'E' Dummy BK2 Latch 3 1/2' x 2 3/8' X-Over TMPDX Mandrel w/l' CEV BK2 Latch 2 3/8' 'X' Nipple Baker SC-IL Packer X-Over Sub Shear-out_ S_a.fety..Jr._ - Baker Weld Screen (0.20 Gauge) O-Ring Seal Sub (I.D. 1.315') 3 7/8' Bull Nose ~.T 7" SOu H9 HIO 9827' Window 9870' 9 11 Casing and Tubing Size Weight ~ 20" 11-3/4" 47# J-55 7" 29# N-80 5" 18# N-80 3-1/2" 9.3# N-80 2 3/8' 4.7# N-80 Perforation Data 10,514'- 10,523' H6 9' 10,531'-10,556' H8 25' 10,567'-10,576' H8 9' 10,584'-10,601' H8 17' 10,613'-10,632. H9 19' 10,646'-10,678' H10 32' 10,688'-11,702' H10 14 io, 7o~,'- IO,?/~/' / 10/717 ' /0,'7 [E~' / ! PBTD - 10,745' TD = 10.790' 0 30' 0 2085' 0 9619' 9619' 10,790' 0 9559' 9559' 10,166' 4 4 4 4 4 4 4 ,-/ -- 5174 5~74 5~74 5174 ,5/74 5/74 5/74 DescrlDtl<~n Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Reperf 10/89 · · · Repor~ 10~ Well SCU 43A-8 JLB 11t15/89 SCU 43B-8 Liner Schematic 20"@ 34' ~,~__ 11-3/4" @ 2,093' Top of SCU 43B-8 5" Liner @ _9,050' SCU 43B-8 7" Section Cut @ _ 9,350'-9,420' Kick off Cement Plug Top of Squeeze Cement/Bottom of Kick off Plug at _9,500' Top of SCU 43A-8 5" Liner @ 9,627' SCU 43A-8 7" Section Cut @ .+9,835' 5" Cement Retainer @ _+10,100' SCU 43A-8 Abandoned Wellbore ..~ PBTD @ 10,753' ~ TD @ 10,798' = Cement Note: All depths are measured, corrected to RKB=178', G.L.=152',RKB-G.L.=26' (Original RKB-G.L.=18') SCU 43B-8 Production (~asing Dato Existing Production Casing Size Wt/Grade MinI.D. Drift Pc Pb Tpb Thd ~ 8160 676 BTC 746 7240 604 BTC 667 6340 532 BTC 588 7240 604 BTC 667 8160 676 BTC 746 11220 929 8RD 797 7 29/N80 6.184 6.059 7020 7 26/N80 6.276 6.151 5410 7 23/N80 6.366 6.241 3830 7 26/N80 6.276 6.151 5410 7 29/N80 6.184 6.059 7020 7 29/P110 6.184 6.059 8510 Calculation Options: Sour gas not considered Bouyancy considered Existing Design Inside mud weight=12.0 ppg Outside mud weight=8.9 ppg Burst backup gradient=0.465 Maximum shut in Design factors: psi/ft pressure=5000 psi C=I.000 B=I.100 TJ=I.800 Casing-Cumulative Loads Depth Collapse Burst Tension 10892 5031 6719 -42510 8471 3913 6337 27699 8471 3913 6337 27699 6658 3075 6051 80276 6658 3075 6051 83045 4818 2225 5760 130885 4818 2225 5760 132874 1150 531 5181 217238 1150 531 5181 216763 302 139 5048 238811 302 139 5048 238685 0 0 5000 247443 (Static) Design Depth C 10892 1.72 8471 2.16 8471 1.77 6658 2.18 6658 1.69 4818 2.26 4818 1.62 1150 6.35 1150 8.76 302 >10 302 >10 0 >10 Factors-Calculated B TJ TPB RTJ RTPB 1.67 .... 1.77 >10 >10 >10 >10 1.29 >10 >10 >10 >10 1.35 9.29 8.42 7.02 6.36 1.20 8.03 7.27 6.28 5.68 1.26 5.10 4.61 4.52 4.09 1.10 4.43 4.00 3.98 3.60 1.22 2.71 2.45 2.66 2.41 1.40 3.08 2.79 3.02 2.74 1.43 2.79 2.53 2.78 2.52 1.62 3.13 2.83 3.11 2.82 1.63 3.01 2.73 3.01 2.73 TPB=l.500 Tension 0 60760 106261 106261 106261 147685 147685 220773 220773 239864 239864 247443 Depth 0-302' 302-1150' 1150-4818' 4818-6658' 6658-8471' 8471-10892' (Running) SCU 43B-8 Production Casing Data-cont, Critical Depth Mud Weight Surface (feet) (ppg) (psi) 4818 9.0 6330 4818 10.0 6080 4818 11.0 5830 4818 12.0 5580 4818 13.0 5330 4818 14.0 5080 4818 15.0 4830 4818 16.0 4579 Shut-in Casing Rupture SCU 43B-8 5" Liner Design Factors Casing 5", 18#/ft, N80, FL4S, R3 Collapse (psi) Burst (psi) Pipe Body Yield Joint Strength (M Make up Torque Tube I.D. Joint I.D. Drift I.D. (M lb) lb) 10,490 10,140 422 274.4 4,000 4.276 4.176 4.151 (minimum parting load) Capacity (BPF) (ft3/ft) 0.0177 0.0997 Setting Depths (ft) Total Footage (ft) 9,050 to 10,800 TD 1,750 TENSION (Air Wt.) Joint Strength String Weight 274,400/(1750)(18.0) 8,71 Pipe Body Yield String Weight 422,000/(1750)(18.0) 1;3,4 COLLAPSE (Void Csg.) 1. Assume 12 ppg 2. Annulus full of mud weight maximum mud Collapse (TD) Annular Pressure 10,490/(10,800)(12.0)(.052) 1,55 Collaose -- Annular BURST (TOL) = 10,490/(9,050)(12.0)(.052) Pressure (Top and Bottom) 1,85 Tot} Burst -- 1. 2. 3. 4. 5. 6. Worst case during production Backup gradient of 8.9 ppg BHP = 5,000 psi @ TVD w/gas column to surface Tubing leak at surface. Oil packer fluid = 7 ppg Gas gravity = 0.65 SITP = BHP * 1/e (lc * TVD · 0.0000347) where: BHP = Bottom hole pressure = Gas gravity TVD = Total vertical depth SITP = (5,000)(1/e(0'65x10,800x0'0000347)) = 3920 psi Top Burst Burst Rating + Backup SITP + Packer Fluid 10.140 + (8.9)(.052)(9,050) = 1,98 3920 + (7.0)(.052)(9,050) Bottom B~lrSt 1. Worst case during treating or frac-away 2. Max treating pressure = 5,000 psi 3. Fluid weight = 8.9 ppg 4. Backup gradient = 8.9 ppg Bottom Burst = Burst Rating + Backllp Surface Pressure + Fluid Gradient 10,140 + (8.9)(.052)(10.800) = 1,51 5,000 + (8.9)(.052)(10,800) SCU 43B-8 Density Drilling Fluids Program From Sidetrack Point Total Depth 10.0-11.0 Funnel Viscosity 38-46 PV 12-18 YP 8-12 Initial Gels 2- 10 10 minute Gels 5-20 Fluid Loss 15-5' pH 8.5-9.5 % Solids 6-12 to * = Maintain fluid loss at 10cc or less below 10,200' TVD Drilling Fluid System - Dual tandem shale - Mud cleaner - Centrifuge - Degasser - Pit level indicators - Trip tank - Fluid flow sensor - Fluid agitators shakers (visual and audio alarm) EPA, OCS APPROVED DRILLING MUDS This table may be periodically updated by EPA. If so, the latest version supersedes all earlier versions. Updated versions are available, from EPA, upon request. Components Maximum Allowable Concentration (lb/bbl) Comnonents Maximum Allowable Concentration (Ib/bbl) 1. Seawater/Freshwater/Potassium/ Polymer Mud 4. Nondispersed Mud KCI 50 Starch 12 Cellulose Polymer 5 Xanthan Gum Polymer 2 Drilled Solids 100 Caustic 3 Barite 575 Seawater or Freshwater As needed Bentonite* 50 Acrylic Polymer 2 Lime 2 Barite 180 Drilled Solids 70 Seawater or Freshwater As Needed 5. Spud Mud 2. Lignosulfonate Mud . Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome Treated 10 Caustic 5 Lime Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 5 Seawater or Freshwater As needed Lime Mud Lime 20 Bentonite* 50 Lignosulfonate, Chrome or Ferrochrome 15 Lignite, Untreated or Chrome- Treated 10 Caustic 5 Barite 575 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Seawater or Freshwater As needed Lime 2 Bentonite* 50 Caustic 2 Barite 50 Soda Ash/Sodium Bicarbonate 2 Seawater As needed 6. Seawater/Freshwater Gel Mud Lime 2 Bentonite* 50 Caustic 3 Barite 50 Drilled Solids 100 Soda Ash/Sodium Bicarbonate 2 Cellulose Polymer 2 Seawater or Freshwater As needed *Attapulgite, sepiolite, or montmorillonite may be substituted for bentonite. The following additives have been approved by EPA in Alaska. Not all of these additives will necessarily be used during the redrills. Product Name Maximum Allowable Generic_ Description Concentration (lb/bbl) Aktaflo-S Aqueous solution of non-ionic 3 modified phenol (equivalent of DMS) Aluminum stearate Ammonium nitrate Agua-Spot Bara Brine Defoam Ben-Ex Bit Lube II Calcium Carbide Cellophane flakes Sulfonated vegetable ester formulation 0.2 Dimethyl polysiloxane in an aqueous emulsion Vinyl acetate/maleic anhydride copolymer Fatty acid esters and alkyl phenolic sulfides in a solvent base 200 mg/1 nitrate or O.O5 lb/bbl 1% by volume Chemtrol-X Polymer treated humate 5 0.1 Con Det Water solution of anionic 0.4 surfactants D-D DMS Desco CF Duovis As needed As needed Blend of surfactants 0.5 Aqueous solution of nonionic 3 modified phenol Chrome-free organic mud thinner containing 0.5 sulfo-methylated tannin Xanthan gum 2 Product Name Generic Description ,Vlaximum Allowable CQncentration (Ib/bbl) Durenex Lignite/resin blend Flakes of silicate mineral mica -- 45 Gelex Sodium polyacrylate and polyacrylamide Glass beads LD-8 Aluminum stearate in ropoxylated oleylalcohol 10 gal/1500 bbl Lube -106 Oleates in mixed alcohols Lubri-Sal Vegetable ester formulation 2.0% (by volume) MD (IMCO) Fatty acid ester 0.25 Miichem MD Ethoxylated alcohol formulation 0.04 gal/bbl or 0.3 Ib/bbl MiI-Gard Basic zinc carbonate As needed Nut hulls, crushed granular As needed Phosphoric acid esters and triethanolamine 0.4 Plastic spheres Poly RX Polymer treated humate 4 Resinex Reacted pheno-formaldehydeurea resin containing no free phenol, urea, or formaldehyde 4 Selec-Floc High molecular weight poly- acrylamide polymer packaged in light mineral oil 0.25 Sodium chloride 50,000 mg/I chloride Sodium nitrate 200 mg/I nitrate or O.O5 Ib/bbl GRACE DRILL:~NG COMPANY - RIG I154 .1.0,000~ CHOK,~ ~A~4ZFOLD ZH SKZDDSD HOUSS TO PITS/~A8 BUSTEI~ RESERVE PIT (1). 10,000t LINg. FROH ]~3PS - -(2)- 10,0001-C~OSg (3) 4" 10,000t (4) 3" 10,0001 (5) 10 t 000t HYD~~XC CHOKES (~) 3" 5000t (7) 3" x 50004 cROgS ."9) 3" x 5000/ ,9 ) 4" Product Name ,.,eneric Description Sodium polyphosphate-- Maximum Allowable Concentration (Ib/bbl) 0.5 Soltex Sulfonated asphalt residuum Sulf-X ES Therma Check Therma Thin Zinc oxide Sulfono-acrylamide copolymer Polycarboxylic acid salt As needed Torq-Trim I! Liquid triglycerides in vegetable oil Vegetable plus polymer fibers, flakes, and granules 50 VG-69 XC Polymer XO2 Organophilic clay Xanthan gum polymer Ammonium bisulfite 12 0.5 Zinc carbonate and lime -- As needed Grace 154 Drilling Fluids System .. I SCU 43B-8 Proposed Cement Specifications Service Company: BJ Services Cement Cement Additives Weight Yield Water Thick. Fluid ,lob Type (ppg) (ft3/sk) (gal/sk) Time Loss(cc) Saueeze Class G .75% -- 150 sx FL-28, .15% CD-31, 1 gal/hsx FP-6L 15.8 1.15 4.92 4:15 64 Kickoff Class G .9% 65 sx A-2, 1% CD-31, .35% R-11, .2% A-7, 1 gal/hsx FP-6L Liner Spacer MCS-2 10 bbl 16.5 1.06 4.19 2:30 0.5 ppg > Mud Wt. Tail Class G .85 % +140 sx FL-28, .15% CD-31, .15% A-2, 1 gal/hsx FP-6L 15.8 1.15 4.95 3.5 hr 30-40 Notes· · · m Assumes BHST of 175 deg. F and BHCT of 145 deg. F @ 10,700'. Additives defined as follows- FL-28: CD-31: A-2/A-7: R-11: FP-6L: Batch mix slurry. Fluid Loss Dispersant Accelerator Retarder Surfactant Have BJ test all slurries prior to job using water sample from the location's water source. Thickening time includes 1 hour of surface time. Additive concentrations for weighted spacer will be provided by Bi 1:5-5/8' 5000 PSI BOP STAu,( DIAGRAM ACCUMULATOR CAPACITY TEST I I REYENTE c I I I PI PE RAMS I ¢ I I BLI ND RAMS DRILLING SPOOL PIPE RAMS I C 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3500 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN LOCK-DOWN SCREWS IN HEAD. 3. OPEN CASING VALVE(S) ON TUBING HEAD. (MONITOR CASING VALVE FOR FLOW THROUGH OUT BOP STACK TEST). 4. CLOSE ANNULAR PREVENTER AND TEST TO 250 AND 3,500 PSI FOR 10 MINUTES. BLEED TO ZERO. 5. OPEN ANNULAR AND CLOSE TOP PIPE RAMS. TEST TOP PIPE RAMS, CHOKE MANIFOLD VALVES, AND STACK VALVES TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 7. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 250 AND 5,000 PSI FOR 10 MINUTES. BLEED TOZERO PSI. OPEN PIPE RAMS. 8. CLOSE CASING VALVE(S) AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF A NON-FREEZING LIQUID AND ALL VALVES ARE SET IN THE DRILLING POSITION. 9. TEST STANDPIPE VALVES TO 250 AND 5,000 PSI. 10. TEST KELLY COCKS AND INSIDE BOP TO 250 AND 5,000 PSI. 11. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 12. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. FUNCTION TEST BLIND RAMS EACH TIME OUT OF THE HOLE. ALL BOP EQUIPHENT 5000 PSI RATED SOU 43A~ ~ ~ ~ I ~ 8~ OF ~ sIDETrACK OPERATIONS ~ JULY II I I ~ I I .I I . i®l · /~'41 Proposed BHL ~ i IIlOIIIl~, ! I I I I I ARCO ALASKA, INC. SCU 43B-8 Swanson River Unit GREAT LAND DIRECTIONAL DRILLING, INC. Client .... : ARCO ALASKA, INC. Field ..... : SWANSON RIVER UNIT Well..' .... : SCU 43B-8 Section at: N,90.00,E 10/31/90 Computation...: RADIUS OF CURVATURE Survey Date...: 10/31/90 RKB Elevation.: 171.00 ft Magnetic Dcln.: 24.00 E STATION IDENTIFICATION SIDETRACK KOP, TURN TO N 90.00 E, BUILD 1.48 DEG 9350 2.25 RECORD OF SURVEY (Calculated from a tie-in station at 9350 MD) MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES DL DEPTH ANGLE BKB SUB-SEA DISTNCE BEARING FROM-WELL-MEAD /100 9347.7 9176.7 -38.2 N 1.00 W 118.0 N 38.2 W <TIE END OF TURN & BUILD 9450 3.73 9447.6 9276.6 -34.9 N 90.00 E 121.3 N 34.9 W 1.53 rARGET/BHL 10805 3.73 10799.7 10628.7 53.2 N 90.00 E 121.3 N 53.2 E 0.00 (SCU43B8) Great L an~ Directional Dr~'lllng. <KB>O 800 tSO0 ~, 2400 3000 3600 4200 4800 T 5400 · ' ! VERTICAL SECTION VIEW ARCO ALASKA, INC. SCU 438-8 Section at: N 90.00 E TVD Scale.: ! inch = 1200 feet Dep Scale.: ! inch = 1200 feet Drawn .....: Marker Identification MD TVO SECTN INCLN A) KB 0 0 0 0.00 B) SIDETRACK KOP 9350 9348 -38 2.25 C) END OF TURN ~ BUILD 9450 9448 -35 3.73 D) TI3 iOB05 10800 53 3.73 0 6000 6600 7200 7800 8400 9000 9600 10200 10800 t200 SCL 43A-9 ! SCU 43R-9 600 0 600 i200 i800 2400 3000 3600 4200 4800 Section Oepaptupe 9200 93OO 9400 9500 9600 9700 9800 9900 t0000 I T totoo V D lo~oo 10300 10400 i0500 10600 10700 tOBO0 tOgO0 tt000 ~00 lO0 G?eab Lmnd Directional D?llllng, Zn£. I-- VERTICAL SECTION VIEW ARCO ALASKA, INC. ISCU 438-8 Section at: N 90.00 E TVD Scale.: 1 inch = 200 feet Oep Scale.: ! inch = 200 feet Drawn .....: 11/01/90 Marker Identification MD TVD SECTN INCLN A} SIDETRACK KOP 9350 9348 -38 2.25 B) END DF TURN ~ BUILD 9450 9448 -35 3.73 10805 t0800 53 3.73 I C) 'ID I t I 1 ' - t00 200 300 400 500 Section Departure 600 700 BO0 A ! i30 i20 iiO 9O 8O 7O 6O 5O Marker Identification NO N/S E/ii A) KB 0 ON OE B) SIDETRACK KOP 9350 ii8 N 38 C)ENO OF TURN ~ BUILD 9450 D)TD i0805 i2! N 53 E PLAN VIEN ARCO ALASKA, INC. SCU 438-8 CLOSURE ..... : 133 ft N 23.69 E DECLINATION.: 24.00 E SCALE ....... : ! inch = 20 feet DRANN ....... : i~/0~/90 4o 3o 2o io iO 60 % 50 40 30 20 "~ J_~/ 0 iO 20 30 40 50 60 <- i~EST ' EAST -> I I ! I ! GREAT LAND Client .... : Field ..... : Well ...... : Section at: Engineer..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. SWANSON RIVER UNIT SCU 43A-8 N,90.00,E INC. MEAS DEPTH 0 100 20O 300 400 INCLN VERTICAL-DEPTHS ANGLE BKB SUB-SEA 0.00 0.0 -171.0 0.50 100.0 -71.0 0.50 200.0 29.0 0.00 300.0 129.0 0.00 400.0 229.0 500 0.50 500.0 329.0 600 0.25 600.0 429.0 700 0.25 700.0 529.0 800 0.25 800.0 629.0 900 0.50 900.0 729.0 1000 0.50 1000.0 829.0 1100 0.25 1100.0 929.0 1200 0.25 1200.0 1029.0 1300 0.00 1300.0 1129.0 1400 0.00 1400.0 1229.0 L 1500 0.25 1500.0 1329.0 L 1600 0.25 1600.0 1429.0 L 1700 1.25 1700.0 1529.0 L 1800 2.75 1799.9 1628.9 L 1900 2.00 1899.8 1728.8 · 2000 1.50 1999.8 1828.8 *Survey Codes: 1/SINGLE 8HOT SECTION DISTNCE 0.0 0.1 0.6 0.7 0.7 RECORD OF SURVEY DIRECTION BEARING S 0.00 W S 32.0O E S 30.00 E S 0.00 W S 0.00 W Computation...: Survey Date...: RKB Elevation.: Reference ..... : Magnetic Dcln.: 11/Ol/9O RELATIVE-COORDINATES FROM-WELL-HEAD RADIUS OF CURVATURE 11/Ol/9O 171.00 ft 24.00 E 0.0N 0.0E 0.48 0.1E 1.28 0.6E 1.68 0.7E 1.68 0.TE 0.4 N 10.00 W 1.6 S 0.4 E 0.3 N 14.00 W 1.0 S 0.3 E 0.1 N 20.00 W 0.5 S 0.1E -0.0 N 22.00 W 0.1S 0.0 W -0.2 N 11.00 W 0.5 N 0.2 W -0.3 -0.5 -0.8 -0.9 -0.9 -0.9 -1.2 -1.4 -2.6 -4.2 N 4.00W N30.00W N53.00W N 0.00E N 0.00E CLOSURE DISTNCE BEARING ---- 0.0 N 90.00 E 0.4 S 16.00 E 1.3 S 26.06 E 1.7 S 23.30 E 1.7 S 23.30 E /ioo 0.00 0.50 0.00 0.50 0.00 1.7 S 13.59 E 0.50 1.0 S 14.64 E 0.25 0.6 S 12.81 E 0.00 0.1 S 12.91 W 0.00 0.5 N 24.08 W 0.25 1.4N 0.3W 2.0N 0.5W 2.3N 0.SW 2.5N 0.9W 2.5N 0.9W N 8.00 W S 5.00 W S 15.00 W 8 24.00 W S 22.00 W 1.4 N 13.78 W 0.00 2.0 N 14.80 W 0.25 2.4 N 19.39 W 0.00 2.6 N 19.96 W 0.25 2.6 N 19.96 W 0.00 2.7N 0.9W 2.7N 1.2W 1.4N 1.4W 1.98 2.6W 5.78 4.2W -5.3 S 20.00 W 8.5 S 5.3 W 2.9 N18.75W 0.25 3.0 N 24.27 W 0.00 2.0 N 45.70 W 1.00 3.2 S 54.20 W 1.50 7.1 S 36.58 W 0.75 10.1 S 31.90 W 0.50 ' SCU43A8 ) SCU 43A-8 MEAS INCLN DEPTH ANGLE 2100 1.00 2200 1.00 2300 0.50 2400 0.75 2500 0.75 2600 2700 2800 2900 3000 L 3100 L 3200 L 3300 L 3400 L 3500 3600 3700 3800 3900 4000 VERTICAL-DEPTHS BKB SUB-SEA 2099.7 1928.7 2199.7 2028.7 2299.7 2128.7 2399.7 2228.7 2499.7 2328.7 SECTION DISTNCE RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD -6.2 S 28.00 W 10.5 S 6.2 W -7.0 S 29.00 W 12.1S 7.0 W -7.8 S 47.00 W 13.1 S 7.8 W -8.6 S 44.00 W 13.9 S 8.6 W -9.8 N 84.00 W 14.3 S 9.8 W 0.75 2599.7 2428.7 -11.1 1.25 2699.7 2528.7 -12.6 1.00 2799.7 2628.7 -14.2 0.75 2899.7 2728.7 -15.5 1.25 2999.6 2828.6 -16.6 1.00 3099.6 2928.6 -18.1 0.50 3199.6 3028.6 -19.2 0.50 3299.6 3128.6 -19.9 0.75 3399.6 3228.6 -20.6 0.75 3499.6 3328.6 -21.0 0.75 3599.6 3428.6 -21.3 0.50 3699.6 3528.6 -21.7 0.50 3799.6 3628.6 -22.0 0.50 3899.6 3728.6 -21.8 0.50 3999.6 3828.6 -21.6 N 76.00 W 14.1 S 11.1 W N 46.00 W 13.2 S 12.6 W N 66.00 W 12.1 S 14.2 W N 45.00 W 11.3 S 15.5 W N 36.00 W 10.0 S 16.6 W N 63.00 W N 49.00 W N 68.00 W N 12.00 W N 21.00 W 4100 0.50 4099.6 3928.6 4200 0.50 4199.6 4028.6 4300 0.00 4299.6 4128.6 4400 0.00 4399.6 4228.6 4500 0.50 4499.6 4328.6 N 8.00 W N 41.00 W N 5.00 E N 14.00 E N 13.00 E -21.4 N 16.00 E -21.3 N 4.00 E -21.3 N 0.00 E -21.3 N 0.00 E -21.2 N 7.00 E -21.2 N 2.00 E 4600 0.50 4599.6 4428.6 8.7S 18.1W 8.0S 19.2W 7.5S 19.9W 6.7S 20.6W 5.4S 21.0W 4.2S 21.3W 3.2S 21.7W 2.4S 22.0W 1.5S 21.8W 0.7S 21.6W 0.2N 21.4W 1.0N 21.3W 1.5N 21.3W 1.5N 21.3W 1.9N 21.2W 2.8N 21.2W Page 2 11/01/90 CLOSURE D I STNCE BEARING 12.2 S 30.50 W 14.0 S 30.25 W 15.3 S 30.91 W 16.3 S 31.87 W 17.3 S 34.46 W 17.9 S 38.27 W 18.3 S 43.61 W 18.7 S 49.52 W 19.1 S 53.92 W 19.4 S 59.07 W 20.1 S 64.34 W 20.8 S 67.45 W 21.3 S 69.35 W 21.6 S 71.97 W 21.7 S 75.43 W 21.7 S 78.88 W 22.0 S 81.61 W 22.1 S 83.78 W 21.9 S 85.98 W 21.7 S 88.18 W 21.4 N 89.58 W 21.3 N 87.27 W 21.3 N 86.10 W 21.3 N 86.10 W 21.3 N 84.92 W 21.3 N 82.58 W 11oo 0.50 0.00 0.50 0.25 0.01 0.00 0.50 0.25 0.25 0.50 0.25 0.50 0.00 0.25 0.00 0.00 0.25 0.00 0.00 0.00 0.00 0.00 0.50 0.00 0.50 0.00 Survey Codes: 1/SINGLE SHOT SCU 43A-8 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 1 4700 0.75 1 4800 0.00 1 4900 0.50 1 5000 0.75 1 5100 0.25 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 4699.5 4528.5 -21.5 N 44.00 W 3.7 N 21.5 W 4799.5 4628.5 -21.8 N 0.00 E 4.3 N 21.8 W 4899.5 4728.5 -22.0 N 47.00 W 4.7 N 22.0 W 4999.5 4828.5 -22.7 N 36.00 W 5.5 N 22.7 W 5099.5 4928.5 -23.4 N 74.00 W 6.0 N 23.4 W 5200 0.50 5300 0.50 540O 0.50 5500 0.50 5600 0.75 5199.5 5028.5 -23.9 N 48.00 W 6.3 N 23.9 W 5299.5 5128.5 -24.2 N 16.00 E 7.1 N 24.2 W 5399.5 5228.5 -24.4 N 50.00 W 7.9 N 24.4 W 5499.5 5328.5 -25.1 N 48.00 W 8.5 N 25.1 W 5599.5 5428.5 -25.5 N 5.00 W 9.5 N 25.5 W 570O 0.75 5800 1.00 5900 1.00 6000 1.50 6100 1.75 5699.5 5528.5 -25.5 N 12.00 E 10.8 N 25.5 W 5799.5 5628.5 -25.1 N 12.00 E 12.3 N 25.1 W 5899.5 5728.5 -24.8 N 8.00 E 14.0 N 24.8 W 5999.5 5828.5 -24.7 N 2.00 E 16.1 N 24.7 W 6099.4 5928.4 -25.1 N 19.00 W 18.9 N 25.1 W 6200 2.00 6300 2.50 6400 2.25 6500 2.25 6600 2.25 6199.4 6028.4 -26.2 N 21.00 W 22.0 N 26.2 W 6299.3 6128.3 -27.3 N 11.00 W 25.8 N 27.3 W 6399.2 6228.2 -27.8 N 5.00 W 29.9 N 27.8 W 6499.1 6328.1 -28.6 N 16.00 W 33.7 N 28.6 W 6599.0 6428.0 -29.1 N 0.00 E 37.6 N 29.1 W 6700 2.25 6800 2.25 6900 2.25 7000 1.75 7100 1.50 6699.0 6528.0 -29.3 N 7.00 W 41.5 N 29.3 W 6798.9 6627.9 -29.9 N 8.00 W 45.4 N 29.9 W 6898.8 6727.8 -30.5 N 12.00 W 49.3 N 30.5 W 6998.7 6827.7 -30.8 N 4.00 E 52.8 N 30.8 W 7098.7 6927.7 -30.5 N 6.00 E 55.6 N 30.5 W 7200 1.75 7198.7 7027.7 -30.2 N 8.00 E 58.4 N 30.2 W 'Survey Codes: 1/SINGLE SHOT Page 3 11/01/90 CLOSURE DL DI STNCE BEARING /100 21.9 N 80.13 W 0.25 22.2 N 78.74 W 0.75 22.5 N 77.85 W 0.50 23.3 N 76.26 W 0.25 24.1 N 75.52 W 0.50 24.8 N 75.15 W 0.25 25.2 N 73.53 W 0.00 25.7 N 71.99 W 0.01 26.5 N 71.26 W 0.00 27.2 N 69.68 W 0.25 27.6 N 67.09 W 0.00 28.0 N 64.02 W 0.25 28.5 N 60.65 W 0.00 29.5 N 56.78 W 0.50 31.4 N 52.94 W 0.25 34.2 N 49.96 W 0.25 37.5 N 46.61 W 0.50 40.8 N 42.98 W 0.25 , 44.2 N 40.25 W 0.02 '~' 47.6 N 37.74 W 0.02 50.8 N 35.25 W 0.01 54.4 N 33.32 W 0.00 58.0 N 31.79 W 0.01 61.1 N 30.27 W 0.50 63.4 N 28.79 W 0.25 65.7 N 27.34 W 0.25 SCU 43A-8 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 7300 2.00 7400 1.75 7500 1.75 7600 1.25 7700 1.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION DISTNCE BEARING 7298.6 7127.6 -30.2 N 10.00 W 7398.6 7227.6 -30.8 N 11.00 W 7498.5 7327.5 -31.1 N 1.00 E 7598.5 7427.5 -31.3 N 10.00 W 7698.5 7527.5 -31.5 N 3.00 W RELATIVE-COORDINATES FROM-WELL-HEAD 61.7 N 30.2 W 64.9 N 30.8 W 67.9 N 31.1 W 70.5 N 31.3 W 72.5 N 31.5 W 7800 1.25 7798.4 7627.4 -31.7 N 4.00 W 7900 1.00 7898.4 7727.4 -31.8 N 4.00 W 8000 1.25 7998.4 7827.4 -32.0 N 7.00 W 8100 1.50 8098.4 7927.4 -32.5 N 16.00 W 8200 1.25 8198.3 8027.3 -33.0 N 10.00 W 74.4 N 31.7 W 76.4 N 31.8 W 78.3 N 32.0 W 80.7 N 32.5 W 83.0 N 33.0 W 8300 1.50 8298.3 8127.3 -33.4 N 9.00 W 8400 1.25 8398.3 8227.3 -33.9 N 14.00 W 8500 1.25 8498.3 8327.3 -34.4 N 15.00 W 8600 1.25 8598.2 8427.2 -35.1 N 19.00 W 8700 1.25 8698.2 8527.2 -35.8 N 23.00 W 85.4 N 33.4 W 87.7 N 33.9 W 89.8 N 34.4 W 91.9 N 35.1 W 94.0 N 35.8 W 8800 2.00 8798.2 8627.2 -36.6 N 10.00 W 8900 3.00 8898.1 8727.1 -37.2 N 5.00 W 9000 2.25 8998.0 8827.0 -37.5 N 2.00 W 9100 2.00 9097.9 8926.9 -37.6 N 0.00 E 9200 1.75 9197.8 9026.8 ' -37.8 N 8.00 W 96.7 N 36.6 W 101.0 N 37.2 W 105.6 N 37.5 W 109.3 N 37.6 W 112.5 N 37.8 W 9300 2.25 9297.8 9126.8 -38.1 N 3.00 W 9350 2.25 9347.7 9176.7 -38.2 N 1.00 W 9400 2.25 9397.7 9226.7 -38.2 N 1.00 E 9500 2.25 9497.6 9326.6 -38.2 N 2.00 W 9600 2.25 9597.6 9426.6 -39.0 N 20.00 W 116.0 N 38.1 W 118.0 N 38.2 W 119.9 N 38.2 W 123.9 N 38.2 W 127.7 N 39.0 W 9700 2.25 9697.5 9526.5 -40.5 N 26.00 W 131.3 N 40.5 W 'Survey Codes: 1/SINGLE SHOT N/INTERPOLATED Page 4 11/01/90 CLOSURE DISTNCE BEARING 68.7 N 26.13 W 71.8 N 25.43 W 74.7 N 24.61 W 77.2 N 23.95 W 79.0 N 23.52 W 80.9 N 23.04 W 82.7 N 22.60 W 84.6 N 22.21 W 87.0 N 21.92 W 89.3 N 21.68 W 91.7 N 21.36 W 94.0 N 21.11 W 96.2 N 20.96 W 98.4 N 20.87 W 100.6 N 20,88 W 103.4 N 20.76 W 107.6 N 20.22 W 112.0 N 19.55 W 115.6 N 18.97 W 118.7 N 18.56 W 122.1 N 18.19 W 124.0 N 17.94 W 125.9 N 17.66 W 129.6 N 17.15 W 133.5 N 16.97 W 137.4 N 17.14 W /lOO 0.25 0.25 O.Ol 0.50 0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.25 0.00 0.00 0.00 0.75 i .00 0.7,~ 0.25 0.25 0.50 0.01 0.01 0.00 0.03 0.01 SCU 43A-8 Page 5 11/01/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 1 9800 N 9830 1 10018 1 10080 i 10119 VERTICAL-DEPTHS BKB SUB-SEA DISTNCE 2.25 9797.4 2.25 9827.4 2.00 10015.2 2.75 10077.2 3.00 10116.1 SECTION DIRECTION RELATIVE-COORDINATES BEARING FROM-WELL-HEAD 9626.4 9656.4 9844.2 9906.2 9945.1 -41.9 N 16.00 W -42.2 N 10.90 W -47.5 S 35.00 W -48.8 S 23.00 W -49.6 S 23.00 W 135.0 N 41.9 W 136.1 N 42.2 W 137.3 N 47.5 W 135.0 N 48.8 W 133.2 N 49.6 W CLOSURE DL DISTNCE BEARING /100 141.3 N 17.25 W 0.02 142.5 N 17.22 W 0.03 145.3 N 19.10 W 0.16 143.6 N 19.87 W 1.2] 142.1 N 20.40 W 0.64 1 10170 1 10227 i 10318 i 10360 I 10447 3.75 10167.1 9996.1 4.25 10223.9 10052.9 6.25 10314.5 10143.5 7.25 10356.2 10185.2 8.25 10442.4 10271.4 -50.5 S 15.00 W -51.4 S 10.00 W -51.5 S 8. O0 E -50.3 S 21.00 E -46.2 S 20.00 E 130.4 N 50.5 W 126.5 N 51.4 W 118.2 N 51.5 W 113.4 N 50.3 W 102.5 N 46.2 W 139.8 N 21.18 W 1.47 136.5 N 22.11 W 0.88 129.0 N 23.55 W 2.21 124.1 N 23.91 W 2.43 112.4 N 24.27 W 1.15 10482 10550 10666 10762 10790 9.25 10477.0 10306.0 9.50 10544.1 10373.1 10.00 10658.5 10487.5 11.75 10752.7 10581.7 11.75 10780.1 10609.1 -44.2 S 24.00 E -39.5 S 26.00 E -30.6 S 28.00 E -21.0 S 36.00 E -17.7 S 36.00 E 97.5 N 44.2 W 87.5 N 39.5 W 70.0 N 30.6 W 54.6 N 21.0 W 50.0 N 17.7 W 107.1 N 24.38 W 2.87 96.0 N 24.31 W 0.38 76.4 N 23.62 W 0.43 58.5 N 21.03 W 1.86 53.0 N 19.44 W 0.00 'Survey Codes: 1/SINGLE SHOT N/INTERPOLATED (8) (4) Cas~ (.1.~ r.i:.ru 22) Company (,7.,.J :Jar: 28) Lease & We!! 1. Is :he pe.--~: fee a=:ached ,. .......................................... Z. Is ye!! to' be located ia a de~i~ed pool ............................. ~_ 3. Is well located proper distance from property lite .................. 4. Is w~e!i located proper dis:anco from other ve!ls ........ ~ ........... 5. is suffi:ien: undedicaued acreage ay ~a/.lahle in this pool ............ 6. Is well :o be deviated and is wellbora plat included ................ 7. Is operator =he o~ly affected party. ................................. ~._ 8. Cam perm,: be approved before f~:~=ueen-day wai= ....................... NO 9. Does operator have a bond in force .................................. 10. Is a conserve:ion order needed ...................................... i!. Is aH~*~*~=.-a:±ve appr~va~ naeda~ ................................... 12.' ~ ~e la~e n~ appropr~ta .................... 13. Do~ ~e ve~ ~ve a ~que ~e ~d :~er ..................... ' .... ' . -- 14. iS c6n~ucuor s:~E pro~ded ........................................ , , ~. ~ suvaco c~g protect ~ zones reaso~iy se~e ~ ~ ~der~o~d so~ce of d~~g ~auar ..................... 16. ~ ~ough c~ ~ed ~o Ca, ua on conducuor =d suvaco ......... , ,,, I7. W~l c~: ~ie ~ ~r~ace ~d ~ua~a~ua or produc~ stags ....' 18. ~1 c~: cover ~1 ~ productive 20. ~ :~s we~ :o be ~c~d off ~r~m ~ 21. Is old ~bora ab~do~= procedure ~. Is a ~ve~ar ~sc~ re~ed ....................................... . 2~. Is ~e d~~g find pro,r= s~e~:ia ~. ~e nacess~ ~a~r~ ~d desc~p=ions of 26. Does BOPE ~ve s~fi=i~: pres~re rau~E - 17. Does ~e ~oka ~=~**oi~ c~ly w/~I ~-53 (~y 2~. ~ ~e pr~ca of EZS gas probable ............................. ~... . . rev: 01/30/89 6.011 POT emp. loratory a~ SUraui~rsp. hic we!isr 29. Are da:a presented on potential overpressure zones? ................. 30. Ars seismic analysis ~a:a presented on shallow gas zones .............. 31. If a: offshore loc., are survey resul:s of seabed condi:ions prese~mtad 32. Ad. cLtr~az:.a.1 req~d.z'eme~:s ............................................. ' ~IIiAL '1' GF_.O'. i UNiT i'ONlO~2 - ,Pool ,,, c....~$ s-'.,-A-m::rs ~ 't,fo: ,, s'~,o~ , ! Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special'effort has been made to chronologically organize this category of information. PROGRAM: LISCAN REVISION: 5.2 PART NUMBER: W5790-MICRO Start of execution: Thu 21 FEB 91 11:38a **** REEL HEADER **** LIS 91/ 2/21 AWS 01 RECEIVED MAR 1 ~ 1991 011 & Gas Cons. Co_mm.i~J~r~ **** TAPE HEADER **** LIS 91/ 2/21 01 FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * API NO. 50-133-10121-02 LOG DATE: 2/20/91 FILE 1 = MAIN PASS NUMBER 1: PDK-100/GR/CCL (5270 - 7340 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES · NAME CODE SAMPLE# UNIT 1 BKL 68 1 CPS 2 BKS 68 1 CPS 3 CCL 68 1 DIM 4 CSS 68 1 API 5 G1 68 1 CPS 6 G2 68 1 CPS 7 GElS 68 1 CPS 8 GR 68 1 API 9 ISS 68 1 CPS 10 LS 68 1 CPS 11 MON 68 1 CPS 12 MSD 68 1 SU 13 RATO 68 1 DIM 14 RBOR 68 1 DIM 15 RICS 68 1 DIM 16 RIN 68 1 DIM 17 SGMA 68 1 SU 18 SPD 68 1 F/MN 19 SS 68 1 CPS BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD DEPTH G1 LS RICS (TYPE# 0) BKL G2 MON RIN 966 BYTES * BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 7340.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7290.000 6083.355 1085.821 17.87625 29.66600 1371.395 2311.605 10.60938 198.4090 102777.6 0.3651477 22.43011 0.0000000E+00 23.08847 21.05357 22.99770 16397.02 295778.6 1.838010 22820.14 7240.000 7894.336 1366.170 16.67021 43.58101 2337.108 2324.859 10.94519 249.8130 109074.7 0.4002585 18.54620 128.5500 20.42586 18.02132 22.99770 18116.51 318042.6 1.837863 24550.10 7190.000 8499.168 1513.889 16.48198 55.62700 2664.385 2320.992 10.39694 172.9910 109221.1 0.2205113 17.87852 0.0000000E+00 23.39319 17.34219 22.99770 18907.86 312925.3 1.815844 26208.53 7140.000 5970.145 1133.686 17.93105 66.69701 1293.015 2309.446 11.09558 195.8790 111152.0 0.5853376 23.19868 0.0000000E+00 29.24197 20.80348 23.76180 17085.75 312092.6 1.889564 23524.02 7090.000 6800.781 1245.292 18.12115 64.22301 1550.454 2325.774 10.90568 262.7620 110968.4 0.4959162 22.20340 0.0000000E+00 30.48483 19.68671 23.65260 17789.28 315719.2 1.861003 24566.82 7040.000 6413.910 1110.733 17.64658 97.68300 1465.735 2296.809 11.05534 252.2230 107925.3 0.3183661 22.09560 0.0000000E+00 31.45674 21.23686 23.99760 17135.06 308204.5 1.889608 23560.09 6990.000 5685.078 1034.350 18.57668 97.59702 1281.673 2294.730 11.13244 209.2690 105062.2 0.5913289 22.70169 0.0000000E+00 34.79918 22.08066 23.99760 16359.71 302444.4 1.886942 22883.79 6940.000 6314.383 1083.979 17.94849 57.28999 1481.937 2286.993 10.85480 251.2270 104145.1 0.3110206 22.49927 0.0000000E+00 34.01408 21.85318 23.99760 16784.62 298146.4 1.860572 23706.18 6890.000 5900.203 1057.242 17.56219 46.93800 1325.029 2278.415 10~61782 204.9340 99748.25 0.3841601 22.92220 0.0000000E+00 19.22632 20.61708 23.99760 15801.59 290056.5 1.799710 21879.03 6840.000 5698.785 997.5110 17.93979 82.51700 1333.283 2297.352 10.78314 202.1150 100464.9 0.6698409 22.31909 0.0000000E+00 20.14270 22.11975 23.99760 15875.68 289160.4 1.833765 22091.86 6790.000 5447.734 1060.107 18.35426 48.34300 1172.143 2282.501 10.75832 161.5870 97918.50 0.6445410 23.69273 0.0000000E+00 14.47347 20.80560 23.88840 15546.64 278514.5 1.801667 21982.93 6740.000 7707.359 1333.549 17.44647 49.04900 2270.177 2308.002 10.95101 209.7500 108897.6 0.4944326 18.87212 0.0000000E+00 22.75583 18.95340 23.99760 18301.53 320141.8 1.873346 25290.16 6690.000 9521.770 1779.734 16.66039 60.90501 3211.151 2323.447 10.60427 167.2490 119126.3 0.4455214 16.52071 50.99998 20.61305 15.34451 23.99760 20422.13 331792.2 1.865446 27317.95 6640.000 7168.523 1268.923 17.61980 74.39700 1881.201 2305.448 10.80668 244.4020 109677.2 0.4093137 20.20735 0.0000000E+00 30.23035 19.24678 22.99770 17763.95 310542.8 1.845733 24449.43 6590.000 9225.422 1567.696 16.33034 6540.000 5882.898 1058.756 18.70979 6490.000 8006.797 1517.356 16.83131 6440.000 6423.742 1148.420 17.63023 6390.000 6205.297 1111.308 18.03400 6340.000 5566.297 1035.895 18.15434 6290.000 8935.047 1557.929 16.58255 6240.000 8415.129 1470.170 16.60513 6190.000 5749.543 1041.762 17.52139 6140.000 5323.965 984.9500 18.24440 55.33400 3035.836 2290.087 10.44165 94.70399 1283.644 2275.894 11.00762 56.25500 2385.528 2302.440 10.56001 90.59402 1417.875 2291.257 10.50658 85.03300 1216.183 2278.178 10.77368 91.03902 1173.469 2239.495 10.71180 67.84300 2936.271 2288.073 10.76354 67.85001 2674.497 2260.731 10.51474 43.04201 1238.379 2200.887 10.17402 82.14999 1058.037 2210.085 10.58437 247.5570 111791.6 0.5145886 17.28973 225.5270 106488.2 0.4532842 23.28484 227.9460 111671.6 0.4763662 18.68256 279.7529 109381.8 0.7902610 22.69966 283.8889 109663.4 0.2609504 24.29517 219.8370 101665.6 0.4115397 23.71851 279.9719 109529.6 0.2781409 16.98886 227.0290 110239.0 0.4716082 17.46875 194.8020 98793.56 0.4238381 23.99590 231.1790 102210.2 0.6896617 25.08780 613.2000 20.32312 17.19821 23.99760 0.0000000E+00 31.78415 21.77473 22.99770 0.0000000E+00 25.34225 17.61807 22.99770 0.0000000E+00 34.75462 21.14665 23.99760 0.0000000E+00 35.74110 21.83324 23.76180 0.0000000E+00 19.24013 21.23447 22.99770 0.0000000E+00 24.61455 17.30658 22.99770 0.0000000E+00 28.28951 17.46570 23.99760 0.0000000E+00 18.30853 21.34764 24.34261 0.0000000E+00 32.59634 22.58479 23.88840 19665.73 320527.3 1.873489 26914.26 16530.22 306702.7 1.850204 23036.73 19017.56 315211.1 1.821294 26741.27 17388.18 308035.7 1.835836 24311.92 17176.29 309305.6 1.846026 24283.74 15864.02 285084.6 1.855465 22101.97 19304.52 318624.6 1.835473 26939.52 18898.62 311570.9 1.846561 25697.62 15737.77 276467.4 1.794911 22231.51 15922.84 290227.5 1.825883 22309.68 6090.000 7053.605 1362.238 17o87340 6040.000 5790o531 1186.597 18.28168 5990.000 3946.797 949.4890 18o91527 5940.000 6327.551 1257o249 17.91650 5890.000 4231.473 1014.840 19.55452 5840.000 8705o812 1972.149 16.89807 5790.000 5004.012 1058.850 18.34155 5740.000 5506.207 1159.092 19.14334 5690.000 5139.187 1060.956 19.37785 5640.000 3764.324 924.2661 19.43358 63.79701 2055.757 2276.590 10.67651 69.31401 1380.060 2257.890 10.45026 63.30602 663.7971 2233.859 10.34327 65.54102 1801.661 2264.491 10.49518 120.4140 878.5461 2243.046 10.70224 66.42300 3364.374 2269.834 9.480032 81.49899 1031.520 2253.018 10.66633 52.20399 1514.622 2263.564 10.36147 103.4060 1252.942 2240.212 10.33655 103.4730 627.0000 2054.055 10.30792 222.2950 111994.1 0.6143126 18.53465 234.3240 113986.3 0.3732177 21.97462 231.5320 110848.9 0.9823099 28.05072 256.1560 110796.2 0.3720725 19.45718 260.7639 116627.7 0.6890682 24.71001 245.8540 119105.6 0.5645040 14.32033 225.7350 113488.6 0.5823197 25.32074 201.3210 111467.4 0.2076372 20.08549 256.6860 111869.7 0.5190457 21.39407 201.6870 115964.2 0.3595648 28.48503 0.0000000E+00 21.93636 17.72887 24.10680 0.0000000E+00 34.01573 19.37866 23.45190 0.0000000E+00 26.32106 22.03894 24.88831 0.0000000E+00 24.21371 18.73038 23.10690 0.0000000E+00 40.80392 19.95715 23.99760 0.0000000E+00 21.88464 12.39291 24.99750 0.0000000E+00 29.47888 21.64574 24.34261 0.0000000E+00 22.10669 18.00670 23.99760 0.0000000E+00 31.07884 18.97118 23.99760 0.0000000E+00 27.17683 22.07210 23.99760 17968.70 311487.2 1.911624 24228.35 17140.50 312719.7 1.863465 23017.82 15629.18 302625.8 1.904552 20936.90 17352.08 310291.2 1.894005 23477.95 16059.67 320183.9 1.959926 20395.41 19461.29 327284.6 1.932464 24299.31 16731.77 309783.8 1.849741 22831.44 16219.33 315494.7 1.984156 20850.30 16006.00 309192.1 1.963489 20142.79 15702.10 305260.6 1.995586 20389.02 5590.000 4606.727 1173.209 20.67162 63.70201 1126.007 2266.899 10.58497 224.2760 116107.5 0.3442253 21.77003 0.0000000E+00 31.36029 16.53984 24.34261 15800.64 325109.2 1.994247 19376.18 5540.000 4337.543 995.8142 19.72389 72.04100 741.0972 2276.447 10.78483 292.1079 116167.9 0.3837064 27.52136 0.0000000E+00 37.70869 22.16507 24.76170 16390.97 322478.6 1.919175 22063.23 5490.000 4936.906 970.9919 18.74500 76.85901 886.2761 2204.388 11.01514 202.8840 109203.0 0.3683974 26.49762 0.0000000E+00 34.23524 22.99362 24.99750 16251.97 302579.5 1.857936 22367.24 5440.000 5939.176 1083.175 17.49524 57.27600 1258.097 2153.513 10.31652 205.5430 99599.25 0.3663400 23.43167 0.0000000E+00 16.89412 20.77451 25.34250 15996.71 280199.1 1.789501 22483.20 5390.000 5649.887 1124.904 18.76465 86.87202 1155.078 2230.705 10.85178 238.4570 109142.8 0.3178917 24.24855 0.0000000E+00 31.21149 21.04288 25.76160 16885.65 307123.4 1.893140 23717.09 5340.000 5903.352 1107.706 18.32346 95.71001 1191.183 2189.208 10.66272 269.7080 104677.2 0.6720077 24.09589 0.0000000E+00 32.18440 21.67374 25.23331 16719.77 307083.6 1.792152 24096.73 5290.000 0.0000000E+00 350.0000 -3.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.000000 O.0000000E+00 0.0000000E+00 0.0000000E+O0 O.0000000E+O0 0.0000000E+00 28.64502 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 346 7340.00 ENDING TAPE DEPTH = 5270.00 **** REEL HEADER LIS 91/ 2/21 AWS 01 **** TAPE HEADER **** LIS 91/ 2/21 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * FILE 2 = MAIN PASS NUMBER 2: PDK-100/GR/CCL (9960 - 10730 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME 1 BKL 2 BKS 3 CCL 4 CSS 5 G1 6 G2 7 GElS 8 GR 9 ISS 10 LS 11 MON 12 MSD 13 RATO 14 RBOR 15 RICS 16 RIN 17 SGMA CODE SAMPLE# UNIT BYTES 68 1 CPS 4 68 1 CPS 4 68 1 DIM 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 SU 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 SU 4 18 SPD 19 SS 68 68 F/MN 4 CPS 4 * DATA RECORD DEPTH G1 LS RICS (TYPE# BKL G2 MON RIN o) 966 BYTES * BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 10730.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10680.000 13431.72 2080.766 14.25605 124.6630 5137.781 2152.930 11.71678 187.2240 94069.19 0.9989160E-01 14.73085 0.0000000E+00 32.94008 15.42700 20.99791 21771.12 298537.2 1.629617 32199.22 10630.000 12171.65 1987.379 14.49459 89.40201 4225.359 2152.263 11.87540 219.0970 95474.00 0.1848149 16.04231 0.0000000E+00 35.03157 15.62451 21.99780 20822.19 302463.3 1.676541 31053.55 10580.000 10777.61 1766.139 14.93591 109.7960 3305.087 2151.205 11.97682 190.5140 98740.19 0.3321697 17.93390 0.0000000E+00 46.73656 17.11713 21.76201 20119.29 303826.4 1.645609 30195.92 10530.000 12075.00 1828.770 14.06042 113.0380 4094.823 2153.250 11.97363 186.8040 94519.25 0.2519344 16.33583 0.0000000E+00 37.32515 16.72238 21.88860 20595.36 293291.1 1.658851 30529.37 10480.000 12975.36 2271.772 13.75010 88.64601 4558.633 2152.766 11.54890 284.9001 105765.7 0.2061736 15.73821 0.0000000E+00 44.24409 13.89355 21.34290 22080.07 322660.9 1.718359 31398.13 10430.000 9818.652 1641.665 15.43446 117.0720 2898.873 2154.840 12.02236 214.7630 97808.94 0.1463892 18.72101 0.0000000E+00 40.08774 17.27946 21.99780 19202.84 296093.7 1.673654 28370.81 10380.000 11725.43 1824.784 14.51914 88.73001 3937.128 2154.617 11.82502 232.9240 96030.44 0.4820686 16.87361 0.0000000E+00 36.43127 16.92995 21.99780 20647.73 293108.7 1.636633 30929.89 10330.000 10506.33 1646.293 14.13580 75.91101 3267.743 2155.448 11.99485 219.2950 97463.37 0.3193233 17.72768 0.0000000E+00 24.72298 18.04385 21.99780 19866.25 284043.9 1.652716 29759.27 10280.000 10299.16 1735.134 14.83528 67.16200 3131.836 2155.355 11.75507 213.3430 97107.12 0.2196909 18.05911 0.0000000E+00 28.46071 17.08118 21.99780 19759.11 289332.4 1.636748 29623.42 10230.000 9995.594 1573.755 14.79658 114.9900 2893.725 2154.702 12.12746 252.0840 93161.62 0.1410336 18.76376 0.0000000E+00 42.07463 18.70448 21.99780 19261.68 283233.4 1.588066 29422.21 10180.000 10558.12 1981.695 14.73834 74.24001 3089.830 2156.382 12.07335 250.1910 108850.1 0.3097677 18.74956 0.0000000E+00 20.53047 16.09616 21.99780 21385.80 302384.1 1.630225 31957.81 10130.000 9099.723 1455.195 15.35146 69.06100 2470.616 2153.980 12.11823 178.0420 94971.25 0.35S7388 19.75085 0.0000000E+00 29.03191 19.1979'/ 22.99770 18497.63 282150.0 1.595211 28001.60 10080.000 8291.988 1351.312 15.25436 45.21600 2087.716 2152.108 12.08751 246.5490 91626.44 0.2351385 21.13518 0.0000000E+00 35.55234 20.18022 21.99780 17781.79 277133.5 1.647407 27229.84 10030.000 10110.50 1619.938 14.61084 71.59801 3047.132 2154.053 12.06944 249.0430 94439.12 0.2590464 18.38379 0.0000000E+00 20.82521 17.99811 22.65269 19308.64 285004.1 1.651738 29115.82 9980.000 0.0000000E+00 350.0000 -3.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.000000 Oo0000000E+O0 0o0000000E+O0 O.O000000E+O0 OoO000000E+O0 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.O000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 129 10730.00 ENDING TAPE DEPTH = 9960.00 **** REEL HEADER **** LIS 91/ 2/21 AWS 01 **** TAPE HEADER **** LIS 91/ 2/21 01 FILE # 3 LIS o 001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * FILE 3 = REPEAT SECTION: PDK-100/GR/CCL (10460 - 10730 FT.) FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 19 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 BKL 68 1 CPS 4 2 BKS 68 1 CPS 4 3 CCL 68 1 DIM 4 4 CSS 68 1 API 4 5 G1 68 1 CPS 4 6 G2 68 1 CPS 4 7 GElS 68 1 CPS 4 8 GR 68 1 API 4 9 ISS 68 1 CPS 4 10 LS 68 1 CPS 4 11 MON 68 1 CPS 4 12 MSD 13 RATO 14 RBOR 15 RICS 16 RIN 17 SGMA 18 SPD 19 SS 68 1 SU 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 DIM 4 68 1 SU 4 68 1 F/MN 4 68 1 CPS 4 * DATA RECORD DEPTH G1 LS RICS (TYPE# BKL G2 MON RIN o) 966 BYTES * BKS GElS MSD SGMA CCL GR RATO SPD CSS ISS RBOR SS 10730.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10680.000 11666.79 ~8~ .985 16.38136 114.9990 3955.512 2163.790 12.19849 241.3370 93569.50 0.4138457 16.53802 0.0000000E+00 29.69257 16.40680 21.10710 20137.21 294609.7 1.708944 29820.42 10630.000 12036.92 1932.522 14.04411 77.99901 4040.319 2161.381 11. 66804 222.0970 93750.37 0.2571409 16.57921 0.0000000E+00 35.68488 15.61359 21.99780 20398.83 293292.5 1.689755 30081.91 10580.000 10304.25 1727.418 15.57883 62.15100 3197.114 2158.479 11.82346 240.3020 95342.00 0.2269029 17.63202 0.0000000E+00 42.89392 16.55344 20.99791 19276.37 288999.0 1.682761 28641.43 10530.000 11860.18 1816.415 15.49290 91.66702 4088.600 2159.933 11.86909 224.5350 90410.56 0.6246138 16.21278 0.0000000E+00 30.86797 16.42523 21.88860 20037.74 282121.5 1.685430 29820.38 10480.000 0.0000000E+00 350.0000 -5.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 5.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0o0000000E+00 0.0000000E+00 31.10893 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 -1.000000 0.0000000E+00 TOTAL DATA RECORDS : 46 STARTING TAPE DEPTH = 10730.00 ENDING TAPE DEPTH = 10460.00 **** FILE TRAILER **** **** TAPE TRAILER **** LIS 91/ 2/21 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 543 **** REEL TRAILER **** LIS 91/ 2/21 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 544 TOTAL RECORDS IN THIS PHYSICAL REEL: 544 End of execution: Thu 21 FEB 91 11:39a Elapsed execution time = 56.68 seconds. SYSTEM RETURN CODE = 0 PROGRAM: LISCAN REVISION: 5.2 Start of execution: Tue 19 FEB 91 9:10a **** REEL HEADER **** LIS 91/ 2/19 AWS 01 PART NUMBER: W5790-MICRO **** TAPE HEADER **** LIS 91/ 2/19 01 FILE ~ 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * LOG DATE: 2/17/91 FILE 1 = MAIN PASS: SZDL/CN/GR (10250 - 10740 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 20 CURVES : NAME 1 CAL 2 CHT 3 CN 4 CR2 5 DEV 6 GR 7 HRD1 8 HRD2 9 LSN 10 PE 11 PORZ 12 RB 13 SFT2 14 SHR 15 SPD 16 SSD 17 SSN 18 TTEN 19 ZCOR 20 ZDEN CODE SAMPLE# UNIT BYTES 68 1 IN 4 68 1 LBF 4 68 1 % 4 68 1 IN 4 68 1 DEG 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 BARN 4 68 1 % 4 68 1 DEG 4 68 1 DIM 4 68 1 DIM 4 68 1 F/MN 4 68 1 CPS ,4 68 1 CPS 4 68 1 LBF 4 68 1 G/C3 4 68 1 G/C3 4 * DATA RECORD DEPTH DEV PE SPD ZDEN 10740.000 0.0000000E+00 0.0000000E+00 0.0000000E+00 2.000000 10690.000 350.2861 3.197433 30.99690 2.384809 10640.000 350.3074 2.382966 31.55490 2.388007 10590.000 350.5991 3.400880 30.47461 2.427567 10540.000 350.9875 3.969946 (TYPE# 0) 1014 BYTES * CAL GR PORZ SSD 4.000000 0.0000000E+00 0.0000000E+00 0.0000000E+00 6.155273 68.60062 16.07213 17244.25 5.979099 58.82956 15.87833 17384.72 6.222857 55.73047 13.48079 16541.64 6.662290 62.37212 19.56068 CHT HRD1 RB SSN 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 232.7587 913.6033 10.27637 308.9753 188.4509 965.7551 10.18709 343.5732 375.0173 859.9412 10.19952 508.4050 185.9312 1020.887 9.822172 CN HRD2 SFT2 TTEN -15.00000 0.0000000E+00 0.0000000E+00 3000.000 18.18231 1190.100 791.2546 4075.879 14.79213 1159.057 833.3215 3976.950 7.779374 1080.245 692.3770 4212.105 14.54343 1316.939 808.1135 CR2 LSN SHR ZCOR 4.000O00 0.0000000E+00 0.0000000E+00 -1.500000 3.638370 129.1178 0.5100130 0.3080295E-01 3.658170 161.9855 0.5796570 0.4025643E-01 3.604993 328.2927 0.4963960 -0.9680176E-03 3.903808 142.7762 0.4622652 31.03850 17864.18 2.327249 299.9731 3971.819 0.3995673E-01 10490.000 6.603124 298.4741 24.60812 3.691633 350.6719 83.94449 919.8096 1152.055 87.36101 2.941956 17.16087 10.20046 734.6631 0.5241909 30.99690 17571.60 253.6225 4086.535 0.7402718E-01 2.366845 10440.000 6.503504 170.0350 17.19243 3.811030 350.0974 60.57324 885.0461 1159.863 127.3141 5.144463 15.60946 10.76491 647.1541 0.3908391 30.99690 16982.48 294.5662 3885.135 0.1830644E-01 2.392444 10390.000 6.567594 181.4981 17.12302 3.585849 351.6465 61.83488 936.8064 1226.531 128.0693 5.383627 17.37936 9.895870 717.8669 0.3873730 31.00281 17059.29 295.6008 3871.436 -0.1283814E-02 2.363240 10340.000 8.009010 206.7954 22.14110 3.585849 351.4377 105.9956 1153.650 1650.177 82.20370 8.234854 13.13285 9.533028 775.0979 0.2969040 31.03261 20471.84 222.6579 3914.438 0.1970583 2.433308 10290.000 8.901287 253.1420 11.06812 3.585849 351.4299 44.31854 695.4954 888.0449 206.7199 0.0000000E+00 0.0000000E+00 9.408115 539.3374 0.4403101 30.99690 17118.11 376.2041 3995.058 -1.500000 2.000000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 82 10740.00 ENDING TAPE DEPTH = 10250.00 **** REEL HEADER **** LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 43B-8 FN : SOLDOTNA CREEK UNIT COUN : KENAI STAT : ALASKA * COMMENT RECORD * FILE 5 = MAIN PASS: DIFL/AC (9390 - 10810 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 11 CURVES : NAME 1 AC 68 2 CAL 68 3 CHT 68 4 CILD 68 5 GR 68 6 RFOC 68 7 RILD 68 8 RILM 68 9 SP 68 10 SPD 68 11 TTEN 68 CODE SAMPLE~ UNIT BYTES 1 US/F 4 1 IN 4 1 LBF 4 1 MMHO 4 1 API 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 MV 4 1 F/MN 4 1 LBF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH AC CAL GR RFOC RILD SPD TTEN 10810.000 -999.2500 -999.2500 10760.000 0.0000000E+00 31.63220 -999.2500 -999.2500 -999.2500 75.02428 8.428656 4485.684 -999.2500 -999.2500 6.000000 7.874264 CHT RILM -999.2500 -999.2500 651.1584 8.266850 CILD SP -999.2500 -999.2500 126.9960 51.53326 10710.000 125.0295 32.99670 10660.000 48.69141 33°59630 10610.000 63.34714 33.99661 10560.000 51.85040 33.99661 10510.000 69.10800 33.99661 10460.000 45.44000 33°99661 10410.000 71.00000 33.99661 10360.000 100.6754 33.43860 10310.000 48.05643 33.99661 10260.000 49.19901 33.99661 ,10210.000 73.45923 .33.99661 10160.000 39.24342 34.55460 10110.000 39.80690 38.96040 10060.000 43.22511 49.99501 10010.000 65.10451 49.99501 76.12891 10.49467 3875.058 83.53513 9.771626 3876.161 75.52573 14.58012 3853.451 83.24191 16.09933 3820.881 91.13220 10.80859 3813.553 83.12527 22.89857 3790.652 83.62007 16.19382 3765.251 79.91373 10.35604 3~748.015 69.12476 10.16820 3748.219 79.59149 7.375498 3737.447 86.02295 8..602135 3724.250 63.57799 8.692745 3688.468 72.87866 6.506389 3705.781 78.59898 5.417401 3713.641 106.2883 8.069862 3697.486 -59.36220 8.102716 -54.75481 7.600420 -68.32210 9.850695 -98.61801 13.62486 -109.3529 9.958345 -125.7596 20.53160 -115.2532 14.93678 -54.71541 7.895132 -49.90930 12.26689 -132.7281 5.687426 -59.98219 7.297019 -93.97641 7.499882 -75.05072 7.783193 -93.74661 5.257078 -62.21101 4,480276 228.3383 8.253862 230.5324 7.634392 217.7042 10.49473 235.9666 14.03627 243.7953 10.14030 247.5379 18.84659 237.5417 13.54490 252.3909 8.156052 242.6765 13.32722 279.1094 6.009519 283.6980 7.647107 261.3232 7.770766 289.3503 7.241143 282.4365 5.572783 289.4397 4.768960 123.4154 92.23695 131.5717 19.23692 101.5157 31.34586 73.39525 4.534754 100.4183 23.04370 48.70540 -1.359531 66.94882 3.807951 126.6603 51.59264 81.52028 40.95102 175.8265 64.20001 137.0423 55.31801 133.3354 68.29115 128.4820 69.84175 190.2197 62.80762 223.2005 104.2535 9960.000 54.39526 49.99501 9910.000 60.75714 49.99501 9860.000 49.07637 49.99501 81.08961 4.341742 3678.877 85.27512 3.254239 3654.279 79.98331 5.811335 3637.706 9810.000 75.65312 47.87744 4.248480 49.99501 3625.271 9760.000 81.25040 35.77628 6.461473 49.99501 .3599.914 9710.000 90.65102 44.05629 5.958008 50.99490 3618.277 9660.000 83.65250 50.70923 5.651104 50.99490 3592.315 9610.000 84.24734 59.66023 4.831981 50.99490 3578.848 9560.000 102.0031 30.16496 12.87942 50.99490 3531.075 9510.000 87.60754 47.16846 5.187846 50.99490 3523.240 9460.000 82.05107 70.45683 5.368846 50.99490 3496.000 9410.000 50.00000 0.0000000E+00 0.2000000 0.0000000E+00 2000.000 -101.1588 3.771889 -83.92351 2.693497 -74.87561 5.696519 -59.82991 2.001911 -64.98091 7.617040 -80.63451 5.265536 -86.21809 '5.631027 -85.98071 4.339974 -58.47691 8.656391 -61.31979 4.976387 -63.72940 4.892671 -63.17940 0.2000000 314.4385 3.961110 303.0662 3.071190 285.2051 6.342393 290.9807 2.353870 296.6311 8.774292 324.5471 4.894147 310.5049 5.718085 298.4763 4.603857 282.2561 8.633677 282.3064 5.268934 277.5447 5.096880 0.0000000E+00 0.2000000 265.1191 83. 19170 371.2646 87.11969 175.5458 76.58069 499.5227 77.40045 131.2846 71.02724 189.9142 109.2113 177.5875 95.72343 230.4161 102.9020 115.5216 104.4840 200.9490 119.5710 204.3874 125.7603 0.0000000E+00 0.0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 136 10810.00 ENDING TAPE DEPTH = 9390.00 **** REEL HEADER **** LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC~ : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * FILE 7 = 4-ARM CALIPER LOG (9290 - 10820 FT.) * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 13 CURVES : NA/~E CODE SAMPLE# UNIT BYTES 1 C 68 1 IN 4 2 C003 68 1 IN 4 3 CAL 68 1 IN 4 4 CCL 68 1 DIM 4 5 CCL1 68 1 DIM 4 6 CHT 68 1 LBF 4 7 DEV 68 1 DEG 4 8 DTEM 68 1 DEGF 4 9 GR 68 1 API 4 10 RB 68 1 DEG 4 11 SPD 68 1 F/MN 4 12 TEMP 68 1 DEGF 4 13 TTEN 68 1 LBF 4 * DATA RECORD DEPTH CCL1 RB 10820.000 -999.2500 -999.2500 10770.000 0.3680000 -1.672361 10720.000 0.3680000 -1.684918 10670.000 0.3680000 -1.684702 10620.000 0.3680000 -1.687557 10570.000 0.3680000 -1.672311 10520.000 0. 3680000 -1. 682813- 10470.000 0.3680000 -1.674227 10420.000 0.3680000 -1.688792 10370.000 0.3680000 -1.675476 10320.000 0.3680000 -1.674004 10270.000 0.3680000 -1.682736 (TYPE# C CHT SPD -999.2500 -999.2500 -999.2500 6.471094 383.4019 40.88670 6.464979 342.9600 40.99591 6.396794 323.2036 40.99591 6.403660 288.9434 40.99591 9.059067 379.5393 41.23170 6.567769 326.5432 41.75999 6.384419 318.2898 40.99591 7.335403 319.6282 41.65080 9.884321 364.6487 40.99591 9.956890 399.5664 40.99591 9.959238 394.7959 40.99591 O) 1014 BYTES * C003 DEV TEMP -999.2500 -999.2500 -999.2500 5.641294 363.8516 0.0000000E+00 6.615441 357.5398 0.0000000E+00 6.182446 356.6189 0.0000000E+00 6. 180704 361.9187 0. 0000009E+00 6.720902 360.2959 ~0.0000000E+00 6.501185 362.5815 0.0000000E+00 6.328576 361.8577 0.0000000E+00 6.728122 362.1167 0.0000000E+00 7.397141 361.8511 0.0000000E+00 7.856474 361.9348 0.0000000E+00 7.490149 361.1138 0.0000000E+00 CAL DTEM TTEN -999.2500 -999.2500 -999.2500 6.056194 0.0000000E+00 3732.761 6.540211 0.0000000E+00 3668.422 6.289620 0.0000000E+00 3603.090 6.292182 0.0000000E+00 3552.098 7.889985 0.0000000E+00 3639.038 6.534477 0.0000000E+00 3552.706 6.356498 0.0000000E+00 3496.143 7.031763 0.0000000E+00 3478.116 8.640732 0.0000000E+00 3505.217 8.906685 0.0000000E+00 3530.145 8.724693 0.0000000E+00 3520.134 CCL GR -999.2500 -999.2500 0.3680000 84.39528 0.3680000 110.5069 0.3680000 50.83289 0.3680000 60.98978 0.3680000 90.82886 0.3680000 66.02319 0.3680000 54.60854 0.3680000 49.93343 0.3680000 95.66582 0.3680000 42.47885 0.3680000 43.12070 10220.000 7.785154 7.665692 7.725424 0.3680000 0.3680000 -1.675476 10170.000 0.3680000 -1.683103 10120.000 0.3680000 -1.689149 10070.000 0.3680000 -1.689944 10020.000 0.3680000 -1.696740 9970.000 0.3680000 -1.679894 9920.000 0.3680000 '-1.684766 9870.000 0.3680000 -1.694609 9820.000 0.3680000 -1.676551 9770.000 0.3680000 -1.672671 9720.000 0.3680000 -1.689979 9670.000 0.3680000 -1.669804 9620.000 0.3680000 -1.692924 9570.000 0.3680000 -1.686881 9520.000 0.3680000 -1.667784 346.4182 41.88660 6.924109 407.0847 41.99580 7.258791 423.9578 41.99580 6.632891 423.3784 41.99580 6.887382 433.3140 41.99580 6.678891 431.1956 41.99580 6.322062 434.9275 41.99580 438.4448 42. 10500 6.401290 409.5425 41.99580 10.02412 410.9534 41.99580 7.088381 455.1875 41.99580 7.373583 436.0730 42.99571 6.850945 420.7246 42.99571 10.17079 421.0366 42.99571 9.188379 458.6377 42.99571 361.0698 0.0000000E+00 9.519728 359.8330 0.0000000E+00 9.915699 361.4148 0.0000000E+00 9.901817 360.1360 0.0000000E+00 8.568474 359.2441 0.0000000E+00 9.345325 360.4041 0.0000000E+00 8.904903 361.0894 0.0000000E+00 10.53765 360.8896 0.0000000E+00 10.74819 362.8325 O.0000000E+00 6.588441 360.0647 0.0000000E+00 9.737801 360.6155 O.O000000E+O0 8.881903 367.1897 0.0000000E+00 7.932169 362.5576 0.0000000E+00 6.489675 361.4028 0.0000000E+00 6.913070 353.9351 0.0000000E+00 0.0000000E+00 3411.025 8.221916 0.0000000E+00 3486.883 8.587242 0.0000000E+00 3475.178 8.267357 0.0000000E+00 3462.460 7.727928 0.0000000E+00 3453.466 8.012108 0.0000000E+00 3445.966 7.613483 0.0000000E+00 3431.750 8.512001 0.0000000E+00 3414.952 8.574738 0.0000000E+00 3362.592 8.306282 0.0000000E+00 3329.823 8.413094 0.0000000E+00 3350.502 8.127747 0.0000000E+00 3313.876 7.391557 0.0000000E+00 3302.079 8.330231 0.0000000E+00 3278.456 8.050728 0.0000000E+00 3326.617 61.96365 0.3680000 46.39131 0.3680000 42.92068 0.3680000 54.11806 0.3680000 44.65009 0.3680000 36.91016 0.3680000 44.38435 0.3680000 69.98428 0.3680000 61.74782 0.3680000 70.79071 0.3680000 52.76938 0.3680000 45.67203 0.3680000 53.93909 0.3680000 63.12016 0.3680000 42.24094 9470.000 9.651745 7.162016 8.406883 0.3680000 0,3680000 407,2629 -1,660979 42,99571 9420,000 7,811335 0,3680000 437,1008 -1,693915 42,99571 9370,000 9,470224 0,3680000 426,3411 .-1,664131 42,99571 9320,000 2,000000 0,3680000 0,0000000E+00 0,0000000E+00 0,0000000E+00 366,1819 0,0000000E+00 9,553598 361,3569 0,0000000E+00 9,796103 360,9724 0,0000000E+00 2,000000 0,0000000E+00 0,0000000E+00 0,0000000E+00 3230,699 8,682465 0,0000000E+00 3236,444 9,633163 0,0000000E+00 3217,927 4,000000 0,0000000E+00 2000,000 76,87831 0,3680000 50,63565 0,3680000 42.35031 0,3680000 0,0000000E+00 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 171 10820,00 ENDING TAPE DEPTH = 9290,00 **** REEL HEADER **** LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 4 LIS ,001 **** FILE HEADER **** 1024 CN~ WN FN COUN STAT : ARCO ALASKA INC, : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * FILE 2 = REPEAT PASS: SZDL/CN/GR (10250 - 10550 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 20 CURVES: NAME 1 CAL 2 CHT 3 CN 4 CR2 5 DEV 6 GR 7 HRD1 8 HRD2 9 LSN 10 PE 11 PORZ 12 RB 13 SFT2 14 SHR 15 SPD 16 SSD 17 SSN 18 TTEN 19 ZCOR 20 ZDEN CODE SAMPLE# UNIT BYTES 68 1 IN 4 68 1 LBF 4 68 1 % 4 68 1 IN 4 68 1 DEG 4 68 1 API 4 68 1 CPS 4 68 1 CPS 4 68 1 CPS 4 68 1 BARN 4 68 1 % 4 68 1-- DEG 4 68 1 DIM 4 68 1 DIM 4 68 1 F/MN 4 68 1 CPS 4 68 1 CPS 4 68 1 LBF 4 68 1 G/C3 4 68 1· G/C3 4 * DATA RECORD DEPTH DEV PE SPD ZDEN 10550.000 -999.2500 -999.2500 -999.2500 -999.2500 10500.000 350.2529 5.615920 31.88760 2.404513 10450.000 350.1663 (TYPE# CAL GR PORZ SSD -999.2500 -999.2500 -999.2500 -999.2500 6.697536 82.76190 14.87796 18338.25 6'.305105 53.29520 0) 1014 BYTES * -- CHT HRD1 RB SSN -999.2500 -999.2500 -999.2500 -999.2500 264.7363 947.7058 10.61232 284.3979 232.3041 930.8350 CN HRD2 SFT2 TTEN -999.2500 -999.2500 -999.2500 -999.2500 18.19295 1239.552 699.0520 4022.098 12.52434 1201.833 CR2 LSN SHR ZCOR -999.2500 -999.2500 -999.2500 -999.2500 3.585849 118.8049 0.3776210 0.1249505 3.585849 191.6798 2.747806 16.64688 31.99680 17297.98 2.375326 10.97063 371.4949 762.3101 3978.124 0.5471269 0.2918547E-01 10400.000 7.029661 164.3286 16.50845 3.585849 350.4253 64.36168 1039.885 1285.691 122.8408 4.668973 20.14536 10.65676 768.5273 0.4213611 31.99680 17347.05 277.4800 3874.848 -0.4083131E-02 2.317601 10350.000 7.854302 214.6223 23.33153 3.585849 351.0847 89.62837 836.5752 1088.072 89.32901 4.722545 9.280758 9.804199 649.8647 0.4186922 31.88760 17235.27 250.3703 3930.102 0.7812089E-01 2.496867 10300.000 9.375393 221.6083 24.87294 3.585849 351.4272 53.79373 928.4966 1204.144 70.84489 4.302454 14.87253 9.634050 718.3604 0.4392911 31.99680 17360.02 207.1415 3920.727 0.3630757E-01 2.404603 10250.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2-500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 51 10550.00 ENDING TAPE DEPTH = 10250.00 **** REEL HEADER **** LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 5 LIS .001 FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 43B-8 FN : SOLDOTNA CREEK UNIT COUN : KENAI STAT : ALASKA * COMMENT RECORD * FILE 6 = REPEAT PASS: DIFL/AC' (9330 - 9700 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 11 CURVES : NAME 1 AC 68 2 CAL 68 3 CHT 68 4 CILD 68 5 .GR 68 6 RFOC 68 7 RILD 68 8 RILM 68 9 SP 68 10 SPD 68 11 TTEN 68 CODE SAMPLE# UNIT BYTES 1 US/F 4 1 IN 4 1 LBF 4 1 MMHO 4 1 API 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 MV 4 1 F/MN 4 1 LBF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * DEPTH AC CAL GR RFOC RILD SPD TTEN 9700.000 -999.2500 -999.2500 9650.000 0.0000000E+00 33.99661 9600.000 65.34157 35.00241 -999.2500 -999.2500 -999.2500 82~73930 '4.769980 3561.705 88.47646 4.133260 3528.578 -999.2500 -999.2500 6.000000 3.799002 -63.52701 3.552958 CHT RILM -999.2500 -999.2.500 274.5564 4.161933 289.6987 3.673371 CILD SP -999.2500 -999.2500 263.2271 106.8405 281.4556 113.0543 9550.000 44.27040 34.59621 9500.000 57.27382 34.99651 9450.000 61.82396 34.99651 9400.000 42.67519 34.99651 9350.000 0.0000000E+00 0.0000000E+00 77.84129 5.151232 3506.142 85.08464 4.043561 3488.762 78.10558 4.980533 3453.410 84.05974 1.762216 3455.488 50.00000 0.2000000 2000.000 -55.20230 4.753706 -67.54071 3.975063 -78.15219 5.138007 -56.52170 2.412812 -51.40671 0.2000000 269.5798 5.060194 284.1648 4.189984 269.9822 4.864809 280.1628 1.190348 0.0000000E+00 0.2000000 210.3622 110.5170 251.5683 124.7493 194.6280 133.4961 414.4541 157.4915 0.0000000E+00 -20.00000 TOTAL DATA RECORDS : .STARTING TAPE DEPTH = **** FILE TRAILER **** 36 9700.00 ENDING TAPE DEPTH = 9330.00 **** REEL HEADER LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 6 LIS .001 **** FILE HEADER **** 1024 CN : ARCO ALASKA INC. WN : SCU 43B-8 FN : SOLDOTNA CREEK UNIT COUN : KENAI STAT : ALASKA * COMMENT RECORD * FILE 3 = CN-CSG LOG: (5350 - 6100 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CN 68 1 % 4 2 GR 68 .1 API 4 3 LSN 68 1 CPS 4 4 SSN 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1006 BYTES * DEPTH CN GR LSN SSN 6100.000 ~999.2500 -999.2500 -999.2500 -999.2500 6050.000 32.80374 40.74539 42.15401 148.2818 6000.000 61.24516 40.21419 22.93390 113.7087 5950.000 36.29337 35.22876 41.59111 156.1655 5900.000 36.47600 31.48032 32.14130 121.0664 5850.000 26.21877 28.88213 46.72050 141.4953 5800.000 41.65811 39.59975 29.18790 119.1791 5750.000 134.0012 24.22961 15.40790 99.67381 5700.000 38.20053 36.79918 36.98621 143.3824 5650.000 46.30261 48.59828 32.42210 140.4650 5600.000 31.46127 43.02486 52.77080 180.5736 5550.000 70.49005 49.62196 23.57100 123.7798 5500.000 56.09058 45.40382 27.10460 129.2227 5450.000 103.2929 17.51761 17.28250 103.5686 5400.000 44.92361 41.91888 32.94231 140.3873 5350.000 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 31 6100.00 ENDING TAPE DEPTH = 5350.00 **** REEL HEADER **** LIS 91/ 2/19 AWS 01 **** TAPE HEADER **** LIS 91/ 2/19 01 FILE # 7 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INC. : SCU 43B-8 : SOLDOTNA CREEK UNIT : KENAI : ALASKA * COMMENT RECORD * FILE 4 = REPEAT CN/CSG LOG: (5320 - 5560 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 4 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CN 68 1 % 4 2 GR 68 1 API 4 3 LSN 68 1 CPS 4 4 SSN 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1006 BYTES * DEPTH CN GR LSN SSN 5560.000 -999.2500 -999.2500 -999.2500 -999.2500 5510.000 47.56479 55.39450 31.87241 140.0763 5460.000 42.15672 54.88712 34.13062 140.3258 5410.000 65.09395 53.66734 26.88991 136.7863 5360.000 37.17137 45.43523 41.40460 157.8170 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 10 5560.00 ENDING TAPE DEPTH = 5320.00 **** TAPE TRAILER **** LIS 91/ 2/19 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 569 **** REEL TRAILER **** LIS 91/ 2/19 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 570 TOTAL RECORDS IN THIS PHYSICAL REEL:- 570 End of execution: Tue 19 FEB 91 9:lla Elapsed execution time = 1 minute , 11.2 seconds. SYSTEM RETURN CODE = 0